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184-064
• • RECEIVED STATE OF ALASKA MAY 2 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANII ;C 1 a.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 1 • Suspended❑ 1 b.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.: 52016 184-064/316-082/ 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 5/17/1984 50-103-20028-00 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 597'FSL,53'FEL,Sec 14,T11N,R8E, UM 5/23/1984 KRU 2A-06 • Top of Productive Interval: 9. Ref Elevations: KB: 130 17. Field/Pool(s): 1354'FNL, 1259'FWL,Sec 23,T11N, R8E, UM GL:94 BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1392'FNL, 1132'FWL,Sec 23,T11N,R8E,UM surface ADL 25570 4 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 498341 y- 5960018 Zone- N 8205/6232 2668 TPI: x- 494374 y- 5958069 Zone- u 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 494247 y- 5958032 Zone- 14 None 1524/1500 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, ing cofi•ar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary n/a SCANNED SEP 2 9 2016 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH NAMOUNT D HOLE SIZE CEMENTING RECORD CASING GRADE FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 Surface 103 Surface 103 24 175 sx CSII 9.625 36 J-55 Surface 2854 Surface 2650 12.25 860 sx PF E,250sx PF C 7 26 J-55 Surface 8202 Surface 6229 8.5 475 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(MDITVD) Size and Number): 3.5 7925 7707/5732 Perforations Plugged � N�ti�� 7916/5962 '-‘;'4.14.4P-- - 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. C)ATE Was hydraulic fracturing used during completion? Yes❑ No 0 s/q/R0 _ Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LV 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(corr): Press. 24-Hour Rate •••► UTL e/3,1 - Form 10-4�0 Yig8/�1/2015 �� CONTINUED ON PAGE 2 RBDMS ""Y 2 6 211 mit ORIGINIAL only • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes LI No 2 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1524 1500 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek A 263-4131 Email: JilI.SimekAcop.com Printed Name: G.L.AlvordjTitle: Alaska Drilling Manager P) Signature: �`-(.,`._,U k, Phone: 265-6120 Date: / 51 2'- 1�/ ,-(6 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2A-06 Plug and Abandonment May 11, 2016 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2A-06, commencing operations on February 4, 2016 and completing the Plug and Abandonment on May 5, 2016. Operations involved excavating and removing the tree and wellhead 4 ft. below tundra level. Top of cement in the surface casing was determined to be at surface while conductor x surface casing annulus was extremely contaminated with ice and RG2401 (surface casing corrosion inhibitor). The conductor x surface casing annulus was cleaned of cement and ice before topping off with fresh 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, cement"top off', marker plate installed, and final site condition after backfill. The field Well Service Report is attached. a"`� �,., ., 414\ "/rzaY ,Nab gyp F \ t,,' .„.- ,*:*:' * ' : 4, xYE J.E 'I)' ��Ait £ . 2A-06 PTD 184-064 -,a"".,... �� "Copyright 2016 All rights reserved This „ photograph is provided to the AOGCC with permission to copy for its own use'. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska. Inc." • • "fir •�'J�r .. l . , 41ir t .4: AN*** f. „., = III *.a ' $ '"i �,it< !` 4.•, -.I <. ^`�' A tt .'. • • • • &� ,, . itte •A„ie ''‘,,,,e, , , . . ....... ,,:, ,.„.IN,54„.„et s% .•,.*.-4.•+,...,,. ..,. ., •. ...„..i..,.. ... ,..., 1.- . .. ,,,,, , ,,,,, ,, \ ,, . . •i ;‘,„,0* ' . "'•‘• ,, ,,, ,� 2A-06 PTD 184-064 ' f, "Copyright 2016 Al 'r'fghts reserved. This .. , . • , ,,,, photograph is p ided to the AOGCC with permission to for its own use. Copying f ;, "y •' ..lih ,.; �k� �' '�" „„Y•,, for any other purpose or by any other party is •. prohibited without the express consent of ' " `' ConocoPhillips Alaska,Inc." • .., ` 't ;,4,. r6, ".,..• >' r„ ^ , «; .; f;. , , :> . t..: .;, :i:,z ,,"v a' .3i;. *,' ita"Jae'=4;a r vot \r.ems ', '`,\ ?''i.' ,,.•\Y > w ,';;1 P` i.w. ` • ';,,. _ •>�;. E `� !,<�,37»rte, ..� .. •`''n�. ,,,„....„.,, ,,,, ,,,,,i::....„, ,,,,,,,:i„ , 4 t ",i• '4":`n ::.;• ^t:^;E. •'"\b 't s,:,, •\:ice.' . t4• * !.:A pr's •' d { -', _>. G. VI „, — . e., a ' t permission to copy for its : use. Copying for any of h., :� ?'vt,. „'i..-: 1 purpose or by any other p _ , .;; ' .a« , h is prohibited without the ;42 , :,,4 express consent of ` , ' :_t'k1,` , ConocoPhillips Alaska, Inc.” '. f • i!° Fifw ja ;;Oio'''-'-1' ''' '''7*',1t..,';- ..i ,a01411, .'t•,:':.•.:E-4,;:y;.:3S..,?rt.?Vii4"::N...:;,i'911, iiiirrAt'';',,:iii f';...,:',N,,:iZIO..0,.,.. - : .• . , • s .it l �' s ', .,•',.:,-, ,,r44,14,,,,-,• , ,.,:,,,•,; :zioppf,r,,,,,,,,,'...i.,,''... .4,11111.0,1r...,,••••••1fie,..7*,, -.•...?•.'...;,;4....i,:, '''., >\ ' 2 ti „ . . . c:,., „ . ,,.4„„,. 5:„„„„„„„„„„... .,.. .,.„„„„„„,„. .... ..„,.. .. .....,., .,......, ,.,,, ., ,,.,,... ,,,...,,,..,„,„onstskitz;::::„,.,„.",.:::Saillgrrl,='!',?vg,,.. liiir:r!!....,.....,:,,,,,,,' ' 'N. � 2A-06 PTO 184-064 • �1'g U, °Copyright 2016 AH rights reserved. This phot ph is provided to the AOGCC with gi f" •permission to copy for its own use. Copying / / ny other purpose or by any other party " " � ••••••,,,,..." 4 4 w . 1.0 ithout the express consent of . -. -.. ••,..-.....—* •....,..,,::‘,...........„,*so- lips Alaska. Inc." a ill � m et n..,.wq; :— - .. — „ " -- -. . ° • 2A-06 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. 3/3/2016 (MISC) :T/I/O=0/0/0. Cement is 62"from top of tree cap on tubing. No fluid present. Cement is 14" 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 2 Ft. of ice to clear work area to remove jewelry. Removed jewelry/valve handles and installed plugs. Final T/1/0/=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. Noticed that the BPV was still in place and notified operator. Well Suport installed tree cap to the top of the tubing hanger,to allow valve crew to hook up to the well to pull the BPV-valve crew pull BPV. Removed Well House from well and moved to the EOP. Final T/I/O =0/0/0 4/1/2016 P&A PREP-T/I/0=0/0/0 Excavation finished hole for shoring box. Assembled shoring box and put shoring box in, excavation then began working on egress for hole. Will have scaffolding out tomorrow to assemble scaffolding for welders to remove standing plate. 4/2/2016 P&A PREP Initial T/1/0=0/0/0 Flew stairs into place for egress and had scaffolding set up in shoring box. Final T/I/0=0/0/0 • • • 4/4/2016 P&A Initial T/I/0=0/0/0 Welder cut and removed standing plate from well.Shut down rest of P&A job due to deteriorating weather and wind gust around 40 MPH. Final T/I/0=0/0/0 4/13/2016 P&A PREP (POST PHASE) Cleared snow from around excavation and staircase. Removed stairs from excavation. 4/22/2016 P&A PREP Cleared snow from excavation Flew stairs into place for egress 4/24/2016 P&A PREP Initial T/I/0=0/0/0 Water-washed and removed all the snow within the shoring box from the 3 week phase weather period. Final T/I/0=0/0/0 4/25/2016 P&A Pumped 1 bbl of water from excavation. GBR welder(Josh Herald) cut window into conductor and chipped cement from the OC. 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 (52' RKB) Topped off remaining well casings with 2 gal of type 1 cement. 4/25/2016 Submitted notification to Witness top of cement and PA marker to AOGCC. 4/26/2016 Notified State inspectors to witness Steam clean out of the conductor • • 4/26/2016 P&A(IN PROGRESS) AOGCC State Inspector Jeff Jones wants the conductor annulus to be steamed clean of poor cement and ice before topping off with fresh cement. State inspection to be done post clean up and before cement top off. GBR welder will be available again on Thursday 4/28/2016 unless notified otherwise. Post cement job to be inspected by state inspector and also during the marker plate being welded on. .5BBL of excavation ground water was removed prior to work. 4/27/2016 P&A(IN PROGRESS) Vac'ed out 1.5 bbls of water from excavation. Upon arrival, cleared debris and water 3 ft from top of conductor. Waited on AOGCC inspector Lou Grimaldi to witness clean up and TOC measurement.Then used 100 psi, 325 degree F steam to heat and loosen debris and vac-hose to clear debris from conductor per state inspector request. Cleared 15 ft 9 in of debris from conductor(68' RKB)to top of sealant. With approval from the state,Victoria Leopp in town, cement will be allowed to be poured on top of RG2401 sealant. 4/27/2016 Notified State Inspectors opportunity to witness top off cement job on conductor • • 4/28/2016 Request sent to AOGCC:Victoria 4-27-16 Current status of 2A-06 P&A. Well head has been removed 4a below tundra level,which is about 15' below ground level. Cement inside the 9 5/8! surface casing is good and was tested with a 5' pry bar by State Inspector Jeff Jones. Cement in the 16 x 9 5/8a conductor annulus was extremely contaminated with ice and RG2401 (surface casing corrosion inhibitor). Jeff Jones requested that we steam the conductor annulus to as deep as possible and have the annulus re inspected. Lou Grimaldi witnessed the steaming operations. We steamed and vac'd the conductor annulus 17' below the conductor cut,the removing water and contaminated solids. We cleaned the casing down to a soft tag level of solid RG2401 sealant.A hard tag was not reached.There is at least 7' of sealant (based on the historic volume of sealant that had been pumped in the well and the soft tag). We were unable to vac out much of the sealant as it would immediately solidify when cooled and clog the vac hose screen. ConocoPhillips requests approval to continue the P&A by topping off the conductor annulus with -2 bbls of cement to bring cement level up to the top of the cut without removing any more of the RG2401 sealant. The remainder of the procedure would by followed as approved on the approved Sundry. Per our discussion please reply with approval. Reply: Approval is granted to continue with the P&A operations as outlined below. Please have our inspector inspect the TOC in the conductor annulus. Victoria Loepp 4/29/2016 Notified AOGCC for the opportuntiy to inspect the welded plate post weld. AOGCC waived inspection by Lou Grimaldi. However,we are required to call if the cement fall out over 12" and we have to send photos to Lou. 4/29/2016 P&A Initially vac'ed out .5 bbl from excavation. Schlumberger pumped and circulated 5 bbl of fresh water taking returns to a dirty vac-truck to clean conductor of any remaining debris per state inspector Lou Grimaldi request. Once the fresh water flush was complete Schlumberger pumped a total of 6 bbls of cement to top of conductor taking cement returns until getting good cement at surface (2 bbl of cement) 15.7 lbs,AS1 Cement. Projected to return Saturday 4-30-2016 to inspect cement and weld marker plate to conductor per approval. • • 4/30/2016 Sent photos to Lou Grimaldi documenting 8" fall back of cement top.After confirming that the cement set up he replied with approval to proceed with welding the plate. 4/30/2016 P&A Vac'd out 1.5 BBLS of excavation ground water. Checked amount of settling cement did overnight, less than 12". Filled in void with dry cement per state inspector request. GBR welder Mike Ayers welded marker plate on.Then removed sump, stairs and shoring box from excavation. All steps were documented with photos per state inspector request. (Lou Grimaldi) 5/3/2016 P&A R&P began backfilling excavation. 5/4/2016 Notified AOGCC for the opportuntiy to inspect the final backfill of 2A-06 PA. AGOCC inspector Robert Noble wavied KUP 2A-06 Con©coPhillips Well Attrib Max AngelD TD Alaska,itw(.. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btrn(ftKB) C )� 501032002800 KUPARUK RIVER UNIT INJ 5528 7,000.00 8,205.0 .. -.. .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2A-06,5/11/2016 1:5645 PM Last WO: 4/10/2009 40.79 5/25/1984 VerWal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 268.0 1/14/2006 Rev Reason:P&A pproven 5/3/2016 iii. ..° 111 lJ asmg rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 51.1 103.0 103.0 62.50 H-40 WELDED CONDUCTOR;51.1-103.6 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len 0...Grade Top Thread SURFACE 95/8 8.921 51.2 2,854.1 2,650.3 36.00 J-55 BTC .. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CMT RETAINER 195.0 PRODUCTION 7 6.276 249.0 8.200.9 6,228.1 26.00 J-55 BTC Tubing Strings ''' Tubing Description !String Mo...l ID(in !To ftKB /Set De th ft..J Set Depth TVD IWt(Ib/ft) I Grade I Top Connection 1 P( 1 P ( P ( )1... ( 1 . : TUBING Abandoned 31/2 2.992 2152 7,925.0 5,969.6 9.301J-55 EUE8rdABM `€ Completion Details '` Nominal ID 5 M Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) a 1,926.2 1,908.1 21.57 SAFETY VLV BAKER FVL SSSV 2.813 7,693.7 5,761.2 28.84 PBR BAKER PBR 3.000 SAFETY VLV;1,926.2 :R,,,. 7,707.4 5,773.2 28.41 PACKER BAKER FHL PACKER 3.000 �, 7,851.8 5,902.6 24.55 BLAST 2.992 IIII$1 RINGS A 7,882.8 5,930.9 23.84 BLAST RING 2.992 A 7,915.7 5,961.0 22.93 LOCATOR BAKER LOCATOR SUB w/2'SEALS IN PACKER 4.000 ` 7,916.5 5,961.7 22.90 PACKER BAKER FB-1 PACKER 4.000 ^w 7,923.0 5,967.8 22.68 NIPPLE CAMCO NO GO'D'NIPPLE 2.750 7,924.4 5,969.1 22.63 SOS BAKER SHEAR OUT SUB 3.000 SURFACE;51.2-2,854.1-� I I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;7,647.4 I Top(ftKB) (ftKB) (") Den Com Run Date ID(in) 195.0 195.0 0.54 CMT 9 5/8"CEMENT RETAINER 3/9/2011 RETAINER 1W. Perforations&Slots Shot Den PBR;7,69x7 Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) MB) (ftKB) Zone Date ft) Type Com PACKER;7,707.4 7,841.0 7,879.0 5,892.8 5,927.4 6/30/1984 12.0 (PERF 5.5"Csg Gun,120 deg M ph ■■ 7,910.0 7,918.0 5,955.8 5,963.2 6/30/1984 4.0 (PERF 4"Csg Gun,90 deg ph GAS LIFT;7,743.7 7,931.0 7,935.0 5,975.2 5,978.9 6/30/1984 4.0 IPERF 4"Csg Gun,90 deg ph q`� 7,936.0 7,956.0 5,979.8 5,998.3 6/30/1984 4.0 (PERF 4"Csg Gun,90 deg ph Cement Squeezes GAS LIFT;7,613.6 !:41 Top(TOD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 215.0 2,350.0 215.0 2,278.4 Cement Plug 3/8/2011 PUMPED 15.8ppg'G'balanced cement;set 9 5/8" cement retainer @ 195'.SQZ 12.5 bbls AS1 cement below retainer into subsidence void;15 bbls above retainer to surface. 2,350.0 3,865.0 2,278.4 3,298.9-Cement Plug 3/9/2011 PUMPED 15.8ppg'G'balanced cement;set 9 5/8" cement retainer @ 195'.SQZ 12.5 bbls AS1 cement (PERF;7,841.0.7,879.0-. below retainer into subsidence void;15 bbls above retainer to surface. I 36.0 249.0 36.0 249.0 Cement Plug 3/10/2011 PUMPED 15.8ppg'G'balanced cement;set 9 5/8" iii.. retainer @ 195'.SQZ 12.5 bbls AS1 cement I below retainer into subsidence void;15 bbls above retainer to surface. Mandrel Inserts st ab on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com (PERF;7610.0-7,918.0 1 7,647 4 5,721.0 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 6/29/1984 LOCATOR;7,915.711,11� 2 7.743.7 5,805.3 MMH FMHO 1 GAS LIFT DPHF BEK 0.000 0.0 2/27/2005 CV IL PACKER;7,916.5 _, 3 7,813.6 5,867.9 MMH FMHO 1 GAS LIFT DPHF BEK 0.000 0.0 2/27/2005 CV - Notes:General&Safety .0` End Date Annotation 1/14/2006 NOTE:TAG w/1.25"LIB @ 268'-POSSIBLE COLLAPSED TUBING I. 4/10/2009 NOTE:Old TBG came apart during workover,left downhole,temp PKR/Nipple set to secure well 12/9/2009 NOTE:See attachment for details of 2A-27 perfs into 2A-06,cementing 8 monitoring NIPPLE;7,92x.0 . 12/9/2009 NOTE:Downhole leak w/corkscrewed TBG in upper wellbore,2A-27 drilled to cement 2A-06 wellbore SOS;7,924.4li 3/5/2011 NOTE:View Schematic w/Alaska Schematic9.0 3/13/2011 NOTE:WELL P&A'd FOLLOWING COLLAPSED TUBING 4/30/2016 NOTE:WELLHEAD HAS BEEN REMOVED AND MARKER PLATE WELDED ON TO THE CASING @ 51.1' RKB. (PERF;7,931.0-7,935.0-. (PERF;7,936.0.7,956.0--. PRODUCTION,249.0-8,200.9 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggeK DATE: 5/8/16 P. I. Supervisor FROM: Bob Noble SUBJECT: Location Clearance Petroleum Inspector KRU 2A-06 Conoco Phillips Alaska PTD 184-064; Sundry 316-082 5/8/16: I was on KRU 2A-pad inspecting the surface abandonment on well 2A-07 with CPA representative Rodger Winter. I ask him if I could inspect the KRU 2A-06 location as they had recently completed its surface abandonment and backfilled the excavation. I found the KRU 2A-06 location to be in good condition with clean snow and ice adjacent to the well location. CPAI had a mound that was about 4 feet high, 20 feet by 30 feet over the cut off well. It looked to be good clean gravel. Attachments: Photos (2) SCANNED SEP 2 3 2016 2016-0508 Location KRU 2A-06 bn.docx Page 1 of 2 • • Location Clearance — KRU 2A-06 (PTD 1840640) Photos by AOGCC Inspector B. Noble 5/6/2016 ram- fi 2016-0508 Location KRU 2A-06 bn.docx Page 2 of 2 • • PTD /el - 0‘ 4 Loepp, Victoria T (DOA) From: Grimaldi, Louis R(DOA) Sent: Thursday, April 28, 2016 9:56 AM To: NSK Well Integrity Proj; Loepp, Victoria T(DOA) Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2A-06 (PTD 184-064, Sundry 316-082) P &A Follow Up Flag: Follow up Flag Status: Flagged Thank you M1. We will plan to attend. Is 08:00 when equipment shows up? Louis R. Grimaldi EQ MAY 0 92016, Petroleum Inspector Sati Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi(a7Alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Thursday, April 28, 2016 9:43 AM To: Loepp, Victoria T(DOA); Grimaldi, Louis R (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2A-06 (PTD 184-064, Sundry 316-082) P&A All, I am working on the procedure now and am planning a pre-flush before we pump cement. We will circulate bottoms up before cementing. The job is planned for 8 am tomorrow morning. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907)659-7043 MJ's Cell (907) 943-1687 1 • • From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,April 28, 2016 8:47 AM To:Grimaldi, Louis R (DOA)<lou.grimaldi@alaska.gov>; NSK Well Integrity Proj<N1878@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]RE: 2A-06 (PTD 184-064,Sundry 316-082) P&A That's what you and MJ were discussing yesterday and this procedure should be followed. From: Grimaldi, Louis R (DOA) Sent: Thursday, April 28, 2016 8:43 AM To: Loepp, Victoria T(DOA); NSK Well Integrity Proj Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2A-06 (PTD 184-064, Sundry 316-082) P &A Victoria/all, Will there be a pre-flush and the cement job performed from the bottom up? Thank you, Lou Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi(c�Alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: Loepp, Victoria T(DOA) Sent: Thursday, April 28, 2016 8:00 AM To: NSK Well Integrity Proj Cc: Grimaldi, Louis R(DOA) Subject: RE: 2A-06 (PTD 184-064, Sundry 316-082) P&A MJ, Approval is granted to continue with the P&A operations as outlined below. Please have our inspector inspect the TOC in the conductor annulus. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 2 • • Victoria.Loeppaa laska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Wednesday, April 27, 2016 3:46 PM To: Loepp, Victoria T(DOA) Cc: Grimaldi, Louis R(DOA); Simek, Jill; Senden, R. Tyler Subject: RE: 2A-06 (PTD 184-064, Sundry 316-082) P&A Victoria, Current status of 2A-06 P&A. Well head has been removed 4' below tundra level, which is about 16' below ground level. Cement inside the 9 5/8" surface casing is good and was tested with a 5' pry bar by State Inspector Jeff Jones. Cement in the 16 x 9 5/8" conductor annulus was extremely contaminated with ice and RG2401 (surface casing corrosion inhibitor). Jeff Jones requested that we steam the conductor annulus to as deep as possible and have the annulus re inspected. Lou Grimaldi witnessed the steaming operations. We steamed and vac'd the conductor annulus 17 below the conductor cut,the removing water and contaminated solids. We cleaned the casing down to a soft tag level of solid RG2401 sealant.A hard tag was not reached.There is at least 7' of sealant(based on the historic volume of sealant that had been pumped in the well and the soft tag). We were unable to vac out much of the sealant as it would immediately solidify when cooled and clog the vac hose screen. ConocoPhillips requests approval to continue the P&A by topping off the conductor annulus with—2 bbls of cement to bring cement level up to the top of the cut without removing any more of the RG2401 sealant. The remainder of the procedure would by followed as approved on the approved Sundry. Per our discussion please reply with approval. Let me know if you have any questions. M1 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,April 27, 2016 1:50 PM To: NSK Well Integrity Proj<N1878@conocophillips.com> Cc:Grimaldi, Louis R (DOA)<Iou.grimaldi@alaska.gov> Subject: [EXTERNAL]2A-06(PTD 184-064,Sundry 316-082) P&A 3 • MJ, Please send a description of the situation and proposal and I will respond with the approval we have discussed. Thanx, Victoria From: Grimaldi, Louis R(DOA) Sent: Wednesday, April 27, 2016 12:44 PM To: Loepp, Victoria T(DOA) Subject: 2A-06 316-083 184-064 Lou Grimaldi(on cell) Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) 4 Ili I ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 12/15/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ftal 2A-01 184-057 SF na SF na 1.5 12/14/2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na t 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.210" 9/24/2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 12/5/2007 2A-06 184-084 , 25'5" 1.5 20" 12/12/2007 8.5 12/14/2007 2A-08 185-248 _j SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.75 12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003 SF _ na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 ' SF _ na SF na 3.5 12/14/2007 2A-17 193-140 SF na _ SF na 15 12/5/2007 2A-18 195-059 NA – na 8' na 35 12/1412007 2A-21 193-133 5' 0.7 18" ' 9/24/2007 12/5/2007 2A-22 195-068 39" na 39" na 12/14/2007 2A-23 193-142 SF na SF na 12/5/2007 G�. 4 __r `- 4 — – 1110 • Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Wednesday, April 27, 2016 2:08 PM To: Grimaldi, Louis R(DOA) Cc: Loepp, Victoria T(DOA) Subject: RE: 2A-06 Attachments: SKM_C454e16042714111.pdf Follow Up Flag: Follow up Flag Status: Flagged That's interesting. CPAI reported to us the well was topped with 1.5bbl cement(initial TOC at 25 ft;final TOC at 20")and 8.5 gallons of blue goo in December 2007. See attached. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Grimaldi, Louis R (DOA) Sent: Wednesday, April 27, 2016 1:16 PM To: Regg, James B (DOA) Subject: RE: 2A-06 Yes blue goo. Approximately 30' below surface. 1.5 bbls. Lou Grimaldi(on cell) Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) Original message From: "Regg, James B (DOA)" Date:04/27/2016 12:54 (GMT-09:00) To: "Grimaldi, Louis R(DOA)" Subject: RE: 2A-06 1 • • 70 ft below surface? They put that much in the 16" by 9-5/8" annulus? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Grimaldi, Louis R(DOA) Sent: Wednesday, April 27, 2016 12:41 PM To: Regg, James B(DOA) Subject: RE: 2A-06 Ee are 27' from shoe and we are sitting on sealant.No evidence of hard cement.They say that it cant be cut with water Victoria is supposed to call me when she gets back to office. Lou Grimaldi(on cell) Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) Original message From: "Regg,James B (DOA)" Date:04/27/2016 12:36 (GMT-09:00) To: "Grimaldi, Louis R(DOA)" Subject: RE: 2A-06 How far were they able to clean out and did they find hard cement? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 2 • S From: Grimaldi, Louis R(DOA) Sent: Wednesday, April 27, 2016 12:35 PM To: Regg,James B (DOA) Subject: 2A-06 Having trouble getting sealant out of conductor to get good cement job. Have call in to Victoria but have not heard from her. Do you want to get involved. 184-064 Lou Grimaldi(on cell) Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) 3 III III vis ai _04.11 ti OF TFJ, ,,i)",\ %%s, THE STATE Alaska Oil and Gas ��.-s0��, Of Conservation Commission TAs KA 5-„1....-_,,,___ _ =-_,_:,... iiii-- t{_ iSTATE OF ALASKA • RECEIVED . ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 4 2016 APPLICATION FOR SUNDRY APPROVALSu, 20 AAC 25.280 I O C0 1.Type of Request: Abandon Plug Perforations . , Fracture Stimulate lµ Repair Well 1- Operations Shutdown r Suspend f Perforate n Other Stimulate -rt Pull Tubing r Change Approved Program E Plug for Redrill r Perforate New Pool n Re-enter Susp Well rAlter Casing E Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. 4 Exploratory EDevelopment(µ_.. 184-064 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service ' 50-103-20028-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes r No Er / KRU 2A-06 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25570 N Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,205' 6,232' 0 Cement to Surface none Casing Length Size MD TVD Burst Collapse Structural Conductor 67' 16" 103' 103' Surface 2,818' 9 5/8 2,854' 2,650' Intermediate Production 7,952' 7" 8,201' 6,228' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7841-7956 . 5893-5998 3.500" J-55 7,925' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL PACKER ' MD=7707 TVD=5773 PACKER-BAKER FB-1 PACKER ' MD=7917 TVD=5962 SAFETY VLV-BAKER FVL SSSV . MD=1926 TVD=1908 12.Attachments: Proposal Summary E Wellbore schematic j 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic r Development r Service P- 14.Estimated Date for 3/1/2016 15.Well Status after proposed work: Commencing Operations: OIL r WINJ E WDSPL E Suspended 16.Verbal Approval: Date: GAS E WAG E GSTOR E SPLUG E Commission Representative: GINJ " Op Shutdown E Abandoned F • 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.Simek(c�cop.com Printed Name Jill Simek @ 263-4131 Title Staff Well Integrity Engineer S.____ z(3fko Signature Phone 263-4131 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ma�yy'' •cost a Plug Integrity El BOP Test D Mechanical Integrity Test El Location Clearance Lp�'' Other: /�to dcc -t-i - f,' e Yl-vifv+l-• 5 v✓"FC Other: /1L U(z�C w i f.-�tss��//" w,e l cl fd �f� Post Initial Injection MIT Req'd? Yes EI No �7 I lP G Cc ti Spacing Exception Required? Yes ❑ No d Subsequent Form Required: j Q--q 0 7 . APPROVED BY Approved by: 267/99“....t41/41+-4- COMM SI ER H C MMISSION Date: -1t�- IppA i � Submit Form and Form 10-403 Reed 11/2015 �/� Z'y�`S roved application is li f 2 h ftrdrtv�t d to of approval. RBDM�tachL`s i�taugicafe� �O�C 1717.,701/6)14.4 CI3I U • 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-06(PTD#: 184-064). 2A-06 was drilled and completed in 1984 as a single selective producer. In February 1988,after almost four years of production,the well was converted to injection. In March 2007,the well was shut in due to tubing leaks and a resultant failed MIT-IA. In April 2009,a rig workover was attempted.Unfortunately,the tubing was parted at-250'KB and,after a failed attempt to mill past the damaged 7"casing,the well was suspended. Video images were taken of the casing showing severely damaged/folded over casing at—250' KB.The 2A-27 well was drilled to intersect the 2A-06 wellbore,and cement was pumped from 2A-27 into 2A-06 to abandon the bottom hole. In October of 2010,coiled tubing attempted to complete the suspend operations.CTU did not gain access to the 3-1/2"tubing,but they did mill past the damaged 7"casing gaining access to the 7"x 3-1/2"annulus. Pictures from a video camera clearly show the 3-1/2"tubing inside the 7"casing below the damaged/folded over section of casing. In March 2011,a rig was used to further suspend the well. Two 3.5"x 7"Class"G"balanced cement plugs were pumped from 2350'to 3865'KB and 250'to 2350'KB. The 7"production casing was pulled above 249'KB and a 9-5/8"cement retainer was set at 195'KB. ArcticSetl cement was squeezed below the retainer and spotted to surface above/An abandonment tree was installed with BPV,diesel above BPV, and tree flanges tested to 500 psi. 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 .COnocoP i ps 2A-06 P&A Permit to Drill #: 184-064 The objective of the proposed 2A-06 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 abandonment 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 and photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld 1/4" 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-06 PTD # 184-064 API # 50-103-20028-00 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 • 40 f Wellbore Schematic: 47" KUP INJ 2A-06 ConocoPhillips Well Attributes MaxIAngle&MD TD • ,Planta,Inc, Wellbore API'Owl Field lame we Inete SaSd net I'1 MD 114(0) Act atm 1500) 501032002800 KUPARUK RIVER UNR NJ 50 28 7,000 00 8203.0 ... Comment 0281PP0 Data Annotadlnn End Date Ke.Grd In) Ria Release Dais aaoe.ovtrote 9oaseAra Last WO: 4/102003 40.79 625/1904 vers.aracaemasc,acua., Annotation Depth 0100) End Date Annota9mt Last Mod ay End Daft Last Tag: 263.0 1/142006 Rev Reason:P&A Imosbor 3/10)2011 r+,vv�C. �a�,taa..aiipae `b i7 Casing Strings _ '"'Caving 00,uipuen CAD line ID lin, Top MB) Sei Depth 1nKB) Se Deem)0/0)-•V7t'ten II,.,Grade Top Thread CONDUCTOR 16 15.060 335.1 103-0 103.0 62.50 1140 WELDED •y•CT•A- .1-1.4.-4 A Cuig01atalpdon OD On) MOM Top 1(Ks) set Dean(000) Set Depth(7901...WtfLen 0.Grade Top Thread SURFACE 358 5.921 36.2 2,8541 1650.3 36.00 655 07C Casing 6,5011011, OD din) 01 Tm) Top/RW5) Set Depth(SKB) Set Doper(IVO)...Mien 0...Grade Top Thread 011011_01510.tool 1-. PRODUCTION 7 6.276 249,0 5,200.9 5228.1 26.00 3-55 0-FC Tubing Stags _ r, Tuning Oearrpvun Sv 1,p rag._iOpel itp 1065) Set Ikpm(n..Set Depth(TVDI t..WI II511 1 J5 1-5T Top C010eola v, TUBING Abandonzd 31.2 2.992 2)5.2 7,925.0 5,959.6 9.30 J-05 EUEBrdA3!r1 a. Completion Detail N. Nominal ID 4 Top IDKe) Top ITVDI;1101 Top Ind(4 Ikm Ds+ Com lin) .ti 1,926.2 1,908.1 21.57 SAFETY VLV BAKER FVLSSSV 2.813 ^^^� 7,693.7 5.7612 '28.84 P6R' BOXER PBR 3.000 510001vw:1.0212 .';/ * ' 7,7074 5,7732 2841 PACKER BAKER FR,PACKER 3000 7,851.8 5,902.6 2455 BLAST RINGS 2592 R - 7,882.0 5,930.9 23.84 BLAST RING 2.992 7,915.7 5,961.0 22.93 LOCATOR BAKER LOCATOR SUB yea SEALS IN PACKER 4.000 ^n tS 7,916.5 5,561.7 22.90 PACKER BAKER F13-1 PACKER 4.000 P. F 7,923.0 6,967,8 22.68 NIPPLE CAMCO ND GO 13'NIPPLE 2.750 v 7,924.4 6,969.1 2263 SOS BAKER SHEAR OUT SUB 3.000 suRFAce 05::5,. 41-. Si, ■ Other In Holekelke retrievable (VY plugs,valves,1^ pumps,fish,etc.) Top(TVD) Top M4 Coal ;t,e+i.a ._ 4 Tap(MD) 111X0: VI Des Run Date ID fin) 4 1910 195.0 0.5;CMT 95(8-CEMENT RETAINER n 3:9/2011 RETAINER - Perforations 8 Slots snot Dena PBP:7.0007 Top 10414 Epp Mtn tenotan 100 0110 50OD M MO) ddell Zone Date t) Type Com PADA..7,7..;: 7,841:0 7,879,0 6892.8 5,927 4 6730/1984 12.0 IPERF 5,5'Csg Gun,120 deg Ph 7,910.0 7,518.0 5,955.0 5,963293071454 4.0)PERF 4'630 Gun.90 deg ph 3.t5:uFT;T.I+eT 4 7.,931-0 7,535.0 5,9752 5,9780 6/3011954 4.0 IPERF 4.630 Gun,50 deg ph 7,936.0 7,9569 5:179.8 5,9983 6130!1984 4.0(PERF 4"Csg Gun.9D deg ph 'Gmmai squeezes 6.._.131.7,@;Sb 4 lop)1050 tot 179111 100004 amt tool inl01) 0 011 Das SbdtOale Com .2159 2,350.0� 215.0 2,2784 Ceelen Plug 3082311 PUMPED 15.Rppg'G'balanced cement;set 958- cement retainer@ 195'.SQZ 125 buts AS1 cement ' below retainer into subsidence void;15 bbls above retainer to surface. I 2,350.6 3665.0 2-278.4 3,298.9 Cement Plug 3192011 PUMPED)5.8ppg'G'balanced Tamen::set 9 538' I cement retainer@ 195'-SOT 12.5 bbls AS1 cement vERP;5,161141.7.06 0I below retainer into subsidence void;15 Ibis above I retainer to surface. 36.0 249.0 38.0 249.0 CementP)sp 3710520)1 PcUMPED150ppg'G'balaacedrernonLset95/0" mmoo r refiner @ 195'.SQZ 12.b bale ASl oamerd below rto retainerinto subsidence void;15 toils above ralainarb outface. Mandrel inserts se 1r, I N Tarp 0901 Valve Latch Pot Sae 1120 Run UP WAD) 1500) make Mudtl 011.0) Serf' Type Type Nd (psi) Run Data Com PERF;T.91pNPt81 I 1 7,647.4 5721,0 2,0011 FMHO 1 GASLIFT DMY BK-2 0-000 0.062911984 2 7,743.7 58053 G81H FMHO 1 GASLIFT DPHF 0EK 0.000 0.0 2,27/2005 •LOCATOR,T,ea5) __ CV 3 7.813.6 5,9967 9 NUM F'A11)0 1-GAS LIFT DPI-1F BEK 0.000 0.0 227/2005 PALItEfl:Tatdb 1=1 CV .- Notes:General&Safely Nl I 01,1 Dat Annmmlln 1114)2036 NOTE:TAG 411.25'LIB @260'-POSSIBLE COLLAPSED TUBING 4/190009 NOTE:Old TBG core aped during workover,k8 downhole,temp PKR/Nipple set to secure well 129280 NOTE.Sea attachment fur details of 2A-27 Peds into 2A-06,cementing&monitoring R;PPO£:r,92a6123972009 NOTE.Downitoie teak vecoihsrae ted TBG in upper wellbore,26-27 drilled to cement 2A-06 wellbore - 3E12051 NOTE:View Schematic wl Alaska Schematic9.0 so s.Tea1I 311312011 NOTE:WELL P8A'd FOLLOWING COLLAPSED TUBING POLE;701al4510-.+ 1PE4F:7.000.140e 5--. I PRODUCTION.NQ.p8,200.e JS • STATE OF ALASKA ALOIL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r RugPerforationsPull Tubing r Fracture Stimulate r Operations shutdown Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill rPerforate New Pool rRepair Well r Re-enter Susp Well r Other:Susp Well lnsp g—, 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory r 184-064 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20028-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025570 KRU 2A-06 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 8205 feet Plugs(measured) None true vertical 6232 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 7707 true vertical 0 feet (true vertical) 5773 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 103 103 1640 630 SURFACE 2818 9-5/8 2854 2650 3520 2020 PRODUCTION 7952 7 8201 6228 4980 4320 Perforation depth: Measured depth: 7841'-7956' 50440,0 NOV 1 22015 True Vertical Depth: 5893'-5998' RECEIVED AUG 12 2015 Tubing(size,grade,MD,and TVD) 3.5,J-55, 7923 MD, 5968 TVD AOGCC Packers&SSSV(type,MD,and TVD) PACKER=BAKER FHL @ 7707 MD and 5773 TVD SSSV= BAKER FVL @ 1926 MD and 1908 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 J 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 n1878(a�conocophillips.com Printed Name Martin� Wallters��� Title Well Integrity Supervisor Signature ,7(1A4779 `,_ (1A4 / 9 Phone:659-7043 Date:Aug 7, 2015 vri ei/7/45 RBDMS Al,!r 1 4 2015 Af//---- Form 10-404 Revised 5/2015 Submit Original Only • • ConocoPhillipsRECEI ED Alaska AUG 12 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCO 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-06 (PTD 184-064) 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-06 (PTD 184-064). 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, i 42 7i/de& 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-06 Field/Pool: KUPARUK RIVER Permit#(PTD): 184-064 Sundry 310-328 API Number: 50-103-20028-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 3/12/2011 Surface Location: 597' 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: 0/0 Wellhead Photos taken (#and description): 3 of wellhouse, wellhead, and cellar Work Required: Vac cellar Operator Rep (name and signature): Martin Walters At&----27 AOGCC Inspector: Johnnie Hill Other Observers: Will Lomer Inspection Date: 8/7/2015 AOGCC Notice Date: 8/3/2015 Time of arrival: 10:15 AM Time of Departure: 10:25 AM Site access method: Passenger Truck KUP . 2A-06 • ConocoPhillips amino Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Incl(') MD(ftKB) Act Btm(ftKB) Alaska,Inc. i�,,,„,,„III, 501032002800 KUPARUK RIVER UNIT INJ 55.28 7,000.00 8,205.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' Last WO: 4/10/2009 40.79 5/25/1984 Well Confq •2A-06,3/19/2011 3 21:(16 PM Schematic Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 268.0 1/14/2006 Rev Reason:P&A Imosbor 3/18/2011 , _ Casing Strings ii AI Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD). String Wt...String... String Top Thrd CONDUCTOR 16 15.060 36.1 103.0 103.0 62.50 H-40 WELDED CONDUCTOR, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 36-103 SURFACE 95/8 8.921 36.2 2,854.1 2,650.3 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CMT PRODUCTION 7 6.151 249.0 8,200.9 6,228.1 26.00 J-55 BTC RETAIN;RR 95 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING Abandoned 31/2 2.992 215.2 7,925.0 5,969.0 9.30 J-55 EUE8rdABM Completion Details Top Depth Cement Plug, (KD) Top Incl Nomi... 3s Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 1,926.2 1,908.0 21.57 SAFETY VLV BAKER FVL SSSV 2.813 7,693.7 5,761.2 28.80 PBR BAKER PBR 3.000 SAFETY VLV, 7,707.4 5,773.2 28.41 PACKER BAKER FHL PACKER 3.000 1.926 7,851.8 5,902.9 25.07 BLAST RINGS _-- _-- 2.992 11. 7,882.8 5,930.9 24.03 BLAST RING 2.992 lilt 7,915.7 5,960.3 20.14 LOCATOR BAKER LOCATOR SUB w/2'SEALS IN PACKER 4.000 Cement Plug, 7,916.5 5,961.0 20.14 PACKER BAKER FB-1 PACKER 4.000 215 7,923.0 5,967.2 20.14 NIPPLE CAMCO NO GO'D'NIPPLE 2.750 7,924.4 5,968.5 20.14 SOS BAKER SHEAR OUT SUB 3.000 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Incl SURFACE, A A Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 36-2.654 195.0 195.0 0.54 CMT 95/8"CEMENT RETAINER 3/9/2011 Cement Plug, RETAINER 2,350 GASIF LIFT, Perforations.&Slots Shot --�- 7'697 Top(ND) Btm(TVD) Dens Top(ftKB)Bim(ftKB) (ftKB) (ftKB) Zone Date (sh.. Type Comment 7,841.0 7,879.0 5,893.3 5,927.4 6/30/1984 12.0(PERF 5.5"Csg Gun,120 deg ph 7,910.0 7,918.0 5,955.0 5,962.5 6/30/1984 4.0(PERF 4"Csg Gun,90 deg ph PBR.7.694 { 7,931.0 7,935.0 5,974.7 5,978.4 6/30/1984 4.0(PERF 4"Csg Gun,90 deg ph J 7,936.0 7,956.0 5,979.4 5,998.1 6/30/1984 4.0(PERF 4"Csg Gun 90 deg ph PACKER,7,707 r... Notes:General&Safety End Date I Annotation GAS LIFT S 1/14/2006 NOTE:TAG w/1.25"LIB @ 268'-POSSIBLE COLLAPSED TUBING ,744 4/10/2009 NOTE:Old TBG came apart during workover,left downhole,temp PKR/Nipple set to secure well 12/9/2009 NOTE:Downhole leak w/corkscrewed TBG in upper wellbore,2A-27 drilled to cement 2A-06 wellbore GAS LIFT. . 12/9/2009 NOTE:See attachment for details of 2A-27 perfs into 2A-06,cementing 8 monitoring 7.814 3/5/2011 NOTE:View Schematic w/Alaska Schematic9.0 3/13/2011 NOTE:WELL P&A'd FOLLOWING COLLAPSED TUBING IPERF, [ 7,841-7,879 &[[ 7 f 1 V 7,91 4 ERF, IPE9F. LOCATOR. 7,916 -_ PACKER.7,916 NIPPLE,7,923tiE Er 50S.7,924 6., Mandrel Details Top Depth Top Port IPERF, (TVD) Incl 00 Valve Latch Size TRO Run 7.931-7.935 Stn Top(ftKB) (ftKB) Cl Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 7,647.4 5,721.3 30.14 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 6/29/1984 IPERF2 7,743.7 5,805.6 27.36 MMH FMHO 1 GAS LIFT DPHFCV BEK 0.000 0.0 2/27/2005 7.636-7,956_ 3 7,813.6 5,869,2,26.34 MMH FMHO 1 GAS LIFT DPHFCV BEK 0.000 0.0 2/27/2005 PRODUCTION. 249-8,201 * . TO,8,205 0.1 _ o p 0 Lu— Q Li j LLI CX W 0 O z O 2 OF oz p 2 VI Cr) mWow woo z W z I J 1,1,J Z O O O, ('l KW V ZO O D. O 00 N w a F F >p z F F ixW Q 2 *� fY w I C� 0 3 m rn Z o a U2 D 3 w 'i 0 J W z W W 00 CO w as 0 0 ( (n Z 1ZQ iw 0 . 4 ® 0 ►i )8( -Q-0 ® >< l-0 I >< c X , ..-:- -,09-------.09--.091- I Iy1\ \ �.. —,OOt= ♦ p .1-1 Wo Z � � Sao j M cc Ir N \� o z 0 cc)• ki I` d d J c+ a- CL o- vo W W n w O O C -;i r'r} 3 w w "' m H cn o v Q N") ` o t— w O N x 101, 001-G1 + > oo� ao o 1 nCO O wJ1," l O O Z ... c o N c , V' z 7 s �JNL N o W Nz � z ° rNI, . � rCr)- .41aZ Q C ,O vo W N V Va d A b Q. 0 oJ14 a /I- 11- j N a` m ---:, CO CO N 00 )o l G- � � O y - o 0 J NN N p' 7 51' W OD �./ cl 0 d CD w Z O r �Oz Lc 'S _ _ _� p 'U, a mla- ccJm Q } Q o k3 .' - O Z =- Z 0 o El (.V=re_ •.••• I a =a nc '� I a 0 I _1 w w p 0 x �a. N La O n 1 LJ a 1 o, O F c_, a F W U� j J Z Z j O O W Ce I O a O O O p ci 2 o o w m 0 i` N o cc N L N li 0j < El* - N 0 A.....N FCC Pi cn V> [ _ ,94 W � N .fiord -O t0 I r�N / W Z• Q. O O O ii I in b poCX • 2 CO CU CD �li Q,„ � 14 J O 41 Cf) �� F- F c Q Vl aZ } O O J t t pe-: �" d ��W W Z Q V) Z iii< d d 1011 koco Wil Q W W < W V Q Q 'O 'O 31 �, • a =� �, 0 E E I 174 LLI o= Q z z J/ cn 0' / LA G' I o w w� p v a `VVVA N J l J uZi z m o g ¢ 4 I-CI b z s 3w0 o Z o AO z I I I I I Z \\ 1 P. H uNa Nal :: o0, 1 • • %mss , Axa, ": 4.1 ,' - ' 7E / F 1 �a t 1 -,Y 16 $. � INIII " vvmau.Wmw aawti`.aw'rt.aygp�r-. G 7 1 1 I ) *: ,., 6 i ilk i4y.:.` .,' 3 2A-06 PTD 184-064 OConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska 0 • . 1 \ . I t 1 , , I t "' ,• ConocoPhillips Alaska .. . . ' I Well Name: 2A-06 API Number: 50-103-2002800-00 PTO: 184-064 1 . Sur. Location: 4683FNL, 53' FEL, Sec. 14, illN, R8E, UM „ - . , ,.. . ., ,. 1 i • v .,i 2A-06 PTD 184-06, ..„,. ..... ©ConocoPhillips A' ; !:,:'nc This photo is copyr'i: , ''''' by . ), .,..,. k ConocoPhillips Alask.,t.:- s- ansiltil "At' • 1 ' ' % cannot be released oi‘, blisht without express written conse- of ConocoPhillips Alaska .... .t. • 0 • ` 184-064 onocoPhil .r, . , k �. s photo is copyrighte � onocoPhillips Alaska, Inc. and cannot be released or publishe 4. without express written co ConocoPh•lli qua„ ,,, t s �ci M'ti ,fit. ._. ;+.: '=' E� a. c; - /....,:::-4 ;$.11,,- ''' * it ': lig te .`\ * % "6 ,2 1.1- =_=, ',„*14: ,7:/-:-*'7:-- _, '-' ' 4,41Aith. 1-:*,• '"4. 'i 11141114 hex ”' ., '" "-, i. i.:,. ,„ .,__ ...:-........-,:,„:„, ----- ,, ,, , t r .--- - ::::--,,,-1-- t'-,..„: a '^+,.,, "'^.++.Y R""'. -«.,, .7*---, � , � 1 A ,q �3 ' r w f f, rear "" 7 • 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-06 - Oper.Rep: Ian Ives PTD No.: 184-064 - Oper.Phone: 659-7043 - Location Verified? Yes - Oper. Email: If Verified,How? ier(specify in commei - Onshore/Offshore: Onshore Suspension Date: 12/10/09 - Date AOGCC Notified: 08/27/10 Sundry No.: 309-346 " Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 100 - Photos Taken? Yes IA 0 " OA 30 " AUG 1 4 2015 SCANNED Condition of _ Wellhead: Location verified with survey plat.All lines blinded with gauges.36"of H2O in cellar.OA valve partially submerged. Well has subsided about 2 ft into the ground.Wellhouse was removed for unknown reason. - Condition of Surrounding Surface The pad condition looked good. Location: Follow Up Actions I ask that CPA suck the cellar out. I recieved an email telling me that it was completed. Needed: Attachments: Photos(3) REVIEWED BY: Insp.Supry )� Comm PLB 08/2010 2010-0828_Suspend_KRU_2A-06_bn.xlsx • . 4, .\, ;,F�ryy . ►. .,TM ', a' - ^ 'ter• .'�•. -.4'64110'‘ fir_ .110414 -7.-" -�J� ;�� - .,,-•`: ,. - „. - ;: ':." I —.r'ir1 ted" a 1 AI% itaifilif tIlIII�, . . 111/1 11// , .lrll r ,� �// �11111 �� � , 111 11)ii�� ��.�killillill 1111 I�� : /! liHrrrlriii i! , q 111�,, IIII 11Hili ii„1 i�, iri .� � ;�, Il����1 II ►; 0,m, I 1I//Ill,, ��.et �rI iipil an 4.. 4 I lilt /I " a< 4 kb Ii 0 b kir1 aa In. k, L i 41. ,..„ I it tiif f; .. , c:T ll%kIlk . ,..) gilt Hi ���li .1 , it�ltj��tl / 1I , TS1:1 • 1,1111111*4, i„7 4t it i- 1 p I ii hi • / C/) a a 00 c� a. • It r i y , 11 ••;.t_ I . - ......==fir "T7' ., 11 wwwww:222,22.mwsaime ':L".....°::.:'"...:: .; IIIIIMMIIIMIIINIMingia , 1'104 WI to I l r h4� 4 OhIIIil _ e0.=sainn=` t r . • - ice, r •fine �; ,4 .00,40,.s1m144 4tk4%,4,, kkot 11 .,n tikEtleitgo ' ,i' ' A , '411.'..4, •. . .,r, r !MT .1 -- , -. . lib , ',..!. // / , ,. 4,„1, 4 t-• . f t / CO g. . ..IfGI� r Q IP'474 '!"'•• .• • i• ��'vy IY, �l SIN ,4 J 44'Ø + Il o bA • 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-06 - Oper. Rep: Martin Walters PTD No.: 1840640 • Oper. Phone: 659-7043 Location Verified? Yes Oper.Email: n1878@conocophillips.com_ If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 03/12/11 Date AOGCC Notified: 08/03/15 Sundry No.: 310-328 Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: good Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: well celler needs vac'd out Comments: well was verified by pad well location map Attachments: Photos(2) SCANNED SEP 0 7 2016 REVIEWED BY: Insp.Supry Comm PLB 06/2014 2015-0808_Suspend_KRU_2A-06jh.xlsx • • r Suspended Well Inspection—KRU 2A-06 PTD 1840640 Photos by AOGCC Inspector J. Hill 8/8/2015 ConocoPhillips Well Name. 2A-06 API Number 50-103-2002800-00 PTO: 184-064 Sur.location:4683 FNL 53Fta, Sec.14 T1114,881 UM 6 , :11 u ;. NAIRIr ` ., . . t , 1 r 41 r, ....04116.4 . 41""k ' 461,,,A. ' .'.* '‘ Plildd ''.A -4 i a ,_ 1 , ,. !or , i , .s '.r fl:14Ifl l��fy, i, .fes ^+ „,,, ° ,�ie, l{ / 7``l, E11 40 .. "�4�. . 'i0 ,,�, r ti `, ii1�1 iii#07P-, ;. . 4 MR 1 2015-0808_Suspend_KRU_2A-06 photos jh.docx Page 1 of 1 ect Well History File C( ge XH VZE 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. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [3 Diskettes, ,No. D Maps: [] Grayscale items: [3 Other. No/Type D Other items scannable by large scanner [] Poor Quality Originals: .,~ OVERSIZED (Non-Scannable) [3 Other: , ~,'D : Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHER~YI~ LOWELl. DATE:~_~ /si Scanning Preparation x 30 = + = TOTAL PAGES _ BY: Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES '~ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND:~., ', / ~/ ~,"~'~" NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIOUAL PAGE ~$1S ~'~--~' ~: '~ ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/06/11 Inspector: Lou Grimaldi Operator: Conoco Phillips Alaska Inc. Well Name: KRU 2A -06 Oper. Rep: Martin Walters PTD No.: 184 -064 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: N1787 @Conocophillips.com If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 01/15/11 Date AOGCC Notified: 09/05/11 Sundry No.: Well Ciompletion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? yes Well Pressures (psi): Tubing None - Photos Taken? yes IA 9 OA 9 Condition of Wellhead: Sunken inside wellhouse, Weathered (OK), valves cycled and OK, Gauges OK, no oil in cellar. Condition of Surrounding Surface Established pad in good shape. Location: Follow Up Actions None Needed: Location verified by pad map. Sta MAR 7 201 Attachments: Photos (2) REVIEWED BY: Insp. Supry J co 3' /' 1 2s Comm PLB 09/2010 2011 -0906 Suspend_KRU_2A -06_Ig Suspended Well Inspection — KRU 2A -06 PTD 1840640 Photos by AOGCC Inspector L. Grimaldi 9/6/2011 iii . , , 1 0„, ., 1 \\,,.\ , tottta'." , ' q , , . S FV CLY I . 4 k � b fS ; = n m. .u._ I s WA x ut3sint Nt:E .. I , altiI4 -"Iii • tIAZ►Ut r • • • • ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE, ALASKA 99510 -0360 SEP 1 4 2Gii September 10, 2011 Alaska Oil & Gas Cons. CorrrnisS• ion Anchorage 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 `s SFP 2 8 Z011 Kuparuk River Unit 2A -06 (PTD 184 -064) 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 -06 (PTD 184 -064). 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, (d / (.d az? Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate r Other p' Suspended Well Inspection Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r i Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 184 - 064 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50 - 103 - 20028 - 00" 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025570 - ..2A -06 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8205 feet Plugs (measured) None true vertical 6232 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7707, 7916 true vertical 0 feet (true vertucal) 5773, 5962 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 103 103 SURFACE 2818 9 -5/8 2854 2650 PRODUCTION 7952 7 8201 6228 4 tREC I E NED . frforation depth: Measured depth: 7841 -7879, 7910 -7918, 7931 -7935, 7936 -7956 to Siggi True Vertical Depth: 5893 -5927, 5955 -5963, 5975 -5978, 5979 -5998 & Gey C4�s' Ott6 01 p 131 Tubing (size, grade, MD, and ND) 3.5, J -55, 7925 MD, 5969 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER FHL PACKER @ 7707 MD and 5773 ND PACKER - BAKER FB -1 PACKER @ 7916 MD and 5962 ND BAKER FVL SSSV @ 1962 MD and 1908 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service = [r! Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL . Daily Report of Well Operations X GSTOR WIND r WAG r GINJ (r SUSP r; SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A )tact MJ Loveland /Martin Walters r Hinted Name Martin Walters Title: Well Integrity Project Supervisor //��?1G2 lt Signature "V Phone: 907 - 659 -7043 Date: 09 -10 -11 RSDMS SEP 14 2011 I A '•L• 4 Form 10 -404 Revised 10/2010 Submit Original Only • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Nell Name: Kuparuk River Unit 2A -06 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 184 -064 Sundry 310 -328 API Number: 50103200280000 Operator: ConocoPhillips Date Suspended: 3/12/2011 Surface Location: Section: 597' 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 Location cleanup needed: No Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Dry 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: Subsided. No tubing in well. Cycled IA need valve and OA valve Cellar description, condition, fluids: 28" of water in wooden cellar. No sheen Rat Hole: No Wellhouse or protective barriers: Wellhouse. Good Well identification sign: Stencil on wellhead and wellhouse Tubing Pressure (or casing if no tubing): N/A Annulus pressures: IA = 9 psi, OA = 9 psi Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: None //� Operator Rep (name and signature): Martin Walters fi L 4)41,i& AOGCC Inspector: Lou Grimaldi Other vers: Carney / Mouser Inspection Date: 9/6/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: Time of Departure: Site access method: Highway Vehicle ID III • 2A -06 , Mining Conoco Phillips fillips " & W l Well Attributes Max Angle & MD TD Al .k;i hU; Wellbore API /UWI Field Name Well Status Intl C) MD (ftK8) Act Btm (ftKB) 501032002800 KUPARUK RIVER UNIT INJ 55.28 7,000.00 8,205.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' Last WO: 4/10/2009 40.79 5/25/1984 Well Conng: - 24-88, 31192011 32106 PM - - Schemata - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 268.0 1/14/2006 Rev Reason: P &A Imosbor 3/18/2011 ,"" Casing Strings la. % Casing Description String 0... String ID ... Top (8K8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd "' CONDUCTOR 16 15.060 36.1 103.0 103.0 62.50 H WELDED CONDUCTOR, Casing Description String 0... String ID ... Top (MKS) Set Depth (f... Set Depth (TVD) ... String Wt,.. String ... String Top Thrd 36 SURFACE 9 5/8 8.921 36.2 2,854.1 2,650.3 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CMT 7 6.151 249.0 8,200.9 6,228.1 26.00 J -55 BTC RETAINER. _. Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Abandoned 3 1/2 2.992 215.2 7,925.0 5,969.0 9.30 J -55 EUE8rdABM Completion Details Top Depth Cement Plug, (TVD) Top Inc' Nomi... 36 Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 1,926.2 1,908.0 21.57 SAFETY VLV BAKER FVL SSSV 2.813 7,693.7 5,761.2 28.80 PBR BAKER PBR 3.000 SAFETY VLV, 7,707.4 5,773.2 28.41 PACKER BAKER FHL PACKER 1000 1,926 7,851.8 5,9029 25.07 BLAST RINGS 2.992 I 7,882.8 5,930.9 24.03 BLAST RING 2.992 !`. 7,915.7 5,960.3 20.14 LOCATOR BAKER LOCATOR SUB w /2' SEALS IN PACKER 4.000 Cement Plug, 7,916.5 5,961.0 20.14 PACKER BAKER FB-1 PACKER 4.000 215 7,923.0 5,967.2 20.14 NIPPLE ' CAMCO NO GO 'D' NIPPLE 2.750 7,924.4 5,968.5 20.14 SOS BAKER SHEAR OUT SUB 3.000 Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! SURFACE, • I • Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 36 - 2854 195.0 195.0 0.54 CMT 9 5/8" CEMENT RETAINER 3/9/2011 Cement Plug, RETAINER 2,350 , Perforations & Slots GAS LIFT, Shot 7647 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (810) Zone Date (sit Type Comment - • 7,841.0 7,879.0 5,893.3 5,927.4 6/30/1984 12.0 IPERF 5.5" Csg Gun, 120 deg ph 1. _ 7,910.0 7,918.0 5,955.0 5,962.5 6/30/1984 4.0 IPERF 4" Csg Gun, 90 deg ph PBR, 7,694 7,931.0 7,935.0 5,974.7 5,978.4 6/30/1984 4.0 IPERF 4" Csg Gun, 90 deg ph 7,936.0 7,956.0 5,979.4 5,998.1 6/30/1984 4.0 IPERF 4" Csg Gun, 90 deg ph PACKER. 7.707 I 0 J 1 Notes: General & Safety End Date Annotation GAS LIFT, 1/14/2006 NOTE: TAG w/1.25" LIB @ 268' - POSSIBLE COLLAPSED TUBING 44 4/10/2009 NOTE: Old TBG came apart during workover, left downhole, temp PKR/Nipple set to secure well 12/9/2009 NOTE: Downhole leak w /corkscrewed TBG in upperwellbore, 2A -27 drilled to cement 2A-06 wellbore GAS LIFT. 12/9/2009 - NOTE: See attachment for details of 2A -27 perfs into 2A -06, cementing & monitoring 7,814 + 3/5/2011 NOTE: View Schematic w/ Alaska Schematic9.0 8 11 0 3/13/2011 NOTE: WELL P &A'd FOLLOWING COLLAPSED TUBING IPERF, 7.841-7,879 PERF, H 7,910 -7,918 LOCATOR, 1- `- 916 = 1 PACKER,7,916 J - NIPPLE, 7,923 lel �. SOS, 7,924 9 Mandrel Details Top Depth Top Port IPERF, (TVD) Intl OD Valve Latch Size TRO Run 7,931 -7,935 Stn Top MKS) (RIMS) (1 Make Model ON Sery Type Type ON (psi) Run Date Com... 1 7,647.4 5,721.3 30.14 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0'6/29/1984 2 7,743.7 5,805.6 27,36 MMH FMHO 1 GAS LIFT DPHFCV BEK 0.000 0.0 2/27/2005 7,938 - 7,958 3 7,813.6 5,869.2 26.34 MMH FMHO 1 GAS LIFT DPHFCV - BEK 0.000 0.0 2/27/2005 PRODUCTION. 249-8,201 T0, 8,205 • __, - �/A TI ON THIS DRILL SITE IS NM CONSIDERED TO BE ^ / „ f PIPELINE uc +), AN H AREA RN POWER LINES \ \ \ \ \ \ \ \ \ \ \ \\ � \ \ \ \ _VAC ' •'... . \ \ \ \ \ \ \ \ \ \ � , r, — TO 1 � XFRMR I I TO J DS2T SPINE . ROAD � i I . I - fi0' } - 60' I - 60' - 275' 235' 2 0', f2- 0�m,- I- 60,- I - - { • © ® © 0 GUARD I j! 13 14 15 16 CTRL _ AIL LINE 22' 1 w 2 £ 3 • I 4 !► 0 0/ ROOM FIEATER 1 I— MOVED RESERVE PIT (PILING ONLY) RESERVE PIT p C RESERVE PIT 1 : _ re PIG Pl ,IIII RESERVE PIT � 12 11 17 1 D 2 PROD METH 24 : 25 5 ' X00 a MOD TAN{t ® r . - GUARD RAILS 50'- 150' -6m' ----6V- - 1 --- 20 , 200' 75' - -75'— 160' 20 1 1 2m ` I m, I i -60' 33V 1 50' Zo . am Zm . zo �3m' A /zza LEGEND FEATURE LOCATIONS . EXISTING PRODUCER LEGEND EXISTING INJECTOR 0 Or - CLEAN SNOW DUMP AREA, ALL EQUIPMENT. Or FROM • ® RESCUE EQUIPMENT PRODUCER TO INJECTOR - ENVIRONMENTAL AREA -NO SNOW DUMPING. ����� * SCBA LOCATIONS NOTE S ABANDONED CONDUCTOR V 1 DESIGNATED SAFE AREA (PRIMARY) j ( EXISTING CONDUCTOR im - POWERLINE -WATCH CLEARANCE.. °1, KODIAK BLOWERS MAY HIT LINES WITH DISCHARGE. 1 1 DESIGNATED SAFE AREA (SECONDARY) NO SNOW IS TO BE PLACED IN ® PARTIAL TREE f Y J, - KODIAK BLOWERS MAY DISCHARGE OVER ' EVACUATION ROUTES DEPENDING ON WIND ANY RESERVE PIT OR LINED PIT. PIPELINES. 1 I•:•:•:•:•:1 - NO SNOW DUMPING AREA. WINDSOCK = BARRICADE /ESCAPE ROUTE gai AREA: 2A A A M � O + DULLE :XXX / p�ci h� NSION UNIT: D2 LOUNSBURY, INC m; P � FIRE EXTINGUISHER APPROVAL: DS2A FACILITY EXPANSION 3 5/30/01 Line Htr Removed,Updote Title Blk Rev Per K01039ACS ROL MRT DATE: 10/19/96 CADD FILE: LK62011 3 FEATURE LOCATION 2 10/29/97 Rev Per K96030ACS DCS AJR DRAWING NO. r !I�� �/ ZZ SHEET: REV: RN. DATE REVISIONS BY r .,,,, JOB ENS CEA-U2AA -3313 001 . • • 2A ®06 (PTD# 184 ®064) © ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and 4 lip cannot be released or published x without express written consent of ConocoPhillips Alaska m � iiii Ce...6., f ! n w "�' , fff _ �: 6 b: Y .' ` a c F .4 7 sr Y4 .+s ..a1... .•.MWe rwty M 44 .yam .ia+IMr *� aw : Nom err �z a �' ffi11'' ''''''',0'..7r `" a 3 x 0• A ' , - s �' �' •' � ' `' , , af t '_ " . y ' , '�°` � „*4 '` d ”, k "f "' +�`s . Y „4t,...*: 0 • * an ' . ,. .. ' ... #1 .. . ..,„ 'k. m !ca ► '.r �lir .� � ' . -' • 0 2A -06 (PTD# 184 -064) :i'°° w a q . © ConocoPhillips Alaska, Inc. ...,m ek , This photo is copyrighted by ,,. ConocoPhillips Alaska, Inc. and cannot be released or f * 4 • published without express written consent of = � i t ConocoPhillips Alaska < b a ;*E # 4 x , , r � i". � x ,.: �, • —,, 4 *may 1 yy ,i • *$. r _AN x i Pr 4 • yam ^6 3 , } sk M lir .fi 1(` 1 40 400 01 M } J • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 ` 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service 0 • Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 12, 2011 • 184 - 064 / 310 - 328 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 17, 1984 50 103 - 20028 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 597' FSL, 53' FEL, Sec. 14, T11N, R8E, UM May 23, 1984 2A - 06 • Top of Productive Horizon: 8. KB (ft above MSL): 130' RKB 15. Field /Pool(s): 1354' FNL, 1259' FWL, Sec. 23, T11N, R8E UM GL (ft above MSL): 94' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1392' FNL, 1132' FWL, Sec. 23, T11N, R8E, 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 - 5960018 Zone 4 • 8205' MD / 6232' TVD • ADL 25570 • TPI: x - 494374 y - 5958069 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 494247 y - 5958032 Zone 4 SSSV @ 1926' MD / 1908' 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) 1524' MD / 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 RCBL not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 103' Surf. 103' 24" 175 sx CSII 9.625" 36# J -55 Surf. 2854' Surf. 2650' 12.25" 860 sx PF E, 250 sx PF C 7" 26# J -55 Surf. 8202' Surf. 6229' 8.5" 475 sx Class G, 250 sx PF C 24. Open to production or injection? Yes ❑ No Ell 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) all perfs plugged 3.5" 215' - 7925' 7704' MD / 5773' TVD 7841' -7879' MD 5893' -5927' TVD 7917' MD / 5961' TVD 7910' - 7918' MD 5955' - 5963' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7931' - 7935' MD 5975' - 5978' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7936' -7956' MD 5979' -5998' TVD 2312' -3865' 48 bbls 15.8 ppg Class G / 223' -2275' 70 bbls 15.7 ppg AS I 195' -223' 12.5 bbls 15.7 ppg AS 1 / surface - 195' 15.5 bbls 15.7 ppg AS 1 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 (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ig • Sidewall Cores Acquired? Yes ❑ No Q . 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. *MAW JUN 5, 4 201"i RECEIVED NONE t . - `y 6 '101 RBDIIAS APR 2 6 2011 4(67 S$tOP Aiss s 0ii &f s: Cont Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE ( Submit ori o nly � ..Z ' • , f ,0\ 3 ,e tt s-.5., „e„--nA 28. GEOLOGIC MARKERS (List all formations and markers etered): 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 1524' 1500' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 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 Na % , C : e Title: Alaska Wells Manager J Signature f4 6 �.� u c fd f P hone 265 -6306 Date /ZS // LC4W 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 la: Classification of Service wells: Gas injection, water injection, Water - Altemating -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 . KU AS __f 2A -06 N.-- ConocoPhIIItp5 a Well Attributes Max Angle & MD TD tl4s ,. / /2 ? I�`.'.` W Ilbore APUUWI Field Name Well Status Inc! (3 MD (ftKB) Act Btm (ftKB) ray+Ors4p -..' 501032002800 I KUPARUK RIVER UNIT I INJ 55.28 7,000.00 8,205.0 Comment H2S (pp m) Date LAnnotation End Date KB-Grd (ft) Rig Release Date .. • well c f g 2A 06, 3!1 /12011 3 21:06 aN i - ■ _ Last WO: 4/10/2009 4079 5/25/1984 Schermafic Aclual _'Annotation Depth (ftKB) End Dar Annotation Last Mod... End Date Last Tag: 268.0 1 1/14/200 jRev Reason' P&A _ Imosbor 1 3/18/2011 q r r, t .,:;..1. K P. Casin Stnn • s gk 4 p C sing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) .. String Wt... String ... String Top Thrd y'.. . ' " CONDUCTOR 16 15.060 36 1 103.0 103.0 62.50 H WELDED CONDUCTOR `�. Cuing Description String O.. String ID Top (ftKB) Set Depth (f . Set Depth (TVD) ... String Wt... String ... String Top Thrd 6 103 "' SURFACE 9 5/8 8.921 36 2 2,854 1 2,6503 36.00 J - 55 BTC Cuing Deuliption String 0... String ID Top (ftKB) Set Depth (f.. Set Depth (TVD)... Siring Wt... String String Top Thrd CMT PRODUCTION 7 6.151 249.0 8,200.9 6,228.1 26 00 J BTC RETAINER. Tubing Strings a A " Tubing Description (String 0. String ID ... Top (ftKB) Set Depth (5... Set Depth (1 VD) .. Stung Wt... String ... String Top Thrd - x TUBING Abandoned I 3 1/2 2.992 215.2 7,925.0 5,969.0 9.30 J -55 EUE8rdABM ' 'Completion Details F Top Depth Cement Plug, (TVD) Top In Nomi... 38 k Top {ftKB) OFIKB) (°) Item Descripgon _.- Comment ID (in) q:, 1,926.2 1,908.0 21.57 SAFETYVLV BAKER FVLSSSV 2.813 7,693.7 5,761.2 28.80 PBR BAKER PBR 3.000 r SAFETY 7,707.4 5,773.2 28.41 PACKER BAKER FHL PACKER 3.000 1,926 1,926 , - "` 7,851.8 5,902.9 25.07 BLAST RINGS 2.992 M1. 7,882.8 5,930.9 24.03 BLAST RING 2.992 a;, 4 7,915.7 5,960.3 20.14 LOCATOR BAKER LOCATOR SUB w/2' SEALS IN PACKER 4.000 7 5,961.0 20.14 Cement Plug, t . PACKER BAKER FB -1 PACKER 4.000 215 7,923.0 5,967.2 20.14 NIPPLE CAMCO NO GO 'D' NIPPLE 2.750 (II Ir �� 7,924.4 5,968.5 20.14 SOS BAKER SHEAR OUT SUB 3.000 i q is Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth i ' ;?1 (TVD) Top Inc! SURFACE, t 3 ; Top (ftKB) (ftKB) (3 Description Comment Run Date ID (in) 36 -2,854 + s 195.0 195.0 0.54 CMT 95/8" CEMENT RETAINER 3/9 /2011 Cement Pug, `7/ RETAINER 2,350 GAS LIFT, • Perforations. &Slots - _vu 7,847 y-.. Shot ='' Top (TVD) Btm (ND) Dens Top MKS) Ban (ftKB) (ftKB) (ftKB) _ Zone Date (sh -. Type Comment 7,841.0 7,879.0 5,893.3 5,927.4 6/30/1984 12.0 IPERF 5.5" Csg Gun, 120 deg ph 7,910.0 7,918.0 5,955.0 5,962.5 6/30/1984 4.0 IPERF 4" Csg Gun, 90 deg ph PBR, 7s9a - -- 7,931.0 7,935 0 5 974.7 5,978A 6/30/1984 4.0 IPERF 4" Csg Gun, 90 deg ph 7.936.0 7,956 0. 5,979 4 5998.1 6/30/1984 4 0 IPERF 4" Csg Gun, 90 deg ph PACKER, 7,707 i___ .. __. Notes: General & Safety End Date Annotation 1/14/2006 NOTE' TAG w /1.25" LIB @ 268' - POSSIBLE COLLAPSED TUBING 7,744 4/10/2009 NOTE: Old TBG came apart during workover, left downhole, temp PKR/Nipple set to secure well III 12/9/2009 NOTE: Downhole leak w /corkscrewed TBG in upperwellbore, 2A -27 drilled to cement 2A -06 wellbore GAS LIFT, - 12/92009 NOTE: See for details of 2A -27 perfs into 2A-06, cementing & monitoring 7,814 ee attachment 3/5/2011 NOTE: View Schematic w/ Alaska Schematic9.0 3!132011 NOTE: WELL P&A'd FOLLOWING COLLAPSED TUBING IPERF, 7,847,879 1 I 1 i IRF. _ I: 7,91 -7,918 " LOOA '9t6 ' �.. PACKER, 7,916 - $ ` NIPPLE, 7,923 SOS, 7,924 ,Mandrel Details Top Depth Top Pod IPERF (TVDI Intl OD Valve Latch Size TRO Run 7,931 -7,935 . Stn Top (ftKB) (MKB) ( ") Make Model (in) Sery Type Type (in) (Pal) Run Date Com... 1 7,647.4 5,721.3 30.14 MMH FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 629/1984 2 7,743.7 5,805.6 27.36 MMH FMHO 1 GAS LIFT DPHFCV BEK 0.000 0.0 2/27/2005 7.93 -7658 3 7,813.6 5,869.2 26.34 MMH FMHO 1 GAS LIFT DPHFCV BEK 0.000 0.0 2/27/2005 1 1 PRODUCTION, ?A9 -6,201 TD, 8.205 2A -06 Well Work Summary DATE SUMMARY 7/20/10 (PRE RWO) T POT - PASSED; T PigT- FAILED; IC POT- PASSED; IC PPPOOASSED 1 MIT OA TO 1000 PSI (FAILED) 0 O ( ) 10/14/10 MADE WASH RAN AND BASELINE VIDEO RUN TO 235 CTMD, RAN 2.72 BAKER ROUND NOSE MILL TO 235 CTMD, MILLED 7 INCHES WITH 300 PSI MOTOR WORK, RAN VIDEO LOG, GOOD IMAGE QUALITY, WILL DISCUSS PLAN FORWARD, RTN IN A.M. 10/15/10 RAN 2.67 FLAT BOTTOM BAKER MILL TO 237 CTMD, APPROX 6 INCHES DEEPER THEN PREVIOUS RUN, LOST 500 PSI CIRC PRESSURE, POOH, JAR IS SNAPPED AT END OF PISTON, RTN IN A.M. TO FISH MOTOR. 10/16/10 FISHED 11.82 FT MOTOR /MILL ASSEMBLY FROM 225 CTMD, RAN VIDEO LOG TO 235 CTMD, WILL SEND TO TOWN FOR REVIEW, RDMO. 10/19/10 PERFORM MILLING WORK ON 7" BUCKLED CASING TO 238.4 CTMD,MILLED APPROX 2 FT., VIDEO LOG SHOWED POSITIVE PROGRESS AT ENTERING THE 3 1/2 TUBING, BACK TOMORROW FOR MORE VIDEO AND POSSIBLE MILL WORK, IN PROGRESS 10/20/10 MILL W/2.72 CRAYOLA MIL FROM 237 TO 238.4 CTMD, UNABLE TO PASS 238.4, POH, RU 2.32 SLIM JSN ON COIL & RIH TO 264.5 CTMD W/ NO WT SWINGS, UNLOAD COIL & WELL W /N2. RIH W/ CAMERA & WORK CAMERA PAST 237 TO 264 CTMD, VIDEO RESULTS AT 237 APPEAR TO BE IN 3 1/2 "x7" ANNULUS, POOR IMAGE RESULTS FROM 237 TO 264 CTMD, RD & MOL 1/15/11 MIT IA TO 480 PSI - GOOD. BLEED GAS / FLUID PACK TBG. SET 2.813" CA -2 PLUG @ 192' RKB. BLEED DOWN TBG, IA, OA TO 0 PSI. COMPLETE. • i ConocoPhillips Time Log & Summary Wellwew Web Reporting Report Well Name: 2A - 06 Rig Name: NORDIC 3 Job Type: ABANDONMENT Rig Accept: 2/5/2011 3:30:00 PM Rig Release: 3/12/2011 11:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/04/2011 24 hr Summary Move rig pad to pad 19.1 miles 18:00 00:00 6.00 MIRU MOVE MOB P Move Nordic #3 rig from 1J -pad to 2A -pad 02/05/2011 Move rig from 2X -pad access road to 2A -pad. MIRU . Pull BPV, monitor well for flow, no flow. Set BPV. ND tree. NUBOP. 00:00 13:30 13.50 MIRU MOVE MOB P Continue rig move from 2X -pad access road to 2A -pad 13:30 16:30 3.00 MIRU MOVE RURD P Remove grating from well cellar. Lay down T- mats. PJSM. Spot rig over wellhead and level rig. Install containment, spot remaining equipment. Rig Accept: 02 -05 -11 @ 15:30 16:30 17:30 1.00 COMPZ WHDBO MPSP P PJSM. Pull BPV. Remove IA flange and install 1502 flanges. 17:30 18:00 0.50 COMPZ WELCTL OWFF P Monitor well for flow 30 minutes. 18:00 19:30 1.50 COMPZ WHDBO NUND P No flow. Set BPV. ND tree. / 19:30 00:00 4.50 COMPZ WHDBO NUND P PJSM. NU BOPE. 02/06/2011 Perform initial BOPE test 250/3,500 psi. MIRU HES S /L, pull CA -2 plug @ 192 -ft, RDMO. MIRU HES E -Line and perforate ECP packer © 159 -ft. Pull 3.5" completion from 239 -ft. 00:00 04:30 4.50 COMPZ WHDBO BOPE P PJSM. Perform initial BOPE function o test 250/3,500 psi. Test witnessed by AOGCC (Chuck Sheave) on 02 -06 -11 @ 04:30. 04:30 07:00 2.50 COMPZ WHDBO PULD P Test hardline to tiger tank 250/3,500 psi. Pull BPV and Blanking plug. MU landing joint, floor valve for S/L work. 07:00 08:00 1.00 COMPZ RPEQP1 SLKL P Wait on Slickline. PJSM. 08:00 09:30 1.50 COMPZ RPEQP1 SLKL P MIRU HES S /L. RIH w/ 2.5" RB to 192 -ft, pull equalizing prong, no pressure change, POOH. RIH w/ 3" JDC to 192 -ft, latch & pull plug body, POOH. RDMO S /L. 09:30 15:00 5.50 COMPZ RPEQP1ELNE P PJSM. Spot equipment. MIRU HES E -Line. RIH w/ CCL and 5' X 2" HCS perforator to 200 -ft. Make two logging passes to correlate depth. Stop CCL 154.1 -ft, pert interval 159' to 164 -ft, shot fired, POOH. RDMO E -Line. 15:00 17:00 2.00 COMPZ RPCOM OTHR P Allow ECP packer element to relax. Page 1 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:00 2.00 COMPZ RPCOM SFTY P Pre -job meeting with crew, discuss hazard identification. 19:00 20:00 1.00 COMPZ RPCOM CIRC P PJSM. Pump down tubing 2 bpm @ 70 psi, no returns to surface. 20:00 23:30 3.50 COMPZ RPCOM PULL P PJSM. BOLDS. Unland hanger and pull to floor, no issues, lay down hanger. POOH w/ 3.5" completion standing back to 239 -ft. Change out floor equipment. 23:30 00:00 0.50 COMPZ PLUG PULD P PJSM. MU Baker BHA # 1 5.875" milling assembly. 02/07/2011 RIH with milling assembly and mill through tight spot at 65' ,Mill on buckled casing f/ 206 -ft to 224 -ft with concaved junk mill., Twisted off. POOH and Fish BHA. MU and RIH with BHA # 3 5 7/8" OD Milling Assy. Reaming from 56 -ft. to 103 -ft. Mill from 103 -ft. to 223 -ft. 00:00 03:00 3.00 65 206 COMPZ PLUG MILL P RIH w/5.875" mill assembly and mill through tight spot @ 65 -ft.. Continue in hole to 206 -ft tag up. 03:00 09:30 6.50 206 224 COMPZ PLUG MILL P Mill through restriction @ 206 -ft, 2 bpm @ 60 psi, Up weight 60 K Down weight 42K, torque 2-4 K RPM's 45-60 to 224 -ft. Start loosing torque, little or no torque, POOH to check BHA. 09:30 10:00 0.50 119 0 COMPZ PLUG TRIP P Stop at Bumper sub, bumper sub broke off at mandrel. Lay down tools, ready floor for fishing tools. 10:00 14:00 4.00 0 0 COMPZ FISH FISH T Wait on fishing tools from Prudhoe. 14:00 15:00 1.00 0 117 COMPZ FISH FISH T MU BHA fishing BHA #2 overshot assembly 15:00 16:30 1.50 117 125 COMPZ FISH FISH T RIH w/ BHA, set down on bumper sub, rotate to engage fish, POOH w/ ✓ fish. 16:30 17:30 1.00 125 0 COMPZ FISH PULD T Lay down fish, scarring on outside of BHA, Twisted off at bottom of knocker, mandrel shows sign off being ran on while rotating. 17:30 18:00 0.50 0 0 COMPZ PLUG SFTY P Held PJSM on PU Milling BHA #3 with Baker Fishing Rep and Rig Crew. 18:00 19:00 1.00 0 0 COMPZ PLUG PULD P PU, MU and Stand Back to stands of hybrid Drill Collars. 19:00 19:30 0.50 0 0 COMPZ WHDBO OTHR P Install wear ring. 19:30 20:30 1.00 0 56 COMPZ PLUG PULD P PU and MU 5 7/8" OD Window mill, 5 7/8" OD Lower mill, on 1 jt of 3 1/2 DP, PU and MU off the bottom of the fishing jars with LBS and 5 7/8" OD string mill. MU to BHA in the hole and RIH to 56 -ft. 20:30 21:45 1.25 56 103 COMPZ PLUG REAM P Ream in the hole from 56 -ft. to 103 -ft. 21:45 22:45 1.00 103 115 COMPZ PLUG MILL P Mill from 103 -ft to 115 -ft at 43 rpms with 2k torque, circulating at 84 gpm at 60 psi, increase pump rate to 168 gpm at 140 psi. Page 2 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 23:30 0.75 115 200 COMPZ PLUG MILL P Continue to Mill from 115 -ft to 200 -ft at 43 rpms with torque increasing to 3k with pump rate at 168 gpm at 140 psi. 23:30 00:00 0.50 200 223 COMPZ PLUG MILL P Continue to Mill from 200 -ft to 223 - at 43 rpms with torque increasing to 3k with pump rate at 168 gpm at 140 psi. Running 2 to 4k WOM. 50k up wt, 45k do wt, 46k Rotary wt. 02/08/2011 Milled through the damaged Casing section from 223' - 229'. Continue down to the top of the Tubing at 243'. — Milled off the Tubing top down to 253'. POOH. Ran BHA #4 to dress off the top of the Tubing. However, unable to get the Dress Off BHA through the damaged Casing section at 227'. POOH. MU tandem mill assembly. 00:00 03:00 3.00 223 229 COMPZ PLUG MILL P Continue to mill from 223 -ft to 229 -ft at 51 rpms at 2 to 4k torque with 1k WOM, Circulating at 168 gpm at 140 psi. Time milling at 229ft. 03:00 12:00 9.00 229 COMPZ PLUG MILL P Continue time milling @ 229ft, increase RPM to 50, 3 -4K torque, pumping 4 bpm @ 140 psi, metal in returns. Mill for 229 to 248 -ft tubing stub depth. 12:00 14:30 2.50 COMPZ PLUG MILL P Mill on tubing stub from 248' to 253', same parameters. 14:30 15:00 0.50 COMPZ PLUG TRIP P POOH w/ BHA #3 and lay down same. Marks on bottom of mill indicate tubing. 15:00 16:00 1.00 COMPZ PLUG WASH P MU magnet and wash BOP stack. 16:00 17:00 1.00 COMPZ PLUG PULD P Lay down magnet, MU BHA #4 5.75" X 3.5" ID Dress Guide and Dress off mill. 17:00 22:30 5.50 0 227 COMPZ PLUG MILL P PJSM. Run in with BHA #4. Up Weight = 50K. Down Weight = 45K. RTW= 42K. RPMs = 52. FST = 1.8K. Pump Rate = 4.0 bpm/70 psi. Tag tight spot at 225ft. Work down with difficulty to 227 -ft. 22:30 23:00 0.50 227 0 COMPZ PLUG TRIP P Decide to trip out to inspect BHA. Found evidence that a piece of Casing was up inside of the Washpipe Extension. 23:00 00:00 1.00 0 0 COMPZ PLUG TRIP P PJSM. Make -up BHA #5, (same as BHA #3) as follows: 5 7/8" Window Mill, 5 7/8" Lower Mill, 1 Jt Drill Pipe, 5 7/8" String Mill, Bumper Sub, Oil Jar, 2 ea 4 3/4" Drill Collars, 1 Jt 3 1/2" Drill Pipe, 2 ea 4 3/4" Drill Collars, 1 Jt 3 1/2" Drill Pipe. 02/09/2011 Run in with BHA #5 tandem mill assembly to re -dress the damage Casing section to 253'. Re -run the Dress Off Assembly. However, unable to get past 195 -ft. POOH. Re- configure several Mill Assemblies in an attempt to get through the damaged Casing areas. Make up BHA #9, 6" Window /String Mill Combo. Mill Casing from 173 -ft down to 240 -ft. Page 3 of 37 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 COMPZ PLUG MILL P Run in a tagged the damaged Casing section at 223 -ft worked through with little problem. Continue down to the top of the Tubing Stump at 253 -ft. Pull back up to the damage section and work through several more times. POOH. MU BHA #6 06:00 10:00 4.00 COMPZ PLUG MILL P RIH w/ BHA #6 Dress -off mill, had to work through several tight spot to 185 -ft, unable to work past. Change parameters as well, unable to work through restriction. POOH. Change bevel on shoe at shop. Add magnet to BHA. 10:00 12:00 2.00 COMPZ PLUG MILL P RIH w/ BHA #7 - Dress -off mill w/ different bevel. Able to work through tight spot at 185'. Continue in hole to 195 -ft, unable to work through tight spot. Increase rpm to 80, unable to work through. POOH. Lay down BHA. MU BHA #8. 12:00 14:30 2.50 COMPZ PLUG MILL P RIH w/ BHA #8 5.75" OD shoe with extension to 185 -ft, work through, 195 -ft still unable to work through restriction, change parameters, no change, POOH. Two small metal pieces missing from leading edge of shoe. MU BHA #9 6" window / string mill combination. 14:30 00:00 9.50 178 240 COMPZ PLUG MILL P RIH w/ BHA #9 6" string/window mill to 178 -ft. Up Weight = 50K. Down Weight = 40K. RTW = 47K. RPMs = 60 - 80. FST = 2.3K. Pump Rate = 4.0 bpm /140 psi. Slow milling from 178' down to 225'. Continue milling from 225' - 240' with faster steady progress. 02/10/2011 Continue down from 240 -ft to the top of the Tubing Stump at 253 -ft with the 6" Window /String Mill combo. Circ clean. POOH. Run Dress -Off Assembly. Unable to get through the damaged Csg section at 222'. POOH. Run Overshot on 3 1/2" Tubing and got down to the top of the Tbg. However, unable to latch Tbg. POOH. Run the Dress -Off Mill without the Extention and mill down to the top of the Tbg. Circ hole clean. POOH. Recovered twisted piece of casing 12" long. RIH w/ overshot and attempt to latch tubing. 00:00 03:30 3.50 240 253 COMPZ PLUG MILL P Continue milling from 240 -ft down to the top of the Tubing Stump at 253 -ft. Back ream up to 215 -ft with no problems. Rotate back to 253 -ft with no problems. 03:30 04:00 0.50 253 253 COMPZ PLUG CIRC P Pump a Hi -Vis Sweep at 7.0 bpm and clean -up Well. Returns = much fine metal fillings 04:00 08:00 4.00 253 0 COMPZ PLUG TRIP P Trip out. Stop to back ream from 215 -ft up to 122 -ft. Run back to 225 -ft with no problem. Continue to finish trip out. Page 4 of 37 • I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 10:00 2.00 0 0 COMPZ PLUG WASH P PJSM. MU magnet/ washpipe assembly. Run assembly down stack three times to clean metal debris. PU magnet & clean magnet. Lay down assembly. 10:00 12:00 2.00 0 222 COMPZ PLUG MILL P PJSM. PU BHA #11 Dress -off mill assembly to 222 -ft, no problems to this depth, unable to work through restriction Up 50k Down 40k 40 rpm's, pumping @ 4 bpm 90 psi ROT 47k, no luck. Blow down top drive, monitor well, static. 12:00 13:00 1.00 222 0 COMPZ PLUG TRIP P POOH w/ BHA # 11 from 222 -ft. Lay down BHA and inspected, leading edge rolled over on shoe, looks to have marks internally as well. Decision made to try OS on 3.5" tbg. 13:00 14:00 1.00 0 0 COMPZ PLUG PULD P MU BHA # 12 overshot assembly on 3.5" tubing. 14:00 17:00 3.00 0 0 COMPZ PLUG TRIP P RIH w/ overshot with pack -off on 3.5" tubing to 253 -ft. Made several attempts to engage tubing, were unsuccessful. POOH, lay down overshot. 17:00 20:00 3.00 0 257 COMPZ PLUG MILL P Make up BHA #13 as follows: Dress -Off Mill, Bit Sub, 2 Jts Drill Pipe, Bumper Sub, Oil Jar, 3 1/2" Drill Pipe to surface. RIH to top of the Tubing Stump at 253.5 -ft. Up Weight = 43K. Down Weight = 43K. RPMs = 60, RTW = 45K, FST = 1K. Bring Pump on at 2.0 bpm /170 psi. Start to dress off the top of the 3 1/2" Tubing. However, no progress and pump pressure increased up to 600 psi. Pull up hole and pressure falls off. Repeat with same results. Shut down Pump. Dry mill from 253.5 -ft down to 255 -ft. Bring Pump back on line at 2.0 bpm /475 psi (pressure still seems to high, but is steady). Continue to Mill down to 257.0 -ft. End tubing dress -off. 20:00 20:30 0.50 257 257 COMPZ PLUG CIRC P Pump Hi -Vis Sweep at 4.0 bpm/1,625 psi. Returns were mill fillings, fine cement and sand solids. 20:30 21:30 1.00 257 0 COMPZ PLUG TRIP P Trip out. Lay down and inspect Mill. Wear pattern on both the Pilot Mill and the Dress Mill indicated that the tubing has been dressed off. Also recovered a twisted piece of Casing approx 12" long that had gotten up inside of the 1" I.D. in the the Pilot Mill which of course was causing the high pressures observed during the dress -off. Discuss findings with Anchorage Engineer and proceed with planned program. Page 5 of 37 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 0 257 COMPZ PLUG FISH P Change handling equipment for 3 1/2" Tubing. Pick -up Bowen Overshot w/3 1/2" Basket Grapple. Run in on 3 1/2" Tubing. Set down at 252 -ft. Bring Pump on line. Work Overshot down to 257 -ft (expected top of Tubing). Continue to work Overshot to get a bite. 02/11/2011 Attempt to latch Tbg. No -Joy. POOH and inspect Overshot. Evidence that OS got kicked outside of the 7" Csg. Mob E- Line /Camera. Repair top drive. RIH w/ muleshoe and 3 -1/2" tubing. Circulate Well. RU E -Line and run camera. Record pictures to determine next option. Found 9 -5/8" & 7" csg damage. 6" mill exited the casing on prior run. Discuss a plan forward after camera log. 00:00 01:00 1.00 257 264 COMPZ PLUG FISH P Continue to attempt to latch Tubing. However, have passed the last know depth of the Tubing top and no sign of a "bite ". Now at 264.0 with no sign of over pull or a pressure increase. 01:00 03:00 2.00 264 0 COMPZ PLUG TRIP P Trip out with Overshot to inspect and ponder next attempt. Lay down Overshot. Overshot was caked with Formation Mud. Basket Grapple in new condition. No marks. It appears that the Overshot "kicked" outside of the the 7" Casing. Discuss findings and a plan forward with Anchorage Engineer. Mobilize HES E -Line and Camera. Have BOT Machine Shop build a Top Sub so we can run a 4 11/16" O. D. Overshot on the next attempt. 03:00 10:00 7.00 0 0 COMPZ PLUG FISH P Secure Well. Mobilize E -Line Equipment. Service and perform maintenance on Rig Top Drive while waiting on third party equipment to arrive on location. E -Line equipment and Expro camera equipment on location @ 10:00. 10:00 13:30 3.50 0 COMPZ PLUG RGRP T Continue work to Top Drive system. Chane out teflon seal on torque tube slide. 13:30 14:30 1.00 COMPZ PLUG TRIP P RIH w/ 3.5" muleshoe on 3.5" tubing to 255 -ft, just above tubing stub. 14:30 15:30 1.00 COMPZ PLUG CIRC P MU head pin and circulate well with clean SW with two well volumes, clean SW back to pits. 15:30 17:00 1.50 COMPZ PLUG ELOG P PJSM with HES & Expro. Rig up E -line equipment. Toolstring: Cable head, Weight bar, Hawkeye chasis, Centralizer, Motor, Centralizer, Sideview Camera TL 21.52'. RIH w/ camera assembly. Page 6 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 00:00 7.00 COMPZ PLUG ELOG P Run in with Camera and record 9 5/8 and 7" Casing damage from 254 -ft up to 242.0 -ft. Also observed that the 3 1/2" Tubing is outside of the 7" Casing at — 244 -ft. This entire area is completely twisted and mangled. At 254 -ft the 6" Mill BHA run has completely exited the Well Bore. Down load videos and sent to Anchorage Engineer for review and discussion. 02/12/2011 Review results from the Camera Log with Anchorage Engineer. Discuss Plan Forward. After reviewing results from the Camera Log with Anchorage Engineer it was decided to cut & pull the 7" casing. RD E -Line. POOH w/ tubing. Bleed down OA to 0 psi. ND BOP. Prep to ND tubing head. Decide to test BOP stack before cut & pull 7" casing. NU BOP. Change lower rams to 7 ". Perform weekly BOPE test. Prep to remove the 7" Casing. After reviewing results from the Camera Log with Anchorage Engineer it was decided to change the scope of the Operations. 00:00 02:00 2.00 COMPZ PLUG ELOG P Continue to review Camera Logs with Anchorage Engineer. Decision made to cut & pull 7" casing. 02:00 03:00 1.00 COMPZ PLUG ELOG P Rig down camera tool string and HES E -Line equipment. 03:00 03:30 0.50 COMPZ PLUG CIRC P Change -out hole fluid to 9.4 ppg KWF. 03:30 04:00 0.50 COMPZ PLUG TRIP P PJSM. TOH w/ 3.5" tubing and lay down. 04:00 06:00 2.00 COMPZ PLUG PULD P Bleed off OA from 150 psi to zero. Wash BOP stack and run magnet. 06:00 09:00 3.00 COMPZ WHDBO NUND P ND BOPE 09:00 11:00 2.00 COMPZ WHDBO PULD P PJSM. RU hydratight equipment. Decision made by State to test BOPE now. Lay down hydratight equipment. 11:00 20:00 9.00 COMPZ WHDBO NUND P NU BOPE for BOP test. Change rams to 7". 20:00 00:00 4.00 COMPZ WHDBO BOPE P PJSM. Begin weekly BOPE test per Conoco /Phillips, AOGCC requirements at 250/3,500 psi. Test Annular at 250/3,500 psi. Perform Koomey Draw Down Test. The State's right to witness test was waived by L. Grimaldi. 02/13/2011 Complete BOPE Test. Set RBP in 7" Casing. Dump sand on RBP. ND BOP Stack. Control Csg growth using Hydra -Tight equipment ND Tbg Spool. Spear 7" Casing to determine if Csg is free. NU BOP Stack to 9 5/8" Csg Head as a "Diverter. Cut off a 7" x 12.44 -ft Casing Stub recovered with Wachs Cutter. Tack weld Slips. NU BOP Stack. 00:00 06:00 6.00 COMPZ WHDBO BOPE P Continue with weekly BOPE test. Change out upper Pipe Rams (VBRs) due to failed pressure test. Fill stack, body test stack, test plug leaking. Pull & Rerun test plug. Complete BOPE test to 250/3500 psi, good test. Load RBP to floor. Page 7 of 37 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:00 08:00 2.00 COMPZ PLUG MPSP P MU 6" RBP BHA. RIH w/ RBP on 3.5" DP, set down @ 155 -ft. Top of RBP @ 155 -ft, unable to make hole, set RBP @ 155 -ft, set RBP with 3,500 psi. TOOH w/ DP, check running tool. PT RBP to 500 psi, good test. 08:00 10:00 2.00 COMPZ PLUG MPSP P PU to dump 20/40 river sand above RBP @ 155 -ft. Lay in 20' of sand on RBP. Tag top of sand at 126 -ft. 10:00 14:30 4.50 COMPZ WHDBO NUND P ND BOPE. PJSM. ND tubing head. RU Hydratight equipment, remove valves, allow 7" to grow, only 1 1/2" of movement. Lay down tubing head and Hydratight. 14:30 18:00 3.50 COMPZ PLUG CUTP P MU 7" casing spear on one joint 3.5" DP, engage casing. Pull on 7" casing, working weight up from 100K to 300K total weight, work casing uphole twelve feet, try to pull casing slips. Decision made to tack slips and Wach's cut casing. 18:00 20:30 2.50 COMPZ PLUG CUTP P Install Wachs Cutter and cut off the 7" Casing Stub pull. Lay down Stub (12.44 -ft). Rig down Wachs Cutter. 20:30 21:00 0.50 COMPZ WHDBO SFTY P PJSM with All. Discuss tacking welding Slips and NU BOP Stack. Review plan forward. 21:00 22:30 1.50 COMPZ WHDBO RTWH P Safe out Cellar. Assign fire watch. Tack weld 7" Casing Slips to the Casing. 22:30 00:00 1.50 COMPZ WHDBO NUND P Nipple Up BOP Stack. 02/14/2011 ✓ NU BOP. Shut down due to Phase III Weather. Spear casing. Lift BOP stack. Attempt to pull casing slips - unsuccessful. Release spear. Remove BOP and set back on stump. Cut casing with mechanical cutter 2' below first casing collar. Spear casing and work up to 150K. No movement. 00:00 04:00 4.00 COMPZ WHDBO NUND P Continue to Nipple up BOP Stack. 04:00 18:00 14.00 COMPZ PLUG OTHR T Phase III Weather conditions. Suspend Operations. Monitor Well. 18:00 20:00 2.00 COMPZ PLUG CUTP P PJSM. Resume operations. Pick -up ITCO Casing Spear and plant in 7" Casing. Lift BOP Stack. Attempted to pull Packing Ring and Casing Slips free. However the "tack welds" attached to the top Pack -Off Ring cracked (175K), while pulling on Casing. Abort further attempt. Release Spear and lay down same. Page 8 of 37 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 COMPZ PLUG CUTP P Review next previous plan forward with Anchorage Engineer. PJSM. Set BOP Stack back on stump. Pick -up Baker 5 1/2" MS Cutter. Install 5/8" Ball on seat. RIH. Locate Casing Collar. Position cutter knives 2 -ft below first Casing Collar below Well Head (42 -ft NRF RKB). Cut Casing with 60 RPMs and 400 psi pump pressure. Made cut in 6 minutes. Pull and lay down MS Cutter. Pick -up Itco Casing Spear. Plant Spear in Casing. Work up to 150K and attempt to pull Pack -Off Ring and Slips. No movement. 02/15/2011 Continue to work to remove Pack -Off Ring and pull 7" Casing Slips. Jar Slips free. Rig up and lay down 187 -ft of parted and cork- screwed Casing. Perform BOP BodyTest to 250/3000 psi. 00:00 02:00 2.00 COMPZ PLUG CUTP T Continue to work to get Pack -Off Ring and Slips out of Wellhead. Apply steam to heat Wellhead. Re- position Spear. Continue to pull on Casing. Gained 1 -ft. However, had to pull 220K to get Casing to "jump ". It appears that the crooked Wellhead is causing the Pack -Off and Slips to cock to the one side when trying to pull Casing. Also it is assume that the cement sheath and Centrilizers around the Casing are causing a lot of over -pull. Discuss next option. 02:00 04:00 2.00 COMPZ PLUG CUTP T PJSM. Safe out Cellar for hot work. Assign a fire watch. Cut a "wedge out of the Top Ring. Remove Top Ring and Packing Elements. Cut a wedge out of the Bottom Ring and remove. 04:00 07:00 3.00 COMPZ PLUG CUTP T Plant Spear and attempt to pull Casing and Slips at 200K. No -Joy. Still have a down hole problem. Tack Slips to Casing (to prevent falling off the end of the Casing Stub). Prep to cut Casing just below surface. 07:00 07:30 0.50 COMPZ PLUG CUTP T Start making cut below Emergency Slips. Up Wt =40k, Down Wt =40k. ROW =40k, 60 RPMS, 1k Free Torque, Start Pump 200 psi and Increase to 400 psi After 2 min. 1.8k Cutting Torque. 07:30 10:00 2.50 COMPZ PLUG CUTP T PJSM. M/U spear. Set Spear 5' in to 3' Below casing slips. Pull 135k 3 times NO -GO. Discuss Next Plan with Town. Release Spear. 10:00 11:00 1.00 COMPZ PLUG CUTP T PJSM. Rig Up SPEAR and Jars.Drill Collar and Intensifier. Page 9 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:45 0.75 COMPZ PLUG CUTP T Plant Spear and Start Jarring. P/U to 150k and Stroked jars Recock jars and P/U to 175k Casing Starting Moving. Pull casing casing and casing slips to Rig Floor. Cut and Remove Casing. 11:45 12:00 0.25 COMPZ WHDBO SFTY P PJSM.Discuss Hazard of Making Up BOPE. 12:00 16:00 4.00 COMPZ WHDBO NUND P Nipple up BOP stack. 16:00 16:30 0.50 COMPZ PLUG CUTP P PJSM.P /U Spear And Run in Tag top of 7" Casing. Work Spear into Casing. Pull Casing to Rig Floor. Pull Max 175k 1 Time. Pulling At 50 -75k. 16:30 17:00 0.50 COMPZ PLUG CUTP P PJSM.Rig up 7" Casing Equipment. 17:00 20:00 3.00 187 0 COMPZ PLUG CUTP P Continue OOH with 7" Casing. Lay down Casing Joint with Baker RBP inside (mark same). Recovered a total of 187 -ft of 7" Casing. All Joints were "cork- screwed ". Last Joint recovered had pin end mangled. 20:00 00:00 4.00 0 COMPZ WHDBO BOPE P Wash BOP Stack. Set Test Plug. Install vales on Spacer Spool. Perform BOP Body Test at 250/3,000 psi. Good test. Pull Test Plug. AOGCC waived the right to witness test. B. Noble. X2/16/2011 Clean out 9 5/8" Csg down to the 7" Csg top at — 187 -ft. Dress Fish. Spear Fish and lay down same. Run 3 1/2" Tbg. Pump Hi -Vis Sweep. Rig up E -Line and Camera. 00:00 04:00 4.00 0 0 COMPZ PLUG CUTP P Clear Pipe Shed. Load 6 1/4" Drill Collars. Load next BHA and bring to Floor. Steam tools and tally Drill Pipe. Ready Floor. 04:00 05:00 1.00 0 0 COMPZ PLUG TRIP P PJSM. For P/U Milling BHA. M/U and RIH with Milling Assembly 05:00 08:00 3.00 222 225 COMPZ PLUG MILL P Tagged 7" Stub @ 222'. Up Wt =50k, Down Wt =50k, ROT Wt= 50k @ 60 RPM, 2 FR k Torque while Circulating @ 5 bpm, 60 psi. Seeing 3 -5k on Mill, 2K Milling Torque while Milling. Seen one Stall, PUH and had Erratic Torque, Resume Milling. Milled Down to 225'. Pumped a 20 bbl High -Vis Sweep @ 8 BPM @ 90 psi. Seeing a lot of metal shaving at the shaker. 08:00 09:30 1.50 225 0 COMPZ PLUG TRIP P TOOH, and Lay down Milling Assembly. 09:30 10:00 0.50 0 137 COMPZ PLUG PULD P M/U Bowen Itco Spear & Jars Assembly. 10:00 10:30 0.50 137 225 COMPZ PLUG FISH P Tagged @ 225' MD roll pump and attempt to spear into 7" csg. Pump rate 4 bpm @ 50 psi. 10:30 11:30 1.00 225 0 COMPZ PLUG TRIP P TOOH to check for fish.B /D top drive & lay down fishing assembly. No fish, seen metal shavings around and inside of spear. Page 10 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 0 150 COMPZ PLUG PULD T UD Fishing assembly. P/U clean out assembly W/ boot basket. 12:00 13:30 1.50 225 252 COMPZ PLUG FCO T Back On back on Bottom with Clean Out Assembly. M/U top drive. EST. Parameters: 47k Up Wt, 47k Down Wt. ROW 47k, pumping 4 bpm @ 60 psi. 1 -2k free torque,Wash down to 252'md. 13:30 14:00 0.50 252 252 COMPZ PLUG CIRC T Circulate 20 bbl High -Vis sweep @ 8 bpm, 80 psi, continue until clean. 14:00 15:00 1.00 252 0 COMPZ PLUG TRIP T TOOH & UD Clean out Assembly 15:00 15:30 0.50 137 224 COMPZ PLUG FISH T Make up spear assembly & RIH. Tag @ 224' MD. Rotate into 7" csg fish, latch spear. Jar up once @ 150k & spear released. Latch spear again, hit 200k, re -cock jars, hit 225k fish moving up hole @ 150 -200k. TOOH to check fish. 15:30 18:00 2.50 224 0 COMPZ PLUG PULL P OOH. Recover a 24' foot section of 7" CSG. L/D fishing Assembly. Review pictures on S- Drive. 18 :00 20:00 2.00 0 242 COMPZ PLUG TRIP P PJSM. Ready Floor to run 3 1/2" Tubing. Run 3 1/2" Tubing to 242 -ft. 20:00 21:00 1.00 242 242 COMPZ PLUG CIRC P Pump a 20 bbl Hi -Vis Sweep at 8.0 bpm to clean hole one more time while waiting for E -Line Unit to arrive on location. Smal amount of metal and cement in returns. 21:00 21:30 0.50 242 235 COMPZ PLUG PULL P Pull Tubing up to 235 -ft. Install TIW Valve and Pump -In -Sub. Prep for E -Line Camera Log. E -Line arrive on location. 21 :30 22:15 0.75 235 235 COMPZ PLUG SFTY P PJSM with All. Prep to rig up E -Line. Announce a Rig Evacuation Drill to include all third party. Evaluate Drill acceptable. 22:15 00:00 1.75 235 235 COMPZ PLUG ELOG P Rig up Halliburton E -Line and EXPRO Video Camera. 02/17/2011 Attempt Camera Video Log. Wellbore blocked with cement chunks. POOH. Lower tubing to 242'. Circ clean. PU tubing to 241'. Attempt camera run. Wellbore still blocked with cement chunks. POOH with Camera. POOH with tubing. RIH with drill pipe and 8 -1/2" concave mill. Clean out Cement debris down to 251 -ft. POOH. RIH with tubing to 251'. Circ clean. RU cameral. Record Video Log. Results still remain inconclusive. Discuss Plan Forward with Anchorage Engineer. POOH with tubing. Wait on tools. 00:00 01:00 1.00 235 235 COMPZ PLUG ELOG P Run in with EXPRO Camera on HES E -Line. Park Camera inside Tubing and clean -up Well with clean Sea Water. Drop out the end of the Tubing at 235 -ft. See and obstruction (Cement Chunks) at 238 -ft. Unable to get any deeper with Camera. POOH and stand back Camera Page 11 of 37 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:30 0.50 235 241 COMPZ PLUG ELOG T Lower Tubing in an attempt to get by Cement debris and sweep hole clean. However, stacked out solid at 242 -ft several times. Pull up hole to 241 -ft. 01:30 03:00 1.50 241 241 COMPZ PLUG ELOG T Pick up Camera. Run back in hole to have a closer "look -see" at blockage. Position Camera at 241.5' Well bore is blocked with cement chunks and slab pieces thast have fallen off of the inside of the 9 5/8" Casing.. POOH with Camera and download video. Discuss fill clean out with Anchorage Engineer. 03:00 03:30 0.50 241 241 COMPZ PLUG ELOG T Rig down Camera and E -Line Tools.. Rig back Lubricator. Leave E -Line Unit spotted. 03:30 04:00 0.50 241 0 COMPZ PLUG TRIP T Trip out with 3 1/2" Tubing. Ready Floor for next BHA and 3 1/2" Drill Pipe. 04:00 05:30 1.50 0 0 COMPZ PLUG PULD T Clear and clean floor. PJSM for BHA #25. MU BHA 05:30 07:15 1.75 126 242 COMPZ PLUG MILL T RIH W/ 8 -1/2" concave mill BHA. Tag @ 242' MD. 47k up wt. 47k down wt. 50k ROW, 60 RPM 2k free torque, 4 BPM @ 60 psi, milling torque 2 -3k, 3-4k WOM 07:15 12:15 5.00 242 251 COMPZ PLUG MILL T Torqued up & stalled @ 245' MD, pick -up, ease back down 1 -2k WOM. Slow progress, pump sweep. set back down and mill for 45 minutes to gain 1', stall out @ 247' MD. making about 1' per 1/2 hour. Finish milling at 251' MD, pump another sweep. Blow down top drive. 12:15 13:00 0.75 251 0 COMPZ PLUG TRIP T TOOH 13:00 14:00 1.00 0 0 COMPZ PLUG PULD T Break down /LD BHA.Obtained sample, 5 gal bucket full of cement and metal in in boot baskets. Mill shows excessive wearon outer pads and wear in center of mill. PJSM, prep to run 9 Jts of 3 1/2" tbg. 14:00 14:45 0.75 0 251 COMPZ PLUG TRIP T RIH W/ 9 Jts of 3 1/2" 14:45 15:15 0.50 251 251 COMPZ PLUG CIRC T @ 251' MD, pump sweep 5 BPM @ 60 psi. to clean up prior to running video. 15:15 15:30 0.25 251 251 COMPZ PLUG SFTY T Conduct PJSM prior to rigging up E -line. 15:30 16:15 0.75 251 251 COMPZ PLUG ELOG T Rig up E -line. 16:15 18:30 2.25 251 251 COMPZ PLUG ELOG P Pump filtered seawater @ 4 BPM, RIH W/ E -line & Expro Camara. POOH with Camera. Down load Video. Page 12 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 22:00 3.50 251 251 COMPZ PLUG ELOG P Discuss Video Log results and several BHA options with Anchorage Engineer. Rig E -Line equipment off of Well. (Unit remains spotted and on stand -by). Order out additional components needed for next BHA. 22:00 22:30 0.50 251 0 COMPZ PLUG TRIP P PJSM. Trip out with 3 1/2" Tubing from 251 -ft. 22:30 00:00 1.50 0 0 COMPZ PLUG MILL P PJSM. Clear and clean Floor. Ready Floor to handle next BHA. Wait on additional BHA components to arrive on Location. 02/18/2011 Review BHA options with Anchorage Engineer. RIH with stiff tandem mill and stabilizer assembly. Mill from 250' to 259'. POOH. Wash stack. Run 3 -1/2" tubing to 257'. Stand -by due to Seismic recording activity in the area. RU E -line and camera while waiting on seismic operations. 00:00 03:00 3.00 0 201 COMPZ PLUG PULD P Off -load BHA components and bring to Floor. Tally same. Make up BHA #26 as follows: 8 1/2" Rough O. D. /Concave Mill, 8 3/8" Lower Watermelon Mill, XO, 1 ea 6 1/4" Drill Collar, XO, 8 1/2" Upper Watermelon Mill, XO, 1 ea 6 1/4" Drill Collar, XO, 8 1/2" Stabilizer, 6 1/4" Bumper Sub, 6 1/4" Oil Jar, XO, 3 ea 6 1/4" Drill Collars, XO. TL = 200.65 -ft 03:00 03:00 0.00 250 251 COMPZ PLUG MILL P Continue in with BHA on 3 1/2" Drill Pipe. Pick -Up Weight = 60K. Slack -Off Weight = 50K Rotating Weight = 50K. RPMs = 70. Free Spin Torque = 2K. Pump Rate = 4.0 bpm /60 psi. Tag up at 249.5 -ft. Begin control milling at 2 - 3K Milling Torque with — 2K Weight on Mill. 03:00 04:45 1.75 251 251 COMPZ PLUG MILL P Milled down to 250.50' and and stalled several times. PUH 2' Started working back down and lost at foot after milling to 250.5', Continue with milling operation. Rotating Weight = 50K. RPMs = 70. Free Spin Torque = 2K. Pump Rate = 4.0 bpm /60 psi. Begin control milling again at 2 - 3K Milling Torque with — 2K Weight on Mill. 04:45 16:00 11.25 259 259 COMPZ PLUG CIRC P Milled down to 259.0' md, seen small milling break @ 255'md. Circulated a 20 bbl High -Vis Sweep @ 4 bpm, 60 psi, continue to circulate until returns where clean. 16:00 18:00 2.00 209 0 COMPZ PLUG PULD P PUH 50' feet, B/D Top Drive, Continue OOH Laying Down Milling Assembly. Inspect Mill and Discuss finding with town. 18:00 19:00 1.00 0 0 COMPZ PLUG PULD P Pick -up Swizzle Stick and Magnet. Wash out BOP Stack. Page 13 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:00 1.00 0 257 COMPZ PLUG TRIP P Ready Floor to handle 3 1/2" Tubing. Run in with 3 1/2" Tubing. Tag up at 259 -ft. Pull back up to 257 -ft. 20:00 21:00 1.00 257 257 COMPZ PLUG CIRC T Alert the Seismic SIMOPS Coordinator that we would like to do a pump -test (while waiting for the clean Sea Water Vac to arrive on Location) to simulate the conditions while we are performing the Video Log. Circulate Well with 9.6 lb/gal al 9 9 Brine at 4 - 5 bpm. Contact Seismic Foreman for results. The vibrations from the Pumps are causing strong interference to their recording devices and they would not be able to record their seismic data. Alert Anchorage Engineer that we are shut down. However, a "window of opportunity" was worked out and scheduled from 00:00 hrs - 02:00 hrs. so we could get the Video Log recorded. 21:00 00:00 3.00 257 257 COMPZ PLUG ELOG T PJSM. Rig up E -Line equipment and Video Camera. Spot Clean Sea Water Truck. Wait for the the midnight Seismic Crew change -out. 02/19/2011 Record Video Log during seismic crew change out and equipment service. Download Video Log and discuss results with Anchorage Engineer. Able to see 3 -1/2" tubing stub. Develop a plan for the next BHA. Run 5 -3/4" cut lip guide shoe with 4 -3/4" inner mill. Attempt to work over tubing stub - unsuccessful. POOH. MU 6" OD guideshoe with 4 -3/4" inner mill. Attemp to work over tubing stub - unsuccessful. POOH. Run 3 -1/2" tubing to 254'. Circ hole clean. RU E -Line and record video log_. POOH with E -Line and RD. 00:00 01:30 1.50 257 250 COMPZ PLUG ELOG P Displace the 9.6 lb/gal Brine from wellbore with clean Sea Water. Run in with Video Camera pumping at 3.0 bpm to clean up Well. Record Video as follows: Run Camera to 260 -ft and see formation. Pick -up Tubing to 255 -ft. Video pass shows a second "side- track" outside of the 9 5/8" Casing at 255 -ft. Pick -up Tubing to 250 -ft. Increase pump rate to 4.0 bpm. Video pass shows "slabs" of the 9 5/8 ", 7 ", and 3 1/2 ". Also shows a camera side view of the shaved 3 1/2" Tubing. Found the mangled top of the 3 1/2" Tubing at 251 -ft. Pick -up Tubing to 248 -ft and then again up to 245 -ft. Increase pump rate to 5.0 bpm. Video Passes show things remain pretty much as previous Camera logs. Drop Tubing back down to 248 -ft and then down to 250 -ft. Continue to record Video pass until out of Sea Water. End Logging. Pull Camera to surface and stand -by. Call Seismic SIMOPS Coordinator and let them know we are done pumping. Page 14 of 37 1 110 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:00 2.50 250 0 COMPZ PLUG ELOG P Discuss Video Log with Anchorage Engineer. Discuss next BHA. 04:00 06:00 2.00 0 0 COMPZ PLUG ELOG P Lay down Camera. Rig E -Line equipment off of Well. E -line Unit remains spotted on Location. Order out additional components for next BHA. 06:00 10:00 4.00 0 232 COMPZ PLUG PULD P Tools Needed for next Run are on location. Load Tools to rig floor. P/U and M/U a 5 3/4" Shoe w /Cutlip Guide and a 4 3/4" OD Junk Mill Assembly. Total Length will Bumper Jar & Oil Jar Stroked Out = 233.52' 10:00 12:30 2.50 232 262 COMPZ PLUG MILL P Set Down @ 262' md, PUH to 242' md, Set Parameters, up wt =45k / down wt =50k, ROT 47k, made several attempts to work Cutlip guide shoe over 3.5" TBG stub. Still no Luck. Blow down top drive. POOH and L/D BHA. 12:30 14:30 2.00 0 0 COMPZ PLUG MILL P PU + MU 6" OD x 4 3/4" Guide Shoe w/ cut right. RIH and set down @ 268' md, continue to try and work over 3.5" TBG stub while rotating and pumping. Pump Rate 3 bpm @ 80 psi, work down from 248' to 268' Rotating 1/8 turn and stopping. Up ✓ Wt =45k Down 50k, 47k rot. Try several attempts to work over 3.5" stub with no success. 14:30 15:30 1.00 0 0 COMPZ PLUG PULD P Blow down top drive and POOH laying down Milling Assembly. 15:30 16:00 0.50 0 0 COMPZ PLUG OTHR P Change Out Handling Equipment 16:00 16:15 0.25 0 234 COMPZ PLUG TRIP P TIH to 234' and with 3.5" TBG. PJSM. 16:15 16:30 0.25 234 234 COMPZ PLUG SFTY P Discuss Hazard of rigging up E -Line equipment 16:30 18:00 1.50 234 254 COMPZ PLUG ELOG P Run 3 1/2" Tubing down lower to 254 -ft. Rig up a -line lubricator and tools with Expro video logging equipment. 18:00 20:00 2.00 254 254 COMPZ PLUG ELOG T Discuss SIMOPS opportunity with Seismic Coordinator. Page 15 of 37 Time Logs • 9 Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:00 22:00 2.00 254 0 COMPZ PLUG ELOG P Displace 9.6 lb/gal Brine in Well with clean Sea Water. End of Tubing at 254 -ft. Record Video pass. Move Tubing up -hole and stop at 251', 249'. At 249 -ft saw a thin section of 7" Casing and a good side -view picture of the 3 1/2" Tubing top. The 3 1/2" Tubing now is plugged with fill. Continue up -hole with stops at 245', 241', 235', and 225'. Record Video passes at each stop. Also saw the bottom section of the hole in the 9 5/8" at 226 -ft. Remainder of the Video Log is pretty much the same as the previous Logs recorded. Pull Camera to surface. 22:00 00:00 2.00 0 0 COMPZ PLUG ELOG P Download Video. Review and discuss findings with Anchorage Engineer. Rig E -line equipment off of the Well. E -Line Unit remains spotted on Location. 02/20/2011 Pull 3 1/2" Tbg. Rig up test equipment. Perform weekly BOPE test to 250/3000 psi. Discuss a Plan Forward. Run 8 -1/2" bell mill and 7" motor w/ 1.76 deg bend. Scribe BHA to surface for orientation. Orient to tubing stub. Mill from 247' to 254'. 00:00 00:30 0.50 254 0 COMPZ PLUG TRIP P PJSM. Trip out with 3 1/2" Tubing from 254 -ft. 00:30 02:00 1.50 0 0 COMPZ WHDBO BOPE P PJSM. Wash out BOP Stack with Swizzle Stick and Magnet. Set Test Plug. Rig up teset equipment. 02:00 06:00 4.00 0 0 COMPZ WHDBO BOPE P Perform weekly BOPE test per Conoco /Phillips and AOGCC requirements at 250/3,000 psi. ,pof Good. Test Annuluar at 250/3,000 r psi. Good. Recorded on Chart. (11 Perform Koomey draw down test. Good. The State's right to witness the test was waived by J. Crisp 02/19/11 at 08:30 hrs. 06:00 16:30 10.50 0 COMPZ PLUG OTHR T Discuss Plan Forward With Town and Baker Rep. Order Bent Sub And Motor from Sperry Drilling Faclitiy in Deadhorse. Shipped Mill over to Prudhoe to Have torque up on motor. 16:30 17:00 0.50 COMPZ PLUG PULD T Load Tools To Rig Floor. 17:00 19:30 2.50 0 133 COMPZ PLUG PULD T PJSM. Make up BHA #29 as follows: 8 1/2 "Bell Mill (with a 1.76 deg Bent Sub), 7" Mud Motor, 6 1/4" Oil Jar, XO, 3 ea 6 1/4" Drill Collars, XO. Note: All BHA components were "scribed" and orientated 180 deg from North. Page 16 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 00:00 4.50 133 254 COMPZ PLUG MILL T Continue in with 3 1/2" Drill Pipe to surface (scribe Drill Pipe). Expected to tag up at 250 -ft . However, keep slipping into one of the side -track holes. Plck -up hole and establish parameters as follows: Up Weight = 50K. Down Weight = 50K. Pump pressure at 9.0 bpm = 620 psi. Found a "ledge" to bite on at 246.5 -ft. However the Mill in now orientated back to the North. Begin to mill with 925 psi pump pressure and 2K WOM. Mill slipped out of milling the Track several times. After milling down to 248.5 -ft the Track was lost completely. Shut down Pump. Pick -up and poke- around trying to find a solid tag to get some kind of reference point. Found a solid tag at 252.0 -ft. Remain orientated in a Northerly direction.. Continue to mill from 252 -ft with 650- 750 psi pump pressure and 2 - 4K WOM. Progress made at Midnight: Milled from 252' -254'. Pump pressure and WOM remain the same. At the start of the 'Track" the Mill was running rough. Mill now cutting smooth....Good sign....Yippee...! 02/21/2011 Continue to mill a "track" back into the 9 5/8" Casing. Record Video Log to view progress made. Plan next BHA. Re -Rn the 8 1/2" Bell Mill with the 7" Mud Motor. Continue to make progress. Record Video Log. Video now shows the top of the 3 1/2" Tubing. Discuss the next BHA. 00:00 00:30 0.50 254 257 COMPZ PLUG MILL T Continue Milling a Track into the 9 -5/8" Casing. Mill continues to run smooth with 2 - 4K WOM. Reached our milling target of a 5 -ft track cut at 257 -ft. Mill still taking weight at target depth. 00:30 01:30 1.00 257 0 COMPZ PLUG TRIP T Blow down the Top Drive. Trip out and lay down BHA. Inspect Mill. Wear pattern on leading edge of the face and on the "Bell" in the center of the Mill. Good indicators. 01:30 02:00 0.50 0 256 COMPZ PLUG TRIP T PJSM. Ready Floor to run 3 -1/2" Tubing. Run 3 -1/2" Tubing to 265-ft. 02:00 02:30 0.50 256 256 COMPZ PLUG CIRC T Pump a 10 bbl Hi -Vis Sweep and chase back to surface with 9.6 lb/gal Brine. Page 17 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 05:00 2.50 256 256 COMPZ PLUG ELOG T PJSM with All. Rig up E -Line equipment. Pick -up Camera. Displace 9.6 lb/gal Brine with clean Sea Water. Run in with Video Camera to 250 -ft. Bring Pump on at 4.0 bpm and clean up Well. Pull Tubing up hole as needed and record Video passes. See 9 -5/8" Csg, 7" Csg, and 3 -1/2" Tubing edges at 252' - 254.2' with the side -view camera lens. It looks like the Mill has started a "Track" back into the 9 -5/8" Casing. 05:00 07:00 2.00 243 0 COMPZ PLUG OTHR T Pull Camera to surface and stand -by. Down load Video and send to Anchorage. Discuss results with Anchorage Engineer and Baker Fishing Tool Supervisors. 07:00 08:00 1.00 0 0 COMPZ PLUG PULD T Lay Down E -Line Equipment & Expro Tools. 08:00 09:30 1.50 0 134 COMPZ PLUG PULD T PJSM. Make up BHA #30 as follows: 8 -1/2 "Bell Mill (with a 1.76 deg Bent Sub), 7" Mud Motor, 6 -1/4" Oil Jar, XO, 3 ea 6 -1/4" Drill Collars, XO. Note: All BHA components were "scribed" and orientated 180 deg from North. 09:30 12:30 3.00 134 253 COMPZ PLUG MILL T Unable to Find depth that was mill earlier. Set down this time @ 252.55' md. Up wt & Down Wt= 50k. Set Parameters, pump rate @ 9 bpm, 600 psi, Wt on mill 2- 4k,working psi 660 -680 psi. 12:30 14:00 1.50 253 258 COMPZ PLUG MILL T Current Depth 257'md Milling Ahead @ 9 bpm, 680 psi. Weight on Mill 2 -4k. Work Mill down to 258'md, unable to make any more footage. 14:00 15:00 1.00 258 0 COMPZ PLUG TRIP T PJSM. B/D top drive. POOH laying milling assembly. 15:00 15:30 0.50 0 0 COMPZ PLUG PULD T PJSM. C/O Floor Equipment for 3.5" TBG. 15 :30 17:00 1.50 0 255 COMPZ PLUG TRIP T PJSM. TIH with 3.5" TBG down to 255'md. Ciruclate 20 bbl High -Vis sweep around @ 3 bpm, 60 psi. 17:00 17:30 0.50 255 255 COMPZ PLUG SFTY T PJSM with HES and Expro. 17:30 19:00 1.50 255 255 COMPZ PLUG PULD T P/U and Rig Up HES equipment and Expro Camera tools Page 18 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:00 2.00 255 247 COMPZ PLUG ELOG T Displace 9.6 lb/gal Brine with clean Sea Water. Run in with Video Camera to 250 -ft. Increase Sea Water rate to 4.0 bpm. Reduce pump rate down to 2 bpm once the Wellbore cleand up. Move Tubing up -hole in steps from 255 -ft up to 247 -ft. Record Video passes at each Tubing stop. The video clearly shows the top of the 3 -1/2" Tubing at 255 -ft. Also the 7" Casing and the 9 -5/8" Casing is shown. However, the two casing strings are not complete as there is still -50% open -hole seen when the camera is rotated and the video is recorded with the side lens. The 3 -1/2" Tubing has cement and metal cuttings between it and the 7 ". The top of the 3 -1/2" is rolled over and has a tab folded over to the inside. End Log. POOH. Lay down Camera. Rig down E -Line equipment. Discuss results with Anchorage Engineer. Down load Video. 21:00 21:30 0.50 247 0 COMPZ PLUG TRIP T PJSM. Trip out with 3 -1/2" Tubing. 21:30 00:00 2.50 0 COMPZ PLUG PULD T PJSM. Bring BHA components to Floor. Make -up and scribe BHA #31 as follows: 6" Smooth Concave Junk Mill, Extention, XO, XO, 7" Mud Motor, Oil Jar, XO Sub, 3 ea 6 -1/4" Drill Collars, XO. 02/22/2011 RIH w/ a 6" Smooth -Side Concave Junk Mill with Mud Motor. Mill f/ 259 -ft. to 262 -ft. POOH. RIH w/ RCJB to ✓ 261 -ft. POOH. RIH w/ 3 -1/2 TBG - open ended. RU Eline and RIH w/ Camera. Record video. POOH. RD Eline. POOH w/ 3 -1/2 TBG. MU and RIH w/ TBG dress off Assy to 259'. Begin attempting to mill over tubing stub. Kept getting kicked into sidetrack hole. POOH. Remove 5 -3/4" boot basket and extension from BHA. RIH w/ dress off assembly. Attempt to dress off tubing stub. Kept gettinc kicked into sidetrack hole. POOH. 00:00 05:00 5.00 259 262 COMPZ PLUG MILL T Tag up at 258.9 -ft. Up Weight = 50K. Down Weight = 50K. Pump Rate 9.0 bpm, Free Motor spin 360 psi. Tag up again and continue to control mill. Motor working pressure at 400 psi. WOM = 2 - 3K. Continue to Mill a track into the 7 ". Dress the inside of the 7" Casing and mill off the top of the 3 1/2" Tubing down to 262 -ft 05:00 05:15 0.25 262 262 COMPZ PLUG SFTY T PJSM. Discuss hazard of TOOH and laying down BHA. 05:15 06:45 1.50 262 0 COMPZ PLUG TRIP T Blow down top drive, remove hoses. TOOH laying down BHA. 06:45 07:45 1.00 0 0 COMPZ PLUG OTHR T Discuss Plan Forward With Town Engineer. Change Out Handling Equipment. Page 19 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 09:30 1.75 0 261 COMPZ PLUG FCO T Make up RCJB and RIH down to 261' and and Ciruclate @ Max Rate to clean hole. 09:30 11:00 1.50 261 0 COMPZ PLUG TRIP T PJSM. Blow down top drive. R/D hoses and POOH with clean out assembly. 11:00 12:30 1.50 0 258 COMPZ PLUG TRIP T M/U and RIH with 3.5" TBG down PJSM with HES and Expro. 12:30 14:00 1.50 0 250 COMPZ PLUG ELOG T Rig up E -Line equipment, and Expro tools and RIH to 250' md. Lost signal on a -line. POOH 14:00 15:00 1.00 250 250 COMPZ PLUG ELOG T Trouble Shot E -Line. Re -Head & change out wire on cable. Test Cable and Expro tools. All tested good. 15:00 16:30 1.50 250 250 COMPZ PLUG ELOG T RIH with E -Line and Expro Tools down to 250' and and Video Damage area. 16:30 17:00 0.50 250 0 COMPZ PLUG ELOG T POOH with e-line and down load data from log. 17:00 17:30 0.50 0 0 COMPZ PLUG PULD T Lay down E -Line and Expro Equipment. Change Out Handling Equipment. 17:30 18:00 0.50 258 0 COMPZ PLUG PULD T POOH f/ 258 -ft laying down 3 1/2 8rd TBG. 18:00 18:30 0.50 0 0 COMPZ PLUG SFTY T Held PJSM on PU and MU of BHA #33 18:30 19:00 0.50 0 13 COMPZ PLUG PULD T PU and MU 6" x 3.563" ID TBG dress off shoe assy 19:00 19:30 0.50 13 250 COMPZ PLUG TRIP T RIH w/ BHA #33 to 250 -ft. 40k up wt, 45k do wt. 19:30 20:30 1.00 250 258 COMPZ PLUG MILL T Taking wt at 258 -ft. (1 -ft. above estimatede TBG stub) attempt to clean up and wash over stub and dress off TBG stub @ 259 -ft. Rotating at 10 rpms, circulating at 168 gpm at 80 psi. Kept jumping off to the side and RIH to side track to 264 -ft. 20:30 21:15 0.75 258 0 COMPZ PLUG TRIP T POOH and lay down BHA #33 Dropped 5 3/4" OD Boot basket and Ext. 21:15 22:00 0.75 0 259 COMPZ PLUG TRIP T PU and MU BHA #34 to 10 -ft. RIH from 10 -ft to 259 -ft. 22:00 22:30 0.50 259 264 COMPZ PLUG MILL T Attempt to locate and dress off TBG stub @ 259 -ft. Rotating at 10 rpms, circulating at 168 gpm at 80 psi. Kept jumping off to the side and RIH to side track to 264 -ft. 22:30 23:00 0.50 264 0 COMPZ PLUG TRIP T POOH and lay down BHA #34. 23:00 00:00 1.00 0 0 COMPZ PLUG OTHR T Call out cross over needed to RIH w/ BHA #35 - Clean and Clear rig floor of un needed BHA components. 02/23/2011 RIH w/ Sizing Shoe to 259 -ft. - unsuccessful, POOH and RIH w/ 6" Concave Mill on mud motor and attempt to locate TBG stub - Unsuccessful. POOH with BHA #36 and drop DC's. RIH w/ BHA #37 - not able to stay on TBG stub - POOH and discuss options w/ ANC engr. Order out tools and standby - Field went to Phase III weather conditions - standby for weather. Page 20 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 COMPZ PLUG OTHR T CaII out cross over needed to RIH w/ BHA #35 - Clean and Clear rig floor of un needed BHA components. 01:00 02:00 1.00 0 255 COMPZ PLUG TRIP T MU and RIH w/ 3 1/2 Sizing BHA #35 to 231 -ft and tagged up had to rotate down to 237 -ft before able to slide in hole to 255 -ft. and tagged up. 02:00 03:30 1.50 255 259 COMPZ PLUG MILL T Mill down and jumped off, possibly 7" casing sliver along side of 3 1/2 TBG. Continue to work down from 255 -ft. to 259 -ft. Not able to stay on stub as before. 03:30 04:00 0.50 259 0 COMPZ PLUG TRIP T POOH w/ BHA #35. No signs of on shoe. 04:00 04:30 0.50 0 0 COMPZ PLUG OTHR T Bring in tools for BHA # 36 04:30 04:45 0.25 0 0 COMPZ PLUG SFTY T Held PJSM on PU and MU BHA #36 04:45 10:00 5.25 0 256 COMPZ PLUG MILL T PU and MU BHA #36 (6" Concave mill assy on 7" Mud motor w/ 1.76 bend.) scribing in the hole to 143 -ft. Continue to hole with 3.5" TBG scribing down and set down with Mill at 262' ms. PUH 2' and set parameters @ 9 bpm, 420 psi Up and Down Wt= 50k. Unable to establish a milling patterns after several attempts. Would set down in the same spot and slid off to the open hole section. PJSM. Blow down top drive and TOOH to inspect milling assembly. 10:00 11:00 1.00 256 0 COMPZ PLUG MILL T OOH with milling assembly. Mill showed no sign of wear or damage. MU same milling assembly and left the drill collars off and use just drill pipe. ( BHA #37) 11:00 15:15 4.25 0 262 COMPZ PLUG MILL T PJSM. RIH with milling assembly and set down at 235' md, after rotating and working work string up and down was able to work BHA passed tag depth. Continue in hole and set down at 261' md, puh and set parameters, 9 bpm at 450 psi, up and down wt =50k. Mill continue to roll off stub or junk in the hole. Continue to rotate bent motor to find top of stub. NO -GO. PUH to 250' and and rih again to try and locate 3.5" tbg stub. Set down at 257' and and was unable to locate. Mill continues to roll off the tbg and down into the open hole section. 15:15 15:30 0.25 262 262 COMPZ PLUG MILL T Blow Down top drive. PJSM. 15:30 17:00 1.50 262 0 COMPZ PLUG TRIP T POOH and lay down milling assembly and discuss next option with town engineer. Page 21 of 37 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 21:00 4.00 0 0 COMPZ PLUG OTHR T Wait On Flat Bottom Shoe From Deadhorse. 21:00 00:00 3.00 0 0 COMPZ PLUG OTHR T Standby for weather - went to phase 3 conditions at 21:00 hrs 00:00 06:30 6.50 0 0 COMPZ PLUG OTHR T Start Digging out from Phase 3 Condition. 02/24/2011 Continue to standby on weather hold. Dig out and check equipment along with secondary containment. PU and MU BHA #38 - 4 -3/4" guide shoe on 3 -1/2" drill pipe and RIH. Able to go over stub. Pull off stub. Attempt to go over stub again - unsuccessful. POOH. RIH w/ 4- 11/16" overshot (includes packoff but no grapple) on 3 -1/2" tubing to 262' md. RU E -Line and RIH w/ camera. Video shows BHA outside casing. Reposition workstring several times and run videos. Workstring is still outside casing. POOH and bend 3 1/2 TBG jt. RIH w/ BHA #41 - 4 -3/4" guide shoe on 3 -1/2" tubing with bent joint on bottom. RU E -Line and RIH with camera. 00:00 06:30 6.50 0 0 COMPZ PLUG OTHR T Standby for weather - went to phase 3 conditions as of 21:00 hrs on Wednesday 2 -23 -11 06:30 07:30 1.00 0 0 COMPZ PLUG OTHR T Start Digging out from Phase III condition. Check All Equipment and Secondary Containment under equipment. 07 :30 07:45 0.25 0 0 COMPZ PLUG SFTY T PJSM. Discuss Plan Forward with Next BHA. 07:45 08:00 0.25 0 0 COMPZ PLUG PULD T Break Down 4.5" Guide Shoe and Inspect. Found bad threads on Crossover connection. Remove and Replace. 08:00 09:30 1.50 0 259 COMPZ PLUG TRIP T P/U and Make Up BHA #38 and 3.5" Drill Pipe.Continue in hole and set down @ 227.50' md, had to rotate pass damage area inside 9 5/8" CSG. Continue in hole and set down at 263.70' md, puh to 248' and & rotated back in and set down at 256' and and rolled passed stub. Up & down wt =45k. Set down again at 255.50', 256.0' and 257.50' and rolled pass again. PUH to 250' and and continue back in hole rotating and set down at 257.05' and and was able to find top of 3.5" stub. Continue to rotate down until we bottom out inside 4.5" Shoe guide, continue to rotate while up 1' and down a 1', was able to stay on 3.5" stub from 257.05' to 259.25' md. 09:30 10:00 0.50 259 259 COMPZ PLUG OTHR T Pulled off stub to confirmed that we can get on and off 3.5" stub. Unable to locate stub again. 10:00 11:00 1.00 259 0 COMPZ PLUG TRIP T PJSM. TOOH and inspect bottom of shoe. Tattle tales gone out of shoe. Appear to have had something inside 1' + - feet. 11:00 11:30 0.50 0 0 COMPZ PLUG PULD T Swap out handling equipment. Page 22 of 37 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 11:30 12:30 1.00 0 262 COMPZ PLUG TRIP T TIH with 3.5" TBG and 4 11/16" Overshot w/ 3.5" Dressed Guide. Dressed w/ 3.5" Type A Packoff and No Grapple, down to 262'md. Rig up TIW valve and pump & Sub. 12:30 13:15 0.75 262 262 COMPZ PLUG ELOG T Wait on E -line to have Crew Change Out. 13:15 13:30 0.25 262 262 COMPZ PLUG SFTY T PJSM, with new E -line crew on location. Discuss Hazards of rigging up a -line and expro video tools. 13:30 17:00 3.50 262 262 COMPZ PLUG ELOG T Rig up E -Line Equipment and Expro Video Logging Tools. Attempt to video top of 3.5" TBG. Video showed that the 3.5" work string was outside the 9 5/8" CSG. Made several attempts to enter into 9 5/8" x 7" CSG with 3.5" work string. No Luck. Run out of clean fluid, had to release vac truck to get another load of Seawater. 17:00 17:30 0.50 262 0 COMPZ PLUG TRIP T POOH while waiting on more fluid to replace bottom shoe drive sub above shoe. 17:30 18:00 0.50 0 262 COMPZ PLUG TRIP T Run Back in with 3.5" Work String to 262' md. 18:00 18:30 0.50 262 262 COMPZ PLUG ELOG T Wait on FLuid. Hold PJSM with Eline and RU Eline 18:30 21:30 3.00 262 262 COMPZ PLUG ELOG T Pump 20 bbls SW at 2 bpm at 10 psi. RIH w/ camera - move pipe accordingly. Not able to see TBG stub, everything wanting to go on the outside. POOH and decentralize camera, RIH and same affect. POOH and RD Eline. 21:30 22:00 0.50 262 0 COMPZ PLUG TRIP T POOH w/ BHA #40 and Bend jt of 3 1/2 TBG in the middle. 22:00 22:30 0.50 0 261 COMPZ PLUG TRIP T RIH w/ BHA #41 to 261 -ft. 22:30 00:00 1.50 261 261 COMPZ PLUG ELOG T RU Eline and camera. Pump 20 bbls at 10 psi. RIH w/ camera. 02/25/2011 POOH w/ camera and RD E line. Pull pup jt and shut well in and Monitor well - phase III. 00:00 03:00 3.00 261 256 COMPZ PLUG ELOG T Verify TBG stub and POOH with camera. RD E line. Pull Pup jt w/ tail at 256 -ft. 03:00 00:00 21.00 256 256 COMPZ PLUG OTHR T Standby for Phase 111 conditions and monitor well. 02/26/2011 Continue to standby on weather hold. Dig out secondary containment and all other areas needed to go back to work. Change hole over to 9.6 ppg KWF and POOH with BHA # 41. Set test plug in preparation for weekly BOP Test. 00:00 15:00 15.00 256 256 COMPZ PLUG OTHR T Standby for Phase III conditions and monitor well. 15:00 23:00 8.00 256 256 COMPZ PLUG OTHR T Phase II Weather Condition. Start Digging Out Equipment. 23:00 23:30 0.50 256 0 COMPZ PLUG TRIP T Change hole over from seawater to 9.6 ppg brine, POOH from 256 -ft and lay down BHA #41 Page 23 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 0 COMPZ WHDBO MPSP P Set 11" Test plug in preparation for weekly BOP Test. 24 hr Notice was given at 7:05 hrs on 2- 26 -11, Right to witness test was waived by Chuck Scheve at 17:40 hrs on 2 -26 -11 02/27/2011 Conduct weekly BOP Test at 250 / 3,000 psi. 24 hr Notice was given at 7:05 hrs on 2- 26 -11, Right to witness test was waived by Chuck Scheve at 17:40 hrs on 2- 26 -11. PU and RIH w/ BHA # 42 - 4.5 "x3 -5/8" cut lip shoe on 3 -1/2" tubing to top of fish. Work shoe over fish. RU E -line and run video log to confirm over fish. POOH w/ E -Line and RD. Mill down 2' on tubing stub. RU E -Line and run video log. Tubing stub is still inside shoe. POOH w/ E -Line and RD. Mill down 3' more on tubing stub. RU E -Line and RIH. Cut tubing at 112 -ft. POOH w/ E -Line and RD. 00:00 06:00 6.00 0 0 COMPZ WHDBO BOPE P Conduct weekly BOP Test, 250/3000 psi. 24 hr Notice was given at 7:05 hrs on 2- 26 -11, Right to witness test was waived by Chuck Scheve at 17:40 hrs on 2 -26 -11 06:00 07:00 1.00 0 0 COMPZ PLUG PULD T Clear Floor of Tools and Un- needed equipment. 07:00 07:15 0.25 0 0 COMPZ PLUG SFTY T PJSM. Discuss Hazard of Making Up BHA. 07:15 14:00 6.75 0 263 COMPZ PLUG FISH T Make up BHA #42. 4.5" x 3 5/8" Cut Lip Shoe on 3.5" TBG work String. RIH and set down @ 262.6' md, made several attempts to find top of 3.5" TBG stub, with no success. Had to order more fuild. 14:00 15:00 1.00 263 256 COMPZ PLUG ELOG T Fluid on location, continue to find TBG stub. Able to find tbg stub at 257'md. POOH and lay down a -line equipment and expro tools. 15:00 16:30 1.50 256 258 COMPZ PLUG MILL T PJSM. Pick -up PUP joint and MU top drive. Set Parameters, 1.0 bpm at 30 psi, rotating @ 10 rpm. Start burning over stub, 1 -1.5k down on shoe. Milled down 2' feet. Bleed down top drive. 16:30 17:30 1.00 258 258 COMPZ PLUG ELOG T R/U E -line equipment and Expro tools again. Rlh and found 3.5" TBG top at 258.4 and ( 2 foot) inside Burn over assembly. POOH and RIG back E -Line and Expro. 17:30 19:00 1.50 258 261 COMPZ PLUG MILL T Continue to burn over 3.5" TBG stub three more feet. 19:00 21:30 2.50 261 261 COMPZ PLUG ELNE T Held PJSM, RU E line and RCT tools. RIH to 230 -ft and run strip log for cutting purposes. Prepare to cut and found kill line was froze up, so we suspended ops to thaw out kill line. 21:30 23:00 1.50 261 261 COMPZ PLUG OTHR T Found kill line to be frozen at rig and kill tank - thaw out lines. 23:00 00:00 1.00 261 261 COMPZ PLUG ELNE T Cut TBG at 112 -ft. POOH and RD E line equipment. Page 24 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/28/2011 24 hr Summary Continue to RD E -line. POOH from 112'. PU and RIH w/ overshot and scoop head deployment sleeve to 112'. Engage tubing stub. Release from deployment sleeve with top at 100'. POOH. PU 2.74" mill & 2 -1/8" motor assy and RIH on 2- 1/16" tubing and 3 -1/2" tubing. Tag at 259'. Begin milling. Mill down to 295' circulating 12 ppg brine. POOH. Run 3 -1/2" tubing to 94'. RU Slickline. Work bailer from 302' down to 355'. Recovered metal shavings. No recovery on second bailer run. RD slickline. POOH with tubing from 94'. RIH with 2.74" mill & 2 -1/8" motor assy and RIH on 2- 1/16" tubing and 3 -1/2" tubing. Tag at 358'. Mill junk from 358' to 368' then able to RIH to 418'. POOH. RU slickline. Run bailer and bail from 430' -456'. Run impression blocks and bailers. Could not get past 456'. Decide to remove deployment sleeve. RU E -Line. 00:00 01:00 1.00 261 261 COMPZ PLUG ELNE T Continue to RD Eline and remove from rig floor 01:00 01:30 0.50 112 0 COMPZ PLUG TRIP T POOH from 112 -ft - RCT cut. 01:30 02:00 0.50 0 0 COMPZ PLUG SFTY T Held PJSM with Baker on PU and MU of BHA #43 02:00 02:30 0.50 0 112 COMPZ PLUG FISH T PU and MU BHA #43 - 5 3/4 OS w/ 7 1/4" Oversized Guide, 10 -ft -3 1/2 8rd Pup jt, Scoop Top Deployment sub, 5" GS Spear, X -O, and RIH to 112 -ft and Engage tbg stub. Pull up 100k - had 30" of movement, Slack off to neutral and pump at 4 bpm and release GS Spear off Scoop head deployment sub at 100 -ft. 02:30 03:00 0.50 100 0 COMPZ PLUG TRIP T POOH and lay down BHA #43 03:00 03:30 0.50 0 0 COMPZ PLUG OTHR T Change over TBG handling equipment to 2 1/16" 03:30 04:30 1.00 0 259 COMPZ PLUG TRIP T PU and MU BHA #44 2.74" Parabolic mill, 2 1/8" Extreme motor, dual circ sub, hydrualic disconnect, dual back pressure valve, oil jar, cross over sub to 2 1/16" CS Hydril TBG, 7 jts of 2 1/16 Hydril TBG, 2- crossovers to 3 1/2 8rd TBG to 234 -ft. PU 1 jt 3 1/2 8rd working joint and Tag up at 259 -ft. 04:30 06:30 2.00 259 295 COMPZ PLUG MILL T MU head pin and begin milling at 259 -ft circulating with 12 ppg NaBr brine at 1 bpm, 290 psi. Work Mill down to 295' md. 06:30 08:00 1.50 295 0 COMPZ PLUG TRIP T PJSM. POOH and L/D BHA #44, milling assembly. Clear Floor. Pick -Up 3.5" TBG, RIH to 94' Secure well. 08:00 11:30 3.50 94 94 COMPZ PLUG SLKL T PJSM with Slick -line crew. Rig up slick -line to rig floor. M/U and RIH with 2.25" Bailer and sat down at 302' slmd, continue to work slick -line bha down to 355' slmd. POOH to bailer and found small shaving of metal. M/U and RIH with 1.25" Bailer and sat down again at 355' slmd, work wire, no footage made. POOH and had more metal shaving inside bailer. Lay down slick -line equipment. Page 25 of 37 • . Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 11:30 15:15 3.75 94 354 COMPZ PLUG MILL T PJSM. Pull and Lay down 3.5" TBG. M/U 2 1/16 Hydrill BHA with 2 1/8" Extreme Motor and 2.74" Parabolic Milling assembly. RIH and sat down at 354'md. Start Milling @ 3/4 bpm, 210 psi. Milled from 354' and down to 418' md. Milled on junk in TBG from 358' and to 368' md. Remove hoses. 15:15 16:15 1.00 418 0 COMPZ PLUG TRIP T PJSM. POOH and lay down Milling BHA Assembly. 16:15 22:00 5.75 0 456 COMPZ PLUG SLKL T Held PJSM, RU lubricator and 1.5" OD Bailer, RIH to 430 -ft sim and work down to 456 -ft. POOH and recovered metal shavings. MU and RIH w/ 2.25" Impression block, POOH -had trash inside middle of impression block. MU and RIH w/ 2.25" Bailer - recovered small rocks and metal shavings. RIH w/ chisel poker and - not able to bust through. RIH w/ 2.25" OD Bailer and recovered same. RIH w/ 2.25" OD magnet and recovered the same. RIH w/ 2.25" OD chesil bottom bailer - recovered the same. Not able to get past 456 -ft. RD slick line unit and pull off to the side. 22:00 22:30 0.50 0 0 COMPZ PLUG SFTY T Held PJSM with e line on rigging up and cutting of 3 1/2 TBG. 22:30 00:00 1.50 0 0 COMPZ PLUG ELNE T Re head line and RU to cut TBG 03/01/2011 RI I F line and rift TBG at 116'. BD E line. Fish scoop head deployment sub assy and POOH. RIH w/ 5 3/4" OS and engage fish at 116'. Pull tubing to 110k and set in slips. RU Slickline and bail from 456' to 540' as of midnight. Saw 40 psi gas pressure on tubing after bailing through bridge at 468' and chasing junk to 490'. Appears to be trapped pressure from hydrates possibly. Fill tubing with 26 bbls 12 ppg brine by pumping down tubing. Probably leaking out the overshot. Inner annulus is still taking fluid to casing leak. 00:00 03:00 3.00 0 0 COMPZ PLUG ELNE T RU to cut TBG, RIH w/ RCT to 260 -ft and log up - tie in and cut TBG at 116 -ft. POOH and RD E line. 03:00 04:00 1.00 0 116 COMPZ PLUG FISH T MU and RIH w/ BHA #46 (GS Spear assy) and engage fish at 100 -ft. POOH w/ scoop head deployment sub and OS. Recovered 4.75 -ft of 3 1/2 TBG below deployment sleeve assembly. 04:00 04:30 0.50 0 106 COMPZ PLUG FISH T RIH w/ BHA #47 (5 3/4 OS w/ 7.25" OD Oversized cut lip guide) to 106 -ft. 04:30 05:00 0.50 106 106 COMPZ PLUG CIRC T Change hole over 12.0 ppg NaBr Brine to 9.6 ppg brine from 106 -ft 05:00 05:30 0.50 106 116 COMPZ PLUG FISH T RIH to 116 -ft and engage 3 1/2 TBG stub, Pull up to 110k and set slips. Break out pup jt and prepare for RU of slick line. 05:30 06:00 0.50 0 0 COMPZ PLUG SLKL P Slick line on location, PJSM, Rig up SLU Page 26 of 37 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:00 00:00 18.00 0 540 COMPZ PLUG SLKL P Continue Bailing Metal Shavings from TBG @ 456' SLMD. Recovered piece of 7" CSG, metal shavings and fill. Bailing at 540 -ft as of midnight. Saw 40 psi of gas pressure on surface after bailing thru bridge at 468 -ft and chased junk to 490 -ft. Fill TBG w/ 26 bbls of 12.0 ppg NaBr Brine as of Midnight. Having to pump down tubing and fluid is probably leaking out the overshot. IA was on Trip Tank and had 10.3 bbl loss of 9.6 ppg brine from 05:00 hrs to 24:00 hrs. 03/02/2011 Continue to bail out metal shavings and junk inside TBG from 540' to 551'. Swage top of tubing stub out to 2.82" at 258'. Continue to bail out metal shavings and junk inside tubing from 551' to 574'. Saw 220 psi pump pressure while proactively filling tubing w/ 2 bbls 12.0 ppg brine. IA fluid level static. Continue bailing recovering sand /hydrates. Proactively load tubing w/ 20 bbls 12.0 ppg brine. See 500 psi max pump pressure. Overshot packoff appears to be holding until pumps are engaged and then fluid leaks by. Will visually monitor tubing fluid level after each slickline run. Continue bailing 574' to 591'. Run magnet and recover grapple pieces. Continue bailing to 645' as of midnight recovering hydrates. Fluid levels remain constant in tubing and annulus. No gains or losses. 00:00 04:30 4.50 540 551 COMPZ PLUG SLKL P Continue to bail out from 540 -ft. to 551 -ft. Recovering metal shavings, fill and miscjunk metal pieces. Ran 2.75" OD Swage and 2.82" OD Swage and swage out TOF at 258 -ft. Recovered Tang from 4 3/4" Spiral grapple (2nd BHA) ran, 04:30 05:00 0.50 551 562 COMPZ PLUG SLKL P Continue Bailing Metal Shavings from TBG @ 551' SLMD. Recovered pc of 7" CSG, metal shavings and fill. Seen 220 psi of pump pressure while filling TBG w/ 2 bbls with 12.0 ppg NaBr Brine. IA was on Trip Tank maintaining static fluid level of 19.5 bbls in trip tank. 05:00 17:00 12.00 562 574 COMPZ PLUG SLKL P Continue Bailing operations, current depth is 574' SLMD. Recovering sand /hydrates. 20 bbls total pumped, Max pressure observed was 500 psi while pumping Overshot packoff appears to be holding until pumps are engaged and + - 200 psi is applied. Begin visually monitoring fluid levels after each slickline run. Fluid level remaining constant in tubing and annulus. No Gains or Loses. Page 27 of 37 i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 00:00 7.00 562 643 COMPZ PLUG SLKL P Continue Bailing operations, Bailed from 574 -ft to 591 -ft as of 19:00 hrs, seen multiple set downs while running same BHA , RIH w/ magnet and recovered 3 more pcs of spiral grapple - after putting the pcs together it was found to have come from the overshot at 259 -ft. current depth is 643' SLMD. w/ 2.25" Bailer, Recovering Hydrates. Fluid levels remain constant in tubing and annulus. No Gains or Loses 03/03/2011 Continue to bail out Hydrates from TBG - tagged solid spot at 960'. Attempt to swage out with 1.61 and 2.39" OD swages. 00:00 06:00 6.00 643 745 COMPZ PLUG SLKL P Continue Bailing operations, Bailed from 643' to 745' as of 06:00 hrs, ROP 17 -ft/hr . Recovering Hydrates. Fluid levels remain constant in tubing and annulus. No Gains or Loses 06:00 12:00 6.00 745 854 COMPZ PLUG SLKL P Continue Bailing operations, Bailed from 745' to 854' as of 12:00 hrs, ROP 18 ft/hr. Fluid levels remain constant in tubing and annulus. No Gains or Loses 12:00 16:30 4.50 854 960 COMPZ PLUG SLKL P Continue Bailing operations, Bailed from 854' to 960' as of 16:30 hrs, ROP 23.5 ft/hr. Fluid levels remain constant in annulus. Added 3 bbls of 12.0 ppg NaBr to TBG at 15:30 hrs. 16:30 22:30 6.00 960 961 COMPZ PLUG SLKL T Continue Bailing operations. Bailed at 960' from 16:30 hrs to 23:50 hrs. Ran misc bailers, LIB and magnets. Pinched in 2.25" mule shoe. Lay down Lubricator and prep for pulling more tension in tubing. 22:30 23:00 0.50 961 961 COMPZ PLUG OTHR T Set TBG in more tension - pull an additional 20k above the original setting of 110k. Set in slips to assist in straightening pipe. 23:00 00:00 1.00 961 961 COMPZ PLUG SLKL T Attempt to swage out TBG w/ 1.61" OD swage and 2.39" OD swage - making progress. 03/04/2011 Continue to attempt to swage out tight spot in TBG at 961' - unsuccessful. RD Slick line and RU E line. Cut TBG at 915'. RD Eline, Circ hole full of 12.0 ppg brine. Pull 33' and tubing hung up. Circulate heated 11.6 ppg brine and tubing came free. POOH laying down tubing and overshots. 00:00 04:00 4.00 961 961 COMPZ PLUG SLKL T Attempt to swage out TBG w/ 1.61" OD swage and 2.39" OD - making hole. 04:00 11:00 7.00 961 961 COMPZ PLUG SLKL T Attempt to RIH w/ 1.16" OD Swage, 1" x 5 -ft. wt bar, 2.21" OD swage - not able to go past 961'. POOH w/ slickline. Slack off tubing to 60k. RIH w/ 1.16" OD Swage, 1" x 5 -ft. wt bar, 2.21" OD swage - not able to go past 961'. Page 28 of 37 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:30 2.50 961 0 COMPZ PLUG ELNE T PJSM RDMO Slick Line, PJSM MIRU E -Line 13:30 15:30 2.00 0 950 COMPZ PLUG ELNE T RIH with E -Line log ccl down to tag, Cut 31/2 tubing at 915' ELMD RD ELINE. 15:30 16:30 1.00 950 950 COMPZ PLUG CIRC T Circulate 12.0 ppg NaBr Brine @ 1.75 bpm @ 530 psi. 16:30 17:00 0.50 950 950 COMPZ PLUG SFTY T Held PJSM on laying down tubing 17:00 17:30 0.50 950 917 COMPZ PLUG PULL T Pull 8 -ft pup jt, and 25 -ft of 1st joint of 3 1/2 TBG - hung up 17:30 19:00 1.50 917 917 COMPZ PLUG CIRC T Circulate in attempt to thaw out well w/ 12.0 ppg NaBr brine at 3 bpm at 370 psi. 19:00 20:30 1.50 917 917 COMPZ PLUG PULL T Work 3 1/2 TBG in attempt to free up, while heating up 11.6 ppg brine in rig pits to 80 degrees to help clear hydrates. Circulate bottoms up at 4 bpm at 70 psi. Tubing came free and was able to move up and down. 20:30 21:00 0.50 917 917 COMPZ PLUG OWFF T Monitor well for flow, hole taking fluid. Blow down top drive. 21:00 22:30 1.50 917 0 COMPZ PLUG PULL T POOH laying down 3 1/2 TBG and 2 overshots. Tubing cut was excellent. 22:30 00:00 1.50 0 0 COMPZ PLUG PULD T PU overshots with fish engaged and release off, and lay down same 03/05/2011 RIH and attempt to engage TBG stub at 915 -ft - Unsuccessful. POOH and make multiple runs in attempt to clean off TBG stub - Not able to get into 7" CSG stub at 260 -ft. Dress off 7" CSG stub w/ string mill. RIH w/ 3 1/2 TBG dressing shoe - not able to get past 260 -ft. RU and Prepare for weekly BOP Test. Begin weekly BOP Test. 00:00 03:00 3.00 0 551 COMPZ PLUG TRIP T PU and MU BHA # 48 ( 5 3/4" Overshot) and RIH on 3 1/2 DP to 255 -ft. Work inside of the 7" CSG stub at 260 -ft. and RIH to 551 -ft. We had to work down from 519 -ft to 551 -ft. 03:00 03:30 0.50 551 551 COMPZ PLUG CIRC T Circulate surface to surface at 4 bpm at 80 psi 03:30 04:00 0.50 551 910 COMPZ PLUG FISH T Continue to PU 3 1/2 DP and RIH w/ BHA #48 from 551 -ft to 910 -ft. 50k up and do wt 04:00 05:00 1.00 910 916 COMPZ PLUG FISH T Attempt to engage fish, circulating at 4 bpm at 90 psi, rotating at 0 to 20rpms, 500 ft/Ibs free torque, up to 1,100 fUlbs on bottom torque with 0 to 20k slack off wt. 05:00 06:00 1.00 916 0 COMPZ PLUG TRIP T Blow down top drive. POOH and inspect overshot. 06:00 08:00 2.00 0 251 COMPZ PLUG TRIP T MU and TIH with BHA #49-6" flat bottom shoe on 3 -1/2" drill pipe with bent joint on bottom. Unable to work past bad spot in casing at 251'. POOH. 08:00 09:30 1.50 0 915 COMPZ PLUG TRIP T MU RIH with BHA #50 -4 -3/4 "x3/5/8" shoe on 3 -1/2" drill pipe with bent joint on bottom. RIH to 915', 50K UP /50K DWN. Page 29 of 37 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 09:30 11:00 1.50 915 916 COMPZ PLUG MILL T Dress off tubing stub @ 915', 1.5 BPM,60 PSIG, 0 -30 RPMS 11:00 12:00 1.00 916 916 COMPZ PLUG MILL T Dress off -1/2 FT. Roll hole over to 12# brine. 12:00 13:30 1.50 916 0 COMPZ PLUG TRIP T POOH & lay down BHA #50. 13:30 14:30 1.00 0 260 COMPZ PLUG TRIP T PU and MU BHA #51(5 3/4" OD x 4 1/2" ID Sizing shoe assy), RIH to 260 -ft. Not able to work past. 14:30 15:30 1.00 260 0 COMPZ PLUG TRIP T POOH and laydown BHA #51(5 3/4" OD x 4 1/2" ID Sizing shoe assy) 15:30 16:30 1.00 0 255 COMPZ PLUG TRIP T PU and MU BHA #52 (6 1/16" OD String mill assy), RIH to 255 -ft. Y) 16:30 19:00 2.50 255 262 COMPZ PLUG MILL T Dress off window at 20 rpm's with 900 -1100 ft/Ibs of torque, circulating at 6 bpm at 90 psi from 255 to 262 -ft. 19:00 19:30 0.50 262 262 COMPZ PLUG OWFF T Blow down Top drive, monitor well for flow - well taking fluid 19:30 20:00 0.50 262 0 COMPZ PLUG TRIP T POOH and lay down string mill. 20:00 20:30 0.50 0 42 COMPZ PLUG PULD T PU and MU BHA #53 (5 3/4" OD x 4 1/2" ID Sizing shoe assy) to 42 -ft. 20:30 21:00 0.50 42 263 COMPZ PLUG TRIP T RIH w/ BHA #53 to 263 -ft - not able to enter 7" CSG stub 21:00 21:30 0.50 263 0 COMPZ PLUG TRIP T POOH and Lay down BHA #53 21:30 22:00 0.50 0 0 COMPZ PLUG PULD T PU and MU BHA #54 (5 3/4" OD x 4 1/2" ID Sizing shoe assy w/o WP ext.) Lay down on skate. 22:00 22:30 0.50 0 0 COMPZ WHDBO WASH P PU and MU String Magnet and BOP wash tool. Wash out BOP cavaties 22:30 23:00 0.50 0 0 COMPZ WHDBO MPSP P Suck out BOP Stack and set 11" Test plug. RU test equipment. 23:00 00:00 1.00 0 0 COMPZ WHDBO BOPE P Conduct weekly BOP Test at 250/3,000 psi. 24 hr notice was given to AOGCC on 3 -6 -11 at 06:00 hrs and right to wittness was waived by Bob Noble at 06:05 hrs on 3 -5 -11. 03/06/2011 Continue to Conduct weekly BOP test. MU and RIH w/ BHA# 54 (5 3/4" Shoe) to 916 -ft and wash over to 918 -ft. POOH and RIH w/ BHA #55 (5 3/4" Overshot) to 917 -ft. CBU, and Engage Fish at 919 -ft. Back off r/ TBG - gain 5k wt. Attempt to Circ. - No circulation. POOH f/ 1,400 -ft± to 1,170 -ft.±. Observe fluid swap out. Monitor well on trip tank w/ 9.6 ppg Brine and switch to 12 ppg NaBr Brine, returning 9.7 ppg thru TBG. 00:00 11:00 11.00 0 0 COMPZ WHDBO BOPE P Conduct weekly BOP Test at 250/3,000 psi. 24 hr notice was given to AOGCC on 3 -6 -11 at 06:00 hrs and right to wittness was waived by Bob Noble at 06:05 hrs on 3 -5 -11. 11:00 12:00 1.00 0 915 COMPZ PLUG TRIP T PJSM. MU and RIH w/ BHA #54 - 5-3/4" shoe assembly 12:00 13:15 1.25 914 916 COMPZ PLUG MILL T On Bottom with 5 3/4 shoe. Attempt to wash over tubing stub. Able to wash over tubing. Tagged top of tbg 8' in on joint #28, washed down an additional 2' over tbg stub. PUH shut down top drive and wash over stub without rotating. 13:15 13:30 0.25 916 916 COMPZ PLUG CIRC T Circulate around 9.6# Brine Page 30 of 37 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:15 0.75 916 0 COMPZ PLUG TRIP T POOH and lay down BHA #54 ( 5 3/4 shoe) 14:15 14:45 0.50 0 0 COMPZ PLUG PULD T PJSM, MU 5 3/4 OS w/ grapple for 3.5" tubing & mill control packoff. 14:45 15:30 0.75 0 915 COMPZ PLUG TRIP T RIH to 915'. 15:30 16:40 1.17 917 1,400 COMPZ PLUG BKOF T Circ Bottoms Up 9.6# Brine, Work tubing and perform back -off. 50k up /50k Dwn Notice break on third turn, worked a total of 13 turns. Up weight 55 -56k looks like +- 500' of tubing backed off. 16:40 17:29 0.83 1,400 1,400 COMPZ PLUG CIRC T Break Circulation at 1 bpm at 250 psi, pressure increased while attempting to get circulation. Was not able to establish circulation. 17:29 17:59 0.50 1,400 1,170 COMPZ PLUG TRIP T POOH from —1,400-ft. to —1,170-ft. Observed fluid swap out. 17:59 23:59 6.00 1,170 1,170 COMPZ PLUG OWFF T Monitor well on trip tank with 9.6 ppg brine, taking returns to pits from TBG. Change Trip tank from 9.6 ppg brine to 12.0 ppg NaBr Brine and continue to swap hole volume. 12 ppg in annulus is swapping with lighter fluid in tubing. Had 36 bbl Toss of 9.6 ppg Brine and 73 bbl loss of 12.0 ppg NaBr brine. 33/07/2011 Continue to swap hole over to 12.ppg NaBr brine by loading IA with 12 ppg fluid and taking returns thru tubing. Pump down drill pipe with 11.8 ppg and was able to establish circulation. Pump 390 bbl to condition hole. Monitor well - on vacuum. RIH to bottom — 1400'. Circ 100 bbls 11.8 ppg for bottoms up. Monitor well for flow. Annulus taking fluid from trip tank. POOH standing back drill pipe and laying down tubing fish. Recovered 519' of 3 -1/2" tubing. Pin looking up in hole. PU and RIH w/ 3 1/2 TBG to 1,436'. Screw into TBG stub. Set tubing in slips with 110K tension. Pump 1/2 bbl and tubing pressured up to 1000 psi. Bleed off pressure. Pressure test 3 -1/2" TIW valve to 250/3000 psi. 00:00 05:00 5.00 1,170 1,170 COMPZ PLUG OWFF T Monitor well on trip tank with 9.6 ppg brine, taking returns to pits from TBG. Change Trip tank from 9.6 ppg brine to 12.0 ppg NaBr Brine and continue to swap hole volume down annulus 05:00 10:00 5.00 1,170 1,170 COMPZ PLUG CIRC T Pumping 11.8# down DP 1/2 BPM @ 300 PSIG, Pumped total of 15 bbls. shut down monitor well, Monitor for 20min DP came up to 40 -50 psig, Circulate 2 BPM dwn DP, DP psi slowly climbing to 600 psig then dropped off to charge pressure. 10:00 12:00 2.00 1,170 1,170 COMPZ PLUG CIRC T Circ around 11.8# for 390bbls, shut down and monitor well. Tour Change. DP on slight vac 12:00 12:45 0.75 1,170 1,450 COMPZ PLUG TRIP T DP still on slight vac. TIH back to BTM +- 1450' (est.) 12:45 14:00 1.25 1,450 1,450 COMPZ PLUG CIRC T Begin circulating 11.8# off bottom, 100bbI bottoms up pumped 170 ICP ,210 FCP, shut down monitor well for flow. Annulus continues to take fluid from trip tank Page 31 of 37 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:00 15:30 1.50 1,450 600 COMPZ PLUG TRIP T Begin TOOH racking back DP 15:30 16:00 0.50 600 600 COMPZ PLUG PULD T DP & BHA Layed Down, Swap floors over to lay down 3.5" Tubing 16:00 17:30 1.50 600 0 COMPZ PLUG TRIP T Begin lay down 3.5" Tbg. Recovered Total of 16 full jts, 1 cut joint, 7 whole bands, 1 partial, Total of 518.65' of 3.5" TBG with Pin looking up in the hole. Broke down overshot and found 1 piece of metal on top of TBG stub that was acting as a flapper valve while attempting to circulate. This was the only restriction found in 3 1/2 Production TBG pulled. 17:30 21:00 3.50 0 1,436 COMPZ PLUG FISH T Fabricate cut lip 3 1/2 TBG Cplg. RIH w/ 1 bent jt of 3 1/2 TBG, 3 1/2 x 2.875" Profile nipple, 45 jts of 3 1/2 L -80 8rd TBG. Tag up on TBG 50k up and do wt., mark for spaceout, Pull jts 45 and 44, install 2 -8 -ft x 3 1/2 TBG pups and 1 -10 -ft x 3 1/2 TBG pup and RIH w/ jts 44 and 45. Screw in with top drive and MU to fish at 1,436 -ft. Set TBG in slips at 110k. Pump 1/2 bbl and Pressured up to 1,000 psi. Held pressure, bleed off and Lay down jt 45. 21:00 23:30 2.50 0 0 COMPZ PLUG OTHR T RU for slick line, Offload all un needed fishing tools. 23:30 00:00 0.50 0 COMPZ WHDBO BOPE P Test 3 1/2 IF TIW Valve at 250/3,000 psi. This valve was shut to prevent flow of fluids from well on 3/6/11. 03/08/2011 Wait on Slickline crew to complete required time off. RU Slickline. Run 2.25" bailer. Tag at 1529' and broke through. Tag at 1623' and broke through. Tag at 2405' and broke through. Hard tag at 6442'. POOH with bailer. Recovered small amount of cement. RIH with same bailer and attempt to get another sample for AOGCC witness at 6450'. No sample recovered. Pressure up to tubing to 1500 psi for 15 min. Tag and pressure test witnessed by John Crisp - AOGCC Field Inspector. RU E -Line and run CBL. Record Cmt Bond Loq. Review and discuss with Anch Enq. Determined TOC in inner annulus at 4810' RKB. _Attempt to cut tubing at 4,394' RKB - Unsuccessful. 00:00 02:00 2.00 COMPZ PLUG OTHR T Wait for Slick line - Crews was timed out 02:00 02:30 0.50 COMPZ PLUG SFTY P Held PJSM with slick line and rig crew on load and rigging up of slick line. Page 32 of 37 • i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 09:00 6.50 0 6,442 COMPZ PLUG SLKL P RU Slick line with 2.25" OD Bailer, RIH and tag up at 1,529 -ft - broke thru, tagged hard at 1,623 -ft - work thru and set down at 2,405 -ft. Fell thru and set down at 6,442 -ft. at 04:15 hrs POOH and recovered small amount of cmt. Change over to 2.5" OD Bailer and RIH to gather sample for verification with the AOGCC. Not able obtain good sample - observed tag at 6,450 -ft. Witnessed by John Crisp at 09:00 hrs on 3 -8 -11. AOGCC was notified at 05:30 hrs on 3 -8 -11. Rig down Slick line. 09:00 09:30 0.50 0 0 COMPZ PLUG PRTS P Pressure up on TBG to 1,500 psi for 15 minutes on chart. 09:30 21:00 11.50 0 0 COMPZ PLUG ELNE P Spot equipment and Hold PJSM. RU and RIH w/ RCBL to 6,450 -ft and log up attempting to locate TOC in the 3 1/2 x 7" Void. Found TOC at 4,810 -ft. Also saw a few minor Cement stringer above TOC. Finish POOH. Review Log and discuss with Anchorage Engineer. 21:00 21:15 0.25 0 0 COMPZ PLUG SFTY P PJSM with All to discuss making up the Radial Cutting Torch tool assembly. 21:15 00:00 2.75 0 0 COMPZ PLUG ELNE P RIH with Radial Cutting Torch. Correlate to the CBL dated 03/08/2010. Log Cutter into place to cut at 4,400 -ft. However, Anchors did not set. Attempt to re -set.. Anchor set with Cutter positioned at 4,394 -ft. Fire Cutter. Release Anchor. POOH into lubricator. Close TIW Valve. Bring Rig Pump on line to confirm communications. However, the tubing pressured up after 1.4 bbls to 1,400 psi. 03/09/2011 Suspend E -Line Ops so Crew can get proper rest. Resume Ops. Attempt one more tubing cut with the RCT. Order out a Jet Cutter. Cut tubing at 3865. 500 psi on tubing after cut. Bleed off pressure. Circulate well with 11.8 ppg fluid. Took 660 psi to get heavy mud in IA to move. Returns include gas cut mud. Pumped 140 bbls total. RD E -Line. Pick up on tubing. Pipe moved free. Attempt to reciprocate pipe. Unable to easily move back down. Work tubing back down to original depth. Circulate and condition Wellbore with 12.0 lb/gal Brine. Prep for cement job. 00:00 01:00 1.00 0 0 COMPZ PLUG ELNE T Rig E -Line off of Well. Lay down Radial Cutting Torch. Inspect same. Cutter attempted to make cut. Suspend E -Line Ops due to E -Line Crew working long hours. Send Crew back to Camp for proper rest. Page 33 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 11:00 10.00 0 0 COMPZ PLUG SFTY T While waiting on E -Line worked pipe from 08:30 to 09::30 up to 120K in attempt to free pipe, were unsuccessful. PT 3.5" tubing against cement to 1,500 psi for 15 mins, pressure dropped to 550 psi during test.E -Line Crew getting proper rest in Camp. Will resume E -Line Ops —10:00 hrs. Notify Schlumberger Cementers of delay for Cement job. Rig Crew service and maintain Rig. 11:00 12:00 1.00 0 0 COMPZ PLUG SFTY T PJSM with Halliburton E -Line crew. MU lubricator and Radical Cutting Torch toolstring. 12:00 14:30 2.50 0 0 COMPZ PLUG ELNE T RIH with Radial Cutting Torch. Correlate to the CBL dated 03/08/2010. Log Cutter into place to cut at 3,865 -ft. However, Anchors did not set. After several attempts to set anchor failed, POOH to check anchor assembly. Tools functioned correctly on surface and no issues with anchor arms. 14:30 17:30 3.00 0 0 COMPZ PLUG ELNE T Decision made to try jet cutter. Wait on arrival of jet cutter from Prudhoe. 17:30 19:30 2.00 0 0 COMPZ PLUG ELNE T Make up Jet Cutter. RIH and correlate to the CBL dated 03/08/2011. Position Jet Cutter at 3,865 -ft. Cut Tubing. Observe 500 psi on Tubing after cut. POOH and park Tool String inside Lubricator. Close TIW Valve. 19:30 21:30 2.00 0 0 COMPZ PLUG CIRC P Bleed Pressure down and bring Rig Pump on at 1.0 bpm/660 psi. to get heavy Drill Mud moving. Increase rate to 3.0 bpm. Circulating pressure leveled off at 200 psi. Circulate Wellbore volume from 3,865 -ft to condition Well and get rid of gas cut Drilling Mud. Total volume circulated 140 bbls. 21:30 23:30 2.00 0 0 COMPZ PLUG ELNE P PJSM. Rig down E -line equipment and move Logging Truck out of way for Cementing Equipment. Ready Floor for cementing operations. Pick -up on Tubing. Tubing free. Attempt to reciprocate Tubing. However, unable to come down. Finally worked Tubing back down. Abort the attempt to reciprocate Tubing during the cementing operations. 23:30 00:00 0.50 0 0 COMPZ CEMEN" CIRC P Circulate and condition Well with 12.0 lb/gal Brine at 3.0 bpm /180 psi. (Begin to spot Cement Equipment and Vac Trucks). Page 34 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment ,� 03/10/2011 24 hr Summary (�' , Finish C &C Well with 12.0 lb/gal Brine. Pump 48 bbls of 15.8 lb/gal Class "G" Cement. Displace with 12.0 D lb/gal Brine and balance the cement column at '-2500'. WOC. Tag cement plug at 2312'. Pressure test cement to 1500 psi for 30 min. Lost 50 psi. Good test. Tag and pressure test witnessed by Jeff Jones - AOGCC Field Inspector. Jet Cut Tubing at 2275'. Pump down tubing to confirm good cut. Prep for next Cement Plug. 00:00 00:30 0.50 0 0 COMPZ CEMEN "CIRC P Finishing C &C Well with 12.0 lb/gal Brine at 3.0 bpm /180 psi. Total volume pumped 150 bbls. 00:30 01:30 1.00 0 0 COMPZ CEMEN" SFTY P PJSM with Rig Crew, Schlumber Crew and Vac Turck Drivers. Perform final walk -thru. 01:30 02:30 1.00 0 0 COMPZ CEMEN" CMNT P Schlumberger on line with 5 bbls of Fresh Water. Shut down and pressure test lines at 1,200/3,700 psi. Good. Batch mix lead Cement to 15.8 lb/gal. Open Well. Start Cement at 2.5 bpm /300 psi. 15 bbls away, weight at 15.9 lb/gal, rate at 3.1 bpm /190 psi. 25 bbls away, 15.9 lb/gal, 3.1 bpm /190 psi. 40 bbls away, 15.8 lb/gal, 3.1 bpm /180 psi. End Cement with 48.1 bbls pumped, 15.7 lb/gal, 3.1 bpm /180 psi. Pump 5 bbls fresh Water Spacer. Start displacement with 12.0 lb/gal Brine. 10 bbls away, 3.1 bpm /370 psi. 15 bbls away, 3.0 bpm /405 psi. End displacement with 17.0 bbls pumped. Final rate 1.5 bpm /325 psi. Balanced Plug in place at 02:13 hrs. Shut in Tubing. 02:30 13:00 10.50 0 0 COMPZ CEMEN" WOC P Begin WOC. Blow down lines. Rig down Cementers. Waiting on cement compressive strength number of 1000 psi. 13:00 14:00 1.00 0 0 COMPZ CEMEN" SFTY P PJSM with HES S/L crew. 14:00 16:30 2.50 0 0 COMPZ CEMEN" SLKL P MIRU HES S/L equipment. RIH w/ 2' x 2.5" Sample bailer to tag TOC @ 2,312 -ft, witnessed by AOGCC (Jeff Jones) @ 15:45 on 03- 10 -11. POOH with Bailer. PT tubing against cement plug to 1,500 psi for 30 minutes (Charted). Good test, only lost 50 psi. 16:30 17:30 1.00 0 0 COMPZ PLUG ELNE P Move in and rig up Halliburton E -Line Unit. 17:30 21:00 3.50 0 0 COMPZ PLUG SFTY P PJSM. Plck -up Lubricator. Make -up Jet Cutter. 21:00 22:15 1.25 0 0 COMPZ PLUG ELNE P Run in with Jet Cutter. Started to set down at 2,290 -ft. Log tie -in pass and corelate to the CBL dated 03/08/2011. Position Jet Cutter to cut the 3 1/2" Tubing at 2,275 -ft. Fire Cutter. POOH and park inside of Lubricator. Shut TIW Valve. Page 35 of 37 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:30 0.25 0 0 COMPZ PLUG CIRC P Bring Rig Pump on at 3.0 bpm /80 psi and confirm communications. 22:30 23:30 1.00 0 0 COMPZ PLUG ELOG P Rig Down E -Line Equipment. Move Logging Unit out of the way to make room for Cementing Equipment. 23:30 00:00 0.50 0 0 COMPZ CEMEN "CIRC P Move in and rig up Cementing Equipment. Circulate and condition Well with 11.8 lb/gal Brine at 3.0 bpm /80 psi. 03/11/2011 RU Schlumberger Cementers. Pump 70 bbls 15.7 ppg AS1 balanced cement plug from 2,275 to -270'. RD cementers. RU E -Line. Jet cut tubing at 215'. RD E -Line. Pick up on tubing. Pump 10 bbls down tubing. POOH. RIH w/ 9 -5/8" cement retainer on drill pipe. Set cement retainer at 195'. Pressure test retainer to 1000 psi. Good test. Squeeze 12.5 bbls 15.7 ppg AS1 below retainer. Unsting from retainer and pump 15.5 bbls 15.7 ppg AS1 cement above retainer to surface. POOH w/ drill pipe and stinger. Nipple down BOP Stack. Observe TOC 5' below surface. Mix cement in buckets and bring TOC to surface. Install tubing hanger and BPV. NU adapter flange. 00:00 00:30 0.50 0 0 COMPZ CEMEN" RURD P Continue to rig up Cementing Equipment. 00:30 01:00 0.50 0 0 COMPZ CEMEN" SFTY P PJSM with Rig Crew, Cement Crew, and Vac Truck Drivers. 01:00 02:30 1.50 0 0 COMPZ CEMEN" CMNT P Perform final walk -thru. Prime up with Fresh Water. Bring Cement Pump on line and pump 15 bbls of Fresh Water. Shut in Well. Pressure test Line at 1,200/3,500 psi. Good. Batch up AS -1 Cement to 15.7 lb/gal. Open Well. Start AS -1 Cement at 2.0 bpm /275 psi, 15.74 lb/gal. 10 bbls away. 3.1 bpm /290 psi, 15.60 lb/gal. 25 bbls away. 3.0 bpm /195 psi, 15.7 lb/gal. 50 bbls away. 3.0 bpm /180 psi, 15.69 lb/gal. 70 bbls away. 2.8 bpm /175 psi, 15.74 lb/gal. End Cement. Displace Cement with 2.5 bbls of Fresh Water. End Displacement. Shut in Tubing. Balanced Cement Plug in place at 02:18 hrs with expected TOC at 270 -ft. 02:30 04:30 2.00 0 0 COMPZ CEMEN' RURD P Rig down Cementing Equipment and move out of the way to make room for Logging Unit. 04:30 08:30 4.00 0 0 COMPZ PLUG ELNE P Move in and rig up E -Line Unit. Run in with Jet Cutter. Started to set down at 223 -ft. Log tie -in pass and corelate to the CBL dated 03/08/2011. Position Jet Cutter to cut the 3 -1/2" tubing at 215'. Tubing collar @ 211'. Fire Cutter. POOH and park inside of Lubricator. Shut TIW Valve. Pull on tubing to verify cut. RDMO E -Line equipment. Page 36 of 37 Time Logs 9 Date From To Dur S. D h E. Depth Phase T Comment ate o o u S e t e t ase Code Subcode Co e P P 08:30 12:00 3.50 0 0 COMPZ PLUG PULL P POOH with 218' cut 3 -1/2 tubing and lay down. Close rams and perform injection test down tubing. Pumped 10 bbls down tubing @ 1 bpm © 90 psi. Load 3 -1/2" DP in pipe shed for retainer run. Ready floor for cement retainer run. 12:00 13:30 1.50 0 0 COMPZ PLUG PACK P Load 9 5/8" cement retainer in pipe shed. MU retainer to 3.5" DP. RIH w/ retainer on 6 jts DP to 195'. Set retainer. PT to 1000 psi. Good test. 13:30 15:30 2.00 0 0 COMPZ CEMEN CMNT P Mix 32 bbls of AS1 15.7 ppg cement. Pump initial 5 bbls FW down DP @ 2 bpm 220 psi. PT surface lines to 2,000 psi. Pumped 14.5 bbls of 15.7 ppg AS1 cement down DP with 12.5 bbls below retainer @ 195 -ft. @ 1.2 bpm 160 psi. Unsting from retainer, pump additional 15.5 bbls of 15.7 ppg AS1 cement above retainer @ 1.6 bpm 145 psi, shut down pump. Break out head pin, POOH, rack back to stands DP, lay down stringer and DP. RDMO cementers. 15:30 22:00 6.50 0 0 COMPZ WHDBO NUND P Clean out BOP Stack. Install 2 7/8" x 5" VB Pipe Rams in both Gates. ND BOP Stack and set back on stump. 22:00 23:00 1.00 0 0 COMPZ CEMEN" CMNT P Observe top of cement —5 -ft below surface. Mix AS -1 Cement in 5 gal buckets and bring cement to surface. 23:00 00:00 1.00 0 0 COMPZ WHDBO NUND P Install Tubing Hanger and BPV. Nipple Up Adapter Flange. 03/12/2011 Nipple up P&A Tree. Clean Pits. Prep to Release Rig. RDMO. 00:00 03:00 3.00 0 0 COMPZ WHDBO NUND P Nipple up P&A Tree. Fill Tree with diesel. Test Tree connections to 500 psi. Begin cleaning pits. 03:00 09:00 6.00 0 0 DEMOB MOVE RURD P Continue to clean Pits. Clear Pipe Shed. De -mob Kill Tank and Lines. Prep to move off of Well Slot. 09:00 11:00 2.00 0 0 DEMOB MOVE RURD P Contact DSO, pull off of well, spot rig middle of pad out of the way. Load out rig mats, clean up well area and cellar. Release Nordic 3 Rig @ 11:00 03/12/11 Page 37 of 37 Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 ©conocophillips.com] Sent: Sunday, April 03, 2011 2:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: CPAI Monthly Injector Report - March 2011 Attachments: CPAI Failed MITIA Monthly Data 03- 11.xls Jim/Tom /Guy, Attached for your records is the ConocoPhillips March 2011 monthly injector report. Wells added to the report: 1B -11 - OAxOOA communication - SC leak 3B -10 - TxIA communication on Ml 3G -16 - OAxAtmosphere communication - SC leak , 3 , APR 1 $ 2O11 Wells removed from the report: 2A -06 - P &A \, - fe Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 4/17/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 14, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAR 302O11 RE: Tubing Cut Record: 2A -06 Run Date: 3/11/2011 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 -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20028 -00 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 U-- a tis(4-0 (04 Fax: 907-273-3535 VT" klinton.woodC 1" G " MAR 9 n Date: € `' jl ' '' ' Signed: C� 5 Anchcrive • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 14, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Ytdifrlia MAR 3 0 Zak; RE: Tubing Cut Record: 2A -06 Run Date: 3/10/2011 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 -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20028 -00 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 — p64 Office: 907 - 273 -3527 U Fax: 907 - 273 -3535 pp`LS /q klinton.wo M AR 2 911 Date: Signed: Alaska N :C C'ffIrli=k10 Avivrepe • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 14, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 1AR302O1 RE: Tubing Cut Record: 2A -06 Run Date: 3/9/2011 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 -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103- 20028 -00 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 Zc �S� -0 6,C1 G Fax: 907 -273 -3535 g f? klinton.wo • ,�� g .' R Date: r�; , �' :? Signed: ✓, c �� • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 14, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 WOO MAR 3 t 201' RE: Radial Cement Bond Log: 2A -06 Run Date: 3/8/2011 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 -06 Data in LAS format, Digital Log Image files 1 CD Rom 50 -103- 20028 -00 Cement Bond Log 1 Color Log 50 -103- 20028 -00 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 V /66(---0(04 Office: 907 - 273 -3527 Fax: 907 -273 3535 ®tr klinton.woo. '%►� -' 'erg o � t'�•�F � f f A Date: Signed: og & ass cam Clral MICR • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 11, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch Record: 2A -06 REP MAR 3 0 2 01) Run Date: 3/4/2011 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 -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20028 -00 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 VSO I, 6 - v& Fax: 907 - 273 -3535 klinton.wo ! -1 ' c _ 1 Date: :MAR S _ � 1' Signed: 1 : ° AfflicherKv MEMORANDUM State of Alai la Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: March 10, 2011 P.I. Supervisor ell 41111( SUBJECT: Plug & Abandonment FROM: Jeff Jones KRU 2A -06 Petroleum Inspector Conoco - Phillips Alaska Inc.(CPAI) KRF / KRU PTD 1840640 / Sundry 310 -328 Section: 14 Township: 11N Range: 8E Meridian: Umiat Drilling Rig: Nordic 3 Rig Elevation: Depths RKB Total Depth: 8205 ft Lease No.: ADL0025570 Operator Rep.: Mike Freeborn Casinq/Tubinq Data: Casing Removal: Conductor: 16" O.D. Shoe@ 103' MD Casing Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2818' MD ' Casing Cut@ Feet Intermediate: 7" O.D. Shoe@ 8164' MD Casing Cut@ 255' MD Feet - Production: O.D. Shoe@ Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: 3.5" O.D. Tail@ 7925' MD ' Casing Cut@ 3865' MD Feet Plugging Data: Type PIuq Bottom of T.O.C. Mud Weight (bottom up) Founded on Cement T.O.C. Depth Verified? above plug Pressure Test casing stub balanced 3865' MD 2312' MD wireline tag 12 PPG 1600 PSI Tvpe PIuq Founded on: Verified? Open Hole Bottom Drillpipe tag APR 04 2 Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag t" Casing Stub Retainer No Surface March 9, 2011: I traveled to the Kuparuk River Field to witness the wire line tag and pressure test of a cement abandonment plug placed in CPAI's subsidence - damaged gas injection well KRU 2A -06. Mike Freeborn was the CPAI representative for the tests today. Prior to my arrival a 263 cubic foot 15.7 PPG class "G" cement plug was pumped down the 3.5" tubing and up into the inner annulus from the tubing cut depth of 3865' and allowed to set. On my arrival Halliburton slick line ran in the hole with a sample catcher, jars and weight bar assembly and I witnessed a solid tag of the top of cement at 2312' MD. The cement plug was pressured up to 1600 PSI and over 30 minutes the pressure dropped 50 PSI, stabilizing at 1550 PSI. Summary: I witnessed the successful pressure test and wire line tag of a cement abandonment plug placed in CPAI's subsidence damaged gas injection well 2A -06 in the Kuparuk River Field. Attachments: none Distribution: -Well File (original) -Read File -DNR /DOG Rev.:01/26/09 by L.R.G. 2011- 0309_Plug_KRU_2A- 06 jj.xis • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 2, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch Record: 2A -06 Run Date: 3/1/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20028 -00 MO 1 6 ?D1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 1 4 4 - UGo G f Office: 907 - 273 -3527 Fax: 907 - 273 -3535 rafael.barret s •. . iveD Date:1 .. Signed: . • WELL LOG TRANSMITTAL id Gas Conservation Comm. March 2, 2011 To: Alaska Oil arine Shartzer Attn.: Christ Avenue, Suite 100 333 West 7ftlaska 99501 Anchorage, 1 g Torch Record: 2A -06 RE: Radial Cuttir27 /2011 Run Date: 2/: ed below is being submitted herewith. Please address any problems or The technical data liston of: concerns to the attenti urton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 Rafael Barreto, Hallib 2A -06 )rmat, Digital Log Image file 1 CD Rom Digital Data in LAS fd -00 50- 103 -2002f MAR a 6 201 EDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE PLEASE ACKNOWLTER TO THE ATTENTION OF: TRANSMITTAL LE1 Halliburton Wireline & Perforatin; Attn: Rafael Barreto � — 0 (0 6900 Arctic Blvd. 518 Anchorage, Alaska 99 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 corp, rafael.barret i , 20I1 Signed: Date: MAR Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 10, 2011 4:41 PM To: 'Gober, Howard' Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2A -06 (PTD 184 -064) Second Cement Plug Howard, The change below is approved. Leaving the tubing in the wellbore for this plug setting sequence (258' - 2500' and ) doesn't change the overall plan or decrease the effectiveness of the plug. After you tag this cement plug and jet cut the tubing at approx 250' you will pull out the tubing to allow the 9 5/8" retainer to be run and pump final cement sqz /plug to surface. Regards, Guy Schwartz ►AF Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Thursday, March 10, 2011 4:29 PM To: Schwartz, Guy L (DOA) Subject: 2A -06 (PTD 184 -064) Second Cement Plug Guy, As per our discussion this afternoon, I discussed the next cement plug on 2A -06 from -2500' to -258' with Schlumberger. They are concerned that we will not be able to pull our tubing through the plug. ArcticSetl cement blend develops gel strength quickly, so we might not get the pipe out of the ground. Therefore I would like to modify the procedure I sent you yesterday. Here is what I propose to do: After tagging the cement plug at -2500' RKB, we will jet cut the tubing. • Pump a ArcticSetl cement plug from -2500' to 258' • Jet cut tubing above TOC (pull tubing now to set retainer) • Run 9 5/8" cement retainer and cement as per the previous plan The only change is we will not pull the tubing after pumping the upcoming plug. Please let me know if you see any issues with our plan. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com 3/10/2011 Page l of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 11:09 AM To: 'Gober, Howard' Cc: Cawvey, Von Subject: RE: 2A -06 (PTD 184 -064) Procedure Addendum Howard, I agree that this procedure outlines what we discussed on the phone today. This still falls within the scope of the original sundry # 310 -328 and follows the outline of your email update of 1 -25 -2011. Based on the cement log of the tubing annulus this looks like a prudent plan to finish up the abandonment cementing of the wellbore and meets all AOGCC P & A requirements in section 20 AAC 25.112. (up to cutting off the casing below ground level). Even though inspectors already witnessed the tag and PT of the lower plug (from the relief well 2A -27) a few days ago please notify as stated below for the next plug placement and PT ( 3800 -2500' plug) . I will update the inspectors on the slope of the current plans.... Regards, Guy Schwartz ; M AR 1 0 ZQ � Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Wednesday, March 09, 2011 10:25 AM To: Schwartz, Guy L (DOA) Cc: Cawvey, Von Subject: 2A -06 (PTD 184 -064) Procedure Addendum Guy, Since we have pulled the 7" casing down to 258' RKB, I need to modify the plugging procedure for 2A -06. As per our phone conversation, we will notify the AOGCC Inspectors to witness the tag of the first plug we pump. TOC will be approximately 2500' RKB. The second plug is not required by the AOGCC regulations and will therefore not require a witness. The last plug will include cement pumped below a retainer and then above the retainer to surface. Since this is a surface plug, witnessing of this plug will not be required either. Please send me a note back letting me know if I have adequately captured our conversation. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com Addendum 1Steps 19. RU Schlumberger cementers. Spot balanced plug by pumping Class G cement down tubing and up into the IA from tubing cut depth (3865' RKB) to -2500'. Reciprocate pipe during cementing operations to ensure good bond. 3/9/2011 Page 2 of 2 • XXX Sacks Class G + 0.3% D65 + 0.2% D46 + D177 Retarder as needed (calculate volume based on tubing cut depth) Weight: 15.8 ppg Yield: 1.16 cu ft/sk Working Time: -3 -4 hours Wait on cement. RU slickline. Tag TOC in tubing. Pressure test tubing to 1500 psi. Chart test for 30 min. AOGCC Inspector will need to be notified for witness of tag depth and pressure test. RD slickline. RU E- Line. RIH and cut 3 -1/2" tubing above TOC with RCT cutter. RD E -Line. RU Schlumberger cementers. Spot balanced plug from cut depth to casing holes at -258' RKB. RD cementer$. XXX Sacks AS1 (calculate volume based on tag depth) Weight: 15.7 ppg Yield: 0.93 cu ft/sk Working Time: -2.5 -3 hours POOH with tubing from cut depth. RIH with 9 -5/8" cement retainer and set at +/ -200' RKB. PT annulus to 1000 psi to ensure retainer is set. RU Schlumberger cementers. Mix and pump -27.5 bbls AS1 cement. Squeeze 12.5 bbls cement below retainer. Unsting from retainer and circulate cement to surface ( -15 bbls including tubing volume). SD pumping and RD cementers. POOH with tubing and stinger. ND BOP. If cement top is more than 5' below original ground level, top off with cement. Take picture of cement top. NU tubing head, adapter flange, master valve, swab valve, and tree cap. RDMO Nordic 3. Post Rig Work 1. None needed 3/9/2011 0 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 7, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2A -06 % ,' , :') \AAR 0 5 2H H' Run Date: 2/6/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20028 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 j.r1 U C I Fax: 907 - 273 -3535 Q. 0--1-5 rafael.barreto@halliburton.com a / . Date: Signed: C Page 1 of 2 a • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 08, 2011 8:46 AM To: 'Gober, Howard' Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2A -06 (PTD# 184 -064) Closing of TIW Valve Howard, As per our discussion it is hard to tell if the tubing flow was hydrate related or just due to the U -tube effect with heavier fluid on the backside. The well should be totally sealed off from any hydrocarbon formations ( 2A -27 relief well from last year ). Although you didn't close BOP rams or annular, using the TIW valve to control fluid flow would still constitute a well control situation (especially since it can't be determined if it was U -tube effect or gas breakout) so you were correct in notifying the commission. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC MIA 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Monday, March 07, 2011 4:31 PM To: Schwartz, Guy L (DOA) Cc: Nordic 3 Company Man; Cawvey, Von; CPA Wells Supt; Packer, Brett B; Toomey, Ian (Baker Oil Tools); Nelson, Erik Q Subject: 2A -06 (PTD# 184 -064) Closing of TIW Valve Guy, As per 20 ACC 25.285 (f)(8), I am notifying the AOGCC that the TIW valve was closed on 2A -06 (PTD# 184 -064) to prevent flow of fluids from the well. Nordic 3 is operating under Sundry 310 -328. This valve closure occurred on 3/6/11 at -1830. The operations at the time were that the rig had performed a blind back off of the tubing to d tubing. Prior to backing off, the wellbore was loaded with 9.6 remove a section of damage g g ppg brine to 960' with no indication of flow. The tubing was latched on to and backed off. We were unable to pump down the drill pipe at this time. We pulled 8 jts when we saw flow up the drill pipe. The TIW valve was stabbed and closed with -40 psi on the drill pipe. Most likely there was either a imbalance in fluid weights or we had hydrates in the tubing Ps PP Y g warmin g up breaking u and breakin out gas. It is unclear at this time what the cause of the pressure was. We began to put 11.8 ppg fluid down the IA using the trip tank. We lined the drill pipe up through the choke and gas buster. After several hours we tried again to pump down the drill pipe. After pressuring up several times we were able to establish circulation and get 11.8 ppg fluid all the way around. We then tripped back in with the 8 jts of pipe and circulated again. Currently we are pulling out of the hole and laying down the backed off tubing. As soon as practical we will pressure test the TIW valve as per 20 ACC 25.285 (0(2). Please note that we did close the annular preventer this morning, but it was not to prevent flow of fluids from the well. We closed the annular to facilitate taking returns to the outside kill tank. We expected oil based mud and possibly hydrates in the returns, so we wanted to take the fluids outside of the rig. The annular will not be pressure tested until another weekly BOP test is necessary. Please let me know if you have any questions. Thanks, Howard Gober 3/8/2011 Page2of2 • • Wells Engineer ConocoPhillips Alaska, Inc. 907 -263 -4220 Office 907 - 240 -5515 CeII Howard.Gober@conocophillips.com 3/8/2011 • 4 Schwartz, Guy L (DOA) From: Packer, Brett B [ J. Brett.Packer ©conocophillips.com] Sent: Saturday, February 12, 2011 11:08 AM To: Schwartz, Guy L (DOA) Cc: Gober, Howard; Nelson, Erik Q; Toomey, Ian (Baker Oil Tools); Nordic 3 Company Man Subject: 2A -06 (PTD#184 -064) Guy, Just an update on the progress of 2A -06. We've spent the last 4 days attempting to mill down over the 3 -1/2" tubing stub. We thought we were making good progress, everything appeared as if we were getting over the tubing and able to dress it off, but subsequent attempts to latch it with an overshot proved unsuccessful. We got to a point last night where we decided to run a video log to see what we are dealing with. We obtained a good quality video, and can see clearly now what we have down there. The video shows that we were not milling over the tubing, but instead milling alonside the tubing and exiting the 7" and 9 -5/8" casing. The top of the tubing stub is visible and still pinched in similar to the end of tubing that was originally pulled out of the well in 2009. From the looks of things, we cannot imagine that anything else we run at the moment won't follow the same path until we open up the well a little more. We are now running down the contingency path Howard had discussed with you prior, which involves removing the 7" casing down to the obstruction depth. As discussed this morning, our weekly scheduled BOP test was supposed to be tomorrow, but at your request, we will test the BOP's today, because once we ND the BOP and tubing head, and NU the BOP's to the casing head, the BOP stack will essentially be a diverter and we will have no way to test it. Plan Forward 1. Test BOP stack w/ 7" rams and VBR's to 250/3500 psi. 2. Set RBP in 7" casing as deep as possible, dump sand on top. 3. ND BOP stack, set aside. 4. ND tubing head w/ Hydratight tensioners in case the 7" wants to grow (7" x 9 -5/8" annulus was cemented in 2009) 5. Spear 7" casing and try to remove slips, if cannot, tack weld slips to casing and cut casing below the wellhead, pull & remove the slips. 6. NU BOP stack to casing head as a diverter. 7. If the 7" grew during ND of the tubing head, it would appear that the cement sheath is broken and we will be able to cut & pull the 7 ", otherwise, commense milling over the 7" casing removing one joint at a time. I won't go any further, because as these wells go, plans may change. We'll keep you up to date on the progress of this P &A as it moves along. Brett Packer Drilling & Wells Workover Engr. Office: 907 - 265 -6845 fir, �Q) Cell: 907 - 230 -8377 1 • Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 26, 2011 9:56 AM To: 'Gober, Howard' Cc: Nelson, Erik Q; Packer, Brett B; Toomey, Ian (Baker Oil Tools); Cawvey, Von Subject: RE: 2A -06 (PTD# 184 -064) Sundry #310 -328 Howard, After our discussion regarding the RWO on 2A -06 I had a couple of comments. This scope of work is covered under the original sundry 310 -328 ... the extra detail is great and clarifies the need for the change in BOP testing pressures. It looks like a similar operation as was done recently on 2T -13. I will forward to the AOGCC inspectors on the slope so they understand the BOP pressure test change. Also as before you are granted a variance per 20 AAC 25.286 (h) to use the BOP as a diverter assembly until an appropriate time to test the stack is available. Regards, Guy Schwartz Senior Petroleum Engineer Ait FEB 1 3. 2011 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober ©conocophillips.com] Sent: Monday, January 24, 2011 12:55 PM To: Schwartz, Guy L (DOA) Cc: Nelson, Erik Q; Packer, Brett B; Toomey, Ian (Baker Oil Tools); Cawvey, Von Subject: 2A -06 (PTD# 184 -064) Sundry #310 -328 Guy, We have an approved Sundry for 2A -06 (PTD #184 -064). The Sundry number is 310 -328. The purpose of this job is to perform further suspension operations up to but not including the surface abandonment. The Sundry had 2 parts to it: 1) a non -rig attempt to complete the work, and 2) rig operations (if necessary). ConocoPhillips Alaska, Inc (CPAI) completed a non -rig attempt. Although the coiled tubing work was not completely successful, we did gain valuable information to the condition of the wellbore below the damaged 7" casing. We milled past the damaged casing and have taken pictures of the wellbore below including the 3 -1/2" tubing string. CPAI is preparing to move Nordic 3 on the well after we finish operations on 1 J -137. This is approximately 1 week away. As I began writing the workover procedure, I realized that I did not give much definition in Step #7 under "Proposed Rig Procedure" (see attached). In order to wash over and remove the 7" casing, we need to remove the BOP stack and then nipple it up as a diverter. There is a hole milled through the 7" and 9 -5/8" casing by coiled tubing. This hole, combined with the fact the 9 -5/8" x 7" annulus will not pressure test, will not allow us to pressure test the BOP at the time of installation. The BOP will need to be treated as a diverter until some of the 7" casing is removed. At that time we can set a test plug and pressure test the BOP stack. We will only be able to pressure test the BOP to 3000 psi maximum due to the casing head flange rating of 3000 psi. Since the Sundry requires a 3500 psi test on the BOP stack, I am requesting a variance if we need to remove the 7" casing. This operation is similar to the work we have performed on the workovers at 2A and 2T pads. I have included the steps below that expand upon Step #7 in the Sundry submittal: 1. If necessary, remove the 7" casing down to the obstruction depth as follows: Set RBP in 7" casing at -100' RKB. Dump 25' sand on top. PT casing to 500 psi. Ensure OA pressure is 0 psi, and if necessary bleed any pressure off. ND BOP and set back on stump out of the way. ND tubing head. 1/26/2011 • • Page 2 of 2 2. Remove tubing head and 7" packoff. Spear 7" casing w/ 5 -3/4" Itco spear, pull up and try to remove slips. If slips cannot be removed, perform sniffer test for obtaining Hot Work Permit. Tack weld slips to casing if LEL levels are acceptable. NU 11" BOPE to the casing head. NOTE: BOP is now considered a diverter due to the surface casing leak at -250' RKB. A pressure test of the BOP equipment cannot be performed at this time. 3. If slips could not be remove in step above, RIH w/ 5 -1/2" multi- string cutter dressed for 7" casing on 3 -1/2" drill pipe. Cut casing -3' below wellhead. POOH and lay down cutter. Spear casing stub recovering slips. Set test plug in casing head. PT BOP break to 250/3000 psi. NOTE: Notify AOGCC 24 hours in advance to witness BOP test. The 3000 psi test pressure is below that stated on the Sundry, but it is the maximum pressure due to the casing head rating of 3000 psi. Pull test plug. 4. RIH with RBP retrieval tool and circulate sand off the RBP. Latch on and pull RBP. MU and RIH with assembly to mill over 7" casing cement sheath and collars. 8 -1/2" rough OD by slick ID ocean wave shoe with a 8 -1/8" TSWP box up connection 1 joint 8 -1/8" TSWP box up by 8 -1/8" TSWP pin down wash pipe 1 - 4 -1/2" IF box up by 4 -1/2" FH pin down by a 8 -1/8" TSWP pin down triple connection wash over boot basket 6 -1/4" OD Bowen lubricated bumper jar (4 -1/2" IF box up by 4 -1/2" IF pin down) 6 -1/4" OD Bowen super oil jar (4 -1/2" IF box up by 4 -1/2" IF pin down) Drill collars co ars and drill i e as necessary rY Mill over casing past one collar and down to the next. POOH. RIH and spear 7" casing joint. POOH laying down. If BOP was not tested in Step 3 above, set test plug in casing head. PT BOP break to 250/3000 psi. NOTE: Notify AOGCC 24 hours in advance to witness BOP test. The 3000 psi test pressure is below that stated on the Sundry, but it is the maximum pressure due to the casing head rating of 3000 psi. Pull test plug. Continue washing over and pulling casing and collars until reach -250' RKB. Remove casing down to this point. MU 5 -7/8" rough OD concave junk mill, bit sub, 4 -3/4" drill collar, 5 -7/8" OD string mill, 4 -3/4" drill collar, bumper sub, jars, and drill collars. Tag deformed casing. Pull collars as necessary and replace with drill pipe so that drill pipe will be across the BOP stack and up to the top drive. Time drill on casing and mill down past wrinkled casing at -255' RKB. Run mills and video log as necessary to until past the wrinkled casing. Another point of clarification: In Step #11 of the submittal, we will utilize 2 cement plugs if necessary to ensure ArticSetl cement is placed across the permafrost. If 2 plugs are pumped, the AOGCC Inspector will be called to witness the tag of the first plug. Then we will fill the well up to surface with cement as per Step #11 of the submittal. Please let me know if you have any questions or need further information. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober@conocophillips.com 1/26/2011 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 2A-06 Run Date: 7/2/2010 July 16, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 ZA-06 Digital Video File (AVI) 50-103-20028-00 r ~ 4~° ~r,~.t . r.,: w .. 1 DVD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto halliburton.com v~ ~ i ~u-~Co~~ Date: ~~i ~ ~ ~~,,~ ~ T 1 ~9 L!~ Signed: ~ . ~~C31~'61 Ar-Gr . WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 2A-06 Run Date: 3/10/2010 March 18, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-06 Digital Video File (AV17 50-103-20028-00 3.'~'~~~~: A~~ ~ ~ ~0~~ 1 DVD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 1 9L~~~ rafael.barreto MAR ~ 3 2010 Date: Signed: P-w' STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~#~/ED~ .: ~; '1 ~ 010 WELL COMPLETION OR RECOMPLETION REP01~~~~~3.Co~~ssof>< 1a. Well Status: pil ^ Gas ^ SPLUG ^ Plugged ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other ^ No. of Completions: 1b. Well Class: ~~~(}[~(~~ Development ^ Exploratory ^ Service ^~ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp. Susp., orAband.: December 10, 2009 12. Permit to Drill Number. 184-064 / 309-346 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 17, 1984 13. API Number. 50-103-20028-00 4a. Location of Well (Governmental Section): Surface: 59T FSL, 53' FEL, Sec. 14, T11N, R8E, UM 7. Date TD Reached: May 23, 1984 14. Well Name and Number: 2A-06 Top of Productive Horizon: 1354' FNL, 1259' FWL, Sec. 23, T11 N, R8E, UM 8. KB (ft above MSL): 130' RKB GL (ft above MSL): 94' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1392' FNL, 1132' FWL, Sec. 23, T11 N, R8E, UM 9. Plug Back Depth (MD + TVD): 4392' MD / 3640' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498341 y- 5960018 Zone- 4 10. Total Depth (MD + TVD): 8205' MD 6232' TVD 16. Property Designation: ADL 25570 TPI: x- 494374 y- 5958069 Zone- 4 Total Depth: x- 494247 - 5958032 Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 1926' / 1908' TVD 17. Land Use Permit: 2668 18. Directional Survey: Yes ^ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness. of Permafrost MD/TVD: approx. 1524' MD / 1500' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drill/Lateral Top Window MDRVD not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE NTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEME PULLED 16" 62.5# H-40 Surf. 103' Surf. 103' 24" 175 sx CS II 9.625" 36# J-55 Surf. 2854' Surf. 2650' 12.25" 860 sx PF E, 250 sx PF C 7" 26# J-55 Surf. 8202' Surf. 6229' 8.5" 475 sx Class G, 25o sx PF C 24. Open to production or injection? Yes ^ No ^ If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MDlTVD) 3.5" 244' 142' MD / 142' TVD, 7707' MD / 5773' TVD, plugged perforations 7891' MD ! 5938' TVD ~ (~ (, G L 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. _• :~`..s~~''~~ +~ ~ j~ °'~ ~ ~ `° ~" DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement squeeze 4392'-6292' 173 sx LiteCRETE 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 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/}~gDMS ~ lAN ~ V 3~"~ Ca-~(~' ' , TINUED ON REVERSE -( / -~-/ ~ Submit original only ~~/~/o 28. GEOLOGIC MARKERS (List all formations and marke ountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes 0 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 1524' 1500' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS / Summary of Daily Operations, schematic ~ - I~ 1(b 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Reimer @ 263-4247 Printed Name /~~ G~. Alvord Title: Alaska Drilling Manager Phone 265-6120 Date ~ ~~(L~~D Signature~ ~ INSTRUCTIONS Sharon Allsup-Drake 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 ~ ~ ~~ ~ ~ ... ~~--~: c ~~. ECP Q 142' sssv Control Line sssv 1926' (lock in open position) Well 2A-06 Current Status 1 /5/10 ~i ConocoPhillips Alaska 16" conductor @ 103' MD _ 3'/z" temp suspension string @ 245' MD (ECP inflated at 142' MD to provide additional barrier) 9 5/8" 36 ppf J-55 BTC surface casing @ 2854' (TOC @ surface, casing leak estimated at 210' MD) Annulus between 9 5/8" & 7" was arctic packed in 1984. Est. TOC @ 1919' MD. Same annulus was downsqueezed with cement 3 times in 2009 until pressure test was obtained 7" 26 ppf J-55 BTC production casing @ 8201' TOC from CBL is 7344' MD 3'/2" 9.3 ppf J-55 EUE 8RD production tubing (tubing is parted with top of stub @ 248' MD -stub has some junk on top that looks like bands along with some SSSV control line -cannot establish injection through top of stub which appears to be NOTE: Well 2A-27 intersect 2A-06 at 7252' - 7255' M D. Squeeze 50 bbls LiteCrete cement Unable to determine TOC 7" Casina Cement Primary Job: TOC verified by CBL @ 7344' MD Completion Details: Upper packer @ 7707' MD Injection mandrels at 7718' MD & 7788' MD (both mandrels open to "C" sand) "C" sand perforations 7841' - 7879' (4 SPF / 90 deg Phasing) Bottom packer @ 7891' M "A" sand perforations 7931' - 7946' (12 SPF / 120 deg PBTD @ 8124' MD Dummied off GLM S"~l., Camco 2.75" "D" Nipple and SOS Dave Reimer 1/5/09 2A-27 Well Status as of November 2, 2009 Permit to Drill Number: AOGCC 209107 API number: 103206040000 wz,~ s« ~.rn ~~~ ~~CC , Current Operations: Drilled float shoe, performed LOT, drilling 12-1/4" hole. Weekly Summary: Oct 23: Rig released from BP Z-pad @ 00:00. Install boosters on rig, fuel rig, remove cellar equipment, heater house and prep to move. Wait on Security escort. Move rig from Z-Pad to J- Pad access road. Trouble time: 0.0 hrs. Total to date: 0.0 hrs. Oct 24: Continue moving rig from J-Pad access road to CPF 2. Move from CPF 2 to 2A-27. Rig on location @16:30 hrs. Remove front ~ rear boosters, PU BOPE and secure in cellar, hang plumb bob and cellar walls. Move rig over well, skid rig floor into drilling position. Trouble time: 0.0 hrs. Total to date: 0.0 hrs. Oct 25: Continue rigging up, hook up service lines, berm up rock washer. Spot fuel tank for LEPD & berm up. Place cellar heater & mouse hole in cellar. Install riser 8~ flow line, take on spud mud. Load pipe shed w/ 105 jts of 5" DP. Install diverter line 8~ 2"d 4" outlet on conductor. PU 8~ std back 105 jts of 5" DP, load 5" HWDP in pipe shed. Trouble time: 0.0 hrs. Total to date: 0.0 hrs. Oct 26: Held safety stand down w/ crew. PU 8~ std back 12 jts 5" HWDP. Bring BHA components to floor. MU BHA: bit, motor, flt sub, 2 NMFDC, 1 std HWDP, tag @ 131' MD. Held shallow gas diverter drill, functioned diverter system. John Crisp, AOGCC, waived witnessing test. Fill hole, check for leaks, test mud line. Wash to bottom of conductor @ 154' MD. Spud in 13:30, drill 16" hole from 154' to 197' MD. PU & inspect pipe grab on top drive. Drill 16" hole from 197' to 289' MD. POOH, bring remainder of BHA components to rig floor. MU remainder of BHA: MWD tools, UBHO, orient motor to MWD. Troubleshoot MWD, hung sheave for gyro. Trouble time: 1.5 hrs. Total to date: 1.5 hrs. Oct 27: MU flt sub, UBHO, NMFDC, jars &HWDP. Drill 16" hole from 289' MD to 2190' MD / 2027' TVD. Trouble time: 0.0 hrs. Total to date: 1.5 hrs. Oct 28: Drill 16" hole from 2190' MD / 2027' TVD to 3384' MD / 2938' TVD. TD surface hole. Circ 3x bottoms up for wiper trip. BROOH from 3384' MD to 2962' MD. Trouble time; 0.0 hrs. Total to date: 1.5 hrs. Oct 29: Continue to BROOH from 2962' MD to 645' MD. Check flow -static. RIH w/ 5" DP to 3333' MD, wash to 3384' MD. Circ 2x bottoms up, POOH on elevators. LD BHA, clear floor of BHA components. PU landing jt &csg tongs, MU hanger running tool on landing jt &csg hanger on running tool, make dummy run. LD same. RU and run 13-3/8" 68# L-80 BTC & TC II csg as follows: Flt shoe - 2 jts BTC csg - flt collar - 2 jts BTC csg. Trouble time: 0.0 hrs. Total to date: 1.5 hrs. Oct 30: Continue running 13-3/8" 68# L-80 csg. Land csg on mandrel hanger w/ FS @ 3373' MD and FC @ 3285' MD. RD csg tongs 8~ fil up tool, MU cmt head. C&C mud for cmt job. Pump cmt job, displace cmt w/ spud mud. Bumped plug, full circulation throughout job w/ cmt returns to surface. Flush stack, LD cmt head &csg equipment. ND diverter lines 8~ hydril. Trouble time: 0.0 hrs. Total to date: 1.5 hrs. Oct 31: Complete ND diverter, install wellhead. Set stack on wellhead, test MTM seal to 1000 psi - ok. Continue to NU BOPE. Test BOP, test witnessed & approved by Chuck Scheve - AOGCC. RD test equipment, pull test plug, install wear bushing, cut & slip drill line. Trouble time: 0.0 hrs. Total to date: 1.5 hrs. Nov 1: PU 8~ standback 135 jts of 5" DP. MU BHA #2, RIH to 2500' MD. Held stripping drill. RIH w/ BHA #2 from 2500' MD to 3235' MD. Wash down from 3235' MD to 3273' MD, tagged top of cmt @ 3273' MD. CBU, pump high vis sweep, displace well over to 10.5 ppg OBM. C&C mud. RU to test csg, test 13-3/8" csg to 2500 psi for 30 min -test good, RD test equipment. Clean shoe track, clean out cmt from 3273' MD to 3283' MD, drill wiper plug & FC @ 3285' MD, drill cmt from 3287' to 3372' MD, top of FS. Trouble time: 0.0 hrs. Total to date: 1.5 hrs. M 2A-27 Well Status as of November 16, 2009 Permit to Drill Number: AOGCC 209107 API number: 103206040000 Current Operations: Finish circulating prior to POOH for ranging run # 8 Weekly Summary: Nov 9: BROOH from 3897' MD to 3341' MD (shoe @ 3374' MD). CBU, hole unloaded large amounts of shale, conveyor stalled, shut down pumps, clean conveyor, circ in csg. RIH from 3341' MD to 5471' MD, wash from 5471' MD to 5600' MD, CBU. RU eline & gyro w/ side entry sub. RIH w/ gyro, tool not working. Troubleshoot, locate loose connection in truck. Run gyro, bit @ 5594' MD, RD gyro & eline. CBU. Stand back DP from 5594' MD to 5471' MD. POOH from 5471' MD to 5000' MD. RU eline & Vector w/ side entry sub. Run Vector & land on crows foot on flt sub, clamp line. RIH to 5425' MD taking ranging shots, hole tight @ 5425' MD, suspect cuttings bed, POOH to 5000' MD. Unclamp line, pull tool to surface, RD Vector & eline. RIH from 5000' MD to 5378' MD, wash 8~ ream from 5378' MD to 5600' MD. Drill 12-1/4" hole from 5600' MD to 5665' MD. Trouble time: 1.5 hrs. (1.0 hr solids control, 0.5 hrs eline) Total to date: 7.5 hrs. Nov 10: Drill 12-1/4" hole from 5665' MD to 6200' MD. Circ 2x BU, standback 2 stds. BROOH from 6027' MD to 3341' MD (shoe @ 3374' MD). Circ 3x BU. RIH from 3341' MD to 6200' MD, wash last std down. Circ 2x BU, trip gas 70 units. POOH on elevators from 6200' MD to 5656' MD, pulling tight. BROOH from 5656' MD to 4730' MD. Trouble time: 0.0 hrs. Total to date: 7.5 hrs. Nov 11: BROOH from 4730' MD to 3341' MD, circ 3x BU. POOH from 3341' MD to 218' MD, stand back & LD BHA. RU eline w/ ranging tool 8~ gyro in combo, RIH. Perform ranging survey to 6198' MD, POOH. RD eline & ranging tool/gyro combo. PU BHA #7 w/ WSAB (wellspot at bit sub), RIH to 3342' MD. Trouble time: 0.0 hrs. Total to date: 7.5 hrs. Nov 12: Fill pipe -pipe plugged. Attempt to unplug, no good. POOH to BHA and found flt sub and top of MWD plugged with shale cuttings. Clean out BHA & mud pits, flush pumps. RIH to 2045' MD, service rig. RIH to 3342' MD, circ 2x BU. RIH to 6121' MD, wash to 6200' MD. Drill 12-1/4" hole from 6200' MD to 6450' MD. Observe loss of 340 psi off bottom pressure in that time. Trouble time: 11.5 hrs -plugged BHA. Total to date: 19.0 hrs. Nov 13: Drill 12-1/4" hole from 6450' MD to 6452' MD. POOH to inspect BHA. POOH to bit, found WSAB sub had parted, left sub & bit in hole. RU eline w/gyro and ranging tool, RIH. Perform ranging survey at 6433' MD, POOH. RD eline & gyrolranging tools. MU fishing tool BHA (overshot, flt sub, circ sub, bumper sub & jars), RIH to 3365' MD, circ 1x BU. Trouble time: 12.5 hrs -fish in hole. Total to date: 31.5 hrs. Nov 14: RIH from 3365' MD to 5738' MD. Wash & ream from 5738' MD to 6420' MD, circ 2x BU. Work over fish @6453' MD, engage same. Pump OOH from 6453' MD to 4566' MD. POOH on elevators from 4566' MD to 398' MD. Set back HWDP, LD fish, LD fishing BHA. Test BOPE, test waived by AOGCC Jeff Jones. Trouble time: 16.0 hrs -fishing. Total to date: 47.5 hrs. Nov 15: RD BOPE test equipment. PU BHA # 10, RIH from 714' MD to 3370' MD. Circ 2x BU, RIH from 3370' MD to 5645' MD. Took weight, wash & ream 5645' MD to 6450' MD. Fanned bottom 8~ washed to 6453' MD for junk. Drill 12-1/4" hole from 6453' MD to 6625' MD, circ 2X BU. RU eline & gyro on side entry sub. RIH, run gyro, POOH and LD gyro. Circ while process gyro & well path. Trouble time: 0.0 hrs. Total to date: 47.5 hrs. N ~ 2A-27 Well Status as of November 9, 2009 Permit to Drill Number: AOGCC 209107 API number: 103206040000 Current Operations: BROOH to csg shoe, RIH, CBU, RU eline, Vector & gyro. Weekly Summary: Nov 2: Finish drill out FS and 20' of new formation to 3404' MD, CBU. Attempt to perform FIT, went to LOT = 13.1 ppg EMW. Drilled 12-1/4" hole from 3404' MD to 3800' MD. Circ 2x BU, BROOH from 3792' MD to 3370' MD. RIH from 3370' MD to 3800' MD, pump high vis sweep, CBU, POOH on elevators from 3800' MD to 640' MD (HWDP), LD BHA. Trouble time: 0.0 hrs. Total to date: 1.5 hrs. Nov 3: Finish LD BHA. RU a-line equipment 8~ sheaves. MU Vector Magnetics connection. Troubleshoot electrical problem w/ a-line unit. PU 8~ RIH w/ Vector Magnetics tool to 3800' MD. Perform active magnetic ranging run #1 to determine approx location of 2A-06 wellbore, results show a center to center distance of about 58' +/- 15' between wellbores. POOH w/ tools. RD e- line. PU BHA #3, RIH to 3365' MD. Circ 2x BU, C&C mud. RIH to 3800' MD. Drill 12-1/4" hole from 3800' MD to 3818' MD. Trouble time: 2.5 hrs install breaker 8~ fuse on a-line unit. Total to date: 4.0 hrs. Nov 4: Drill 112-1/4" hole from 3818' MD to 4070' MD. Circ 5x BU, BROOH from 4070' MD to 3600' MD. Attempt to POOH on elevators, tight spot @ 3580' MD, CBU. POOH, LD BHA. RU eline 8~ Vector Magnetics tool, RIH to 4070' MD. Perform ranging run # 2 to check location of 2A- 06, results center to center distance of 50' +/- 12'. POOH w/ tools & RD a-line. PU BHA #4, RIH to 641' MD. Trouble time: 2.5 hrs install breaker 8~ fuse on a-line unit. Total to date: 4.0 hrs. Nov 5: Continue to RIH from 641' MD to 3325' MD, fill pipe, CBU. RIM from 3325' MD to tight spot @3930' MD. Wash & ream from 3930' MD to 4040' MD, wash to 4070' MD. Drill 12-1/4" hole from 4070' MD to 4400' MD. BROOH from 4400' MD to 3600' MD. POOH on elevators from 3600' MD to 640' MD. Stand back BHA.RU a-line & Vector ranging tool, RIH to 4400' MD to perform RR # 3 to check 2A-06 distance. Trouble time: 2.5 hrs install breaker & fuse on a-line unit. Total to date: 4.0 hrs. Nov 6: Results of RR # 3: center to center distance 29' +/-9'. POOH, RD Vector & eline. MU BHA # 5, RIH to 3350' MD. CBU, RIH to 4265' MD, wash to 4355' MD. 2A-06 well pressure went rom 300 psi to 1700 psi, circ & POOH slowly until 2A-06 pressure below 700 psi, RIH to 4400' ~~~-~u' ~~•~~ MD. Drill 12-1/4" hole from 4400' MD to 5000' MD. POOH, circ. Trouble time: 2.0 hrs well ~,rt~'~~ control. Total to date: 6.0 hrs. (= ~~ -r~~~ Nov 7: Continue to pump OOH from 4810' MD to 471 T MD. POOH from 471 T MD to 4163' MD, ,, N ~Fa - pulled into cuttings bed @ 4163', CBU. POOH from 4163' MD to 3885' MD, puAed into cutting '~ bed @ 3885', CBU. POOH from 3885' MD to 3359' MD, CBU. POOH, stand back BHA. RU eline, MU Gyro & Vector ranging tool, RIH to 4972' MD to perform RR # 4 to check distance to ~-~°' 2A-06. POOH, RD eline, Vector 8~ Gyro. MU BHA # 6 w/ gap subs, RIH to 480' M .Trouble ~~~,.Chj time: 0.0 hrs. Total to date: 6.0 hrs. r-=7 D:~I'~-= ~ •- ~':~: ~-,'_~ ~-~~ n• ~~'~w-~ - ~~ l/y.~ Nov 8: RIH from 480' MD to 3341' MD, CBU. Slip & cut drill line, service rig. RIH from 3341' MD to 4915' MD, Tag bridge, wash from 4915' MD to 5000' MD. Drill 12-1/4" hole from 5000' MD to 5600' MD. Circ 2x BU. POOH from 5600' MD to 5378' MD. BROOH from 5378' MD to 3897' MD. Trouble time: 0.0 hrs. Total to date: 6.0 hrs. • • 2A-27 Well Status as of November 23, 2009 Permit to Drill Number: AOGC~'' API number: 1032060400A0 Current Operations: Weekly Summary: Nov 16: Circ while processing gyro data. Drill 12-114" hole from 6625' MD to 6700' MD. Circ 2x BU, stand back 1 stand. BROOH from 6605' MD to 4883' MD. POOH from 4883' MD to 3308' MD. Circ 1x BU, POOH to 3215' MD. Service rig. POOH to 626' MD. Stand back BHA. RU eline w/ ranging tool and gyro in combo. RIH to 6700' MD and log w/gyro & ranging tool. Trouble time: 0.0 hrs. Total to date: 58.0 hrs. Nov 17: POOH w/ ranging tool 8~ gyro. PU BHA, RIH to 718' MD, test MWD - no pulse. POOH, change out pulser, RIH to 718' MD, retest -good. RIH from 718' MD to 6650' MD. Rotate through tight spot @ 5605' MD, rotate to 5810' MD. Wash from 6650' MD to 6700' MD. Drill 12- 1/4" hole from 6700' MD to 6850' MD. Circ 2x BU. POOH from 6820' MD to 6340' MD, tight spot @ 6340' MD. BROOH from 6340' MD to 4515' MD. POOH on elevators, pulling tight. Circ 3x BU @ 2930' MD, fine sand & shale over shakers. Trouble time: 6.0 hrs. -MWD, hole conditions. Total to date: 64.0 hrs. Nov 18: BROOH from 4515' MD to 3314' MD. Circ 1x BU. POOH on elevators from 3314' MD to 200' MD. Stand back BHA. RU eline w/ ranging tool 8 gyro in combo. RIH to 6846' WLD 8~ log w/ ranging tool & gyro. POOH, LD ranging tool, gyro and RD lower sheave. PU BHA, RIH from 627' MD to 3314' MD. Attempt to circ -drill string plugged. POOH from 3314' MD to 626' MD. -Std back HWDP & DC's. Found DC's 8~ MWD packed with cuttings. Clean 8~ LD BHA. TD of 12-1/4" hole called at 6850' MD based on data from last ranging run, RR # 9. Trouble time: 5.5 hrs. -hole conditions, plugged pipe. Total to date: 69.5 hrs. Nov 19: Finish LD BHA. MU clean out BHA, RIH from 120' MD to 3346' MD. Circ 2x BU, RIH from 3346' MD to 6773' MD. Wash from 6773' MD to 6850' MD, circ 3x BU. POOH from 6850' MD to 6588' MD, BROOH from 6588' MD to 3624' MD. Circ 3x BU, observe heavy amt of cutting at shaker after 2x BU. BROOH from 3624' MD to 2883' MD, Circ 3x BU. POOH on elevators from 2883' MD to 566' MD. Std back HWDP & DC's, LD BHA. Pull wear bushing. Prep to change top pipe rams. Trouble time: 0.0 hrs. Total to date: 69.5 hrs. Nov 20: Changed upper pipe rams to 9 5/8" casing rams and tested to 250/5000 psi. Ran 9 5/8" casing to 6850' MD (stopped and circulated at 13 3/8" casing shoe and at 5316' MD). M/U cement head. Nov 21: Circulate and condition mud. Cement casing by pumping: 100 bbls low vis OBM, 20 bbls CW8, 40 bbls Mudpush II, 142 bbl class G cement @ 15.8 ppg, and displaced with 7 bbls Mudpush II and 505 bbls MOBM. Reciprocated pipe throughout job and plug bumped on calculated displacement volume. Set slips, cut casing, and installed pack-off. Changed upper pipe rams to 4'/2" x 7" VBR's. Tested BOPE to 250/5000 psi, annular to 250/3500 psi. Nov 22: Made up BHA and tripped in hole. Test casing to 3500 psi for 30 min (good test). Drilled firm cement from 6757' to 6850' MD. Swapped mud to 11.8 ppg MOBM with micronized barite. Drilled from 6850' to 6870'. Perform LOT to 14.4 ppg EMW. Drill ahead to 7000' MD. • r 2A-27 Well Status as of November 24, 2009 Permit to Drill Number: AOGCC 209107 API number: 103206040000 Current Operations: Daily Summary: Nov 23: After drilling to 7000' MD, POOH and L/D BHA. R/U a-line and run combo tool (Vector Magnetics and Gyrodata). Data shows edge to edge well separation of 2.46' +/- 0.75' @ 6989' MD. P/U BHA with WSAB (Wellspot at bit) and TIH. Drill to 7150' MD. Starting ranging run #11 as of 6 AM 11/24. RR#11 to be performed through drill pipe using side entry sub. Nov 24: WSAB sub failed (no signal). POOH and L/D BHA (6 of 8 retaining pins in WSAB were gone). R/U a-line and perform RR#11 in open hole. Target well is 5.7' away +/- 0.75' (126 deg left of high side) @ 7138' MD. Currently preparing to P/U drilling BHA to TIH and drill next ranging run depth (est. 7280' MD) Nov 25: P/U drilling BHA and TIH to 7150' MD. Drill to 7255' MD. Motor stalled at 7252' MD .while drilling ahead, and tubing pressure increased on 2A-06 from 533 psi to 973 psi (around, 19:00 11/25). Shut down pumps and pressure on 2A-06 fell to 800 psi. After resuming circulation on 2A-27, 2A-06 tubing pressure increased from 800 psi to 975 psi.. After drilling from 7252' to 7255' mud losses were noted on 2A-27, and drilling was stopped. Pressure was bled back on 2A-06 down to 680 psi, and was then shut in. Static mud losses on 2A-27 reduced rapidly to around 5 BPH after 2A-06 was shut in. 2A-06 tubing pressure has been stable at around 700 psi since it was shut in. POOH to shoe and discussed options. RIH to bottom (to make sure hole is in good condition for logging), then POOH and UD BHA. Currently running in hole with open ended drill pipe to 9 5/8" casing shoe, where magnetic ranging run #12 will be run through open ended drill pipe. Static losses remain around 5 BPH. Nov 26: POOH and L/D BHA (hole taking around 5 BPH). M/U muleshoe and TIH to 9 5/8" casing shoe. Run Vector Magnetics tools through side entry sub. VM tools confirmed 2A-06 wellbore was intersected on bottom of hole @ 7255' MD. Circulated MOBM around to surface on 2A-06. Established injection/circulation rates and pressures (circulating from 2A-27 through 2A- 06 to surface with annular preventer closed on 2A-27 and choke open on 2A-06): 2BPM @ 140 psi, 3 BPM @ 260 psi, 4 BPM @ 330 psi. Observed 1 MOBM to surface on 2A-06 at the n t. ~th ipe. m losses of 23 Is as of aU~60~'I'172'7/09'°"'~ _ Nov 27: IH with Baker packer with 2 joints of 2 7/8" tail pipe below packer. Set packer at 6745' MD inside 9 5/8" casing. Set packer and established circulation rate of 3 BPM @ 330 psi (taking returns out of 2A-06). Pump cement job as follows: 25 bbls 12.0 ppg spacer / 50 bbls 12.0 ppg LiteCRETE cement / 10 bbl 12.0 ppg spacer /Displace with 35 bbls 13.1 ppg hi-vis MOBM followed by 118 bbls 11.8 ppg MOBM. ISIP on 2A-27 - 250 psi ISIP on 2A-06 -150 psi. WOC for 12 hours. After midnight performed LOT on 2A-27: broke at 13.3 ppg EMW, repeat test broke at 13.06 ppg EMW. Small pressure response observed on 2A-06 during LOT (8 psi). Pumped 20 bbls diesel down tubing of 2A-06 at 0.5 BPM. Tubing pressure remained constant during test @ 150 psi. After 9 bbls pumped, observed slight flow on 2A-27, measured 0.5 bbls gained on 2A-27 upon completion of pumping the full 20 bbls. Unseated packer, and POOH. Nov 28: Finished POOH with squeeze packer. Tested BOP equipment to 250/5000 psi. Tested ar,~ular preventer to 2/3500 psi. After midnight,~l 8 %" clean out BHA and TIH. pumps off. Circulate and condition mud for liner job. POOH and L/D BHA. Minimal mud losses last 24 hours. 2A-06 has around 50 psi tubing pressure currently. r, ~~ is~ l~ ~ w 2A-27 Well Status week of November 30, 2009 Permit to Drill Number: AOGCC 209107 API number: 103206040000 Current Operations: Daily Summary: Nov 30: Ran 7" liner and tagged bottom at 7255' MD. P/U to place liner shoe @ 7248' MD. Set liner hanger, inflated ECP, and opened stage collar. Cemented liner with full returns. Reversed out 8 bbls contaminated cement off liner top after setting ZXP {lap packer). Dec 1: POOH and lay down liner running tools. P/U 6 1/8" clean out BHA. TIH and performed 10 minute pressure test to 2000 psi on top of stage collar (good test). Drilled out stage collar and performed liner test to 3500 psi for 30 minutes (good test). Drilled out float shoe and cleaned out down to intersection point at 7255' MD. No cement found below float shoe (as planned). Performed FIT to 15.0 ppg EMW. Formation did not break. No apparent pressure response on 2A-06 tubing pressure. 2A-06 tubing pressure has fallen from around 20 psi to around 5 psi since yesterday. 2A-06 OA was bled down from around 450 psi down to around 50 psi this morning. It built back to around 90 psi and is holding stable. Dec 2: Circulate, work bit from shoe to 7255' MD to create tough. Drill 1.5' of new hole. No increase in torque. RU and performed FIT test to 15.00 ppg EMW. POOH and lay down BHA. PU new BHA consisting of mill, motor 8~ MWD and RIH. Attempt to mill into 2A-06 casing and tubing to establish communication for squeeze. RIH to 7250' MD. Orient motor and time drill from 7250' MD to 7251.-~a-n~ nrecs~res holding stable Dec 3: Orient and time drill from 7251' MD to 7258' MD. Drill from 7258' MD to 7271' MD. Were unable to establish communication with 2A-06 tubing. POOH and lay down milling BHA and PU high shot density pert gun. Run in hole, set guns on depth with top shot at 7244' MD and bottom shot at 7259' MD. Fire guns, monitor well -static. Did not establish communication with 2A-06 tubing. CBU and pull out of hole. 2A-06 pressure stable with wellhead pressure at 0 psi and OA at 75 psi. Dec 4: Continue to POOH with pert guns. LD perf gun BHA. PU milling BHA consisting of bladed junk mill, motor (2.4° bend) and MWD. RIH with milling BHA. Orient and mill with several different TF settings in an attempt to 2A-06. Mill from 7250' MD to 7269' MD. Had best indication of milling from 7256' MD to 7260' MD, but no real definite signs of milling on csg. Perform FIT to 15.0 ppg EMW. POOH to LD milling BHA. 2A-06 pressure remains stable. Dec 5: Laid down milling BHA. Make up clean out BHA with bit and junk baskets, RIH. Wash and ream to 7271' MD (well TD). CBU, pump super sweep and circulate. POOH to 6683' MD, pump super sweep and circulate 3x BU. Had large amounts of shale with metal chips to surface after first BU then cleaned up. POOH and lay down clean out BHA. MU oriented pert gun BHA and RIH. 2A-06 pressure remains stable with wellhead pressure at 0 psi and OA at 72 psi. Dec 6: Continue to RIH with perf guns. Tag up at 7263' MD, space out with bottom shot at 7256' MD and top shot at 7241' MD. Rig up and run gyro to orient pert guns. Pump ball on seat to fire guns. Pull up and perform FIT to 15.0 ppg. No indication of communication with 2A-06. POOH to lay down perf guns. Conducted weekly BOP test. Witnessing of test waived. PU clean out BHA to rotate and circulate well clean prior to running Halliburton CAST tool. 2A-06 pressures remain stable. w • 2A-27 Well Status week of December 7, 2009 Permit to Drill Number: AOGCC 209107 API number: 103206040000 Current Operations: Daily Summary: Dec 7: Completed BOP test. Witnessing of the test was waived by AOGCC rep Jeff Jones. PU and ran clean out BHA. Wash and ream to 7271' MD, circulate and pump super sweep. POOH and LD BHA. Rig up and run Halliburton's CAST tool from 7241' MD to 7271' MD. Evaluate results. Log indicated pert guns fired as planned. Currently rigging down Haltiburton and preparing to PU tubing to spot plug. Dec 8: Completed rigging down Halliburton. PU tubing and 3-1/2" stinger for cement plug. RU Dowell and pump cement plug as follows: 9 bbls of 13.5 ppg MudPush, 25 bbls 15.8 ppg class G cement, 1 bbl 13.5 ppg MudPush. Displace cement with 110 bbls 11.8 MOBM. Pull up and circulate out contaminated cement, CBU. WOC a total of 14 hrs. Currently WOC to tag and test plug. AOGCC notified about testing plug. Dec 9: Completed WOC. Washed down and tagged cement at 6692' MD. RU and test casing and cement plug to 1500 psi for 30 minutes, test good. Test results sent to AOGCC rep. RU and displace well to 11.8 ppg brine with corrosion inhibitor. Completed displacing well, POOH laying down drill pipe. Currently completing laying down drill pipe. Dec 10: Completed POOH and laying down drill pipe and tubing. PU and run 4-1/2° kill string. Nipple down BOP, nipple up dry hole tree and test. Freeze protect well. Release rig at midnight on Dec 10. i • Time Lo s ' Date From To Dur S. De th E. De th Phase Code - Subcode T Comment 11:00 13:00 2.00 6,835 6,835 PROD1 EVALWE ELOG T Pull wireline f/inside DP f/ 6835' to 300' -Std back 1 std DP -Break out side entry sub -lift SES up to board - pull remaining wireline & Vector Magnetics tool f/ DP - LD tools to pipe shed -disconnect Hallburton socket f/ VM tool - RD lower wireline sheave - LD SES 13:00 13:30 0.50 6,835 7,150 PROD1 DRILL TRIP T RIH w/ bit f/ 6835' to 7150' PU wt. 199 k SO wt 140 13:30 14:30 1.00 7,150 6,835 PROD1 DRILL TRIP T Establish circ -stage pump up to 500 gpm @ 2920 psi - BROOH f/f! 7150' to 6835' w! pump @ 500 gpm @ 2920 psi w/ 70 rpm's -torque 5-7 k 14:30 15:00 0.50 6,835 6,835 PROD1 DRILL CIRC T Circ btms up @ 9 5/8" csg shoe - 500 gpm @ 2910 psi w/ 70 rpm's - rotating & recipricating pipe Monitor well 10 mins. Static -Blow down TD 15:00 19:00 4.00 6,835 627 PROD1 DRILL TRIP T POOH f/ 6835' to 627' (top of HWDP) - monitor well 10 mins. Static 19:00 20:30 1.50 627 0 PROD1 DRILL PULD T Std back HWDP & NM flex DC's - Down load MWD - LD MWD -Break bit &WSAB sub - LD motor * NOTE - 6 of 8 set screws on the top of the WSAB sub were gone - lowerset still in lace 20:30 21:00 0.50 0 0 PROD1 DRILL OTHR T Clean - up & clear rig floor 21:00 21:30 0.50 0 0 PROD1 EVALWE ELOG T PJSM - RU Halliburton E-line - PU G ro Data & Vector Ma netics tools 21:30 00:00 2.50 0 0 PROD1 EVALWE ELOG T RIH w/ Gyro Data /Vector Magnetics tools 11 /25/2009 Finished RR#11 - RD wireline -Cut & slip DL - MU BHA # 16 - RIH to 616' & shallow test MWD -RIH to 6850' - Break circ &circ btms up - RIH to 7150' -Drilled to 7255' @ 7252' .Observed pressure spike in target well - Appears to have intersected target well - Pull to 9 5/8" csg & Monitor well -Static losses 6-9 bbls/hr. Discuss o tions with in town drillin team & Boots & Coots - RIH to 7255' No Fill -POOH slowl to 6454' 00:00 04:00 4.00 0 0 PROD1 EVALWE ELOG P Continue RR #11 and gyros from 7145' to 6830'. POH w/ tools 04:00 05:00 1.00 0 0 PROD1 EVALWE ELOG P PJSM. RD Halliburton WL. 05:00 07:00 2.00 0 0 PROD1 RIGMNT SLPC P PJSM. Slip and cut drilling line. Service to drive, blocks and crown. 07:00 08:30 1.50 0 616 PROD1 DRILL PULD P MU BHA #16. Upload MWD. Pulse test tools at 616'. 08:30 12:00 3.50 616 6,157 PROD1 DRILL TRIP P RIH from 616' to 6157'. Fill pipe every 20 stds. 12:00 12:30 0.50 6,157 6,850 PROD1 DRILL TRIP P Inspect TD -Cont. RIH f/ 6157' to 6850' - MU TD PU wt. 176 SO wt. 145 Rot wt. 155 12:30 13:00 0.50 6,850 6,850 PROD1 DRILL CIRC P Break circ -stage pump up to 500 gmp @ 2900 psi - w/ 50 rpm's &circ btms. u 13:00 13:30 0.50 6,850 7,150 PROD1 DRILL TRIP P Cont. RIH f/ 6850' to 7110' - MU TD & Break circ -wash down f/ 7110' ti 7150' Page 24 of 36 :Time Lo s Date 'From To Dur S. De th E. De th Phase Code Subcode T Comment 13:30 19:00 5.50 7,150 7,255 PROD1 DRILL DDRL P Drilled 8 1/2" hole w/ motor f/ 7150' to 7255' MD 5422 TVD ADT- 3.08 hrs =ART .97 AST 2.11 hrs. WOB 25 k RPM 70 GPM 502 @ 3000 psi String wt. PU 187 SO 137 Rot 158 Torque on/off btm.- 8,000/6,000 ft/Ibs "* Note - @ 7252' observed rotary stall & pressure spike on 2A-06 well f! 533 psi to 973 psi -Shut down & monitored well -well static - Pressure on target well dropped to 800 psi -Drilled to 7255' -pressure on target well back to 975 psi -hole taking fliud loss 11 bbls -Shut down - Bleed target well to 680 psi - Stopped bleeding down target well - Pressure stabalized 700 si 19:00 22:30 3.50 7,255 6,824 PROD1 WELCTL OWFF P Pull up to 7193' -Monitor well on trip tank -Discussing options with Drilling Engineer & Boots & Coots - Pulled slowly back into 9 5/8" casing @ 6824' -Static losses 6 to 9 bbls/hr. -Pressure on target well stablizin 735 si 22:30 00:00 1.50 6,824 6,454 PROD1 DRILL TRIP P RIH slowly f/ 6824' to TD @7255' - Nofill -POOH slowly f/ 7255' to 6454' -Observed well @ 9 5/8" shoe - static losses 6 bbls/hr. 11 /26/2009 POOH w/ BHA # 16 - LD MWD & Motor - MU mule shoe & RIH w/ OEDP to 6850' - RU & run RR # 12 through & out the tail of 5" DP to 7250' (intersect of target well confirmed) - POOH w! wireline & RD -Monitor well - U tubing 11.8 ppg OBM into 2A-06 - OBM to surface 11.3 ppg -Est. injection rates @ 2 bbls/min 140 si - 3 bbls/min 260 si - 4 bbls/min 330 si -Monitor well -Blow down TD - POOH w/ OEDP f/ 6850' to 600' 00:00 03:30 3.50 6,454 616 COMPZ DRILL TRIP P POH from 6454' to 616'. Flow check well. Well still taking less than 6 b h. 03:30 05:00 1.50 616 0 COMPZ DRILL PULD P Std back HWDP, Jars and NMFC's. LD MWD, motor and bit. 05:00 05:30 0.50 0 0 COMPZ DRILL PULD P Clean and clear rig floor. 05:30 08:00 2.50 0 6,850 COMPZ DRILL TRIP P MU 4 1/2" mule shoe - RIH w/ DP to 6850' 08:00 08:15 0.25 6,850 6,850 COMPZ DRILL SFTY P Pre-job meting w/ rig crew & E line crew 08:15 15:00 6.75 6,850 6,850 COMPZ EVALWE ELOG P PU floor safety valve & side entry sub - PU Vector Mag. 2" Well spot tool - MU floor valve &SES to DP - RIH w/ tool to 7250' -Made Ranging run # 12 f/ 7250' -POOH w/wireline & tool to 300' 15:00 16:00 1.00 6,850 6,850 COMPZ EVALWE ELOG P Pre- job meeting -Break out SES & pull it up to working baord -Pull Well Spot tool out of DP w/ tuggers & LD tool in i e shed - RD E-line Page 25 of 36 r • Time Lo s .bate From To Dur S. De th E De th Phase Code Subcode <T Comment 16:00 17:00 1.00 6,850 6,850 COMPZ EVALWE OWFF P LD floor safety valve -Monitor well on tri tank 17:00 18:00 1.00 6,850 6,850 COMPZ DRILL CIRC P Open choke @ 2A-06 -Establish circ & stage pump up to 9 bbls/min @ 730 psi -Observed 11.3 ppg OBM f/choke @ 2A-06 -shut down pump - Monitorwell for 15 mins. very slight losses -Closed Hydril -Establish injection rate into 2A-06 - 2 bbls/min @ 140 psi - 3 bbls/min @ 260 psi - 4 bbls/min @ 330 psi -Pumped 12 bbls total -Observed pressure @ 2A-06 @ 100 psi or less during injection test - 9 bbls returns @ 11.5 ppg -pressure dropped off to 28 psi after injection test 18:00 19:30 1.50 6,850 6,850 COMPZ DRILL OWFF P Open Hydril -Blow down TD - Monitor well on TT lost 2 bbls in 45 mins. 19:30 00:00 4.50 6,850 600 COMPZ DRILL TRIP P POOH w/ OEDP f/ 6850' to 600' Lost 235 bbls OBM to 2A-06 last 24 hrs. 11 /27/2009 POOH w/ OEDP - MU squeeze packer &RIH -Monitor well -Set packer @ 6745' w/tail @ 6813' -Est. injection rate into 2A-06 @ 3 bbls/min @ 330 psi -Perform cmt squeeze into 2A-06 tbg x 7" annulus w/ 50 bbls 12.0 ppg Litecrete -displaced to place cmt f/ 6292' to 4392' - CIP @ 1400 hrs. Shut in both wells & WOC 00:00 00:30 0.50 600 0 COMPZ DRILL TRIP P Finish POH with 5" DP and mule shoe. 00:30 01:00 0.50 0 0 COMPZ DRILL PULD P Clear and clean rig flor. PU Baker pkr and 2 'ts of 2 7/8" tail i e. 01:00 05:00 4.00 0 6,813 COMPZ DRILL TRIP P RIH w/ 5" DP to 6745' w/ pkr and tail i e 6813'. 05:00 06:00 1.00 6,813 6,813 COMPZ CEMEN' RURD P RU head pin, safety valve and cement hose. 06:00 10:30 4.50 6,813 6,813 COMPZ CEMEN" OTHR T Monitor well for losses while waiting for bulk cement and batch mixer to arrive from Deadhorse. 10:30 11:00 0.50 6,813 6,813 COMPZ CEMEN" SFTY P PJSM with all personnel on cementin annulus of tar et well. 11:00 12:00 1.00 6,813 6,813 COMPZ CEMEN" CIRC P Set pkr at 6745' with end of 2 7/8" tail pipe at 6813'. Open choke on 2A-06 well. Pump 10 bbls 11.8 OBM down DP thru intersection on out 2A-06 at 3 b m 330 si. Page 26 of 36 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 14:00 2.00 6,813 6,813 COMPZ CEMEN" CMNT P Open by-pass on pkr. Shut-in 2A-06. Close annular preventer. Tested cement lines to 2000 psi. Schlumberger pump 25 bbls 12.0 ppg mudpush, 50 bbls 12.0 ppg LiteCrete followed by 10 bbls 12.0 ppg mud push. Held 150 psi back pressure on choke while taking returns to pits. Closed by-pass. Opened choke on 2A-06. Displace cement and spacers into 2A-06 annulus with 35 bbls 13.0 ppg OBM and 118 bbls 11.8 ppg OBM. Shut-in both wells. ISIP on 2A-27 = 250 psi. 2A-06 = 150 si. 14:00 .00:00 10.00 6,813 6,813 COMPZ CEMEN" WOC P Wait on cmt to attain 1000 psi com ressive stren th on UCA 11 /28/2009 WOC - RU & Perform LOT- RU -Pumped 20 bbls. diesel into 2A-06 -Observed slight flow @ 2A-27 after 9 bbls pumped -Release squeeze packer - Circ btms up - POOH w/ squeeze packer - LD 2 7/8" tail pipe & acker - RU & test BOPE -Had tq chan a rubber seal on test lu After test # 3 00:00 02:00 2.00 6,813 6,813 COMPZ CEMEN" WOC P WOC. Final press DP - 0 psi. 2A-06 - 126 si. 02:00 03:00 1.00 6,813 6,813 COMPZ CEMEN" LOT P Perform LOT w/ 11.8 ppg mud - 5172' TVD - 400 psi surface pressure for 13.28 ppg EMW. Change out pressure sensator. Perform 2nd LOT w/ 11.8 ppg mud - 5172' TVD -340 psi surface pressure for 13.06 ppg EMW 03:00 04:00 1.00 6,813 6,813 COMPZ CEMEN" OTHR P Little Red pumped 20 bbls diesel down tbg on 2A-06 at 1/2 bpm - 150 psi. After 9 bbls were pump observed slight flow in 2A-27. Gained 1/2 bbl in tri tank after 20 bbls um ed. 04:00 06:00 2.00 6,813 6,813 COMPZ DRILL CIRC P Release pkr. CBU at 4 bpm - 285 si. 06:00 07:00 1.00 6,813 6,813 COMPZ DRILL OWFF P Monitor well for flow. Blow down top drive ,choke manifold, kill and choke lines. 07:00 14:00 7.00 6,813 0 COMPZ DRILL TRIP P POH with 5" DP and pkr. Well not taking proper fill on 1st 10 stds. Bleed off pressure on 2A-06 and maintaine at 50 psi. Well static. POH slowly with 5" DP. Check flow eve 10 stds.. 14:00 14:30 0.50 0 0 COMPZ DRILL PULD P LD 2 jts. 2 7/8' tbg (tail pipe) & make service breaks on packer & LD acker Page 27 of 36 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:30 00:00 9.50 0 0 COMPZ WHDBO BOPE P Drain BOP stack -pull wear bushing - Set test plug - Ru to test BOPE - Test as follows: Tested Annular to 250 & 3500 psi -Tested pipe rams - choke manifold valves -Choke & kill lines valves - TD IBOP's -Floor safety & dart vlaves to 250 & 5000 psi -After test #3 had to pull test plug & change rubber -Set test plug & continue w/ testing. Test witnessed b Bob Noble AOGCC 11 /29/2009 Finish BOP test - MU BHA # 17 - RIH to 6824' -Cut & Slip drill line -Circ btms up - RIH f/ 6824' to 7255' TD - Circ 2X btms up while back reaming back to 6825' -Circ btms up F 6825' -Flow Ck - POOH to elevators to 2933' 00:00 04:00 4.00 0 0 COMPZ WHDBO BOPE P Finish testing BOPE remainder of ckoke manifold valves -lower pipe rams -blind ramsto 250 - 5000 psi. Performed accumulator recovery test - Could not get test on 7" test jt with u er VBRS. 5" tested OK. 04:00 05:00 1.00 0 0 COMPZ WHDBO BOPE P RD BOP test equipment. Pull test lu .Install wear bushin . 05:00 06:00 1.00 0 616 COMPZ DRILL PULD P MU BHA #17. Orient motor. Upload MWD. Pulse test MWD at 616'. 06:00 11:30 5.50 616 6,824 COMPZ DRILL TRIP P RIH slow with 5" DP from 616' to 6824'. Fill i e eve 20 stds. 11:30 13:30 2.00 6,824 6,824 COMPZ RIGMNT SLPC P Cut & slip drill line -service top drive 13:30 14:30 1.00 6,824 6,824 COMPZ DRILL CIRC P Break circ &Circ btms up @ 400 gpm @ 1970 psi - PU wt. 177 SO wt. 144 Rot. wt 162 -Tor ue 5 k 14:30 15:00 0.50 6,824 7,255 COMPZ DRILL TRIP P RIH f/ 6824' & tag btm @ 7255' 15:00 17:30 2.50 7,255 6,825 COMPZ DRILL TRIP P Break circ & stage pumps up to 400 gpm @ 2010 psi - BROOH f/ 7255' to 6825' while circ 2 X btms u 17:30 19:00 1.50 6,825 6,825 COMPZ DRILL CIRC P Break circ &circ btms up @ 500 gpm @ 2820 psi w/ 50 rpm's -torque 5 k -Flow ck 10 mins. -well static - Blow down TD -Dropped 2 7/8" OD holllow drift 19:00 00:00 5.00 6,825 2,933 COMPZ DRILL TRIP P POOH f/ 6825' to 2933' -hole taking ro er frill 11 /30/2009 POOH and lay down BHA. Change Upper 7" x 4" VBR's and test to 250/5000 psi. Make up 7" liner and hanger and run in the hole to 7248'. Circulate and condition mud. Drop opening dart and displace to set liner han er. 00:00 02:30 2.50 2,933 616 COMPZ DRILL TRIP P Finish POH with 5" DP from 2933' to 616'. Hole was takin ro er fill. 02:30 04:00 1.50 616 0 COMPZ DRILL PULD P Std back HWDP, jars and collars. LD MWD, motor and bit. 04:00 05:00 1.00 0 0 COMPZ WHDBO BOPE T Clean and clear rig floor. Pull wear bushin .Install test lu . 05:00 10:00 5.00 0 0 COMPZ WHDBO BOPE T PJSM. Replace elements on upper VBR. Test 5" and 7" VBR's to 25- 5000 psi. Pull test plug. Install wear bushin . Page 28 of 36 i Time Lo _s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:00 10:45 0.75 0 0 COMPZ CASING RURD P RU 7" liner equipment. 10:45 11:00 0.25 0 0 COMPZ CASING SFTY P PJSM with all personnel on running 7" liner and a ui ment. 11:00 14:00 3.00 0 530 COMPZ CASING PUTB P RIH with 7" float shoe, Halliburton baffle collar, 1 jt 7" csg, Baker ECP, Halliburton ES Cementer and 11 jts 7" 26# L-80 BTCM csg. Re-drift Baker running tool to 3.375". MU Halliburton wiper pluig assembly on Baker running tool. MU liner hange and ZXP kr. 14:00 14:30 0.50 530 530 COMPZ CASING CIRC P Circulate 1-1/2 times casing volume at 4 b m/ 90 si 14:30 19:00 4.50 530 6,864 COMPZ CASING RUNL P Run 7" liner on drill pipe filling every 10 stands from 560'. to 6864' 19:00 19:30 0.50 6,864 6,864 COMPZ CASING CIRC P Circulate pipe volume ata 4 bpm/240 si. P/U = 170k, S/O = 137k 19:30 20:00 0.50 6,864 7,230 COMPZ CASING RUNL P Run in the hole from 6864' to 7230'. Mud flowin u drill i e 20:00 20:30 0.50 7,230 6,864 COMPZ CASING PULL P Pull out of the hole from 7230' to 6864' 20:30 21:30 1.00 6,864 6,864 COMPZ CASING CIRC P Circulate pipe volume at 6 bpm/ 450 si and check float-OK 21:30 22:00 0.50 6,864 7,255 COMPZ CASING RUNL P Run in the hole with 7" liner from 6864' and to bottom at 7255' 22:00 22:30 0.50 7,255 7,248 COMPZ CEMEN" RURD P Stand back one stand and blow down top drive. Make up 15' drill pipe pup jt. and cement head. Hook up lines to cement head and set liner on de th at 7248' 22:30 23:30 1.00 7,248 7,248 COMPZ CEMEN" CIRC P Circulate and condition mud at 6 b m/580 si. 23:30 00:00 0.50 7,248 7,248 COMPZ CEMEN" PACK P Safety meeting with cementers. Pump 2 bbl mud and test lines to 4000 psi. Drop first dart and pump 113 bbl mud 12/01 /2009 Pump & bump plug, Set Hanger, Inflate ECP, Open Stage collar, Break circ, Cement liner w/ 10 bbls CW100, 30 bbls 13.5 ppg MudPush, 26.3 bbls 15.8 ppg CMT, Drop plug #2, Pmp 25 bbls 13.5 ppg MudPush, 132 bbls 11.8 ppg mud, Bump plug w/ 2700 psi, Circ 2X btu, POOH w/ liner running tool, M/U clean out BHA, RIH & Ta cmt strip er 6855', Test liner to to 2000 si f/ 10 min, Drill cmt to 7164' & drill on sta a collar. 00:00 01:00 1.00 7,248 7,248 COMPZ CEMEN" PACK P Continue pump 113 bbl 11.8 ppg mud. Bump plug. Pressure DP to 1500 psi to set hanger - 2000 psi to inflate pkr -3400 psi to open stage tool. 01:00 01:30 0.50 7,248 7,248 COMPZ CEMEN" CIRC P Circulate well at 6 bpm - 600 psi while transferring fluid. Schlumberger batched u cement. 01:30 03:00 1.50 7,248 7,248 COMPZ CEMEN" CMNT P Schlumberger pumped 10 bbls CW8, 30 bbls 13.5 ppg mudpush, 26.3 bbls 15.8 cement, dropped top plug, 25 bbls 13.5 ppg mudpush and 108 bbls 11.8 OBM. Bumped plug to close ES cementer with 2600 si. Page 29 of 36 n r Time L s Date From To Dur S. De th E. De th, Phase ` Code Subcode T Comment 03:00 04:00 1.00 7,248 7,248 COMPZ CEMEN" CIRC P Pull seals out of pkr. Set ZXP liner top pkr. Reverse out approx 8 bbls cement. 04:00 05:00 1.00 7,248 6,600 COMPZ CEMEN" RURD P RD cement line and top drive head. Set back 1 std DP. 05:00 06:00 1.00 6,600 6,600 COMPZ CEMEN" CIRC P CBU 2X at 12 bpm - 1120 psi to clear DP of an residual cement. 06:00 06:30 0.50 6,600 6,600 COMPZ DRILL OWFF P Monitor well. Blow top drive. 06:30 10:30 4.00 6,600 0 COMPZ DRILL TRIP P POH with 5" DP and Baker setting tool. 10:30 11:00 0.50 0 0 COMPZ DRILL RURD P PJSM with crew and Halliburton personnel. Remove upper wireline sheave from derrick. 11:00 12:00 1.00 0 0 COMPZ DRILL PULD P Lay down GAP subs from derrick, Clear ri floor 12:00 13:30 1.50 0 0 COMPZ DRILL PULD P Lay down MWD tools, Jars, Flex collars & 5" HWDP in mouse hole, Clear ri floor. 13:30 14:30 1.00 0 0 COMPZ DRILL PULD P MOB BHA tools to rig floor. 14:30 18:00 3.50 0 777 COMPZ DRILL PULD P PJSM, Make up 6-1/8" clean out BHA 18:00 21:00 3.00 777 6,855 COMPZ DRILL TRIP P RIH & Tag cement stringer @ 6855' 21:00 22:00 1.00 6,855 6,855 COMPZ DRILL PRTS P Rig & Test liner top to 2000 psi f/ 10 min - OK 22:00 00:00 2.00 6,855 7,164 COMPZ DRILL COCF P Drill out cement stringer f/ 6855' to 7164' Stage collar Up 165K, Dn 138K, Rot 150K, 285 gpm @ 1820 si, 30 RPM w/ 4K T 12/02/2009 Continue to drill out stage collar f/ 7164' to 7169', Circ BTU, Test csg to 3500 psi f/ 30 min - OK, Wash f/ 7169' to 7245', Drill out shoe @ 7248', Circ BTU, Perform 15.0 ppg EMW FIT, Trench hole f/ 7248' to 7255', Re eat 15.0 EMW FIT w/ same results, POOH break bit, M/U 6"Mill &MWD BHA, RIH to 6720'. 00:00 01:00 1.00 7,164 7,169 COMPZ DRILL COCF P Drill stage collar from 7164' to 7169'. Up 165K, Dn 138K, Rot 150K, 285 m 1750 si, 30 RPM w/ 4K T 01:00 02:00 1.00 7,169 7,169 COMPZ DRILL CIRC P CBU at 285 gpm - 1800 psi - 40 rpm. 02:00 03:00 1.00 7,169 7,169 COMPZ DRILL DHEQ P Blow down top drive. RU and pressure test 9 5/8" csg and 7" liner to 3500 si for 30 min. OK. 03:00 05:00 2.00 7,169 7,169 COMPZ DRILL COCF P Drill out cement stringers, wiper plugs and float collar from 7185' to 7248'. Tag bottom at 7255' with out um s. Std back 1 std to 7169'. 05:00 06:30 1.50 7,169 7,169 COMPZ DRILL CIRC P CBU 1.5x at 285 gpm - 1850 psi - 40 r m. 06:30 09:00 2.50 7,169 7,169 COMPZ DRILL FIT P RU and perform FIT with 11.8 ppg mud - 5422' TVD - 900 psi surface pressure - 15 ppg EMW. Monitor pressure while discussing plan forward. 09:00 10:30 1.50 7,169 7,257 COMPZ DRILL CIRC P Circ well at 285 gpm - 1850 psi - 40 rpm. Work bit from shoe to 7255' to create trough. Drill 1.5' new hole. No increase in for ue. .Page 30 of 36 Time Lo s :.Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:30 11:00 0.50 7,257 7,257 COMPZ DRILL FIT P RU and perform FIT with 11.8 ppg mud - 5422' TVD - 900 psi surface ressure - 15 EMW 11:00 16:00 5.00 7,257 777 COMPZ DRILL TRIP P Check flow. POH with 5" DP to BHA 16:00 17:30 1.50 777 0 COMPZ DRILL PULD P Stand back 4" HWDP, Flex collars, Clean Junk baskets 17:30 20:30 3.00 0 790 COMPZ DRILL PULD P Pick up MWD & Motor, Shallow test MWD, Beak off bit, Make up 6" Mill, Adjust AKO to 1.76, Oreint MWD, RIH w/ BHA 20:30 00:00 3.50 790 6,720 COMPZ DRILL TRIP P RIH to 6720' 12/03/2009 RIH w/ 6" Milling BHA to 7250', Attempt to mill into 2A-06 csg & tbg f/ 7250' to 7258' - N.G, Drill new hole to 7271' for Perf gun spacing, Work tight hole @ 7271' & circ, POOH w/Milling BHA, Wait on pert guns, M/U Perf un Assembl , RIH to 6799' 00:00 01:00 1.00 6,720 7,250 COMPZ DRILL TRIP P Continue RIH with 5" DP from 6720' to 7250'. Check SPR's. 01:00 05:30 4.50 7,250 7,258 COMPZ DRILL MILL P Orient and time drill from 7251' to 7258' at 285 gpm - 2400 psi in a attempt to mill into 7" csg of 2A-06 with no success. 05:30 06:30 1.00 7,258 7,271 COMPZ DRILL DDRL P Drill 6 1/8' hole with concave mill from 7258' to 7271'. Stalled motor and rotary. Work pipe free. Flow check well. Static. 06:30 08:30 2.00 7,271 7,271 COMPZ DRILL CIRC P Circ and reciprocate pipe from 7249' to 7271' at 300 gpm - 2630 psi - 40 r m. 08:30 09:00 0.50 7,271 7,250 COMPZ DRILL OWFF P Monitor well. Static. Blow down top drive. 09:00 12:00 3.00 7,250 1,716 COMPZ DRILL TRIP P POOH to 1716' 12:00 12:30 0.50 1,716 1,716 COMPZ RIGMNT SVRG P Service rig & top drive 12:30 14:30 2.00 1,716 0 COMPZ DRILL TRIP P POOH to BHA, Stand back & Lay down Mill BHA 14:30 19:00 . 4.50 0 0 COMPZ DRILL OTHR T Wait on pert guns 19:00 21:00 2.00 0 683 COMPZ DRILL PULD P PJSM, Bring tools to floor, Make up & RIH w/Gun BHA 21:00 00:00 3.00 683 6,799 COMPZ DRILL TRIP P RIH w/Guns to 6799' 12/04/2009 RIH w/ Guns to 7260' (Tagged Fill), Set guns on depth, Drop ball & Shot .34" - 12 SPF @ 45 deg Phase holes f/ top shot @ 7244' / Btm shot @ 7259', Pull guns out of open hole, Monitor well -Static, Circ BTU, Perform 15 ppg EMW w/ 910 psi, 1514' TVD, 11.8 ppg mud, POOH to 5408', Cut & Slip Drlg line, Service rig, POOH & UD Gun BHA, M/U 6" Mill #2 w/ Motor set at 2.4 AKO &MWD, RIH to 7250', Mill w/ several different tool face settin sin attem t to mill 2A-06 No real ood indication of millin on cs 00:00 01:00 1.00 6,799 7,260 COMPZ DRILL TRIP P Continue RIH w/ pert guns from 6799' and tag up at 7260'. Spot guns with top shot at 7244' and bottom shot at 7259'. 12 s f - 45° hasin . 01:00 02:00 1.00 7,260 7,260 COMPZ DRILL PERF P Drop 5/8" ball. Pressure DP to 2000 si to fire uns. Monitor well. Statick 02:00 03:00 1.00 7,260 7,239 COMPZ DRILL CIRC P CBU at 250 gpm - 1510 psi. 03:00 04:00 1.00 7,239 7,239 COMPZ DRILL FIT P Perform 15 ppg EMW FIT. No communication to ZA-06. Results were similar to revious FIT's. Page 31 of 36- Time Lo s Date from To bur S. De th E. De th Phase Code Subcode T Comment 04:00 05:30 1.50 7,239 5,408 COMPZ DRILL TRIP P POH with 5" DP from 7239' to 5408'. 05:30 07:30 2.00 5,408 5,408 COMPZ DRILL SLPC P Slip and cut drilling line. Service top drive. 07:30 12:00 4.50 5,408 683 COMPZ DRILL TRIP P POH with 5" DP from 5408' to 683'. Flow check well. OK. Change handlin a ui ment to 4". 12:00 13:30 1.50 683 0 COMPZ DRILL PULD P Break & Lay down Perfguns 13:30 15:30 2.00 0 786 COMPZ DRILL PULD P Make up Motor &MWD, Adjust motor to 2.4 AKO, Orient tools, Shallow test MWD, Make up 6"Junk Mill, RIH w/ BHA 15:30 19:00 3.50 786 7,250 COMPZ DRILL TRIP P RIH to 7250' 19:00 00:00 5.00 7,250 7,269 COMPZ DRILL MILL P Orient & Mill with several different tool face settings in attempt to Mill into 2A-06 f/ 7250' to 7269', Up 173K, Dn 142K, 250 gpm @ 1680 psi (Note; Had best indication of milling f/ 7256' to 7260' but no real definite si ns of millin on casin 12/05/2009 Continue to mill on 2A-06 csg to achive communication f/ 7250 to 7269', Perform 15 ppg FIT- No communication, POOH (Had tight hole in 7" csg f/ 6777' to 6710' -Possibly due to metal shavings bird nest), POOH & UD Mill & Motor BHA, M/U Bit f/ clean out run, RIH to 7238', Wash to TD @ 7271', Circ hole clean & Pump super sweep, POOH to top of liner @ 6694' Circ hole clean & Pump super sweep, POOH & Stand back HWDP 00:00 02:00 2.00 7,269 7,269 COMPZ DRILL MILL P Orient & Mill with several different tool face settings in attempt to Mill into 2A-06 f/ 7250' to 7269', Up 173K, Dn 142K, 250 m 1680 si 02:00 02:30 0.50 7,269 7,240 COMPZ DRILL FIT P RU and perform 15 ppb EMW FIT. No communication with 2A-06. 02:30 03:45 1.25 7,240 6,710 COMPZ DRILL TRIP P POH from 7240' to 6777'. Work thru tight hole from 6777' to 6710'. Flow check well. Static. 03:45 08:00 4.25 6,710 786 COMPZ DRILL TRIP P POH from 6710' to 786'. 08:00 09:30 1.50 786 0 COMPZ DRILL TRIP P Monitor well. Change handling e ui ment to 4". POH BHA. 09:30 10:00 0.50 0 0 COMPZ DRILL OTHR P Clean and clear rig floor. 10:00 11:30 1.50 0 753 COMPZ DRILL PULD P PJSM. MU clean out BHA. 11:30 12:00 0.50 753 2,143 COMPZ DRILL TRIP P RIH from 753' to 2143'. 12:00 12:30 0.50 2,143 2,143 COMPZ RIGMNT SVRG P Service rig and inspect top drive. 12:30 14:30 2.00 2,143 7,238 COMPZ DRILL TRIP P RIH f/ 2143' to 7238' 14:30 15:00 0.50 7,238 7,271 COMPZ DRILL REAM P Wash & Ream f/ 7238' to 7271', Up 173K, Dn 143K, Rot 155K, 500 gpm w! 60 RPM, 5K T 15:00 17:30 2.50 7,271 7,271 COMPZ DRILL CIRC P Circ BTU w/ 500 gpm @ 2560 psi, 80 RPM, Pump 40 bbls Super sweep & Circ hole clean 17:30 18:00 0.50 7,271 6,683 COMPZ DRILL TRIP P Monitor well, POOH to 6683' Page 32 of 36 +• Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 19:30 1.50 6,683 6,683 COMPZ DRILL CIRC P Break circ, Pump 40 bbls Super sweep, Circ 3 time BTU & Hole clean at rate of 640 gpm @ 3590 psi, 120 RPM 4K Tq, Had large amounts of shale with metal chips to surface for first BTU then cleaned u . 19:30 23:00 3.50 6,683 753 COMPZ DRILL TRIP P Monitor well, POOH to BHA @ 753' 23:00 00:00 1.00 753 200 COMPZ DRILL TRIP P POOH & Stand back HWDP 12/06/2009 Continue to POOH w/Clean out BHA, UD BHA & Clean out boot baskets, Service rig, M/U Oriented Gun assembly, RIH to 7263' (Tag fill), Space out guns on depth, Rig Halliburton & GYRO, RIH w/ GYRO & Orient guns, POOH w/ GYRO, Drop ball & rig down GYRO /Halliburton, Pump ball on seat & fire 5 spf, "O" Phasing guns into 2A-06 -top shot @ 7241' / btm @ 7256', Pull up to 7165' & perform 15.0 ppg FIT (No sign of communication with 2A-06), CBU, POOH & UD Gun assembly, Flush stack, Pull wear bushing, Set test lu & Be in BOP Test. 00:00 01:00 1.00 200 0 COMPZ DRILL TRIP P POH with BHA. 01:00 01:30 0.50 0 0 COMPZ RIGMNT SVRG P Service drawworks. Inspect top drive and blocks. 01:30 04:00 2.50 0 676 COMPZ PERF PULD P Clear floor. PJSM. MU 15' perfgun assembl .RIH 'ars and 4" HWDP. 04:00 08:00 4.00 676 7,257 COMPZ PERF TRIP P RIH with assembly on 5" DP. Tag up at 7263'. Space out with bottom shot at 7256'. 08:00 15:00 7.00 7,257 7,257 COMPZ PERF PERF P PJSM, Rig Halliburton wire line sheaves in derrick, Rig GYRO, RIH w/GYRO & take check shots, Orient 15' of Guns on depth for top 8' to shoot at 125 left of high side and bottom 7' to shoot at 180 to perforate 2A-06, POOH w/ GYRO. 15:00 15:30 0.50 7,257 7,257 COMPZ PERF PERF P Drop firing head ball, Rig down GYRO, Halliburton & sheaves. 15:30 16:00 0.50 7,257 7,257 COMPZ PERF PERF P Pump ball on seat at 2 bpm @ 270 psi, Pressure up to 2390 psi & fire guns 1/2" - 5 spf at "O" Phase top shot @ 7241' w/ btm shot @ 7256', Good indication of uns firin . 16:00 17:00 1.00 7,257 7,165 COMPZ PERF LOT P POOH 1 stand to 7165', UD TIW valve & Pup jt. ,Rig & perform 15.0 ppg EMW FIT w/ 910 psi, 5415 TVD, 11.8 ppg mud (No sign of communication with 2A-06 17:00 18:30 1.50 7,165 7,165 COMPZ PERF CIRC P Circ BTU at 5 bpm @ 1220 psi 18:30 21:30 3.00 7,165 676 COMPZ PERF TRIP P POOH w/Guns to 676' 21:30 23:00 1.50 676 0 COMPZ PERF PULD P Change over to 4" elevators & dies, POOH & stand back HWDP & Jars, UD Guns (All guns fired & Guns were still oriented correctly to UBHO sub 23:00 23:30 0.50 0 0 COMPZ WHDBO BOPE P Pick up wash tool & wash stack for BOP Test, Pull wear bushing, Rig up floor valves. 23:30 00:00 0.50 0 0 COMPZ WHDBO BOPE P Testing floor valves to 250 psi low & 5000 psi high while Installing test lu ,Fill choke, Ri test a ui . Page 33 of'36 Time Lo 's :Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12/07/2009 2a hr Summary Finish testing BOPE to 2501ow & 5000 high, Hydril 250 low & 3500 high -Test waived by AOGCC Jeff Jones, Pull test plug & run wear bushing, M/U 6-1/8" bit & BHA, RIH to 3984', Slip & cut drlg line & service rig, Replace drawworks chain, RIH to 7225', Wash to 7271', Pump Super sweep @ 7246', POOH to 740', Change over to 4" & UD 4" HWDP, Jars, Flex DC's, Break bit. 00:00 07:00 7.00 0 0 COMPZ WHDBO BOPE P Test all BOPE to 250 - 5000 psi with annular to 3500 psi. Used 5" and 4 1 /2" test jts. Witness of test was waived b AOGCC re Jeff Jones. 07:00 08:00 1.00 0 0 COMPZ WHDBO BOPE P Pull test plug and install wear bushin . 08:00 08:30 0.50 0 0 COMPZ DRILL PULD P Clean and clear rig floor. 08:30 11:00 2.50 0 3,984 COMPZ DRILL TRIP P MU 6 1/8" bit. RIH with 4" HWDP and 5" DP to 3984'. 11:00 13:30 2.50 3,984 3,984 COMPZ RIGMNT SLPC P PJSM. Slip and cut drilling line, Service ri . 13:30 14:30 1.00 3,984 3,984 COMPZ RIGMNT RGRP T Replace drawworks chain 14:30 16:00 1.50 3,984 7,246 COMPZ DRILL TRIP P RIH to 7225', Wash & Ream to 7271' TD with 500 gpm @ 2410' psi & 60 RPM, Pick up to 7246' inside 7" shoe. 16:00 17:30 1.50 7,246 7,246 COMPZ DRILL CIRC P Pump 40 bbls Super sweep at rate of 600 gpm @ 3050 psi, 80 RPM w/ 4K T. 17:30 21:00 3.50 7,246 740 COMPZ DRILL TRIP P POOH to BHA @ 740' 21:00 00:00 3.00 740 0 COMPZ DRILL PULD P Change over to 4" elevators, Lay down 4" HWDP, Jars, XO's, Flex Collars & Bit. Pick up MWD from pipe shed & Break service breaks, Clear floor of service tools. 12/08/2009 Rig & run Halliburton C.A.S.T. log to 7260', POOH & rig down loggers, Rig & run 30 jts 3-1/2" PH-6 tbg, RIH to 7271', Circ BTU, Rig Dowell test lines to 2000 psi, Pump 9 bbls 13.5 ppg MudPUSH, 25 bbls 15.8 ppg cmt, 1 bbls MudPUSH, Displace cmt w/ 110 bbls 11.8 ppg OBM CIP @ 20:25 hrs (Calc TOC @ 6654'), POOH to 6318', Circ out trace cmt & s acer, Circ hole clean, WOC 00:00 00:30 0.50 0 0 COMPZ DRILL PULD P Brought muleshoe and XO to rig floor. 00:30 01:45 1.25 0 0 COMPZ EVALWE ELOG P PJSM. RU Halliburton E log. 01:45 04:15 2.50 0 0 COMPZ EVALWE ELOG T RIH with CAST Log. Tool failed POOH and Chan ed out tool. 04:15 11:30 7.25 0 0 COMPZ EVALWE ELOG P RIH with CAST Log. and ran log to 7260'. POOH and ri ed downt tool. 11:30 15:00 3.50 0 945 COMPZ CEMEN" PUTB P Rig & Pick up 30 jts. 3-1/2", 12.95#, PH-6 tb , Ri down ower ton s. 15:00 15:30 0.50 945 945 COMPZ CEMEN" CIRC P Pump pipe volume 250 gpm @ 290 si 15:30 17:00 1.50 945 7,271 COMPZ CEMEN" TRIP P RIH w/ 5" DP to 7271' Tag btm. 17:00 17:30 0.50 7,271 7,266 COMPZ CEMEN" RUf~D P Rig Dowell, Break circ, Wash down & tagged up at 7266' unable to work ast 7266' 17:30 19:30 2.00 7,266 7,266 COMPZ CEMEN" CIRC P Circ hole clean at rate of 600 gpm @ 3190 si. Page 34 of 36 ~~ Time Lo s Date From To Dur S De th E. De th Phase `Code Subcode T Comment 19:30 20:00 0.50 7,266 7,266 COMPZ CEMEN" CMNT P Help PJSM on laying cmt plug with Dowell and all hands, Batch mix cement & Spacer (Cement batched at 19:40 hrs), Switch over to Dowell, Pump 2 bbls 13.5 ppg MudPUSH, Test lines to 2000 psi - OK, Continue to Total of 9 bbls 13.5 ppg MudPUSH at rate of 2.4 bpm @ 160 psi, followed by 25 bbls (121 sxs) 15.8 ppg Cement at rate of 4.0 bpm @ 225 psi, Followed cmt w/ 1 bbl 13.5 ppg MudPUSH at rate of 2.2 bpm @ 160 si. 20:00 20:30 0.50 7,266 7,266 COMPZ CEMEN' DISP P Switch over to rig & Displace cement w/ 110 bbls 11.8 ppg OBM at rate of 9 bpm @ 1150 psi - CIP @ 20:25 hrs. 20:30 21:30 1.00 7,266 6,318 COMPZ CEMEN' TRIP P Lay down single, POOH 10 stands to 6318' 21:30 00:00 2.50 6,318 6,318 COMPZ CEMEN' CIRC P Circ BTU at rate of 650 gpm @ 2740 psi, Had trace of cement & spacer at bottoms up, Continue to circ hole clean, U 140K, Dn 125K, Rot 130K. 12/09/2009 Wait on cmt, RIH & Wash f/ 6659' to 6692' (Tagged cmt @ 6692' w/ 10K while pumping 265 gpm @ 550 psi), Circ hole clean, Pull to 6596', Test csg & cmt plug to 1500 psi f/ 30 min - OK, Pump spacers & Change over to 11.8 ppg Brine, Observed contamination of fluids for last +/- 130 bbls brine on DP side, Reverse circ 75 bbls Brine, Clean its & UD 5" DP in derrick while wait on more brine. 00:00 10:00 10.00 6,318 6,226 COMPZ CEMEN' WOC P Pull 1 stand to 6226', Wait on cement 10:00 10:30 0.50 6,226 6,659 COMPZ CEMEN' TRIP P RIH f/ 6226' to 6659' 10:30 12:00 1.50 6,659 6,596 COMPZ CEMEN' WASH P Wash down f/ 6659' to 6692' & Tag cmt w/ 10K while pumping 265 gpm @ 550 psi, Circ btm's up at rate of 460 gpm @ 1490 psi, Rack back 2 stands to 6596' 12:00 13:30 1.50 6,596 6,596 COMPZ CEMEN' PRTS P Rig & Test casing & cement plug to 1500 si f/ 30 min - OK 13:30 15:30 2.00 6,596 6,690 COMPZ DRILL CIRC P RIH to 6690', PJSM, Pump 35 bbls LVT-200, 60 bbls Hot Seawater, 30 bbls Hi-vis Spacer Displace well to 11.8 ppg Brine at rate of 12 bpm @ 1150 si, 60 RPM 15:30 17:30 2.00 6,690 6,690 COMPZ DRILL CIRC P Break head pin off drill pipe and observed OBM in pipe, After investigation found that +/- 130 bbls OBM had been pumped at the last end of displacement. Rig & reverse circ 75 bbls 11.8 ppg brine down annulus at rate of 5 bpm @ 650 psi - No brine to surface et. 17:30 19:00 1.50 6,690 6,690 COMPZ DRILL OTHR P Clean mud pits while waiting on more brine 19:00 21:00 2.00 6,690 6,690 COMPZ DRILL PULD P Lay down drill pipe from derrick via mouse hole 21:00 23:00 2.00 6,690 6,690 COMPZ DRILL OTHR T Wait on more brine Page 35 of 36 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 23:00 00:00 1.00 6,690 6,690 COMPZ DRILL CIRC P Spot brine truck in position, PJSM, Reverse circ 120 bbls 11.8 ppg brine until clean 12/10/2009 Finish reverse circ brine, service rig, POOH & Lay down 5" DP &Tbg, Rig & run 4-1/2" Kill string to 2068', N/D BOP, N/U Tree & test same to 250 low &500 psi high, Rig little red &circ 151 bbls diesel around to surface, Set BPV, Secure well, Release ri at Midni ht. 00:00 00:30 0.50 6,690 6,690 COMPZ DRILL CIRC P Finish Reverse circ 120 bbls 11.8 brine until clean 00:30 01:00 0.50 6,690 6,690 COMPZ RIGMN7 SVRG P Service rig 01:00 07:00 6.00 6,690 0 COMPZ DRILL PULD P PJSM, POOH laying down 5" Drill i e & 3-1/2" tb cmt strin 07:00 07:30 0.50 0 0 COMPZ DRILL OTHR P Pull wear bushing 07:30 12:00 4.50 0 2,037 COMPZ DRILL RCST P PJSM, Rig tubing tongs, Pick up & run Kill string as follows -Wire line entry guide, 4-1/2", 12.6#, L-80, IBTM 5' Pup, 4-1/2" Camco 3.875" DB Nipple, 66 jts 4-1/2", 12.6#, L-80, IBTM Tbg (All tbg special clearance 4.92" OD Collars -Except bottom 12 jts which are 5.25" OD Non special clearance ,FMC Han er w/ u 12:00 13:00 1.00 2,037 2,068 COMPZ DRILL HOSO P Land tubing hanger w/ Wire line guide @ 2,068.68', RILDS, Lay down landin 't., Install FMC 2-wa check 13:00 14:00 1.00 2,068 2,068 COMPZ DRILL PULD P Clear floor of all service tools 14:00 16:00 2.00 COMPZ DRILL NUND P Nipple down flow line, riser, choke line, BOP & stand back BOP 16:00 20:30 4.50 COMPZ DRILL NUND P Nipple up adapter flange, Test same to 250 low & 5000 psi high, Nipple up dry hole tree & test same to 2501ow & 5000 si hi h, Pull 2-wa check 20:30 22:30 2.00 COMPZ DRILL FRZP P Rig little red service, Test lines to 2500 psi, Pump 151 bbls diesel down annulus & up tbg until diesel to surface at rate of 2 bpm @ 650 psi, Ri down little red. 22:30 00:00 1.50 COMPZ DRILL OTHR P Rig FMC, Set BPV, Rig down FMC, Rig down all pump lines on well, Secure well, Clean cellar. Released ri at Midni ht Page 36 of 36 Page 1 of 1 Schwartz, Guy L (DOA) From: Reimer, David J (David.J.Reimer@conocophitlips.com] Sent: Monday, December 07, 2009 3:36 PM To: Schwartz, Guy L (DOA) C~ „ .~ t(! ~' Subject: 2A-06 ~, v Guy: Per our discussion, CPAI would like to request changing the status of 2A-06 from plugged to suspended. Thanks Dave 12/7/2009 ~J ~ p ~ :~ ~. ~ ~:~ ~ ~ 1 V ~ ; µ' r~~-k ~ ~ r ~ fi~ ,~ k 'i~.. B k~~ ~ rc ~ ~ ~^ ~,~ ~ ~ ~' ~ p ~ t " € R ~ k$~~ ~ ~ ~ ~ a ~ ~~ ' ~`R ~ r ~ ~ ~ ~~ ~ ~ ~ ~~ ~ ~ SEAN PARNELL, GOVERNOR 11~ ~.~,, ~ . a '~ ~ ~~~~~~~ ~r~ ~~ ~ ~ ~~~~~ tLUt~-7~ ~IL tu~is 17~7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOr1T COM~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Scott Lowry Drilling Manager ConocoPhillips Alaska, Inc. ~~P~ P.O. Box 100360 ~ Anchorage, Alaska 99510 ~ ~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-06 Sundry Number: 309-346 Dear Mr. Lowry i~~.,:~;~~ii~~~,~ `.',;~,J ~ ~ 20c~:~ 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 October, 2009 Encl. _ _ . , ~~ e `~ • ,.~%~.f'~ ~ ,Q~'~ OCT 0 2 2Q~1~/O~-d~ ~ STATE OF ALASKA '~ • ALASKA OIL AND GAS CONSERVATION COMMISSION ka Oil & Gas Cnns. COIY~t711~~~~ APPLICATION FOR SUNDRY APPROVA~ Anchorase 20 AAC 25.280 ~ 1. Type Of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ~ Alter casing ^ Repair well ^ Plug Perforations ^~ - Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ^ Exploratory ^ 184-064 - 3. Address: Stratigraphic ~ Service ~, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20028-00 - 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 ^~ 2A-06- 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25570 _ RKB 130', Pad 94' Kuparuk River Field / Kuparuk River Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8205' - 6232' ~ 8124' 6154' Casing Length Size MD TVD Burst Collapse CONDUCTOR 103' 16" 103' 103' SURFACE 2724' 9-5/8" 2854' 2650' PRODUCTION 8072~ ~~~ g2~2~ 6229' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7841'-7879', 7910'-7918', 7931'-7935', 7936'-7956' 5893'-5928', 5956'-5963', 5975'-5979', 5980'-5999~ 3-1 /2~~ L-$~ 244~ Packers and SSSV Type: Packers and SSSV MD (ft) Baker external Casing pkr, Baker'FHL' pkr, Baker'FB-1' pkr @ 142', 7707', 7891' Baker'FVL' SSSV @ 1926' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ r 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 16, 2009 Oil ^ Gas ^ Plugged ~- Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative; 18. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Lowry @ 263-4247 Printed Name SCOtt LOW Title: Drilling Engineer Signature Phone 263-4247 Date j.p / ~ b q Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness O-, f~~ Plug Integrity ~BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~ ~ . ~ O ~ ~ APPROVED BY ~ ~ Approved by MISSIONER TH COMMISSION Date: ( Form 10~3 I~evised 06/20 ~~~~ I Iv H L~~~~ ~~1~ (~~ ~~ Submit in buplicate ~ • • Abandonment operations for we112A-06 will be conducted via the 2A-27 intervention well (PTD 209- 107). The procedure below is an excerpt from the abandonment portion of the 2A-27 procedure. Please refer to Attachments 1- 5: Well Schematics L Directionally dri118'h" hole to 7" liner point (7,788' MD / 5,856' TVD). Active and passive magnetic ranging technology will be employed in the 8'/2" interval to help maintain precise control of wellbore placement. Two intersection intervals will be targeted. The upper target interval is 7500' to 7700' MD (2A-06 MD), and the lower target interval is between 7707' MD and 7800' MD (2A-06 MD). Both intersection points will target a minimum of 20' of well-to-well contact area with a maximum of 1' of edge-to-edge wellbore separation. The upper intersection interval is just above the top completion packer in 2A-06, and the lower intersection interval is just below the top completion packer in 2A-06. 2. Run 7" 26# L-80 BTCM liner to 7788' MD. Minimum of 150' overlap between 7" and 9 5/8" strings will be used. Cement liner. 3. Pressure test liner to 3500 psi. Record results. Drill out liner shoe, plus 5' of new formation. Length of new formation drilled is shortened due to close proximity to reservoir. Perform LOT to confirm fracture gradient near intersection intervals. Hole will most likely be displaced to kill weight brine (12.3 ppg) prior to performing LOT. 4. Set bridge plug above 7" liner shoe. Pressure test bridge plug to ensure integrity. 5. Perforate the lower intersection interval using oriented TCP guns (+/- 20' gun length). Guns will be designed to penetrate through both the production casing and tubing of we112A-06. Pressure will be bled down on 2A-06 just prior to perfarating. Monitor pressures on both 2A-27 and 2A- 06. 6. Establish injection rates & pressures. Squeeze cement into 2A-06 through retainer or retrievable packer. Cement formulation and volumes will be fmalized upon establishing injection rates & pressures. If injection cannot be established below fracture pressure, an additional perforating run is the first contingency. 7. Drill out cement from across perforated interval. Pressure test perforations to approximately 400 psi. Maximum test pressure will be adjusted based on the observed fracture pressure of the formation. Using retrievable packer, inflow test the perforations by displacing the drill string to fresh water. This equates to a draw down of 200 psi below the absolute minimum anticipated reservoir pressure gradient of 9.0 ppg EMW (based on 2A-OS PBU in August 2009). If pressure tests fail, repeat cement squeeze until isolation is obtained. 8. After successful positive and negative tests of lower perforations, set bridge plug above perforations. Pressure test bridge plug to ensure integity. At this point, displacing out the 12.3 ppg brine with seawater will be evaluated. This will make cementing operations easier at the upper intersection intervaL 9. Bleed off all pressure on 2A-06, and monitor for 1 hour. If well is dead, proceed to upper intersection procedure. If well is not dead, all information will be assessed, and the plan forward will be determined. 10. Perforate upper intersection interval using oriented TCP guns (+/- 20' gun length). Guns will be designed to penetrate through both the production casing and tubing of we112A-06. Monitor pressures on both 2A-27 and 2A-06. If hydraulic communication has been established with 2A- 06, displace brine or seawater down 2A-27, and up through the tubing x production casing annulus of 2A-06, and through the choke manifold. 11. Establish injection rates and pressures. Determination will be made if hydraulic communication has been established down the tubing to the reservoir. It is possible the tubing will have been cemented where it is perforated, thus preventing hydraulic communication. Using a retainer or retrievable packer, squeeze cement mto 2A-06. Returns will be taken through the choke manifold on 2A-06 in order to circulate cement up the tubing x production casing annulus. Cement will be • • squeezed down the tubing if a flow path exists. Cement formulation and volumes will be finalized upon establishing injection rates & pressures. 12. Drill out cement from across perforated interval. Pressure test perforations while the 2A-06 well is monitored far flow/pressure. Maximum test pressure will be adjusted based on the observed fracture pressure of the formation. A successful pressure test of the upper perforations will conclude activities covered under this sundry for 2A-06. Final abandonment of 2A-06 is not covered under this sundry. ~ Cement between 9-5l8" 8~ 7" (est TOC @ 1919') ~J 9-5/8" 36 ppf J-55 @ 2854'. 47~ Incfin~tion, 241 ° Azm T' 26 ppf J-55 BTC @ 8201' {buckled but hold+ng pressure with tiquids) Max inc 55° 3-1/2" 9.3 ppf J-55 8R~ Tubing 61-ed with 12 3 p~g brine (Jan 2008) Est TQC behind T' @ 7344'. Inc = 42° Start drop c~?i 7040', DLS = 4°/140' C-Sand Perfis 7841' - 7879' A-Sand Perfs 7~31' • 7948' PBTD 8124` Injectio~ Mandrels 7718' & 7788' (open) LP '(ja~' 7891' Upper Packer @ 7707'. 1=29° Attachment 1: 2A-06 Target Well Current Condition • ~ 2A-06 .~'~'\ Dual I ntersection - Lower P&A ~ zA-z7 rried wan i2.s r~ nnns • Upper Packer 77QT Oriented TCP Gun. 5 SPF, Phass 355`~'i5' +f- 20' Gun, assume 1fl0 sbots, 7740' ta 7764" (~efe~en~ to 7J48) Tvro-way Injedio~ VaMes Estimated TFA into 7" (1Q0 x 0.3"): 7i~ 7T18' 3 7788'. Sr16" ID Esteneted TFA in 3-1/2' (1U0 x 0.157: 1.7 n2 TFA= O.aBinz ea ~ • 2A-27, 7", 28 ppf ~ N- 7804 M~ (raiar$nce ta 2A-8) Annular~iume beMreen Packers 184', d.85 bbls Tubiny W Wme bebw Upper I njectian Valws, 181', 1.58 bbis sc~ Lower Padcer7691 MD T31~'- ~973 i~) ~7 31' - ~ 935 ;4 ) 793~i - 7J56' {24? SPF ~~'J' ph, 4" Csg CrossSection of Perfs (Best GaseAGgnment) ~^' '_ _A~T ' :R ud. 0 38' '" ~: ~! Tn W~ i . esa c 7' Voiuma below P k L I er ower ac ~ 233'. 8.92 hbl; t ~ 4 5f$' iCP "- (flS5LLRl8 f fl4d WRI1 ~2.3 ~~ bflM) _ '__.__ .. . ,__ , _ _ ~ i ' . _ ~~n,55vv r. h r : t:z Moie i 1 5 7" - :c: rteM St~eu'~ `~,~ ~ i i ~ to~"6~,. f r i~ :A~CG ~- ` ' r ~ 1 3 g r~,~~y pBTp8124 MD ~ ~ _ ~93ipl.Q75.. ~ ~ YtNi Thtl~.~^es+i I I l . - + ~ i ~ ?e au~. c ~s' ~ ~ ~ ~.wn m,c'~n.,. \_~~_ ,,, tub.ng6Mn~us f,~~a w~h a~n~ : r, Z6 ppt J-55 ~~/- 8Z01 MD 1 ~ i ~JdblN~it 3.JS~ ~' Sa Perbra8rtg 9+et Pteing ~ o Scek Attachment 2: Lower Intersection Detail • ~ 2A~-27 Duai Intersection - Lower P&A 2A-06 r ~ - 2A-27 f~led uith 12.3 ppQ brine Upptr Packer 77C7 ~ Cemeni Retainerar Tesl Packer Set above Tap Pe~foratians ~ ~ - Twa-way Injcdion Valves j T718' ~ 778$', 5:'1fi° ID ` TFA = 4.08inz ea • 2A-27, 7'", 26 ppi~ ++- 7800 MD (reference to 2~A-6) Annul~ r Valume beh,~.esn Packers i`r 184", 4.95 bbls Tubing 1Rslume be~w Upper In~ction Val~~, 182', 1.~8 bbls if.wt' ;sSr ~A3° - ~92'r . '.:`1Z5«•~ f.?G'pn,5-1;7' . . . . . . . . . . . . . . . . . . . .. .. . .. .. .. .. .. .. .. .. .. 4` : iVR]I Pk= Lawer Pscker 7891' MD ~ai~-;319'{~; 7:~31' - ti335' { 4' i 733~` - ~ ~56 ~:2+7 } 5r''F ~q~ ph, s" Cs~ ~, 7' Vclume t~Iow Lovrer Packer 233', 8.=32 bk(s fcemeflt svs~ap ~~writh brine, brine s~ueeze~ int~ sana~ PBT~ 5124' Iv1C ~ 7'. 26 ppf J-55 ~+!- 8201 MD Attachment 3: Lower Intersection Abandonment Chake hi~n~told ~R Tanks on A~annu#us Pirtched tubing ~ cannot m~ect fluids. gas Ieak+ng cxit Gas Likely ~~ migrated mRo !ubing & into T'-a r~nu lus ~ ~ Upper Perforation~ Diagram 2A-2T ftled wnth 12.3 ppg brine prior #p PeA 2A-06 'A" a-u~utus Ried with Crude ' 1i 2A-081'ubing fiFed with 12.3 ppg b~ne (tfb6) (C~rrr~rN ma y n~v8 Ct+er9 s0'ue~te~0 SOme ~st~nce u~ tt~t rtrA~nq ar c~c+m}ares~+~} gasJ 9 5/8" @ 6985' MD / 5246' TVD 7" Lmer Tauching for 2Q ft minimwn above productian p~ker (t7esign 7550' - 757(Y} relative to 2A-Of: `nented 3 x 7' P~r~ ~ns *I- 21' tolal tength ~ 7 Lmer Io~ver secUOn cemented l'~, .. _ .~._._ C ~ ~~~' Attachment 4: Upper Intersection Detail ~~ ~M'~ 2A-C~a Choke Manifold ~ A ann~ us ~( I~ ~ I l i l Pincheti tubeng ~,/~ cannot +nject t~uFds. gas 4ea~c-ng aut Gas L ~ke~y ~ m~gratea into tubing 8 mto T"•ann~lus ~ ?r~ l i I I?.0" ~} +l- 154 ft lkd j ! Ko~' aQ +t- B00 fl tvd 13 3/8" @ 3008' TVD ~ Upper Intersection Cement Placement Diagram 2A•27 filed w~th t 2 3 ppg bfine pnar to Perf Attachment 5: Upper Intersection Abandonment _~ ~ - -__~~ KU P ~ •` • CQ~'}(~Q~~~~I~"j~ ~ , Well Attributes , ~~~.,,,rt, ;; WellboreAPWWI ~~FieldNamE ~ 501032002800 KUPARUI c~ ant m _ ___ _weo Csr~a~:.:.2n-o5 utn2uo,~ `3:, aa . . . . --_ SSSV~ LOCKED OUT . . _ . . _ Stl~einMic-Acwvi 1 Annotation Depth(ftKB) Last fny 268.0 !Casing Strings _ Casing Description Strin l CONDUCTOR 9 16 15.060.. ._Y,0.0 VV.103.0~.... /~.-~103.0 ~... V~62.50... VH-40.. V.....~.V~.... HANGER.31 - :~~ ~~~~" ~Casing Description ~String 0... String ID... Top (ttHB) Set Dapt~ (f._ Set Dapth (NO) ... String Wt... String ... IString TopThi ~ SUHFACt ~ 95/8 SJ65 362 2,854.1 2,650.3 36.00 J-55 . BTC ~-'. Casing Description String O._ String ID._ Top (flKB) Set Daptl~ (~~~~ Set Dapth (ND) ... String Wt... .String ... String Top Thi PRODUCIION ~~ 7 6.151 3fi5 8,200.9 6,228.1 ~ 26.00 ~ b55 c -" Tubing Strings ' TuEing Description _ __ String 0... String ID... Top (NKB) Set D pth (i... Sat Depth (ND) String Wt.. String ... String Top Thi ~ I Temp AbanAon 31/2 2.992 I 30.5 I 244.8 I 244.8 9.30 L-80 ~ EUE Srd TUBING I . .- covoucTOR, ComPletion Det ails 0~'03- - ' TopDep~~ ~ (ND) Top Incl ~ -- ITOp(HKB) (HKB) ~ (°) ItemDasaiptioni CommeM ID ~ 30.5 3Q5 -0.40 HANGER ~Vetco Gray TBG Hanger - H Profle, W/ 3 12 EUE 8rd Pup joint 3. ~ ~i 135.3 1382 022 XO - Enlarging 3 l l2 EUE Srd Box z 4 1/2 IBT-M Pin XO sub 4. i 139.6 139.6 023 XO BUSHING 4 V2 IBT-M Box x 4 1/2 BTC Pin XO Pup Joint 3. XOBUSHMG, iao ~ 141J 141] 0 24 ECP 4 1/2 12.6u "Baker" Payzone Extemal Casing Packer ~ - - 3. eca. u2 --- I 164.6 164_6 j 0.37I XO BUSHING 4 1/2 BTC Box x 4 1/2 IBT-M Pin XO Pup Joint 3. XO BUSHING. ___ I r . 165.9 165.9~ 0.38 XO - Reducing 4 12 BT-M Box z 3 1/2 EUE 8rd XO sub -. 2. iss z 1g1.g 7g1.g ~ 0.52 NIPPLE Camco "DS" Nipple w/ 2.812" Profile Nipple w/ CA-2 Plug 2. ~ k ~ 2393 239.3 0.57 WLEG '~4 1l2 Wash Pipe Cul Lip Guide w/ 470' Swallow w/ 3J9" ID i 3. '...~. ~ Tubing Des cription IString O ._ String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... IString Wt... IString ... String Top I Thr ~ TUBING 312 I 2.86/ I 245.0 I J,925.0 I 5969.0 ~~ 9.30 SRDEUEAI I J-55 NIPPLE,t92 Other I n Hole ( Top Dep~h Wireline retrievable plugs, valves, pumps, fish, etc.) .-... .- ' (TV~) Top Incl I TOp(ftKB) (nKg) (°) ~ Description ~'i Comment RunDate •ID .. 1,926 1,907.8 21.56 SAFETY VLV Baker'FVL' (Locked Out) _ 6/30/19&4 2. ,r ~' 7,647 5,J20.9 ._._._- . 30.15 GAS LIFT MMH/FMH011IDMYlBK-Zll Comment STA 1 62911984 2. - 7693 _ SJ60.6 _ .__._-. 28.82 PBR ~~.gaker ~ ___ 6/30/198d 3. : 7,707 5,772.9 . ._ .....____. 28.42 PACKER ~Baker'FHL' ~ _ 6/30/1984 3. w~eGZ3s-- ,~ i 7,718 5,7826 I 28.10IINJECTION 'MMHIFMFIO/1/DPHFCV/BEK///COmment STA2 2/2~/2005 i ~-~~ 7,788 { 5,844.9I 26.081NJECTION '~MMHIFMH0/1/DPHFCV/BEK///CommentSTA3 I 2127/2005 ~ ~' ~~? 7,891 _ 5,938.4~ 23J5 PACKER Baker'FB-1' 6/30t1984 j;; 7,898 5,944.8 23.52 NIPPLE Camco'D' Nipple NO GO ~~ ~ 6/30/1984 snvEn'v~v. 7.899 5,945J 23.48~SOS IBaker 6/30l1984 ~'9~ 7,900 5,946.6~ 23AS;TTL ~~.ELMD @ 7900' ON SWS IPROF 5/2D2001 6/30/1984 SURFACE._ . I . __ _ . _ ~s-x.au i Perfora tions & SIOtS Shot I Top (TVD) Blm (TVD) Dens I GASUFT, ~ " Top(HKB) Bbn(kKB) (HKB) (ftKB) 2one Date (sh... Type I CommeM ~'~~ .. " ~ ~~~ 7 847 7 879 S 893 3 5 927 4 6l30119&4 12 0 IPERF ~5 5"C G 120d ~ h ~ ~ f , , _ . . . . sg un, eq p t 7.910 7,918'i 5 955D 5.9625 6/30/1984 4.0 IPERF ~4" Csg Gun, 90 deg ph PBR. ].693 ~ y i ~ 7.931 ~ 7.935~'~ 5.974J 5,978.4 6/30/1984 ~I 4.OI IPERF .4" Csg Gun, 90 deg ph . - --,_ . ' . _ _ _ __. ~ ~~ . Z93f,, 7956 59194 5,998.1 __ _ ~6130/1984 4.O IIPERF I4'CsgGun 90degph _ _ . ~ . _.__ _.__ ~ PACKER 7 70] " Y Notes: General 8 Safet _ - E~a oata n~nota<~o~ .. . -- , , ~ ~ ~ 1/14/2006 NOTE: ~AG w/125' LIB @ 268' - POSSIBLE COLLAPSED TUBING ~ ~ ~ r I ~ ~ ~4i10/2009 NOTE: Old TBG came apan dunng workover, leN downhole, temp PKR/Nipple setto secure well . _ ._ INJECTION, 7 ]18 INJECTION, 7.788 IPE3F. 7.86t-).8]9 ~'~CKER. ].891 NIPPLE, ].899 S0.S. ].899 TTL. 7.900 IPERF. 7.910-7.9t8 IPERF, 7,931-],935 ~ ~ IPERF. 7.93fi-],956- " - ~ PRODI/CTION, ~ 36-8,201 \ T0.6,205 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ~ Alter Casing ^ Pull Tubing Q• 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, IIIC. Development ^ Exploratory ~ 184-064 /, 3. Address: Stratigraphic ^ Service ^~ ° 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20028-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 130', Pad 94' 2A-06 • 8. Property Designation: 10. FieldlPool(s): ADL 25570 Kuparuk River Field / Kuparuk River Oil Pool ' 11. Present Well Condition Summary: ., ~, p ,,,,.~} , ~y ~~~«:~~~~r~+~ ~~LI1.. ~ t~ ~t~~'~ Total Depth measured 8205' ` feet true vertical 6232' . feet Plugs (measured) Effective Depth measured 8124' feet Junk (measured) true vertical 6154' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 103' 16" 103' 103' SURFACE 2724' 9-5/8" 2854' 2650' PRODUCTION 8072' 7" 8202' 6229' ~~4s~~ V R~.LJ .~UN ~ Q ~~~~ Perforation depth: Measured depth: 7841'-7879', 7910'-7918', 7931'-7935', 7936'-7956' true vertical depth: 5893'-5928', 5956'-5963', 5975'-5979', 5980'-5999~ Alaska Oii & Gas Cons~ ~~171-'!'11SSIOft Anch~orapmi Tubing (size, grade, and measured depth) 3-1/2" , L-80, 244' MD ~ PaCkerS & SSSV (type & measured depth) Baker external casinp pkr, Baker'FHL' pkr, Baker'FB-1' pkr @~,:, 7707', 7891' Baker'FVL' SSSV @ 1926' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9-5/8" x 7" outer annulus 3 stages: 150 sx AS 1 cement, 23 bbls AS 1 cement, 20 bbls Treatment descriptions including volumes used and final pressure : AS 1 13. Representative Daily Average Production or Inject+on Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI ` -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~~ Daily Report of Well Operations _X 16. Well Status after work: ~ Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 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: 309-111 contact Jim Ennis @ 265- 1544 Printed Name Ennis r Title Ph 265 1544 Wells Engineer q C- D t ~~ 0 1 ~ Signature one: - a e 0 Pre red b aron Alf u Diake 63-4612 ~~,~~ ~~ f'~hj~3 f7• l °G`~ Form 10-40 evised 04/2006 '~`~F ~~ ~ 2~~Q Submi Original Only ~,~~~/ ~~.~~'j `, .___ KU P 2A-06 CQnQtQrl f~~~~p5 ~~ Well Attribute s __ _ ~ ~ ~ _ Max Angle & MD ~ ' TD ~.'SM1_: ..,', - ' WellboreAPVUWI FieldNama I WeIIS~a~us Protl/InjType Incl(°) ~~MD~ftKB) Act81m(flKB) ~ 501032002800 . e... . :KUPARUK RIVER UNIT I INJ PWI 5528 I 7,000.00 , 8,205.0 ... C n~ ~~H25(ppn) ~~~.Date iMnotation EndDate 'KB-Grd(fl) -~RigReleaseDaL ~'~ .._ _SSSV. LOCKED OUT I ~ - i ILast WO. I 4/10/2009 I 40 79 I 5/25/1984 wpnca~ zn-4s,amr~o ~~ _.., Sche_matic Act _ iP, ~~. ~~d.aa ~,n ~al ~.l~ t tion Depih (ftKB) End Oata Mnotation . , End Date L~st laq~. I 268.0 1/14/2006 IRev Reason: WORKOVER 4/77/2009 Casing Strin~ s - Casing Description i5tring 0... 'Siring ID ._ Top (flKB) Set Dap~~ (f... - --- Sat Depth (ND) ... String Wl... iString ... '.5[nng Top Thrd CONDUC I OH ~I 16 15.060 0.0 103.0 103A ~ 6250 H-00 ' HANGER, 31 ~~- Casing Description String 0... String ID ... Top (kKB) Set Dap~~ (t. .. Sat Depth (ND) _. String Wt... ~~String ... ~String Top Thrd ~ . SUHFACE 95B SJ65 362 2,854.1 2,650.3 36.00 J-55 B1C I Casing Description String 0... ~String ID... Top (kKB) Se~ Dapih (f. .. Set Depth {TVD~ _.. ~String Wt... String ... S~nng Top Thrd PRODUCIION _ 7 I 6.151 36.5 8,200.9 6228.1 ,, 26.00 , b55 ~ : ~ Tubing String Tubing ~es iption s I String 0... Siring ID ... I Top (kKB) I Sat D p~h (f... Sat DepM (ND) .. St 'ng Wt.., Str g... I String Top Thrd '. iemp AhanAUn 3 V2 2.992 30 5 244.8 ~ 244.8 9.30 , L 80 EUE Srd ~ .. . .... ~ IUBING l .. . ~ .._ - .. ~ .. . .-.___ ... . . . I . _. - ... _. __ coNOUCroR. , ~Completion D etails 0-103 . ~ 'TOPDeplh ~. ~ 30.5 30.5 -0.40 IHANGER Vetco Gray 7BG Hanger- H Profile, W/ 3 1l2 EUE Srd Pupjoirrt 738.3 1382 0221 X0 - Enlarging 3 1/2 EUE Srd Box x 4 1/2I8T-M Pin XO sub 139.6 139.6 023 XO BUSHING 4 1!2 IBT-M Box x 4 12 BTC Pin XO Pup Joint XO BUSHING. -- " " ~qp 741J 741J 024 ECP 4 1/2 12.6# Baker Payzone 6nemal Casing Packer ECP.1~2- .. 164.6 164.6 0.37 ~ XO BUSHING 4 1!2 Bl"C Box x 4 V216T-M Pin XO Pup Joint ~ ~~ 165.9 765.9 1 0.38 XO - Reducing 4 1J2 16T-M Box x 3 1/2 EUE Srd XO sub XO BUSHING, _ i65 191 9 197.8~~, 0.52 NIPPLt ~ Camco "DS" Nipple w/ 2.812" Profle Nipple w! CA-2 Plug ', 239.3I 2's93, 0.57~ WLEG 4 l l2 Wash Pipe Cut Llp Guide w/ 4J0' Swallow wl 3J9" ID Tubinq Ges cription Strinq 0 ... IString ID ... ~T Op (flKB) ~Sat Dapth (f... ~Set Depth (TVD) ... IString Wt... ~'iString~ NIPPLE. 192 - WLE6.235 Inc •FB ~ SAF ~_ lY VLV 2 I SRD EUE ABM Run Data ID linl ~~ ~~ Top (TVD) Btm (TVD) ~ Dens GASLIFT. Top(HKB) Btrn(ftKB~ (HKB) (flKB) ~: Zone ~ Deta (sh... Type Comment ~'~~ 'i 7,&41 7,879 . ', 5,893.3 5,927.4I 1 6/30/1984 120 IPERF 5_5" Csg Gun, 120 deg ph l 7,910 7,918 , 5 955.0 ~ 5,9625 I 6/3011984 4.0, IPERF 4" Csg Gun, 90 deg ph 7.931 7.935 ~I 5,974J 5,978.4 6/30/1984 ' 4.O~~IPERF 4"CsgGun 90degph PBR.'/.693 ~~ '~ ~~ 7.936 /.956 ~ 5.979.4 5,998.11 ~ . 6l30/1984 4 O~IPERP - 4" Csg Gun 90 aeg ph_ ACKER "/ ]0] ~ -~ Notes: Ge Entl Date neral ~ & Safety . -- AnnoUtion _ . -~ - - - , , ' 1/14/2006 NOTE TAG w1125" LIB o~ 268' - POSSIBLE COLLAPSED TUBING ~ ~ ~~ ~ 4/10/2005 INOTE: Old TBG came apan dunng workover, left tlownhole, temp PKR/Nipple set ro securewell INJECTION, 'i ],]88 I IPERF, _. -' ' - ].Ba1-7.879 • __. ~ PACKER. ],851 ___~_ NIPP~E.],858 ~ '.~ SOS.7.699 -- - ~' TTL.7,900- --- ~~ ~ IPERF, 7.910-7.918 - ' -"~ IPERF, ].931-].935 IPERF. _ _~ ~.936-].956 PRODUCTION, ~ 36-8,201 ~ TD, 8,205 ~c~na-ca-Phillips iNe7Nfew We6 ReporUng Well Name: 2A-06 Job Type: RECOMPLETION Time Log & Summary Report Rig Name: NORDIC 3 Rig Accept: 4/5/2009 7:30:00 AM Rig Release: 4/10/2009 2:00:00 PM 4/04/2009 24 hr Summarv RDMO 2E-05, moved rig from 2E Pad to 2D Pad, enroute to 2A Pad. 22:00 00:00 2.00 COMPZ MOVE TRNS P Move rig from 2E Pad to 2C Pad enroute to 2A Pad. Spot and level rig over 2A-06, berm up, RU hardline to kill tank and spot tanks, pull BPV, test hardline, attempt to bulihead 100 bbls 12.3 down tbg to kill well and was only able to pump 17 bbis, install BPV, ND tree, install test dart, NU BOPE, test BOPE, ull test dart and BPV, MU landin ~nt. 00:00 07:30 7.50 COMPZ MOVE TRNS P Cont moving rig from 2C Pad to 2A Pad. Acc?~t Nordic 3 Ri~ 07~30 hrs 4-5-2009. 07:30 08:30 1.00 COMPZ RPCOM RURD P Hang tree in cellar, spot spools behind well head, pull rig over well and level up, berm up cellar, spot tanks and equipment, MU hardline to kill tank, 08:30 12:00 3.50 COMPZ WELCTI OTHR P PU lubricator and ~ull BPV. Re laced bad valve on hardline. 12:00 15:30 3.50 COMPZ WELCTL KLWL P PJSM. Test hard line to kill tanks to 3000 psi. Pumped 12.3 ppg formate brine down tubing starting at 5 BPM,pressure continued to build until 3000 psi rate down to 3/4 BPM. Pumped total of 15 bbls. While pressure coming up on tubing the IA pressure matched it, SD pump. Let pressure bleed down to 1600 psi. Pumped up again to 3000 psi w/2 bbls. SD, bleed back to only 2500 15:30 16:30 1.00 COMPZ WELCTL KLWL P Opened manifold to equalize OA, IA & tubing. Opened to kill tank and bled off all three to 0 psi. Monitored well for 1 hr. Well pressure 0 psi w/ trace of as. 16:30 17:00 0.50 COMPZ WELCTL OTHR P 17:00 19:30 2.50 COMPZ WELCTI NUND P ND tree. 19:30 00:00 4.50 COMPZ WELCTL NUND P Install test dart, MU DSA, riser spool, NU 13 5/8" BOPE. Cont IVU BOP, test all BOPE at 250/3,000 psi, with 2 7/8" and 3 1/2" testjoints, pull test dart and BPV, MU landing joint and top drive, BOLD's, pull 114K and put 3 1/2" completion string in tension, RU slickline and attem t to RIH down tb . 00:00 02:00 2.00 COMPZ WELCTt NUND P Cont NU 13 5/8" BOP, DSA, riser s ool, choke and kill lines. 02:00 02:30 0.50 COMPZ WELCTI RURD P RU test equipment, fill stack. 02:30 07:30 5.00 COMPZ WELCTL BOPE P Test BOPE at 250/3,OOO~si on chart. Tested variable rams and annular with 2 7/8" and 3 1/2" test jnts. AOGCC Rep Chuck Scheve waived witness of BOP test on 4/5/2009 at 18:00 hrs. 07:30 08:30 1.00 COMPZ WELCTL OTHR Pull test lu . heck well f ressure, well dead. Pulled BPV. 08:30 09:00 0.50 COMPZ RPCOM PULL P MU landing jt. MU top drive. BOLDS, tubing jumped up 1". Pulied hanger to ri floor ulling control line for SSSV apart. UP wt 35K (Top Drive Wt). Filled hole with 12 bbls 12.3 KV1IF. Break out and LD tubing han er and Landin 't. 09:00 10:00 1.00 COMPZ RPCOM PULL P POOH w! 217'- 3 1/2" tubin . Tubing was parted just below tubing collar. LD tubin and clean ri floor. 10:00 12:00 2.00 COMPZ RPCOM PULL P Wait on 6 1/8" stop sub on rope s ear comin from Deadhorse. 12:00 16:00 4.00 COMPZ RPCOM PULL P MU 6 1/8" OD stop sub on Rope Spear & bumper sub on 3 1/2" drill pipe. RIH and fish 3/8" SS Gontrol line from SSSV. Retrieving approximately 60' per run. 240' of control line u to this oint. 16:00 16:30 0.50 COMPZ RPCOM PULL P RIH to 182' stacked out, could not rotate. POOH and replaced 6 1/8" stop sub w!5 7/8" stop sub. RIH to 229' engauge more control line pulled up hole dragging approx. 10K over, ulled loosed 10' u 219'. 16:30 17:00 0.50 COMPZ RPCOM CIRC P SI and circulated 13 bbls 12.3 KWF around. Shut in and pressured up to 2400 psi on tbq and IA monitorinq OA. OA had been bled to 0. OA sta ed at O si no commun' Bled off pressure and blow down hardlines. 17:00 18:00 1.00 COMPZ RPCOM PULL P Continue attempt to fish control line out, last two runs stacked out at 229'. POOH with no fish. 18:00 19:00 1.00 0 0 COMPZ RPCOM PULD P LD rope spear assembly, load Baker tools and DC's in shed, monitor well, trip tank fluid level alternating between 9.6 and 11 bbls, gas level alternating between 0 and 5,000 units. 19:00 21:30 2.50 0 0 COMPZ RPCOM MILL P MU BHA #2 (6" Inner Dressinq Mill Assembl washed down to 176' and losing string weight, made severai attem ts but could not et ast 182' POOH and changed out 6" mill shoe to 5 3/4", 21:30 22:30 1.00 0 0 COMPZ RPCOM MILL P RIH with 5 3/4" Inner Dressin Mill Assembly to 182', had to siow roll string and worked down to 223', could not et ast 223' had 20K overpull starting OOH at 223', POOH LD BHA, called Well Engineer, decision made to run DP with 5" tool joints and bull nose to try and reach tubin stub de th. 22:30 00:00 1.50 0 235 COMPZ RPCOM MILL P MU BHA # 4(4 3/4" Buil Nose) on 3 1/2" DP and bum er sub RIH to 246' and tagged solid with no problem, pumped 10 bbls 12.3 ppg to circ out gas, called Well Engineer, decision made to run Baker RBP, load Baker tools, monitor well for 30 minutes, trip tank still alternating gaining and losing 1 bbl, gas units still aiternating betnveen 0 and 5,000 units. 4/07/2009 POOH LD bull nose and bumper sub, PU RIH with Baker RBP attempt to set at 165', POOH w/ RBP, PU and RIH w/ 5.75 WP to 177' and ta . Wait on offsite e ui ment. 00:00 01:00 1.00 235 235 COMPZ RPCOM OWFF P Close baa and observe for anv ressure build up in DP and IA. obtained 20 psi on both drill qi~e and IA, bled off. 01:00 02:00 1.00 235 0 COMPZ RPCOM TRIP P POOH LD bullnose sub and bumper sub, had 1 K overpull from 246' to 223' with 5" tool 'oints. 02:00 06:00 4.00 0 165 COMPZ RPCOM PLUG P MU Baker model "L" retrieving head and model "G" Lock-Set RBP. RIH with 5 jnts 3 1/2" DP, set top of RBP at 163' released set tool, still getting gas around RBP, element not energized, POOH check RBP, PU 4 jnts 4 3!4" DC's, RIH and re-set RBP at 16 ', slips set but element not sealing, sting in and release RBP, gas at 5,000 units, circ~out aa~. shut down and wait on orders at 165'. 06:00 11:30 5.50 165 165 COMPZ RPCOM OWFF P Shut well in and monitored, WOO. IA built u to 110 si 11:30 12:00 0.50 165 165 COMPZ RPCOM OTHR P Bled down IA to 0 psi. Opened wel~ and monitored. Well static. 12:00 12:30 0.50 165 0 COMPZ RPCOM TRIP P POOH w/RBP from 163' and LD. 12:30 13:30 1.00 0 177 COMPZ RPCOM TRIP P PU and MU 5 3/4" washpipe, dart valve and RIH on 3 1/2" drillpipe, worked thru tight spot at 42' to 47'. Continued to RIH and tagged solid @ 177'. 13:30 14:30 1.00 177 177 COMPZ RPCOM PULD P LD drill collars and unload pipe shed w/all fishin tools. 14:30 00:00 9.50 177 177 COMPZ RPCOM EQRP P Senrice rig while waiting for offsite equipment to serviced and delivered. 4/08/2009 24 hr Summarv Continue to wait on offsite equipment. POOH w/ 5.75 WP & RIH w/ TA string to 248', space out & land hanger. Set ECP @ 155' center of element. RU SLB Cementers and down squeeze 7" x 9.625". WOC & PT to 500 si. w/ diesel - Failed, Set TWC . W/O SLB Cementers 00:00 02:00 2.00 177 177 COMPZ RPCOM EQRP P Service rig while waiting for offsite e ui ment to serviced and delivered. 02:00 02:30 0.50 177 0 COMPZ RPCOM PULD P POOH laying down 3 1/2 DP & 5.75 WP 0230 08:00 5.50 0 244 COMPZ RPCOM PUTB P Pll and RIH w/ Temporary Abandonment Com letion to 244'. While running packer in, forcing fluid up tubing. MU Safety valve in each connection until ready to lower in hole. Stacked out 4' from top of fish. PU, repface 6' pup jt with a 2' pup jt. for space out. NU head pin and circulated well w/60 deg F 12.3 ppg brine. Landed hanqer w/Wash Pins cut li shoe 244' ECP packer 141' and DS ni le 191'. 08:00 09:30 1.50 COMPZ RPCOM SLKL P RILDS. RU HES Slickline. RIH and set CA2 plug in 2.813" DS nipple @ 191'. POH stand back setting tool to the side while we set acker. 09:30 10:00 0.50 COMPZ RPCOM PACK P RU test pump, presured up on plug to 750 psi to o en ECP and inflate, pressure bled down to 700 ps Increased pressure to 1500 psi to close held for 5 min. Bled IA & tubing to Zero. 10:00 11:00 1.00 COMPZ RPCOM SLKL P RD slickline, break out Landing jt. 11:00 13:00 2.00 COMPZ RPCOM CMNT P Held PJSM with SLB cementers. Break out bull plug from OA valve with much difficulty. RU cement e ui ment to OA. RU Su erSucker in cellar for ossibl r turns. 13:00 15:OQ 2.00 COMPZ RPCOM CMNT P FiAed lines with freshwater, SI and PT lines to 250 low and 3500 psi HI. Established in'ection into OA w/100 bbls of 65 deg. freshwater, 5 BPM w/ 200 psi. Mixed and pumped 25 bbls (150 sx) 15.7 ppg Arctic Set1 cement w/ 3hr pump time 2@ 50 deg. Pumped cement @ 2.3 BPM w/ 91 psi. SD flushed lines w/26b1s diesel. ND lines and move SLB off. 15:00 20:30 5.50 COMPZ RPCOM WOC P Waiting on Cement, Clean and or anize ri while waitin 20:30 23:00 2.50 COMPZ RPCOM PRTS P Check lines, test 9.625" x 7" OA to 500 psi and bled off to 200 psi in 15 minutes. Pressure up to 840 psi and broke down. est. injection rate @ .25 bpm Ccil 250 psi. Shut down @ 250 psi and bled down to 130 psi in 15 minutes. RD Lines. 23:00 I 00:00 1.00 COMPZIRPCOMIOTHR P Waiting to offsite cement equipment to arrive W/O SLB Cementers, RU SLB Cementers and down squeeze 7" x 9.625". WOC & Attempt PT to 500 psi. w/ diesel - Failed W/O Cementers, Mix and Pum 35 bbls of Arcticset1, 25 bbls w/ Cemnet 00:00 02:00 2.00 COMPZ RPCOM OTHR P Waiting to offsite cement equipment to arrive 02:00 06:30 4.50 COMPZ RPCOM SQEZ P Held PJSM, RU SLB Cementers and P7 @ 2,500 psi. Establish injection rate 2 b m 133 si for 20 bbls Follow w/ 23 bbls of 15.7 AS1 @ 2.0 -2.6 bpm @ 110 - 247 psi. Shut down and pressure fell to -37 psi. wait for 25 minutes, pump 3 bbis and hesitate for 5 minutes, pump 1.5 bbls and hesitate for 15 minutes, pump 1 bbl and hesitate for 15 minutes, pump 1 bbl and hesitate for 15 minutes, pump 1 bbl and hesitate for 5 minutes, Pump 3 bbls for 33.5 total bbls of slurry and follow w/ 2.2 bbls of diesel to clear Cmt lines and place 1 bbl in OA.Shut down and shut in OA w/ 18 psi on OA. Flush and clean out cmt lines. RD SLB cementers. CMT in place 06:30 hrs. 06:30 12:30 6.00 COMPZ RPCOM WOC P Wait on Cmt 12:30 14:30 2.00 COMPZ RPCOM PRTS P Open OA valve, 110 psi. W/test pump pumping diesel @ 9 GPM pressure gradually climbed to 320 psi (20 min) pressure broke down @ 320 si to 170 si. Shut down pump pressure bled down to 130 psi in 2 min. Open bleeder - 15 min bled down to 0. Shut bleeder for 15 min. pressure built up to 40 psi. Opened bleeder, pressure down to 0 in 2 min. Monitored for 15 min get only trace of diesel back. Shut bleeder monitor ressure, WOO. 14:30 21:00 6.50 COMPZ RPCOM CMNT P Ordered out 3rd cement job products and pumping equipment. Waiting on arrival. 21:00 00:00 3.00 COMPZ RPCOM CMNT P PJSM, RU Cementers, Prime up CMT Pumper, Fill pump line. PT @ 2,500 psi. ~Establish Iniection rate Ccil 1 b m 145 si for 2 bbls. Mix and Pump 20 bbls of Arcticset 1 w/ Cemnet @ 1 bpm @ 160 psi for the first 5 bbls away, @ 125 psi @ 10 bbls away, 133 psi @ 15 bbls away and 127 psi @ 20 bbls away. Shut down, Pressure @ 73 psi and batch up 5 bbls of slurry w/ Cemnet. Pump after 5 minutes being shut down (pressure @ 50 psi) @ 1 bpm @ 165 psi. Shut down, pressure @ 101 psi and Batch up 5 bbls of slurry w/o Cemnet: Pump after 5 minutes being shut down (pressure @ 50 psi) @ 1 bpm @ 175 psi. Shut down, pressure @ 73 psi and Batch up 5 bbls of slurry w/o Cemnet. Pump after 5 minutes being shut down (pressure @ 92 psi) @ 1 bpm @ 200 psi. Displace w/ 2 bbls of diesel @ 120 psi. Shut down and SWI w/ 70 psi. Total slurry pumped was 35 0/2009 CMT in place Ca~ 00:30 hrs WOC, Attempt PT to 500 psi. w/ diesel - Failed, Reported results to RWO Eng, ND BOPE, NU Tree and Test. RDMO of 2A-06 and Release Nordic Ri 3 14:00 hrs on 4-10-09. 00:00 06:30 6.50 COMPZ RPCOM WOC P Cement in place @ 00:30 hrs - WOC 06:30 07:00 0.50 COMPZ RPCOM DHEQ P Fluid pack hose to OA w/diesel. Open OA, 110 psi. Pressured up on OA w/test pump slowly to 470 psi and broke down to 170 psi. Pumped total of 5.3 bbls. diesel. Bled pressure down and SI. Shut in w/110 psi. Report results to Workover Engineer. Directions forward were to ND BOPE, NU and test tree and move ri off. 07:00 14:00 7.00 COMPZ RPCOM NUND P ND BOPE. NU tree. Test tree and ackoffs to 5000 si. Pull TWC and install BPV. Clean cellar and around well with SuperSucker. RDMO Release Nordic 3 ria CcD_ 1400 hrs on 2A-06 Well Work Summary DATE SUMMARY 3/14/09 T& IC POT/PPPOT - PASSED, NCTION TEST T& IC LDS ( PRE-RWO~ 4/8/09 SET 2.81" CA-2 PLUG (a~ 191' SLM, ***JOB COMPLETE*"" 4/22/02~OMPLETED SUCCESSFUL MIT-OA TO 1800#. BLED GAS FROM OA AND THEN HAD TO PUMP UP OF SEVERAL TIMES BUT EVENTUALLY HELD. PRESSURE DROPPED FROM 1800 TO 1740 THE FIRST 15 MINS AND THEN DOWN TO 1730 AFTER 30 MINS. IA DID NOT FLUCTUATE DURING TEST. 5/8/09 PULLED 2.81" A-2 PLUG @ 192' RKB.TAG TBG STUB W/ VARIOUS LIB'~..2.79",2.71" , ~4 ~~ 2.295" & 1.91" HAD SAME IMPRESSION ON ALL. PICTURES TAKEN OF LIB'S & E- MAILED TO TOWN. BLEED TBG DOWN FROM 1700 PSI TO 100 PSI, MONITOR FOR 45 MIN PRESSURE CAME UP TO 225 PSI. ***JOB COMPLETE''** 5/10/09 AC-EVAL, INITIAL T FL @ 156', UNAB~E TO PUSH FLUID DOWN WITH 21 BOTTLES OF N2 ANY DEEPER, 5/15/09 FLUID LEVE~ WAS DETERMINED TO BE BELOW 3 1/2" TUBING WLEG AT 239' 5/19/09 LOGGED EXPRO DOWNHOLE VIDEO OF TUBING STUB AT 245'. FOUND FLUID LEVEL AT STUB. PRESSURED UP TUBING WITH NITROGEN WHILE OBSERVING FLUID LEVEL TO CHECK FOR CASING LEAK. FLUID LEVEL DID NOT MOVE WITH 1000PSI ON TUBING. 6/15/09 MONITOR WHP's T/I/0= 1775si/220/460 --~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # FI 4F ~7 ., ~ d ~ 20G9 ~`'a~it~re «.iY k,rr~ ~. Lw.s~ Log Description NO. 5261 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/03/09 2U-15 AZCM-00012 GLS 03/28/09 1 1 3G-12 B04C-00047 INJECTION PROFILE - `~- f JJ 05/10/09 1 1 iC-172A B04C-00049 GLS 05/11/09 1 1 3G-11 804C-00050 PRODUCTION PROFILE 05/12/09 1 1 2A-O6 B14B-00048 DDL - 05/15/09 1 1 2A-16 8146-00047 LDL 05/15/09 1 1 3G-16 B14B-00049 INJECTION PROFILE p ~ 05/16/09 1 1 3G-18 6148-00050 PRODUCTION PROFILE 05/17/09 1 1 2D-05 AYS4-00072 INJECTION PROFILE - 05/21/09 1 1 1 E-15 B14B-00058 LDL 05/24/09 1 1 3H-33 B04C-00006 CH EDIT (PEX,SONIC SCANNER,CHFR) 02/09/09 4 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • f Ct • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, April 09, 2009 9:55 AM To: 'Ennis, J J' Subject: RE: 2A-06 RWO supplemental procedure (PTD 184-064) Jim, Sorry I did not get back to you sooner. As discussed, a real can of worms. Your proposal should provide a safer working environment and allow further diagnostics to be performed. I have apprised Commissioner Foerster of your plan and she has no objections. Keep us advised of the diagnostics. As discussed, a new sundry will be needed once the new path forward is determined. Call or message with any questions. Tom Maunder, PE AOGCC -----Ori final Messa e----- -- r ai'~ ~ `~ ~~ ~~'~~ From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] °`"'y' "" Sent: Tuesday, April 07, 2009 4:42 PM To: Maunder, Thomas E (DOA) Subject: 2A-06 RWO supplemental procedure (PTD 184-064) Tom, The procedure for 2A-06 we discussed this afternoon is attached. I included the rig reports through this morning and the pics we looked at for reference. Please let me know if you need anything further. Thanks. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) 1 • • Rig Workover Procedure Supplement Well 2A-06 Kuparuk Injector /TJR subsidence damaged tbg &csg , Prepared By: `I/ z /09 JimiEhnis Engineer Ri~l Work: 1. RIH w/ following string to temporarily ~ar~i S~J~- ~~ `'`~ ~-~~ ~~~~~S~S~`iL"`~~ ~" a) 4.5" 16.6# washpipe shoe w/ cutlip, drive sub & 8RD handling sub ~ ~-+L b) One~joint 3.5" 8RD tbg c) 2.8.13" 'DS' nipple w/ 8RD handling subs d) One joint 3.5" 8RD tbg e) External csg packer (ECP) w/ xovers & 8RD handling subs (spaced so btm above 170' KB) fl 3.5" 8RD tbg to surface Tag tbg stub @ 248' KB and attempt to slide over. Space out so that shoe has swallowed the tbg stub or is resting on it. Land hanger and RILDS. Circ well w/ 60 deg F 12.3 ppg brine. RU slickline. Set'CA2' plug in 2.813" nipple. RU test pump to se# ECP & pressure tbg as specified by BOT ECP service hand (opening 750 psi, closing 1000 psi). Bleed IA & tbg to zero and verity no gas bubbles. 2. RU SLB cementers. Est injection into OA w/ 100 bbls hot seawater staying below 500 psi. Down squeeze OA w/ 150 sx 15.7 ppg ArcticSet1 cement w/ 3 hr pump time @ 50 deg F. If OA holding pressure after pumping cmt, displace w/ 1 bbl diesel in casing. If OA on vac, do not displace but allow cmt to fall. WOC 4 hours to allow it to achieve 500 psi compressive strength. PT OA 500 psi w/ diesel. Install TWC. NDBOP. NUWH. Test tree and packoffs to' 5000 psi. Pull TWC. Install BPV. RDMO. Turn well over to Production via Handover Form. Post Rig Work 1. RU slickline. 2. Retrieve CA2 plug. PT tbg to 2500 psi to verify ECP integrity. 3. RD slickline. 4. Prepare for CT intervention. Jim Ennis Page 1 4/7/09 • rft~ BAKER IR16NE8 Baker OilTools Type of Toal : ECP Packer Assy Inspector : Date : 4107109 Threads : 31/2" EUE box X 31/2" EUE pin Well No. 2q-06 Rig : Nordic 3 r* I 1.77' 20.11' -~-F t~ ~_ Pup Joint 3-112" 9.3 # L-80 EUE mod Cross Over Sub 3-112" EUE mod box x 4-112"IBTpin MM # 10785912 Cross Over Pup Size : 4-112" 4112" IBTM box x BTC pin MM # 10936690 Payzone External Casing Packer Size : 4-112" 1Z.6# L-80 Threads ;~ 112" BTC box x box Locking Shear Valve =1000 psi Pressure Control Valve = 750 psi Comm. No.. 301-37-2402 S/N Knock Off Rods Removed ? :Yes Cross Over Pup Size :4-1/2•• 4-112" BTC pin x 4-112" IBT pin MM # 10936690 Cross Over Sub 4-112" IBTM box x 3-112" EUE pin MM # 10541947 Pup Joint 3-1 /2" 9.3 # L-80 EUE mod f1-:K Q:-... O 04a / A OlA.. • ConocoPhillips Time Log & Summary WelN7ew Web RepoK~ng Report Wetl Name: 2A-06 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 415/2009 7:30:00 AM Rig Release: Time Logs - D~e To Dur S'. l~~th E. De~h..Phase Coda Subcode T Comment _ /04/2009 24 hr summary RDMO 2E-05, moved rig from 2E Pad to 2D Pad, enroute to 2A Pad. ' 22:00 00;00 2.00 COMPZ MOVE TRNS P Move rig from 2E Pad to 2C Pad enroute to 2A Pad. /05/2009 .Spot and level rig over 2A-06, berm up, RU hardline to kill tank and spot tanks, pull BPV, test hardline, attempt to bullhead 100 bbls 12.3 down tbg to kill well and was only able to pump 17 bbls, install BPV, ND tree, install test dart, NU ROPE, test BOPE ult test dart and BPV, MU landin 'nt. ao:oo 07:30 7.50 COMPZ MOVE TRNS P Cont moving rig from 2C Pad to 2A Pad. Accept Nordic 3 Rig @ 07:30 hrs 4-5-2009. 07:30 08:30 1.00 COMPZ RPCOM KURD P Hang tree in cellar, spot spools behind well head, pull rig over well and level up, berm up cellar, spot tanks and equipment, MU hardline to kill tank, 08:30 12;00 3.50 COMPZ WELCTI OTHR P PU lubricator and ull BPV. Re laced bad valve on hardline. 12:00 15:30 3.50 COMPZ WELCTI KLWL P PJSM. Test hard line to kill tanks to 3000 psi. Pumped 12.3 ppg formate brine down tubin startin at 5 BPM,pressure continued to build until 3000 psi rate down to 3/4 BPM, Pumped total of 15 bbls. While pressure comin u on tubin the IA ressure matched it, SD pump. Let pressure bleed down to 1600 psi. Pumped up again to 3000 psi wJ2 bbls. SD, bleed back to only 2500 si. 15:30 16:30 1.00 COMPZ WELCTI KLWL P Opened manffold to equalize OA, IA & tubing. Opened to kill tank and bled off all three to 0 si. Monitored well for 1 hr. Well ressure 0 si w/ trace of as. 16:30 17:00 0.50 COMPZ WELCTI OTHR P RU lubricator and set BPV. 17:00 19:30 2.50 COMPZ WELCTI NUND P ND tree. 19:30 00:00 4.50 COMPZ WELCTI NUND P Install test dart, MU DSA, riser s ool, NU 13 5/8" ROPE. 4/06/2009 Cont NU BOP, test all ROPE at 250/3,000 psi, with 2 7/8" and 3112" test joints, pull test dart and BPV, MU landing joint and top drive, BOLD's, pull 114K and put 3 1/2" completion string in tension, RU slickline and attem t to RIH down tb . 00:00 02:00 2.00 COMPZ WELCTL NUND P Cont NU 13 5/$" BOP, DSA, riser s ool, choke and kill tines. 02:00 02:30 0.50 COMPZ WELCTL RURD P RU test equipment, fill stack. Page 1 of 3 ; . Time Logs -- _- D~g_ Fro To ~r____ $. De h E. De h h e Co a Su co e T mertt 02:30 07:30 5.00 COMPZ WELCTL ROPE P Test BOPS at 250/3,000 si on chart. Tested variable rams and annular with 2 718" and 3 1/2" test jnts. AOGCC Rep Chuck Scheve waived witness of BOP test on 4/5/2009 at 18:00 hrs. 07:30 08:30 1.00 COMPZ WELCTL OTHR Puil #est lu .Check well for ressure well dead. Pulled BPV. 08:30 09:00 0.50 COMPZ RPCOM PULL P MU landing jt. MU top drive. BOLDS, tubing 'um ed u 1". Pulled han er ton floor ullin control line for SSSV apart. UP wt 35K (Top Drive Wt .Filled hole with 12 bbis 12.3 KWF. Break out and LD tubing han er and Landin 't. 09:00 10:00 1.00 COMPZ RPCOM PULL P POOH w/ 217'- 31/2" tubing. Tubing was parted just below tubing collar. LD tubin and clean ri I floor. 10:00 12:00 2.00 COMPZ RPCOM PULL P Wait on 6118" stop sub on rope s ear comin from Deadhorse. 12:00 16:00 4.00 COMPZ RPCOM PULL P MU 6 1/8" OD stop sub on Rope Spear & bumper sub on 3112" drill pipe, RIH and fish 3/8" SS Control line from SSSV. Retrieving approximately 60' per run. 240' of control line u to this oint. 16:00 16:30 0.50 COMPZ RPCOM PULL P RIH to 182' stacked out, could not rotate. POOH and replaced 6 1/8" stop sub w/5 7/8" stop sub. RIH to 229' engauge more control line pulled up hole dragging approx. 10K over, ulied loosed 10' u 219'. 16:30 17:00 0.50 COMPZ RPCOM CIRC P SI and circulated 13 bbis 12.3 KWF around. Shut in and pressured up to 2400 psi on tbg and IA monitoring OA. OA had been bled to 0. OA sta ed at O si no communication. Bled off pressure and blow down hardlines. 17:00 18:00 1.00 COMPZ RPCOM PULL. P Continue attempt to fish control line out, last two runs stacked out at 229'. POOH with no fish. 18:00 19:00 1.00 0 0 COMPZ RPCOM PULD P LD rope spear assembly, load Baker tools and DC's in shed, monitor well, trip tank fluid level alternating between 9.6 and 11 bbis, gas level alternating between 0 and 5,000 units. 19:00 21:30 2.50 0 0 COMPZ RPCOM MILL P MU BHA #2 (8" Inner Dressing Mill Assembly) washed down to 176' and losing string weight, made several attempts but could not get past 182', POOH and changed aut 6" mill shoe to 5 3/4", Page 2 of 3 Time Loys Date Fr m To ! Dur S, Da h E D, Phase :Cade S bcode T e t 21:30 22:30 1.00 0 0 COMPZ RPCOM MILL P RIH with 5 314" Inner Dressing Mill Assembly to 182', had to slow roll string and worked down to 223', could not et ast 223', had 20K overputl starting OOH at 223', POOH LD BHA, called Well Engineer, decision made to run DP with 5" tool joints and bull nose to try and reach tubin stub de th. 22:30 00:00 1.50 0 235 COMPZ RPCOM MILL P MU BHA # 4 4 3/4" Bull Nose) on 3 1/2" DP and bumper sub, RIH to 246' and to ed solid with no roblem, pumped 10 bbls 12.3 ppg to circ out gas, called Well Engineer, decision made to run Baker RBP, load Baker tools, monitor well for 30 minutes, trip tank still alternating gaining and losing 1 bbl, gas units still alternating betrween 0 and 5,000 units. 4/07/2009 POOH LD bull nose and bumper sub, PU RIH with BAker RBP< set at +/-150' and test RBP, POOH, drain stack, ND 80P, ND tb head, NU BOP on casin head, s ar 7" cs . 00:00 01:00 1.00 235 235 COMPZ RPCOM OWFF P Close bag and observe for any pressure build up in DP and IA, obtained 20 psi on bath drill pipe and IA, bled off. 01:00 02:00 1.00 235 0 COMPZ RPCOM TRIP P POOH LD bullnose sub and bumper sub, had 1 K overputl from 246' to 223' with 5" tool 'oints. 02:00 04:00 2.00 0 COMPZ RPCOM PLUG P MU Baker model "L" retrieving head and model "G" Lock-Set RBP, RIH with 5 jnts 3 112" DP, set top of RBP at 163', released set tool, still getting gas around RBP POOH with 31/2" DP, PU 3 'nts 4 314" DC's, RIH and re-set RBP released set t ool, R ~~~'~ wc,v~r~ y~~. Page 3 of 3 i .~~~. ~~ ,; .,~; ~, ~~ s i ~~~»,~: ~, f • r~ • "°°`~ ,; s ~ ~", ~e~, .. „,m - _r~ ~~ ,r `~~_~~~ f q .. • • * a .. i 1 ~ F ~ - ~ ~~~ ~ ~ C Esc. >r&, ' i ~ ~6 $ ~~`""3 "' u ~ ' y a 9 ks' ~ '- ~. d~Y ~., t r ~r r t ~ .~~.: • • ~ .~ ~ - "?~' ' ~ ~ ~'~ ~ ~~ ~ SARAH PALIN, GOVERNOR ~, ~..a ..,..~ ~ ..x"1.4 rl. c_I~. C'~ t~Lt~-7~ OIL A1sD ~ 333 W. 7th AVENUE, SUITE 100 COI~TSER~ATIOI~T COl~'IIIIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Jim Ennis ! FAX (907) 276-7542 Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 ~ a Anchorage AK 99510-0360 ~` Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-06 Sundry Number: 309-111 ~'~'cx~ ~. ~~ -' 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 S ' DATED this ~ day of April, 2009 Encl. ~'!)~ 3.~ STATE OF ALASKA ~ \~O ALASKA OIL AND GAS CONSERVATION COMMISSION 3~ MAR ~ '~ 7~n ~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.2so ~la~sk~i Gib ~ Gas Cans. Gafnmissian 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ aiJer ^ Other ^ Alter casing ^~ Repair well ^/ Plug Perforations ^ 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 ^ 184-064 3. Address: Stratigraphic ^ Service Q • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20028-00 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? YeS ^ NO ^~ 2A-06 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25570 ~ RKB 130', Pad 94' Kuparuk River Field /Kuparuk River Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8205' 6232' 8124' 6154' Casing Length Size MD TVD Burst Collapse CONDUCTOR 103' 16" 103' 103' SURFACE 2724' 9-5/8" 2854' 2650' PRODUCTION 8072' 7" 8202' 6229' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7841'-7879', 7910'-7918', 7931'-7935', 7936'-7956' 5893'-5928', 5956'-5963', 5975'-5979', 5980'-5999' 3-1 /2" J-55 7925' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'FHL' ; BAKER'FB-1' pkr= 7707' ; 7891' Baker'FVL' SSSV @ 1926' 13. Attachments: Description Summary of Proposal 0 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 April 6, 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 Name Jlm EnnIS Title: Wells Engineer Signature ~ ~~ p,~ E~~(I lj Phone 265-1544 Date 3 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ' Plug Integrity ^ BOP Test ~ Mechanical Integrity Test '~ Location Clearance ^ w ~~`~~ ~ ~~~^~ b`1 Other: ~VO~ pS4 C-C9~~~~i~ ~ a~~JV &~>G i~~Y`~il~l~~`'~t~~'1V.~~C"~~~ Subsequent Form Required: ~~~ APPROVED BY ~ A Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 F~evised 06/2006 Submit in Du licate ~~ ~ ~,. r , ~ /~+'~ ~. ~, ~~~ ~ ~ 2009 ,~~/T/~~ ~-''~ ~ L~'~~~r • • Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophillips.com] Sent: Tuesday, March 31, 2009 12:34 PM To: Maunder, Thomas E (DOA) Subject: RE: 2A-06 403 PTD#184-064 Attachments: 2A-06 RWO sundry procedure.pdf 2A-06 RWO sundry procedure.pdf... Tom, My apologies, step 4 should have been eliminated during my wordsmithing. Please cross it out or, if you prefer, a corrected replacement is attached for your use. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 31, 2009 12:18 PM To: Ennis, J J Subject: RE: 2A-06 403 PTD#184-064 Jim, I am reviewing your proposal. It appears that step 4 repeats step 7 and likely should be removed. Please have a look at the procedure and let me know. If it needs to be removed, I can just cross it out. I look forward to your reply. Tom Maunder, PE AOGCC -----Original Message----- From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Tuesday, March 31, 2009 8:24 AM To: Maunder, Thomas E (DOA) Subject: 2A-06 403 PTD#184-064 «2A-06 403 sundry 3-26-09.PDF » Good morning Tom, Attached is a copy of the 403 for 2A-06 that we submitted last Thursday. Because it has a shorter fuse than normal (4/6/09) due to some recent rig schedule changes, I wanted to give you a heads up so it didn't blindside you later this week. Procedure is very similar to that which was performed on 2A-05 last year. Please let me know if any questions or if you need any additional info. Jim Ennis j.j.ennisCconocophillips.com (907)265-1544 (W) (907)632-7281 (C) 1 ~ig Workover Sundry Procedur~ Well 2A-06 Kuparuk Injector Repair subsidence damaged tubing & casing PTD# 184-064 1. Verify sundry approval has been received. 2. MIRU Nordic #3. Pull BPV. Bullhead 100 bbls 12.3 ppg formate brine down tbg @ max rate below 3000 psi. SD & record SITP & SICP. Verify tbg is dead, backside may trickle fluid from fluid imbalance through bleeder tbg leak. Install BPV. ND tree. NU 13-5/8" BOP w/ 2.875"-5" VBR's. Function test BOP. Pull BPV. Install test plug. PT BOP rams & annular to 250/3000 psi. (5/13/07 60 day SI pressures T/IA/OA 1700/1680/60 psig) Pull test plug. (Note: 24 hr advance notification to AOGCC required prior to testing BOPE.) 3. Unland tbg hanger & attempt to pull tbg from Baker PBR. If successful, IA fluid (Kuparuk crude) will U-tube. Circ well to equalize fluids. If unsuccessful @ 80% tbg yield (114M#), land tbg on slips in tension. RU slickline. Attempt 1.375" and, if successful, 2.5" drift of tbg past tight spot. RD slickline. RU eline. If 2.5" drift was successful, shoot 2.5" power cutter mid joint as deep as possible w/ string in tension. If .only 1.375" drift was successful, RIH w! 1.375" tbg punch toolstring and punch tbg as deep as possible. (Note: 1.375" tbg punch cannot be run w/ SLB SafelSecure system so radio silence will be required.) Circ hole over to 12.3 ppg solids free formate brine through ~0.2" punched holes. If tbg punched or neither drift will go, shoot 2.5" power cutter mid-joint above tight spot. POOH w/ 3.5" tbg laying down, spooling SSSV control line as necessary. No equipment shall leave location until surveyed for NORM. IH w/ WRP for 3.5" tbg & s e ow `FHL' packer @ 7730' MD. PT WRP & csg to 1000 psi. R T and log from PBR to surface. RIH w/ 3" IBP ~ - oint in 7" casing @ 3500' MD. Dump 300# san on 5. If tbg was cut shallow, single in w/ 5-3/4" control mill overshot dressed for 3.5" tbg, OS extension, bumper jar, oil jar, six 4-3/4" DC's, accelerator jar and pump-out sub on 2.875", 10.4 ppf, S-135, HTPAC workstring. Engage fish and jar to remove PBR stem. If successful, POOH laying down production tbg, go to step #5. If unsuccessful, release overshot & POOH. 6. RIH w/ 6" smooth OD x 4-5/8" burnover shoe, ten joints washpipe, reverse circ boot basket, 4- 3/4" DC's and pump-out sub on workstring. Establish circ and washover bent tbg. POOH and add 6" outside cutter dressed to cut 3.5" tbg to fishing assembly. RIH, engage lowest possible collar and cut 3.5" tbg. POOH w/ fish. RIH w/ 5-3/4" OS and top extension on 3.5" workstring after drifting for 2.5" power cutter. Engage fish and rig up E-line. Pulling 10M# over on tbg, power-cut tbg in middle of first full joint above PBR. POOH, laying down production tbg. RIH w/ 5-3/4" control mill overshot dressed for 3.5" tbg, OS extension, bumper jar, oil jar, six 4-3/4" DC's, acceleratorjar and pump-out sub on workstring. Engage fish and jar to remove PBR stem. 7. After PBR pulled, RU eline. RIH w/WRP for 3.5" tbg & set mid-joint below 'FHL' packer @ 7730' MD. PT WRP &csg to 1000 psi. RIH w/ PDS memory caliper &SCMT and log from PBR to surface. RIH w/ 3" IBP & set mid-joint in 7" casing @ 3500' MD. Dump 300# sand on IBP. 8. RIH w/ 3.75" multi-string cutter dressed for 7" casing on 2.875", 10.4 ppf, S-135, HTPAC workstring. If cutter will not pass through shallow doglegs, go to Step #10. With pump off, perform torque checks @ 500' & 1000'. After locating collar below w/ blades extended by pump, cut 7" csg mid joint 100' above TOC as determined by SCMT. POOH, laying down 2.875" workstring. Establish 7" csg x OA circulation w/ hot seawater & pump until clean returns. ND & lift BOP's. ND tbg head. RU csg crew. Spear 7" casing w/ 5.75" Itco spear and remove slips. NU 13-5/8" BOP on 7" csg head (11" 3M flange) w/ VBR's. POOH sideways w/ 7" csg and Jim Ennis Page 1 3/26/2009 ~ig Workover Sundry Procedure We112A-06 Kuparuk Injector Repair subsidence damaged tubing & casing PTD# 184-064 number joints for later identification during inspection. Store casing on racks for GKA Integrated Planning Team inspection at a later date. Go to Step #10. 9. If 3.75" MS cutter will not pass through doglegs @ 250', do not try to push cutter down. POOH. RIH w/ 20' 2.875" pilot stinger, 3.25" string mill, bumper jar, oil jars & six 3.125" DC's on 2.875" workstring. Mill/trip down as necessary. POOH. RIH w/ Baker 3.125" piloted 3.5" ~ 3.875" step mill. Mill/trip down as necessary. Circulate hole w/ hot seawater. POOH. RIH w/ 3.75" multi- string cutter dressed for 7" casing on 2.875" workstring. After locating collar below w/ blades extended by pump, cut 7" csg mid joint @ 330' MD. POOH. Establish 7" csg x OA circulation w/ hot seawater & pump until clean returns. ND & lift BOP's. ND tbg head. Spear 7" csg w/ 5.75" Itco spear and remove slips. NU 13-5/8" BOP on 7" csg head (11" 3M flange) w/ VBR's. POOH sideways w/ 7" csg and number joints for later identification during inspection. 10. RU slickline. Roundtrip PDS 9.625" csg caliper & GR/CCL memory tools to 7" stub. RD slickline. 11. RIH w/ 7" casing back-off tool & DC's on 3.5" workstring. Straddle 7" connection below csg cut and pressure up tool as necessary to loosen connection. Release back-off tool & POOH. RIH w/ csg spear, stop sub & bumper sub on 3.5" workstring. Spear csg stub and back out loose connection. POOH. Note: If back-off assembly or 7" casing will not pass through 9.625" casing bore, utiliize piloted string mills to achieve needed drift. 12. RIH w/ 10' csg pup, HES Type H ES cementer w/ six shear pins (3300 psi to open w/o opening plug) on new 7" 26# L-80 BTC Mod csg w/ one centralizer per joint. Bakerlock all connections below `ES' cementer. Screw into csg connection & overpull 50M#. PT csg to 2500 psi. NU cement head w/ `ES' closing plug loaded. 13. RU SLB cementers. Pressure csg to 3500 psi to open `ES' cementer. Est circ w/ 100 bbls hot seawater @ 5 BPM. Pump 50% excess 15.7 ppg ArcticSet1 cement w/ 3 hr pump time @ 50 deg F. Launch closing plug and displace w/ hot seawater until bump to close `ES'. After good cement returns to surface are achieved, close OA valve to squeeze cement into 9-5/8" csg teak. After plug bumps & closes 'ES', PT 1500 psi. Bleed off & verify no flow. ND cement head. WOC 4 hours to allow it to achieve 500 psi compressive strength. NDBOP & lift. Cut 7" csg & land on slips w/ 50M# tension. Install Vetco csg packoffs. 14. NU Vetco tbg head & 13-5/8" BOP stack w/ VBR's. PT csg, tbg head & BOP body 3000 psi. RIH w/ 6.125" mill tooth bit, boot baskets & DC's on 3.5" workstring to 'ES' cementer. Drill up HES plugs & chase to top of sand on IBP. PT csg to 2500 psi. Dry drill any remaining debris on sand to crush. POOH. 15. RIH w/ 10' wash shoe & inside junk baskets on workstring. Tag sand & reverse circ down to IBP. Circ hole over to 9.6 ppg brine. POOH. 16. RIH w/ IBP retrieving head on workstring to IBP. Engage IBP & release. POOH w/ workstring & IBP. 17. If seal assembly was pulled from the PBR, go to Step #18. If tbg cut remains above FHL, RIH w/ following on workstring: a) 3.625" ID Baker Poorboy overshot w/ handling sub Jim Ennis Page 2 3/26/2009 ~ig Workover Sundry Procedure Well 2A-06 Kuparuk Injector Repair subsidence damaged tubing & casing PTD# 184-064 b) 2.813" `X' nipple w/ RHC plug installed w/ handling subs c) FHL pkr (pinned 60M# shear) w/ handling sub below d) PBR (pinned 40M# shear) w/ handling sub above on Locate cut tbg stub and spot CI brine (1% by volume Baker Petrolite CRW-132) between packers and in well below 7500' MD. Engage tbg stub and stack 10M# over. Pick up to string weight. Drop ball & rod. Pressure tbg up to 2500 psi and set FHL. Shear PBR. POOH w/ workstring, laying down. 18. Single in w/ 3.5" completion as follows: • 3.5", 9.3#, L-80, 8RD AB mod torque (ft-Ibs): 1680 min, 2240 optimum, 2800 max a) PBR seal assembly w/ handling sub above b) 1 joint 3-1/2", 9.3#, L-80, EUE 8RD Mod tubing c) 2.813" `DS' nipple w/ handling subs d) 1 joint 3-1/2", 9.3#, L-80, EUE 8RD Mod tubing e) KBMG GLM containing 1500 psi SOV w/handling subs f) New 3.5", 9.3#, L-80, EUE 8RD Mod tubing g) 2.875" 'DB' nipple @ 500' (3.5" tbg above must drift 2.91 ") 19. Space-out PBR 2' off btm and land tbg hanger with a full joint immediately below. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 3000 psi for 15 minutes. Bleed off tubing pressure to 2000 psi. Holding the tubing pressure at 2000 psi, PT IA to 3000 psi for 30 minutes. Bleed off IA & then tubing pressure. Pressure IA to 2000 psi rapidly to shear the SOV. Install TWC. NDBOP. NUWH. Test tree and packoffs to 5000 psi. Pull TWC. Freeze protect well by pumping 75 bbls diesel into IA & equalize across tree. Install BPV. RDMO. Turn well over to Production via Handover Form. Post Rig Work 1. RU slickline. 2. Replace shear valve with dummy. PT tbg 2500 psi. 3. Retrieve ball/rod &RHC plug, if necessary. Retrieve WRP. 4. Install GL design. 5. RD slickline. Jim Ennis Page 3 3/26/2009 ! ~ ,~ . 555 (1926-1927, OD:3.500) TUBING (0-7925, OD:3.500, ID:2.867) Gas Lift 3ndrel/Dummy Valve 1 (7647-7648, OD:5.313) PBR (7693-7694, OD:3.500) PKR (7707-7708, OD:6.156 ) Injection MandrelNalve 2 (7718-7719, Injection MandrelNalve 3 (7788-7789, PKR (7891-7892, OD:6.156) NIP (7898-7899, OD:3.500) SOS (7899-7900, OD:3.500) Per( (7910-7918) Perf (7931-7935) Perf (7936-7956) KRU 2A-06 Canaca~'trllp~ Al~~kas Inc. • Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~,~CGt~~~fl ©~ ~ ~ $ ZOC? • ~~ E ~< .~~~; ~. ~_ ~~_ ~~ -~` ~: . Dear Mr. Maunder: Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves. as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitorlsealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the. well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ®n~~~~~~5 Asa ~l~~e Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant 1"op-off Report of Sundry Operations (10-404) Kuparuk Field Date Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft a1 2A-01 184-057 SF na SF na 1.5 12/14/2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44'° na 50 12/14!2007 2A-04 184-053 9'6" 1.2 10" 9!24!2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 12/5/2007 2A-~ 1i~4-064 25'5" 1.5 20" 12/12!2007 8.5 12f4~20t)T 2A-OS 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.75 12/14/2007 2A-10 186-002 23' 3.1 11" 9!24!2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/512007 2A-12 186-004 SF na SF na 6 12!5!2007 2A-13 185-144 SF na SF na 1.75 12!14/2007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14!2007 2A-21 193-133 5' 0.7 18" 9/24!2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 RE: 2A-06 PTD # 184-064 failed MITIA . . Jim, Sorry for the misunderstanding. I've enclosed the data in the state format. Please note I reported 1650psi as the starting IA pressure in my last e-mail. The starting IA pressure was 2475 psi. The IA bleed to 2650 in less than 5 minutes after pumping stopped. The actual time of that pressure reading is not recorded more specifically than, less than 5 minutes from the time pumping stopped.. The IA returned to 1475 by 15 minutes as indicated in the enclosed report. Let me know if you have any other questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 ICANNED MAH 27 2007 n161 11 .com -----Original Message----- From: James Regg [Tl1?:~~.t:c:;:jiTr,_:r::~99(iì)êlc3:rn~Il. state. ak. us Sent: Thursday, March 15, 2007 4:04 PM To: NSK Problem Well Supv Subject: Re: 2A-06 PTD # 184-064 failed MITIA ...." ,'''"' n... ''''0'' -. guess I should have been more exact in my request - please send the test results on the normal MIT form. Thank you. Jim Regg AOGCC NSK Problem Well Supv wrote: Jim, We attempted an MITIA to 3000 psi but could not build IA pressure above 2900 psi. The IA pressure rose from 2650 psi to 2900 psi in 3 minutes but would not build above 2900 psi. DHD pumped 3 bbls of diesel and determined the liquid leak rate to be 2.2 gal per minute. Once the pump was shut down the tubing pressure fell to 2650 psi in less than 5 minutes. The test was terminated at that point. Let me know if you have any further questions. lof2 3/15/20074:34 PM RE: 2A-06 PTD # 184-064 failed MITrA . . Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n161 '-L . corn -----Original Message----- From: James Regg [mailt.o:jim regg@adrnin.state.ak.us] Sent: Thursday, March15,200i12:42PM~-·--- To: NSK Problem Well Supv Subject: Re: 2A-06 PTD # 184-064 failed MITIA please send test results for failed MITIA; thank you. Jim Regg AOGCC NSK Problem Well Supv wrote: Jim 2A-06 PTD # 184-064 produced water injector, failed an MITIA. T/I/O = 2850/2475/120 psi. Immediate action will be to freeze protect and shut in the well. The well has been added to t.he failed MITIA report. Let. me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 nl 1 11. corn «2A-06.pdf» > Content-Description: MIT KRU 2A-06 03-06-07.xls MIT KRU 2A-06 03-06-07.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 20f2 3/15/20074:34 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test \2.1:( '3IJr>/D1 Email to:BobJleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /2A-06 03/06/07 Perry Greenwood / Ian Ives Packer Depth Pretest Initial 15Min. 30 Min. Well 2A-06 Type Inj. I W TVD 5,773' Tubing 2850 2850 2850 I nterval 0 P.T.D.!1840640 I Type test I P Test psil 1500 Casing 2475 2900 2475 p/FI F Notes: troubleshooting T X IA communication OA 120 120 120 Pumped 3 bbls, unable to build pressure above 2900 psi, aborted test, IA liquid leak rate of 2.2 gpm @ 2900 psi Well I Type Inj. TVD I Tubing Interval P.TD. Type test! Test psi! Casing P/F Notes: OA D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 ./ M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT KRU 2A-06 03-06-07.xls MEMORANDUM State of .Alaska Alaska Oil and Gas Con5en'ation Commission TO: Jim Regg P.I. Supen'i~or .---, 1~t-1'¡ b(z~/tJ4 DATE: Wednesday. June 23. 200~ SlIBJECT: Mechanlcallmegrity Tests CONOCOPHlLLlPS ALASK.A TNC 1A-06 FROM: Chuck Scheve Petroleum Inspector KUPARUK RIV UNIT 1A-06 Src: InspeclOr Reviewed By: P.I. Supn' 33~ Comm NON-CONFIDENTIAL Well Name: ~UPARUK RJV UNIT 2A-06 Insp Num: mitCS04062 1 122751 Rei Insp Num: API \Vell Number: 50-103-20028-00-00 Permit Number: 184-064-0 Inspector Name: Chuck Scheve Inspection Date: 6/20/200~ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1A-06 Type Inj. P TVD 6130 IA 1770 2680 16~0 2620 P.T. 18.106.10 T)/peTest SPT Test psi I.1U15 OA 10 20 10 10 I ntenal .JYRTST PIF P Tubing 2170 2270 1170 1170 Notes: The pretest pressures were observed for 30+ minutes and found stable. \\lell demonstrated good mechanical integrity. Wednesday. June 23. 200~ Page 1 of I MEMORANDUM TO: THRU: FROM: Dan Seamount Commissioner Blair Wondzell P.I. Supervisor Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept. 1,2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 2A Pad 2A-01A, 2A-02, 2A-03, 2A-04, 2A-06, 2A-08, '2A-20, 2A-21,2A-23 KRUlKuparuk River Field NON- CONFIDENTIAL P.T.D.I Notes: WellI P.T.D~I Notes: WellI - P.T.D.I Notes: WellI 2A-04 P.T.D.I 1840530 Notes: P.T.D:I 1840640 Notes: WellI 2A-08 P'T'D'I 1852480 Notes:- w "l PiT'D'I :1931510 Notes: WellI 2A-21 P.T.D.~ 1931330 Notes: WellI 2A-23 P.T.D.~ 1931420 Notes: 'ype INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER IN J. N = NOT INJECTING Packer Depth Pretest Initial 15 Min. 30 Min. 2A-O~A I Ty,~j.IG I T.V.D. I 5796 ITubml 35001 38001 35001 3800 I~nterva~l 4' 1840570 ITypetestl P I Testpsii 1449 I CasingI 520 117601176011760I P/FIE ~^-0~ i Type lnjlJ s I ~.V,D. I 5800 ITubingl 27401 2750 I 2750 I 2'~50 I lntervall 4 184o5oo ITypetestl P I Testpsil 1450 I CasingI 575 I 1710 I 1700 I 17.10 I P/F I P 2A-03 I Typelnj.I GI T.V.D. I 5845 ITubingl 3550 I 35001 35001 3500 l lntervall 4 . 1840510ITypetestl P I Testpsil 1461 I casingl 11601167511610116101 P/FI P I Type~nj.I G IT'V'D'I 5813 ITubingl 3600 I 3600 I 3625 I 3625 I~nte~a~l 4' Type testI p.' I TestPsil 1453 I CasingI 115o1169o1168o1168oI P/FI P I Typeinj. G IT-v:D' I I Int,~all 4 Type testI p I Testpsil 1443 IC'asingI 1650I 2200I 2200I 2200 I PIF I P s I -vlD' I 5785 Imubingl 27251 27251 2725 I 2725 I'ntem'l 4 TypetestI p ITestPsill 1446 I CasingI 950 I 16251 16251 1625 I P/F I P_' I~-ype,nj.I s I T.V.D. I 5786 I'l:ubingl 2850 ! 2850 I 2850 I 2850 Ilntervall 4 ITypetestl P I-Testpsil 1447 I CasingI 1175 I 1700 I 1725 I 1710I P/FI P I Type Inj. I S' I T.V.O. ! 5774 I Tubing I 2700 I 2700 I' 2700 I 2700 I,nterva,I 4 Typetesq P I Testpsil 1444 I~asingI 60O I 1720 I 1725 I 1725I P/F I P' IType Inj. Type test 's IT.V.D. t 5765 ITubingl 11251 11501 ~S01 I lntervall 4 i P }TestpsiI 1441 ICasingI 600 11650 I' 1610116001 PIF I P' -. Type Test M= Annulus Monitoring ' P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= TemPerature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Test's Details- Wednesda% Atm, 30,-2000: I traveled to Phillips Alaska Inc.'s KRU 2A pad to witness the 4 year M1Ts on wells # 0lA, 0A, 03, 04, 06, 08, 20, 21, 23. Jerry Dethlefs was the PlA rep. In charge of testing. The standard annulus pressure test was performed with all nine wells passing the 30 minute pressure tesL Summary': I witnessed nine sUCCeSsful MITs on PlA's KRU 2A.Pad. M,I,T.'s performed: ~_ Number of Failures: 0_ Attachments: Well schematics {9) MIT report form · 5112/00 L.G. Total Time during tests: 8 hrs cc: MIT KRU 2A 8-30-00 JJ.xls 9/5/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of ReqUest: Abandon Alter casing _ Change approved program 2. Name of Operator ARCO Alaska, Ir~. 3. Address P. O. Box 100360, Anchorage, AK Suspend_ Operation Shutdown _ Re-enter suspended well _ Repair well Plugging _ Time extension Stimulate m m ~ Pull tubing _ Variance _ Perforate _ Other (~ONVERSION 5. Type of Well: Development __ Exploratory _ feet Stratigraphic _ 7. Unit or Property name 99510 Service _ lruk River Unit 4. Location of well at surface 597' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1354' FNL, 1259' FWL, SEC 23, T11N, R8E, UM At effective depth 1384' FNL, 1159' FWL, SEC 23, T11N, R8E, UM At total depth 1392' FNL, 1132' FWL, SEC 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8205' feet Plugs (measured) 6230' feet NONE 81 24' feet Junk (measured) 6 1 5 4' feet NONE Size Cemented 1 6" 175 SX CS II 9 5/8" 860 SX PF E 250 SX PFC 7" 475 SX CLASS "G" 250 SX PFC 7841 '-7879', 7910'-7918', Effective depth: measured true vertical Casing Length Structural Conductor I 0 3' Surface 2 8 5 4' Intermediate Production 8 2 0 2' Liner Perforation depth: measured 8. Well number 9. Permit number 10. APl number 11. Field/Pool Kuparuk River Field River Oil Pool Measured depth True vertical depth 103' 103' 2854' 2649' 8202' 6227' 7931 '-7946' true vertical 5891'-5925', 5954'-5961', 5973'-5987' RECEIVED Tubing (size, grade, and measured depth) 3 1/2", J-55, @ 7925' Packers and SSSV (type and measured depth) ,~as~a~ .0[[ ~ Gas 00tls. BAKER FHL PACKER@7707', BAKER FB-1 PACKER @ 7899', BAKER FVL SSSV @ 1926' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Convert from gas injection to production ;~ kl~,~er'~ Iq 9-/. 14. Re_oresentative Daily Average Prod¥¢ion or Iqjectiop Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Pressure Tubing Prior to well operation 5000 500 4000 Subsequent to operation 150 4880 0 500 2OO 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Water Injector Daily Report of Well Operations~ Oil X Gas Suspended 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ~ OILAND GAS CONSERVATION COMMI,'SSION REPORT OF SUNDRY WELL OPERATIONS Suspend Plugging _ Pull tubing m .x 1. Type of Request: Abandon Alter ca'~ing _ Repair we~ Change approved program X.__- 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 597' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1354' FNL, 1259' FWL, SEC 23, T11N, RSE, UM At effective depth 1384' FNL, 1159' FWL, SEC 23, T11N, R8E, UM At total depth 1392' FNL, 1132' FWL, SEC 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 1 0 3' Surface 2854' Intermediate Production 8 2 0 2' Liner Perforation depth: measured Operation Shutdown_ Re-enter suspended well _ Time extension Stimulate Variance Perforate Ct h er . 6. Datum elevation (DF or KB) true vertical Tubing (size, grade, and measured depth) 3 1/2", J-55, @ 7925' 130' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-06 feet 9. Permit number 84-64 10. APl number 5o-103-20028 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 8205' feet Plugs (measured) 6230' feet NONE 81 24' feet Junk (measured) 61 5 4' feet NONE Size Cemented Measured depth True vertical depth I 6" 175 SX CS II 9 5/8" 860 SX PF E 250 SX PFC 7" 475 SX CLASS "G" 250 SX PFC 7841 '-7879', 791 0'-791 8', 5891'-5925', 5954'-5961' Packers and SSSV (type and measured depth) 103' 103' 2854' 2649' 8202' 6227' 7931 '-7946' 5973'-5987' RECEiVF[ d U L 2 3 1993 Alaska .0il .& 6as Cons. C0ml BAKER FHL PACKER@7707', BAKER FB-1 PACKER @ 7899', BAKER FVL SSSV @ 1926' Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. '' Reoresentative' Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 17. 15o 4880 O .500 2.0.0 ,7.ooo . - . _ 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector x Daily Report of Well Operations Oil_ Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned Form 10-404 Rev 06/15/88 Service Title Kuparuk ' Petroleum Enc, lineer Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Date: July 15, 1988 RETURN TO: Transmittal #: 7225 ARCO Alaska, Inc. Attn' Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. t30-15 Kuparuk Fluid Level Report · 30-10 Kuparuk Fluid Level Report t 2 D- 15 Kuparuk Fluid Level Report * 2A-06 Kuparuk Fluid Level Report - 1 G- 07 Kuparuk Fluid Level Report ~-1 G-08 Kuparuk Fluid Level Report ~ 1 G-15 Kuparuk Fluid Level Report ' 31-0~1 Kuparuk Fluid Level Report ~ 31-1 2 Kuparuk Fluid Level Report · 2A-03 Kuparuk Fluid Level Report , 3 H- 14 Post Frac Job Report ' 2 B- 16 Bollom Hole Pressure' Survey ,, 3J-1 0 Kuparuk Well Pressure Report . Please acknowledge receipt and return 7-11-88 7-11-88 7-12-88 7-12-88 7-08-88 7-08-88 7-08-88 7-08-88 7-08-88 7-06088 7-09-88 7-03-88 3-08-88 Tubing Tubing Casing Tubing CasIng Casing Casing Tubing Tubing Casing Alia Frac A-10 PBU Amerad Receipt Acknowledged: - ' .................. Date' - ........... DISTRIBUTION: ' D&M State of Alaska SAPC Mobil Unocal Chevron ARCO Alaska, Inc. Date: Transmittal #: 7212 July 1, 1988 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records 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-01 Kuparuk Fluid Level Report 6-23-88 Tubing 2 A- 0 2 Kuparuk Fluid Level Report 6 - 2 3 - 8 8 Tubing 2A-06 Kuparuk Fluid Level Report 6-23-88 Tubing 2 A- 0 8 Kuparuk Fluid Level Report 6 - 2 3 - 8 8 Tubing Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: D & M -!~;. ~tate of Alaska Chevron Unocal Mobil SAPC ARCO Alaska, Inc. Date: June 17, 1988 Transmittal #: ~194 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. ,~ 1L-16 2D-05 Kuparuk Well Pressure'Report Water Injection Spinner Data Sheet Water Injection Spinner Data Sheet Gas Injection Spinner Data Sheet Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressure Report -~ Kuparuk Well Pressure Report - ~ 2A-06 '~ 2W-09 ~ 3K-02 '~ 2G-07 ~- 2G-07 ~ 3B-06 ~ 3Q-15 Please acknowledge receipt and return 6-02-88 PBU - Sand A 6-08-88 Both Sands 6-09-88 Both Sands 6-08-88 Both Sands 6-10-88 Tubing 6-10-88 Tubing 6-14-88 Casting 6-06-88 Static - Sand A 5-15-88 PBU - Both Sands R~ Nast~ 13ti & &~s Cons. Commission wledged: /m~n__m?,L .................... Date' DISTRIBUTION: D & M State of Alaska Chevron Mobil Unocal SAPC Kuparuk Well 2A-6 Well 2A-6 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'O037 RECEIVED Gas Cons. CommissJoD Anch!:ra. ge STATE OF ALASKA ALASK, .)IL AND GAS CONSERVATION COMM. .,ION 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.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 597' FSL, 53' FEL, Sec. 14, TllN, R8E, UM 5. Datum elevation (DF or KB) RKB 130' 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Permit number 84-64 feet At top of productive interval 1354' FNL, 1259' At effective depth 1384' FNL, 1159' At total depth 1392' FNL, 1132' FWL, Sec. 23, 11. Present well condition summary Total depth: measured true vertical FWL, Sec. 23, FWL, Sec. 23, T11N, R8E, UM T11N, R8E, UM Tll_N, R8.E,. UM 8205' 6230' feet feet Plugs (measured) 9. APl number 50-- 103~20028 10. Pool Kuparuk River Oil Pool Effective depth: measured 8124' feet true vertical 6154' feet Junk (measured) Casing Length Size Structural Conductor 103' 16" Surface 2854' 9-5/8" Intermediate Production 8202 ' 7" Liner 7841'-7879' Perforation depth: measured Cemented Measured depth 175 Sx Cold Set II 103' 860 Sx Permafrost E 2854' 250 Sx Permafrost C 475 Sx Class "G" 8202' 250 Sx Permafrost C , 7910' -7918', 7931' -7946' MD ~ue Vertical depth 103' 2649' 6227' true vertical 5891'-5925' 5954'-5961' 5973'-5987' TVD Tubing (size, grade and measured depth) 3-1/2", J-55, @ 7925'. Packers and SSSV (type and measured depth) _ _Baker FHL @ 7707'., Baker FB-1 @ 7899'. Baker FVL SSSV @ 1926'. 12.Attachments Description summary of proposal ~r Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation i\ L '~ L ! V L [J February 7, 1988 14. If proposal was verbally approved Name of approver Naska 0ii & Gas Cons. 61:~i¢~roved 15. I hereby certify that the foregoing is true and correct to the best of ~hl~q~ledge Signed ,~&~_~.,,,¢~! ~'~ .2//'~~'9~~. Title Commission Use Only · Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Approved by ORIGINAL SIGNED BY LONNIE C. SMrrH ~,pp?oved Copy Returned ~.~ Commissioner Form 10-403 Rev 12-1-85 the commission Submit in triplicat~r/ ARCO Alaska, Inc~'-'~. Post Office .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 multiple Applications for Sundry Approvals on Kuparuk wells. The wells were both conversions and fractures as listed below. Well Action Anticipated Start Date 2A-3 Convers i on 2A-6 Conversion 2A-7 Conversion 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 OCT 1 6 1987 Alasl~ 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfieldCompany STATE OF ALASKA ALA,.,KA OIL AND GAS CONSERVATION COl,,,,wlSSlON 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 597' FSL, 53' FEL, Sec. 14, T11N, R8E, UH 5. Datum elevation (DF or KB) RKB 130' 6. Unit or Property name Kuparuk River Unit 7. Well number 2A-06 feet At top of productive interval 1354' FNL, 1259' FWL, Sec. 23, At effective depth 1384' FNL, 1159' FWL, Sec. 23, At total depth 1392' FNL~ 1132' FWL~ Sec. 23~ 11. Present well condition summary Total depth: measured true vertical TllN, R8E TllN, R8E T11N ~ R8E 8205' 6230' feet feet , UM , UM ~ UM Plugs (measured) 8. Permit number 84-64 9. APl number 50-- 103-20028 10. Pool Kuparuk River Oil Pool Effective depth: measured true vertical 8124' feet 6154' feet Junk (measured) Casing Length Structural Conductor 103' Surface 2854' Intermediate Production 8202' Liner Perforation depth: measured Size 16" 9-5/8" 7" Cemented Measured depth True Vertical depth 7841 '-7879' 175 Sx Cold Set II 103' 860 Sx Permafrost E 2854' 250 Sx Permafrost C 475 Sx Class "G" 8202' 250 Sx Permafrost C , 7910' -7918', 7931' -7946' MD true vertical 5891'-5925' 5954'-5961' Tubing (size, grade and measured depth) 103' 2649' 6227' 3-1/2", J-55, @ 7925'. Al.~ska 0il & Gas Cons. Commissi0~ Packers and SSSV (type and measured depth) Anchorage Baker FHL @ 7707', Baker FB-1 @ 7899', Baker FVI. $$$V @ 192§', 12.Attachments Description summary of proposal J~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 20, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the fpregoing is true and correct to th~,,best of my knowledge Signed /,~/¢_./,¢. ~ 2 ~'~ Title ~ ~,):¢..~J_./c.C;IA,/-;-. ~ Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Approved by Form 10-403 Rev 12-1:85 ~turned .,. _ Commissioner by order of the commission Date Submit in triplicate Kuparuk Well 2A-6 Well 2A-6 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'O006 ARCO Alaska; Inc. ~ Post Office B,... 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 '}" I:~: Al' !.?; t'i ]:'l' r~-.~.._"" ~ t-~, ("~ .... ' '"".' ; ,..."~ ", .'h , F::!F_"f'UF:H 'l"(!]' r~ F: ['. ."'i ,",l._.~q.S'l(/~,.' ]ZI--.~C,. i. ~ ¥" ", r ~ ~. .1:~: E: C [)I;: ~),!i' C: I... Ii!: I':,' I-.': · . " ,~'f () --i ! i ]:~; - .. / ~T -' 'i" · -,..' /..-'- ," -'.- .' ;. I'" , .] ."fi ~' : ~''~ ;" - ~...,...A~.. ,,, i.t ,-- ,..' t..' '-.! . ' ~, ~ "':: !' i [) I':: ~';:'~ (]' !.".: , ~'::"I': ??5 i 0. .... . 'l"[!:f) I -I E: F:: [:' f;.,' ]: T I -I ~'ql'::l]: TI!i:!: F:'C)L.I...riH]:H(:~ .I l'l!i:H~ .~'' F:'I... '""I:: ~..~ ..... I: P,'Cl<i~.0H'....ii!'.~),'..'~ I.~I'-'.: I F:'"I" ~'qJ~qI;" !';:l!!:'f't. Jl"('i'J. 0i'-Jli~.S' ]: C i]li!:D C(]F"Y [)F" '1:1--I':I: .S' TF~.'.'~i'-!.S'H .. · -..... ~....-~ . '" (.. ,-.~, = ~_. (:1 i) l IF:' I ( ~''' F'[] i'::'i".S' '- . · . . ,' [.1 j'-.! E'. C [)F' Y 'Ii I'"' Fi' ~'-"; C I'1 ) , ARCO Alaska, Ir Post Office Box 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 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: on Well Action Date Performed 1E-6 Fracture 1/26/85 1E-7 Reperf 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 Fracture 2/7/85 1E-18 Fracture 3/13/85 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 1L-7 Fracture 1/30/85 1Q-9 Fracture 3/18/85 1Q-10 Fracture 3/5/85 1Q-12 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversion 2X-8 Perforation 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 AllanticRichfieldCompany "----' STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION CO,vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, ]:NC, 3. Address P, O, BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4. Location of Well SURFACE LOCAT]:0N- 597' FSL, 53' FWL, Sec. 14, T11N, R8E, UM BOTTOM HOLE LOCATION' 1392'FNL, 1132' FWL, Sec. 23, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 130' PAD 94' I ADL 25570 Al K 12. 7. Permit No. 84-64 8. APl Number 50- 103-20028 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 2A-6 1 1. Field and Pool KUPARUK RIVER KUPARUK RIVER 2668 PFC01 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD OIL 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 [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 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-6 was converted from a producer to an injector. Injection will be in the "C" sand only. KUPARUK ~4. ~ hereby oertifv that the foregoing is true and oorre~t to the best of ~l~6~g~. ON S The space below for Commission use Title COORDINAIOR 3/28/85 Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. :'.'.. :--:~.; ) - - c:~ :. ?.~k~ , -;':c':,c ~.~,T 277 Transmittal No: 4741 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 %ransmitted 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 Complet ion 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 ~A-7 CCL & Perf. Record 7~05/84 Run ! 2A-7 Collar Log for Sq. Guns 7/01,02/84 (Sq. #1, #2) ~+:"~'~J'7'::~':cBL::"'Va~iable'DenSlty" 7/04/84 Run 2 6800 - 7819 -2×3 ,,:,:-:-,-: ,,:-. · ': "' 7/06/84 Run 3 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 f-.. /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE DISTRIBUTION Dr illing Geology Mobil W.¥. Pasher Alaska Oil & Gas 5.C~schCommis C . s~on G. Phillips ~.'i~:~-a: -~e..:.o'~ Alaska Phillips Oil Sohio J.J. Ra t~hme 11 Union Chevron NSK Operations R g D Well Files ARCO Alaska, I Post Offic,; Box 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) RECEIVED JAN 0 4 1985 Alaska 0ii & Gas Cons. C0mrnJssJ0rt Anchorage ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL 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. 84-64 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA. 99510 50-103-20028 OTHER [] 4. Location of Well SURFACE LOCATION: TllN, R8E, UM 597' FSL, 53' FWL, Sec. 14, BOTTOM HOLE LOCATION: 1392'FNL, 1132' FWL, Sec. 23, TllN, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 130' PAD 94' I ADL 25570 ALK 2668 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2A-6 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 [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 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). It is proposed that Kuparuk well 2A-6 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 26, 1985. '~ ~ No,~D~t~d AlasKa Oil & Gas Cons. commission A,~cho, ag-, 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS COORDINATOR The space below for Commission use Date 1/3/85 Conditions of Approval, if any: IlltlGIII,~[ StlIIElt BY LONtI"IE ~. SIiIITII Approved by. CQMM ISS ION ER ~kl~proved By Order of the Commission Form 10-403. Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Im Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 17, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2A-6 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. Si ncerely, ~]. Gruber Associate Engineer JG/tw GRU1/L42 Enclosure RECEIVED SEP 2 4 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .. ":' ~'~ STATE OF ALASKA ALASK~.-.)IL AND GAS CONSERVATION (. :IMISSION 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 A1 aska, Inc. 84-64 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 103-20028 4. Location of well at surface 9. Unit or Lease Name 597' FSL, 53' FEL, Sec.14, TllN, R8E, UN j~;~ ....... ~,~, .--,'r,,.~{ Kuparuk River Unit At Top Producing Interval j V~P, IFI~D j 10. Well Number 1354' FNL, 1259' FWL, Sec.23, T11N, R8E, UMI Surf. E i 2A-6 ____ At Total Depth lB. [-k ~ j 11. Field and Pool 1392' FNL, 1132' FWL~ Sec.23, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l 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 116. No. of Completions 05/17/84 05/23/84 06/30/8/+ N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'l'VD) 19. DirectionalSurvey { 20. Depth where SSSV set I 21. Thickness of Permafrost 8205'MD, 6230'TVD 8124'MD,6154'TVD YES ~ NO [] 1926 feetMD 1500' (approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/FDC/CNL/Cal ~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 175 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2854' 12-1/4" 860 sx Permafrost E & 2;0 sx Permafrost C 7" 26.0# J-55 Surf 8202' 8-1/2" 475 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) 7936' - 7946' 3-1/2" 7925' 7891' & 7707' 7931' - 7935' w/4 spf, 90° phasing 7910' - 7918' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL usED 7841' - 7859' N/A 7859' - 7879' w/12 spf~ 120° phasing 27. N/A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.} I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-oiLRATIO :TEST PERIOD J~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE. RECEIVED SEP 2 4 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 GRU1/WC03 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :.:'~'i'."~ "': ..... -;:: :' ~',-~'~'- .... :.:-,'-~ ' .... ¢::-'~ ......... ~- '~-'~' :~'. :":. '"'-',:'.-,-?..,.;~,~,. ;:,..,FOflM~,TioNTE~.i,S.., ,~ r'?'~. _,.-~.:~:.-.,!!,.. '~. · '-: .¢:-"GEOEOGICMARKERS' ~: ~ ~:,¢ :'-'; .... -...,.~_: .', ' -...: .. ,~-~ ~:~ -. , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · . : Top Upper Sand 78/~0' 5890~ N/A Base Upper Sand 7878~ 5924' Top Lower Sand · -7893' 5937' Base Lower Sand 8050' ' 6084' · 31. LIST OF ATTACHMENTS Well H~s~:o~¥= Workover Well H~stor¥; Gvroseooic Sur've.v .(2 c0p~e$) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Ar~;~ tlr{ 11 { nn Fnnr Date /-~, ~.// ............. ~ ~ ~._ , INSTRUCTIONS General' This fOrm is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so State in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, sl~owing the . data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Fi;~II Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and repre~tatl~ t~'~t data In blocks provided. The "Final Report" form may be used Ior reporting the entire operation if space is available. Accounting cost center code District . ICounty or Parish Alaska Field Lease or Unit Kuparuk River Auth. or W.O. no. ~Title I AFE 901725 North Slope Borough Slate Alaska Well no. ADL #25570 2A-6 Drill, Complete & Perforate Operator 1A.R.Co. W.I. ARCO Alaska, Inc. 56.25% Spudded or W.O. begun Date Spudded 5/17/84 Date and depth as of 8:00 a.m. Complete record for each day reported 5124184 5/25/84 5/26/84 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 0045 Hrs. 9-5/8" @ 2854' 8205', (135'), POOH LD DP Wt. 10.3, PV 17, YP 11, PH 9, WL 6.2, Sol 13 Drl to 8205' TD (5/23/84), short trip, circ, POOH. RU Schl, log DIL/SFL/GR/SP/FDC/CNL/CAL f/8187'-2854' WLM. RIH, circ, POOH & LD DP. 7" @ 8202' 8124' PBTD, (0'), Inj mud into ann Wt.. 10.2, ?V 15, YP 9, PH 8.5, WL 6.6, Sol 12 LD DP. RU & rn 209 jts, 7", 26#, J-55 csg to 8202'. Circ, recip. When pipe is moved, hole starts packing off. M&P 475 sx 15.8 ppg C1 "G" cmt. Displ cmt w/NaC1 using rig pmp. Bump plug. CIP @ 2315 hrs, 5/24/84. ND BOPE, lnd csg on slips, set pack-off. Instl &tst tree to 3000 psi. WOC. Prep to move. Inj mud dn 9-5/8" x 7" ann. 7" FS @ 8202' - FC @ 8124' 7" @ 8202' 8124' PBTD, (0'), RR 10.2 NaC1 RR @ 0730 hrs, 5/25/84. Inj fluids. Arctic Pak w/250 sx PF "C" @ 15.5 ppg, followed by 57 bbls Arctic Pak. CIP @ 0445 hrs, 5/27/84. Old TD New TO 8205 ' 0730 Hrs. Released rig Classifications (oil, gas, etc.) Oil Date IPB Depth Kind of rig 5/25/84 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparu~ Sands Producing method Flowing Potential test data RECEIVED 8 8Ep 2 4 ]984 '-,,~:~ka Oil & Gas Cons. Commission ..... ,,urage Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ...... 5/30/84 Drilling Superintendent Well Hiatory - Initial Report- Dally end cut,mit the "la~at ~ on the flret Wedneeday afte, · well Il apudded or worlmver operations are .ta~ed. w~rk I~ter to .pud41.g ahould be summarized on the fen~ giving Inclu~i~ d~tei only. DIItrtct ~laska Field Kuparuk River Auth. or W.O. no. AFE 90172~ North Slope Borough IL,,,. ADL ~25570 Unit l~tle Drill. Complete & Ferforate Alaska ell no. 2^-6 ARCO Alaska. Inc. I^RCO wJ. 5'6.24% Prior Italu', if a W.O. Operator Spudded Date and depth es of 8:00 a.m. Spudded or W.O. begun IDate 5/17/84 · Complete record for each day reported 5/17/84 5/18/84 5/~9/84 thru 5/21/84 5/22/84 5/23/84 IHour 004~ Hrs. 16" @ 103' 1100', (997'), Drlg Wt. 9.4, PV 21, YP 32, PH 8.6, WL 10.8, Sol 7 Accept ri~ @ 2200 hrs, 5/16/84. Spud well @ 0045 hrs, 5/17/84. Drl 12¼" hole to 1100'. 16" @ 103' 2725', (1625'), Drlg Wt. 9.4, PV 21, YP 29, PH~8.0, WL 10.4, Sol 8 Drl & surv 12¼" hole to 2725'. 1200', 0°, Assumed vertical 1371', 3.7°, N84W, 1370.88 TVD, 4.67 VS, .58S, 5.49W 1844', 20.5°, S69.7W, 1832.34 TVD, 96.36 VS, 17.40S, 98.80W 1970'. 23.5°, S66W, 1949.15 TVD, 143.44 VS, 35.19S, 142.51W 9-5/8" @ 2854' 6686', (396i'), TOH Wt. 9.4, PV 10, YP 6, PH 9.0, WL 5.8, Sol 8 Drl 12¼" hole to 2874', short trip, C&C hole. Rn 72 jts, 9-5/8", 36#, J-55 HF/ERW BTC csg & lnd w/FS @ 2854', FC @ 2775'. M&P 860 sx PF "E" @ 12.3 ppg, followed by 250 sx PF "C" @ 15.6 ppg. CIP @ 2045 hrs, 5/18/84. ND diverter, NU & tst BOPE to 3000 psi. TIH w/8½" BHA, tag FC, tst csg to 1500 psi. DO plugs, FC, FS, cmt + 18' new hole. Conduct formation tst to 12.5 EMW. Drl & surv 8½" hole to 6686'. 3070', 50-1/2°, S63.5W, 2789.76, 835.50, 333.878, 766.84W 4298', 49.5°, S61W, 3576.93, 1777.42, 775.25S, 1599.46W 4604'' 48 75°, S61W, 3777.18, 2008.56, 886.59S, 1802.32W 6300', 54.25°, 867.5W, 4821.42, 3343.13, 1442.008, 3016.34W 9-5/8" @ 2854' 7270', (584'), Drlg Wt. 9.2+, PV 7, YP 5, PH 9.0, WL 6.8, Sol 6 TIH, drl & surv 8½" hole to 7270'. 6850', 54-3/4°, S62.5W, 5140.80, 3790.16, 1631.18S, 3422.02W 9-5/8" @ 2854' 8070', (800'), Drlg Wt. 10.2+, PV 15, YP 12, PH 9, WL 5.8, Sol 12 Drl & surv 8½" hole to 8070'. 7473', 39-3/4°, S61-1/2W, 5562.50, 4246.59, 1845.34S, 3824.79W 7985', 21-3/4°, S73-1/2W, 6000.71, 4506.30, 1944.93S, 4065.21W The above la correct Signature IDlt, I~tl, /_! / /) FI . ., ............ ARCO Oil and Gas Company Daily Well History-Final Report In~l~t~tteae: Prepare and submit the "Final Rel~erl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Flail RII~IT' should be submitted also when operatimm:l~l sick, ended for an indefinite, or appreciable length ,o,f time. On workovera when an official felt II nol required upon completion, report completion a~..:-~~ ~ In blocks prowded. The '*Final RegeM form may be used for reporting the entire operation if space is available. District Alaska Fie~d Kuparuk River Auth, or W.O. no. AFE 901725 Operator ARCO Alaska, Inc. lCounty or Parish Lease or Unit Title North Slope Borough ADL #25570 Comple t ion Accounting State COSt center code Alaska IWell no. 2A-6 Spudded or W.O. begun Workover Date and depth as of 8:00 a.m. 6/30/84 thru 7/02/84 Old TD A.R.Co. W.,. 56.24% Date 6/28/84 Complete record for each day reported ITotal number of wells (active or inactive) on this i Icost center prior to plugging and I .labandonment of this well I IHour I Prlor status If a W.O. { 1800 Hrs.. I 7" @ 8202' 8124' PBTD, Ri{ Crude in ann & tbg w/±20 bbls diesel cap in tbg Fin rev circ hole, spot BridgeSal pill, POH w/3½" tbg. RU Schl, tst lub to 1000 psi. Perf 7936'-7946', 7931'-7935', 7910'-7918' w/4 SPF @ 90° phasing. Perf 7841'-7859' & 7859'-7879' @ 12 SPF/120° phasing. Rn JB & 6.125" gage ring to PBTD. RIH w/WL & set FB-1 pkr @ 7891'. Rn 245 its, 3½", 9.3#, J-55, 8RD EUE ABM tbg w/SSSV @ 1926', Bkr PBR 7693', FHL Pkr @ 7707', Bkr FB-1 pkr @ 7890.5' WLM, "D" Nipple @ 7923', Bkr shear sub @ 7924' Tbg Tail @ 7925'. ND BOPE, NU &tst tree to 250/5000 psi. Displ well to crude & 30 bbl diesel. Set BPV. RR @ 2215 hrs, 6/30/84. Released rig 2215 Hrs. Classifications {oil, gas, etc.) Oil Producing method Flowing Potential test data INew TD ! { PB Depth 8205 6/30/84 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands RECEIVED Alaska 0i/ &.Gas Cons Commission 8124' Rotary Well no. I Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i8 correct Signature Drilling Superintendent .. .,pc,... AlaSMa- ' ........ North Slope Boroush [ Alaska I=teid IWell no. Kuparul~ River [ ADL #25570 [2A-6 Au~. or W.O, no. [Title AF~ 901725 Comple~io~ Ol~rator ]ARCO W.I. ARCO Alaska, Inc. 56.24% $13udd~d or W.O. begun IDl~e [Hour ]Pdor status If a W.O. Workover 6/28/84_.. 1800 Hrs. Complete record for each day reported Date and depfft aa of 8:00 a.m. 6/29/84 7" @ 8202' 8124' PBTD, Rev CBU 10.1 ppg NaCl/NaBr Accept r±g @ 1800 hrs, 6/2~/84. ND tree, Nil &ts[ BOPE to 250/3000 psi. RIH w/6-1/8" bit, 7" csg scrprs & 255 jts, 3%" tbg to PBTD, rev CBU. The above la correct Suggested form to be ir~ertcd in each "Active" well folder to d~.eck for timely ccmpliance with our regulations. Operator, ~el 1 Nam~ a~nd number Reports and Materials to be received by: Date ' Required Date Received Remarks Ccmpletion Report Yes '. Well History Yes -.. _~a~. ,4"4 -?t ~u~. ~.~ x~ - P~ ~ /~ · . Core Chips -' -///'~~ -- ~Z Core Description /~ ~.. . ...... . Registered Survey Plat ~~ ~--,/2 -- F~ ~~. Inclination Survey ./~) L Directional Survey y ~ ~. ~_ ~ ~_. ~/~~~ ~~_~_ Drill St~n Test Reports ,_ · Digitized Data y~_~ ARCO Alaska. Ir c:~.: C,~ ~.~:~' 36'$' ~.r, choraoe. Aiaska 99510 Telephone 907 277 5637 Date: 8/17/84 Transmittal No: 4691 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 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 8800 - 9050 Run 1 2A-lA CBL " " GCT 6/02/84 5895 - 7502 " 2A-2~" CBL " " GCT 6/02/84 5291 - 6544 " 2A-3'''~- CBL " " CIS 6/01/84 4948 - 7092 " 2A-4~''r CBL " " 6/01/84 6750 - 8018 " 2A-3~-~ CBL " " CR$/RTS/DDL 6/15/84 6583 - 7081 Run 2 & 3 2A-5 ~ CBL " " 6/03/84 7695 - 8938 Run 1 2A-6_~- CBL " " 6/03/84 6995 - 8078 " 2A-7 ~ CBL " " GCT 6/03/84 6895 - 7823 " 2A-lA ~ Gyro Cont. Tool "CBL/VDL" 6/02/84 60 - 7454 " 2A-2 -'~- " " " " " 6/04/84 60 - 8060 " 2A_3/'-' ,, " " " " 6/02/84 60.5 - 7050 " 2A_4~ " '" " " " 6/02/84 60.5 - 8003 " 2A-6 / " " " " " 6/04/84 60 - 8060 " 2A_7~, ,, " " " " 6/04/84 Surf - 7805 " /cat Receipt Acknowledged: B. Adams F.G. Baker P Baxter BPAE Chevron DISTRIBUTION D&M Drilling Geology -Mobil NSK Operations W.¥. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D Sohio Union Well Files KUPARUK ENGINEERING Well Name: ~ Transmittal Type of Tape . qk-bj Date Tape Number .-- DH -L~s _ DISTRIBUTION 7 S'ta te'i~bf 'i- .AK ?. 'Ge°i°~y/c. Smith R-FCaEIVED Sign & return the attache copy as receipt of data, ilO 3~ ~4,_)..~~' Alaska Oil & ~i Cons. Commission / Anchorage OH LIS Return to: ARCO ALASKA, INC. ATTN: ?aura m. W~FI~3 ATO-1115B P.0. Box 100360 Anchorage, AK 99510 Please note: Blueline, Sepia,~ Tape, Photocopy ARCO Alaska, In,.,. 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, Area rilling Engineer JBK:jh LO1 06/14/84 Enclosures RECEIVED JUN 2 AlasIm 011 & Gas Cons. Commission An~orage ARCO Alaska, Inc. is a Subsidiary of AllanticRichlieldCompany " ~ ,~--, STATE Or: ALASKA ALASK OIL AND GAS CONSERVATION'""~MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERA'r, IONS , · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No, ARCO Alaska, Inc. 84-64 8. APl Number 50- 103-20028 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 597' FSL, 53' FEL, Sec. 14, TllN, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ?~B !30' Pad 94'I A_~T..~ 25570 AT_.~_ _?668 For the Month of May ,1984 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2A-6 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0045 hfs 5/17/84. Drld 12~" hole to 2874'. Ran, cmtd & tstd 9-5/8" csg. Drlg 8½" hole to 8205'TD as of 5/23/84. Ran logs. Ran, cmtd & tstd 7" csg. Secured well & released rig @ 0730 hfs 5/25/84. Performed Arcticpk. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# 5-55 HF/gRW BTC csg w/shoe @ 2854'. Class "C". Cmtd w/860 sx Permafrost "E" & 250 sx 7" 26# J-55 HF-ERW BTC csg w/shoe @ 8202'. Cmtd w/475 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/8187' to 2854'. 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED jUN 2 o Alaska 011 & Gas Cons. Commi~si0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~../.~ ~-~/~ ~,~-,/, ~ TITLE .... DATE NOTE--F~ort ~d/n/~i//orm is required for each calendar month, regardless of the status of operations, and must b'e file(J in duplicate with the Alaska Oil and Gas Cons~a~ion Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 H-FLT~/MR154 Submit in duplicate KUPARUK ENGINEERING Date: ~O~O~ Well Name: Transmittal Log Date Run ~,' ! DISTRIBUTION NSK Operation Blueline Dr ill ing Bluel ine Geology/L. J. Bi/Se R&D Bluel ine D&M Bluel ine S'~ ~"'~7~-~ B 1 / S E F.G. Baker Blueline G eology/Ken Film & fetus%% the attached, ..... ~ copy as r ' ' '"~'"~ ~-~* Return to: ARCO ALASKA,-' .INC:~: ATTN: Fauum ~. ~q67ql ~ ATO-1115B P.0. Box 100360 Anchorage, AK 99510 OHFinal MEMORANDUM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO'- C. V terton DA/E: May 21, 1984 THRU~ Lonnie C. Smith Commissioner FILE NO: D. 5 I. 33 TELEPHONE NO: FROM: Edgar .W. Sipple, Jr Petroleum Inspector SUBJECT: Witness BOPE test on ARCO' s 2A-6, Sec. 14, TllN,RSE,UM, Permit No. 84-64, Doyon Rig #9. Friday, May ~18, 1984: I traveled this date from ARCO's 2}I-4, p~rker Rig ~#141, to witness a BOPE test on ARCO's 2A-6, Doyon Rig #9. The drilling contractor was in the process of running casing. Saturday, May 19 1984: The BOPE test commenced at 2:00 am and was hOz{clUded at 3' '2.~ am. There were no failures. i filled out the AOGCC BOPE inspection Report which is attached to this report. In summary, I Witnessed the BOPE test on ARCO's 2A-6, Doyon Rig #9. Attachment 02-00IA(Rev. 10/79) - O&G ~4 5/s4 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Well Operator Well D ~ Location: Sec /~z T~ R~'~M Drillin~ Contractor 7_~~ Location, General o ~ General Housekeeping ~ Reserve Pit ~ Mud Systems Visual Trip Tank Pit Gauge Flow Monitor Gas Detectors Well Sign ~Rig ~p~ Audio BOPE Stack Ann.uJ~ar~P r event er Pipe Rams Blind Ram~ Choke Line _Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure i Ri~ # ? ACCUMULATOR SYSTEM Full Charge Pressure ~ ?00 Pressure After Closure / ~O Pump incr. clos. pres. 200 psig Full Charge Pressur~e_Attai~ed: N° - 2 l~gZo~ ~o LZ.,:,o 2~oo Controls: Master o/x Remote o & Rep res ent at ive Permit ~/Casing Set Representative psig psig ~ min 30 sec. ~ min ~ sec. psig Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves I~ ~'~est Pressure O~Test Pressure o~ -'~Test Pressure O~ ~/Test Pressure Ot~ Test Pressure No. flanges ~ Adjustable Chokes /- /14~ Hydrauically operated choke Test Time / hrs.-~,~ ~days an~ Repair or Replacement of failed equipment to be made within Commission ot~/~ce notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~~r / ~ay 3, 1984 Mr. Jeffrey Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re ~ Kuparuk River Unit 2A-6 ARCO Alaska, Inc. Permit No. 84-64 Sur. Loc. 597'FSL, 53'FEL, Sec. 14, T!IN, R8E, Btmho!e Loc. 1423'F~rL, ]!10'FWL, Sec. 23, TllN, RSE, Dear M~. Kewin : Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey J.s required as per 20 AAC 25.050(b)(5). If available, a tape containin~ the digitized log information shall be submitted on all logs rot copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage 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 re~lations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohib~ted by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code,. Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Jeffrey B. ~eWtn Kuparuk River Unit 2A-6 -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 before 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. Very truly yours, C. V. Chatterton 6¥ ORDER OF Tf~E CO?~q.~I~SION Chairman of Alaska Oil and Gas Conservation Co~issi~ be Enclosure cc- Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. ARCO Alaska, Inc. ~--"~ Post Office B,.~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2A-6 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2A-6, along with a $100 application fee 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 16, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. //Area ~rilling Engineer JBK/JG7/L12'tw Attachments RECEIVED APR 2 5 1984 AJaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany "-" STATE OF ALASKA ~: ALASKA b,L AND GAS CONSERVATION CO,,~MISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E](X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE []XX MULTIPLE Z~,~ [] 9 Unit or lease name Kuparuk R~ver Uni~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 597' FSL, 53' FEL, Sec.14, TllN, R8E, UM At top of proposed producing interval 1282' FNL, 1398' FWL, Sec. 23, T11N, RSE, UM At total depth 1423' FNL, 1110' FWL, Sec. 23, TllN, RSE, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 130', PAD 94' I ADL 25570 ALK 2668 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 8100' MD, 6159' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1180 feet. 21 14. Distance to nearest property or lease line miles 1110 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 48 o (see 20AAC25.035(c) (2) 10. Well number ~,~ 2A-6 -~2 ~. 11. Field and pool '~ Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15, Distance to nearest drilling or completed 2A-5 well 60' @ surface feet 18. Approximate spud date 05/16/84 2750 psig@__80° F Surface ___,~LL~___psig@ ¢,O?Sft. TD (TVD) Proposed Casing, Liner and Cementing Program si Hole i 12-1/4" 8-1/2" Casing 16" 9-5/8" Weight 65.5# 36.0# 7" 26. O# CASING AND LINER Grade I Coupling/ Length H-40 ! Wel~ 80 J-55 HFTERWBTC/ 2754 J-55 HFIERW ,,Te/ SETTING DEPTH MD TOP TVD 36' I 36' 35' I 35' I 22. Describe proposed program: I 33' I 33' MD BOTTOM TVD 1161 116' 27891 2605' I 8100~ 6159' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 590 sx Permafrost E & 250 sx Permafrost C 290 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8100' MD (6159' 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 2750 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-5 will be 60' away from 2A-6 at the surface. There are no closer wellbbres anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (Continued on next page.) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge CONDITIONS OF APPROVAL DATE Samples required Mud log required Directional Survey required APl number ~YES [~NO E]YES [2¢NO ~[YES E]NO 50- / (D J - '7-- (20 'Z. ~ Approval date /84 SEE COVER LETTER FOR OTHER REQUIREMENTS / Permit number Form 10-401 GRU7/PD2 ,COMMISSIONER by order of the Commission DATE May 3: 1994 Submit in triplicate PERMIT TO DRILL Name of Operator: Well number: 2A-6 Page Two ARCO Alaska, Inc. The well will be completed by the workover rig. It will be completed with 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 & tested upon conclusion of the job. GRU7/PD2 RECEIVED APR 2 ~ ]984 Alaska Oil & ~as Cons. Commission Anchorage ? · P=4265-- ETr-¢ NTR r _:-'f-TV D' '-7 8 5-~ (LO(~ G'-} N (~+ P T-)-='T-? D= 6:'t-59--~T MD= 8-fO0-~ ' ' : ¢ : · £' ' ' _j_' ' j~ :_ ; t ' ! ' . 4586~ J ~ ; I : 597, FSIL, 53~,F , 320.,.:.. F~L¢_, ;- .... ~psi TankCO starting head. 1. TankCO quick connect asSY. adapter. 3. 16" X 20" 2000 psi double studded ~. 20" 2000 psi drilling spool w/lO" side outletS. 5. 10" ball valves, hydraulically actuated, w/lO" ~ines to reserve pit. Valves to open autOmaticallY upon closure of annular preventer. 6. 20" tO00 psi annular preventer. ?. tO" bell n~Pple' Upon initial installation clOSe annular preventer and verify ~hat ball valves have opened properly. Close annular preventer and blOW air through d~verter fluid lines every 12 hours. CloSe annular preventer in the event that gas or detected' ) f necessary ) manually flow to surface is upwind diverter line. override and close ball valve to 16" conductor RECEIVED APR 2 5 1904 Alaska Oil & Gas Cons. Commission Anchorage 9 PIP~. P. AM~ L 8 (- DIAGRAM ~1 13-5/8" 5000 PSi RSRRA BOP STACK 1. 16"'- 2000 psi Tankco szar%ing head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacsr 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 spoo] w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rants B. 13-5/8" - 5000 psi blind rams 9. 13-5/8" -_5000 psi annular ACCUMULATOR CAPACII'Y TEST BLIND 1~ 2 i 1. CHECX AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREJ~M OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI RE)~AINING PRESsuR£. 13-5/8" BOP STACK TEST 1. FILL BOP STACX AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- S. PREDET'EIUtINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCX DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND VAL'v'~S LTP~ OF CI-IO~S. DON'~T T]3ST AC.v~IN~ CZOSF__J) CI'{)ICES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD'FOR 10 MINUTES. 5. INCRE.kSE 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 T0 3000 PSI AND HOLD FOR 10 S. ~'Pl%E$SLEU~ 00~~ OF CI-X3Kt~ ISOI~k?ION IFAL¥]~S. T0 ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTI~D MANIFOLD .VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE P~S AND CLOSE BOI'FOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOt'FOM Scl' OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND R~J~S AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P, AMS 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 COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST R ErE / VED FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCo TIONALLY OPEP~ATE BOPE DAILY. Alas~ Oil & Gas Cons. , ~ ~nomm,ss.on Anchorage ARCO Alaska, Ir'''-''' Post Offic~ Jox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 9, ]984 Hrs. Elaine Johnson State of Alaska Alaska Nil & Gas Conservation Commission 300! Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Wells 1-8 Dear Elaine' Enclosed is an as-built location If you have any questions, please Sincerely, J. Gruber Associate Engineer JG6/L85'tw Encl osure Location plat call Plat for me 2A-Pad th'e subject at 263-4944. wel 1 s. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany D.S 2-A 12 0 II 0 ~0 7 0 60 0 14 0~5 0 ZI 14__~1:3 LOCATED IN SECTIONS 13,14,23, _ T liN',. ESE. UMIAT MERIDIAN. . . ~ . - _ · _ _. _ DRIJ--L SITE 2.A CONDUCTORS .;. BUILT LOCATIONS WELL-I ¥ = 5,960,138.235 x · 498,62(3996 z Z7'FwL, 717~FSL LAW.= 70°18'0836 73' LONG= 150° OO' 4 07--II" EL: .94.3:0G=89.9 WELL-Z Y = 5,950,078.4zo X= 498,62.0.914 2Z7' FWL, 657' FSL LAT =70°18'07778g" · LONG = 150° 00'40~15' EL= 94.4, OG =89.8 WELL-3 Y :5:960, 018.185 LAT= 70018°071865" x= 498,620.91Z LON(3 '- 150e 00'40ZI3'* 2Z?'FWL, 597'FSL ' EL= 94.4: OG= 89.6 WELL-4 Y:5:959, 958.355 LAT = 70° 18' 065580'' X= 4c_-_-_-_-_-_-_-_-_~B, GZO.969 LONG: 150°00:40ZII' Z?_71FWL:537'FSL · EL=94.SlOG:90.4 WELL -5 Y=5:959:958 261 LAT = 70°1B'065965'' 498:340.910 LOJ',iB: 150° 00'48 376' 53'FEL: 537' FSiI. EL: 94.0,0G: 89.5 WELL-6 Y =5,960,018.341 LAT=70° 18' 071874' X: 498:340.956, LONG;150°O0'48376' 53'FEL, 597' FSL ; EL'-93.9, OG :89.~ WELL-7 $,9G0,07 8.~_ 81 498:340.906 53'FEL, B57'FSL LAT: ?0° 18'077769" LONG: 150'°00'4 8377" EL = 93.8, OG: 88.7 WELL-8 y :5,9 60,13 8.371 X = 498~ 340.932. 53'FEL~ 71'/' FSL LAT'- 70°18'08~ LONG: 15(7~00' 4 837 7'" EL=93.?~ OG = 87.8 DAVID LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF UNDER MY DIRECT SUPERVISION 8~ THAT ALL DETAILS ARE CORRECT AS OF ..... Al(:]---,~-c. -- ]- THI RFEY .~ ~_K_~£or,~, Project North Sl0p___e___D_rilling ~? CONDUCTOR AS- BUILT · c-:'~,~ -~ ~ LOCATIONS r~ IJ U L-: ~ fJI CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc /(2 thru 8) '(8)' (3) Aamin <~? ~%~,t, ('9 t,hru 11) (10 and 11) (12 thru 20)- ii mi 3. 4. 5. 6. 7. 8. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. (5) BOPE ~,~/f,~ ~-~Z& (21 thr~ 24) 21. 22. 23. 24. (6) Add: .~r.~ q-~L~ :f ~ 25. Company ~.~C,~ Lease & Well No. YES NO REMARKS Is the permit fee attached ........................................ ,::~.._i~X-~j. ,,, Is well to be.located in a defined pool ............................ Is well located proper distance from property line .................. [,~. _ Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this noel Is well to be deviated and is well bore plat include~ ............... ,.~ -- Is operator the only affected party ................................ .,' '~. . · ~... ~ ,,.,,~.~,~ Can. permit be approved before ten-day wait .......................... :',',:',,~ ....... ,, Does operator have a bond in force ................. L~'~ eeeeee.eeeeeeee.. ...... Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ...... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ............................ Is a diverter system required ................................... Are necessary diagrams of diverter and ;;; equipmen~ attached . Does BOPE have sufficient pressure rating - Test to · . Does the choke manifold comply w/API RP-53 (Feb.78). ' ............... Additional requirements ............................................. Additional Remarks: dZPS~_cT-PPP£o~H Geology: Engig~e~ing: HWK t~, LCS f~( ,BEW ......... JAL~_i~rM.-~ ~- .. rev: 12/08/83 6.CKLT INITIAL GEO.: UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. .o '' W ~ C 'r I"~ [Pi::C'.[ I.L.~,~.!AI., SdNVF;Y ~ KA~llh! E;D 0.00 100.00 200, O0 ~()~;,'~,., 300, O0 400,00 399.9~ 500, O0 49~. 600. 70(}.00 -3{) 17. lu9 lOOO.O0 110o.00 1200,00 1300.00 1299,'94 1400,00 1399,'14 1500,00 149h.96 1600,00 17uO.t) O i800,00 lgo0,o0 1')69 1467 lhbg l '7 5 t I)A fl;:; 27-dON-t~q 2000,00 1975.dq 2100,00 20bb,35 2200.00 2151,94 2300,00 2236.~ 2400,00 211~,u8 2500,00 2Jgb. U'l 2600.0~ 2471,29 2700,00 2543,~4 2800,00 2613,23 2900°00 2BSO,2B 19J5 2021 210b 218~ 2341 24i3 24~3 3000.00 2745,t19 2~15.Y 3100.00 2810,86 2,",~ o. ~ 3200 O0 287~,28 2 145.2 3300:00 29].,35 2~uo. 3 3400,0U 3003,20 2~ / 3.2 3500.0u 3065,B5 2'~36.q 3600,00 3130,22 3Ugt),2 3700.00 3193,29 3('),~ 3. ~ 3800.00 3250.75 3126.7 39(;0,00 33'2,),.~4 3190..l t,,19 u.b2 O, 3(') ;), 2 ,J ~,U7 O.Z4 d,b9 O,t9 0.26 I,U'I 2,19 3, 't4 .'4.91 ~,t4 1,33 ' q. O1 3,74 3,74 3.rtl 1.38 I)A'FK OF 8UP, VEX: 4-dUN-84 l-:~{t, lNhLP: !,~C BHIDE I~FC'I'Af,,GULA~ Cf3(.;F:DiNAT[<5 HORIZ, m['i~3 titS()U1. H t..A 5TI wES'r DlS~f, ~ ~.K'j' F i:.;E I FEE;T 0.00 N 0.00 h 0,00 0,19 S 0,25 E 0,32 O,lS N 1,16 E 1.17 O,uO ~'~ 2.34 E 2,47 1.3b i~. 3,25 ~; 3,b~ 1.94 ~ 3.~5 ~: 4.22 2.44 ~ 4,07 E 4.,74 2.71 ~ 3.90 E 4,75 Z.?~ N 3.42 2.lq ~ 3,11 E 3,77 1.60 t,,: 2,ub E 3,28 1.21 f< 2,74 E 3,00 1.lO ~" 0.94 E 1,45 1.~ ~ 5.17 w 5,38 O.u~ 8 17.42 W 17,42 2,~b $ 35,73 W 35,79 4.94; $ 61,29 W 61,48 12,54 $ 90 10 W 90,98 24.00 S 122~23 W 124,56 38.58 S 150,95 W 161.62 bb,5b 5 197,79 W 205,71 75.07 $ 243,82 W 255,42 99,iU $ ~91,27 W ~07,~ 124.63 $ 342,79 ~ 364,74 151,95 $ 39~,08 W ~27,U3 1~2,39 S 458.25 W 493,2! 214,1e 6 519,52 W 561,94 248.11 S 5B2,80 W 633,41 284,31S 547,55 w 707,21 320.71 8 713,55 w 782,40 35/.43 $780.23 w 858,20 J~4.58 S 847,08 w 934,47 432.10 S 914,06 w ]011,05 459 o~ ~ 981,23 ~ IOB'/,B5 501:2~ 5 1048,57 W 1164,8] b4b.i~ ~ 1110,03 W 1242,05 5~3.1~ $ 1183.70 W 1319.54 o2i.U3 5 1251.06 ~ 1~96,72 658.94 $ 131u.~7 w 1473.78 PAGE 130,00 FT · DEPAR:URE AZIMUTH DEG MIN N 0 0 E N 63 ,22 E a 71 15 E N 67 17 E N 62 Lib E N 59 2 E a 55 14 E n 50 52 E n 55 26 E N 60 42 E ~ 66 16 E h 40 23 E $ 73 56 W 6 69 47 W S 6b42 W $ 65 25 W S 62 OW 6 78 53 W 8761 ti 74 " $ 72 40 6 71 12 S 7 0 & 67 ~5 8 66 56 ,5 65 48 S 65 23 W 865 $6441 :5 64 25 :564 10 M S 63 56 S 63 4b $ 63 36 S 63 26 A1'LANT1C R iCrtVl I:'1,I) 2A-6 ~,I.IPA RUK NI~RTH ,S[,ODF., AL.,Abi, A Dt.P'i'H V El, iT 1 (:A i, [') t'< P T f~ L. I.' r,, J" b I ~ ~'..j' t; :.! I :'. DA']'K: 27-dUN-t~4 4O0O. O0 4100,00 4200.00 4300.00 4400. O0 4500,00 4600,00 4700.00 4800.00 4gUO,OU 5000,OU blO0.O0 5200.00 5300.00 5400.00 5500.00 5600,00 5700,00 580O Ou 590O:00 6O00.0O 6100 OU b200:OU b300.00 b400.O0 6500.OU 6600.0U bTU00u 6800~00 b900,O0 7000.Ou 7100.Ou '12OO.OU 7300,00 7400,0U 7500.00 7700.00 7800,00 7900,00 33H4.19 3513,19 3643.,'1 )17b,~l 3842.b4 4033. ,~ 4111..t4 41'lb 423'1199 4300. 31 4360, b~' 4420. z'l 4480.21 46()0.83 4~61,U4 4722,55 47H3,16 4~43.U3 49bU.21 $019.4q 507~,b~ 5138,14 5{96,0~ 5252,27 5311.34 5375,01 5443,55 5595.98 5~TB,bl 5764,68 5853,b9 5944.31{ 3254.19 5u 25 S 331B.4~ 49 50 ]3a3.19 .19 16 J4,{H, ~2 49 3519,75 4u 3b.$5.71 48 34 3712.u3 4U 7 3'119.,13 48 7 3H4b.~z 4'1 33 [',ATE oF SURV[',Y: 4-dUN-B4 [.,LL[,Y RU,"ihTi~,G EhKVATION{ BRIDE EVEN E V E R 'r l C A I., l) t:; ¢; b Z 1 ,," u T Id ,5 [: C '110 N ~ ,. V J:, KG '"' 11 F'F I-:"I' DF;G/ 60 6 U 6O bl bZ 02 :~b a 1821.54 U,16 63 11 ', 1899.10 3.13 bl o~9 , 1952.11 J.gl 65 19 ~ 2016,18 0.30 6b 22 ~ 2080,81 l,J3 6b 22 W 2107.17 bo 22 , 22t3.9.{ u,d8 hb 22 N 22~0.51 0.~5 60 22 ~ 23'17,0h 0,98 &h 3~ * 2~1).,18 U,lO PAGE, 2 130,00 FT DEPARTURE AZIMUTH DEC MIN 31~5.96 2. /i 320q.90 2.9H 321{).h9 3,43 t327.'11 4.53 3380.36 3.8M 34'13.~7 35.L4.'1(, 3.57 3hb3.70 3590.95 ~.04 69o.91 $ 1385.22 w 1550.66 S 63 17 W 134,73 5 1~51,~4 W 1627,17 ~ 63 9 w /'12.1b 5 1518,25 W 1'103,32 S 63 2 W ~OY.Ul S 1584,58 W 1'179,15 ~ b2 57 W ~4b,q5 S 1650.7~ W 1.854,64 S 62 52 W ~l,b4 8 17lb,b9 W 1929,85 S 62 48 W 91'1.45 S 17~2.56 ~ 2004,80 S 62 45 W 952.'11 8 184~.2b ~ 2079,37 8 62 4J W ~B'/.bl $ 1913.90 w 2153,69 8 62 42 W IU21,~O S 1979,~0 w 2227,76 S ~2 41 W ]OhO,Il fi 2034.80 W 2289,'19 8 62 42 W lOU8.Yb $ 2111.27 w 2375.56 S 62 42 W 11~2o7b ~ 21BU,20 w 245~ ~ 8 ~2 45 w 115b.4~ S 2251.02 W 2530~24 S 62 49 w ll~'l,b9 ~ 2322.32 ~ 260~i36 $ 62 54 W 1219,99 5 2395,34 w 268'7 94 S 63 I W 12~,12 $ 2542,11 ~ 2848,04 S 6] 11 ~ 131~.23 $ 2015.37 w 2927,90 $ 63 17 W 1341.83 S 2b~8.37 W 3007,32 S 63 22 W 1379.34 $ 2761.24 w 3086.59 S 63 27 W 1410.U2 $ 2~34,02 w 3165,77 ~ 63 32 W 1442,40 8 2907,03 W 3245,20 8 63 36 W 1414,04 S 29~0,b0 W 3325,11 $ ~J 41 W 1505.69 S 3054.94 ~? t405,85 fi 63 45 W lblB,I1 $ ]12~,43 w ~486,99 $ 6~ 49 { 1571.01S 3203.03 w 1567,55 ~ 63 52 W lbO3,g] 8 32'lbeb8 w 3648,09 $ b3 55 W 1uJ7,~4 $ 1349,45 ~' 3728,45 $ 63 56 W lb)3.OO 5 3422,b9 w 3809,98 8 63 5b N 1711,~Z 6 349b,26 w 3~92,U6 8 63 55 W 1.'t4u.1¢ ~. 3567.77 w 3973,29 S 63 53 W 1'1U4,89 $ 3635 86 w 4050.35 $ 63 51 w 1819.55 S 3699~88 w 4123.08 S 63 48 w 1Mbl.SU ~ 3759 03 W 4190 40 S 63 4~ w lu~1:23 s 3813~38 w 4252:16 $ 63 44 W 19O'I.lb 8 3~b3,34 W 4308,43 ~ 63 43 ~ 19~9.24 ~ 3909,16 w 4359.30 S 63 43 N 194~.13 ~ 3951,08 ~ 4404,90 $ b3 4b W 1vb8.94 $ 3991.76 ~ 444b,b3 $ 63 51 ~ PAGE, 3' KUPANtiK NORTH 5T,UPk:, AL, AL, r,p, l~A['b; UF SURVEY: 4-OUN-8~ KP:i.,LY P. U3i~TNG EL, EVA'.rl(IN) r. NG]'I~F~F.R: MC BRIDE 130,00 I~,'i'r-'FP:.ll.4T~.;i) I.'i~.I,.JF:,., l"OR EVeN 1. I;P I-'Ei<i t,[-' M[.'.ALgUJRED i)EPTH MEA,SURED VEHTICAI. VENi'ILA/ L,,t, tJVl,~.~'riL,)h; AZIMU'ftt DEPTH L)FiP'I',I '),,.,p'~ ~i I~'t.; ,'l [ ,, L)F'.G ,i I r, 8000,00 8100,00 6lit.lO 6001.10 2U 3 8200,00 b225.U~ C~()95.~)~ 20 3 8205,00 6229,74 609~,74 20 3 [, 73 46 k 3624.00 5 73 49 W 3054.'1~ 5 73 49 ~ ]085.52 5 73 a9 W 3b~7.0b 0,90 U, tJ 0 O , (.J C' r.) ;4 [-' O T A 1' .{. ~ l i,. D A 1. {"J ~ 27 - J 0 N - 84 PAGE ATL,&NTIC R {.CHV 1 t':L,{> 2A-6 K[IPARUK ,q OH'I'H ~ [,i)P{rj, DATI-: OF SURVEY{ 4-dUN-B4 KELLY BUSHING EhEVATIONC 130,00 F~ I .~"IV.c'PL)i.,,~'I'LD ~AI.,U{'.;;, I,'OR EVEN lOOU I~'F..;~'f Cji.' ~E.ASOREO DEP'I "4EAStIRED ~ERTICAI, V~LR.I ] CAL, ~,V lR']'J,()['~ .AZiMu'.rt~ DEPTH VERTICAl., DOGI,~.G RECTA~GULAg COURDINArE$ HORIZ, DEPARTURE SECTIt.~N ,5~,V~[.i/'f't NOH:IH/~OLITH EA~'.[/WES'f DIST, A~I~UTH FFkT l.)gG/100 FEET VEE'f FEET lO00,OO 999, U'I Uog, ~'t O 34 2000,00 1975,ou za45,a9 3000,00 2745,U~ 261b.a9 49 16 4000.00 338,~,1u 37'.)4, 19 50 50OO,OO 4033,4~ 3903.4b 47 33 bOuO,Ou 46bl,b4 4531.6q 52 7000,OO 5252,ZI b122,27 5b 17 8000.00 603 ~. 1(, 5907. 8205,00 5229. /4 609~,'~q 20 .'{ 5 22 1o ~ -2,69 $ 6b ~ W 147,87 &; 61 12 W b47,12 ~; 60 38 w 12,i3.1/, 8 hZ 56 w 1821,54 ~ 62 ~1 ~ ~145.96 ~ 73 46 k 3624,C0 B 73 49 W 3667,(,,5 0,00 0,19 'i., 6 l o,'t9 0,16 O. 32 2, / 1 3,89 0 ,'UO O.ou N 0,00 E 0,00 N 0 0 E 2,14 ~ J.ll g 3,77 N 55 2~ E ~8.5s $ 15b,95 w 161,62 S 76 11 W 32U,71 5 713,b5 w 782,40 8 65 4{ M 09u,91 $ 13Bb,22 W 1550,66 S 63 17 W lObO 11 S 20J4 80 W 2289,79 S b2 42 W ) 13'/9~34 $ 2761:24 w 3086,59 S 63 27 W 1'111,42 $ 3~gU.2b W 3892,6b $ 63 55 W 1969,bl S 4027.20 W 4483,04 $ 63 56 W 1989.36 $ 4094,'11 W 4~5Z,~8 ~ b4 5 W ,) C!~K['uTA]'J.L)I~ DJ' fF:: 27-dtJN-B4 PAGE ATL, AN'r 1C p ].CiIF lt"'bl) 2A-6 KU[.,'ARUK hORTH $1~OPk;, AL, A;'>k3 OF' ~URVE¥I 4-dUN-B4 BUSHING EbEVATiONI kiNGII~Ek.R: MC BRIDE 130,00 F,T t'~.~ih'gPL)L, ATLI:' V~L,i.it,.L-, FOR ~Vi<N lot.) F,:;5'I (il"' ~LJF.~, %' 'J'R O F: F, :,.t ~i- S .,~ C! VERTICAl, D~iCiI,I<G t~ECTANt~ULAi~ CC)UROINATES HOR[~ FI-' b:'l t~F,(~I I 0() FE~:T FEET FEET DEPARTURE 0.00 U,O(, -'130.(,t, 0 0 f, 0 0 [< 13.85 31).U(, -IOO.Uu O 17 S 5'1 6 E 130,00 13u.uL' c.,)(, 0 () :; 1332 E 230.00 2,]O.OU IuO.UU o 34 N 7b 34 E 330.Ol ]JO.O0 ~tjt~et}l~ U J~ b,' b() 44 ~. 4J0,02 43U.UO ]O0.()u 0 34 r., 59 35 E 530,02 530,0~ 40n.,'~t, 0 34 ~,; 44 bb E 630,(021 6]U.UO 5'jU,VU 0 34 N 3313 ~' 730, 3 73U.U~ bv~.'"(, 0 r) S h5 49 ~ 830,03 ~3(),o0 IO0,U() O 34 N 6o 49 W 0.0o 0.00 o. OO N 0.00 E 0,00 33,38 O,OO ~ 0.00 E -o.04 0.32 0.09 S 0.02 g -0.49 U.b4 O,ib S 0,47 E -1.43 U.15 0,33 N [,5! F' -2,4b O,jO 0.91N 2.b7 E -3.]3 0.32 1.53 N 3,45 E -3,44 0,04 2,11 N ~,87 E -3.5E O,4n 2.b3 ;~ 4,08 E -J,21 0,22 2,7~ h 3,'15 E 0.00 N 0 0 E 0,00 N 90 0 E 0.10 $ 12 0 g 0,49 ~ 7116 E 1.54 N 77 47 E I'8' . ?o 2 ) ,77 N 66 2 E ' 4,41 N ~1 19 E 4,80 N 58 13 g 4,67 N 53 27 E 034 S J{u 40 k, L) 34 S 2552 ~' O u $ U 10 w u ']4 ~ 7421 ~ 2 42 ri 8,t JO w 1430 43 14]O,uu j[39(',:.rl~k, (, 17 S ~449 ~' 1531:45 153U.00 140O.r)O 951 S 82 b2 w 1633,73 lb30.O~' 1500,,~,~ 14 6 5 ~4 31 ~ 1737.81 1730,00 160().OU 171]. S 75 22 ~ -2.80 O,3~ 2.b4 h 3,30 '2,b3 0.2~ 1.94 ~. 3,01 -2.5~ 0.22 1,50 ~ 2,84 -2.26 1.46 1.09 N 2.49 0,4'I 3,18 1.22 N O 26 ~.41 3.~7 1,34 Il 8~30 21.94 3,91 Up'l'l $ 22,42 4~.49 4,1,1 2.7b $ 43.64 bg.gB 4 23 N 51 24 E, 3:58 N 57 15 E 3,22 N 62 5 E 2,72 N 66 18 E 1,25 N 12 13 W 8,41 N80 48 W 22.43 5 66 I W 43 ,72 $ 86 22 W b,bl $ 72,05 W 72,27 S 6532 # 17.lb $ 103.50 W 104.91 $ 8035 W 1950.13 19]b.O0 I "..l 0 t). u {/22 2060.00 2030.00 1900.()0 2'1 11 21'14,47 21 ]O.OU 2ouO.(;O '{0 20 2291,77 2230.00 21OO,Ou 32 b5 2414,23 2316,0{, 2'2 UP. L"U 3'1 27 2544,1b 243U.U¢~ 2JU('), O0 41 30 26H0.87 253u.u() ?.-I Vt,. ~,u 44 2824075 2b3O,UO 2500,00 4'I 25 2975.71 2730.00 2bor). ()O 49 l~. 3129,6B 2830,00 2'lUl,. Ou 4~ bO ,':;; 07 H w L]1.61 4.07 S bO lb w 169.32 4.b3 ,5 6025 ~ 216.11 2,53 .% b2 bb W 266,U4 3.46 F, 64 4 ~, 322.Rq 3.'97 S h2 bO w 3~9.71. Z.~8 & oU JiB ~' 5.t4,91 1.05 $Kl 12 * 632.gl U.30 ~ '~1 12 w 723.94 0,35 30.74 $ 139.06 w 142,42 S 7732 W 49.138 1B0,59 w 167,16 ~ 74 46 w 70.70 S 231,91W 242,45 $ 73 2 W 9'l,Ob S 267.26 W 303e21 $ 7119 W 12~.44 S 350,b2 W 373,31 S 69 52 W lhb.09 S 424.BB w 455,83 & 68 45 20B.u~ S b07.58 w 548.$B S 6742 311.85 S 697.5b w 764,09 $ 65 54 W 5b~.40 S UOOe07 w 880.U1 $ ~5 lb W 3285.40 2930,00 2Hu().OU %u 25 3442,02 3030.0o 2'~0(~.o(, 50 25 3599,6~ 31.30,00 31)O(). (,0 50 b9 3757,0U 3230,00 jl u(;.,.~[, 50 25 3915,1~ 3330.00 32uO.ou 50 4071.38 3430,00 4225.83 353U,V0 4378.89 3630.0o 35uo.()0 ,'tS 4~ 4530,6B 3730.00 4681,21 3830.u(') .]7o(,. 9{; 4B '7 0 , 2 t' 0.36 O. lt~ 0,'~3 4~b.47 S 1009,48 w 1120,15 S64 19 W b44.9~ S 1115,79 w 1241,78 $ 63 56 W 6nb.uU S 1222.72 W 1364.25 $ 6340 w ,~.~./! $ lj28,46 w 1485,48 ~ ~{ Z5 w 7~.95 $ 1432,82 w 16o5,32 s 6~ ~! w 7~1.72 ~ 19Jb,J7 w 1722,92 ~ ~{ i w ~.17.;9 s 1636.78 w 1838.74 $ 62 53 W ~92.u! 5 1736,91 w 1952,88 ~ ~2 47 w 94b.lb ~ 1~3b.91 W 2065,38 $ 6244 W C(~it!~JTA'I' 1(11, DAIE: 27 - d u N -. B 4 DEPTtt 4830,67 4979,02 5128,69 5287,2] 5448,55 5616,28 5782.97 5947,98 ~112.2] b278,07 6448.14 b617.R9 6786.22 69b0,33 7130,07 7280.8~ 7416.42 7541.70 7660,1'1 7773.69 7884.]3 7992,37 8098.83 8205.00 'l' t,' d Fi .]930. 4 t 30. 42]0,00 4330, ur) 4430.00 4b3O.OI' /3, '7 '{ L). 4~ Jr), OU 4930. 513C', 52 ] (';. O 543k).00 5630.u~ 57J0,00 5930. 6030,0O fil 6229. /'~ J.'ii'l"l~Pui,a'l'i..;."'~ 't/AI,L)I':6 t,'OR EVEN I00 ,.ti.f,. k' F:l.,:'r D i,.:f; / 4'1 ..~.~ :; 62 21 W 1'1.]~,32 47 3t :3 62 b6 W 1818.53 49 35 ,q 63 30 w 1007. 52 ,If) C, 60 22 W 2112.8t) bJ 17 $ ~b 22 W 2224,79 53 15 [~ 66 2~ w 2335,'13 52 q2 S bb 22 W 2445,3~) 52 42 5 b~ 2 ~ ~ 2554.1, 53 17 ~{ 6b bb w 2bo~.6f) 54 25 S bO 22 w 27/9.~31 5.{ 51 $ 65 47 ~ 289].5~ 56 ~ [~ 62 56 ~ 3119.9l 45 2~ $ 61 Ih w 3317.1~ .3~I .t9 ~ 02 3g ~' 3447.7:) 30 8 S b~ 18 ~ 349~.7~ 20 2o S 69 bt) ~ 2,t 7 S 72 40 h 35~5.27 2t) 20 S 73 32 W 3621.78 2U 3 S 7J ~9 W 55~7.05 v I< t.( i.'.l CA 3900.0 40 (J 0.0 4100,0 42 '..) 0. ~) 4JOr~, ~ 4 '10 (~, O 5000,0 5 ! (30.0 52U(~. 0 540O. 0 5500,0 b '1 u (.). ~) 5800. t~ 5900, {; 0(3 df), 0 o 099. 'l tJl" PAGE [.)A't'I,; OF ,SUI~VE~I 4-dUN-B4 t<i<[.,[.,Y BUSHING E;bEVATIUN: 130,OO [~NGI. Nk:E~; MC BRIDE DF]PI'H R l']."i N tJ~'l'It/ 1 t~ (') ["IE F; 0,(,,8 99B. U,$4 1048, 2.~0 1098. 0,27 1151. 2.95 1202 0,1~ 125'1~ 0,80 1JlO, U,13 1362. 0.~1 1414. O,~U l~h'l. l.U4 1521, 0.20 lb7b. 1,1.t lOJ3, 1.24 169o, 3,lb 1759, '1.o0 1813. J,~5 1856, 3,d(.) 1U92. 4.41, 1920. 3.12' 1942. 3,21 1.957. 3,9B 19h~, O.O0 1979. O,OO 1989. GUI,AR COORDINATES HORIZ, 5OtJTtt 6A~T/WEST DIST, FEET FEET 18 $ 1934,04 W 2176,43 39 8 2U31,44 W 2286,02 73 S 2130,75 W 2397,35 30 5 2241,96 W 2520,30 ')8 .q 2357,51 W 2646,70 17 5 24B0.79 w 2781,15 77 S 2~02,89 , 2914.30 9~ S 272],34 w 3045 36 Ob ~{ ~042.94 ~ 3175:47 09 $ 296~,39 W 3307,56 13 S 3090,91 W 3444,93 91 S 3216,22 w 3582,00 Ob $ 3339.42 W 3717,34 26 S 3467.13 W 3859,83 72 S 3588,64 W 3996,87 Ob S 308,,04 W 4!09,60 ~2 S 316B.30 W4200,93 51 $ 3834,68 W 4276,25 9'1 $ 3891,41 W 4339,7~ 18 $ 3940,72 W 4393,33 02 [~ 3985,66 ~ 4440,20 Ob ~ 4024,68 W 21S 4059,74 W 4516,51 36 ~ 4094,7t ~ 4552,38 DEPARTURE AZIMUTH DEG MIN $ 62 42 S 62 42 $ 62 43 $ 62 49 $ 62 57 563 16 w $ 63 24 S 63 32 & 63 40 8 63 47 S63 6 63 56 S 63 55 6635 $ 63 49 S 43 ~ 6~ 45 W S 63 50 S 6] 56 W 564 564 Ct~t.~l-'tJ'r AT 1 {)N l) A'i' [':: ATLANTIC R1CHFIF:UI> 2A-6 KUPAEUK NARKF't{ PB TOTAl, DEP'I'~ ;.~ ;'.; [~ S I,l F~, [., [>, D E P T ii T V O b'LL, UW F,D ~'~RLi~ Kit ,SU 784U.UO b889.7 .{ 5759,7] 7~7{i. U0 5!)24.?.2 5'794.22 7t~9].UO b93b,65 5806,b5 B050.{)~' bud4,13 5954.13 [~124,0{) blS],6b ~023.05 [~205, O() 622g,7 .t b099,74 PAGE DATE UF SURVEY: 4-JUN-84 KELLY BUSHING EbEVATION: 130.0o FT, Id~(;iaF. t',R: MC BRIDE S[JRf'ACE LOCATION AT ORIGIN= 53 FEL 597 FSh 1951,4B 1956.24 1959,55 1974,55 1981,62 1989,3b 3967 95 W .~991 W 4043 67 W 4068 03 ~ 4094 ? 1 W DATE (.IF SUNVE¥: 4-dUN-U4 KEbI,¥ RUSHING EbEVATION~ 130.00 ~NGI'NEERI ~C BRIDE DEPTH TVD TOP UPPER SAND BASE UPPER TOP bOWER BASF Lt)WER SAND PB TUTA[, DEPI'H TOTAL, DEPTH 7840,Ut} 5889.73 5759. 13 'IB'I~i. Ou 5924.22 579,1.22 '!~93. UO 593b. bb 5~00, ~5 ~050.()~ 60~4.1J 5954.13 8124,00 b153.65 6U2~ 05 ~205.0(') b2~g.74 b099~ SUHf'ACE bOCATION AT ORIGIN: 53 FEL 597 SEC 4 T N R SE. UM ~AH INA?~S NO.rS/SOUTH 1956 24 $ 98 1959:55 ~ 3991 1974,55 $ 4043 1981,62 $ 4068 1989,36 S 4094 6'/ ~ mil iIg&: [:-1 J , "I'~FK HE~DER ** EPVTC~i ~A~E ATE ;B4/0.~/31 APL k~M~ :q257 ONTINI.~ATION ~ 'RMV 7OI,S T~PF 'O~NFNTS :[,,IBR~RY TAPE ** RE(:O. D TYPF 137 ** * FT[,,F I.~EADER ** E~vTc~ MA~E ~AX]',M~ LENGTH ~ 1024 'ILE TYPm : *' INFOR~ATION RECORDS o 000 o:o:o 0'0:~ 000 O0 0 0 0~0 88oo ooo oo~ 000 006 000 000 004 O65 VP oln,HO~ VE~IFICA~lnN LTSmI"G PAGE 2 5CHE, U~BER~E~ ~GA$~A Cn~PUTING CENTER OWP~NY = ~?L~TIC ~ICHF~LD CONP~hY ELL = 2~-6 IFLP = KIIPARUK OUN?Y = NORTH SLOPE BOROUGH TATF = AZ,,ASF~ OB Nb~S~R ~T ~CC~ 6O257 A$I~'G = 9 6~5" ~ 2850' -~IT STZE = 8,50" ?0 YPE F[.,U~D = ~I~H?ED POLY'~ER E~$~TY = 10,2 LB/G ~ = ] 600 ~ 68,0 DP ISCOS~TY = 3~ 0 $ R~F = 3!120 ~ ~.~ O'~ ~LUI~ ~,,0~5 = 5,6 C~ ~ IT BRT * nUgI,., I~:*DUCTInN SP~tMRICg~Ij[,¥ FOCItSED bOG {DIL) * I 1 ~ 4 7'3: 6'0 9 4 65 0 I 66 0 hOG TYP~ CLASS IU:OD NO L~VEL vT 0 0 0 0 0 4 0 ~H~ 7 0 0 0 0 nf,~u~' 7 OH~ 7 0 0 0 0 4 0 ~ 7 1 0 0 0 4 0 ! CAPI 7 CA¢I ~23 1 32 0 0 4 0 ! TN 42 2~ 3 0 0 4 0 I C/C3 42 C/C3 a2 4~ 1 0 0 4 0 1 42 0 0 0 0 4 0 PC CPS 42 34 92 0 0 4 0 6'$ 88 -14 0078 ~On. r~OoO -14.75o0 ?. 3555 j r:, T 740 lob ~: 2 3,4 g 3 0 6,30 47 r l., n. 84,,5000 GR O, 0264 N~,~T 1., 8936 TLD 117.25n0 ca 0 064(i) .~, 7 4 7 ~ .nono 2.~8~7 T[,B 1.25.0~95 CR 0.0376 ~'RAT 1753.0000 ~CNL 2,5566 T[~D 22~.3750 Ok 0 0073 ~I,R~T 1.792:000() ~(:)')l.., -o99.2500 3.64 ? 6, 1' L B ? 41 .7500 CR - a '9 q, ? 5 o 6, F" C N I, 0 4, 0 2,4453 -qgg. 2500 ggg,2500 3,3652 2],5156 !.1~,4'824 ,1250 2,~551 1.1,1.1875 3,4395 494,0000 . 7383 8 ,5000 500 (1 6 al41 ,..7051 8 7 1:' 0 0 0 0 1,,4971 3.6699 417,7500 2.4121 125,0625 3.703l 434,0000 !.8955 729.~750 3,671.9 42~.5000 4,0781 245,0000 -g99.7500 -~99.7500 3.50~0 141.7500 I L ~'~ CALl RN R~ CaLl CALl RNRA CALI IhN CAI: I. ~NP~A I [J IU CAI.. 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' .... .71~8 6~00.0000 SFt, U -2~,7500 ' -32 . ~.31 3 ln~, -ag9 2500 D ~ ~,:..:) ;PT 6600 ~ 00 ,'..'} SF'I,L} ' -2~179a9 lfli.~ -999.9500 ~HI -a9~,2500 , -27.5000 b4OO.P()O0 SF1,U -3o.7~1 3 aR ',PT ~300. aUO0 a.. 4, 7 ? 7 110.9375 -~90,25oo $. 6602 -qg~. ~5('.~0 FCNL ~ 5 ] ~ TLD . ~.,.. ~,. 100,2500 -q99,2~00 ~.TR AT -ggg ~ ~500 FCP!b 1 05,06~5 -Ogq 2500 ~,~AI, -. 3 5'1 [~ 1 TbP ~o7' ~ 75°o -q99,250o NRAT -~9~. ~500 FCNb 1 I q , 625o -099. ~500 NRAT -~9~. 2500 ~,04.12SO 999 9~ ..... ~ 00 C i~9o: ~5oo 3 26~ ~ -09~,~500 -999,~500 FC~L 3.7949 TLD 7~.~500 -g90.2500 -999.2500 3,4961 7 {~. 750 9 -99o. 25o0 ~CNI, ~.g352 100.3175 4.07 n 3 I b" [~ ~375 CALI -99 r"O ' '~gg, 2500 5,~031 000 C~t,I -g99,~500 RNRA 500 3,6~55 TL~ I 00, ~ 500 C A b I -999,'2500 -egg ~,~500 ~ 05, O0 PNRA -99g. 3.5410 t07.7500 -999.2500 ~NgA -09~.2500 4,0078 Ib~ -999,2500 CAI, I -~90.2500 ~NRA -990,2500 3.~648 -999. 500 CALl -99q,~500 -999. 500 3,5977 TI,dP '999,~500 CAI.I -e99, 5aO -~99,2500 3. 2227 -q9q,250~q -a99,2500 4.1250 12, t250 -g99.2500 5,4531 11.g453 -ggg*2500 402 o 4,2891 2500 3 5547 -99 ,2500 ,3359 1 ,2109 -999,2500 3, '999,~ O0 -999,2 O0 3 5332 -9991250o '999,~500 3,5176 '999,~500 -999,2500 1.2695 g99,25nO :g99,2500 3 30n8 -999!2500 -ggg ~500 ' H l" - ¢ 9 O, ') 50 () ),! C ''''? L : P T 6000.0000 S ~" b U )HI -~9o,750{) ;r,'T 560n,,no00 ' -'1 g. 78 ! ,:.{ C .R 5qUO. nC, nO ~F'T -16.5625 -~9o.75o0 -o90.75n0 . o 9 ~. P 5 n 0 ~ C N b 9:9 ,; 25:0 3.5 938 T t:~ D I 2?, 5695 CR - g99 · 2500 ~'!,g A T -q90,2500 .9580 7bD 122.6250 ,2500 t~.; R a']'' -oga. 750.. 0 1 0 K. 5000 C R -99q.250n -09o.2500 F'C I,~ l... i?...421.9 93.06P5 -99o,7500 -ogq. 2500 ?.96P7 TLn !l.n 3125 cg -09q1250,:) s:RAT -qgo.25no ~C~I ! OP, 7500 CR -999.2500 -o99.~5~0 -999,P500 -qgq.2500 4.0039 -999~25:00 '999~500 -999~500 -99g ~500 -9:9'9 -099 3'6133 '99g'~500 '999.~590 '999.2500 4,,,4:1~0 '99~,~500 -99.2500 -~9g,2500 ~o~074 -099.2500 -999 2500 -o99[7500 2 ()72~ -999:2500 -g99.2500 ~.54~8 -n99.2500 -999.~§00 -~99.7500 3.t4~5 -ogO,?sno -o9a.75oo CALl R N ~ A CALI PaRA CA 1, :1 I b~.~: CA I., l: CALl: PNRA RN~A DNRA CALl (T A [, I 3,6:03::5 -999':2:5:00 3,9668 - g99 :' 5::0::0 -999 500 -999,a500 2,5:625 -g99,2500 'g99.2500 . 4.3398 999.~500 -999,~500 2.~996 -.99g, 500 '99g,~500 ~.0508 ~999,2500 999.~500 ~ 60?4 -999:~500 -99g.~500 ?.0820 'g9g,2500 3.3262 -~9~.25n0 D q' 4 I00, Ot.)nO 20.5O00 egg. 2500 ~C~b -990 7500 3.n2!5 TLD 111.25O0 GR -09q,25nO ~"~ R ,~, T ,,,O90. 2500 ~CNi, . -999.~500 NRAT -a9a . 2500 5008 ~1 ~8~5 GR -999.'2500 ~"R~T 'g90'2500 FCNL 2,7930 111,, 2500 -~gg, 2500 -egg. 2500 ~'CNL ? 9473 ILn , ,,.7500 -99 ~ 2500 ~'RAT .g9a' ~50g FCNL, 3.t8t6 ,7 ~. 250 -ggg'2500 MR,~T -ggq. ~500 FCNL 3.5508 80.0625 -090.2500 -ugo.~500 FC~L 3 1'177 -099 2500 ~R~T -O90 ~ PSO(.) FCNL 3.3262 97 75n0 -o9o.250o ~ 0840 TL, 9 -agg.25no NR~T ~,1250 TL, n -a99,2500 -990.2sno 3,1953 -999 ;~500 -q9q ~" ,2 ,~ ( 0 '099,~500 ,-999 -999 5O0 - O., 500 -g99 ~500 "99 -090 .~500 -99~,~500 -~90,~500 -999, 500 -999, ~500 .. , 00 3 ~656 -999: 500 -~90,~500 -999,~500 ~.4785 -999.~500 -q99.~500 -099.~500 -999.2500 -o99,9500 3 1758 -09q~2500 -Ogg, 25n0 3,4531 C.A [, I [.~ N~ A C A I,. I CALl ~N'~A C A L I ~,NRA CALl R.f~RA ~AI, I C~bI CALl RNRA CA{,I R~JRA T b ~ CALl T -999.2500 3,1348 '999,2:500 2':5::00 ~g99, 10 '999, '999, 'g99' '999,2500 'g99,~500 ~999,2500 999 ' ~$00 3.7'148 '999,2500 -099,2500 -999 -99q: 2500 3,3008 -q99,2500 -999.~500 3,0586 '999.2500 -999.2500 3,2930 -25. PSnO -090,2500 -999,'~500 3~00 -999.~5n0 25,n156 3600.000o -99g.~500 ~00, O00O ~2q. ~750 -099,2500 3400 0000 -090,250t) -09o.2b00 3~00.o000 - o 9 0. P 5 n o 3200.0000 -2O.PO]l -99n - o 9 o ~ 25 n 0 90,56,25 -990,2500 .N'RAT -Og9 PSO0 ~RAT -090 ~ 2500 FCNL -9~0.2500 PC~L 3.4043 lLn 94.5~25 -q9o, 95n0 3. R457 TLD -g99,~500 3.7891 100, t 875 - o g g. 25 n 0 ~, ~ 602 95,5000 GR -~9o. ~5o0 ~CNL 4.01t7 1, 0.1.. 5 0 0 0 C R -99o 2500 t:~RA T -09g'~500 VCr, I I., m . ~ On, 6250 -qgo.25nt) -99~,250~ ~.1641, -~O~. 2509 R.32~1 'l ?, 8125 -o9g 2500 -~99!2500 -~99 2500 3.5175 -q99,~§00 -~99,~500 -q99.~500 4, 0859 -g 25O§ -9 250 -°99 2500 4,0859 '999,~500 '999,2500 'g99.~5~0 4.5391 "999,~500 4,5000 '~99,~500 -999.~500 -999.2500 7,0430 o .2500 -~99.2500 4,6094' -g99.2500 ~o99,~500 qgq.?500 5.3945 -99~,2500 -099,2500 -ggg,~500 6.0547 -099.7500 -999,7500 -qgg.2500 -999,7500 -o9~.75~9 CALl ! L M CA t, .[ RNRA AI~, I ,NPA RN~A CALI ~NRA flLI ~NI~A CALI RNmA T t,~ OAL~ R N ~ A CALl I ~., ~'~ C~,I.,I -gg9 2500 -999:25o0 ] 37. · ,999 2500 3,89,45 -ggg, ~'~o 0 -999,2500 q99, '"00 -.999.25:00 4,!.602 -999. 4,]125 ~999. ~00 '999.~00 6.7344 -99~,250'0 ,2500 4,2969 'g9g,2500 '999,~500 4,8672 '099,~500 'ggg, 500 5,6172 '09q.2500 '999,~500 ao3906 -999'2500 -999,9500 m~.'.l",'~ [I i, i i i 1 ,I:4 ii; [q~ 2500 ~' R ~ T TYPE 137 ** ** PECFiRD TYPF: 1.37 ** 5 :. O: ;] 1 :t I: .'999 5 O0 A -99~ 5 0 ,) R'NR 6 9922 -999 :500 -gg~ 500 9g :~500 -999 O0 CAlX ~999 90 ~ M:~ A -999 uO - 999, ~500 L""~ ~ l I l i il i].:,.] i[4 [:]j --? -- i'.,- :. VER[F'ICATT('J~ LIST · u 0:1 j Fi ?J * * , E: C U P, T Y .f? F, 1 37 O00 t)O0 000 o 0 000 0 0 0 CATE 000 000 goo 0 O0 OOU 000 uO0 0 O t) u!ri, 0o4 002 002 t' 06 ,.~ ,,,,, ,,.. ,~, 065 06b 065 065 $ C f] 81 i,' Y U i r) ' q" = 9,5 k a'C : 2,140 ~ 68.0 DV = b,o C3 ka AT ttH'~fJ = 1,800 (a lq3.0 0[" r'~UAL ]'NDUCTZr~;,~ SPHERTC.AI.~,Y ~OCUSEi.) LOG FL.JR:fi.A]:~IU~,: [):~}."~i[5].:'i'~ C(~'~}'~E:~."~SATED LOG (FDN] UNIT APl A?'I APl ~pT F:t.L,E S.'[Z~: PROCEBS SA~:[:'I.~E ~EPR P 01. 0. ~,{ 0 P V.E P ,[ I;' 1 C A ? I 0 :\f [., I S T I t,! G P A G E 4 PT [)b H I .PT ;P ! 'H1 :PT 'H I ;PT ~06 ;P'i .' lO b ~HI 10 B ~P T .jOb OOnO 2'1 I b t.! C N 1',., 7 850. 0000 SFLiJ -14.75o0 GR 2.355 ~) L') R F! {3 4,3. 247 t NCNb 7700. 0000 - 21.500 {; 2.3281. 44.433o 7600.000U SFI,U -17.25n() GM 2.2b95 DRHC. 4:4,1406 ',ICNL 7500. nuo0 SF'[.,U - 25.2 b 0 u G R -q99,750~i I'!CN b 74u0. nO()u -ggg. PbnL:, - q 9 9.2 5 o 0 ~xi C ~.:' 1.., 42 34. 93 u 6.3 u 47 I i., D Fi 4 ' %000 G R 0.0264 N R A T 277F{*0000 FCNL , . .) 55 T L D '11 , 5525 fir 0. 0303 N'R~T 2704, ¢)OOu F'CNb 1, , 8936 I: .6 D 17.2500 GR 0,0040 ~; t,{AT 7.0000 F C N b '2.,. 888 '7 ! b D 1.25.0u~5 GR 0,037 b N R A T 1753,0000 FC.qh 2.5566 229. 3750 O. 0073 .NRAT 1792,0u00 FCNb 7.343H 245.no0t~ -99q.2500 NRAT -999.250U 3.6420 IL.r) 141 .7500 GR - 99 q. P 50 ti t,i iq A -09g. 2500 0 4 0 2.44.53 -999,2500 -c~99'2500 -999. 2500 3,3Ooz 2 3.51 5 6 1. 16.1250 2,455I 111,1875 3.4395 494.,000~ 4.7383 84,5O00 2,843"/ 751.5000 6.9141 '11. 5625 2.705i 871,000 o 1,4971 117'.2500 3.6699 417,7500 2.412i 125.0o25 3,703i 434,0000 1,8955 229.3750 3.6'719 42R.5000 4.0'781 245. 0000 -999. 250O -999. 250t) 3,5U2t) 141 .7500 -999. 2500 -999. 250() R N .R A CAi., R 14 R CALl RNRA C' A l., i R N R A I lJ M CAbi RNRA I C t~. I., i R N R A I L, N C A L I R,~iRA I b M CAI, i R H R A I 6N CAI,I RItRA I b h! CALl R [~ R A 1, o 8 4.0898 -999,2500 -999.2500 4.089~ 8'632S 3.8027 2.50 7 ~ 9 0525 3.6113 5,0000 9.3359 3.0313 5,6992 g. 3,1035 1,571.3 10'3281 4,1797 2.5156 10,3359 4.0391 1.9375 i0.1562 4.1797 4,0391 10.3510 -99g,25oo 3,6309 I1.9062 -999,2500 'JPT' ,¢'~. 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'75 O 0 ,2500 .25OO ,2500 .2500 007 8 250u 250 0 2500 .4648 .2500 .2500 .2500 .597'1 .2500 .250v .25 c) 0 .1 '77 'I · 2500 .250U .250o .2227 .25(,)U ,2500 C A L I R ~4R ~ R~RA I b M C .a L I ,1, b C A I,, I R )~ R A I' b N' C..A I,, 1 RrtRA I b M C A L I R :',i R A CALl R ~,iRA C A L I CaLl Ri'~RA C A I,-[ R ~ R a I CAI,~ R N R A 4,12,~0 12 1 ..... . z vO -q99. 250{.) 5,4531 ] .I_. 9453 -999. 2500 3.7402 1,2,~75u - q 99. 500 4.289i 12. 1484 - ~ '99.250 t) 3.5547 12.476~ -q99.2500 3. 3359 1.3,2109 -999,2500 3.97 g 5 -999. 2500 -999,2500 3. 5332 -999. 2500 -999. 250U 3.5176 -999.250U -999.250U 3.2095 -999.250U -999.2bOU 3.300~ -999,2500 -999.2500 P 010 b;09 vE,~),IFJC.~[?i(It'~ bI'j, TING PAGE 6 PT OB H I 'H I ;P T ! I 0 B ;PT > H ,.:PT i 0 b <P T 5P1' - 33 . 0025 G' "'"'a 5700.0000 SFT,ij -999.2500 r)R}~[3 -og~-. 25C'u f\!CN b 560.0, -18.'7U13 - 999 - g 99 -16...ho2b -999.2500 ,5 ;? 00. (~ 00 ,J S F .[. d 2. 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NRA -999.250~} 4.41.89 Ih'~l =999. 2500 CALl -999. 2500 RNRA -999. 250u 2.1,075 -999. 2500 CaLl -999.2500 -999. 2500 2,0723 Ib~ -999,250u CALl -999.2500 RNRA -999.2500 2.5488 1LM -999.2500 CAL.I -999.2500 Ri~RA -~99.250,) 3.1465 II~ -999.2500 C~L.( -999.2500 Ri',~RA -999.250U :3.36 :l. 3 I b ~'~ -099.2500 CALL 3 6035 -999' .250O -9c9. 9 · 250O 3,9668 -999,2500 ( 4.121i, -999.2500 -999.2500 3.5879 "'' 2500 -,999.~500 2.5625 -999.2500 -999.250o 4.3398 -9~9,2500 -999.2500 2.0996 -999,25o0 -999,2500 2,0508 -999.2500 -999.2500 2.6074 -999.2500 -999.2500 3,0820 -999.2500 -999.2500 3.3262 -999.2500 P T Ob H 1 ,p' . {? b :PT ~lq '1' i P 1' .TPT ;HI -19, (.t 150 GR -~ga, 2500 DR!4 - 999, ? b (3 t; !~I C N b 4 700,0 ~ o 0 -999,250o -999,250u q, 6~(), Ou 0 ~ . 2n . 2650 - 999,2bO[~ -999,2~09 4 $ g O, 0 <) 0 ,,) -099,'>b00 - 999,2 b 0 c 4300. 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'132g -qgg 2500 RECORD tYPE 137 RECURD TYPF i. 3'1' ** I I :
