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Home My WebLink About184-065 JVED • 0 iUN08ZOlb STATE OF ALASKA ,��. ALASKA OIL AND GAS CONSERVATION COMMISSION , 4 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas CI SPLUG❑ Other ❑ Abandoned 2 ' Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service 0 ' Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 5/9/2016 • 184-065/316-081 • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 5/25/1984 50-103-20029-00 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 657'FSL,53'FEL,Sec 14,T11N, R8E, UM 5/31/1984 KRU 2A-07 J Top of Productive Interval: 9.Ref Elevations: KB:YP 123.21 17. Field/Pool(s): 1313'FSL, 1278'FWL,Sec 14,.T11N, R8E, UM GL:82 BF: Kupurak River Field/Kuparuk Oil Pool. Total Depth: 10. Plug Back Depth MDITVD: 18. Property Designation: 1369'FSL,994'FWL,Sec 14,T11N,R8E,UM Surface " ADL 25570 r 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498341 y- 5960078 Zone- 4 7956/6227 2668 TPI: x- 494391 y- 5960738 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 494108 y- 5960792 Zone- 4 1932/1917 1500/1499 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary n/a SCANNED SEP 2 9 2010 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 41 110 41 110 24 175 sx CS II 9 5/8 36 J-55 41 2695 41 2545 12.25 850 sx PF E,250 sx PF C 7 26 J-55 255 7931 255 6209 8.5 275 sx Class G,250 sx PF C 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 7634 7373/5800 Perforations Plugged: 7625/5984 7530-7600 MD 5914-5965 TVD 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. 7630-7642 MD 5987-5996 TVD Was hydraulic fracturing used during completion? Yes❑ No 2 7652-7688 MD 6003-6024 TVD Per 20 AAC 25.283(i)(2)attach electronic and printed information 1000-1010 MD 1000-1010 TVD ACiRNOnKe1) DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED surface to 1010'RKB,in 49.5 bbls AS1 Cement pumped through DATE 7"&7"x9 5/8 cement retainer@293'RKB,5 bbls pumped annulus above VERIFIED 6870-1538'in 3 1/2 tubing 184 bbls 15.8 ppg cement pumped down &3 1/2x7 annulus tubing and up IA l.-- Perfs to 7209', in 7 and 3 1/2 26.4 bbls 15.8 ppg cement pumped into tubing perforations and tubing 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A 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(torr): Press. 24-Hour Rate O r Form 10-407 Revisec�),1/201 IC VII-�/3I r / CONTINUED ON PAGE 2 RBDMS (/v JUN 0 8 10jbmit ORIGINIAL only • • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No E If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1500 1499 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263-1431 Email: Jill.Simekncop.com Printed Name: G.L.Alvord Title: Alaska Drilling Manager Signature: r 644-- Phone: 265-6120 Date: G'fZ ft"( INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • EVENT_DATE EVENT TEXT 2/4/2016 Prep for P&A Initial T/I/0=0/0/0 Opened needle valves to check for pressure which had 0 psi. Cycled Master and Swab valves checking for cement,which moved freely(IA and OA were covered in ice in the cellar box). Well house, cellar grating, and iron cross beam well house supports will need to be removed for excavation. Final T/I/O=0/0/0 3/3/2016 (MISC) :T/I/0=0/0/0. Cement is 81"from top of tree cap(gate valve) on tubing. Tubing has 34" of fluid on top of cement. Cement is 34" below THA and MV flange. Wrench nut size for flange between THA and MV is 1 13/16". Flange has eight 1 1/8" bolts. 3 1/8"flange is needed. 3/9/2016 Initial T/I/O=0/0/0 Chipped 3 Ft. of ice to clear work area to remove jewelry. Removed jewelry and installed plugs. Removed tree cap and flange assembly and removed 4 gal of fluid from tubing with air hog to TOC. Re-installed tree cap and flange assembly. Final T/I/O/=0/0/0 3/13/2016 (P&A Prep) Initial T/I/O=0/0/0 Verified 0 pressure. Removed flange from the top of the Swab valve. Removed Swab and Master valves. Installed flange to top of tubing hanger. Removed Well House from well and moved to the EOP. Final T/I/O=0/0/0 5/1/2016 P&A Rigged down ground thaw unit. Initially vac'ed out 5 bbl of water from excavation area and continued to periodically vac water to a total of 45 bbl of water. Verified 0 psi on wellhead. R&P Excavation crew then began to excavate well 2A-07 for P&A. 5/3/2016 P&A R&P excavated to 17 Ft. and laid 1 Ft. of gravel in the bottom of the excavation. Set sump. Vac'ed out 215 bbl of water from excavation. Inflow rate was 50-60 bbl of water per hour. 5/4/2016 Notified AOGCC for the opportuntiy to inspect the casing cut prior to any cement top off (if it is needed). 5/4/2016 P&A Initially removed 200 BBLS of water upon arrival. Water level rose approx 2.5'to 3' overnight. Continued removing water throughout the day. Set shoring box and began digging egress. Stairs were set into place once the egress was finished.Vac'd out a total of 285 BBLS total. • • 5/5/2016 Notified AOGCC for the opportuntiy to inspect top of cement and weld marker plate. AGOCC Johnnie Hill replied that an inspector would be there. 5/5/2016 P&A Pumped 40 bbl of water from excavation. Continued periodically vac'ing water from the excavation for a total volume of 100 bbls. GBR welder(Mike Ayers) cut window into conductor. Conductor/OC void was clear. Welded Weld-O-Let to OC Drilled into Weld-O-Let/Valve assembly to verify 0 pressure. Cut window into OC. Chipped cement from well. Finished cutting remaining casings and removed the conductor and OC with a crane. Notified the DTH to come and NORM test before removing from pad. Cut off well head 4 Ft. below tundra level. TOC in the Conductor/OC void was 58 ft. 5/6/2016 P&A Initially vac'd out 40 BBLS upon arrival.Vac'd out 26' of 58' conductor void to TOC. Schlumberger spotted up and set up their cement set up. Pumped 14BBLS of type AS1 15.7 PPG cement into the conductor. Receiving 15 PPG cement returns at the top of conductor by the end of the pump job. Leaving a manned vac truck on site till cement has set and hardned to prevent excavation water from entering conductor. 5/7/2016 P&A Initial morning inspected cement in conductor that was poured Friday 5/6/16. Cement was not cured. Will return Sunday 5/8/16 to re-check cement and possible state inspection. 5/8/2016 P&A AOGCC State Inspector Bob Noble witnessed original cement in conductor from 5/6/2016. Requested the conductor be topped off with cement. Poured 10 gallons of Portland Type 1 cement into the conductor. Mr Noble gave approval to GBR welder Mike Ayers to weld marker plate on after witnessing the cement top off job. Removed sump, stairs and shoring box from excavation after welding marker plate on and delivered them to 2T pad. Road and Pads filled in excavation hole. 5/9/2016 Notified AOGCC for the opportuntiy to inspect final back fill.AOGCC Brian Bixby replied that an inspector would witness. • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2A-07 Plug and Abandonment May 11, 2016 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2A-07, commencing operations on February 4, 2016 and completing the Plug and Abandonment on May 9, 2016. ✓ The tree and wellhead were removed at 4 ft. below tundra level. Surface casing top of cement was determined to be at surface while conductor x surface casing annulus top of cement was 58ft. Conductor x surface casing annulus was topped off with cement. The State Inspector determined that cement was in good condition and the well was capped and excavation backfilled. Pictures below show cement to surface in all annuli, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. } Yf �' r''4',,,,,,,,,', § t w ,,,,„...,,,,,, tt / b+; litt , . '< ,• % , i ,,,,.,,,,„„:,,,,,,, ,, ,, sy- 4,.,._,i ,,..,...„“,..,,.,. . :;„<et.,,, E ; ,i.. .: x ,° r c .a 2€}1 isegs ah _*otog ' -''..',7:i.:, �max. • • „,,.,,,,,,,„„,; -,',1,-,-,-,',/rrc� ,�i ,�� ' t� aria ?. • ri//'/' � - g„ ;,'' a F i �� tom r - k D/-4:-,1(,'%,,,-'A',-/-,-,-'',,-,, dam ., -,,,f,.,', .'-.1-1,,,,-,.‘,,. ,,,,..,..,,: A ,:,-„,:::'. '' ‘',;,..2,4„-. ,, .,,s' 'Ai ''°' I-0 -.;--,s ' ' !: -,,,4,.. . .,:',:,-,„0,;1,-;„-,.--f:,,,,,,-,-,5, Lk.) r ,,Zi..'t*Mif*It'l ' ,,' , ;4., ,''. ,'..,',!1 yr ''anf rid ` t a z: ,v. ''�;.. BL.r E 3 . lia.„III M aeb _ 0�1., yam . Q.':... a �,a,,....� ,q,..e...,. a ' -• " , r'.�� . KUP 2A-07 ConocoPhillips - Well Attribu Max Angl D TD ' Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(RKB) Act Btm(ftKB) AIdSi4d,.Inc. Cxmcod'h II ps r 501032002900 KUPARUK RIVER UNIT INJ 48.90 6,100.00 7,956.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2A-07,6/7/201611,4340 AM SSSV:LOCKED OUT Last WO. 41.29 6/2/1984 Var4cal nc/mOooc(aofuak� Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ............. .............. ... ..................___.. _._ _..___.Last Tag:CMT 1,538.0 11/16/2011 Rev Reason:P&A WELL pproven 5/19/2016 s ngngs C ng D cription OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTORs 16 15.060 51.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;51.0-110.0 _ SURFACE 95/8 8.921 51.0 2,696.0 2,545.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 265.9 7,925.4 6,204.4 26.00 J-55 BTCMOD RETAINER;2930 li 9 Tubing Strings - - Tubing Description String Me...ID(in) Top(ftKB) Set Depth(it..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.992 1,141.0 7,633.9 5,989.9 9.30 J-55 EUE-ABMOD IPERF,1,000.0-1,0100- Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) TBG CUT;1,141.0 a - a r 1,931.7 1,916.6 21.59 SAFETY VLV BAKER FVL SSSV-LOCKED OUT 8/9/88 2.813 CMT PLUG,36.5 5,789.9 43.62 PBR BAKER PBR 3.000 7,373.3 5,799.8 43.59 PACKER BAKER FHL PACKER 3.000 5,906.4 42.97 BLAST JT 2992 nr 7,624.5 5,983.1 42.97 LOCATOR BAKER LOCATOR w/2'SEALS 3.000 5,983.5 42.97 PACKER BAKER FB-1 PACKER 3.000 7,631.7 5,988.3 42.97 NIPPLE CAMCO D NIPPLE NO GO 2.750 ' 7,633.1 5,989.3 42.97 SOS BAKER SOS-ELMD TTL @ 7617'ON SWS IPROF 3.000 4/29/2003 Other in Hole(Wireline'retrievable plugs,valves,pumps,fish,etc.) SURFACE,51.0-2,696.0 I Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Corn Run Date ID(in) PUNCHES;6,6700 ii 36.5 36.5 0.00 CMT PLUG PUMPED 49.5 BBLS CEMENT THRU RETAINER; 11/20/2011 0.000 PUMPED 5 BBLS ABOVE RETAINER OVER 3 CMT PLUG;6,8700 DAYS 293.0 293.0 0.00 RETAINER 7"CEMENT RETAINER 11/19/2011 FISH;6,942.0 1,141.0 1,141.0 0.00 TBG CUT 3.5 TUBING STUB 11/17/2011 2.992 6,870.0 5,441.3 45.61 PUNCHES TUBING PUNCHES:2"x10'BIG HOLE CHARGES, 11/14/2011 2.992 6 SPF,60 DEG PHASE 6,870.0 5,441.3 45.61'CMT PLUG PUMPED 184 BBLS CLASS'G'CEMENT 11/15/2011 0.000 - 6,942.0 5,491.7 45.41 FISH 64"TWO PRONG SLICKLINE WIRE GRAB 11/11/2011 0.000 11. 7,209.0 5,681.2 44.09 CMT PLUG 2 CEMENT OFF TUBING-PUMPED TTL 11.4 BBLS 6/28/2009 0.000 CEMENT,3.7 BBLS PLUG(425') 11. 7,300.0 5,746.7 43.75 CMT PLUG CEMENT OFF TUBING-PUMPED TTL 15 BBLS 6/21/2009 0.000 CEMENT,3 BBL PLUG(333') 7,405.0 5,822.7 43.50 PATCH 21'Menlo Patch 1/26/1996 2.313 7,412.0 5,827.8 43.46 NIPPLE Patch Includes AVA BPL Ported Nipple;Set 3'feet 1/26/1996 2.750 below Top of Mandrel NIPPLE',7,412.0 7,412.0 5,827.8 43.46 SLEEVE AVA CII Sleeve;Set 3'below top of Mandrel 1/28/1996 1.875 SLEEVE;7,412.0 PATCH,7,4050 ®®®®22'Merla Patch Set ®® IV 7,632.0 5,988.5 42.97 NIPPLE AVA Nipple Reducer w/Camco"D"profile 1/24/2000 1.813 CMT PLUG 2;7,209.0 REDUCER • CMT PLUG;7300.0 7,787.0 6,102.2 42.46 FISH 1'BullPlug Lost on Run#2 6/10/1988 Perforations&Slots PATCH;7,4740 g., Shot I Dans Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(RKB) (ftKB) (RKB) Zone Date R) Type Com 1,000.0 1,010.0 1,000.0 1,010.0 11/16/2011 6.0 IPERF 7"CASING:2.5"X10' GUN,60 DEG PHASE, 4 BH CHARGES (PERF;7530 U-7,6000-- S iir _ 7,530.0 7,600.0 5,913.9 5,965.1 C-4,UNIT B, 7/9/1984 12.0 IPERF 5 1/2"Csg Gun;120 deg ry + 2A-07 ph ti _::'.:e, 7,630.0 7,642.0 5,987.1 5,995.8 A-4,2A-07 7/9/1984 4.0 IPERF 4"Csg Gun;90 deg ph j a 7,632.0 7,640.0 5,988.5 5,994.4'A-4,2A-07 6/10/1988 4.0 RPERF k;. s 7,652.0 7,688.0 6,003.2 6,029.5 A-3,2A-07 7/9/1984 4.0 IPERF 4"Csg Gun;90 deg ph - y <<_ ;. 7,652.0 7,680.0 6,003.2 6,023.7 A-3,2A-07 6/10/1988 4.0 RPERF Stimulations&Treatments - ti IMin Top Moo Btm i- Depth Depth Top(TVD) Btm(TVD) y (ftKB) (ftKB) (RKB) (RKB) Type Date Corn 0.0 0.0 0.0 0.0 Clay Acid Stim 7/31/1988 NIPPLE,7,631 7 4 1 `r_ Cement Squeezes NIPPLE REDUCER;7,fi32.0� � I. ♦ ri k T- Top(TVD) Btm(TVD) pL - Top(ftKB) Btm(ftKB) (RKB) (ftKB) Des Start Date Com SOS;7,633.1 h i 7,599.0 7,600.0 5,964.4 5,965.1 Cement 7/10/1984 IPERF;7,630.0-7,6420 Squeeze RPERF;7,632.0.7,6400 4 r 7,629.0 7,631.0 5,986.3 5,987.8 Cement 7/10/1984 wSqueeze i 0:'''' 7,631.0 7,688.0 5,987.8 6,029.5 Cement 6/21/2009 SQUEEZE PERFS W/12 BBLS CEMENT Squeeze 4 eii 7,300.0 7,633.0 5,746.7 5,989.3 Cement Plug 6/21/2009 PUMP CEMENT PLUG W/REMAINING 3 BBLS(333 RPERF,7,652.0-7,680 0 IPERF;7,652.0-7,688.0 # FT)ESTIMATED TOC:7300'RKB a 36.0 7,633.0 36.0 5,989.3 Cement Plug 6/28/2009 PUMP CEMENT PLUG W/REMAINING 3.7 BBLS (425 FT)ESTIMATED TOC:7209'RKB 7,530.0 7,652.0 5,913.9 6,003.2 Cement 6/28/2009 SQUEEZE PERFS W/7.7 BBLS CEMENT Squeeze 36.5 2,696.0 365 2,545.6 Cement Plug 11/20/201 PUMPED 49.5 BBLS CEMENT THRU RETAINER; FISH;7,787.0 1 PUMPED 5 BBLS ABOVE RETAINER PRODUCTION',265.9-7,925.4 KUP e 2A-07 ConocoPhillips 3 ID Alaska,Inc, A' ConocoPhillips ••• 2A-07,.6/7201611.43.41 AM Vertical schematic(actual) Mandrel Inserts at 11 Top(TVD) Valve Latch Port Size TRO Run _,..,,,_CONDUCTOR;J1.0-110.0 _ '. N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Oate Corn ��°• " 1 7,313.6 5,756.5 MMH FMHO 1 GAS LIFT -DMY 'BK-2 0.000 0.0 6/15/2000 2 7,412.0 5,827.8 MMH FMHO 1 INJ PATC BK-2 0.000 0.0 1/26/1996 RETAINER;293.0 I! H 3 7,481.6 5,878.5 MMH FMHO 1 INJ 'PATC BK-2 0.000 0.0 1/26/1996 H IPERF;1,000.0-1,010.0— Notes:General&Safety End Date Annotation '1 1/14/2006 NOTE:TAG w/1.25"LIB @ 11'RKB-POSSIBLE COLLAPSED TUBING TBG CUT;1,141.0 6/20/2006 NOTE:VIDEO LOG SHOWS POSSIBLE CORKSCREW TBG OR TBG DAMAGE @ 11' CMT PLUG;38.5 9/8/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 3/17/2011 NOTE:UNABLE TO PASS RESTRICTION @ 70'SLM,see WSR 3/17/2011 ",:111 11/12/2011 NOTE:TUBING PUNCHES @ 6890'8 6920'UNSUCCESSFUL 11` 11/12/2011 NOTE:TBG CUT @ 6889'UNSUCCESSFUL ar^m _ v 11/16/2011 NOTE:JET TBG CUTS @ 1480'&1475'UNSUCCESSFUL �; 11/16/2011 NOTE:TUBING CEMENT TAG WITNESSED BY AOGCC I ' 11/20/2011 NOTE:P&A-WELL CEMENTED TO SURFACE b 4/8/2016 NOTE:FINAL PBA COMPLETED 4/8/2016 d : 4/8/2016 NOTE:PLATE 4'BELOW TUNDRA LEVEL 51'RKB SURFACE;51.0-2,680— -' 4/8/2016 NOTE:REMOVED WELL HEAD&WELDED MARKER PUNCHES;6,8700 CMT PLUG;8,870.0 'O.' FISH;6,942.0 it i' NIPPLE;7,412.0 _ SLEEVE;7,412.0 PATCH;7,405.0 '.: CMT PLUG 2;7,208.0- 711: CMT PLUG;7,300.0 PATCH;7,474.0 IPERF;7,530.07,800.0 '4, i H ViELpt A. 0 x i NIPPLE;7,631.7 3< NIPPLE REDUCER;7,6320 "'-. °�R si„fit SOS;7,633.1 IPERF;7,630.0-7,642.0N''' .--.1:1 RPERF;7,632.0-7,640. ki i RPERF;7,652.07,680.0 IPERF;7,852.07,688.0 0. A FISH;7,787.0 PRODUCTION;265.9-7,925.4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (i �' �Z ,� DATE: 5/8/16 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector KRU 2A-07 Conoco Phillips Alaska PTD 184-065; Sundry 316-081 5/8/16: I traveled to Conoco Phillips Alaska's KRU and met with CPA Rep. Rodger Winter to inspect a cut off that he was in charge of on KRU 2A-07. We discussed what he had already done to the well: - On May 5th they had cut the well at 3.5 feet below tundra level. After cutting they found inside the 9 5/8" casing to be full of good hard cement. Cement was found 58 feet down in the 9-5/8" by 16" annulus. - On May 6th they pumped 14 bbls of 15.7 ppg AS1 cement to fill up the 9-5/8" by 16" casing annulus. I inspected the marker plate. It was found to have the proper company name, well name, API and PTD name on it. It was 3/8" thick and the same size as the outer most string of pipe. We looked at the well. It was found to be cut off 3.5 feet below tundra level as stated. There were two strings of pipe, 16" and 9 5/8". The work string had been removed. Good hard cement was found to be at the top of the 9 5/8" string and good hard cement was found to be about 1 foot down on the 16" string. I ask them to top it off with cement. I told them that they were free to weld the plate on and cover it up. Summary: I inspected the surface abandonment of KRU 2A-07 and found it in compliance with AOGCC requirements. Attachments: Photos (3) • `ANNE® SEP 2 32016 2016-0508 Surface Abandon KRU 2A-07 bn.docx Page 1 of 3 • Surface Abandonment— KRU 2A-07 (PTD 1840650) Photos by AOGCC Inspector B. Noble 5/8/2016 �, .. �. ►' , is . ;4 :.. a ':41t"Illt , ...3.;',3 '41 r . yf� , Cutoff;9 " d " :4 casings with cemeannt 16 .,*IL,. . : . tx ti r i s , 4. Casings topped off with cement a L V H. i ." - f ... j 4 ,3y .QFC. tf 2016-0508 Surface Abandon KRU 2A-07_bn.docx Page 2 of 3 : ' t t h # 1.lj , max:+..-. ♦ pr� k4 F s _ M4 A "' .44 t. 4 t.♦ t % • Marker plate r - — Th '- . 7t .4 t .1,77 t 2016-0508 Surface Abandon KRU 2A-07 bn.docx Page 3 of 3 of • • 0, 1//7„ ,v///%' THE STATE Alaska Oil and Gas • ��0,,;, �� ofALAsKA Conservation Commission 333 West Seventh Avenue Anchorage,e, Alaska 99501-3572 GOVERNOR BILL WALKER g *A• Main: 907.279.1433 OFALASY' ' Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek �iij Staff Well Integrity Engineer c ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A-07 Permit to Drill Number: 184-065 Sundry Number: 316-081 Dear Ms. Simek: 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, j Cathy . Foerster Chair DATED this /0 day of February, 2016. RBDMS FF. 1 1 2016 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 4 2016 • APPLICATION FOR SUNDRY APPROVALS hr's Z/€t //C 20 AAC 25.280 Annirti 1.Type of Request: Abandon Plug Perforations F Fracture Stimulate F Repair Well Ia Operations Shutdown I Suspend r.. Perforate I Other Stimulate F Pull Tubing Change Approved Program 1— Plug for Redrill " Perforate New Pool Re-enter Susp Well [ Alter Casing r Other: 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory E Development Iv 184-065 3.Address: 6.API Number: Stratigraphic Service �.. P.O. Box 100360,Anchorage,Alaska 99510 50-103-20029-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 2A-07 Will planned perforations require a spacing exception? Yes ';,— No 1. 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL 25570 • Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,956' 6,227' 0 Cement to Surface NONE Casing Length Size MD ND Burst Collapse Structural Conductor 74' 16" 110' 110' Surface 2,660' 9 5/8 2,696' 2,546' Intermediate Production 7,660' 7" 7,925' 6,204' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7530-7680 5914-6024 3.500" J-55 7,632' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL PACKER - MD=7373 TVD=5800 SAFETY VLV-BAKER FVL SSSV-LOCKED OUT 8/9/88 , MD=1932 TVD=1917 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Stratigraphic r Development Service r.i 14.Estimated Date for 3/1/2016 15.Well Status after proposed work: Commencing Operations: OIL I WINJ I WDSPL I Suspended I..... 16.Verbal Approval: Date: GAS I...... WAG i GSTOR I... SPLUG I Commission Representative: GINJ I Op Shutdown r Abandoned Iv 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jill Simek Email Jill.Simekcop.com Printed Name Jill Simek @ 263-4131 Title Staff Well Integrity Engineer CNIf 2/3/1fo Signature Phone 263-4131 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31O�1 �- Plug Integrity ❑ BOP Test El Mechanical Integrity Test I] Location Clearance Other: ,7g0Z-7 '6 ttil /rrr,r-55/j� h� t-O GGVCt--✓L-e.fv)-)- �lpN f v? t fT, 5 vim C c !ry f /d s ri p! a -LJ /o e, 4, i-i`�,-, i Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No d Subsequent Form Required: lv 40 7 gif4APPROVED BY Approved by: U COMMISSIONER RAI:SION Date: /(/� !!! ///---""' O �� Subr�t Form and Form 10-403 Revi d 11/2015 Approved application is vah t r 1tr6t oeapproval. �SD. ^�*,chmen�inDuplcat112016vn- /5/16, Afkip4 vV m5 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 1 February 2016 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon West Sak well 2A-07(PTD#: 184-065). 2A-07 was drilled in 1984 and completed as a selective Kuparuk A and C sand well. The well was pre- produced for several months and then converted to injection and used for field gas storage for several years. Commingled A/C water injection began in September 1988. In 1996,the well was converted to an A-only injector and remained A-only until injection ceased in April 2009 and the well was shut in due to subsidence-induced casing and tubing damage. A suspension of the well was completed in June 2009 when 26.4 bbls of 15.8 ppg cement was bullheaded into the well in order to obtain isolation from the reservoir. A cement plug was deemed necessary at the time because a shallow restriction at 32 ft.did not allow the setting of a mechanical isolation plug. In 2011 a rig was used to regain access to the wellbore and suspend operations were continued. A balanced cement plug was placed in the tubing and tubing x production casing annulus from approximately 6,870 ft. to 1,538 ft.KB. This was followed by cut and pull of the tubing at 1,141.0 ft.KB and the perforating of the 7 in.production casing at 1,000.0 ft.- 1,010 ft.KB. Utilizing a cement retainer set at 293.0 ft.KB,cement was pumped to fill the 7 in.and 9-5/8 in.casing strings. Cement was also squeezed into the 9-5/8 in. surface casing leak at approximately 120 ft.KB. After rig operations,the well was left suspended with cement to surface. / Due to water collecting in the well cellar,periodic fluid vacuum operations are required. It is recommended that a P&A be performed by excavating 4 feet below original ground level,removing the wellhead and cellar,and backfilling with gravel/fill to ground level. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek Well Integrity Engineer CPAI Drilling and Wells Conochips 2A-07 P&A Permit to Drill #: 184-065 The objective of the proposed 2A-07 P&A is to excavate 4 feet below original ground level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Wellhead Excavation / Final P&A: 1) Remove the Well House (if still installed). 2) Bleed off T/I/O to ensure all pressure is bled off the system. 3) Remove the dry-hole tree, in preparation for the excavation and casing cut. 4) If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5) Cut off the wellhead and all casing strings at 4 feet below original ground level. 6) Perform Top Job and verify that cement is at surface in all strings. AOGCC witness mu piioc 7) Send the casing head w/stub to materials shop. Photo document. 8) Weld '/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2A-07 PTD # 184-065 API # 50-103-20029-00 9) Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10)Obtain site clearance approval from AOGCC. RDMO. 11) Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. JS • 0 Wellbore Schematic: 1 KUP INJ 2A-07 ConocoPhillips0 On wAttrIbutos Max Angle 8 MD TD Ik4;:dt L lug: U n AFJN1 NartR n'�tda.e 5:a:4s �+. ' MT TOT Act 07m 00451 ;;r, ta4n � __. h,_ I O'CC CD, 7 9_c.O --. Comm* /42S llymp 60e Annotation End Elate /0404448 1188(W>•ORM /4-57.L'LA2p s33.46 51.nM 3350.LOCKED OUT Last WO' 4129 61111184 .sr/al x6-mM(aau3....,8080 8080 8080 Annota4on Oap0,ORM End OM Anna io., LM Mod Bp End Bit Last Tag:CMT 1.038:3 110142011. Rey Reason.WELL REVIEW asb,L+ 1,17:2012 Casing Strings 76 1 1 Care Desayh 00 re+) D(( Top 1888) Set Depth 7446) Set Depth(11/5)...soften 40 Goad? Try Thread 8080 ..`1 UCTOP 10 15.633 350 110.6 /10.0 025004-43 WELDED ��6+71'Cas+ng Desooptlon 00(in) D 1e) Top 61881 Set Depe'+1M(113) Sat 0466 10111.5..%AU.(L..Geode top T11Nad _,5...A./CONDUCTOR:34021169 SURFACE 655 1.821 355 2.;"95.0 22545.6 3003184 BIC Cases)Descep4,00 0 0 On) D/ell Top 1888) Set Topah iwe) Set Depth 11161...1MI7an 11,.,G6646 lop r read PF DDLC?ICv 7 0.275 230.8 5..25.1 5.2744 20.091-55 0701130 45740458:293.9 Tubing Strings 80 80 Tub+0O004ro p<,c- string 4/00.10:01 Top.NAE&; Set Depth M3. Ser Depth>r2O:,_.7R•1b"p Goode Top Comedies T...0,1F . _ .6F_ :''4/F 533E ¶FiOe F FD_,7 EJE-ABMOO POPE:1300.61910.0- Completion De46i16 Nomad D Top(58334 TuP evi5/61884,Top ane!') Bean Des Cd, {+n) TOG OUT 9,'410 1,3317 1,618.6 21.59 SAFETYVLV BAKER FV_SSS',:-LOCKED.;;-7:e.':3 2.813 LIa7 RA.33.97,3598 57E9.8 43E2 PER BAKER FOR 3:@03 7,373.3 5799.3 43.59 PACKER BAKER PHL PACKER 3,00 7518.0 56004 4287 BLAST IT 2.852 7.315 5.663.1 42.97 LOCATOR BAKER LOCATOR 4,2'SEALS 3.(X0 5.983.5 4297 PACKER BAKER FB-1 PACKER 3.100 4/ i". 9,v 7-631.7 S SE e? 4207 NIPPLE CARCO D NPPLE NO GO 2.750 iitk �v 7,533.^. -e._ 4297 SOS BAKER SCG,-ENID TTL a 701T ONSWSIPOF 3.049 , l 4/29;2003 •s I Oi3 Hole(Week* w se4tieoabie pkgs. Mes,pumps fish,etc,} ..mono 364-2,6541 6Odin,t Tao TiD. D DO bol • 2..... Top'6A:1.1 MOB fes Com. Run Oso ID fin) CUT 11 MPE0 Ai.•t»6 SE'{T N F T ,N= .'20201' 6.003 P,)NLee5 00700 ',. .- -I_� JMBED S 1313L O ABOVE RETAINER C ER i 116701.14-53170/: ,� ti 0Af5 ::,-2.S 203.3 3.00 RETAINER 7'CEMENTRETA33ER 11/152011 Fel,8562-, y 147.0 1-3478 0.00786 CUT 3511900004 ST/JO "1/17/2011 2.992 • �5, 0,870.0 54441.3 4581 PUNCHES T1BPO'PUFNCHES'.2'r/0BIT HOLE CHARGES.8 11/3142011 2.992 SPF,00 DEG PHASE 6,8780 5.441.9 45.81 CMT PLUG PUMPED 184 0055 CLASS'Ci CEMENT 11/10.2011 0.500 t 8542.0 5.491.7 45.41 01,104 5141903 PRONG 51830144E WIRE GRAB 11111/2011 0.000 '..11r. 7,299.0 5,0812 44,09 COOT PLUG 2 CEMENT OFF TUBING-PUMPED TTL 114 BOL TT 8282009 0.000 k® CEMENT,3.7 B8L5 PLUG(420) i. K 7,300,0 5,748.7 43 75 CMT Pt.t13 CEMENT OFF TUBING-PUMPED TTL 15 08(3 021/2909 0.(100 CEMENT,3 BBL PLUG(333') la 7,405.0 5,8223 43.50 PATCH 21'Mn4o Patch 128/1998 2.313 7,4120 5,0276 43.48 NIPPLE Paton 86udes AVA BPL Ported ipp3e:Set 3'feet 126//900 2.750 beM Top of Mandrel I 0/0:r 8/00 ;1i' 7,412.0 5,8275 43.40 SLEEVE AVA CS Sleeve:Set 3'beaav by a Mandrel 126/1990 1.876 0030/4/04/00 ,'I®I.g 7,474.0 0872.9 43.12 PATCH 22'Mwfa Patch Set 120/1508 2.375 PA 06,7;4135.9 ,I Y 7.832.0 5 9885 42.97 18008E AVA 51430e Reduac,rlCamco"D'pn3T 1,24/2000 1.813 C16503.82/2980 REDUCER Gori 1,30.3]OQ6 )°+ 7 737 0 5.'0271 42401 FMM 1'Ba>7PW9 Los'or.Run 0.2 5:16/1988 i Pe.fo496LOR6&1&x5 PAtE/I 54740 Shot De's i !1054 0, 6. 7MM1®1 86apltu) T t�A z Dae ( QC Type C4a 1.1090.9 1016.@ tA'N10 1816.6 11/702@I1 801053E 1"CAD81G:2.5"X10' LII'''‘'',"''' GUN.60 DEG PHASE. BH CHARGES P5 7,530 7-590.0 ?,!0080@ 59135 09661 C4,UNIT B. 7f9?1984 120[PERF 512 Cog Gve;120 deg A: i 24-07 58 7/30.0 7,642 0 5.5571 59555 4.4,24.137 77911404 4 0 PERF 4'Coy Gun:99 deg ph 7932.0 7,640.6 5.6865 5695.4 4.4,24-07 670/7988 44.RPERF 111 7552,0 7.568.0 61032 8,059,0 A-3.2A-07 7911561 40/PE80' 4'Cog G.-,030.003 ;110 7.502'.0 7.>6f_0 6003.2 0,62803.7 A-3.2A-07 8110/1508. 4.0 50E05 Stimatedens Treatments Ws Top YAM ERN, Tnp1 [R � 4 am% macro 4110331 MOB) 1301 Dole 80"80 L 7L 5.0 0:oy 4.. .. 1'St"499 NI F4+65:7A3t VW' k05l5 R51,7.5R,7,632;\ m.i t# Canteen Squeezes 2:::,:.. pop 1'6 B/00/) Top(MC) Bon 4888 1 16861/ 1609481 Des Sort Date Co. 3639;7.6131-___,__ 7.5990 7,0000 5.04544 5585.1 Cement 3400.0 7'19.'108/ Pf6F:71300.?.540-( yyyg ,0010'.7540.9?MM9.0 : y 7. 829.0 7,831.0 5,068.3 5.067.5 Cement Squeeze 7/1961984 7,831 0 7,0888 5,487.8 8.024.5 Cement Squeeze 6212089 SQUEEZE PERF3 W/12 88L S CEMENT pp} 7,300 0 7,833 0 5,7487 5,989 3 Cement Pup 61212005 PUMP CEMENT PLUG W;REMAWING 3 08LS(333 '0_4/1:::f 55 91 t5CC S FT)ESTIMATED TOC:73001 RK8 98.0 7,833.0 36.0 5.989.3 Gement Plug 62812908 PUMP CEMENT PLUG W/REMAININ39.?BELS /425 FT)ESTIMATED TOC 7290'RK.B 7,5300 7,652.0 5,9139 6.003.2 Cement Squeeze 628/2304 SQUEEZE PERFS 017.78115 CEMENT 30.5 2.690.0 30.0 2,5456 Content Plug 1120201 PUMPED 49.5BBLS CEMENT THOU RETAINER: 1 PUMPED 513816 ABOVE RETAINER P 105400MN;243.9'r,MSA JS • 0 r KUP INJ 2A-07 Conoco 1.-- hiiiips u$11211 Ate'-1d7.InD.. ••• 2Ad-.3.217.015 3a634 PM • 'v'• Manch el Tap{7N1) Vivre LANATypo PPR Sia TRU IP Run n,CONA}CT6R 35.1 qac • I Tap 1� {Moe{ t HO tnt�Pl Sue True -2 101 {p*0 N.15 21 .Pm 1 ? 135 5.58.5 MATH WHO 1 GAS LIFT YAY BN-2 O.OW OA E'15.'20i��=� 2 7.4120 5.82'@ MAAH FMHO 1 IN: PATC 1332 0.007 00 1.8.'18.6 H RET4464401:63.0 3 ?.4810 5.8785'MUM =MHO 1 N.. PATO NA:-2 0000 0.0 Ef38i19e? Notes:General&Wet, PERF.i.oar El.,Li0.: ``J +"�'"+"- End Lite A mtYion ki' 1.14 2000 NOTE TAD*1.251 LIB*'11'RK8-POSSIBLE COLLAPSED TU000G TBIIC T i,A<t' ' 11420 3000 tdOTE.VIDEO LOG SNOW'POSSIBLE CDR}SCREW TBG OR 713G DAMAGE�4 t' CMT P itO;_NS , i SAE"A 0 NOTE VIEW 3,00EWTIC•;0aMA 5C emetee 0 307.201, NOTE UNABLE TO PASS RESTRCTOte a 10SLM,see WSR 3 122011 4`1'11. 11012'2011 NOTE:TUS0CG PUNCHES It 0890'S 0020'U 0030CCESSFUL * '�e.e S1F12ra�11 NOTE.iHG CUT it env I.4SllCCE3SPUl 93, I' 41/11512011 NOTE.3E6 TVGCUTS r*`1403.6 1475'UotSUCCESSPUL q 'am' 1 t:'...2L+1 t NOTE'.'VBAiG CEMENT TACT WETMESSEO B'r AOGOC 4 _�"1 NOTE RSA-WELL CEMENTED TO SURFACE qua it 00*ACE#4-2,ems 0 000' PJNCNEC 6.ETGL On PUiG.6.610.' • ti "wmy Et,I EFt:_ q'P 1 • i j s�P:E;7,109 *� Ee0 E.rn. 20' ; P01011.7.0; ggpp C'PLi0 01300' 1 CAPr Pt inS:T363t 2 PATC1t1079A 1.<: li PKE,.T,6e?r¢'0 ', X11 i•y tet+ A 2. MV601:1,631.4�_. NIPPLE 000400007.6329lirS 4. 0001.6341---, ...... it MERE 1,430.0-1.64z0 RPERF1430.0.1,60001 POOP.i 632.0-1.6600-\ veeF,T65a.o-1.646.0=— Fd6N:1.747 0 13800401e05;0609-1.6210 JS STATE OF ALASKA ALEC OIL AND GAS CONSERVATION COMIRSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other Stimulate r- Alter Casing r Change Approved Program r" Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Susp Well Insp 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 184-065 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20029-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025570 KRU 2A-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7956 feet Plugs(measured) None true vertical 6227 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 7373 true vertical 0 feet (true vertical) 5800 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 1640 630 SURFACE 2660 9-5/8 2696 2546 3520 2020 PRODUCTION 7660 7 7925 6204 4980 4320 SCANNED NOV 1 2 2015 Perforation depth: Measured depth: 7530'-7680' RECEIVED True Vertical Depth: 5914'-6024' AUG 12 2015 Tubing(size,grade,MD,and TVD) 3.5, J-55, 7632 MD, 5988 TVDAOGC C Packers&SSSV(type,MD,and TVD) PACKER=BAKER FHL @ 7373 MD and 5800 TVD SSSV=BAKER FVL(LOCKED OUT)@ 1932 MD and 1917 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development r Service Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP P SPLUG r 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: NA Contact MJ Loveland/Martin Walters Email n1878conocophillips.com Printed Name Martin Walaalterrss� Title Well Integrity Supervisor jf,4 ,. Signature ,, , L �v Phone:659-7043 Date:Aug 7, 2015 VTL R/2//S �1�� RBDMSA AUG 1 4 2015 A / l Form 10-404 Revised 5/2015 Submit Original Only • • RECEIVED Nipv- ConocoPhillips AUG 1. 2 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West'7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 2A-07 (PTD 184-065) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2A-07 (PTD 184-065). 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, y(01/, -4:17. I Ir Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 2A-07 Field/Pool: KUPARUK RIVER Permit#(PTD): 184-065 Sundry 311-215 API Number: 50-103-20029-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 11/20/2011 Surface Location: 657' FSL, 53' FEL Section: 14 Township: 11N Range: 8E Nearest active pad or road: KRU DS2A Meridian: UMIAT 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 Location cleanup needed: None Pits condition: NA Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None 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 Cellar description, condition, fluids: Water filled Rat Hole: NA Wellhouse or protective barriers: Wellhouse Good Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 Annulus pressures: Underwater Wellhead Photos taken (#and description): 2 of wellhouse, wellhead, and cellar Work Required: Vac cellar. Elevate gauges above wellhouse floor level Operator Rep (name and signature): Martin Walters "nhfA!I% /04/7 ),* AOGCC Inspector: Johnnie Hill Other Observers: Will Lomer Inspection Date: 8/7/2015 AOGCC Notice Date: 8/3/2015 Time of arrival: 10:25 AM Time of Departure: 10:35 AM Site access method: Passenger truck v. ,01„ KUP I 2A-07 ConocoPhiHHips " 7 rWelI Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) Alaska.Inc. 501032002900 KUPARUK RIVER UNIT INJ 48.90 6,100.00 7,956.0 Cor wcoPtuleps y., Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date . Well Cont¢-2A67,1/17rz0121:3546 PM SSSV:LOCKED OUT Last WO: 41.29 6/2/1984 Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:CMT1,538.0 11/16/2011 Rev Reason:WELL REVIEW osborl 1/17/2012 Clay Acid Sum - -..___----- _-- - Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...'String... String Top Thrd CONDUCTOR 16 15.060 36.0 110.0 110.0 62.50 H-40 WELDED '... Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 36.5 2,696.0 2,545.6 36.00 J-55 BTC CONDUCTOR, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 36110 PRODUCTION 7 6.276 265.9 7,925.4 6,204.4 26.00 J-55 BTCMOD Tubing Strings RETAINER, Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd 293 1 TUBING 31/2 2.992 1,141.0 7,633.9 5,990.2 9.30 J-55 EUE-ABMOD IPERF, - Completion Completion Details 1,000-1,010 - - Top Depth (ND) Top Incl Nomi... TBG CUT, Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 1,141 I 1,931.7 1,916.5 21.59 SAFETY VLV BAKER FVL SSSV-LOCKED OUT 8/9/88 2.813 CMT PLUG,37 7,359.6 5,790.0 43.76 PBR BAKER PBR 3.000 7,373.3 5,799.8 43.68 PACKER BAKER FHL PACKER 3.000 SAFETY VLV, _. 1,932 7,519.8 5,906.4 42.97 BLAST JT 2.992 1":'. 7,624.5 5,983.5 43.42 LOCATOR BAKER LOCATOR w/2'SEALS 3.000 7,625.1 5,983.9 43.41 PACKER BAKER FB-1 PACKER 3.000 7,631.7 5, AIPL .7 7,633.1 5,989.7988.6 43.3643.37 SOSNIPPLE BC AA SOSDN-EP LI_ NOT[FL GO @ 7617'ON SWS IPROF 4/29/2003 23300500 SURFACE. 362,696\ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) CEMENT,37 Top Depth PUNCHES, (TVD) Top Inc! 6,670 .,--tiTop(RKB) (RKB) (°) Description Comment Run Date ID(in) CMT PLUG, 36.5 36.5 0.00 CMT PLUG PUMPED 49.5 BBLS CEMENT THRU RETAINER; 11202011 0.000 6,870 PUMPED 5 BBLS ABOVE RETAINER OVER 3 DAYS FISH,6,942 f' 293.0 293.0 0.00 RETAINER 7"CEMENT RETAINER 11/192011 1,141.0 1,141.0 0.00 TBG CUT 3.5 TUBING STUB 11/17/2011 2.992 6,870.0 5,441.3 45.60 PUNCHES TUBING PUNCHES:2"x10'BIG HOLE CHARGES,6 SPF, 11/14/2011 2.992 60 DEG PHASE GAS LIFT, 6,870.0 5,441.3 45.60 CMT PLUG PUMPED 184 BBLS CLASS'G'CEMENT 11/15/2011 0.000 7.314 6,942.0 5,491.8 45.41 FISH 64"TWO PRONG SLICKLINE WIRE GRAB 11/11/2011 0.000 all",s 7,209.0 5,681.2 43.95 CMT PLUG 2 CEMENT OFF TUBING-PUMPED TTL 11.4 BBLS 6/28/2009 0.000 NI CEMENT,3.7 BBLS PLUG(425') 7,300.0 5,747.3 44.09 CMT PLUG CEMENT OFF TUBING-PUMPED TTL 15 BBLS CEMENT, 6/21/2009 0.000 3 BBL PLUG(333') PACKER.7,373 ... 7,405.0 5,822.4 42.97 PATCH 21'Merla Patch 1/26/1996 2.313 NIPPLE,7,412 .., 7,412.0 5,827.6 42.97 NIPPLE Patch Includes AVA BPL Ported Nipple;Set 3'feet below 1/26/1996 2.750 SLEEVE.7.412\ Top of Mandrel GAS LIFT, 7,412 7,412.0 5,827.6 42.97 SLEEVE AVA CII Sleeve;Set 3'below top of Mandrel 1/28/1996 1.875 PATCH,7,405 CMT PLUG 2, 7,474.0 5,872.9 42.97 PATCH 22'Merle Patch Set 1/26/1996 2.375 7.209 7,632.0 5,988.9 43.37 NIPPLE AVA Nipple Reducer w/Camco"D"profile 1/24/2000 1.813 CMT PLUG, REDUCER 7,300 GAS LI 7,787.0_ 6,102.2 42.46 FISH 1'BullPlug Lost on Run#2 6/10/1988 7,482 PATCH,7,474 C „ I!i Perforations&Slots shot T Top(TVD) Btm(TVD) Dens Top(11KB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 1,000.0 1,010.0 1,000.0 1,010.0 11/16/2011 6.0 IPERF 7'CASING:2.5"X10'GUN,60 DEG IPERF, - PHASE,BH CHARGES 7,530-7,66 7,530.0 7,600.0 5,913.9 5,965.1 C-4,UNIT B, 7/9/1984 12.0 IPERF 5 12"Csg Gun;120 deg ph Squeezed _ 2A-07 Perls,7.599 " 7,630.0 7,642.0 5,987.4 5,996.1 A-4,2A-07 7/9/1984 4.0 IPERF 4"Csg Gun;90 deg ph 7,632.0 7,640.0 5,988.9 5,994.6 A-4,2A-07 6/10/1988 4.0 RPERF 7,652.0 7,688.0 6,003.3 6,029.5 A-3,2A-07 7/9/1984 4.0 IPERF 4"Csg Gun;90 deg ph 7,652.01 7,680.0 6,003.3 6,023.7 A-3,2A-07 6/10/1988 4.0 RPERF PACKER,7,625 nl Stimulations&Treatments yl rl Bottom FFIO" Min Top Max Btm TopDepth Depth DepthDepth (TVD) (ND) p�:j� _ (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment NIPPLE,7.632 `\., " -- NIPPLE 0.0 Clay Acid Slim 7/31/1968 REDUCER, jj II Cement Squeezes CEME7.NT Top Depth Btm Depth PLUG.7,300 (TVD) (TVD) CEMENT 11 -" Top(ftKB) Btm(ftKB) (ftKB) MKS) Description Start Date Comment PLUG,36 _ SOS,7633 - 7,530.0 7,652.0 5,913.9 6,003.3 Cement Squeeze 6/28/2009 SQUEEZE PERFS W/7.7 BBLS CEMENT IPERF, '' - 7,599.0 7,600.0 5,964.4 5,965.1 Cement Squeeze 7/10/1984 7,6367,642 RPERF, " 7,632-7,640 Mandrel Details _ Top Depth Top Port Cement (TVD) Incl OD Valve Latch Size TRO Run Squeeze.7,530 Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type lin) (psi) Run Date Com... RPERF, 1 7,313.6 5,756.9 44.01 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 6/15/2000 7,652-7,680 MERE, 2 7,412.0 5,827.5 42.97 MMH FMHO 1 INJ PATCH BK-2 0.000 0.0 1/26/1996 7,652-7888 Cement - 3 7,481.6 5,878.5 42.97 MMH FMHO 1 INJ PATCH BK-2 0.000 0.0 1/26/1996 Squeeze,7,631 FISH,7,787 • PRODUCTION, 2667,925N . TD,7,956 e , KU P • 2A-07 - ConocoPhillips \ —',,,„ Alaska,Innc. ConocoPhiltips KB-Grd(ft) Rig Release Date ... Well Contig -2A-07,1/17/20121'.35-.46 PM _ _ -.... 4129 6/2/1984 Schematic-Actual Clay Acid Shim. 0 Cement Squeezes Top Depth Btm Depths (ND) (TVD) i Top(fIKB)Btm(ftKB) (ftKB) (ftKB) Description Start Date Comment 7,629.0 7,631.0 5,986.7 5,988.1 Cement Squeeze 7/10/1984 CONDUCTOR, 7,631.0 7,688.0 5,988.1 6,029.5 Cement Squeeze 6/21/2009 SQUEEZE PERFS W/12 BBLS CEMENT 36-110 -- Notes:General&Safety End Date Annotation RETAINER, °® 1/14/2006 NOTE:TAG w/1.25"LIB @ 11'RKB-POSSIBLE COLLAPSED TUBING 293 ■ 6/20/2006 NOTE:VIDEO LOG SHOWS POSSIBLE CORKSCREW TBG OR TBG DAMAGE @ 11' (PERF, _- 9/8/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1,000.1,010 _- 3/172011 NOTE UNABLE TO PASS RESTRICTION @ 70'SLM,see WSR 3/17/2011 TOG CUT, 11/12/2011 NOTE:TUBING PUNCHES @ 6890'&6920'UNSUCCESSFUL 1,141 CMT PLUG,37 11/12/2011 NOTE:TBG CUT @ 6889'UNSUCCESSFUL 11/16/2011 NOTE:TUBING CEMENT TAG WITNESSED BY AOGCC SAFETY VLV. 1.11_iii i 11/16/2011 NOTE:JET TBG CUTS @ 1480'&1475'UNSUCCESSFUL 1'932 Zi11/20/2011 NOTE:P&A-WELL CEMENTED TO SURFACE ,� SURFACE, 36-2,696 CEMENT,37 PUNCHES. 6.870-- - e CMT PLUG, 6.870 FISH,6,942 t C11 GAS LIFT, 7,314 11 I.'r,.. PACKER,7,373 NIPPLE,7,412 SLEEVE,7,412 GAS LIFT, 7,45 --F.1,.,.: PATCH,7,4002 CMT PLUG2, �� 7,209 CMT PLUG. 7.300 y: GAS LIFT I !({{ 7,482 PATCH,7,474 7,530-7 600 Peds,7,599 1 OW PACKER,7,625 Squeezed Perls,7,629 _ NIPPLE,7,632 — — NIPPLE ___ REDUCER, �� , 7,632 CEMENT PLO _ CEMENT PLUG,36 SOS,7,633 IPERF, _A F`. 7,630.7,642 - .. RPERF, 7,632-7,640 Cement Sque e,7,530 e RPERF, 7,652-7,680 (PERF, - 7,652-7,688 Cement _ N ii)I-1-1 °o Q re ,,, o,-- re Z 7''`� 0 < CO V p w EO U Z W p --I Q Q 0 U D w 2 0� 0 U p d JW(n Z c� c� p c> a o C_) —Th z --/ cc W N 0 t n' F F 5 Op z F F ��ii11 I C": W X X OK m N < -8-1 W Q J W Z W W 0 d < W d 0 m I- CZ, Z HOQ O * . ® ►4X ®-t7-O U+ X Li- >C tY X y- _ --.09---.09.--.09t-- I I.iJ /' 40/ two Z _ � oa. 2-4 • W W 3 1 d d \ J U N W —— f: - MQ 0 p Q OC LLI W w O L o I- a) O O O I po N) VI.., U 00+51 CV Cp o U o I 1 O w > ID' 1 z W / 1 n IJrrM \ >- dL-0 c Z �Q r \ O Z °D z a o r 40 211: L N.0--. III g o Z Q Y C �VL,.. 0 c0 04 0 O • - N \ O V O Z Nr Q -N 1--4-11 PC \ 0 \ �. J N 4.I J F. Y \ J 7> Z Z U �' c>CD d M H K cc) } ¢ 0 d F < J _ CC in f . w¢0= �¢ Q 2 0 0 z < o C1 I N =�x •} 1 re w z 'o s _ • o a. LA �P..-. .• C ccJ O O I ¢ ¢ o O 2c°5 • I ¢- TO Tt I a.�O in \ w W yi d 0 0g / 1 - \ W OU w w F Y c, F - Z , N U 1 D 0 U c N < Z re UQ CC O ' K fn 0 0 w m w a i 0 FAA FAA o o W N IZI* .- N 11 L_N )1c` E r„ cv3 1 � �^ N O ,' 'io �.. N1 J2 \ I I LA Z Z U O O N a 1 o O 0 U �. .^- �N \ W • -N d d i-®- 1 g \ Z U \\ D. V o I- IT opcn II I \ O aw o W Lri tz OOro w w I CC < w 0 a s — w w D cc ¢ F= a z Z / z• 3 a o v -o �J l J z �� m o rg Q N 1 O V I _:�\ 0 W 0 m Z _ rn Z �, < Zi Z I 1 I II - N o Li] N r 0 — 0 , C] Hi iij ii --I ; 4M+ c_1a O a' i ii, ,,,,,,zu, ,_ 1 \ , Y eH ejp 1 . L , r ConOcoPh'l lips 4, Well Naar. 2A-07 Nwihar 50 12U9A0- 0 PTO 184 055 Set tacat#ara 4823'03 FMI.0?53' EEl. See.14,T11M,RBE. UM s '-',.. NB 7 _._ , , t ....ii t 4;- ' a q UOWtd q. ---''' rM :, 'r - , ,,,, ,. --..„ , .*. „.. .., ,,....,, ., ., ... . .., ,. . . ,. ;,..,..,,,,,,,,,,,..,,,,,,,,i .,.:7- , -,,,,---: , „: i477:777,......., , I 2A-07 PTD 184-065 ©ConocoPhillips Alaska, Inc: This photo is copyrighted ConocoPhillips Alaska, Inc. and cannot be released br published without express written consent � - of ConocoPhillips Alaska . ., ; ,.� • I '1A 07 PTD 184-065 ' • nocoPhillips Alaska, Inc. ,.:I -7 - hoto is copyrighted by >ocoPhillips Alaska, Inc. and `'' 4 .; ot be released or published " Eut express written consentr.'— , , ‘ acoPhillips Alaska 1 ;' • ,,,„ p *^ta S i w ro �.; ..air �s'"::1;.:,-',:„„,:;: s az ` >r ��w Y, 4. �. N"« "w �.w.3g`*s qs' e r F , go gy�pp &"- .. .IPS r y C `" i3. q�ty� y+e i . ,4,6 PI ' iitil Vic, r/ r J/ iii. 1 t aa, i j/;:////////://fril; '-:'7 4'4 4-ill * ' ;it/ 1 '..".."4.- .".17-'74t4"41 17174.-Itr-d...71-1" it $ s£ a + c e 1 '* g N. s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/28/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 2A-07 Oper.Rep: Ian Ives - PTD No.: 184-065 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ler(specify in commei Onshore/Offshore: Onshore Suspension Date: 06/28/09 Date AOGCC Notified: 08/27/10 Sundry No.: 309-202 Type of Inspection: Initial Wellbore Diagram Avail.? Yes - Well Pressures(psi): Tubing 200 Photos Taken? Yes IA 650 ' OA 40 scp itiE® AUG 1 4 2095 Condition of Wellhead: Location was verified with survey plat.Wellhead is leaning,Flowline is still attached,Wellhead has subsided 22"below pad grade. 58"of H2O in cellar. IA partually and OA completely submerged. Condition of Surrounding Surface The pad conditions look good. Location: Follow Up Actions I asked for the cellar to be sucked out and I received an email saying that it was done. Needed: The subsiding and leaning wellhead needs to be addressed if not already done. v Attachments: Photos(6) REVIEWED BY: Insp.Supry Comm PLB 08/2010 2010-0828_Suspend_KRU_2A-07_bn.xlsx :'''''' — ,,t • :I+ y ttl �'111614Lai + X44 lfi i „ :: `; ?3 G r r Y,• � . t. b 1 It 4 r �t ` S .moo - i x -r-- — t 4 L. i ' , '.:.1'..,t , 3 + e „ t . N 44 o -o O NI o V • SSI-= N •CO cna • .., x • I �ago • acn I00 oo M,o od 740 . Nao o O^� o N= oo c4 t . to oat.Q48oBHNoo Vaa, 00cv k r. i $fil 0 e I 0•0 . ' • • • % Rpi/ << 7. .' lc e. v -a .: .,',, _ , 0 „ Ili ins .,) -,-,, 4 of 11-71r, - -- $ c ', l 11111/ 1t'j i:d H . .NN1t' t, ''. ii r41 1 '''!!"1 1)11111 i. il I;444 ih'.'1 ill I 1:1 11111 1. OM o neAl r# ` y I w. a �, ` -.;�� r . -0 � r �, Q y,,F ,,,� �J�► t Mie` . 04 11 yy� 1 i 1 R� iii1,i,F i i.0 00 M • .--, 00 t ,..,.....,,,, ........ p . _.,..,. ..,...._ . , . ... __ _.. 4 . . _.:Aiimil_ -sr..--a.- a 1- 1i: ,4 ! ,_____ ...r.'-.-..:,.,:':::,.,., fr, „, ...._ .. , ,. . ., TT.. , S, . ....: „ . ..,,,. . _- ,„ ii. .,..,,,.. , .... . ... ' 01iiiiiiii , . , .. . . . .., . i . ._ .. I. • . . .....,, . . • .„,,. fP ,..... ... i r ' '' ''' 'l''''110 10 0)00 I _r_•._ ,,,,••_,...,, • ..,, . — 'i ' ##$#°P Pr 0. I it 000400 10- i • — 11 ;;i r' 4, ' ?Iv ... ii d • . /y, f i SID i •. , it A ® ■f o Q o /: Ina ;moial al J •�I CI il = a.- y _• 10 SON Bill ` �� • b 1 ft?, a �`F 4.4413 ¢. r. holot♦ [ pp44 F{yJ 7 ' �s►.`,,l%' �� ” Eifr2 SIM • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/08/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: KRU 2A-07 - Oper. Rep: Martin Walters PTD No.: 1840650 Oper. Phone: 659-7043 Location Verified? Yes Oper. Email: n1878(aconocophillips.com_ If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 11/20/11 Date AOGCC Notified: 08/03/15 Sundry No.: 311-215 Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 Photos Taken? Yes IA under water OA under water Condition of Wellhead: good Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: well celler needs vac'd out;see attached photo ✓ Comments: well was verified by pad well location map Attachments Photos(2) SCANNED SEP 0 ? 2016 REVIEWED BY: Insp.Supry J 1Z151‘5" Comm • PLB 06/2014 2015-0808_Suspend_KRU_2A-07Jh.xlsx • Suspended Well Inspection-KRU 2A-07 PTD 1840650 Photos by AOGCC Inspector J. Hill 8/8/2015 Conocop Philli s , Al Well Name: 2A-01 API Number: 50-103-2002900-00 PTD: 184-065 Sur. Location: 4623' FNL, 53' FEL. Sec. 14, T11N, R8E, UM Ilt ._. r 1 it '1511 :. + ' t.R 19A55,, 5 4 , si3..5. Ao � /i// l// :�i msautu � , /tinnnut "'� , nu mn��►�►t`` /m»>/1Iininhmm rmnkusa ... , /lnll!IIIHInuhn11,- n nnrnn�urtm , /l1//IIllllIinirtn UrrhIrii nnnr�ru�ut,��xt►�►1 " "11/////////Iil111H11111111111 mama „ �' 1111/1111111111111111111111111 ..rte IIIllhI11U/l111.'.I111111111111. 1111'1��\ AM* 4111111110111111111aliaa .-g 2015-0808 Suspend_KRU_2A-07 jh.docx Page 1 of 1 Ima ect Well History File Cove~l~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~ ~/-(~ ~,,~Well History File Identifier RESCAN DIGITAL DATA [] Color items: r~ Diskettes, No. [] Grayscale items: D Other, No/Type [] Poor Quality Originals: ~ D Other: , NOTES: BY: BEVERLY BREN VINCENT SHE~LOWELL Project Proofing BY: BEVERLY BRE~SHERYL MARIA LOWELl_ Scanning Preparation x 30 = Ry: BEVERLY BREN(~ SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scanna ble) ~ Logs of various kinds [] Other DATE: 7-~, IS~ DATE: /S/ ~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~'~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,/X,% YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINCEN~ARIA LOWELL DATE:///~ {SCANNINQ ~ COblPLETE AT THIS POlDrr UNLE~ SPECI/~d. ATTENTION ~ REQUIRED ~ AN IND~DUAL PAGE $A$1S DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (individual page [special attention] scanning completed) NO NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd STATE OF ALASKA ALGA OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r FFrf orate r Other p Suspended Well Inspection Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 184 - 065 3. Address: 6. API Number: Stratigraphic r Service rI P. O. Box 100360, Anchorage, Alaska 99510 -- 50 103 - 20029 - 00 r- 7. Property Designation (Lease Number): 8. Well Name and Number ADL0025570 2A - 07 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field /guparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7956 feet Plugs (measured) None true vertical 6227 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7373 true vertical 0 feet (true vertucal) 5800 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 630 1640 SURFACE 2660 12 2696 2546 2020 3520 PRODUCTION 7659 7 7925 6204 4330 4980 Perforation depth: Measured depth: 1000 -1010, 7530 -7600, 7630 -7642, 7632 -7640, 7652 -7688, 7652 -7680 True Vertical Depth: 1000 -1010, 5914 -5965, 5987 -5996, 5989 -5995, 6003 -6030, 6003 -6024 RECEIVED Tubing (size, grade, MD, and TVD) 3.5, J -55, 7634 MD, 5990 TVD OCT 1 1 2012 Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 7373 MD and 5800 TVD AOGCC SSSV_ BAKER FVL SSSV - LOCKED OUT 8/9/88 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service F7 Stratigraphic r 16. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations X �, GSTOR r WIND r WAG r GINJ r SUSP r7 SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Martin Walters / MJ Loveland Printed Name Martin Walters Title Well Integrity Supervisor Signature / - Phone: 659 -7043 Date: 10/08/12 //Zig/ // /4162 e - , OCT 1 2012 +, 1 1, �r /'tf Form 10-404 Revised 11/20 1 4 C L 1 r7 Submit Original Only • • RECEIVED Conoco Phillips Alaska OCT 1 1 2012 P.O. BOX 100360 A ANCHORAGE, ALASKA 99510 -0360 October 8, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2A -07 (PTD 184 -065) 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 2A -07 (PTD 184 -065). 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, '/;( itt7 /V Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures St.ended Well Site Inspection Forni Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk River Unit 2A -07 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 184 -065 Sundry 311 -215 API Number: 50103200290000 Operator: ConocoPhillips Date Suspended: 11/20/2011 Surface Location: Section: 657' FSL, 53' FEL, Sec 14 Twsp: T11 N Range: R8E UM Nearest active pad or road: KRU DS2A 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. Doyon 141 drilling rig adjacent to well Location cleanup needed: No Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Minimal Discoloration, Sheens on pad, pits or water: No sheen Samples taken: No 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: Weathered dry hole tree. OK. Cycled MV, SV, IA, & OA valves Cellar description, condition, fluids: No oil in cellar. Wooden cellar box and grating covver need repair Rat Hole: None Wellhouse or protective barriers: Wellhouse - Good Well identification sign: Stencil on wellhead & wellhouse Tubing Pressure (or casing if no tubing): 7 psi Annulus pressures: IA = 7 psi, OA = 7 psi Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: Wooden cellar box and grating covver need repair W Operator Rep (name and signature): .� 7 ij; �;� �� ' / AOGCC Inspector: Waived by Chuck Schieve Other Observers: Kuzma Inspection Date: 10/7/2012 AOGCC Notice Date: 10/4/2012 Time of arrival: 13:30 Time of Departure: 14:00 Site access method: Highway Vehicle KU P • Max An 2A -07 IV ConocoPhillips c Well Attributes A le & MD TD Alask htC C . Wellbore API /UWI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (ftKB) corxxd+�+e,ps 501032002900 KUPARUK RIVER UNIT INJ 48.90 1 6,100.00 7,956.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (R) Rig Release Date Well cen6q - 2A-07, 1/17/2012 1:35 :46 PM SSSV: LOCKED OUT Last WO: 41.29 6/2/1984 Schematic - Actual Annotation Depth (ftKB) IEnd Date Annotation Last Mod ... End Date Last Tag: CMT 1,538.0 11/16/2011 Rev Reason: WELL REVIEW osborl 1/17/2012 ,Clay Acid Stim, Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.060 36.0 110.0 110.0 62.50 H WELDED i Casing Description String 0... String ID ... Top (ftKB) Set Depth (0.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 36.5 2,696.0 2,545.6 36.00 J - 55 BTC CONDUCTOR, Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 36 - 110 PRODUCTION 7 6.276 265.9 7,925.4 6,204.4 26.00 J -55 BTCMOD Tubing Strings RETAINER, 7 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 293 TUBING 31/2 2.992 1,141.0 7,633.9 5,990.2 9.30 J -55 EUE -ABMOD IPERF, Completion Details 1,000 -1,010 Top Depth (TVD) Top Inc' Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) TBG CUT, 1,141 2 1,931.7 1,916.5 21.59 SAFETY VLV BAKER FVL SSSV - LOCKED OUT 8/9/88 2.813 CMT PLUG. 37 I5 7,359.6 5,790.0 43.76 PBR BAKER PBR 3.000 5 , 7,373.3 5,799.8 43.68 PACKER BAKER FHL PACKER 3.000 SAFETY VLV, - 7,519.8 5,906.4 42.97 BLAST JT 2.992 1,932 i. 7,624.5 5,983.5 43.42 LOCATOR BAKER LOCATOR w/2 SEALS 3.000 ilk 7,625.1 5,983.9 43.41 PACKER BAKER FB -1 PACKER 3.000 7,631.7 5,988.6 43.37 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,633.1 5,989.7 43.36 SOS BAKER SOS - ELMD TTL @ 7617' ON SWS IPROF 4/29/2003 3.000 SURFACE, 38 3 8 � I Other In Hole (Nireline retrievable plugs, valves, pumps, fish, etc.) CEMENT, 7 Top Depth PUNCHES,_ (TVD) Top 'ncl 8.870 1 i Top (ftKB) (M PI Description Comment Run Date ID ('n) CMT PLUG, 36.5 36.5 0.00 CMT PLUG PUMPED 49.5 BBLS CEMENT THRU RETAINER; 11/20/2011 0.000 6.870 PUMPED 5 BBLS ABOVE RETAINER OVER 3 DAYS 293.0 293.0 0.00 RETAINER 7' CEMENT RETAINER 11/19/2011 FISH, 8,942 1,141.0 1,141.0 0.00TBGCUT 3.5 TUBING STUB 11/17/2011 2.992 6,870.0 5,441.3 45.60 PUNCHES TUBING PUNCHES: 2'x10' BIG HOLE CHARGES, 6 SPF, 11/14/2011 2.992 60 DEG PHASE el 6,870.0 5,441.3 45.60 CMT PLUG PUMPED 184 BBLS CLASS 'G' CEMENT 11/15/2011 0.000 GAS LFT, 7.314 IL 6,942.0 5,491.8 45.41 FISH 64" TWO PRONG SLICKLINE WIRE GRAB 11/11/2011 0.000 IF 7,209.0 5,681.2 43.95 CMT PLUG 2 CEMENT OFF TUBING - PUMPED TTL 11.4 BBLS 6/28/2009 0.000 CEMENT, 3.7 BBLS PLUG (425') NM 7,300.0 5,747.3 44.09 CMT PLUG CEMENT OFF TUBING - PUMPED TTL 15 BBLS CEMENT, 6/21/2009 0.000 3 BBL PLUG (333') PACKER, 7,373 ,, 7,405.0 5,822.4 42.97 PATCH 21' Merla Patch 1/26/1996 2.313 NIPPLE, 7.412 7,412.0 5,827.6 42.97 NIPPLE Patch Includes AVA BPL Ported Nipple; Set 3' feet below 1/26/1996 2.750 SLEEVE, 7,412 Top of Mandrel GASLIFT, \ 7,412.0 5,827.6 42.97 SLEEVE AVA CII Sleeve; Set 3' below top of Mandrel 1/28/1996 1.875 PATCH, 7,405 CMT PLUG 2, 7,474.0 5,872.9 42.97 PATCH 22' Merle Patch Set 1/26/1996 2.375 7.209 5,988.9 43.37 NIPPLE AVA Nipple Reducer w/Camco "D" profile 1/24/2000 1.813 CMT PLUG, REDUCER 7,300 GAS LIFT, 7,787.01 6,102.2 42.46 FISH 1' BullPlug Lost on Run #2 6/10/1988 7,482 PATCH, 7,474 it Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (RKB) (ftKB) MB) Zone Date (.h ... Type Comment 1,000.0 1,010.0 1,000.0 1,010.0 11/16/2011 6.0 IPERF 7' CASING: 2.5 "X10' GUN, 60 DEG IPERF, PHASE, BH CHARGES 7530 - 7,600 7,530.0 7,600.0 5,913.9 5,965.1 C-4, UNIT B, 7/9/1984 12.0 IPERF 512 "Csg Gun; 120 deg ph 2A -07 Squeezed Perfs, 7,599 7,630.0 7,642.0 5,987.4 5,996.1 A-4, 2A -07 7/9/1984 4.0 IPERF 4" Csg Gun; 90 deg ph 7,632.0 7,640.0 5,988.9 5,994.6 A-4, 2A -07 6/10/1988 4.0 RPERF 7,652.0 7,688.0 6,003.3 6,029.5 A -3, 2A -07 7/9/1984 4.0 IPERF 4" Csg Gun; 90 deg ph 7,652.0 7,680.0 6,003.3 6,023.7 A -3, 2A -07 6/10/1988 4.0 RPERF PACKER, 7825 - Stimulations & Treatments Bottom I Min Top Max Btm Top Depth Depth Squeezed Depth Depth (TVD) (WD) Pens 7829 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment NIPPLE, 7,832 0.0 Clay Acid Stim 7/31/1988 NIPPLE REDUCER. Cement S • ueezes 7,832 CEMENT Depth Z^ Btm Depth PLUG, 7,300 -- CEMENT - 1 ■ Top (ftKB) Btm (ftKB) Date Comment PLUG, 36 SOS, 7,633 7,530.0 6,003.3 6/28/2009 SQUEEZE PERFS W/7.7 BBLS CEMENT t IPERF, I ° 7,599.0 7,600.0 5,964A 5,9111111 7,830-7,642 F, .. i t RPER 7,632 -7,640 _ Mandrel Details -. Top Depth Top Port Cement (WD) Inc' OD Valve Latch Size TRO Run Squeeze, 7,530 Stn Top (ftKB) (*KB) ('1 Make Model (In) Sery Type Type Ifni (psi) Run Date Corn... RPERF, 1 7,313.6 5,756.9 44.01 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 6/15/2000 7,65 IPERF, ll 2 7,412.0 5,827.5 42.97 MMH FMHO 1 INJ PATCH BK -2 0.000 0.0 1/26/1996 7,652 - 7,688 Cement 3 7,481.6 5,878.5 42.97 MMH FMHO 1 INJ PATCH BK - 2 0.000 - 0.0 1/26/1996 Squeeze, 7,631 FISH, 7,787 PRODUCTION, 286 - 7.925 • TD, 7,958 KUP • 2A -07 ConocoPhillips Alaska 1111, KB-Grd (ft) Rig Release Date ••' 41.29 6/2/1984 Well Confiq - 24-07,1/17/2012 1:35 46 PM Schematic - Actual Coy Acid Stun - 0 Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top (ftKB) Btm (ftKB) (RKB) (RKB) Description Start Date Comment 7,629.0 7,631.0 5,986.7 5,988.1 Cement Squeeze 7/10/1984 CONDUCTOR. 7,631.0 7,688.0 5,988.1 6,029.5 Cement Squeeze 6/21/2009 SQUEEZE PERFS W/12 BBLS CEMENT 36-110 Notes: General & Safet" End Date Annotation RETAINER, ■ 1/14/2006 NOTE: TAG w/1.25" LIB @ 11' RKB - POSSIBLE COLLAPSED TUBING 293 ! 6/20/2006 NOTE: VIDEO LOG SHOWS POSSIBLE CORKSCREW TBG OR TBG DAMAGE @ 11' IPERF, 9/8/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1'000.1' 010 3/17/2011 NOTE: UNABLE TO PASS RESTRICTION © 70' SLM, see WSR 3/17/2011 TBG CUT. 11/12/2011 NOTE: TUBING PUNCHES @ 6890' 8 6920' UNSUCCESSFUL 1'141 11/12/2011 NOTE: TBG CUT 6889' UNSUCCESSFUL CMT PLUG, 37 g @ II 11/16/2011 NOTE: TUBING CEMENT TAG WITNESSED BY AOGCC SAFETY VLV, 11/16/2011 NOTE: JET TBG CUTS @ 1480' 8 1475' UNSUCCESSFUL 1,932 11/20/2011 NOTE: P&A - WELL CEMENTED TO SURFACE alt SURFACE. 36-2.696N { f CEMENT, PUNCHES, 0,870 8 1 CMT PLUG, 6,870 FISH, 6,942 ft GAS LIFT. `. 7,314 • at PACKER. 7.373 ,- NIPPLE, 7,412 SLEEVE, 7,412 GAS LIFT. 7,412 PATCH, 7,405 GMT PLUG 2 7,209 CMT PLUG, 7.300 GAS LIFT, 7,474 PATCH, 7,474 IPERF. 7,530.7,600 Squeezed Perla, 7,599 4 PACKER. 7,625 Squeezed Perk, 7,629 NIPPLE. 7,632 NIPPLE REDUCER. 7,632 - _ CEMENT PLUG. 7,300 -'-- CEMENT PLUG, 36 SOS. IPERF, "" '" ERF, 7,830 -7,842 RPERF, 7.632 -7,840 - Cement Squeeze, 7,530 RPERF. 7,6 7417 II 7852-7,688 Cement ..... Squeeze, 7,631 FISH, 7,787 PRODUCTION. 266 -7,925 IS 11 TD, 7,958 AU TI ON , [ _ _ __. ________ ___ THIS DRILL SITE IS I CONSIDERED TO BE —PR PIPELINES c�o» AN H AREA 1 1111 �• POWER LINES Mt _ /\' \' \'/\/\/\/\ \/\ / \' / \ \'%\ \ , 7 • • : .:. ..:.: • 7x7x 7\,/\' 7\' 7\' 7/\\'/\\' / \ \' /\ / /w '1', ' t' —TO XFRMR TO J I DS2T' 12I SPINE E i ROAD I '- { - 6B- 60'- I --60' I 275' 235' 2 I I [ 1 6 0 ' -{--60'-}-60' / 0 0 ® ® 1 GUARD 2200 2 • • • 1 • 3 14 15 16 CTRL _ AIL LINE 8 ROOM HEATER 1 - REMOVED / RESERVE PIT (PILING ONLY) RESERVE PIT A � RESERVE PIT —>Oc W PIG PIT RESERVE PIT / 12 11 17 10 9 PROD METH 24 8 20 1) ,...., 2 25 6 5 2 00(:)S• / 0 0 0 MOD TANK 0• A♦ • • 0 / / - GUARD / RAILS _ _ 50' 150' 60' 4 I � 0 , 200' 75' 75' 180' 20.J I � 20 � 20 L �0 338' I 50' lo 0 20'120 \20' 20' k 30' LEGEND FEATURE LOCATIONS ® EXISTING PRODUCER • LEGEND • EXISTING INJECTOR 0 CONVERTED FROM r /./j /1 - CLEAN SNOW DUMP AREA. ALL EQUIPMENT. ® RESCUE EQUIPMENT PRODUCER TO INJECTOR �� — ENVIRONMENTAL AREA —NO SNOW DUMPING. * SCBA LOCATIONS NOTE T ABANDONED CONDUCTOR POWERLINE —WATCH CLEARANCE!!. KODIAK I 1 DESIGNATED SAFE AREA (PRIMARY) )6( EXISTING CONDUCTOR ,esr�>•i BLOWERS MAY HIT LINES WITH DISCHARGE. 1 I DESIGNATED SAFE AREA (SECONDARY) NO SNOW IS TO BE PLACED IN ® PARTIAL TREE O.> ,,, — KODIAK BLOWERS MAY DISCHARGE OVER 1l EVACUATION ROUTES DEPENDING ON WIND ANY RESERVE PIT OR LINED PIT. PIPELINES. — - :'. — NO SNOW DUMPING AREA. WINDSOCK i: ® BARRICADE /ESCAPE ROUTE 0 AREA: 2A MODULE:XXXX UNIT: D2 ' A LOUNSBURY, INC ,,5, FIRE EXTINGUISHER APPROVAL: DS2A FACILITY EX - ANS1ON 3 5/30/01 Line Htr Removed,Updote Title Blk Rev Per K01039ACS ROL MRT DATE: 10/19/96 CADD FILE: EK620113 FEATURE LOCATION 2 10/29/97 Rev Per K96030ACS DCS AJR DRAWING NO. SHEET: REV: NO' DATE REVISIONS BY CHK EN ENS CEA -D2AX -3313 001 3 l &U .U111 111V I iii U 1 II1 L si a , , , 1 I 1/4 ‘,. . k xxxs . . 1,11k 1,.. iiiiiiiiiiiiiiiiim . 4 : • , p iiii ,0 „ it, fill/ iii , 1 It Ili Ai , ,,,i tilkiksi .., l ir L III ii 1 i ‘, vL ‘ivis,Ni 1.111111111111111/811 Illitilif: ill 0 Uli x '' %XI 1111111111 � : / 1/11/1 /1 L ‘ P Al &XX . ,f W x _'\ ° ' 1 !. ai i ii. ‘ v\k‘ \ li II tes . 1111 11 11 : i ... . %' 1 ,,‘ , ,,,,:. 1 . 4 A lsiii \ ‘‘ \\ \-\ v‘ t x t t v i . . - t , s , . I a t . -.‘, ,- \ ..\„ _ x µ i, , , � W R fir„ T .LY . A � W # v j t F • . ... , jo loaLisuctn . , \1 t ,, N 0 i 0 • * k 4 : 6 . , tilt , , ,,. .,- ) . , • , a ' ) 1 ) ,. ' 4 :-, - .1k ‘‘ , i i S 1 I I INN Il klilsi, lh i 1 t ' s 1 k , N i1/4 0 vl ... ., \ :. i llk iii. % 11111i6, A, I • ii, . - ,,. 1 ,., s 1111446, „ 4 „ ,,.. 11 N_ .,. , i \ 111 f - , ........ 0 . V/Viltlik t ,. liL ‘ iSit7‘. 1.1%Liiiiiitiii\Nks1:14#.44141/Nilhtfikk t , - .. * Ilk tort. ,4 AT , il .„ ........ * 167 AfOophi'gPi ''''' ..._. . .... - - .;.. , ... - :„,.•,-.". „.‘ , .., ' ' .....- ... 1*111 likt Iti .0., *-.. *..., ! '12 '''' ,.-,. '''' ',' ' silo •*- ' 4 .,-, .0 0 .40 . . .,, ...,..,..., ,..„..,.„,...„ . . . ., .. i i,...... . • STATE OF ALASKA • AN 1 7 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION RE FAMMINUMrgammissjort la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Q 1 b. Well ClaAnchQrat 20AAC 25.105 20AAC 25.110 Development ❑ Explorator ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: ` l. a", f,,,.�..- • Service El Stratigraphic Test III 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: November 20, 2011 184 - 065 / 311 - 215 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 25, 1984 50 103 - 20029 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 657 FSL, 53' FEL, Sec. 14, T11N, RO8E, UM May 31, 1984 2A - 07 Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 1313' FSL, 1278' FWL, Sec. 14, T11N, RO8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: , 9. Plug Back Depth (MD + TVD): 1369' FSL, 994' FWL, Sec. 14, T11N, RO8E, UM surface Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498341 y 5960078 Zone 4 7956' MD / 6227' TVD ADL 25570 TPI: x - 494391 y - 5960738 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 494108 y 5960792 Zone 4 SSSV @ 1932' MD / 1917' TVD 2668 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1500' MD / 1499' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 41' 110' 41' 110' 24" 175 sx CS II 9.625" 36# J -55 41' 2695' 41' 2545' 12.25" 850 sx PF E, 250 sx PF C 7" 26# J -55 255' 7931' 255' 6209' 8.5" 275 sx Class G, 250 sx PF C 255' 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 1141' - 7634' 7373' MD / 5800' TVD and perfs plugged off: 7625' MD / 5984' TVD 7530' -7600' MD 5914' -5965' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7630' -7642' MD 5987-5996' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7652' - 7688' MD 6003' - 6024' TVD surface to 235' 24.3 bbls AS1 1000' -1010' MD 1000' -1010' TVD 235' - 1010' 54.5 bbls AS1 1538' -6880' 184 bbls Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged Date of Test 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 OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Ei Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE tkiiiiileD FEB 0 ? r> re. i RBDMS JAN 1 a Q Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only --,.----9€1--z_ 6 28. GEOLOGIC MARKERS (List all formations and markerakuntered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1500' 1499' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263 - 4220 Printed Narr . Cae Title: Wells Manager Signature L-- l� Phone 265 -6306 Date Mj )2/20) Z' 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. 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. Item 1 a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: 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 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 0 0 v, , , .' KUP 2A -07 Conoc©Philhps f _. Well Attributes Max Angle & MD TD Alaska. Inc, Wellbore APIIUWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) Conocovtul0pc 501032002900 KUPARUK RIVER UNIT INJ 48.90 6,100.00 7,956.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date SSSV: LOCKED OUT Last WO: 41.29 6/2/1984 Well Conhg: - 2A - 07, 1/17/2012 1:35:46 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod -.. End Date cla Aad snm Last Tag: CMT 1,538.0 11/16/2011 Rev Reason: WELL REVIEW osborl 1/17/2012 0 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 36.0 110.0 110.0 62.50 H -40 WELDED ..7 '1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 36.5 2,696.0 2,545.6 36.00 J -55 BTC CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 36 PRODUCTION 7 6.276 265.9 7,925.4 6,204.4 26.00 J -55 BTCMOD Tubing Strings RETAINER, '`7 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 293 .J ` - TUBING 3 1/2 2.992 1,141.0 7,633.9 5,990.2 9.30 J -55 EUE -ABMOD IPERF, Completion Details 1,000 -1,010 - . Top Depth (TVD) Top Inc/ Nomi... TBG CUT, Top (ftKB) (ftKB) (°) Item Description Comment ID (In) 1,141 SR 1,931.7 1,916.5 21.59 SAFETY VLV BAKER FVL SSSV - LOCKED OUT 8/9/88 2.813 CMTPLUG,37 7,359.6 5,790.0 43.76 PBR BAKER PBR 3.000 ar 7,373.3 5,799.8 43.68 PACKER BAKER FHL PACKER 3.000 SAFETY VLV, 1,932 7,519.8 5,906.4 42.97 BLAST JT 2.992 7,624.5 5,983.5 43.42 LOCATOR BAKER LOCATOR w /2' SEALS 3.000 7,625.1 5,983.9 43.41 PACKER BAKER FB -1 PACKER 3.000 33 7,631.7 5,988.6 43.37 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,633.1 5,989.7 43.36 SOS BAKER SOS - ELMD TTL @ 7617' ON SWS !PROF 4/29/2003 3.000 SURFACE, , I t 36-2,698 I ` ;. CEMENT, , 37 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth PUNCHES, (TVD) Top Inc! 6,870 1 Top (ftKB) (ftKB) (°) Description_ Comment Run Date ID (in) CMT PLUG, 6,870 36.5 36.5 0.00 CMT PLUG PUMPED 49.5 BBLS CEMENT THRU RETAINER; 11/20/2011 0.000 PUMPED 5 BBLS ABOVE RETAINER OVER 3 DAYS FISH, 6,942 293.0 293.0 0.00 RETAINER 7" CEMENT RETAINER 11/19/2011 1,141.0 1,141.0 0.00 TBG CUT 3.5 TUBING STUB 11/17/2011 2.992 6,870.0 5,441.3 45.60 PUNCHES TUBING PUNCHES: 2 "x10' BIG HOLE CHARGES, 6 SPF, 11/14/2011 2.992 60 DEG PHASE GAS LIFT, 6,870.0 5,441.3 45.60 CMT PLUG PUMPED 184 BBLS CLASS 'G' CEMENT 11/15/2011 0.000 7,314 6,942.0 5,491.8 45.41 FISH 64" TWO PRONG SLICKLINE WIRE GRAB 11/11/2011 0.000 illi 7,209.0 5,681.2 43.95 CMT PLUG 2 CEMENT OFF TUBING - PUMPED TTL 11.4 BBLS 6/28/2009 0.000 fit CEMENT, 3.7 BBLS PLUG (425') AL 7,300.0 5,747.3 44.09 CMT PLUG CEMENT OFF TUBING - PUMPED TTL 15 BBLS CEMENT, 6/21/2009 0.000 PACKER, 7,373 3 BBL PLUG (333') 7,405.0 5,822.4 42.97 PATCH 21' Merla Patch 1/26/1996 2.313 NIPPLE, 7,412 7,412.0 5,827.6 42.97 NIPPLE Patch Includes AVA BPL Ported Nipple; Set 3' feet below 1/26/1996 2.750 SLEEVE, 7,412 \ -- Top of Mandrel GAS LIFT, 7,412 7,412.0 5,827.6 42.97 SLEEVE AVA CII Sleeve; Set 3' below top of Mandrel 1/28/1996 1.875 PATCH, 7,405 CMT PLUG 2, 7,474.0 5,872.9 42.97 PATCH 22' Merla Patch Set 1/26/1996 2.375 7,209 - 7,632.0 5,988.9 43.37 NIPPLE AVA Nipple Reducer w /Camco "D" profile 1/24/2000 1.813 CMT PLUG, REDUCER 7,300 GAS LIFT, 7,787.0 6,102.2 42.46 FISH 1' BullPlug Lost on Run #2 6/10/1988 7,474 PATCH, 7,474 Perforations & Slots ' Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 1,000.0 1,010.0 1,000.0 1,010.0 11/16/2011 6.0 IF'ERF 7" CASING: 2.5 "X10' GUN, 60 DEG IPERF, s i, _ PHASE, BH CHARGES -.. 7,530 - 7,800 y- ? - 7,530.0 7,600.0 5,913.9 5,965.1 C -4, UNIT B, 7/9/1984 12.0 IPERF 5 1/2" Csg Gun; 120 deg ph t Squeezed ^ 2A - Perfs, 7s99 7,630.0 7,642.0 5,987.4 5,996.1 A -4, 2A -07 7/9/1984 4.0 IPERF 4" Csg Gun; 90 deg ph 3 7,632.0 7,640.0 5,988.9 5,994.6 A -4, 2A -07 6/10/1988 4.0 RPERF 7,652.0 7,688.0 6,003.3 6,029.5 A -3, 2A -07 7/9/1984 4.0 IPERF 4" Csg Gun; 90 deg ph 7,652.0 7,680.0 6,003.3 6,023.7 A -3, 2A -07 6/10/1988 4.0 RPERF PACKER, 7,625 Stimulations & Treatments 1 = Bottom Min Top Max Btm Top Depth Depth Squeezed Depth Depth (TVD) (TVD) Perfs, 7,629 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment NIPPLE, 7,632 r - 0.0 Clay Acid Stim 7/31/1988 NIPPLE is r REDUCER, i Cement S 7,632 • +or- .. . ... _ CEMENT Top Depth Btm Depth PLUG, (TVD) (TVD) CEMENT KB) Description Start Date Comment PLUG, 36 Top (ftKB) Btm (ftKB) (ftKB) ( p SOS, 7633 7 ,530.0 7,652.0 5,913.9 6,003.3 Cement Squeeze 6/28/2009 SQUEEZE PERFS W/7.7 BBLS CEMENT IPERF, _ _ . 7,599.0 7,600.0 5,964.4 5,965.1 Cement Squeeze 7/10/1984 7,630- 7,642 RPERF. _. 7,632 -7,640 Mandrel Details . . Top Depth Top Port cement (TVD) Inc! OD Valve Latch Size TRO Run Squeeze, 7,530 Stn Top (ftKB) (ftKB) ( °) Make Model (In) Sery Type Type (In) (psi) Run Date Com RPERF, 1 7,313.6 5,756.9 44.01 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 6/15/2000 7,652 - 7,680 - -- IPERF, i 2 7,412.0 5,827.5 42.97 MMH FMHO 1 INJ PATCH BK - 2 0.000 0.0 1/26/1996 7,652 - 7,688 cement _ i 3 7,481.6 5,878.5 42.97 MMH FMHO 1 INJ PATCH BK - 2 0.000 0.0 1/26/1996 Squeeze, 7,631 FISH, 7,787 1 g 1 1 PRODUCTION, 266 -7,925 TD, 7,956 • KU P 2A -07 ConocoPhillips Alaska, Inc., Conocoi'tutkps KB - Grd (ft) Rig Release Date Well earths': - 2A -07, 1/17/2012 1:35:46 PM 41.29 6/2/1984 Schematic - Actual Clay Acid Stim, ° Cement Squeezes Top Depth Btm Depth (TVD) (TVD) �i Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment 7,629.0 7,631.0 5,986.7 5,988.1 Cement Squeeze 7/10/1984 CONDUCTOR, . � . 7,631.0 7,688.0 5,988.1 6,029.5 Cement Squeeze 6/21/2009 SQUEEZE PERFS W/12 BBLS CEMENT 38- 110 Notes: General & Safety End Date Annotation RETAINER, ^ '1♦ L 1/14/2006 NOTE: TAG w/1.25" LIB @ 11' RKB - POSSIBLE COLLAPSED TUBING 293 # 6/20/2006 NOTE: VIDEO LOG SHOWS POSSIBLE CORKSCREW TBG OR TBG DAMAGE @ 11' IPERF, 9/8/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1,000 3/17/2011 NOTE: UNABLE TO PASS RESTRICTION @ 70' SLM, see WSR 3/17/2011 TBG CUT, . ' 11/12/2011 NOTE: TUBING PUNCHES @ 6890' & 6920' UNSUCCESSFUL 1,141 CMT PLUG, , 37 11/12/2011 NOTE: TBG CUT @ 6889' UNSUCCESSFUL 11/16/2011 NOTE: TUBING CEMENT TAG WITNESSED BY AOGCC SAFETY VLV, _ 11/16/2011 NOTE: JET TBG CUTS @ 1480' & 1475' UNSUCCESSFUL 1,932 � 11/20/2011 NOTE: P &A - WELL CEMENTED TO SURFACE tk . SURFACE, N :I 36 -2,896 CEMENT, 37 PUNCHES, I. 6,870 �: CMT PLUG, FISH, 6,942 GAS LIFT, 7,314 at PACKER, 7,373 NIPPLE, 7,412 SLEEVE, 7,412 GAS LIFT, 7,412 PATCH, 7,405 3 �� CMT PLUG 2, 7,209 CMT PLUG, 7,300 GAS LIFT, 7,482 , PATCH, 7,474 IPERF, 7,530.7,600 ' S _ a Squeezed Perts, 7,599 PACKER, 7,625 _ �t Squeezed Perfs, 7,629 NIPPLE, 7,832 NIPPLE REDUCER, CEMENT PLUG, 7,300 �. CEMENT - -- PLUG, 36 - - -- _ SOS, 7,633 -- " IPERF, 7,630.7,642 RPERF, _ 7,0se -1,64U • Cement Squeeze, 7,530 RPERF, 7,652 -7,680 IPERF, 7,652-7,688 Cement Squeeze, 7,631 FISH, 7,787 { PRODUCTION, 266 -7,925 TD, 7,958 2A -07 Pre -Rig Wellwork DATE SUMMARY 7/1/11 (PRE -RWO) BLEED T, IA & OA APPSI. (IN PROGRESS) DUE TO SLOW Bilk UP ON T & IA WHICH DOES NOT APPEAR TO BE COMING FROM OA. 7/2/11 BLEED T /IA/OA TO 0 PSI FOR BUR. TUBING CONTINUES TO BUILD BETWEEN 4 TO 5 PSI IN 1 HOUR, IA CONTINUES TO BUILD ABOUT 1 PSI IN 1 HOUR. 7/4/11 BLEED T / IA / OA TO 0 PSI FOR BUR. T had built up to 11 psi in 48 hrs and IA had built up to 18 psi. Bled both down to 0 psi and had about 4 to 5 psi build up in 1 hour on both T and IA. 7/8/11 LOAD IA WITH 12.1 BRINE. (IN PROGRESS) 7/9/11 LOAD IA WITH BRINE (In Progress) 7/10/11 LOAD IA WITH 12.1 # BRINE. IN PROGRESS. 7/11/11 LOAD IA WITH 12.1# BRINE. IN PROGRESS 7/12/11 (PRE RWO) NORMAL UP WELL. COMPLETE. 7/13/11 Potential one way comunication TxIA. Press test 500 psi CMITxIA passed (0 min T /I /O = 490/515/10, 15 min T /I /O = 490/505/10, 30 min T /I /O = 490/501/10). Tubing pressure tracks IA when testing from the IA side, but IA does not track tubing when test from the tubing side. 7/14/11 Confirmed TxIA communication, unable to establish circulation rate. CMITxIA: 0 min T /I /O = 535/535/12, 15 min T /I /O = 530/530/12, 30 min T /I /0 = 525/525/12. 7/15/11 Continue with Diesel and Brine swap. 7/16/11 Continue brine loading operations. 7/17/11 Continue brine loading operation. 7/18/11 Continue with brine loading operations 7/19/11 CONTINUE BRINE LOADING OPERATIONS. IN PROGRESS. 7/24/11 Continue loading of KWF brine into IA 7/25/11 PUMP BRINE DOWN IA (TOTAL OF 5 BBLS PUMPED DOWN IA) 7/27/11 PUMP BRINE DOWN IA (IN PROGRESS) 7/30/11 PUMP BRINE DOWN TUBING 7/31/11 PUMP BRINE DOWN TUBING (IN PROGRESS) 8/1/11 Pump Brine Down Tubing (In Progress) 8/2/11 LOAD WELL WITH BRINE. IN PROGRESS. 8/3/11 LOAD BRINE TO WELL. 8/4/11 LOAD WELL WITH BRINE. 8/5/11 LOAD WELL - BRINE. 22 BBL IN. 6.93 BBL DIESEL OUT. 8/6/11 CONTINUE BRINE LOADING WELL. 11 BBL BRINE IN. 10.5 BBL DIESEL OUT. 8/7/11 CONTINUE BRINE LOADING WELL. BRINE LOADED INTO WELL. 27 BBLS. DIESEL RETURNS OUT OF WELL. 22 BBLS. 8/8/11 CONTINUE BRINE LOADING OPERATION. 7 BBLS BRINE INTO WELL. 6 BBLS MIXED BRINE AND DIESEL RETURNS. 8/9/11 CONTINUE LOADING WELL WITH BRINE. BRINE LOADED INTO WELL 1.5 BBLS. RETURNS FROM WELL 1 BBLS MIXED DIESEL AND BRINE. 8/10/11 CONTINUE BRINE LOADING WELL. TOTAL BBLS BRINE LOADED INTO WELL 4. TOTAL BBLS RETURNS FROM WELL 3.5. 8/11/11 CONTINUE LOADING BRINE. BRINE LOADED INTO WELL 1 BBL. — 10 GALLONS TO CONTROL LINE. RETURNS FROM WELL 1 BBL. 8/12/11 CONTINUE BRINE LOADING WELL. BRINE LOADED INTO WELL TOTAL= 1.5 BBLS RETURNS FROM WELL TOTAL= 1 BBL 8/17/11 PUMP BRINE DOWN IA, TAKE RETURNS UP THE TUBING. CONFIDENT THE TUBING IS FLUID PACKED WITH BRINE 60 MIN DD TEST, INITIAL T /I /O= 0/0/8, 30 MIN T /I /O= 5/7/8, 60 MIN T /I /O= 8/12/8 8/20/11 BLED T & IA. T FL 2 SF (DIESEL) IA FL @ SF (DIESEL) 9/1/11 MONITOR AND BLEED WHP. 9/4/11 INITIAL T = 0, IA = 15. BLED T AND IA TO 0 PSI ( GAS ) 9/6/11 T /I /O= 0/13/8. BLED IA 30 SECONDS ALL GAS TO 0 PSI. FINAL T /I /O= 0/0/8. 9/13/11 INITIAL T /I /O= 0/40/8; BLED IA, DIESEL 1GAL. SOME GAS, 2MIN. FINAL T /I /O= 0/0/8 . • Time Log & Summary ConocoPhillips Wellview Web Reporting Report Well Name: 2A - 07 Rig Name: NORDIC 3 Job Type: ABANDONMENT Rig Accept: 10/5/2011 9:30:00 AM Rig Release: 11/20/2011 11:00:00 PM Time Logs. , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/01/2011 24 hr Summary Release Rig From 3K -10 at Noon. Move Rig Camp from 3K -10 to 2A -Pad. Wait On Support Equipment for Rig Move. 12:00 17:00 5.00 MIRU MOVE MOB P Move Rig Camp from 3K -Pad to 2A -pad. 17:00 00:00 7.00 MIRU MOVE MOB T Waiting On Drilling Support Crew and Equipment. 10/02/2011 Begin moving Nordic Rig 3 from 3K -Pad to 2A -Pad. 00:00 14:00 14.00 MIRU MOVE MOB T Waiting On Support Crew and Equipment to set rig mats for move. 14:00 00:00 10.00 MIRU MOVE MOB P Rig Mats are in place and support personnel are assisting with moving the rig. Move Rig off of 3K -Pad and start mobilizing toward 2A -Pad. 10/03/2011 Continue moving Nordic Rig 3 to 2A -Pad. 00:00 05:00 5.00 MIRU MOVE MOB P Continue moving Nordic Rig 3 to 2A -Pad. Continue to Rig Mat Road as needed. 05:00 13:15 8.25 MIRU MOVE MOB P Stop Rig at the Oliktok Road Entrance for Field Wide Change Out, and Let Doyon 16 move from Z -pad to S -pad. 13:15 16:30 3.25 MIRU MOVE MOB P Continue moving Nordic Rig 3 to 2A -Pad. Continue to Rig Mat Road as needed. 16:30 19:30 3.00 MIRU MOVE MOB P Stop Rig at CPF3 Road Entrance for Field Wide Change Out. 19:30 00:00 4.50 MIRU MOVE MOB P Continue moving Nordic Rig 3 to 2A -Pad. Continue to Rig Mat Road as needed. 10/04/2011 00:00 05:00 5.00 MIRU MOVE MOB P Continue moving Nordic Rig 3 to 2A -Pad. Continue to Rig Mat Road as needed. 05:00 07:00 2.00 MIRU MOVE MOB P Stop Rig Move at CPF2 for Field Wide Change Out. 07:00 09:00 2.00 MIRU MOVE MOB P Continue moving Nordic Rig 3 from CPF2 to 2B -Pad. 09:00 16:00 7.00 MIRU MOVE MOB P Shuffle Rig Mats ahead of Rig. 16:00 18:00 2.00 MIRU MOVE MOB P Move Rig from CPF2 to 2A Access Road. 18:00 00:00 6.00 MIRU MOVE MOB P Shuffle Rig Mats on 2A Access road to 2A -Pad. Page 1 of 67 Time Logs 1 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/05/2011 24 hr Summary Finished moving the rig to 2A -07. Spot over the well, accept rig @ 0930. Rig up equip. Pull BPV, well appears to be dead. Re -set BPV and start to nipple down the tree. Bled 8 gallons of fluid from control line and pressures back up to 450 psi when shut in. Troubleshoot control line. 00:00 07:00 7.00 MIRU MOVE MOB P Continue moving Nordic Rig 3 to 2A -Pad. Continue to Rig Mat Road as needed. 07:00 08:30 1.50 MIRU MOVE OTHR P Load 11" 5M BOPE Stack in cellar - Operating time 08:30 09:00 0.50 MIRU MOVE SFTY P Rig On 2A -Pad. PJSM. 09:00 09:30 0.50 MIRU MOVE MOB P Call Out DSO. Spot Rig Over Well 2A -07. 09:30 12:00 2.50 COMPZ MOVE RURD P Accept Rig at 09:30 am. Spot Equipment and MU treating iron to kill tank. 12:00 15:00 3.00 COMPZ WHDBOSEQP P Reposition OA Valve in cellar. Had to remove bushing from OA valve to install bleed line connection to monitor OA pressure. 15:00 15:15 0.25 COMPZ WHDBO SFTY P PJSM with Valve crew. Discuss hazard with removing the BPV. 15:15 16:00 0.75 COMPZ WHDBO MPSP P Load Lubricator and Equipment to Rig Floor. 16:00 16:30 0.50 COMPZ WHDBO MPSP P Lubricate Out BPV. 16:30 17:15 0.75 COMPZ WHDBO OWFF P Monitor Well for 45 mins. 0 Pressure on TBG,IA and OA. 17:15 19:00 1.75 COMPZ WHDBO MPSP P Lubricate In BPV. Release Valve Crew and Un -load Lubricate System from Rig Floor. 19:00 23:00 4.00 COMPZ WHDBO NUND P Attempt to nipple Down Wellhead, slow going due to limited space in cellar. Bleeding control line. 23:00 00:00 1.00 COMPZ WHDBO OWFF P Bled 8 gallons from control line, obvious control line leak down hole. Shut in bled and control line builds up to 450 psi. Getting dirty diesel & well bore fluids out of the line. Call town engineer. Decided to bleed control line for an hour, monitoring fluid type and amount. 10/06/2011 Bled SSSV control line from 450 psi to O. ( -15 gallons bled back) Nippled down tree /nippled up BOP. Test BOPE 250/3000. Fish Blanking Plug. Pull BPV. Lost Prong from Blanking Plug retrieval tool on top of tubing hanger. 00:00 01:00 1.00 0 0 COMPZ WHDBO OWFF P Control line bled at a steady rate for 1 hour and suddenly bled to 0. Possible plugged line? Hook -up pump to control line, pump 1/2 gallon down with no problem. bled fluid back and to 0 psi. 01:00 03:15 2.25 0 0 COMPZ WHDBO NUND P Nipple down the tree, get control line plugged off. Get spools to adapt to the low well head. 03:15 03:30 0.25 0 0 COMPZ WHDBO SFTY P Conduct Pre -job for nipple up BOP. 03:30 07:00 3.50 0 0 COMPZ WHDBO NUND P Nipple up X -over and BOPE. Page 2 of 67 Time Logs 411 I Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 07:00 10:15 3.25 0 0 COMPZ WHDBO NUND P Align BOP Stack to Floor Opening. 10:15 12:45 2.50 0 0 COMPZ WHDBO NUND P PJSM. R/U Hoses and Gray -Lock connection from flow -cross and return lines for testing BOPE. 12:45 13:00 0.25 0 0 COMPZ WHDBO SFTY P PJSM. Discuss Hazard for testing BOPE. 13:00 18:00 5.00 0 0 COMPZ WHDBO BOPE P Fluid Pack BOP Stack and Test BOPE at 250/3,000 psi. RD Test equipment. Right to witness was waived by John Crisp at 12:50 hrs on 10- 04-11. 18:00 19:00 1.00 0 32 COMPZ WHDBO MPSP T RU and attempt to pull test plug, test plug pulling tool broke from dry rod. 19:00 23:15 4.25 0 0 COMPZ WHDBO MPSP T Standby for Fishing tools from Prudhoe. 23:15 00:00 0.75 0 32 COMPZ WHDBO FISH T PU MU Baker 5.875" OD overshot w/ 3 3/4" grapple, RIH to 32 -ft- POOH w/ blanking plug. 10/07/2011 Fish Prong from top of hanger. Pull tubing hanger and 222 -ft of corkscrewed 3 1/2" tubing. RIH with 5" OD bullnose to 85.5 -ft. RU E -line and RIH with Camera to 80 -ft. PU and RIH w/ 3 1/2" DP to 55 -ft. PU and RIH w/ 2 7/8" EUE 8rd tubing to 89 -ft. Circulate 20 bbls Fresh Water. RU Equipment for Camera Run. 00:00 01:00 1.00 32 32 COMPZ WHDBO MPSP P RU and pull BPV, noticed 8" L x 7/8" OD prong from blanking plug retrieval tool was missing and sitting on top of tubing hanger beside flange. 01:00 05:00 4.00 32 32 COMPZ WHDBO FISH T Made several attempts to fish prong from top of tubing hanger using multiple sized magnets and wire grabs. 05:00 05:30 0.50 32 32 COMPZ WHDBO MPSP T Set BPV. 05:30 07:30 2.00 32 32 COMPZ WHDBO FISH T RU slick -line grappels, attempt to retrieve lost prong from top of tubing hanger. Able to recover prong. Check for PSI, Pull BPV. 07:30 10:00 2.50 0 0 COMPZ RPCOM PULL P PJSM. Discuss hazard for un- landing hanger and tubing. M/U landing Joint w/ 8rd TIW on top, screw into Hanger. M/U to top drive. BOLDS. Pull Up Hole with tubing, seeing 15k drag at 55k total up weight. Able to turn tubing with chain tongs, call town for next step. Continue POOH with tubing, recover 222 feet of cork screwed tubing w/ control line. 6 joints total and 5 pups + 1 pup with hanger 10:00 10:30 0.50 COMPZ WELLPF OTHR T PJSM.Change Out Handling Equipment. 10:30 11:30 1.00 COMPZ WELLPF STRP T Wait On Order. Discuss finding with town Engineer. Call out E -Line. 11:30 12:00 0.50 COMPZ WELLPF PULD T PJSM. Pick -up and Make Up BHA #1, 5" OD bull nose w/ 4 3/4" OD x 2" ID bumper sub and jars on drill collars. 12:00 12:30 0.50 0 86 COMPZ WELLPF TRIP T RIH and Set down at 85.50' RKB, POOH Page 3 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:00 0.50 0 0 COMPZ RPCOM OTHR T Clean & Clear Rig Floor. Call for 150 bbls of Fresh Water. 13:00 15:00 2.00 0 0 COMPZ EVALWE ELOG T Wait on E -Line. 15:00 16:30 1.50 0 0 COMPZ EVALWE ELOG T E -Line crew and unit on location. Wait on Camera coming from Prudhoe. PJSM with Halliburton crew. 16:30 17:00 0.50 0 55 COMPZ EVALWE ELOG T RIH with Camera and en- counted fluid at 55 -ft, POOH and Stand -back E -Line equipment. 17:00 17:30 0.50 55 0 COMPZ WELLPF TRIP T RIH with 3.5" Drill Pipe and attempt another drift run while waiting on Fresh Water to clean the wellbore. Sat down at 55 -ft RKB- POOH. 17:30 18:30 1.00 0 0 COMPZ WELLPF OTHR T Change out handling equipment to 2 7/8 ", unload pipeshed 18:30 20:00 1.50 0 0 COMPZ WELLPF OTHR T Waiting on 2 7/8" EUE Tubing and Fresh Water. 20:00 21:00 1.00 0 0 COMPZ WELLPF PULD T Water and 2 7/8" pipe on location, bring in 2 7/8" EUE tubing, rack and tally. 21:00 22:15 1.25 0 89 COMPZ WELLPF TRIP T PJSM- PU MU and RIH with 2 7/8" 6.5# EUE 8rd Tubing to 89 -ft RKB, circulate 30 bbls fresh water. 22:15 23:15 1.00 89 0 COMPZ WELLPF OTHR T Leak noticed at auger box downshoot, 1/2 gal fresh water on pad behind cuttings box, security and appropriate supervisors notified, cleaned up, PIR generated. crack observed at downshoot flange in auger box. 23:15 00:00 0.75 0 0 COMPZ EVALWE ELOG T RU equipment for E -line camera run. 10/08/2011 RIH with Camera to 230 -ft RKB, No pictures. Set IBP. Dump 10 -ft sand on IBP and Test. ND BOP Stack. NU Hydratight Equipment. HSE- Wait on Doyon Rig 141 move from 1J-pad to 2A -pad prior to initiating casing growth procedure. 00:00 00:15 0.25 0 0 COMPZ EVALWE SFTY T PJSM with E -line Crew. 00:15 03:45 3.50 0 0 COMPZ EVALWE ELOG T Attempt RIH with 2.125" camera, trouble getting thru 2 7/8" tubing, stand back E -line, Pooh with 2 7/8" tubing, TIH with 3 1/2" IF muleshoe (1.79" oal x 4 3/4" OD on 1 joint of 3 1/2" DP. E -line RIH with Camera, unable to pass 34 -ft, move DP down 2 -ft, continue RIH with camera getting frequent pick up weights to 230 -ft RKB. POOH with no excessive drag. No Pictures, clarity of fluids to dense. RD E -line 03:45 04:00 0.25 0 0 COMPZ WELLPFSFTY T PJSM with Baker Rep, Hazards of running and setting IBP 04:00 05:00 1.00 0 0 COMPZ WELLPF PULD T Bring in Baker tools, PU MU 3 3/8" Baker IBP. 05:00 06:30 1.50 0 75 COMPZ WELLPF PACK T RIH with IBP on 3 1/2" DP to 75 -ft, start setting sequence for IBP. Good set, stack weight on IBP. POOH Page 4 of 67 Time Logs • Date From To Dur " S. Depth E. Depth Phase Code Subcode T Comment 06:30 08:00 1.50 75 55 COMPZ WELLPF PACK T PJSM. Load Sand to Rig floor. RIH and Dump 250# of sand on top of IBP. Let sand settle, RIH and Tag top of sand at 65' md. POOH 08:00 09:00 1.00 0 0 COMPZ WELLPF PULD T Offload Slick -line equipment + Baker Tools, clear floor of tools. 09:00 10:30 1.50 0 0 COMPZ WHDBO EQRP T Make Modification to BOPE. Change out LPR from 2 7/8" x 5" VBR to 7" Rams. 10:30 13:00 2.50 0 0 COMPZ WHDBO NUND T Nipple Down BOPE. 13:00 14:30 1.50 0 0 COMPZ WHDBO NUND T Remove cross over spool and spacer spool from casing head. 14:30 16:30 2.00 0 0 COMPZ WHDBO SFTY T PJSM- Discuss hazards associated with installing and use of Hydratight tool. Discussion of HSE issues of preforming Hydratight procedure during rig move, logistics and emergency support while road blocked. 16:30 18:00 1.50 0 0 COMPZ WHDBO NUND T Rig up Hydratight Casing Growth Control Equipment. 18:00 00:00 6.00 0 0 COMPZ WHDBOOTHR T Stand by for Doyon Rig 141 move from 1J -Pad to 2A -Pad. Clean and clear floors. Bring in Baker Fishing equipment. Will continue Hydratight procedure when road open for emergency response services. 10/09/2011 Continue to wait on Doyon Rig 141 move. Initiate Hydratight control of 7" Casing growth. Pull 7" Casing in tension (200k) and Set Slips. 10" total growth of 7" casing. NU Spool's and BOPE. 00:00 11:00 11.00 0 0 COMPZ WHDBO OTHR T Continue stand by for Doyon Rig 141 move from 1J -Pad to 2A -Pad. Clean and clear floors. Bring in Baker Fishing equipment. Will continue Hydratight procedure when road open for emergency response services. 11:00 13:00 2.00 0 0 COMPZ WHDBO NUND T PJSM. Start 7" CSG Hydratight growth process. Had a total of 7 inches of casing growth over 28 steps. Initial pressure 12,500 # Final pressure 500 #. 13:00 14:00 1.00 0 0 COMPZ WHDBO CUTP T PJSM. Pickup and MU 6.220" OD spear. Spear and Pull tension on 7" CSG to 125k, 150k, 175k and 200k, seen 3" of movement. 14:00 14:15 0.25 0 0 COMPZ WHDBO OTHR T Call and Discuss results with Town Engineer. 14:15 18:00 3.75 0 0 COMPZ WHDBO NUND T Nipple Up Spool + BOPE. ( Slips still installed in casing head on 7 ") Change out lower Rams from 7" to 2 7/9 x 5" VPR. 18:00 20:00 2.00 0 0 COMPZ WHDBO NUND T Nipple Down BOPE to add 2nd Spacer spool below double gate. 20:00 00:00 4.00 0 0 COMPZ WHDBO NUND T Nipple Up Spool + BOPE. ( Slips still installed in casing head on 7 ") Page 5 of 67 Time Logs I • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/10/2011 24 hr summary NU Spool and BOPE. Test BOPE Break's and VBR's against IBP 250/3000. Clean out Sand and Pull IBP. Drift to top of Tubing Stub with 2 7/8" Hydril 511 Tubing. Flush WellBore with Fresh Water. RU N2 and displace fluids from wellbore to 254 -ft. RU E -line. Run Camera to evaluate damaged Casing and Tubing Stub. 00:00 02:45 2.75 COMPZ WHDBO NUND P Continue to Nipple Up Spool + BOPE. ( Slips still installed in casing head on 7 ") Change out lower Rams from 7" to 2 7/9 x 5" VPR. 02:45 03:00 0.25 COMPZ WHDBO SFTY P Discuss hazards with aligning BOP stack to line up Riser. 03:00 05:00 2.00 COMPZ WHDBO NUND P Align BOPE with floor opening and install Riser. 05:00 06:30 1.50 COMPZ WHDBO NUND P PJSM. NU Choke, Kill Lines + Flow Riser and Bell Nipple. 06:30 08:30 2.00 COMPZ WHDBO BOPE P PJSM. Test Breaks 250/3000 psi + LPR with 2 7/8" and 3 1/2" Test Joints. Had two failure on XOver Spool. RD Test Equipment. Good Test 08:30 09:30 1.00 0 75 COMPZ WELLPF FCO T NU and RIH with C/O assembly down to top of sand top at 65 feet. Circulate out fill down to top of IBP at 75 feet at 2 bpm, 70 psi, pump 10 bbl High -Vis sweep around at same rate. Circulate until returns are clean. 09:30 13:30 4.00 75 0 COMPZ WELLPF PULL T Having problems latching IBP, call out for bigger guide shoe. New guide shoe on location. NU and RIH and Engage and Pull IBP at 75 feet, let elements relax PUH 5 feet monitor well for 10 minutes and POOH and lay down same. 13:30 13:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of Next steps for changing out the handling equipment and using 2 7/8" TBG. 13:45 14:30 0.75 0 254 COMPZ WELLPF PULD T C/O Handling Equipment. NU and RIH with 2 7/8" Hydril 511 TBG. Set down at 254' MD, try rotating to gain more footage, no luck. 14:30 15:00 0.50 254 254 COMPZ WELLPF CIRC T Circulate 12.1 KWF at 6 bpm, at 110 psi. Pump 5 Hole volume. Switch over to Fresh Water and circulate until clean fluid is seen at surface 6 bpm at 80 psi, 50 bbls. 15:00 18:00 3.00 254 254 COMPZ WELLPF OWFF T Space out pipe across BOPE, monitor well, wait on E -line and N2 unit to arrive. 18:00 18:15 0.25 254 254 COMPZ EVALWE SFTY P PJSM- Discuss Hazards with rigging up and preforming N2 displacement. 18:15 19:30 1.25 254 254 COMPZ EVALWE RURD T Rig Up Schlumberger N2 unit, Pressure test lines and equipment 2000 psi 19:30 20:15 0.75 254 254 COMPZ EVALWE CIRC T Begin N2 displacement to 254 -ft, 250 scfm at 110 psi, 2 Tubing /IA/OA volumes pumped. Rig Down N2 pump. 20:15 20:30 0.25 254 254 COMPZ EVALWE SFTY P PJSM- Discuss Hazards of E -line Rig Up and Camera Job. Page 6 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:45 1.25 254 250 COMPZ EVALWE RURD T Rig Up E -line camera unit. Pick Up with 2 7/8" Hydril 511 TBG 4 -ft. 21:45 00:00 2.25 250 252 COMPZ EVALWE ELOG T RIH with 1- 11/16" OD Camera, Fluid at 110 -ft, dip into fluid no picture - POOH and Rig Down E -line tools to rehead thru Grease Head. Run 2 7/8" Hydril TBG back down to 252 -ft. Bring tools to floor. Hotshot for EUE 8rd connection. Rig Up E -line Pump -in -Sub and Grease Head with N2 hard line.. 10/11/2011 Run Camera with N2 support to evaluate damaged Casing and Tubing Stub at 254 -ft. Caliper casing from 245 -ft to surface. Ran Dual string mills. Ran 5- 1/16" Bull Nose Mill and work 253.5 -ft to 254 -ft. Circulate hole from 254 -ft to fresh water. 00:00 00:15 0.25 252 252 COMPZ EVALWE SFTY P PJSM- Sim -ops. Discuss Hazards with E -line and N2 together. 00:15 00:30 0.25 252 252 COMPZ EVALWE PRTS T Bring Camera to floor. Pressure test lines and equipment 2000 psi. 00:30 02:00 1.50 252 253 COMPZ EVALWE ELOG T RIH with 1- 11/16" camera to fluid level at 43 -ft, bring on N2, 500 scfm at 120 psi, follow fluid in hole to 251 -ft, can see end of Hydril, dip into fluid at 252 -ft, picture goes dark, PUH to 250 -ft, appears to be water - POOH move TBG down to 2.53 -ft.No fluid returns this run. 02:00 03:45 1.75 253 116 COMPZ EVALWE ELOG T RIH w/ same to fluid level at 200 -ft, bring on N2 at 500 scfm, 120 psi and follow in to 250.6 -ft, same as before, step up N2 to 1000 scfm, 210 psi, move down to 251.6 -ft and get undefinable pictures of top of tubing stub, adjust light and position for a variety of pic's- POOH single down 4 joints Hydril and 16' 3 1/2" DP. 03:45 04:30 0.75 116 116 COMPZ EVALWE ELOG T RIH with Camera and exit end of Hydrill and 116 -ft, continue down to fluid level at 213 -ft, able to see collars, not able to determine if casing damaged or corkscrewed - POOH, with no over pull, swap over to 2 1/8" camera for more reflective light. 04:30 06:30 2.00 116 31 COMPZ EVALWE ELOG T RIH with 2 1/8" camera to fluid at 218 -ft, come on with N2 at 500 scfm, 300 psi, fluid moving down 1 fpm, 7" casing pressures up to 1100 psi and holding, fluid level at 238 -ft, no flow thru OA to kill tank, 7" casing holding 1100 psi- POOH, bleed 7" casing to 0 psi, single down last 4 joints Hydril. Page 7 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 10:30 4.00 31 31 COMPZ EVALWE ELOG T RIH with 2 1/8" Camera, record pictures from surface to 125 -ft, no damage to casing at 85 -ft, slightly corkscrewed- POOH, rehead for caliper, E -line crew change out, wait on caliper from KIC. 10:30 11:30 1.00 31 31 COMPZ EVALWE ELOG T PU 2 3/4" 40 arm Caliper and RIH, caliper 7" casing from 245 -ft to surface, Send data and discuss options with town. 11:30 12:00 0.50 31 31 COMPZ EVALWE OWFF T Monitor well prior to breaking down HES E line equipment. 12:00 14:00 2.00 31 31 COMPZ FISH RURD T RD HES Eline and RU rig floor for 3 1/2 DP. Bring BHA equipment to rig floor. 14:00 14:30 0.50 31 31 COMPZ FISH SFTY P Held PJSM with Baker Fishing hand and rig crew on build of BHA and dangers involved with mills, jars and bumper sub. 14:30 15:30 1.00 31 148 COMPZ FISH PULD T PU and MU BHA #6 and RIH to 52 -ft, set down, POOH and drop lower and upper string mill. RIH to 52 -ft and work thru to 90 -ft. Tagged up at 98 -ft and rotate thru at 40 rpm's and was able to work down to 148 -ft. 15:30 16:45 1.25 148 0 COMPZ FISH TRIP T POOH from 148 -ft and drop jar and bumper sub from BHA due to side load and poor fishing ability due to hole conditions. Pull 5 1/16" OD bull nose mill to surface and inspect - showed signs of shoulder wear. 16:45 17:45 1.00 0 253 COMPZ FISH TRIP T RIH with 5- 1/16" OD bull nose mill on 3 1/2" DP and tag up at 253.5 -ft (15.5 -ft in on jt# 8) 17:45 20:00 2.25 253 254 COMPZ FISH MILL T Obtain Parameters 40 rpm's @ 1,100 ft/lbs Torque, ROT wt 48k. Circ at 3 bpm at 70 psi. Tag up and begin milling at 17:55 hrs WOM 500 to 1k with 1,255 ft/lbs torque. Mill to 254.0 -ft, Torque on bottom 1350 ft/lbs. 20:00 20:30 0.50 254 254 COMPZ FISH OWFF T BD Top Drive, monitor well, static 20:30 21:00 0.50 254 0 COMPZ FISH TRIP T POOH from 254.0 -ft Up wt 50k, Lay Down BHA #6 21:00 22:00 1.00 0 254 COMPZ FISH OTHR P PJSM- Change over floors and RIH w/ Circulating string Mule shoe, 8 joints 2 7/8" Hydril 511 Tubing, XO, 16.5 -ft 3 1/2" DP 22:00 23:30 1.50 254 254 COMPZ FISH CIRC T Circulate Fresh Water 6 bpm at 50 psi, until) clean returns. 256 bbls 23:30 00:00 0.50 254 254 COMPZ FISH OTHR T Wait on E -line and N2 unit for Camera run. 10/12/2011 RU E -line Pump -n -Sub, grease head and N2 Unit . Displaced 12.1 ppg brine in well bore to fresh water. RIH w /camera to evaluate tubing stub. Complete evaluation. RD N2 Unit and HES E -Line. Displace hole back to 12.1 ppg KWF and monitor well. MU RBP, RIH and set at 60 -ft RKB would not test, PUH and set RBP w /top at 50 -ft RKB and test to 3000. Dumped 2 bags of sand on top of RBP. ND BOPE Page 8 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 254 254 COMPZ EVALWE ELNE T HES E -line and Schlumberger N2 unit and crew onsite. E -line rehead thru Grease Head for Camera. start bringing equipment to floor. 02:15 02:30 0.25 254 254 COMPZ EVALWE SFTY P PJSM- Sim -ops Discussed Rig up with HES and Schlumberger crews. 02:30 03:30 1.00 254 254 COMPZ EVALWE RURD T Rig Up HES Pump -in -Sub and Grease head. N2 unit to Rig. Hook up to pump Fresh Water first. 03:30 04:00 0.50 254 254 COMPZ EVALWE ELOG T RIH w/ 1- 11/16" Camera to 234 -ft, bring on water 3 bpm- 20 bbls, picture very poor- POOH to clean lens. 04:00 04:30 0.50 254 254 COMPZ EVALWE CIRC T Bring on N2, 500 scfm at 130 psi, work up to 1000 scfm at 160 psi, displace 2 hole volumes. 04:30 05:15 0.75 254 254 COMPZ EVALWE ELOG T RIH w/ 1- 11/16" camera with N2 assist at 1000 scfm, 160 psi, unable to see tubing stub at POOH- set down with circ string at 254 -ft and pick up 2 ". returns of 8 bbls 05:15 07:00 1.75 254 0 COMPZ EVALWE ELOG T RIH with 1- 11/16" camera to fluid level at 42 -ft, Bring on N2 at 500 scfm at 110 psi, get multiple snap shots at 250.5 -ft, adjusting N2 up to 1000 scfm at 160 psi and down to 250 scfm at 90 psi for best shots - POOH, confer with town on progress forward. 07:00 07:30 0.50 0 0 COMPZ FISH RURD T RD SLB N2 unit and HES E line unit 07:30 08:00 0.50 245 245 COMPZ FISH CIRC T Change hole over to 12.1 ppg KWF at 245 -ft. 08:00 09:00 1.00 245 0 COMPZ FISH PULD T POOH laying down 2 7/8 Hydril 511 string. 09:00 17:30 8.50 0 0 COMPZ FISH OWFF T Monitor well for flow while waiting on fishing tools to arrive from Dead horse for 3 hrs with No flow. Place well on trip tank for 1.5 hrs - lost 1.2 bbls. Continue to monitor well on trip tank while offsite equipment is being delivered to rig. 17:30 18:00 0.50 0 0 COMPZ FISH SFTY P PJSM- Discussed hazards of making up and running RBP with Baker Rep - Bring in Tools delivered from Prudhoe. 18:00 19:00 1.00 0 0 COMPZ WELCTL PULD T Pick Up / Make Up 5.97" OD Model 'G' Lock Set RBP. RIH and set top of RBP at 60 -ft RKB- POOH with Running tool. Attempt Pressure test unsuccessful. RIH with retrieving tool, release RBP, Reset RBP at 50 -ft RKB (Top)- POOH w/ Running tool. 19:00 21:00 2.00 0 0 COMPZ WELCTL PRTS T Rig Up and Test RBP X 7" annulus 3000 psi, lost 75 psi in 15 minutes, Rig Down test equipment. Page 9 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:30 1.50 0 0 COMPZ WELCTL OTHR T Pick Up / Make Up 7" casing test joint plus 5 -ft pup, RIH with Test joint to top of casing stub, dump 100# sand and allow to settle, POOH and lay down test joint. 22:30 22:45 0.25 0 0 COMPZ WHDBO SFTY P PJSM- Discussed Hazards associated with Nipple Down of BOPE. 22:45 00:00 1.25 0 0 COMPZ WHDBO NUND T ND BOPE at lowest flange to swap out lower spool for Tubing Head. 10/13/2011 ND BOPE. Cut Casing Stub. Spear and reland casing in tension. Install Tubing Head. Set Tubing Hanger and BPV, NU BOPE. Tested Tie Back Equipment. Set Riser. 00:00 02:00 2.00 0 0 COMPZ WHDBO NUND T ND BOPE at lowest flange to swap out lower spool for Tubing Head. 02:00 04:30 2.50 0 0 COMPZ WHDBO OTHR T Rig Up Wach's Cutter and cut 13 1/8" from casing stub leaving 2 13/16" stub looking up. The 7" casing grew approximately 3" inches after original stretch pulled on 10 -9 -11 - max growth of 10 ". 04:30 07:00 2.50 0 0 COMPZ WHDBO HOSO T PU MU 6.220" Spear, change out grapple, RIH and spear casing, pull 7" casing in tension up to 200k gained 1" of movement. Stub was too tall for tolerance in the bottom of the Tubing Head and too short to cut with Wachs cutter. Release spear and lay down same. 07:00 07:15 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with all involved on trimming off 7" CSG stub w/ cutting torch. Discussed having fire watch and hot work permit in place. 07:15 09:30 2.25 0 0 COMPZ WHDBO OTHR T Obtain all appropiate permits, Rig up to cut casing with torch. 09:30 10:30 1.00 0 0 COMPZ WHDBO OTHR T Suspend Cellar / Hot Work due to faulty switch on Multi -gas detector. Make calls for one to borrow. 10:30 12:00 1.50 0 0 COMPZ WHDBO NUND T Multi -gas detector on -site, sniff celllar and continue with cutting of 7" casing. NU Tubing Head. 12:00 13:00 1.00 0 0 COMPZ WHDBO PRTS T Test Tubing Head packoffs 250/1500 for 15 minutes. 13:00 18:00 5.00 0 0 COMPZ WHDBO NUND T Nipple up BOPE 18:00 21:00 3.00 0 0 COMPZ WHDBO NUND T Nipple Down BOPE, install 3 1/2" Tubing Hanger with pup and BPV in Tubing Head. 21:00 00:00 3.00 0 0 COMPZ WHDBO NUND T Nipple Up BOPE. Test each Tie Back (4- 3 Ton come - along's) with Dana gauge, each shared average 3000 ft/lb force to pull BOPE into place to line up to Rig floor for Riser instalation, Set Riser. 10/14/2011 Pull BPV and Tubing Hanger. Shell Test 250/3000 and Chart. Set Test Plug. Conduct Weekly BOPE Test 250/3500. Rig Repair Faulty Evacuation Alarm. Repair Auger Shoot on Rig. Pull Test Plug. Pull RBP. MU and attempt to RIH with 5 1/2" Concave Junk Mill on Drill Collars. Page 10of67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 COMPZ WHDBO HOSO T Pull BPV. PU 1 joint DP, BOLDS, RIH and Pull 3 1/2" Tubing Hanger to Floor. 00:30 01:30 1.00 0 0 COMPZ WHDBO PRTS P Rig up test equipment. Conduct Shell Test against RBP x 7" casing 250/3000, Chart same. 01:30 07:45 6.25 0 0 COMPZ WHDBO BOPE P MU and RIH with 7" Test plug and Set. Conduct weekly BOPE test 250/3500 psi. 24 notice was given at 09:50 hrs on 10 -12 -11 and Right to witness was waived at 09:55 hrs by Matt Herrera. RD test equipment. 07:45 13:00 5.25 0 0 COMPZ WHDBO SFTY P Called Doyon 141, Security and DSO and informed them that we would be holding a Rig Evacuation drill. Contacted driller to sound alarm - alarm failed, had rig crew and third party show up at safe briefing area. Discussed the findings - suspended operations till siren alarm was replaced and functioning. Looked into fixing cuttings chute while waiting for siren to arrive and be installed. Siren alarm was installed and function tested at 13:00 hrs - working properly. 13:00 21:30 8.50 0 0 COMPZ RIGMNT RGRP T Continue to fix cuttings chute while well was still in secured position. 21:30 21:45 0.25 0 32 COMPZ WHDBO SFTY P PJSM- Discussed pulling Test plug to floor and continuing on with milling operations. 21:45 22:00 0.25 32 0 COMPZ WHDBO PULL P Pull Test Plug to floor, lay down and kick out. 22:00 23:00 1.00 0 50 COMPZ FISH CIRC T PU MU Baker Retrieving Head and RIH on DP to 45 -ft, Circulate tong way 5 bpm, ease in hole to 50 -ft, engage, release and pull RBP to floor, lay down, kick out same. 23:00 23:30 0.50 0 0 COMPZ FISH OWFF T Monitor well, lost 1/10 bbl in 30 minutes, Diesel migrated to surface. 23:30 00:00 0.50 0 98 COMPZ FISH TRIP T PU MU 5 1/2" Concave Junk Mill - 10-ft 3 1/2" DP Pup, 1 Stand of 4 3/4" DC's and RIH, rotate in 23 -ft on 3rd joint of DC's- POOH 10/15/2011 MU and RIH with 5 1/2" Concave Junk Mill on 3 1/2" Drill Pipe. Mill on Tubing Stub at 254 -ft. RIH with 5" Bull Nose Mill. RU E -line and run Camera. Monitor well. 00:00 00:15 0.25 98 14 COMPZ FISH PULL T POOH with 5 1/2" Concave Junk Mill - 10-ft 3 1/2" DP Pup, 1 Stand of 4 3/4" DC's from 98 -ft, change Drill Collars over to 3 1/2" Drill Pipe. 00:15 00:30 0.25 14 254 COMPZ FISH TRIP T RIH with 5 1/2" Concave Junk Mill - 10-ft Pup- 8 joints of 3 1/2" DP. Page 11 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 04:00 3.50 255 0 COMPZ FISH MILL T Obtain Parameters 40 rpm's @ 1,450 ft/Ibs Torque, ROT wt 48k. Circ at 3 bpm at 70 psi. Tag up and begin milling at 00:40, WOM 2k to 3k with 2150 ft/Ibs torque. Mill to 254.5 -ft, Torque on bottom 2200 to 2700 ft/Ibs. POOH with Mill, Face worked 3/8" in from edge, moderste wear on outside of mill above centralizer fins, pictures in file. 04:00 04:30 0.50 0 0 COMPZ FISH OWFF T Monitor Well, No loses of any fluids. confer with town. 04:30 05:15 0.75 0 254 COMPZ FISH TRIP T PU MU 5" Bull Nose Mill on 3 1/2" DP and RIH. 05:15 06:30 1.25 254 255 COMPZ FISH MILL T Obtain Parameters 55 rpm's @ 1000 ft/Ibs Torque, ROT wt 48k. Circ at 3 bpm at 70 psi. Tag up at 254.0 and begin milling at 05:25, WOM 2k to 3k with 1500 ft/fbs torque. Circ pressure fluctuating 70 to 130 psi. Milled down to 255 -ft. 06:30 07:00 0.50 255 255 COMPZ FISH CIRC T Circulate bottoms up at 5 bpm at 110 psi. BDTD 07:00 07:30 0.50 255 0 COMPZ FISH TRIP T POOH w/ mill from 255 -ft. 07:30 08:30 1.00 0 255 COMPZ FISH PULD T PU and MU 2 7/8" 511 Hydril mule shoe on 9 jts to 255 -ft. and tag up on fish. 08:30 09:00 0.50 255 255 COMPZ FISH OWFF T monitored well while gathering space out pups. 09:00 11:30 2.50 255 254 COMPZ FISH HOSO T Space out to place TBG hanger 4 -ft under upper pipe rams for room to move during reverse out with N2 blowdown for camera run. 11:30 12:00 0.50 254 254 COMPZ WELCTL OTHR T Clear 2" kill fine to return tank with air. Flush rig circulate system with 27 bbls fresh water to kill tank 12:00 12:30 0.50 254 254 COMPZ WELCTL PRTS T Pressure test 2" kill line at 250 / 3,500 psi and chart. 12:30 13:00 0.50 254 254 COMPZ FISH CIRC T Circulate well over from 254 -ft displacing out 12.1 ppg Sodium Bromide with 100 bbls of fresh water at 4 bpm at 60 psi and recovered 97 bbls into pit#1. 13:00 14:30 1.50 254 254 COMPZ EVALWE OTHR T RU 2" hard line from TBG to choke manifold 14:30 14:45 0.25 254 254 COMPZ EVALWE SFTY P Held PJSM with SLB N2 and rig crew on rigging up to IA. 14:45 16:30 1.75 254 254 COMPZ EVALWE OTHR T RU N2 Unit to IA, Pressure test treating line. Pump 1,211 cu ft of N2 down IA, taking returns through choke to kill tank. Max pressure seen on IA = 250 psi and TBG 150 psi. Recovered 13 bbls. SWI with 60 psi on IA and 40 psi on TBG. RD line from TBG to choke manifold. 16:30 16:45 0.25 254 254 COMPZ EVALWE SFTY P Held PJSM with e line Page 12 of 67 Time Logs • ` Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:30 1.75 254 254 COMPZ EVALWE RURD T Rig up HES E -line equipment, Bring Camera to floor for Camera run #3. 18:30 20:00 1.50 254 250 COMPZ EVALWE ELOG T RIH w/ 1- 11/16" camera, found fluid at 249 -ft, pressure system up to 200 psi, RIH to 252.6 -ft, decent pictures of what appears to be top of tubing stub, POOH, bleed down system, pick up 2 7/8" Hydril 4 -ft to 250 - -ft, clean lens and light on camera. 20:00 21:30 1.50 250 250 COMPZ EVALWE ELOG T Bring on N2, pressure system up tp 200 psi. RIH w/ 1- 11/16" camera, fluid at 252 -ft, bring on N2 and pressure system up to 250 -ft, fluid drops to 255 -ft, obtain good clean pictures of 7" casing and tubing stub - POOH and confer with town. 21:30 22:00 0.50 250 250 COMPZ WELCTL RURD T Rig Down HES E -line and SLB N2 unit. 22:00 00:00 2.00 250 250 COMPZ WELCTL OWFF T Change well over to 12.1 brine, 22 bbls to fill 9 bbl system, put on trip tank and monitor well. fliud loses 7/10 bbl in first hour, 1/10 bbl in second hour. 10/16/2011 Monitor well, next step forward TBD. Single down 2 7/8" Hydril tubing. Establish Communication IA / OA, Circulate 1.5 volumes down OA with 1:1 returns up 7 ". Monitor Well, Static. Attempt set 3 -3/8" IBP at 85 -ft. 00:00 15:00 15.00 250 250 COMPZ WELCTL OWFF T Well on trip tank, monitor well. fluid loses overall for 15 hrs 1.2 bbls 15:00 15:15 0.25 250 250 COMPZ WELCTL SFTY P PJSM- Discuss confined entry, Pull permits. 15:15 17:30 2.25 250 0 COMPZ WELCTL PULL T POOH single down 2 7/8" Hydril 511 tubing from 250 -ft. 17:30 17:45 0.25 0 0 COMPZ WELCTL SFTY P PJSM- discussed hazards with circulating out OA 17:45 19:00 1.25 0 0 COMPZ WELCTL CIRC T Rig up lines to OA, IA thru Mud Cross to cuttings box, pressure test lines and equipment 1000 psi. 19:00 20:30 1.50 0 0 COMPZ WELCTL CIRC T Establish Injection rate down OA 1 bpm at 70 psi, 2 bpm at 70 psi, 3 bpm at 70 psi and 4 bpm at 90 psi, 1:1 returns thru out circulating, 26 bbls of 12.1 ppg brine total pumped. Shut down and monitor well, static on 7 ", 50 psi on OA, bleed OA to 20 psi, small amount of gas then to fluid, 20 psi hydrostatic difference due to 33 -ft difference in Pit Tank Level and valve on OA, monitor well, 30 minutes 7" static, OA 20 psi. 20:30 21:30 1.00 0 0 COMPZ WELCTL PULD T Bring in and MU 3 3/8" IBP (S /N# 11719947) on 3 1/2" DP and RIH to 85 -ft (top of IBP) run thru setting sequence, sheared at 2890 psi - POOH w/ setting tools. 21:30 22:30 1.00 0 0 COMPZ WELCTL OTHR T BDTD- dump 200# sand on top of IBP and let settle, bleed OA from 20 psi to 0 psi (fluid) 7" static. monitor well. Page 13 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:15 0.75 0 0 COMPZ WELCTL PRTS T Attempt to pressure test IBP, pressure up to 300 psi then dropped off, 40 psi on OA, IBP did not set. 23:15 00:00 0.75 0 100 COMPZ WELCTL FISH T PU MU 5 3/8" IBP Retrieving Head and RIH to 100 -ft. 10/17/2011 Fished IBP at 246 -ft. Set IBP at 85 -ft and test. Dump Sand on IBP. Cut 7" Casing. Monitor well, Gas to surface on OA. Pull IBP. 00:00 01:30 1.50 246 0 COMPZ WELCTL FISH T Continue TIH with 5 3/8" IBP Retrieving Head from 100 -ft, Latched IBP at 246 -ft, POOH with 3 3/8" IBP, IBP did not inflate. 01:30 03:00 1.50 0 0 COMPZ WELCTL OWFF T Wait on IBP from Prudhoe. Monitor well on trip tank, OA shows 20 psi hydrostatic pressure. 03:00 04:30 1.50 96 0 COMPZ WELCTL PACK T Bring in Baker tools, PU MU 3 3/8" IBP and TIP to 96 -ft, top of IBP at 85 -ft, Start setting sequence 1000, 2000 and 2800 psi for 5 minutes each, setting tool sheared at 3790 psi- POOH 04:30 05:00 0.50 0 0 COMPZ WELCTL PRTS T Pressure 7" to 1000 psi, chart. Bleed OA from 20 psi to 0 psi, OA holding 0 psi. 05:00 06:30 1.50 0 0 COMPZ WELCTL OTHR T Pick Up 7" test joint with 6 -ft pup, set on top of tubing hanger, Dump 200# 20/40 river sand on IBP, let settle. 06:30 07:00 0.50 0 0 COMPZ FISH SFTY P Held PJSM on MU of Baker 4 1/8" Multi string cutter 07:00 08:00 1.00 0 0 COMPZ FISH CPBO T PU MU 4 -1/2" M/S cutter on 1 stand DP. RIH to 83 -ft and tag "No Sand ", PU to 35 -ft and bring pump on line at 2.3 bpm at 300 psi. Slide in hole looking for 7" CSG Collar at 45 -ft pit room reported that sand was coming over shakers. Stop pumping and POOH with M/S cutter and lay down same. 08:00 10:00 2.00 0 0 COMPZ FISH TRIP T RIH to 83 -ft and change hole over to fresh water, POOH. PU 7" test jt and RIH and set on 7 1/16 x 11" DSA. Dump 5 sacks of 20/40 sand over 30 minute period. Lay down 7" test jt. 10:00 11:00 1.00 0 75 COMPZ FISH TRIP T PU and MU 4 1/8" OD M/S cutter, RIH to 75 -ft, 30 minutes to cut 7" casing at 73 -ft- POOH. 11:00 16:30 5.50 75 0 COMPZ FISH OWFF T BDTD, Monitor well on Trip Tank, 50 psi on OA, Bleed to 0 psi, Oa at 30 psi in 5 minutes, weight up fluids in pits to 12.1 ppg visc. brine. 16:30 17:00 0.50 0 0 COMPZ FISH CIRC T Load OA with 13 bbls of 12.1 ppg visc. brine with charge pump. Page 14 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 23:00 6.00 0 0 COMPZ FISH OWFF T Monitor well on Trip Tank, 19.5 bbls in TT, 20 psi on OA, 18.6 in TT at 18:15, 20 psi on OA, small amount of gas, 18.5 bbls in TT at 20:00, 20 psi on OA, small amount of gas. 18.5 bbls in TT @ 22:30, 20 psi on OA with small amount of gas that sets off LEL on sniffer. 23:00 23:15 0.25 0 0 COMPZ FISH SFTY P PJSM- PU MU of IBP retrieving BHA with Baker Rep. 23:15 00:00 0.75 0 79 COMPZ FISH TRIP T PU MU and TIH with Retrieving Head, tag casing cut at 73 -ft, rotate 90 deg. and tag TOS at 79 -ft, 10/18/2011 Set Pump Thru Packer. Circulate 1 1/2 times volume 12.1 ppg Visc. Brine thru Pump Thru Packer, returns out OA to cuttings box. Monitor Well. Pull Pump Thru Packer. Set IBP. ND BOPE 00:00 01:00 1.00 79 86 COMPZ FISH PULL T Tag TOS at 79 -ft, wash sand from IBP, engage IBP and POOH with 3 3/8" IBP, no problems back thru casing cut. Lay down IBP and kick out for redress to rerun. 01:00 02:00 1.00 0 0 COMPZ FISH PULD T Bring in and MU Baker 3 1/2" Pump Thru Packer. 02:00 03:00 1.00 0 85 COMPZ FISH PACK T TIH with Pump Thru Packer to 85 -ft, run Packer setting sequence, pressure up to shear bottom sub at 1380 psi. 03:00 03:45 0.75 85 85 COMPZ FISH CIRC T Circulate 26 bbls of 12.1 ppg visc brine thru packer up OA to cuttings box, 1:1 returns. 03:45 05:00 1.25 85 85 COMPZ FISH OWFF T BDTD. Monitor well, 17.9 bbls in trip tank, 20 psi on OA at 03:45. 05:00 07:30 2.50 85 85 COMPZ FISH OWFF T 17.8 bbls in trip tank, 20 psi on OA, very small amount of gas, rig up 2" hose from OA to choke, monitor well. 07:30 09:00 1.50 85 85 COMPZ WELCTL CIRC T Cleared 7" x 9 5/8" annulus from surface to 73 -ft with 12.1 ppg Non - viscousified Sodium Bromide. Then displace well bore from 255 -ft to surface with 12.1 ppg Non - viscousified Sodium Bromide. Circulating down through Baker Inflatable packer at 85 -ft and through hole in 7" casing at 255 -ft. Returning up 7" x 9 5/8" annulus and back into 3 1/2" x 7" annulus at mechanical cut at 73 -ft and back to surface. Blow down Top drive with well shut in. 09:00 10:00 1.00 85 85 COMPZ WELCTL OWFF T With well shut in, check OA bleeder and had some gas with 20 psig on gauge. Open annular to monitor well on Trip tank with 29.6 bbls, OA pressure rising to 31 psig and falling back to 12 psig, checking OA bleeder and having some gas. Page 15 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 85 85 COMPZ WELCTLCIRC T Circulate down IA taking returns up the OA to Choke manifold thru gas buster at 70 psi with charge pump - returning gas and 12.1 ppg Sodium Bromide. 12:00 14:15 2.25 85 85 COMPZ WELCTL OWFF T With well shut in, check OA bleeder and had some gas with 12 psig on gauge. Open annular to monitor well on Trip tank at 30.0 bbls, loosing 2/10 bbl in this interval. OA pressure staying at 12 psig , checking OA bleeder showing signs of diesel and some gas. 14:15 16:15 2.00 85 85 COMPZ WELCTLCIRC T Circulate down IA taking returns up the OA to Choke manifold thru gas buster at 70 psi with charge pump - returning gas, diesel and 12.1 ppg Sodium Bromide. 16:15 19:30 3.25 85 85 COMPZ WELCTL OWFF T With well shut in, check OA bleeder and had some gas with 12 psig on gauge. Open annular to monitor well on Trip tank at 29.9 bbls, loosing 1/10 bbl in this interval. OA pressure staying at 12 psig , checking OA bleeder showing signs of black diesel, Arctic pack and some gas. 19:30 21:30 2.00 85 85 COMPZ WELCTLCIRC T Circulate down IA taking returns up the OA to Choke manifold thru gas buster at 70 psi with charge pump - returning gas, diesel and 12.1 ppg Sodium Bromide. 21:30 23:30 2.00 85 85 COMPZ WELCTLOWFF T With well shut in, check OA bleeder and had some gas with 12 psig on gauge. Open annular to monitor well on Trip tank at 30.4 bbls, loosing 1/10 bbl in this interval. OA pressure staying at 12 psig , checking OA bleeder showing signs of black diesel, Arctic pack and some gas. 23:30 00:00 0.50 85 85 COMPZ WELCTL CIRC T Change circulating route Circulate down Drill Plpe taking returns up the OA to Choke manifold thru gas buster at 70 psi with charge pump. 10/19/2011 Monitor Well. Centinue to circulate out a small amount of Gas, Diesel, and Arctic Pac. OAP = 12 psi. Continue to monitor Well. Discuss plan forward with Anchorage Engineering Team. Continue to circulate and monitor. 00:00 02:30 2.50 85 85 COMPZ WELCTLCIRC T Continue to circulate down the Drill Plpe and taking returns from the OA. Still using just the Charge Pump at —70 psi. shut down circulating to once again monitor Well. Blow down Top Drive. Page 16 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:30 1.00 85 85 COMPZ WELCTL OWFF T Monitor Well with same results as circulating down the IA and returning back up the OA. Fresh Water entering into the Cellar Box from the Pad, has slowed down to — 0.9 bph. Continue to monitor. 03:30 06:00 2.50 85 85 COMPZ WELCTLCIRC T Change circulating route once again. Now circulating 12.1 lb/gal Sodium Bromide down the OA with the charge pump at —70 psi taking returns up the Drill Plpe. 06:00 11:30 5.50 85 85 COMPZ WELCTL OWFF T Monitor well on Trip tank w/ 4/10 bbl loss while building 30 bbls of 12.1 ppg 3 lb/bbl flo visc plus 11:30 12:30 1.00 85 85 COMPZ WELCTL CIRC T Displace well to 255 -ft with 30 bbls of 12.1 ppg 3 lb/bbl flo visc plus 12:30 16:30 4.00 85 85 COMPZ WELCTL OWFF T Monitor well on Trip tank w/ 6/10 bbl loss while building 35 bbls of 12.1 ppg 3 lb/bbl flo visc plus 16:30 17:00 0.50 85 85 COMPZ WELCTLCIRC T Reverse circulate well to 255 -ft with 36 bbls of 12.1 ppg 3 lb/bbl flo visc plus down OA taking returns back thru the DP. We saw diesel returns at 7 1/2 bbls pumped - by strap with recovered 6 bbls of diesel. 17:00 17:30 0.50 85 85 COMPZ WELCTL OWFF T Monitor Well. Blow down Top Drive. OAP = 22 psi. Bleed gas down to 14 psi. Well drank 2 bbls from Trip Tank. 17:30 19:30 2.00 85 85 COMPZ WELCTLCIRC T Pump down the Drill Pipe at 1.0 bpm/70 psi., taking returns from the OA. Blow down Top Drive. 19:30 23:00 3.50 85 85 COMPZ WELCTL OWFF T Monitor Well. Build 100 bbls of clean 12.1 lb/gal HI -Vis Sodium Bromide in Pits. Checked OA every 15 minutes. Bleed small amount of gas. Shut well in and the pressure would climb back to 14 psi (hydrostatic pressure of the fluid weight in the BOP Stack to the OA Valve). During the last hour 1.5 checks, no gas was observed. 23:00 00:00 1.00 85 85 COMPZ WELCTLCIRC P PJSM. Begin to circulate clean 12.1 Ib.gal HI -Vis Sodium Bromide down the OA at 1.0 bpm/70 psi, taking returns up the Drill Plpe. 10/20/2011 Continue to circulate out a small amount of Gas, Diesel, and Arctic Pac. OAP = 14 psi. Continue to monitor Well. Inject 12.1 lb/gal Hi -Vis Sodium Bromide into the Outer Annulus at 0.25 bpm x 110 psi. x 20 total barrels. Monitor Well. ND 7 1/16" Tubing Spool and BOP Stack. NU 11" Tbg Spool and BOP Stack. 00:00 01:00 1.00 85 85 COMPZ WELCTLCIRC T Continue circulating 12.1 lb/gal Hi -Vis Sodium Bromide. Total of 80 barrels circulated. Shut down Pump. Blow down Top Drive. Shut in Drill Pipe. Page 17 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:45 0.75 85 85 COMPZ WELCTL CIRC T Bring Pump on line at 0.25 bpm and begin to inject 12.1 lb/gal HI -Vis Sodium Bromide down the Outer annulus. Pressure climbed to 142 psi. Broke back to 120 psi. Then leveled off at 110 psi. continued to inject at 0.25 bpm /110 psi. Shut down pump after 10 barrels away. 01:45 02:00 0.25 85 85 COMPZ WELCTL OWFF T Monitor pressure fall -off. ISIP = 80 psi. Stabilized at 60 psi. 02:00 02:45 0.75 85 85 COMPZ WELCTL CIRC T Bring Pump back on line at 0.25 bpm /110 psi. Injected an additional 10 bbls. Shut down Pump with a total of 20 barrels injected. (Note: no sign of any fluid increase in the Cellar Box or in the Well Cellars next to Rig on either side). 02:45 03:30 0.75 85 85 COMPZ WELCTL OWFF T Monitor pressure fall -off. ISIP = 80 psi. After 15 minutes = 55 psi. After 45 minutes = 40 psi 03:30 07:30 4.00 85 85 COMPZ WELCTL OWFF T Slowly bleed remaining pressure off of the OA from 40 psi to 0 psi (30 minutes) observed no Gas. Shut in Well. Line up Trip Tank. Begin to monitor Well every 15 minutes for pressure, Gas, and any fluid losses. 07:30 08:30 1.00 85 85 COMPZ WELCTL CIRC T Pump 10 bbls of 12.1 ppg viscous Sodium Bromide down IA and returning up OA at 70 psi ICP;FCP to vacate void. Close annular and pump 20 bbls of 12.1 ppg viscous Sodium Bromide down OA and returning up DP at 90 psi ICP; FCP. 08:30 09:00 0.50 85 85 COMPZ WELCTL OTHR T Bull head 1/2 bbl at .25 bpm at 70 psi ICP and 130 psi FCP. Shut down pumping ops and SWI at 80 psi. bled down to 40 psi in 30 minutes. 09:00 09:30 0.50 85 85 COMPZ WELCTL OWFF T shut well back in 20 psi TBG and 16 psi OA. monitor for pressure build. - static 09:30 10:30 1.00 85 0 COMPZ WELCTL PACK T Open up well, Equalize pip at 15k and Release PIP at 50k allow element to relax. Monitor well for 30 minutes. POOH and lay down PIP. 10:30 13:00 2.50 0 0 COMPZ WELCTL OWFF T Monitor well for 15 minutes - Static, Drain stack. Monitor IA and OA into 5 gallon buckets - no flow 13:00 13:30 0.50 0 0 COMPZ WELCTLTHGR T MU and RIH with 3 1/2 x 7 1/16 TBG hanger with "F" type BPV installed. RILDS 13:30 13:45 0.25 0 0 COMPZ WHDBO SFTY P PJSM on ND BOPE Page 18 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 16:00 2.25 33 33 COMPZ WHDBO NUND T Flush stack with fresh water, pull riser and ND BOP at CMT cross. Pull remainder of fluid from below mud cross to top TBG hanger. ND TBG Spool and remainder of space out spools. BOLDS on 7" pack off. 33 73 COMPZ FISH FISH T Spear and pull 7" CSG, remove pack off and slips. Lay down cut joint. 16:00 21:30 5.50 33 33 COMPZ WHDBO NUND T PU and install FMC 11" 3M x 11" 5M TBG Spool with 3 1/2" x 11" TBG hanger with Type "H" BPV installed. Nipple up 11" BOP Stack. 21:30 23:00 1.50 33 33 COMPZ FISH PULD T PJSM. Release Casing Spear. Lay down the 7" Casing Fish (30.23 -ft Landing Joint and a 3.20 -ft Cut Off Stub. Overall 39.43 -ft recovered). Lay down Casing Spear. 23:00 00:00 1.00 33 33 COMPZ WHDBO PLUG T PJSM. Pick -up Landing Joint. BOLDS. Pull Tubing Hanger w/ BPV. Lay down same. 10/21/2011 Run 9 5/8" CSG Scraper. Set 9 5/8" RBP. Shell test BOP. Pull 9 5/8" RBP. Set Test Plug and perform weekly BOPE Test.. PU 7" Csg Spear. Pull Casing free from 255 -ft. Call -out Casing Crew. 00:00 01:00 1.00 0 0 COMPZ RPEQPITRIP T PJSM. Pick -up BHA #23, 9 5/8" Casing Scraper. Run in to 70 -ft on 3 1/2" Drill Pipe. POOH. Lay down BHA. 01:00 01:30 0.50 0 0 COMPZ WELLPF OTHR T Wash stack with swizzle stick 01:30 06:00 4.50 0 38 COMPZ RPEQP1 PRTS T Pick -up BHA #24, Baker 9 5/8" Model G Lock -Set Retrievable Bridge Plug. RIH and attempt to get to a target depth of 60 -ft. However, unable to get that deep due to 9 5/8" Casing damage. Set RBP at 48 -ft. (Top of RBP elements at 12 -ft below the 9 5/8" LDS). Attempt to pressure test, however fluid was being injected away at 130 psi. Released RBP after several attempts. POOH and inspected, OK. Ran RBP back in at set with the top element at 4 -ft below the 9 5/8" LDS. Perform BOP Shell Test and test the 9 5/8" Flange at 250/1,500 psi. Good. Record on Chart. 06:00 07:00 1.00 38 0 COMPZ WELLPF PACK T RIH and Release RBP and POOH laying down 6 1/4" OD DC and RBP. 07:00 08:30 1.50 0 0 COMPZ WHDBO OTHR P RIH and Set 11" FMC upper Test plug, Drain stack and open Lower Pipe ram cavities and change out from 2 7/8 x 5" VBRs to 7" Solid bodies. Page 19 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 17:00 8.50 0 0 COMPZ WHDBO BOPE P Conduct weekly BOP Test at 250 / 3,500 psi with 3 1/2, 7" and 2 7/8" Test joints. Test kill line at 250 / 3,500 psi. Test gas monitors. The State's right to witness the test was waived by B. Noble. 17:00 17:30 0.50 0 0 COMPZ WELLPF BOPE P Rig down test equipment. Pull Test Plug. Install Wear Bushing. 17:30 21:00 3.50 73 247 COMPZ FISH FISH T Make -up BHA # 25, ITCO 7" Casing Spear. Run in to the top of the 7" Casing Stump at 73 -ft. Up Weight 42K. Down Weight 42K. Work Spear Assembly to enter. No -Joy. Pull out and lay down Spear Assembly. Pick -up BHA #26, ITCO 7" Casing spear w /Mule Shoe Joint on the bottom of the Spear. Run in and tag the top of the 7" Casing. After several attempt, Mule Shoe entered the top of the Casing. Continue on down. Plant Casing Spear. Pick -up to 100K. Casing pulled free from - 255 -ft. However dragging and chattering. Pull Casing up -hole 8 -ft and position a Drill Pipe Tool Joint at Rig Floor. Attempt to go back down hole. No -Joy. Leave Tool Joint at working floor height. 21:00 00:00 3.00 247 247 COMPZ FISH FISH T Call out Casing Crew. Prep to rig up Doyon Casing Services. Ready Pipe Shed to lay down Casing. 10/22/2011 RU 7" Casing Equipment. Single down 7" "corked- screwed" Casing from 255 -ft. Rig -up E -Line and record Video Logs. Decision will be made on the next BHA after reviewing Video Logs. Record a 40 -Arm Caliper Log in the 9 5/8" Casing. 00:00 02:30 2.50 247 247 COMPZ WELLPF RURD T Casing Crew arrived on Location. Bring equipment to the floor. Rig up 7" Casing handling equipment. Page 20 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 07:30 5.00 247 0 COMPZ FISH FISH T PJSM. Continue to pull 7" Casing. 80 -100K dragging and chattering. Spear released with top of Casing at — ground level. Pull Spear and inspect Grapple. Good. Run back in and plant Spear again. Continue pulling first joint of Casing. Dragging. Spear to the floor. Continue pulling. Noticed Spear trying to release due to Casing trying to turn counter clock -wise. Re -set Spear in full position and continue pulling (with much caution) to first Casing Collar. Break -out and lay down Spear Assembly and first "cork- screwed" Joint. Change over to 7" Casing Elevators. Continue to single down remaining 7" Casing. RD CSG Equipment. PU and Rih w/ test plug . PU and RIH w/ fish and release spear, POOH and lay down 7" jt and break down spear and lay down same. 07:30 07:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM on changing LPR's from 7" Solid bodies to 2 7/8 x 5" VBR's and testing same. 07:45 09:30 1.75 0 0 COMPZ WHDBO BOPE T Set test plug. Change LPR's 7" Solid bodies to 2 7/8 x 5" VBR's and test w/ 3 1/2 test jt at 250 / 3,500 psi. Pull test plug and install wear ring 09:30 11:00 ; 1.50 0 249 COMPZ FISH TRIP T RIH w/ 3 1/2 IF Bull nose on 8 jts of 3 1/2 DP and tag up at 252 -ft. Space out to have full jt of dp across BOPE and 3 -ft off bottom to 249 -ft. for camera run. 11:00 13:30 2.50 249 COMPZ EVALWE CIRC T Change hole over from 12.1 ppg 175 visc Sodium Bromide to 12.1 Non viscous Sodium Bromide at 4 bpm at 70 psi. Then changed hole over to 10 micron filtered fresh water at 4 bpm at 60 psi. 13:30 13:45 0.25 COMPZ EVALWE SFTY P Held PJSM on RU and RIH w/ camera. 13:45 17:30 3.75 COMPZ EVALWE ELOG T RU E line and RIH w/ Camera unable to get clear picture, using 10 micron filtered fresh water. Adjust pump rates from .25 bpm to 3 bpm with no change in clarity. Discuss options with Town engr and choose to POOH and Run 40 arm caliper. 17:30 18:00 0.50 255 0 COMPZ EVALWE TRIP T POOH with 3 1/2 DP from 255 -ft. while RU for 40 ARM caliper log. Page 21 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:30 2.50 0 255 COMPZ EVALWE ELOG T Install Shooting Nipple. RU and RIH with GR, CCL, and 40 ARM Calliper Tool to 256 -ft elmd -ft. Record the Caliper Log back to surface in the 9 5/8" Casing. Rig down E -Line Tool String. Set back their equipment. E -Line Unit remains on Location. Sent the E -Line Crew back to Camp for bed rest due to reaching the safe working hours limit. 20:30 00:00 3.50 0 252 COMPZ EVALWE OTHR T Ready Pipe Shed and Floor to resume video logging in the morning. RIH with BHA #28 , Mule Shoe on 3 1/2" Tubing. Lightly tag up at 252 -ft. 10/23/2011 Continue with Video Logging. Prep Well with N2. Also run the Expro "Side -View Camera ". Decision will be made on the next BHA after review the Video Log. Run BHA #29. "Time Mill" 7" Csg and 3 1/2" Tbg. 00:00 06:00 6.00 252 248 COMPZ EVALWE RURD T Continue to prep for next Video Log run. Displace the Fresh Water from the Well with 12.1 lb/gal Sodium Bromide. Space -out the 3 1/2" tubing with the Mule shoe 4 -ft above bottom and the Tubing Hanger 1 -ft below the upper set of Pipe Rams. Also space out from the Tubing Hanger back to the Rig Floor for proper working height. Swap out Filtration Skid Unit w /clean filter elements. Spot Clean Fresh Water Vac Truck. Rig up Schlumberger N2 Unit. Swap Well back over to Fresh Water. 06:00 06:15 0.25 248 248 COMPZ EVALWE SFTY P Held PJSM with SLB N2 and Rig crew on PT treating lines at 1,500 psi and displacing well. 06:15 09:00 2.75 248 248 COMPZ EVALWE OTHR T Pressure test treating lines at 1,500 psi. Open well and come on line with N2 and displace fresh water from well bore to 248 -ft. with 10,800 scf of N2. Max pressure saw on IA was 240 psi. Recovered 12 bbls of fluid in kill tank. 09:00 09:15 0.25 248 248 COMPZ EVALWE SFTY P Held PJSM with HES E line, SLB N2, Expro, ASRC Vac truck drivers and Rig crew. 09:15 13:30 4.25 248 248 COMPZ EVALWE ELNE T RU E line and Expro side view camera. PT lubricator with N2 to 500 psi. RIH with camera and pressure up wellbore to 200 psi, push fluid downhole away from fish. Gather data 220 psi TBG pressure and 240 IA Pressure. POOH with camera and blow down system. RD E line and Camera. Page 22 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 248 248 COMPZ WELLPFCIRC T Circulate 12.1 High Viscous Sodium Bromide in hole to vacate N2 from system. Offload rig of un- needed Tools and bring up BHA #29 equipment while displacing. 14:00 15:30 1.50 248 0 COMPZ WELLPFTRIP T POOH with 3 1/2 EUE 8rd TBG and RD TBG equipment. 15:30 16:00 0.50 0 251 COMPZ FISH PULD T PU and RIH with BHA # 29 (6 1/8" Rough OD sizing shoe assy) to 251 -ft. 16:00 18:00 2.00 251 252 COMPZ FISH MILL T Gather Parameters - 48K up wt, 48k do wt, and 45k Rot wt at 40 rpms with 1,053 ft/Ibs of free torque. Circulating at 3 bpm at 70 psi. Begin rotating and taking wt at 252 -ft, continue to time milling from 252 -ft to 254.5 -ft. 18:00 21:45 3.75 252 256 COMPZ FISH MILL T Continue "time milling" the 7" Casing and the 3 1/2" Tubing Stub from 254.5 -ft. Milling parameters as follows: RPMs = 55, Torque = 1,000 ft/lbs, WOM = 1 - 2 K, Pump Rate = 3.0 bpm /60 - 70 psi. Fluid = 12.1 lb/gal Sodium Bromide in /12.0 lb/gal returned (continue to weight up returns Pit as needed). Milled down to the agreed target depth 256 -ft for the 7" Casing with the top of the 3 1/2" Tubing Stub at 255 -ft. Mill started packing -off. End milling. 21:45 23:00 1.25 254 254 COMPZ FISH CIRC T Pick -up off of Fish. Circulate and condition hole at 3.0 bpm /70 psi. 12.1 lb/gal in / 12.1 lb/gal returned. 23:00 00:00 1.00 254 0 COMPZ FISH TRIP T PJSM. Trip out with BHA #29 standing back 3 1/2" Drill Pipe in the Derrick. BHA at surface. 10/24/2011 Continue to dress -off 7" Casing and 3 1/2" Tubing. RIH with Reverse Circulating Junk Basket. Continue to dress -off 7" Casing and 3 1/2" Tubing. 00:00 02:00 2.00 0 0 COMPZ FISH PULD T Lay down BHA #29. Inspect Mill. No sign on the tattle -tails that the Tubing Dress Mill had done any work. However the Bull Nose was polished smooth. The 6 1/8" OD Shoe had done little or no work, too. Discuss next Mill run. 02:00 03:00 1.00 0 0 COMPZ FISH TRIP T PU and MU BHA #30 (5 3/4" OS) to 248 -ft and POOH due to decision change 03:00 05:30 2.50 0 253 COMPZ FISH TRIP T Pick -up BHA #31, Mill Shoe w /Inter Flat Bottom Junk Mill. Trip in hole. Parameters are as follows: RPMs = 55, Torque = 1,000 ft/Ibs, Weight on Mill = 1- 2 K, Pump rate = 3.0 bpm/70 psi. Tagged up high, back to BHA #29 start depth at 253 -ft. Page 23 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 07:30 2.00 0 253 COMPZ FISH TRIP T Pick -up BHA #32, 6 1/8" x 3.563 Mill Shoe w/ 5" Flat Bottom Junk Mill. Trip in hole. Parameters are as follows: RPMs = 40, Torque = 900 ft/lbs, Weight on Mill = 1- 2 K, Pump rate = 3.0 bpm /120 psi. Tagged up high, back to BHA #29 start depth at 252.8 -ft. Mill down from 252.8 -ft to 253.1 -ft. PU to 248 -ft. 07:30 12:30 5.00 248 248 COMPZ FISH CIRC T Circulate and condition hole while waiting for tools to arrive from Deadhorse. 12:30 13:30 1.00 248 0 COMPZ FISH TRIP T Held PJSM, BDTD and POOH f/ 248 -ft and Iaydown BHA #32 - inspect mill - no scarring, Mild scarring on outside of rotary shoe head. 13:30 19:00 5.50 255 0 COMPZ FISH TRIP T MU and RIH w/ BHA #33 (5 7/8 RCJB) to 250 -ft, drop 7/8 ball and RIH to 254.7 -ft, milled down 6" to 255.3 -ft in 35 minutes at 40 rpms at 800 to 900 ft/lbs of free torque, circulating at 8 bpm at 1,280 psi with 2K WOM. PU and Dry tag at 254.5 -ft. BDTD and POOH - recovered 11" of 3 1/2" twisted TBG stub. 19:00 19:30 0.50 0 254 COMPZ FISH TRIP T Make -up BHA #34, 5 3/4" x 4 5/8" Mill Shoe w /5" Flat Bottom Inner Mill. Trip in. 19:30 21:30 2.00 254 258 COMPZ FISH MILL T Up Weight = 45K. Down Weight = 45K. RPMs = 45, Free Spin Torque = 900 ft/lbs, Working Torque = 1,200 - 1,300 ft/lbs, WOM = 1 - 2 K, Pump Rate = 3.0 bpm /120 psi. Tag up at 254.3 -ft. Milled down to 256.5 -ft 21:30 22:00 0.50 258 0 COMPZ FISH TRIP T Trip out. Inspect Mill. Good indication the the 4 3/4" Inner Mill was on the top of the Tubing. The 5 3/4" Shoe had also cleaned out some damage along side to the 3 1/2" tubing. 22:00 22:30 0.50 0 254 COMPZ FISH TRIP T Make -up BHA #35, 5 3/4" x 4 5/8" Mill Shoe w/ 4 3/4" Inner Dress Mill /2 7/8" Pilot Mill. Trip in. 22:30 00:00 1.50 254 258 COMPZ FISH TRIP T Record the same parameters as last BHA run. Tag up at 254 -ft. Rotate past damage casing area. Slide down to the expected top of the Tubing at 257.5 -ft. Pump Rate = 3.0 bpm /120 psi. Milled down to 258 -ft. Pressure jumped up tp 230 psi (hopefully because the 4 3/4" Inner Dress Mill set down on the top of the "dressed -off' 3 1/2" Tubing top). 10/25/2011 Continue to dress -off 7" Casing and 3 1/2" Tubing. RIH with Overshot to latch 3 1/2" Tubing. Made several Overshot runs. Last attempt, recovered 4 -ft of mangled /twisted 3 1/2" Tubing. Page 24 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 258 256 COMPZ FISH CIRC T Pick up off of Tubing top. Increase pump rate to 5.0 bpm /170 psi. Circulate nd clean Hole. Blow a e e do wn Top Drive. 00:30 01:00 0.50 256 0 COMPZ FISH TRIP T Trip out. Lay down BHA. Inspect Mills. Inspected the 2 7/8" Pilot Mill and observe good side wear as expected indicating that it was inside the Tubing. The inspection of the 4 3/4" Inner Dress Mill showed that the brass tattle -tail pads were worn down, Also a good sign the the Dress Mill had work on the top of the Tubing. 01:00 02:00 1.00 0 0 COMPZ FISH OTHR T Clear and Clean Rig Floor. Change floor equipment over to handle 3 1/2" Tubing. 02:00 03:30 1.50 0 257 COMPZ FISH TRIP T Trip in with BHA #36, 5 3/4" Overshot w/3.5 Spiral Grapple. Rotate/Work to get past 254 -ft. Got down to 256 -5 -ft (the top of the Tubing). Attempted many times to plant overshot on the 3 1/2" Tubing. No -Joy. 03:30 04:00 0.50 257 0 COMPZ FISH TRIP T Trip out. Inspect Overshot. The 5 3/4" Cut -Lip Guide was flared out to 6 1/4 ". Change out cut lip guide to a shorter one. 04:00 06:00 2.00 0 257 COMPZ FISH TRIP T Trip in with BHA #37, 5 3/4" Overshot w/3.5 Basket Grapple. Rotate/Work to get past 254 -ft. Got down to 256.5 -ft (the top of the Tubing). Attempted many times to plant overshot on the 3 1/2" Tubing. No -Joy. 06:00 07:00 1.00 257 0 COMPZ FISH TRIP T Trip out. Inspect Overshot. The 5 3/4" Cut -Lip Guide was polished on inside face of cut lip guide 07:00 08:30 1.50 0 257 COMPZ FISH FISH T Trip in with BHA #38, 4 11/16" Overshot w/3.5 Spiral Grapple. Rotate/Work to get past 254 -ft. Got down to 256.5 -ft (the top of the Tubing). Attempted many times to plant overshot on the 3 1/2" Tubing. No -Joy. 08:30 10:30 2.00 257 0 COMPZ FISH TRIP T POOH f/ 256.5 with 4 11/16 overshot, Lay down and Inspect tools. 10:30 11:30 1.00 0 259 COMPZ FISH FISH T PJSM. MU /BHA # 39 (5 3/4" Overshot) 41k Up & Dn, tagged at 256.5 ft, work to 258.5. Attempt to engage tubing stub, no luck. POOH 11:30 13:30 2.00 259 259 COMPZ FISH FISH T POOH f /258.5 ft, inspect BHA #39, no sign of damage or failure, RIH w/ same, sat down at 256.5, charge pump on at 3 bpm, 60 psi. Work down to 259 ft, had 15k over pull, still slipping off tubing, made several more attempts. POOH. Page 25 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 259 0 COMPZ FISH FISH T OOH. PJSM. lay Down and inspect tools. No damage. 14:30 17:30 3.00 0 259 COMPZ FISH FISH T MU & RIH with BHA #40. 5 3/4" Over shot dressed for 3.5" TBG. Worked down to 259 ft, try rotating and pumping to engage tubing. No Luck. Discuss options with town. 17:30 21:30 4.00 259 0 COMPZ FISH FISH T Blow down Top Drive. POOH and lay down BHA. Recovered two pieces of 3 1/2" twisted and split Tubing. Total length recovered 4 -ft. Discuss plan forward with Baker Fishing and Anchorage Engineering. Wait on 4 11/16 grapple and pack -off for 5 3/4" Overshot from BOT. Change -out handover with "change -out day" incoming Fisherman (Jeff R. in, Donny G out). 21:30 22:00 0.50 0 259 COMPZ FISH TRIP T Make -up BHA #41, 5 3/4" Overshot w/3 1/2" Spiral Grapple. Trip in. 22:00 23:00 1.00 259 258 COMPZ FISH FISH T Up Weight = 41 K. Down Weight 41 K. RPMs = 45, Free Spin Torque = 900 If /Ibs, Pump Rate = 3.0 bpm /60 psi. Tagged top of Tubing 259 -ft. Worked Overshot several times. Finally got a "bite ". Pulled off of Fish, twice at 5K over. The third time the fish was latched the Overshot let go with 29K over. Tagged top of Tubing now at 258 -ft. 23:00 00:00 1.00 258 0 COMPZ FISH TRIP T Trip out. Lay down BHA. Break down and inspect Overshot. Spiral Grapple had the leading 25% of the teeth dull and flat. Also the Pack -off was ruined. 10/26/2011 Resume Milling Operation to dress the Tubing Top. Run Overshot to latch Tubing. RU S -line and drift Tubing, RU E -Line for Video Logging. Resume Milling Operations. 00:00 01:30 1.50 0 256 COMPZ FISH TRIP T Make -up BHA #42, 6" Superloy Concave Junk Mill. Trip in with 3 1/2" Drill Pipe. 01:30 03:30 2.00 257 261 COMPZ FISH MILL T Up Weight = 42K. Down Weight = 42K. RPMs = 60, Free Spin Torque = 900 ft/Ibs, Working Torque = 1,200 ft/Is, Weight on Mill = 2 - 4K, Pump Rate = 3.0 bpm /90 psi. Tagged the top of the Tubing at 256.5 -ft. Pushed down to 259 -ft. Started "Timed Milling" at 259 -ft. Made the first foot in 40 minutes. Made the second foot in 80 minutes. End Milling at 261.0 -ft 03:30 04:00 0.50 261 0 COMPZ FISH TRIP T Blow down Top Drive. Trip out. Lay down BHA. Inspect Mill face. Face of Mill showed signs of milling work. However, no clear imprint of a 3 1/2" Tubing top. Page 26 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 0 260 COMPZ FISH TRIP T Make -up BHA #43, 5 3/4" Overshot w/3.50" Basket Grapple. Trip in. 04:30 05:30 1.00 260 261 COMPZ FISH FISH T Up Weight = 40K. Down Weight = 40K. Tagged top of Tubing at 260 -ft. Work to plant Overshot and got down to 261 -ft. Attempt to latch Tubing. However, the Overshot body seems to be getting "pinched" in a casing buckle and it takes 5K over string weight to pull free. (5 times). 05:30 06:00 0.50 261 0 COMPZ FISH TRIP T Monitor Well. POOH, inspect Overshot. Guide shoe was rolled in toward the ID of the Shoe, the grapple was still in good shape. 06:00 10:00 4.00 0 260 COMPZ FISH PULD T PJSM. Lay down fishing assembly. Prep for Video Log. MU and RIH with 3.5" TBG with mule shoe down to 260 feet and park. 10:00 10:30 0.50 260 260 COMPZ FISH CIRC T PJSM. Circulate Fresh Water down OA taking returns up the TBG at 4 bpm, ICP 120 psi, FCP 130 psi. 10:30 11:00 0.50 260 260 COMPZ FISH SFTY P PJSM with HES E -Line crew, SLB crew and Rig Crew. Discuss equipment rig up, high pressure pumping and SIM -OPS, and good communication. 11:00 11:30 0.50 260 260 COMPZ FISH CIRC T RU SLB Pumping unit and Equipment. Displace Fresh Water From wellbore with N2 at 500 scfm, 60 psi. 11:30 15:45 4.25 257 260 COMPZ FISH ELOG T Rig Up and Load E -Line equipment and tools to Rig floor.PUH with TBG to 257 feet. PT Lubricator to 500 psi. RIH w/ Video down to 200 feet and the Camera failed. POOH and Change Tools. RIH with different camera down to 257 feet, seeing fluid at that depth, increase N2 rate to 800 scfm from 500 scfm while holding different psi on choke. Unable to obtain clear picture. POOH and Clean camera. Adjust TBG depth to 260 feet. RIH with Video again to 200 feet, lens on camera dirty again, POOH and clean camera again. RIH down to 259 feet, still seeing fluid above TBG stub, increase N2 Rate from 500 to 900 scfm while adjusting psi on choke to try and move fluid away from TBG stub. NO LUCK. 15:45 16:45 1.00 260 0 COMPZ FISH PULD T POOH, and R/B E -line equipment and Tools. POOH lay down 3 1/2" TBG. 16:45 17:00 0.25 0 0 COMPZ FISH SFTY T PJSM, Discuss plan forward for next step. Page 27 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:15 1.25 0 260 COMPZ FISH PULD T MU BHA #45. 5 3/4" Cut Lip Guide Shoe with a 5 3/4" (3.37 feet) Wash Over Boot Basket. RIH Down to top of 3.5" Stub at 259 feet. Up Wt 43k / Dn Wt =40k. No Luck With Cut Lip Guide Shoe, stacking out at 260 feet while trying to rotate. Load wellbore with 12.1 PPG. POOH 18:15 19:15 1.00 0 0 COMPZ FISH OTHR T Rig back N2 Pumper and E -Line equipment and release crew until tomorrow. 19:15 19:15 0.00 0 260 COMPZ FISH TRIP T Make -up BHA #46, 6" Superloy Concave Junk Mill (re -run). Trip in with 3 1/2" Drill Pipe. 19:15 22:30 3.25 260 265 COMPZ FISH MILL T Up Weight = 42K. Down Weight = 42K. Tag top of Tubing at 260.0 -ft. RPMs = 70, Torque = 2,000 ft/lbs, WOM = 6K - 10K, Pump Rate = 3.0 bpm /80 psi. Steady milling down to 265 -ft. Then Mill quit. 22:30 23:00 0.50 265 0 COMPZ FISH TRIP T Blow down the Top Drive. Trip out with BHA. Lay down and inspect same. Mill face had a complete circle measuring 4 1/2" outside and 4" inside. Mill worn out. 23:00 23:15 0.25 0 265 COMPZ FISH TRIP T Make -up BHA #47, 5 3/4" Overshot w/3.50 Basket Grapple. Trip in on 3 1/2" Tubing. 23:15 00:00 0.75 265 265 COMPZ FISH FISH T Up Weight = 40K. Down Weight = 40K. Tag top of Fish at 265 -ft. Attempt to latch many times. No -Joy. (It is our opinion that by using the 3 1/2" Tubing there is just not enough "horse power" to flip the top of the Tubing off of the side of the Casing so it can be swallowed by the Overshot. 10/27/2011 Run 5 3/4" Overshot and resume Fishing Operations. Record E -Line Video Log. Continue Milling Operations. 00:00 00:30 0.50 265 0 COMPZ FISH TRIP T Trip out with 3 1/2" Tubing. Lay down and inspect BHA. Observed the beginning of a round circle pattern on the lip of the Guide, possibly confirming that we are on top of the Tubing but just can not "kick it over into the Overshot. No evidence that the Tubing top had entered the Overshot. 00:30 01:00 0.50 0 265 COMPZ FISH TRIP T Clean -up the Lip on the Overshot Guide. Make -up BHA #48, same 5 3/4" Overshot for re -run. Trip in on 3 1/2" Drill Pipe. Page 28 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:45 0.75 265 265 COMPZ FISH FISH T Up Weight = 42 K. Down Weight = 42K. Tag top of Tubing at 265 -ft. Attempted many times to get over the top of the Tubing. No -Joy. The Tubing has to be "pined" or held against the wall of the Casing due to the Casing and the Tubing being cork - screwed or still buckled below the top of the Tubing Fish. We tried different rotations speeds with the Top Drive, different set -down weights, and different speeds coming down on the Tubing top. The Cut -Lip Guide just bounced on the Tubing top as we rotate. We even tried left-hand rotation one time while slowly coming down. 01:45 02:30 0.75 265 0 COMPZ FISH TRIP T Trip out with 3 1/2" Drill Pipe. Lay down and inspect Overshot. The Cut -Lip was deeply marked from rolling and bouncing over the top of the Tubing. Once again, no sign that the Tubing had entered or even started to enter into the Overshot. 02:30 03:30 1.00 0 COMPZ FISH TRIP T Make -up Mule Shoe on 3 1/2" Tubing. Trip in Hole. Space -out with the Tubing Hanger below the Upper Pipe Rams and the Mule Shoe "parked" at 263 -ft. Clear and clean Floor. Prep for E -Line video Logs. 03:30 06:00 2.50 COMPZ FISH ELOG T Standby and Discuss Opinion with Town Engineer. 06:00 06:30 0.50 265 0 COMPZ FISH TRIP P PJSM. POOH to change BHA. 06:30 07:30 1.00 0 0 COMPZ FISH PULD T OOH with TBG. MU One Joint of 2 7/8" TBG with Mule Shoe on bottom. 07:30 09:30 2.00 0 264 COMPZ FISH TRIP T RIH down to top of 3 1/2" TBG stub at 264.5' and rotated mule shoe down to 265.5 feet, pump down drill pipe at 1/4 bpm at 350 psi. Appears that the 2 7/8" TBG is inside the 3.5" Tubing. 09:30 10:00 0.50 264 266 COMPZ FISH SFTY P PJSM with HES E -Line Crew and Rig crew. Discuss hazard for rigging up E -Line tools. 10:00 10:45 0.75 266 266 COMPZ FISH PULD T R/U E -Line. MU Tools and Rig Up Lubricator. PT Lubricator against TIW valve to 1000 psi. 10:45 12:15 1.50 266 266 COMPZ FISH ELOG T RIH with Video Camera on E -Line and sat down at 264 feet. Was only able to Circulate at 2 SPM at 380 psi. Not able to obtain a clear picture of TBG Stub. POOH and Rig Back E -Line Equipment. Page 29 of 67 Time Logs r • Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:15 12:45 0.50 266 265 COMPZ FISH CIRC T PUH to 264.5 to neutral weight. Reverse Circulate 12.1 PPG Brine from wellbore with fresh water at 4 BPM, 40 psi until clean. Switch over to Circulate down the Drill pipe taking returns up the OA at 4 BPM, 70 PSI. 12:45 13:30 0.75 265 265 COMPZ FISH PULD T MIRU SLB N2 Unit and Treating Iron. 13:30 13:45 0.25 265 265 COMPZ FISH SFTY P PJSM with all personal on Location. Discuss hazard for pumping N2 and E -Line operation. 13:45 16:00 2.25 265 265 COMPZ FISH CIRC T PT Treating Iron to 1000 psi with N2. Circulate N2 down the OA taking returns up the TBG at 500 SCFM and them increase N2 Rate to 1000 SCFM for 10 minutes. Shut down N2 and Line to Pump N2 down the TBG taking returns up the OA at 500 scfm for 5 minutes. Bleed down and Rig Up E -Line Video Logging Equipment. Test Lubricator to 500 psi. 16:00 16:45 0.75 265 262 COMPZ FISH ELOG T PUH to 262 feet and park Drill Pipe. Open TIW Valve and RIH with Logging Tools down to 263 feet while pumping N2 at 500 SCFM, 800 SCFM, 1000 SCFM and 1200 SCFM while changing the back pressure being held on the choke. Still unable to obtain a picture of the 3 1/2" TBG stub. 16:45 18:00 1.25 262 262 COMPZ FISH TRIP T POOH with E -Line Logging Assembly. R/D and Release E -Line Unit and Crew and SLB pumping Unit and Crew. Load Welibore with 12.1 PPG Brine before POOH with the Workstring. 18:00 19:00 1.00 262 0 COMPZ FISH TRIP T PJSM. Trip out with BHA #50. Lay down Mule Shoe. Clear and clean floor. 19:00 20:00 1.00 0 265 COMPZ FISH TRIP T Make up BHA #51, 6" Concave Junk Mill. Trip in with 3 1/2" Drill Pipe. 20:00 22:30 2.50 265 277 COMPZ FISH MILL T Up Weight = 42K. Down Weight = 42K. RPMs = 70, Free Spin Torque = 1,000 ft/lbs, Pump Rate = 4.0 bpm /190 psi, WOM = 5K - 10K, Milling Torque = 1,00 ft/lbs - 2,000 ft/lbs. Tagged top of Tubing at 265 -ft. Milled down to 270 -ft with no problems or high torque spikes. Tubing fell away. Caught up to the Tubing again at 277 -ft. Mix and pump a Hi -Vis Sweep. Recovered 10 gals of sand and formation clay. No fluid losses. Page 30 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 277 0 COMPZ FISH TRIP T Trip out with BHA #51. Lay down and inspect Mill. Pattern on Mill face indicated that the Mill "walked" all over the top of the Fish (no real clear pattern). Discuss findings and plan forward with Anchorage Engineering. 10/28/2011 Continue with Milling Operations. Continue with Fishing Operations. Found more down -hole Casing problems. Discuss plan forward, possibly another Video Log at new depth. Perform Weekly BOPE Test. 00:00 01:00 1.00 0 0 COMPZ FISH OTHR T Continue discussing plan forward. Bring Tools to Rig Floor. 01:00 01:30 0.50 0 0 COMPZ FISH SVRG T Lub Rig. Service and inspect Top Drive. 01:30 02:00 0.50 0 266 COMPZ FISH TRIP T Make -up BHA #52, 5 3/4" Overshot w /Basket Grapple. Trip in on 3 1/2" Drill Pipe. 02:00 03:00 1.00 266 276 COMPZ FISH FISH T Up Weight = 42K. Down Weight = 42K. Ease in hole. Set down at 266 -ft. Had to work several times, with slow Top Drive rotation from 266' - 267'. Fell through and eased down to a soft tag at 275 -ft. Drilling off with slow rotation and 2K Mill weight. End any further progress. No problem pulling back above 266 -ft. 03:00 03:30 0.50 276 0 COMPZ FISH TRIP T Trip out with 3 1/2" Drill Pipe. Lay down and inspect Overshot. Found a ball of junk inside Overshot. Also found clay /sand inside of the Overshot and the same at the Drill Pipe Overshot connection. 03:30 04:30 1.00 0 0 COMPZ WHDBO CIRC T Need to discuss another plan forward with Anchorage Engineer. Pick -up Swizzle and String Magnet and wash out BOP Stack. Monitor Trip Tank. 04:30 07:30 3.00 0 0 COMPZ WELCTI OWFF T Continue to monitor Trip Tank. Prep for either a weekly BOPE test of E -Line Logs. Hole Static, No Gains or losses. 07:30 09:00 1.50 0 0 COMPZ WHDBO OTHR T Call Out For RBP from Baker Shop. 09:00 09:15 0.25 0 0 COMPZ WHDBO SFTY P RBP on Location. Hold PJSM with Rig Crew and Baker Rep. 09:15 09:30 0.25 0 0 COMPZ WHDBO PULD P Load Baker Tools to Rig Floor. 09:30 11:00 1.50 0 42 COMPZ WHDBO MPSP P MU and RIH to 42' and Set RBP. Top of Element at 38 feet. 11:00 11:30 0.50 0 0 COMPZ WHDBO PULD P LD BHA Setting Tool Assembly 11:30 12:30 1.00 0 0 COMPZ WHDBO PRTS P RU Testing Equipment.Fluid Pack Lines, Pressure test RBP to 250/500 psi. 12:30 13:30 1.00 0 0 COMPZ WHDBO SEQP P PJSM. Pull Wear Bushing and Set Test Plug. 13:30 15:30 2.00 0 0 COMPZ WHDBO SVRG P Inspect and Clean Pipe Ram Body. Found Metal Shaving In Ram Cavity and a Trace of Sand. (Called AOGCC Rep at 1330 hours). Jeff Jones Wants to Witness BOP Test. Page 31 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 0 0 COMPZ WHDBO PRTS P Fill BOP Stack and Perform Shell Test. 250/3500 psi. 16:00 16:45 0.75 0 0 COMPZ WHDBO OTHR P Wait On AOGCC State Rep. 16:45 21:30 4.75 0 0 COMPZ WHDBO BOPE P AOGCC Rep Called Back and Waived Witness to Test (Jeff Jones). Start BOP Test. Perform weekly BOPE test per ConocoPhillips / AOGCC requirements at 250/3,500 psi. Perform Koomey drawdown test. Record pressure test on a chart. 21:30 23:15 1.75 42 0 COMPZ WHDBO BOPE P Rig down test equipment. Pull Test Plug. Release, pull, and lay down the Baker 9 5/8" Retrievable Bridge Plug. Set Wear Bushing. 23:15 00:00 0.75 0 0 COMPZ FISH OTHR T Clear and clean Floor. Kick out Baker Retrievable Bridge Plug. Kick out all used and not needed Baker Fishing Tools. Ready floor. Bring 7" ITCO Casing Spear to the Floor. 10/29/2011 Run 7" Csg Spear and recover the remainder of the parted 7" Casing Joint. Run Reverse Circulating Basket. Run 5 3/4" Overshot and locate the top of the 3 1/2" Tubing. Prep for Video Logging. 00:00 00:30 0.50 0 254 COMPZ FISH TRIP T Make -up BHA #54, 7" ITCO Casing Spear. Trip in with 3 1/2" Drill Pipe. 00:30 00:45 0.25 254 254 COMPZ FISH FISH T Up Weight = 45K. Down Weight = 45K. Tag top of the 7" Casing Fish. Plant Spear. Pick -up with 40 K over pull. Fish free. 00:45 02:15 1.50 254 0 COMPZ FISH TRIP T Trip out with BHA and Fish. Fish dragging 5K over. Break out and lay down Fish and BHA. Recovered the bottom section of the parted Joint of 7" Casing. Overall length = 10.87 -ft. Total Casing recovered to date = 265 -ft, the Landing Joint and 6 full Joints. The recovered section had two places where a hole was milled through the side while milling (chasing) the tubing. Eventually, due to the cork - screwed Casing and milling off the Tubing the 7" Casing was side - tracked. Take pictures. 02:15 02:45 0.50 0 255 COMPZ FISH TRIP T Make -up BHA #55, Reverse Circulating Junk Basket. Trip in with 3 1/2" Drill Pipe. 02:45 03:30 0.75 255 267 COMPZ FISH FISH T Up weight = 41K. Down Weight = 41 K. Tag up at 255 -ft. Work and rotate to pass through. Continue down to 267 -ft. Unable to make any further progress. Work RCJB up /down at 8.0 bpm /1,000 psi. 03:30 04:00 0.50 267 0 COMPZ FISH TRIP T Trip out with BHA. Lay down and empty Reverse Circulating Junk Basket. No recovery. Page 32 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 0 255 COMPZ FISH TRIP T PJSM. Make -up BHA #56, 5 3/4" Overshot w/3 1/2" Basket Grapple. Trip in on 3 1/2" Drill Pipe. 04:15 05:00 0.75 255 267 COMPZ FISH FISH T Up Weight = 41K. Down Weight = 41 K. Tagged up again at 255 -ft. Work and rotate through. Continue down to top of window at 267' to bottom of window at 270 -ft. Attempt many times to get past but kept going out side of the 9 5/8" to 276 -ft (formation). 05:00 07:30 2.50 267 0 COMPZ FISH TRIP T Trip out with 3 1/2" Drill Pipe. Lay down Overshot. Formation Clays inside of Overshot. Discuss Next BHA. 07:30 08:00 0.50 0 0 COMPZ FISH FISH T PJSM. MU 5 3/4" Short O/S Guide with a 23.57 feet long, 3.5" Bent Joint. 08:00 10:00 2.00 0 0 COMPZ FISH RGRP T Having a problem with the Top Drive. Unable to rotate elevators. 10:00 11:15 1.25 0 266 COMPZ FISH FISH T Continue in hole with BHA. Set Down at 255' Rotate 1/4 turn and was able to work past. Set Down again at 265' Rotate 1/4 turn and work past, sat down again at 266 feet with charge pump on, no pressure increase, rotate 3 more time and fall past 3 1/2" TBG Stub and fall in sidetrack section, PUH and repeat same process to try and engage TBG stub. PUH to 258 feet and RIH and set down at 261 feet, stacked 10k down, swallowed 2, PU. Saw 25k over pull, slip off fish, repeat again and tagged same spot,swallowed 2 feet with 18k over pull, with same results. POOH to check Guide Shoe, there may be a broken section of TBG in Grapple. 11:15 12:45 1.50 266 0 COMPZ FISH TRIP T POOH and Inspect Fishing Assembly. Found marks inside Grapple where the TBG stub was inside slips. Add one Section 5 3/4" Extension with same BHA. 12:45 14:00 1.25 261 0 COMPZ FISH FISH T RIH & Sat Down At 261 feet, seen good indication that we slid down over TBG stub, had 30k over pull but slip off again. Make several more attempts before POOH and Check Guide Shoe. Blow down TD and POOH. Page 33 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:30 2.50 0 267 COMPZ FISH FISH T After Inspecting Fishing Assembly, found marks on Grapple and part of the rubber seal was torn. MU another Extension for a total of 2 and RIH with same fishing assembly. Set down at 266.50' Made several different attempt to Locate and swallowed TBG Stub. Try pumping, Try rotating Fishing String, Try With pump off. No luck. 16:30 18:30 2.00 267 0 COMPZ FISH TRIP T TOOH and change Fishing BHA around. Try something different. Clean floor. Crew Change -out. 18:30 19:30 1.00 0 265 COMPZ FISH TRIP T PJSM. Make -up BHA #61, 5 3/4" Overshot w/3 3/8" Basket Grapple. Also added a 3 -ft Overshot Extension. Trip in with 3 1/2" Drill Pipe. 19:30 20:00 0.50 265 266 COMPZ FISH FISH T Up Weight = 42K. Down Weight = 42K. Worked and rotate Overshot 1/4 turn at a time and attempt to latch fish. Tried many times. No -Joy. 20:00 20:30 0.50 266 0 COMPZ FISH TRIP T Trip out with BHA. Lay down and inspect same. No marks to indicate any new clues. 20:30 00:00 3.50 0 270 COMPZ EVALWE RURD T Prep for Video Logging. Expro Serviceman and Camera on location. Call for E -Line Crew. E -line Crew remains in Camp for proper bed rest. Expect on location at midnight. N2 Pumper arrived on location and rig up. Rig Crew trip in with Mule Shoe on 3 1/2" Drill Pipe to 270 -ft and stand -by to swap Well over to fresh Water). 10/30/2011 Rig up E -Line. Record Video Logs. Unable to obtain a video recording of the damage Casing or the top of the Fish due to sand and fluid entry coming from outside of the Casing. 00:00 02:00 2.00 270 270 COMPZ EVALWE SFTY T Continue to wait on E -Line Crew to arrive on location (Crew getting required bed rest in Camp before coming to work). 02:00 03:00 1.00 270 270 COMPZ EVALWE CIRC T E -Line arrived on Location. Bring Rig Pump on line at 4.0 bpm /60 psi. Displace 12.1 lb/gal Sodium Bromide from the Wellbore with Fresh Water. 03:00 03:30 0.50 270 270 COMPZ EVALWE SFTY P Hold a safety and operations meeting with All. discuss high pressure, Nitrogen cloud, communications, and general good safety habits. 03:30 04:30 1.00 270 270 COMPZ EVALWE RURD T Rig -up E -Line equipment. Cool down N2 Pumper. Pressure test N2 Line at 2,500 psi. Page 34 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:30 1.00 270 270 COMPZ EVALWE CIRC T Bring N2 Pumper on line at 500 scfm. Evacuate the fresh water from the Wellbore routing returns through Choke , holding 100 psi back pressure to the Kill Tank. End N2. Gauge Tank. Calculated fluid to recover = 21 bbls. Tank strap recovered = 17 barrels. Bring N2 back on line to finish evacuation. N2 line pressured up with no pressure against the choke. Bleed N2 back. Check and double check Rig surface lines. No problem found. Attempt to circulate Well with N2 again with same results. Bleed N2 back. (It is assumed that the formation behind the split Casing has heaved, and had packed off the Drill Pipe around the Mule Shoe). 05:30 11:00 5.50 270 0 COMPZ EVALWE FCO T PUH to Investigate Problem. Saw 12k -15k over pull, worked drill pipe up and down, pull free. Made one attempt to circulate again down drill pipe, pressure up to 500 psi. PJSM, Discuss hazard of plugged drill pipe and trapped pressure. Rig Back E -Line and SLB Equipment. Continue to POOH, stood back one stand,next stand was packed off with solids (sand) S/D down each joint and try to clear, no luck. Shipped out 3 joints to wash bay to have clean out. 11:00 13:00 2.00 0 269 COMPZ EVALWE FCO T PJSM. Prep for FCO. MU and RIH with 3.5" Drill Pipe and Mule Shoe Assembly down to 227 -ft and start circulating down at 4 bpm, 60 psi. Seeing small trace of sand at the shakers, continue to circulate until clean. PU another single joint and circulate down to 258 -ft at 4 bpm, 60 psi, continue to see sand and clay at the shakers. Circulate clean. PU a 10 -ft PUP Joint and start circulating down at 4 bpm, 60 psi, reciprocate from 260 -ft to 269 -ft until returns are clean. 13:00 15:00 2.00 269 269 COMPZ EVALWE RURD T PJSM. RU SLB N2 Treating Iron and E -Line Logging Equipment with Expro Video Logging Tools. 15:00 15:30 0.50 269 269 COMPZ EVALWE CIRC T PT N2 Treating Iron to 2500 psi. Reverse Circulate N2 down OA taking returns up the drill pipe until N2 is seen at kill tank. 15:30 15:45 0.25 269 269 COMPZ EVALWE RURD T Shut Down N2 Pumper, bleed down psi and move N2 line over to pump down drill pipe. Page 35 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:45 16:00 0.25 269 269 COMPZ EVALWE PRTS T Pressure Test N2 Treating Iron to 2500 psi. Open service valve and pressure test lubricator to 500 psi. 16:00 18:30 2.50 269 269 COMPZ EVALWEOTHR T N2 is leaking from Stuffing Box Seal. Rig Down E -Line and Inspect and repair seal is needed. Head Catcher was Bad. 18:30 20:00 1.50 266 266 COMPZ EVALWE ELOG T E -Line Lubricator repairs completed. Pressure test Lubricator at 500 psi. Good. Start Expro Camera in hole. Stop. Pull out and clean Camera Tens (grease from injector head smeared lens). RIH with Camera. Saw fluid level at 70 -ft. Stop Camera at 65 -ft. Bring N2 on line to evacuate fluid from Welibore. Once again Camera lens got smeared with injector head grease. Pull back out and clean Tens. Run back in hole. This time found Fluid level at 65 -ft. Bring N2 on at 500 scfm /130 psi. Evacuate fluid from Welibore and continue down with Video Camera. Set down at 266 -ft end of Drill Pipe. Increase N2 to 900 scfm in an attempt to blow formation fines ahead of camera. No -Joy. Unable to get below Mule Shoe at 266 -ft. No picture of anything useful. (It is assumed the the fluid level found at —70 -ft is from "ground water" leaching in). Page 36 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 255 255 COMPZ EVALWE ELOG T Pull out of hole with Camera. Continue to pump N2 while POOH to maintain positive pressure on the Drill Pipe to prevent sand from U- Tubing back into the Drill Pipe. End N2. Reconfigure to run Video Log using clean fresh water in an attempt to get a clear picture. Stab Lubricator back on Well. Circulate Wellbore x 2 volumes with clean fresh water. Open TIW Valve and start to run in with Camera. Continue to circulate clean fresh water with Charge Pump ( -4.0 bpm). Video recording inside of the Drill Pipe while RIH are "useable quality ". Stop at 266 -ft end of Drill Pipe. Saw just a couple seconds of what looked like cement chunks in the damage casing area. However, the picture quickly diminished due the camera setting down in fill. Pulled the Drill Pipe up to — 255 -ft. Continue pumping. Drop Camera out the end of the Drill Pipe and attempted to get a recording of anything. Once again sand and other formation BS prevented a picture of the casing damage or find the top of the Fish. Much sand now in returns across the shakers. Also just about out of fresh water(290 bbls pumped in an attempt to keep the hole clean). Pull up inside of Drill Pipe and POOH while maintaining fresh water flow down the Drill Pipe. Pull up inside Lubricator and close the TIW Valve. Abort Video Logging attempt. 10/31/2011 Discuss plan forward with Anchorage Engineer. Resume Fishing Operations. 00:00 02:00 2.00 255 255 COMPZ EVALWE RURD T Discuss plan forward with Anchorage Engineer and Baker Fishing Tools. Rig down N2 Pumper and E -Line. Remain on stand -by untill in the Morning. Clean and clean floor. 02:00 02:45 0.75 255 255 COMPZ FISH CIRC T Circulate Well back over to 12.1 lb/gal Sodium Bromide. Monitor Well. Fluid level remains just below Rig Floor level. However, while circulating Well besides the sand in the returns, we are now getting pieces and chunks of shale. It is assumed that a cavity has been washed out behind the damaged casing. 02:45 03:15 0.50 255 0 COMPZ FISH TRIP T Trip out with BHA #63, Mule Shoe. Page 37 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:30 0.25 0 265 COMPZ FISH TRIP T Make -up BHA #64, 5 3/4" Overshot w/3 1/2" Basket Grapple, # 1/2" IF Bent Sub. Trip in with 3 1/2" Drill Pipe. 03:30 04:00 0.50 265 265 COMPZ FISH FISH T Work and rotate to find and latch the Top of the Tubing. No -Joy. Unable to get deeper the 265 -ft. 04:00 05:30 1.50 265 0 COMPZ FISH TRIP T Trip out with BHA 64. Lay down Overshot and inspect same. No markings to indicate anything. Monitor Well for 30 minutes. Losses at 2 BPH. 05:30 06:30 1.00 0 55 COMPZ FISH TRIP T PJSM. MU and RIH w/ 8 1/8" Bowen Overshot. Set Down with Drift at 55' unable to rotate or make any footage. 06:30 07:00 0.50 55 0 COMPZ FISH TRIP T POOH from 55' and lay down BHA 07:00 09:30 2.50 0 0 COMPZ FISH OTHR T Discuss Plan Forward. Wait on Tools from baker shop. Load Tools to floor after arriving on location. 09:30 11:00 1.50 0 254 COMPZ FISH TRIP T PJSM. MU Milling BHA. 5 3/4" Cut Lip Guide, 5 3/4" TSWP Box x TSS Pin , XO with an inner mill assembly (4 3/4" Bladed junk Mill) RIH and Attempt to locate 3 1/2" TBG Stub and Mill and dress off top of TBG, set down at 254 -ft, try and rotate passed. After 22 attempts, POOH and change out BHA. 11:00 13:00 2.00 0 265 COMPZ FISH MILL T Un -load E -Line equipment from Rig floor and release E -line crew. Remove 1 stand of drill collars, replace with drill pipe with same milling assembly. Run back in hole and set down again at 254 -ft, rotate 1/4 turn and work passed, continue in hole and try and locate 3 1/2" TBG stub. Set down at 262.5 -ft, puh 1 foot, set parameters 4 BPM, 90 psi, 40 RPM, 1000# Free Torque. Milled down to 265 -ft and mill torque up and slid off, loss 3.5" TBG. PUH to 250 -ft to reference depth, RIH and set down at 259 -ft, unable to work passed 259 -ft after several attempts. 13:00 15:00 2.00 265 0 COMPZ FISH TRIP T POOH to inspect milling assembly. Saw good pattern on face of mill and marks on face of cut lip. Add bent sub to same BHA. MU BHA 15:00 21:00 6.00 0 265 COMPZ FISH PULD T RIH and Set down at 259 -ft again was able to rotate passed. Continue down and located 3 1/2" TBG stub. Set parameters and started milling again at 4 BPM, 100 psi, 60 RPM, 1k Free Torque and 2K Torque while milling. Worked and milled down to 265 -ft Page 38 of 67 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:00 1.00 265 0 COMPZ FISH TRIP T Trip out with BHA #68. Lay down and inspect MITI. Mill face showed good evidence that it had milled on "something ". However, the pattern was inclusive as to what. 22:00 22:45 0.75 0 255 COMPZ FISH THGR T PJSM. Make -up BHA #69, Reverse Circulating Junk Basket. Trip in on 3 1/2" Drill Pipe. 22:45 23:30 0.75 255 266 COMPZ FISH FISH T Tagged up at 255 -ft with the RCJB. Finally worked through. continue down to 265 -ft. Worked RCJB up /dawn at 4.0 bpm /350 psi and 8.0 bpm /1,050 psi 23:30 00:00 0.50 266 0 COMPZ FISH TRIP T Trip out with the Reverse Circulating Junk Basket. Lay down and empty. No recovery. 11/01/2011 RIH w/ BHA 70, no recovery. RIH w/ BHA 71, recovered 5.5 -ft of 3 1/2" tubing. RIH w/ BHA 72 to 266.5 -ft work to 267.5 -ft. RIH w/ BHA 73, RCJB, recovered 3 1/2" L X 1 1/2" W piece of 7" Casing. RIH w/ BHA 74 to 266.5 -ft, work to 268 -ft. RIH w/ BHA 74 to 266.5 -ft, work to 268 -ft. RIH w/ BHA's 75 & 76, no recovery. RIH w/ BHA 77 to 267 -ft, No results. PU BHA 78. 00:00 00:45 0.75 0 265 COMPZ FISH TRIP T PJSM. Make -up BHA #70, 5 7/8" Short-Catch Overshot w /Extension. Trip in on 3 1/2" Drill Pipe. 00:45 01:45 1.00 265 265 COMPZ FISH FISH T Up Weight = 42K. Down Weight = 42K. Tag up at 265 -ft. Work Overshot several times to get over Fish. Pull 12 K over string weight. Then slipped off. Could not re -latch Overshot. 01:45 02:30 0.75 265 0 COMPZ FISH TRIP T Trip out with BHA #70. Lay down and inspect Overshot Grapple. First couple of the Grapple teeth were stripped. 02:30 03:30 1.00 0 0 COMPZ FISH TRIP T Make -up BHA #71, 5 3/4" Short Catch Overshot with no Extension. Trip in on 3 1/2" Drill Pipe. 03:30 04:30 1.00 0 269 COMPZ FISH FISH T Up Weight = 42K. Down Weight = 42K. Attempt to engage tbg. No Luck. 04:30 06:00 1.50 269 269 COMPZ FISH FISH T CBU x 1 1/2, B/D Top Drive, Attempt to engage tbg stub again w/o mud pump. No Indication of Fish. 06:00 07:00 1.00 269 0 COMPZ FISH TRIP T PJSM. POOH L/D Fishing Assembly. Recovered 5.5' of 3 1/2" Tubing. Page 39 of 67 Time Logs 411 1111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:30 2.50 0 268 COMPZ FISH MILL T PJSM. MU and RIH with Milling assembly. Sat down and locate 3.5" TBG top at 266.5 -ft, set parameters, start milling and slipped off the side. PUH again re- locate again at 266.50 -ft, start milling at 4 BPM,100 psi,40 rpm,lk free torque,2k milling torque, 3k WOB, 42k up wt, 42 dn wt. Milled down to 267.75 -ft, unable to make any more footage. PUH 5 -ft and had a 10k over pull, unable to locate tbg top again after several attempts. 09:30 10:00 0.50 268 0 COMPZ FISH TRIP T Blow down top drive & POOH and inspect milling assembly. Cut Lip Guide showed damage. See Pictures. The Guide Shoe was missing a small piece on the end and was cracked in several places. 10:00 10:15 0.25 0 30 COMPZ FISH PULD T MU 5 3/4" RCJB with a 5 7/8" Head. 10:15 10:30 0.25 30 266 COMPZ FISH TRIP T RIH with a 5 3/4" RCJB with a 5 7/8" Head on Drill Pipe. 10:30 10:45 0.25 266 266 COMPZ FISH CIRC T Sat Down With RCJB at 266.25 -ft. PUH 1 foot, and started circulating at 8 bpm, 1150 psi for 15 minutes working up & down. Unable to work passed 266.25 -ft. 10:45 11:15 0.50 266 0 COMPZ FISH TRIP T Shut Down Mud Pump. Blow Down Top Drive. POOH and Inspect RCJB. Recovered 3 1/2" L x 1 1/2" W Piece of 7" CSG. 11:15 12:00 0.75 0 56 COMPZ FISH PULD T Lay Down RCJB Assembly & RU Milling Assembly.5 3/4" TSWP Guide Shoe with 4 3/4" Inner Mill Assembly 12:00 14:00 2.00 56 268 COMPZ FISH MILL T TIH with Milling Assembly. Located and Started Milling on TBG Stub at 266.50 -ft at 4 bpm,100 psi,lk free torque, 1.5k Milling torque,40 rpm,3k WOB, 42k up & dn weight. Work Mill Down to 268 -ft, Unable to make any headway 14:00 14:15 0.25 268 0 COMPZ FISH TRIP T TOOH and Inspect Milling Assembly. Cut right was smooth on the face of skirt. 14:15 15:00 0.75 0 0 COMPZ FISH PULD T Lay Down Milling Assembly. MU Fishing Assembly.(5 3/4" Short O/S Guide w/ a 3 1/2" Catch. 15:00 16:00 1.00 0 268 COMPZ FISH FISH T TIH with Fishing Assembly, Set down at 254 -ft, rotate 1/4 turn, fall passed, set down at 265 -ft try 5 times to locate tbg stub,rotated 4 times and worked over fish to 268- ft.Pulled 10k and slip off 4 times, seen good stall and over pull and slip again.Up & Dn Wt 42k Page 40 of 67 Time Logs 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:15 0.25 268 0 COMPZ FISH TRIP T Blow Down Top Drive, POOH and Inspect Fishing assembly. Run Same Fishing Assembly again, change Catch from 3 1/2 to 3 3/8". 16:15 18:00 1.75 0 270 COMPZ FISH FISH T TIH with Fishing Assembly, Set down at 254 -ft, rotate 1/4 turn, fall past, set down at 266 -ft rotated down to 268 -ft rotated and torque up several seen 5k,8k -10k over - pulls, work down to 269 -ft with same results, continue to slip off. POOH 18:00 20:00 2.00 0 0 COMPZ FISH OTHR T Make Repairs to Cut Lip Guide Shoe. Clean and Clear floors. 20:00 21:00 1.00 0 267 COMPZ FISH OTHR T PJSM. MU Milling Assembly.5 3/4" TSWP Guide Shoe with 4 3/4" Inner Mill Assembly and RIH to 266.7 -ft 21:00 23:30 2.50 267 251 COMPZ FISH OTHR T Sat down at 266.7 -ft, set parameters, start milling and slipped off the side. PUH again re- locate again at 266.7 -ft, start milling at 2 BPM, 70 psi, 40 rpm, 1 k free torque, 2k milling torque, 2k to 6k WOB, 42k up wt, 42 do wt. unable to hold mill on Tubing, slipping off to side. PUH 15 -ft and recondition hole 1.5 times volume 4 bpm at 100 psi. TOOH, wear on bottom outside only of cut lip shoe of overshot. 23:30 00:00 0.50 0 0 COMPZ FISH OTHR T MU Fishing Assembly. 6 1/8" Short O/S Guide w/ a 3 1/2" Catch. 11/02/2011 RIH w/ BHA 77 & 78, no recovery. RIH w/ 7 3/4" swage , Drift 9 5/8" casing to 95 -ft. Discuss plan forward with Anchorage Engineer. RU E -line. Run Expro Side View Camera to 268 -ft. Ran 7 3/4" Junk Mill , Mill from 266 -ft to 267.8 -ft. Run 5 7/8" RCJB to 268 -ft. PU BHA 84 and RIH to 69 -ft. 00:00 01:30 1.50 0 267 COMPZ FISH TRIP T RIH w/ Fishing Assembly. 6 1/8" Short O/S Guide w/ a 3 1/2" Catch, straight on 3 1/2" DP to 254 -ft, rotate 1/4 turn to pass, sat down at 267 -ft, rotate 1/4 turn and fell thru to 271 -ft, PUH and repeat several times, unable to stay on fish- TOOH, no marks on Cut Lip Shoe 01:30 04:00 2.50 0 267 COMPZ FISH TRIP T RIH w/ same Fishing Assembly on 4 3/4" Bent Sub to 267 -ft, same results as previous run- TOOH. 04:00 05:00 1.00 0 0 COMPZ FISH PULD T MU 7 3/4" Swage Assembly, secure well for safety stand up. 05:00 07:00 2.00 0 0 COMPZ FISH SFTY P Safety Stand Up with Nordic Rig 3 crews, Transport drivers in attendance, Focus on 4th quarter safety awareness. 07:00 08:00 1.00 0 95 COMPZ FISH TRIP T PJSM- PU and RIH w/ Bull Nose, XO Sub's, 7 3/4" casing Swage, XO Sub, Bumper Sub, Jars (BHA 80) on 1 Stand of 4 3/4" DC's, sat down at 55 -ft, 3k down wt to ease thru to 95 -ft, unable to get deeper- TOOH. Page 41 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:00 1.00 0 267 COMPZ FISH PULD T PU MU 5 3/4" Overshot (3 3/8" Grapple) 1.75° Bent Sub and RIH on 3 1/2" Tubing to 267 -ft and park. 09:00 10:30 1.50 267 267 COMPZ EVALWE ELOG T Wait On E -Line. 10:30 12:00 1.50 267 267 COMPZ EVALWE PULD T E -Line On Location. PJSM. Spot E -Line Unit and Load Equipment to Rig Floor.. 12:00 15:00 3.00 267 266 COMPZ EVALWE ELOG T Displace welibore with filtered fresh water, 18 bbls at 1 bpm, 60 psi. Open TIW valve and RIH with Expro camera while circulating at same rate and pressure. Was able to obtain good picture of 7" Casing and 9 5/8" CSG, was able to see inside the 7" CSG and obtain side view of sidetrack section of 7" & 9 5/8" Note: See Video on S -Drive 15:00 15:45 0.75 266 266 COMPZ EVALWE PULD T POOH with E -Line and Lay the Same. Download Data. Load Welibore with 12.1 ppg brine. 15:45 16:15 0.50 266 0 COMPZ EVALWE TRIP T PJSM. POOH with 5 3/4" Overshot 3 3/8" Grapple) 1.75° Bent Sub.Lay Down Same. 16:15 18:45 2.50 0 268 COMPZ FISH MILL T MU & RIH w/ 7 3/4" Milling Assembly, had to rotate at 55' 95' and 254 -ft. Dry Tagged at 266.88 -ft, PUH and Set Parameters.Rotate at 60 rpm, pumping 4 bpm, 140 psi, 1k free torque, 2 -3k WOB. Time Milled from 266.88 -ft to 267.75 -ft, Pump 10 bbl High -Vis Sweep around to surface. 18:45 21:00 2.25 268 0 COMPZ FISH TRIP T PUH and pulled 40k over, set back down and rotate out from 268 -ft to 260 -ft with several stalls, continue rotate to 250 -ft, POOH with no more problems. Inspect Mill, minimal wear on face, outer edges rounded, stabilizer blades on mill body show wear, Lay down Same. 21:00 23:00 2.00 0 268 COMPZ FISH TRIP T MU and RIH with 5 7/8" RCJB, sat down with RCJB at 266.25 -ft. PUH 1 foot, and started circulating at 8 bpm, 1150 psi for 15 minutes working up & down to 268 -ft, good returns across shaker. 23:00 23:30 0.50 268 0 COMPZ FISH TRIP T POOH from 268 -ft w/ RCJB, no returns. 23:30 00:00 0.50 0 69 COMPZ FISH PULD T PJSM- PU MU 5 3/4" Overshot ( 3 3/8" Grapple) 1.75° Bent Sub and RIH on 3 1/2" Tubing to 69 -ft. 11/03/2011 Run BHA 84. Ru E -line. Ran Expro Side View Camera. Ran 5 3/4" Magnet. Discuss plan forward with Anchorage Engineer. Ran Expro SVC to evaluate 9 5/8" Casing at 254 -ft, 95 -ft and 54 -ft. Page 42 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 69 268 COMPZ FISH TRIP T Continue TIH w/ 5 3/4" Overshot ( 3 3/8" Grapple) 1.75° Bent Sub, on 3 1/2" Tubing from 69 -ft to 268 -ft and park. 01:00 02:00 1.00 268 268 COMPZ EVALWE RURD T PJSM- RU a -line. Load E -line equipment to floor and RU E -line and Expro Side View Camera equipment. 02:00 02:15 0.25 268 268 COMPZ EVALWESFTY T PJSM- Hazards of Sim -ops, communication a must. 02:15 04:15 2.00 268 268 COMPZ EVALWE ELOG T Displace wellbore with filtered fresh water, 15 bbls at 3 bpm, 60psi. Open TIW valve and RIH with Expro camera while circulating at same rate and pressure. Able to obtain good picture of 7" Casing and 9 5/8" CSG, was able to see Drive. 04:15 05:15 1.00 268 268 COMPZ EVALWE ELOG T POOH with E -Line and Lay the Same. Download Data. Load Wellbore with 12.1 ppg brine. 05:15 06:30 1.25 268 0 COMPZ FISH TRIP T PJSM. POOH with 5 3/4" Overshot 3 3/8" Grapple) 1.75° Bent Sub.Lay Down Same. 06:30 07:30 1.00 0 266 COMPZ FISH OTHR T PU BHA #85, RIH w/ 3.5" Drill Pipe, set down at 254 -ft, tagged and parked BHA at 266.13 -ft with Fishing Magnet. POOH. Magnet was clean. 07:30 11:00 3.50 0 0 COMPZ EVALWE OTHR T Discuss plan forward with Anchorage Engineer. Call Out E -Line Crew. 11:00 12:00 1.00 0 259 COMPZ EVALWE PULD T PJSM. PU BHA #86, RIH and Park at 259 -ft. 12:00 13:15 1.25 259 259 COMPZ EVALWE OTHR T Wait On E -Line Change Out. 13:15 22:00 8.75 259 40 COMPZ EVALWE ELOG T PJSM. Rig Up E -Line, Load Lubricator and Expro Tools to Rig Floor. MU Logging BHA to Work String. Flush Wellbore with Filtered Fresh Water at 4 bpm, for 10 min, open TIW valve and RIH with logging tools with charge pump only. Start logging key area of 9 5/8" CSG. Locate and Tie in at 266.13, PUH w/ TBG to 261.4, perform 360 video log, area was cloudy, PUH to 252',RIH to 256',PUH to 255' PUH to 253 -ft and was able to obtain good video of damage 9 5/8" CSG. PUH to next area at 105 -ft to view damage area and PUH to 55 -ft and repeat same video log, good 360° video logs of 9 5/8" CSG from 115 -ft to 40 -ft. See Video on S drive. 22:00 22:30 0.50 40 0 COMPZ EVALWE ELOG T POOH with E -Line and Lay Down Same. Download Data. Single down last 2 joints of 3 1/2" TBG. 22:30 23:00 0.50 0 0 COMPZ FISH OTHR T Clear and clean floors. Change over floors to run Drill Pipe. Page 43 of 67 Time Logs • • Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 259 COMPZ FISH CIRC T PJSM- PU MU and TIH with Bull Nose on 3 1/2" DP, Park at 259 -ft. Load Wellbore with 12.1 ppg brine, 2 volumes. BDTD. 11/04/2011 Set 9 5/8" RBP. Set Test Plug. Perform Weekly BOPE Test. Pull Test Plug and 9 5/8" RBP. Ran Tandem 6 1/8" String Mill Assembly. Ran 6 3/8" String mill Assembly. Ran Tandem 6 3/4" String Mill Assembly. Ran 7 3/4" Strin• Mill Assembl . 00:00 00:15 0.25 259 0 COMPZ FISH PULD T TOOH with 3 1/2" DP from 259 -ft stand back same. 00:15 00:30 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM with Rig Crew and Baker Rep. 00:30 00:45 0.25 0 0 COMPZ WHDBO PULD P Load Baker Tools to Rig Floor. 00:45 01:45 1.00 0 50 COMPZ WHDBO MPSP P MU and RIH to 48 -ft and Set RBP. Top of Element at 42 -ft. 01:45 02:00 0.25 0 0 COMPZ WHDBO PULD P LD BHA Setting Tool Assembly 02:00 03:00 1.00 0 0 COMPZ WHDBO PRTS P RU Testing Equipment.Fluid Pack Lines, Attempt to pressure test RBP to 250/500 psi failed, trouble shoot, RBP not holding. 03:00 04:30 1.50 0 43 COMPZ WHDBO PULD T MU Retrieving Head and RIH to RBP at 48 -ft, release and PUH, Set RBP at 43 -ft, Mid Element at 39 -ft, TOOH and LD Setting Tool Assembly. 04:30 05:00 0.50 0 0 COMPZ WHDBO PRTS P Fluid Pack Lines, Pressure test RBP to 250/500 psi. 05:00 06:00 1.00 0 0 COMPZ WHDBO SEQP P PJSM. Pull Wear Bushing and Set Test Plug. 06:00 11:00 5.00 0 0 COMPZ WHDBO SVRG P Inspect and Clean Pipe Ram Body. Found Sand and Debris in Ram Cavities . Change Out Blind Ram Seals. Contacted AOGCC at 10:50 AM, States right to witness test waived by Chuck Scheve at 10:55 AM on 11/03/2011 11:00 16:00 5.00 0 0 COMPZ WHDBO BOPE P Test Weekly BOP Test. Test BOPE and Annular to 250/3500 psi. Perform Draw Down On Accumulator System. Pull Test Plug and Set Wear Ring. 16:00 17:30 1.50 0 38 COMPZ WHDBO MPSP P MU RBP Retrieving Head, RIH, Locate and Latch Plug at 38 -ft. Pull Tension, Let seals Relax. POOH and Lay down same. 17:30 18:00 0.50 0 63 COMPZ FISH PULD T PJSM. MU 6" OD Stabilizer with a 6.30" OD String Mill Assembly. Page 44 of 67 lime Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:30 0.50 63 267 COMPZ FISH MILL T RIH with String Mill Assembly. Set Down at 62.5 -ft, MU to Top Drive and Rotate Thru with no problem. Continue down and set down at 266.75 -ft with 3 1/2" Mule Shoe(Note: The Full Gauge of the 6 3/8" String Mill was 1.5 -ft Up from the Bottom of Mule Shoe) Did Not Encounter any problems getting passed the damage area at 254 -ft of the 9 5/8" CSG. 18:30 19:00 0.50 267 0 COMPZ FISH TRIP T TOOH and Remove 6.30" OD String Mill assembly. 19:00 19:30 0.50 0 267 COMPZ FISH MILL T PJSM. MU Tandem 6 3/4" OD String Mill Assembly and TIH to 267 -ft, no problems, set down 3k and fell to 268.8 -ft, pick off clean. Did Not Encounter any problems getting passed the damage area at 254 -ft of the 9 5/8" CSG. 19:30 20:00 0.50 267 267 COMPZ FISH SFTY P Crew Change out, PJSM, Bring BHA to floor 20:00 20:30 0.50 269 0 COMPZ FISH TRIP T TOOH and Remove 6 3/4" OD Tandem String Mill assembly. 20:30 21:00 0.50 0 0 COMPZ FISH PULD T PU MU Bull Nose, 7 3/4" String, 6 3/4" String Mill Assembly. 21:00 22:45 1.75 0 267 COMPZ FISH MILL T RIH with Tandem String Mill Assembly. Set Down at 54 -ft, MU to Top Drive, Continue down from 54 -ft with 2k to 4k drag to 115 -ft. Continue TIH with no problems and set down at 258.5 -ft (Note: The Full Gauge of the 7 3/4" String Mill was 2.4 -ft Up from the Bottom of Bull Nose) PUH with 5k over pull. Set Parameters 42K up wt / 42k do wt, 3 bpm at 60 psi, 40 rpm, 1000 ft-lb free torque, start milling at 256.5 -ft, 1k WOB, 1000 Torque while milling thru to 258.5 -ft, stop rotation, set down at 267 -ft, Pick off with 5k overpull. 22:45 23:30 0.75 267 0 COMPZ FISH TRIP T TOOH and Remove 7 3/4" OD and 6 3/4" OD Tandem String Mill assembly. 23:30 00:00 0.50 0 0 COMPZ FISH PULD T PJSM- PU MU 6 3/4" Concave Junk Mill on 4 3/4" Mud Motor (set at 1.15 °) Assembly. 11/05/2011 Ran 6 3/4" Concave Junk Mill on 4 3/4" Mud Motor. Ran 5 7/8" RCJB. RU E -line. Run Expro Side View Camera. Continue with Fishing and Milling Operations. Ran 7 3/4" Junk Mill on 4 3/4" Mud Motor. 00:00 00:30 0.50 0 0 COMPZ FISH PULD T Continue MU 6 3/4" Concave Junk Mill on 4 3/4" Mud Motor (set at 1 °) Assembly. Page 45 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T. Comment 00:30 02:15 1.75 0 267 COMPZ FISH MILL T TIH with 6 3/4" Junk Mill / Motor Assembly while scribing pipe to heel of motor. sat down at 266.5 -ft, Pick up, rotate and sit down at same place multiple times, unable to fall out window for orientation of mill 02:15 03:00 0.75 267 0 COMPZ FISH TRIP T PJSM- TOOH with 6 3/4" Junk Mill / Motor Assembly and lay down same. 03:00 04:00 1.00 0 269 COMPZ FISH TRIP T PU MU 5 3/4" Over shot, 1.75° Bent Sub Assembly and TIH scribing DP to heel of Bent Sub and Cut Lip Shoe, Sat down at 266.5 -ft, Rotate 1/8 turns unable to pass 266.5 -ft, rotate 10 rpm and slip by to 269 -ft, PUH and sat down at 266.5 -ft again 04:00 05:00 1.00 269 265 COMPZ FISH OTHR T Pick up and drop 10.09 -ft DP Pup, add 6.10 -ft 3 1/2" DP Pup, set back down at 266.5 -ft and Pick Up 1.5 -ft, set in slips and ready for E -line Camera Run. 05:00 06:00 1.00 265 265 COMPZ FISH CIRC T Ciculate 10 bbl high visc sweep. 06:00 09:00 3.00 265 265 COMPZ EVALWE ELOG T E -Line On Location. PJSM. Spot E -Line Unit and Load Equipment to Rig Floor.. RIH with Expro Video Logging tools on E -Line down to top of damage 7" CSG. Was able to Orient Cut Lip Guide to the top of damage 7" area and make scribe marks on tools, rig floor table and draw works. 09:00 10:30 1.50 265 0 COMPZ EVALWE PULD T POOH and Stand back E -Line Equipment and Tools. POOH with Drill Pipe Work String and Lay Down same. 10:30 10:45 0.25 0 51 COMPZ FISH PULD T MU 6 3/4" Concave Junk Mill on 4 3/4" Mud Motor (set at 1°) Assembly. 10:45 11:30 0.75 51 254 COMPZ FISH MILL T TIH with 6 3/4" Junk Mill / Motor Assembly while scribing pipe to heel of motor. Unable to Get Passed 254 -ft after several attempts. POOH and UD Same. 11:30 13:00 1.50 0 254 COMPZ FISH MILL T MU and RIH with String Mill Assembly. Set down at 254 -ft, no milling action, bullnose spinning of downhole object. POOH, UD Same. 13:00 14:30 1.50 0 266 COMPZ FISH MILL T MU 7 3/4" String Mill Assembly with a 6" Smooth OD Junk Mill. Set down at 255 -ft w /6" Mill, Up /Dn wt 42k,Mill thru bad spot at 4 bpm,60psi,60 RPM,2 -4K WOB,1 -2K free torque. Milled passed and No -GO at 266 -ft. Work tight spot at 255 -ft 10x. POOH and UD Same Page 46 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:15 1.75 0 266 COMPZ FISH MILL T MU and RIH with 6 3/4" Junk Mill on 4 3/4" bent motor. Tagged at 266.5 -ft, Up /Dn Wt= 42k,circulate at 6 bpm,460 psi. Motor work at 560 psi, located and Milled 1 foot, and went out window. P/U turned 30 degs left. S/O tag, motor work to 560 psi, Slipped out agian. Rotate 30 degs Right Slight motor work and slipped out. Started rotating 10 degs at a time. Worked 360 degs. Saw slight motor work just before slipping out window each time. 16:15 16:45 0.50 266 0 COMPZ FISH TRIP T PUH, B/D Top Drive. TOOH, Inspect Motor and Mill and Lay down same. 16:45 17:00 0.25 0 34 COMPZ FISH PULD T PJSM. MU RCJB Assembly. 17:00 17:30 0.50 34 269 COMPZ FISH CIRC T TIH 5 3/4" RCJB w/ 5 7/8" Head and 6" OD Stabilizer. Parked Junk Basket at 265 -ft, On Line with Mud Pumps @ 8 bpm, 1120 psi, rotating at 25 RPM, 750 ft-Ibs. Continue Down Hole while Rotating to 269 -ft, repeat 4x. 17:30 18:30 1.00 269 0 COMPZ FISH TRIP T TOOH and Inspect and Lay Down RCJB. Clean & Clear Floor. 18:30 19:15 0.75 0 266 COMPZ FISH TRIP T PU MU 5 3/4" Over shot, 1.75° Bent Sub Assembly and TIH scribing DP to heel of Bent Sub and Cut Lip Shoe, Sat down at 266 -ft. Ready for Camera run. 19:15 21:45 2.50 266 266 COMPZ EVALWI ELOG T E -Line On Location. PJSM. Spot E -Line Unit and Load Equipment to Rig Floor.. RIH with Expro Video Logging tools on E -Line down to top of damaged 7" CSG. Cut Lip Guide oriented 180° from center of window, top of damaged 7" CSG still needs dressing off, does not appear that 6 3/4" Junk Mill over far enough to get all of damaged 7" CSG, make scribe marks on tools, rig floor table and draw works. 21:45 23:15 1.50 266 0 COMPZ EVALWI ELOG T PJSM- POOH and Stand back E -Line Equipment and Tools. POOH with Drill Pipe Work String and Lay Down same. 23:15 00:00 0.75 0 52 COMPZ FISH PULD T MU 7 3/4" Concave Junk Mill on 4 3/4" Mud Motor (set at 1.5 °) Assembly. 11/06/2011 Ran 7 3/4" Concave Junk Mill on 4 3/4" Mud Motor. Ran RCJB. RU E -line. Ran Expro Side View Camera. Ran 4 3/4" x 2 7/8" Inner Mill. MU 5 3/4" Overshot with 3 1/2" Grapple. Page 47 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 52 268 COMPZ FISH MILL T TIH with 7 3/4" Junk Mill on 4 3/4" bent motor set at 1.5 °. Tagged at 264.5 -ft, Rotate 1/2 turn to slide past and sit down at 266.25 -ft, orientate and set parameters, Up /Dn Wt= 42k,circulate at 6 bpm,460 psi. Motor work at 560 psi, located and Milled 1.75 foot, SD pumps and tagged at 268.0 -ft 01:30 01:45 0.25 268 0 COMPZ FISH TRIP T PJSM- PUH, B/D Top Drive. TOOH, Inspect Motor and Mill and Lay down same. * *Note: Day Light Savings Time, Clocks set back 1 Hour. 01:45 02:45 1.00 0 34 COMPZ FISH SFTY T PJSM. MU Shortened RCJB Assembly. 02:45 03:45 1.00 34 268 COMPZ FISH CIRC T TIH 5 3/4" RCJB w/ 5 7/8" Head scribing pipe heel side. Parked Junk Basket at 267.8 -ft, On Line with Mud Pumps @ 8 bpm, 1020 psi, reciprocate up / down 4x 03:45 04:45 1.00 268 0 COMPZ FISH TRIP T PJSM- TOOH and Inspect and Lay Down RCJB. Clean & Clear Floor. 04:45 06:00 1.25 0 266 COMPZ FISH TRIP T PJSM- PU MU 5 3/4" Over shot, 1.75° Bent Sub Assembly and TIH scribing DP to heel of Bent Sub and Cut Lip Shoe, Sat down at 266.25 -ft. Ready surface equipment for Camera run. 06:00 07:00 1.00 266 266 COMPZ EVALWE ELOG T E -Line On Location. PJSM. Load Equipment to Rig Floor. 07:00 09:00 2.00 266 266 COMPZ RIGMN1 RGRP T Repair Shale Shaker Motor. 09:00 10:30 1.50 266 266 COMPZ EVALWE ELOG T PT Lubricator 500 psi. Displace wellbore with 15 bbl filter fresh water, open TIW and RIH w /Expro camera on a -line. Logged area milled,could still see a small section of 7" CSG above 3 1/2" TBG Stub. POOH and S/B E -Line. 10:30 14:15 3.75 0 266 COMPZ EVALWE ELOG T MU & RIH with BHA #101, 5 3/4" OD x 4 5/8" ID Flat Bottom Shoe with 5 3/4" Washover Boot Basket. Park Work String at 266 -ft, R/U E -Line and Expro Logging Tools.RIH and used camera to rotate Shoe inside 7" CSG, R/B E- Line,Dry drill down 4 -6 inch, RU E -Line and RIH to top of tubing stub. Appears we our over the stub. POOH and S/B E -Line. Dry Drill 7" one more inch. RU E -Line to take another look. 3 1/2" Stub is now inside the shoe. POOH and S/B E -Line. 14:15 14:45 0.50 266 269 COMPZ FISH MILL T Start Burning over 3.5" TBG with Flat Bottom Shoe with charge pump only, rotating at 50 RPM,50 psi. Page 48 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 16:30 1.75 269 269 COMPZ EVALWE ELOG T B/D Top Drive. RU E -Line & Expro Camera Tools Again to take another look at the process. Camera indicated that the shoe was milled down over the 3.5" TBG 1.7 -ft. Discuss Process with town engineer and plan forward. POOH and R/B E -Line. 16:30 17:00 0.50 269 0 COMPZ FISH TRIP T Swap Wellbore over to 12.1 ppg brine. Blow down Top Drive. POOH and Rig Down Work String. 17:00 17:30 0.50 0 58 COMPZ FISH PULD T Bring in Baker Tools and MU BHA #102, 5 3/4" x 4 5/8" Flat bottom Shoe, (Cutright on leading edge and insde shoe only) 4 3/4" x 2 7/8" Dress Off Mill (Note: 3" from btm of shoe to nose of Inner Mill, 1.2 -ft swallow to tag 4 3/4 Mill on 3 1/2 top) 6 3/4" Washover Boot Basket, 3 1/2" Bent Joint, Bumper Sub, Jars. 17:30 20:30 3.00 58 269 COMPZ FISH MILL T TIH with BHA #102, slipping by, work to sit down at 267.6 -ft and stay, 42k up wt / 42k do wt, 40 rpm, 3 bpm at 70 psi, 900 ft/lbs free torque, start milling with 1100 to 1300 ft/Ibs torque to 269.0 -ft, PUH pump 10 bbl high visc sweep. 20:30 21:00 0.50 269 0 COMPZ FISH TRIP T PJSM- B/D Top Drive. TOOH with BHA #102, Inspect and Lay Down Dress Off Mill. 21:00 21:30 0.50 0 39 COMPZ FISH PULD T PJSM- MU BHA #103, 5 3/4 Overshot with 3 1/2 Grapple (7" from bottom of shoe to bottom of grapple) (3 1/2 Mill Control Packoff) with Upper Extention, Bent Joint. 21:30 22:15 0.75 39 267 COMPZ FISH FISH T TIH with BHA #103 on DP, Park at 266.5 -ft, Tool Joint across KB, swap top joint and pup around, Ready Surface equipment for Camera run. 22:15 00:00 1.75 267 267 COMPZ EVALWE ELOG T PJSM with E -line / Camera crew, RU _ E -line with Expro Camera. 11/07/2011 Ran BHA #103- 5 3/4" Overshot with 3 1/2" Grapple. RU E -line. Ran Flat Bottom Shoe BHA #104. Ran BHA #105- 5/34" Overshot and Engage Tubing Stub at 272 -ft. Pull Tubing to 90k on the hook. Test Overshot Seal to 500 psi. RU Slickline. Bail Metal Shavings from 267 -ft to 300 -ft. 00:00 01:00 1.00 267 268 COMPZ EVALWE ELOG T TIH with E -line and Expro Camera. Overshot sitting on top of 7" CSG, 1/4 turn right and fell 1 -ft, good pictures of clean top of TBG stub at 268.3 -ft, sit down at bottom of window with OS, 1/4 turn left and fell past to just above top of TBG, TOOH and Stand Back E -line. 01:00 01:30 0.50 268 268 COMPZ WELCTE CIRC T Circulate well to 12.1 ppg brine. RD circulating equipment, Clear and clean floors. Page 49 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:00 0.50 268 269 COMPZ FISH FISH T Add 2 ea. 3 1/2" DP Pups to work string, Hook up to Top Drive and slide Overshot on 3 1/2" Tubing stub, unable to engae stub, pulls off 3 -5k over. 02:00 02:30 0.50 269 0 COMPZ FISH TRIP T PJSM- TOOH with Overshot, inspect and LD same. 02:30 04:15 1.75 0 272 COMPZ FISH FISH T PU MU and TIH with BHA #104- 5 3/4" x 4 5/8" Flat Bottom Shoe, Drive Sub, Bent Joint, Bumper Sub, Jars on DP to 269 -ft, set parameters 42k up / dn wt, 30 rpm, 2 bpm at 70 psi, 1000 ft/lb free torque, rotate down to 270 -ft, 1300 to 1500 ft/lb working torque, stalled PU 10k over to free, up rate 40 rpm, 3 bpm at 70 psi, 1000 ft/lb free torque, TBIH and rotate down to 270.5 -ft, stalled PU 20k over to free, TBIH and rotate down to 272 -ft, PUH stop rotation, TBIH and tag at 272 -ft- PUH and circulate 10 bbl high visc sweep. 04:15 04:45 0.50 272 0 COMPZ FISH TRIP T PJSM- B/D Top Drive. TOOH with BHA #104, Inspect and Lay Down Flat Bottom Shoe. 04:45 05:15 0.50 0 39 COMPZ FISH PULD T PJSM- MU BHA #105, 5 3/4 Overshot with 3 1/2 Grapple (7" from bottom of shoe to bottom of grapple) (3 1/2 Mill Control Packoff) with Upper Extention, Bent Joint. 05:15 06:00 0.75 39 272 COMPZ FISH FISH T TIH with BHA #105 on DP, 42k up wt / 42k dn wt, Engage Tubing Stub at 272.0 ft, PU to 50k, pressure Tubing to 150 psi, holding, Tool Joint nearing bushing, PU to 65k and set in slips, Pressure Tubing to 500 psi, holding good, Bleed Tubing to 0 psi. Ready Surface equipment for Slickline Drift. 06:00 07:00 1.00 272 272 COMPZ FISH OTHR T Wait on Slickline to arrive. 07:00 10:30 3.50 0 268 COMPZ FISH SLKL T Slick -line On Location. Held PJSM with Rig Crew and SL Crew. Spot Unit and Load Equipment to Rig Floor. MU and RIH w /Slick -line tool and set down at 268 -ft SLMD with 1 3/4" Bailer. POOH and Inspect tools, found bailer full of fill and junk from inside of TBG. Continue Slick -line Operations. 10:30 11:00 0.50 0 267 COMPZ FISH SLKL T PT RIH W/ 5'x 1.75" DRIVER DOWN BAILER MULE SHOE BALL, SIT DOWN @ 267' SLM WORK TOOLS DOWN 1' POOH OOH W/ MUD / ROCK / METAL 11:00 11:30 0.50 0 0 COMPZ FISH SLKL T MODIFY BAILER BOTTOM . Page 50 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:15 0.75 0 274 COMPZ FISH SLKL T RIH W/ 5'x 2" DRIVE DOWN BAILER MULE SHOE FLAPPER, SIT DOWN @ 269' SLM WORK DOWN TO 274' SLM POOH OOH W/ 1 CUP OF MUD /ROCK/METAL OD OF BIGGEST ROCK IS 1.05" . 12:15 13:30 1.25 0 279 COMPZ FISH SLKL T RIH W/ 5'x 2" DRIVE DOWN BAILER MULE SHOE FLAPPER, SIT DOWN @ 274' SLM WORK DOWN TO 279' SLM POOH OOH RECOVER 1 CUP OF MUD /ROCK/ METAL. 13:30 14:00 0.50 0 0 COMPZ FISH SLKL T SWAP TO 16' 1.875" STEM. 14:00 15:00 1.00 0 283 COMPZ FISH SLKL T RIH W/ 5'x 2.25" DRIVE DOWN BAILER MULE SHOE NO FLAPPER, SIT DOWN © 279' SLM WORK DOWN TO 283' SLM BEAT DOWN FOR 45 MIN POOH OOH BAILER EMPTY. 15:00 15:30 0.50 0 0 COMPZ FISH SLKL T PULL LUB OVER BEAVER SLIDE DROP TOOLS DOWN SLIDE CUT 300' WIRE. 15:30 16:15 0.75 0 284 COMPZ FISH SLKL T RIH W/ 5'x 2.25" DRIVE DOWN BAILER W/ CHISEL BOTTOM, SIT DOWN @ 283' SLM WORK DOWN TO 284' SLM BEAT FOR 40 MIN POOH, Metal Shavings. 16:15 16:45 0.50 0 285 COMPZ FISH SLKL T RIH w/ 2.25" Magnet to 285 -ft, POOH with Magnet covered approximately 1/4 cup metal. 16:45 17:15 0.50 0 275 COMPZ FISH SLKL T Drop 5 -ft of 1 7/8" stem from Toolstring, RIH with 10 -ft x 2.25" Pump Bailer (mule shoe ball) work bailer at 275 -ft 10 minutes, POOH with little return. 17:15 18:00 0.75 0 283 COMPZ FISH SLKL T RIH with same Pump Bailer Assembly to 275 -ft, work past tight spot to 283 -ft, work bailer 10 minutes, POOH with 1/2 cup Metal and small rocks. 18:00 18:45 0.75 0 285 COMPZ FISH SLKL T RIH with Same 2.25" P. Bailer Assembly to 285 -ft. Work bailer, POOH with little return. 18:45 19:45 1.00 0 293 COMPZ FISH SLKL T MU 1.99" Centralizer, 3 -ft x 1.2" stem and 1" Chisle Bottom prong and RIH to 285 -ft, work to 293 -ft and lose Spangs, pull 1000 LBS over pull to free up tools, POOH, no marks on prong. 19:45 21:00 1.25 0 0 COMPZ FISH SLKL T Cut 300 -ft .125" wire, wire jumped top sheave, send up man on tugger to fix. Page 51 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:00 1.00 0 294 COMPZ FISH SLKL T RIH with 5 -ft x 2.25" Drive Down Bailer, sit down at 290 -ft, work to 294 -ft and lose spangs, pull free, Sit back down at 290 -ft and work to 294 -ft, lose spangs, POOH no returns, marks on side of bailer indicate corkscrewed tubing. Swap Toolstring to 1.5" OD with K -Jars. 22:00 23:00 1.00 0 298 COMPZ FISH SLKL T RIH with 5 -ft x 2" DD Bailer, sit down at 290 -ft work to 298 -ft, PUH with 300 to 500# overpull, sit back down at 290 -ft and work to 294 -ft, tool stuck, work free and POOH, marks indicate corkscrewed tubing, no returns. Swap to 1.25" OD Slinky Toolstring. 23:00 23:30 0.50 0 300 COMPZ FISH SLKL T RIH with 1.75" sample bailer to 298 -ft, PUH clean, work bailer to 300 -ft, POOH with little return. 23:30 00:00 0.50 0 0 COMPZ FISH SLKL T Slickline relief crew change out on location, PJSM, Stand Back Slickline Equipment, Pull Tubing to neutral string weight 90k on the hook, DP moved up 1.5 -ft. 11/08/2011 Ran Bailers and Assorted Tools to Drift Tubing from 300 -ft to 616 -ft. 00:00 01:00 1.00 0 306 COMPZ FISH SLKL T RU Slickline Equipment. Swap Toolstring to 1.5" OD and RIH w/ 5 -ft x 2" Drive Down Bailer, work bailer from 297 -ft to 306 -ft, pick off clean with out over pull several times - POOH w/ 1 cup Metal shavings and small rocks. 01:00 01:30 0.50 0 309 COMPZ FISH SLKL T RIH w/ 1.99" Centralizer, 2 -ft x 1.25" stem and 1" chisel bottom prong, work prong from 306 -ft to 309 -ft, POOH, no marks 01:30 02:00 0.50 0 0 COMPZ FISH SLKL T Cut 100 -ft .125" wire. 02:00 02:30 0.50 0 287 COMPZ FISH SLKL T RIH with 10 -ft x 2.25" Pump Bailer, sat down at 286 -ft, work to 287 -ft, 500# overpull to free, length problem - POOH no return. 02:30 03:00 0.50 0 304 COMPZ FISH SLKL T RIH with 5 -ft x 2.25" DD Bailer to 306 -ft, work 10 minutes and losing ground to 304 -ft, POOH, 1/4" ding on muleshoe bottom, no returns. 03:00 04:00 1.00 0 312 COMPZ FISH SLKL T RIH w/ 1.99" Centralizer, 2 -ft x 1.25" stem and 1" chisel bottom prong, work prong from 306 -ft, unable to make hole, pressure tubing up to 500 psi, RBIH to 309 -ft, work bailer to 311 -ft, POOH with tools, Surge pressure to 0 psi, RBIH to 311 -ft, work to 312 -ft, POOH, 2 bottom T Tails broke off, no marks. 04:00 04:15 0.25 0 75 COMPZ FISH SLKL T RIH with 5 -ft x 2.25" DD Bailer to 75 -ft- POOH. Page 52 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:45 0.50 0 312 COMPZ FISH SLKL T RIH with 5 -ft x 2.0" DD Bailer, work bailer from 311 -ft to 312 -ft, POOH little returns. 04:45 06:00 1.25 0 312 COMPZ FISH SLKL T RIH with 1.99" Centralizer, 2 -ft x 1.25" stem and 1" chisel bottom prong, work prong at 312 -ft for 15 minutes no progress, POOH, no marks, T Tails intact. Cut 100 -ft .125 wire. Swap toolstring to 1.875" OD x 16 -ft. 06:00 06:45 0.75 0 312 COMPZ FISH SLKL T RIH with 5 -ft x 2.0" DD Bailer, work bailer at 312 -ft for 15 minutes, action appears good. POOH Ino returns. 06:45 08:15 1.50 0 312 COMPZ FISH SLKL T RIH with 1.99" Centralizer, 2 -ft x 1.25" stem and 1" chisel bottom prong, work prong at 312 -ft for 30 minutes no progress, POOH, no marks, T Tails intact. Slickline crew change out. 08:15 09:00 0.75 0 312 COMPZ FISH SLKL T RIH with 2" DD Bailer, Beat down hard at 312 -ft for 30 minutes with no progress, POOH no returns, small gouge on edge of muleshoe bottom. 09:00 09:45 0.75 0 312 COMPZ FISH SLKL T RIH with 3 -ft stem, 2.13" centralizer , 2.0" LIB to 312 -ft, POOH, 2 small pieces of debris on face of LIB. 09:45 10:15 0.50 0 312 COMPZ FISH SLKL T RIH with 2.15" magnet to 312 -ft, POOH with 2 small pieces of mill shavings. 10:15 10:45 0.50 0 312 COMPZ FISH SLKL T RIH with 3 -ft stem, 2.13" centralizer , 2.1" LIB to 312 -ft, POOH, 3/4" x 1" beveled mark on face of LIB. 1 0:45 11:30 0.75 0 312 COMPZ FISH SLKL T RIH with 2.13" centralizer ane 5 -ft x 1.75" DD Bailer, sat down at 312 -ftj. Jr dn, tools sticking, pull free and set back down at 312 -ft, unable to make hole or stick tools again, POOH 11:30 12:15 0.75 0 312 COMPZ FISH SLKL T RIH with 1.99" Centralizer, 2 -ft x 1.25" stem and 1" chisel bottom prong, work prong at 312 -ft for 30 minutes no progress, POOH, good marks. 12:15 13:15 1.00 0 312 COMPZ FISH SLKL T RIH with 2.15" magnet to 312 -ft, POOH fine mill shavings and small piece of metal, POOH and cut 150 -ft .125 wire. 13:15 13:45 0.50 0 312 COMPZ FISH SLKL T RIH w/ 2" Hydrostatic Bailer to 312 -ft, shear disc, POOH w/ bailer ful of fluid. 13:45 14:15 0.50 0 312 COMPZ FISH SLKL T RIH with 3 -ft stem, 2.13" centralizer , 2.1" LIB to 312 -ft, POOH, metal marks. 14:15 15:00 0.75 0 321 COMPZ FISH SLKL T Pressure well to 1000 psi and RIH with 2" Hyd. Bailer to 321 -ft, POOH did not shear bailer disc. Page 53 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 1.00 0 348 COMPZ FISH SLKL T Pressure Tubing to 1000 psi and RIH with 2.15" cent., 2 7/8" Braided Line Brush, 12" ext and 1" x 12" Prong to 321 -ft, work to 348 -ft, have to tap out of debris, POOH 16:00 17:00 1.00 0 335 COMPZ FISH SLKL T Pressure Tubing to 1000 psi and RIH with 2.15" cent., 2 7/8" Braided Line Brush, 12" ext and 1" x 12" Prong to 335 -ft, unable to work past 335 -ft with 1500 and 2000 psi on well, POOH. Cut 150 -ft .125 wire. Swap to 1.25" OD Slinky Toolstring. 17:00 18:00 1.00 0 324 COMPZ FISH SLKL T Pressure Tubing to 1000 psi and RIH with 2.15" cent., 2 7/8" Braided Line Brush, 12" ext and 1" x 12" Prong to 324 -ft, unable to work past 324 -ft, POOH. 18:00 18:45 0.75 0 0 COMPZ FISH SLKL T Nordic Rig 3 Crew Change Out, Move Pump -in -Sub above TIW. 18:45 19:30 0.75 0 347 COMPZ FISH SLKL T PfT surface equipment 2000 psi, Pressure Tubing to 1500 psi and RIH with 2 -ft x 1.25" stem and 3/4" OD poker to 339 -ft, unable to work deeper, PUH and bleed Tubing to 0 psi, RBIH to 317 -ft, pressure Tubing to 2000 psi and tag at 347 -ft, unable to work deeper, POOH. 19:30 20:15 0.75 0 0 COMPZ FISH SLKL T LD Slickline Equipment, Pull Tubing to 105k (14k over string weight) 20:15 22:15 2.00 353 486 COMPZ FISH SLKL T PfT surface equipment 2000 psi, RIH with 2 -ft x 1.25" stem and 3/4" OD poker to 321 -ft, Pressure well to 1000 psi and tag at 353 -ft, Pressure up and Surge well to 0 psi and work tools to 486 -ft, POOH 22:15 00:00 1.75 486 618 COMPZ FISH SLKL T Pressure Tubing to 1500 psi and RIH with 1.75" DD Bailer to 486 -ft, Rock Pressures 0 to 1500 psi and work Bailer to 618 -ft. Slickline crew change out. 11/09/2011 Continue Bailing and Drift Tubing with Slickline from 616 -ft to 2,180 -ft. 00:00 03:45 3.75 618 741 COMPZ FISH SLKL T Continue with 1.75" DD Bailer run, Rock Pressures 0 to 1500 psi and work Bailer from 618 -ft to 741 -ft. POOH. Swap to 1.5" OD Toolstring. Cut 500 -ft .125" wire. 03:45 06:15 2.50 0 1,084 COMPZ FISH SLKL T RIH with 2" x 5 -ft DD Bailer to 741 -ft, work thru and sat down at 780 -ft, PUH and continue working bailer getting frequent pick up weights to 1084 -ft and sat down, no spangs or K -jars, unable to free up spangs, surge pressures 0 to 1500 psi while working wire, POOH with tools, some metal in bailer. Page 54 of67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 16:30 10.25 0 2,175 COMPZ FISH SLKL T Change over tool string to 2.17" 1 Guage ring, 1.25" x 3 -ft stem bar, 2.875" TBG brush, RIH on 1.50 tool string to 1,210 -ft and was able to work down to 2,157 -ft over 10 hr session. POOH and change over to 2.26" OD guage ring with 1.875" stem. 16:30 18:00 1.50 2,175 2,180 COMPZ FISH SLKL T RIH with 2.26" OD gauge ring, work from 2,175 -ft to 2,180 -ft, POOH 18:00 00:00 6.00 2,180 2,180 COMPZ FISH SLKL T PJSM- Rig Down Slickline Unit 764 for scheduled maintenance in Prudhoe. PJSM with new Slickline crews. Move In and Rig Up HES Slickline Unit 214. 11/10/2011 Continue Bailing and Drift Tubing with Slickline from 2,180 -ft to 2,680 -ft. 00:00 02:00 2.00 2,180 2,213 COMPZ FISH SLKL T Pressure Test Equipment 2000 psi and RIH with 2.17" centralizer- 2 -ft x 1.25" stem, BLB and 12" x 1" prong to 2,180.0, work to 2,213 -ft, POOH to change out tools. 02:00 04:15 2.25 2,213 2,260 COMPZ FISH SLKL T RIH w/ 2" x 5 -ft DD Bailer to 2,213 -ft work bailer to 2,260 -ft unable to work deeper, POOH, good sized metal pieces in bailer. 04:15 06:00 1.75 2,260 2,276 COMPZ FISH SLKL T RIH w/ 2 -ft stem, BLB and 2.26" Gauge Ring to 2,266 -ft, work to 2,276 -ft, POOH, Cut 200 -ft .125" wire. 06:00 08:45 2.75 2,282 2,330 COMPZ FISH SLKL T RIH with 2" X 5 -ft DD bailer, work from 2,282 -ft to 2,330 -ft, POOH with metal shavings 08:45 10:15 1.50 2,332 2,400 COMPZ FISH SLKL T RIH with 5 -ft x 2.0" DD Bailer, work from 2.232 -ft to 2,400 -ft, POOH, no marks or returns. 10:15 13:00 2.75 2,411 2,412 COMPZ FISH SLKL T RIH w/ 2 -ft stem, BLB and 2.27" Gauge Ring to 2,411 -ft, work tools and unable to make hole. Make S/L crew change out at 11:30, work to 2,412 -ft, POOH, no marks, swap to 1.5" OD toolstring. 13:00 14:00 1.00 2,412 2,462 COMPZ FISH SLKL T RIH with 5 -ft stem and 2.27" Gauge Ring, work from 2,412 -ft to 2,462 -ft, POOH swap to 1.5" OD roller stem toolstring with 2.20" OD wheels. 14:00 16:00 2.00 2,462 2,462 COMPZ FISH SLKL T RIH with 1.5" rope socket, 5 -ft stem, 1.82" centralizer and 2 prong wire grab baited with 2" RS to 2,462 -ft, plant grab, JU for 10 minutes and come free, POOH work thru 260 -ft (bottom of DP) POOH, 1 tine bent on grab. Swap to 2 1/8" OD Toolstring. 16:00 18:30 2.50 237 2,507 COMPZ FISH SLKL T RIH with 5 -ft stem and 2.27" Gauge Ring, sat down at 237 -ft, chase obstruction down hole to 2,507 -ft, unable to work further down, POOH. Cut 100 -ft .125 wire. Page 55 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:30 2.00 2,504 2,504 COMPZ FISH SLKL T RIH with 2.25" bait sub, 3 -ft stem and 2 prong wire grab baited on 2.5" GR, sat down at 2,504 -ft, unable to engage fish or make hole, POOH, wire grab bent, repair and modify grab. 20:30 00:00 3.50 2,504 2,680 COMPZ FISH SLKL T RIH w/ same baited wire grab assembly, work from 2,504 -ft to 2,680 -ft, S/L crew change out, PJSM with Rig crew. 11/11/2011 Continue Bailing and Drift Tubing with Slickline from 2,680 -ft to 6,939 -ft. 64" OAL Slickline BHA left at 6,939 -ft. Cement in returns of last Bailer run to 6,939 -ft. 00:00 03:00 3.00 2,680 2,802 COMPZ FISH SLKL T Continue RIH w/ 2.25" baited wire grab assembly, work from 2,680 -ft to 2,802 -ft, pulled several binds while working grab assembly, POOH with 2" x 2- 13/16" x 1/2" piece of metal stuck inside wire grab, wire grab bent, cut 100 -ft .125" wire. 03:00 04:30 1.50 2,802 2,865 COMPZ FISH SLKL T RIH w/ 5 -ft stem and 2.27" Gauge Ring, sat down at 2,809 -ft, work to 2,865 -ft little progress, POOH, good marks on GR of another large piece of metal. Swap to 1 7/8" OD x 16 -ft toolstring. 04:30 05:30 1.00 2,868 2,902 COMPZ FISH SLKL T RIH with 2" x 5 -ft DD Bailer, work from 2,868 -ft to 2,878 -ft, pressure up tubing to 2000 psi, tag obstruction at 2,902 -ft, unable to make hole, PUH while bleeding tubing to 0 psi, tag obstruction at 2,878 -ft, repeat several times, POOH, 1 cup mill shavings in very thick slurry in bailer. 05:30 06:30 1.00 2,899 2,889 COMPZ FISH SLKL T RIH with Baited 2 prong wire grab assembly to 2,899 -ft, poor tool action, unable to work deeper, POOH. 06:30 07:30 1.00 2,889 2,900 COMPZ FISH SLKL T RIH with 5 -ft x 2.25" DD Bailer, work bailer down from 2,870 -ft to 2,900 -ft. Unable to work any deeper, reciprocate for 300 -ft and POOH. Bailer was full of schmoo and metal. 07:30 09:00 1.50 2,900 2,902 COMPZ FISH SLKL T Run back in hole with same setup to 2,870 -ft. Work down to 2,902 -ft, very poor action on tools. Recovered less metal and more crosslinked gel. Change out tool string for new - TS= 10 -ft of 2.125 ", 5 -ft of 1.875 ", OJ, KJ and LSS with 2.25" DD bailer. 09:00 10:15 1.25 2,902 2,903 COMPZ FISH SLKL T RIH to 2,903 -ft, unable to make hole - POOH and recovered Crosslinked Gel, control line and chunks of TBG. 10:15 16:00 5.75 2,903 3,477 COMPZ FISH SLKL T RIH w/ same tool string and work multiple times, POOH and recovering same plus a large piece of TBG to final depth of 3,477 -ft. Page 56 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:00 1.00 3,477 4,140 COMPZ FISH SLKL T RIH w/ same tool string and set down at 3,477 -ft, work down to 4,140 -ft - solid. Attempt to work while pressuring up to 1,500 psi on TBG - No help. POOH and recover Cross linked Gel, scale and metal cuttings. Bailer shoe showed good signs of metal markings. 17:00 21:00 4.00 4,140 6,924 COMPZ FISH SLKL T RIH w/ 2 prong wire grab assembly on 2.25" GR and work down from 4,140 -ft to 6,924 -ft, pulled 2 good binds and set off Oil Jars, POOH w/ out 2 Prong Wire Grab Assembly (64" OAL) redress and rerun GR. 21:00 22:30 1.50 6,924 6,932 COMPZ FISH SLKL T RIH with 2.25" GR, sat down at 6,928 -ft, unable to relatch grab assembly while working down to 6,932 -ft, POOH, no marks, not sheared. 22:30 00:00 1.50 6,936 6,939 COMPZ FISH SLKL T RIH with 2.25" x 10 -ft DD Bailer to 6,936 -ft, work to 6,939 -ft, POOH, good marks of fish -neck, metal, 2 pieces of control line and cement in bailer. Slickline crew change out. PJSM. 11/12/2011 Continue Bailing and Drift Tubing with Slickline from 6,939 -ft. 64" OAL Slickline BHA left at 6,942 -ft. Tubing Drifted 10 -ft x 2.25" to 6,942 -ft, Cement in returns. Perforate Tubing. Unable to establish T x IA communication. 00:00 01:30 1.50 6,939 6,939 COMPZ FISH SLKL T RIH with 2.25" GR to 6,939 -ft, unable to latch grab assembly, POOH 01:30 03:00 1.50 6,939 6,939 COMPZ FISH SLKL T RIH with 10 -ft x 2.25" Pump Bailer, work bailer at 6939 -ft, POOH, bailer full. 03:00 04:45 1.75 6,939 6,942 COMPZ FISH SLKL T RIH with 2.25" GR to 6,939 -ft, work tools to 6,942 -ft, unable to latch, POOH w/ out grab assembly. 04:45 06:15 1.50 6,942 6,942 COMPZ FISH SLKL T RIH with 5 -ft x 2.25" DD Bailer, work bailer at 6,942 -ft, no hole made, POOH w/ sand and cement in bailer. 06:15 08:00 1.75 0 0 COMPZ FISH PRTS P Rig Preform MIT -T to top of cement at 6,942 -ft to 2000 psi, Lost 50 psi in 30 minutes, Chart test. 08:00 10:30 2.50 0 6,940 COMPZ FISH SLKL P RIH with 2.29" centralizer, 10 -ft x 2.25" DD Bailer to 6,940 -ft and POOH - seen over pull at 340 -ft. RD Slick line unit. Page 57 of 67 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 10:30 00:00 13.50 6,950 6,950 COMPZ FISH ELNE P Spot E -Line unit, Held PJSM with rig crew. PU and MU lubricator and Radial torch perforator. PT lubricator against TIW valve and grease head at 500 psi. RIH to 6,950 -ft and attempt to punch hole at 6,920 -ft with 500 psi over balance on Tubing. Seen 40 psi increase. POOH and bump Lubricator. Pressure up to 1,500 psi with .5 bbls. No communication. Bleed off pressure and inspect perforator - fired. PU and MU perforator #2 and RIH to 6,950 -ft and attempt to punch hole at 6,890 -ft with 500 psi over balance, pressure spike to 1340 psi and settles back to 550 psi, pressure up to 1500 psi, No communication, POOH inspect perforator, fired. standby for 2" RCT from Prudhoe. 11/13/2011 Cut Tubing with Halliburton RCT. Unable to Establish Communication. Work Pipe 42k to 115k. RU E -line. Ran Free Point from 5,813 -ft. Ran CBL from 5,844 -ft. 00:00 05:00 5.00 6,950 6,950 COMPZ FISH PERF T 2" RCT from Prudhoe and fresh E -line crew on location, PJSM, PU and MU 2" Radial Cutting Torch with anchor system and RIH to 6,950 -ft PUH (1200# pick up wt) and set anchors and PU to 1400# line weight, cut tubing at 6,887 -ft with 70 psi over balance, 600# decrease in line weight, PUH and Pressure up to 1,500 psi with .5 bbls. No communication. Bleed off pressure and POOH to inspect RCT - fired. Stand back E -line equipment. 05:00 07:00 2.00 6,950 6,950 COMPZ FISH OTHR T Circulate Top Drive to 12.1. MU TIW to Top Drive with 10 -ft handling pup. Work pipe 42k to 115k with 5 -ft strech in pipe, tubing appears not cut, work pipe same pull weights with 1500 psi to hydraulic assist pipe, no movement and no communication. pull to 115k with 2000 psi, tubing sitting down 2 -ft high, bleed pressure off, set pipe back in slips at 115k, BDTD and confer with town engineer. 07:00 11:00 4.00 0 0 COMPZ FISH OTHR T Wait for Free point tools to arrive from Deadhorse Page 58 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 00:00 13.00 0 5,842 COMPZ FISH ELNE T Held PJSM on MU of free point tools. Set TBG at at neutral weight. MU and RIH with free point tools to 5,813 -ft and set down attempt to work thru - not able to. Had slight over pull. POOH and set free point tools and lubricator back. Cycle TBG 20 times from 40k to 115k land back in slips at 40k. RU and RIH • with free point tools minus earth magnets. Log showed to 75% free at 1,400 -ft, 25% free at 1,938 -ft (SSSV) and slowly tapered to 0% at 5,800 -ft. POOH and Change out tool string to CBL. Set lubricator back and land TBG in slips at 115k. Hang lubricator and RIH with CBL to 5,819 -ft, 600# over pull, pressure tubing to 1500 psi, tag at 5,824 -ft, work down to 5,844 -ft while workung tubing from 2000 psi to 0 psi, pick clean 5,842 -ft, POOH logging up CBL. 11/14/2011 Continue CBL from 5,844 -ft. RD E -line. RU Slickline and Drift Tubing. RU E -line and Run CBL from 6,919 -ft. MU Perf Gun. 00:00 03:30 3.50 5,842 0 COMPZ FISH ELOG T Continue POOH logging up with CBL from 5,842 -ft to surface, bump up with tools, unable to drop out of lubricator, PJSM on unusual Rig Down of E -line tools and Lubricator. 03:30 05:00 1.50 0 0 COMPZ FISH PRTS T RU pumping equipment, Cycle tubing pressures 0 psi to 1500 psi, 2000 psi, volumes consistent at .6 bbls to 1500 psi, .7 bbls to 2000 psi, RD pumping equipment and ready floor for Slickline. wait on Slickline. 05:00 12:30 7.50 0 6,887 COMPZ FISH SLKL T Slickline on location, spot equipment, PJSM hazards with bringing equipment to floor. RU Slickline and RIH with 10 -ft x 2.25" DD Bailer to 6,887 -ft. POOH and Dump bailer - recovered Schmoo and slag. PU and RIH w/ 2.25" OD LIB to 6,887 -ft - fell thru tight spot 5,870 -ft. POOH and had scuff marks. RD Slick line. 12:30 00:00 11.50 0 6,932 COMPZ FISH ELNE T RU E -line PU and MU GR/CCL and RIH to 6,932 -ft, POOH and PU CBL and RIH, sat down at 5,872 -ft, PUH and RBIH at 120 fpm to pass down to 6,919 -ft, Pressure up tubing to 2000 psi, Log Up maintaining 2000 psi to surface. PJSM- Hazards with rigging up Rig Safe Perf Guns, MU and RIH with 10 -ft x 2" Perf Gun, 6 spf with Big Bore Charges to 200 -ft. Page 59 of 67 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/15/2011 24 hr Summary Perforate Tubing. Establish Circulation Rate and Condition Hole. Pump Balance Plug. Wait on Cement. 00:00 03:00 3.00 200 6,880 COMPZ PLUG PERF T Continue RIH with 10 -ft x 2" Perf Gun, 6 spf with .59" OD Big Bore Charges from 200 -ft, Pressure tubing to 500 psi, Perf interval 6,870 to 6,880 -ft, tubing pressure dropped to 260 psi, PUH 1000 -ft, bring on pump 1 bpm at 570 psi and have returns to surface, POOH while circulating 1 bpm, pressure dropping to 70 psi at 25 bbls away, 1:1 returns 12.1 ppg heavy, Bump up E -line and hang in lubricator. 03:00 05:30 2.50 0 0 COMPZ PLUG CIRC P 100 bbls away at 1 bpm, 80 psi, 11.1 ppg returns, gradually bring pumps up to 2 bpm at 260 psi, 2.5 bpm at 320 psi, 3 bpm at 380 psi, 4 bpm at 540 psi and 5 bpm at 650 psi, 12.0 ppg heavy in and 12.0 ppg heavy out 05:30 07:00 1.50 0 0 COMPZ PLUG ELNE P PJSM- RD E -line 07:00 10:00 3.00 0 0 COMPZ PLUG CIRC P Circulate and condition wellbore at 5 bpm at 590 psi, circulating through perf holes from 6,870 -ft to 6,880 -ft. 12.1 ppg in and 12.1 ppg returns with 1 to 1 returns. 10:00 12:30 2.50 0 0 COMPZ CEMEN "CMNT P Held PJSM with rig crew, SLB and ASRC on cement job. MIRU and clear lines with fresh water. PT treating lines at 3,500 psi. Mix and pump 184 bbls of 15.8 ppg Class G cement and displace with 14.5 bbls of 12.1 ppg. Shut well in with 580 psi. Cement in place at 12:00 hrs. RD cementers. 12:30 00:00 11.50 0 0 COMPZ PLUG WOC P WOC with 540 psi shut in pressure till 18:00 hrs. Open up well to bleed, had zero psi. Continue to WOC. 11/16/2011 Continue to wait on Cement. Pressure test the Cement Plug to 1800 psi. RIH with E -line and tag top of Cement at 1538' RKB. Tag and pressure test witnessed by John Crisp AOGCC Inspector. RIH and Cut Tubing with 2.25" jet cutter at 1480' RKB. Could not establish circulation. Shoot 5' string shot 1473'- 1478'. Cut tubing at 1475 with 2" RCT cutter. Pull on tubing. Not free. 00:00 05:00 5.00 0 0 COMPZ PLUG WOC P Continue to wait on Cement. Spot E -Line Unit. Rig up floor to pressure test the Cement Plug. Call out State AOGCC Rep to witness the pressure test. Rig up E -Line equipment. Page 60 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:00 1.00 0 0 COMPZ PLUG PRTS P AOGCC Rep arrive on Location. Drain Stack and open the IA and OA to monitor during pressure testing the Cement Plug. Pressure test the cement plug down the Tubing. Starting pressure = 0 psi. Pressure up at 1,800 psi with 8 strokes (0.337 bbls). 15 minute pressure reading - 1,700 psi, 30 minute pressure reading = 1,650 psi. IA = no -flow. OA = no -flow, Good test. Test recorded on chart and witnessed by AOGCC Rep, J. Crisp. 06:00 08:00 2.00 0 0 COMPZ PLUG ELOG P Finish rigging up E -Line. RIH w/ CCL and Toolstring and tag up at 1,538 -ft. Retag for for verification. Tag was witnessed by AOGCC Rep, J. Crisp. 08:00 09:30 1.50 0 0 COMPZ PLUG SFTY P Suspend well operations and secure well. Held Safety Stand Up with Nordic Employee Day shift, HES E -Line - -Mike Berry's crew and Jeff Carter with Baker fishing. 09:30 20:00 10.50 0 0 COMPZ FISH ELNE P Open up well and re -land TBG at 60k in the slips, install dog collar and close annular. MU and RIH with 2.25" Jet cutter to 268 -ft, unable to get thru, POOH and found bow spring centralizer to be hanging up. PU on TBG string to 70k, land back in slips. PU and RIH w/ 2.25" Jet cutter to 1,550 -ft, PU to cut depth of 1,480 -ft and fire - good. POOH to 1,380 -ft and Run back in hole to 1,550 -ft - log out and CCL kicked at Jet cut depth, Continue to POOH and attempt to circulate - 2,000 psi in 9 pump strokes. MU and RIH w/ 5 -ft 160 GR string to 1,477.5 -ft and shoot from 1,472.5 -ft to 1,477.5 -ft. POOH. Halliburton Crew change -out. 20:00 22:00 2.00 0 0 COMPZ FISH ELNE P PJSM. Make -up 2" Extended Reach RCT. Pressure test lubricator at 500 psi. Good. Run in with RCT. Log into place with cutter at 1,475.0 -ft. Set Anchor. Good. Fire Radial Cuter Torch. Looks good on surface and in the Logging Unit. Jar the Anchor free on the first attempt. Pull RCT up inside the Lubricator. Attempt to break circulation with Rig pump at 500 psi and at 1,000 psi. No -joy. Lay down RCT. Cutter appears to have worked properly. Page 61 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 COMPZ FISH ELNE P Discuss plan forward with Anchorage Engineer. Set back E -Line. Pull on the Tubing up to 140K (80 %, included Blocks), several times. Land tubing back in slips w /55K on wight indicator and mark pipe. Prep for Free -Point logging. 11/17/2011 Record Free -Point Log and determing tubing is free at 1200'. Shoot string shot at 1140'- 1145'. Cut Tbg at 1141'with Radial Cutting Torch. Circulate well with 100 bbls 12.1 ppg brine. POOH with drill pipe, overshot, and tubing to 565'. Perforate 7" Csg at 1000' -1010' with 2.5" OD gun. RD E -Line. Continue to LD the remaining Tbg. Set 9 -5/8" bridge plug at 42'. 00:00 05:00 5.00 0 1,575 COMPZ FISH ELNE P Rig -up E -Line back on Well to free -point the Tubing. Pressure test Lubricator at 500 psi. Run in with Free -Point Tool (w /magnet installed). Tag TOC inside the Tubing at 1,575 -ft. Record base -line Log. Pull out. Set back E -Line. Cycle Tubing six times from 55K up to 140K. Land Tubing back at the 55K mark. Set Slips. Rig E -Line back up. Run in with the Free -Point Tool (no magnet), and record the Free -Point Log. Stop Tool at 1,550 -ft. Log up at 65- ft/min. Found good "free" Tubing at 1.200 -ft . Continue to log out of hole. 05:00 11:00 6.00 0 1,145 COMPZ FISH ELNE P Set back E -Line. Lay down Free -Point Tool. Build String Shot and prep for a 1 3/4" RCT run. RIH w/ string shot and shot from 1,140 to 1,145 -ft. POOH. PU and RIH w/ 1.75" OD ER RCT Cutter and RIH to 1,141 -ft and cut 3 1/2" TBG - good cut. POOH and spot toolstring up inside lubricator and leave hang. 11:00 11:30 0.50 1,145 1,145 COMPZ PLUG CIRC P Circulate 100 bbls of 12.1 ppg at 3 bpm at 110 ICP and 80 psi FCP. 11:30 12:30 1.00 0 0 COMPZ PLUG ELNE P RD Eline and lay off to the side for 2.5" x 10 -ft pert gun run. 12:30 14:00 1.50 0 565 COMPZ PLUG PULD P POOH with 3 1/2 DP, 5 3/4" OS w/ 6 -ft stub inside, 10 jts of 3 1/2 TBG to 565 -ft. Land TBG in slips at 50k. 14:00 17:00 3.00 0 1,250 COMPZ PLUG ELNE P PJSM, PU and RIH w/ 2.50" OD x 10 -ft pert gun and RIH to 1,250 -ft , pull up and shoot from 1,000 to 1,010 -ft. - good shot. POOH and RD E -line. Page 62 of 67 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:30 2.50 565 0 COMPZ PLUG TRIP P POOH w/ 4 jts fora total of 14 jts out and recovered a ball of .25" Control line. Worked control -Line through BOP Stack. Continue to lay down the remainder of the 3 1/2" Tubing and the attached Control Line. Recovered a total of 27 full Joints of 3 1/2" Tubing, a 22.10 -ft RCT Cut -Off Stub, 8 ea SS Bands. Note: the Halliburton 1 3/4" Extended Reach Radical Cutting Torch had made a "perfect" cut. 19:30 20:30 1.00 0 0 COMPZ PLUG BOPE P PJSM. Make -up the Swizzle Stick and jet out the inside of the BOP Stack. 8.0 bpm /50 psi. 20:30 00:00 3.50 0 42 COMPZ PLUG PACK P PJSM. Ready Rig Floor and Pipe Shed. Make -up BHA #106, Baker 9 5/8" Model G Retrievable Bridge Plug. Run in and set the RBP with the center element at 42 -ft and the fishing neck at 38 -ft. Pressure test the RBP at 1,000 psi. Good. Record on Chart. Lay down Setting Tool and Drill Collars. Pull Wear Bushing and set Test Plug. 11/18/2011 Perform Weekly BOPE Test. Slip and Cut Drilling Line. Pull 9 -5/8" bridge plug. RIH with drill pipe and drill collars. POOH laying down. 00:00 04:00 4.00 0 0 COMPZ PLUG BOPE P Open BOP Doors and inspect cavities. Remove VBPRs from the upper gate and install 3 1/2" solid Ram Blocks. Prep for Weekly BOPE test. 04:00 05:30 1.50 0 0 COMPZ PLUG SFTY P Shut down so that the night Crew, Mud Man, and Company Man can attend the scheduled "Safety Stand -Up" meeting. The Well is secured. 05:30 21:30 16.00 0 0 COMPZ WELCTI BOPE P Perform the weekly BOPE Test per ConocoPhillips and AOGCC requirements at 250/3,500 psi. Perform Koomey draw down test. Pressure tests recorded on Chart. The State's right to witness the test was waived by J. Crisp. Changed out Kill line shock hose and rebuild kill line mud manifold valve and Re test same. (Note: Held PJSM with crew. Slip and cut 84 -ft of Drill line and service Draw works during the BOPE test, 2 hours). 21:30 22:00 0.50 0 0 COMPZ PLUG OTHR P Pull Test Plug. 22:00 23:00 1.00 0 42 COMPZ PLUG MPSP P PJSM. Pick -up Baker Retrieving Head. Latch and release Baker 9 5/8" Retrievable Bridge Plug. Page 63 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 COMPZ PLUG PULD P RIH w/ 3 1/2 DP and POOH laying down same. RIH w/ 4 3/4" DC's and POOH laying down same. Clear Floor. 0 COMPZ PLUG 11/19/2011 MU and RI w /Baker 7" Cement Retainer. Set Retainer. Attempt to establish a circulation. No -Joy. However, an injection rate was established at 1.0 and 2.0 bpm. RU Cementers. Pump 54.5 bbls AS1 Cmt. Estimated TOC 235'. Unsting from retainer. POOH with tubing and remove stinger. RIH with tubing to 221'. Pump 15.3 bbls cement. Estimated TOC 43'. POOH laying down tubing 6 jts tubing leaving 1 jt tubing in well. Pump 4 bbls AS1 cement until get returns out OA valve. Close OA valve and squeeze 1.8 bbls cement into 9 -5/8" casing leak. Pull tubing. WOC. PT cement to 500 psi for 5 min . Good test. Tag TOC at 58' RKB (27' below ground level). Run tubing 2' from TOC. 00:00 01:00 1.00 0 297 COMPZ PLUG TRIP P PJSM. Make -up Baker 7" Cement Retainer. w/a 14.50 -ft 2/3/8" Mule Shoe Bent Tail -Pipe Joint. Scribe the "heel" of the Bent Joint with the "toe" pointed at the Baylor Brake. Scribe tubing while RIH. Set down at 255 -ft. Pick -up slightly and rotate 1/4 turn to the right. Fell through and enter the top of the damaged 7" Casing. Set Retainer at 293 -ft, this puts the Mule Shoe at 307 -ft. 01:00 04:00 3.00 297 297 COMPZ PLUG CIRC P Rig up to circulate through the perforations in the 7" Casing at 1,000' - 1,010'. Attempt to establish a circulation rate with 12.1 lb/bbl with Sodium Bromide. No -Joy. Broke formation down at 1/4 bpm /3,000 psi. Established an injection rate at 1.0 bpm /1,200 psi and 2.0 bpm /2,300 psi. Call out Cementers. Check Well Cellars on both sides of 2A -07. Good. Tried to inject with Sea Water. However, due to the fluid weight differences the well locked up again. Re- establish injection rate with 12.1 Sodium Bromide at 2.0 bpm. End injection test. Page 64 of 67 Time Logs • Date From To Dur S. Depth. E. Depth Phase Code Subcode T Comment 04:00 11:30 7.50 297 0 COMPZ CEMEN" CMNT P Spot and Rig up Cementers PJSM with Rig Crew, Baker, SLB and ASRC 09:30 - 10:00 Pump job #1 RU 12.1 ppg to CMT truck. Fill lines with 5 bbls of 12.1 ppg brine 10:28 - 10:33 No returns - fluid level at 6 ft from rig floor At 1.4 bpm at 124 psi 5 bpm at 200 psi. Down on the pumps. PT lines at 4,500 psi. Establish injection rate with 5 bbls of 12.1 Brine with Cementers. At 1 bpm at 100 psi, 1.5 bpm at 128 psi, 2.5 bpm at 192 psi, 4 bpm at 260 psi, 5 bpm at 275 psi, Flush lines with 10 bbls of fresh water at 5 bpm at 394 psi. Mix and pump 49.5 bbls of AS1 15.7 ppg slurry, pumping at 5 bpm at 700 ICP and 700 FCP , Slow rate to 3 bpm at 2 bbls left. Unsting from retainer. Mix and pump 5 bbls of AS1 15.7 ppg slurry. Total pumped 54.5 bbls of slurry. Displace with 1.0 bbls fresh water. Bleed off and Breaking off, POOH laying down 10 -ft pup jt., 2 jts 3 1/2 TBG and Stand back 2 stands. Break off stinger from single. Estimated TOC at 235 -ft. Page 65 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 15:30 4.00 0 0 COMPZ CEMEN" CMNT P Pump job #2 RIH with 10 -ft x 3'A TBG pup jt and single and 2 stands (10 -ft pup jt and 7 jts of 3'h) from derrick to 221 -ft. RU head pin Fill lines with 5 bbls fresh water, PT lines at 1,500 psi. Mix and pump 15.3 bbls of AS1 15.7 ppg slurry and Pump at 4.5 bpm at 500 psi. Follow with 1.0 bbls of fresh water. Break off and wash up POOH laying down 6 jts, Monitor well for losses off Trip tank for 30 minutes. Estimated TOC at 43 -ft Pump job #3 RU for top job, Fill lines with 8 bbls fresh water 4 bpm at 142 psi. PT lines at 1,500 psi. Pump 5 bbls fresh water ahead Mix and pump 4.0 bbls of till AS1 15.7 ppg slurry returns from OA (Pinching back on 3" Gate valve to squeeze cmt into formation) 9 psi well head pressure. Squeezed away 1.8 bbls 10 psi - Bleed off cmt in place at 14:00 hrs. Open OA valve and wash up to cellar. Clean and Wash out BOPE through OA Valve RD Cementers 15:30 22:00 6.50 0 0 COMPZ CEMEN" WOC P Wait on cement for 8 hrs. 22:00 22:45 0.75 0 58 COMPZ CEMEN" PRTS P PJSM. Pressure test Cement at 500 psi x 5 minutes. Good. Pick -up 3 1/2" Tubing and tagged the top of Cement at 57.64 -ft KB. Top of cement at 27.20 -ft (volume = 2.1 bbls) below ground level. 22:45 00:00 1.25 58 58 COMPZ CEMEN" RURD P Rig up Cementers. Park the end of the Tubing 2 -ft off bottom. 11/20/2011 Rtl Cement Pump AS1 "top job Cementers. ND BOP Stack. Well full of cement to casing head flange. NU tubing head with tubing hanger installed and no BI .V. NU Dry-Hole Tree. Test Tree to 500 psi. Pressure bleeds off to 250 psi in 5 min. No visible leaks at surface and well is full of cement. Secure Cellar. Release Rig at 2300. Page 66 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 58 0 COMPZ CEMEN - CMNT P Complete rigging up cementing line. Mix and pump -5 bbls of 15.7 lb/gal, AS1 Cement. Attempt to circulate cement for the "top job" with the charge pump. Had to bring on Cement Pump at 1.0 bpm /100 psi. Circulated 6 bbls. Observe clean Cement returns at surface. Flush line. Pull Tubing from Well. Rig down Cementers. 01:30 10:30 9.00 0 0 COMPZ WHDBO NUND P Open BOP Stack doors. Inspect cavities. Install 2 7/8" x 5" VBPRs in the upper gate. Nipple down BOP Stack and set back on Stump. 10:30 15 :30 5.00 0 0 COMPZ WHDBO NUND P Take picture of cmt at Top of 11" 3M CSG flange. NU 7 1/16" 5M x 11" 3M TBG spool with TBG hanger with (No Type "F" BPV installed). NU 7 1/16" 5M x 3 1/8" 5M Adapter, 3 1/8" 5M master valve and swab valve with tree cap. 15:30 20:00 4.50 0 0 COMPZ WHDBO PRTS P Fill with diesel and PT at 500 psi. Pressure fell off to 250 psi in 5 minutes. Tried several more times with the same results. Trouble shoot test equipment. Found no problems. Charted the Dry-Hole Tree one more time. Observe no visible flange leaks (Cement at surface). End pressure test. Rig down test equipment. 20 :00 23:00 3.00 0 0 COMPZ RPCOM RURD P Blow down Steam Lines. Hang Tree for next Well. Clean -up and secure Cellar. Back Rig off of Well. Pick -up Spill Containment Berm. Clean -up foot -print area. Released Rig at 23:00 hrs. Page 67 of 67 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 30, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Free Point /Tubing Cut Records /Bond Logs /Perforating Record/String Shot: 2A -07 Run Date: 11/12/2011- 11/17/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -07 Data in LAS format, Digital Log Image files 1 CD Rom 50 -103- 20029 -00 Cement Bond Logs 2 Color Logs 50 -103- 20029 -00 SCANNED FEB 2 7 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Signed: t ‘ 15 8_/44 Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, December 15, 2011 2:22 PM To: 'Gober, Howard' Cc: Allsup- Drake, Sharon K Subject: RE: 2A -07 (PTD 184 -065) Sundry 311 -215 Howard, In consideration of the complex nature of the whole project the added time to review the results and submit the report a bit later (January 16, 2012) is approved. Regards Guy Schwartz ; . f , i° Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Thursday, December 15, 2011 11:36 AM To: Schwartz, Guy L (DOA) Cc: Allsup- Drake, Sharon K Subject: 2A -07 (PTD 184 -065) Sundry 311 -215 Guy, The 10-407 report on the activities undertaken to suspend 2A -07 with cement plugs to the surface is due to the AOGCC on 12/20/11. I would like to formally request an extension of the due date of this report of operations. I request that the due date be moved back to 1/16/2012. Thank you for you consideration of this request. Thanks, Howard Gober Wells Engineering Supervisor ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 CeII Howard.Gober @conocophillips.com 12/15/2011 -06 •• •• ∎Lk95% WELL LOG TRANSMITTAL 64t) To: Alaska Oil and Gas Conservation Comm. October 18, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) / Downhole Video: 2A -07 Run Date: 10/1./2011 - 10/15/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -07 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom Downhole Video, Downhole Video Pictures 50- 103- 20029 -00 S aNNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING•A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: E Z., Signed: 6lli • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 4, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT)/Down Hole Video: 2A -07 Run Date: 10/22/2011 - 10/27/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -07 Digital Data (LAS), Digital Log file, Casing Report, 3D & Video Viewer 1 CD Rom 50 -103- 20029 -00 t4e2- C7 SCANNED FEB 2 7 2013 (� ()G PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: tl $C %1 Signed: n4L.k. Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 16, 2011 4:05 PM To: 'Gober, Howard' Subject: RE: 2A -07 Revised Procedure (PTD 184 -065) Howard, reviewed the updated procedure and it is acceptable as written. We will accomplish the work scope as set out in the original sundry (311 -215) with these steps. Contact me if the procedure needs to be modified significantly. Guy Schwartz Senior Petroleum Engineer AOGCC v 793 -1226 (office) , At_est� ;;.Ill 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober ©conocophillips.com] Sent: Wednesday, November 16, 2011 3:28 PM To: Schwartz, Guy L (DOA) Subject: 2A -07 Revised Procedure Guy, As we discussed earlier, here is the revised P &A procedure for 2A -07. I started the numbering to coincide with the original procedure. Please let me know if this plan is acceptable. Thanks, Howard Gober Wells Engineering Supervisor ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com 11/16/2011 • urotietki Revised Rig P &A Procedure Well 2A -07 Kuparuk Injector PTD #: 184 -065 Sundry #:311 -215 21. Wait on cement. PT tubing to 1800 psi. Unable to PT IA due to casing leak. RU E -Line. RIH and tag TOC in tubing. Shoot string shot. Cut tubing with 2" RCT cutter -100' above TOC. RD E -Line. NOTE: AOGCC Inspector will need to witness pressure testing and tag. (PT and tag were witnessed 11/16/11 by John Crisp) 22. Pick up on tubing to ensure free. Circulate a minimum of 1 hole volume of 12.1 ppg brine. 23. POOH laying down tubing to above 950'. 24. RU E -Line. RIH with 10' - 2.5" OD Titan Prospector perf gun and perf holes in 7" casing at +/- 1000'. 25. Continue POOH laying down tubing. 26. Wash BOP stack with swizzle stick. 27. RIH and set 9 5/8 RBP and test at 1,000 psi. 28. RIH and set test plug. 29. Conduct weekly BOP test. 3Sc0 30. Retrieve test plug and RBP 31. RIH with 7" cement retainer on drill pipe. Set cement retainer at +/- 300' RKB. Set down weight on retainer to ensure retainer is set. 32. Close pipe rams and annular. Circulate out Arctic Pack with heated seawater. 33. RU Schlumberger cementers. Pump cement as follows: /- f fs " .6.4:19 /1 _ a. 5 bbls fresh water b. 49.5 bbls AS1 Cement --' 6 G( 7" � 3 ao r� c. Open pipe rams and annular. d. Unsting from retainer e. 19 bbls AS1 Cement. This volume allows for 10 bbls cement to go outside the 9- 5/8" casing through the casing hole at -260' -270' f. 2 bbls fresh water to clear lines g. Shut down pump and let cement u -tube and equalize. 34. POOH with drill pipe. WOC for 8 hours. 35. RIH and tag TOC. If TOC is below 250' RKB, go to Step #37. Otherwise continue with Step #36. 36. RU Schlumberger cementers. Fill 9 -5/8" casing with AS1 Cement from tag to surface. Cement volume to be determined by tag depth. Go to Step #41. 37. Bullhead into well to ensure wellbore will take fluid 38. RIH with 9 -5/8" cement retainer. Set retainer at -225' RKB. Close pipe rams and annular preventer. a.(ia�,�- d^"' 39. RU Schlumberger cementers. Pump cement as follows: a. 5 bbls fresh water b. 15 bbls AS1 Cement c. Open pipe rams and annular d. Unsting from retainer e. 17 bbls AS1 Cement f. fresh water to clear lines 40. Shut down pump and let cement u -tube and equalize. We should have cement returns to surface. • 41. POOH with drill pipe. 42. ND BOP. If cement top is more than 5' below original ground level in 9 -5/8" casing, top off with cement. Take picture of cement top. ND FMC Gen 5 tubing head. Rinse and clean for return to stock. Tubing head will probably need to go to FMC for inspection. NU Gray Gen 3 tubing head. Install tubing hanger w/ 3 %2 stub. NU adapter flange, master valve, swab valve, and tree cap. Pressure test tree to 500 psi to ensure all flanges hold. Bleed off pressure. 43. RDMO Nordic 3 NOTE: The AOGCC does not need to witness any pressure tests or tags of abandonment plugs listed in this procedure with the exception of what was already witnessed in Step #21. • • • Page 1 ®f1 Regg, James B (DOA) KeLk From: Nordic 3 Company Man [n1433 @conocophillips.com] P7 1 °4 _°6S Sent: Thursday, October 13, 2011 11:41 PM T 010- it To: Nordic 3 Company Man; DOA AOGCC Prudhoe Bay Cc: Gober, Howard; CPA Wells Supt Subject: RE: 2A -07 Weekly BOP test extension Chuck, We were able to get the equipment needed right here in Kuparuk and we are finished with our pull test as of 23:30 on 10 -13 -2011, we are continuing on with our Shell test and follow up on our weekly BOPE test. Thank you for your patience, Randy Dolcater - Rory Ober Cell 907 - 943 -1096 Office 659 -7446 From: Nordic 3 Company Man Sent: Thursday, October 13, 2011 5:29 PM To: ' doa .aogcc.prudhoe.bay @alaska.gov' Cc: Gober, Howard; CPA Wells Supt J- ; ?.',: Subject: 2A -07 Weekly BOP test extension Chuck as per our phone conversation at 16:10 hrs on 10- 13 -11, We are due for our weekly BOP test today ending as of midnight tonight. I am asking for a extension for up to 3 days as I may need to bring equipment up from Anchorage. We want to make sure that we are pulling our BOP stack back to center (Due to our subsidence of the well) within the limitations of our equipment being used and not putting our personnel in harms way. The well was cemented off in 6 -21 -09 (est. TOC is 7,209 -ft in tubing and 7.7 bbls were squeezed into perfs.) The well is loaded with 12.1 ppg sodium bromide; we have a RBP set at 50 -ft and test plug installed in TBG spool. We gave a 24 hr notice at 09:50 on 10 -12 -11 and right to witness was waived at 09:55 hrs on 10- 12 -11. We will keep you updated daily as to when we will be ready to test. We appreciate your cooperation in this matter. Randy Dolcater - Rory Ober Cell 907 - 943 -1096 Office 659 -7446 10/14/2011 Lr, 71C 'rrriTI E 3i L'b ,LJJ E TE A\ In\ SEAN PARNELL, GOVERNOR +��11 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION RVAiON COM1'HSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Howard Gober Wells Engineering Supervisor ConocoPhillips Alaska, Inc. 40LAMMED JUL 0 1 7 ZV P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -07 Sundry Number: 311 -215 0 (— Dear Mr. Gomer: 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 DATED this day of July, 2011. Encl. /E y/ ConocoPhillips(. � �„ - ts, CtimmiSSl Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 - June 30, 2011 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 complete further plug and abandonment work on the suspended Kuparuk Well 2A -07 (PTD 184 -065). 2A -07 was originally completed in 1984. The well is a selective single injector located in an area with surface subsidence. Since 2003, we have been unable to drift the tubing. It was initially thought to be a problem with injection "Schmoon, but now we suspect subsidence issues to be the problem. The well developed a surface casing leak in 2009 at —120'. Due to the fact we could not get slickline tools downhole to isolate the reservoir CPAI made the decision to isolate the perforations with a cement plug. Two cement plugs were pumped on 6/21/09 and on 6/28/09. A passing MIT of the tubing was obtained to 2550 psi on 6/29/09. Currently the well is in suspended status. The objective of this operation is to perform additional P &A operations up to but not including final / surface abandonment. The well will remain suspended until the pad is ready for surface abandonment. The current estimate for SBHP is 3685 psi. 2A -07 is in the same fault block as 2A -06 and 2A -27. It is assumed that the pressure in 2A -07 is similar to these wells. Since 2A -27 was drilled with 11.8 ppg mud which was slightly overbalanced to 2A -06 once the well was intersected. The MASP is —2300 psi based on the highest recorded shut -in tubing pressure on Well Service Reports since 2006. If you have any questions or require any further information, please contact me at 263 -4220. Sincerely, /0• Howard B. Gob -r Wells Engineer CPAI Drilling and Wells • STATE OF ALASKA gee ♦, ALASKA OIL AND GAS CONSERVATION COMMISSION ill „pipe 11 �� . APPLICATION FOR SUNDRY APPROVALS 1 1 20 AAC 25.280 1. Type Re uest: bandon f Rug for Redrill r Perforate New Fbol r Repair w ell r Change Approved R r li A 4d.-1-ioa uspend 17 • Rug Perforations f Perforate r Pull Tubing r Time Extension fl Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casin 9 1-- Other.Additional suspension work ]y • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory f ► 184 - 065 3. Address: 6 . API Number: Stratigraphic r Service go • P. O. Box 100360, Anchorage, Alaska 99510 r 50- 103 - 20029 -00 •eO 0 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 fl No 17 r 2A -07 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25570 . Kuparuk River Field / Kuparuk River Oil Pool " 1 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): 7956 ' 6227 ' 7851' 6144' 7209', 7300' 7787' Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110' 110' SURFACE 2660 9 -5/8" 2696' 2545' PRODUCTION 7889 7 7925' 6204' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7530'- 7600', 7630'- 7642', 7652' -7688' 5914'- 5965', 5987'- 5 6003' -6030' 3.5 J - 7634 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 7373 TVD= 5800 PACKER - BAKER FB -1 PACKER MD= 7625 TVD= 5983 SAFETY VLV - BAKER FVL SSSV MD= 1932 TVD= 1917 12. Attachments: Description Summery of Proposal p 13. Well Class after proposed work: Detailed Operations Program f BOP Sketch r Exploratory Development " Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/24/2011 Oil r 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: Howard Gober @ 263 -4220 Printed Name Howard Gober Title: Wells Engineering Supervisor Signature /I - Phone: 263 -4220 Date w30/1 Commission Use Only Sundry Number: '- Or �Z / Conditions of appro I: Notify Commission so that a representative may witness Plug Integrity BOP Test r Mechanical Integrity Test f Location Clearance r Other: 3000 / 03, 56 e Te.S & �S s i 4 1v ,.n.,:..1 --aV s,: Ahh /_ / I\1 0 -t Sto-e f `. r (Ls ih el: agi�cdP. Subsequent Form Required: A „ C,/O/ " 0 APPROVED BY t Approved by: COMMISSIONER THE COMMISSION Date: 7 / 7 i Form 10 -403 Revised 1/2010 0 R 1 G 1 NA n iBDMS JUL 0 7 f'i 4..;;.? plic i, .ii 2A -07 Kuparuk Injector Suspend Well (PTD #: 184 -065) Current Status The well is currently shut in and considered suspended by the AOGCC. Two cement plugs were pumped • down the tubing to isolate the A sand perforations in 2A -07. The well passed an MIT of the tubing to 2550 psi on 6/29/09. The last State Witnessed MIT -IA was 5/2/08 to 2620 psi. We did an MIT -IA to 500 • psi on 5/28/11. Although the well passed the pressure test, the IA is suspect since it took 5 bbls of diesel • to fill up the annulus and another 7.5 bbls to pressure up the IA to 500 psi. The OA has a leak at • P p p p approximately 120'. Scope of Work Complete further plug and abandon work with Nordic 3. Tag current cement plug in tubing. Gain access to the tubing and fill both the IA and tubing with cement. Fill the OA with cement from as deep as possible to surface. Leave well suspended until entire pad is abandoned. ✓ General Well info MASP: 2300 psi. Max SI tubing pressure recorded on Well Service Reports since 2006. Reservoir pressure/TVD: The current estimate for SBHP is 3685 psi at 6,006' TVD mid perf in the A sand. 2A -07 is in the same fault block as 2A -06 and 2A -27. It is assumed that the pressure in 2A -07 is similar to these wells. Since 2A -27 was drilled with 11.8 ppg mud which was slightly overbalanced to 2A- 06 once the well was intersected. Wellhead type /pressure rating: Gray Gen 3, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams IA / OA Status: IA passes a pressure test to 500 psi, but is suspect due to the volumes necessary to achieve 500 psi. OA has a leak at —120'. A cement shoe with Arctic Pack was pumped in the OA on 6/1/84. Well Type: Injector (Suspended) Estimated Start Date: July 24, 2011 for Nordic 3. Production Engineer: Mike Balog / Evan Reilly Workover Engineer: Howard Gober (263 -4220 / howard.gober@conocophillips.com) Pre -Riq Work 1. Bleed tubing and IA to 0 psi. • 2. Load IA with 12.1 ppg brine. This will be done by gravity feeding and /or slow pumping a viscosified ✓ brine into the IA. The viscosified brine will fall to bottom and the current annulus fluid (diesel) will be bled off. 3. Bleed OA to 0 psi. • 4. Set BPV. Proposed Riq Procedure 1. MIRU Nordic 3. 2. Pull BPV. Ensure tubing and IA are dead. Set BPV. ND tree. MU blanking plug in lift threads. NU 11" 5M BOP and adapter spool. Pressure test BOP including annular to 250/3500 psi. Maximum potential surface pressure is 2300 psi based on max SI tubing pressure recorded on Well Service Reports since 2006. 3. Pull blanking plug and BPV. Pull tubing to neutral weight. 4. RU slickline and attempt to drift tubing. If able to drift, go to Step #8 5. If tubing will not drift, RU E -line. Punch holes in tubing as deep as possible. Gravity feed 12.1 ppg viscosified brine in IA so that it swaps with the fluid in the tubing. Take returns off the tubing. Continue until tubing is loaded with 12.1 ppg viscosified brine. 6. Perform blind backoff as deep as possible. POOH with tubing. 2A -07 Kuparuk Injector Suspend Well (PTD #: 184 -065) 7. Mill 7" casing or cut and pull 7" casing as necessary to get past any bad casing and latch on to the tubing. If the 7" casing is pulled, the tubing head will need to be removed and the BOP stack will be nippled up to the casing head. Due to the surface casing leak, the BOP will be considered a diverter ��, until the 7" casing is removed so that a BOP test can be performed. Any BO te Derfm o red while nippled up to the casing head will be limited to 3000 psi due to the pressure rating of the casing head. <— 8. Once access is gained to the tubing by either drifting or latching on with an overshot, RU slickline and Tag cement inside tubing. RD slickline. Note: Pressure test of the cement plug in the tubing to 2580 psi was performed on 7/1/09. The pressure test was witnessed by Mr. Lou Grimaldi, AOGCC Inspector. 9. RU E -Line. Perforate tubing above TOC or top packer whatever is higher. 10. RU Schlumberger cementers. Circulate balanced plug of Class G cement from pert holes to -1700'. 11. WOC. PT tubing and IA if possible to 1500 psi (PT of the IA may not be possible if the 7" casing has been milled or removed). Bleed tubing and IA to 0 psi. AOGC • • - ° - - - tin.. � 12. RU E -Line. Tag TOQ. Cut tubing with jet cutter above TOC, RD E -Line. - 13. Pick up on tubing to ensure free. Circulate in 12.1 ppg fluid to -1000'. POOH with tubing laying • down. 14. RU E -Line. Punch holes in 7" casing at -1000'. 15. Pump down 7" casing taking returns off the 7 "x9 -5/8" annulus to remove arctic pack.. If necessary due to casing holes above 1000', set a cement retainer on drill pipe to facilitate circulation and cementing. 16. RU Schlumberger cementers. Fill 7" casing and OA with ArcticSetl cement to surface. If a cement retainer is set in Step #15, fill 7" casing above the retainer with ArcticSetl cement to surface. /..� ' S L 5 u...•- f-u.mac. car 3.- 17. ND BOP stack. Install dry hole tree. / 2--o ' , 18. RDMO Nordic 3. (+ - S 4-.<< <K�G 5 tif Post Riq Work c p l � �,-ob ' w 7 1. None needed. /70v' 1 . , % , 1 ° r —73 ,ci gal L / a / a 0 - KU 2A-07 Conoco 'till r cA W o ?'p e11 Attributes Ntax Angle � IND -. -:TD t ,/-ns y! � Wellbore APUUWI (Field Name IW ll Status Incl () MD (ftKB) Act B8 (ftKB) 501032002900 KUPARUK RIVER UNIT INJ 48.90 6,100 00 7,956.0 ` ' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ...• o SSSV: LOCKED OUT Last W 41.29 6/2/1984 Weil c n6 A 07 LP91'9 .,. 7'-. Annotation SdMm A tlual T �_ Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 112.0 1/14/2006 Rev Reason: TAG OBSTRUCTION Imosbor 3/18/2011 Clay Acid slim. Ga Stnng - -. - - „ . , - e s Casing Description String O String ID .. Top (ftKB) Set Depth (f. Set Depth (TVD)... String Wt... String ._ String Top Thrd r CONDUCTOR 16 15.060 36.0 110.0 110.0 62.50 H-00 HANGER, 34 --_. --- t - x �, Casing Description String 0... String ID ._ Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thai '" SURFACE 95/8 5921 36.5 2,696.0 2,545.6 36.00 J - 55 "" Casin Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth TVD) ... String Wt... String String Top Thrd 9 P<o^ 9 9 ) P ( P ( 9 9 8 , 'x,.. PRODUCTION 7 6 151 35.9 7,925.4 6 204 4 26.00 J-55 BTC Tu bing Stnnns '- :_,s,A,- >y_-w -:ncsathintm •,n. _ 01 Tubing Description IStrmg 0.. String ID ... Top (ftKB) ISetDepth (f.ISetDepth (TVD) .(String Wt._ISt.i g ... String Top Thrd TUBING 3 1/2 2.992 33.6 7,633.9 5,990.2 9.30 J-55 EUE ABMOD Completion- Details „ - _ - - Top Depth (TVD) Top Intl Nom^_ - -- (ftKB) /9K8) (°) Item Description Comment ID (in) CONDUCTOR, - - 33.6 33.6 0.00 HANGER GRAY GEN III TUBING HANGER 3.500 36 - 110 1,931.7 1,916.5 21.59 SAFETY VLV BAKER FVL SSSV - LOCKED OUT 8/9/88 2.813 Jr 7,359.6 5,790.0 43.76 PBR BAKER PBR 3.000 SAFETY VLV, 7,373.3 5,799.8 43.68 PACKER BAKER FHL PACKER 3.000 1,932 IT - 7,519.8 5,906.4 42.97 BLAST JT 2.992 J 7,624.5 5,983.5 43.42 LOCATOR BAKER LOCATORw /2' SEALS 3.000 II 7,625.1 5,983.9 43.41 PACKER BAKER FB -1 PACKER 3.000 7,631.7 5,988_6 43 37 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,633.1 5,989.7 43.36 SOS BAKER SOS - ELMD TTL @ 7617 ON SWS !PROF 4/29/2003 3.000 4 SURFACE, 0 Other itt Hole VVireline.-retrievable plugs, valvesrpumps�.fish „etc - Top Depth ��/� T o / VL-'l A 7!6 -- , - ) t � " (ND) Top Intl nJ 9» i Jc T p,N1KB) (ftKB) (°) Description Comment Run Date ID (in) ii 0 7,209.0 5,6812 43.95 CMT PLUG 2 CEMENT OFF TUBING - PUMPED TTL 11.4 BBLS 6/28/2009 0.000 GAS LIFT, >a CEMENT, 3.7 BBLS PLUG (425) 7,314 a 7 5,747.3 44.09 CMT PLUG CEMENT OFF TUBING - PUMPED TTL 15 BBLS CEMENT, 6/21/2009 0.000 „., . 3 BBL PLUG (333') 1 ' \ 7,405.0 5822.4 42.97 PATCH 21' Meda Patch 1/26/1996 2.313 3 7,412.0 G � 5,827.6 42 -97 NIPPLE Patch Includes AVA BPL Ported Nipple; Set 3' feet below 1/26/1996 2.750 Top of Mandrel PACKER, 7,373 - -� 7,412.0 5,827.6 42.97 SLEEVE AVA CII Sleeve; Set 3' below top of Mandrel 1/28/1996 1.875 $ IA 7,474.0 5,872.9 42.97 PATCH 22' Meda Patch Set 1/26/1996 2.375 NIPPLE,7,412 - 1i ` 7,632.0 5 43 N IPPLE AVA Nipple Reducer profile 1/24/2000 1.813 SLEEVE, LIFT, PP P GAS LIFT, � REDUCER 7,412 PATCH, 7,405 y f _ 7 787.0 6,102.2 42 46 FISH 1 BullPlug Lost on Run #2 6/10/1988 CMT PLUG 2, L �$ y - _ _ _ 7,209 - 0 Perforation "&.Slots = - . - : . CMT PLUG, - Shot - - - 7,300 't T p(TVD) Btm(TVD) D ens GAS LIFT, �. 'ti (7 1 Toc(ftKB Btm (ftKB) (ftKB) (ftKB) Zone D t (h.. Type Comment 7,474 PATCH, 7,474 ?£ 7,530.0 7,600.0 5,913.9 5,965.1 C UNIT 8, 7/9/1984 12.0 IPERF 5 12" Csg Gun; 120 deg ph - "':' - 2A -07 ! 7,630.0 7,642.0 5,987.4 5,996.1 A-4, 2A -07 7/9/1984 4.0 IPERF 4" Csg Gun; 90 deg ph !I! ' 1632 -0 7,640.0 5,988.9 5,994.6 A -0, 2A -07 6/10/1988 4 -0 RPERF 7,652.0 7,688.0 6,003.3 6,029.5 A-3, 2A -07 7/9/1984 4.0 IPERF 4" Csg Gun 90 deg ph IPERF, - ! 7,652 0 7,680.0 6 6 003 3 5023.7 A -3, 2A -07 6/10/1988 4.0 RPERF 7,530 -7.600 1411:':- - - - _ - � ' timultions- .&_-Tr - - ",.1',,-: -. Squeezed - ( s4 Bottom _ Perfs, 7,599 ...._ T7 . ' ' Min Top Max Btm Top Depth Depth .' m ' ( Depth Depth (ND) (TVD) a k e (ftKB ) (ftKB) (ftKB) -.,f.._,E ) ( ftKB 1 KB Type Date Comment m 0 0 Clay Acid Sfim 7/31/1988 _ S 3 a GeenfS'qu � -_: -� - -_ _ - - ' .' �- - - - - - .� - # - .'< Top Depth Btm Depth i (TVD) (ND) PACKER, 7,625 1 - Top (ftKB) 860 (ftKB) ( 8 ) P 8 ) Description Start Date Comment x 7,530.0 7,652.0 5,913.9 6,003.3 Cement Squeeze 628/2009 SQUEEZE PERFS W/7.7 BBLS CEMENT // `. 7,599.0 7,600.0 5,964.4 5,965.1 Cement Squeeze 7/10/1984 '&!'.. ''0,f. 7,629.0 7,631.0 5,986.7 5,988.1 Cement Squeeze 7/10/1984 ' - 7 631 0 7,68 0 5 988 1 6,029 5 Cement Squeeze 6/21/2009 SQUEEZE PERFS W /12 BBLS CEMENT Squeezed - k+ NIPPLE, _ s, i NIP , 7,632 NIPPLE _ Annotation REDUCER, _fi .!..V" „= End Date 7,632 - / , - ( i) 1/14/2006 NOTE: TAG w/125" LIB @ 11' RKB - POSSIBLE COLLAPSED TUBING CEMENT a ,mot °, PL CEMENT 3 a ' . ('o 6/20/2006 NOTE: LOG SHOWS POSSIBLE CORKSCREW TBG OR TBG DAMAGE @ 11' PLUG, 7,209 � ' t ^- 9/8/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 50, - • T , i _, - IP 0,7ERF633 ,N is f i --'- 3/17/2011 NOTE: UNABLE TO PASS RESTRICTION @ 70' SLM, see WSR 3/17/2011 7,630 -7,642 -.1 ' - -. -_- - _- RPERF, . � -s . _ _ 7,632 -7,640 _ .. -i ce k _ r - Mandrel Details - _ Cement i Top Depth Top Port Squeeze, 7,530 -z (TVD) Intl OD Valve Latch See TRO Run RPERF, a Stn Top U(B) (ftKB) 1') Make Model (i^) 5ery Type Type (in) (psi) Run Date Com... 7,6524,66 0 - -. ]. 7 - __ 1 7 -6 5 ,756.9 44 - 01 MMH FMHO 1 GAS LIFT DMY BK - 2 0.000 0.0 6/15/2000 IPERF, � 7,652-7,688 E;._. /' Ir..j -It " 2 7,412.0 5,827.5 42.97 MMH FMHO 1 INJ PATCH BK - 2 0.000 0.0 1/26/1996 Cement t Squeeze, 7,631 3 7,481.6 5,878.5 42.97 MMH FMHO 1 INJ PATCH BK -2 0.000 0.0 1/26/1996 FISH. 7.797 Al 1 �e e 15 4,0 0...e t-'N 1, Q✓ nil 11)5 c.L[7y ✓S� 1 - } 2 p Fs"Lc e - f or f '.. -live cl, vt u [cur y p a_C_e_ 0P 4 c, 64. d se -live 0,...),- ytele c 1, PRODUCTION, L yp _ (� 1 D,7,956 T ro C. lA t tJY/LrL L ., 6p �i T0.7,956 l.�> � S / � G? � /1'�c'�f � � �"l� �� l� 1 STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 5 2009 WELL COMPLETION OR RECOMPLETION REPO JAW %.CommissiQ:; 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: Anchirlman 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service D Stratigraphic Test❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: June 28, 2009 184 - 065 / 309 - 202 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 25, 1984 50 - 103 - 20029 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number. Surface: 657' FSL, 53' FEL, Sec. 14, T11N, R8E, UM May 31, 1984 2A - 07 Top of Productive Horizon: T. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 1313' FSL, 1278' FWL, Sec. 14, T11 N, R8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1369' FSL, 994' FWL, Sec. 14, T1IN, R8E, UM 7851' MD / 6144' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 498341 y- 5960078 Zone-4 7956' MD / 6227' TVD ADL 25570 TPI: x-494391 y- 5960738 Zone-4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 494108 - 5960792 Zone-4 SSSV @ 1932' MD / 1917' TVD 2668 18. Directional Survey: Yes ❑ No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) approx. 1500' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 175 sx CS 11 9 -5/8" 36# J -55 Surf. 2695' Surf. 2545' 12.25" 850 sx Permafrost E, 250 sx Permafrost C 7" 26# J -55 Surf. 7931' Surf. 6209' 8.5" 275 sx Class G, 250 sx Permafrost C 24. Open to production or injection? Yes ❑ No a If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 7634' 7373' MD / 5800' TVD, 7625' MD / 5984' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED �y D EC- w:EC- 1 7530'- 7652',7631' -7688' 19.7 bbls cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test 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 OIL GRAVITY - API (oorr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No a Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations and marker countered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1500' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 7530' 5909' Base Kuparuk C 7600' 5960' Top Kuparuk A 7608' 5965' Base Kuparuk A 7816' 6118' NIA Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265 - 1544 Printed N ! J. Ennis Title: Wells Engineer � j ® 1 Signature Phone 265 -1544 Date °2 "! Sharon Allsup -Drake 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. 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. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: 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 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 7/2009 I i RECEIVED STATE OF ALASKA JUL 2 2 1009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATICIAP"a Oil & Gas Cons. Commission I. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ✓ . Stimulate Other Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 184 3. Address: Strati ra hic Service ✓ g p ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - - 0 7. KB Elevation (ft): 9. Well Name and Number: RKB 130' ° 2A -07 ' 8. Property Designation: 10. Field /Pool(s): ADL 25570 Kuparuk River Field / Kupar River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7956' ' feet \\. W true vertical 6227' . feet Plugs (m �t's 7209' (est. TOC) Effective Depth measured 7851' feet Junk m red) 7787' true vertical 6144' feet Casing Length Size MD (� Burst Collapse Structural CONDUCTOR 110' 16" 110' / 110, SURFACE 2565' 9 -5/8" 2695' 2545' PRODUCTION 7801' 7" 7931'. 6209' Perforation depth: Measured depth: sqZ34'. 530' -7 9', 7642', 7652' -7688' true vertical depth: 598' 996', 3' -6030' Tubing (size, grade, and measured depth) 3. 4 . Packers & SSSV (type & measured depth) Ba( @/ 1932' Ba 7373', Baker'FB - 1' pkr @ 7625' 7373', 7625' 12. Stimulation or cement squeez71umes �"T'�. >y � r- V�p�� e.Q�4�.�.��M/( Intervals treated (measured) 7530'- 7652, 763V -7688' 19.7 bbis cement Treatment descriptions includinsed and f inal pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl I Casing Pressum Tubing Pressure Prior to well operation Subsequent to oper ion 14. Attachments 15. Well Class after work: Copies of Log and Surveys run _ Exploratory El Development El Service 0 ` Daily Rep of Well Operations _X 16. Well Status after work: Plugged ❑✓ Oil[] Gas F] WAG ❑ GINJ F] WINJ El WDSPL [I /[here certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -202 Jim Ennis @ 265 -1544 e J Ennis Title Wells Engineer Phone: 265 -1544 Date 1 L- Pre Dared b S aron 263 -4612 MOM ;y' i;,- zr LIIQ� Uzi S /Z Form 10 -404 sed 04/2006 Submit Original O jy • MEMORANDUM To: Jim Regg ~~~ ~~~~ f P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 12, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2A-07 KUPARLTK RIV LTNIT 2A-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~r~ Comm Well Name: xuP~ux xiv vtvrr 2A-o7 Insp Num: mitLG090812114959 Rel Insp Num: API Well Number: so-1o3-20029-00-0o Permit Number: 184-065-0 ~ Inspector Name: Lou Grimaldi Inspection Date: ~~1/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2A-07 TYPe Inj. N TVD 5799 ~' IA ~so ~~o ~~o ~~o ~~o P.T.D ~g40650 ITypeTest SPT Test psi zsso ~ pp ao aa ao ao ao Interval o~R p~ e ' Tubing iso zsao 2aas 2aoo 2390 - NOteS: Pressure test of tubing plug installed to safe-out well. ~ ~En. ~~ ~ -k~ ~- ~ s~aP~~~ , j~rt•i~ " , ~' '. i~~~~il ~ _ ~:. Wednesday, August 12, 2009 Page 1 of 1 2A-07 Well Events Summary DATE SUMMARY 6/5/09 PUMPED 150 BBLS (2 TBG V MES) OF DIESEL DOWN TUBING TO ~FIRM COMMUNICATION WITH FORMATION. PUMPED 1.4 BPM WITH MAX PUMP PRESSURE OF 2400#. 6/21/09 Pumped 15 bbl of 15.8 ppq cement down the tubinq. Displaced with 5 bbl fresh water, 40.5 bbl 9.6 ppg brine and 18 bbl of diesel freeze protect to 2000'. Squeezed cement into perfs, 3bbls remaininq in tubinq (333', TOC (c~ 7300' in tubinq). 6/22/09 MITT failed. Attempted to pressure test tubing post cement plug to 2500 psi. Unable to pressure up, leak rate of 0.5 bpm Cc~ 2150 psi. Attempted to draw down the well, pressure would build up from 80 psi to 960 psi. 6/28/09 PUMPED 11.4-BBL OF 15.8-PPG CLASS-G CEMENT DOWN THE TUBING. DISPLACED WITH 5-BBL FRESH-WATER, 29.5-BBL 9.6-PPG BRINE, AND 28-BBL DiESEL FOR FREEZE-PROTECT. [ESTIMATE 7.7-BBL CEMENT SQUEEZED INTO PERFS, WITH 3.7- BBL (425-FT) REMAINING IN TUBING.] ESTIMATED TOC AT 7209-FT IN TUBING., 6/29/09 PERFORMED MIT: PASSED. (2550-PSI INITIAL MIT PRESSURE, 2450-PSI 15-MI~ r~r~re+r~~ ir~r niw~ r~r+~ nn ~~~~~ ~e~~~~~ ~~~ ~ BLED TUBING TO 0-PSI AFTER MIT. 7/1/09 STATE WITNESSED ( LOU GRIMALDI ) MIT-T ( PASSED ) " -~- KUP ~ 2A-07 • ____ ConocoPhillips ' '' Well Attributes 'Max Angle & MD ~ITD ~ WellboreAPUUWI IFieltlNama WeIlStatus ~Incl(°) IMD(flKB) ActBtrn~ttKB) ~~~`"h"~ ~~' ~`~ _ _ 501032002900 IKUPARUK RIVER UNIT ~~INJECiWG ~I 48.90 6.100.00 7956.0 .. . _ . _. . ScheMetl4 ~ Ae0. pay Aaa Sum, 0 ~ ~ F SAFETV VLV. 1.93Y SURFACE. 2,695 GAS LIFT. _ 1.31a PBR,7,360- - PACKER, I,313 - SLEEVE.7.a1P ~ PATCH.7,405 - CEMENT PLUG _ 2.1209 CEMENT PLUG , __ 1.7.300 INJECTION, _ __ zaez PATCH, 7,~74 - IPERF, __ 7.530-7.fi00 ~- sa eezea Perh.7.599 PACKER,7,625 - -- 7.630 7.642 5.987AI 5.996 7 632 7 640 5,986-9~, 5,994 7652~ 7.688~~ 6.003.3 6.029 7,652 itimula 7,680~ tions & T 6,003.3 reatmen 6,023 ts Min Top Max Btm Top Depih Bottort Dapth Depth Dep~h (TVD) , (TVO) (ftKB) ' (kKB) ((tKe) I (ftKB) O.Oi~ I 7.530.01 7 sos. 2A-07 ~6/10/1988 ', 4.0!RPERF 2A-07 7l9l1984 '~. 4.0 IPERF 4' Csg Gun; 90 deg ph ~ 2A-07 6/10/1988 ~ 4.0 RPERF 7ype Date ~ __ Commant ~ Acitl Snm 7l37I7988 il1412006 'INOTE: TAG w/125' LIB @ 11' RKB - POSSIBLE COLIAPSED TUBING 6l20/2006 INOTE: VIDEO LOG SHOWS POSSIBLE CORKSCREW TBG OR TBG C cemem Sq~eeze,],530 RPERF, ],652-],680 IPERF. 7.fi51~7.668 Cem Squeue. 7,631 FISH. 7787 ._ ~ Annotation IDepth(flKB) IEnADa~a Annotation '~LastModBy Last lag: I ~ 112.0 I 1/14l2006 Rev Reason: CEMENT PWG TRIPLW Casing Strin gs String OD Shing ID 'i Set ~epth Set Depih (TVD~ ~ String Wt ~ SU CasingDescription (in) (in) Top(kKB) (ftKB) (ftKB) . ~ Qbs/(1~ .i Gr. CONDUCIOR 16 15.060 30.0 1700 1100~ 62.50'H~li SURFACE 951fl 8J65 0.0 2,695.0 2,544.9iI 36.OOIJS° PRODUCTlON 7i~ 6.157 ~ 00 _ 7.931.0 6,208.6I~ 26.OO~J-5`. Tubing Strin gs String OD I Strin9 ID __ ~ I Set Depih ' Set Dept~ (TVO) '. Siring Wt I Sir TubingDescrip[ I ion (in) ' (in) Top(ftKB) (fiKB) (flKB) ~. Qbslk) I Gr: TUBING I, 3 V21 2867 ''i 0.0 7,634.0~'. 5.990-31, 9-30'I .1-5` p Incl (7 Desaipfion Comment Run Date ID 21.60 SAFE (Y VLV Baker'FVL' (Locked Out 8i9/88) 7/9/1984 2. 43.95 CEMENT CEMENT OFF TUBWG - PUMPED TTL 11.4 BBLS 6/28/2009 0. PLUG 2 CEMENT, 37 BBLS PLUG (425') 44.09 CEMENT ~ CEMENT OFF TUBWG - PUMPED TTL 15 BBLS CEMENT, 6/21l2009 0. PLUG 1 3 BBL PLUG (333') 44.01 GAS LIfT MMH/FMHO/1/DMY/BK-2U/ Comment WlWATER INJ. 6/15/2000 2. PACKING STA 1 ~ 43J5 PBR BAKER PBR 7!9/19&9 3. 43.68 PACKER Baker'FHL' PACKER 7/9l1984 3. 42.97 PATCH 21' Metla Patch 1/26/1996 2. 42.97 NIPPLE Patch Includes AVA BPL Portetl Nipple; Set 3' feet below 1/26/1996 2. I Top of Mandrel 42 97 INJECTION '~MMHlFMHO/1/PATCHlBK-2//f Comment STA 2 7/2611996 2. 42.97 SLEEVE AVA CII Sleeve; Set 3' below top oi Mandrel 1/28/1996 1. 42.97 PATCH 22' Meda Patch Set ; 1/2611996 2. 7,632 7,632 7,633 7.787 profle set Shot Den (sh.s 7,530I 7,600I 5,913.9 5,965 ~~ Y PRODUCTION. ],931 TD, ],95fi -- • MEMORANDUM State of Alaska !~ Alaska Oil and Gas Conservation Commission TO: Jim Regg )~~~~ DATE: July 3, 2009 P. I. Supervisor i FROM: Lou Grimaldi SUBJECT: Tubing Plug Integrity Test Petroleum Inspector C.P.A.I. well 2A-07 ~ P.T.D. #184-065 Wednesdav, July 1, 2009; I witnessed the pressure test of a cement plug set in tubing on C.P.A.I.'s Kuparuk River Units well #2A-07. This plug had been squeezed in to secure the well due to subsidence issues and awitnessed pressure test was required by Sundry #309-202 I arrived to find Ian Ives (DHD tech) rigging up on the well. The wellhead has sunk considerably compared to the adjacent wells. A photograph accompanies this :~ report (see "KRU 2A-07 Sunken Wellhead 07-01-09 LG.jpg") showing the severity of subsidence at this wellsite. The tubing pressure was 150 psi when I arrived. A 2580 psi pressure test was applied for 45 minutes with the following decline observed 15 min 2445, 30 min / 2400, 45 min 2390. Attachments: KRU 2A-07 Sunken Wellhead 07-01-09 LG.jpg Non-Confidential ~~~ ~, , ~.Q1 Wellbore plug integrity KRU 2A-07 07-O1-09 LG.doc 1 of 2 KRU 2A-07 Sunken Wellhead PTD 184-065 Photo by AOGCC Inspector L. Grimaldi July 3, 2009 Wellbore plug integrity KRU 2A-07 07-01-09 LG.doc 2 of 2 3 r • r ~ ~ ~ ~ ~ r ~ ~ ~, e N k~ i I~ 4 p ~ L @ ~ N M ~~ ~ p ~~ I < gp E c ti. ~i e.:,,: °._._:. m_ _'.~~ ~~ ~ 'J ~ ~ yam. ~.-~ ~~~ &~' ~ ~ ~_~ c. s ~ .-~, ALASSA OIL A1~TD GAS - COI~TSERQATIOI~T COrIIKISSIOIQ f Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. ~'~~1~~.~ .~ ~R 't, ~~ '~~~" 5 {%. P.O. Box 100360 Anchorage, Alaska 99510 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~,p(o ~/~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-07 Well Sundry Number: 309-202 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 'PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of June, 2009 Encl. STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~~°~ 20 AAC 25.280 6 ~~~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations Q - Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 184-065 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20029-00 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 Requires? Y@S NO Q 2A-07 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s}: ADL 25570 ~ RKB 130' - Kuparuk River Field /Kuparuk River Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth nno (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7956' - 6227' ~ 7851' 6144' 7787' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 2565' 9-5/8" 2695' 2545' PRODUCTION 7801' 7" 7931' 6209' i`sl~ls .a pl ~ Gas Cons. of1NI11~Siafl flC Oi`8Q8 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7530'-7599', 7631'-7642', 7652'-7688' 5914'-5964', 5988'-5996', 6003'-6030' 3.5" J-55 7634' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'FVL' SSSV @ 1932' Baker'FHL' pkr, Baker'FB-1' pkr @ 7373', 7625' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ~' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat June 22, 2009 Oil ^ Gas ^ Plugged ~ ~ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Na Jim Ennis Title: Wells Engineer Signature Phone 265-1544 Date ~ (p Q Commission Use Onl ~ p~~- Sundry Number: W~`,~ rp~ *~ ~~ ~ Conditions of approval: Notify Commission so that a representative may witness 2 ~~~~~ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. ~~~~ ~~~ ~~ ~~ ~~.~~--_ ~ ~~~~Lrs s ~~~~~ p~ res~~ ~ ~~~'r' Subsequent Form Required: \ t ~~~ '"~ ~~\; ,i APPROVED BY ~~ ~ Approved by: COMMIS I ER THE CO ISSIO Date: ~ ,off Form 10-403 Revised 06/2006 ~ ~ ~ `_, ~ ~ ~ ~ ,[~~~~ ~ ,~ ~ ' ~/j Sub/~~T®1~ ' • Plug Perfs Procedure • Well 2A-07 Kuparuk Injector Pump cement plug for well control barrier Network 10252433 Well History: 2A-07 was originally completed as a single Kuparuk water injector in 1984. In November 2008, a surface casing leak was identified ~ 120' via fluid level shots and the well was SI. A deep mechanical plug is not an option as ~ rkscrewed tubing has limited access since 2004. The corkscrewed tubing is believed to be the result of well subsidence. Recent experience on neighborin well 2A-06 indicates this reservoir shniilri ha icnlatari hafnra fiirthar riamagP to t~bularS OGGUfS The procedure outlined below will plug the Kuparuk reservoir w/ cement until a workover can occur. Work accomplished to date: 6/5/09 PUMPED 150 BBLS (2 TBG VOLUMES) OF DIESEL DOWN TUBING TO CONFIRM COMMUNICATION WITH FORMATION. PUMPED 1.4 BPM WITH MAX PUMP PRESSURE OF 2400#. .11/25/08 SURFACE CASING LEAK DETECT 11/22/08 SCIT -FAILED 6/20/06 DRIFT W / BLB AND 2.23" GAUGE RING TO 32' SLM. MADE SEVERAL CAMERA RUNS TO DEPTH OF 9' - 14' SLM PUMPING SEAWATER; USED FILTER SKID. CLARITY OF PICTURE IS FUZZY; APPEARS TO BE CORKED SCREWED TBG_ 5/25/06 ATTEMPTED TO I OG VIDEO TO OBSTRUCTION IN TUBING AT 200', UNABLE TO ENTER WEI I BEYOND 20' DUE TO HIGH WHP/LOW TOOLSTRING WEIGHT. HAD SHUT IN WELL ON PRIOR DAY TO TRY TO REDUCE WHPATTEMPT TO PUMP DOWN TOOLS WERE UNSUCCESSFUL. RESCHEDULE JOB ONCE WEIGHTBAR IS AVAILABLE .NOTIFY PAD OP TO RETURN 2A-07 & 2A-06 TO INJECTION. 4/10/06 ATTEMPTED TO LOG_VI_DEO TO.,OBSTRUCTION IN TUBING. UNABLE TO ENTER WELL DUE TO HIGH WHP/LOW TOOLSTRING WEIGHT. RESCHEDULE JOB ONCE NEW TOOLSTRING CONFIGURATION IS AVAILABLE OR IF WHP CAN BE REDUCED. 1/13/06 RAN NUMEROUS LIBs FROM 2.84" TO 1.25" TO MAX DEPTH OF 112' RKB. SUSPECT COLLAPSED TUBING. 1/12/06 ATTEMPTED DRIFT TBG. RAN VARIOUS POKERS, PRODS, BAILERS & BROACHES ACHIEVING MAXIMUM DEPTH OF 83' SLM. IN PROGRESS. 10/6/05 UNABLE TO OBTAIN SAMPLE SD IN TBG @ 11' WLM (2.50") AND 62' WLM (2.114") [TAG] 5/31/05 CLEAN OUT SCHMOO FROM 80' TO 225' CTMD USING HOT SEAWATER. RUN BACK IN WITH 2.7" MILL AND MOTOR AND ATTEMPT TO CLEAN UP "TIGHT" SPOTS. TUBING APPEARS TO BE CORKSCREWED, PULLING 18,000# AT 750' CTMD. POOH AND BRING WELL BACK ON INJECTION. [CORK SCREWED v1s/04 ___UNABLE TO PASS 81' WLM SCHMOO [TAGI Remaining work: RU SLB cementer. Bullhead 40 bbls fresh water down tbg at max rate below 2500 psi followed by 65 sx Class 'G' cement w/ additives. Launch "nerf" cmt plug and displace w/ 5 bbls fresh water, 40.5 bbls 9.6 ppg brine and 18 bbls diesel. SI and record SITP. WOC 24 hours. PT cmt plug to 2500 psi. Bleed tbg pressure to zero. S ~'`t©.s ~ ~~ = lO3 .~ ~b\ S '~ ~'kx~~`~ T'O C ~, 'Z3o~' ~ ~3`ab®vr~ Qac~ ~ ~ ~1 Jim Ennis Page 1 6/15/2009 .. • `~~ Conc~co~~till~~ AI>~~~~; ~2,n-o~ sssv (1932-1933, OD:3.500) Gas Lift 3ndrel/Dummy Valve 1 (7314-7315, OD:5.313) PBR (7360-7361, OD:3.500) PKR (7373-7374, OD:6.156) PATCH (7405-7426, OD:3.500) TUBING (0-7634, OD 3.500, ID:2.867) PATCH (7474-7496, OD:3 500) Injection MandrelNalve 3 (7482-7483, Perf (7530-7600) PKR (7625-7626, OD:6.156) NIPPLE REDUCER (7632-7633, OD:2.750) Perf (7652-7680) Perf (7652-7688) 1' BuIlPlug - (7787-7788, OD:1.000) Inc • KRU 2A-07 2A-07 PTD # 184-065, notice of surface casing leak Page 1 of 1 ,. ~ • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, April 20, 2009 4:49 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: 2A-07 PTD # 184-065, notice of surface casing leak Attachments: 2A-07.pdf; 2A-07 90 day TIO.jpg Jim, 2A-07 PTD # 184-065, WAG injector is suspect of having a surface casing leak. The well has been shut in and freeze protected. Enclosed is a 90 day TIO and schematic for your convenience. Please call or write with any questions. Sincerely Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Voice Pager 659-7000 x937 «2A-O7.pdf» «2A-07 90 day TIO.jpg» 6/17/2009 ~ ~ € ~ = KRU 2A-07 ~a~r~c~-~~il'1i~ A~~w~~aa ~~~. - ~ ~ z -~~ ~ ~~~~, ~ ~, w ~~~ ~ ~ ~ ~ ~ ~ ~~~. ~~ ~ LL ~~~~~,, ~ API: Well T e. INJ 501032002900 An le TS: 43 de 7530 SSSV Type: LOCKED OUT Orig 6/2/1984 Angle @ TD: 42 deg @ 7956 Com letion: sssv (1932 1933 Annular Fluid: Last W/O: Rev Reason: ADD TTL ELMD - , OD3.500) Reference Lo : Ref Lo Date: Last U date: 9/6/2007 Last Ta : 112' TD: 7956 ftK6 Last Ta Date: 1/14/2006 Max Hole An le: 49 de 6100 ~ ~ '° `j'~ F [~~~ ~~i J~ ` ;,. , E, , ~M;~~~~n ~ ~~~.! - ~ ~ Descri tion Size To Bottom N Wt Grade Thread D~ CONDUCTOR 16.000 0 110 110 62.50 H-40 Gas ~in andreUDummy ~'' SURF CASING 9.625 0 2695 2545 36.00 J-55 va~ve 1 PROD CASING 7.000 0 7931 6209 26.00 J-55 (7314-7315, - p .. iK~n :° iI ~. '~s > § ._ '1i `; '' ~~i ~ '; ~ ~ " z ~ii' _ ,' ~~ ,. ? ~~ ~ • ~ ~ zi ~ ~ .~.~,~ ~ ~ti i ~ ~ 'a rr: -~ ~ OD:5.313) ~ .. : i+, Size To Bottom . .~ z TVD ~ Wt Gred . e Thread 0 0 7634 3.50 5990 9.30 J-55 8RD EUE ABM j ~1]~I:iK1~#~f~ ~~flE 4-[~~~~ o! ~ - ~ ~ .. ~ ~ ~' , ~~ ~~'v~ 51 5 ~ ..; peR Status Interval ND Zone Ft SPF Date T e Comment psso-~ssi, 7530 - 7599 5914 - 5964 C-4,UNIT 69 12 7/9l1984 IPERF 5 1/2" Csg Gun; 120 deg ph OD:3.500) B 7599 - 7600 5964 - 5965 UNIT B C 1 0 7/10/1984 S z 7630 - 7631 5987 - 5988 A-4 1 0 7/10/1984 7631 - 7632 5988 - 5989 A-4 1 4 7/9/1984 IPERF 4" Cs Gun~ 90 de h 7632 - 7640 5989 - 5994 A-4 8 8 6/10/1988 RPERF PKR 7640 - 7642 5994 - 5996 A-4 2 4 7/9/1984 IPERF 4" Cs Gun• 90 de h (7373-7374, - ~652 - ~6$O 6003 - 6024 A3 28 8 6/10/1988 RPERF OD:6.156) 7680 - 7688 6024 - 6030 A-3 8 4 7/9/1984 IPERF 4" Cs Gun; 90 de h _ ~yr~ - ' . ~3VGi ~ 4 ~ ~~a ~ .~~ a ~ ,, 'S'S~ ';= \ ~~ _ ~ u_ I ~ - S ~ ME ~~ ~ 4 Interval Date T e Comment PATCH 7599 - 7600 7/10/1984 S ueezed Perts pao5aa2s, 7629 - 7631 7/10/1984 S ueezed Perfs OD:3.500) 0- 0 7/31/1988 Cla Acid Stim ;g ~~~-~-.~ .~ ~~~ ~~ ~ 'lYl ' ~ t~i ~_i 5 ~~e~ ~ _ hi..,:. . ~ I~ " = ~.; ~ ~ r ~ ~ P~ ~~ ~ i , St MD ND Man Mfr , ~ _ . > ,.. , ~ Man Type V Mfr V Type V OD Latch Port ~~ TRO Date Run Vlv ruBiNG ~oassa, Cmnt OD:3.500, 'I 7314 5757 MMH FMHO DMY 1.0 BK-2 0.000 0 6/15/2000 1 ID:2.867) 1, w/waterin'. ackin ~ ~VYEI~ "'~CI~~~ V ~ ':.. ~ .SiF~T. ~ .i~ i I:k ~ cqi ~ ~ ' .I..:i ~~"~ ~ ,t ~ F y1~ _ 'a = 4 TII ~ _ ~ ~ V Mfr St MD ND Man Mfr Man Type V Type V OD TRO Oate Run Vlv Latch Port Cmnt 2 7412 5828 MMH FMHO PATCH 1.0 BK-2 0.000 0 1/26/1996 PATCH (7474-7496, 3 7482 5879 MMH FMHO PATCH 1 0 BK 2 0 000 0 1/26/1996 OD:3.500) ~# _ ~ e i ' ~ ~ ~ - ~ ~i ~ ~ m ,~~ ~~a ~,~' ~A ~ iJ ~E .- a, - ~ : "~ ri r ~ ~ Injectlon ~~~ ~i De th ND ~ ~ T e ~ . ~ _ . , . _> ~ _ . ~ ~ ID ~ ~Descri tion MandrelNalve 3 1g32 1917 SSSV Baker'FVL' Locked Out 8/9/88 2•$~3 ~~asz-~ass, 7360 5790 PBR Baker 3.000 7373 5800 PKR Baker'FHL' 3.000 Perf - 7405 5823 PATCH 21' Merla Patch Set 2.313 (7530-7600) 7412 5828 SLEEVE AVA CII Sleeve~ Set 3' below to of Mandrel 1.875 -- 7412 5828 NIP Patch Includes AVA BPL Ported Ni le~ Set 3' feet below To of Mandrel 2J50 7474 5873 PATCH 22' Merla Patch Set 2•375 7625 5983 PKR Baker'FB-1' 4.000 - - -- 7632 5989 NIPPLE AVA Nipple Reducer w/Camco "D" profile set 1/24/2000 1.813 - REDUCER - 7632 5989 NIP Camco'D' Ni le NO GO 2.750 7633 5989 SOS Baker 2•992 7634 5990 TTL ELMD TTL 7617' ON SWS IPROF 4/29/2003 2.992 PKR S~ 's~ ~~ "~ y' ~~. ~ ~ ~~ .I'i~l'i , =- ' i i~s,. i i ,'._ ,~i"~im€ ~ ,~ I;+; i ~ _ _ °_~ rr ~ (~s25aszs, De th Descri tion Comment OD:6.156) 77$7 1' BuIIPIu Lost on Run #2 ~ ~ ~, i ~~~ „ ? ~ii , _ ~;~ °, ii = : ~ `~) i S.f ~ ~I ' I, ., '~4 ~~ 5 ', 4 , ' V~Y'.e~ = - - vt. +F i Date Note 1/14/2006 NOTE: TAG w/1.25" LIB 11' RKB - POSSIBLE COLLAPSED TUBING 6/20/2006 NOTE: VIDEO LOG SHOWS POSSIBLE CORKSCREW TBG OR TBG DAMAGE 11' NIPPLE - REDUCER = _ (7632-7633 - - , OD2.750) -_ Pert -- - . (7652-7680) ' Pert - - (7652-7688) - -- 1' BuIlPlug (7787-7788, OD:1.000) MEVIORANI)UM • TO: Jim Regg ~ ~ ~ ~,l~l >~ C~~ P.I. Supervisor { ~. FRONT: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 07, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPI-IILLIPS 4LASKP.ItiC 2A-07 KUPARUIC RIV U?VIT 2A-07 Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~t Pr'-- Comm Well Name: KUPARUK RIV UNIT 2A-07 API Well Number: >o-I o3-zoo29-00-0o Inspector Name: John Crisp Insp Num: mitJCr080s0408s834 Permit Number: 184-065-0 Inspection Date: ~%212008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well - z4 07 (Type Inj. ~ N j TVD sgoo ~ ~', IA Aso z62o ~~ za9o ~'~ z47o ! --- ~isao6so i ~ sPT I Test psi a6oo ~ OA zo ' zo '~ zo z° P.T TypeTest aYRrsT F P Tubing. zioo ztoo I zloo ~ zloo i Interval P/ - --- L--- NOtes• 3.5 Uhl's pumped for test. uin_~~~ ~'`i?SSLti~_ Czl,LewcEl - ~~~'~5. Wednesday, Maq 07, 3008 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Consen'ation Commission TO: Jim Regg P.I. Supen'isor R11 tl Z'[ (c4 DATE: Wednesday. June 23. 2004 SUBJECT: f\1echamcallmegrl£Y Tests CONOCOPHILLlPS ALAS!\....o\ fNC ~1\-O7 FROM: Chuck Scheve Petroleum Inspector KUPARUK RIV UNIT ~A-(i7 Src: Inspector Reviewed By: P.I. Supn' Il::P- Comm NON-CONFIDENTIAL Well Name: KUPARUK RJV UNIT 1A-07 Insp Num: mitCS04062 I 123137 Rellnsp Num: API Well Number: 50-103-20029-00-00 Permit Number: 184-065-0 Inspector Name: Chuck Scheve Inspection Date: 6/20/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2.'\-07 Type Inj. P TVD 6222 IA P.T. 18.t0650 T~'peTest SPT Test pS!___I~ OA 1670 ~580 2550 2510 2470 2'¡60 0 0 0 0 0 0 Interval '¡YRTST P/F P Tubing 2500 2500 2500 2500 2500 2500 Notes: The prelesl pressures were observed for 30+ minules and found slable. Pressures appeared 10 show a sleady decline. Tesl pressure held for an hour and appeared 10 slabilize over Ihe last 15 minule period. Wednesday. June 23, 2004 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Per/orate _ Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development __ Explorato~ Stratigraphic__ Service__X 4. Location of well at surface 657' FSL, 53' FEL, Sec. 14, T11N, R8E, UM At top of productive interval 1313' FSL, 1278' FWL, Sec. 14, T11N, R8E, UM At effective depth (asp's 498340, 5960080) (asp's 494391, 5960738) At total depth 1355' FSL, 1063' FWL, Sec. 14, T11 N, R8E, UM (asp's 494176, 5960780) 12. Present well condition summary Total depth: measured true vertical 7956 feet Plugs (measured) 6227 feet Effective depth: measured true vertical Casing Length CONDUCTOR 1 1 0' SURF CASING 2565' PROD CASING 7801' 7780 feet Junk (measured) 6097 feet 6. Datum elevation (DF or KB feet) RKB 130 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2A-07i 9. Permit number / approval number 184-065 10. APl number 50-103-20029 11. Field / Pool Kuparuk Oil Pool Tagged PBTD (3/23/00) @ 7780' MD. Size Cemented Measured Depth True vertical Depth 16" 175 Sx Cold Set II 110' 110' 9-5/8" 850 Sx PFE & 250 PFC 2695' 2545' 7" 275 Sx G, 250 Sx PFC 7931' 6209' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7530 - 7599'; 7631 - 7642'; 7652 - 7688' RECEIVED 5914- 5964'; 5988- 5996'; 6003- 6030' F E B 1 co 2001 3.5', 9.3#, J-55, Tubing @ 7634' MD. Alaska 0il & Gas Cons. Commission Anchorage Baker 'FHL' Packer @ 7373' MD; Baker 'FB-I' Packer @ 7625' MD. Baker 'FVL' (Locked Out 8/9/88) @ 1932' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiFBbl Shut In Representative Daily Average Production or Injection Data Gas-Md Water-Bbl _ - - 3000 Casing Pressure Tubing Pressure - 250O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service ~(WAG) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Form 10-404 Rev 06/15/88 · Prepared by John Peirce 265-6471 SUBMI'IrlN DUPLIC~.~ 2A-07i XYLENE TREATMENT DESCRIPTION OF WORK COMPLETED 3/23/00: RIH & tagged PBTD at 7780' MD. 5/25/00: MIRU & PT equipment. Pumped 22 bbls of Xylene fullbore, followed by 60 bbls Diesel @ 1.5 bpm, to soak the perforation intervals located at: 7530-7599' MD 7631 -7642' MD 7652- 7688' MD Rigged down. Returned the well to water injection & obtained a valid injection rate. RECEIVED FEB :1 6 ZOO1 Naska Oi~ & Gas Cons, Commission Anchorage STATE OF ALASKA O/~/~.~//~ ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Typeof Request: Abandon_ Suspend- Operation Shutdown_ Re-enter suspended well_ ~'~1 Alter casing _ Repair well Plugging _ Time extension Stimulate 2. Name of Operator Change approved program 99510 ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK X.- Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 657' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1313' FSL, 1278' FWL, SEC 14, T11N, RSE, UM At effective depth 1355' FSL, 1063' FWL, SEC 14, T11N, R8E, UM At total depth 1369' FSL, 992' FWL, SEC, 14, T11N, R8E, UM Variance Perforate Other X 6. Datum elevation (DF or KB) 130' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 9. Permit number 84-65 10. APl number 5o-103-20029 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7 9 5 6' feet true vertical 6222' feet Effective depth: measured 7851 ' feet true vertical 61 44' feet Casing Length Size Structural Conductor I 0 3' I 6" Surface 26 95' 9 5/8" Intermediate Production 7 9 31 ' 7" Liner Perforation depth: measured 7530'-7600', Plugs (measured) NONE Junk (measured) NONE Cemented 175 SX CS II 850 SX PF E 25O SX PFC 275 SX CLASS "G" 25O SX PFC 7630'-7642', Measured depth True vertical depth 103' 103' 2695' 7931 ' true vertical Tubing (size, grade, and measured depth) 3 1/2", J-55, @ 7634' Packers and SSSV (type and measured depth) BAKER FHL PACKER@7538', BAKER FB-1 PACKER @ 7610', BAKER FVL SSSV ~ 1917' 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Pressure Prior to well operation Subsequent to operation J U L 3 199 Alask_'a .0il .& 6as Cons. C0mm~ss' 'Anchorage Treatment description including volumes used and final pressure '7//~//~ convert from production to water injection Re_~resentative Daily Average Production or Injeqtion Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing 2OO 537O 0 50O 200 2000 500 2400 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector ;~ Daily Report of Well Operations Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Si~Ined C-~- ~ Title Kuparuk _ Petroleum Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE STATE OF ALASKA /'1 ALASKA OIL AND GAS CONSERVATION COMMISSION (.,//~'"~/ REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate__ Change approved program X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 657' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1313' FSL, 1278' FWL, SEC 14, T11N, RSE, UM At effective depth 1355' FSL, 1063' FWL, SEC 14, T11N, R8E, UM At total depth 1369' FSL, 992' FWL, SEC 14, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7 9 5 6' feet true vertical 6222' feet Effective depth: measured 7 8 5 1 ' feet true vertical 61 44' feet Casing Length Size Structural Conductor 1 0 3' I 6" Surface 26 95' 9 5/8" Intermediate Production 7 9 3 1 ' 7" Liner Perforation depth: measured 7530'-7600', 130' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 9. Permit number 84-65 10. APl number 5o-103-20029 11. Field/Pool Kuparuk River Field , Kuparuk River Oil Pool Plugs (measured) NONE Junk (measured) NONE Cemented 175 SX CS II 850 SX PF E 250 SX PFC 275 SX CLASS "G" 25O SX PFC 7630'-7642', Measured depth True vertical depth 103' 103' 2695' 7931 ' E ¢ E IV E D true vertical d U L 2 t99;5 Tubing (size, grade, and measured depth) Alaska. 0il & Gas 6011S. 60mrf~[ss 3 1/2", J-55, @ 7634' ~ch0rage Packers and SSSV (type and measured depth) BAKER FHL PACKER@7538', BAKER FB-1 PACKER @ 7610', BAKER FVL SSSV @ 1917' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure gas injection to production '~, 14. Re_oresentative Daily Average Production or Injectior~ Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure Tubing Prior to well operation Subsequent to operation 15, Attachments Copies of Logs and Surveys run Daily Report of Well Operations 5000 500 200 5370 0 500 16. Status of well classification as: Water Injector Oil X Gas Suspended 4OOO 20O Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned C'~I")' ~~ Title Kuparuk Petroleum En~lineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS'" /T, '//? / . ed well Abandon Suspend Operation Shutdown Re-enter suspend - Alter ca~ing _ Repair we~ _ Plugging Tim; extension _ Stimulate __ Change approved program Pull tubing - Variance Perforate X Other 1. Type of Request: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 657' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1313' FSL, 1278' FWL, SEC 14, T11N, R8E, UM At effective depth 1355' FSL, 1063' FWL, SEC 14, T11N, R8E, UM At total depth 1369' FSL, 992' FWL, SEC 14, T11N, R8E, UM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7956' feet Plugs (measured) true vertical 6 2 2 2' feet NONE measured 785 1 ' feet Junk (measured) true vertical 61 4 4' feet NONE Length Size Cemented I 03' 1 6" 175 SX CS II 2695' 9 5/8" 850SXPFE 250 SX PFC 7 9 31 ' 7" 275 SX CLASS "G" 250 SX PFC measured 7530'-7600', 7630'-7642', 130' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-07 9. Permit number 84-65 10. APl number 5o-103-20029 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 1 03' 1 03' 2695' 7931 ' 7652'-7688' I 'EEE'IVED true vertical J U L 2 3 199;5 Tubing (size, grade, and measured depth) Alaska 0JJ & Gas Cons. Oomrnis 3 1/2", J-55, @ 7634' Packers and SSSV (type and measured depth) Anchorage BAKER FHL PACKER@7538', BAKER FB-1 PACKER @ 7610', BAKER FVL SSSV @ 1917' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure reperforate the A Sand 14. Pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing 156 56 0 500 200 187 72 0 500 200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~-,_ ~ Nfl J Si~tned/'"~ \('~'~"J' ~,t.A,cj~,,~.,fi Title Kuparuk Petroleum Engineer =orm 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ,ion ARCO Alaska, Inc~_~ Sub~dlaty of Atllntlc Flichfleld ~' , ~ELL -? 5/ CONTRACTOR REMARKS -_ IFIELD - DISTRICT - STATE /l"~m/,c OPERATION AY REPORT TIME WELL SERVICE REPORT DAYS/ DATE ~ -/o-~g 0930 0¢$5' !o30 Io,.~- oo !ZoS' I~oo 13~o JUL 2 ~ 1993 ,Oil & Gas Cons, 6ornr~issio~* Anchorage I-'] CHECK THIS BLOCK IF-SUMMARY CONTINUED ON BAcK R..o, I ,F! 'Fi ........... mile; t" ...... kn°t" I ARCO Alaska, Inc. Date: December 21,1990 Transmittal #: 7965 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2A-07 Kuparuk Fluid Level Report 1 2-1 5-90 Tubing 2 H- 01 Kuparuk Fluid Level Report 1 2 - 1 5 - 9 0 Tubing 2 H- 03 Kuparuk Fluid Level Report 1 2 - 1 5 - 9 0 Tubing 2 H - 0 4 Kuparuk Fluid Level Report 1 2 - 1 5 - 9 0 Tubing 2 H - 1 3 Kuparuk Fluid Level Report 1 2 - 1 5 - 9 0 Tubing 2 H- 1 5 Kuparuk Fluid Level Report 1 2 - 1 5 - 9 0 Tubing 2 H- 1 6 Kuparuk Fluid Level Report 1 2-1 5 - 9 0 Tubing 3 M - 0 8 Kuparuk Fluid Level Report 1 2-1 5 - 9 0 Tubing Receipt Acknowledged: )~"~~--- Date: DISTRIBUTION: BP Chevron D&M Mobil Unocal State of Alaska RECEIVED DEC 2'7 1990 Alaska Oil & Gas Cons. Oommissior. Anchorage AL, A OIL AND GAS CONSERVATION COME. ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ~ 2. Name of Operator ARCO Alaska. Inc. 3. Address Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate M Pull tubing _ Variance _ Perforate _ Other P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory I Stratigraphic Service 4. Location of well at surface 657' FNL, 53' FEL, Sec. 14, T11N, R8E, UM At top of productive interval 1313' FSL, 1278' FWL, Sec. 14, T11N, R8E, UM At effective depth 1355' FSL, 1063' FWL, Sec.14, T11N, R8E, UM At total depth 1369' FSL, 992' FWL, Sec. 14, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7956' feet Plugs (measured) 6222' feet 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-07 9. Permit number 84-65 10. APl number 50-103-20029 11. Field/Pool Kuparuk River Field Kul3aruk River Oil Pool Effective depth: measured true vertical 7851 ' feet Junk (measured) 61 4 4' feet None Casing Length Structural Conductor 1 03' Surface 2 6 9 5' Intermediate Production 7 9 31 ' Liner Perforation depth: measured 7530'-7600', true vertical 5914'-5965', Size 16" 9 5/8" 7" Cemented Measured depth 175 Sx Cold Set II 1 3 0' 850 Sx Permafrost E 2695' & 250 Sx Permafrost C 250 Sx Class G & 7 9 31' 250 Sx Permafrost C 7630'-7642', 7652'-7688' MD 5987'-5996', 6003'-6030' TVD Tubing (size, grade, and measured depth 3 1/2", J-55, @ 7634 Packers and SSSV (type and measured depth) Baker FHL @ 7538', Baker FB-1 @ 7610', Baker FVL SSSV @ 1917' True vertical depth 130' 2545' 6209' 13. Attachments Description summary of proposal X.~ Detailed operation program _ BOP sketch 14. Estimated date for commencing operation 15. September. 1988 oi~ 16. If proposal was verbally approved Name of approver L, ~/~1 i ~L Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. - FOR COMMISSION USE ONLY Status of well classification as: Gas m Suspended ~-~ .-~, Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test '~___ Subsequent form ORIGINAL SIGNED BY Approved by the order of the Com~E C. SMITH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Kuparuk Well 2A-07 Well 2A-07 is a selective single A and C Sand producer. Proposed is conversion of the well to water injection service. No downhole work will be required. Static bottomhole pressures from wellhead pressures and fluid levels indicate a staic BHP of 3150 psig in the A Sand and 3130 psig in the C Sand. STATE OF ALASKA ALAS~-.. OIL AND GAS CONSERVATION COMJ~,.oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ ] Re-enter suspended well -- Alter camng [': TIme extension Change approved program Plugging '-]_ Stimulate .7 Pull tubing Amend order .r Perforate'~( Other Name of Operator ARCO Alaska. Inc. Address P.O. Box 100360, Anchorage, Alaska 99510 Location of well at surface 657' FS.L, 53' FEL, Sec. At top of~productive ~nterval 1313' FSL, 1278' FWL, Sec. At effective depth 1355' FSL, 1063' FWL, Sec. At total depth 1369' FSL, 992' FWL, Sec. 14, T11N, R8E, UM 14, T11N, R8E, UM 14, T11N, R8E, UM 14, T11N, R8E, UM 11. Present well condition summary 7956' Total depth: measured 6222' feet true vertical feet 5. Datum elevation (DF or KB) RKB 130' feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2A-07 8. Per r~ ~[_n~'n be r 9. APl number 50- 103-20029 10..POOkuparuk River Oil Pool Plugs (measured) Effective depth: measured 7851 ' feet true vertical 6144 ' feet Junk (measured) Casing Length Structural Conductor 103' Surface 2695' Intermediate Production 7931 ' Liner Perforation depth: measured Size Cemented Measured depth True Vertical depth 16" 175 Sx Cold Set II 103' 103' 9-5/8" 850 Sx Permafrost E 2695' 250 Sx Permafrost C 7" 275 Sx Class "G" 7931' 250 Sx Permafrost C 7530'-7600', 7630'-7642', 7652'-7688' MDR~CEIvED true vertical Tubing (size, grade and measured depth) Alaska 0il & Gas Cons. Con,mission 3-1/2", J-55, @ 7634'. AnChorage Packers and SSSV (type and measured depth) Baker FHI @ 7538' Baker FB-1 @ 7610' Baker FVL SSSV @ 1917' 12.Attachments Description summary of proposal/~ Detailed operations program 13. Estimated date for commencing operation June 10, 1988 14. If proposal was verbally approved Name of approver Z, No. ~ ....... D~ted..__/~a~te approved 15. I hereby certify that the foregoing is true and correct to thp best of my knowledge Signed ~(.,~ ,~ ./~;;~ ~ ~_~~--~ Title /j/~ 2 ,W.-~/~ ..~~... ' ~' Commission Use O~nnly L~-~ Date · Conditions of approval Notify commission so representative may witness I Approval No. I-'., Plug integrity E] BOP Test ~., Location clearance Approved by ORIGINAL ~SIGNED_BY / LONNIE u. SM~ Form 10-403 Rev 12-1-85 Approved Copy ~_~leturned .-,~/ Cumn,issioner by order of __ '.~-~ - -~'/-'~ the commission Dat~.~ Submit in triplicate Kuparuk Well 2A-07 Well 2A-07 is a selective single producer with only' the A Sand open at this time. Proposed is re-perforating sections of the A Sand to reduce the completion pressure drop and enhance rate. A copy' of the proposed program to add the subject perforations is attached. All downhole work will be performed with electric line conveyed tools. A 5000 psig electric line BOP and lubricator will be employed during all downhole work. Static bottomhole pressures from wellhead pressure and fluid levels indicate a static BHP of 3'150 psig in the A Sand, and 3`130 psig in the C Sand. Messrs. Chambers and Jordan June 2, 1988 page 4 Procedure To Add A Sand Perforations Well 2A-07 1. MIRU electric line unit and mast truck. . GIH with semi-expendable perforating gun w/CCL. Tie in to Schlumberger CBL dated 7/6/84. Avoid tagging bottom w/gun. PBTD tagged 5/28/88 at 7787'. . Flow well to system to allow a slight underbalance while perforating. Perforate the folowing intervals at 4 SPF, 0 degree phasing, magnetically decentralized: 7632' 7640' 7652'- 7680' Depths are RKB measurements. The following semi-expendable guns are suitable for this job: Schlumberger Enerjet II Dresser Silverjet Gearhart E-jet e RD electric line equipment and produce well to system. Obtain stabilized well test at earliest convenience. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A P. ECElVED Alaska Oil & t3as Cons. Anchorage 1. 5000 PSI ?" WE:LLHE.4D CONNECTOR FLANGE: 2. 5000 PSI WIRE:LINE RAMS (VARIABLE 2~. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" IrLC)W TUBE PACK-OFF bi]RELINE BOP EOU]PMENT I ARCO Alaska, Inc,~--.~ Post Offic6 x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiplJ Applications for Sundry Approvals on Kuparuk wells. The wells were both conversions and fractures as listed below. Wel 1 Action 2A-3 Conversion 2A-6 Conversion 2A-7 Convers i on Anticipated Start Date October 19, 1987 October 19, 1987 October 19, 1987 3K-15 Conversion October 15, 1987 3N-4 Conversion 3N-5 Conversion 3N-11 Conversion October 15, 1987 October 15, 1987 October 15, 1987 3Q-5 Conversion 3Q-12 Conversion 3Q-15. Conversion October 15, 1987 October 15, 1987 October 15, 1987 If you have any questions, please call me at 265-6840. Sincerely, lwood Senior Operations Engineer GBS'pg:0117 Attachments cc' File KOE1.4-9 RECEIVED OC"F 1 6 1967 Alaska Oil & Gas Cons. Commission Anchorage .. ARCO Alaska, Inc. is a Subsidiary of AtlanUcRichfieldCompany "- STATE OF ALASKA AL~-,_,~-~ OIL AND GAS CONSERVATION CO,.,,v~,.SSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska: Inc, 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 657' FSL, 53' FEL, Sec. 14, T11N, R8E, UM At top of productive interval 1313' FSL, 1278' FWL, Sec. 14, T11N, R8E, UM At effective depth 1355' FSL, 1063' FWL, Sec. 14, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB 1~0' 6. Unit or Property name Kuparuk River Unit 7. Well number 2A-07 8. Permit number 84-65 9. APl number 50-- 103-20029 feet At total depth 1369' FSL, 992' FWL, Sec. 11. Present well condition summary Total depth: measured true vertical 14~ T11N, R8E~ UM 7956' 6222' feet feet 10. Pool Kuparuk River 0il Pool Plugs (measured) Effective depth: measured 7851' feet Junk (measured) true vertical 6144' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 103' 16" 175 Sx Cold Set I I 103' 103' Surface 2695' 9-5/8" 850 Sx Permafrost E 2695' Intermediate 250 Sx Permafrost C Production 7931' 7" 275 Sx Class "G" 7931' Liner 250 Sx Permafrost C 7530'-7600', 7630' -7642', 7652'-7688' MD Perforation depth: measured true vertical Tubing (size, grade and measured depth) 3-1/2", J-55, @ 7634'. Packers and SSSV (type and measured depth) ' ' ~','o/:~ Baker FHL @ 7538', Baker FB-1 @ 7610' Baker FVL SSSV 12.Attachments Description summary of proposalS" Detailed operations program [] BOP sketch [] "~;'~'~ 13. Estimated date for commencing operation October 21, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~_4ertify that the foregoing is true and correct to.~e bes~t of my knowledge Signed /~/~. ,/~ ,~.X~f)~l~~r~ Title/~/_ 0~~~ ' ' Commission Us~nly - - Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner I Appr°valN°' .~_.~ ~ (~]) ~_.~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicat~]~ Kuparuk Well 2A-7 Well 2A-7 is a selective single comletion currently utilized for gas injection. Surface modifications will be performed to allow production of the well, and subsurface work will be performed to shut-in the C Sand and open A Sand production. ARR'tc'O007 ARCO Alaska, Inc. 'Post OHice Box 10.0360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 9-$ 5 TRANSMITTAL NO' 5199 RETURN TO: T IL\NSM ITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-illSB .P.O. BOX 100360 AI'~HORAGE, AK 99510 tlEREWITIi ARE Tile FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK WELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 STATIC-'C' SAND 2A-7 04-23-85 STATIC-'A' & 'C' SAND 2F-6 03-21-85 STATIC-PBU-'A' SAND 2G-8 03-21-85 PBU-'A' SAND 2G-12 03-23-85 STATIC-PBU-'A' SAND 2H-13 04-26-85 STATIC-'A' SAND 2~1-14 04-28-85 STATIC-'A' SAND 2H-15 04-29-85 STATIC-'A' SAND 2U-1 04-11-85 PBU-'A ' SAND 2U-2 04-11-85 PBU-'A' SAND 2U-3 04-11-85 STATIC-'A' SAND 2U-4 04-11-85 STATIC-'A' SAND 2U-5 05-02-85 STATIC-'A' SAND 2U-6 05-03-85 STATIC-'A' SAND 2U-7 05-04-85 ST~.~TC-'A' SAND 2U-8 05-04-85 STATIC-'A' SAND 2U-13 03-09-85 STATIC 2U-14 03-21-85 STATIC-'A' &'C' SAND 2U-!5 03-20-85 STATIC-'A ' &'C ' SAND 2U-!6 03-15-85 STATIC-'A' &'C' SAND 2V-2 03-23-85 STATiC-'C' SAND 2V-SA 03-17-85 STATIC-'C' SAND 2V-SA 01-2 4-85 STATiC-'A'&'C' SAND 2W-4 04-13-85 c,, -,,,~ 'A ' o.,.~. IC- SAND 2X-! 04-14-85 STATIC-'A' &'C ' SAND ~X-3 04-13-85 STATiC-'A' & 'C ' SAND 2X-13 03-30-85 PBU-'A ' SAND _-~ ECEI PT ACKNOWLEDGE D: DISTRIBUTION: ;PAE* DRI LLiL~G W. PASHER CURRIER* L. JO, .... TO.] EXXON ~,.".v~,~,~, MOBIL* PHILLIPS OIL* M* NSK CLERK J. RATHHELL* DATF~,I[s~ 0i~ ~ L..s t;cr,s. Uu,,;;mmst0n STATE OF ALASKA* SOiiiO* UNION* K. TULiN/VAULT ARCO Alaska, Inc' Post Office oox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 -:li:'l'URiq TEl: .ARCO ALASKA, INC,, A T'¥ N: F,' El C O R D S C'L. li:.; I::: K A 'l" [..)-' t- t t 5 B I::', 0, ;['.'~ 0 X i 0 0 36 0 AN(.31--IDI:;;~::iC;IE Al( ',o,- ' :' t:;; A N,7 i"l I T T Ii; D H E R E H I 'T H -A I:;; E T I-I Iii; F i;.~ 1... 1... (] W ]; N C, '4 E C E :1; F:' T r."~ N I) R I:'"'¥ U R N · 0 N E S' )' L1. i'4 E D C 0 F:' Y 1 i' E H 5', I" I... E. A .~ E A C K hi. 0 ~ L E I) C; r-E 0 F T 1-1 ]: :; 'f I:(A N S M I T'f'A L, : 17. -.-7 i 1'-'-7 ':, (;!-.'.6 1 0,-7 :2 f::i -- t 2A-4 2A.-~ 2A-5 2A-7 2B-t2 2C-.4 ?. C - 4 2C-5 2C-5 ?. C-'f 4 '.2 [;- t 4 2 D-- 2 2 I) - t ,3 2D-t0 R U N L Y N E S i:;: E: C I;)I:;; 1) E I:k ~'.,' RETFeZI:VE L_YNES I_ Y N I:: S I::~ R E X S L)R E: I':: 0 H [< S-' F' BU SBHF' 'C' ~AND ' C ' 2AND I:'~:U T¢i~ FILL/5'BHF' o L I"1 [" X B I"I F' FALL OFF TE3T FALl.., OF:F TEXT SBHF' E/LZNEE 2F"ZN/TCL SUI:;;VEY I_EAK DETEOTZON ' F'BU F'BU RUN TORQUE F'I~U-F'ULL TOFCqtJE "f't. IRN/ AHE:RAI)A BONI:<~ R'.tJ N TOR(~UE F'BU-F'LII_L TORC,~UE TURN/ AHERAI)A Be)MB3' RUN TORQUE TURN/AMERAI)A3 I;: U N T 0 I:(q U E ]' L! R N / A H E I:(A D A S F'BLI-F'ULL T OR.(;~U E ANIEI'-<GDA 21"--6 F'BtJ 2F-'kl PBLJ 2F-8 F'I'.4U 21":-t t PBLI ;:::. F"- t IF' I:; t.J 2. C; - t l::' I:.'. U 2 f.; -' 1 F:' B U 2(.'; "'8 I'"' BLJ 2 .F.,-~8 I:"'1:.; U ;':,'ECl: I F"T ACKi',tCiL, JLE:I)C;EI): ] :". F:' A E: * I? R I L I... :[ N f.'.;- :3, C U R I:;: :1:1'::: R :' 1 ..... J (.} H i'-!..'7, T (:) iq :.': H I::". V I';.' El N --"~ ~- H CI B :1: L ¢,, 1. } :) & N ~,:- N.:-.. kC L. IE I::: ,t 04-'2t .... 85 [)T ]:S O 4 .... ,~.,.;~,.~. (-)4-2t - [':~ '.~ ;. '",:l _~ C A i4 C 0 04_2,/:> c ~.: 04-21 -.C, 5 CAHC:[) 04-25-85 CAHCO ., ~. -,¢ ¢-) (-> 4 -. 2 ,0 -. o 5 CAHCO 04-t ,_/,-- ~35 CAMCO 04 -',~. '> -.. ''> -' or' .,r-" C A i't C O 04-22-85 O'rIS -' (')4-2t " -'~ "> 04 '" ,= .-- - ..... C-) 4- ''> _ . ~.~ ,.,., O'l' I S - d .* 0 T 12 04-t6 "~'- · - -8.> CA}"iCO ,34 '2.4 ~':' (-) 4-25-,9,5 CA?4C[.) c~.~ B A K E R ¢,4_2t 04 04-2t 04-23-85 03-20-8'.5 04--t 9-85 ~, '~T W.. %1 %., O4- '18-85 O 4-1 '"' '"'= 0 4- t 7 ' o 04'-t ':' ~5--2t -85 E X X 0 iq -)~ F' I--1 :l: 1...I... :f F:'.? CI .[ I_ :,¢.. j. F;: A T I..I H E: L L I?,AI< ER/T OI';:QU[" TURN OTI 2 B A I< E I:;:/'I' 0 I:;: r~ LJ E TURN D T :[ ;.9 I3AI< ER/"I'OI:~RLJE -'I'LIIqN O'¥ I S (,,At,CO - CANCO / C A H C 0 (]AMC(] ~-as~8 Oil & ~aS Cons. Cor~{nlisnio[, 0 T ]: S ' O T I S ~.r~ct:uraCe DATE: · ~.STATE OF ALAXKA x. S 6)I"11:0 ~' U N ~ 0 N K, '[' LI L I N/VAULT STATE OF ALASKA ALASKA .- AND GAS CONSERVATION C~..MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLINGWELL [] COMPLETED WELL r)(i OTHER [] 7. Permit No. 2' Na~F~ ~f0OP~ S KA, INC. 84-65 3. Address 8. APl Number P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 50-103-20029 53' FEL, Sec. 14, IVER UNIT 4. Location of W~I SURFACE LOCATION' 657' FSL, T11N, R8E, UM BOTTOM HOLE LOCATION' 1355' FSL, 1063' FWL, Sec. 14, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB' 130', PAD' 94' . 6. Lease Designation and Serial No. ADL 25570 ALK 2668 12. 10. Well Number 2A-7 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Char)ge Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-¢,07 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On March 12, 1985, Kuparuk well 2A-7 was converted from a producer to an injector. Injection will be in the "C" sand only. KUPARUK OPERAT!ONS COORDTNATOR 14. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed ~,~ ~) _(~_(~¢¢~(~ Title The space below for Commission use 3/28/85 Date Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Oear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field. On Wel I Act ion Date Pe. rformed 1E-6 Fracture 1/26/85 1E-7 Reper f 1E-7 Fracture 3/1/85 1E-8 Reper f 1/28/85 1E-11 Reloe r f 2 / 1 / 85 1E-11 Fracture 2/7/85 1E-18 Fracture 3/1 3/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3 / 23 / 85 1E-22 Fracture 3 / 22 / 85 1E-24 Fracture 3 ! 22 / 85 1L-6 Fracture 2/2/85 1 L-7 Fracture 1 / 30 / 85 1Q-9 Fracture 3/1 8/85 1Q-1 0 Fracture 3 / 5 / 85 1Q-1 2 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Convers i on 3 / 12 / 85 2A-5 Convers i on 3 / 1 2 / 85 2A-6 Convers i on 3 / 1 2 / 85 2A-7 Conve rs i on 3 / 12 / 85 2C-4 Reper f 2 / 23 / 85 2D-4 Reper f 2 / 2 / 85 2V-8A Convers i 2X-8 Per fora t i on 1 / 27 / 85 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) the ARCO Alaska, Inc. is a Subsidiary of AllanticRichlieldCompany ARco Alaska, ln~_.~ -, - -,.~_.:,c ~,.;..-- ;77 5c37 Transmittal No: 4741 Return To: >~CO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 f Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PRODUCTION FINALS/Schlumberger 2A-6 Completion Record "JB/PPS" 6/29/84 Run 1 7747 - 8059 2A-7 Completion record 7~08/84 " 7540 - 7750 2A-7 CET Log 7/04/84 " 6800 - 7827 2A-7 CET Log 7/06/84 Run 2 6800 - 7806 gA-7 CCL & Perf. Record 7/05/84 P;an ! 2A-7 Collar Log for Sq. Guns 7/01,02/84 (Sq. #1, #2) 2A-7 CBL "Variable Density" 7/04/84 Run 2 ~ 2A-7 " " " 7/06/84 Run 3 ; 6800.- 7819 6800 - 7805 2C-7 Completion Record 7/28/84 Run 1 6200 - 6600 1F-14 ' CCL & Perf. Record 6~23/84 " 1G-6 Completion Record 7/22/84 " 8012 - 8576 /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE DISTRIBUTION Drilling Geology Mobil W.V. Pasher G. Phillips State of Alaska Phillips Oil Sohio J.J. Ra t~hmell Union Chevron NSK Operations R ~ D Well Files ARCO Alaska, ~ Post Offic= 8ox 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to stimulate Kuparuk Field well 1F-6 and to convert the following wells: 1Y-2, 1Y-8, 1Y-12, 1Y-15 2A-l, 2A-2, 2A-3, 2A-4, 2A-5, 2A-6, 2A-7 2V-l, 2V-2, 2V-3, 2V-4 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate)- ECEI%/ED JAN 0 4 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a subsidiary of AtlanticRIchfieldCompany STATE OF ALASKA ALASKA tJIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-65 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-103-20029 OTHER [] 4. Location of Well SURFACE LOCATION: TllN, R8E, UM 657' FSL, 53' FEL, Sec. 14, BOTTOM HOLE LOCATION: 1355' Sec. 14, TllN, R8E, UM FSL, 1063' FWL, 5. Elevation in feet (indicate KB, DF, etc.) RKB 130' PAD 94' 6. Lease Designation and Serial No. ADL 25570 ALK 2668 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2A-7 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other 1~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other L~ 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 2A-7 be converted from a producer to a gas injection well. The well has produced from both the "A" and "C" sands. For injection, however, 'the "A" sand will be blanked off and injection will be' in the "C" sand only. ANTICIPATED START DATE: January 27, 1985. Subsequent Work Reported 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ J.._l~_ Title OPEI~TION$ COORDINATOR The space below for Commission use Date 1/3/85 Conditions of Approval, if any: I~Y LOHHIE 'C. SMITII Approved by CQMM ISS ION ER Approved Copy Returned ~/--- 7 - By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ Post Office L t00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 25, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2A-7 Dear Mr. Chatterton: Enclosed are the Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263 -4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU1/L56 Encl osure RECci LD Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '~'----- STATE OF ALASKA ALASK .... AND GAS CONSERVATION ~ .VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-65 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20029 4. Location of well at surface 9. Unit or Lease Name 657' FSL, 53' FEL, Sec.14, T11N, R8E, UM Kuparuk River Unit / i ' LOCATIONS i At Top Producing Interval 10. Well Number 1313' FSL, 1278' FWL, Sec.14, TllN, R8E, UM VERIFIED 2A-7 Surf. ~ ll. FieldandPool AtTot~ Depth 3. H.~ Kuparuk River Field ' ~35'~' FSL, ~' FWL, Sec.14, TllN, R8E, UM · 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore ] 16. No. of Completions 05/25/84 05/31/84 07/09/84 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7956'MD, 6222'TVD 7851'MD,6144'TVD YESJ~[ NO[] 1932 feetMDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, BHCS/GR, Gyro, CBL/VDL/CCL, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24- 175sx Cold Set II 9-5/8" 36.0# J-55 Surf 2695' 12-1/4" 850 sx Permafrost E & 2!;0 sx Permafrost C 7" 26.0# J-55 Surf 7931' 8-1/2" 275 sx Class G & 250 sx Permafrost C 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) 7682' - 7688' 3-1/2" 7634' 7610'WLM & 7373' 7.672' - 7682' 7662' - 7672' 4 spf, 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7652' - 7662' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7630' - 7642' 7630' - 7631' 40 sx Class G 7452' - 7453' 150 sx Class G 7580' - 7600' 7540' - 7560r w/12 spf, 120° phasin] 7629' - 7630' 100 sx Class G 7560' - 7580' 7530':- 7540' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ;'" ~'~ Al~,::: -, u,i & Gas Cons. Commission Anchorag~ Form 10-407 Rev. 7-1-80 GRU1/WC06 Submit in duplicate CONTINUED ON REVERSE SIDE ::'- ~:' -:!i: ':- ::' '-.-!'? ~:~i:.~'~o,?o~;~'~'~'-~F~;S~'' .!;~ ~-':, :? ~ ~:!??;-.-.":"~-~ ~?:~; :~ ;-i'-',-,? .~'~ ~.-.,, " .... ;'-'-FO R I~/IAT I'O N ;~ ESTS: ".: ' : · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH . GOR, and time of each phase. .. Top Upper Sand 7530~ 5909~ N/A . Base Upper Sand 7600~. 5960~ ToP Lower Sand 76087 59657 Base Lower Sand 78167 6118~ : · . 31. LIST OF ATTACHMENTS I~ell Histsory: Workover V/eli History: Gyroscopic Survey ~f2 conies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ,/--//~ /~-- ......... . .... 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 (G L) 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 Wi<lnem~/~m' · well I,, .podded or worl~wr c)~rmtone ~'. ~cl. Ute form giving Inoludve dm o~ly. Alaska Kuparuk River Au~. or W.O. no. AFE 901733 e-?" ;':~::': -l:~: u.~ North Slope Borough I ~.e ADL t/25570 I Drill~ Complete & Perforate IStm Alaska 2A-7 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 5/25/84 thru 5129/84 5/30/84 5/31/84 61o1184 ID-*, 5/25/84 Complete record for each day reported JARCO W.,. ~7.24~, Prior otetul if I W.O. 1100 Hrs. 9-5/8" @ 2695' 6021', (5911'), Drlg w/Navi-Drl Wt. 9.1+, PV 8, YP 6, PH 9.5, WL 6.4, Sol 6 Accept ri~ @ 0915 hfs, 5/25/84. NU riser & diverter sys. Spud well @ 1100 hfs, 5/25/84. Drl 12¼" hole to 1240', Navi-Drl, drl & surv 12¼" hole to 2725'. Rn 68 Jts, 9-5/8", 36#, J-55, BT&C csg & lnd w/FS @ 2695' & FC @ 2613'. Pmp 850 sx PF "E" @ 12.3 ppg, followed by 250 sx PF "C" @ 15.6 ppg. Displ w/rig pmps, bump plugs. CIP @ 0015 hfs, 5/27/84. ND 20" diverter. NU & tst BOPE to 3000 psi. RIH w/BHA, tst csg to 1500 psi, DO cmt, FC, FS + 10' new formation. Conduct formation tst to 12.5 EMW. Drl & surv 8½" hole to 6021'. 1552', 8.4°, N69W, 1499 TVD, 18 VS, 6N, 17W 1942', 2432", 2921', 3708', 4717', 5723', 23.2°, N79W, 1924 TVD, 134 VS, 25N, 132W 36.5°, N83W, 2301TVD, 355 VS, 57N, 350W 46.3°, N89W, 2663 TVD, 687 VS, 79N, 683W 46.4°, N84W, 3193 TVD, 1241VS, 92N, 1243W 45.5°, N77.2W, 3882 TVD, 1904 VS, 217N, 1955W 44.3°, N75.3W, 4603 TVD, 2676 VS, 399N, 2047W 9-5/8" @ 2695' 7684', (1663'), Drl w/Navi-Drl Wt. 10.2, PV 12, YP 14, PH 9.5, WL 5.2, Sol 11 Dr! & surv 8½" hole to 7684'. 6024', 47.4°, N81.gW, 4952 TVD, 3035 VS, 470N, 2999W 6288', 45.4°, N80.SW, 5300 TVD, 3400 VS, 526N, 3359W 9-5/8" @ 2695' 7840', (164'), TIR w/RFT Wt. 10.2, PV 8, YP 8, PH 9, WL 5.2, Sol 11 Drl 8¥' hole to 7840', short trip, POH. RU SOS. Rn triple combo f/7835' WL TD - 2696'. Rn BHCS/GR f/7835'-7300'. Rn RFT, unable to wrk below 4150'. 7165', 44.6°, NS1.6W, 5654.62 TVD, 3754.74 VS, 581.29N, 3709.77W 7763', 42.8°, N80.6W, 6086.93 TVD, 4167.83 VS, 645.21N, 4117.92W 9-5/8" @ 2695' 7956', (16'), LD BHA Wt. 10.3, PV 15, YP 15, PH 9.5, WL 5.2, Sol 12 POH w/RFT, did not go below 4150'. TIH w/8½" bit, rm 7314'-7840', drl to 7956', short trip, POH, LD BHA. 81gn~dure 6/27/84 ITM _ ARCO and Gas Company · Daily Well History-Final Report I~e= Prepare lad submit the *'Fla~I Re~e~' on the flrlt Wednesday a~ter allowable has been assigned or well IS Plugged, Abandoned, or Sold· "Fia~ Relle~' Ihould be aobmltted al~o whoa operetlone are ~ for an indefinite or appreciable length o! lime. On workovere when an official test is not required u~,n completion, report completion-a~d'repm~l~V~ dat~ in block~ provided. The "Final Rel~l" form may be u~ed for repo'rtlng the entire operation if apace ia &vaileble. . -...~- - · .. J Accounting COSt center code District I State Alaska North· Slope Borough Alaska Field Auth. or W.O. no. ICo~nty or Parish Lease or Unit Title nODS 2A-7 Kuparuk River AFE 901733 Operator. ARCO Alaska, Inc.- ADL #25570 Drill, Complete & Perforate W.I. ITotal number of wells (active or inactive) on this [cost center prior to plugging and I labandonment of this Well I IHour ]Prior status it a W.O. ! 1100 Hrs. Spudded or W..D~.begun 5/25/84 Spudded Date and depth as of 8:00 a.m. 6/02/8.4 Complete record for each day reported 7" @ 7931' 7851' PBTD, (0'), RR 10.2+ NaC1/NaBr RU & rn 201 its, 7", 26ti, 3-55 BTC csg w/FC @ 7851', FS @ 7931'. Cma w/275 sx C1 "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ w/lO.2+ NaC1/NaBr. Bump plug. CIP @ 1645 hfs, 6/1/84. ND BOPE, displ 110' of brine f/surf. NU &'tst tree to 3000 psi. Arctic Pak w/250 sx PF "C" @ 15.6 ppg, followed by 63 bbls Arctic Pak. RR @ 0100 hrs, 6/02/84. Old TD I New TO I PM Depth i 7956' Released rig Date IKInd of rig 0100 Hrs. 6/02/84 I Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oi1 I Single Producing method Official reservoir name(e) Flowing Kuparuk Sands Potenlial test date 7851' Rotary Weli no. Date Reservoir Producing Inter'al Oil or gas Tesi time' Production · OII on test Gas per day _ Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected , _ . ., The above Is correct Signature 6/~7/R/, ARCO Oil and Gas Company Daily Well History-Final Report I~L,~eti~e: Prepare and submit the "Final Ref~rl' on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final ReI~W' should be submitted also whet~ operetlona are sueponded for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion a~d repre#ntative teat data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District County or Parish I State Alaska North Slope Borough I Field Lease or Unit Kuparuk River ADL # 2 S $ 7 0 Auth, or W.O. no. T tie AFE 901733 Completion Operator ARCO Alaska, Thc. COSt center code Alaska IWell no. 2A-7 I A.R.Co. W.I. Spudded or W.O. begun I Date Workover I 6/30/84 Complete record for each day reported Date and depth as of 8:00 a.m. 7/10/84 Old TD Released rig 1230 Hrs. Classifications (oil, gas, etc.) Oil 56.24% I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prlor statue if a W.O. I 2330 Hrs. 7" @ 7931' 7847' DPM PBTD, RR Kuparuk crude Oil Displ well w/crude oil. SITP @ 700# psi. Tst tbg to 1200 psi. Bleed tbg to 800# psi, ann to 0 psi. Secure well, set BPV. R_~R @ 1230 hrs 7/09/84. Producing method Flowing New TD Date 7 9 S 6 ! I PB Depth Kind of rig 7/09/84 Typo completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7847' DPM Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on teat Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abOve Is correct JD,te 7/23/84 ITM Drilling Superintendent Aull~. or W.O.. AFE 901733 ] gt~e North Slope Borough Alaska AOL ~ 25570 [2A-7 Completion ' ms #1 O~mtor ARCO Alasi~, ]'nc. Spudded or W.O. be~m ~ork. over ID~e I Hour 6/30/84 2330 Hrs. Date and delhi u of 8:00 Lin. 6/30/84 thru 7/02/84 7/03/84 7/04/84 thru 7/05184 7/06/84 Complete record for ~ch day reported IARCO w.,. 56.24% Pdor I~Ul If i W.O. 7" @ 7931' 7851' PBTD, ?OH w/perf gun Wt. 10.1+ NaCl/NaBr Accept rl~ @ 2330 hfs, 6/30/84. ND tree, NU & cst BOPE to 250/3000 psi. RIH w/sqz guns, perf 7630'-7631' & 7599'-7600' @ 4 SPF/90° phasing. RIH w/7" EZSV recnr & sec @ 7615' WLM. Hesitate sqz perfs w/40 sx C1 "G" w/8% D-60 & .2% D-46. WOC. RIH w/sqz gun, perf 7452'-7453' @ 4 SPF/90° phasing, POH. 7" @ 7931' 7851' PBTD, DD on CR @ 7188' Wt. 10.1+ NaCl/NaBr WOC. RIH w/EZSV, set @ 7188'. Sqz perfs w/150 sx C1 "G" w/.8% 9-60 & .2% 9-46 @ 15.8 ppg. CIP @ 1652 hfs, 7/2/84. Rev out DP, POH, WOC. PU mil!, DD, RIH, tag CR @ 7188', DD w/mill on EZSV. 7" @ 7931' 7851' PBTD, RIH w/EZSV Wt. 10.2 NaC1/NaBc:._ DD w/mill thrU EZSV r~tnr @ 7188'-7191', mill cmt 7193'-7~', mill cmt strin~srs 7566'-7587', CBU. Tst sqz perfs 745~07/453' to 150~~~._Hill cmt 7597'-7623', tag 2nd CR @ 7623~, CBU, ts~..::~;~i~l-B7599'-7600' to 1500 psi; OK. Mill CR @ 7623'-762~mil~'cm~' 762t'-7638', mill cmt strings 7638'-765~ CBU. Tst sqa perfs 1-A 7630'-7631' to 1500 psi; OK. RIH, wsh & rm to PBTD, CBU, POOH. Tst lub to 250/1500 psi, rn CBL/VDL/CCL f/7830'-6800'; poor bonding. RIH w/6-1/8" bit, tandem boot bskts & 7" csg scrprs, tag PBD @ 7843', ctrc& wsh to 7851' DPM. RIH, perf 7629'-7630' @ 4 SPF/90° phasing. RIHw/EZSV retnr on WL. 7" @ 7931' 7851' PBTD, Mllling EZSV retnr Wt. 10.1NaCl/NaBr Fin RIH w/retnr, set @ 7618' WLH. Hesitate sqz 20-1/2 bbls C1 "G" w/.8% D-60 & .21 D-46. CIP @ 1410 hfs, 7/5/84. WOC. RIH w/230 its, 3½" DP, WOC, tag firm cmt @ 7618' DPM, mill cmt f/7618'-7624' DPM, mill EZSV retnr !.~ ~"'"! .... ~ """. Alaska 0ii 6., arts ~'~*~ r" -~o ARCO Oil and Gas Company <) - -. :... ./ %. ..... Dally Well History--Interim l.~na~lm~: This form lo u~ed during drilling or wo~over operation.. If to.ting, coting, or perfecting, show formation name. In d,,e,_~.flb, lnR w. ork performed. Number ~11 drill stem te~t~ ~eClulntl~lly. Attach dllcrlptlml of Iii ~ WOH~ perfom~d by Product .n~...Section will ~ rel~. rtlo ~ ,.nltrlll II~__l~t.e until final completion. Report official or repre.entativl reit ~1 ~ ~nl. 1) 8.bruit "llterf~¢' sheetl when fluid o~t-but not ion frl<lUently man every 3u (llyl, or (2) on Wedne.day of the week in which oll Itrfng II I~L Submit ~ for worf~lwl~l and following ~4ttlng of otl ~trin§ until completion. Dletrlct ICounty or Perish IStat, Alaska North Slope Borough Field ILea~e or Unit Kuparuk River I ADL # 2 $ $ 7 0 Complete record for each day while drilling or workover in progre~ Date and depth as of 8:00 a.m. 7/07/84 thru 7/09/84 Alaska IWell no. 2A-7 7" @ 7931' 7847' (DPM) PB~, Displ br w/diesel & crude Fin mill retnr-& cmt f/7627'-7645' DPM, mill cmt stringers f/7645'-7657' DPM. Tst csg to 1500 psi; OK. RIH to PBTD, CBU, balance well, POOH. RU & rn CBL f/7805'-6800' WLM; good bond. Rn 6-1/8" bit/tandem ink bskts/csg scrprs, displ well w/cln 10.1+ NaC1/NaBr, POOH, spot 25 bbl 10.8 ppg BridgeSal pill. RIH, perf 7682'-7688', 7672'-7682~, .7662'-7672', 7652'-7662' & 7630'-7642' @ 4 SPF/90° phasing. Perf 7580'-7600', 7560'-7580', 7540'-7560'~ 7530'-7540' @ 12 SPF/120° phasing. Rn 6-1/8" OD gage ring/jnk bskt to PBTD, POOH. RIH w/Bkr FB-I Pkr & tailpipe assy, set @ 7610' WLM. Rn 175 jts, 3½", 9.3#, J-55 8RD EUE ABM tbg & ind. Instl BPV, ND BOPE, NU & tst tree to 250/5000 psi. Displ well w/30 bbls diesel, followed by crude. Tho above is correct For form p~epa'~ati~n and distribution lee Procedures Manual Section 10. Drilling, Pegee 86 and 87 IOat, 7/23/84 ]Title Drilling Superintendent GCT Di~C~IUNA~ FU~ AJqCU AI..,ASKA~ INC, 2A'7 KUPARUK ALASKA 6U~VEJ DA~'E: 4 dU~E 19~ METliOD'$ OF CO.~.qFUTATION ~ 'TOOb [,OCATION: TANGEI~TiAL- averaqed deviation arid azlmuth Ii'~TERPtPL/%TIUN: I, IN~AR ~ JM~TJ. CAL 5~]CTION: i{OF,][ZO~TAL, DISTA~.~CE Pk ~"~CTEU UNTO AN"' AZiMUTH OF NO RCD AbASKA~ IJPA~UK bASEA ASU'REO VERTICAb 0 O0 lO0 O0 200 OU 300 O0 400 O0 500.00 600,00 700 O0 800~00 900.00 0,00 200,00 300.00 500.00 b00,00 700,UO 800.00 900,00 COi'qPdTATi['I~ DATE; 16 JULY 1984 PAGE , [)ATE OF SURVEY~ 4 dUNE 1984 K~b~] BUS,ING ~b~VA~IONI 130~00 V iRTICA DEViATiOt,~ AZL~UTti 30, 0 0 .... 0 17700: 0 0' 470,00 0 0 570,00 0 0 670,00 0 0 77 0.00 0 0 000.00 1000.00 870.o0 0 0 100'00 1100,00 970,00 0 0 200.00 1200.o0 1070,00 0 0 300,00 1299'99 1169,99 1 19 400,00 1399,83 1269,83 4 51 500.00 1499,~ 1369.18 7 4b 60O .00 1597.86 1467.86 lO 56 700.00 1695,61 1565.bl 13 8 800,00 1792.12 1662.12 17 3 900,00 1806,~b 1756,96 20 12 000.00 1979.48 1849,4~ 24 35 100.00 2068,~"1 1938,87 28 24 200,00 2155.41 2025.41 31 34 300,00 2239'71 2109'71 33 46 400.00 2321,52 21~1.52 36 ~4 500.00 2400,10 2270,10 39 22 600,00 2475,65 2345.65 42 lO 700,00 2547.80 2417.80 44 58 800.00 2b17,00 2487,60 4b 4 900~00 2bSa,Th 2556.75 46 14 O E: G ~ I m ~ 0 O E U,0O & 75 3] £ -0.05 0.28 $ 42 2 g -0.11 o,21 $ 3 19 E -0.19 0.08 8 35 O g '0.23 U,l~ s lo -o.3v o. o s50 w -o, 5 N 1.8 48 ~ -0.35 0.06 ~ 84 18 E -0.38 0,12 $ 28 32 W -0.40 N 22 41E -0.3b 0.17 S 0 0 W -0.4b 0,21 S 36 53 W -0.37 0.10 N 75 40 W 0,18 3,09 N 62 58 W 5.35 3.34 ~ bB 10 W 16.10 ~ 78 57 W 32.09 3.35 N 89 bN w b3,06 2,96 N 89 41 W 78.82 3.34. N 82 b3 W 110,~5 ~ 83 50 W 148.1B P. 85 53 W 192,87 N M't 54 w 242.6~ N 88 26 w 295.95 h 87 bU W $b3.09 N B8 5 ~ 414.57 S 89 bl W 4'19,3b N ~8 42 w 547.78 N $~ 25 w blB.79 h ~ 25 W b90.43 000.00 275b.11 2626.11 45 50 iO0,O0 2825 5b 2695,5~ 45 50 200,00 2894:8~ 2704.86 46 24 300,00 2963,~1 2833,91 ~6 24 400.00 30]~.57 2902.57 46 58 500.00 3100,9b 29'10.9b 4b 27 600,00 3169,b~ ]039.82 46 24 700.00 3238,79 3108,79 4b 24 800.00 3307.80 3177.80 46 24 900.00 3370,49 3246,49 46 33 ~ 88 25 ~ 7bl.ti9 a 87 50 w 833.27 N 87 50 ~ 904.79 N 80 25 W 9'16,59 ~ ~6 25 ~ 1048.72 m 87 1~ W 1121,11 N 83 54 w 1193.3t~ h ~2 b ~ 1265,7b N 81 32 W 133~.~2 N 78 b~ W 14~0.78 t.b9 4,09 2,82 4.11 3,09 3,38 2,~b 2,50 0,77 0,35 0.42 0,36 O,4b 0.50 2,44 1.10 ~,~5 .4! 3,17 URt; ' l' NXN o.ou N o,oo 0,07 id 0,06 E 0 0,04 N 0,12 E 0 O.IB S 0,16 f 0 0.31 ~ 0 17 E 0 ,, [ 0,4? $ 0 30 E 0 0,64 $ 0 25 g 0 68 ~ , 0,7~ $ 0,34 1.04 S 0.21 g 1,'06 (,,Ob N 15.34 w 16,49 N ~8 28 W 10,37 N 30,65 W 32,54 N71 24 W 12.2'N 51,78 W 53,21 N 76 40 W 12.09 N 77,88 W 78.82 N B110 W 1~,$2 N IVg,4b W 110,39 N 82 32 W 1B.7b , 147.0b w 148 25 N 82 43 W 191.66 W 193 O1 N 83 12 W 22,82 N 25,51 N 241'0'1 w 243 2b.69 N 295.42 W 296 Jb,4"l m b20,BB W b21 37.4U N 693.10 W 694 01 N 85 58 W 62 N 64 50 W 90 S 66 43 W 11 N 86 54 W , .. 44,3] N 909.04 W 910 12 N W 4b,09 N 9UI,37 w 982 48 N 87. M 48,93 N 1054,04 W 1055 lB N 8 W bl,31 N 1126,9b W 1128 12 N 87 2J W , ?~.5o N 1342.69 ~ 1344,86 N8644 W ~u.l~ m 1414,40 w 1417,15 N 86 25 W ALA6K.A~ ~.'7 IPARUK TRbE YERT]CAL DEPTH 3445,~4 3514,51 3584,35 3654.54 3724.70 3 '19~i, gO 3865.]3 3935,29 4005.35 4075.47 414.5.52 4215'50 4285.3] 4354,~2 4424.70 4~95.~ 4566.42 4638.08 470U.60 4776, I 7 49()7 4975.24 5042,2 ~] 5108,72 517'/.45 52~7,73 531 ~. 02 538~.12 545~.2~ 552~.~ 5598,99 5741,~1 5814.24 5959.99 6032,9"1 6~06.35 618U.20 SUB-S V E R 1' I 3315 3384 3454 3524 3594 3735 3805 3875 3945 4015 4085 4155 4224 429~ 4355 4436 4508 457E ~712 ~ 'l 7 't 4912 4978 5 o 4 'l 5117 518~ 5258 5328 5468 b5'lO 5611 5757 5~29 5902 59'16 6050 16 ,J~,hx' j, 9i.'4 PAGE DATE DF SURVEY{ 4 dUNE 1984 Ki~bh¥ BUSHING E~EVAXlON{ l~O,OO ENGINEER; ~CBRID~ vI~RT] CA~ F E; F .T 14~3,18 1555.24 1626.08 1697..%o I"lOB.bl 1B39.39 1910.20 1981 2052,00 2~22 ,5'~,~ 45 5C) ?~ "1~ b w 2193.72 ,50 45 50 N 74 b W 22h4.62 .31 45 50 N 74 5 w 2335.67 '82 45 50 a 76 38 W 2407,18 .70 45 15 ,],b 44 b2 N 75 ,42 44 7 ~ 75 20 ~ 261{).13 ,08 44 7 N 75 14 W 2588.55 ,80 46 29 & 77 2 ~.~ 275E.96 ,17 48 7 ~ 77 ~1 ~ 2~32.71 290).41 2982... 84 3O56. l '1 3130.96 ~205.65 3278.24 3349.39 3420.51 3563.13 3634.30 3705.17 3775.5O 3U45.i3 3914.06 39U2.54 4050.95 4119.27 4187.%5 UU(;bt~U HEC'I'ANGUL, AR COORDINATE6 HOI ~URE SEVERITY NORTh/SUUTH EAST/WEST DIS' [)~G/1 O0 FEET FEET FE~' 0.28 O,a7 0,38 G.39 0.4! u,09 0,32 0,'10 1,02 0.39 0.45 4,32 U,46 3.t;5 0.23 2,th 1.3o 0,45 0.42 0.51 0.31 0,45 u.50 1.08 1,19 0.73 ~, 0 0,00 IO3 54 N 1485,26 119:74 a 1555.66 132,97 N 1625,29 153,43 N 169~,42 171 OZ N 17~3,47 189 O1N 1832,38 207 31 N 1901,1B 225 84 N 19~9,98 244. ~Z N 20~8'43 263 5] N 2107,56 2B2,~6 N 21'lb,2b 302,49 N 2244,94 322,41N 2313.72 340 83 N 2383,20 357:0~ N 2452,88 3'13,'11 N 2521,84 390.81 N 2589,88 408,42 N 2557,37 425,59 ~ 2725,95 441,71 N 2798,05 457,9J N 28'11,13 ~'74.2"/ N 2944.91 ~U8,'18 N 301'1,46 502.5~ N 3090.41 515,2~ N 3153,~3 529.22 N 3 35.28 b4~,~1N 3305 4'1 552,95 N 3375~57 555,2; N 3445,8~ 577.69 N 35~6,04 590.09 N 3586.14 OO~,4~ N 61~.65 N 3725,21 ~27,21 N 3793,72 ~9.67 N 385*.54 552,1% N 665.14 N 399b.10 0'1~,2~ N i053,19 691.49 N 4129.82 704,7~ N 4195,94 1488 1560 177 1841 1 · 0 W w 5 N 81 2053,45 W, 2123,98 2194 57 2265 3 2335 ~8 2407 45 2478 72 2619 2688 57 2758 97 2832'71 2907,42 2982,85 3056,79 3131,01 3205,68 3278,28 3349,43 3420,56 3491,87 3563,18 3634,36 3705,24 3775,58 3845 22 3914:15 3982,e5 4051.07 4119~%2 4187,32 4254,71 N8] 9W N 82 52 W (,.:C.) AL, ASKA, li'~C~, -7 PARUK ASKA ENGINEER~ MCB~ID~ . :I'RUE 8U~-~EA ~ :'~',::: C('}Ut{~E VEN'i'IL'AL DL]G~EG ~ECTA,NGUbA~ COORDINA'~E~ 5URED VERTiCAl, V~;R'I'ICAb DEViATIO~ AZ~'~J'[h ~EiCTJC~N 5EVER:ITY NC]RTH/8OUTH EAST/WEST DIST' ~PTH DEP~'h DEP'I'H DEG MIN FE:L'I D~G/IO0 FLEi FEE~' 5 6,0 0 6 2 21,5 5 ~ 0 ~ 1,5 5:4 2~::~?~::2::3 ~ 7 ~ ~ u ~ ~I 2 9 2. ~ b 0, u 0 '/1;,:.].~ N 42~12,97 W ii ~RCO ALASKA, lA-7 [UPARUK C. Oi-'iPUTATIO.r~ uA']j[~: 1~ JiJL.'Y' lY84 ;ASURED VERTICAI V£R'.i'ICA~"~EV'~ATIOI'~ AZI,~UTH DEPTH DEPTh OEG PAGE: 4 DAI'~ OF' SURVEY1 4 aliNE 1984 ,000.00 1000.00 ~70.0 !000.00 t000,00 2756,. 1, 2626.1i 45 5'0 ooo.oo iO00.O0 4145.52 4015. iO0~.O0 4842.49 474~,49 48 42 ~00 .00 5528.44 53 .44 45 15 ~956,00 6221,5b 6091,55 42 23 N 0 O E 0.00 N 22 41 E -0.36 N 8~ ~O W 14~,1~ N 88 25 w 761.89 N 74 5 W 2193.72 N 77 31 W 2907.41 N 79 49 W ]634'30 O.UO 0'17 0,42 O.h9 0,49 0.]1 O,VO O,OO N O,OO ~ 0 0,64 S ~.26 E 0 iB,7b N 14 .0~ W 148 39.60 N 765.11 W 766 28~.86 N 2{7 :26 W 2194 ~90.09 N 358 14 W 36. 712,1~ N ~232~97 W 4292 IN~,$~Q!~A~I/ED VAL, UE3 FOR E, VEN lOOt) T V~RTJ, CAL UtJGG~G R~C,FANGUUA~ COORDiNA~E~ HOR:~:~vj~ARTURZ 8EC]IE, N SEVERITY NOR ti/50[{Tl,{ EAST/WEST qCO A6A,SKA, I~'~C. JPARUK Ti~UE ~.SURED VERTICA6 )EPTH DEPTi~ ¸ 00 §:oo 5~ 00 5]0,00 5 0.00 630.0O 130,00 ~30,00 CC);.~PdTAI'IOh DA'rE: 1~ dung 19h4 PAGE . OATE OF SURVEY: 4 JUIVE 1984 · ENGINEER{ MCBRIDE )30.00 930.00 BUO.00 0 0 )30,00 1030,00 900,00 0 0 [30,00 1130.00 1000,00 0 0 }30,00 1230,00 Il00,00 0 0 {30'02 1330.00 12uO,00 2 10 ?35'42 1730,0o lbO0.O0 14 40 ~39,75 18J0,00 1700,00 18 b V ii~{.<'J' I C Ab DIJGL[~j(, SECTION SgVgRIT¥' ~"E~I' D~G/100 0.00 ,00 0.00 ~.00 -0,05 0,11 -0.1.3 0.19 -0,21 0,14 -0. Y5 0.08 -0.42 0,1.8 -0.42 0,09 -0..33 0,~3 '0.40 0,i2 O,UU N 0,00 E 0,00 N 0,00 E . O,Ob N 0,07 E O,0U N 0.14 E 0, 0,2'/ ~ 0,17 f 0.39 5 0,19 E 0 U,5~ S 0,34 ~ 0 o,60 $ 0,32 E 0 O,bU 8 0.24 E 0,57 $ 0.31 g )46,12 1930,00 1BUO,O0 22 14 D56,09 20]O.UO 1900.00 27 3 70,35 2130,00 2OO0,00 30 21 89.38 2230.00 2100.00 33 31. ~I~ 59 2],0.00 2200.00 3b 57 06 2430.00 2300.00 40 22 574 88 2530,00 2400,00 44 24 817 93 ~630.60 2500.00 46 24 962 38 2730,00 2500.00 45 bO 106 40 2830,00 2700.U0 45 50 250.85 2930.00 2800.00 46 24 396,25 3vJ0,0o 29v0.00 45 58 542.19 3130.60 3000.00 40 24 $87,25 3230.0U 3100.00 45 24 844,39 3330.60 3200.00 46 977,7~ 3430 bO J3UO,00 4b 24 12~,29 3530~CO 3400.00 45 50 255,05 3030.00 3500,0U 45 lb 407,56 3730.00 3600.00 45 15 549,99 383~.00 37V0.00 45 51 lb W -0.38 O.n6 0.63 BO 5 E -0.38 0,28 O,b$ 18 16 W '0.44 0.19 0,85 69 24 ~ 1.01 4,38 V,79 62 3 W 8,06 ~,16 2,~b 72 13 W 20.q9 3,50 7,5& 82 33 W 38,54 ~,57 11,39 89 27 w 61.43 4,0! 12,12 87 B w 90,75 3,89 12,~7 3,82 J,~O 3.24 2,72 0.29 0,~2 0,32 0,31 0,52 3.51 ~,57 1.73 O,bB 0.~9 O, 0,44 N 82 55 W 126,91 ~; 8~ 45 W 172..51 ~i 88 42 W 289.65 h 87 33 w 359.39 ~i 89 7 W 439.47 h U9 15 ~ 530,24 N 88 25 ~ 63~.63 ~ ~ 25 ~ ?35.02 I~ 87 bO ~ 837.84 0,29 u,2B 0,31 0,16 I 15 7 77 19 56 37 22 bO 27 0 0 20 3~ 61 90 lb,il IV 125,89 W 126 21,18 N 171,30 W 172 b 88 25 ~ 9~1.28 h Bu 25 W 1046,01 N H5 27 ~ 1151.%7 N B2 b W 1256,53 ~{ 81 14 ~ i361,~*/ h 7i 31 w 1457.11 t,i 76 57 W 1571.22 m 75 4~ w 1~t2.78 N 75 14 W ~773.88 ~ 75 It w 18'~4o~0 , 95 33 04 N 39 72 35,84 N b3 ,B3 W 634,84 N 8 45 k 3u,79 N 7ia.03 w 739,05 N 85 $~ M 42,05 N 841.b3 w 842,58 N 87 ~ 45,5b N 945.80 W 945,90 N 87 24 ~ 53.15 N bb. OO N 12bl 90 1365:78 IOU,IU N 1469,55 W 1472 12~,3'I N 15'11,27 W 1575 1~'1,30 h lb'10,29 w 1676 172,35 h 1758,69 w 1777 lYB,IO N 18bb,79 W 1877 leo ALASKA~, ~., "/ tPARUK ,AS~A ~BURED Vk'.RTICAb VERT1C. ~EPTH DEPTft Dt~P'f ,92 45 3930 O0 ~77'~3 4130,0o 4000' .2o.71 423o.00 ~64 29 4~3o.00 4200 ;07:55 4430,00 ~49~05 4530.00 4400, ,88.73 4630,0U 4500, I31.16 4730.00 4600, .33.11 181.66 ~31,58 i74.77 ' ! 7 .,10 159 80 }02i21 .43 80 ~B3 60 ~21.65 ('[It..,Pu'];AT II)i'.: DA'.i?E: A ' R i5B.9i i95.9 2,02 I~6,00 o 0 45 '50 ~'45 i'5 O0 44 41 O0 44 7 O0 47 14 O0 48 42 4930,00 48U0. ()0 4'7 33 N 5030.00 4900.00 48 7 N 5130,()() bOOC'.O0 47 5230,00 5100,00 45 15 5330.00 5200,00 45 5430 "00 5~00, O0 45 5530.uo 540o.00 45 t5 5630,00 5500,00 44 41 h 5730.0 () 5600.00 44 7 ~,~ 5830,00 5700,00 5930,00 b~O0,O0 43 5 N 6030.00 5900,00 42 bN i'~ 6130,00 bOOO,OU 42 23 N 6221,55 6091.55 4223 h 16 E VERTICAL ZI~'~!JTH SECIIr. n EG ~I~ FEET 74 40 W 197b.'?1 ?~ 40 ~ 2076.91 74 ~ ~ 2178.00 74 5 W 22'19,30 75 46 W 2181.5~ 7~ 23 w 24~3.b9 7b ~B W 2683.65 75 1~ W 2680.73 77 31 ~ 2781,75 77 31 ~ 2893.22 7~ ~ W 3007.53 79 15 w 31~7 32 79 3h ~ 32~ 80 Z3 W ~331.44 80 23 ~ .$432.70 79 49 W 3634.49 79 49 ~ 3635.~ 79 b2 ~ 79 15 ~ 3833.77 '1~ ~9 w 79 15 W %022.~8 76 40 ~ 4116.50 78 ~0 W ~2U~.'13 78 40 W DATE OF SURVEY: 4 JUNE KELLY BUSHING EbEVAXlONI ., 8UB-8~A DEPTH DUGGE(, 5EV~:R1TY OgG/lO0 0,28 0,22 0,22 0,34 0.31 O,bl 0.23 9 3.h4 0,39 3,t8 o,s7 0,39 0.28 1,07 0.95 u,~5 (.).71 0.00 0,00 PAGE b 1984 '130.,00 r~ NOR li/SOUTtt EAST/~EST DiS~ ~'~T FEET F£~I :#X.# ,,'., ~!.:'., 22~,44 N 19~,79 W 1977, '38 251.2~ a 2063,01 W 2078, '3 306,59 N 225 ,15 W , 33~t,80 N 2358,24 i ~, 358,27 N 2458,10 W , 382,01N 2555,35 , 258,.7,93 N Il579 W 40~.42 n 2649.77 W 2680.76 N ~6 ~JO,bl N 2748,23 W 2781.76 N ,5 ~5~,~5 n 2857,24 W 28 ,22 N , , lI ' 625,1~ N 3782,54 W 3833,85 N 803~ b42,3~ N 3~'10,13 W 392~,00 N 80'3 059.80 ~ 39b~,b3 W 4023.00 N 80 ~3 677,74 ti 4060,47 W 4116,64 N80 3 b95.'13 N 4151.00 W 4~.90 N 1~ )~ 712.14 N 4212.97 W 4 .~5 N ~,RCO AL, ASKA, .~A-7 ]'/',lC, 'l'OP UPPEI~ bA¢iD 7530,u0 ~ASE UPPER SAND "., 7600,00 20P I,O~ER ;~A{~D 7608.00 BA~E [,O~ER $~ND 7~1~,O0 RKB ] 30, O0 ~OTAh DEPTH 7956,00 PLUGGED BACK TOTAL DLPTit 7E51.00 D A T E;: ],r, JUI,~ i904 '].' ¢ ['"' k O f'~ Kb 5908.97 .':,:,959.99 5'064.57 0 1 1 8. l 'i 442.30 b221,55 6 ,144.01 5778.9'1 5834'57 59UU,17 312.]U 6014,01. PAGE OA'I'E OF SURVEY~ 4 dUNE 1984 K~talaY BU,SHiNG EIaEVAT~UN{ RECTANGUb N';,: T NORTH/SOUTH E 656 03 N 5 666,08 N b93'87 323, 7! ,2 :CO ALASt~A, IA~C? TOP UPPEN SAND BASE tIPPER SAND TOP LOWER SARD BASE ~OWgR SAND RKB PLUGGED BACK TOTAl,, C{)i~:I:'~IJTA'I'i{,i,r~, I';A],'E: 'it; dUi.,,k' 19H4 7950,00 7851.00 DATE C)r SUR'VE~: 4 JUNE 1954 ,, T VU 5o08.97 5778.97 5964,57 553~.57 &11~,17 59BB,~7 ~'42.30 312. 0 ~221,5b ~091 5b 6)44,01 6014:01 ORIGIN= 53 ~C~ANGU~A~'C~;'' ~ GC'£ DIRECI'IONAL SURVEY 2A-'~ KUPARUK AbA~KA SURVEY DATE; 4 dUbiE 19E14 Suggested form tc be insertcd in each "Active" well folder to d~eck for timely ccmpliance with our regulations. ' ' ~Opera~oJ, ~el 1' Na~ -and ~u~bef Reports and Materials to be received by: K--~ - Date R.equired Date Received ~Remarks -. ~re ~ips -' ,. /~~-' ~ ..... 0 15 ' .,. m . Inclina~on S~ey /~/~ Dire~ional ~ey ~~p[ ~_ ~-- ~ ~ ~. Dril 1 St~ Test Re~s · ' - ~--"~ ~~ ARCO Alaska. I~ Cc~.' C,~. cc:~ 360 Anchorage. Alaska 9_°.510 Telephone 907 277 5537 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 8/17/84 Transmittal No: 4691 Transmitted herewith are the following items. Please acknowledge receipt and return-one signed copy of this transmittal. CH FINALS/Schlumberger 1G-16~'~' CBL Variable Density 5/29/84 2A-lA CBL " " GCT 6/02/84 2A-2~~ CBL " · " GCT 6/02/84 2A-3 ..... CBL " " CIS 6/01/84 2A-4 ~ CBL " " 6/01/84 2A-3j- CBL " " CRS/RTS/DDL 6/15/84 2A-5 f CBL " " 6/03/84 2A.-6v~ CBL " " 6/03/84 2A-7 ~ CBL " " GCT 6/03/84 2A-lA .-~ Gyro Cont. Tool "CBL/VDL" 2A-2 ~- " " " " " 2A-3 /~ " " " " " 2A_4~ ,, -,, ,, ,, ,, 2A-6 ~ " " " " " 2A-7 ~ " " " " " 6/02/84 6/04/84 6/02/84 6/02/84 6/04/84 6/04/84 8800 - 9050 Run 1 5895 - 7502 " 5291 - 6544 " 4948 - 7092 " 6750 - 8018 " 6583 - 7081 Run 2 & 3 7695 - 8938 Run 1 6995 - 8078 " 6895 - 7823 " 60 - 7454 " 60 - 8060 " 60.5 - 7050 " 60.5 - 8003 " 60 - 8060 " Surf- 7805 " /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron DISTRIBUTION D&M Drilling W.V. Pasher G. Phillips Geology 7---~ Phillips Oil -Mobil J.J. Rathmell C. R. Smith ~.i:.state· of 'AlaSka Sohio Union NSK Operations R&D Well Files KUPARUK ENGINEERING Transmittal Type of Tape _ J / Date Tape Number -- DISTRIBUTION GeolOgy/C. Smith REC.FIVED Sign & return the attachea copy as receipt of dat~4½40 3~4 ~.,~~/'-- Alaska Oil & flas Cons. Commission / Anchorage OH LIS Return to: ARCO ALASKA, INC. ATTN: ?aura m. WE~T/~ ATO-1115B P.0. Box 100360 Anchorage, AK 99510 Please note: Blueline, Sepia,~ Tape, Photocopy ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2A-4 3C-6 2A-5 2H-3 2A-6 2H-4 2A-7 Oliktok Pt. #2 CPF-2 Waste Water Disposal Thank you. Sincerely, ~ wln ~' A;~ Engineer JBK:jh LO1 06/14/84 Enclosures RECEIVED JUN 2 0 9114 Naska 011 & Gas Cons. Commission Anchorage · ARCO Alaska. Inc. is a Subsidiary ol AtlanticRIchlieldCompany ~: .... STATE OF ALASKA --,. ALASK. _ AND GAS CONSERVATION ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER · Drilling well l~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-65 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20029 4. Location of Well at surface 657' FSL, 53' FEL, Sec. 14, TllN, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ?~_n 130' Pad 94'I _A_DT_. 25570 AT.if 2668 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2A-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of May ,1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1100 hrs 5/25/84. Drld 12~4" hole to 2725'. Ran, cmtd & tstd 9-5/8" csg. Drld 8½" hole to 7840'. Ran logs. Cont drlg 8½" hole to 7956'TD as of 5/31/84. Ran, cmtd & tstd 7" csg. Displ brine from top 100' of well. Secured well & released rig @ 0100 hfs 6/2/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HF-ERW BTC csg w/shoe @ 2695'. sx Permafrost "C". Cmtd w/850 sx Permafrost "E" & 250 7" 26# J-55 HF-ERW BTC csg w/shoe @ 7931'. Cmtd w/275 sx Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP/FDC/CNL/CAL f/7835' to 2696', BHCS/GR f/7855' to 7300'. RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data N/A JUN 2 0 1984 Alaska 011 & Gas Cons, Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.~/. /~~. ~ .... Area Drilling Engineer SIGNED ~ /_~,5__/~r.~..,¢-~/. ~~ TITLE DATE NOTE--R~ort ~ ~rm is required for each calendar month, regardless of the status of operations, and must be filed 'in duplicate with the Alaska Oil and ~as Conser~a~n Commission by the 15th of the succeeding month, unless otherwise directed. Form 10A04 ~ HILL/~155 Submit in duplicate KUPARUK' ENGINEERING Date: ~O~4E %\) We~ ~a~e: ~%~ Transmittal Date Run ¢' ~/,~/%,4I ,5/~/~,. DISTRIBUTION NSK Operation Blueline Dr ill ing B luel ine Geology/L. J. Bi/Se R&D Bluel ine D&M Bluel ine State B1/SE F.G. Baker Blueline G eology/Ken Film OHFinal ~turg. the attached copy as recezpt of data. Return to: ARCO ALASKA, INC. ATTN: ?~uo~l m. we'r/'l ~4 ATO-1115B ~E~if.V~. ,.o. ~ox ~00~0 Anchorage, AK 99510 THRU: MEMORANDUM State of Alaska ALASKA O~J~, AND GAS CONSERVATION CO~fISSION C. rton Chain-- _~/~ ~i/ FILE NO: Lonnie C. Smith ~? n ~& ~' TELEPHO~ENO: ~9~iss loner ~W ~ SUBOEC*: Ben LeNo~an Petroleum Inspector May 29, 1984 Witness BOPE Tests On Arco's Kuparuk 2A-7, Sec. 14, TllN, R8E, ~.~. Kuparuk River Unit _Saturd...a¥, .?!ay 26. I departed my home at 3:30 p.m. for a 4:00 p.m. shOwup'andL 5:00 p.m' departure via Alaska Airlines Flight #59 for Deadhorse arriving at 6:40 p.m. Weather: +36°F, Clear, ~unday....,...Ma~Y 27. B.O.P.E. tests began at 6:20 a.m. and were com- pleted at 7:20 a.m., B.O.P.E. inspection report is attached. I departed Deadhorse at 5:15 p.m. via Alaska Airlines Flight #56 arriving in Anchorage at 6:50 p.m. and at my home at 7:20 p.m. In summary, I witnessed successful B.O.P.E. tests on Arco's Kuparuk 2A- 7. 02-001A(Rev. 10/79) #4' 4/81 STATE OF ALASKA ALASKA OIL & G~S OONSERVATION CCMM/SSION B .O.P.E. Inspection Report Operator. /~ Well ~ Location: Sec Pril linq Contractor Representative Permit # ~- ~~sing Set Representative location, General Wel 1 Sign Ceneral Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams _ Blind Rams chOke L~ ne Valves H.C.R. Valve. Kill Line Valves- Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure ~D~) Pressure After Closure /0~o ~ Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: N2-~-'"~ °_~/~,~,~,~/~,o~,o '"?"~ ~1:; / psig psig psig min min ~-sec. Controls: ~laster (f~/~ Remote ~)/~ Blinds switch cover~/~ Test Pressure Test Pressure Test Pressure Test Pressure Kelly and Floor Safety Valves - Upper Kelly Lower Kelly Ball Type . Inside BOP Choke Manifold valves _/3 No. flanges ~) Adjustable Chokes / Hydrauically operated chcke / Test Pressure Test Results: Repair or Replacement of failed equipment to be made within., Inspector/Ccmmission office notified. Failures. ~) Test Time,' / hrs.. days and -. Distribution orig. - AO&(t2C cc - Operator cc - Supervisor Inspector May 3, 1984 Mr. Jeffrey Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Kuparuk River Unit 2A-7 ARCO Alaska, Inc. Permit No. 84-65 Sur. Loc. 657'FSL, 53'FEL, Sec. 14, TllN, RSE, UM. Btmhole Loc. 1355'FSL, !099'F%fL, Sec. 14, TllN, RSE, UM. Dear Mr. Kewtn : Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one Cubic inch ch~p from each foot of recovered core is required. Samplms of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainag~ systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you ma}- be contacted by the Habitat Coordinator's Office, Departmept of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska A~Inistrative Code, Chapter 70) and by the Federal Watsr Pollutzon Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Enviro~nental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Jeffrey B. ~.~win Kuparuk River Unit 2A-7 -2- May 3, 1984 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 b~fore drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. V~)L.. t ru ! v~...ur s C. V. Chatt~rt~ BY ORDER OF THE Chatham o f AlasP~ Oil and Gas Conservation Co~isston be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl, Department of Environmental Conservation w/o eno!. la. Type of work. -'"' STATE OF ALASKA ALASKA U~L AND GAS CONSERVATION CO,v~MlSSlON PERMIT TO DRILL DR ILL E~X REDRILL [] DEEPEN [] 20 AAC 25.005 SERVICE [] STF~_T GRAPHIC SINGLE ZONE []XX ~ MULTIPLE ZONE [] ~. ~ 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~(X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 657' FSL, 53' FEL, Sec.14, T11N, R8E, UM At top of proposed producing interval 1306' FSL, 1401' FWL, Sec. 14, TllN, R8E, UM At total depth 1355' FSL, 1099' FWL, Sec. 14, TllN, RSE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 2A-7 11. Field and pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 130', PAD 94' ADL 25570 ALK 2668 Federal insurance Company 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 14. Distance to nearest property or lease line 1099 feet 16. Proposed depth (MD & TVD) 7822' MD, 6150' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1240 feet. I 21 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 46 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program Kuparuk River Oil Pool Amount $500,000 15, Distance to nearest drilling or completed 2A-6well 60' @ surface feet 18. Approximate spud date 05~24/84 2746 psig@__80° F Surface 3151 .psig@_ 6010ft. TD (TVD) QUANTITY OF CEMENT (includestagedata) ± 200 cf 580 sx Permafrost E & 250 sx Permafrost C i Hole j 12-1/~" /2" SIZE Casing 9-5/8" 7!! Weight 65.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER Grade I Coupling/ H-40 / Wel~l J-55 HFIERW TCj J-SS HFIERW JCj SETTING DEPTH Length MD TOP TVD 80 36' I 36' 2726 35' I 35' I I 33' 33' 7789 MD BOTTOM TVD 116~ 116' 27611 2605' 78224 6150' I I 290 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7822' MD (6150' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2746 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2A-7 will be 60' away from 2A-6 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. (Continued on the next page.) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED //~~~ ( ~'/~-~.,O~.,~.' TITLE Area Dril ling Engineer The space byv~ f/~ssion use CONDITIONS OF APPROVAL DATE Samples required Mud log required I Directional Survey required APl number I~YES [~4~10 I-lYES E~NO I !~'ES []NO 50- !O5- ¢-o O~, ~ Permit number Approval date ~-~; J ~ 05/0~/8~ ~ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED B~ ~~//~ ,~OMMISSIONER DATE ~ .~, ~ t { of C o m o. Form 10401 ~UT~D~~ / ~ Submit in triplicate Name of Operator: Well number: 2A-7 Page Two ARCO Alaska, Inc. PERMIT TO DRILL The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon completion of the job. '~°ra~e GRU7/PD3/pg 2 AL^SKA,--ENC, ~:2A;-~ELL_-2NO~-7~-- POSEb UK-F[ELD~.-flORTH-SUOPE 24.0 -DEP=O ?--I' V D= 2555.-_THD~_2690 - DEP,= 525- -CSI~-PT--T 'D _=_ _2.6 .o5 --THD=27'Sl 'OP i UPPE SNDS ~ 'TVD-- 5850 :T. lflD-?~94 DEP=:)81)I TOP LOWFt SNDS'"TVD=5905 .TMD=74'i'3 0EP=3957 - -'- BASE-KUP -sNDs ' :-'[VD=6010.--THD=7622 OEP 09 'P~) D=61 50 'THD=7822 ~187' I ...} , ~ ! VEt : .... ~ ....... t ...... i .... _-'_:-__-'_:t.- ...... ---:-'~-:---:i:!~-~--~-~-:l---'iii--------: ' i ........ '- . ! ...... -_- -;- :-::-l~ :-:--.-.-- ...... [ ~ ...... ~4-58 2. 3. 4. .5. Surface Diverter System 16"-2000 psi Tankco starting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lO" side outlets. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. b Maintenance & Operation 1. Upon initial installation close annular preventer and verify Ghat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED APR 2 5 19134 Alaska 0il & Bas 0OHS. Oommi$$ion Anchorage PIP~.8 ~ ~ DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams .6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. I3-5/8" - 5000 psi pipe rmms 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" -.5000 psi annular BLIND ORI J. 6 PIPE 2 15. RECEIVED. APR 2 5 191 4 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WIlq~ HYDRAULIC F1.UID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITl~ 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ~d.L UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABL£ LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REI~AINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND VAL¥]~S DPS~ 01~ CH(])I<~S. DON'iT TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 8. ~.~'PRESSURE DOWNgrREAM OF CHOKE ISOLATION VAL.'%~S. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTRF.~ OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY CDC]CS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc.. Post Office Bo,,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 24, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2A-7 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 2A-7, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on May 24, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ~ .~~~ea~rely' ~' Engineer JBK/JG7/L13: tw Attachments RECEIVED APR 2 5 1 11 4 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc Post Office :,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Apri! 9, 1984 Mrs. Elaine Johnson State of A1 aska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat- 2A-Pad Wells 1-8 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG6/L85'tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,4lOska Oil & Gas COns AnChorag-~ CommiSsion ~;' 0 ~ 0 ~o0 90 ? 0 013 0 ~4 2:5 I 24 LOCATED IN SECTIONS . _ TllN',. RBE. UMIAT MERIDIAN. D.S 2-A z$ DRI .. SITE 2.A CONDUCTORS . I . BUILT LOCATIONS WELL-I y = ~,96o,~3e. z3s LA~.= 70°15' 083673~= X= 498,62G995 LONG = 150°00'40ZII" 2ZT'FWL, 717~FSL EL -' 94.:~, 0G=89.9 WELL-Z y= 5,960,078.4Z0 LAT=70° 18'07778g.' X= 498,6Z0.9 14 LONG =150°00' 40:>13. - 227' FWL~ 657'FSL EL= 94.4, OG =89. B WELL-5 Y =5,960,018.185 LAT= 700~8'071865' x-- 498~620.91Z LONI3 ~ 150e O0' 4021:~' 2ZT'F'~'Ls 597'FSL ' EL= 94.4~ OG= 69.6 WE L L. 4 y= 5,9 59,958.355 LAT '- 70° 18' 065~80" X= 4-38~6Z0.969 LONG= 150000'40ZII'' ZZ7'FWL~537'FSL ' EL=94.5~OG=90.4. WELL -5 Y=5,959, 958 261 LAT = 70°18'065965" X: 498,340.910 LO..N6:ISO° 00'48376' 5:5'FEL , 5:37' FS4. EL=94.0,OG: 89-$ WELL-6 Y=5,960,018.341 LAT=70° 18'071874" X= 498~340.956 LONE;150°O0'48376" 5$'FEL, 597' FSL ' EL=9;S.9~ .. WELL-?' Y= 5,960,078. Z8! LAT= ~0°18'077769'' X~ 491~3 40.90~ LONG= 150°00'48377'' 5$'FEL~ 657'FSL EL=93.8, OG= 88.? WELL-8 y =5~960, 13 8.371 LAT= 70018'083680"' X= 498~ 3 40.9~. LONG= 150°00' 4 8577" 53'FEL, 717 FSI. EL:95.7sOG =87.8 . 14,25,24, - ' ~/,,'..' A-'..' ''s . ' - w LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF. I&R~ UNDER .Y DIRECT S.PERVlSION & THAT ALL DETAILS ARE I ~ X7 ~,~ ~ -- ARco Ai°ska, ~ nc. ~1 ~, ~'~- Kuporuk ~oject North Slope Drilling 1 ~ ~,..;~ DRILL SITE Z' IB :t LOCAT, O.~ i ~ ~m~: Dote= 3 21 84 Scale: I"= 300' CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc (2 thru 8) (3) Admin ("' '..i,.i<.-'"'~-.- cf.. "b"~' ~'~! ..('.9, thru il) (10 and ) (12 thru 20)' Company Lease & Well No. YES NO 1. Is the permit fee attached ............................... ........... .,aY 2. Is well to be.located in a defined pool ............................ '~?'?~---,.~__ 3. Is well located proper distance from property line . . 4. Is well located proper distance from other wells . 5. Is sufficient undedicated acreage available in this pool .............. 6. Is well to be deviated and is well bore plat included .... ' . 7. Is operator the only affected party ........................ 8 Can. permit be approved before ten-day wait . eeeeeeeeeeeeeeeeeeeeeeeeee . 10. 11. Does operator have a bond in force ......... .eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee. ~.,~f.~ ........ Is a conservation order needed ...................................... " Is administrative approval needed ................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. Is conductor string provided ....................... Is enough cement used to circulate on'cg~d~cto~ an~ surfac Will cement tie in surface and intermediate or production Will cement cover all known productive horizons .......... Will surface casing protect fresh water zones ...... Will all casing give adequate safety in collapse, tension Is this well to be kicked off from an existing wellbore .. Is old wellbore abandonment procedure included on 10-403 . Is adequate well bore separation proposed ................ ele·eeeeele e . · strings ... ........... and burst.· ·eel.··.ele ··.·lellel. ............ REMARKS (5) BOPE /~-// ¢~-g~-~9 (21 thru 24) 21. 22. 23. 24. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~ ~Z> psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. ~. Additional .! Geology: Engi~.eering: :% .cs ' C'X EW "-- WVA~ JKT ~~JH ~ JAL ~.ri.~ ~..,J~M ..... f rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE · ~17 o,, ~ , / / / f, "o0,,'u 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 ^PPENDIXi No 'special'effort has been made to chronologically organize this category of information. .o * I,'F'F.~ ';,:;'.~,DI:"H TYPE C,~E $IE~ ~ODE 000 000 016 065 OaO 000 0O4 065 000 OOO 008 065 OhO OOO 002 0~5 000 OOO 004 065 OOg 000 On2 065 <)00 000 OmB 065 OhO OnO (~n~ 065 OhO 000 O04 065 ,m ~8~o DP ( ~ L"I"I] I"[1! l iil ii:-] i[! [:-] ~ 4 4 4 4 4 4 4 4 4 4 68 6~ 6~ 68 68 6~ 68 68 32 0 2 1 6P t 68 LC' R C~ i.., EPT R w,' 7~56.n000 SFT,U 2. ~840 TI'.,.'" -57."500 ' Q ~' ¢" '" 5 n 0 t~ ~ 7 '~ :..'. '~0(10 KFLU "". v5!9 TLU :'. °7~i0 ' 406 ~175 .."L" ~ r.;O00 .62~; .257 '..187' I 3, a .... j3© ,~fr'; ," . . 7P. 0 '4 · p, I' C'AT.,I ,~FLti 7. 257 :~ 2. fl 51:, ,~ 1'7 9.. 55 2:,0703 1'8311 39. 2500 9.93'/5 4,. ! 875 ,4:336 1992 * OCtO0 I °9277 ! DT ~PHI T SP ~HOB 2,5840 -57~7500 -999.2500 1 9365 44:9707 3 7539 -60!5000 95 5625 ~.7754 -5.097'7 4 .94 R C~,I I. ,, ,. 3.75,- ' ~31.0C " 3~71 ,-~ a. 95 "5 2.7031 .] 17 . 50f',n 317.50o0 -9 .qO. 9500 45n.0000 4 5117 3 ~ 7461 ~13· 2500 ~13.2500 -99q.~500 52~.0000 4.73~3 3.96~7 -09o.2500 ~ 9 a. 1707 1.28.~7M0 -999. 950O ~?~. nOOn n 6 ~ 5 l?~a,0 .... , :t24, I. 14. I I a. 5625 ,~ 51'lb c,'~ T,, C If,u CALT C'~LI ,.qFr, u ., .'7383 ~' .06~7 ~<'.3175 1 ¢. ~.5371 4,7539 4.1797 n, 6750 3. 6797 ~.8008 625 t.8711 3 , 6484 t 1, 4'562'5 10,6797 3,0879 3,5176 ! 20. 250o I Lr,, I) "l NP ~[ Sp DT qP~I ? b D ~HOB ~,l PI41 DT SP SP MP~I 24,5406 t12,87~0 2.4492 46,0938 2.53t2 '24,5781 '999,2500 '999.~500 '999,9500 t.5469 -,t7.]1~5 -099.2500 -099,2500 -099.2500 3,909..3 -22.68't5 :999.~500 999 ~,500 4 7781 -9 953 -999 2500 -Ogq 2500 -999 2500 4 7801 -8 9697 -o90 2500 ugo ~' ' -999 25~0 3.6172 -9~q,2500 -999,~500 -999,~500 3.3770 3, ?949 . a 99.25 n 0 P E D '," L~ - , "~ 5n0 ;;:' ~.aOnO r':R [ I R a T ~FtU TI,," eR ~'IRAT ~CNb ~T,U Y ~CUL T h ~ .'~ .. ~ :;' ,: ~.~7~ ~ 116,00~0 ! '.~02 ~,4395 3. ~0~9 ~11.7500 9 95 1. 2 !.02,6~75 -999,~500 -99g, ~500 -~99.~ 500 3,1309 86. :;625 :990, :~nU 999. 500 ], ' 152 :999 9500 3.7930 4. n 0 7 H 91.25n0 -ogq, 25n9 -090,95ni~ ,10. n :! 't 4 R ?.,~340 TL, D ?.n71 l ! 16. 0000 0.4531 3,~60~ T I.,~ 3.69~3 10.2344 3.4305 Ik.n 3.%059 ~ l ~ · 7500 0.7344 RH~)B 3,3008 ~PqI 2.9512 rI,n 3.0801 SP I OY .6975 -999.~500 ~!OB 3.1309 It,n 3.0 234 -~99,~500 NPHI ?.4902 !:LD 3.1152 -9gq. ~500 3 . 79 3 0 4.0078 ~P 9 ~ ~ 500 -999:~ 500 -g99. ~500 ~. 5qqA T -q99.2500 -999.2500 2.~()47 7 3370 -999:2500 -o9Q 2500 -9q9:2500 3 6563 -q99,2500 -999.~500 -q99,~500 3.~453 99.~500 ~99,2500 -99~,2500 -999 ~500 -38! 000 -Q99 ~500 -990.~500 -q99,2500 -999 ?500 -6t 21 a7 -099 ~500 -.099 ~,~00 -99g ~500 -o9g.2500 '45 OOnO ~ ,~oo 99,250o 21.9375 -Q9~,2500 -09 ,2500 -999. 2500 -q99.9500 -23.'~.~ CR -09g.?'' -g~~.?,~'''':~ 5100, -~99.95n0 -~99. 46. 9 0 , ~c~ · .... -a99. -999 , -099, -090. -090 -990 '999 '~9g, -ggg. t17, -099, .0 9 o * 7754, 2500 ~5~0 ~SO0 0238 1250 ~500 ~500 ?50O ~715 0820 5000 2500 2500 ~500 7441 8574 3750 2500 ~500 2500 6455 7207 ~500 0't4 ..035 O0 500 5OO T [_, i4 e'.t,I S F t, LI GR 5762 ~. 701.2 ~.. ~500 { ~50u 5 64, :> 591 3.7754 SP 13~,,.2500 -090.?500 -000.2500 ~'P~I 3.7383 14~."250 ?.'>715 T[.,~ ''>~>.qO00 OT 1.7441 II,,D 1.n574 ~P !6~,3750 OT -o99.2500 ~HnB '-~9q.2500 ~PgI 1.6455 ThO . DT .2500 R'~OB .~500 ~ 576 ox 125 0 -o99 ~500 -O~g ~T ~HOB MPHI 3.,56q85 3.591. 1 ~7.~(')00 0'I' -O 9, 500 PF:,OP, -099. 2500 -46.~1~7 099 500 -~99 500 '999,2500 '21.21e7 '999,2500 -999,95n0 -099.2500 -g99.9500 -2 9629 -~99 ~5o0 -099 2500 .099 2500 -999 2500 018457 -999 ~500 -999 '99~,~-500 "' ,7344 ,2500 .9.50o -o99,~500 =25, 187 :ogv.2$o:o .999,2500 999,~500 -999,~5n0 -32.*$000 -999,~500 -g99,2500 -qgg ]500 ,,,69 1~5 -099 ~500 EPT P R Clu L P,~T LO LD P C~L C ,~! L E/, P T P R R n t} EP T lSD P R ~R 500rt.:lO00 -090.. ?500 -°99. ~500 -~90,9500 -090. ~500 ~CHI., -ogq.?Sn(> -.t ~.). qS44 7.4 -999.2500 ,'7 ?.6992 " LI' 666C) ' 750O .: ',t. 1 .... " n(3," SFI,1Lt -g9©. 25n0 CALl -099.2500 RN~A .q~o. 75o0 3.~{ 9 13 TLD 9!,'"6:;5 DT -gg' , )5')0 DHOH ~ . ': ...: .., p I 02.75 ' ¢.. -~9o.75~ "~99.7500 7. ]0' 11,,t3 -099.9,5" r) -099.2500 -85.5000 -qgq.2500 -~99.2500 -99n.750C, -999.2500 99. 500 -999 9,500 -999,'25o0 -q99.2500 -53.8750 -099 2500 -999. 2500 -999 2500 -37 0000 -999 25OO -~99 2500 -999 2500 -099.2500 -9 .: .... O0 . .2500 -~99 ~500 -26 *99? ~500 -09q 2500 -099 2500 -999 25o0 -2~ 7188 ~50 -q9 0 -999 ~500 -99g 2500 -099. 9500 -10, A44. -999,~500 -999.2500 - ~ 7500 2.39 ? 6 T 'i., '~'~ 125,7500 ~P . 250 0 C A f., T :a99, ,, qgg. 2500 P~',~ -~9o . ?500 2,";520 TL~ -egg~soo CALl 3,Pli)5 94.!.250 ~.9171 ILO 3,0762 SP 1. 07. ! 250 DT -099,2500 ?HOB . c~ 9 o. ? 5 n 0 a~' P ,q I 3. ] 758 ILr~ 3. 3848 SP 09.6875 DT :9.qq,25nO 9.3:574 2,39~6 SIP 125.7:500 -~9~.~500 2 75~0 10. 0000 -~9~ 25O0 -o9~. 9...500 T LD DT ~,TPb!I -~9q.25~,0 '15 9'. ~ 1 '999 9.. nO -999 2t nO 999!250.O -11 054.7 999 ~500 :.~99,~.500 99.~500 -999.~500 -12.7813 9~. ~.500 -999.2500 -ggg,~500 -'~99.2500 -o99 ~.500 -tI99:2500 2500 0 -gg~ 2500 - 8437 -ggg -g99 500 -999 9,2500 999,~500 -999~500 -g9g, 2500 -16. 3750 -090: -~99,15~3(.! a 9 g - 99. .oar, ) , , - a 9 ':~. -099. 9500 9.2~'71 ~. 3 117.TbnO -99~). 25n0 -09q 2~nn , ~ .a023 ~. ~ 690 -qqq. 2500 -o9o.2500 5.6~{75 ~ 17~9 .' 83 ~7~0 -~9~ ~ 950,3 -99° o 1 7~7 99 ~875 -gg~' 2500 ,, , -090. ~50o -o9a. ~ 7I¢9 ' 5078 7~.5695 2.'. n . o 9 ':~, 07.1. 250 PT 4. r<5n6 TL, 9 4.773,~ 8P O6. 0000 DT ~7.75n0 BT -~94.2500 -~99.9500 NPHI 4.9023 ~,~680 99,56?5 -g99.2500 PHOB 5.6875 ILO 6.]7~g 83.~ 75O PT ~, 17 n 7 l 6,1602 9~,6~75 -qgg. 25'00 -o9q.~5~0 ~JPgi 10,4219 Ibm 10.~938 85,5000 c). 2500 -09g. ~500 4.71.09 5,507 ~ -o. 9o. ~500 ~.~P~I -g99 2500 -ggg ~5oo -g99,7500 -g9~.2500 -099'2500 -g99,2500 -'999.2500 ~20 32 t:t 1. - :ogg. 250o 999.2500 -17,8125 -499,2500 -999,2500 -o99,~500 -ggg.25nO -lg 6250 -ogg 2500 -q99 25oo -ggO 2500 .o ~500 -999 2500 -~99 2500 '99g,2500 '13,5391 -999,~500 -99a ~500 '999'" ' ,~500 -999 25n0 -q99 25n0 -999 2500 -g9o ?500 b~ RI-I L~ 3.~975 7~.5n25 EoT P R C~vl. 200n. OOCO TL~ -g9~.~500 6.6494 ILO 3.~875 SP 74.5625 DT -ngo.95no 7.3828 2~00.00o0 SP 47.6875 nT -~ga.259n -o9q.~5,~O -999 2500 -16i~750 -09~ ~500 -999.~500 -999 2500 -20 4375 -g99 ?500 -999 ~500 -~99 ?500 ATF :~,~I06/ 5 RiG~t~ :0000 APE ~R : ~2~I, OMMF'~S :T,,,I~R.~R¥ TAPE