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201-169
RECEIVED STATE OF ALASKA • AUG 3 12017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANE CC la.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned ❑ - Suspended lb.Well Class: 20Awc 25.105 20AAc 25.110 Development 0• Exploratory ❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: -4/'5t_a/312047_ 201-169 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 8/27/2001 50-103-20388-00• 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 394'FNL,94'FEL,Sec 11,T10N, R8E,UM 9/10/2001 KRU 2K-27 • Top of Productive Interval: 9. Ref Elevations: KB:25.8 17. Field/Pool(s): 1754'FNL,429'FWL,Sec 10,T10N, R8E, UM GL: BF: Kuparuk River Field/Kuparuk River Oil Pc • Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 1766'FNL,2'FWL,Sec 10,T10, R8E, UM Surface ADL 25589 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 498311 y- 5937910 Zone- 4 14037/7357 ALK 2676 TPI: x- 488275 y- 5936559 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 487848 y- 5936548 Zone- 4 1513/1488 5.Directional or Inclination Survey: Yes ❑ (attached) No E] 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL)I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary SCANNED JAN 1 8 2018 N/A 23. CASING, LINER AND CEMENTING RECORD * WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.6 H-40 31 150 31 150 24 5.5 sx High Early 7.625 29.7 L-80 31 6776 31 3820 9.875 113 sx AS Lite,270 sx AS Lite, 600 sx Class G w/GasBlok 5.5 x 3.5 15.5 L-80 28 13988 28 7309 6.75 390 sx Class G 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 3 1/2 12,582 N/A ALL PERFORATIONS PLUGGED OFF 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes El No (] A ' 'D Per 20 AAC 25.283(i)(2)attach electronic and printed information t r DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED q- i IP' Plug 1 Tubing 12624'-11733'RKB 3.5bbls 15.8ppg Class G ( r (tagged) Plug 2 Tubing:11710'-1324'RKB 200 bbls 15.8ppg Class G - k' (tagged),IA 11,710'-2,000'(estimated) Plug 3 Tubing IA,OA 1265';RKB to 95 bbls 15.7ppg"A-1" surface Top Off Job 0.7 bbls 15.7 ppg"A-1"in tubing 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): PLUGGED BACK 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 -► Form 10-407 Revised 5/2017 V`rL 1/ // " CONTINUED ON PAGE 2bmit ORIGINIAL only ?Ns I/itV i it RBDMS t,� � 5 20 ' 1 • • 28.CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1513 1488 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©TPI- Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results. ger 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. -\1111 Authorized Name: G.L.Alvord Contact Name: Jill Simek ,n Authorized Title: Alaska Drilling Manager Contact Email: Jill.Simekacop.co 5(3rf f- _- Authorized J� c. n I, J 1� Contact Phone: 263-4131 1 Signature: L2#\ Date: , " INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water:Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2K-27 Plug and Abandonment August 15, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2K-27, commencing operations on March 10, 2017 and completing the Plug and Abandonment on August 3, 2017. After tagging the WRP at 12,624' RKB, 3.5 bbls of 15.8ppg Class "G" cement was placed on top of the plug. Top of Cement was tagged at 11,733' RKB and holes were punched in the tubing from 11,705' to 11,710' RKB. 200 bbls of 15.8 ppg Class "G" cement was then pumped, fullbore, down the tubing and up the IA. Top of Cement in the tubing was tagged at 1,324' RKB. Tubing and production casing were perforated from 1,260' to 1,265' RKB and 95 bbls of 15.7 ppg"A-1"cement was pumped down the tubing and up the IA and OA, with cement returns to surface. The tree was removed and a 0.7 bbl top job was performed. The well was then excavated to 16', wellhead removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. r "' SA a 'v';r";° an „ ' € m � f . xd : e^ * _., -° ID s°`a a '4� R } '-' - ' Q{u** '07';;P' ,..„,-;:,,.:'' ta--::"7":-/..„„t!',„„,;-' — -,,,, :1„,-'7. '' .'011;.4'-iti'-:-.41.:-...„ '';'''',,,c4;,, z a s " 7 v -!. � w ;me g .00,,---.4i.,,,4,,,,,.1:10,;(e.4e a i ` • " t ` r • • • .tea: s • mow -'' k. . to t � ra -'It*. 'pt. <414 airOft.',-,,:E` $ 'fit ,to t F k 3Y t` O p :Q,�, S k� -r ,sem • 11, P&A Work Summary 8/3/2017 STATEMAN GUY COOK WAIVED P&A SITE CLEARANCE. 7/31/2017 (MISC)P&A STATE WITNESS CEMENT/WELDED MARKER PLATE 7/30/2017 (MISC)P&A CUT AND REMOVED WELLHEAD>4'BELOW TUNDRA 7/29/2017 (MISC)P&A PREP/SET SHORING BOX,STAIRS,AND SCAFFOLDING 7/28/2017 Excavate to 16'for P&A of well. 5/2/2017 (P&A): POURED 0.7 BBLS OF CEMENT IN TUBING. 4/18/2017 (MISC)ASSIST WI REMOVING TREE INSTALL FLANGE. 4/13/2017 (SEC):MEASURE TOC IN T,IA,&OA. 4/12/2017 PUMPED TOTAL 95 BBLS 15.7 A-1 CEMENT,GOOD CMT RTNS FROM 0/A AND I/A.READY FOR DHD. 4/10/2017 RIH WITH SCMT,BOBBLE PAST PREVIOUS TAG DEPTH 722'RKB,TAG CEMENT AT 1324'RKB,PERFORM CBL LOG UP, NO TOP OF CEMENT FOUND,ANNOMALIES IN LOG NOTED AT PREVIOUS TAG DEPTH OVER 720'-745'RKB,POOH SHOOT GUN OVER INTERVAL 1260'-1265'RKB,CCL TO TS=5.7',CCL STOP DEPTH=1254.3',2 CARRIER/1 SPF/6 SHOTS TOTAL/0 DEG PHASING/2006 POWERFLOW CHARGES/4.5"PENETRATION/0.45"ENTRANCE HOLE,NO CHANGE IN T/IA/0 PRESSURES WHEN GUN SHOT,POOH LRS PERFORM INJECTIVITY TEST: PUMP 8BBLS DOWN TBG AT 2BPM TAKING RETURNS UP IA TO TANK,T/IA/O=600/600/400 PSI,RETURNS SEEN AT TANK PUMP 8BBLS DOWN TBG AT 2BPM TAKING RETURNS UP OA TO TANK,T/IA/O=600/500/400 PSI,RETURNS SEEN AT TANK PUMP 8BBLS DOWN TBG AT WITH IA/0 SHUT,T/IA/0=1500/1050/1075 PSI,LLR OF 1.92BPM @1500PSI. RDMO. READY FOR PUMPING 4/4/2017 PERFORM DRIFT/JUNK BASKET RUN,TAG TOC at 722'RKB,SHUT DOWN DUE TO HIGH WINDS,JOB IN PROGESS 3/25/2017 PUMPED FULLBORE CEMENT PLUG,CIRCULATED 15 BBLS DIESEL,2 BBLS FW,200 BBLS CLASS"G"CEMENT,5" FOAM BALL,3 BBLS FW,AND 14.4 BBLS DIESEL DOWN THE TUBING TAKING RETURNS UP THE IA,READY FOR TAG ON 3/27/2017. 3/24/2017 RIH TO LOCATE NIPPLE,CORRECT DEPTH TO 524.92'RKB,TAG TOP OF CEMENT AT 11733'RKB,WAIT 3 HRS FOR STATE WITNESS,RIH WITH PERF GUNS(4 SPF 0 DEGREE PHASE),RIH TO FLAG AND CORRECT DEPTH TO 11606.4' RKB,CONTINUE TO RIH TO SHOT DEPTH,SHOOT HOLES FROM 11705.4'RKB TO 11710.15'RKB,PERFORM INJECTIVITY TEST AT 2 BPM(500 WHP,30 IA),TBG LEFT F/P WITH SLICK DIESEL,READY FOR CEMENT PLUG#2,JOB IN PROGRESS 3/17/2017 ATTEMPTED TAG TOC;UNABLE TO PASS 11,577'RKB WITH 2.61"CENTRALIZER AND SAMPLE BAILER.UNABLE TO PASS 11,620'RKB WITH 1.95"BAILER ASSEMBLY.JOB SUSPENDED FOR PLAN FORWARD. 3/10/2017 RIH AND TAG WRP AT 12,624'RKB,SPOT 3.5 BBLS OF 15.8 PPG CLASS"G"CEMENT ON TOP OF WRP(ESTIMATED TOC AT 12,248'RKB),WELL LEFT SI AND FREEZE PROTECTED,READY FOR SLICKLINE TAG IN 48 HR. ***IN PROGRESS*** • KUP PROD • 2K-27 Conoc hiliips i, a f Well Attributes Max Angle&MD TD Alaska inc Wellbore APIIUWI Field Name Wellbore Statusncl("I MD(ftKB) Act Blm(ftKB) rr#,„ ,tt: 501032038800 KUPARUK RIVER UNIT PROD 1 72.42 6,142.88 14,037.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-27,81311201710:46:16 AM SSSV NIPPLE 45 12/30/2012 Last WO: 34.89 9/17/2001 Verpralsctremabc(aetUaQ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,732.0 12/13/2014 Rev Reason:P&A WELL pproven 8/31/2017 ' Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 51.0 150.0 150.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 7 5/8 6.875 51.0 6,775.5 3,819.9 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 5 1/2 4.950 51.0 13,987.8 7,308.8 15.50 L.80. EUE8RD -A./CONDUCTOR;51.0-150.0• / Tubing Strings - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection NIPPLE;523.6 TUBING 31/2 2.992 29.0 12,581.9 6.018.4 9.30 L-80 EUE-8rd Completion Details Nominal ID Top(ftKB) Tqp(ND)(ftKB).Top Incl(°) Item Des Com (in) 523.6 523.5 2.25 NIPPLE CAMCO DS NIPPLE 2.875 Cement Plug-OA;O.OftKB _ _ PLUG#3;0.0 MB 12,541.8 5,986.6 38.28 NIPPLE CAMCO DS NIPPLE 2.812 Cement Plug-IA;0.06/B III I - 3.000 12,580.1 6,016.9 37.17 NO GO TBG BAKER NO-GO SUB SUB 12,580.9 6,017.6- 37.)5 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl GAS LIFT;3,038.5 Top(ftKB) (ftKB) (t) Des Com Run Date ID(in) 12,621.3 6,049.9-36.06 CATCHER AVA STYLE CATCHER(OAL=32",MAX OD=2.72; 10/7/2016 2.31"G F/N) 12,624.0 6,052.2 35.99 PLUG WEATHERFORD 2.69"WRP 12/15/2014 0.000 13,019.0 6,386.4 28.17 CEMENT DUMP/BAIL 5 GALLONS OF CEMENT ON TOP OF 11/1/2001 0.000 BRIDGE PLUG 13,020.0 6,387.3 28.15 PLUG WEATHERFORD 3.5"CAST IRON BRIDGE PLUG, 10/21/2001 0.000- SURFACE;51.06,775.5 • W/10,000#RATING 13,891.0 7,213.5 10.57 FISH 3.5"ER PACKER ANCHOR 7/19/2009 1.000 Perforations&Slots Shot GAS LIFT;7,305.8 Dons Top(ND) BM,(TVD) (shots/f Top(958) Wm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,748.0 12,762.0 6,154.0 6,165.6 C-4,2K-27 4/30/2003 6.0 APERF ZONE C-4-2.5"HSD 2506 PJ,60 deg phase 12,774.0 12,794.0 6,175.6 6,192.4 A-4,2K-27 12/18/2002 6.0 RPERF 2.5"HSD,BH Chrgs,60 GAS LIFT;10,054.8 Deg phase 12,774.0 12,794.0 6,175.6 6,192.4 A-4,2K-27 11/7/2001 4.0 (PERF 2.5"HSD BH Chgs,180 Cement Plug-IA;2,000.0158 deg phase PLUG 62;1,324.0 Po(Bl It Stimulations&Treatments I I Proppant Designed(Ib) Proppant In Formation(Ib) Date 11/15/2001' Stimulations&Treatments GAS LIFT;11,888.0 ��,�', Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date Slim/Treat Fluid (bbl) Vol Slurry(bbl) 1 12,774.0 12,794.0 11/15/2001 I ctl Proppant Designed(Ib) Proppant In Formation(Ib) Date 12/23/2002 Stimulations&Treatments GAS LIFT'.12498.3 Vol Clean Pump Stg# Top(ftKB) B5n(ftKB) Date StimlTreat Fluid (bbl) Vol Slurry(bbl) �'� 1 12,774.0 12,794.0 12/23)2002 Cement Squeezes NIPPLE;12,541.8 Top(ND) Btm(ND) 1 I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Cont 13 019.0 13 020.0 6,386.4 6,387.3 11/1/2001 1,324.0 11,710.0 1,311.8 5,491.4 Cement Plug- 3/5/2017 PLUG 2:200 bbls of 15.8 ppgg Gass"G Tubing NO GO 100 SUB;12,580.1 q1 2,000.0 11,710.0- 1,927.5 5,49).4 Cement Plug-IA 3/5/2017 PLUG 2:200 bbls 0115.8 ppgg Class"G 1 11,733.0 12,624.0 5,500.1 6,052.2 Cement Plug- 3/10/2017 PLUG 1:SPOT 3.5 BBLS OF 15.8 PPG CLASS"G" SEAL ASSY;12,580.9 Tubing CEMENT ON TOP OF WRP(ESTIMATED TOC AT 12,248'RKB) 0.0 1,265.0 0.0 1,255.9 Cement Plug-IA 4/12/2017 PLUG 3:95 BBLS 15.7 A-1 CEMENT 0.0 1,265.0 0.0 1,255.9 Cement Plug- 4/12/2017 PLUG 3:95 BBLS 15.7 A-1 CEMENT Tubing CATCHER;12.621,2 r', 0.0 1,265.0 0.0 1,255.9 Cement Plug- 4/12/2017 Cement Plug;11,733.0 ftKB .�„„7 OA 'N PLUG;12,624.0 Mandrel Inserts St a0 on APERF;12,746.0-12,762.0 NTop(ND) Valve Latch Port Size TRO Run RE-FRAC;12,774.0 , Top(ftKB) (f(KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com RPERF;12,774.0-12,794.0 1 3,038.5 2,552.0 CAMCO KBG 2- 1 GAS LIFT DMY BTM 0.000 0.0 10/1/2009 4:00 WERE;12,774.0-12,794.0 I 9 FRAC;12,774,0 2 7,305.8 3,993.0 CAMCO KBG 2- 1 GAS LIFT DMY BTM 0.000 0.0 12/14/2005 9:00 9 CEMENT;13,019.0 3 10,054.8 4,912.2'CAMCO KBG 2- 1 GAS LIFT DMY BTM 0.000 0.0 12/14/2005 12:00 Cement;13,019.015B 9 PLUG;13,020.0 -4 11,886.0 5,565.1 CAMCO KBG 2- 1 GAS LIFT DMY BTM 0.000 0.0 12/15/2005 2:00 9 5 12,498.3 5,952.8 CAMCO KBG 2- 1 GAS LIFT DMY BTM 0.000 0.0 10/16/2016 9 Notes:General&Safety FISH;13,891.0 End Date Annotation 11/5/2010 NOTE.View Schematic w/Alaska Schematic9.0 12/15/2014 NOTE:RESTRICTION @ 710'SLM,PRODUCTION CASING LEAK @ 8393'RKB 10/16/2016 NOTE:2ND LEAK FOUND AT COLLAR AT 6,234' PRODUCTION 5.5'03.5";51.0- 13,987.8 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggQ ������ DATE: July 31, 2017 P. I. Supervisor‘p l ' FROM: Brian Bixby SUBJECT: Surface P &A Petroleum Inspector KRU 2K-27 Conoco Phillips Alaska Inc. PTD 2011690 Sundry 317-022 ' 07/31/2017: I arrived in Kuparuk at 2K-27 well and met with Roger Winters (Well Integrity Field Supervisor). We went over all the numbers on the surface marker plate and verified they were correct. I then went down to the cut off well and verified it was - more than 3 feet below the tundra level. I verified that there was hard cement to surface on all pipe strings. I then took pictures of the hard cement and the surface marker plate that covers the outer most casing. The location was clean and didn't show any signs of past spills. I gave them the approval to weld the marker plate on. Attachments: Photos (4) scow.) FLIti L, 2017-0731_Surface Abandon KRU 2K-27_bb.dox Page 1 of 3 • • Surface Abandonment— KRU 2K-27 (PTD 2011690) Photos by AOGCC Inspector B. Bixby 7/31/2017 II tom:x,•3`[y�` :«. '°°'''°'xx 'fly» u„. KRU 2K-27 �, excavation �n 0)i).,0W4' - Al 3�ey, "�.. r 5 v " ' nr r 1< r i ' ', ._> Well cutoff and ' cement to surface AV , iff i y( ? � SIN P ;� � i ilt i t W ��. Q'9 i r. • 0 x } !� ,.. , ., p" � ^fitV' gym^'" � ^ 'i „.., � 4` 0$i {. � "!{yam„ - ..,-..".., ' / ,/"."`,, 7 ., , . ,....,..,....., „....., ,,, . , • ,14. :...:*P.-z -.‘+‘ 7 �, ;x* 45: 4'7 as f� ..rte 1 .., f -it -,,, r .+#a,t, •r' � ' is ,. -, a • -1,e;,"' • vrt. s.='; r� r .�.► .:) 9 r„ 1, ...4-•W`,;„. r 7. -I k .t. � . 1 4'i c, , r i n ,..;..-,41-..9,,,--44:..--„...--- -..,-*�. ; Mwr tr :, ni.. {� 1^'"V".:.; :17.11141t4:;.-.:',-.‘9 t:,.�_'u Marker plate info(above);plate installed(below) • \' :'* - .< , . C.LC � T '�P� dee; • .€ + i ° • �' 1/4----- -'*.4. h'''�".r`� Y y a. ,. RYw..r ^ ,, 1 r \k G is e•..-i.14". icc.,i,rtt.... ...!.-:',.-. 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J d d J 03 L -J 0- la 0 0o U o ; N - 1444 0 h o r �yZ a C z \ i 03 •-y, ' O '3 AI 7 coGq 5 a J J J J J J J i.,., 1Cii LLD MAz i ` ww333 � � � 3 Z r , cexcercremce ww w w w w w w.. > > > > > > > z Y Y Y Y Y > > > > > > > w Q Q Q Q Q Q Q ,y d d a d 0- d n. 11 8 Y Y Y Y Y C a Y Y c 1- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CU 0 0 0 0 0 0 0 T fj 0 al ano ono ano N O N w 0 a OO O o 0 0 0 0 `6 n o 0 0 0 0 0 0 Q 0 'V' 00 CO N - � �+ = a Im 4 0) M M (0 N M (() '- N p. N N N N N N E r s g" Q O M M O M 6 O) C •O O_ 0 N 0 O N 0 N N 01 O O O o c o O A v O o 0 0 0 0 0 i+ +' c 0 pCc. C N )1Y uY N N O N 'GJ O; 0 CID Ln - 13Cv linth E y a ui Y w, 'N CU CU Z Q N N N Q n O ++ .. Y L p) ,,}, 44. n' E v al al im1 = ac N e 1� z (5 Y Y C9 U (o (n ,., ,., C 6 Q O N N N N N N t' E Z H 0 0 ( ei t ^ w 7 ro . f0 • 0CA S < i I F cvo0 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r`1�L 5147 DATE: 03/27/17 P.I. Supervisor SUBJECT: Plug &Abandonement FROM: Jeff Jones KRU 2K-27 - Petroleum Inspector ConocoPhillips Alaska Inc. (CPAI) PTD 2011690 Section: 11 Township: 10N Range: 8E Meridian: Umiat Lease No.: ADL 25589 Drilling Rig: Rig Elevation: Total Depth: 14,037 ft Operator Rep.: James McAnelly Casing/Tubing Data: Casing Removal: Conductor: 16" - O.D. Shoe@ 150'MD Casing Cut@ Feet Surface: 10" - O.D. Shoe@ 6776"MD Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: 6" O.D. Shoe@ 13,988"MD - Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: 3.5" O.D. Tail@ 12,582"MD Casing Cut@ Feet Plugging Data: Type Plug Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement(M.D.) T.O.C. Depth Verified? above plug Test Tubing Bridge plug 12624 ft MD ' 11734 ft MD C.T.Tag 12K - 8.6 No Type Plug Founded on: Verified? Open Hole Bottom Drilipipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T.Tag !3'ELP 5 2O`-.. Casing Stub Retainer No • SCANNED �:-- Surface March 24, 2017: I traveled to CPAI's Kuparuk River Field (KRF)well 2K-27 to witness the coil tubing tag of an abandonment plug set in the tubing. Jim McAnelly was the CPAI representative for the test today and we discussed the procedure prior to running in the hole with coil tubing. A wireline retrievable plug had been previously set at 12,624' MD. 3.5 BBLS of 15.8 ppg class "G"cement was placed on top and was allowed to harden.A previous attempt to tag this plug with wireline was unsuccessful on 3/17/17(AOGCC witness). Coil tubing was then run in the tubing to clean out the well and to perform the plug tag. I witnessed a solid tag at 11,734 ft MD.The top of cement was tagged shallower than expected(CPA indicated 0.6 BBLS extra cement was pumped when setting this plug). Summary: I witnessed a successful coil tubing tag of a cement abandonment plug placed in the tubing of CPAI KRF well 2K-27. Attachments: none Rev.:5/28/00 by L.R.G. 2017-0324_Plug_Verification_KRU_2K-27jj 5/5/2017 411/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg1�-S151r DATE: 3/17/17 P. I. Supervisor 7 FROM: Bob Noble SUBJECT: Plug & Abandonment Petroleum Inspector KRU 2K-27 ConocoPhillips Alaska PTD # 201-169 3/17/17: I traveled to KRU 2K pad and met with CPA rep Tyson Wiese. We discussed the procedure that they were going to use to tag the plug. I ask if they were going to do a pressure test too and he said no because there was a hole in the tubing farther up hole. Tyson told me that they had spotted 3.5 barrels of class G 15.8 cement on 3/10/17 with a CTU. They had set a WRP plug at 12,624 ft MD and the cement was spotted on top of that. Digital slickline was rigged up to the well and ran into the hole. TOC was expected to be around 12,289 ft MD. Slickline got down to 11,577 ft MD and couldn't go any deeper. They said they thought it could be combination of a heavily deviated well and stringers. They attempted to work it down and then lost their spang action and had to come out of the hole. Tyson told me they were going to make some scraper runs to clean up the stringers. He said if that didn't work they would have to rig up CTU. I told him to send out another notification when he was able to get to the bottom. Summary: I witnessed the UNSUCCESSFUL tag of the abandonment plug at KRU 2K-27. Tag will be rescheduled after some cleanout runs. Attachments: none SCANNED !' 1 5 2017 2017-0317_Plug_V erification_KRU_2K-27_bn.docx Page 1 of 1 4111 OF TFJ� O )yy ,), THE STATE Alaska Oil and Gas ,w 0.f Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w h' Main: 907.279.1433 O� ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer SCOW"AR 9 2.0117, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-27 Permit to Drill Number: 201-169 Sundry Number: 317-022 Dear Ms. Simek: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ii())111A-.-OL. Cathy P. Foerster Chair SF DATED this I day of February, 2017. RDDMS FEJ - 3 2017 • • 'RECEIVED STATE OF ALASKA JAN 17 2017 ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Ai�Q`� G _ � 20 AAC 25.280 1.Type of Request: Abandon 1. Plug Perforations E Fracture Stimulate E Repair Well n Operations Shutdown E Suspend fl Perforate r Other Stimulate f Pull Tubing I— Change Approved Program E Plug for Redrill ]l Perforate New Pool fl Re-enter Susp Well fl Alter Casing E Other: la 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. , Exploratory E Development F ' 201-169 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service E501032038800 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 I No l J KRU 2K-27 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25589 - 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): 14,037' ' 7,357' I 4 13890 7213 • 200psi 12624', 13020' 13891 Casing Length Size MD TVD Burst Collapse Conductor 119' 16" 150' 150' Surface 6,745' 10" 6,776' 6776' Intermediate Production 13,960' 6" 13,988' 7,309' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12748-12762,12774-12794 ' 6154-6166,6176-6192 3.500" L-80 12,582' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic E Development 1•Service r 14.Estimated Date for 2/1/2017 15.Well Status after proposed work: Commencing Operations: OIL I- WINJ WDSPL fl Suspended I- 16.Verbal Approval: Date: GAS I WAG E GSTOR E SPLUG 1- Commission Representative: GINJ E Op Shutdown 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 @ 263-4131 Email JiII.Simek(c�cop.com Printed Name Jill Simek Title Staff Well Integrity Engineer /l I /I6/Il- Signature '• I Phone 263-4131 hate COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: HCl ^ v22 Plug Integrity V BOP Test D Mechanical Integrity Test ❑ Location Clearance Other: 7fe6ee ,,,,,,./..,,,...55 4. 12 ,,„_, tz, d a c vi,zr ,t-]— a5 {'tofi-ra ti^ 1�{�ocCciUre . 4/+crv, atepLig pLac-rmCom-}- -/Jp ► yeaprr ..0A r 215, 11Z ( ) Post Initial Injection MIT Req'd? Yes ❑ No re' f"{ 1S 2.1. 1pq Spacing Exception Required? Yes ❑ No l( Subsequent Form Required: /6- .4-67- ( R6DrMS 1,k7 F 3 - 3 2317 APPROVED BY Approved by: CfMMISSIONER THE COMMISSION Date: 2. . 1- 9141IFII6 G I Submit Form and Form 10-403 Revised 115 �pfQVeQa p c tionL is valid for 12 months from the date o ..,r. al. Attachments in Duplicate AeW7-47 VTL z-/' l17 ,r • ! RECEIVED ConocoPhilli JAN 17 2017 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Commissioner,State of Alaska 11 January 2017 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 (P&A)Kuparuk Producer 2K-27(PTD#: 201-169). 2K-27 is a Kuparuk A and C sand producer drilled in September,2001. It was produced until September,2014 when it was shut in due to seawater power fluid concerns. During wellwork,a production casing leak and a subsidence related tubing restriction were discovered. In December,2014 the well was secured with 2.69"WRP and has since remained shut-in. The well is completed with 3 V2"tubing to 12,582' KB and 5 'h"x 3 'A"production casing to 13,988' KB. 7-5/8"surface casing is set at 6,776'KB. The production casing leak is at 8,393' KB and tubing restriction is-710'KB. Additionally,recent diagnostics have identified tubing leaks at 8,234'KB and 12,498' KB. A rig workover to replace tubing and repair the casing leak has been determined to be uneconomical and,as an alternative to repair,2M-08 CTD plans to sweep the .- area. Shark Tooth expansion grassroots wells are planned for 2 1 - 'r e ur 51 e s mane old is filled to capacity,and 2K-27 is not providing any service,2K-27 has been identified for Slot Recovery P&A.J Per this procedure,P&A steps will be performed with coiled tubing to place a cement plug on the existing WRP to isolate perforations from the wellbore. Holes will then be punce m e to mg,a ove g#1 Topatement(TOC)and cement will be placed in the tubing and tubing x production casing annulus(IA) to approximately 2,000'KB. Tubing and production casing will be perforated above Plug#2 TOC and a third cement plug will be pumped,fullbore,to bring cement to surface in the tubing,IA,and production casing x surface casing annulus(OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed,and site backfilled with gravel/fill to ground level. / Due to the subsidence related tubing restriction at 710' KB,it is not recommended to pull the WRP,as the risk of sticking the plug in the restriction is high. Should the plug become stuck,the P&A operation may be compromised and the well would be left in an unsecured state. ConocoPhillips thereby requests a variance from the AOGCC well plugging requirements as specified in 20 AAC 25.112(c)(1)(E): "if the perforations are isolated from open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and either a minimum of 75 feet of cement placed on top of the plug by the displacement method or a minimum of 25 feet of cement placed on top of the plug with a dump bailer;" The WRP is set at 12,624'KB 138 feet above the perforations. ConocoPhillips proposes to place 326 feet L-7- of �of cement on this existing WRP,to isolate the formation from the wellbore. Please refer to the attached procedure for more details. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, 1 11 Si elicli-r-\ ell Integrity Engineer ConocoPhillips 2K-27 P&A Permit to Drill #: 201-169 Per this procedure, P&A steps will be performed with coiled tubing to place a cement plug on the existing WRP to isolate perforations from the wellbore. Holes will then be punched in the tubing, above Plug #1 Top of Cement (TOC) and cement will be placed in the tubing and tubing x production casing annulus (IA) to approximately 2,000' KB. Tubing and production casing will be perforated above Plug #2 TOC and a third cement plug will be pumped, fullbore, to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level Proposed P&A: Coiled Tubing /Cementing: Objective: Plug #1 — Place a cement plug from WRP to 12,298' KB. Cement Volume Calculations : • 3-1/2" Production Casing, Plug to Seal Assembly: (0.008696 bbl/ft) * (12,624' — 12,582') = 0.4 bbl • Tubing, Seal Assembly to 200' above leaking GLM: (0.008696 bbl/ft) * (12,582' — 12,298') = 2.5 bbl • Total volume = 0.4 + 2.5 = 2.9 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Wesley Miller/ Ed Jans 907 670- 5827). The job is designed for 2.9 bbls of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and Cementers. Pressure test surface equipment as required. 5. Reference 10/17/2016 schematic and tubing details for depth correlation. 6. RIH with coil tubing and tag WRP at 12,624' KB. 7. Pump 10 bbls fresh water spacer 8. Pump 2.9 bbls of 15.8 ppg Class "G" Cement 9. Pump 10 bbls fresh water spacer behind 10. With approximately 50' of cement out of the nozzle, begin to pull out of hole, laying in cement, taking 1 for 1 returns up the coil tubing backside. 11. Wash up surface equipment. RDMO. JS • Slickline: Objective: Tag TOC 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. Notify the AOGCC Inspector of the timing of the cement plug tag and pressure testing. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4T 4. RIH and tag TOC @ approximately 12,298' KB. Record Results. ,1 TAG MUST BE AOGCC 1N!TNFSSFfl 5. Report issues and results to Well Integrity Engineer. 6. RDMO Eline / Little Red: Objective: Punch tubing, injectivity test 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU E-Line and PT Equipment as required. 3. RIH with 2" x 4' tubing punch, 4 spf; reference 10/17/2016 schematic and tubing details for depth correlation. 4. Punch 30'-50' above TOC or as close to mid joint as possible. 5. Pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO. Cementing: Objective: Plug #2 - Fill the wellbore with cement from tubing punch (-12,250' KB) to approximately 2,000 KB. We will be circulating cement down the 3 '/2" tubing and up the 3 '/2" x 5 1/2" annulus. Cement Volume Calculations (TOC approximately 2,000' KB in tubing and annulus): • Volume in 3 1/2" x 5 1/2" annulus: (12,250' -2,000') x 0.01190 bbl/ft = 122 bbl • Volume inside 3 '/2" tubing: (12,250' -2,000') x 0.008696 bbl/ft = 89.1 bbl • Total volume: 122 + 89.1 = 211.1 bbl • Displacement volume: (2,000' KB) * (0.008696 bbl/ft) - 3 bbl spacer = 14.4 bbl JS • • 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Wesley Miller/ Ed Jans 907 670- 5827). The job is designed for 211.1 bbls of 15.8# Class "G" cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. Ensure a 5" foam ball is loaded into the tree prior to the cement job. 4. MIRU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. 5. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 1/2" x 5 1/2 " (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 6. PT surface equipment as required 7. Establish circulation with diesel. 8. Pump 2 bbls fresh water spacer 9. Pump 211.1 bbls of 15.8 ppg Class "G" cement. • Assumes tubing punch at 12,246' - 12,250' KB. Recalculate based on actual tubing punch depth. • Pump up to 2 bpm initially and slow pump rate to <1 bpm for last 20 bbl of cement, to avoid pumping through leak into formation. 10. Drop 5" Foam Ball 11. Pump 3 bbls fresh water spacer. 12. Displace with 14.4 bbls diesel to leave Top of Cement in tubing and IA at 2,000' KB. 13. Shut down pumps and close in Tubing and IA. Do not overdisplace. 14. Wash up cement pumps and clean up surface lines. 15. RDMO Slickline / Little Red Objective: Tag TOC, CMIT-TxIA, DDT-TxIA 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 2,000' KB. Record results and report tag depth to Well Integrity Engineer. 5. RU LRS and PT Surface Equipment as required. 6. Perform CMIT-TxIA to 1,500 psi. Record results. 7. Perform DDT on Tubing and IA. Record results. 8. Report issues & results to Well Integrity Engineer. 9. RDMO JS s E-line / Little Red Objective: Punch 31/2" tubing and 5 1/2" production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT Equipment as required. 3. RIH with dual-string perforating gun, referencing 10/17/16 schematic and tubing details for depth correlation. 4. Punch 30' above TOC, as close to mid joint as possible. 5. Pump 8 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). Ensure circulation to both IA and OA. 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO Pumping Services: Objective: Plug #3 - Fill the wellbore with cement from perforating depth (-2,000' MD) to surface. We will be circulating cement down the 3 1/2" tubing and up the 7 5/8" x 5 1/2" annulus as well as up the 5 1/2" x 3 1/2" annulus. Cement Volume Calculations: • Volume in 3 '/2" x 5 1/2" annulus: (2,000'-0') x 0.01190 bbl/ft = 23.8 bbl • Volume in 5 1/2" x 7 5/8" annulus: (2,000'-0') x 0.01653 bbl/ft = 33.1 bbl • Volume inside 3 1/2' tubing: (2,000'-0') x 0.008696 bbl/ft =17.4 bbl • Excess: 20 bbl • Total volume: 23.8 + 33.1 + 17.4 + 20 = 94.3 bbl 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Wesley Miller/ Ed Jans 907 670- 5827). The job is designed for 94,3 bbls of Permafrost Cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU HAL Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 7 5/8" x 5 '/2" (OA) and 5 1/2" x 3 1/2" (IA) annuli independently. Also, ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up "Permafrost C" cement. JS • 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 94.3 bbl of "Permafrost C" cement (cement to surface in T/1/O, including 20 bbls excess) 9. After approximately 50.5 bbls of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good Permafrost cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. This step must be performed efficiently as Permafrost Cement is thixotropic and will develop gel strength quickly when static. 11. After approximately 23.8 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good Permafrost Cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 12. After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO DHD: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. 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 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. 4OGCC witness and photo document required. 7. Send the casing head w/ stub to materials shop. 'hoto document. JS • • 8. Weld Y4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. erioio ui ie ic. AOGCC Witness Required. ConocoPhillips 2K-27 PTD # 201-169 API # 50-103-20388-00 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. r'now aocu meni rinzai aii.ti viii work is completed, JS O • Schematic: i KUP PROD 2K-27 •ConcoPhillips I i c wsN Attributes Max Angle s MD TO p-1`i+.a : Ar22m.. G..7*1 Flp40 Nam. '..2,,.stetu 14.1c,i M6{0123 Art 390 flew ,,,Tv.7rronai; 6210.20_13:5 JIARJ3 RY.1341207 '.ROD 72 12 3,152 31 4 337 2 ... 5.***** 1013(opn) Onlo Moot** BM Dab IIIII-Orn it60488 ti5055101D]13N Au 3555 NIPPLE 4_.a 1'030,201'2 2.01420: 34191 3,'M1**ow 170001 .N=e •w&.e1f08vuF4 inulin'..... Anfbilon 6NPS 14109) Ertl 04448 04.0015181 LW Mod I3 Lad Dib 4)501793:2.4 '2,732 2 *211'2:14 v 043693 225,0T 310331 C.1.3 240, 94r3... 10171035 ._ms's::_.'_4k5 SEE"NOTES Casing Strings NA3300:049 ;0, Cac't90.03000on 00ilni 09m1 Too1RP6j 4010.03'74,01 641 080th RYDI.-*Mon 0. 0+004 Top 00.1 �13UCTCP, le 13.042 31 3 150.0 150.0 62.53 902 W57.302 Cac+r.S DSFont6pn CO 30401 S IRIoo,fiKe) so 04o.WS) tot 040P11301..Whoop. WM1 Ono. Top T0 ,,:"FACE 5.'9 5.175 T 12 3 '5,775.5 3119.9 29.7C 7.30 570M i�yi� r **no Daortp6cn ODI) oO(W6} M 005)8783 3e1 OMA 11391_.*Vivi 44*4-....n****l<cFMe0l�awew:_.' .,4. R-. 61 ,L)O ill Y 0...2-30 h3 1001 e1��PR04IX'T10N..: .952 233 1},997.3 T,Ad.d 76.30 4)30 E...111 AO €.-.. Tubing Strings T.mint DetarIclK 83^0,Ma...16(911 'o4'1!K. 50 Devil,ill..M 0600 DIV01 I_,9008801 Mtla To.€43 031011 7UDk2- .. _ 2 95: 21- .0,55'5 3,113.4 3 33 L-65 3-E. _GNDUGi0R,31.0+50 Pd✓--- •' C On Details (, Ham10$16 NfNiE 6 r„,„„,., ) Top R"D KJ -co mai I) hem Iw! Dae _,zn 25.3 2°E 0.3E HAL ER FMC GEN)/5725(145 HANGER 3300 623.5 521"5 2.25'NIPPLE CA6100 OS NIPPLE 2.916 G 12,541.5 5,535'. 33.2E NIPPLE CANDO 30 NIPPLE 2312 Li 12,0001 5,0)55 37.17 NO GO 5'801 845 ER 430-30 2240 3130 0,05 ,H 12,510 9 3.0175 37.1'.SEAL A033 EA::ER 9-03 -22 25O 3..A,ES1E.Y 3 070 5.552FT,30905 Other In hole Offiretate retrievable plugs.valves,pumps,fish etc.) Top(11M1 TLP Me Teo MAID pixel Ft iw8 Lam RL00aM iD(80 12,121.3 6,0453 3606:DITCHER AVA STYLE.CATCH ...OAS-32"-MAO OD-2.72. 10,-12016 p. 1 2.11-G F'N' 3 12,62450 8,0522 35.99 PLUG WEATHERFORD 2 fig'WRP 12/15/2014 2.020 13,019.0 6,300.4 29.17 CEMENT 2JMP.RAL 5 GALLONS OF CEMENT ON TOP OF 1131/2001 2 2130 BRIDGE PLUG 6WfiGE.]59,317631-- ' 13,14)10.0" 6,3111 2815 PIA.* WEA781E880502 r LAST,PON BROCE PLUG, 10012001 C:DY 0115,0010 RATOSG L-: • • , P&A Diagram: 2K-27 P&A PTD #: 201-169 ,:kgt JP:iposed P&A Carreit c Dmoistiart F 62 58 I-MC' Ccrieuer G 15'2 AiIli 7:1,44(4;441;6247:: ::7: L TAM Plug T° 8 C.C*42CTISurMeefit PerTnaotAi Ai ,lik:. 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Q t) M rii o 0o cn M r� :=9, 4,,, : Ln • r CO CO M N CO4— CO r) CO co ra M M ~ = a r 0 0 0 0 r N N E ..1•Z C N N N N N N N NN N t n Q o) C) o) o) r) r) d) o) d) d, C • o a Q N N N N O O N N N N 01 O O O O O O O O "- u O O O10 IC 0 0 0 0 0 0 0 It ++ +' C O N N N N N M V in 1n )P) Q -0 0 C C9 Gl C . U �+ E a ac a aa W 8 U d Q I� � _ m -° `0 `° 9 ~ d pj rl -.4 N N c0 n CO N M .- ', c0c--1 C i Y d a Z b pp !y1 ;Z O O N O N e- 3 e- N N ++ C co N p) = 20 g n , _, J J di 11- Y Y X >. E ro v*'i CI. Q N W r N N N N H zc 4, 0 O o .c CA CI I ^ co c a) O O F� S — O CA a Q .. F- a s 1- H III • (VS,. WELL LOG TRANSMITTAL PeoAciivE DI MNOSric SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ;A $EP d ; K 2011 [907] 659 -5102 °' ,. " RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. 1 Attn: Robert A. Richey 130 West International Airport Road AUG Suite C RECE6 2011 Anchorage, AK 99518 Fax (907) 245 -8952 I 1) Caliper Reso 8- Jul -11 2K -22 1 Report / CD 50-103-20119-00 2) Caliper Report 29- Jul -11 2K -27 1 Report / CD 50- 103- 20388 -00 2- «� i Signed : Date : A`� l \Ltol..,--L-CD Print Name: a C�k�a -,. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAx: (907)245 E -MAIL : PDSANCHORAGEcMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhillips_Transmit.docx 1 0 • Multi- Finger Caliper I Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 2K -27 Log Date: July 29, 2011 Field: Kuparuk Log No. : 10258838 ZX70 State: Alaska I Run No.: 2 API No : 50-103-20388-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 12,493 Ft. (MD) I Inspection Type : Corrosive & Mechanical Damage COMMENTS : I This caliper data is correlated to tubing detail record dated (September 15, 2001) This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged appears to be in good condition, with no significant 1 wall penetrations, areas of cross - sectional wall loss or I.D. restrictions throughout the logged interval. This is the second time a caliper has been run in this well and the 3.5" tubing has been logged. A I comparison of the current and previous log (January 11, 2008) indicates no change in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint-by-joint basis between the current and previous logs is included in this report. I The summary report is an interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: I No significant wall penetrations (> 14 %) are recorded throughout the logged interval. I MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the logged interval. 1 MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the logged interval. I Mandrel Orientation I 2K -27 Joint No. Tool ConocoPhillips Deviation Alaska, Inc. Mandrel No. Kuparuk July 29, 2011 Latch Orientation 96.2 68 1 4:30 232.2 71 2 9:00 I 319.2 70 3 12:00 377.2 62 4 2:00 1 Field Engineer: Galligan & E. Reginier Analyst: C. Lucasan Witness: J.Condio I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS ©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I I 2o[ -l6°1 1 • • Correlation of Recorded Damage to Borehole Profile 1 • Pipe 1 3.5 in. (50.5' - 12482.4') Well: 2K -27 Field: Kuparuk I Company: Conoco Alaska, Inc. Country: USA Survey Date: July 29, 201 Phillips 1 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 -- 53 i 50 ---,_ 1590 GLM 1 100 5 3173 s I 1 50 ) 4731 it 1 200 / 6283 E _ Z 1 GLM 2 c t i 250 ) 7864 i C1 300 9429 1 GLM 3 350 11005 1 GLM 4 -II 1 397 12482 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 1 Bottom of Survey = 397 1 1 III • • 1 Maximum Recorded Penetration 11 Comparison To Previous I Well: 2K -27 Survey Date: July 29, 2011 Field: Kuparuk Prev. Date: January 11, 2008 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 10000429 (HA I Country: USA Tubing: 3.5" 9.3 lb L -80 EUE 8RD Overlay Difference 1 Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) I 0.1 0 50 100 150 200 250 -100 -50 0 50 100 0.1 8 8 17 17 _ I 27 27 37 37 47 47 57 57 I 67 67 77 77 87 87 96.1 96.1 104 104- ' 114 114 - 124 124 134 134 144 144 I 154 154 164 164 174 174 *- 1 184 .1 184 194 Z 2 04 Z 204 . 204 3 214 214 224 224 232.2 232.2 ?' I 241 241 251 251 261 261 271 271 281 281 291 291 301 301 311 311 1 319.2 328 319.2 328 338 _ 33: 348 34: 358 358 1 368 :' _ 36: 377.1 377.1 385 385 1 395 I 395 ` -28 -14 0 14 Approx. Contusion Rate (mpy) ■July 29, 2011 ■January 11, 2008 1 1 I • • 1 PDS Report Overview �ti- Body Region Analysis I Well: 2K -27 Survey Date: July 29, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L -80 EUE 8RD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 in. 9.3 ppf L -80 EUE 8RD 2.992 in. 3.5 in. 6.0 in. 6.0 in. 1 I Penetration(% wall) Damage b Profile (% wall) 500 Penetratio ody Metal loss body 0 50 100 400 0 I 300 1 200 48 I 100 0 GLM 1 96 a ' 0 to 20% 20 to 40 to over y 40% 85% 85% g i Number of joints analysed (total = 408) 146 _ 1 408 0 0 0 1 196 1 1 Damage Configuration ( body ) 10 GLM 2 1 244 1 1 5 294 . I GLM 3 i 0 342 I Isolated General Line Other Hole/ y Pitting Corrosion Corrosion Damage Pos. Hole 1 2 GLM 4 1. Number of joints damaged (total = 3) 390 I 3 0 0 0 0 Bottom of Survey = 397 1 1 1 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L-80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 0.1 50 0 0.01 6 0 2.98 Pup 1 53 0 0.03 11 1 2.97 1.1 85 0 0.02 9 2 2.94 Pup 1.2 93 0 0.01 5 0 2.91 Pup Lt. Deposits. 2 95 0 0.03 10 1 2.97 I 3 125 0 0.02 8 2 2.96 4 157 0 0.02 9 1 2.96 5 188 0 0.02 9 2 2.96 6 219 0.04 0.04 15 6 2.92 Shallow Pitting. Lt. Deposits. I 7 248 0 0.03 11 2 2.97 8 279 0 0.02 8 2 2.97 9 309 0 0.02 9 1 2.96 10 340 0 0.03 10 2 2.96 I 11 372 0 0.02 9 2 2.94 12 403 0 0.03 12 2 2.96 13 434 0 0.03 11 1 2.96 14 465 0 0.02 8 2 2.96 15 497 0 0.02 9 2 2.97 I 16 528 0 0.02 9 1 2.95 16.1 559 0 0 0 0 2.88 Camco DS Nipple 17 561 0.03 0.02 8 2 2.95 18 592 0 0.02 8 1 2.97 I 19 623 0 0.02 9 1 2.96 20 654 0 0.01 6 2 2.96 21 685 0 0.02 7 1 2.95 22 716 0 0.02 8 2 2.97 I 23 748 0 0.03 12 3 2.95 24 779 0 0.02 7 2 2.94 25 810 0 0.02 9 3 2.96 26 842 0 0.01 6 2 2.96 I 27 873 0 0.02 8 2 2.96 28 904 0 0.02 9 2 2.96 29 936 0 0.02 9 1 2.95 30 967 0 , 0.02 9 2 2.95 31 998 0 0.03 10 3 2.96 32 1029 0 0.02 8 2 2.97 33 1061 0 0.02 8 2 2.96 34 1092 0 0.02 8 2 2.95 35 1123 0 0.02 9 1 2.96 I 36 1155 0 0.02 9 2 2.96 37 1185 0.03 0.03 11 2 2.97 38 1216 0 0.02 9 2 2.97 39 1247 0 0.02 9 2 2.97 I 40 1278 0 0.01 5 1 2.95 41 1310 0 0.01 5 2 2.96 42 1339 0 0.02 9 2 2.96 43 1371 0 0.01 6 2 2.94 44 1402 0 0.01 6 2 2.94 I 45 1433 0 0.01 6 2 2.94 46 1464 0 0.02 7 2 2.96 dy y I Metal Penetration Loss B Page 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L-80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in. Country: USA Survey Date: July 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 47 1496 0 0.02 6 2 2.94 48 1527 0 0.01 6 2 2.96 49 1558 0 0.01 5 2 2.93 Lt. Deposits. I 50 1590 0 0.02 7 1 2.94 0 51 1621 0 0.01 5 2 2.95 1 I 52 1652 0 0.01 5 2 2.95 53 1683 0 0.02 7 2 2.96 54 1715 0 0.02 8 1 2.96 0 55 1746 0 0.01 6 2 2.96 1 I 56 1777 0 0.02 7 2 2.96 57 1809 0 0.01 6 1 2.94 0 58 1840 0 0.01 6 2 2.94 59 1872 0 0.01 6 1 2.94 I 60 1903 0 0.02 7 2 2.94 61 1934 0 0.01 6 2 2.96 62 1966 0 0.02 6 2 2.93 Lt. Deposits. II 63 1997 0 0.02 7 2 2.96 I 64 2029 0 0.01 5 1 2.96 65 2060 0 0.01 5 2 2.97 66 2090 0 0.02 6 1 2.94 1 67 2122 0 0.01 6 2 2.97 1 68 2153 0 0.01 6 2 2.98 1 I 69 2184 0 0.02 7 2 2.97 70 2216 0 0.01 5 2 2.94 71 2247 0 0.02 7 1 2.96 0 72 2278 0 0.02 6 2 2.97 1 I 73 2309 0 0.01 6 2 2.93 Lt. Deposits. 74 2341 0 0.01 6 2 2.96 75 2372 0 0.02 6 2 2.96 1 76 2403 0 0.01 6 1 2.96 1 I 77 2434 0 0.02 7 1 2.98 78 2466 0 0.01 6 1 2.96 79 2497 0 0.02 6 1 2.98 0 80 2528 0 0.02 7 2 2.97 a 81 2560 0 0.01 6 1 2.97 1 I 82 2591 0 0.01 5 2 2.97 83 2622 0 0.02 6 2 2.94 1 84 2653 0 0.02 7 2 2.97 II 85 _ 2685 0 0.01 5 ! 2.96 1 I 86 2716 0 0.02 8 2 2.97 87 2747 0 0.01 6 1 2.94 II 88 2779 0 0.01 6 2 2.98 89 2810 0 0.02 9 1 2.96 • I 90 2841 0 0.01 5 1 2.97 91 2872 0 0.02 9 2 2.95 • 92 2904 0 0.02 8 2 2.97 • 93 2935 0 0.01 6 2 2.97 94 2967 0 0.01 5 2 2.95 I 95 2998 0 0.02 7 1 2.96 96 3030 0 0.03 11 2 2.98 1 ' Penetration Body I Metal Loss Body Page 2 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in.. Country: USA Survey Date: July 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 96.1 3060 0 0.02 9 1 2.98 Pup I 96.2 3066 0 0 0 0 2.69 GLM 1 (Latch @ 4:30) 96.3 3072 0.17 0.02 8 2 2.98 Pup • 97 3078 0 0.02 8 1 2.95 • 98 3110 0 0.01 6 2 2.95 i I 99 3142 0 0.02 7 2 2.95 C 100 3173 0 0.03 10 2 2.96 101 3204 0 0.02 7 2 2.96 V 102 3236 0 0.02 7 2 2.97 1 I 103 3267 0 0.03 10 2 2.96 C 104 3298 0 0.03 11 2 2.98 105 3330 0 0.02 9 2 2.96 • 106 3361 0 0.02 6 2 2.98 II I 107 3392 0 0.02 8 1 2.96 108 3423 0 0.02 6 2 2.97 109 3454 0 0.03 11 2 2.95 • • 110 3486 0 0.02 7 2 2.97 111 3517 0 0.02 9 2 2.96 • I 112 3548 0 0.03 12 1 2.96 • 113 3579 0 0.01 6 1 2.94 • 114 3611 0 0.01 6 2 2.97 115 3641 0 0.02 7 1 2.94 • I 116 3673 0 0.02 8 1 2.97 117 3704 0 0.02 6 1 2.94 • II • 118 3734 0 0.02 9 2 2.95 119 3765 0.02 7 1 2.95 i I 120 3797 0 0.01 5 2 2.98 121 3827 0 0.01 6 1 2.94 122 3859 0 0.02 8 2 2.92 Lt. Deposits. 123 3890 0 0.01 6 2 2.98 i I 124 3921 0 0.02 9 1 2.94 125 3952 0 0.01 5 2 2.98 • 126 3982 0 0.02 8 2 2.98 • 127 4013 0 0.02 9 2 2.96 II 128 4044 0 0.02 8 1 2.96 • I 129 4076 0 0.02 8 2 2.98 II 130 4107 0 0.02 6 2 2.97 C 131 4139 0.03 0.01 6 2 2.95 132 4171 0 0.02 7 2 2.96 • I 133 4201 0 0.02 8 ? 2.96 134 4233 0.03 0.04 14 2.94 Shallow Pitting. • MO 135 4265 0 0.01 6 2 2.95 136 4295 0 0.02 7 2 2.96 IN I 137 4327 0 0.02 7 2 2.96 138 4358 0 0.01 6 2 2.96 139 4389 0 0.03 12 2 2.95 II • 140 4419 0 0.02 7 2 2.97 II 141 4450 0 0.01 6 2 2.95 1 I 142 4481 0 0.02 8 2 2.93 Lt. Deposits. 143 4513 0 0.02 9 2 2.94 • ration d y y I Metal Loss Bo Page 3 Penet 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: July 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 144 4544 0 0.02 6 2 2.98 145 4575 0 0.01 6 1 2.98 146 4606 0 0.02 6 2 2.94 147 4637 0 0.03 11 2 2.94 148 4668 0.03 0.03 10 1 2.96 I 149 4700 0 0.03 11 2 2.94 150 4731 0.04 0.02 9 2 2.90 Lt. Deposits. 151 4762 0 0.03 11 2 2.96 152 4791 0 0.01 5 2 2.96 I 153 4821 0 0.03 11 1 2.96 154 4851 0.04 0.03 12 2 2.95 155 4882 0 0.02 9 1 2.95 156 4914 0 0.02 7 2 2.94 I 157 4944 0 0.02 9 2.95 158 4976 0 0.02 0 2 2.94 159 5008 0 0.02 9 I 2.96 160 5039 0.04 0.03 11 2 2.96 161 5069 0 0.03 10 2 2.95 I 162 5100 0 0.02 7 1 2.96 163 5132 0 0.03 12 2 2.96 164 5163 0 0.02 7 2 2.96 165 5193 0 0.02 8 2 2.96 I 166 5224 167 5254 0 0.01 6 1 2.99 0 0.01 6 2 2.97 168 5285 0 0.02 9 2 2.93 Lt. Deposits. 169 5317 0 0.02 6 1 2.97 I 170 5349 0 0.02 7 1 2.96 171 5379 0 0.02 7 1 2.97 172 5410 0 0.02 7 1 2.94 173 5441 0 0.03 11 1 2.93 Lt. Deposits. I 174 5473 0 0.02 8 1 2.92 Lt. Deposits. 175 5504 0 0.02 8 2 2.93 Lt. Deposits. 176 5536 0 0.02 9 1 2.94 177 5567 0 0.02 6 2 2.94 178 5598 0 0.01 6 1 2.93 Lt. Deposits. I 179 5629 0 0.02 7 2 2.94 180 5660 0 0.02 7 2 2.92 Lt. Deposits. 181 5691 0 0.01 5 1 2.94 182 5722 0 0.02 9 1 2.94 I 183 5753 0 0.01 6 1 2.94 184 5784 0 0.02 7 2 2.93 Lt. Deposits. 185 5814 0 0.02 7 2 2.95 186 5845 0 0.01 6 1 2.97 I 187 5876 0 0.01 6 2 2.93 Lt. Deposits. 188 5908 0 0.01 6 2 2.96 189 5939 0 0.02 7 2 2.93 Lt. Deposits. 190 5970 0 0.02 8 2 2.95 191 6001 0 0.02 9 2 2.97 I 192 6032 0 0.02 8 1 2.94 193 6064 0 0.02 9 1 2.93 Lt. Deposits. tion Bo I Metal Loss Body 1 Page 4 Penetra 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 29, 2011 I Joint Jt. Depth Pere. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 194 6095 0 0.02 7 3 2.95 195 6127 0 0.02 8 2 2.92 Lt. Deposits. 196 6158 0 0.02 9 2 2.92 Lt. Deposits. C 197 6189 0 0.02 9 2 2.95 198 6221 0 0.02 8 2 2.95 • I 199 6252 0 0.01 6 2 2.95 200 6283 0 0.02 7 2 2.93 Lt. Deposits. II 201 6314 0 0.02 8 2 2.92 Lt. Deposits. il 202 6346 0 0.02 6 2 2.93 Lt. Deposits. I 203 6377 0 0.02 9 1 2.94 204 6408 0 0.02 7 2 2.93 Lt. Deposits. 205 6439 0 0.02 6 2 2.94 • II 206 6471 0 0.02 6 2 2.94 I 207 6501 0 0.02 7 2 2.93 Lt. Deposits. 208 6533 0 0.01 6 2 2.94 209 6563 0 0.02 9 2 2.94 II • 210 6594 0 0.03 12 2 2.94 C 211 6626 0 0.01 5 1 2.95 I 212 6657 0 0.02 7 2 2.94 213 6689 0 0.01 6 2 2.98 II 214 6720 0 0.01 6 2 2.95 215 6751 0 0.02 7 2 2.94 II I 216 6783 0 0.02 7 2 2.94 217 6814 0 0.02 8 2 2.93 Lt. Deposits. • 218 6845 0 0.01 5 2 2.94 219 6876 0 0.02 8 1 2.93 Lt. Deposits. • I 220 6908 0 0.02 8 1 2.92 Lt. Deposits. 221 6939 0 0.01 6 2 2.94 222 6970 0 0.02 7 2 2.95 • 223 7002 0 0.02 9 2 2.95 • I 224 7033 0 0.03 11 2 2.95 225 7064 0 0.03 10 2 2.95 • 226 7096 0 0.02 6 2 2.96 • 227 7127 0 0.02 7 2 2.92 Lt. Deposits. V 228 7158 0 0.02 6 2 2.93 Lt. Deposits. I 229 7189 0 0.02. 7 2 2.91 Lt. Deposits. • 230 7221 0 0.02 7 2 2.96 V 231 7252 0 0.02 9 1 2.93 Lt. Deposits. • 232 7282 0 0.02 8 2 2.95 • I 232.1 7313 0 0.01 6 0 2.96 Pup 232.2 7320 0 0 0 0 2.91 GLM 2 (Latch @ 9:00) 232.3 7326 0 0.02 9 2 2.95 Pup I 233 7332 0 0.02 8 2 2.92 Lt. Deposits. • I 234 7364 0 0.02 8 3 2.96 235 7395 0 0.02 7 2 2.95 236 7426 0 0.03 10 2 2.93 Lt. Deposits. • 237 7458 0 0.03 11 2 2.94 • 238 7489 0 0.03 11 1 2.93 Lt. Deposits. II I 239 7520 0 0.02 8 2 2.94 • 240 7551 0 0.02 9 2 2.96 • Penetration Body I Metal Loss Bod Page 5 Penetra 1 1 1 1 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L-80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: US Survey Date: July A 29, 201 1 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 241 7583 0 0.02 , 9 2 2.96 242 7614 0 0.01 2.94 243 7645 0 0.02 2 2.96 244 7676 0 0.02 2 2 2.96 245 7707 0 0.02 8 2 2.96 I 246 7738 0 0.03 12 2 2.96 247 7770 0 0.02 7 2 2.94 248 7801 0 0.02 9 2 2.95 249 7832 0 0.03 11 2 2.94 I 250 7864 0 0.02 7 2 2.95 251 7895 0 0.03 10 2 2.95 252 7926 0 0.02 9 2 2.95 253 7958 0 0.02 9 2 2.95 I 254 7989 0 0.03 12 2 2.95 255 8020 0 0.03 11 2 2.96 256 8051 0 0.03 11 2 2.95 257 8083 0 0.02 8 2 2.94 I 258 8114 0 0.02 9 1 2.94 259 8145 0 0.02 8 2 2.95 260 8177 0 0.03 10 2 2.94 261 8208 0 0.02 9 2 2.93 Lt. Deposits. 262 8239 0 0.02 8 2 2.93 Lt. Deposits. I 263 8271 0 0.03 10 1 2.92 Lt. Deposits. 264 8302 0 0.02 9 2 2.92 Lt. Deposits. 265 8334 0 0.02 7 2 2.91 Lt. Deposits. 266 8365 0 0.02 7 2 2.93 Lt. Deposits. I 267 8396 0 0.03 10 2 2.93 Lt. Deposits. 268 8428 0 0.02 9 1 2.93 Lt. Deposits. 269 8458 0 0.03 10 2 2.95 270 8490 0 0.02 9 2 2.91 Lt. Deposits. I 271 8521 0 0.03 2 2.93 Lt. Deposits. 272 8553 0 0.02 2 2.92 Lt. Deposits. 273 8584 0 0.03 11 2 2.96 274 8615 0 0.01 t, 2 2.92 Lt. Deposits. 275 8646 0 0.02 2 2.91 Lt. Deposits. I 276 8678 0 0.01 2 2.96 277 8709 0 0.02 2 2.91 Lt. Deposits. 278 8740 0 0.01 ( 2.91 Lt. Deposits. 279 8771 0 0.02 is 2.90 Lt. Deposits. I 280 8802 0 0.02 t3 2.92 Lt. Deposits. 281 8834 0 0.02 9 2 2.96 282 8865 0 0.02 8 1 2.95 283 8896 0 0.03 10 2 2.94 I 284 8927 0 0.03 1 _ 2.94 285 8958 0 0.02 2.93 Lt. Deposits. 286 8990 0 0.02 b 2.92 Lt. Deposits. 287 9021 0 0.02 7 2 2.92 Lt. Deposits. I 288 9053 0 0.02 7 2 2.92 Lt. Deposits. 289 9084 0 0.01 6 1 2.92 Lt. Deposits. 290 9115 0 0.03 10 2 2.94 ration I Metal Loss Body Page 6 Penet 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Nominal I.D.: 2.992 in. Company: Conoc oPhillips Alaska, Inc. Country: Survey Date: July 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 291 9146 0 0.03 12 2 2.92 Lt. Deposits. 292 9178 0 0.02 8 2 2.93 Lt. Deposits. 293 9209 0 0.02 8 2 2.94 294 9241 0 0.02 7 2 2.94 295 9272 0 0.02 9 1 2.94 I I 296 9303 0 0.02 7 2 2.93 Lt. Deposits. 297 9334 0 0.02 8 2 2.93 Lt. Deposits. 298 9366 0 0.01 6 2 2.92 Lt. Deposits. 299 9397 0 0.03 10 2 2.93 Lt. Deposits. ■ I 300 9429 0 0.03 11 2 2.92 Lt. Deposits. 301 9460 0 0.02 7 2 2.93 Lt. Deposits. 302 9491 0 0.02 8 .2 2.94 303 9523 0 0.02 8 2 2.92 Lt. Deposits. I 304 9554 0 0.02 9 2 2.93 Lt. Deposits. 0 305 9585 0.02 9 2 2.94 ■ 306 9616 0 0.03 10 2 2.94 307 9648 0 0.02 8 2 2.93 Lt. Deposits. il I 308 9679 0 0.02 8 2 2.94 309 9710 0 0.01 6 2 2.93 Lt. Deposits. 310 9741 0 0.02 8 2 2.92 Lt. Deposits. 311 9773 0 0.02 7 2 2.93 Lt. Deposits. 312 9804 0 0.02 7 2 2.93 Lt. Deposits. I 313 9835 0 0.03 11 2 2.92 Lt. Deposits. 314 9866 0 0.02 7 2 2.91 Lt. Deposits. 315 9898 0 0.02 8 2 2.92 Lt. Deposits. 316 9929 0 0.01 6 2 2.91 Lt. Deposits. I 317 9960 0 0.03 10 2 2.92 Lt. Deposits. ■ 318 9991 0 0.02 9 2 2.93 Lt. Deposits. 319 10023 0 0.02 7 2 2.94 319.1 10053 0 0.02 8 1 2.95 Pup I 319.2 10059 0 0 0 0 2.89 GLM 3 (Latch @ 12:00) 319.3 10065 0 0.02 7 0 2.95 Pup 320 10070 0 0.03 10 2 2.93 Lt. Deposits. ■ 321 10102 0 0.03 11 2 2.90 Lt. Deposits. 322 10134 0 0.01 6 2 2.92 Lt. Deposits. I 323 10165 0 0.02 6 1 2.90 Lt. Deposits. 324 10196 0 0.02 6 2 2.92 Lt. Deposits. 325 10227 0 0.02 7 2 2.91 Lt. Deposits. 326 10259 0 0.02 8 1 2.94 I 327 10290 0 0.02 9 2 2.91 Lt. Deposits. 328 10322 0 0.02 7 1 2.91 Lt. Deposits. 329 10353 0 0.02 9 2 2.91 Lt. Deposits. 330 10384 0 0.01 6 2 2.91 U. Deposits. I 331 10415 0 0.02 7 2 2.91 Lt. Deposits. 332 10447 0 0.02 6 2 2.92 Lt. Deposits. 333 10478 0 0.02 7 2 2.93 Lt. Deposits. 334 10509 0 0.01 6 2 2.91 , Lt. Deposits. 335 10541 0 0.01 6 2 2.93 Lt. Deposits. I 336 10572 0 0.02 8 2 2.91 Lt. Deposits. 337 10603 0 0.02 9 2 2.90 Lt. Deposits. I Metal Penetrati Loss on B dy 1 Page 7 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I _ 338 10634 0 0.03 11 2 2.94 339 10665 0 0.02 8 2 2.88 Lt. Deposits. 340 10697 0 0.01 6 2 2.90 Lt. Deposits. 341 10727 0 0.01 6 2 2.91 Lt. Deposits. 342 10758 0 0.03 10 2 2.89 Lt. Deposits. I 343 10787 0 0.01 6 1 2.89 Lt. Deposits. 344 10818 0 0.02 7 2 2.91 Lt. Deposits. 345 10849 0 0.02 9 2 2.92 Lt. Deposits. 346 10881 0 0.03 10 2 2.93 Lt. Deposits. I 347 10911 0 0.02 8 2 2.94 348 10943 0 0.02 7 1 2.91 Lt. Deposits. 349 10974 0 0.03 10 2 2.91 Lt. Deposits. 350 11005 0 0.02 7 2 2.92 Lt. Deposits. I 351 11037 0 0.01 6 2 2.95 352 11067 () 0.02 7 2 2.90 Lt. Deposits. 353 11099 0 0.03 11 2 2.89 Lt. Deposits. 354 11130 0 0.02 8 1 2.89 Lt. Deposits. 355 11161 0 0.02 7 2 2.91 Lt. Deposits. I 356 11192 0 0.02 9 3 2.95 357 11223 0 0.02 9 2 2.94 358 11255 0 0.03 10 2 2.93 Lt. Deposits. 359 11286 0 0.02 8 2 2.92 Lt. Deposits. I 360 11317 0 0.02 7 2.91 Lt. Deposits. 361 11349 0 0.02 8 2.93 Lt. Deposits. 362 11380 0 0.02 7 2.90 Lt. Deposits. 363 11411 0 0.02 ? 2.88 Lt. Deposits. I 364 11442 0 0.02 2.90 Lt. Deposits. 365 11473 0 0.02 2.92 Lt. Deposits. 366 11504 0 0.03 2.90 Shallow Pitting. Lt. Deposits. 367 11536 0 0.01 u i 2.94 I 368 11567 0 0.02 7 2 2.89 Lt. Deposits. 369 11598 0 0.02 8 2 2.91 Lt. Deposits. 370 11629 0 0.02 7 2 2.95 371 11660 0 0.01 6 2 2.94 372 11691 0 0.01 6 2 2.93 Lt. Deposits. I 373 11722 0 0.03 11 1 2.94 374 11753 0 0.01 0 1 2.94 375 11784 0 0.01 2.95 376 11815 0 0.02 8 2.94 I 377 11846 0 0.02 8 2.94 377.1 11877 0.02 8 2.94 Pup 377.2 11884 0 0 0 0 2.88 GLM 4 (Latch 0 2:00) ; 377.3 11889 0 0.03 10 1 2.91 Pup Lt. Deposits. I 378 11895 0 0.02 8 2 2.91 Lt. Deposits. 379 11926 0 0.02 9 1 2.91 Lt. Deposits. 380 11957 0 0.02 9 2 2.92 Lt. Deposits. 381 11988 0 0.02 9 1 2.88 Lt. Deposits. 382 12019 0 0.03 11 _ 2.91 Lt. Deposits. I 383 12050 0 0.03 11 1 2.90 Lt. Deposits. 1 384 12081 0 0.03 10 1 2.91 Lt. Deposits. , d y I Metal Loss Body Page 8 Penetration 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8RD Well: 2K -27 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 29, 2011 I Joint Jt. Depth Peri. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 385 12112 0 0.03 11 3 2.90 Lt. Deposits. C 386 12143 0 0.02 8 2 2.92 Lt. Deposits. 387 12174 t) 0.02 9 2 2.90 Lt. Deposits. • 388 12205 0 0.02 9 1 2.90 Lt. Deposits. • 389 12236 0 0.02 7 2 2.89 Lt. Deposits. I 390 12268 O 0.01 6 2 2.88 Lt. Deposits. 391 12298 0 0.03 10 2 2.89 Lt. Deposits. • 392 12329 O 0.03 11 1 2.90 Lt. Deposits. a 393 12360 (1 0.02 9 2 2.91 Lt. Deposits. • I 394 12391 0 0.03 10 2 2.91 Lt. Deposits. 395 12422 0 0.01 6 2 2.91 Lt. Deposits. • II 396 12453 0 0.03 10 1 2.94 ■ 397 12482 0 _ 0.01 4 0 2.93 Lt. Deposits. ' Penetration Body ' Metal Loss Body 1 1 1 1 1 1 1 1 1 Page 9 1 1 I KUP ConocoPhillips 8 Gv . Attributes CO & MD TD WNlbore APIIUWI FI Id Name Well Status Intl(°) M)(txB) 2K -27 Act Mtn (ftKB) cr<iomefrtn 501032038800 KUPARUK RIVER UNIT PROD 72.42 6,142.88 14,037.0 Comment !QS (ppm) Date Annotation End Date KB-Grd 119 Rig Release Date I ••• Well Cone° - 278/1520107:0934 AM SSW, NIPPLE 400 1/13/2009 Last WO: 34.89 9/17/2001 Schematic - Actual Annotation Depth phis) End [Pate Ann0(9800 Last Mod ... End Date Last Tag: SLM 12.820.0 11/25/2009 Rev Reason: GLV C /O, SET PATCH Imosbor 8/15/2010 Casing Strings imam, 'Casing Description String 0... Stung ID ... Top (01(8) Set Depth (f... SA Depth (1VD) ... Stung Wt.. Stung... Stung Top Thrd CONDUCTOR 16 15.062 70.0 150.0 150.0 62.58 H - 40 WELDED 1 ' Casing Desedptlan String 0... String 1D ... Top (018) Set Depth 0... Set Depth (1VD) ... String Wt... String... String Top Thrd SURFACE 75/8 6.875 0.0 6,776.0 3,820.4 29.70 L BTCM C0NOU7a15o Casing Description String 0... String ID _ Tap (RIB) Set Depth (f._ Set Depth (TVD) ... String Wt_ String... String Top lh,d PRODUCTION 51/2 4.950 0.0 12,571.0 6,009.7 15.50 L - 80 LTCM Casing Description Stung 0... String ID ... Top (RIB) Set Depth R... Set Depth (IVD) ... String WL.. String... String Top Thrd NIPPLE. 523 LINER 31/2 2.992 12,571.0 14,037.0 7,357.3 9.30 L-80 EUE8RD I I A Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth p... Set Depth (1VD) ... String Wt.. String ... String Top Thrd TUBING 31/2 2.992 0.0 12,598.0 6,031.2 9.30 L-80 EUE8RD Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT. SURFACE. (WD) Top Ind I 3 001 Top ((KB) gm) r) Description Comment Run Date ID (in) 523 522.9 2.25 NIPPLE CAMCO'DS' 9/15/2001 2.875 3,041 2,554.6 69.82 GAS LIFT CAMCO /KBG- 2- 9/1 /DMY /BTM/// Comment: SUSPECT 10/1/2009 2.900 O 77 LEAK @ 3041' STA 1 7,309 3,994.1 70.29 GAS LIFT CAMCO/KBG-2-9/1/DMY/BTM/// Comment: STA 2 12/14/2005 2.900 I 10,058 4,913.3 69.79 GAS LIFT CAMCO/KBG- 2 -9/1 /DMY /BTM/ // Comment: STA 3 12/14/2005 2.900 11,889 5,566.5 61.89 GAS LIFT CAMCO/KBG-2-9/1/DMY/BTM/// Comment STA4 12/15/2005 2.900 GAS 9 12,492 5,948.1 39.92 PACKER UPPER WEATHERFORD ER PACKER 8/13/2010 1.810 12,494 5,949.7 39.85 PATCH COMBO PATCH/JET PUMP SPACER PIPE 8/13/2010 1.630 12,500 5,954.1 39.67 PUMP JET PUMP (S /N PH -1127, #7 NOZZLE, #7 THROAT) 8/13/2010 2.670 I GAS , LFT• s n.o5 12,502 5,956.2 39.58 PATCH COMBO PATCH/JET PUMP SPACER PIPE 8/13/2010 1.630 12,503 5,956.7 39.56 GAS LIFT CAMCO/KBG -2 -9/1 /OPEN / /// Comment STA 5 8/13/2010 2.900 12,540 5,985.2 38.34 PACKER LOWER WEATHERFORD ER PACKER 8/13/2010 1.900 • GAS LIFT, 12,542 5,986.8 38.27 NIPPLE CAMCO'DS' NIPPLE W/2.812 NO GO PROFILE 9/15/2001 2.812'. ii 889 ' 12,581 6,017.7 36.29 SEAL BAKER 80 -40 GBH -22 SEAL ASSEMBLY 9/15/2001 3.000 12,582 6,018.5 36.27 CSR BAKER 80-40 GBH -22 CASING SEAL RECEPTACLE 9/15/2001 4.000 PACKER. 13,019 6,386.4 28.21 CMT PLUG DUMP /BAIL 5 GALLONS OF CEMENT ON TOP OF 11/1/2001 0.000 12,492 't ' ',, , BRIDGE PLUG 11 /1/01 13,020 6,387.3 28.19 PLUG WEATHERFORD 3.5" CAST IRON BRIDGE PLUG, 10/21/2001 0.000 PATCH,12 496 W/10,000# RATING set 10/21/01 i PUMP,12,500 13,327 6,667.4 18.24 NIPPLE 13,890 7,212.6 10.57 FLOAT HES'X'NIPPLE w/2.812 PROFILE 9/15/2001 2.812 FLOAT COLLAR 9/15/2001 2.992 COLLAR 13,891 7,213.6 10.57 FISH 3.5" ER PACKER ANCHOR 7/19/2009 1.000 i GAS LFT. '2'503 Perforations & Slots PATCH, 12,502 lop (7VD) Bh Shot n (1VD) Dens Top (NB) Elm (MB) MEE) ( Zone Date (sh.. lype Comment PACKER 12,540 ' 12,748 12,762 6,154.8 6,166.2 C -4, 2K -27 4/30/2003 6.0 APERF ZONE C-4 - 2.5" HSD 2506 PJ, 60 deg phase I NIPPLE, 12,542 12,774 12,794 6,176.1 6,192.6 A -4, 2K -27 11/7/2001 4.0 IPERF 2.5" HSD BH Chgs, 180 deg phase 12,774 12,794 6,176.1 6,192.6 A -4, 2K-27 12/18/2002 6.0 RPERF 2.5" HSD, BH Chrgs, 60 Deg phase Stimulations & Treatments PRODUCTION. Bottom 0-72,571 Mn Top Max Btm Top Depth Depth I 7D, 12,571 Depth Depth (1VD) (ND) 1 8 ) (feKt) ( ) TVD) lYP! Date Comment 12,774.0 12,794.0 6,176.1 6,192.6 FRAC 11/15/2001 INITIALA &C SAND FRAC, 107,000# 16/20 SUB. 12,580 CARBOLITE, 7.4 PPA ON PERFS 12,774.0 12,794.0 6,176.1 6,192.6 RE -FRAC 12/23/2002 207 ,221# OF 1620 PROPPANT PUMPED BEHIND SEAL 12,581 THE PIPE W /10 PPA ON PERFS 1 CSR. 12582 / _ I ( APERF. 12,748 - 12,762 IPERE. 1 2,774 - 12794 RPERF, 12.77412.794 FRAC. 12.774 RE-FRAC. I 12.774 CMT PLUG, Npr Npro 13.019 Abu I PLUG, 13.020 - ` 1 __ NIPPLE. 13.327 i, I FLOAT y p i COLLAR, 0 3.890 FISH.13.891 I t I LINER, 12,571-14037 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2K-27 Run Date: 7/12/2009 August 11, 2009 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 2K-27 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20388-00 w .~ , ~;a, ~ ~ ~C~~~~ 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 ~ `~~ ' ~~~ Date: S~.P 0 1 2009 ~.~~sk~ 4~ik t~~ C~~s Garis. ~c~m^~rii~~ic~~s ~ ~nch~r~ge~ ~~~~~~ 1`6~/~`~ Signed: _ ConocoP hffffps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ~~~~ AU ~ ~ ~ 20fl$ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECEIVEp AUG 2 5 2008 Alaska OiI & Gas Cons, Com~i,,;an Anchor~ga ab~-t~9 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. 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 corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle ~ ~ ~ ~( Y' ~ ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ ./ Date Kuparuk Field ell Name TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date O/"1 Corrosion inhibitor //LVVif Corrosion inhibitor/ sealant date ft bbls ft al 2H-05 185-168 SF N/A SF N/A 5.10 8/2/2007 2H-17 200-019 6" N/A 6" N/A 1.27 8/2/2007 21<-27 201-169 10" N/A 10" N/A 8.92 8/2!2007 2M-03 191-141 16" N/A 16" N/A 2.13 8/2/2007 1 B-14 194-030 SF N/A SF N/A 1.70 8/13/2008 1 B-18 194-061 9" N/A 9" N/A 8.07 8/13/2008 1 B-19 194-064 SF N/A SF N/A 5.10 8/13/2008 16-20 203-115 21" N/A 21" N/A 5.95 8/13/2008 1 B-101 203-133 3" N/A 3" N/A 1.00 8/17/2008 1 B-102 203-122 4" N/A 4" N/A 1.00 8/17/2008 1Y-05 183-087 6" N/A 6" N/A 1.27 8/13/2008 1 Y-07 183-068 6" N/A 6" N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A SF N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 2.12 8/13/2008 1Y-26a 188-116 SF N/A SF N/A 3.83 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 204-091 14" N/A 14" N/A 5.95 8/17/2008 1 E-119 204-031 14" N/A 14" N/A 4.67 8/17/2008 1 E-121 204-246 6" N/A 6" N/A 1.00 8/17/2008 1 E-123 204-074 5" N/A 5" N/A 1.00 8/17/2008 • ALL L Ti~ANSM/TT~4L fit. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Ca(iper%~MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ~'X~ /- /!og ~ 'l5 '2~5 ~~ 1) Caliper Report / IVITT 11,Jan-08 2K 27 1 Report / E~ 50-103-20388-00 2) ,. Signed . Date ~~. ~ ~~ ~`'`'I` ~~ ~, „ Print Name: ~~~ i 1,~-1-n P ah rn ~,[.p PROACTIVE DIAGNOSTIC SERVES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8851 FAX: (9071245-88952 E-MAIL : pdsanchorape(a~memorViog com WEBSITE : ww~N.rr~emory6og.corn D:Uvlaster_Copy_00_PDSANC-20~oc\Z_Word\DistribuQon\Transmittal_Sheets\Ttansmit Otiginal_New.doc ! ~ Memory Multi-Finger Caliper &MTT Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2K-27 Log Date: January 11,2008 Field: Kuparuk Log No.: 9527 State: Alaska Run No.: 1 API No.: 50-103-20388-00 Pipet Dese.: 3.5" 9.3 fb. L-80 EUE 8RD Top Log Intvl1.: Surtace Pipet Use: Tubing Bot. Log Intvl1.: 12,446 Ft. (MD) Pipet Desc.: 5.5" 15.5 Ib. L-80 LTCM Top Log Intvl1.: Surtace Pipet Use: Production Casing Bot. Log Intvl1.: 12,394 Ft. (MD) Pipe3 Desc.: 7.625" 29.7 Ib. L-80 BTCM Top Log Intvl1.: Surface Pipe3 Use: Surface Casing Bot. Log Intvl1.: 6,680 Ft. (MD) Pipe4 Desc.: 16" 62.5 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe4 Use: Conductor Bot. Log Intull.: 119 Ft. (MD) Inspection Type : Mete/ Loss to Tubing and Production Casing COMMENTS The caliper and MTT data are tied into the Casing Hanger @ 0'. This is the first log of this well made with the Multi-Finger Caliper and 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total thickness of metal of the 3.5" tubing, 5.5" production casing, and 7.625" surface casing with some influence from the 16" conductor pipe. A pass at 8Hz was made at 20 fpm, providing high quality data below the interval of 7.625" casing and fair quality data within the interval of 7.625" casing, where it was decided that data filtering was not required. INTERPRETATION OF CALIPER LOG RESULTS This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing logged is in good condition with respect to corrosive damage. No significant wall penetrations (>20%), areas of significant cross-sectional metal loss, or significant I.D. restrictions are recorded. 3,5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded throughout the tubing logged. 3,5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 7%} are recorded throughout the tubing logged. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. INTERPRETATION OF MTT LOG RESULTS A log plot of the MTT recordings at 8Hz ftom surface to 200' is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool, which includes both the ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: {281) er (888) 565-9085 Fax: {281) 565-1369 E-mail: PDS:g;memorylog,com Prudhoe Bay Field Office Phone: {90?} 659-2307 Fax: {907) 659-2314 ~~'~~o-l ~l~s~ ' • tubing and casing strings. The MTT recordings indicate increased noise upon entering the interval of additional metal volume from the 7.625" surtace casing. A maximum of 12% circumferential metal loss is recorded between 36' to 42'. Circumferential metal loss of 3% to 5% is re~rded in the interval between 16' and 30'. Circumferential metal loss of 5% to 8% is ' indicated over the interval from 50' to 57'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5", 7.625" and 16" pipe. If all of the metal 1 loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing, 5.5" production casing or 16" conductor. ' Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (12,151'}, where the readings are ' assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" production casing, 7.625" surtace casing, and 16" conductor pipe. Field Engineer: S. Carpenter Analyst: M. Lawrence/H. Yang/J. Burton Witness: C. Fitzpatrick ' ProActive Diagnostic Services, Inc, / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (0.1' - 12436.9') Well: 2K-27 Field: Kuparuk Company: Conoco Phillips Alaska, Inc. Country: USA Survey Date: January 11, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 3 50 1537 GLM 1 100 3106 150 4652 ~ 200 6185 .: ~ .c Z s GLM 2 a ~ ~ 250 7750 300 9291 GLM 3 350 10839 GLM 4 GLM 5 400 12 437 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 400 • • PDS Report Overview ~ ~M Body Region Analysis Well: 2K-27 Survey Date: January 11, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: B. i Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body tti~ metal loss body 400 300 200 100 0 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of'oints anal sed total = 415 pene loss . 0 297 84 331 118 0 0 0 0 0 0 0 Damage Configuration (body ) 40 30 20 10 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 33 33 0 0 0 0 Damage Profile (°~ wall) ~ penetration body ~,,,, metal loss body 0 50 100 0 GLM 1 195 GLM 2 2 93 GLM 3 GLM 4 389 AIM 5 Bottom of Survey = 400 Analysis Overview page 2 • . PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 11, 2008 Joint No. Jt. Depth (Ft.) I'~•n. I tlsc•t Ilns.) Pen. Body (Ins.) Pcn. % ~1c•lal I iris ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 0 O 0.01 4 1 2.94 PUP 1 3 i~ 0.03 I~ 4 2.91 1.1 34 i~ 0.02 ~i I 2.91 PUP 1.2 42 a 0.01 ~ I 2.88 PUP 2 44 ~ ~ 0.03 I 1 ~ 2.92 3 74 ~ ~ 0.03 I I 2.93 4 105 a 0.03 II 7 2.93 5 135 l I 0.03 1< 5 2.94 6 166 tl 0.03 I ~' i I 2.90 7 195 U 0.02 ~~ 1 2.93 8 226 (~ 0.03 I I ~I 2.93 9 56 l) 0.02 ~~ ~~ 2.93 10 286 Ii 0.02 ~i 2.93 11 318 I~ 0.03 11 ~ 2.88 12 349 ~ ~ 0.03 1 I -i 2.93 13 379 a 0.03 11 2.93 14 411 ~ ~ 0.02 ~) I 2.93 1 442 U 0.02 ~) -1 2.93 16 473 (I 0.02 '~ 2.91 16.1 503 ~1 0 i) a 2.88 Ni le 17 506 l ~ 0.02 t3 (, 2.94 18 536 a 0.03 1O 4 2.93 19 567 ~ I 0.03 12 4 2.93 20 597 t) 0.02 '~ 2.92 21 629 Il .02 7 I 2.91 22 660 to 0.01 E~ 2.93 3 692 I ~ 0.01 5 1 2.91 24 723 U 0.02 7 I 2.90 25 75 U 0.02 7 2.92 26 786 cI 0.01 I, I 2.93 27 817 (I 0.01 I~ 2.91 28 848 U 0.02 7 ~' 2.92 29 880 U 0.02 7 _' 2.91 30 911 U 0.03 1 U ? 2.91 31 943 a 0.02 7 2.92 32 974 11 0.02 1 2.93 33 1006 Il 0.01 b ~' 2.91 34 1037 U 0.01 5 1 2.92 35 1069 l? 0.03 II -} 2.93 36 1101 U 0.03 II ~, 2.91 37 1132 U 0.03 II i> 2.93 38 1164 (I 0.02 ~> 2.93 39 1195 ~ ~ 0.02 ~) 2.93 40 1226 lI 0.02 ~) U 2.90 41 1258 ~ I 0.02 t3 1 2.92 42 1287 a 0.03 11 I 2.92 43 1318 ~ 1 0.02 7 2.91 44 1350 i I 0.03 l U ? 2.92 45 1381 ~' 0.0 t3 I 2.90 46 1413 0.01 ~, I 2.93 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 11, 2008 Joint No. Jt.Depth (Ft) I'~~n. Uls~~t (Ins.) Pen. Body (Ins.) I'en. % ~Ic~fal I~~55 ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1443 tt 0.03 11 _' 2.89 48 1475 )1 0.02 I 2.93 49 1506 t t 0.01 (~ I 2.90 50 1537 U 0.03 I ~~ 2.90 51 1569 U 0.02 rs I 2.91 52 1600 ~) 0.02 I 2.9 53 1632 ~t 0.02 ti i 2.92 54 1663 t t 0.02 ~ ~ 1 2.93 55 1694 ~) 0.02 I 2.93 56 1725 )1 0.02 9 2.91 57 1757 ~ t 0.02 - 2.91 58 1788 ~ t 0.01 5 2.91 59 1820 ~) 0.02 2.91 60 1851 l t 0.02 t i 2.92 61 1883 ~ t 0.02 7 2.92 62 1914 i t 0.02 2.90 63 1946 ~) 0.01 r, 2.93 64 1977 ~ t 0.02 - 2.93 65 2008 ~~ 0.01 (~ 2.92 66 2039 (1 0.02 FS 2.91 67 2070 a 0.01 t> 2.92 68 21 1 ~ t 0.02 ~ t t 2.93 69 2133 ~ 1 0.02 7 :.' 2.90 70 2167 ~) 0.02 9 1 2.93 71 200 ) t 0.02 ti I .9 72 2232 a 0.03 12 I 2.92 73 2260 i t 0.03 I I 2.90 74 2291 ~) 0.01 i, I 2.92 75 2328 U 0.03 12 2.92 76 2353 U 0.02 ~) I 2.91 77 2385 t t 0.02 ~+ I 2.91 78 2416 i t 0.02 1 2.91 79 2442 t) 0.02 'i -t 2.91 80 472 a 0.02 f 9 2.91 81 2502 tt 0.02 ti 1 2.92 82 2532 O 0.02 ~) ~ 2.93 3 2562 )) 0.03 L- 2 2.91 Shallow itlin . 84 2594 ct 0.02 7 ' 2.91 85 2625 U 0.03 II a 2.91 86 2656 (t 0.03 11 _' 2.93 87 2687 ct 0.03 Itt 2.93 88 2718 ~! 0.03 11 _' 2.91 89 749 i t 0.03 I I 2.92 90 2781 ~t 0.03 I U ~' 2.91 91 811 n 0.01 ~ 3 2.92 92 2842 a 0.03 1 U _' 2.91 93 2873 ~ ~ 0.03 11 2.92 94 2904 ~t 0.02 ~) ~ 2.91 95 2935 0.03 I I 2.92 ~i(~ 2966 0.03 I ~ ! 2.92 Penetration Body Metal Loss Body Page 2 i • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiBips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: January 1 1, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ulnc~t (Inti.j Pen. Body (Ins.) I'e~n. `%~ ~1c~t,il 1u5~ ",~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96.1 2996 a 0.03 13 3 2.94 PUP Shallow it6n . 96.2 3002 tl 0 0 t) N A GLM 1 Latch @ 1:30 96.3 3009 t ~ 0.03 12 5 2.95 P P 97 3014 i ~ 0.02 ~~ 1 2.92 98 3045 t ~ 0.03 1,' 3 2. 3 99 3076 (~ 0.03 12 2 2.91 100 3106 t~ 0.04 15 ~~ 2.93 hallow itUn . 101 3137 i~ 0.02 8 2.92 102 3168 t ~ 0.02 9 2.94 103 3199 i i 0.0 8 t 2.92 104 3230 !! 0.03 13 ~ 2.91 Shallow itUn . 105 3262 i i 0.02 ~) i 2.93 106 3292 i~ 0. 4 17 4 2.91 Shallow it6n . 107 3323 it 0.03 l ~ 2.91 Shallow ittin . 108 3354 a 0. 3 11 t~ 2.92 109 3385 i ~ 0.03 1 Z 2.92 110 3416 i ~ 0.03 1 I 2.91 111 3447 i ~ 0.02 7 ' 2.92 112 3478 t ~ 0.03 1 ~ 2.90 113 3509 U 0.03 12 2.91 114 3539 tl 0.02 ~) 1 2.91 115 3570 U 0.04 15 4 2.90 Shallow itbn . 116 602 t ~ 0.02 fi 2 2.90 117 3633 t) 0.02 ti _' 2.90 118 3 63 t ~ .02 7 2.94 119 3694 i ~ 0.02 £3 ,' 2.91 120 3724 ~ ~ 0.03 1 U 5 2.91 121 3756 tl 0.03 I ~ 3 2.92 122 3787 U 0.02 fi ~' 2.89 123 3818 t~ 0.02 8 2.95 124 3849 t~ 0.03 11 ~ 2.89 125 3880 t~ 0.02 H 2.91 126 3909 t} 0.04 17 5 2.90 Shallow it6n . 127 3941 U 0.02 ~) t> 2.91 128 3971 t ~ 0.02 9 2.91 129 4003 i ~ 0.03 1 1 ? 2.91 130 4034 U 0.0 9 ' .93 131 4064 c ~ 0.03 1 I ~' 2.91 132 4095 a 0.04 17 6 2.92 Shallow itUn . 133 4127 a 0.04 l U i 2.89 Shallow itUn Lt. De sits. 134 4157 t~ 0.04 15 _' 2.90 Shall ittin . 135 4188 ~ ~ 0.03 1 I (, 2.89 136 4219 i ~ 0.03 1 'I t~ 2.91 137 4251 ! ~ 0.02 9 2.93 138 4282 t~ 0.04 14 ~' 2.93 Shal ow ittln . 139 4312 i ~ 0.02 ~ ~ 0 2.93 140 4343 ! ~ 0.02 tf 1 .95 141 4373 i ~ 0.02 t9 _' 2.90 142 4405 t t 0.02 ' ~ 2.90 ___ 143 4435 ~ t 0.02 ' ~ 2.91 Penetration Body Metal Loss Body Page 3 i • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 11, 2008 Joint No. Jt. Depth (Ft.) I'~•n. Ulxet (In..) Pen. Body (Ins.) Pen. °/~ Mct,~l I cxs ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 144 4466 a 0.02 7 2.91 145 4497 t) 0.02 8 ~' 2.96 146 4528 t) 0.03 I ~ 5 2.91 147 4559 U 0.02 ~) 5 2.90 148 4590 t ! 0.03 1 1 -l 2.92 149 4621 t! 0.04 1 5 I 2.92 Shallow ittin . 150 4652 ~ ! 0.02 ~) ~ ~ 2.92 1 1 4683 a 0.03 I I (, 2.93 152 4712 U .03 12 2.91 Shallow ~tUn . 153 4742 tl 0.02 ~) ~7 2.93 154 4772 U 0.02 7 S 2.93 155 4802 tl 0.03 1 U 4 2.92 156 4833 t! 0 01 ~ I 2.92 157 4864 I! 0.02 ~~ (, 2.91 158 4895 U 0.03 I1 t, 2.91 159 4926 O 0.02 ' ~ ~ 2.93 160 49 7 U 0.02 ~) ~l 2.93 161 4987 U 0.0 ~) 4 2.92 162 5018 t1 0.03 I I -1 2.94 163 5049 a 0.02 ~( -( 2.93 164 5080 t! 0.03 I < -l 2.92 1 5 5110 U 0.03 l U 2.92 166 5141 a 0.03 I u 2.95 167 5170 i? 0.02 t4 -i 2.90 16 5201 t! 0.02 8 2.91 169 5232 t! 0.02 ~) _' 2.90 170 526 t1 0.03 11 1 2.92 171 5294 t! 0.02 ~! ~ 2.91 17 5325 a 0.02 ! 2.91 173 5356 ~) 0.02 £3 2.95 174 5387 !! 0.02 £3 2.89 175 5418 i ~ 0.02 8 I 2.94 176 5448 t 1 0.02 I 2.94 177 5479 O 0.02 i _' 2.90 178 5510 U 0.02 £3 a 2.90 179 5539 t! 0.02 7 I 2.92 180 5570 ~! 0.02 £3 I 2.91 181 5601 a 0.03 I t) a 2.94 182 5632 t! 0.02 2.91 183 5662 t! 0.02 - I 2.91 184 5692 U 0.02 7 1 2.91 185 5722 a 0.02 7 <' 2.91 186 5753 U 0.02 7 _' 2.89 187 5784 t! 0.02 £3 2.90 Lt. De its. 188 5815 t) 0.03 lU _' 2.94 189 5846 i! 0.02 £3 2.93 190 5877 a 0.02 ~! 2.92 191 5907 (! 0.02 t3 I 2.91 192 5938 (~ 0.03 I t! _' 2.88 193 5969 0.03 It! ~ 2.89 _ Penetration Body Metal Loss Body Page 4 ' • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 93 ppf L-80 Well: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. ' Nominal I.D.: 2.992 in Country: USA Survey Date: January 11, 2008 Joint No. Jt. Depth (Ft.) F'en. Upset (Ins.} Pen. Body (Ins.) Pen. "r<, ~telal I oss °i~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 194 6000 U 0.02 ~) ! 2.91 195 6032 ~) 0.02 £~ 2.90 96 6062 (~ 0.02 f f Z 2.89 197 6093 II 0.03 III -£ 2.91 198 6124 I~ 0.03 ll 2.93 199 6154 i) 0.03 11 1 2.93 200 6185 U 0.04 15 2.91 Shallow itUn . 201 216 U 0.02 ~) I 2.89 202 6247 U 0.03 1 u ~' 2.91 203 6278 U 0.02 7 ~ 2.91 204 6309 U 0.02 8 2.92 205 6340 t) 0.03 12 ~' 2.90 206 6372 tl 0.02 7 2.92 207 6401 ! ? 0.03 I I 2.90 208 6433 II 0.02 ~ 2.91 209 6463 U 0.02 ~ I 2.90 210 6494 O 0.02 tt ~' 2.90 211 6526 tl 0.01 t, 1 2.9 212 6556 I) 0.02 2.92 213 6587 I) 0.01 (~ ' 2. 0 214 6619 a 0.02 7 1 2.92 215 6650 U 0.01 E~ ~ 2.91 216 6681 U 0.02 7 t) 2.92 217 6712 I) 0.01 6 2.90 21 6743 i) 0.02 ~) 1 2.91 219 6774 I) 0.03 13 1 2.91 Shallow ittin . 2 6805 t ~ 0.01 ~ 2.91 221 6836 a 0.02 tf _' 2.92 222 6867 t } 0.03 1 U I 2.93 223 6897 n 0.02 t3 ~ 2.93 224 6928 U 0.02 ~~) 6 2.92 225 6958 (I 0.02 ti 2 2.92 226 6989 l) 0.02 i 2 2.91 227 7020 U 0.02 ~I ~' 2.90 228 7051 U 0.02 ~ 2.91 229 7082 U 0.02 ~ I 2.91 230 7114 U 0.0 7 ~ .91 231 7145 U 0.02 8 1 2.91 232 7175 t) 0.03 tU ? 2.92 232.1 7207 a 0.01 v 1 2.94 PUP 232.2 7211 u 0 U I) N A GLM Latc ~ 11:1 232.3 7219 U 0.02 ~> 3 2.94 PUP 233 7225 U 0.03 I ~' 2.91 234 7256 !! 0.02 2.92 235 7287 i ~ ! I-i 0.03 I I 2.93 236 7318 t I 0.03 1 I 2.91 237 7349 U 0.02 ~~ _> 2.92 238 7380 ti 0.03 Il) 2.91 239 7411 a 0.03 I I 2.91 _ 240 7442 t) 0.03 IU _' 2.92 Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 WeU: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: Nominal I D : 0254 in 2 992 in Company: ConocoPhilips Alaska, Inc. . . . Country: USA Survey Date: January 11, 2008 Joint Jt. Depth I'cvr. Pen. Pc~n. ~t<~t.rl Min. Damage Profile No. (Ft.) Ulrsc~t Body % I r,~~ LD• Comments (% wall) (InS.j (Ins.) °~~ (Ins.) 0 50 100 7d1 7A7Z n n n~ 242 - 7504 a 0.01 6 1 G.JJ .92 243 7534 a 0.04 16 ~ 2.92 Shallow it6n . 244 7565 a 0.03 I U 2.92 245 7596 U 0.0 ~) 1 2,91 24b 7627 ~) 0.02 9 2.92 247 7658 (r 0.02 7 2.91 248 7689 U 0.03 12 ~ 2.92 249 7720 U 0.02 9 ~ 2.91 50 7750 i) 0.03 1 I ~' 2.92 251 7781 rr 0.03 11 .93 25 7812 a 0.03 1 t) _' 2.93 53 784 O 0.03 11 ~ 2.91 254 7873 r) 0.0 13 _ 2.93 Shallow itUn 55 7904 n 0.03 1 U 4 2.93 . 256 7935 ~) 0.02 9 4 2.91 257 7 65 r) 0.03 1 1 ~ 2,92 258 7996 i t 0. 3 l U 2,91 259 8027 O 0.03 13 _' 2.93 Shallow i Un . 260 8058 U 0 03 12 2.93 261 8089 U 0.02 7 s 2.92 262 8120 l) 0.02 t3 1 2.89 263 81 1 U 0.02 9 ? 2,g0 264 8182 O 0.02 ~) 2.91 26 8213 O 0.02 ~ I 2.90 266 8244 ~) 0.02 7 _' 2.89 267 8274 U 0.03 12 4 2.91 268 8305 c) 0.02 t3 1 2.90 269 8335 O 0.02 9 2,8g 270 8366 O 0.02 7 I 2.91 271 8396 U 0.02 t3 2.90 2 72 8426 O 0.02 ti 2.96 273 8457 a 0.01 ~ 2.89 2 74 8488 U 0.0 ~ ~ 2.90 75 8519 O 0.0 t3 I 2.91 276 8549 n 0.02 y I 2.90 277 8580 U .02 t3 2.95 278 8610 U 0.02 7 ~ 2.g9 79 8642 a 0.01 4 ~ 2.89 280 8673 a 0.03 12 ! 2.90 281 8703 U 0.02 ti .94 282 8734 U 0.02 ~) ~ 2.92 283 8765 a 0.02 ~_) ~~ 2.92 284 8796 O 0.03 11 5 2.92 2 5 882 7 U 0.02 ~~ -1 2.92 286 8859 (r 0.02 ~~ 2.91 287 8889 ~) 0.02 t3 ~ 2.90 288 8920 O 0.02 ti ~ 2.92 289 8952 a 0.02 ti I 2.91 290 8983 U 0.03 11 2.93 Penetration Body Metal Loss Body Page 6 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 WeA: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiYips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 11, 2008 Joint No. Jt. Depth (Ft.) I'~•n. l llxei Iln~.} Pen. Body (Ins.) Pen. %> ~I~~I,~I L~n~ ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 291 9013 U 0.03 12 2.92 292 9045 a 0.02 ~) 2.92 293 9076 ~) 0.03 1 '1 2.93 94 9106 t? 0.01 6 I 2.93 295 9137 ~? 0.03 Il 2.92 296 9168 ~~ 0.03 II 2.92 297 9198 ~~ 0.02 ~? 2.94 298 9230 ~~ 0.03 1:3 I 2.91 Shallow ittin . 299 9261 ~~ 0.03 1 U ~ 2.93 300 9291 t~ 0.03 10 2.93 301 932 t7 0.03 11 ~' 2.92 302 9353 t) 0.02 7 2.91 303 9384 U 0.03 12 ~ 2.93 304 9414 ~ I 0.03 1 U ? 2.92 305 9445 U 0.02 9 ~' 2.96 306 9476 i ~ 0.03 1 1 2.96 307 9506 ! ! 0.03 I U 2.91 308 9538 ~ ~ 0.03 1 U 2.95 309 9568 ~ ~ 0.03 I l) 2.93 310 9599 U 0.02 U 2.94 311 9630 U 0.03 1 f) 2.92 312 9661 0 0.03 10 I 2.93 313 9691 t) 0.02 9 4 2.95 314 9722 U 0.02 9 ~' 2.90 315 9753 t~ 0.02 f3 ~' 2.92 316 9783 n 0.02 £i 2.90 317 9814 ~ ~ 0.04 1 5 -I 2.92 Shallow ittin . 318 9845 ~ ~ 0.02 t3 ~' 2.95 319 9876 t) 0.03 1 U 2.95 319.1 9906 (~ 0.02 8 ~ 2.89 PUP 319. 9911 U 0 U U N A GLM 3 Latch C~ 5:45 319.3 9920 ~1 0.01 2 I 2.93 PUP 320 9924 U 0.03 12 ~ 2.91 321 9955 ~~ 0.02 f3 ~ 2.93 322 9986 ~~ 0.02 t3 1 2.90 323 10017 U 0.03 I2 2.95 324 10048 t I 0.02 _' 2.91 325 10078 l~ 0.03 1 Z 2.90 326 1011 0 ~ ~ 0.02 7 I 2.92 327 10140 ~? 0.03 I i 2.91 Shallow itUn . 328 10171 ~ ~ 0.03 I U 2.91 329 10202 ~! 0.03 1~~ 2.94 330 10232 ~? 0.02 E3 2.91 331 10262 ~ ~ 0.01 5 I 2.91 33 10293 a 0.01 > 2.91 333 10324 U 0.03 lU I 2.93 334 10355 U 0.01 6 ,' 2.89 335 10386 t~ 0.02 7 I 2.94 336 1041 6 ~ ~ 0.03 12 2 2.90 Shallow ittin . 337 10447 li 0.03 10 _' 2.90 Penetration Body Metal Loss Body Page 7 s • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 11, 2008 Joint No. Jt. Depth (Ft.) I'~•n. Ill~se) (Ins.) Pen. Body (Ins.) Pen. %, ,~tet,vl Ic~ss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 338 10478 t) 0.02 t3 2.91 33 10509 O 0.03 11 2.95 340 10540 I) 0.02 ~) ~' 2.89 341 10570 t ~ 0.04 I.1 'i 2.91 Shallow ittin . 342 10600 O 0.02 ti 2.96 343 10627 (1 0.02 7 _' 2.89 344 10658 O 0.02 ti ! 2.95 345 10688 O 0.03 II _' 2.89 346 10719 l) 0.02 ~) ; 2.92 347 10748 l) 0.04 15 -1 2.95 Shallow it ~n . 348 10778 (~ 0.03 1 i I 2.90 349 1080 9 (~ .02 t; 2.94 350 10839 t) 0.02 ~~ 2.92 351 10871 c) 0.02 ~> 2.95 352 10900 c) 0.03 1U ~' 2.92 353 10931 U 0.02 t3 ? 2.91 354 10961 l) 0.04 I (~ a 2.89 Shallow ittin . 355 10992 O 3 I (t 3 2.91 356 11022 n 0.02 ~) 2 2. 6 357 11052 a 0.01 G 1 2.92 358 1 1082 ~) .03 1 ; Z 2.88 Shallow ittin . 359 11114 U 0.03 l l I 2.89 360 11144 U 0.02 F3 Z 2.95 361 11174 I) 0.03 1 ; 2.89 Shallow itti 62 11206 O 0.0 t3 2.90 363 11236 a 0.02 t; 2.94 364 11 66 l) 0.02 ~~ 2.90 365 11297 O 0.03 1u 2 2.92 366 1 132 6 U 0.0 ~i 2 2.90 367 11356 n 0.02 E3 2 2.95 368 11387 I) 0.02 ~j 2 2.90 369 1 141 7 i ~ 0.04 14 _' 2.90 Shallow ittin Lt. De osits. 370 11448 ) ~ 0.03 I Z 2 2.90 Shallow corrosion. 371 11479 a 0.03 11 ~' 2.94 372 11510 !1 0.02 t3 _' 2.94 373 11540 U 0.04 14 5 2.92 Shallow itUn . 374 11571 U 0.0 ~) ~' 2.91 375 11602 U 0.02 9 ; 2.91 376 11632 U 0.03 12 2 2.89 377 11663 U 0.03 11 ~' 2.93 377.1 11694 O 0.02 t3 2 .96 PUP 377.2 11698 u 0 O O N A GLM 4 Latch @ 8:00 377.3 11704 U 0.04 14 -! 2.90 P P Shallow ittin . 378 11710 I ~ 0.02 E3 2.94 379 11740 a 0.02 t) 2.95 380 11771 a 0.01 4 _' 2.91 381 11802 U 0.02 ti 1 2.96 382 1 1831 O 0.01 5 2.89 383 11861 ! ! 0.02 2.89 384 11892 ~? 0.03 I 2.90 Shallow ittin . Penetration Body Metal Loss Body Page 8 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2K-27 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 11, 2008 Joint No. Jt. Depth (Ft.) Pc~n. I llxc,t Ih~s.) Pen. Body (Ins.) Pen. "4, McLrl I c,« °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 SO 100 385 1192 3 t I 0.02 ~ -1 2.94 386 11953 (l 0.03 12 ? 2.92 387 11984 t~ 0.02 I 2.89 388 12015 t t 0.02 ti I 2.95 389 12045 tt 0.02 ti _' 2.90 390 12076 n 0.02 8 2.89 391 12106 U 0.02 7 I 2.90 392 1213 7 U 0.03 1 I ~ 2.91 393 12167 tl 0.02 ~~ 2.91 394 12199 U 0.02 t3 ~ 2.94 395 1222 9 U 0.02 8 ? 2.93 396 12260 tt 0.03 12 ~ 2.90 396.1 12291 t t 0.01 t~ I .95 PUP 396.2 12295 a (1 u N A GLM 5 Latch @ 1:00 396.3 12300 a 0.03 1 tt _' 2.93 PUP 397 12308 tt 0.02 t3 .94 397.1 12337 i? 0 U rt 2.81 Ni le 398 12341 t? 0.02 9 ? 2.95 398.1 12370 !t 0 0 t) 3.00 Ni le 398.2 12371 i) 0.01 ? 2.94 PUP 398.3 12375 U 0 U u N A Seal 398.4 12394 ~~ 0 U u N A CSR 398.5 12397 a 0.03 1l) I 2.91 PUP 399 12407 a 0.03 13 I 2.91 Shallow ittin . 124 7 t) 0.02 9 ~ 2.89 Penetration Body Metal Loss Body Page 9 • Average Recorded Metal Thickness Relative to Calibration Point Pipe 1 3.5 in (0.1' - 12436.9') Well: 2K-27 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: January 11, 2008 ^ Decrease 1 50 GLM 1 100 150 .~ 200 Z _ GLM 2 C 250 300 GLM 3 350 GLM 4 GLM 5 1537 3106 rnne Potential Exaggeration Due to Noisy Data 4652 6185 Bottom of ; 5%$" CasinK .c Y O 7750 ')~ 91 10839 400 12437 Change in Melal Thickness ('%) ^ Increase I~Ottt7nl Ol SUf4'ey = 400 Magnetic Thickn~ Log (8Hz) January 11, 2008 Surface to 200' PRd~C1IVE ~I/1gNO67IC SERVICES.. I~. Database File: d:lwarriorldatal2k-2712k-27.db Dataset Pathname: 2k-27.1 Presentation Format: 3.6 scale Dataset Creation: Mon Jan 1413:50:37 008 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:150 0 MTT Frequency (Hz) 20 3.6 MTTP01 (rad) 13.G -50 MPCMN (%} 50 -5.2 MTTP12 (rad) 4.$ 0 Line Speed (ftlmin) -200 ~ a Tree 5" 5" Casing 5" Metal Loss Hanger Jt. 1 20 ~~ -; -12% Metal Loss Pup Jt. 1.1 ~ ~ 3.5" Colla ~' Ca sin g Co llart i --~ I i -- 3 5" Coll ar Pu - . ~ 7 625" C ll . o ar 8% Metal Loss Jt. 2 60 5" Collar 80 '-C}a-sing Collar I I Jt. 3 • • ConacoPhiltips Alaska, Inc. KRU 2K-27 2K-27 - API: 501032038800 Well T : PROD An le TS: 34 d 12747 TUBING lalzssa, OD:3 500 SSSV Type: Nipple Orig Com letion: 9/17/2001 Angle @ TD: 9 deg @ 14037 . , ID:2.992) Annular Fluid: Last W/O: Rev Reason: Tag, GLV C/O, Set TBG PKR PUMP Reference L Ref L Date: Last U ate: 1/2/2006 last Ta : 12888 TD: 14037 ftKB Last Ta Date: 12/11/2005 Max Hole An le: 72 d 6143 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grede Thread CONDUCTOR 16.000 0 150 150 62.58 H-40 WELDED SURFACE 7.625 0 6776 3820 29.70 L-80 BTCM PRODUCTION 5.500 0 12571 6010 15.50 L-80 LTCM LINER 3.500 12571 13988 7309 9.30 L-80 EUE8RD Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 12598 6032 9.30 L-80 EUE8RD Perforations Summa - Interval TVD Zone Status Ft SPF Date T Comment 1 12748 - 12762 6154 - 6166 C-4 14 6 4/30/2003 APERF 2.5" HSD 2506 PJ, 60 deg hase I' I 12774 - 12794 6176 - 6193 A-4 20 10 12/18/2002 RPERF 2.5"HSD, BH Chrgs, 60 D hase - Stimulations 8 Treatments I Interval Date T Comment I 12774 - 12794 11/15/2001 FRAC INITIAL A&C SAND FRAC, 107,000# 16/20 CARBOLITE, 7.4 PPA ON PERFS ~ 12774 - 12794 1223/2002 RE-FRAC 207,221# OF 16/20 PROPPANT PUMPED BEHIND THE PIPE W/10 PPA ON PERFS -~ Gas Lift Mandrels/Valves PUMP St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv 1248612511, r I :~ Mfr Run Cmnt oD:z.74o) t , 1 3041 255 3 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 3/4/2002 1 2 7309 399 4 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 2/14/200 3 10058 491 3 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 2/14/200 I 4 11889 556 7 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 2/15/200 5 12503 595 7 CAMCO KBG-2-9 DPHFCV 1.0 BTM 0.000 0 2/17/200 1. Sus ecr leak 3041' Other lu s ui .etc. -JEWELRY De th TVD T e Descri Lion ID 523 523 NIP CAMCO'DS' NIPPLE 2.875 12486 5944 PUMP SET STRADDLE JET PUMP ASSEMBLY W/TTS PACKER (TTS PACKER, SPACER PIPE, JET PUMP (SER. PH-1127 / # 7 NOZZLE ! # 7 THROAT ), X-OVER, SHEAR JOINT, SPACER PIPE, AND ANCHOR===25' OAL) IN LOWER ECLIPSE PACKER @ 12511' RKB TOP TTS PACKER 12486' RKB .12/20/2005 0.000 12511 5963 PACKER THRU-TUBING ECLIPSE PACKER set 12/16/2005 1.812 12542 5987 NIP CAMCO 'DS' NIPPLE W/2.812 NO GO PROFILE 2.812 12580 6017 NIP BAKER NO GO SUB 3.000 12581 6018 SEAL BAKER 80-40 GBH-22 SEAL ASSEMBLY 3.000 12582 6019 CSR BAKER 80-40 GBH-22 CASING SEAL RECEPTACLE 4.000 SEAL 13019 6386 CMT DUMP/BAIL 5 GALLONS OF CEMENT ON TOP OF BRIDGE PLUG 11/1/01 0.000 1zss1-lzsaz, OD 400°) 13020 6387 PLUG WEATHERFORD 3.5" CAST IRON BRIDGE PLUG, W/10,000# RATING set 10/21 /01 0.000 pert 13327 6667 NIP HES'X' NIPPLE w/2.812 PROFILE 2.812 m48-12762) _-- --- 13890 7213 COLLAR 2992 RE-FRAC > 1277412794) CMT 13019-13020, OD:3 500) PLUG 130'1413021, OD:3.500) Ç) Se~luIIbepgep RECE\\/ED NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NO\! 1 3 lOnG Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 !'11~¡¡;} I'~ G~GOOS, (~rJromi~ AI1COOf~ ()61-/~q Field: Kuparuk Well Job# Log Description BL Color CD Date 1 R·26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G..16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2P-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE WIDEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 21.:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kp27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 11/10/06 . . . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc RECEIVE DEC 2 6 2005 ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSlaska Oil & Gas Con;;, e Repair Well 0 Pull Tubing 0 Operat. ShutdownD Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 149' 1. Operations Performed: 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 14037' 7357' STATE OF ALASKA e true vertical measured true vertical Length Size Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Stimulate 0 Waiver 0 Time Extension 0 o 150' 6627' 12422' 1417' 16" 7-5/8" 5-1/2" 3-1/2" Other Re-enter Suspended Well Exploratory Service o o 5. Permit to Drill Number: 201-1691 6. API Number: 50-103-20388-00 Measured depth: 12748-12762'; 12774-12794' true vertical depth: 6154-6166'; 6176-6193' 9. Well Name and Number: 2K-27 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD - Burst Collapse 150' 6776' 12571' 13988' 150' 3820' 6010' 7309' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12598' MD. 8~Nf:U 7G 8 2G(15 Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 523' 12. Stimulation or cement squeeze summary: NA Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 15 142 Not available Not available 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 GasD WAG 0 GINJ 0 WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: NA 13. Oil-Bbl 109 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Not available Daily Report of Well Operations _X Contact Printed Name Signature Form 10-404 Revised 04/2004 ORIGINAL Casin Pressure Tubin Pressure 210 Not available 1168 Not available WDSPLD Problem Well Supervisor Date Submit Original Only e 2K-27 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary: Convert from GL to Suñace Powered Jet Pump 12/14/2005 PULLED OV AT 12503' RKB, SET DGLV AT 7309' RKB AND 10058' RKB. ATTEMPT TO SET DGLV AT 11889' RKB. SET 2.81" CAT STANDING VALVE AT 12542' RKB. 12/15/2005 SET 1" DV AT 11889' RKB AND 12503' RKB. DISPLACE TUBING AND IA WITH 290 DIESEL. COMBO PT TIIA TO 3000#. MITIA TO 3000#. BOTH TESTS GOOD. PULL "CAT" STANDING VALVE. MITIA: Pre 900/950/150, initial 1 050/3000/375, 15 minute 1050/2950/350, 30 minute 1050/2950/350 psi. 12/16/2005 DRIFT TUBING WI 20' X 2.81" TO DS NIPPLE AT 12542' RKB. DEPTH CORRELATION RUN TO STATION #5 AT 12503' RKB. SET ECLIPSE PACKER AT 12476' SLM. TEST PACKER TO 2500#. 12117/2005 PULL DV AT 12503' RKB AND SET 1" DPHFCV 12/1812005 SET STRADDLE JET PUMP ASSEMBLY WI TTS PACKER ( TTS PACKER, SPACER PIPE, JET PUMP ( SER. PH-11271 # 7 NOZZLE 1#7 THROAT), X-OVER, SHEAR JOINT, SPACER PIPE, AND ANCHOR===25' OAL) IN LOWER ECLIPSE PACKER @ 12511' RKB ( TOP TTS PACKER @ 12486' RKB ). RAN TTS TEST TOOL, TESTED TO 2500 PSI, AND CONFIRMED UPPER PACKER SET AND PUMPED 5 BBLS OF DIESEL DOWN IA WI TBG. COMMUNICATING. Summary MIT-T passed, MITIA passed; Set formation powered Jet pump on patch from 12511-12486' NIP 13327-13328, OD:3.500) CMT 3019-13020, OD:3.500) PLUG 13020-13021, OD:3.500) Perf 12774-12794) Perf 12748-12762) SEAL 2581-12582, OD:4.000) LINER 2571·13988, OD:3.500, Wt9.30) NIP 2542·12543, OD:3.873) ".... -¡ ~..... -~ I .,.-,' i LJ ~ : r -.:5e--t-I'CA.-¡O , I,)..r¡ / - />z~k//~~ J"'1'í ~ /¿Ifß Gas Lilt MandrelNalve 2 (7309-7310, I ?:~.1fI .,.,,&&-. I ....ft·1 ).ot=, I ;'·;;11 ~ ' ) 6387 PLUG 13327 6667 NIP 13890 7213 COLLAR CAMëO ·'DS'NIPl'i.E CAMCO 'Ds'NipPCE Wí?f!J2 Ño GC)"PRmILE BAKEifÑo GO SlÆ' .-. .-- . -- BAKERBO.40GBH=-2? S~AL ASSrMI3Tv .-. BAKER 80·40 C:fRH-27 CAS'ING SÎ'AL r\[-CEPfÃCLE-- DUMPtB/'iiL 5 GALLOÑS OF-C:E~.ilT:NT"õÑ TOï'-ÖF Bi{IDGE pClJG- 11/1/01 WEATHERFORD 3.5" CAST IRON BRIDGE PLUG, W/10,OOO# RATING set 10/21/01 HES 'X' NIPPLE w/2.812 PROFILE 2.812 2.992 ID'-- i:im;- -¡ 2:812 -: 3.000- , 3~iJon ï 4.600 ;- O.OCIO 0.000 , , ~.þesçi)ptiori~~ D'r"W õïv div GI.V ov ; V-CD ~atch I '-'1.Ö-' SiM -- 1.0- , U'fM 1.0-: BTM ; - 1.0 -- B'-iVI . - 1.n ."¡ _BÜ\n Port Date -" , Run . <i.000 -¡ Ij" '3i4/7.fJoi· 6'.1' BH ", 1366 ! "1 i9í?'OO:{ I if:i f!H ", 13!)3 ' 1 !f!/5õ03 ï 0.~50 ~ 1,148 ' 1i5i2Õ03-' n. f~~" I.i--:_. fì~!2Õº:i - Vlv Cmnt 11) = -~ , V Mtr -,i'Type IRO 12774 $tJtiiukitlØiis'&ITtêaiiri.êoìs· Interval Date 2774 - 12794 1/15/2001 12794 12/23/2002IRE-FRAë · -ë-OmrTIEmt--" "iNITIAi. A&C;'SAN[)"FRAC, 107 .ÕOOII 16:2Õ CÄRBOuTE · PPA ON PERFS ;'2iJ7,221 # oi: 16í2(fPROprANT-PUMPEIJ BlïllND TliE · f~IPE -Y'!..!..1 0 F~eA O'iPER.F_§ "RODUCTlON .. (0-12571, OD:5.500, WtI5.50) SURFACE 10-6776, OD:7.625, Wt:29.70) A Rë C ·Ph·.r . AI t... I .OflOCO .LtpS. ..a$~at ,nc~ API: 501032038800 SSSV Type: Nipple e 'rva =-12762 61 . 12794 6176 FRAC A4 Tïpe 2(j'- 7~<1 sp(:·_· Qiite :_=rype_oo _ =-C~ißiI)~nt._ 00 6 ·4/30/2003! APEW· !2.!i" HSD 2!)06 1'.1,60 de!) _ _ _L __ ,pt!flSe_ _.... . 10 .12!18/2002, RPEHF ;2.5" I-ISD. BH Chrgs. 60. ._~.. . D.!!g p..b!'!$e Slatus~' 'Ft-; -. - 14-' --Bottom "i2598 ~ , --- Toi'" ; --'Bottõñï ,. --" ¡- õ - -;- 150 T : ---. 0'- ¡- . 6776 .¡- ;" Ö"-;- 1257-1 -- .~__. 1[f?1 .~:. .~?J88.-=_-~ 1""00 -Wt ~- 9.·:jÕ YVD .- 6U3:> --, Giãd~_ i -::-L-BO TVD" fšõ- 382'Õ- 6010 i3'09 ! '-'Wt:" '-Grade ¡-. TtireacT ~'-62.58 r H40 -; WELDËD ¡-·-29.70 ;n L-BO -. [{TC~..1 ï-·15.50 ~. L-80 -,. Crc~,if' ~;- 9}O._~. ..Ç80~ ¡ "tlJ~_!!..RD_, .-. Thread r:"DEHRD .. ¡ i w:9il Typi 'P~º_ö _ Orig '9/17/2001 __ C0.!!lpleti~l!: I .__ _ LustW/O:, ~.ß.~f LiW D'3ti~ '.-= -=_. = TO: '14037 ftKß ~x H~t()AngLP.: ;7.2_~~ii @6141.~ e ...- , ------- -----. -. ... r-.. - - _on ----: .___Angl~@ .IB: :)4 d~g @..12717 . ~ Angle @ TO:· 9 deg @ 1403/ i _ ..J - ~ 2K-27 KRU -'Rev Rea~õñ: : :fA(Ü;/LC' LAst -Çipd,!le:; 1i22i~õoLC ¡~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011690 Well Name/No. KUPARUK RIV UNIT 2K-27 Operator CONOCOPHILLIPS ALASKA INC j~ ;{? 1l-'7J API No. 50~O3~O388~O~O MD 14037 ... -----~--- --~ -- -- TVD 7357 --- Completion Date 1117/2001 --- Completion Status ~ REQUIRED INFORMATION Mud Log No Samples No 1-01L Current Status 1-01L UIC N --~--- u ------- _u- -- Directional Survey -No- Y M... DATA INFORMATION -- --- Types Electric or Other Logs Run: Well Log Information: Logi Data Digital Type Med/Frmt r----- ¡ Log I ¡ ! Log ~ C Pdf I i ! ED W--Lis Electr Dataset Number Name Log Log Run Scale Media No 1 Blu 1 (data taken from Logs Portion of Master Well Data Maint) --- Interval OH / Start Stop CH Received Comments -------- - -- - 25 12900 Case 8/30/2002 Static Bottom Hole Pressure Survey with Jewelry -- - ~)... 0 931 12795 Case 7/26/2002 14037 ~ 11/6/2002 13988 MPT/GRlEWR4/CNP/SLDI ¡ ROP . ; -------- ------ ------ 1 Blu 1 1 Digital Well Log data 886 Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ì~ Daily History Received? Chips Received? ,---.,. I N ~ Analysis Received? Formation Tops ~ Colt}ments: {\b I f........J tv..t1S"""' L4---^^'" 1'1,,1 v. , oJ. l-..uJ14 ÞÆ~.l"Jtl ~~{ð' S,i"", K JV1.M~6fj»)... \....~k Q..ð \.cJ I, "'" II M8\;\..À. Cl Ii)... .s).cJ¿~ t>ftl().......~t~ PV'(jJfJ'l ,..)j\A.. .ft",f' 7 Nd v ~'ð -f Sample Set Number Comments -~- (j IN ~N ------- éßl. ()],~ JJùo/ (j t1J ")f} J'-\.Vv') ) \ d~ ~.tÙ .t Compliance Reviewed By: Date: l\Jbv --~ ~ 3 ( (' Mike Mooney Wells T earn Leader Drilling & Wells ConocÓPh iln ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 21, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2K-27 (201-169) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforating operations on the Kuparuk well 2K-27. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, I1.M~ M. Mooney Wells Team Leader CPAI Drilling RECEIVED MAY 2 7 2003 Alaska Oil & Gas Cons. Commission Anchorage MM/skad ORIGINAL 1. Operations Periormed: ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon Alter Casing D D D Suspend D Repair Well D Pull Tubing D Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 26' 8. Property Designation: ADL 25589, ALK 2675 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 14037' 7357' true vertical measured 12800' 6197' true vertical Length Size 150' 6627' 12422' 1417' 16" 7-5/8" 5-1/2" 3-1/2" Operation Shutdown D D D Perforate [2] Variance D Annular Disp. D Stimulate D Time Extension 0 Other D Re-enter Suspended Well 0 5. Permit to Drill Number: Plug Periorations Periorate New Pool 4. Current Well Status: Development [2] Stratigraphic D Exploratory D SeNice D 201-169 J 6. API Number: 50-103-20388-00 9. Well Name and Number: 2K-27 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool feet feet Plugs (measured) Junk (measured) 13020' feet feet MD TVD Burst Collapse 150' 6776' 12571' 13988' 150' 3820' 6010' 7309' true vertical depth: 6154' - 6166', 6176' - 6193' Measured depth: 12748' - 12762', 12774' - 12794' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12598' MD. Packers & SSSV (type & measured depth) no packer RECEIVED MAY 2 7 2003 Alaska Oil & Gas Cons. Commission Anchorage sssv= NIP sssv= 523' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 837 244 691 384 15. Well Class after proposed work: Exploratory D Development [2] Service D 16. Well Status after proposed work: Oil[2] GasD WAGD GINJD WINJ D 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: Oil-Bbl 129 261 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney !/{. ~ Form 10-404 Revised 2/2003 . ¡~lQ)~J@ i1~t. L M/j\\? ê1\ ~ '1!1!1'1 !~$\\)f /:., l / ¡ It' . Casino Pressure Tubina Pressure 236 242 - - WDSPL D Title Phone Wells Group Team leader t"1. .1 Date f Z ., (d 'J Prenared bv Sharon AI/sua-Drake 263-4612 ORIGINAL SUBMIT IN DUPLICATE Date 04/14/03 04/21/03 04/24/03 04/30/03 (' ( 2K-27 Event History Comment TAGGED 12687' SLM. EST 87' ABOVE TOP PERF.OBTAINED SAMPLE OF CARBOLITE. [TAG, PERF] CLEANED OUT FILL TO TOP OF CEMENT/PLUG @ 12,980' CTM (EST. 200' OF RATHOLE) W/ SLICK DIESEL & DIESEL GEL. ABLE TO INJECT 1.8 BPM @ 475 PSI INTO WELL--PERFS CLEAR. WELL LEFT SHUT IN PENDING DRIFTfTAG/PERF; F/L AND TBG. FREEZE PROT'D W/ DIESEL. [FCO] DISPL TBG W/40 BBL DSL, DRIFT TBG DOWN TO 12900' WLM, W/ 14' X 2.65" DUMMY GUN, COMPLETE [TAG] PERFORATED 12748' - 12762', 2-1/2" HSD, 6 SPF POWERJET, 60 DEG PHASING. [PERF] / Page 1 of 1 5/20/2003 ( ConocoPhillips Alaska, Inc. Perf (12748-12762) RE-FRAG (12774-12794) GMT (13019-13020, 00:3.500) --1 .~-] ,.'> ~\ "" . ;> ~.......JI ".. J~ "" ¡I ¡'i ...~~~ 1-",<::" . i' I < ~ ',., 41 2K-27 API: 501032038800 SSSV Type: Nipple 12774-12794 6176-6193 Bottom 12598 Zone C-4 A-4 Stimulations & Treatments Interval Date T e 12774-12794 11/15/2001 FRAC CAMCO 'DS' NIPPLE CAMCO 'DS' NIPPLE W/2.812 NO GO PROFILE BAKER NO GO SUB BAKER 80-40 GBH-22 SEAL ASSEMBLY BAKER 80-40 GBH-22 CASING SEAL RECEPTACLE DUMP/BAIL 5 GALLONS OF CEMENT ON TOP OF BRIDGE PLUG 11/1/01 WEATHERFORD 3.5" CAST IRON BRIDGE PLUG, W/10,OOO# RATING set 10/21/01 HES 'X' NIPPLE w/2.812 PROFILE 12774 - 12794 12/23/2002 RE-FRAC 13327 6667 13890 7213 NIP COLLAR ( KRU 2K-27 To Bottom TVD Wt Grade Thread 0 150 150 62.58 H-40 WELDED 0 6776 3820 29.70 L-BO BTCM 0 12571 6010 15.50 L-BO LTCM 12571 13988 7309 9.30 L-BO EUE8RD TVD Thread 6032 EUE8RD Status Ft SPF Date T e Comment 14 6 4/30/2003 APERF 2.5" HSD 2506 PJ, 60 deg hase 20 10 12/18/200 RPERF 2.5" HSD, BH Chrgs, 60 De hase Comment INITIAL A&C SAND FRAC, 107,000# 16/20 GARBOLlTE, 7.4 PPA ON PERFS 207,221# OF 16/20 PROPPANT PUMPED BEHIND THE PIPE W/10 PPA ON PERFS V Type Date Run DMY 1.0 BTM 0.000 0 3/4/2002 GLV 1.0 BTM 0.188 1366 1/9/2003 GLV 1.0 BTM 0.188 1353 1/8/2003 GLV 1.0 BTM 0.250 1448 1/5/2003 OV 1.0 BTM 0.188 0 1/4/2003 Descri tion ID 2.875 2.812 3.000 3.000 4.000 0.000 0.000 2.812 2.992 (' ConocÓPh ill i ps ( Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 14, 2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2K-27 (201-169) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2K-27. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, J;( M~ M. Mooney Wells Team Leader CP AI Drilling MM/skad RECEiVED JAN ~'302J&~~ ¡.,\¡" q' 'c'" {\':\' la...Kü vh ;I:¡,~ , ' i:",.'¡¡,L,.i~";:"';';'~(l)i J;,:,¡~~:,h-':"r.' ..~ ,r&'~I<I!fJ..,. ,.:. (;;111:!.,;:<; . '. "I' ("\ ¡~~) 1: ¡ I I\! i 1".i !: '\ i1 Ii ~ 'I L.".~ (" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ( 1. Operations performed: Operation shutdown- Pull tubing 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 AnchoraQe, AK 99510-0360 4. Location of well at surface 392' FNL, 94' FEL, Sec. 11, T10N, R8E , UM At top of productive interval 1754'FNL,429'FVVL,Sec.10, T10N, R8E,UM At effective depth At total depth 1764' FNL, 5277' FEL, Sec. 10, T10N, R8E , UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURFACE PRODUCTION LINER LINER Length 150' 6627' 12422' 1417' Size 16" 7-5/8" 5-1/2" 3-1/2" Perforation depth: measured 12774' - 12794' true vertical 6176' - 6192' Tubing (size, grade, and measured depth) Kuparuk Unit 8. Well number 2K-27 9. Permit number I approval number (asp's 488276, 5936559)' .J 201-169 / " 10. API number 'v 50-103-20388 -" GJ 11. Field / Pool Kuparuk Oil Pool Stimulate _XX Alter casing 5. Type of Well: Development _X Exploratory - Stratigraphic - Service (asp's 498310,5937910) (asp's 487848, 5936547) 14037 feet 7357 feet Plugs (measured) 13003 feet 6372 feet Junk (measured) Cemented 5.5 sx High Early 383 sx AS Lite, 600 sx Class G wIt 390 sx Class G included above Packers & SSSV (type & measured depth) 3-1/2",9.3#, L-80 Tbg @ 12598' MD. CAMCO 'DS' @ 523' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) 12774' - 12794' Treatment description including volumes used and final pressure 207,221# of 16/20 proppant pumped behind pipe 14. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl 142 868 154 no packer Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil- X Gas- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 201 Signed Michael Mooney 11 Ii, .~ Of, _.J Form 10-404 Rev 06/15/88 . 481 Title: Wells Team Leader ¡,,'-"\ ¡ ¡ I . r i t : Plugging - Perforate _XX Repair well Other 6. Datum elevation (DF or KB feet) RKB 26 feet 7. Unit or Property name Measured Depth 150' 6776' 12571' 13988' True vertical Depth 150' 3820' 6010' 7309' Casinç¡ Pressure Tubinç¡ Pressure 217 236 - 521 - Suspended - Service - Questions? Call Mike Mooney 263-4574 Date ¡ /2.. ?5);.7 Prepared 6: s;aron Allsup-Drake 263-4612 RBOMS 8Fl JßN 3 0 2003 ~ SUBMIT IN DUPLICATE Date 12/07/02 12/08/02 12/09102 12/11/02 12/12/02 (' 2K-27 Event History (: Comment TAGGED @ 12,882' WLM (NOT CORRECTED); PULLED DV @ 7309' RKB, IN PROGRESS. [FRAC- REFRAC] SET DV @ 7309' RKB, PULLED GLV'S @ 10,058' & 11,889' RKB & SET DV'S IN SAME, ESTABLISHED TBG TO IA COMMUNICATION, IN PROGRESS. [FRAC-REFRAC] TESTED TBG & CONFIRMED NO ANN COMM ABOVE 10000'. PULLED TOP HALF OF SEVERELY ERODED OV @ 12,503' RKB. SET CATCHER SUB @ 12,542' RKB. POCKET PUNCHED GLM @ 12503' TO REMOVE BITS & PIECES OF ERODED OV. JOB SUSPENDED FOR UNIT MAINTENANCE. [FRAC- REFRAC] PULLED CATCHER & FLOW CUT OV, ESTABLISHED TBG & IA INTEGRITY TO 2500#, SET 2.182" M1-DS STANDING VALVE @ 12,503' RKB, IN PROGRESS. [FRAC-REFRAC] DISPLACED IA WI 125 BBLS SEAWATER W/24 BBL DIESEL CAP; DISPLACED TBG WI 110 BBLS DIESEL, SET 1" DV @ 12,503' RKB, MITTBG & IA TO 3500#, PULLED SV @ 12,542' RKB. [FRAC-REFRAC] 12/18/02 12/23/02 12/24/02 PERFORATED 12774-12794 FT MD WITH 2.5" HSD @ 6 SPF, BIGHOLE CAHRGES. [PERF] PUMPED FRACTURE TREATMENT WITH 50# DELAYED X-LINKED GEL @ 20 BPM. USED A TOTAL OF 207,221 LBS OF 16/20 PROPPANT. PLACED 174,342 LBS OF PROPPANT BEHIND PIPE WITH 10 PPA ON PERFS. ENCOUNTERED HIGH TREATING PRESSURES, CUT SAND AND WENT TO FLUSH, SCREENED OUT WITH 10 PPA AT WELLHEAD. LEFT 32,879 LBS OF PROP IN WELLBORE. NO TREESAVER RUBBER RECOVERED. PERFORMED A FCO TO 13,003' CTMD. RETURNS 1-1 ALL DAY. WASHED ALL MANDRELS ON WAY TO SURFACE. UTILIZED 100 BBLS DIESEL GEL, 600 BBLS SLICK SEA WATER, 150 BBLS SLICK DIESEL. WELL FREEZE PROTECTED TO 3500'. [FCO] Page 1 of 1 1/13/2003 ~. ~': ~. ¿JOjr-/fo c¡ f/3Q WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 November 5, 2002 RE: MWD Fonnation Evaluation Logs 2K-27, AK-l\1M-11146 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalisl\ Speny-Sun Drilling Services, 6900 Arctic Blvd., J\nchorage, AK 99518 2K-27: Digital Log Images 50-103-20388-00 1 CD Ronl i~ECErVE[) NOV 06 2:002 AtaBka o~ & Gas Celia. Commiuion AnchOfage Schlumbel'gep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth ~--=e' Date Well Job# Log Description 2X-13 1 Y -25 1A-08 2M-34 3N-07 2V-03 1 D-1 06 2K-08 1 D-1 03 2K-27 2F-09 3G-10 3F-20 2K-25 1 .. J -¡ PROD PROFILE/DEFT <l .. OS c¡ PROD PROFILE/DEFT 0 PROD PROFILE -07 INJECTION PROFILE lc . Q LEAK DETECTION . 10 INJECTION PROFILE ... ~VO INJECTION PROFILE PROD PROFILE MPSP INJ PROFILE SBHP SURVEY SBHP SURVEY INJECTION PROFILE SBHP SURVEY SBHP SURVEY 08/08/02 08/13/02 08/06/02 08/12/02 08/10/02 08/11/02 08/12/02 08/10/02 08/15/02 08/17/02 08/18/02 08/16/02 08/16/02 08/17/02 c..~ SIGNE~~) DATE: NO. 2361 Company: Field: BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Sepia 08/27/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD Color ~; ,t" BO n¡,í\'Ï i' \ ' , ., . . . J ; l ~' .! n'-"V ..,'J J... A\í:l3Ktl O;-j i.5~ u~~;:. '-~,~",.- '~':.. ;~'UÜLtt:.n f\\1C\VJ\'B.QD Schlumbergel' Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth -- Well Job # Log Description Date 1C-131 1C-133 1 F-02 1 Q-15 2G-03 2H-15 2K-08 2K-27 2X-13 3C-15 1 D-1 03 07/08/02 07/05/02 07/07/02 07/03/02 07/01/02 07/09/02 07/02/02 06/30/02 07/04/02 07/07/02 06/08/02 ----- SIGN~ ~ !J~ NO. 2255 Company: Field: BL Sepia 07/23/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD Color 1 1 1 1 1 1 1 1 1 1 1 RECEIVED DATE: JtJL 2 6 20ez. Alaska Oi,l & Ga C Co, . Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. u S ens. mrmssion Anchorage 04/26/02 Scblum_el'ger NO. 2030 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk - Well Job# Log Description Date BL Sepia CD Color -'-<- 1M-17d OJ..;;}~ PRESSITEMP SURVEY 03/20/02 1 1 2P-441~ t~...o/1 STATIC BOTTOMHOLE 03/30/02 1 1 2K-25 Ie.. 'O"'OJ~ RST -WFL 03/08/02 1 1 2K-27 .::J.(jJ-J~q LEAK DETECTION LOG 03/11/02 1 1 2K-27 ..J, LEAK DETECTION LOG 03/08/02 1 1 3H-21 1'?Æ'DtJi( PRODUCTION PROFILE . 03/07/02 1 1 SIGNE~ í) DATE: RECEIVED ~'p'D -:: O. ')OO? 1.< ~ I' \ V ¡ L ... Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. -\laska Oil & Gas ConS. Commission A.nchorage { { . lffiJJ:,tfafL' ) 0/'/&1 WELL LOG TRANSMITI AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 701 Avenue, Suite 100 i\nchorage, Alaska February 1, 2002 RE: MWD Formation Evaluation Logs 2K-27 , AK-MM-11146 1 LDWG formatted Disc with verification listing. AJPI#: 50-103-203~-00 g PLEASE ACKNOWLEDGE RECEIPT BY SIGNJNG AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Dat~ECE 1\, ED FEB 0 ì 2002 Alaska Oil & Gas A "'Mgons. COmI1JÌOð' H"U/"'iUTSge øvgl0n Si~~ . , (" I , PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 1 00360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 December 3, 2001 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for Kuparuk We1l2K-27 (201-169/301-258) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk 2K-27 well. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. Sincerely, C. Mallary Drilling Engineering Supervisor P AI Drilling CM/skad RECEIVED DEC 0 4 2001 Alaska Oil & Gas Cons. Commission Anchorage OR'Gl~JAL .' ~' ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 394' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At Top Producing Interval : ~ ';.:.. . 1754' FNL, 429' FWL, Sec. 10, T10N, R8E, UM ~ ._LL--7~ 0../- . (ASP:488276,5936559) ~7::,a~~t:, FWL, Sec. 10, nON, RaE, UM :-:-~'jk~:-~:-- (ASP: 487848, 5936547) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 25.8 feet ADL 25589, ALK 2675 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore August 27,2001 September 10,2001 _Septt:\r:J1BSr 11, A:::U1r1 Itf7ÞI gh N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TV D) 19. Directional Survey 20. Depth where SSSV set 14037' MD /7357' TVD 13890' MD /7213' TVD YES ø No 0 Camco Nipple @ 523' 22. Type Electric or Other Logs Run GR/Res/PWD, CBL 23. 1. Status of well Oil ø Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended 0 Service 0 Abandoned 0 1.oCA ~ . ~ SuA: >"1""'\ , t'.. IUI ~ ~ ; I ~;".~.,.--,:;-".;:.x;! . "" - . " (ASP: 498310, 5937910) CASING SIZE CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 150' Surface 6776' Surface 12571' 12571' 13988' wr. PER FT. 62.6# 29.7# 15.5# 9.3# GRADE H-40 L-80 L-80 L-80 HOLE SIZE Classification of Service Well 7. Pennit Number 201-169/301-258 8. API Number 50-103-20388-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2K-27 11. Field and Pool Kuparuk River Field Kuparuk River Pool 16. No. of Completions 1 21. Thickness of Permafrost 1513' 16" 24" CEMENTING RECORD AMOUNT PULLED 7.625" 9.875" 5.5 sx High Early 113 sx AS Lite, 270 sx AS Lite, 600 sx Class G w/GasBlok 390 sx Class G included above 5.5" 3.5" 6.75" 6.75" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) Weatherford CIBP set @ 13020' Baker inflatable bridge plug set at 3300' TUBING RECORD DEPTH SET (MD) 12598' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12774' -12794' 107M# 16/20 carbollte behind pipe 25. SIZE 3.5" 12774' - 12794' MD 6176' - 6192' TVD 4 spf 27. Date First Production November 27,2001 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing OIL-BBL GAS-MCF 207 672 OIL-BBL GAS-MCF 207 672 CORE DATA Production for Test Period> Calculated 24-Hour Rate> WATER-BBL 246 WATER-BBL 246 11/27/2001 23.5 Flow Tubing Casing Pressure press. 246 psi 1228 28. Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Fonn 10-407 Rev. 7-1-80 CO~~Dr~EriRSE SIDE U 1\ lJ I~ A kBDMS BFL . PACKER SET (MD) N/A CHOKE SIZE 176 OIL GRAVITY - API (corr) N/A GAS-OIL RATIO 583 RECEIVED DEC 0 4 2001 Alaska 011 & Gas Cons. Commission Anchorage ~ 1= Submit In duplicate DEC I n ~~om 29. . 30. j' GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 12747' 12763' 12763' 12881' 6153' 6166' 6166' 6266' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Title Drillina EnaineerinQ Supervisor Date d j) ~ e. r4 Prepared by 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. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ~~:-~::O~:~~:~~~i~peration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, ~rð~{I~ion, Item 28: If no cores taken, indicate "none", DEC 0 4 2001 Form 10-407 ORIGINAL Alaska Oil & Gas Cons. Commission Anchorage (' (' PHILLIPS ALASKA INC. Operations Summary Report Page 1 of 5 Legal Well Name: 2K-27 Common Well Name: 2K-27 Event Name: ROT - DRILLING Contractor Name: n1433@ ppco.com Rig Name: Nordic 3 Date From - To Hours Code Sub Phase Code 8/26/2001 21 :00 - 22:00 1.00 MOVE MOVE MOBMIR 22:00 - 00:00 2.00 DRILL RIRD SURFAC 8/27/2001 00:00 - 04:00 4.00 DRILL RIRD COND1 04:00 - 08:30 4.50 DRILL RIRD COND1 Start: 8/26/2001 Rig Release: 9/17/2001 Rig Number: 3 Spud Date: 8/27/2001 End: Group: Description of Operations Move Rig from 2K-28 to 2K-27 Rig Accept @ 22:00 - Move and set Diverter on well - Spot and Level Rig over well - Spot Equip change out drip pan in cellar, ru diverter & lines. Off load spud mud, load pipe shed wi bha, complete ser tds & mu saver sub to tds. Ru floor handling tools. Spot mud lab & sperry mwd Ilwd shack. 08:30 - 10:30 2.00 WELCTL BOPE COND1 Function test Diverter, conduct accumulator draw down test, run diverter test accompanied wI shallow gas drill I discussion of shallow gas indicators & reaction to same. 10:30 - 11 :00 0.50 WELCTL SFTY COND1 PJSM IPre spud meeting. Discussed safety, well geometry & shall gas. 11 :00 - 12:00 1.00 DRILL PULD COND1 Pu bha, scrib same & tih to tag cmt @ 135' 12:00 - 16:30 4.50 DRILL DRLG SURFAC Spud well in @ 1200 hrs. - Drlg 135' to 167' - Poor ROP - Bit & BHA bouncing excessively 16:30 - 17:30 1.00 DRILL TRIP SURFAC TOH to Ck Bit - Bit had no damage and was not locked up - TIH 17:30 - 00:00 6.50 DRILL DRLG SURFAC Drlg 167' to 363' MD - Run gyro as needed for directional control. From drlg rate determined end of conductor @ 187' rkb. Gyro survey 167' = .35? @ 075? Az. 8/28/2001 00:00 - 08:00 8.00 DRILL DRLG SURFAC Drlg F/363' - 931' MD [930' TVD]. Slide= 1.3 Hrs. Rotate = 2.75 Hrs. Circ., Gyro survey = 3.95 Hrs. 08:00 - 09:00 1.00 DRILL CIRC SURFAC Circ and cond hole 09:00 - 13:00 4.00 DRILL WIPR SURFAC Wiper trip to suface, change BHA, P/U MWD, LWD, change out saver sub to 4" HT-38, Upload MWD, TIH 13:00 - 00:00 11.00 DRILL DRLG SURFAC Drlg F/931' to 1955' MD, 1903' TVD Slide = 3.7 Hrs. Rotate = 3.75 Hrs. Circ. and survey = 3.55 Hrs. 8/29/2001 00:00 - 05:30 5.50 DRILL DRLG SURFAC Drlg F/1955' to 2584' MD, 2336' TVD 05:30 - 06:30 1.00 DRILL CIRC SURFAC Circ. and Condo hole for wiper trip 06:30 - 09:30 3.00 DRILL WIPR SURFAC Wiper trip to 950'. 09:30 - 00:00 14.50 DRILL DRLG SURFAC Drlg. & surveys from 2584' to 4007'. Slide-4.05 Rotate-9.45 8/30/2001 00:00 - 11 :30 11.50 DRILL DRLG SURFAC Drlg. & surveys from 4007 to 5006'. 11 :30 - 13:30 2.00 DRILL CIRC SURFAC Circ. -clean hole for wiper trip. 13:30 - 21 :00 7.50 DRILL TRIP SURFAC POH to surface-down load mwd-change mud motor from 1.55 deg. to 1.22 deg.-clean & check bit-service mwd. 21 :00 - 22:00 1.00 DRILL OTHR SURFAC Service top drive-grease crown & blocks-change out saver sub. 22:00 - 00:00 2.00 DRILL TRIP SURFAC Run in hole wI bha #3. 8/31/2001 00:00 - 02:00 2.00 DRILL TRIP SURFAC Finish wiper trip. 02:00 - 03:30 1.50 DRILL CIRC SURFAC Circ. heavy mud out to clean hole. 03:30 - 00:00 20.50 DRILL DRLG SURFAC Drilling & surveys to 6019'. 9/1/2001 00:00 - 15:30 15.50 DRILL DRLG SURFAC Drlg. & surveys from 6019' to 6786'-stop drilling due to slow penetration Printed: 10/19/2001 7:39:50 AM - ~ ~ / --, ~ PHILLIPS ~ ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/1/2001 9/2/2001 9/3/2001 9/4/2001 9/5/2001 Date (O ( PHilliPS ALASKA INC. Operations Summary Report 2K-27 2K-27 ROT - DRILLING n1433@ ppco.com Nordic 3 Sub From - To Hours Code Code Phase 00:00 . 15:30 15:30 - 16:00 16:00 - 19:30 19:30 - 00:00 00:00 - 00:30 00:30 - 04:30 04:30 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 19:00 19:00 - 19:30 19:30 - 00:00 00:00 - 09:30 09:30 - 13:30 13:30 - 15:00 15:00 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 00:00 00:00 - 05:00 05:00 - 06:00 06:00 - 11 :00 11 :00 - 12:00 12:00 - 12:30 12:30 - 14:30 14:30 - 18:00 18:00 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 10:00 10:00 - 00:00 15.50 DRILL 0.50 DRILL 3.50 DRILL 4.50 DRILL 0.50 DRILL 4.00 DRILL 1.50 DRILL 2.00 DRILL 1.00 DRILL 10.00 CASE 0.50 CASE 4.50 CASE 9.50 CASE DRLG SURFAC CIRC SURFAC WIPR SURFAC CIRC SURFAC CIRC SURFAC TRIP SURFAC PULD SURFAC OTHR SURFAC OTHR SURFAC RUNC SURFAC RUNC SURFAC CIRC SURFAC CIRC SURFAC 4.00 CEMENl PUMP SURFAC 1.50 CEMEN' PULD SURFAC 2.50 CEMEN' CIRC SURFAC 0.50 CEMEN' PUMP SURFAC 1.00 CEMEN'TRIP SURFAC 5.00 DRILL OTHR PROD 5.00 DRILL 1.00 DRILL 5.00 DRILL 1.00 DRILL 0.50 DRILL 2.00 DRILL 3.50 DRILL 4.00 DRILL 2.00 DRILL 0.50 DRILL 5.00 DRILL 0.50 DRILL 1.00 DRILL 3.00 DRILL 14.00 DRILL OTHR PROD OTHR PROD OTHR PROD OTHR PROD PROD TRIP PROD PULD PROD TRIP PROD DEOT PROD TRIP PROD. DRLG PROD LOT PROD DRLG PROD OTHR PROD DRLG PROD Page 2 of 5 Start: 8/26/2001 Rig Release: 9/17/2001 Rig Number: 3 Spud Date: 8/27/2001 End: Group: Description of Operations rate-check wI anchorage personel to call 6786' surface td. Circ. hole clean. Wiper trip to 4000' & back to bottom. Hole in good condition. Pump sweeps Circ. till hole cleans up for running 7 5/8" csg. Finish circ. hole clean @ 10 bpm 2480#. Monitor well-poh to run 7 5/8" csg. Lay down bha #3. Down load mwd-water flush mud motor & lay down. Cut & slip drlg. line & check crown-o-matic. PJSM-Rig up & run 156 its. 7 5/8" 29.7# L-80 BTCM Csg. No hole problems. Make up hanger-landing it. & cement head-rih & tag wi hanger. Break circ. @ 1/2 bpm to 1 bpm-reciprocate pipe-increase circ. rate gradually to 3 bpm @ 61 O#-Begin losing circ.-pump @ 1.5 bpm attempting to regain circ.-pumping @ 1.5 bpm 390# wi 25% returns. Reciprocate pipe every 30 mins. Pump new mud down hole wI therma thin & bicarb @ 9.5#wt.& 71 vis. Continue to circ. @ 1.5 bpm @ 380# losing 1 bpm-Established full circ. when thin mud hit surface-circ. @ 7 bpm-gaining 1 bpm. Circ. till well stabilized. PJSM-Pump 5 bbls. CW100-test lines to 2500#-pump 25 bbls. CW100 & 50 bbls. mud push @ 10.5# wI red dye ahead-pump lead & tail cement as per program. Lost complete returns after 3500 strokes while displacing cement wI rig pump-bumped plug on calculated strokes @ 4197. Lay down cement head & landing it.-Rig up to run 4" dp wI Port collar shifting tool. RIH to 987'-test shifting tooI1000#-rig up vac truck to conductor pipe. Open port collar-circ-recovered red dye after 12.39 bbls.-recovered cement returns after 48.37 bbls.-circ. hole clean. Pump 5 bbls. water-90 bbls. lead cement @ 10.7#-2 bbls. water-displace wI 8 bbls. mud-close port collar-test to 1 OOO#-shear out choke & circ. capacity of dp. Pull 10 stands-lay down tam tool. N/D diverter-install tree in sub-Load well head equipment & nipple up bope. Finish nipple up bope. Service rig & top drive. Pick up test it. & test plug & test bope 250#-5000#. Lay down test plug & test it. Change out rig tongs & rig up to lay down 31/2" hwdp. Set wear ring & lay down setting tool. Rih wlhwdp & lay down same. Pick up BHA #4-upload mwd & rih wI 22 its. dp. Shallow test mwd & picking up 4" dp. CBU & test csg. to 3500# OK. RIH-tag @ 6667'. Break circ.-drill cement-float collar-float shoe & 20' new hole to 6806'. Circ. hole clean. Perform LOT-FIT 16.0#. Drlg. from 6806 to 6897. Change fluids in hole-clean mud tanks. Drlg. & surveys from 6897' to 8427'. Printed: 10/19/2001 7:39:50 AM ~ ~ - ~'PHILLlPS) ~~) ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/6/2001 917/2001 9/8/2001 9/9/2001 9/10/2001 9/11/2001 9/12/2001 9/13/2001 ( ( PHILLIPS ALASKA INC. Operations Summary Report 2K-27 2K-27 ROT - DRILLING n1433@ ppco.com Nordic 3 Page 3 of 5 Start: 8/26/2001 Rig Release: 9/17/2001 Rig Number: 3 Spud Date: 8/27/2001 End: Group: Sub From - To Hours Code Code Phase 00:00 - 09:30 09:30 - 11 :00 11 :00 - 13:30 13:30 - 14:00 14:00 - 15:30 15:30 - 00:00 00:00 - 00:00 - 17:00 17:00 - 21 :00 21 :00 - 23:00 23:00 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 07:00 07:00 - 08:30 08:30 - 10:30 10:30 - 13:00 13:00 - 20:30 20:30 - 00:00 00:00 - 04:00 04:00 - 04:30 04:30 - 07:00 07:00 - 08:00 08:00 - 11 :00 11 :00 - 14:00 14:00 - 20:30 20:30 - 00:00 00:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 04:00 04:00 - 06:00 06:00 - 10:00 10:00 - 10:30 10:30 - 15:00 15:00 - 19:00 19:00 - 21 :00 21 :00 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 08:00 08:00 - 00:00 00:00 - 05:00 9.50 DRILL 1.50 DRILL 2.50 DRILL 0.50 DRILL 1.50 DRILL 8.50 DRILL DRILL 17.00 DRILL 4.00 DRILL 2.00 DRILL 1.00 DRILL 3.00 DRILL 0.50 DRILL 3.50 DRILL 1.50 DRILL 2.00 DRILL 2.50 DRILL 7.50 DRILL 3.50 DRILL 4.00 DRILL 0.50 DRILL 2.50 DRILL 1.00 DRILL 3.00 DRILL 3.00 DRILL 6.50 DRILL 3.50 DRILL 23.50 DRILL 0.50 DRILL 1.50 DRILL 2.50 DRILL 2.00 DRILL 4.00 DRILL 0.50 DRILL 4.50 DRILL 4.00 DRILL 2.00 DRILL 3.00 DRILL 3.50 DRILL 2.50 DRILL 2.00 DRILL 16.00 CASE 5.00 CASE DRLG PROD CIRC PROD WIPR PROD OTHR PROD WIPR PROD DRLG PROD PROD DRLG PROD CI RC PROD CIRC TRIP TRIP LOT TRIP PULD OTHR PULD TRIP DRLG DRLG OTHR TRIP OTHR TRIP OTHR PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD TRI P PROD DRLG PROD DRLG PROD CIRC PROD CIRC PROD WIPR PROD CIRC PROD TRIP PROD REAM PROD CIRC PROD OTHR PROD CIRC PROD TRI P PROD TRI P PROD PULD PROD OTHR PROD RUNC PROD RUNC PROD Description of Operations Drilling & surveys. Circ.-condition hole for wiper trip. Monitor well-poh to shoe @ 6776'. (Hole in good condition) Service rig & top drive-clean torque tube. Rih to 9279 (hole in good condition.) Drlg. & surveys from 9279' to 10132'. Drlg. & surveys from 10132' to 11742'. Pumping sweeps while drlg. Circ. hole clean while waiting on new mud= Truck driver said he had to go to "doghouse" meeting @ APC prior to bringing mud out. Unload mud-build to 10.2 & displace well w/1 0.2# mud. POH f/ new bit & sperry tools. SLM. POH to shoe @ 6776' (SLM) FIT to 12.8#. Finish poh-strap out of hole-no correction in strap. Download mwd & lay down bha. Repair grabber clutch on top drive. Make up bha #5-upload mwd-PJSM-Ioad source. Shallow test mwd & rih to 11673'. Drlg. & surveys from 11742 to 11895'-turning hole down. Drlg. & surveys from 11895' to 12116'. Circ.-Attempt to get Detection tools downhole working. POH to Shoe @ 6452'. Slip & cut drlg. line. POH to HOC & BHA. PJSM-UD nukes-download mwd-change out pulser-check bit & orientation-upload mwd-surface test tools & load nukes. (changed out telemetry module & pulser) RIH-Wash to bottom. Drlg. & surveys from 12116 to 12352'. Drlg. & surveys from 12332' to 14037' (TD) eire-clean hole for wiper trip. Circ.-condition hole for wiper trip. Wiper trip to 12142'. (tight @ 13914' to 13725'. Circ.-pump sweeps & work pipe. POH to 9560'-monitor well-Orders to go back to bottom-due to no emergency flights for an accident or injury. Wash to bottom-fill @ 14019 to 14037'. Circ.-condition hole while waiting for word on back up flights in case of emergency. Rig motors died-cause by 24 volt batteries shorting out-creating scr,s to short out. Attempting to solve problem-moving pipe down occasionaly. Circ. -condition After shut down. POH to run csg. Continue poh to run 5.5" X 3.5" csg. Lay down bha #5-PJSM on nukes-lay down same-down load mwd-Iay down mwd & mud motor. Clean floor-pull wear ring-change upper pipe rams to 5.5"-rig up floor to run csg. Run 44 jts. 3.5" csg.-change handling tools-run 5.5" csg.-circ. cap. csg @ 6776'.-circ. @ 8700'. Continue running 5.5" X 3.5" csg.-circ. @ 13496'-rih-clean out fill & land csg. @ 14029'. Printed: 10/19/2001 7:39:50 AM ~ ~ ~ ~'PHILLlPS) l[lj ....". Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/13/2001 9/14/2001 9/15/2001 9/16/2001 9/17/2001 Date ( . -. (' PHilliPS ALASKA INC. Operations Summary Report 2K-27 2K-27 ROT - DRILLING n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 05:00 - 15:00 15:00 - 17:00 17:00 - 19:30 19:30 - 00:00 00:00 - 04:30 04:30 - 08:30 08:30 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 08:00 08:00 - 20:00 20:00 - 21 :00 21:00 - 21:30 21 :30 - 23:00 23:00 - 00:00 00:00 - 03:00 03:00 - 10:00 10:00 - 15:00 15:00 - 19:30 19:30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 07:00 07:00 - 07:30 07:30 - 08:30 08:30 - 12:30 12:30 - 13:00 10.00 CASE 2.00 CASE CIRC PROD OTHR PROD 2.50 CEMENl PUMP PROD 4.50 CEMENl OTHR PROD 4.50 WAlTON CMT PROD 4.00 CASE NUND PROD 2.00 CASE NUND 0.50 DRILL RIRD 1.00 RIGMNT RURD 12.00 DRILL PULD 2.50 DRILL PULD 0.50 DRILL PULD 5.00 CMPL TN RURD 12.00 CMPLTN RUNT 1.00 WELLSR DEOT PROD PROD PROD PROD PROD PROD CMPLTN CM PL TN PCPTST 0.50 WAlTON ORDR CMPL TN 1.50 CMPL TN SOHO CMPL TN 1.00 WAlTON EOIP CMPL TN 3.00 WAlTON EQIP CMPLTN 7.00 WELLSR PLGM CMPL TN 5.00 WAlTON EQIP CMPLTN 4.50 WELLSR PLGM CMPL TN 4.50 WAlTON EOIP 1.50 WAlTON EalP 1.50 CMPLTN TRIP 4.00 CMPLTN TRIP 0.50 WELLSF PLGM 1.00 WELLSF PLGM 4.00 CMPLTNTRIP 0.50 CMPLTN TRIP CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN Page 4 of 5 Start: 8/26/2001 Rig Release: 9/17/2001 Rig Number: 3 Spud Date: 8/27/2001 End: Group: Description of Operations Circ. & work pipe-Partial returns-circ. & attempt to get returns-tight hole. Unable to work hanger down-stop @ 13989'. Lay down landing jt. & hanger-unable to lay down next jt. Batch mix cement & fill mud tanks. PJSM-pump 5 bbls. CW100-test lines to 3500#-pump 35 bbls. CW100 @ 4.3 bpm-drop bottom plug-pump 48 bbls. 12# mud push @ 6 bpm-pump 93.4 bbls. 15.8# cement @ 6 bpm followed wI 2 bbls. water-drop top plug-pump @ 6 bpm to 1940 strokes-2 bpm to 2000 strokes-6 bpm to 2150 strokes-2 bpm t02250 strokes-6 bpm to 51 00 strokes-2 bpm to 5360 strokes-did not bump plug-floats did not hold. Had 950# back pressure. (Calculated strokes to bump was 5338 strokes wI 5" liners in 10" pump @ 96% efficiency. Floats not holding-hold 950# pressure on csg. Con't waiting on CMT (SIP 950psi I FSIP 1470psi) PIU & Hang off BOPs -FMC Install Csg Slips - Set wI 25K on slips Cut Csg - Install Packoff & test to 5000psi N/U 11" BOPs -C/O Top Pipe rams to 31/2" RlU & CIO Handling equip to UD 4" DP out of derrick Slip & Cut drill line (49' cut) UD 4" DP out of derrick. Stds had to be broke down in mouse hole Con't UD 4" DP out of derrick RID Eckels DP Power Tongs - Clean floor area Finish loading 31/2" completion string & jewerly in pipe shed Run Completion 3 1/2" 9.3# L-80 EUE 8rd Mod Tbg Test Csg - @ 47 stks pumped, Csg test failed @ 2850psi (Wet Shoe) - Shut down- Bleed off pressure Confer with Week end duty engineer and Team Leader about plan forward Space out and land Tbg - Ran 398 jts 31/2" Tbg - Space out wI 2 pups ( 8.11' & 2.34' ) Pups are located 1 jt below Tbg hanger Tbg correction 13.04' Waiting on E-line unit & Tbg Plug Waiting on E- Line Unit Run Baker IBP on Schlumberger E-line - Attempt to set IBP @ 3300' (Failed) - IBP would not set - TOH wI IBP- BID Baker setting tool & plug Baker will CIO setting tool & IBP and make another run - Setting tool will need to be re-built & dressed in Prudhoe Bay - Waiting on Baker to CIO setting tool & IBP Run # 2 - Attempt to set Baker IBP @ 3300' (failed) - IBP would not set - Small pump in setting tool would not pump with 10.4 mud in hole - Solids pluged pump - TOH - RID Wire Line After conferring with TL the decision was made to set the Baker IBP on Tbg - Ordered Equip to run IBP( 2 1/16" CS Hydril Tbg) - Wait on equip **Note**: AOGCC rep Chuck Scheve was notified of all results & plan forward. He gave state approval to process as planned Waiting on 2 1/16" CS Hydril Tbg- Will run Baker IBP on Tbg Load & Strap 119' Jts 2 1/16" 3.25# CS Hydril Tbg in pipe shed M/U Setting tool & Baker IBP on running string - TIH to 3300' Establish Circu - Drop Setting Ball Pressure up per Baker Rep instructions 5001 1000/15001 1950/2110 - IBP set & sheared off. Baker IBP set @ 3300' - Fishing neck = 1.375" JDC I 5500# pull to release TOH - UD work string 21/16" CS Hydril- BID setting tool Clean & Remove all work string tools from floor Printed: 10/19/2001 7:39:50 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/17/2001 ( ,/ ~ PHilliPS ALASKA INC. Operations Summary Report 2K-27 2K-27 ROT - DRILLING n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 13:00 - 13:30 13:30 - 15:00 0.50 RIGMNT RGRP CMPL TN 1.50 CMPLT DEOT CMPLTN 15:00 - 16:30 1.50 CMPL TN RURD CMPL TN 16:30 - 19:30 3.00 CMPL TN RURD CMPL TN 19:30 - 20:00 0.50 WELLS FRZP CMPL TN 20:00 - 20:30 0.50 WELLS FRZP CMPL TN 20:30 - 21:30 1.00 WELLS FRZP CMPL TN 21 :30 - 00:00 NUND CMPL TN Page 5 of 5 Start: 8/26/2001 Rig Release: 9/17/2001 Rig Number: 3 Spud Date: 8/27/2001 End: Group: Description of Operations Repair sending unit & re-build hose to chart recorder Pressure Test Tbg pi ug to 2500 psi 1 hold 15 min 1 loss 20 psi - Bleed Tbg pressure back to 700 psi. While holding 700 psi on Tbg, Pressure test 5.5" X 3.5" Ann. to 3000 psi -After 15 min loss 30 psi -- Bleed pressure off Tbg to shear DCK valve - Valve sheard at 2850psi - Install 2 way check RID Circ Iines,LJ & NID Stack NIU Tree - Test packoff to 5000psi - Test tree to 5000psi Pull 2 way ck - R/U circu lines to tree Freeze Protect well -Pump 50 bbl diesel dn 5.5" X 3.5" ann @ 2.5 BPM = 2050 psi - Take returns from Tbg Put Ann. & Tbg in communication - SITP 0 - SICP 0 - 7 5/8" X 5.5" ann psi = 100psi Set BPV - RID all surface lines - Clean Cellar area - Move Rig off Rig released 11 :59(Midnight) PM 9/17/2001 Printed: 10/19/2001 7:39:50 AM (' 2K-27 Event H ¡story t \ Date 10/20/01 Comment SET 3.5M WEATHERFORD CIBPW/TOP OF PLUG @ 13020' (9' BELOW COLLAR), HAD SOME PROBLEMS GETTING BACK UP THROUGH THE SEAL ASSY (12580'), LEFT WELL SI. .. - u- ----.-- ..-.- -.. .... -. ..... ..-.....--.. .......... ..-- .-. -------- --.-- -......... -. -.. .-.. .... .--. ...... .--.. ..--...... .... ..... .-- ---..--- -- -. ---- - - - -- -- --. -.. .-.. - - -- --- - -.---. --.- - .--. ----- - - -... ....... -... .-.-..... -- .--- --- .--- .-.. .-----.....- u,,--... .-.. ..-- --- 11/01/01 DUMP BAILED 5 GALLONS OF CEMENT ON TOP OF BRIDGE PLUG @ 13020' ELM. 11/04/01 PERFORMED AN MIT @ TUBING INTEGRITY TEST. 3000# ON TUBING FOR 30 MIN. TEST PASSED. 3500# ON IA FOR 15 MIN. TEST PASSED. [MIT] PERFORATED @ 12774-12794 FT - 2.5M HSD - 35B UP, RDX @ 4 SPF - 180 PHASING. OBTAINED SBHP OF 3569 PSI @ 12784' (162 DEG). [PERF, PRESSURE DATA] SET 2.81. CATCHER SUB @ 12542' RKB.IN PROGRESS. [GLV] REPLACED DV @ 12503' RKB W/ PETREDAT GAUGE. TESTED IA 3500 PSI, GOOD. ATTEMPT PULL CATCHER, FAILED. IN PROGRESS. ""---------.....u_---------- u_------.----------------.--- ........ ........... -...-.. .__u--- -.---- ----.------- --- -----------------... .... .... ....--........ ......--. ----.- .-- - ---.----------- .----- ---- -_.- ---- ----------.---... .........- -.....---- -.. ..n. -.... .------... 11/14/01 BAILED MUD & CEMENT OFF CATCHER @ 12,542' RKB. PULLED SAME. [FRAC-REFRAC] 11/15/01 PUMPED INITIAL FRACTURE TREATMENT. PLACED 107M# 16/20 CARBOLITE BEHIND PIPE, 7.4 PPA ON PERFS. HAD NWBSO DURING 6-10 PPA RAMP STAGE, 47% OF DESIGN PLACED. LEFT 27M# IN WELLBORE. ALL TREESAVER RUBBER RECOVERED. [FRAC-REFRAC] PERFORMED A FCO TO TOP OF CEMENTED IBP AT 12,997' CTMD. WASHED ALL MANDRELLS ON WAY TO SURFACE. NO INDICATION OF FLOW FROM PERFORATIONS. WELL FREEZE PROTECTED TO 6000'. RETURNS 1-1 + ALL DAY. SMALL AMOUT OF GAS & CRUDE WHILE POOH. [FCO] 11/07/01 11/12/01 11/13/01 11/17/01 Page 1 of 1 11/28/2001 ( ( 05-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 2K-27 Gyro éJOJ-/fo4 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 0.00 MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ECEI'/ED I'~OV 0 7 2001 A!j~ska Oil & Gas Cons. Commission .~nC~twage ~ --- . 1 --- () CO. D EFI N 'riVE -- Kuparuk River Unit North Slope, Alaska Kuparuk 2K, Slot 2K-27 2K-27 Gyro Job No. AKMM11146, Surveyed: 28 August, 2001 SURVEY REPORT 5 November, 2001 Your Ref: API 501032038700 Surface Coordinates: 5937910.20 N, 498310.10 E (700 14' 29.7326" N, 150000' 49.1308" W) Kelly Bushing: 148.700 above Mean Sea Level c ~--- 5 P E! II"'" Y - s u .., DRILLING SERVices A Halliburton Company Survey Ref: svy9610 Kuparuk River Unit Measured Depth (ft) "-~ 0.00 162.00 257.00 344.00 435.00 523.00 610.00 698.00 793.00 883.00 Incl. Azlm. Sperry-Sun Drilling Services Survey Report for 2K-27 Gyro Your Ref: API 501032038700 Job No. AKMM11146, Surveyed: 28 August, 2001 DEF\N\T\ 0.000 0.000 0.350 75.000 0.400 68.000 0.400 55.000 1.750 204.000 2.250 214.000 2.450 240.000 2.250 240.000 5.350 243.000 5.500 249.000 North Slope, Alaska Kuparuk 2K Sub-Sea Vertical Depth Depth (ft) (ft) -148.70 0.00 13.30 162.00 108.30 257.00 195.29 343.99 286.28 434.98 374.23 522.93 461.16 609.86 549.08 697.78 643.86 792.56 733.46 882.16 Local Coordinates Northlngs Eastlngs (ft) (ft) Global Coordinates Northlngs Eastlngs (ft) (ft) Comment Dogleg Rate (0/100ft) Vertical Section O.OON O.OOE 5937910.20 N 498310.10 E 0.00 Tolerable Gyro 0.13 N 0.48 E 5937910.33 N 498310.58 E 0.216 -0.46 0.33N 1.07 E 5937910.53 N 498311.17 E 0.071 -1.06 0.62N 1.60 E 5937910.81 N 498311.70 E 0.104 -1.66 0.47 S 1.29 E 5937909.73 N 498311.39 E 2.311 -0.78 3.13 S 0.22W 5937907.07 N 498309.88 E 0.691 1.99 5.48 S 2.79W 5937904.72 N 498307.31 E 1.235 5.44 7.288 5.91 W 5937902.92 N 498304.19 E 0.227 9.04 10.23 8 11.47W 5937899.98 N 498298.62 E 3.269 15.28 13.68 S 19.24 W 5937896.53 N 498290.86 E 0.652 23.60 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Structure. Northings and Eastings are relative to 394' FNL & 95' FEL. Magnetic Declination at Surface is 25.806° (27-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 394' FNL & 95' FEl and calculated along an Azimuth of 234.594° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 883.00ft., '- The Bottom Hole Displacement is 23.60ft., in the Direction of 234.594° (True). 5 November, 2001 - 12:39 ------,-- - n Page 2 of 3 DrillQuest 2.00.08.005 ~ " Kuparuk River Unit Survey tool program for 2K-27 Gyro ---- From Measured Vertical Depth Depth (ft) (ft) 0.00 -" 5 November, 2001 - 12:39 To Measured Vertical Depth Depth (ft) (ft) 0.00 883.00 882.16 Tolerable Gyro Sperry-Sun Drilling Services Survey Report for 2K-27 Gyro Your Ref: API 501032038700 Job No. AKMM11146, Surveyed: 28 August, 2001 . North Slope, Alaska Kuparuk 2K Survey Tool Description -------. --- Page 3 of 3 DrillQuest 2.00.08.005 f ( 05-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 2K-27 dO/-lbQ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 883.00' MD Window / Kickoff Survey , MD Projected Survey: 14,037.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED lV'ov 0 7 2001 Alaska Oil & Gas C " .'1 !"òr.&.. 0815. CommisSion .""Iff fI,;j,,:-orage ,- DEFINITIVE Kuparuk River Unit North Slope, Alaska Kuparuk2K, Slot 2K-27 2K-27 Job No. AKZZ11146, Surveyed: 28 August, 2001 -',,-. SURVEY REPORT 5 November, 2001 Your Ref: API 501032038700 . Surface Coordinates: 5937910.20 N, 498310.10 E (70°14' 29.7326" N, 150000' 49.1308" W) Kelly Bushing: 148. 70ft above Mean Sea Level ----\ 55 P E!"" ..., Y - !!i U 11 DRII-LING SERVICES A Halliburton Company Survey Ref: svy9682 Sperry-Sun Drilling Services .. Survey Report for 2K-27 DEFINIT\VE Your Ref: AP/501032038700 Job No. AKZZ11146, Surveyed: 28 August, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical . Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (D/100ft) 883.00 5.500 249.000 733.46 882.16 13.685 ~ 19.24 W 5937896.53 N 498290.86 E 20.85 AK-6 BP IFR-AK 934.96 6.390 256.020 785.14 933.84 15.27 S 24.37 W 5937894.94 N 498285.73 E 2.209 26.14 1031.61 9.330 256.440 880.87 1029.57 18.40 S 37.21 W 5937891.80 N 498272.89 E 3.042 39.28 1125.98 13.070 253.460 973.43 1122.13 23.24 5 54.88 W 5937886.98 N 498255.21 E 4.009 57.43 1220.87 16.950 251.980 1065.07 1213.77 30.57 S 78.33 W . 5937879.64 N 498231.77 E 4.109 81.63 1314.96 18.890 250.370 1154.59 1303.29 39.93 S 105.72 W 5937870.29 N 498204.37 E 2.128 110.00 1409.80 21.580 245.000 1243.57 1392.27 52.475 135.99 W 5937857.77 N 498174.09 E 3.444 141.64 1504.73 21.450 244.420 1331.89 1480.59 67.34 5 167.47 W 5937842.90 N 498142.61 E 0.263 174.78 1599.03 20.640 249.880 1419.91 1568.61 80.50 5 196.63 W 5937629.74 N 498111.45 E 2.249 207.38 1694.00 22.810' 254.660 1508.13 1656.83 91.13 5 232.11 W 5937619.12 N 498077.97 E 2.946 241.95 1788.81 24.900 259.180 1594.85 1743.55 99.745 269.45 W 5937810.52 N 498040.63 E 2.927 280.09 1883.53 28.720 258.220 1679.37 1828.07 108.13 S 311.33 W 5937802.14 N 497998.75 E 4.059 322.70 1978.60 33.020 261.350 1760.96 1909.66 116.705 359.32 W 5937793.58 N 497950.75 E 4.827 371.40 2073.09 37.150 262.080 1838.26 1986.96 124.50 S 413.06 W 5937785.79 N 497897.02 E 4.393 425.70 2167.55 40.270 260.350 1911.96 2060.66 133.555 471.42 W 5937776.75 N 497838.65 E 3.496 484.74 2262.15 44.500 259.980 1981.82 2130.52 144.45 S 534.24 W 5937765.87 N 497775.83 E 4.4 79 548.44 2356.75 47.520 258.060 2047.52 2196.22 157.44 S 601.03 W 5937752.89 N 497709.03 E 3.510 616.35 2451.30 51.790 259.470 2108.72 2257.42 171.45 S 671.70 W 5937738.90 N 497638.36 E 4.657 688.24 ~ 2545.28 54.980 260.270 2164.77 2313.47 184.71 S 745.95 W 5937725.66 N 497564.11 E 3.462 763.58 2642.15 58.670 259.320 2217.77 2366.47 199.08 S 825.73 W 5937711.30 N 497484.33 E 3.897 844.55 2736.93 58.310 259.910 2267.30 2416.00 213.65 S 905.21 W 5937696.75 N 497404.84 E 0.653 925.25 2831.67 62.120 259.380 2314.36 2463.06 228.43 S 986.08 W 5937681.99 N 497323.97 E 4.051 1007.35 2926.10 64.080 261.350 2357.08 2505.76 242.51 S 1069.09 W 5937667.93N 497240.95 E 2.787 1091.49 3021.25 66.840 261.790 . 2396.59 2545.29 255.20 S 1154.71 W 5937655.26 N 497155.34 E 2.931 1178.02 3115.37 69.500 262.540 2431.59 2560.29 267.10 S 1241.25 W 5937643.38 N. - 497068.79 E 2.921 1265.38 3210.13 69.090 262.170 2465.09 2613.79 278.89 S 1329.11 W 5937631.61 N 496960.93 E 0.566 1354.02 3305.14 70.670 . 261.980 2497.78 2646.48 291.19 S 1417.46 W 5937619.32 N 496692.57 E 1.674 1443.23 3403.56 70.080 262.930 2530.83 2679.53 303.37 S 1509.36 W 5937607.17 N 496800.67 E 1.089 1535.93 3494.91 69.760 262.330 2562.19 2710.89 314.37 S 1594.45 W 5937596.19 N 496715.56 E 0.709 1621.73 3587.36 71.450 263.030 2592.89 2741.59 325.48 S 1680.94 W 5937585.10 N 496629.09 E 1.963 1708.93 ---_. -- - --0" -.--- --.-- -- _-__n_- 5 November, 2001 - 12:44 Page 2 of 7 DrillQuest 2.00.08.005 "" .. . . Sperry-Sun Drilling Services Survey Report for 2K-27 Your Ref: API 501032038700 Job No. AKZZ11146, Surveyed: 28 August, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3683.85 72.100 262.340 2623.07 2771.77 337.15 S 1771.84 W 5937573.45 N 496538.18 E 0.957 1800.57 -" 3779.02 70.820 262.550 2653.33 2802.03 349.01 5 1861.29 W 5937561.60 N 496448.74 E 1.361 1890.80 3873.55 70.360 261.710 2684.75 2833.45 361.225 1949.60 W 5937549.42 N 496360.42 E 0.969 1979.96 3968.57 69.240 261.440 2717.56 2866.26 374.28 S 2037.81 W 5937536.37 N 496272.20 E 1.208 2069.12 4063.42 70.170 263.630 2750.46 2899.16 385.84 S 2126.02 W 5937524.84 N 496184.00 E 2.377 2158.07 4157.86 70.160 265.080 2782.51 2931.21 394.57 5 2214.42 W 5937516.12 N 496095.59 E 1.444 2246.86 4253.02 69.620 264.940 2815.22 2963.92 402.35 S 2303.44 W 5937508.37 N 496006.57 E 0.584 2336.14 4346.93 70.330 265.060 2847.38 2996.08 410.045 2391.33 W 5937500.70 N 495918.67 E 0.766 2424.29 4442.06 70.100 264.770 2879.58 3028.28 417.975 2480.50 W 5937492.79 N 495829.51 E 0.375 2513.73 4536.21 69.100 263.950 2912.40 3061.10 426.64 5 2568.31 W 5937484.13 N 495741.69 E 1.340 2601.93 4630.85 69.760 263.790 2945.65 3094.35 436.105 2656.41 W 5937474.69 N 495653.59 E 0.715 2690.51 4725.67 70.610 263.400 2977.79 3126.49 446.06 5 2745.06 W 5937464.76 N 495564.94 E 0.976 2779.70 4820.29 69.820 262.450 3009.82 3158.52 457.025 2833.41 W 5937453.82 N 495476.58 E 1.261 2868.73 4914.99 68.840 262.270 3043.25 3191.95 468.80 5 2921.23 W 5937442.06 N 495388.76 E 1.050 2957.34 5006.35 70.680 262.700 3074.86 3223.56 480.01 S 3006.21 W 5937430.87 N 495303.78 E 2.062 3043.05 5100.73 70.950 263.160 3105.87 3254.57 490.98 S 3094.67 W 5937419.92 N 495215.32 E 0.542 3132.19 5195.68 71.200 263.230 3136.67 3285.37 501.625 3183.85 W 5937409.29 N 495126.13 E 0.272 3222.00 5290.65 70.040 263.000 3168.18 3316.88 512.365 3272.80 W 5937398.57 N 495037.19 E 1.243 3311.58 ~ 5385.40 69.440 262.660 3200.99 3349.69 523.45 S 3360.99 W 5937387.50 N 494948.99 E 0.717 3400.47 5480.48 68.690 263.060 3234.96 3383.66 534.49 5 3449.10 W 5937376.48 N 494860.88 E 0.881 3489.27 5575.12 70.950 262.290 3267.61 3416.31 545.82 5 3537.20 W 5937365.17 N 494772.78 E 2.507 3578.09 5669.83 70.020 261.780 3299.25 3447.95 558.19 S 3625.61 W 5937352.82 N 494684.37 E 1.105 3667.36 5764.91 68.380 262.470 3333.01 3481.71 570.37 S 3713.65 W 5937340.66 N 494596.32 E 1.853 3756.23 5859.64 69.580 262.720 3366.99 3515.69 581.775 3801.34 W 5937329.29 N 494508.63 E 1.290 3844.66 5953.57 70.750 263.060 3398.86 3547.56 592.70 5 . 3889.01 W 5937318.37 N 494420.96 E 1.291 3933.01 6048.12 69.760 263.230 3430.80 3579.50 603.32 S 3977.37 W 5937307.77 N 494332.60 E 1.061 4022.00 6142.89 72.420 263.220 3461.51 3610.21 613.90 S 4066.39 W 5937297.21 N 494243.58 E 2.807 4111.64 6238.18 71.410 262.040 3491.09 3639.79 625.51 5 4156.22 W. 5937285.62 N 494153.74 E 1.584 4202.22 6332.64 71.200 263.190 3521.37 3670.07 637.025 4244.95 W 5937274.~4 N 494065.01 E 1.174 4291.69 6426.53 70.550 263.060 3552.13 370p.83 647.63 5 . 4333.02 W 5937263.54 N 493976.94 E 0.705 4380.40 5 November, 2001 - 12:44 Page 3 of 7 DriflQ( est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-27 Your Ref: API 501032038700 Job No. AKZZ11146, Surveyed: 28 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth. Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6521.80 70.300 263.680 3584.05 3732.75 658.00 S 4422.18 W 5937253.19 N 493887.77 E 0.667 4470.15 --, 6616.55 69.510 264.810 3616.61 3765.31 666.92 S 4510.71 W 5937244.29 N 493799.24 E 1.396 4559.09 6711.20 69.560 265.120 3649.70 3798.40 674.71 8 . 4599.05 W 5937236.53 N 493710.90 E' 0.311 4647.69 6743.50 70.740 265.040 3660.67 3809.37 677.31 S 4629.32 W 5937233.93 N 493680.63 E 3.661 4678.04 6843.81 71.300 263.600 3693.29 3841.99 686.708 4723.70 W 5937224.56 N 493586.24 E 1.468 4772.85 6938.23 71.070 263.350 3723.74 3872.44 696.86 S 4812.50 W 5937214.42 N 493497.45 E 0.350 4862.21 7031.60 71.240 263.070 3753.90 3902.60 707.308 4900.24 W 5937203.99 N 493409.70 E 0.337 4950.57 7127.10 70.850 262.020 3784.93 3933.63 719.02 S 4989.80 W 5937192.30 N 493320.14 E 1.117 5040.89 7221.93 70.560 261.760 3816.26 3964.96 731.658 5078.41 W 5937179.69 N 493231.53 E 0.401 5130.39 7317.13 70.260 261.970 3848.18 3996.88 744.34 S 5167.19 W 5937167.02 N 493142.74 E 0.377 5220.07 7411.80 70.020 261.360 3880.34 4029.04 757.25 S 5255.29 W 5937154.13 N 493054.64 E 0.657 5309.10 7506.02 69.440 259.620 3912.99 4061.69 771.858 5342.46 W 5937139.55 N 492967.4 7 E 1.838 5397.42 7601.46 69.080 259.540 3946.78 4095.48 787.99 S 5430.24 W 5937123.43 N 492879.68 E 0.385 5486.56 7696.57 70.460 260.920 3979.67 4128.37 803.138 5518.19W 5937108.31 N 492791.73 E 1.990 5575.72 7791.45 70.700 261.670 4011.22 4159.92 816.678 5606.64 W 5937094.79 N 492703.28 E 0.787 5665.18 7886.33 70.750 261.430 4042.54 4191.24 829.83 8 5695.23 W 5937081.65 N 492614.69 E 0.245 5754.73 7981.36 71.210 262.890 4073.51 4222.21 842.08 S 5784.23 W 5937069.41 N 492525.69 E 1.531 5844.56 8075.79 71.310 263.050 4103.85 4252.55 853.03 S 5872.98 W 5937058.49 N 492436.93 E 0.192 5933.98 /-.. 8170.40 71.090 263.810 4134.34 4283.04 863.28 S 5961.95 W 5937048.26 N 492347.96 E 0.795 6023.54 8265.31 71.270 263.990 4164.96 4313.66 872.82 S 6051.28 W 5937038.73 N 492258.63 E 0.261 6113.35 8360.35 70.720 263.790 4195.91 4344.61 882.39 8 6140.63 W 5937029.19 N 492169.28 E 0.612 6203.18 8455.77 69.950 263.840 4228.02 4376.72 892.07 8 6229.96 W 5937019.53 N 492079.94 E 0.808 6293.01 8549.30 69.920 263.290 4260.11 4408.81 901.91 8 6317.26 W 5937009.70N 491992.64 E 0.553 6380.85 8643.75 70.080 263.720 . 4292.41 4441.11 911.958 6405.44 W 5936999.68 N 491904.46 E 0.460 6469.60 8738.89 69.660 263.760 4325.15 44 73.85 921.69 S 6494.24 W 5936989.96 N. . 491815.66 E 0.443 6558.90 8833.56 69.120 . 263.940 4358.48 4507.18 931.198 6582.34 W 5936980.49 N 491727.56 E 0.598 6647.49 8928.31 68.590 . 263.740 4392.66 4541.36 940.678 6670.20 W 5936971.03 N 491639.69 E 0.593 6735.84 9021.72 69.700 264.530 4425.91 4574.61 949.59 8 6757.03 W 5936962.13 N 491552.86 E 1.427 6823.10 9117.08 69.260 264.720 4459.34 4608.04 957.95 S 6845.94 W 5936953.78 N 491463.94 E 0.498 6912.35 9212.13 70.860 265.550 4491.75 4640.45 965.53 8 6934.97 W 5936946.23 N 491374.91 E 1.873 7001.61 5 November, 2001 - 12:44 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-27 Your Ref: API 501032038700 Job No. AKZZ11146, Surveyed: 28 August, 2001 .. North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth. Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9305.80 71.010 267.300 4522.35 4671.05 971.055 7023.33 W 5936940.73 N 491286.56 E 1.773 7089.93-- 9400.22 71.800 263.550 4552.47 4701.17 978.195 7112.51W 5936933.60N 491197.37E 3.856 7179.29 9494.99 71.830 263.640 4582.04 4730.74 988.235 7201.99 W 5936923.58 N 491107.89 E 0.096 7269.31 9590.48 72.040 262.840 4611.66 4760.36 998.92 S 7292.14 W 5936912.91 N 491017.74 E 0.826 7360.09 9684.86 71.760 262.990 4640.98 4789.68 1009.995 7381.16 W 5936901.87 N 490928.71 E 0.333 7449.80 9779.57 70.680 262.720 4671.47 4820.17 1021.145 7470.13 W 5936890.74 N 490839.74 E 1.172 7539.46 9874.61 70.950 262.720 4702.70 4851.40 1032.51 S 7559.17 W 5936879.38 N 490750.70 E 0.284 7629.22 9969.51 70.170 262.180 4734.28 4882.98 1044.27 S 7647.88 W 5936867.65 N 490661.98 E 0.982 7718.71 10063.80 69.720 261.430 4766.62 4915.32 1056.89 S 7735.55 W 5936855.04 N 490574.31 E 0.887 7807.28 10158.60 68.570 262.970 4800.37 4949.07 1068.925 7823.31 W 5936843.03 N 490486.55 E 1.943 7895.86 10253.10 69.550 261.820 4834.14 4982.84 1080.605 7910.79W 5936831.37N 490399.07E 1.539 7984.11 10348.30 69.920 263.930 4867.12 5015.82 1091.685 7999.40W 5936820.32N 490310.45E 2.115 8073.41 10442.90 69.120 262.210 4900.22 5048.92 1102.375 8087.37 W 5936809.65 N 490222.48 E 1.902 8162.03 10537.40 69.040 261.740 4933.96 5082.66 1114.695 8174.78 W 5936797.34 N 490135.07 E 0.472 8250.29 10632.40 69.210 262.510 4967.81 5116.51 1126.855 8262.71 W 5936785.20 N 490047.14 E 0.778 8339.05 10726.40 69.530 262.440 5000.93 5149.63 1138.37 S 8349.92 W 5936773.70 N 489959.93 E 0.347 8427.02 10821.20 69.620 262.200 - 5034.02 5182.72 1150.24 S 8437.96 W 5936761.85 N 489871.88 E 0.256 8515.86 10916.10 69.620 261.750 5067.07 5215.77 1162.665 8526.05 W 5936749.45 N 489783.79 E 0.445 8604.82 ---. 11010.70 70.110 262.640 5099.63 5248.33 1174.725 8614.05 W 5936737.41 N 489695.79 E 1.024 8693.63 11105.50 70.230 263.050 5131.79 5280.49 1185.835 8702.53W 5936726.32N 489607.31E 0.426 8782.81 11200.10 69.840 262.930 5164.09 5312.79 1196.685 8790.78 W 5936715.49 N 489519.05 E 0.429 8871.72 11294.70 69.830 262.530 5196.70 5345.40 -1207.925 8878.87 W 5936704.27 N 489430.96 E 0.397 8960.52 11389.80 69.400 260.120 5229.83 5378.53 1221.36 5 8966.98 W 5936690.85 N 489342.84 E 2.418 9049.64 11484.70 69.590 260.330 5263.07 5411.77 1236.45S 9054.58W 5936675.78N 489255.24E 0.288 9138.45 11579.30 69.560 261.620 5296.09 5444.79 1250.365 - 9142.13 W 5936661.89 N - 489167.69 E 1.278 9227.07 11673.80 68.950 263.160 5329.56 5478.26 1262.065 9229.72 W 5936650.21 N 489080.09 E 1.655 9315.44 11702.30 68.490 263.340 5339.91 5488.61 1265.195 9256.10W 5936647.09 N 489053.72 E 1.718 9341.99 11797.40 65.380 264.920 5377.16 5525.86 1274.155 9343.12W - 5936638.15N 488966.70E 3.610 9429.44 11892.30 61.740 265.200 5419.41 5568.11 1281.475 9427.76 W 5936630.85 N 488882.05E 3.845 9514.32 11986.20 57.640264.600 5466.79 5615.49 1288.665 9508.49 W 5936623.67 N 488801.32 E 4.401 9595.30 - ~_n_- ---- 5 November; 2001 - 12:44 Page 5 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-27 - Your Ref: API 501032038700 Job No. AKZZ11146, Surveyed: 28 August, 2001 . . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) '-.-- 12082.50 54.180 264.760 5520.76 5669.46 1296.065 9587.88 W 5936616.29 N 488721.93 E 3.596 9674.99 ,--"', 12177.00 50.550 262.880 5578.45 5727.15 1304.085 9662.27 W 5936608.28 N 488647.54 E 4.152 9749.78 12271.30 47.840 262.650 5640.07 5788.77 1313.075 9733.08 W 5936599.32 N 488576.73 E 2.880 9821 .16 12366.20 44.270 262.120 5705.92 5854.62 1322.11 5 9800.79 W 5936590.29 N 488509.01 E 3.783 9889.47 12460.90 40.940 261.400 5775.61 5924.31 1331.28 S 9864.23 W 5936581.13 N 488445.57 E 3.554 9953.56 12555.40 37.830 262.300 5848.64 5997.34 1339.80 S 9923.57 W 5936572.63 N 488386.23 E 3.346 10013.51 12650.50 35.280 262.640 5925.03 6073.73 1347.235 9979.72 W 5936565.21 N 488330.08 E 2.690 10070.15 12745.10 33.910 263.200 6002.90 6151.60 1353.85 5 10033.02 W 5936558.60 N 488276.78 E 1.487 10123.86 12839.90 31.820 263.310 6082.53 6231.23 1359.89 5 10084.11 W 5936552.57 N 488225.69 E 2.206 10175.29 12935.10 29.750 - 264.160 6164.31 6313.01 1365.22 5 10132.53 W 5936547.25 N 488177.26 E 2.222 10224.01 13029.90 27.960 265.810 6247.33 6396.03 1369.24 5 10178.10 W 5936543.24 N 488131.69 E 2.066 10269.71 13123.70 25.810 266.220 6330.99 6479.69 1372.195 10220.41 W 5936540.30 N 488089.38 E 2.301 10312.05 13218.40 22.760 267.340 6417.30 6566.00 1374.40 S 10259.29 W 5936538.10 N 488050.50 E 3.257 10350.89 13313.50 19.590 268.070 6505.97 6654.67 1375.79 S 10293.61 W 5936536.71 N 488016.18 E 3.345 10385.10 13407.80 16.920 270.900 6595.52 6744.22 1376.11 5 10323.14 W 5936536.40 N 487986.65 E 2.983 10414.41 13502.60 15.370 270.910 6686.58 6835.28 1375.69 5 10349.49 W 5936536.83 N 487960.30 E 1.635 10440.50 13597.10 14.470 274.760 6777.89 6926.59 1374.51 S 10373.78 W 5936538.01 N 487936.01 E 1.416 10464.43 13692.20 12.960 273.890 6870.28 7018.98 1372.81 S 10396.26 W 5936539.73 N 487913.53 E 1.603 10486.50 ....-...., 13787.30 11.960 275.140 6963.14 7111.84 1371.205 10416.72 W 5936541.34 N 487893.07 E 1.089 10506.57 13881.60 10.650 275.970 7055.60 7204.30 1369.42 S 10435.12 W 5936543.12 N 487874.68 E 1.400 10524.59 13973.70 9.900 278.970 - 7146.23 7294.93 1367.305 10451.40 W 5936545.25 N 487858.39 E 1.000 W540.46 14037.00 9.900 278.970 7208.59 7357.29 1365.60 S 10462.15 W 5936546.94 N 487847.64 E 0.000 10550.90 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. - Vertical depths are relative to Structure. Northings and Eastings are relative to 394' FNL & 95' FEL. Magnetic Declination at Surface is 25.805° (27-Aug-01) The Dogleg Severity is in Degreesper 100feet(US). Vertical Section is from 394' FNL & 95' FEL and calculated along an Azimuth of 262.563° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14037.00ft., - - ----- n______---- 5 November, 2001 - 12:44 Page 6 of 7 DrillQuest 2.00.08.005 ... I . Kuparuk River Unit Sperry-Sun Drilling Services Survey Report for 2K-27 Your Ref: API 501032038700 Job No. AKZZ11146, Surveyed: 28 August, 2001 The Bottom Hole Displacement is 10550.90ft., in the qirection of 262.563° (True). Comments "-......- Measured Depth - (ft) 14037.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7357.29 1365.60 S Survey tool program for 2K-27 From Measured Vertical Depth Depth (ft) (ft) 0.00 883.00 5 November~ 2001 - 12:44 0.00 882.16 To Measured Vertical Depth Depth (ft) (ft) 883.00 14037.00 Comment 10462.15 W Projected Survey Survey Tool Description 882.16 Tolerable Gyro (2K-27 Gyro) 7357.29 - AK-6 BP _IFR-AK (2K-27) ----_u_-- _h_-h Page 7 of 7 .. North Slope, Alaska Kuparuk 2K --- --- __m_____- DrillQuest 2.00.08.005 (' AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2K-27 MWD ÒJO/-Ib9 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 883.00' MD . Window / Kickoff Survey , MD Projected Survey: 14,037.00' MD (if applicable Please call me at 273-3545 if you have any ,questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) (' 05-Nov-01 REC,E"/ED {\iOV 0 7 2001 Aras!,r~ O'! Þ G'~ ,"". . - i\g tI ~~ ",.BS c,O!'!i/;¡ .1 'l"'i'i:"j"'", "li'!"I"','",¡, '. > li.".'io..I.~I~~¡4t:;)un Aner;,:)~'~~gf} (j- ~' '--.. I -..... <J ra -c=--" Kuparuk River Unit North Slope, Alaska Kuparuk 2K, Slot 2K-27 2K-27 MWD Job No. AKMM11146, Surveyed: 28 August, 2001 SURVEY REPORT 5 November, 2001 Your Ref: API 501032038700 Surface Coordinates: 5937910.20 N, 498310.10 E (70014' 29.7326" N, 150000' 49.1308" W) Kelly Bushing: 148. 70ft above Mean Sea Level "'"- 5pe"""y-!5uf'1 DRILLING. seRVIc:es A Halliburton Company SUlvey Ref: svy9683 Sperry-Sun Drilling Services Survey Report for 2K.27 MWD Your Ref: API 501032038700 Job No. AKMM11146, Surveyed: 28 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 0 Oft) 883.00 5.500 249.000 733.46 882.16 13.68 3 19.24 W 5937896.53 N 498290.86 E 20.82 MWD Magnetic 934.96 6.390 256.570 785.14 933.84 15.24 3 24.38 W 5937894.97 N 498285.72 E 2.279 26.12 1031.61 9.330 256.670 880.87 1029.57 18.30 3 37.23 W 5937891.91 N 498272.86 E 3.042 39.26 --- 1125.98 13.070 253.390 973.43 1122.13 23.11 3 54.91 W 5937887.10 N 498255.19 E 4.019 57.40 1220.87 16.950 252.040 1065.07 1213.77 30.45 3 78.36 W 5937879.77 N 498231.74 E 4.105 81.60 1314.96 18.890 250.630 1154.59 1303.29 39.73 S 105.78 W 5937870.50 N 498204.31 E 2.113 109.97 1409.80 21.580 244.320 1243.58 1392.28 52.38 3 135.99 W 5937857.85 N 498174.10 E 3.649 141.55 1504.73 21.450 244.310 1331.89 1480.59 67.473 167.36 W 5937842.77 N 498142.72 E 0.137 174.59 1599.03 20.640 249.660 1419.91 1568.61 80.72 S 198.49 W 5937829.52 N 498111.59 E 2.210 207.15 1694.00 22.810 254.650 1508.14 1656.84 91.42 S 231.94 W 5937818.83 N 498078.14 E 2.999 241.69 1788.81 24.900 258.940 1594.85 1743.55 100.11 S 269.26 W 5937810.15 N 498040.82 E 2.864 279.81 1883.53 28.720 257.980 1679.37 1828.07 108.68 3 311.10W 5937801.59 N 497998.97 E 4.059 322.40 1978.60 33.020 261.300 1760.96 1909.66 117.363 359.08 W 5937792.92 N 497951.00 E 4.863 371.09 2073.09 37.150 262.670 1838.27 1986.97 124.903 412.85 W 5937785.39 N 497897.22 E 4.449 425.38 2167.55 40.270 260.940 1911.97 2060.67 133.35 S 471.30 W 5937776.96 N 497838.77 E 3.496 484.44 2262.15 44.500 259.410 1981.83 2130.53 144.263 534.11 W 5937766.06 N 497775.96 E 4.602 548.13 2356.75 47.520 258.390 2047.53 2196.23 157.38 3 600.89 W 5937752.96 N 497709.18 E 3.285 616.03 2451.30 51.790 259.220 2108.72 2257.42 171.35 S 671.56 W 5937739.00 N 497638.50 E 4.565 687.91 2545.28 54.980 260.890 2164.77 2313.47 184.35 3 745.85 W 5937726.02 N 497564.20 E 3.682 763.25 2642.15 58.670 259.590 2217.77 2366.47 198.11 S 825.74 W 5937712.27 N 497484.31 E 3.971 844.24 -'- 2736.93 58.310 261.680 2267.31 2416.01 211.263 905.46 W 5937699.14 N 497404.59 E 1.918 924.98 2831.67 62.120 259.780 2314.37 2463.07 224.53 S 986.59 W 5937685.89 N 497323.46 E 4.382 1007.14 2926.10 64.080 262.260 2357.09 2505.79 237.66 S 1069.76 W 5937672.78 N 497240.29 E 3.129 1091.30 3021.25 66.840 262.390 2396.61 2545.31 249.21 S 1155.53 W 5937661.24 N 497154.51 E 2.903 1177.85 3115.37 69.500 263.520 2431.61 2580.31 259.92 S 1242.23 W 5937650.56 N 497067.81 E 3.038 1265.21 3210.13 69.090 263.240 2465.11 2613.81 270.14 3 1330.28 W 5937640.36 N 496979.76 E 0.513 1353.84 3305.14 70.670 262.980 2497.79 2646.49 280.84 3 1418.85 W 5937629.68 N 49689~ .19 E 1.683 1443.05 3403.56 70.080 264.300 2530.85 2679.55 291.11 S 1510.97 W 5937619.43 N 496799.06 E 1.398 1535.74 3494.91 69.760 263.030 2562.21 2710.91 300.58 3 1596.25 W 5937609.98 N 496713.79 E 1.352 1621.52 3587.36 71.450 263.760 2592.91 2741.61 310.61 S 1682.87 W 5937599.97 N 496627.16 E 1.974 1708.71 ---- ------ 5 November, 2001 - 13:13 Page 2 of 7 DrillQlJest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-27 MWD Your Ref: AP/501032038700 Job No. AKMM11146, Surveyed: 28 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth. Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O /1 OOft) " 3683.85 72.100 263.170 2623.09 2771.79 321.04 S 1773.92 W 5937589.56 N 496536.11 E 0.889 1800.35 3779.02 70.820 263.260 2653.35 2802.05 331.70 S 1863.52 W 5937578.92 N 496446.51 E 1.348 1890.58 3873.55 70.360 262.310 2684.76 2833.46 342.89 S 1951.97 W 5937567.74 N 496358.06 E 1.065 - 1979.73 '- 3968.57 69.240 262.580 2717.57 2866.27 354.62 S 2040.37 W 5937556.04 N 496269.65 E 1.208 2068.91 4063.42 70.170 263.160 2750.47 2899.17 365.66 S 2128.64 W 5937545.02 N 496181.38 E 1.136 2157.87 4157.86 70.160 262.890 2782.52 2931.22 376.45 S 2216.82 W 5937534.25 N 496093.20 E 0.269 2246.70 4253.02 69.620 265.140 2815.24 2963.94 385.77 S 2305.68 W 5937524.95 N 496004.33 E 2.292 2336.03 4346.93 70.330 265.910 2847.40 2996.10 392.65 S 2393.64 W 5937518.09 N 495916.37 E 1.079 2424.15 4442.06 70.100 264.470 2879.60 3028.30 400.15S 2482.84 W 5937510.60 N 495827.17 E 1.445 2513.58 4536.21 69. 100 261.570 2912.42 3061.12 410.87 S 2570.42 W 5937499.91 N 495739.59 E 3.076 2601.81 4630.85 69.760 262.810 2945.68 3094.38 422.91 S 2658.20 W 5937487.89 N 495651.80 E 1.411 2690.41 4725.67 70.610 261.880 2977.82 3126.52 434.79 S 2746.61 W 5937476.02 N 495563.39 E 1.286 2779.61 4820.29 69.820 262.210 3009.85 3158.55 447.12 S 2834.79W 5937463.72 N 495475.21 E 0.897 2868.64 4914.99 68.840 261.280 3043.27 3191.97 459.83 S 2922.47 W 5937451.02 N 495387.53 E 1.384 2957.23 5006.35 70.680 262.140 3074.88 3223.58 472.19 S 3007.29 W 5937438.69 N 495302.70 E 2.199 3042.93 5100.73 70.950 262.690 3105.89 3254.59 483.95 S 3095.65 W 5937426.94 N 495214.34 E 0.620 3132.07 5195.68 71.200 262.630 3136.69 3285.39 495.43 S 3184.73 W 5937415.48 N 495125.26 E 0.270 3221.88 5290.65 70.040 262.380 3168.20 3316.90 507.11 S 3273.55 W 5937403.82 N 495036.43 E 1.246 3311.47 5385.40 69.440 261.890 3201.01 3349.71 519.28 S 3361.60 W 5937391.68 N 494948.38 E 0.798 3400.35 5480.48 68.690 262.980 3234.99 3383.69 530.97 S 3449.63 W 5937380.00 N 494860.35 E 1.330 3489.15 ~- 5575.12 70.950 262.060 3267.63 3416.33 542.54 S 3537.70 W 5937368.46 N 494772.28 E 2.556 3577.98 5669.83 70.020 262.240 3299.27 3447.97 554.73 S 3626.13 W 5937356.28 N 494683.85 E 0.998 3667.24 5764.91 68.380 261.870 3333.03 3481.73 567.01 S 3714.16 W 5937344.02 N 494595.82 E 1.763 3756.12 5859.64 69.580 262.090 3367.01 3515.71 579.35 S 3801.72 W 5937331.70 N 494508.25 E 1.285 3844.53 5953.57 70.750 263.290 3398.88 3547.58 590.59 S 3889.35 W 5937320.48 N 494420.62 E 1.731 3932.89 6048.12 69.760 263.390 3430.83 3579.53 600.91 S 3977.74 W 5937310.18 N 494332.22 E 1.052 4021.87 6142.89 72.420 263.230 3461.54 3610.24 611.35 S 4066.78 W 5937299.76 N 494243.18 E 2.811 4111.51 6238.18 71.410 262.270 3491.12 3639.82 622.78 S 4156.63 W 5937288.35 N 494153.33 E 1.428 4202.09 6332.64 71 200 263.140 3521 .40 3670.10 634.15 S 4245.39 W 5937277.01 N 494064.57 E 0.900 4291.57 6426.53 70.550 263.150 3552.16 3700.86 644.73 S 4333.46 W 5937266.44 N 493976.50 E 0.692 4380.27 --._._~._--- ---~~_u 5 November, 2001 - 13:13 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-27 MWD Your Ref: API 501032038700 Job No. AKMM11146, Surveyed: 28 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6521.80 70.300 263.050 3584.08 3732.78 655.52 S 4422.57 W 5937255.67 N 493887.38 E 0.,280 4470.03 6616.55 69.510 264.140 3616.63 3765.33 665.45 S 4511.00W 5937245.77 N 493798.95 E 1.365 4559.00 6711.20 69.560 265.700 3649.73 3798.43 673.30 S 4599.32 W 5937237.93 N 493710.63 E 1.545 4647.61 -~""=-" 6743.50 70.740 264.940 3660.69 3809.39 675.78 S 4629.60 W 5937235.46 N 493680.35 E 4.271 4677.96 6843.81 71.300 266.110 3693.32 3842.02 683.18 S 4724.16 W 5937228.08 N 493585.78 E 1.236 4772.69 6938.23 71.070 265.910 3723.77 3872.47 689.39 S 4813.32 W 5937221.88 N 493496.62 E 0.315 4861.92 7031.60 71.240 265.620 3753.93 3902.63 695.92 S 4901.45W 5937215.38 N 493408.50 E 0.346 4950.16 7127.10 70.850 264.590 3784.95 3933.65 703.63 S 4991.44 W 5937207.69 N 493318.51 E 1.099 5040.40 7221.93 70.560 261.040 3816.29 3964.99 714.82 S 5080.22 W 5937196.52 N 493229.72 E 3.546 5129.88 7317.13 70.260 261.980 3848.21 3996.91 728.06 S 5168.92 W 5937183.30 N 493141.01 E 0.982 5219.55 7411.80 70.020 261.350 3880.38 4029.08 740.96 S 5257.02 W 5937170.41 N 493052.91 E 0.675 5308.58 7506.02 69.440 260.440 3913.02 4061.72 754.95 S 5344.29 W 5937156.45 N 492965.64 E 1.095 5396.92 7601.46 69.080 260.420 3946.82 4095.52 769.79 S 5432.31 W 5937141.63 N 492877.62 E 0.378 5486.10 7696.57 70.460 262.040 3979.71 4128.41 783.39 S 5520.50 W 5937128.05 N 492789.42 E 2.159 5575.31 7791.45 70.700 262.110 4011.25 4159.95 795.73 S 5609.13 W 5937115.73 N 492700.79 E 0.262 5664.79 7886.33 70.750 261.620 4042.57 4191.27 808.40 S 5697.79 W 5937103.08 N 492612.13 E 0.490 5754.34 7981.36 71.210 263.840 4073.55 4222.25 819.77 S 5786.90 W 5937091.73 N 492523.02 E 2.261 5844.17 8075.79 71.310 263.510 4103.88 4252.58 829.62 S 5875.78 W 5937081.90 N 492434.13 E 0.347 5933.58 8170.40 71.090 264.300 4134.37 4283.07 839.13 S 5964.84 W 5937072.41 N 492345.08 E 0.824 6023.12 8265.31 71.270 266.330 4165.00 4313.70 846.46 S 6054.37 W 5937065.09 N 492255.54 E 2.033 6112.86 ,- 8360.35 70.720 264.660 4195.95 4344.65 853.52 S 6143.94 W 5937058.06 N 492165.97 E 1.759 6202.61 8455.77 69.950 264.160 4228.06 4376.76 862.27 S 6233.37 W 5937049.33 N 492076.54 E 0.946 6292.42 8549.30 69.920 262.700 4260.15 4408.85 872.32 S 6320.64 W 5937039.29 N 491989.26 E 1.467 6380.26 8643.75 70.080 264.030 4292.45 4441.15 882.58 S 6408.80 W 5937029.06 N 491901.10 E 1.334 6469.01 8738.89 69.660 263.340 4325.20 4473.90 892.40 S 6497.59 W 5937019.26 N 491812.31 E 0.812 6558.32 8833.56 69.120 263.630 4358.52 4507.22 902.46 S 6585.62 W 5937009.22 N 491724.27 E 0.638 6646.92 8928.31 68.590 262.970 4392.70 4541.40 912.76 S 6673.39 W 5936998.93 N 491636.51 E 0.857 6735.29 9021.72 69.700 263.580 4425.95 4574.65 922.98 S 6760.08 W 5936988.73 N 491549.82 E 1.336 6822.57 9117.08 69.260 264.660 4459.38 4608.08 932.14 S 6848.92 W 5936979.60 N 491460.98 E 1.157 6911.85 9212.13 70.860 265.820 4491.80 4640.50 939.54 S 6937.95 W 5936972.21 N 491371.93 E 2.037 7001.11 ------ --- u_--- 5 November, 2001 - 13:13 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-27 MWD Your Ref: API 501032038700 Job No. AKMM11146, Surveyed: 28 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ----, 9305.80 71.010 266.330 4522.39 4671.09 945.60 S 7026.28 W 5936966.17 N 491283.61 E 0.þ39 7089.49 9400.22 71.800 263.390 4552.51 4701.21 953.63 5 7115.40 W 5936958.17 N 491194.49 E 3.067 7178.90 9494.99 71.830 263.670 4582.08 4730.78 963.77 S 7204.86 W 5936948.04 N 491105.02 E 0.282 7268.93 '~. 9590.48 72.040 263.070 4611.69 4760.39 974.25 S 7295.04 W 5936937.58 N 491014.85 E 0.637 7359.71 9684.86 71.760 263.170 4641.02 4789.72 985.00 5 7384.10 W 5936926.86 N 490925.78 E 0.313 7449.41 9779.57 70.680 262.620 4671.51 4820.21 996.09 5 7473.08 W 5936915.79 N 490836.80 E 1.266 7539.08 9874.61 70.950 262.580 4702.74 4851.44 1007.65 S 7562.09 W 5936904.25 N 490747.78 E 0.287 7628.84 9969.51 70.170 262.330 4734.32 4883.02 1019.40 S 7650.80 W 5936892.52 N 490659.07 E 0.859 7718.33 10063.80 69.720 261.340 4766.66 4915.36 1031.985 7738.48 W 5936879.96 N 490571.39 E 1.096 7806.89 10158.60 68.570 264.330 4800.41 4949.11 1043.03 S 7826.36 W 5936868.92 N 490483.51 E 3.187 7895.46 10253.10 69.550 261.880 4834.19 4982.89 1053.64 S 7913.97 W 5936858.34 N 490395.89 E 2.634 7983.71 10348.30 69.920 262.910 4867.17 5015.87 1065.45 S 8002.49 W 5936846.54 N 490307.37 E 1.087 8073.02 10442.90 69.120 262.380 4900.26 5048.96 1076.80 S 8090.38 W 5936835.22 N 490219.48 E 0.995 8161.63 10537.40 69.040 261.490 4934.01 5082.71 1089.185 8177.78 W 5936822.85 N 490132.08 E 0.884 8249.90 10632.40 69.210 263.040 4967.86 5116.56 1101.135 8265.73 W 5936810.93 N 490044.12 E 1.535 8338.65 10726.40 69.530 262.600 5000.98 5149.68 1112.12 5 8353.01 W 5936799.95 N 489956.84 E 0.555 8426.63 10821.20 69.620 262.280 5034.06 5182.76 1123.81 S 8441.08 W 5936788.28 N 489868.77 E 0.330 8515.47 10916.10 69.620 261.860 5067.11 5215.81 1136.08 S 8529.19 W 5936776.03 N 489780.66 E 0.415 8604.42 11010.70 70.110 261.050 5099.68 5248.38 1149.28 S 8617.02 W 5936762.85 N 489692.82 E 0.956 8693.22 11105.50 70.230 261.910 5131.84 5280.54 1162.49 S 8705.21 W 5936749.66 N 489604.63 E 0.863 8782.37 . -"...- 11200.15 69.840 261.940 5164.15 5312.85 1174.995 8793.29 W 5936737.18 N 489516.54 E 0.413 8871.33 11294.74 69.830 261.500 5196.76 5345.46 1187.785 8881.16W 5936724.41 N 489428.67 E 0.437 8960.11 11389.82 69.400 260.350 5229.88 5378.58 1201.835 8969.17 W 5936710.38 N 489340.66 E 1.221 9049.19 11484.70 69.590 260.330 5263.12 5411.82 1216.745 9056.78 W 5936695.49 N 489253.05 E 0.201 9137.98 11579.30 69.560 262.200 5296.13 5444.83 1230.21 5 9144.40 W 5936682.04 N 489165.43 E 1.853 9226.60 11673.80 68.950 263.630 5329.61 5478.31 1241.11 5 9232.09 W 5936671.16 N 489077.73 E 1.555 9314.97 11702.30 68.490 263.330 5339.95 5488.65 1244.125 9258.48 W 5936668.15 N 489051.35 E 1.889 9341.53 11797.40 65.380 264.920 5377.21 5525.91 1253.09 S 9345.50 W 5936659.20 N 488964.32 E 3.614 9428.98 1189,2.30 61 .740 265.340 5419.45 5568.15 1260.31 5 9430.15 W 5936652.00 N 488879.67 E 3.856 9513.86 11986.20 57.640 264.570 5466.83 5615.53 1267.43 S 9510.88 W 5936644.91 N 488798.93 E 4.423 9594.85 - ----- ---- ___-0 --------- 5 November, 2001 - 13:13 Page 5 of 7 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2K-27 MWD Your Ref: API 501032038700 Job No. AKMM11146, Surveyed: 28 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical . Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) eft) (ft) (ft) (ft) (0/100ft) 12082.50 54.180 264.890 5520.80 5669.50 1274.76 S 9590.28 W 5936637.59 N 488719.53 E 3.(303 9674.53 12177.00 50.550 263.000 5578.50 5727.20 1282.62 S 9664.69 W 5936629.75 N 488645.12 E 4.155 9749.33 12271.30 47.840 262.760 5640.12 5788.82 1291.46 S 9735.51 W 5936620.92 N 488574.30 E 2.880 9820.71 ~- 12366.20 44.270 262.360 5705.96 5854.66 1300.30 S 9803.25 W 5936612.10 N 488506.55 E 3.774 9889.02 12460.90 40.940 261.780 5775.66 5924.36 1309.13 S 9866.74 W 5936603.28 N 488443.07 E 3.541 9953.12 12555.40 37.830 262.410 5848.69 5997.39 1317.39 S 9926.12W 5936595.04 N 488383.68 E 3.318 10013.07 12650.50 35.280 262.620 5925.07 6073.77 1324.77 S 9982.28 W 5936587.67 N 488327.53 E 2.685 10069.70 12745.10 33.910 263.250 6002.95 6151.65 1331.38 S 10035.58 W 5936581.07 N 488274.23 E 1.497 10123.41 12839.90 31.820 263.330 6082.57 6231.27 1337.39 S 10086.67 W 5936575.07 N 488223.13 E 2.205 10174.85 12935.10 29.750 264.060 6164.35 6313.05 1342.75 S 10135.09 W 5936569.72 N 488174.71 E 2.209 10223.57 13029.90 27.960 265.810 6247.38 6396.08 1346.81 S 10180.65 W 5936565.67 N 488129.14 E 2.088 10269.27 13123.70 25.810 266.240 6331.04 6479.74 1349.76 S 10222.97 W 5936562.73 N 488086.83 E 2.301 10311.62 13218.40 22.760 267.370 6417.35 6566.05 1351.95 S 10261.85 W 5936560.55 N 488047.95 E 3.258 10350.46 13313.50 19.590 268.070 6506.01 6654.71 1353.33 S 10296.16 W 5936559.18 N 488013.63 E 3.344 10384.68 13407.80 16.920 271.150 6595.56 6744.26 1353.59 S 10325.69 W 5936558.93 N 487984.11 E 3.010 10413.99 13502.60 15.370 271.190 6686.62 6835.32 1353.05 S 10352.05 W 5936559.47 N 487957.75 E 1.635 10440.07 13597.10 14.470 275.020 6777.94 6926.64 1351.76 S 10376.33 W 5936560.77 N 487933.47 E 1.412 10463.99 13692.20 12.960 274.060 6870.32 7019.02 1349.96 S 10398.80 W 5936562.57 N 487910.99 E 1.606 10486.05 13787.30 11.960 275.340 6963.18 7111.88 1348.29 S 10419.25 W 5936564.25 N 487890.55 E 1.091 10506.12 13881.60 10.650 276.100 7055.65 7204.35 1346.45 S 10437.65 W 5936566.08 N 487872.15 E 1.398 10524.13 -~- 13973.70 9.900 279.110 7146.27 7294.97 1344.30 S 10453.93 W 5936568.25 N 487855.87 E 1.001 10540.00 14037.00 9.900 279.110 7208.63 7357.33 1342.57 S 10464.67 W 5936569.97 N 487845.13 E 0.000 10550.44 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Structure. Northings and Eastings are relative to 394' FNL & 95' FEL. Magnetic Declination at Surface is 25.805° (27-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 394' FNL & 95' FEL and calculated along an Azimuth of 262.689° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14037.00ft., -- ------ -- ------______n 5 November, 2001 - 13:13 Page 6 of 7 DrillQuest 2.00.08.005 Kuparuk River Unit Sperry-Sun Drilling Services Survey Report for 2K-27 MWD Your Ref: API 501032038700 Job No. AKMM111461 Surveyed: 28 Augustl 2001 The Bottom Hole Displacement is 10550.44ft., in the qirection of 262.689° (True). .........~ Comments -- Measured Depth (ft) 14037.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7357.33 1342.57 S Survey tool program for 2K-27 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 883.00 "- 5 November, 2001 - 13:13 0.00 882.16 To Measured Vertical Depth Depth (ft) (ft) 883.00 14037.00 882.16 7357.33 - _nq___- Comment 10464.67 W Projected Survey Survey Tool Description Tolerable Gyro (2K-27 Gyro) MWD Magnetic (2K-27 MWD) Page 7 of 7 . North Slope, Alaska Kuparuk 2K ------ -- DrillQuest 2.00.08.005 Se_lulI_.rgep NO. 1641 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia Color CD 2K-27 ~r} d ~ STATIC BOTTOMHOLE PRESSURE 11/07/01 1 1 2L-317A ~/J/)- ~ It\ WATERFLOW LOGJRST-C WIPSP 11/08/01 1 1 2N-304 ':;<01- (30 SBHP & JEWELRY LOG 11/12/01 1 1 2N-307 IC 'i-b}"1 INJECTION PROFILE 11/09/01 1 1 2N-325 /CI9-/{ð3 INJECTION PROFILE 11/11/01 1 1 2N-331 I Ot 9' J / ï INJECTION PROFILE 11/11/01 1 1 2N-343 / ~ s? - (")q.:> INJECTION PROFILE 11/13/01 1 1 2N-349A ~OD-,'2"q INJECTION PROFILE 11/13/01 1 1 SIG~ (1 Chz~ RECEIVED DATE: NeV 2 7 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~ Oil & Gas Cons. Commission AnctrOrage 11/26/01 --, --\ SI~lInbepgep NO. 1566 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color " 1 C-11 UD t-/;1t 21439 USIT V 10/06/01 1 1 C-119 --::70}- '30, 21438 SCMT V 09/20/01 1 2K-27..:Jö/-/fn'1 21440 SCMT V --c- 10/03/01 1 2N-302':> ,..., I-I IS 21437 SCMT ,/ 09/01/01 1 ...., ^^ ,.......",¡ -O7~9.'81 .... ~. SIGNED:~~ RECEIVED DATE: OCT 3 0 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Æ~ØØff&'Gas Cons. Commission Anchorage 1 0/24/2001 ,-- ~, DIVISION OF OIL AND GAS 6J OJ-lle'J TONY KNOWLES, GOVERNOR V' ~~&~rn @~ &lJß~rJYA DEPARTMENT OF NATURAL RESOURCES Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 550 WEST 7TH A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 RECEIVED SEP 07 2001 Alaska Oil & Gas Cons. Coffinf . Anchorag@ . ISSJon '" September 4,2001 Via Facsimile (263-4966) and Mail Attention: Paul K. Wharton Senior Landman Subject: Kuparuk River Unit DS 2K-27 Timberline Tail Tract Operation on KRU Tract 75 (ADL 25589) Dear Mr. Wharton: Your September 4, 2001 letter requested approval to drill a Timberline Prospect tail from the KP A 2K-27 development well. The purpose of extending the well is to log and evaluate the Upper Jurassic Timberline Prospect intervals in the 2K KPA area. It is the DNR's understanding that the tail will be drilled and logged and that no production testing will be performed of the Upper Jurassic intervals. I approve the request to drill the Timberline Tail from the 2K-27 well. Any production testing of the Upper Jurassic and commingling of Upper Jurassic interval production with other Kuparuk River Unit production will be subject to a separate request and approval. If you have any questions regarding this approval, please contact Mike Kotowski at 269-8812. Sincerely, ~Çl~ Mark D. Myers Director cc: Jack Hartz - A OGCC KR U. Timberline2K27TO.doc "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." ( MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor cß Chair DATE: September 6, 2001 SUBJECT: Mechanical Integrity Tests BPX E & F Pads F-73Ai, E-29i, E-26i FROM: Jeff Jones MPU Petroleum Inspector Milne Point Field NON- CONFIDENTIAL THRU: Tom Maunder P.I. Supervisor Packer Depth Pretest Initial 15 Min. 30 Min. Well F-73A Type Inj. S T.V.D. 7033 Tubing 760 760 760 760 Interval I P.T.D. 197-030 Type test P Test psi 1758 Casing 2000 1950 1950 PIF e Notes: Pre-test pressures monitored 30 min. & stable. Well is a conversion to injector. Well E-29 Type Inj. S T.V.D. 4138 Tubing 1200 1200 1200 1200 Interval 4 P.T.D. 201-037 Type test P Test psi 1035 Casing 1150 2000 1970 1970 PIF P Notes: Pre-test pressures monitored 30 min. & stable. Well E-26 Type Inj. G T.V.D. 6792 Tubing 3610 3610 3610 3610 Interval 4 P.T.D. 200-206 Type test P Test psi 1698 Casing 175 4100 4050 4040 PIF P Notes: Pre-test pressures monitored 30 min. & stable. Type INJ. Fluid Codes F = FRESH WATER INJ. G::;GASINJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details Thursday~ September ~ 2001: I traveled to BPX'S E & F Pads and witnessed an initial MIT on well F-73A, a producer recently convertedt() an injector, and 4 year MIT's on wells E-29 and E-26. The pretest tubing and casing pressures were observed for 30 minutes and found to be stable. The standard annulus pressure test was then performed with all three wells passing the MIT's. Summary: I witnessed successful 4-year MIT's on BPX wells E-29i, E-26i and an initial MIT on well F-73Ai in the . Milne Point Field I MPU. M.I.T.'s performed: ~ Attachments: Number of Failures: 0 Total Time during tests: 3.5 hrs. ~ MIT report form 5/12/00 loG. MIT E & F Pad MPU 9-6-01 JJ.xls 9/14/01 (' f PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 August 27, 2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2K-27 Application for Sundry Approval (APD 201-169) Dear Commissioner Taylor: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to change the approved program on the Kuparuk 2K-27 well. As discussed with Tom Maunder, we intend to deepen the surface casing depth to 7000' MD and 3899' TVD. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. CRM/ skad RECEIVED AUG 3 0 2001 Alaska Oil & Gas C A ons. Commission nchorage ORIGI~lJ4t.. ( ( Jf'vi11' c,J} ~ /61 k7>(~ ~ )/c ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 394' FNL, 95' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1769' FNL, 295' FWL, Sec. 10, T10N, R8E, UM At effective depth At total depth 1814' FNL, 48' FEL, Sec. 9, T10N, R8E, UM 12, Present well condition summary Total depth: measured true vertical Effective depth: N/A N/A N/A N/A measured true vertical Casing Conductor Surface Length 26' Size 16" Production Liner Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth N/A Packers & SSSV (type & measured depth) N/A 13. Attachments Description summary of proposal- 14. Estimated date for commencing operation August 27, 2001 16. If proposal was verbally approved Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Re-enter suspended well - TIme extension - Stimulate - Variance Perforate 6. Datum elevation (OF or KB feet) RKB 30' feet 7. Unit or Property name Other - Service Kuparuk River Unit 8. Well number 2K-27 (as proposed) (as proposed) 9. Permit number I approval number 201-169 10. API number 50-029-20388-00 11. Field / Pool Kuparuk River Field I Kuparuk River Pool feet feet Plugs (measured) feet feet Cemented Junk (measured) Measured Depth 118' True vertical Depth 118' 5.5 sx High Early RECEIVED AUG 3 0 2001 Alaska Oil & Gas Cons. Commission Anchorage Detailed operations program - 15. Status of well classification as: BOP sketch - Oil_X Gas- Suspended - ate approved Service - ct the best of my knowledge, Signed c. Maffa Title: Drilling Engineering Supervisor Questions? Call Todd Mushovic 265-6974 Dai>tJ ~ JðD ) Pre ared b Sharon Affsu Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Co~mission so repre tative may witness Approval no, 761 ... ÎC(l" Plug integnty -- BOP Test - Location clearance - ù ~...) I) Mechanical Integrity Test - Subsequent fonn required 10- ~~ "'"\ co A CÐ~~\<è~\ ~ ~ a~ ~ <? \ \.. ,Original Signed By Form 10-403 Rev 06/15/88 . Commissioner Date ORIGI~JAt- SUBMIT IN TRIPLICATE (: ~1r~1rŒ ill)~ ~~~~[(~ / ,J " ~, TONY KNOWLES, GOVERNOR ALAS IiA 0 IL AND GAS CONSERVATION COMMISSION 333 W. "'{fH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL 190.016 Re: The application of Phillips Alaska, Inc. to deepen the surface casing setting dept to 3899' true vertical depth from rig Kelly bushing (TVDRKB) for Kuparuk River Unit (KRU) we1l2K-27 (PTD 201-169). Mr. Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Mallary: The commission has received Phillips' request from Mr. Todd Mushovic dated August 27, 2001 requesting pem1ission to set surface casing at approximately 3899' TVDRKB for KRU well 2K-27 (PTD 201-169). The purpose of this request is to reduce drilling torque values by providing a longer surface casing section than originally planned. Commission Staff has reviewed your request and has made a recommendation to approve your proposal. This action is based on sound engineering principles and will not cause waste. The Commission hereby authorizes the setting of surface casing at approximately 3899' TVDRKB in KRU we1l2K-27 (PTD 201-169). This action is taken pursuant to Rule 3 of Conservation Order No. 190. DONE in Anchorage, Alaska this 29th day of August 2001. ø~ aniel T. Seamount, Jr. Commissioner duuÞM,~ Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION ..I."1II""""~~,,' ,4# (~if'" '~r ,#I" f .' , (1 #,..".,¡C~_::'..~,o' ..~ 1 ."-':"'.;;!~"¡';>'""'~"""'~ J ~,.^ 'I¡~!~~"'r \ I ~-V . \,~~",~;.l'\',J:'i",;~'~',',,\\ f ~/ I~: 0 I, ", .":h I I 7. I,' " 1-.:,:,;\ I ',., ,," .:!~':',"'-'----". (p ....... ../',';) i}" },<;:~~_.",,~- ~--'J \"':}":~;::~",:',~)"',,;f::!':,":,',,'"',:',,,',,;,',',',',,',),;,".,I,"~~ ì- ,¿:;";t.::;;"'.cr,;;{~?:- in ,~, ,~; ,::;:..."':,",,\",'r.i\, ,"-.... ~9 ","'; "," '"""':;,,,", ~. \,~ '"¡:\¡¡:<':"".':"!~':"":"":' ",~c.';.'1, <:~~::::~':":.:'~:;'~:;;:~f',{),~.;.!;:'~::;i,.:',.:::,~.it:(4;~) , \ ~1f~VŒ [ill~ &\~~~[K\!Æ ( ALAS IiA 0 IL AND GAS CO1\1SERVATI 01\1 COMMISSIO1\1 TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 2K-27 Phillips Alaska, Inc. Permit No: 201-169 Sur Loc: 394' FNL, 95' FEL, Sec. 11, TI0N, R8E, UM Btmhole Loc. 1814' FNL, 48' FEL, Sec. 9, TI0N, R8E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does. not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit 2K-27. Blowout prevention equipment (BOPE) must be. tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ Iv1 / ~'1~ Julie M. Heusser Commissioner . BY ORDER OF THE COMMISSION DATED this t1~day of August, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY '( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 August 9, 2001 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 2K-27 Surface Location: Target Location: Bottom Hole Location: 394'FNL,95'FEL,Sec.11,T10N,R8E 1769'FNL,295'FWL,Sec.10,T10N, R8E 1814'FNL,48'FEL,Sec.9,T10N,R8E Dear Ms. Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2K-27. This well has a tail that extends into the Timberline formation. The pressure information is no different than the 2K-10 previously drilled. The well will be drilled and completed using Nordic 3. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Dave Shafer, Geologist 263-4284 If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974. Sincerely, ~, C. Mallary Drilling Engineering Su rvisor RE<:EIVED AUG 1 0 2001 OR\GINAL Alaska Oil & Gas Gems. Commission Anchorage 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone ø 5. Datum elevation (OF or KB) RKB Surf. feet 6. Property Designation Kuparuk River Field ADL 25589 ALK 2675 Kuparuk River Pool 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 2K-27 #59 52 180 9. Approximate spud date Amount August 23,2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13999' MD /7249' 1VD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surfac.e 2588 psig At total depth (TVD) 3282 psig Settlna DeDth ( ( STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRI LL 20 MC 25.005 1a. Type of work: Drill ø Redrill 0 Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surtace 394' FNL, 95' FEL, Sec. 11, T10N, R8E, UM At top of productive Interval 1769' FNL, 295' FWL, Sec. 10, T10N, R8E, UM At total depth 1814' FNL, 48' FEL, Sec. 9, T10N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 3466' @ TD feet 2K-25 14' @ 601' 16. To be completed for deviated wells Kickoff depth: 500 MD 18. Casing program size feet Maximum hole angle 700 TOD TVD Surf. Surf. Surf. 6136' Hole 24" Casino 16" Specifications Grade Coupllno H-40 Weld L-80 BTC-Mod L-80 BTCM L-80 EUE8rd Lençrth 120' 3595' 12766' 1199' Bottom TVD 150' 2754' 6136' 7249' MD Surf. Surf. Surf. 12800' Weloht 62.5# 29.7# 15.5# 9.3# 7.625" MD 150' 3629' 9.875" 6.75" 12800' 13999' 5.5" 3.5" 6.75" 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical Plugs (measured) feet feet Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface Length Size Measured depth Cemented Production " "'.' .. " .' " .-,....,.,. Pertoration depth: measured true vertical ,f,'kl ( o OC?J=' Development Oil ø Multiple Zone 0 10. Field and Pool Quantltv of Cement (include staae data) 5.5 sx High Early 590 sx AS3 Lite, 310 sx LiteCrete 390 sx Class G GasBlok see above True Vertical depth RECEIVED AUG 1 0 2001 Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee ø Property Plat 0 BOP Sketch 0 Diverter Sketch D Drilling program ø Drilling fluid program ø Time vs depth plot DRefraction analysis D Seabed report 0 20 AAC 25.050 requirements D 21. I hereby C'Z:hat the fOregOI"?i r1;' and correct fo fhe besf of my knowledge QuosYons? Call T odd M~hOViO 26~:'7' Signed I rZ ~ AvJ'~ V Title: Drilling Engineering Supervisor Date 9 """'1(,1 J , ?fJO I c. Mal/atY / L. ~1IC:lln-nrt:l a:. ( Commission Use Onl\ Permit Number /.. A~umber Approval date .:zC'/-/b9 50- /ð3- ;)..o3gSl Conditions of approval Samples required D Yes ~ No Hydrogen sulfide measures DYes J8] No Required working pressure for BOPE D2M; D 3M; 0 5M; Other: See cover letter for other requirements Mud log required' ,. DYes i8I No Directional survey required ~ Yes D No 0 10M;D .~ ~SQO~~, tJ\\~""'-\Jk. ~~~ Dale ~}J1 Jf) I I I I 11/0 I ADDroved bv ORIGINAL SIGNED BY ,j, M. Heusser Commissioner ~ l1li ~~ ~~ by order of -. i~ i~n ß . (.1. n r P J. Form 10-401 Rev. 12/1/85. Submit in triplicate ( I( .cation for Permit to Drill, We1l2K-27 Revision No.1 Saved: 8-Aug-O1 Permit It - Kuparuk 2K-27 Application for Permit to Drill Document MoximizE Well Valul; Table of Contents 1. Well Name........................ .......... ...................... ........ ................................................. 2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary . ............ ......... ................................... ........................ .................. 2 Requirements of 20 AAC 25. 005(c) (2) ...................................................................................................2 Requirements of 20 AAC 25.050(b)........................................................................................................2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c)(3) ...... .................................. .................... .......... .............................3 4. Dri II ing Hazards Information ......................... .......... ............. ............. ......................3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25. 005(c) (6) ................................................................................................... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25. 005(c) (7) ......................... .................. .............. ........... ........ .... ................... 4 8. Dri Iii ng FI uid Program ....... ...................... ....... .............. ......... ....... ...........................4 Requirements of 20 AAC 25. 005(c)(B) .................................. .......... ............. ................... ....................... 4 9. Abnormally Pressured Formation Information ............................~.......................:. 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ................................................................................ ......... .............5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bond i ng............................. .................... ...... ......... .......... ......................5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................5 Permit It.doc Page 1 of 6 OR J GTrv Ife-°j ( ( . . ,.cation for Permit to Drill, Well 2K-27 Revision No.1 Saved: 8-Aug-O1 13. Proposed Dri II i ng Program........ ...................... ............. ............ ..... ................... ....... 5 Requirements of 20 MC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 MC 25.005 (c)(14) ................................................................................................ 6 15. Attach ments ...............,¡................. .............. ............... ......................... ...................... 6 Attachment 1 Directional Plan. """"" """"""""""" """'" ........ ..................... ............ ......... ....... .............6 Attachment 3 Drilling Hazards Summary.... """""""""""""'" """""""""""""""""""""""'" ............. 6 Attachment 4 Cement Loads and CemCADE Summary. ...................................................................... 6 Attachment 7 Well Schematic. ...............................................................................................................6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must similarly be Identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2K-27. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.. (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. . (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; . Location at Suñace I 394' FNL, 95' FEL, Sec 11, TI0N, R8E, UM NGS Coordinates RKB Elevation 148.8' AMSL Northings: 5,937,910.2 Eastings: 498,310.1 Pad Elevation 118.5' AMSL Location at Top of Productive Interval Ku aruk Sand NGS Coordinates Northings: 5,936,544 1769' FNL, 295' FWL, Sec 10, TI0N, R8E, UM Eastings: 488,141 12877 6198 6049 Location at Total De th NGS Coordinates Northings: 5,936,499.11 Eastings: 487,799.06 13999 7249 7100' and (0) other information required by 20 MC 25.050(b); Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must Permit It. doc Page 2 0(6 0 RJGtN~l ( ( .¡cation for Permit to Drill, Well 2K-27 Revision No.1 Saved: 8-Aug-O1 (1) include a pla~ drawn to a suitable scale, showing the patl7 of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) . An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; Refer to documents on File 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pem7it to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient,' The expected reservoir pressure in the Kuparuk sands in the 2K-27 area is expected to be 3250 psi, 0.52 psi/ft. This pressure was extrapolated from offset wells. The maximum potential surface pressure (MPSP) based on the expected reservoir pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Kuparuk formation is 2588 psi, calculated thusly: MPSP =(6312 ft)(0.52 - 0.11 psi/ft) =2588 psi (8) data on potential gas zones,' The well bore is not expected to penetrate any gas zones. and (C) data concemingpotential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file witl7 the commission and identified in the application: {5)a description of the procedure for conducting formation integrity tes~ as required under 20 AAC 25.030{f}; A formation integrity test will be performed in accordance with the LOT / FIT procedure that Phillips Alaska has on file with the Commission. Permit It. doc Page 3 of 6 0 R TãlïVAIL ( ( . ,¡cation for Permit to Drill, We1l2K.27 Revision No.1 Saved: 8-Aug-O1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted finer, pre- perforated liner, or screen to be installed; Casing and Cementing Program Hole Top atm Csg/Tbg Size Weight Length MDfTVD MDfTVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 120 Surf 150 / 150 Cemented from surface 7-5/8 9-7/8 29.7 L-80 BTCM 3595 Surf 3629 / 2754 See Attachment 5-1/2 x 6-3/4 15.5 & L-80 BTCM & 12766 Surf 12800 / 6136 See 3-1/2 9.3 EUE 1199 12800/6136 13999 / 7249 Attachment See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Pem7it to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description oftl7e diverter system as required by 20 AAC 25.035, unless this requirement is waived bytl7e commission under 20 MC 25.035(17)(2); Please refer to documents on file with the Commission for Nordic Rig 3. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file witl7 the commission and Identified in the application: (8) a drilling fluid program, including a diagram and description of the dnlling fluid system, as reqUJi-ed by 20 AAC 25.033; Drilling will be done with a bentonite slurry having the following properties over the listed intervals: Interval Density (ppg) Funnel Yield Point Plastic 10 secGel 10 min Gel Viscosity (cP) Viscostiy Strength Strength (seconds) (Ib/100 sf) (Ib/100 sf) (Ib/100 sf) Suñace Hole Surface to 500'. 8.5 - 9.0 150 - 250 50 -70 40 - 60 15 - 30 8 - 15 500' to Base of. Permafrost 8.6 - 9.4 100 - 250 Final 9.4 ~ 9.6 60 - 150 25 - 50 20 - 40 15 - 40 6-8 Production hole Initial section 8.6 - 9.0 35 - 45 8 -12 5 - 10 3-6 8 -15 Intermediate section 10.4 45 - 55 15 - 25 10 - 20 6 - 10 <5 Top Kup to TO 10.4 - 10.6 50 - 65 15 - 25 15 - 25 4:- 7 <5 cc's (Tau 0) Please refer to documents of file with the Commission for Nordic Rig 3. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Permit It. doc Page 4 of 6 0 IftG'liVà L ~. (' ,cation for Permit to Drill, Well 2K-27 Revision No.1 Saved: 8.Aug-01 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); The tail of this well is to TO into the Timberline formation that 2K-10 drilled into with a 10.5 - 10.6 ppg mud and was plugged back after being logged. 2K-10 was drilled in April 1990 and no abnormally pressured zones were encountered. There are no faults isolating pressure from 2K-27 to 2K-10 so the expected pressure should be consistent with 2K-10. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test we/~ a seismic refraction or reflection analysis as required by 20 MC 25. 061 (a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: . (11) for a well drilled from an offshore platfOlm, mobile bottom-founded structure, jack-up rig, or floating dnlling vesse~ an analysis of seabed conditions as required by 20 MC 25. 061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a PermIt to Drill must be accompanied by each of the following item~ except for an Item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of tIle following Items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor. 2. MIRU Nordic Rig 3. Install diverter and function test same. 3. Spud and directionally drill 9-7/8" hole to planned surface casing point. Run MWO/LWD/ PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hole to run casing. POOH. 5. Run and cement 7-5/8" 29.7# L-80 BTCM casing string to surface. Displace cement with mud and perform stage job or top job if required. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test to 5,000 psi. Permit It. doc Page 5 of 6 Oifjdìrp1O1 - ; nhi VAL (' ( ,Jlication for Pennit to Drill, We1l2K-27 Revision No.1 Saved: 8-Aug-O1 7. Shut in BOP's and pressure test casing to 2500 Dsi for 30 minutes per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 MC 25.030 (0.5 ppg less than the FIT or LOT EMW). 9. Directionally drill 6-3/4" hole to total depth (13999' MD), run 5-1/2" 15.5# by 3-1/2" 9.3 L-80 BTCM/EUE casing to surface and cement. 10. Run and land 3-1/2" tubing with gas lift completion. 11. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 12. Freeze protect well. Set BPV. Release rig and turn well over to production. 13. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mllstc be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; , Waste fluids generated during the drilling process will be disposed by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska intends to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary. Attachment 4 Well Schematic. Permit It.doc ' , amG1ÑAL c::> ::D - - ø -/- ~ r- ~~ f{uparul< Rhferyni!;~. -. North SlOpe, At~~~, I< u p8 ru k 21<, ,i lott~i~4V' 21< -21 PlaJJ;é~J:21 {WpOi) 1:1..~i!t~ )\~t 2001 5 AUgust. 2001 ~ 14' 29 7326' N 1SO' 00' 49.1308' Vi) s~,,;~.,;:~:;~~~:::;:~í:: ~. p:E~:¿ ~;:..~~::::; ~.~ ~6~~: w (GrklJ . Surface CoordInates .re . 148 8"" .bOve MeSn se. !.O""I KellY BushIng. . \1" proposal Ref: pro9598 C) ::x:J ~ ~. --=- ~", r--- Kuparuk River Unit Measured Depth (ft) 100.00 160.00 200.00 300.00 400.00 500.00 600.00 650.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1320.00 1400.00 1500.00 1513.25 1578.20 1600.00 1700.00 1800.00 1900.00 Incl. 0.00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1.500 2.250 3.250 5.250 18.956 19.546 19.546 19.546 19.546 19.546 20.285 23.693 27.123 30.568 5 August, 2001 - 20:25 Azim. 0.000 0.000 0.000 0.000 0.000 0.000 0.000 241.000 241 .000 241.000 241.000 250.480 250.816 250.816 250.816 250.816 250.816 251.376 253.512 255.137 256.421 Sub-Sea Depth (ft) -148.80 -48.80 11.20 51.20 151.20 251.20 351 .20 946.85 1043.63 1139.00 1157.88 1233.27 1327.51 1340.00 1401.20 1421.70 1514.41 1604.73 1692.31 Vertical Depth (ft) 100.00 160.00 200.00 300.00 400.00 500.00 1095.65 1192.43 1287.80 1306.68 1382.07 1476.31 1488.80 1550.00 1570.50 1663.21 1753.53 1841.11 0.00 Sperry-Sun Drilling Services Proposal Report for 2K-27 Plan - 2K-27 (wp01) Revised: 5 August, 2001 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 N 0.00 N O.OON O.ooN 6.18 S 11.67 S 19.25 S 28.27 S 38.04 S 48.54 S 50.72 S 59.52 S 70.51 S 71.97 S 79.11 S 81.51 S 92.75 S 104.31 S 116.13 S 0.00 E 0.00 E O.OOJi; 0.006; 4.67W 11.16W 21.06 W 34.74 W 52.84 W 76.00 W 104.15 W 110.37 W 135.65 W 167.25 W 171.44 W 191.96 W 198.98 W 234.69 W 276.00 W 322.76 W Page 2 of 9 Global Coordinates.' '. Northings Eastir\g~ (ft) (ft) 5937910.20 N498310.10 E 5937910,20N 498310.10 E 593~910.20N 498310.10 E 5937-f}10.20 N 498310.10 E 5937910;20 N 498310.10 E 5937910.20 N 5937910.20 N 5937909.57 N 5937908.77 N 5937907.61 N 5937904.02 N 5937898.53 N 5937890.95 N 5937881.94 N 5937872.18 N 5937861.69 N 5937859.50 N 5937850.71 N 5937839.73 N 5937838.27 N 5937831.14 N 5937828.73 N 5937817.50 N 5937805.96 N 5937794.15 N 498310.10 E 498310.10 E 498308.96 E 498307.52 E 498305.43 E 498298.94 E 498289.04 E 498275.36 E 498257.25 E 498234.09 E 498205.94 E 498199.72 E 498174.44 E 498142.84 E 498138.65 E 498118.13 E 498111.10 E 498075.39 E 498034.08 E 497987.31 E Dogleg Rate CO/100ft) 0.000 0.000 0.000 0.000 0.000 0.000 1.500 1.500 2.000 2.000 2.500 2.500 3.000 3.000 3.000 3.000 0.000 0.000 0.000 0.000 3.500 3.500 3.500 3.500 Vertical Section 11.88 22.42 36.99 56.14 80.39 109.69 116.15 142.37 175.15 179.50 200.79 208.07 244.96 287.44 335.36 . North Slope, Alaska Kuparuk 2K Comment 0.00 SHL: X=49831 0.1' & Y=593791 0.2' (394' FNL & 95' FEL, SEC. 11-T1 ON- R8E) 0.00 0.00 0.00 0.00 -. 16" Conductor 0.00 0.00 Begin Dir @ 1.500/100ft (in 9-7/8" Hole): 500.ooft MD, 500.00ft TVD 1.22 2.74 Increase in Dir Rate @ 2.0°/1 0 Oft : 650.000 MD, 649.96ft TVD 4.98 Increase in Dir Rate @ 2.5°/10Oft : 800.000 MD, 799.62ft TVD Increase in Dir Rate @ 3.00/10Oft : 1000.00ft MD, 997.73ft TVD ---~ End Dir, Start Sail @ 19.55° : 132C MD, 1306.68ft TVD Base Permafrost Begin Dir @ 3.5°/1O0ft: 1578.200 M[ 1550.00tt TVD -_._--_u_-_._~-_.._------ Dril/Quest 2.00.09.003 . Sperry-Sun Drilling Services Proposal Report for 2K-27 Plan - 2K-27 (wp01) Revised: 5 August, 2001 North Slope, Alaska Kuparuk 2K Kuparuk River Unit Vertical Section Dogleg Rate . e1100ft) Global Coordinates Northings Eastingt; (ft) (ft) Local Coordinates Northings Eastings (ft) (ft) Sub-Sea Depth (ft) Vertical Depth (ft) Measured Depth (ft) Comment Incl. Azim. 5937782.11 N .. 49.7935.27 E . . . . . .. . ~937769.9GN> 497878.14 E q~3115ÿ.5~N' 497816.14 E 5g37745;13N.' 497749.49 E 5937743.18N 497738.71 E 3.500 3.500 3.500 3.500 3.500 388.54 446.79 509.88 577.59 588.54 128.17 S 140.40 S 152.75 S 165.20 S 167.14 S 374.80 W 431.93 W 493.93 W 560.57 W 571 .36 W 2000.00 2100.00 2200.00 2300.00 2315.58 34.023 37.486 40.954 44.426 44.967 257.466 258.340 259.086 259.735 259.829 1776.83 1857.97 1935.43 2008.92 2020.00 1925.63 2006.77 2084.23 2157.72 2168.80 c"--,- West Sak D .. 631;ôOW; 7Qq.76W '.' 785;77 W. .. 868.32 W ' 954.12 W 5937732:65 N 5937720.19 N 5937707.78 N 5937695.47 N 5937683.30 N 649.65 725.80 805.76 889.22 975.88 497678.46 E 497603.30 E 497524.29 E 497441.73 E 497355.93 E 3.500 3.500 3.500 3.500 3.500 2400.00 2500.00 2600.00 2700.00 2800.00 47.902 51.380 54.860 58.342 61.825 260.308 260.821 261.287 261.715 262.111 2078.17 2142.92 2202.93 2257.96 2307.83 2226.97 2291.72 2351.73 2406.76 2456.63 1065.41 1157.48 1180.34 1193.84 ~39. 0.87S 253.71 S 255.37 S 3.500 3.500 3.500 3.500 497267.20 E 497175.88 E 497153.20 E 497139.80 E 5937671.32 N 5937659.58 N 5937656.75 N 5937655.10 N 1042.85 W 1134.16 W 1156.85 W 1170.24W 262.483 262.834 262.917 262.966 2900.00 3000.00 3024.45 3038.83 65.309 68.794 69.646 70.147 Base West Sak End Dir, Start Sail @ 70.15° : 3038.83 MD, 2553.74ft TVD 1251.37 0.000 497082.69 E 5937648.06 N 1227.35 W 262.41 S 70.147 3100.00 1345.43 1439.48 1533.53 1627.58 1721 .63 0.000 0.000 0.000 0.000 0.000 496989.34 E 496895.99 E 496802.64 E 496709.29 E 496615.94 E 5937636.57 N 5937625.07 N 5937613.57 N 5937602.07 N 5937590.58 N 1320.70 W 1414.05 W 1507.40 W 1600.74 W 1694.09 W 273.93 S 285.45 S 296.97 S 308.48 S 320.00 S 2608.48 2642.44 2676.40 2710.36 2744.32 2459;68 493.64 2527.60 2561.56 2595.52 70.14 70.147 70.147 70.147 70.147 3200.00 3300.00 3400.00 3500.00 3600.00 ...-.~ . 7-5/8" Casing 1748.44 1815.68 1909.73 2003.78 2097.83 0.000 0.000 0.000 0.000 0.000 496589.32 E 496522.58 E 496429.23 E 496335.88 E 496242.53 E 5937587.30 N 5937579.08 N 5937567.58 N 5937556.08 N 5937544.59 N 1720.71 W 1787.44 W 1880.79 W 1974.14 W 2067.49 W 323.29 S 331.52 S 343.04 S 354.56 S 366.08 S 2754.00 2778.28 2812.24 2846.20 2880.16 2605.20 2629.48 2663.44 2697.40 2731.36 262.966 262.966 262.966 262.966 262.966 70.147 70.147 70.147 70.147 70.147 3628.51 3700.00 3800.00 3900.00 4000.00 2191.89 2285.94 2379.99 2474.04 2568.09 0.000 0.000 0.000 0.000 0.000 496149.18 E 496055.83 E 495962.48 E 495869.12 E 495775.77 E 5937533.09 N 5937521.59 N 5937510.10 N 5937498.60 N 5937487.10 N 2160.84 W 2254.19 W 2347.53 W 2440.88 W 2534.23 W 377.59 S 389.11 S 400.63 S 412.15S 423.67 S 2914.12 2948.08 2982.04 3016.00 3049.96 2765.32 2799.28 2833.24 2867.20 2901.16 262.966 262.966 262.966 262.966 262.966 70.147 70.147 70.147 70.147 70.147 4100.00 4200.00 4300.00 4400.00 4500.00 c :J:- ~ c: ~ -'-0 ~ ~C.,- r--= .-------..-.-------.---- DrillQuest 2.00.09.003 Page 3 of 9 5 August, 2001 - 20:25 Sperry-S un Dr; II; ng Services Proposal Report for 2K-27 Plan - 2K-27 (wpO1) Revised: 5 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2K Measured Sub-Sea Vertical Local Coordinates Global Coordinates. . Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ... (ft) ... (°/1 0 Oft) 4600.00 70.147 262.966 2935.12 3083.92 435.19 S 2627.58 W 5937475.60N.. 495682.42 E 0.000 2662.14 4643.80 70.147 262.966 2950.00 3098.80 440.238 2668.47 W 5937470.5'('iN' 495641.53 E 0.000 2703.34 C-80 4700.00 70.147 262.966 2969.08 3117.88 446.708 2720.93 W 59374ßJ.h11N. 495589.07 E 0.000 2756.19 4800.00 70.147 262.966 3003.05 3151.85 458.228 2814.28 W 5937452;S1N... 495495.72 E 0.000 2850.24 4900.00 70.147 262.966 3037.01 3185.81 469.748 2907.63W, 593'l441.11N 495402.37E 0.000 2944.30 - . . 5000.00 70.147 262.966 3070.97 3219.77 481.26 S3000i9àW' 5937429:61 N 495309.02 E 0.000 3038.35 5100.00 70.147 262.966 3104.93 3253.73 492.78 S .. 3094.33W 5937418.12 N 495215.66 E 0.000 3132.40 5200.00 70.147 262.966 3138.89 3287.69 ..,..3187:67 W'- 5937406.62 N 495122.31 E 0.000 3226.45 5300.00 70.147 262.966 3172.85 3321.65328~.02 W 5937395.12 N 495028.96 E 0.000 3320.50 5400.00 70.147 262.966 3206.81 3355.613374.37 W 5937383.62 N 494935.61 E 0.000 3414.55 5500.00 70.147 262.966 3240.773389.57 3467.72 W 5937372.13 N 494842.26 E 0.000 3508.60 5600.00 70.147 262.966 3274.73, ;:~23.53 3561.07W 5937360.63 N 494748.91 E 0.000 3602.65 5700.00 70.147 262.966 3308.69;ÚgJ57.49 3654.42 W 5937349.13 N 494655.56 E 0.000 3696.70 5800.00 70.147 262.966 334?65< .... 34~~A5 3747.77 W 5937337.64 N 494562.20 E 0.000 3790.76 5900.00 70.147 262.966 :}376;ôt~$525i41 3841.12 W 5937326.14 N 494468.85 E 0.000 3884.81 6000.00 70.147 ..2e;21966> 3410.57 3559.37 596.44 S 3934.47 W 5937314.64 N 494375.50 E 0.000 3978.86 6100.00 70.147 '262:~6€). .. 3444.53 3593.33 607.96 8 4027.81 W 5937303.14 N 494282.15 E 0.000 4072.91 6200.00 70.147262.9~63478.49 3627.29 619.48 S 4121.16 W 5937291.65 N 494188.80 E 0.000 4166.96 6300.00 70.147262.96'6 3512.45 3661.25 631.00 S 4214.51 W 5937280.15 N 494095.45 E 0.000 4261.01 6400.00 70.147262:966 3546.41 3695.21 642.51 S 4307.86 W 5937268.65 N 494002.10 E 0.000 4355.06 6500.00 70.147 262.966 3580.37 3729.17 654.03S 4401.21W 5937257.15N 493908.74E 0.000 4449.11 6600.00 70.147 262.966 3614.34 3763.14 665.55 S 4494.56 W 5937245.66 N 493815.39 E 0.000 4543.17 6700.00 70.147 262.966 3648.30 3797.10 677.07 S 4587.91 W 5937234.16 N 493722.04 E 0.000 4637.22 6800.00 70.147 262.966 3682.26 3831.06 688.59 S 4681.26 W 5937222.66 N 493628.69 E 0.000 4731.27 6900.00 70.147 262.966 3716.22 3865.02 700.11 S 4774.61 W 5937211.16 N 493535.34 E 0.000 4825.32 7000.00 70.147 262.966 3750.18 3898.98 711.628 4867.95W 5937199.67N 493441.99E 0.000 4919.37 7100.00 70.147 262.966 3784.14 3932.94 723.14 S 4961.30 W 5937188.17 N 493348.64 E 0.000 5013.42 7200.00 70.147 262.966 3818.10 3966.90 734.66 S 5054.65 W 5937176.67 N 493255.28 E 0.000 5107.47 ~ 7300.00 70.147 262.966 3852.06 4000.86 746.18 S 5148.00 W 5937165.18 N 493161.93 E 0.000 5201.52 :::J::::J 7400.00 70.147 262.966 3886.02 4034.82 757.70 S 5241.35 W 5937153.68 N 493068.58 E 0.000 5295.57 - - G-:> - - <: .---..---.----..---.-.--.---.---- ):::r. 5 August, 2001 - 20:25 Page 4 of 9 DrillQuest 2.00.09.003 r--- ..- .- . Sperry-Sun Drilling Services Proposal Report for 2K-27 Plan - 2K-27 (wpOI) Revised: 5 August, 2001 North Slope, Alaska Kuparuk 2K Kuparuk River Unit Vertical Section Global Coordinates. . Northings Easti~g~ (ft) .. . (ft) Dogleg Rate e/100ft) Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) Comment Incl. Azim. 5937142.18 N 5937t30.68N 59~7119,J9N " 5937107.69N 5937096.19N 492975:23 E 492881:88 E 492188.53 E 492695.18 E 492601 .82 E 7500.00 7600.00 7700.00 7800.00 7900.00 262.966 262.966 262.966 262.966 262.966 769.21 S 780.73 S 792.25 S 803.77 S 815.29 S 5334.70 W 5428.05 W 5521 .40 W 5614.74 W 5708.09 'N, . 5801A4W ..'. 5894.79W . 5988i14 W; 6081.49 W . . .6174.84 W 0.000 0.000 0.000 0.000 0.000 5389.63 5483.68 5577.73 5671.78 5765.83 70.147 70.147 70.147 70.147 70.147 3919.98 3953.94 3987.90 4021.86 4055.82 4068.78 4102.74 4136.70 4170.66 4204.62 - 5937084.69 N 5937073.20 N 5937061.70 N 5937050.20 N 5937038.71 N 492508.47 E 492415.12 E 492321.77 E 492228.42 E 492135.07 E 5859.88 5953.93 6047.98 6142.04 6236.09 0.000 0.000 0.000 0.000 0.000 826.81 S 838.32 S 849~84~S .. 00. 86J'.B6 S 00..0 ...00872:'88 S . 4238.58 4272.54 4306.50 4340.47 4374.43 8000.00 8100.00 8200.00 8300.00 8400.00 70.147 70.147 70.147 70.147 70.147 262.966 262.966 262.966 262.966 262.966 4089.78 4123.74 4157.70 4191.67 4225.63 8S4.4ÖS ...,895.92 S .0907.43 S 918.95 S 930.47 S 6330.14 6424.19 6518.24 6612.29 6706.34 492041.72 E 491948.36 E 491855.01 E 491761.66 E 491668.31 E 0.000 0.000 0.000 0.000 0.000 5937027.21 N 5937015.71 N 5937004.21 N 5936992.72 N 5936981.22 N 6268.19W 6361.54 W 6454.88 W 6548.23 W 6641.58W 262.966 262.966 262.966 262.966 262.966 8500.00 8600.00 8700.00 8800.00 8900.00 70.147 70.147 70.147 70.147 70.147 6800.39 6894.44 6988.50 7082.55 7176.60 491574.96 E 491481.61 E 491388.25 E 491294.90 E 491201.55E 0.000 0.000 0.000 0.000 0.000 5936969.72 N 5936958.22 N 5936946.73 N 5936935.23 N 5936923.73 N 6734.93 W 6828.28 W 6921 .63 W 7014.98 W 7108.33 W 941.99 S 953.51 S 965.03 S 976.54 S 988.06 S 4578.19 4612.15 4646.11 4680.07 4714.03 70.147 70.147 70.147\ 70.147 70.147 9000.00 9100.00 9200.00 9300.00 9400.00 4463H~5 4497.31 4531.27 4565.23 ~~ 0.000 0.000 0.000 0.000 0.000 7270.65 7364.70 7458.75 7552.80 7646.85 491108.20 E 491014.85 E 490921.50 E 490828.15 E 490734.79 E 5936912.23 N 5936900.74 N 5936889.24 N 5936877.74 N 5936866.25 N 7201.68 W 7295.02 W 7388.37 W 7481.72 W 7575.07 W 999.58 S 1011 .10 S 1022.62 S 1034.13 S 1045.65 S 4747.99 4781.95 4815.91 4849.87 4883.83 262.966 262.966 262.966 262.966 262.966 4599.19 4633.15 4667.11 4701.07 4735.03 70.147 70.147 70.147 70.147 70.147 9500.00 9600.00 9700.00 9800.00 9900.00 0.000 0.000 0.000 0.000 0.000 7740.91 7834.96 7929.01 8023.06 8117.11 490641.44 E 490548.09 E 490454.74 E 490361.39 E 490268.04 E 5936854.75 N 5936843.25 N 5936831.75 N 5936820.26 N 5936808.76 N 7668.42 W 7761.77 W 7855.12 W 7948.47 W 8041.82 W 1057.17 S 1068.69 S 1080.21 S 1091.73 S 1103.24 S 4917.80 4951.76 4985.72 5019.68 5053.64 4769.00 4802.96 4836.92 4870.88 4904.84 262.966 262.966 262.966 262.966 262.966 10000.00 10100.00 10200.00 10300.00 10400.00 70.147 70.147 70.147 70.147 70.147 C ::t::J - - ~ ~ ~ r--- -___'__0_.____-- DrillQuest 2.00.09.003 Page 5 of 9 5 August, 2001 - 20:25 . Sperry-Sun Drilling Services Proposal Report for 2K-27 Plan - 2K-27 (wp01) Revised: 5 August, 2001 North Slope, Alaska Kuparuk 2K Kuparuk River Unit Vertical Section Dogleg Rate r/100ft) Global Coordinates Northings EastiÍ'lg~ (ft) . .(ft) ...... Local Coordinates Northings Eastings (ft) (ft) Sub-Sea Depth (ft) Vertical Depth (ft) Measured Depth (ft) Comment Incl. Azim. 5936797.26 N. 59367B5.7ØN .. 5936774.27N 5936762Fm/N . .. 5936751.21N 490174.69 E 490081.33 E 489987.98 E 489894.63 E 489801 .28 E 8211.16 8305.21 8399.26 8493.31 8587.37 0.000 0.000 0.000 0.000 0.000 1114.76 S 1126.28 S 1137.80 S 1149.32 S 1160.84 S 8135.16 W 8228.51 W 8321 .86 W 8415.21 W 8508.56 We 10500.00 10600.00 10700.00 10800.00 10900.00 70.147 70.147 70.147 70.147 70.147 262.966 262.966 262.966 262.966 262.966 5087.60 5121.56 5155.52 5189.48 5223.44 4938.80 4972.76 5006.72 5040.68 5074.64 ~ . . . ...~691,91W..... .. SG9S.26tH ... 878Ø;61 881.95 . 75.30 W 8681.42 8775.47 8869.52 8963.57 9057.62 489707.93 E 489614.58 E 489521.23 E 489427.87 E 489334.52 E 0.000 0.000 0.000 0.000 0.000 5936739.77 N 5936728.28 N 5936716.78 N 5936705.28 N 5936693.79 N 1172.35 S 1183.87 S . 1195.39, J 20.6J~1 ..1218¡~ 11000.00 11100.00 11200.00 11300.00 11400.00 70.147 70.147 70.147 70.147 70.147 262.966 262.966 262.966 262.966 262.966 5108.60 5142.56 5176.52 5210.48 5244.44 5257.40 5291.36 5325.32 5359.28 5393.24 9151.67 9245.72 9339.78 9344.58 0.000 0.000 0.000 0.000 1229.94 1.46 S 1252.98 S 1253.57 S 489241.17 E 489147.82 E 489054.47 E 489049.70 E 9068.65 W 9162.00 W 9255.35 W 9260.12 W 5936682.29 N 5936670.79 N 5936659.29 N 5936658.71 N 5427.20 61.16 ;.~.5.13 54aQ.86 11500.00 11600.00 11700.00 11705.11 70.147 70.147 70.147 70.147 262.966 262.966 262.966 262.966 Begin Dir @ 3.00/100ft (in 6-314" Hole :11705.11 ft MD, 5496.86ft TVD 9432.99 488961.95 E 3.000 5936647.88 N 9347.87 W 1264.42 S 67.301 11800.00 9524.19 9613.12 9699.53 9783.19 9863.88 488871 .44 E 488783.19 E 488697.43 E 488614.42 E 488534.36 E 3.000 3.000 3.000 3.000 3.000 5936636.67 N 5936625.70 N 5936614.99 N 5936604.59 N 5936594.50 N 9438.37 W 9526.62 W 9612.37 W 9695.39 W 9775.44 W 1275.64 S 1286.64 S 1297.36 S 1307.79 S 1317.89 S 64.301 c ...... 26~. 61 .301 ...262. -c- 58.301262.8,g6 55.301~62U824 52.301 262.789 5572.28 5617.98 5668.27 5723.02 5782.07 ..54 5469.18 5519.47 5574.22 5633.27 11900.00 12000.00 12100.00 12200.00 12300.00 ~ 9941 .36 10015.44 10085.89 10140.45 10152.54 3.000 3.000 3.000 3.000 3.000 488457.49 E 488384.01 E 488314.12 E 488260.01 E 488248.02 E 5936584.77 N 5936575.41 N 5936566.46 N 5936559.49 N 5936557.94 N 9852.31 W 9925.79 W 9995.68 W 10049.79 W 10061.78 W 1327.64 S 1337.01 S 1345.98 S 1352.96 S 1354.51 S 5845.27 5912.43 5983.38 6043.80 6057.91 5696.47 5763.63 5834.58 5895.00 5909.11 262.752 262.711 262.666 262.625 262.615 49.301 46.302 43.302 40.859 40.302 12400.00 12500.00 12600.00 12681.42 12700.00 Base HRl 10215.19 10260.46 488185.89 E 488141.00 E 3.000 3.000 5936549.87 N 5936544.00 N 10123.91 W 10168.79 W 1362.60 S 1368.48 S 6135.84 6197.80 5987.04 6049.00 37.302 35.000 262.558 262.509 12800.00 12876.74 TARGET: 12876.74ft MD, 6197.80ft TVD Kuparuk C4 (Target) Target - 2K-27 (Kup C4), 250.00 Radius., Geological C ::0 - - ~ - - <: ::t::=.. r--- 10273.69 10280.37 10327.85 3.000 3.000 3.000 488127.89 E 488121.26 E 488074.18 E 5936542.28 N 5936541.41N 5936535.23 N 10181.90 W 10188.53 W 10235.61 W 1370.20 S 1371.08 S 1377.27 S 6216.93 6226.80 6300.98 34.302 33.945 31 .302 262.509 262.509 262.509 6068.13 6078.00 6152.18 12900.00 12911.92 13000.00 Kuparuk A4 . --------__-_._0 - --.-.- -.--.-.. -.. -.--- Dril/Quest 2.00.09.003 Page 6 of 9 5 August, 2001 - 20:25 C =0 - ~ ~.; ~ ~~J ~"'., ~'" c::::~ ~----, ~ Kuparuk River Unit Measured Depth (ft) 13012.64 13045.12 13100.00 13200.00 13300.00 13400.00 13500.00 13600.00 13697.06 13700.00 13800.00 13808.37 13900.00 13938.91 13998.95 Incl. 30.923 29.949 28.302 25.302 22.302 19.302 16.302 13.302 10.390 10.302 7.302 7.051 4.302 3.135 1.334 All data is in Feet (US) Vertical depths are relative Azim. 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 262.509 Sub-Sea Depth (ft) 6163.00 6191.00 6238.94 6328.19 6419.67 6513.14 6608.34 6705.01 6800.00 6802.89 6901.70 6910.0 7001.1 704' 7) Vertical Depth (ft) 6311.80 6339.80 6387.7 4 6476.99 6568.47 6661.94 6757.14 6853.81 6948.80 6951.69 Sperry-Sun Drilling Services Proposal Report for 2K-27 Plan - 2K-27 (wp01) Revised: 5 August, 2001 Local Coordinates Northings Eastings (ft) (ft) 1378.12 S 1380.26 S 1383.74 S 1389.62 S 1394.88 S 1.63 S 2.81 S 1413.14 S 1413.44 S 10242.09 W 10258.40 W 10284.88 W 10329.58 W 10369.59 W. .- .. . -. - ... . .. .. -- . .lO404,SOW". ......104íl5.1tW\ 1 04E)(}~44 W -~gø.19W> -80.71 W 1 0495.88 W 10496.92 W 10505.90 W 10508.41 W 10510.73 W Global Coordinates Northings Eastings (ft) (ft) .. 5936534.38 N 9g36532.2~N . 5~36528.76N . . 5936522r89N 5936p17.64'fj 5936513¡Ö2 N 5936509.04 N 5936505.72 N 5936503.12 N 5936503.05 N 5936501.06 N 5936500.93 N 5936499.75 N 5936499.42 N 5936499.11 N ted. Directions and coordinates are relative to True North. 8.8' MSL). Northings and Eastings are relative to 394' FNL & 95" FEL. Magnetic Declination at Surface is 25.8240 (05-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from SHL to C4 Target and calculated along an Azimuth of 262.3400 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13998.95ft., The Bottom Hole Displacement is 10605.34ft., in the Direction of 262.3410 (True). 488067.71 E 488Ö51.39 E . 488024.91 E 487980.21 E 487940.20 E 487904.99 E 487874.68 E 487849.35 E 487829.60 E 487829.07 E 487813.90 E 487812.87 E 487803.88 E 487801.38 E 487799.06 E Dogleg Rate CO/100ft) 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 Vertical Section 10334.39 10350.84 1 0377.55 10422.64 10462.99 10498.50 1 0529.07 10554.61 10574.54 10575.06 10590.37 10591.41 10600.47 10603.00 10605.34 <I North Slope, Alaska Kuparuk 2K Comment Base Kuparuk A3 Miluveach Timberline Sand J-4 -. Base J-4 Bench Total Depth: 13998.95ft MD, 7248.80- TVD 5-1/2" x 3-1/2" Casing ~~ .-----.--.--.-.---------..---.. ..---- 5 August, 2001 - 20:25 Page 7 of 9 aliI/Quest 2.00.09.003 C ::t:J - - ~ - ~ :J::::=.. r--- Kuparuk River Unit Comments Measured Depth (ft) 0.00 500.00 650.00 800.00 1000.00 1320.00 1578.20 3038.83 11705.11 12876.74 13998.95 Formation Tops Station Coordinates TVD Northings Eastings ~) (ft) ~) 0.00 500.00 649.96 799.62 997.73 0.00 N O.OON 1.43 S 6.18 S 19.25 S 1306.68 1550.00 2553.74 5496.86 6197.80 50.72 S 79.11 S 255.37 S 1253.57 S 1368.48 7248.80 For mat ion P',tan e -; (Below Well Origir'l)i - -.,> Sub-Sea Dip DipDií< (ft) Deg. Deg. Sperry-Sun Drilling Services Proposal Report for 2K-27 Plan - 2K-27 (wp01) Revised: 5 August, 2001 O.OOE 0.00 E 2.58W 11.16W 34.74 W 110.37cV?J - 191.~W --- 117q~~5 W 9260~~;~;W ~0168. jO.73 W Comment - -- -- - - - - --- --- - - - SHL: X=49831 0.1' & Y=593791~~?' (à9*~JÏNL&95' FEL, SEC. 11-T1 ON-R8E) Begin Dir @ 1.50°/1 Oqtt,.(in 9-71~~tjole):5ÖO.OOft MD, 500.00ft TVD Increase in Dir Rqt~@gkpo/1 OOft--~lçqQ~OOO MD, 649.96ft TVD Increase inpirRa:tê;~2íRo/1ooft: 800;000 MD, 799.62ft TVD Increasei,hDirft~te @;~;f;).°/1ooft : 1000.00ft MD, 997.73ft TVD -- - - - - - - - - - - -- - - - - -- -- -- ---- -- - - - - - - - - - - - - - - - --- - - - - -- --- - -- - - -- .End Diri Start8åif@ 19:550 : 1320.000 MD, 1306.68ft TVD Begin lJir @~;5°/10Oft : 1578.20ft MD, 1550.000 TVD Ehd[)it,StartSail @ 70.15° : 3038.83ft MD, 2553.74ft TVD Beghi Dir @ 3.0°/1000 (in 6-314" Hole) :11705.11ft MD, 5496.86ft TVD TARGET: 12876.74ft MD, 6197.800 TVD Total Depth: 13998.95ft MD, 7248.800 TVD « Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Formation Name 1340.00 0.000 359.987 1513.25 1488.80 2020.00 0.000 359.987 2315.58 2168.80 2400.00 0.000 359.987 3024.45 2548.80 2950.00 0.000 359.987 4643.80 3098.80 5895.00 0.000 359.987 12681.42 6043.80 6049.00 0.000 359.987 12876.74 6197.80 6078.00 0.000 359.987 12911.92 6226.80 6163.00 0.000 359.987 13012.64 6311 .80 6191.00 0.000 359.987 13045.12 6339.80 6800.00 0.000 359.987 13697.06 6948.80 1340.00 71.97 S 171.44 W Base Permafrost 2020.00 167.14 S 571.36 W West Sak D 2400.00 253.71 S 1156.85 W Base West Sak 2950.00 440.23 S 2668.47 W C-80 5895.00 1352.96 S 10049.79 W Base HRl 6049.00 1368.48 S 10168.79 W Kuparuk C4 (Target) 6078.00 1371.08 S 10188.53 W Kuparuk A4 6163.00 1378.12 S 10242.09 W Base Kuparuk A3 6191.00 1380.26 S 10258.40 W Miluveach 6800.00 1409.43 S 10480.19 W Timberline Sand 5 August, 2001 - 20:25 Page 8 of 9 . North Slope, Alaska Kuparuk 2K --- ~- --------------- OrillQuest 2.00.09.003 c:::> ::c ~ ~ ~ r-- Kuparuk River Unit Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Formation Tops (Continued) 6910.00 7040.00 0.000 359.987 0.000 359.987 Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> Targets associated withtbis WI Target Name 2K-27 (Kup A4) 2K-27 (Kup C4) Profile Measured Vertical Depth Depth (ft) (ft) 13808.37 13938.91 7058.80 7188.80 Sperry-Sun Drilling Services Proposal Report for 2K-27 Plan - 2K-27 (wp01) Revised: 5 August, 2001 Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (ft) 6910.00 7040.00 16" Conductor 7 -5/8" Casing 5-1/2" x 3-1/2" Casing Formation NalTl8 Base J-4 Bench Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: 6226.80 6078.00 1376.49 S 10227.79 W 5936536.00 N 488082.00 E 70° 14'16.1252" N 150° OS' 46.4310" W 1368.48 S 10168.79 W 5936544.00 N 488141.00 E 70° 14'16.2048" N 150005' 44.7164" W 5 August, 2001 - 20:25 To Measured Vertical Depth D~R!h (ft) Ift\ 250.000 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: Target Thickness: 6197.80 6049.00 250.000 114.000 Page 9 of 9 Target Shape Circle Circle . North Slope, Alaska Kuparuk 2K ,--- Target Type -- Geological Geological ------------ DrillQuest 2.00.09.003 .= ~. ~~:' ~~\; I '~~,,~, 16' Condœtor 160,0011 MD 160.0011 TVD 1200 2400 3600 .c ã. Q) - Om -~ ~a: .-- t Q) > 4800 6000 7200 3H!- X:49831().1' K '1':5'-'379101 !3~}<¡' i=NL& g:,' i=EL. SEe. 1,T1GN.R:?Ð Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 2K Pad 0 JIL. ,Begin Dir @ 1.500/100ft (in 9-7/S" Hole): 5OO.00ft MD, 5OO.00ft TVD / / /' Increase in Dir Rate @ 2.00/100ft: 650.00ft MD, 649.9611 TVD / ~ Increase in Dir Rate @ 2.5°/100ft : SOO.OOft MD, 799.6211 TVD Increase in Dir Rate @ 3.0D/100ft: 1000.00ft MD, 997.73ft TVD / End Dir,Start Sail @ 19.550: 1320.00ft MD, 1306.6811 TVD ¡f)9() ,~ ,,/' Begin Dir @ 3.5°/100ft : 1578.201t MD, 1550.00ft TVD - , ,." ," 'uH ",,' , H q -, .. .. .,ß¡f) End Dir, Slart Sail @ 70.15°: 3038.83ft MD, 2553.7411 TVD '/.'fj'-/ §f¡f) 7 518' Casing -;;;¡ 3628.51f1 MD 2754.00II TVD p.,'-' """',,, ,', ..,.- ...'., . ...... ... H ",""'., "-' 'u' "'u , .. ....' _H . . ,- 0 1200 2400 3600 4800 6000 7200 8400 9600 10800 Scale: 1 inch = 1200ft ...> ~ ~~ ~~ ~~~ 2k-27 (wpO1) N "~.. Well: Reference is True North Current Well Properties 2K-27 Plan ~ Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 5937910.20 N, 498310.10 E 689.98 S, 0.08 E 70014' 29.7326' N, 150000' 49.1308" W (394' FNL & 95' FEL. SEC. 11-nON-R8E) 148.8Oft above Mean Sea Level True North Feet (US) ". ','. ", ,. , .". RKB Elevation: North Reference: Units: ,.:,-,':,. ...,,':.. ',-, "'" 'o' U,.., .,,' sp e ....".., \/- 5 U Il DRILLU\fG SSAVIt:~S A HilII¡þ-.dton ~ny ...................._...,---,......... ........----.........,..-.........-...-....-.-................-............ 2/0.-27 7'«1'1«(" rlo:up (;.1). 25fJ' Rlltti//.< Cir,:/I! (i:: fill}?.'iIJ' 7'\.11, /3".8..1/\' S ,( /1J16~. 79' no o{SIII, f 17(j'J' ],"8/, &. :!I}S' F\-II. Sf'/'. f()-T/fJ"y.f(.'iFj ¡ -.....---.-..............""""""-""'-"""""-"""-"""""'-'-'-""'-"......,...-......., ..--, Begin Dir @ 3.00/10011 (in 6-314" Hole) :, 11705,11tt MD, 5496.S611 TVD .. """ r:,',..,.',,'-- ':..:~-.",:"" '" ------. 5.1/2'x3.1/2'Csg 13998.9511 MD 7248.8011 TVD Tolal Deplh @ 1399S.95tt MD, 7248.8011 TVD (1814' FNL & 48' FEL, Sec. 9- T1 ON-R8E) -10800 1200 Scale: 1 inch = 120Oft 0 -1200 \ \ /'_.---\ ¡ Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 2 K Pad 2k-27 (wpO1) -9600 -8400 -7200 Begin Oir@ 3.0°/100" (in 6-314' Hole) : 11705."" MO, 5496.86"TVD / / / /- / Tolal Depth @ 13998.95ft MO, 7248.8011 TVO (1814' FNL & 48' FEL, Sec. 9- T10N-R8E) r\ = ¿.,~ "'--_/ ....... '. ". -.---.---------.---¡ 5.1/2' x 3-112' Csg -- ". r--.----.--. ¡ 13998.9511 MD '. . IX.]? 1"ar;:et (/(up C-li. ' 7248.8O!1 TVD 250' Radius Ofd" if" 6]97.81)' TFD. /368.48' S &. J{jUiS,7!)' W vfSHL (J7M' fNl, &. 295' FW¡~ Sec, }!J.TlfJN-RSF.¡ -2400 -10800 S~Oo S~q, 2K~27 lwP°1) &... ~ ~'b 'b.'b Eastings -6000 m_,-- '-00 ""b.'b ---..-------------...--- -6000 -9600 -8400 -7200 Current Well Properties 2K-27 Plan Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates ; AKB Elevation; North Reference: Units: 5937910.20 N, 498310.10 E 689.98 S, 0.08 E 700 14' 29.7326" N, 1500 00' 49,1308" W (394' FNL & 95' FEL, SEC. 11-T10N-R8E) 148.80ft above Mean Sea Level True North Feet (US) ~~,,~.. --. ^ ^^ ^^ ^^^ __m'_,_m- spe..r-~-SUI! fiFí'fLLïNGS~ERvrèe-~ .....-. ,... ". . . o. .... .. ., ..'. ..' ., . . '" A t-lililiburtoo Compuny -4800 -2400 -1200 0 -3600 Begin Djr @ 1.SOO/1001l (in 9-7/8' Hole): 500.0011 MO, 500.0011 TVD \ Increase in Djr Rate @ 2.0°/10011 : 650.00II MD, 649,9611 TVD \ Increase in Oir Rale @ 2.5°/1001t : 800.00II MO, 799.6211 TVQ " \ Increase in Ojr Rale @ 3.0°/10011: 1000.00II MO, 997.7311 TVI1 ',\ \ ", "\ End Oir, Slart Sail @ 19.55° : 1320.00II MO, 1306.68ft TVD --""........'" \ \ --.. --.. ,," \ Begin Oir @ 3.5°/100II: 1578.2011 MO, 1550.0011 TVO --.. "-. "-. "'. ,,\ \ ,---on -' .._".---_mn _.. ---'--'m'--' m" - -. - -- -- .~.~-:'. ,"i End Ojr, Slart Sail @ 70.15°: 3038.8311 MD, 2553.7411 TV[}- - - - - ~ <'Ilq, ~ .~ ~'b 7518' Caslr¡g 3628.5111 MD 2754.0011 TVD 1200 ~~ 0 <'~'b (/) C) .S L:. t 0 Z '-lb '-00 a~'b -1200 'o;HL: X=4()$'::<~(). ~' (, "=5~:mi10.2" (:;;':'1' FNL "" ')G' FOEL. ~;í::c. ~ I,T 1'ì!"¡ .¡:¡~E ¡ --, -2400 -4800 -3600 -2400 -1200 0 N . '...ÌL: - T ~ . Reference is True North <::> ::c - - c-> - ::æ: ~ r-- MD Inc ~(~1:::::,:::::,:::::::::::::1~:;:W 0.00 0.00 160.00 0.00 500.00 0.00 650.00 2.25 800.00 5.25 1000.00 10.25 1320.00 19.55 1513.25 19.55 1578.20 19.55 2315.58 44.97 3024.45 69.65 3038.83 70.15 3628.51 70.15 4643.80 70.15 11705.11 70.15 12681 .42 40.86 12876.74 35.00 12911.92 33.95 13012.64 30.92 13045.12 29.95 13697.06 10.39 13808.37 7.05 13938.91 3.14 13998.95 1.33 Phillips Alaska, Inc. Azim. J~:;p ) 0.00 0.00 0.00 241 .00 241.00 241.00 250.82 250.82 250.82 259.83 262.92 262.97 262.97 262.97 262.97 ' 262.63 262.51 262.51 262.51 262.51 262.51 262.51 262.51 262.51 SSTVD 5~l::::::::::: -148.80 11.20 351.20 501 .16 650.82 848.93 1157.88 1340.00 1401.20 2020.00 2400.00 2404.94 2605.20 2950.00 5348.06 5895.00 6049.00 6078.00 6163.00 6191.00 6800.00 6910.00 7040.00 7100.00 TVD ~ 0.00 160.00 500.00 649.96 799.62 997.73 1306.68 1488.80 1550.00 2168.80 2548.80 2553.74 2754.00 3098.80 5496.86 6043.80 6197.80 6226.80 6311.80 6339.80 6948.80 7058.80 7188.80 7248.80 NIS L 0.00 N 0.00 N 0.00 N 1.43 S 6.18 S 19.26 S 50.72 S 71.97 S 79.11 S 167.14 S 253.71 S 255.37 S 323.29 S 440.23 S 1253.57 S 1352.96 S 1368.48 S 1371.08 S 1378.12 S 1380.26 S 1409.43 S 1411.63 S 1413.14 S 1413.44 S EIW L 0.00 E 0.00 E 0.00 E 2.58 W 11.16 W 34.74 W 110.37 W 171.44 W 191.96 W 571 .36 W 1156.85 W 1170.24 W 1720.71 W 2668.47 W 9260.12 W 10049.79 W 10168.79 W 10188.53 W 10242.09 W 10258.40 W 10480.19 W 10496.92 W 10508.41 W 10510.73 W y ~:::::::::::::::::,:::-:::::, 5937910.20 N 5937910.20 N 5937910.20 N 5937908.77 N 5937904.02 N 5937890.95 N 5937859.50 N 5937838.27 N 5937831.14 N 5937743.18 N 5937656.75 N 5937655.10 N 5937587.30 N 5937470.57 N 5936658.71 N 5936559.49 N 5936544.00 N 5936541 .41 N 5936534.38 N 5936532.24 N 5936503.12 N 5936500.93 N 5936499.42 N 5936499.11 N 2K-27 (wpO1) X DLS (ft)r(:~::~:~) 498310.10 E 0.00 498310.10 E 0.00 498310.10 E 0.00 498307.52 E 1.50 498298.94 E 2.00 498275.36 E 2.50 498199.72 E 3.00 498138.65 E 0.00 498118.13 E 0,00 497738.71 E 3.50 497153.20 E 3.50 497139.80 E 3.50 496589.32 E 0.00 495641.53 E 0.00 489049.70 E 0.00 488260.01 E 3.00 488141.00 E 3.00 488121.26 E 3.00 488067.71 E 3.00 488051.39 E 3.00 487829.60 E 3.00 487812.87 E 3.00 487801.38 E 3.00 487799.06 E 3.00 V.S. (ft) ,',' :,:" ,,"" :,: :,::,: :::,:,: :,::: :,: :,: :,: :_: :,: :,: :,: :_: :,: :,: :,' :,: :,: ',: :,: :,: :,: ',", ,",' 0.00 0.00 0.00 2.74 11,88 36.99 116.15 179.50 200.79 588.54 1180.34 1193.84 1748.44 2703.34 9344.59 10140.45 10260.46 10280.37 10334.39 10350.84 10574.54 10591.41 10603.00 10605.34 Comment xxxxxxx xxxxx~~xx xxxx ,'" SHL 16" Conductor Begin Dir @ 1.50°/1 OOft Incr DLS to 2.0°/1 OOft Incr DLS to 2.5°/1 OOft Incr DLS to 3.0°/1 OOff End Dir; Start Sail Base Permafrost Begin Dir @ 3.5°/1 0 Off West Sak 0 Base West Sak End Dir; Start Sail 7 -5/8" Casing C-80 Begin Dir @ 3.0°/1 0 Off Base H RZ TARGET Kuparuk A4 Base Kuparuk A3 Miluveach Timberline Sand J-4 Base J-4 Bench :,::::::,::!?:t~,IP:~P~~:: ~.. --, ( { \ Sperry-Sun Anticollision Report í-"-c~~~~~~-- -------- - ------r; hï"i-~~- AÎ~~ k~ï ~c ~----------- ---------~ a te : ---S/5/2001-----"--Ti ~~ ~---~5: 1--3:50 -. ------- --;~ ;-- ----~--- --1 I Field: Kuparuk River Unit i Reference Site: Kuparuk 2K Pad Co-ordinate(NE) Reference: Well: Plan: 2K-27, True North ì Reference Well: Plan: 2K-27 Vertical (TVD) Reference: 2K-27 @ 148.8 (Nordic 3 148.8 ¡ Reference Wellpath: 2K-27 Plan Db: Oracle ! GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.00 ft Depth Range: 148.80 to 13996.87 ft Maximum Radius: 1584.81 ft Reference: Error Model: Scan Method: Error Suñace: Definitive Survey & NOT PLANNED PROG AM ISCWSA Ellipse ! Horizontal Plane I Circle + Casing Survey Program for Definitive Weltpath Date: 8/5/2001 Validated: No Planned From To Survey ft ft 148.80 900.00 900.00 13996.87 Version: Toolcode 7 Tool Name Planned: 2K-27 (wp01) V1 Planned: 2K-27 (wp01) V1 CB-GYRO-SS Camera based gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CÞ:Z. SCC Casing Point~ MD TVD Diameter Hole Size ft ft in in -......----...---..-----...------------------..-------..-----..-----..-------....------..----.-------.-..-----------..--------..------------------------....--..-----------------------------------.-------..-..----------------..----------..---"----..------- 160.00 160.00 16.000 20.000 16" 3568.61 2754.00 7.625 9.875 7-5/8" 12864.82 6190.35 5.500 6.750 5-1/2" Name Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Welt Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft - ........._...... ""-"..- -...... ...... .._--- _..-.... no.. -- ........... - .._........ ..._....... - .._....... _.. ...... ..,.... ........-.... _...... ............. ....................... ................. - .............- ............. - ............ _.... .......... -......... _.......................... ........... ............ ......... ................... ........... ............. ................ .......... ..""-' _...... ....-......- ..-.... .-- _.. ....-.... .............. ..................""""""- """""'-"'" Plan: 2K-27,2K-27 Plan 13996.87 13997.47 0.34 No Reference Casings Kuparuk 2K Pad 2K-13 2K-13 VO 4200.00 3938.03 455.08 0.00 287.26 Pass: Major Risk Kuparuk 2K Pad 2K-14 2K-14 VO 600.00 600.00 302.24 0.00 294.08 Pass: Major Risk Kuparuk 2K Pad 2K-15 2K-15 VO 600.00 600.00 276.62 0.00 267.77 Pass: Major Risk Kuparuk 2K Pad 2K-16 2K-16 VO 700.00 699.91 250.50 0.00 240.75 Pass: Major Risk Kuparuk 2K Pad 2K-17 2K-17 VO 700.00 699.94 225.12 0.00 215.66 Pass: Major Risk Kuparuk 2K Pad 2K-18 2K-18 V2 600.00 599.99 201.43 0.00 193.03 Pass: Major Risk Kuparuk 2KPad 2K-19 2K-19 V2 2200.00 2281.81 151.78 0.00 109.80 Pass: Major Risk Kuparuk 2K Pad 2K-20 2K-20 VO 1900.00 1948.67 43.21 0.00 1.92 Pass: Major Risk Kuparuk 2K Pad 2K-21 2K-21 V2 1500.00 1516.28 34.37 0.00 10.94 Pass: Major Risk Kuparuk 2K Pad 2K-21 2K-21 A V2 1500.00 1516.28 34.37 0.00 10.94 Pass: Major Risk Kuparuk 2K Pad 2K-22 2K-22 VO 1200.00 1202.74 57.97 0.00 39.25 Pass: Major Risk Kuparuk 2K Pad 2K-23 2K-23 VO 700.00 702.11 61.57 0.00 50.74 Pass: Major Risk Kuparuk 2K Pad 2K-24 2K-24 VO 800.00 801.75 22.16 0.00 9.88 Pass: Major Risk Kuparuk 2K Pad 2K-25 2K-25 VO 600.00 600.90 14.47 0.00 5.67 Pass: Major Risk Kuparuk 2K Pad 2K-28 Plan 2K-28 VO Plan: 2K-28 w 2400.00 2360.11 232.80 0.00 179.16 Pass: Major Risk ORIGINAL waL DEr.o\Il5 Nom: +NI.S +FJ-W Northi1g Easti1g Laliude Longiude Sbt pm., 2K-27 Æ>9O.O" 0.08 59~791O.20 ~98.11O.1O 7W14'2\I.733N ISO'!XT~9.I3I\V N/A 3 50 40 30 ---20 IO 0 10 20 30 -40 0 3 COMP"NY IJlITAJI$ WI~J.PATII IJIITAII.~ Imcr¡xllalion Mcthod:MD Depth Range Fmm: 148.80 Maximum Range: 1584.81 ANTI-COLLISION SETIlNGS Rig: Ref. IJatwo: N,'nlic ~ 2K.27 III 1 <lit." (Nnnh.: J '-'I.R/) 14II. !(H' O!t,m I¡.f.lh I'm 11o.1'lh Tn Survcyll'M 9110.1)1 PI,....-.J: 2K.~7 ("1'/11) VI 1:19')9.91 l'hnn.>J: 2K.27 "'1'011 VI ClJ-tWRO.SS MWI"-IFR.AK.C!v,S 270" "'-.. PhiEp' AII,ka Inc. Engi1œmg KupiU11k Cu:ukl..,n M"tb.>d: Mi1oomCIJfVJIUre "nor SY'I<m: ISCWSA Scan M"tb.>d: l...i",nl:1l 1"'"" . ". .... ,"' 2K-27 PM Interval: 20.00 To: 13999.91 Reference: Plan: 2K-27 (""'pon Origß +F/.W f~","'-fvIJ ~. :,'. \ '. '1>/1\, \. \ / 24Ò'\i........X-.\ / '-". , \>~ I i~'"" \,- -'<".... . '2:~'~~ / -- / / i ; I , i i ¡.... i i I \ \ \ \, " ". " '-" Ori¡m +N1-S 0.00 V.S",,'i1n Anglo 262.J5" O.lJO 0.1)1 =I .- // / / í ; I ! i , \ " ., '. '-, i I / .' .' / /' 'r( ./ " / " //" ~/ -.... ""'.... . -""""'---~ >", .... . ", "-"'" -~- .. .~_/ ~'" '---.... "", "'<, . """............... . .. -----------.:.. SURVEY I'ROCòRAM T,",I From 0 SOO 1000 ISOO 2000 2S00 :WOO 4IX)O SIX)(} 601X) 1000 KOIX) I)IXX) ] ()O( X) I 1000 ] 201 Colour ToMD SOO (IXX) ISIX) 2(X)(} 251X) ](XX) 4IXX) S(XX) filX)(} 10m !lOOO I)(XX) 1IXX)(} IIIXJO 120{X) Reference Azimuth Angle [deg] vs Centre to Centre Separation [20ft/in] LEGEND 2K-13 (2K-IJ). Major F 2K-14 (2K-14). Major R. 2K-IS (2K-IS). Major Risk 2K-I(J (2K-16), Major Risk 2K-17 (2K-I7). M¡ijorRisk 2K-1 X (2K-1 K), Major Risk 2K-1 Y (2K-IIJ). Major Risk 2K-20 (2K-20). Major Risk 2K-21 (2K-2(), M¡ljor Risk 2K-21 (2K-21 A). Major Risk 2K-22 (2K-22). Major Risk 2K-2J (2K-D). Major Risk 2K-24 (2K-24), Major Risk 2K-25 (2K-25). Major Risk 2K-2K Plan (2K-2R). Major 2K-27 Plan 2K-21 (wpO() ~ ..., ¡.. t,) ~ ,'J ¡.. .~ PI,.; 2K.27 ("pOIJ (I"'n: 2K.27I2K.27 I"'nl :"'"", (ly; I~m E~nJahl .t-o....k...l: ------ 1>",<:IV:II2O1J1 IRk: -- R.,...""I: ----- Appm""d; --------- 1""",- Do"" ---- SECTION IJIIT"ß$ Sot' MD I"" 1\,; TVI> .N/.S .E/.W III..., '1'0« VS", T....I'" I 1-1I!.W 0.110 0.011 14I!.1<!1 O.IXI 0.011 0.1'1 0.011 (1.011 2 5œ.lXJ o.m 0.00 sw.oo II.f)I) 1110 0-00 O.IJI fll{ 3 6.....).00 ::.25 241.00 (,.10.% -1.0 .2.58 UO 241.111 2.7.~ 4 800.00 5.L~ W.OO 799.1,2 .6.18 -ll.Ib 2.00 (1.111 II.IUI 5 100nllO ().L~ 241.1K1 "'773 .I'I.H .),1.74 2.~1 11.00 )6-," " 1320.00 19.55 ZSO.1!2 1;10'>.1>11 .50.72 .110..17 .\.II) 20m Ilb.I.! 7 I 51J!.20 19.55 1.<41.112 15SO.tXJ .1'1.11 .191.1 (, 0.00 0.011 2IXI.1J! 8 JIJJH.85 70.15 2112.95 2.~5.1.7J .2<5.54 .1170.25 3.~1 IUI 119~.1\.I 9 11711'>.06 70.15 2112.95 54%."7 .1255.*-1 .9'!HH5 fHXI (Hn 9:45.t.O III 12877.70 35.00 2112.88 6197.80 .1J6H.62 .11I16/I.KI 3.10 .17'/.91 Imbl.." 2K.27 (Kup <:4 180 ~- { ( 2K-27 Drillinq Hazards Summar'l (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 9-7/811 Hole /7-5/8" CasinQ Interval Event Conductor Broach Well Collision G ravel and sand slou hin Shoe Fracture/Lost Returns during cement 'ob Risk Level Low Low Low Low M iti ation Strate Monitor cellar continuousl durin interval. Careful well planning and surveying, adherence to anti-collision olic Elevated mud viscosity from spud; Hi dens swee s. Reduced pump rates, and lightweight tail cement 6-3/4" Hole / 5-1/2 & 3-1/2" CasinQ Interval Event Shale stability in HRZ High ECD and swabbing if higher MW is re uired . Hole cleaning in long, hi h an Ie tan ent Shale stability across K- 1 interval Shale stability across Miluveach Risk Level Moderate Moderate Moderate Moderate High M iti ation Strate Control with higher MW and proper drilling ractices. Pumping and rotating out on all trips to reduce swab and barite sag potential. Good drilling practices. Control with higher MW and proper drilling ractices. Control with higher MW and proper drilling ractices. 2K-27 Drilling Hazards Summary. doc prepared by Todd Mushovic 8/8/01 OR IG1fVÄ L Schlumberger CemCADE Preliminary Job Design . . 75/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Kuparuk Client: Phillips Alaska, Inc. Revision Date: 8/8/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 800' above West Sak formation. Lead Slurry (Minimum thickening time: 180 min.) ASLite @ 10.7 PPg, Class G + 50%0124,9%044,0.4%046,300/0053, 1.5%S1, 1.5%079 - 4.44 ft /sk 0.9513 fe/ft x (120') x 1.00 (no excess) = 114.2 fe 0.2148 ft3/ft x (1513' -120') x 3.50 (250% excess) = 1047.3 fe 0.2148 ft3/ft x (1516' - 1513') x 1.45 (45% excess) = 0.9 ft3 114.2 fe + 1047.3 fe+ 0.9 ft3 = 1162.4 fe 1162.4 fe /4.44 fe/sk = 261.8 sks Round up to 270 sks <: TOC at Surface A'evious (Sg. <: 16", 62.6# casing at 120' tv[) <: Base of ~rrraf root at 1,513' tv[) (1 ,489' lVD) <: Top of Tail at 1,516' tv[) <: Top of West Sak at 2,316' tv[) <: 7518",29.7# casing in 9 7/8" a-t TO at 3,629' tv[) (2,754' lVD) 'Mark of Schlumberger Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (Minimum thickening time: 140 min.) LiteCRETE @ 12.0 ppg - 2.40 ft /sk 0.2148 felft x (3629' - 1516') x 1.45 (45% excess) = 0.2578 ft3/ft x 80' (Shoe Joint) = 658.1 fe + 20.6 fe = 678.7 ft3f 2.40 fefsk = Round up to 290 sks 658.1 fe 20.6 ft3 678.7 ft3 282.8 sks BHST = 62°F, Estimated BHCT = 71°F. (BHST calculated using a gradient of 2.4 °F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Lead Slurry 6 214 35.7 53.7 Tail Slurry 6 124 20.7 74.4 Drop Top Plug 3.0 77.4 Displacement 6 143 23.8 101.2. Bump Plug 3 20 6.7 107.9 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ~ 17-20, T y ~ 20-25 Centralizers: Recommend 1 per joint from 1316' MO to TO for proper cement placement. ORIGIN,QL Schlumbe rger CemCADE Preliminary Job Design . 51/2"x3 1/2" Production. Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Kuparuk Client: Phillips Alaska, Inc. Revision Date: 8n/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@ slb.com Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 800' above the top of crossover. Tail Slurry (minimum thickening time 160 min.) GasBLOK wI Class G + 30/0 053, 2 gps 0600, 0.15 gps 0135, 0.12% 0800,0.2°/00047, 0.6% 0065, per lab testing @ 15.8 ppg, 1.2 fe/sk < Base of Pennaf rost at 1,513' MJ{1,48Y' IVU) A"evious Csg. < 7 5/8", 29.7# casing at 3,629' rvo < 51/2",15.5# casing in 63/4" OH < TOC at12,000' rvo < X-over at 12,800' rvo < Top of C4rrarget at 12,877' rvo < 31/2",9.3# casing in 6 3/4" OH IDat 13,999' rvo (7,249' lVD) Mark of Schlumberger 0.0835 ft3/ft x 800' X 1.75 (75% excess) = 0.1817 fe/ft x (13999' - 12800') x 1.75 (750/0 excess) = 0.0488 ft3/ft x 80' (Shoe Joint) = 73.1 fe + 381.3 fe + 3.9 fe = 458.3 ft3/1.2 fe/sk = Round up to 390 sks 73.1 ft3 381.3 ft3 3.9 ft3 458.3 fe 381.9 sks BHST = 170°F, Estimated BHCT = 141°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Tail Slurry 6 83 13.8 31.8 Drop Top Plug 3.0 34.8 Displacement 6 294 49.0 83.8 Bump Plug 3 20 6.7 90.5 MUD REMOVAL Recommended Mud Properties: 10.4 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv := 19-22, T y := 22-29 . Centralizers: Recommend 1 per joint from 11800' MD to TO for proper cement placement. . ORIGINAL ( 2K-27 Producer Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +/- 150' MD Depths are based on Nabors 16E AKB Surfaeeesg. 7-5/8" 29.7# L-80 BTCM 3629' MD / 2754' TVD Intermediate esg. 5-1/2" 15.5# L-80 BTCM (+/-12,800' MD / +/- 6136' TVD) Future Perforations - Kuparuk Future Perforations - Timberline Production csg 3-1/2" 9.3# L-80 13,999' MD I 7249' TVD ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Cameo 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" X 1" Cameo 'KBG-2-9' Mandrels w/ DV's and RK latch's (Max. OD 4.725", ID 2.90"), IBT box x box, 3-1/2" x 6'L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below. Spaced out wI 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM# TVD-RKB MD-RKB GLM Numbers and Spacing To Be Determined 3-1/2" X 1" Camco 'KBG-2-9' mandrel w/ DCK-3 shear valve and latch (Max. CD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco'DS' nipple w/2.812" No-Go profile. 3-1/2" x 12' L-80 EUE8RD spaceout pup installed above, 3-1/2" x 6' L-80 EUE8RD handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assemblyw/15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +/- 1 00' above top perforation 3-1/2" Halliburton 'X' nipple w/2.812" profile. 3-1/2" x 12' L-80 EUE8RD spaceout pup installed above, 3-1/2" x 6' L-80 EUE8RD handling pup installed below. Set +/- 200' above the Timberline interval. ORISINAL American Express@ Advance Draft 158 DATE ~vs 11, wi ., <N'O" . - flcktCL- \ s [¡ø.CJo . 1 Cash PAY TO THE ORDER OF DOLLARS ~ --~ Nçl=~:~!~ ¿ P;;¡;;; A.- I"> r I: ~ 0 2 ~ DOl. 0 0 I: ~ 5 III 0 ~ 7 5000 5 ~ b II. 0 ~ 5 a Issued by Integrated Payment System. Inc. Englewood. Colorado Payable at Norwest Bank of Grand junction - DowntOwn. NA Grand junction. Colorado PERIOD ENDING ...- >J I( { TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL / (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION ANNULAIWISPOSAL ~NO INJECTION WELL ANNULAR DISPOSAL L..J YES INJECTION WELL RED RILL ANNULAR DISPQ§åk THIS WELL ~ D> \L--d-~ "CLUE" The permit is for a new wellbore segment of existing weD . Permit No, API No. . Production should continue to be reported as a function, of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULU~ ' L:J YES + SPACING EXCEPTION , Enclosed is the approved application for permit to drill the above referenced well. The, permit is approved, subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance' of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any prøtest to the spacing exception that may occur. áA~ :rr D/6i>o~ -h>0- W~~~ r=:-M . lí-\,~ 1I..)éJ...L - 'jVO t\~k:JUL-1 -P\iAn..:1\ßu.. 0 f-\ 2)L. ÞA.D.. ~') ~Ut:)i f\~t-.)u Ir--of'o L FOp- r1-ì It:> V\.J~L-L Aí WN\PI--L'{JON ðF t)~~L--) N&., ""'^-'\- Templates are located m drive\jody\templates I< WELL PERMIT CHECKLIST COMPANY WELL NAME 2K -2- 7 PROGRAM: exp - dev X redrll FIELD & POOL LlQDloO INIT CLASS .lJG!v /-ð,'/ GEOLAREA 9,7,..-j ADMINISTRATION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . Y N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . Y N. 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . Y N 11. Pennit can be issued without conservation order. . . . . . . . Y N 12. Pennit can.be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N 14. Conductor string provided. . . . . . . . .. . . . . . . . . . ~ N 15. Suñace casing protects all known USDWs. . .. . . . . . . . 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . N "- 20. Adequatetankageorreservepit.. . . . . . . . . . . . . . . . ' N~\">\\~ ~ (~~~.~\~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~ ~ ~ ~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling .fluid program schematic & equip list adequate. . . . . N ~~: :g~~spr~~~~:~:e:~~~~~~~~~;nt~sÙ~ . . . . 3SOO . ~sig: ~ ~~ <>" ~\~~~~ ~8; ~ i , . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdöwn. . . . . . . . . . . Y ~ Q.~~'><è..~~~{~~t-.....<;O~~O\Q~~ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . <t!) 30. Permit can be issued wlo hydrogen sulfide measures. . . .. Y N 31. Data presented on potential overpressure zones. . . . . . . Y.4' I LJ 32. Seismic analysis of shallow gas zones. . . . . . . . . . '.' . N /Vj n. APPR EJ\!9, 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N' . . ,~ ~ 34. Contact name/phone for weekly progress reports [exploratory 0 yJ Y N - ~ "\ ~ ~'{ Ð~~~\ ,<\o.t'..~\"'>~~'>'"> ~ ~~\\, þ.~~\~\\\. ~s.o~"~" ANNULAR DISPOSAL35. With proper cementing records, this plan. Y N "'o'rD ,...""'~t.bT~.(() IÞJ! P7{) fW'pl-J (;A7l 0 ~- (A) will contain waste in a suitable receiving zone; . . . . . . . ~ (8) will not contaminate freshwater; or cause drilling waste. .. Y N to surface;. .. (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:.. UIC/Annuiar COMMISSION: ~þ~ WM .8~S~J/ò/ ~ JM~' serv wellbore seg _ann. disposal para req - / / / [; ð ON/OFF SHORE GN UNIT# Z -I ,X GEOLOGY APPR DATE Com mentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -I ~ :::0 ( , - -I m - - en )- :::0 m > (' ,¡f ~i ~' Well History File APPENDIX Information of detailed nature that is not , particularly gennane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History fHe and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically . . organize this category of information. ¡"Ii'" ~ ( Sperry-Sun Drilling Services LIS Scan Utility 2k-27.tapx $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 04 15:35:46 2002 Reel Header Service name............ .LISTPE Date.....................02/02/04 Origin...................STS Reel Name................UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................02/02/04 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # Writing Library. Scientific Technical Services 2K-27 501032038800 Phillips Alaska, Inc. Sperry-Sun Drilling Services 31-JAN-02 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-11146 AK-MM-11146 AK-MM-1l146 A. WEAVER A. WEAVER A. WEAVER D. HElM D. HElM D. HElM MWD RUN 4 MWD RUN. 5 AK-MM-11146 AK-MM-11146 A. WEAVER A. WEAVER D. HElM D. HElM 11 ION 8E 394 94 MSL 0) 148.70 118.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 150.0 6.750 7.625 6774.0 Page 1 ~ 0/ -[ bC! ( ( 2k-27 . tapx REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. MWD RUNS 4 AND 5 COMPRISED DIRECTIONAL, DGR, EWR4, STABILIZED LITHO- DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ (PHILLIPS ALASKA) TO R. KALISH (SSDS) DATED 1/4/02, QUOTING AUTHORIZATION FROM GKA GEOSCIENCE GROUP. 6. MWD RUNS 1 - 5 REPRESENT WELL 2K-27 WITH API# 50-103-20388-00. THIS WELL REACHED A TOTAL DEPTH OF 14037'MD / 7357.25'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN PROCESSING POROSITY LOGS: FIXED HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER FLUID DENSITY: MATRIX: MATRIX DENSITY: SALINITY: 6.75" 10.2 - 10.3 PPG 400 PPM CHLORIDES 31,000 PPM CHLORIDES 1. 0 G/CM3 SANDSTONE 2.65 G/CM3 $ File Header Service name............ .STSLIB.OOI Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/04 Page 2 (' Maximum Physical Record. .65535 File Type................LO Previous File Name... ... .STSLIB.OOO Comment Record FI LE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP RPX RPS RPM RPD FET GR NCNT FCNT NPHI RHOB DRHO PEF $ 1 ( 2k-27.tapx clipped curves; all bit runs merged. .5000 START DEPTH 850.0 876.5 876.5 876.5 876.5 876.5 886.0 11646.5 11647.5 11647.5 11662.5 11662.5 11662.5 STOP DEPTH 14037.0 13995.5 13995.5 13995.5 13995.5 13995.5 13988.5 13940.5 13941.5 13940.5 13956.5 13956.5 13956.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 850.0 5006.0 MWD 2 5006.0 6787.0 MWD 3 6787.0 11742.0 MWD 4 11742.0 12116.5 MWD 5 12116.5 14037.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ........ .......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing..... ............... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Page 3 (" f 2k-27.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 850 14037 7443.5 26375 850 14037 ROP MWD FT/H 0 1049.11 146.81 26328 850 14037 GR MWD API 16.62 587.02 115.858 26206 886 13988.5 RPX MWD OHMM 0.95 230.4 8.65275 26207 876.5 13995.5 RPS MWD OHMM 1.13 782.56 10.4706 26207 876.5 13995.5 RPM MWD OHMM 1.12 2000 13.0429 26207 876.5 13995.5 RPD MWD OHMM 1.16 2000 14.0406 26207 876.5 13995.5 FET MWD HOUR 0.13 88.54 1.13617 26207 876.5 13995.5 NPHI MWD PU-S 10.44 53.96 30.8137 4587 11647.5 13940.5 FCNT MWD CNTS 149.7 1054.6 323.025 4589 11647.5 13941.5 NCNT MWD CNTS 15781. 7 34084.5 20812.3 4589 11646.5 13940.5 RHOB MWD G/CM 1. 84 3.1 2.44869 4589 11662.5 13956.5 DRHO MWD G/CM -0.318 0.503 0.0740532 4589 11662.5 13956.5 PEF MWD BARN 2.47 12.24 4.68627 4589 11662.5 13956.5 First Reading For Entire File......... .850 Last Reading For Entire File.......... .14037 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/02/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPS RPX RPD FET RPM GR $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 850.0 876.5 876.5 876.5 876.5 876.5 886.0 STOP DEPTH 5006.0 4954.0 4954.0 4954.0 4954.0 4954.0 4962.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 30-AUG-01 Insite 66.16 Memory 5006.0 850.0 5006.0 Page 4 {' BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ,~, 2k-27.tapx 6.4 72.1 TOOL NUMBER PB02118HRG6 PB02118HRG6 9.875 Water 9.60 125.0 9.2 250 7.5 Based 5.200 3.450 6.000 4.500 68.0 105.8 68.0 68.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 850 5006 2928 8313 850 5006 ROP MWD010 FT/H 0.59 1049.11 179.684 8313 850 5006 GR MWD010 API 16.62 150.52 84.0502 8153 886 4962 RPX MWD010 OHMM 2.69 230.4 19.4046 8156 876.5 4954 RPS MWD010 OHMM 2.97 782.56 25.1614 8156 876.5 4954 RPM MWD010 OHMM 2.79 1937.33 30.9089 8156 876.5 4954 RPD MWD010 OHMM 2.8 1827.49 29.2792 8156 876.5 4954 FET MWD010 HOUR 0.13 6.6 0.655422 8156 876.5 4954 Page 5 (' First Reading For Entire File........ ..850 Last Reading For Entire File.......... .5006 File Trailer Service name...... ...... .STSLIB.002 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record. .65535 File Type....... ........ .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name.... ........ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 ( 2k-27 . tapx header data for each bit run in separate files. 2 .5000 START DEPTH 4954.5 4954.5 4954.5 4954.5 4954.5 4962.5 5006.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 6734.5 6734.5 6734.5 6734.5 6734.5 6742.0 6787.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 01-SEP-01 Insite 66.16 Memory 6786.0 5006.0 678 6.0 68.4 72.4 TOOL NUMBER PB02118HRG6 PB02118HRG6 9.875 Water Based 9.60 135.0 Page 6 ( ( MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2k-27.tapx 9.4 220 3.5 2.000 1.150 7.000 1.940 65.0 118.4 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction. .............. ..Down Optical log depth units........ ...Feet Data Reference Point... ....... ... .Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 4954.5 6787 5870.75 3666 4954.5 6787 ROP MWD020 FT/H 0 295.26 77.1588 3541 5006.5 6787 GR MWD020 API 65.18 170.78 114.064 3560 4962.5 6742 RPX MWD020 OHMM 1. 85 17.34 4.19981 3561 4954.5 6734.5 RPS MWD020 OHMM 2.13 18.27 4.38858 3561 4954.5 6734.5 RPM MWD020 OHMM 2.56 23.33 4.60839 3561 4954.5 6734.5 RPD MWD020 OHMM 3.15 24.79 4.77737 3561 4954.5 6734.5 FET MWD020 HOUR 0.48 18.49 1. 48935 3561 4954.5 6734.5 First Reading For Entire File......... .4954.5 Last Reading For Entire File.......... .6787 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation. .... ..02/02/04 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.004 Physical EOF File Header Page 7 (" Service name............ .STSLIB.004 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record. .65535 File Type................LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 4 ( 2k-27.tapx header data for each bit run in separate files. 3 .5000 START DEPTH 6742.5 6751.0 6751.0 6751. 0 6751.0 6751.0 6800.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11686.0 11693.0 11693.0 11693.0 11693.0 11693.0 11742.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 07-SEP-01 Insite 4.3 Memory 11742.0 6786.0 11742.0 68.4 72.0 TOOL NUMBER PB02065GR4 PB02065GR4 6.750 Water 8.80 45.0 9.9 300 6.8 Based 5.000 2.860 6.000 2.800 70.0 127.4 70.0 70.0 Page 8 ( (' 2k-27.tapx # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction............ .... . Down Optical log depth units. ......... .Feet Data Reference Point............. .Undefined Frame Spacing... ...... .......... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6742.5 11 742 9242.25 10000 6742.5 11 742 ROP MWD030 FT/H 0 428.53 164.306 9884 6800.5 11 742 GR MWD030 API 42.27 239.24 134.962 9888 6742.5 11686 RPX MWD030 OHMM 0.95 16.11 3.88507 9885 6751 11693 RPS MWD030 OHMM 1.14 16.82 3.92465 9885 6751 11693 RPM MWD030 OHMM 1. 75 2000 5.89027 9885 6751 11693 RPD MWD030 OHMM 1. 86 2000 9.70336 9885 6751 11693 FET MWD030 HOUR 0.21 88.54 1.24805 9885 6751 11693 First Reading For Entire File... ...... .6742.5 Last Reading For Entire File.... ...... .11742 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.... ...02/02/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT 5 header data for each bit run in separate files. 4 .5000 START DEPTH 11646.5 STOP DEPTH 12021. 5 Page 9 ( NPHI FCNT PEF DRHO RHOB GR RPD RPX RPS RPM FET ROP $ 11647.5 11647.5 11662.5 11662.5 11662.5 11686.5 11693.5 11693.5 11693.5 11693.5 11693.5 11742.5 12021. 5 12021.5 12036.0 12036.0 12036.0 12059.5 12076.0 12076.0 12076.0 12076.0 12076.0 12116.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ............ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.....................60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... ( 2k-27 . tapx 09-SEP-01 Insite 4.3 Memory 12117.0 11742.0 12117.0 57.6 68.5 TOOL NUMBER PB02065GR4 PB02065GR4 PB02065GR4 PB02065GR4 6.750 Water 10.20 49.0 9.0 400 10.0 Based 1.750 .990 2.500 1. 300 68.0 125.6 68.0 68.0 Page 10 ( ( 2k-27.tapx Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11646.5 12116.5 11881.5 941 11646.5 12116.5 ROP MWD040 FT/H 0 180.72 101.328 749 11742.5 12116.5 GR MWD040 API 94.28 185.42 131.125 747 11686.5 12059.5 RPX MWD040 OHMM 1.2 7.33 3.48278 766 11693.5 12076 RPS MWD040 OHMM 1. 26 7.64 3.48701 766 11693.5 12076 RPM MWD040 OHMM 1. 31 9.8 3.72129 766 11693.5 12076 RPD MWD040 OHMM 1. 38 10.87 4.01437 766 11693.5 12076 FET MWD040 HOUR 0.27 29.52 4.1552 766 11693.5 12076 NPHI MWD040 PU-S 17.5 47.63 29.1047 749 11647.5 12021. 5 FCNT MWD040 CNTS 159.2 625 345.294 749 11647.5 12021. 5 NCNT MWD040 CNTS 16245.9 27857.9 21537.7 751 11646.5 12021. 5 RHOB MWD040 G/CM 1. 84 2.72 2.3673 748 11662.5 12036 DRHO MWD040 G/CM -0.01 0.503 0.126302 748 11662.5 12036 PEF MWD040 BARN 3.03 12.24 5.87384 748 11662.5 12036 First Reading For Entire File......... .11646.5 Last Reading For Entire File.......... .12116.5 File Trailer Service name..... ....... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 6 header data for each bit run in separate files. 5 .5000 START DEPTH STOP DEPTH Page 11 ( NPHI FCNT NCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ 12022.0 12022.0 12022 . 0 12036.5 12036.5 12036.5 12060.0 12076.5 12076.5 12076.5 12076.5 12076.5 12117.0 13940.5 13941. 5 13940.5 13956.5 13956.5 13956.5 13988.5 13995.5 13995.5 13995.5 13995.5 13995.5 14037.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction......... ....... . Down Optical log depth units.. ........ .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 ( 2k-27 . tapx 11-SEP-01 Insite 4.3 Memory 14037.0 12117.0 14037.0 9.9 54.2 TOOL NUMBER PB02065GR4 PB02065GR4 PB02065GR4 PB02065GR4 6.750 Water 10.30 46.0 9.1 400 9.0 Based 1.600 .690 2.500 1. 500 70.0 172.0 70.0 70.0 Page 12 ( (' 2k-27.tapx Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12022 14037 13029.5 4031 12022 14037 ROP MWD050 FT/H 4.41 255.39 103.72 3841 1211 7 14037 GR MWD050 API 40.45 587.02 132.812 3858 12060 13988.5 RPX MWD050 OHMM 1.15 28.86 3.24866 3839 12076.5 13995.5 RPS MWD050 OHMM 1.13 26.09 3.14979 3839 12076.5 13995.5 RPM MWD050 OHMM 1.12 25.91 3.18724 3839 12076.5 13995.5 RPD MWD050 OHMM 1.16 36.05 3.42703 3839 12076.5 13995.5 FET MWD050 HOUR 0.22 17.6 0.939424 3839 12076.5 13995.5 NPHI MWD050 PU-S 10.44 53.96 31.1473 3838 12022 13940.5 FCNT MWD050 CNTS 149.7 1054.6 318.681 3840 12022 13941. 5 NCNT MWD050 CNTS 15781.7 34084.5 20670.4 3838 12022 13940.5 RHOB MWD050 G/CM 1. 99 3.1 2.46454 3841 12036.5 13956.5 DRHO MWD050 G/CM -0.318 0.36 0.0638782 3841 12036.5 13956.5 PEF MWD050 BARN 2.47 10.46 4.45501 3841 12036.5 13956.5 First Reading For Entire File......... .12022 Last Reading For Entire File.......... .14037 File Trailer Service name......,..... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name..... ..,.... .LISTPE Date.....................02/02/04 Origin...................STS Tape Name.. ............, . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.... ",..,. ..LISTPE Date.....................02/02/04 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments... "..,........ .STS LIS Writing Library. Scientific Technical Services Page 13 { ( 2k-27.tapx Physical EOF Physical EOF End Of LIS File Page 14
