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189-119
a�yp :4_nm' terra rd .AR . • • 3 G' f ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 2 " Suspended ❑ lb.Well Class: 20AAC 25.105 zoMc 25.110 Development 2 i Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 8/24/2016 '189-119 ?31 ,,! Li I 3.Address: 7. Date Spudded: 15.API Numb r: P.O.Box 100360 Anchorage,AK 99510-0360 11/14/1989 50-103-20121-00 • 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number Surface: 169'FNL,94'FEL,Sec 11,T1ON, R8E, UM 11/20/1989 KRU 2K-17 • Top of Productive Interval: 9. Ref Elevations: KB:154.0 17. Field/.Pool(s): 1352'FSL 1323'FEL,Sec 12,T1ON,R8E, UM GL: 113.9 BF: Kupurak River Field/Kuparuk Oil Pool ' Total Depth: to `` 10. Plug Back Depth MD/TVD: 18. Property Designation: 1177'FSL, 1091'FEL,Sec 12,T.QiN R8E, UM Surface ADL 25588 • 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498310 y- 5938135 Zone- 4 9145/6404 2674 TPI: x- 502363 y- 5934376 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 502595 y- 5934202 Zone- 4 1789/1759 1402/1400 5. Directional or Inclination Survey: Yes ❑ (attached) No 2 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 n/a , • SCANNED FEB 2 4201Z 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH NAMOUNT CASING GRADE D HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 surf 115 surf 115 24 170 sx AS II 9.625 36 J-55 surf 3563 surf 2954 12.25 1100 sx ASIII,450 sx Class G 7 26 J-55 surf 9129 surf 6409 8.5 200 sx Class G 24.Open to production or injection? Yes ❑ No E 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 8705 8657 MD/6085 ND PERFS SQUEEZED OFF paa.)e-Y2 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. `:AT (/� Was hydraulic fracturing used during completion? Yes❑ No 0 ?IVA i 1 I Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 46'-8710' Pumped 63 bbls 15.7 ppg AS I 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): not applicable Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -p Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate ► Form 10-407 Revised 11/2015 (/TL I o/ /!h NTIN E ON PAGE 2 R eMS (z1-'. SEP - 1 2016 Submit ORIGINIAL only iC (I' 10'/0'' G • S 28.CORE DATA Conventional Core(s): Yes ❑ No Sidewall Cores: Yes ❑ No 2 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1402 1400 Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. not applicable Formation at total depth: not applicable 31. List of Attachments: Summary of Daily Operations, P&A Marker Plate Pictures,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 MC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263-4131 Email: JiILSimekacop.com Printed Name: G.L.Alvord Title: Alaska Drilling Manager - • Signature: G l'cc4 Phone: 265-6120 Date: i°1( Uoily 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 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2K-17 Plug and Abandonment August 29, 2016 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2K-17, commencing operations on July 24, 2016 and completing the Plug and Abandonment on August 24, 2016. Operations involved pumping 231 bbls of Class "G" cement down tubing and up tubing x production casing annulus (IA). Top of cement was tagged at 1,252' KB in the tubing and a cement bond log determined IA TOC to be at 1,080' KB. Tubing was then punched at 1,056'- 1,060' KB and 63 bbls of ArcticSet 1 (AS1)pumped fullbore, to bring cement to surface in tubing and IA. A cement downsqueeze followed to place 16 bbl of AS 1 cement in the surface casing x production casing annulus (OA). The well was then excavated and wellhead and cellar removed. Top of cement in the tubing and IA was determined teeo be at surface while OA TOC was 98'. A 4.5 bbl top job was performed in the OA to bring cment to surface. The State Inspector determined that cement was in good condition and thwell was capped and excavation backfilled. Pictures below show cement to surface in all annuli, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. a :1,1,4 '''°- ''-:-'4,,,.,'Itkol? ,: ,,'-'' -,:a, ,71,,,,-,-k-, i:,,-, ,,,„ ..., -, . , ,,—. It, '," ,,,,,,„„n i ' ''' Ali.,-` ,•,' , '4- ' '°'. ,,,,i' ' f'.tt''''a,,,,' -' s ''' ......flp,,, ' ,',--"' - =,-,..,-4,4-,6".cvo.,11•,:,.:, • , ,„ , , . u ' u ' 'nj �: 1 x ',t= " r 4,,,....,zik,,,,,-„' ,em + X a '. ;o- aa. ''* r - ,'it.,,,,;: ',,, "-iti-,„2:-°,',,v,,, :, .*r I At. ip �: aw ; # r° „,„,i,,4., ., v as �' . a x ° si € - n -. '� 3 't g axe s ` +”�°.� ,. • 0 7;,i4," ..,„'•,;,'„;''0,';'?4,ft:Ii‘:1 ' it%, * " .-''' ' ' ' ''''. .'" •'a ''''4&"—;—cs:''''' ,,...,r4ittAt1/4, ‘.1 ,„ . ..„,,,,,„.1 ,,,,, ,, ,4,, 014' ',1 ....? L .,,, :. -,', 7 �� f £ .-,}itit dei.. d w,� 4"+ :-r,'''cilrm ''',..,.,..t.,, '..4 -,.,::7 ':':-,°:-:?:, -.. 'Aefitt,i1;,;,-..: \:!0!C.,,,„,,?, 41:''' :t.'7, ..:°,;.4 ,,-.., ,., ..- - ., . p Ass _ y 10 z � s � ,� � ��y�ex pi's `� � —t {'� � � -,,..*1„,...- ,...,„ , -',it ,,..,, ,- 4.,..t.,., ,..,,, ,,,,,1...„... , .4::iltivta,„,,,,,..,,.........,...,14,,,,a,..,...,,,,,..„„„ .., ,, ...,, ..,. _ .', ' ry .. '-1 .°1;$47'4`,\::r 7,44.*1$44Z A 1 .•.' # IP nghte •'GgCh' "Co yrighOprovd o th' nt 'tre oyais h4r•� aresp" k t t+ ."' �y:, ., y', * „,, i -a , r'. lbg tilattra 411 .iiii 4.:1:10.:11111'"--'44. ' * y , .� iy� :s^ :ti , ' waazY.r � w# • • EVENT_DAT EVENT_TEXT 8/24/2016 Took pictures of final burial of P&A and sent info to town engineer Jill Simek. 8/23/2016 Sent pictures of marker plate to Stateman Robert Noble. 8/23/2016 Initial T/I/0=0/0/0 GBR welder Danny Wilkins welded the marker plate on Removed sump, stairs and shoring box R&P began backfilling excavation Final T/I/0=0/0/0 8/22/2016 Invite State to witness hard cement and P&A marker plate, Brian Bixby& Robert Noble responded that they wanted to witness. Robert Noble witnessed hard cement and asked for a picture of marker plate on well. 8/21/2016 Initial T/I/0=0/0/0 Pumped and circulated 3 bbls of 15.8 ppg of Type G cement through the OA and observed good cement returns with fluid breaking out. Let cement set for 1 hour allowing fluid to break out. Vac'd out breakout fluid. Pumped and circulated 1.5 bbls of 15.8 ppg Type G cement through OA until receiving good cement returns with no breakout fluid. 8/20/2016 Initial T/I/0 = 10/10/10 Vac'ed out 230 bbl of H2O from excavation. Bled T/I/O to 0 psi T gas test= H2S-0 ppm, CO-6 ppm, LEL-4.6%, 02 -9.5% IA gas test= H2S-0 ppm, CO- 165 ppm, LEL-60%,02-2% OA gas test= H2S-0 ppm, CO-0 ppm, LEL-OL%,02- 1% Had continuous N2 purge on T/I/O while cutting well head. Rigged crane to well head. GBR welder Steve Pape cut windows into conductor and removed cement from around the surface casing. Welded weld-O-lets to surface casing and installed valve assembly to drill and verify no fluid. Cut windows into surface casing. Welded weld-O-lets to production casing and installed valve assembly to drill and verify no fluid. Cut windows into production casing and removed cement from around tubing. Welded weld-O-lets to tubing and installed valve assembly to drill and verify no fluid. Cut and removed tubing. Made final cuts on tubing, production, surface and conductor casings 4 ft below tundra level and flew out well. Shrink wrapped well for future cement job on 8-20-16. 8/19/2016 Invite State to witness P&A stub and topping with cement.. Stateman Robert Noble replied that stub inspection and pumping cement was not reqiured by state-they would like to witness hard cement and welding marker plate. S • 8/19/2016 P&A Initial T/I/0=0+10+10+ IA cement level at 10'8" Bled T/I/0 to 0 PSI T; 02=20.9%, C0= 6, LEL=6.5%, H2S=0 IA=02=8%, C0=OL, LEL=OL, H2S=0 OA; 02= 2%, C0=22, LEL=OL, H2S=0 Pressured up T/I/0 to 30 PSI w/N2 and bled to 0 PSI 3 times. Left 10 PSI of N2 on T/I/0 Final T/I/0= 10/10/10 8/18/2016 P&A • Initial T/I/0=0/0/0 Backfilled around shoring box, Depth of hole is—12-13' Built egress, Set stairs Had scaffold built Final T/I/0=0/0/0 8/17/2016 P&A Initial T/I/0=0/0/0 Cut and removed standing plate Excvated to—6' below tundra Set sump Backfilled-1' of pea gravel Set shoring box Final T/I/0=0/0/0 8/16/2016 P&A Initial T/1/0=0/0/0 Removed Jewelry, Removed conductor mounts for floor kit and begun excavation. Final T/I/0=0/0/0 8/15/2016 P&A PREP Initial T/I/0=0/0/0 Removed Tree, installed a 3 1/8" 5000PSI blind with bleeder, Found T TOC is 14' and Vac'ed out T. Final T/1/0=0/0/0 0 • 8/14/2016 P&A PREP : N2 MIT-OA to 500 psi. Initial T/I/0 =0/0/0+ OA FL @ 36' Pressured OA to 500 psi w/N2 Starting T/1/0=0/0/500 15 min T/I/0=0/0/490 30 min T/I/0=0/0/485 Bled OA to 0 psi in 20 min OA FL @ 35' Shut in OA for BUR • 15 min=0.4 PSI 30 min=0.8 T TOC 12" Dropped a string weight to find OA TOC OA TOC 98' Final T/I/0=0/0/0 8/13/2016 P&A PREP, BLED T/1/0,T/I/0 BUR, OA FL Initial T/I/0=0+/Vac/1.4 Bled and left on a open bleed for 7 hrs to allow to breathe and relax on T/I/0. Initial Bleed Time: T= 1 sec(Gas) 1= N/A 0= 3 sec(Gas) Shut in for 60 mins 30 min BUR T=0.2 1=0 0=0.05 60 min BUR T=.28 1=0 0=.09 Bled T/I/0 to 0 PSI OA FL 36'6" Final T/l/0=0/0/0 8/12/2016 Initial T/I/0= 3/Vac/8 T bled to 0 PSI almost instaneously. Bled OA(30 sec)and T(< 2 sec) (Both gas), Let relax for 1 hour. OA BUR 3 PSI after 30 min shut in. T BUR 0 PSI after 30 min shut in. Let relax and breathe for 2 hr. OA BUR 0+PSI after 30 mins shut in. T BUR 0 PSI after 30 min shut in. Repeated process with same results. Bled T/I/0 before leaving. Final T/l/0=0/0/0 8/6/2016 (MON)T/I/0= 5/3/3. (T=+5 psi IA=+3 psi OA=+3 psi since 8/5/16) • • 8/5/2016 (AC EVAL) MITT TO 1500 PSI FAILED MITIA TO 1500 PSI FAILED TBG/IA/OA DDT IN PROGRESS Initial T/I/O=0/90/10 T FL NS IA FL @ SF Pressured IA to1500 psi multiple times with small amount of diesel but greater than 5%losses in 5 minutes. Bleed IA to 0 (20 min/fluid) Pressured T to 1500 psi with 7 gallons 15 minutes 1020 psi Pressured T to 1500 psi 5 minutes 1275 psi Pressured T to 1500 psi 5 minutes 1340 psi Pressured T to 1500 psi 5 minutes 1400 psi Pressured T to 1500 psi 5 minutes 1420 psi Pressured T to 1500 psi 15 minutes 1360 psi Pressured T to 1500 psi 15 minutes 1360 psi.Bleed tbg to 0 (10 min/fluid) Bleed OA to 0 (1 min/gas) Allow all annuli to breathe 10 min.T/I/O=0/0/0 15 monitor T/I/0 =8/0+/0+ bleed tbg to 0 allow to breathe 15 min. Continue to monitor IA/OA while bleeding tbg 30 monitor T/I/O=0/1+/1+(SI tbg bleed) 15 monitor T/I/O=6/2/1 Bleed all annuli to 0 allow to breathe 15 min 15 monitor T/I/O=4/1/0+ 120 minute reading T/I/O=9/3/1 8/4/2016 (AC EVAL): MITIA(IN PROGRESS), Initial T/I/0 =0+/vac/50.T FL @ 30', IA FL near surface. Bled T to 0 psi in 5 sec,bled OA to 0 psi in 12 min. Pumped^' 1 bbl of diesel down OA,OA did not gain pressure,OA FL @ "'30' Pressurized IA to 1500 psi with 13 gal of diesel. 15 min reading: 950 psi. (-550) Re-pressurized IA to 1500 psi with a small amount of diesel. 15 min reading: 950 psi. Re-pressurized IA to 1500 psi with a small amount of diesel. 15 min reading: 1000 psi. Re-pressurized IA to 1500 psi with a small amount of diesel. p 15 min reading: 1040 psi. Re-pressurized IA to 1500 psi with a small amount of diesel. 15 min reading: 1180 psi. Re-pressurized IA to 1500 psi with a small amount of diesel. 15 min reading: 1290 psi. Re-pressurized IA to 1500 psi with a small amount of diesel. 15 min reading: 1330 psi. Re-pressurized IA to 1500 psi with a small amount of diesel. 15 min reading: 1340 psi. Re-pressurized IA to 1500 psi with a small amount of diesel. • 15 min reading: 1350 psi. Bled IA down to 1000 psi in 10 sec. Final T/I/O=0/1000/0+. 8/1/2016 PUMPED 10 BBLS FW SPACER AND 63 BBLS OF 15.7 PPG AS-1 CEMENT DOWN TUBING TAKING RETURNS FROM IA UNTIL GOOD CEMENT CONFIRMED AT SURFACE. PUMPED 10 BBLS OF 15.7 PPG AS-1 CEMENT AND 6 BBLS AS-1 CEMENT WITH 1 PPB CEMNET DOWN OA. FLUSHED TREE VALVES WITH .5 BBL FW. • • 7/31/2016 MIRU. RIH WITH SCMT.TAG TD AT 1240'. PERFORM REPEAT PASS FROM TD TO 900'AT 30 FPM. PERFORM MAIN PASS FROM TD TO 600'AT 30 FPM. FIELD PICK TOP OF CEMENT AT 1080. POOH. RIH WITH 4' PUNCHER WITH SMALL CHARGES. MISRUN WITH PUNCHER. POOH. RIH WITH ANOTHER 4' PUNCHER WITH SMALL CHARGES. PUNCH HOLES FROM 1056'- 1060'. CIRCULATE DIESEL DOWN TUBING TO IA THORUGH 7/30/2016 (MISC) : Bled T, IA&OA to 0 psi, Removed IA&OA Companion Bull Plugs &VR Plug, Installed Purge Jewelry. Initial =si5/0+/40. Bled T to 0 psi in 10 sec(gas) & held on open bleed. Bled IA to 0 psi in 5 min (gas) & held on open bleed. Bled OA to 0+ psi in 1 hour(gas) & held on open bleed. Pulled IA companion 2" bull plug&VR plug, installed 2" bushing& 1/2" ball valve. Pulled OA companion 2" bull plug, installed 2" bushing& 1/2" ball valve. Normaled up wellhead. Final T/I/0=si0/0/0+. 7/28/2016 STATE WITNESSED (BOB NOBLE);TAG TOC @ 1252' RKB; MITT& MITIA TO 1650 PSI ***PASS***; DDT TBG & IA***PASS***. READY FOR E-LINE. RU LRS TO TREE CAP TO PERFORM MITT STATE WITNESSED, INITIAL T/IA/OA= 160/125/40 STARTING = 1650/125/40, 1/10 BBL TO PSI UP, 15 MIN = 1560/125/40 30 MIN = 1525/125/40 ***PASS*** BLEED TBG TO 0 PSI START DDT, RU LRS TO IA,STARTING =0/125/40 15 MIN =38/125/40 30 MIN = 38/125/40 MITIA STATE WITNESSED, INITIAL T/IA/OA=38/125/40 STARTING =200/1650/45, 1.2 BBLS TO PSI UP 15 MIN = 220/1490/45 BUMP BACK UP STARTING =260/1680/45 15 MIN = 260/1625/45 30 MIN = 7/27/2016 Notify State of opportunity to witness cement plug tag,State man Bob Noble said they want to witness. 7/27/2016 TAG TOP OF CEMENT @ 1224' SLM. IN PROGRESS. 7/24/2016 Pumped fullbore cement plug. Circulated 40 bbls 9.6# NaCI brine, 231 bbls 15.8 Class "G" cement, 5"foam ball, and 13 bbls 9.6# brine down tubing, up IA to tank.Will be ready to tag 7/26. KUP OD 2K-17 Cono oPhillips Well Attrib Max Ang MD TD a Alaska Ins. Wellbore APVUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) S:ar,,,x4 1iNTa- 501032012100 KUPARUK RIVER UNIT PROD 55.61 3,925.00 9,145.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 2K-17,8/30120167.44.38 AM SSSV:TRDP Last WO. 40.09 11/22/1989 Vertical schemanc(ectual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,710.0 10/4/2010 Rev Reason:P&A WELL,WELDED MARKER pproven 8/24/2016 • . ;x . PLATE ON Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 46.0 115.0 115.0 62.50 H-40 WELDED A/�CONDUCTOR;46.0.115.0 . '4 p Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len IL..Grade Top Thread SURFACE 95/8 8.921 46.0 3,563.1 2,950.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)... WtLen(I...Grade Top Thread ';:7-4•:, gg PRODUCTION 7 6.276 46.0 9.133.0 6,396.2 26.00 J-55 BTC SAFETY VLV;1,788.7 � It Tubing Strings TubingDescription String Ma...ID TopftKB Set Depth B..I Set Depth TVD Wt Ib/ft Grade TopConnection P 9 lin/ I 1 P 1 P ( 11��� 1 1 TUBING 31/2 2.992 46.0 8,704.7 6,116.2 9.30 J-55 EUE-MOD Completion Details GAS LIFT;2,511.2 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 1,788.7 1,759.4 29.55 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 1 8,642.9 6,076.2 49.81 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 8,656.6 6,085.1 49.68 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8,692.7 6,108 4 49.53 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 8,704.0 6,115.7 49.49 SOS BAKER SHEAR OUT SUB 2.992 SURFACE;46.0-3,563.1-.1 p 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) g Top(TVD) Top Incl GAS LIFT,5,188.0 }1 G,5 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) &°z 8,082.0 5,715.8 49.97 TUBING TUBING PUNCH FROM 8082-8087'. 3/24/2016 PUNCH 8,097.0 5,725.5 49.49 FISH LOST 33.4'SLICKLINE TOOLSTRING w/1-3/8" 10/4/2010 0.000 GAS LIFT;6,729.7 FISH NECK(ROPE SOCKET)@ 7535'RKB OR @ C'> 8710'TOC Perforations&Slots GAS LIFT;7,567.5 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(MB) (ftKB) (RKB) Zone Date ft) Type Com 8,762.0 8,772.0 6,153.5 6,160.0 C-4,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5" HC Gun GAS LIFT;8,066.9 @ 8,838.0 8,854.0 6,203.2 6,213.6 A-5,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5" • HC Gun • 8,882.0 8,920.0 6,232.0 6,256.8 A-4,2K-17 4/21/1990 4.0 IPERF 180 deg.Phasing,4.5" HSC Cement Squeezes TUBING PUNCH;8,082.0 Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 8,710.0 9,145.0 6,119.7 6,404.0 Cement Plug 9/30/2010 CEMENT PLUG SET PRE CTD WORK 46.0 8,705.0 46.0 6,116.4 Display Cement 8/1/2016 AS-1 15.7ppg cement. Pumped 63 bbls cement. FISH;8,097.0 Fill TOC-46'RKB 46.0 8,710.0 46.0 6,119.7 Surface Casing 8/1/2016 AS-1 15.7 ppg cement Cement TOC-46'RKB Mandrel Inserts g St 1on GAS LIFT,8,598.2 ati kS Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,511.2 2,319.6 MERLA TMPD 1 GAS LIFT GLV BK 0.125 1,327.0 8/23/2002 2 5,168.0 3,896.6'MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,350.0 8/23/2002 +; 3 6,729.7 4,851.0-MERLA TMPD 1 GAS LIFT 'GLV BK 0.188 1,371.0 8/23/2002 PBR;8,642.9 :II 4 7,567.5 5,384.1 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,355.0 8/23/2002 lIV:!!' 5 8,066.9 5,706.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.156 0.0 8/23/2002 PACKER 8,856.6 6T 8,598.2 6,047.5 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 `' Notes:General&Safety I., '4.i,v1:;:: End Date Annotation � iNIPPLE;8,692.7 :,:i;0 4r, 9/30/2010 NOTE:CEMENT PLUG SET PRE CTD WORK;ALL PERFS COVERED 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 8/23/2016 NOTE:WELDED MARKER PLATE ON OVER CASING STUB,REMOVED.STAIRS AND SHORING BOX, SOS;8,704.0 BACKFILLED EXCAVATION .a Display cement Fill:46.0 ftKB h. Surface Casing Cement 46.0 \,;', ftKB (PERF;8,762.0.8,772.0- n IPERF,8,838.0-8.854.0-- -.4111r41i (PERF,8,8820-8,920.0--. I" PRODUCTION;46.0-9,1330 Cement Plug,8,710.0 ftKB • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission t �� TO: Jim Regg � �� Z DATE: 8/22/16 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector KRU 2K-17 ConocoPhillips Alaska PTD 1891190 8/22/16: I traveled to ConocoPhillips Alaska's KRU 2K-17 well to inspect an abandonment cut- off. On arrival I met with the ConocoPhillips Representative Rodger Winters. We looked at the well and the pipe sizes were 20", 9 5/8", 7", and 2 7/8". All strings were found to have good hard cement in them. The well was cut off 3.5 feet below tundra level. I then inspected the marker plate; it is '/-inch and sized to the outer most string of pipe. The marker plate had the proper information on it (Oil company name, Well name, PTD number, and API number). Attachments: Photos (2) SCANNED MAY 0 12017 2016-0822 Surface Abandon KRU 2K-17 bn.docx Page 1 of 2 • • Surface Abandonment— KRU 2K-17 (PTD 1891190) Photos by AOGCC Inspector B. Noble 7/13/2016 • zr: 3 <y 's 4 >Y, 4'.4 , ^ti t fie � , � ,.;,,tio,.:.01.,„,::,,..„.itiet.:4?..,,, ,,..,f7, ..:, .. . „.. . : . it.:.:g......,..-- .....„.....,-7:i...i.,..„,,,,;(:::::/z.....4...,,,,_ ,, . , - .. . .,,,„..:„....„. .2...,,,i .. ...., ',.I. -,.. . .,. .,....,, r a d ,: �-. 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Y Y Y Y Y V C N 1.11 - On O C K X cn O. w 0 O OO CO 0) cv I I 0 000000 ° �� ar 0 0 0 0 0 0 C u 0 0 0 o O o (c ill U c) U U U 0 E co N co co co NE 4 %Pw O - 0 0 0 0 o O U ro O O O co o coE Y r eN On OO OO 4 o Oro )n O CO a0 N u Q xt 0 CO 0 0 N N 0N M M 0 0 a+ _ N • p„ N (-4 NNNN — n - 0) 0) 0) 0) M M — p N N N N 0 0 L Q1 O O O O CO n- OO o O O O '- u0 O On in N N On N a+ O C. CO C _a 'O O C 07 C a) u U V N 00 Q QQQJJJ t w '^ E E 4 Z M N + 'ea ,ri 'a-)1a d Q N I , 1.1Jm W cs a N U £ Z cu O O T. V —, u b 2i c y E E • PTD 189 -/I`J' Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Friday,July 29,2016 9:14 AM To: Noble, Robert C (DOA); Loepp,Victoria T(DOA) Subject: FW: Please read Attachments: Plug Tag and Test, KRU, 2K-17.docx Follow Up Flag: Follow up Flag Status: Flagged Re: KRU 2K-17 (PTD 1891190)tag and test; I would not accept the tag; pressure tests are marginal at best for an abandonment plug. This is a recurring problem we encounter with operators trying to assess the competence of a plug with a bailer on slickline. They have not demonstrated a competent plug; should bail or get service coil on the well to wash down to solid cement.Then retest. What instructions did you leave them with? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 SCANSJAN 1s 4 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Noble, Robert C(DOA) Sent: Friday, July 29, 2016 8:31 AM To: Regg,James B(DOA) Subject: Please read Jim You might want to look at this as I was not happy with the MIT-IA part of this test. Follow up on the tire issue. Had Loraine call Peak to pay the bill.They said no charge.So I called Peak.The guy I talked to said Danny Kerns(Peaks top dog)said no charge. Danny Kerns and I have known each other for 30 years,so I figure he must have saw my name. I got hold of DOT this morning and they said I did the right thing. I told him about the issues with the studs and he said he was surprised that we were able to get 7 out of the 8 off. The Peak tire man was only able to put 7 out of the 8 nuts back on as one stud was missing a bunch of the treads from taking the nut off. He also said he thinks that all the studs need replaced. I told DOT this and going to take it over shortly. Bob Noble AOGCC 333 W.7th Ave.Ste. 100 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 7/28/16 P. I. Supervisor FROM: Bob Noble SUBJECT: Plug Tag and Test Petroleum Inspector KRU, 2K-17 ConocoPhillips Alaska PTD 189-119 7/28/16: I traveled to CPA, KRU, 2K-17 well site to witness a plug tag and test on their well. On arrival I met with CPA Rep. Eddie Zumba and we went over the procedure they were going to use to tag and test the well. They had pumped 231 bbls of 15.8 ppg class G cement. Slickline was rigged up and a bailer was run in the hole. TOC was found at 1252 RKB. The bailer was pulled out of the hold and it was full of what looked to be contaminated cement that was the consistency of modeling clay. Slickline was then rigged off the well. A MIT-T was then performed with the following results. Pretest: T/I/0=160/125/40 Initial: T/I/0=1650/125/40 15 min: T/I/0=1560/125/40 30 min: T/I/0=1525/125/40 A MIT-IA was performed with the following results. Pretest: T/I/0=38/125/40 Initial: T/I/0=200/1650/45 15 min: T/I/0=220/1490/45 160 psi was lost in the first 15 min so I ask them to bump the pressure back up and start the MIT-IA over. Pretest: T/I/0=220/1490/45 Initial: T/I/0=260/1680/45 15 min: T/I/0=260/1625/45 30 min: T/I/0=260/1570/45 45 min: T/I/0=260/1525/45 60 min: T/I/0=260/1510/45 [File name] Page 1 of 2 •SOF T4, • �jsTHE STATE Alaska Oil and Gas �� o fI�AS�<eA Conservation Commission ___- 1� z_-- 333 West Seventh Avenue ^h, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O4t'ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer ���� ConocoPhillips Alaska, Inc. ' FEB 0 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-17 Permit to Drill Number: 189-119 Sundry Number: 316-341 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, Daniel T. Seamount Commissioner DATED this IZ day of July, 2016. RBDMS L'- JUL 1 4 2016 ECE1VED • STATE OF ALASKA • JUN 2 2 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon F ' Plug Perforations 1- Fracture Stimulate 1- Repair Well 1- Operations Shutdown Suspend E Perforate I T Other Stimulate r Pull Tubing I Change Approved Program I Plug for Redrill I.— Perforate New Pool IT Re-enter Susp Well IT Alter Casing 1- Other: Plug&Abandon F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. ` Exploratory IT Development F• 189-119 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic T Service h 50-103-20121-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes I` No I✓ / KRU 2K-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 • 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): 9,145' 6,404' - 8710 . •6120 0 8710 8097 Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3,528' 9 5/8 3,563' 2,951' Production 9,100' 7" 9,133' 6,396' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8762-8772,8838-8854,8882- 6153-6160,6203-6214,6232- 3.500" J-55 8,705' 8920 ' 6257 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER HB RETRIEVABLE PACKER ' MD=8657 TVD=6085 SAFETY VLV-CAMCO TRDP-IA-SSA SAFETY VALVE - MD=1789 TVD=1759 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory I-- Stratigraphic T Development F• Service 14.Estimated Date for 7/15/2016 15.Well Status after proposed work: Commencing Operations: OIL T WINJ I- WDSPL IT Suspended T 16.Verbal Approval: Date: GAS I WAG 1.-- GSTOR IT SPLUG 1- Com m issi on - Commission Representative: GINJ T Op Shutdown r Abandoned • 1 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 JilI.Simekaconocophillips.com ::::::ame Jill Sim k ---, Title Staff Well Integrity Engineer Phone 263-4131 W COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity V BOP Test ❑ Mechanical Integrity Test 0 Location Clearance Other: VcPost Initial Injection MIT Req'd? Yes 0 No RBDMS " 4 201u Spacing Exception Required? Yes ❑ No fd Subsequent Form Required: /b —¢t 7 APPROVED BY �'J_`� Approved by: ACOMMISSIONER THE COMMISSION Date: G.- -(' For in-an uo,,,S a,•((01s O R 1,64d Ii ids is valid for 12 months from the date of a rov . Sibs in DuplicateGorrli pre `�j\'�wJ/itt n 4i / '\\VA ^ 4146 4`�9/4 �6 P /1 V l i Alb chments in I • * ConocoPhillips RECEIVED Alaska P.O. BOX 100360 JUN 2 2 2016 ANCHORAGE,ALASKA 99510-0360 OGC 16 June 2016 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to Plug and Abandon Kuparuk Producer 2K-17(PTD#: 189-119). 2K-17 was originally drilled and completed in 1989 as a 3- 1/2"single producer. In January 2010,the well was shut-in due to subsidence induced integrity issues. In September 2010,the well was suspended by pumping 24 bbl of cement across the perforations. When attempting to tag Top of Cement,an obstruction was encountered at 7,568'KB and then the tool string hung ? up on the Subsurface Safety Valve(SSSV)flapper on the way out of the hole. Wire above the ropesocket i' was cut and 33.4' of toolstring was left downhole. A tubing caliper log performed June 16,2010 showed buckling at approximately 700' -720'KB and a 2.70"restriction at 716'KB. On July 30,2015,a variety of drifts were made past the 716'KB restriction to determine perforating/puncher options to establish a deep circulating point for additional cementing operations. On March 24,2016,the lost toolstring from 2010 operations was tagged at 8,097'KB and the tubing was punched at 8,082-8,087'KB. Evaluations conducted indicate the wellbore does not have any remaining utility for the Kuparuk River Unit. Additionally,the observed subsidence induced buckling demonstrates an increased risk for additional loss of barriloss o we bore access as time progresses. By progressinga well to P&A a lower it-17 s no - n e i- ion is posse I e. The well has 9-5/8"surface casing to 3563.1'KB and 7"production casing to 9,133.0'KB. There is 3-1/2" tubing with a packer at 8,656.6'KB. Three sets of Kuparuk perforations are isolated from the wellbore with 15.8 ppg Class"G"cement. Per this procedure,P&A operations will be performed by pumping 231 bbls of Class"G"cement from 8,087'KB to 1,500'KB in the tubing and tubing x production casing annulus(IA). Tubing will then be punched above Top of Cement(1,500'KB)and 72.5 bbls of ArcticSet* 1 will be pumped fullbore,to bring cement to surface in the tubing and IA. A cement downsqueeze will follow to place approximately 270 linear feet of cement in in the surface casing x production 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. V If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek Well Integrity Engineer CPAI Drilling and Wells CO/CLf• • • ConocoPh i l l i ps 2K-17 P&A Permit to Drill #: 189-119 The objective of the proposed 2K-17 P&A is to pump 231 bbls of Class "G" cement from 8,087' KB to 1,500' KB in the tubing and tubing x production casing annulus (IA). Tubing will then be punched above Top of Cement (-1,500' KB) and 72.5 bbls of ArcticSet* 1 will be pumped fullbore, to bring cement to surface in the tubing and IA. A cement downsqueeze will follow to place approximately 270 linear feet of cement in in the surface casing x production casing annulus (OA). Surface excavation for removal of wellhead and final P&A operations will follow. Proposed P&A: Schlumberger Cementing: Objective: Plug #1 - Fill the wellbore with cement from tubing punch depth (8,087' KB) to approximately 1,500' KB. We will be circulating cement down the 31/2" tubing and up the 31/2" x 7" annulus. Cement Volume Calculations (TOC -1,500' KB in tubing and annulus): • Tubing: (0.00869627 bbl/ft) * (8,087' KB- 1,500' KB) = 57.3 bbl • 3 '/2" x 7"Annulus: (0.0263627 bbl/ft) * (8,087' KB- 1,500' KB) = 173.7 bbl • Total volume = 57.3 + 173.7 bbl = 231 bbl • Displacement volume = 1,500' KB * (0.00869627 bbl/ft) - 10 bbl spacer = 13.0- 10 = 3.0 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. Ensure a 5"foam ball is loaded into the tree prior to the cement job. 3. MIRU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. 4. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3'/2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 5. PT surface equipment as required 6. Establish circulation. Pump 10 bbls brine spacer. 7. Pump 231 bbls of 15.8 ppg Class "G" Cement 8. Drop 5" Foam Ball 9. Pump 10 bbls brine spacer. 10. Displace with 3 bbis diesel to leave Top of Cement in tubing and IA at 1,500' KB. 11. Shut down SLB pumps and close in Tubing and IA. Do not overdisplace. 12. Wash up SLB cement pumps and clean up surface lines. 13. RDMO JS Slickline/ Little Red 1/J` Objective: Tag TOC, MIT-T & MIT-IA, DDT 1. WOC for 48 hr or until field blend UCA ch shows cement developed 1,000 psi compressive strength. Notify the AO CC Inspector of the timing of the cement plug tag and pressure testing. TAG MUST BE AOGCC WITNESSED. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU SL and PT Equipment as required. 4. RIH and tag TOC @ approximately 1,500' KB. IF TOC IS BELOW SSSV (1,789' KB). DO NOT TAG. Record results and report tag depth to Well Integrity Engineer. 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record results. 7. Perform MIT-IA to 1,500 psi. Record results. 8. Perform DDT on Tubing and IA. Record results. 9. Report issues & results to Well Integrity Engineer. 10. RDMO E-line/ Little Red Objective: Punch 31/2" tubing 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 a-line and PT Equipment as required. 3. RIH with 2" x 4' tubing punch. 4. Punch 30' above TOC, as close to mid joint as possible. If TOC was not tagged (ie. TOC is below SSSV), punch at 1,710'. 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 Schlumberger Cementing: Objective: Plug 2 - Place a cement plug from 1,500' KB to surface. We will be circulating cement down the 3'/2" tubing and up the 31/2" x 7" annulus. Cement Volume Calculations (TOC at surface): • Tubing: (0.00869627 bbl/ft) * (1,500' KB) = 13.0 bbl • 3-1/2" x 7"Annulus: (0.0263627 bbl/ft) * (1,500' KB) = 39.5 bbl JS • • • Excess: 20 bbl • Total volume = 13.0 + 39.5 + 20 = 72.5 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU SLB Cement Equipment, ensuring that hardline is rigged up to pump down the tubing and take returns to a tank from the 3'/2" x 7" annulus. 3. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen at surface. 4. PT surface equipment as required. 5. Pump 10 bbls fresh water spacer. 6. Pump 72.5 bbls of 15.7 ppg ARCTICSET* 1 (AS1) Cement. a. This calculation assumes 20 bbl of excess cement to ensure good cement to surface. 7. Monitor returns on surface, taking samples and checking pH/density. 8. Once good cement returns are verified on surface (use mud scale for cement density measurement), shut down and open up the surface bypass line to flush all lines with water. 9. Wash up SLB cement pumps. 10. RDMO Schlumberger Cementing: Objective: Plug 3 — Downsqueeze 7" x 9-5/8" Annulus (OA) from surface to approximately 270' KB. Cement Volume Calculations (TOC at surface): • 7" x 9-5/8" Annulus: (0.0297103 bbl/ft) * (270' KB) = 8.0 bbls • Excess: 8.0 bbl • Total volume = 8.0 + 8.0 = 16.0 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. Pressure test SLB lines 3. Line up down surface casing 4. Pump 5 bbl of water as spacer ahead at 5 bpm 5. Pump 16 bbl of ArcticSet* 1 (AS1) at 2 bpm a. 5 bbl of neat AS1* b. 6 bbl of AS1*with 1 ppb CemNET* i. Confirm minimum restrictions if CemNET* is used c. 5 bbl of neat AS1* d. Slow rate to 1 bpm for last 2 barrels e. If well locks up while pumping cement, go to step 6 6. Line up to open top 7. Pump 5 bbl of water to clear SLB lines at 5 bpm JS e e 8. Line up down surface casing 9. Pump wellhead volume at 0.5 bpm (count pump strokes) a. Wellhead volume needs to be calculated before job and agreed upon with co-rep and SLB field personnel Little Red: Objective: MIT-T, MIT-IA, & MIT-OA, DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,000 psi compressive strength. 2. RU LRS and PT equipment. 3. MIT-T with Diesel to 1,500 psi. Record results. 4. MIT-IA with Diesel to 1,500 psi. Record results. 5. MIT-OA with Diesel to 1,500 psi. Record results. 6. 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 production 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. 2,4 11,1 vto f k c c fi0 r.. , 6. Perform "pp Job and verify that cement is at surface in all strings. AOGCC witnessnd photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld 1/4"thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2K-17 PTD# 189-119 API # 50-103-20121-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work i,---- is 0is completed. / JS • p�� KUP WE) 2K-17 t:onocbPhdlips - Wets Well Attribu Max Angl D TD • Alaska,Inc, z) Wellbore API/UWI Fold Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) i11,,; 501032012100 KUPARUK RIVER UNIT PROD 55.61 3,925.00 9,145.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 2K-17,6(21/20163.18;34 PM SSSV:TRDP Last WO: 40.09 11/22/1989 Verona(schematic(admen Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,710.0 10/4/2010 Rev Reason:FISH DEPTH CORRECTION lehallf 6/21/2016 1' l� 0 Casing StringsHANGER.31 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I SURFACE 9 5/8 8.921 35.0 3,563.1 2,950.6 36 00 J-55 BTC """"'""'"""":"7::15.0,1 , ur,` ` a , "noun. "'1 I 1 in Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread vu e PRODUCTION 7 6.276 33.0 9.133.0 6,396 2 26.00 J-55 BTC I .Tubing Strings TO;38.0.115.O�e/ „/e.�Tubing Description String Ma...I ID(in) I Top(ftKB) Set Depth(ft..1 Set.Depth(TVD)(...I Wt(Ib/ft) I Grade I Top Connection TUBING 31/2 2.992 31 1 8,7047 6,1162 9.30 J-56 EUE-MOD Completion Details itNominal ID - Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SAFETY VLV;1,788.7 ' '`;. 31.1 31.1 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 1,788.7 1,759.4 29.55 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 8,642.9 6,076.2 49.81 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 GAS LIFT;2,511.2 - 8,656.6 6,085.1 49.68 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8,692.7 6,108.4 49.53 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 • I 8,704.0 6,115.7 49.49 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Mel Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,082.0 5,715.8 49.97 TUBING TUBING PUNCH FROM 8082-8087'. 3/24/2016 SURFACE,350-3,563.1 PUNCH 8,097.0 5,725.5 49.49 FISH 'LOST 33.4'SLICKLINE TOOLSTRING w/1-3/8" 10/4/2010 0.000 FISH NECK(ROPE SOCKET)@ 7535'RKB OR @ GAS LIFT;5,168.0 t 8710'TOC Perforations&Slots GAS LIFT;8,728.7 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (RKB) (RKB) Zone Date ft) Type Com 8,762.0 8,772.0 6,153.5 6,160.0 C-4,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5" GAS LIFT;7,567.5. HC Gun 8,838.0 8,854.0 6,203.2 6,213.6 A-5,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5" 9 HC Gun 8,882.0 8,920.0 6,232.0 6,256.8 A-4,2K-17 4/21/1990 4.0 IPERF 180 deg.Phasing,4.5" HSC GAS LIFT;8,0669 c_:: Cement Squeezes Top(TVD) Btm(TVD) Top(RKB) Btm(ftKB)I (ftKB) (ftKB) Des Start Date Com 8,710.0 9,145.0 6,119.7 6,404.0 Cement Plug 9/30/2010 CEMENT PLUG SET PRE CTD WORK Mandrel Inserts TUBING PUNCH,8,082.0 1 St tk ati N Top(TVG) Valve Latch Port Size TRO Run _ Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date Com FISH,8,0970 1 2,511.2 2,319.6 MERLA TMPD 1 GAS LIFT GLV BK 0.125 1,327.0 8/23/2002 2 5,168.0 3,896.6 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,350.0 8/23/2002 3 6,729.7 4,851.0 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,371.0 8/23/2002 4 7,567.5 5,384.1 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,355.0 8/23/2002 5 8,066.9 5,706.2 CAMCO MMG-2 1 1/2 GAS UFT OV RK 0.156 0.0 8/23/2002 GAS I.AT 8598.2 6 8,598.2 6,047.5 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 7.!.: Notes:General&Safety End Date Annotation 9/30/2010 NOTE:CEMENT PLUG SET PRE CTD WORK;ALL PERFS COVERED d. 11/3/2010 'NOTE:View Schematic w/Alaska Schematic9.0 PBR;8,642.9 ila x=j PACKER;8,856.8 NIPPLE;8,692.7 SOS;8,704.0 kyr i IPERF;8,762.0-8,772 0-. IPERF;8,838.0-8,854.0 IPERF;8,882 0-8,920 0-. PRODUCTION;33.0-9,133.0 .' • • .. P&A Diagram: 2K-17 Plug & Abandonment PTD#: 189-119 < t1\ III Current Completion Proposed P&A QJ ` ::„: Third Pl g(OA)270'KB-Surface 016"62.5#H-40 Conductor @ 115'KBF. .. 15.7 ppg Ard)cSet 1 00/7 '',#/$47" Second Plug a&IA)1,500'KB-Surface 15.7 ppg ArcticSet 1 c.:i®-:_a First Plug(T&IA)8,08T-1.500'KB 15.8 ppg Class"G <Vie e (14/74 4,„,'," A 9 5/8"36#J-55 Surface Casing @ 3.563_1°KBy7,/,,o #41 "." / /1":„:7 '1'. 1040 0,,,,,:,„ GLM: sty @ 5,168.O'KB ,,�'. ALV CO 6,729.T KB �GLYG7.567.8'KB aV@8,066.9'KB .w.,,, ,,i.,70.,/,,,,,,,,:'.1/:,.//e9;4.:1 t7MY G 8.5982 KB :,,,,,,,././1,,,,,, 7,,,,„ ,,,,„:,„, . ,, ,,,,,,,./,7,, .,..„.„,,,,,,,,, a 4, Tubing punch: &.082'-8,0&T KB —� '`G , _ l �� FISH @ 8,09T KB �'i ��� Batter H8 Relnevvabie Packer @ 8,656.6'KB a` �W(r, cj PS i Oils z.al3'XN 1111 / 1o,3�Zc�1Q Nipple wi2.75"NO-GO C 8,692_T KB ii�4 1 c) 3-1,,9.3#J-55 Tubing 8.704.7"KB TOC @ 8,710'KB(estmated) iVi' ," "I ✓ ,f��.,',!.,: Pads: -..,mac r`" »� ."'`` 1 &,762.0-8.772-0'KB • -� _.-,--'',/,/;,,,,,,,,,,1 �^ .� 8,838.0-8,854.0'KB _....�,, - :: 8,882_0-8,920 0'KB -u+c A�'r"0' .. T 26#G80 Production Casing g @ 9.133-0'KB / .__ JS 6-9-2016 JS STATE OF ALASKA ' AlikA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations I.... Fracture Stimulate ...... Pull Tubing Operations Shutdown r Performed: Suspend I I Perforate I Other Stimulate i..... Alter Casing I Change Approved Program E Plug for Redrill F Perforate New Pool r_. Repair Well E Re-enter Susp Well F Other:Tubing Punch s 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fe- Exploratory 189-119 3.Address: 6.API Number: Stratigraphic '1 Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20121-00 7.Property Designation(Lease Number): 8.Well Name and Number: AD;25588 KRU 2K-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9145 feet Plugs(measured) None true vertical 6404 feet Junk(measured) 8680 Effective Depth measured 8710 feet Packer(measured) 8657 true vertical 6120 feet (true vertical) 6085 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3528 9 5/8 3563 2951 PRODUCTION 9100 7 9133 6396 RECEIVED Perforation depth: Measured depth: 8762-8772, 8838-8854,8882-8920 MAY 0 5 2016 True Vertical Depth: 6153-6160,6203-6214, 6232-6256 Tubing Punch Depth: 8082-8087 MD /�,OGy C 5716-5719 TVD /�V v� Tubing(size,grade, MD,and TVD) 3.5,J-55,8704 MD,6116 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HB RETRIEVABLE PACKER @ 8657 MD and 6085 TVD SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE @ 1789 MD and 1759 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: SCANNED JUN 2 4 20 J6 13. Representative Daily Average Production or Injection Data U Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Suspended Subsequent to operation Suspended 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations f'‘; Exploratory I— Development iv. Service Stratigraphic 1— Copies of Logs and Surveys Run r 16.Well Status after work: Oil Gas I WDSPL F Printed and Electronic Fracture Stimulation Data 1...... GSTOR TI WINJ .... WAG I GINJ i SUSP iv SPLUG j...... 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: 316-176 Contact Jill Simek ( 263-4131 Email JiII.Simek(a�conocophillips.com Printed Name Jill Simek Title Staff Well Integrity Engineer Signature n — Phone:263-4131 Date Form 10-404 evised 5/2015 L �� � 0 6 2016 Submit Original Only ✓ 5/9/ RDDMS 0t, �.tiv • • • 2K-17 Daily Operations Start Date Last 24hr Summary 4/16 (MON) T/I/O = 40/310/50 lift gas line and flowline disconnected, no panel T FL @ 432'. IA FL @ 1740'. OA FL @ 144' 3/24 TUBING PUNCH FROM 8082'-8087'. TAG WITH TUBING PUNCH AT 8097' SHOOT TUBING PUNCH WITH TOP SHOT AT 8082' CCL TO TOP SHOT 4' CCL STOP AT 8078'. TIED INTO TUBING TALLY. LRS ABLE TO PUMP 2.0 BPM AT 500 PSI DOWN TUBING WITH JUMPER RIGGED UP TO 2K-16 FLOW LINE. ABLE TO WORK THROUGH SSSV PUMPING AT 5 BPM AFTER MULTIPAL ATTEMPTS AT LOWER RATES AND AT 5 BPM. LRS SHOWED 450 PSI AT 5 BPM. LRS ATTEMPTED CMIT. PUMPED 15 BBL DOWN TUBING AT .85 BPM T/IA PRESSURES DID NOT BUILD ABOVE 750/300 PSI. ,. KUP FOD 2K-17 Co ocoP iflips ,o' Well Attribu Max Angl D TD Alaska,If3{. Wellbore APVWellbore UWI Field Name eore Status Inc!(°) MD(ftKB) Act Btm(ftKB) co oco'tottt s `7� 501032012100 KUPARUK RIVER UNIT PROD 55.61 3,925.00 9,145.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-17,5/5201611:41.49 AM SSSV:TRDP Last WO: 40.09 11/22/1989 Verryral schemata(actual, Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,710.0 10/4/2010 Rev Reason:TUBING PUNCH pproven 3/26/2016 ■ a? Casing Strings HANGER;31.1 li.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread _ CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED �'^ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft(B) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1: SURFACE 95/8 8.921 35.0 3,563.1 2,950.6 36.00 J-55 BTC 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread = ' a ,ny PRODUCTION 7 6.276 33.0 9,133.0 6,396.2 26.00 J-55 BTC Tubing Strings ten.CONDUCTOR;36.0-115.0 Tubing Description 'String Ma...IID(in) 'Top(NOB) 1Set Depth(ft..Set Depth(ND)(...1Wt(Ib/ft !Grade Top Connection TUBING Completion Details31/22.99231.18,704.76,116.29.30J-55 EUE-MOD Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SAFETY VLV;1,788.7 31.1 31.1 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 1,788.7 1,759.4 29.55 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 8,642.9 6,076.2 49.81 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 GAS LIFT:2,511.2 - 8,656.6 6,0851 49.68 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8,692.7 6,108.4 49.53 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 • 8,704.0 6,115.7 49.49 SOS BAKER SHEAR OUT SUB 2.992 1 iii Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (%) Des Com Run Date ID(in) 8,082.0 5,715.8 49.97 TUBING TUBING PUNCH FROM 8082-8087'. 3/24/2016 SURFACE;35.03,563.1-1 I ` PUNCH 8,680.0 6,100.2 49.58 FISH LOST 33.4'SLICKLINE TOOLSTRING w/1-3/8" 10/4/2010 0.000 FISH NECK(ROPE SOCKET)@ 7535'RKB OR @ GAS LIFT;5,168.0 c- 8710'TOC Perforations&Slots Shot GAS LIFT,6,729.7 Dens Top(ND) Btm(TVD) (shoal Top(11601 Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8.762.0 8,772.0 6,153.5 6,160.0 C-4,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5" GAS LIFT;7,567.5 HC Gun 8.838.0 8,854.0' 6,203.2 6,213.6 A-5,2K-17 4/27/1997 6.0 (PERF Zero deg.Phasing,2.5" HC Gun 8,882.0 8,920.0 6,232.0 6,256.8 A-4,2K-17 4/21/1990 4.0 (PERF 180 deg.Phasing,4.5" HSC GAS LIFT;13066.8-11!! Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) )ftKB) (ftKB) Des Start Date Com 8,710.0 9,145.0 6119.7 6,404.0 Cement Plug 9/30/2010 CEMENT PLUG SET PRE CTD WORK a �u Mandrel Inserts TUBING PUNCH;8,082.0 0. St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (RKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com 1� 2,511.2 2,319.6 MERLA TMPD 1 GAS LIFT GLV BK 0.125 1,327.0 8/23/2002 2 5,168.0 3,896.6 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,350.0 8/23/2002 GAS LIFT,85982 3 6,729.7 4,851.0 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,371.0 8/23/2002 0.188 1,355.0 8/23/2002 4 7,567.5 5,384.1 MERLA TMPD 1 GAS LIFT GLV BK 5 8,066.9 5,706.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.156 0.0 8/23/2002 6 8,598.2 6,047.5 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 Notes:General&Safety FOR;6,642.9 End Date Annotation 9/30/2010 NOTE.CEMENT PLUG SET PRE CTD WORK;ALL PERFS COVERED PACKER.8,656.6 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 li NIPPLE;8,692.7 11W FISH;8,680.0 SOS;8,704.0 IJ[tJI,, 1111 I NOV IPERF,8.762.0-8,1720- . IPERF;8,838.0-8,854.0 . IPERF,6882.0-8,920.0 • "` PRODUCTION,33.0-9,1330 RECEIVED 2.1% 21 MAY 0 6 20L4' WELL LOG TRANSMITTAL#903201990 AOGC( To: Alaska Oil and Gas Conservation Comm. May 4, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 5nzr2oi� iai. K.BENDER SCANNED RE: Tubing Punch Record: 2K-17 Run Date: 3/24/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2K-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20121-00 Tubing Punch Record(Field Print) 1 color log 50-103-20121-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ /, „ ` V OF Tji� • • A THE STATE Alaska Oil and Gas 1, ,;-s=� � ofA A C ` eConservation Commission -------- t# 333 West Seventh Avenue " 11 C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'ALA Y'P' Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity EngineerS t ,P ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2K-17 Permit to Drill Number: 189-119 Sundry Number: 316-176 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, Cathy P Foerster Chair DATED this 414-d-ay of March,2016. RBDMS l.t Ma.R 1 0 2016 i It Ea. STATE OF ALASKA AltA OIL AND GAS CONSERVATION COM ION 1',1;',:R. 0 J c .i APPLICATION FOR SUNDRY APPROVALS 07". �-3/ 9 /(,..20 AAC 25.280 1.Type of Request: Abandon fa Plug Perforations f" Fracture Stimulate r Repair Well I— Operations Shutdown Suspend Perforate r Other Stimulate c" Pull Tubing r Change Approved Program Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: Tubing Punch F* 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory [ Development F 189-119' 3.Address: • 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic E Service 50-103-20121-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a / Will planned perforations require a spacing exception? Yes No F J KRU 2K-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 P Field/Kuparuk Kuparuk River Field/Ku aruk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 9,145' 6,404' 8710 6120 0 None 8680 Casing Length Size MD TVD Burst Collapse Structural . Conductor 79' 16" 115' 115' Surface 3,528' 9 5/8' 3,563' 2,950' Intermediate Production 9,100' 7" 9,133' 6,396' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8762'-8920' • 6154'-6257' 3.500" J-55 8,704' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER HB RETRIEVABLE PACKER • MD=8657 TVD=6085 SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE • MD=1789 ND=1759 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory - Stratigraphic fl Development F. Service fl 14.Estimated Date for 3/10/2016 15.Well Status after proposed work: Commencing Operations: OIL F • WINJ E WDSPL fl Suspended 16.Verbal Approval: Date: GAS fl WAG E GSTOR E SPLUG Commission Representative: GINJ E Op Shutdown I— Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jill Simek Email Jill.Simek@conocophillips.com Printed Name Jill Simek •263-4131 Title Staff Well Integrity Engineer Signature � Phone Date 3/4/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `U... `. i to Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No lE Spacing Exception Required? Yes ❑ No 2/. Subsequent Form Required: /D — 4 O RBDMS LL M'9 1 0 2016 APPROVED BY ? Approved Fo: ; firci,GliNiMir oOI�F2R TI jL CaleMhSSION Date: J�� orm and Form 10-403--vised 11/2015 for months f r�onL e a eoT apprOV81. AttarhmPnfc in n„pIira4P TL 3/9//(o -A141 3/1/K• ,d -3/ie . • • ConocoPhillips 2K-17 Tubing Punch Permit to Drill #: 189-119 2K-17 is being evaluated for potential Slot Recovery Plug and Abandonment. This procedure will include steps to tag the fish and perform a tubing punch to establish a circulation point for future fluids and/or cement placement. Depending on results of the tag and puncher operations, a separate sundry application will be made for the plug and abandonment process. Procedure: Eline / Little Red: Objective: Tubing punch; pump diesel to confirm circulation; CMIT-TxIA. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Eline and PT Equipment as required. 3. RIH with 1.69" x 4' tubing punch, 4spf. Ensure Maximum Rigid Length for complete toolstring is less than 10ft. 4. Punch at approximately 8,630' KB (- middle of tubing joint above PBR) or, if unable to reach 8,630' KB, punch at deepest point reached. 5. Pump diesel down tubing, taking returns to IA, to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 6. Perform CMIT TxIA to 1,500 psi. Record initial, 15 min, 30 min TIO pressures. Report issues & results to Well Integrity Engineer. 7. RDMO JS KUP 1110D 2K-17 ConocoPhithhps = Well Attribu Max Angle D TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) c 0(4,,4 , 501032012100 KUPARUK RIVER UNIT PROD 55.61 3,925 00 9,145.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-17.3/4/2016 11 01 20 AM SSSV:TRDP [Last WO. 40.09 11/22/1989 Vertical schema5c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,710.0 10/4/2010 Rev Reason:WELL REVIEW osborl 7/16/2012 Casing Strings HANGER,31.1ICasing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(...Grade Top Thread 111)1 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED �I � Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread SURFACE 9 5/8 8.921 35.0 3,563.1 2,950.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I_Grade Top Thread PRODUCTION 7 6.276 33.0 9,133.0 6.396.2 26.00 J-55 BTC Tubing Strings I� iii Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection _A-/s.CONDUCTOR;36.0-115.0• TUBING 3 1/2 2.992 31.1 8,704.7 6,116.2 9.30 J-55 EUE-MOD I•i I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SAFETY VLV;1,788.7 'a' 31.1 31.1 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 1,788.7 1,759.4 29.55 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 8,642.9 6,076.2 49.81 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 GAS LIFT;2,511.2 • .. 8,656.6 6,085.1 49.68 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8,692.7 6,108.4 49.53 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 8,704.0 6,115.7 49.49 SOS BAKER SHEAR OUT SUB 2.992 i 1 :1:, 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) 1 Top Incl Top(ftKB) (ftKB) I) Des Com Run Date ID(in) 8,680.0 6,100.2 49.58 FISH LOST 33.4'SLICKLINE TOOLSTRING w/1-3/8" 10/4/2010 0.000 FISH NECK(ROPE SOCKET)a@ 7535'RKB OR @ SURFACE;35 0-3,563.1- • 8710'TOC Perforations&Slots GAS UFT;5,168.0 - Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,762.0 8,772.0 6,153.5 6,160.0 C-4,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5" GAS LIFT;6,728.7 - HC Gun 8,838.0 8,854.0 6,203.2 6,213.6 A-5,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5" HC Gun GAS LIFT,7,5875 8,882.0 8,920.0 6,232.0 6,256.8 A-4,2K-17 4/21/1990 4.0 IPERF 180 deg.Phasing,4.5" HSC Cement Squeezes Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 8,710.0 9,145.0 6,119.7 6,404.0 Cement Plug 9/30/2010 CEMENT PLUG SET PRE CTD WORK GAS LIFT a ossa - Mandrel Inserts III St ati N Top(ND) Valve Latch Port Size TRO Run lop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,511.2 2,319.6 MERLA TMPD 1 GAS LIFT GLV BK 0.125 1,327.0 8/23/2002 2 5,168.0 3,896.6 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,350.0 8/23/2002 GAS LIFT;8,598.2 3 6,729.7 4,851.0 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,371.0 8/23/2002 4 7,567.5 5,384.1 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,355.0 8/23/2002 5 8,066.9 5,706.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.156 0.0 8/23/2002 6 8,598.2 6,047.5 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 Notes:General&Safety End Date Annotation PBR;8,6428 r 1m 9/30/2010 NOTE.CEMENT PLUG SET PRE CTD WORK;ALL PERFS COVERED PACKER;8,656.6 -' -' 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 .a r. NIPPLE,8,692.7 '�y�/Ir FISH;8,680.0 � � SOS;8,704.0 '"�" FfattAtA IPERF;8,762.0-8,772.0 e 4 IPERF;8,838.0-8,854.0 VW IPERF;8,882.0-8,920.0 PRODUCTION;33.0-9,133 0 ^^'^'0 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/08/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: 2K-17 Oper. Rep: Martin Walters PTD No.: 1891190 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: n18780conocophillips.com_ If Verified, How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 10/17/10 Date AOGCC Notified: 08/03/15 - Sundry No.: 310-301 Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing s/i Photos Taken? Yes IA 260 OA 41 Condition of Wellhead: good SCANNED SEP 0 6 2D16 Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: Missing well sign Comments: well was verified by pad well location map Attachments: 1 D'1V5 ( Z1 REVIEWED BY: /// Insp.Supry )`� 141616- Comm PLB 06/2014 2015-0808_Suspend_KRU_2K-17jh.xlsx • Suspended Well Inspection—KRU 2K-17 ' PTD 1891190 Photos by AOGCC Inspector J. Hill 8/8/2015 is k I ill " .:' <� f Arl g.;,..ter.. ___. s 17 • ,t � C \i\%� . , - IN 41 . ' , ,. _ , . , v : is w. . _•, ` ilia - i V l ,1 t f i.3,'ft , t - fir 't ' _- 1 +� • s 3 ' 1. si j! 2015-0808_Suspend_KRU_2K-17_photos jh.docx STATE OF ALASKA ALIC OIL AND GAS CONSERVATION CO • SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other StimulateAlter Casing9 Change Approved Program " Plug for Redrill r Perforate New Pool Repair Well r Re-enter Susp Well Other:Susp Well lnsp 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r 189-119 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20121-00 7.Property Designation(Lease Number):8.Well Name and Number: ADL0025588 KRU 2K-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool__ 11.Present Well Condition Summary: Total Depth measured 9145 feet Plugs(measured) None true vertical 6404 feet Junk(measured) None Effective Depth measured 8710 feet Packer(measured) 8657 true vertical 6120 feet true vertical) 6085 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 115 115 1640 630 SURFACE 3528 9-5/8" 3563 2950 3520 2020 PRODUCTION 9100 7 9133 6396 4980 4330 RECEIVED Perforation depth: Measured depth: 8762'-8920' 2015 AUG 2015 True Vertical Depth: 6154'-6257' sc 0~ OU AOGCCOGCC Tubing(size,grade,MD,and TVD)3.5, J-55, 8704 MD,6116 TVD Packers&SSSV(type,MD,and TVD) PACKER= BAKER HB RETRIEVABLE PACKER @ 8657 MD and 6085 TVD SSSV=CAMCO TRDP-1A-SSA SAFETY VALVE @ 1789 MD and 1759 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work:Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP 17 SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland/Martin Walters Email n1878@conocophillips.com Printed Name Martin Walters Title Well Integrity Supervisor Signature , G 2 77 kiajetteei Phone:659-7043 Date:Aug 7,2015 v71- 412/15 gig Form 10-404 Revised 5/2015 Sub It Original Only RBDM AUG 1 4 2015 1111PV RECEIVED ConocoPhillips AUG 12 Z015 Alaska P.O. BOX 100360 A CC ANCHORAGE,ALASKA 99510-0360 August 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 2K-17 (PTD 189-119) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2K-17 (PTD 189-119). The following documents are attached: 10-404 Sundry Suspended Well Check List Wellbore Schematic Location Plot Plan Photographs Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, 144,/7a1/ ifk; Martin Walters ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 2K-17 Field/Pool: KUPARUK RIVER Permit#(PTD): 189-119 Sundry 310-301 API Number: 50-103-20121-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 9/30/2010 Surface Location: 169' FNL, 94' FEL Section: 11 Township: 10N Range: 9E Nearest active pad or road: KRU DS2K Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: NA Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: No Access road condition:Good Photographs taken (#and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids:Good. Dry Rat Hole: NA Wellhouse or protective barriers: Removed for summer Well identification sign:Missing (attached to wellhouse) Tubing Pressure (or casing if no tubing): Shut In Annulus pressures: 260/41 Wellhead Photos taken (#and description): 2 of wellhead and cellar Work Required: Install identification sign on well Operator Rep (name and signature):Martin Walters 17a4-4/4.9/ AOGCC Inspector: Johnnie Hill Other Observers: Will Lomer Inspection Date: 8/7/2015 AOGCC Notice Date: 8/3/2015 Time of arrival: 10:00 AM Time of Departure: 10:10 AM Site access method: Passenger Truck p1.1 KUP 2K 17 COnOCor'hiilipS ""'I,. ,, Well Attributes Max An.le&MD TO Alaska,Inc,nc *, r:. a i Wellbore API/UWI Field Name Well Status all MD(ftKB) Act Btm(ftKB) a 501032012100 KUPARUK RIVER UNIT PROD 3,925.00 9,145.0GArocoPtullpsB Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:TR DP 50 1/17/2010 Last WO: 40.09 11/22/1989 Well Confm:-2K-17.7/16/20122:17:27 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last TagSLM 8,710.0 10/4/2010 Rev Reason'WELL REVIEW osborl 7/16/2012 Casing Strings I. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd HANGER,31 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 35.0 3,563.1 2,950.5 36.00 J-55 BTC t CasingDescription 0... StringID...TopftKB Set Depth f...Set Depth TVD...String Wt...StringStringTopThrdString1P ( P (TVD) PRODUCTION 7 6.276 33.0 9,133.0 6,396.2 26.00 J-55 BTC Tubing Strings1TubingDescription String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String... String Top Thrd CONDUCTOR, TUBING 31/2 2.992 31.1 8,704.7 61161 J 9.30 J-55 EUE-MOD 36-115 Completion Details Top Depth 1801 Top not Nomi... Top(ftKB) (ftKB) (^) kem Desuiptlon Comment ID(in) SAFETY VLV, 31.1 31.1 -0.77 HANGER FMC GEN IV TUBING HANGER 3.500 1,789 U 1 1,788.7 1,759.4 29.55 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 8,642.9 6,076.2 49.14 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 GAS LIFT, 8,656.6 6,085.1 49.68 PACKER BAKER HB RETRIEVABLE PACKER 2.890 2'511 c„ 8,692.7 6,108.4 49.53 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 8,704.01_6,115.6 49.24 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievat ,plugs,valves,pumps,fish,etc.) Top DepthTVD) Top Incl Top(ftKB) (ftKB) 1°) Description Comment Run Date ID(in) 8,680.0' 6,100.2 49.58 FISH LOST 33.4'SLICKLINE TOOLSTRING w/1-3/8"FISH 10/4/2010 0.000 SURFACE, . '' 4. NECK(ROPE SOCKET)@ 7535'RKB OR @ 8710'TOC 35-3,563 Perforations&Slots GAS LIFT, Shot 5,168 Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(RKB) (ftKB) (RKB) Zone Date (ah-- Type Comment 8,762.0 8,772.0 6,153.5 6,160.0 C-4,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5"NC Gun GAS, 73LIFT, 0 8,838.0 8,854.0 6,203.2 6,213.7 A-5,2K-17 4/27/1997 6.0 IPERF Zero deg.Phasing,2.5"NC Gun 8,882.0 8,920.0 6,232.0 6,256.8 A-4,2K-17 4/21/1990 4.0 IPERF 180 deg.Phasing,4.5"HSC Notes:General&Safety GAS LIFT,7,568 End Date Annotation 1 9/30/2010 NOTE:CEMENT PLUG SET PRE CTD WORK;ALL PERFS COVERED 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,8,067 GAS LIFT.8,598 C PBR,8,643 ----- - PACKER,6657 il NIPPLE,8,693 E'. FISH,8,680 -_.--___- SOS,8,704 IPERF, 8,762-8,772 IPERF, 8.638-g,854 Mandrel Details Top Depth Top Port TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°l Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,511.2 2,319.5 47.56 MERLA TMPD 1 GAS LIFT GLV BK 0.125 1,327.0 8/23/2002 8,682-8,92IPERF, 0 2 5,168.0 3,896.6 53.53 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,350.0 8/23/2002 3 6,729.7 4,851.0 51.28 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,371.0 8/23/2002 4 7,567.5 5,384.2 49.40 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,355.0 8/23/2002 5 8,066.9 5,706.2 50.45 CAMCO MMG-2 1 12 GAS LIFT OV RK 0.156 0.0 8/23/2002 6 8,598.2 6,047.5 50.06 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 PRODUCTION, 33-9,133 Cement Plug,8,710 TD,9,145 N J W O N Z13 O, cF oO>, 0-) ce m O N U Z Qaw- O m2 U oUO- gW 0 a_ O zc2m 43 m O . z ow U w = I W O Z Z CC O 2 O OWI- Up ¢ w( n < O N ( Zpaceen Z O W O woaa w caw wOJ W o„ vv Z x JEtQ00' N N N 41 W v)= cpo J` mow Q Cf) Z O CDT) U HO Q N Z 16 O 0 t- 1- Z a_ w a O_ r v Y° c I - I II CNI OO 0 Z s o II M „ Z z Q P".o w a Z CC p Q# el Kir I ` r• C7 t' ill' 2. 11 N ! I V v v ww a5Ea V) F II— N el w meg++" o g O N taon/7 N = Cn ti" I ' w W a g 11, 00"© o OD LL, Q O O O w 2 CO L.,_ __ iJ d U d I W J a a a O U x Z ' m GL 1- r N H. O Cz7 O w N E w w N w O W m I- i V IY N pU In W N 0A- ICK W N LL Q LI¢ 1 Z air® zU cp O_ N CD M W M N O = U 0 0 w N t N 3 -^ D U-. Y Y O 41 O = CD CD w 1\--4 a Z QW Vl - Z1 • t O O K I JZ O a C IX CC M Q U~ Q 2 0 U N N Z o . 7 3} 2 a> a> 0 3 3 o w W o v o v v N z _ z-i m 0 Q U Q Q W3'' 3 N 0 W a m uzi 0 Cl) o o I I 1 IZI Z i cn N o J N M [ di 0 a0 CV rnoo y r co co ter e.. 4 S e I it N Ir. t a t! s, t K 41 4 1 l, ter _ itfl C. S\\V"Sint" , k. z mo;° s ,_ > '41,4-4-..--,.-d ," , p 1 Sx r. t lK nk 114r 4 . u Inc. f 3 kf.,hTis a ConocoPh1 .0 cannot be =r ed or . r without express written e* of ConocoPhillips Alaska fil I i rl ' 14/ 14, 141!" 4.. ' * 1/ 1"/ , ii,./ If/: I• 1 If f /( ill itif Itilti I il 8iy- I 4bR 41 :`W 4, 4„,„,......., IV4_ wda- A SSS R a tk t s t, kt4 4 44 o7jm a x Akt.., t. t le, f46/ 11, 11.141', 1 At c, sa, ci) BUN c 4, ss U Z.--) co w A^ t p '' ' e" Adtftrtf3 Q • L- L Q o( iiilt K ft K 1f; f7 . 1 #..‘ < 00 2 YL 4', e,, t tf ' f,# r i A r V U f, $ 4 # fi i fg, L$ a r I /! YL frf LL A} trr 7" p 0 . ^' 0 r 12 ip, le w . t f i+ I J W 1,,, P . t t U C Cl i',. a' ra i i d , fx ,. Ii{ if° l • I.. r O C O O p+;;, 3 4 r r{! ,' '{ , ( n C C 4-' U f Ir r c O — c U0 ( 13 3 O r • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/06/11 Inspector: Lou Grimaldi Operator: Conoco Phillips Alaska Inc. Well Name: KRU 2K -17 Oper. Rep: Martin Walters PTD No.: 189 -119 • Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: N1787Aconocophillips.com If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 10/17/10 Date AOGCC Notified: 09/05/11 Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? yes - Well Pressures (psi): Tubing 1314 Photos Taken? yes IA 470 OA 53 Condition of Wellhead: Inside wellhouse, Weathered (OK), valves cycled and OK, Gauges OK, no oil in cellar. Condition of Surrounding Surface Established pad in good shape. "S" riser and A.L line behind wellhouse. Location: Follow Up Actions None Needed: Location verified by pad map. ': ',-t IN ,'� MAR t 'u ZW2 Attachments: Photos (2) REVIEWED BY: Insp. Supry ;24._ Comm I I PLB 09/2010 2011- 0906_Suspend_KRU_2K -171g • Suspended Well Inspection — KRU 2K -17 PTD 1891190 Photos by AOGCC Inspector L. Grimaldi 9/6/2011 a ' T w • f • 1 c: ! 4 • #r e • v.. V • -----. I e i • i f / f -.a r d j .'" 5 , 0 0' - yam , . 1 /r� / •, 00' < ' '' � ''� ' � / 0 � - ., '° /�,,r . '/. F ,r • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 10, 2011 RECEPVED SEP 14 20i1 Commissioner Dan Seamount Atoka oa & Gas Cons. Commission Alaska Oil and Gas Conservation Commission Anchorage 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry It Kuparuk River Unit 2K -17 (PTD ) /81 Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2K -17 (PTD 1'). fScl iIZ The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic ? '�� - Location Plot Plan - Photographs Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, Atit17 //d/ Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I 1. Operations Performed: Abandon Re air w ell Pl u Perforations Stimulate Suspended Well (� P 9 r O ther r Inspection Alter Casing r Pull Tubing r Perforate New Pool fl Waiver fl Time Extension Change Approved Program r Operat. Shutdown r" Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Development 1 Exploratory r "- 189 - 119 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 ° 50 - 103 - 20121 - 00-- 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025588 ` , 2K - 17 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9145 feet Plugs (measured) None true vertical 6404 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8657 true vertical 0 feet (true vertucal) 6085 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE (QC) 3528 9 -5/8 3563 2951 PRODUCTION 9100 7 9129 6394 rerforation depth: Measured depth: 8762 - 8772, 8838 - 8854, 8882 8920 True Vertical Depth: 6154 -6160, 6203 -6214, 6232 -6257 & G LOOS' °1 s 810 �t °a pA Ogo Tubing (size, grade, MD, and TVD) 3.5, J -55, 8705 MD, 6116 TVD • Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'HB' RETRIEVABLE PACKER @ 8657 MD and 6085 TVD TRDP - CAMCO TRDP -IA -SSA @ 1789 MD and 1760 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ' • Service r Stratigraphic r 15. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP F SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact MJ Loveland /Martin Walters )ed Name Martin Walters Title: Well Integrity Project Supervisor Signature / Phone: 907 - 659 -7043 Date 09 -10 -11 RBDMS SEP 14 2011eCen 74 47,43, I /$4 Form 10 -404 Revised 10/2010 Submit Original Only Y • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Nell Name: Kuparuk River Unit 2K -17 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 189 -012 Sundry 310 -301 API Number: 50103201210000 Operator: ConocoPhillips Date Suspended: 9/30/2010 Surface Location: Section: 169' FNL, 94' FEL, Sec 11 Twsp: T10N Range: R8E UM Nearest active pad or road: KRU DS2K Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good. Gravel Pad. "S" riser and AL line behind wellhouse Location cleanup needed: No Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Dry Discoloration, Sheens on pad, pits or water: No sheen Samples taken: No Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Weathered well. OK. Cycled SV, SSV, MV, IA valve, and OA valve Cellar description, condition, fluids: No oil in cellar. Gravel w/ floor clamp mounted to conductor Rat Hole: None Wellhouse or protective barriers: Wellhouse - Good Well identification sign: Stenciled on wellhead and wellhouse Tubing Pressure (or casing if no tubing): 1314 psi Annulus pressures: IA = 470, OA = 53 Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: None Operator Rep (name and signature): Martin Walters d& / c !/' AOG CC Inspector: Lou Grimaldi Other bservers: Carney / Mouser Inspection Date: 9/6/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: Time of Departure: Site access method: Highway vehicle 4. • KUP • 2K -17 ConocoPhillips = Well Attributes Max Angle & MD TD Wellbore APINWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Ala.■n, I' 501032012100 KUPARUK RIVER UNIT PROD 55.61 3,925.00 9,145.0 Conoc PhdLps Comment 1125 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: TRDP 50 1/17/2010 Last WO: , 11/22/1989 Wee Config: - 2K-17,105/2010 7:44.36 AM Schematic --dual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 8,710.0 10/4/2010 Rev Reason: FISH Imosbor 10/5/2010 Casing Strings '" - " -' String OD String ID Set Depth Set Depth (ND) String Wt String ' Casing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrd 111111111 CONDUCTOR, CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 115 SURFACE 95/8 8.765 0.0 3,563.0 2,950.5 36.00 J -55 El PRODUCTION 7 6.151 0.0 9,129.0 6,3935 26.00 J -55 SAFETY VLV, Tubing Strings i 1,785 String OD String ID Set Depth Set Depth (ND) String Wt String Tubing Description (In) (in) Top (ftKB) (RKB) (ftKB) (Ibs /ft) Grade String Top Thrd TUBING 31/2 2.992 0.0 8,705.0 6,116.3 9.30 J -55 EUE -MOD Other In Hole (All Jewelry: Tubinc Run & Retrievable, Fish, etc.) GAS LIFT. _ Top Depth 2,511 (N Incl De lop (ftKB) (RKB) D) Top ( °) Description 2.511 Run Data ID (In) 1,789.0 1,759.6 29.56 SAFETY VLV Camco TRDP-1A-SSA 4/22/1990 2.812 SURFACE, 2,511.0 2,319.3 47.54 GAS LIFT MERLA/TMPD /1/GLVBK/.125/1327/ Comment: STA 1 8/23/2002 2.875 3,563 5,168.0 3,896.6 53.53 GAS LIFT MERLARMPD /1/ Comment: STA 2 8/23/2002 2.875 6,730.0 4,851.2 51.2 9GASLIFT MERLA/ TMPD /1 /GLVBK/.188/1371 /Comment: GAS LIFT. STA3 &23/2002 2.875 7,568.0 5,384.5 49.39 GAS LIFT MERLA/TMPD /1 /GLV /BK/.188/1355/ Comment: STA4 8/23/2002 2.875 5,168 8,067.0 5,706.3 50.45 GAS LIFT CAMCO/MMG- 2/1.5/OV/RIV.156// Comment: STA 5 8/23/2002 2.920 8,598.0 6,047.4 50.06 GAS LIFT CAMCO/MMG- 2/1.5/DMY/RK/ // Comment STA 6 8/23/2002 2.920 8,643.0 6,076.2 49.15 PBR Baker '80-40 w/ 10' Stroke PBR 4/22/1990 2.810 GAS LIFT, 8,657.0 6,085.3 49.68 PACKER Baker RETRIE PACKER 4/22/1990 2.890 6,730 8,680.0 6,100.2 49.58 FISH LOST 33.4' SLICKLINE TOOLSTRING w/ 1 -3/8" FISH 10/4/2010 0.000 I NECK (ROPE SOCKET) @ 7535' RKB OR @ 8710' TOC 1 8,693.0 6,108.6 49.53 NIPPLE 2.81 "Otis' (N' Nipple 2.75" NO GO 4/22/1990 2.750 8,704.0 6,115.7 49.24 SOS Baker 4/22/1990 2.992 GASLIFT,_ 8,705.0 6,116.3 49.24 4/22/1990 2.992 111 ],568 Perforations & Slots Shot Top (ND) Bbn (ND) Dens GAS LIFT, Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (°h••• Type Comment 8,067 - ' 8,762.0 8,772.0 6,153.5 6,160.0 C -4, 2K -17 4/27/1997 6.0 IPERF Zero deg. Phasing, 2.5" HC Gun 8,838.0 8,854.0 6,203.2 6,213.7 A-5, 2K -17 4/27/1997 6.0 IPERF Zero deg. Phasing, 2.5" HC Gun 8,882.0 8,920.0 6,232.0 6,256.8 A -4, 2K -17 4/21/1990 4.0 IPERF 180 deg. Phasing, 4.5" HSC GAS LIFT, 1. 8,598 II P61. 8643 - -- ■ PACKER. 8,657 0 e�s•� NIPPLE, 8,693 FISH. 8680 i SOS, 8,704 1 TTL. 8,705 II 1 IPERF, _ 6,762 -6.772 IPERE, 8,638-8,854 I IPERF, 8.882-,920 PRODUCTION. 9.129 Cement Plug, 8.710 TD. 9,145 POWERLINES aI1811 sr CULVERT P,Pra �nES C CAUTION ` x:•: 1 •:9 THIS DRILL SITE IS (..-- f [ TRL ROOM CONSIDERED TO BE XFRM I it PROD HEATER AN H AREA rill r METH TANK G UARD RAIL , 1 f1 II RESERVE PIT : 1 1 �� AUNCHER BLDG w I I � TEST SEPARATOR ' PROD MOD— PROD MOD \ 3 r I21 272'2123222 1111 281 1 19 3 3 a 1 3 2 E Lit 611 ow•s0 ®,►001®♦ a4. .fig 0x. 1 I'I 13 SPACES O 25-300' 45' 45' 12 SPACES O 25' •300' TO DS 2H — N 'yr 1—,00.--I LEGEND FEATURE LOCATIONS U EXISTING PRODUCER EXISTING INJECTOR LEGEND ''v CONVERTED FROM PRODUCER TO INJECTOR = — CLEAN SNOW DUMP AREA, ALL EQUIPMENT, 0 RESCUE EQUIPMENT L ABANDONED CONDUCTOR * SCBA LOCATIONS NOTE A{ EXISTING CONDUCTOR 0:•:... - ENVIRONMENTAL AREA —NO SNOW DUMPING. — POWERLI NE— WATCH CLEARANCE!!, KODIAK 1 1 DESIGNATED SAFE AREA ( PR I MARY ) PARTIAL TREE BLOWERS MAY HIT LINES WITH DISCHARGE. 12 I DESIGNATED SAFE AREA (SECONDARY) NO S NOW IS TO BE PLACED IN .p, ^s} - KODIAK BLOWERS MAY DISCHARGE OVER EVACUATION ROUTES DEPENDING ON WIND ANY RESERVE PIT OR LINED PIT. PIPELINES. r WINDSOCK • .:a - NO SNOW DUMPING AREA. ® BARRICADE /ESCAPE ROUTE A LOUNSBURY, INC FIRE EXTINGUISHER FORM: ASIZEL ConocoPhillips AREA: 2K MODULE:XXXX UNIT: D2 Alaska ,Inc . DS 2K FACILITY EXPANSION APPROVAL: 5 04/25/03 Add Well 27, Rev Per K03060ACS RLS MRT DATE: 10/25/96 LK621112 FEATURE LOCATION PART: REV: 4 05/01/02 Add Well 28, Rev Per K02013ACS MRT SCT D RAWING NO. aZ i CUMST DATE REVISIONS BY CHK Jr. Pr ., - D2KX -3321 1 5 . • • • f...-tr 2K-17 (PTD# 189-119) ,.- © Conoco Phillips Alaska, Inc. „ ? i This photo is copyrighted by ....., Conoco Phillips Alaska, Inc. .,- 1 and cannot be released or ' published without express written consent of P ' ... ConocoPhillips Alaska A ,- ,?: mos,... . , 1 0 • 1 . , 4 4 a litt , I "Weft. 1 , 9 1 i's —411111116. # , . . ' "irb i I I , Ai IQ , , 17 ,, 77.7-719 , i i I . ., . ..... ,...,, , r L , A, - „ testi .., , . , . - ... i.....- .,.,...-, --- r . • I 41 y` M 1 ,. , IMF a r x f r i iii L g 4 T NA ilk A 2K -17 (PTD# 189 -119) © ConocoPhillips Alaska, Inc. o This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express , A 444414 written consent of ConocoPhillips Alaska MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Superviso � p DATE: Wednesday, November 10, 2010 To: Jim Regg J P.I. Su / I 'r SUBJECT: Mechanical Integrity Tests L` CONOCOPHILLIPS ALASKA INC 2K -17 FROM: John Crisp KUPARUK R1V UNIT 2K -17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry - NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K -17 API Well Number: 50- 103 - 20121 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr101017185321 Permit Number: 189 -119 -0 Inspection Date: 10/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-17 , Type Inj. I N ' TVD boss 1 IA 620 620 620 620 ` 1891190 SPT 2000 60 60 60 60 P. T.Di TypeTest Test psi OA I nterval OTHER P/, P , Tub ing 1800_ 2000 1940 1940 Notes: MITT to cemented perfs; after verification SSSV was open (prior report mitJCr101017184244). Nov Wednesday, November 10, 2010 Page 1 of I MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Wednesday, November 10, 2010 P.I. Supervisor ll ( (V P SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -17 FROM: John Crisp KUPARUK RIV UNIT 2K -17 Petroleum Inspector Src: Inspector Reviewed B P.I. Supry NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K -17 API Well Number: 50- 103 - 20121 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr101017184244 Permit Number: 189 -119 -0 Inspection Date: 10/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -17 Type Inj. I N I TVD 6085 IA 620 620 620 P.T.D 1891190 TypeTest SPT I Test psi 2000 OA 60 60 60 In terval OTHER P/F I Tub j 900 2000 1800 Notes: M ITT t o test cement plugged perforations from 8762 9145. Test thru tubing to perfs & packer. Test was prio to verifying the SSSV was op en. No operator report. Please see report mitJCR101017185321 NOV 18 201 I Wednesday, November 10, 2010 Page 1 of 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: September 30, 2010 189 - 119 / 310 - 301 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 November 14, 1989 50 103 - 20121 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 169' FNL, 94' FEL, Sec. 11, T1 ON, R8E, UM November 20, 1589 - 2K - 17 Top of Productive Horizon: 8. KB (ft above MSL): / KB - 15. Field /Pool(s): 1352' FSL, 1323' FEL, Sec. 12, T10N, R8E, UM GL (ft above MSL): 11 ' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1177' FSL, 1091' FEL, Sec. 12, T10N, R8E, UM 9047' MD / 6355' TVD Kuparuk River Oil Pool, 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-498310 y - 5938135 Zone- 4 ' 9145' MD / 6419' TVD ' ADL 25588 ' TPI: x-502363 y- 5934376 Zone-4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 502595 - 5934202 Zone-4 1789' MD / 1760' TVD 2674 18. Directional Survey: Yes ❑ No F 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1402' MD / 1400' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none I not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 170 sx AS II 9.625" 36# J -55 Surf. 3563' Surf. 2954' 12.25" 1100 sx ASIII, 450 sx Class G 7" 26.0# J -55 Surf. 9129' Surf. 6409' 8.5" 250 sx Class G 24. Open to production or injection? Yes ❑ No a If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 8705' 8657' MD / 6085' TVD perfs squeezed off � �Su.S�.t -� � ''` S w S S i /f SSA) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. � DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED across perfs 24 bbls 15.8 ppg Class G S�ANINEW NOV 4 2010 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE - C IVE OC 2 g ?010 Form 10 -407 Revised 12/2009 CONTINUED ON REVERS9 a u mit original only //z vo AJJ[)&&Q MV 0 2 Be � , 28. GEOLOGIC MARKERS (List all formations and markers untered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1402' 1400' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Herrmann @ 623 -4619 Printed N V a e Title: Alaska Wells Manager p Signature Phone 263 -4619 Date l D 1 Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 KUP , 2K -17 CCH11lCCi� til�l�3S a gg Max Angle &I MD TD -- WellboreAPUUWI Field Name Well Sf fus IIncl ( °) MD (ft KB) Act Btm (ftK6) AIaSF Inc, 501032012100 _1KUPARU RIVER UNIT PROD 55.61 1 3 ,925.0 01 9 145.0 C t WS (ppm) Date An otatan End Date KB-Grd (ft) Rig Rekurse Data SSSV TRDP 50 1/17/2010 Last WO _ _- 40 09 11/22/1989 Well coot g . zK- .,'L3,�+ 19 7 ndas AM - _ - - - -s - - S A�m A9L�a1 Annotation Depth (ftK6) End Date Annotation tl Date Last Mod By En Last Tag: SLM 8,710 0 10/4/2010 Rev Reason FISH Imosbor 10!5/2010 Casina .Strirl s t String OD String ID Set Depth Set Depth (TVD) String Wt ' String 1 Casing p scription _ (in) (in) _ To ftK6 (ftK6) (ftKB) (Ibs/ft) I Grade Stri Top Thrd_ CONDUCTOR,_ (CONDUCTOR 16 15.062 0.0 115.0 ^` 115.0 62.50 H-40 - r 15 SURFACE 9 8 8 -765 0 0 3,563.0 2,950.5 36.00 J-55 . ..- �.... .____.. �- PRODUCTION - 7 6.151 0.0 9,1290 6,393 .5 26.00 J -55 SAFETY VLV, Tubing String ring OD String Sel Depth Set Depth (TVD) String Vlt String 1.789 Si P >�.. P ( ) I ( __,_g__P Tubing Descn toy (in) (inl ID To ftK6 (ft 4 (ftK6 Ibs/N Grad. Strin - r Thrtl TUBING 3 12 2 992 0 0 8,705.0 6,116 -3 9.30 J 55 EUE -MOD Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) GAS LIFT, - Top Depth 2,511 (TVD) Top Inc! Top KB (ftK6) ( °) Description Comment Run Date ID In 1,789.0 1,759 -6 29.56 SAFETY VLV Camoo TRDP -1ASSA 4/22/1990 2.812 ' suRFAce, - 2,511.0 2,319.3 47 AS LIFT .54 G ii WTMPD /1 /GLV /BW.125n 3271 Comment STA1 81232002 2.875 ^ _ �_ �..�_ _ .__ '?. 5,168.0 3.896.6 53.53 GAS LIFT MERWTMPD /1 /GLV /BW.156 /7350 /Comment STA2 823/2002 2.875 3.563 ---- 6,730 -0 4,8512 5129 GAS LIFT MERWTMPD /1IGLVBW.188 /7371 /Comment: STA 3 8123/2002 2.875 _� --- `- GAS LIFT, _ °.. 7,568.0 5, ,384.5 49.39 GAS LIFT MERLAITMPD /1 /GLVBW.788/7355 /Comment: STA4 8232002 2.875 5,166 8,067.0 5,706.3 50.45 GAS LIFT CAMCO /MMG- 2/1.5/OV/RW.1561 /Comment: STA 5 82312002 2.920 8,598.0 6,047.4 50.06 GAS LIFT CAMCO /MMG- 2 /1.5 /DMY /RW / /Comment: STA6 8232002 2.920 ,,. 8,643.0 6,076.2 49.15 PBR Baker'8040' w/ 10' Stroke PBR -- 422/1990 2.810 GAS LIFT, _ S,6S7 85 .D 6,0.3 49.68 PACKER Baker'HB' RETRIEVABLE PACKER - 4/22/1990 2.890 6,730 8,680.0 6,100.2 49.58 FISH LOST 33.4' SLICKLINE TOOLSTRING w/ 1-3/8" FISH 1014/2010 0.000 NECK (ROPE SOCKET) Q 7535' RKB OR (d 8710' TOC 8,693.0 6,108 -6 49.53 NIPPLE 2.81" Ohs 'XN' Nipple 2.75" NO GO 4/2211990 2.750 8,704.0 6.115) 49.24 SOS Baker 4/22/1990 2.992 GAS LIFT, _ 7,56e 8,705.0 6,116.3 49.24 TTL - 4/22/7990 2.992 Perforations & Slots -- sna T flKB Top GAS LIFT. - (TVD) at. (rVD) Dens ' Btm (ftK6 (ftK6) (ltl(B) Iona Date (h... a Comment - - ". - 6,os7 8,76 ?.0 8.772.0 - 6,153.5 6,160.0 C-4, 2K -17 427/1997 6.0 IPERF Zero deg. Phasing, 2.5" HC Gun 8,838.0 8,854.0 6,203.2 6,213 -7 AS, 2K -17 427/1997 6.0 IPERF Zero deg. Phasing, 2.5" HC Gun 8,8820 8,920.0 6,232.0 6,256.8 A-4, 211 421/1990 4.0 IPERF 1180 deg. Phasing, 4.5" HSC GAS LIFT. 8 598 PBR, 8,643 PACKER, 8,657 N / NIPPLE, 8,693 -- - -- it FISH, 8,680 Iv ,1 a SOS, 8,70! - - µ TTL, 8,705 I IPERF, 8,762 -8,772 IPERF,_ 8,838 -8,854 IPERF,__ 8,682 - 8,920` PRODUCTION, 9,129 C-ern Plug, 8,710 TD, 9,145 2K -17 Well Events Summary DATE SUMMARY 9/30/10 Pumpe 24 bbl of 15.8 ono class cement across serfs- Displace with 56 bb fresh water and 20 bbl of diesel freeze protect Top of cement - 8710'. 10/4/10 ATTEMPTED TO TAG CEMENT TOP AND UNABLE TO GET BY GLM @ 7568' RKB. POOH TOOLSTRING AND HUNG UP IN TRDP -1A -SSA, FLAPPER CUT WIRE @ ROPE SOCKET LEAVING 33.4' TOOLSTRING DOWNHOLE ( TOP OF TOOLSTRING W/ 1 3/8 FISH NECK PRESUMED TO BE @ 7535' RKB ). NOTE: CEMENT PLUG MIT WAS TESTED 10 -3 -10 TO 2000 PSI (PASSED); SEE NOTE IN THIS WSR FOR PRESSURES. 10/17/10 S TATE WITNESSED ( JOHN CRISP) MIT -T (PASSED). I PaoAcrive DiAgnos~ic SeevicES, INC. ~~L~ +LQV ;~ 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 lnspection[Caliper/ 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 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C AK 99518 `~` E7 ~ i, ~y Anchorage, s ~, ~~ ~~:a, I~,f~~~ ~~ Fax: (907 j 245-8952 ~~' ~~ `''' k ~.~. 1) Caliper Report 2) 16-May-10 2K-17 i~sg- i iq Signed : Date Print Name: 1~~~g PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~s~5a~r~~r~Ce!nJi~~::zoT~?cC.w~:s~ WEBSITE:=r~~,~r.ssE~sra~~~~~.~.~:° 1 Report 50-103-20121-00 C:\Docomems and Set[ings\Diane Williams\pesktop\Tcar~smit_Conoco.docx • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2K-17 Log Date: May 16, 2010 Field: Kuparuk Log No.: 10633 State: Alaska Run No.: 1 API No.: 50-103-20121-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 EUE-MOD Top Log Intv11.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 8,705 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the 3.5" tubing tai/ @ 8,705' (Driller's Depth). 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 appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations or areas of cross-sectional wall loss recorded. Buckling is recorded in the 3.5" tubing from 700' to 720'. Deposits are recorded from 716' to -717', restricting the I.D. to 2.70" at 716'. No other significant I.D. restrictions are recorded. A graph illustrating minimum recorded diameters on a joint-by joint basis is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 12%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 2%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 2.70" Jt. 22 @ 716 Ft. (MD) No other significant I.D. restrictions are recorded. Field Engineer: G. Etherfon Analyst: C. Waldrop Witness: 8. Boehme ProActive Diagnostic Services, Inc. / P.G. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax.: (281) 565-136° E ~~nail: PDSz~memorylog.com Prudhoe Bay Field Gffice Phone: (907) 659-2307 Fax: (907) 659-2314 i! ~s`~ -r ~ ~ l ~ ~-d~i Correlation of Recorded Damag Pipe 1 3.5 iri (9.0' - 8705.0') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 2 K-17 Kuparuk ConocoPhillips Alaska, Inc. USA May 16, 2010 A pprox. Tool De viation ~ A pprox. Borehol e Profil e I ~~ I ^~~ I i (>l4 ~ GLM 1 i 24;2 i 3251 ~ 4063 } ; c s 4872 v GLM 2 ~ 5688 6499 GLM 3 7309 GLM 4 GLM 5 8143 GLM 6 265.3 8705 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 265.3 1 25 50 100 I i ~ 125 E Z ~ 150 'o 175 2\/\/ 225 ~ 1 ~ 250 • PDS Report Overview ~,. S,, Body Region Analysis Well: 2K-17 Survey Date: May 16, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 EUE-MOD 2.992 ins 3.5 ins 6,0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 300 250 Z00 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10%~0% 40% 85% 85% Number of'oints anal sed total = 272 pene. 0 197 75 0 0 0 loss 253 19 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 265.3 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE-MOD Well: 2K-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 16, 2010 Joint No. Jt. Depth (Ft.) I'en. l)Ixc~i (Ins.l Pen. Body (Ins.) Pen. %, ~1et,~l Ices °4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 9 n 0.01 Z 1 2.98 PUP 1 13 ~) 0.02 ~) i ~ 2.90 2 46 t I 0.02 `i ~,' 2.90 3 79 i ~ 0.01 ~ I 2.89 4 112 i1 0.03 1!1 !I 2.90 5 144 ~) 0.01 ~, i ~ 2.92 6 177 t i 0.02 ~i i 2.90 7 209 i) 0.03 11 it 2.91 8 242 i~ 0.03 I1 a 2.90 9 27 U 0.01 b 1 2.92 10 307 t1 0.01 5 I 2.94 11 339 t1 0.01 4 !) 2.90 12 372 t~ 0.03 12 t~ 2.89 13 404 a 0.02 8 (~ 2.90 14 437 U 0.03 11 I 2.90 15 469 (1 0.02 9 i ? 2.90 16 502 t) 0.02 9 it 2.90 17 534 i I 0.01 5 ! 2.92 18 567 i i 0.01 -1 I 2.93 19 599 U 0.03 12 I 2.90 20 632 U 0.01 U 1 2.91 21 664 i) 0.02 9 7 2.89 22 697 ~) 0.03 1 I _' 2.70 Bucklin De osits. 23 729 t1 0.01 v 1 2.88 24 762 i) 0.01 o i~ 2.93 25 794 (? 0.01 5 1 2.91 26 827 0 0.01 4 U 2.90 27 860 U 0.01 6 1 2.93 28 892 i) 0.01 5 1 2.93 29 925 U 0.02 9 1 2.91 30 957 i t 0.01 ~1 1 2.92 31 990 a 0.03 1I a 2.90 32 1022 t) 0.03 11 ~~ 2.91 33 1055 l) 0.02 ? 2.90 34 1087 n 0.01 2 1 2.93 35 1120 i~ 0.02 ~) I 2.89 36 1152 t) 0.02 ~) 1 2.90 37 1185 t? 0.01 4 ~~ 2.93 38 1217 i ~ 0.01 ~1 I 2.93 39 1246 ii 0.02 ') 2.90 40 1279 ii 0.02 ~) [ 2.89 41 1311 i? 0.03 lU 2.90 42 1344 ; ~ 0.01 6 1 2.91 43 1376 U 0.01 4 U 2.92 44 1409 U 0.01 5 1 2.90 45 1441 l) 0.03 1 Z + i 2.88 46 1474 c ~ 0.02 ~) a 2.89 47 1506 t? 0.03 12 l) 2.89 48 1539 ti 0.02 ~? I 2.89 49 1571 t' 0.03 12 !1 2.89 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 EUE-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: • ELATION SHEET 2 K-17 Kuparuk ConocoPhillips Alaska, Inc. USA May 16, 2010 Joint No. Jt. Depth (Ft.) Pen. Upset {Ins.) Pen. Body (Ins.) Pen. % Met,~l I oss °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 50 1604 t) 0.01 5 I 2.93 51 1636 ! i 0.03 1 1 ' 2.89 52 1669 t) Q_02 ~i . 2.90 53 1701 (i 0.02 ~) r t 2.89 54 1734 t i 0.02 `) !) 2.89 54.1 1766 t) 0.02 ~) ~ 2.96 PUP 54.2 1772 t ~ 0 0 i? 2.81 Camco TRDP-1 A-SSA SSSV 55 1783 i) 0.01 V 1 2.90 56 1816 t) 0.01 ~ I 2.91 57 1848 t) 0.01 4 I 2.90 58 1881 ! i 0.02 8 ~ ~ 2.90 59 1912 U 0.01 5 1 2.91 60 1944 (1 0.01 5 1 2.91 61 1977 t) 0.02 ti I 2.90 62 2009 t~ 0.02 ~~ t) 2.91 63 2042 U 0.03 1 ~ ! i 2.89 64 2074 U 0.03 i U 1 2.90 65 2107 U 0.03 I U 1 2.90 66 2139 t) 0.02 `? I 2.87 67 2172 !> 0.01 5 1 2.93 68 2204 !) 0.03 1 1 I 2.8 69 2237 U 0.02 ~) I 2.89 70 2269 ! 1 0.01 ~~ ! 2.90 71 2302 tl 0.02 ~i I 2.89 72 2334 U 0.02 ~) I 2.91 73 2367 i~ 0.03 11 t~ 2.88 74 2399 i) 0.03 I2 i 2.87 75 2432 U 0.03 It) I 2.89 76 2464 O 0.01 ~ 1 2.89 76.1 2497 i) 0 0 0 N A GLM 1 Latch C~ 9:00 77 2504 a 0.02 6 ? 2.92 78 2537 ! ~ 0.02 9 I 2.89 79 2569 U 0.02 ~) I 2.89 80 2602 t) 0.03 10 I 2.89 81 2634 n 0.03 11 1 2.88 82 2667 t! 0.02 9 I 2.88 83 2699 U 0.02 9 I 2.89 84 2732 U 0.03 11 I 2.89 85 2764 C) 0.01 4 I 2.93 86 2795 O 0.02 9 1 2.91 87 2828 t) 0.02 `~ I 2.92 88 2861 ! ~ 0.03 10 2 2.88 89 2893 ti 0.03 12 i 2.88 90 2925 t) 0.03 10 ~' 2.88 91 2958 U 0.02 9 1 2.91 92 2990 U 0.02 t9 I 2.90 93 302 3 t i 0.03 I U ! 2.75 94 3056 c ~ 0.01 5 U 2.91 95 3088 U 0.02 9 I 2.89 96 3121 !! 0.01 5 I 2.88 Penetration Body Metal Loss Body Page 2 • ~ i PDS REPORT JOINT TABULATION SHEET '' Pipe: 3.5 in 9.3 ppf J-55 LUF-MOD Well: 2K-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. '~' Nominal LD.: 2.992 in Country: USA Survey Date: May 16, 2010 Joint No. Jt. Depth (Ft.) PE~n. 111,tie~t (Ins.; Pen. Body (Ins.) Pen. % Mcial Loss °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3153 ~ ~ 0.03 10 I 2.88 98 3186 to 0.03 12 (! 2.90 99 3218 i l 0.02 9 I 2.89 100 3251 !~ 0.02 ~~ 1 2.91 101 3283 !) 0.03 12 1 2.89 10 3316 (1 0.01 4 1 2.92 103 3348 a 0.01 6 I 2.90 104 3381 a 0.02 ~) 1 2.92 105 3413 l? 0.01 5 I 2.90 106 3446 O 0.01 6 I 2.90 107 3478 U 0.01 4 t) 2.89 108 3511 U 0.02 9 1 2.90 109 3543 U 0.03 12 I 2.89 110 3576 ll 0.03 I t) 2 2.90 111 3608 U 0.02 ~) 1 2.90 112 3641 l) 0.01 4 7 2.89 113 3673 :> 0.02 <~ I 2.92 114 3706 t) 0.02 4 i 2.88 115 3738 U 0.02 ~~ I 2.90 116 3771 U 0.02 ~~ I 2.88 117 3803 t) 0.01 4 I 2.89 118 3836 U 0.01 5 I 2.90 119 3868 U 0.02 8 1 2.88 120 3901 a 0.02 '~ 1 2.88 121 3933 i) 0.02 ~? 1 2.90 122 3966 n 0.03 11 1 2.88 123 3998 t t 0.03 1,! I 2.88 124 4030 c) 0.03 10 1 2.88 125 4063 ti 0.02 ~ ( 2.91 ~ 126 4095 !) 0.02 ' ~ 2.88 127 4128 tr 0.03 12 1 2.89 128 4160 1i 0.03 11 1 2.88 129 4193 U 0.03 10 1 2.89 130 4224 O 0.03 12 I 2.89 131 4256 (~ 0.03 11 1 2.89 1 2 4289 ~~ 0.03 1O I 2.89 133 4321 1~ 0.03 10 I 2.92 134 4354 t 1 0.02 9 _' 2.89 135 4386 U 0.03 11 I 2.89 136 4419 U 0.03 10 2.87 137 4451 a 0.01 5 I 2.89 ro- 138 4484 U 0.03 11 2.88 139 4516 t? 0.02 9 1 2.87 140 4549 t~ 0.03 11 l~ 2.86 Lt De osits. 141 4581 (1 0.02 ~> 1 2.88 142 4614 t ~ 0.01 ~ ' 2.91 143 4646 i ~ 0.02 ~) O 2.87 144 4677 r) 0.03 lU i) 2.88 145 4710 t ~ 0.03 10 U 2.88 146 4742 ~ ~ 0.02 8 2 2.91 '' ~ _ Penetration Body Metal Loss Body Page 3 i • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE-MOD Well: 2K-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: May 16, 2010 Joint No. Jt. Depth (Ft) Pr~n. Il~~se1 (Ins.l Pen. Body (Ins.) Pen. °4, Mehl Los. °4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 147 4775 ~ i 0.03 1 1 U 2.88 148 480 7 r) 0.03 i 2 0 2.88 149 4840 i ~ 0.03 1 t) l) 2.91 150 4872 n 0.03 10 l) 2.91 151 4905 ~ i 0.02 8 (? 2.90 '~ 152 4934 0 0.02 ~) ~:) 2.87 153 4966 U 0.02 9 t? 2.88 154 4999 ~) 0.02 9 ;! 2.87 155 5031 U 0.03 11 ~~ 2.88 156 5064 0 0.01 ~ U 2.91 157 5096 l) 0.02 9 (~ 2.89 Lt. De osits. 158 5129 (1 0.03 11 i) 2.88 158.1 5161 U 0 U it N A GLM 2 Latch @ 11:30 159 5168 r) 0.01 (~ ~ 2.89 ~ 1 GO 5201 U 0.02 9 ~ i 2.88 161 5233 tl 0.02 9 U 2.89 - 162 5266 U 0.03 10 i i 2.88 163 5298 ~i 0.03 IO U 2.92 164 5331 O 0.02 9 U 2.91 165 5364 U 0.02 ~) i i 2.86 166 5396 U 0.02 f~ t) 2.90 167 5428 ,) 0.03 11 1 2.86 168 5461 ~~ 0.02 <i U 2.86 169 5493 ! i 0.02 ~~ ~) 2.88 170 5526 ~i 0.01 4 U 2.90 171 5558 (> 0.03 1 U U 2.90 172 5591 0 0.02 7 ~ i 2.91 173 5623 t) 0.03 10 U 2.87 174 5656 U 0.03 1 Z t1 2.84 175 5688 a 0.02 9 lJ 2.86 176 5721 i 1 0.03 12 (1 2.85 Lt. De osits. 177 5753 ~l 0.02 ~s ~i 2.86 178 5786 U 0.03 1 l ~ i 2.90 179 5818 U 0.03 11 a 2.87 180 5851 (1 0.02 ~i a 2.86 181 5883 ~i 0.03 1 i) a 2.86 _ 182 5916 i) 0.02 9 i i 2.86 Lt. De osi ts. 183 5948 (1 0.03 1 1 t) 2.90 184 5981 0 0.03 11 U 2.88 185 6013 ! i 0.02 `i U 2.88 186 6046 ~ i 0.03 1 1 (1 2.88 187 6078 t i 0.03 i 2 U 2.89 188 6111 ~ ~ 0.02 ~> ~ ~ 2.87 189 6143 tl 0.03 1 U i i 2.90 190 6176 (i 0.02 ~, a 2.87 191 6209 a 0.03 i 1 ~. ~ 2.87 Lt. De osi ts. 192 6241 a 0.03 11 i; 2.87 193 6274 U 0.03 11 U 2.87 194 6305 l) 0.02 ~i U 2.89 195 6337 a 0.02 ti 0 2.88 _ Penetration Body ~'vletal Loss Body Page 4 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 EUE-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 2 K-17 Kupanrk ConocoPhillips Alaska, Inc USA May 16, 2010 Joint No. Jt. Depth (Ft.) Pcn. i )t~sc~t (Ins.) Pen. Body (Ins.) Pen. % Mci,il I oss `i~~ Min. LD• (Ins.) Comments Damage Prolile (% wall) 0 50 100 196 6370 n 0.03 10 O 2.87 197 6402 t) 0.03 10 O 2.89 198 6435 t) 0.03 12 t) 2.85 199 6467 0 0.03 ! ~ t~ 2.87 200 6499 c) 0.03 I 1 t) 2.84 Lt. De osi ts. 201 6532 U 0.03 12 U 2.85 202 6564 t) 0.03 lI U 2.86 203 6597 U 0.03 11 U 2.89 204 6629 U 0.03 11 U 2.85 205 6662 U 0.02 9 U 2.88 206 6694 U 0.03 12 t) 2.86 206.1 6727 u 0 t) t) N A GLM 3 Latch @ :30 207 6734 O 0.03 1U r) 2.87 208 6766 U 0.02 9 u 2.86 209 6799 ;) 0.03 1 i) ~ 2.87 210 6830 U 0.02 t~ i ~ 2.86 211 6862 t) 0.02 c; a 2.85 Lt. De osits. 212 6891 t) 0.03 ls) t! 2.84 213 6924 0 0.03 1 ~ f i 2.86 214 6956 U 0.02 9 t i 2.85 215 6989 t) 0.03 1 1 t) 2.87 216 7021 ~) 0.03 1(] t i 2.86 217 7054 U 0.03 10 tl 2.87 218 7086 0 0.03 1 t 1 n 2.84 Lt. De osi ts. 219 7119 t) 0.03 1(1 ! ~ .86 220 7151 t ~ 0.03 1 c) I 2.87 Lt. De osits. 221 7181 t) 0.03 1 1 ~) 2.86 222 7213 t) 0.03 1 1 U 2.82 223 7246 U 0.03 1 ' U 2.84 224 7278 t) 0.03 1 1 t) 2.85 225 7309 t) 0.03 11 U 2.84 226 7341 t) 0.03 1 ] O 2.84 Lt. De osits. 227 7372 ~:t 0.03 i I Ci 2.85 228 7404 t) 0.03 I ~ ±) 2.84 229 7436 t) 0.03 1 ~' i) 2.84 230 7469 t) 0.02 t3 tl 2.85 231 7501 t? 0.03 1 U U 2.85 232 7534 (> 0.02 8 t) 2.87 232.1 7566 t) 0 0 C) N A GLM 4 Latch Q 9:00 233 7574 n 0.02 r3 t] 2.88 ' ~"' 234 7606 O 0.02 ~a ~) 2.85 235 7639 (t 0.03 12 0 2.87 236 7671 t) 0.02 ~) U 2.85 237 7704 t ~ 0.02 ~> t t 2.87 238 7736 t? 0.02 is ~ 2.88 239 7769 t~ 0.02 '~ ~~ 2.88 240 7801 ; ! 0.02 ~? t ~ 2.88 241 7834 !) 0.02 9 U 2.87 242 7866 ~) 0.02 7 ~) 2.88 243 7899 !) 0.03 1 I l) 2.87 _ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf )-55 EUE-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEET 2 K-17 Kuparuk ConocoPhillips Alaska, Inc. USA May 16, 2010 Joint No. Jt. Depth (Ft.) Pen. I lhsc~t !Ins.} Pen. Body (Ins.) Pen. % .Metal I cuss °i~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 244 7931 n 0.02 ~? ~~ 2.87 245 7964 O 0.03 1t) t) 2.84 246 7996 i) 0.02 f3 O 2.84 Lt. De osits. 247 8029 t'~ 0.03 1t) U 2.79 Lt. De osits. ~ 247.1 8061 U 0.01 ~ t) 2.91 PUP ~ ~ ~ 247.2 8068 O 0 U ~ ~ N A GLM 5 Latch @ 7:30 248 8074 U 0.01 ~ 1 2.89 Lt De osits. 249 8110 U 0.02 9 U 2.84 Lt. De osits. 250 8143 0 0.03 12 i) 2.83 251 8175 t) 0.02 9 t) 2.85 252 8204 i) 0.03 11 ~) 2.8.5 Lt. De osits. 253 8237 U 0.02 9 l? 2.79 Lt. De osits. 254 8269 U 0.02 9 U 2.85 255 8301 ~) 0.03 1~ U 2.85 Lt. De sits. 256 8334 U 0.03 .2 t ~ 2.86 257 8366 i) 0.02 s,1 ~) 2.85 258 8399 U 0.02 9 u 2.85 Lt. De osits. 259 8432 t) 0.02 ~) a 2.88 260 8464 a 0.02 <j s ~ 2.84 2 61 8497 t) 0.03 12 ! ? 2.85 Lt. De osi ts. 262 8529 t) 0.03 10 U 2.84 Lt De osits. 263 8562 U 0.02 ~) i ~ 2.87 263.1 8594 t) 0.02 7 ~ 2.91 PUP 263.2 8600 t) 0 U n N A GLM 6 Latch C~ 7:30 263.3 8606 ~) O.U2 )s 2.92 PUP 264 8613 U 0.02 '> i 2.86 264.1 8645 a 0.03 11 2.92 PUP 264.2 8657 u 0 O a 3.00 Baker'80-40' w 10' Stroke 264.3 8658 U 0 U U 2.89 Baker'HB' Retr. Packer 265 8666 U 0.01 5 0 2.87 265.1 8695 ~ 0 tl U 2.75 Otis XN-Ni le No Go 265.2 8697 U 0.03 1 'I ~ 2.84 PUP 265.3 8705 t) 0 t) 0 2 99 3.5" Tubin Tail ___ Penetration Body Metal Loss Body Page 6 PDS Report Cross Sections Well: 2K-17 Survey Date: May 16, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f J-55 EUE-MOD Anal st: C. Waldro Cross Section for Joint 22 at depth 715.923 ft Tool speed = 43 Nominal ID = 2.992 Nomina- OD = 3.500 Remaining wall area = 100 Tool deviation = 4 ° Finger 6 Projection = -0.28 ins Deposits Minimum I.D. = 2.70 ins HIGH SIDE = UP • LJ Cross Sections page 1 ConocoPhillips Alaska, Inc. KRU 2K-17 2K-17 API: 501032012100 Well T e: PROD An le TS: 49 de 8761 SSSV Type: TRDP Orig 11/22/1989 Angle @ TD: 49 deg @ 9145 sssv Com letion: (176s-17so, Annular Fluid: Last W/O: Rev Reason: TAG OD:3.500) Reference L Ref Lo Date: Last U date: 7/1/2006 Last Ta : 8969' RKB' TD: 9145 ftK6 Last Ta Date: 6/30/2006 Max Hole An le: 55 de 3900 Casin Strin -A LL STRINGS Gas Lift Descri tion Size To Bottom ND Wt Grade Thread MandrelNal~2 CONDUCTOR 16.000 0 115 115 62.50 H-40 1 (2511-2512 ~ SUR. CASING 9.625 0 3563 2954 36.00 J-55 , PROD. CASING 7.000 0 9129 6409 26.00 J-55 Tutan Strin -TUBING Size To Bottom ND Wt Grade Thread Gas Lift 3.500 0 8705 6132 9.30 J-55 EUE-MOD MantlrelNalve Perforations Summa 2 (51sa51ss Interval ND Zone Status Ft SPF Date T e Comment , 8762 - 8772 6169 - 6175 C-4 10 6 4/27/1997 IPERF Zero deg. Phasing, 2.5" HC Gun 8838 - 8854 6218 - 6229 A-5 16 6 4/27/1997 IPERF Zero deg. Phasing, 2.5" HC Gas Lift Gun MandrelNalve ~ _ + ggg2 _ gg20 6247 - 6272 Ate! 38 4 4/21/1990 IPERF 180 de . Phasin 4.5" HSC 3 (6730.6731, - Gas Lift Ma ndrels Nalves 5t MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2511 2320 Marla TMPD GLV 1.0 BK 0.125 1327 8/23/2002 Gas Litt 2 5168 3906 Marla TMPD GLV 1.0 BK 0.156 1350 8/23/2002 MandrelNalve 4 _ 3 6730 4864 Marla TMPD GLV 1.0 BK 0.188 1371 8/23/2002 (7568-7569, 4 7568 5398 Marla TMPD GLV 1.0 BK 0.188 1355 8/23/2002 5 8067 5721 Camco MMG-2 OV 1.5 RK 0.156 0 8/23/2002 6 8598 6063 Camco MMG-2 DMY 1.5 RK 0.000 0 8/23/2002 Oth er lu s e ui .etc. -JEWELRY Gas Lift De th ND T Descri tion ID MandrelNalve 5 1789 1759 SSSV Camco TRDP-IA-SSA 2.812 (6os7-aosa, 8643 6092 PBR Baker'80-40' w/ 10' Stroke 3.000 8657 6101 PKR Baker'HB' Retr. 2.890 8693 6124 NIP Otis'XN' Ni le NO GO 2.750 8704 6131 SOS Baker 2.992 Gas Lift antlrel/Dumm 8705 6132 TTL 2.992 y valve 6 J (8598-8599, OD:5.793) PBR (86438644, OD:3.500) PKR (8657-8658, OD:6.151) NIP (86938694, OD:3.500) TU I G B N (0-8705 , OD:3.500, ~ ID:2.992) S0.S (8704-8705, OD:3.500) Pert (8762-8772) Pert (883&8854) Pert (8882-8920) • COIlOCO~'II~~IpS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 ~ ~~~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 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 cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 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, ,.~i~~ ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor A ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) r Date Kuparuk Field 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-OZ 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10!2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30!2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.92 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/90/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-41 185-049 SF NA 4" NA 1.7 7!24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 9.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 Schlunlbepgep 5) ~<'> NO. 3887 . .1".,. ,Hn;;...r, ·~:~:<tl~ ',~~~~:_,.:.:; Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth I ~L) - 11 ¿ì Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Color CD Job# Log Description Date BL ~ 'J 1E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-105L 1 11213766 INJECTION PROFILE 06/20/06 1 18-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 F8HP SURVEY 07/14/06 1 1J-156 11216308 US IT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-2i 11249925 LDL 06/06/06 1 1F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04106 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1D-1O'1 N/A INJECTION PROFILE 06/27/06 1 2Z-U 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth atthe above address or fax to (907) 561-8317. Thank you. 07/24/06 e e THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 P M C:LO~.DOC E E L E W A T E R IA L U N D ER THIS M A.R K E R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing Operation Shutdown__ Stimulate Plugging Perforate X Alter casing Repair well Ct h e r 5. Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 169' FNL, 94' FEL, SEC 11,T10N, R8E, UM At top of productive interval 1375' FSL, 1357' FEL, SEC 12, T10N, R8E, UM At effective depth 1222' FSL, 1157' FEL, SEC 12, T10N, R8E, UM At total depth 1177' FSL, 1099' FEL, SEC 12, T10N, R8E, UM 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) RKB 154 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-17 9. Permit number 89-119 10. APl number 50-1 03-201 21-00 11. Field/Pool Kuparuk River Field/Oil Pool measured 91 45 feet Plugs (measured) None true vertical 6427 feet Effective depth: measured 9047 feet Junk (measured) None true vertical 6 3 6 3 feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 200 CF Surface 3528' 9-5/8" 1100 Sx AS III & Intermediate 450 Sx Class G Production 9 0 9 6' 7" 250 Sx Class G Liner Perforation depth: measured 8762'-8772', 8838'-8854', 8882'-8920' true vertical 61 68'-6177', 621 8'-6228', 6247'-6272' Tubing (size, grade, and measured depth) 3-1/2", 9.3#. J-55 @ 8705' Packers and SSSV (type and measured depth) Packer: Baker HB @ 8657'; SSSV: Camco TRDP-1A-SSA @ 1789' Measured depth True vertical depth 115' 115' 3563' 2956' 9129' 6416' ORIGINAL 13. Stimulation or cement squeeze summary Perforate 'A5' and 'C4' sands on 4/27/97. Intervals treated (measured) 8762'-8772', 8838'-8854' Treatment description including volumes used and final pressure Perforate using HC guns w/DP charges @ 6 spf, phased 0°, fp -- 820 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 9 3 2 4 5 4 891 256 Subsequent to operation 400 107 4 902 258 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 7. I her~.~rtify that the foregoing is true and correct to the best of my knowledge. Signed "~~'/~,V' ~,,~ Title Wells Superintendent Form lpZ'454 ~e~ Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(2K-17(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-17 PERFORATE, PERF SUPPORT 0407970801 ..5 DATE DAILY WORK UNIT NUMBER 04/27/97 PERFORATE: 2 1/2" HSD, 6 SPF, DP 8293 DAY OPERATION COMPLETE ] SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes ('~ NoI (~) Yes O No SWS-JOHNSON CH.A.N~Y FIELD AFC# CC# DALLY COST ACCUM COST SiSi~e ~ .,,.~' _..,, ESTIMATE KAWWRK 230DS28KL $9,822 , $12,160 ,/,t.,,/~,. /.// ,. Initial T b.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I F'Tnal Outer An, l;r~ 620 PSI 820 PSI 950 PSI 950 PSII 775 PSII 7~/5 PSI DALLY SUMMARY PERFORATED "C4" SAND INTERVAL @ 8762' RKB - 8772' RKB W/2-1/2" HC GUN, DP CHGS, 6 JSPF, 0 DEGREE PHASING & "A5" SAND INTERVAL @ 8838' RKB - 8854' RKB W/2-1/2" HC GUN, DP CHGS, 6 JSPF, 0 DEGREE PHASING. NO IMMEDIATE WHTP CHANGES. TIME LOG ENTRY 08:00 ARRIVE LOCATION WITH UNIT 8293 (JOHNSON) 09:00 FINISH RIG UP, PRESSURE TEST TO 3000 PSI SHUT IN WELL AT WING VALVE 09:30 RIH WITH 6' 1 11/16" WT BAR AND 16' 2 1/2" HSD PERF GUN 10:00 TIE INTO BCL DATED 12/25/89 RUN TIE IN PASS 10:38 PERFORATE: 8838' TO 8854', 6 SPF DP. NO PRESSURE CHGS. 10:45 POOH 11:20 AT SURFACE, ALL SHOTS FIRED 12:10 RIH WITH 10'2 1/2" HSD PERF GUN 12:55 PERFORATE: 8762' TO 8772', 6 SPF DP. NO PRESSURE CHANGE 13:00 POOH · 14:00 AT SURFACE, ALL SHOTS FIRED RIG DOWN 14:30 MOVE TO 2K-26 SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 $180.00 APC $250.00 $250.00 HALLIBURTON $0.00 $1,058.00 LR-rLE RED $0.00 $1,100.00 SCHLUMBERGER $9,572.00 $9,572.00 TOTAL FIELD ESTIMATE $9,822.00 $12,160.00 ARCO Oil and Gas Company 4) Well History - Initial Report - Daily Instructions: Prepare and submit the "lltilili R~' on the first Wednesday after a well Is spudded or workover operations are started. Daily work prior to Sl~dd~,~.a~lld be summarized on the form giving inclusive dates only. District ~'!~ ! ICounty, parish or borough ARCO ALASKA INC. '~: I NORTH SLOPE Field ILease or Unit KUPARUK RIVER'UNTT I ADL: 25588 ALK: 2674 ITItleAuth. or W.O. no. I COMPLETIONS IState AK vell no. KRU ~K-17 Operator I ARCO W.I. 55.8533 Date IHour Prior status if a W,O. 11/14/89 00:00 ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 04/22/90 (10) TD: 9145 PB: 9047 SUPV:DB Complete record for each day reported NORDIC i RIH W/ 3-1/2" COMPLETION MW:10.2 NsC1 MOVE RIG FROM 2K-16, ACCEPT RIG 1400 4/21/90, ND.DRYHOLE TREE, NU BOPE AND TEST TO 3000 PSI, RU HLS E-LINE UNIT, RIH W/ GUN #1, PERF 8900-8920, POH, ASF, RIH W/ GUN #2, PERF 8882-8900, POH, ASF, RU AND RIH W/ 3-1/2" SINGLE COMPLETION ASSEMBLY DAILY:S48,327 CUM:$954,264 ETD:S954,264 EFC:$1,201,0000 The above is/Ge)rrect For form preparatigfl' a~d distribu- tion, ~ see Procedures M n/~. _, Section 10, Drilling, Pages 86 and 87. Date -- AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPage no. ' 0 11 I G A 1. ST^,, o, WELL COMPLETION OR RECOMPLETION REPORT AND L I Status of Well Classification of Service Well OIL [~] GAS r'~ SUSPENDED E~] ABANDONED r~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, I nc 89-119/9-1093 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 -.~.-__._.._,_., 50-103-20121 4 Location of well at surface ~i;UM PLETIrJN 9 Unit or Lease Name 169' FNL, 94' FEL, SEC 11, T10N, R8E UM I~-~~' KUPARUK RIVER At Top Producing Inten/alV.~RiFJl;_D~¢~'~~ ITMI, trip t 10 Well Number At Total Depth ~ 1 3. ~ -__._~! 11 Field and Pool 1177' FSL, 1091' FEL, SEC 12, T10N, R8E UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154'I ADL: 25588 ALK: 2674 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 11/14/89. 11/20/89. 6/11/90.I N A feet U SLJ' 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost & 6419' TVD 9047' MD & 6355' TVD YES ~ NO U 1789' feet MD 1400' APPROX 9145' MD 22 Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CN L/CAL/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 170 SX AS II 9 5/8" 36# J-55 SURF 3563' 12-1/4" 1100 SX AS III, 450 SX CLASS G 7" 26# J-55 SURF 9129' 8-1/2" 250 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD · interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.3#, J-55 8705' 8657' 8882' - 8920' W/4~1/2" @ 4 SPF MD 6247' - 6272' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MO) [ AMOUNT & KIND OF MATERIAL uSED SEE ATTACHED ADDENDUM ,,, 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~- ,, Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,~ 28 CORE DATA ._ ~ ~ ,, ~.. ~.-~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~,~ f::" · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 8761' 6168' NA KUPARUK C Be'FI'OM 8773' 6176' KUPARUK A TOP 8817' 6204' KUPARUK A Be'I-rOM 9011' 6331' , · 31. LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __~_.~_~~ Title AREA DRILLING ENGINEER Date ""~//~/~'(~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain° Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Flrlal Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District County or Parish State ARCO ALASKA It~C. NORTH SLOPE AK Field Lease or Unit IWell no. KUPARUK RIVER UNIT I ADL: 25588 ALK:' 2674 K~U 2K-17 Auth. or W.O. no. ITitle I COMPLETIONS Operator A.R.Co. W.I. ARCO I 55. 8533 Spudded or W.O. begun ~Oate SPUD I 11/14/89 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC I 04/23/90 (11) TD: 9145 PB: 9047 SUPV:DB Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well our I Prlor status if ~ W,O. 00:00 RIG RELEASED MW:10.2' NaC1 CONT. RIH W/ 3-1/2" COMPLETION AssEMBLy, MU CONTROL LINE AND TEST, CONT. RIH W/ COMPLETION, MU TBG HGR, TEST CONTROL LINE, LAND TBG, RILDS, PRESS TBG TO 2500 PSI TO SET PKR, PRESS ANNULUS TO 1000 PSI, BLEED ANNULUS, BLEED TBG TO 1700 PSI, PU & SHEAR PBR, RELAND TBG, RILDS, PRESS ANNULUS/TBG TO 1000 PSI, TEST SSSV, BLEED PRESS, ND BOPE, NU TREE AND TEST TO 5000 PSI, PRESS TEST ANNULUS TO 2500 PSI, PRESS TBG TO 3800 PSI AND SHEAR OUT BALL, REV CIRC. 6 BBLS DIESEL INTO ANNULUS, BULLHEAD 2 BBLS DIESEL DOWN TBG, RELEASE RIG 1330 4/22/90 DAILY:S154,377 CUM:$1,108,641 ETD:S1,108,641 EFC:$1,201,000 Old TD Released rig INew TD I PB Depth Date IKInd of rig Classifications (oil, gas, etc.) Type completion (single, dual. etc.) Producing method Official reservoir name(s) Potential test data Welt no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water %" GOR Gravity Allowable Effective date corrected AR3B-459-3-C The above.~ correct Drilling, Pages 86 and 87. ~'" 'I'"; ~''~ ''~' Number all daily well history forms consecutively ~ Page no. as they are prepared for each well. Dlvl~on of AllanllcRIchfteld~mPan~ ADDENDUM WELL: 6/06/90 2K-17 Frac KRU "A" Sand in 5 stages as follows: Stage 1. Pmp Pmp Prop Pmp 200 bbls Gel H20; @ 25 bpm 6715-4810psi 60 bbls Gel H20; @ 26 bpm 4200-4450 psi and 45 bbls Gel H20; @ 15 bpm 3800-4210 psi 30 bbls Gel H20; @ 10 bpm 3520-4050 psi Stage 2 Pmp 80 bbls Slick Diesel; @ 25 bpm 5000-4150 psi ISIP: 2184 frac grade .71 ped frac 0 Stage 3 Pmp 1300 bbls Gel H20; @ 25 bpm 4700-4550 psi *Stage 4 Pmp 56 bbls Gel H20; WI2# 16/20 Carbolite @ 4550-4560 psi Stage 5 Pmp 85 bbls Slick Diesel Flush 4560-4399 Abort job, went to flush when sand chief hydraulic return line on filter blew out. Back up system used same return line. Over displaced well by 3 bbls past top peals. Will attempt frac again 6/12/90 Fluid to recover: Sand in zone: Sand in casing' 1640 Gel/H20 + 232 diesel 3620 '0- SUB. SURFACE DIRECTIONAL SURVEY ~UIDANCE r~ONTINUOUS F~looL Company , ARCO ALAS,,KA~ INC,. I I I i · Well Name 2K-17 (169' FNL,9,4' FEI~,SEC ll.TION.R8E-UM)_ FleldlLocation KUPARUK. NORTH SLOPE, ALASKA , . Job Reference No. 73623 MCBRIDE Date iq i C II 0 Fi L M E ompu~ed-,a~ I~-i O I ,~ ~ I oL~ SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FDR ARCO ALASKA, 1NC. 2K-17 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 25-DEC-1989 ENGINEER: MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HDRIZ. OIST. PROJECTED ONTO A TARGET AZIMUTH DF SOUTH 46 DEG 55 MIN EAST COMPUTATION DATE: 4-JAN-gO PAGE ARCO ALASKA, INC. 2K-17 .KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 25-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT- ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED OEP'TH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN TRUE SUB-SEA COURSE MEASURED VERTZCAL VERTICAL DEVIATION AZIMUTH OEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 0.00 N 0.00 E -0.13 0.45 0.11 N 0.07 W -0.65 0.65 0.18 N 0.72 W -0.84 0.18 0.01 S 1.17 W -1.29 0.21 0.13 S 1.90 W -1.81 0.08 0.53 S 2.98 W -2.26 0.12 1.00 S 4.03 W -2.89 0.00 1.44 S 5.30 W -3.63 0.08 1.B8 S 6.73 W -4.41 0.05 2.39 S 8.28 W 0.00 0.00 -15~.. O0 0 0 N 0 0 E 100.00 100.00 -54.00 0 13 N 45 18 W 200.00 200.00 46.00 0 24 S 66 17 W 300.00 300.00 146.00 0 16 S 83 29 W 400.00 399.99 245.99 0 34 S 74 50 W 500.00 499.99 345.99 0 43 S 65 41 W 600.00 599.98 445.98 0 41 S 68 10 W 700.00 699.97 545.97 0 50 S 73 25 W 800.00 799.96 645.96 0 54 S 72 14 W 900.00 899.95 745.95 0 58 S 70 24 W S 59 51 W -5.07 S 4 22 W -4.77 S 29 I E -0.62 S 33 31 E 8.27 S 33 59 E 21.99 S 38 20 E 46.82 S 38 14 E 79.23 S 37 18 E 119.44 S 39 9 E 165.89 S 42 51 E 217.77 1000.00 999.93 845.93 0 53 1100,.00 1099.92 945.92 I 29 1Z00.00 1199.80 1045.80 3 58 1300.00 1299.36 1145.36 6 21 1400o00 1398.33 1244.33 11 3 1500.00 1495.04 1341.04 17 17 1600.00 1589.50 1435.50 21 7 1700.00 1680.78 1526.78 26 28 1800.00 1769.01 1615.01 29 54 1900.00 1854.29 1700.29 33 18 S 45 ZB E 275.02 S 46 48 E 333.64 S 47 16 E 395.22 S 46 12 E 460.33 S 44 31 E 529.10 S 44 21 E 601.76 S 44 37 E 678°06 S 44 28 E 756.62 S 43 57 5 834.65 S 44 9 E 912.18 2000.00 1936.23 1782.23 35 41 ZlO0.O0 2017.24 1363.24 36 35 ZZO0.O0 2096.01 1942.01 39 45 2300.00 2171.90 2017.90 41 40 2400.00 2244.44 2090.44 45 29 2500.00 2313.06 2159.06 47 44 2600.00 2377.58 2223.58 51 41 2700.00 2439.36 2285.36 51 38 2800.00 2501.79 2347.79 51 6 2900.00 2564.81 2410.81 51 7 S 47 28 E 991.78 S 47 22 E 1073.28 S 47 2 E 1155.02 S 46 31 E 1236.62 S 45 43 E 1317.81 S 45 14 E 1398.56 S 44 35 E 1478.81 S 44 27 E 1559.40 S 44 26 E 1540.64 S 44 25 E 1722.47 0.30 3.03 S 2.34 4.46 S 2.52 8.82 S 1.79 16.59 S 8.87 28.39 S 4.15 48.59 S 5.31 74.23 S 2.78 106.45 S 4.01 143.52 S 5.64 0.83 2.11 2.73 3.13 3.75 2.21 1.85 0.79 0.77 2.58 0.00 N 0 0 E 0.13 N 34 7 W 0.74 N 76 17 W 1.17 S 89 21 W 1.90 S 85 59 W 3.03 S 79 54 W 4.15 S 76 2 W 5.50 S 74 47 W 6.99 S 74 23 W 8.62 S 73 53 W 9.78 W 10.24 S 72 47 W 10.70 W 11.59 S 67 22 W 9.10 W 12.67 S 45 52 W 4.19 W 17.11 S 14 10 W 3.56 E ZB.61 S 7 9 E 18.67 E 52.05 S 21 1 E 39.06 E 83.88 S 27 45 E 63.98 E 124.20 S 31 0 E 92.91 E 170.97 S 32 55 E 183.08 S 126.95 E 222.79 S 34 44 E 1.64 0.45 0.26 0.74 0.73 0.70 0.61 0.43 0.68 0.67 3000.00 2625.28 2471.28 54 15 3100.00 2683.22 2529.22 54 46 3200.00 2740.84 2586.84 54 49 3300.00 2798.63 2644.63 54 29 3400.00 2857.00 2703.00 54 8 3500.00 2915.95 2761.95 53 35 3600.00 2975.54 2821.54 53 24 3700.00 3034.64 2880.64 54 8 3~JO0.O0 3092.86 2938.86 54 42 3900.00 3150.22 2996.22 55 17 223.87 S 167.19 E 279.41 S 36 45 E 264.57 S 209.38 E 337.40 S 38 21 E 306.36 S 254.61 E 398.35 S 39 44 E 350.98 S 302.03 5 463.04 S 40 43 E 399.36 S 350.94 E 531.65 S 41 18 E ) 451.35 S 401.80 5 604.29 S 41 41 E 505.90 S 455.25 E 680.58 S 41 59 E 561.91 S 510.44 5 759.14 S 42 15 E 617.90 S 554.91 E 837.21 S 42 26 E 673.90 S 618.70 E 914.84 S 42 33 E 729.15 S 676.02 E 994.31 S 42 50 5 784.22 S 736.09 E 1075.57 S 43 11 E 839.76 S 796.06 5 1157.11 S 43 28 E 895.61 S 855.56 E 1238.59 S 43 41 E 951.93 S 914.05 E 1319.72 S 43 50 E 1008.61 $ 971.60 i 1400.47 S 43 56 E 1065.51 S 1028.26 E 1480.76 S 43 59 5 1123.05 S 1084.80 E 1561.42 S 44 0 E 1181.13 S 1141.71 E 1642.73 S 44 2 E 1239.65 S 1199.02 5 1724.64 S 44 3 E 'COMPUTATION DATE: 4-JAN-90 PAGE Z, ARCO ALASKA, INC. 2K-17 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 25-0EC-1989 KELLY BUSHING ELEVATION: 154.00 ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR caoRDINAT~S HgRIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000.00 3207.81 3053.B1 53 57 4100.00 3267.23 3113.23 53 23 4200.00 3326.84 3172.84 53 27 4300.00 3386.28 3232.28 53 33 4400.00 3445.82 3291.82 53 24 4500.00 3505.54 3351.54 53 13 4600.00 3555.54 3411.54 53 5 4700.00 3625.63 3471.63 53 4 4800.00 3685.62 3531.62 53 12 4900.00 3745.40 3591.40 53 22 5000.00 3805.01 3651.01 53 27 5100.00 3864.45 3710.45 53 33 5200.00 3924.23 3770.23 53 0 5300.00 3984.48 3830.48 52 56 5400.00 4044.91 3890.91 52 40 5500.00 4106.01 3952.01 52 5 · 5600.00 4167.52 4013.52 52 0 5700.00 4229.13 4075.13 51 57 5800.00 6290.79 4136.79 51 57 5900.00 4352.37 4198.37 52 3 6000.00 4413.82 4259.82 52 9 6100.00 4475.06 4321.06 52 18 6200.00 4536.07 4382.07 52 30 6300.00 4596.84 4442.84 52 39 6400.00 4657.51 4503.51 52 36 6500.00 4719.09 4565.09 51 18 6600.00 4781.78 4627.78 51 10 6700.00 4844.46 4690.46 51 9 6800.00 4907.11 4753.11 51 22 6900.00 4969.28 4815.28 51 41 7000.00 5031.04 4877.04 52 3 7100.00 5092.46 4938.46 52 2 7200.00 5155.78 5001.78 49 29 7300.00 5221.20 5067.20 48 57 7400.00 5286.97 5132.97 48 46 7500.00 5353.00 5199.00 48 44 7600.00 5418.68 5264.68 49 8 7700.00 5483.91 5329.91 49 30 7800.00 5548.67 5394.67 49 46 7900.00 5613.08 5459.08 50 0 DEG MIN FEET DEG/IO0 S 44 5'7 ~: 1804.15 S 45 19 E 1884.54 S 45 39 E 1964.80 S 45 57 E 2045.21 S 46 37 E 2125.54 S 47 20 E 2205.75 S 47 59 E 2285.74 S 48 19 E 2365.66 S 48 41 E 2445.64 S 49 1 E 2525.75 S 49 18 E 2605.99 S 49 25 E 2686.32 S 47 46 E 2766.45 S 4.7 34 E 2846.26 S 47 29 E 2925.93 S 45 25 E 3005.07 S 45 1'-) E 3083.89 S 45 30 E 3162.63 S 45 46 E 3241.34 S 45 56 E 3320.12 S 46 6 E 3399.00 S 46 21 E 3478.04 S 46 37 E 3557.28 S 46 46 E 3.636.69 S 47 2 E 3716.19 S 4.8 12 E 3794.96 S 48 29 E 387Z.85 S 48 39 E 3950.73 S 48 49 E 4028.64 S 49 7 E 4106.92 S 49 ZO E 4185.50 S 49 38 E 4264.34 S 49 31 E 4341.63 S 49 24 E 4417.20 S 49 45 E 4492.44 S 49 59 E 4567.45- S 50 14 E 4642.74 S 50 31 E 4718.40 S 50 40 E 4794.43 S 50 57 E 4870.75 2.13 0.24 0.18 0.45 0.47 0.92 0.33 0.25 0.41 0.18 0.32 0.54 1.10 0.13 0.93 1.07 0.19 0.21 0.22 0.25 0.22 0.31 O.1B 0.20 0.47 1.11 0.14 0.32 0.42 0.47 0.26 0.99 1.78 0.40 0.64 0.44 0.36 0.44 0.42 0.39 FEET FEET FEET DEG MIN 1297.87 S 1256.40 E 1806.38 S 64 4 E 1354.58 S 1313.43 E 1886.80 S 44 7 E 1410.88 S 1370.68 E 1967.07 'S 44 10 E 1466.97 S 1428.31 E 2047.45 S 44 14 E 1522.51 S 1486.37 E 2127.75 S 44 19 E 1577.29 S 1544.96 E 2207.88 S 44 24 E 1631.13 S 1604.12 E 2287.75 S 44 31 E 1684.46 S 1663.66 E 2367.53 S 44 39 E 1737.50 S 1723.56 E 2447.36 S 44 46 E 1790.23 S 1783.94 E 2527.32 S 44 54 E 1842.76 S 1844.66 E 2607.40 S 45 2 E 1895.09 S 1905.72 E 2687.59 S 45 10 E 1948.04 S 1965.90 E 2767.61 S 45 16 E 2001.90 S 2024.80 E 2847.36 S 45 20 E 2055.64 S 2083.64 E 2926.98 S 45 23 E 2110.21 S 2140.96 E 3006.11 S 45 25 E 2165.70 S 2196.98 E 3084.96 S 45 25 E 2221.01 S 2253.06 E 3163.72 S 45 25 E 2276.06 S 2309.35 E 3242.46 S 45 25 E 2330.94 S 2365.88 E 3321.25 S 45 26 E 2385.75 S 2422.63 E 3400.13 S 45 26 E 2440.46 S 2479.68 E 3479.18 S 45 27 E 2495.01 S 2537.15 E 3558.40 S 45 29 E 2549.49 S 2594.93 E 3637.79 S 45 30 E 2603.85 S 2652.93 E 3717.27 S 45 32 E ) 2656.98 S 2711.11 E 3796.00 S 45 35 E 2708.73 S 2769.35 E 3873.83 S 45 38 E 2760.30 S 2827.76 E 3951.64 S 45 42 E 2811.73 S 2886.33 E 4029.48 S 45 45 E 2863.17 S 2945.39 E 4107.69 S 45 49 E 2914.53 S 3004.95 E 418,6.20 S 45 53 E 2965.84 S 3064.91 E 4264.96 S 45 56 E 3015.8=~ S 3123.94 E 4342.18 S 46 0 E 3065.17 S 3181.31 E 4417.69 S 46 4 E 3114.03 S 3238.64 E 4492.88 S 46 7 E 3162.43 S 3296.06 E 4567.82 S 46 11 E 3210.82 S 3353.90 E 4643.06 S 45 15 E 3259.15 S 3412.28 E 4718.66 S 46 19 E 3307.54 S 3471.14 E 4794.65 S 46 23 E 3355.89 S 3530.41 E 4870.92 S 46 27 E COMPUTATION DATE: 4-JAN-g0 PAGE 3- ARCO ALASKAt INC. ZK-17 KUPARUK NORTH SLOPEr ALASKA DATE OF SURVEY: 25-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT' ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG REC'TANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EaST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 5677.36 5523.36 50 3 8100.00 5741.63 5587.63 49 55 8200.00 5806.09 5652°09 69 49 8300.00 5870°54 5716.54 49 59 8400°00 5934.83 5780.83 49 56 8500.00 5999.21 5845.21 49 56 8600°00 6063.¢$ 5909.46 50 7 8700.00 6127.99 5973.99 49 30 8800.00 6193.14 6039.14 49 11 8900°00 6258.56 6104.56 49 7 S 51 2 E 4947.16 S 51 19 E 5023.57 S 51 47 E 5099.77 S 52 11 E 5175.94 S 52 40 E 5252.17 S 53 7 E 5328.27 S 53 10 E 5404.45 S 52 57 E 5480.41 S 52 59 E 5555.95 S 53 8 E 5631.05 0.38 0.33 0.41 0.49 0.30 0.15 0.07 0.59 0.32 0.08 3404°09 S 35~9.95 E 4947°28 S 46 31 E 3452.15 S 3649.62 E 5023.65 S 46 36 E 3499.69 S 3709.49 E 5099.82 S 46 40 E 3546.79 S 3769.73 E 5175.96 S 46 45 E 5252.17 S 46 50 E ~) S 38.30.44 3639.64 S 3891.47 E 5328.27 S 46 55 E 3685.60 S 3952.78 E 5404.46 S 47 0 E 3731.49 S 4013.86 E 5480.43 S 47 5 E 3777.23 S ~074.38 E 5555.90 S 47 10 E 3822.65 S 4134.84 E 5631.14 S 47 15 E 9000°00 6324.00 6170.00 49 9 9100.00 5389.41 6235.41 49 9 9145.00 6418.84 6264.84 49 9 S 53 7 E 5706.15 S 53 7 E 5781.36 S 53 7 E 5815.20 0.00 0.00 0.00 3868.00 S 4195.28 E 5706.30 S 47 19 E 3913.40 S 42.55.78 E 5781.56 S 47 24 E 3933.84 S ~283.01 E 5815.43 S 47 26 E CDMPUTATION DATE: 4-JAN-90 ARCO ALASKA, INC. 2K-17 KUPARUK NORTH SLOPE, ALASKA DATE DF SURVEY: ZS-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT, INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0,00 -154.00 0 0 1000.00 999.93 845.93 0 53 2000.00 1936.23 1782.23 35 41 3000.00 2625.28 2471.28 54 15 ENGINEER: MCBRIDE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 0.00 S 59 51 W -5.07 0.30 S 45 28 E 275.02 0,83 S 47 28 E 991.78 1.64 0.00 N 0.00 E 0.00 N 0 0 E 3.03 S 9.78 W 10.24 S 72 47 W 223.87 S 167.19 E 279.41 S 36 45 E 729.15 S 676.02 E 994.31 S 42 50 E 6000.00 3207.81 3053.81 53 57 5000.00 380~.01 3651.01 53 27 6000.00 4613.82 4259.82 52 9 7000.00 5031.04 4877.04 52 3 8000.00 5677.36 5523.36 50 3 9000.00 6324.00 6170.00 49 9 9145.00 6418.84 6264.84 69 9 S 64 57 E 1804.15 S 69 18 E 2605.99 S 46 6 E 3399.00 S 49 20 E 4185.50 S 51 Z E 4947.16 S 53 7 E 5706.15 S 53 7 E 5815.20 2.13 0.32 0.22 0.26 0.38 0.00 0.00 1297.87 S 1256.40 E 1806.38 S 46 4 E ) 1862.76 S 1844.66 E 2607.40 S 45 2 E Z385.75 S Z422.63 E 3400.13 S 45 Z6 E 2916.53 S 3004.95 E t186.20 S 45 53 E 3404.09 S 3589.95 E 6947.28 S 66 31 E 3868.00 S 4195.28 E 5706.30 S 47 19 E 3933.84 S 4283.01 E 5815.43 S 47 26 E COMPUTATION DATE: 4-JAN-90 PAGE ARCO ALASKA, INC. 2K-17 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 25-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT ' ENGINEER: MCiBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF'SUB-SE~ DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL OEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICA~L DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEC~TION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 ;EET FEET FEET DEG MIN 0.00 0.00 -154.00 0 0 N 0 0 ~ 154.00 154.00 0.00 0 27 N 33 51 W 254.00 254.00 100.00 0 15 S 64 45 W 354.00 354.00 200.00 0 27 S 81 52'W 454.0! 454.00 300.00 0 41 S 69 45 W 554.02 554.00 400.00 0 38 S 65 16 W 654°02 654.00 500.00 0 47 S 71 5 W 754.03 754.00 600.00 0 51 S 72 52 W 854.05 854.00 700.00 0 56 S 71 52 W 954.06 954.00 800.00 0 57 S 67 42 W 0.00 0.00 0.00 N 0.00 E -0.43 0.56 0.22 N 0.37 W -0.74 0.23 0.04 N 0.97 W -1.06 0.36 0.05 S 1.50 W -1.58 0.22 0.32 $ 2.46 W -2.05 0.29 0.80 S 3.55 W -2.57 0.29 1.24 S 4.68 W -3.29 0.05 1.67 S 6.07 W -4.06 0.03 2.15 .S 7.56 W -4.31 0.18 2.71 S 9.12 W 0.00 N 0 0 E 0.44 N 59 15 W 0.97 N 87 43 W 1.50 S 88 14 W 2.48 S 82 42 W ) 3.64 S 77 21 W 4.84 S 75 7 W 6.29 S 74 36 W 7.86 S 74 9 W 9.52 S 73 27 W 1054.07 1054.00 900.00 0 58 1154.12 1154.00 1000.00 2 50 1254.39 1254.00 1100.00 5 29 1355.07 1354.00 1200.00 8 5 1457.22 1454.00 1300.00 15 17 1562.16 1554.00 1400.00 19 31 1670.22 1654.00 1500.00 25 24 1782.71 1754.00 1600.00 29 15 1899.66 1854.00 1700.00 33 17 2021.86 1954.00 1800.00 35 34 S 36 18 W S 20 53 E S 32 42 E S 33 3 E S 37 9 E S 38 36 E S 37 33 E S 38 40 E S 42 50 E S 45 38 E -5.17 1.29 3.57 S -3.16 3.29 6.39 S 3.69 2.23 12.65 S 14.. 91 4.93 22.31 S 34.91 5.77 39.06 S 66.28 3.25 63.97 S 106.60 4.48 96.11 S 157.39 4.55 136.86 S 217.59 5.63 287.76 0.82 10.43 W 11.02 S 71 5 W 10.29 W 12.11 S 58 13 W 6.77 W 14.35 S 28 11 W 0.44 W 22.31 S I 8 W 11.26 E 40.66 S 16 5 E 30.92 E 71.05 S 25 48 E 56.07 E 111.27 S 30 16 E 87.51 E 162.45 S 32 36 E 182.95 S 126.82 E 222.61 S 34 44 E 232.79 S 1'76.28 E 292.00 S 37 8 E 2146.12 2054.00 1900.00 37 47 2276.13 2154.00 2000.00 ¢1 2 2413.70 2254.00 2100.00 45 54 2562.50 2354.00 2200.00 50 25 2723.56 2454.00 2300.00 51 29 2882.83 2554.00 2400.00 50 57 3049.42 2654.00 2500.00 54 40 3222.84 2754.00 2600.00 54 48 3394.87 2854.00 2700.00 54 9 3563.89 2954.00 2800.00 53 20 S 47 23 E 361.49 S 46 31 E 444.54 S 44 26 E 538.$9 S 44 26 E 648.92 S 44 21 E 775.06 S 43 54 r- 89 (3.86 S 47 34 E 1032.00 $ 46 5'3 E 1173.68 S 45 45 E 1313.65 S 44 46 E 1449.86 3.56 2.72 2.75 4.92 0.55 1.38 0.45 0.27 0.69 0.90 283.53 S 229.79 E 364.95 S 39 I E 340.07 S 290.61 E 447.33 S 40 31 E 406.36 S 357.81 E 541.44 S 41 22 E 485.11 S 434.80 E 651.45 S 41 52 E 575.09 S 523.36 E 777.59 S 42 18 E 664.29 S 609.4~ E 901.50 S 42 32 E 756.30 S 705.68 E 1034.40 S 43 1 E 852.49 S 809.71 E 1175.74 S 43 32 E 949.03 S 911.07 E 1315.56 S 43 50 E 1044.91 S 1007.90 E 1451.79 S 43 58 E 3733.09 3054.00 2900.00 54 18 3906.64 3154.00 3000.00 55 20 4077.81 3254.00 3100.00 53 24 4245.66 3354.00 3200.00 53 33 4413.72 3454.00 3300.00 53 23 4580.78 3554.00 3400.00 53 5 4747.26 3654.00 3500.00 53 8 4914.41 3754.00 3600.00 53 23 5082.41 3854.00 3700.00 53 36 5249.42 3954.00 3800.00 52 56 S 44 25 E 1586.22 S 44 25 E 1727.92 S 45 15 E 1866.73 S 45 45 E 2001.50 S 46 42 E 2136.55 S 47 53 E 2270.38 S 48 28 E 2403.44 S 49 3 E 2537.30 S 49 32 E 2672.19 S 47 29 E 2805.90 0.57 0.73 0.21 0.39 0.43 0.37 0.32 0.18 0.05 0.28 1142.22 S 1103.59 E 1588.26 S 44 i E 1243.55 S 1202.84 E 1730.10 S 44 3 E 1342.05 S 1300.78 E 1868.99 S 44 6 E 1436.52 S 1396.94 E 2003.75 S 44 12 E 1530.08 S 1494.36 E 2138.75 S 44 19 E 1620.83 S 1592.72 E 2272.41 S 44 30 E 1709.56 S 1691.92 E 7_405.24 S 44 42 E 1797.81 S 1792.67 E 2538.85 S 44 55 E 1885.88 S 1894.99 E 2673.48 S 45 8 E 1974.64 S 1995.04 E 2807.03 S 45 18 E COMPUTATION DATE: 4-JAN-90 PAgE 6~ ARCO ALASKA, INC. 2K-17 KELLY BUSHING ELEVATION: 154.00 F'T ' KUPARUK NORTH SLOPE9 ALASKA ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG REC'TANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET OEG/IO0 FEET FEET FEET DEG MIN 5414.96 4054.00 3900.00 52 33 5578.03 4154.00 4000.00 52 1 5740.33 4254.00 4100.00 51 55 5902.66 4354.00 4200.00 52 3 6065.57 4454.00 4300.00 52 16 6229.46 4554.00 4400.00 52 32 6394.22 4654.00 4500.00 52 37 6555.71 4754.00 4600.00 51 9 6715.21 4854.00 4700.00 51 8 6875.37 4954.00 4800.00 51 38 7037.37 5054.00 4900.00 52 8 7197.27 5154.00 5000°00 49 31 7349.91 5254.00 5100.00 48 53 7501.52 5354.00 5200.00 48 44 7654.06 5454.00 5300.00 49 17' 7808°26 5554.00 5400.00 49 47 7963.65 5654.00 5500.00 49 58 8119.21 5754.00 5600.00 49 54 8274.31 5854.00 5700.00 49 55 8429.77 5954.00 5800.00 49 55 8585.26 6054.00 5900.00 50 6 8740.00 6154.00 6000.00 49 22 8893.03 6254.00 6100.00 49 8 9045.86 6354.00 6200.00 49 9 9145.00 6418.84 6264.84 49 9 S 47 12 E 2937.80 S 45 16 E 3066.58 S 45 38 E 3194.37 S 45 56 E 3.322.21 S 46 14 E 3450.81 S 46 40 E 3580.65 S 47 0 E 3711.59 S 48 25 E 3838.37 S 48 41 E 3962.58 S 49 2 E 4087.61 S 49 24 E 4214.96 S 49 33 E 4339.56 S 49 35 E 4454.78 S 49 59 E 4568.59 S 50 25 E 4683.59 S 50 41 E 4800.73 S ~1 3 E 4919.38 S 51 24 E 5038.22 S 52 6 E 5156.36 S 52 48 E 5274.84 S 53 10 E 5393.21 S 52 53 E 5510.62 S 53 8 E 5625.81 S 53 7 E 5740.64 S 53 7 E 5815.20 1.67 0.28 0.25 0.24 0.28 0.22 0.44 0.14 0.39 0.40 0.27 1.97_ 0.28 0 0.54 0.37 0.02 0.38 0.40 0.38 0.17 0.29 0.03 0.00 0.00 DATE OF SURVEY: 25-DEC-1989 2063.71 S 2092.35 E 2938.85 S 45 24 E 2153.52 S 2.184.67 E 3067.64 S 45 25 E 2243.24 S 2275.73 E 3195.47 S 45 25 E 2332.40 S 23~$7.39 E 3323.34 S 45 26 E 2421.64 S 2460.00 E 3451.95 S 45 27 E 2511.06 S 2554.14 E 3581.77 S 45 29 E 2600.72 S 2649.58 E 3712.68 S 45 32 E 26~5.85 S 2743.54 E 3839.37 S 45 37 E 2768.12 S 2836.66 E 3963.48 S 45 42 E 2850.52 S 2930.80 E 4088.40 S 45 48 E 2933.74 S 3027.33 E 4215.63 S 45 54 E 3014.54 S 3122.36 E 4340.11 S 46 0 E 3089.62 S 3209.90 E 4455.24 S 46 6 E 3163.17 S 3296.93 E 4568.96 S 46 ll E 3236.95 S 3385.39 E 4683.88 S 46 17 E 3311.53 S 13476.02 E 4800.93 S 46 23 E 3386.58 S 3568.30 E 4919.52 S 46 30 E 3461.33 S 3661.10 E 5038.30 S 46 36 E 3534.72 S 3754.21 E 5156.39 S 46 43 E 3607.28 S 3848.57 E 5274.84 S 46 51 E 3678.82 S 3943.73 E 5393.21 S 46 59 E 3749.81 S 4038.10 E 5510.66 S 47 7 E 3819.52 S 4130.62 E 5625.90 S 47 14 E 3888.8Z S 4223.03 E 5740.81 S 47 22 E 3933.84 S 4283.01 E 5815.43 S 47 Z6 E ) ARCO ALASKA, INC. 2K-17 KUPARUK NORTH SLOPEr ALASKA MA~KER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A GCT LAST READING BASE KUPARUK A PBTD 7# CASING TD COMPUTATION DATE: 4-JAN-90 PAGE 7, DATE OF SURVEY: 25-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT~ ENGINEER: MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 169' FNL & 94' FEL, SEC11 TION RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3563.00 8761.00 8773.00 8817.00 8980.65 9011.00 9129.00 9145.00 2953.47 2799.47 6167.6B 6013.68 6175.51 6021.51 620~.25 6050.25 6311.35 6157.35 6331.20 61T7.20 6354.74 62D0.74 6408.38 6254.38 6418.84 6264.8,4 1044.40 S 3759.43 S 3764.91 S 3784.98 S 3859.21 S 3872.99 S 3889.34 S 3926.57 S 3933.84 S 1007.39 E 4050.80 E 4058.06 E 4084.65 E 4183.58 E 4201.94 E 4223.72 E 4273.33 E 4183.01 E ARCO ALASKA, INC. 2K-17 KUPARUK NORTH SLOPEr ALASKA MARKER TOP KUP~RUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK a PBTD TD COMPUTATION DATE: 4-JAN-gO PAGE 8 O.~,TE OF SURVEY: 25-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT. ENGINEER: MCBRIDE ***********~ STRATIGRAPHIC SUMMARY SURFACE LOC.~T[DN = 169~ FNL & 94" FEL~ SEC11 TJON RSE MEASURED DEPTH BELOW KB TVO FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 8761.00 8773.00 8817.00 9011.00 9047.00 91&5.00 6167.68 6013o68 6175.51 6021.51 6Z04.25 6050.25 6331.Z0 6177.20 6354.74 6200.74 6418.8~ ~ 6264.8~ 3759.43 S 3764o91 S 3784.98 S 3872.99 S 3889.34 S 3933° 84 S 4050.80 E 4058.06 E 4084.65 E &223.72 E ~283.01 E FINAL WELL LOC6TION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9145.00 6418.84 6264.8~ HORIZONTAL DEPARTURE DISTANCE AZIMUTH t:EET DEG MIN 5815.43 S 47 26 E SCHLUMBERGER O I RECT I ONAL SURV E Y COMPANY ARCO ALASKA. IN'c. · NELL 2K- 17 FIELO KUPARUK COUNTRY USA RUN ONE BATE LOOOEO 2S - DEC - 89 REFERENCE 73623 WELL · 2K-' 17 ~(169''FNL, 94' FEL, SEC ll, TION, R8E, UM) ---RIZONTAL PROJECTION NOR'IH BO00 REF 7982~ SCALE : 1/ID00 IN/FT 2OO0 1000 -2000 -9OO0 -4000 SOUTH -BO00 -2000 -1000 1000 2000 9000 4000 SO00 BO00 £~T WELl' 2K-17~-' ~-~"ERTICAL PROJECTION (169J FNL, 94' FEL, SEC l~, TION, R8E, UM) 313. - 1000 0 0 1000 2000 3000 4000 SO00_ 6000 7000 · 4--4--4.-b- ..4..4..4..4...: .4H..4..-Hb4.-4..4-.4..~ ..&4..4..4... ,.4..4,4..4 ...... ~...g-4..4..4~4..4..4..4~x-.4.-.,..4.-~..4...~.~..&-¢-..4..4..4..4.w..4..4.4.-~ ...... 4..~..-[..4..4.-~..4..-~..4...~ ...~..4..-[....u -~- 4...~...:}..4..- ,.4.-p4.-[.-..,-4..4..4....~ ...... ~k-4-.--b.'.--.;.-,-~--4 ........ b.4..4..-m.,~ .-4..4.--b.4 ...... -4 $---.~--4---~ ....... ~....p-b.4.--,..4...4..4.--~ ..... ~..4.-4-.4 ...... ~--4.-;,.4 ...... ;.-4..4..-.[.--~ ..4..2,.4..4 ........ ;....F..-F,.; ........ }..4 ........ ; ....... ~ ;.,..h.4....~ ...... 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'f'+'+'"~"' ........ ~ ~ :: : , ;i ..... ~ i i i i i i i ~ : ~ ~ ~ ill'~; i i i i i I ~ ~ ~ ~ ~ .--H-.-b-i---.-44.-4..4-..i---b~4--+--.-H4-4----4.--bN--~-..H---b-i ........ N--4.-4.--bb-b4--b.i-+4.4-4 ........ H-H-.. ~ ~ ~ .... [..4..+..~ ........ ~..H..-~ ....... ~.-.*...~...~ ........ ~,...i+..~.-. II PROJECTION ON VERTICAL PLANE 133. - 313. SCALED IN VERTICPi. OEPIHS HORIZ SCALE = I/1000 [N/FT 133. PERMIT ~ ~ ~' - COMPLETIONu~," ,,-r,. WELL NAME ~a CO. C OI'.rTACT I " ^o~cc GEOLOGICAL MATEI~IALS INVENTORY LIST [ check off or list data as it is received ~ .o~ ! .;,~-?~o drilling history ~-"~ survey I ~ ~" tests, ! core' desription I cored i~te~als core an~!~sis . .. d~ ditch ~nte~als. digital data . I .... I ........... LOG TYPE RU'N INTERVALS .' SCALE NO. ii i i i 2] h '- ~, ~'~ ~,..~ ~,~,- ~ 6~,~ / ~~ ' ~ fi/, ~/ .~"+ ~". / xo ,, lO) 11] 121 ~31 ......... , 1 4) ... 1~] ............. 16] ,. , ,, ARCO Alaska, Inc. Date: January 5, 1990 Transmittal #: 7640 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 03 ' Acoustic Cement Bond Log 9 - 26 - 89 6894 - 8742 2 K - 04 Acoustic Cement Bond Log I I - 04 - 89 9000 - 10703 2 K - 14 Acoustic Cement Bond Log 1 I - 05 - 89 5019 - 8042 2K-1 7 CBT 1 2-25-89 7245-9018 2K-20 CER' I 2-24-89 7889-9698 2K-22 CBT I 2-24-89 7923-9708 Receipt Acknowledged: DISTRIBUTION; NSK Drilling RECEIVED JAN ! 2 .'l.;gO Alaska 0il ~ 13as Cons. C0mmissi Anchorage STATE OF ALASKA ~ A~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown .~ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program_ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well' 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Exploratory Stratigraphic Service 4. Location of well at surface 169' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1375' FSL, 1357' FEL, Sec. 12, T10N, R8E, UM At effective depth 1222' FSL, 1157' FEL, Sec. 12, T10N, R8E, UM At total depth 1177' FSL, 1099' FEL, Sec. 12,T10N, R8E, UM (approx) (approx) (approx) RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-17 feet 12. Present well condition summary Total Depth: measured 9145' feet Plugs (measured) (approx) true vertical 6427' feet None Effective depth: measured (approx) true vertical 9047' feet Junk (measured) 63 63' feet None 9. Permit number 89-119 10. APl number 50-103-20121 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3563' 2956' (approx) 91 29' 6416' (approx) Casing Length Size Cemented Structural 8 0' 1 6" Conductor Surface 3528' 9 5/8" 1100 Sx AS III & Intermediate 450 Sx Class G Production 9096' 7" 250 Sx Class G Liner Perforation depth: measured true vertical RECEIVED Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None None BOP sketch Description summary of proposal 13. Attachments Date approved 15. Detailed operation program Status of well classification as: Oil X Gas __ 14. Estimated date for commencing operation February, 1990 16. If proposal was verbally approved Date Suspended _ Name of approver Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~ ~ ~ Title Area Drillincj Encjineer FOR COMMISSION USE ONLY Commissioner Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require IIAppr°val N~,._/O/~.,~_ . Date /~ -) 7 ~? SUBMIT IN TRIPLICATE Approved by the order of the Commission Uflt6iNAL SIGNED SY LONNIE C. SMITH Form 10-403 Rev 06/15/88 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. KUPARUK RIVER UNIT County. parish or borough NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 Tit e J State KRU 2K-17 IWell no, Auth. or W.O. no. AK4290 Operator ~CO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 11/15/89 (1) TD: 1454'( 1454 SUPV:SC 11/16/89 (2) TD: 3583'( 2129 SUPV:CD 11/17/89 ( 3) TD: 3583'( 0 SUPV:CD 11/18/89 ( 4) TD: 5319'( 1736 SUPV:CD 11/19/89 ( 5) TD: 8468'( 3149 SUPV:CD 11/20/89 ( 6) TD: 9127'( 659 SUPV:CD 11/21/89 (7) TD: 9145'( 18 SUPV:CD 11/22/89 ( 8) TD: 9047'( SUPV:CD IDate Hour 11/14/89 18:30 Complete record for each day reported DOYON 14 IARCO W.L 55 .8533 Prior status if a W,O. DRLG 12.25" HOLE MW: 8.9 VIS: 89 MOVED 2K19 TO 2K17, RU DIVERTER, SPUD @ 1830HRS 11/14/89, DRLG DAILY:S71,767 CUM:$71,767 ETD:S71,767 EFC:$1,201 POOH FOR HOLE OPENER MW: 9.3 VIS:102 DRLG F/ 1454 T/3583, CIRC, POOH F/ HOLE OPENER DAILY:S75,330 CUM:$147,097 ETD:S147,097 EFC:$1,201 TESTING BOPE MW: 9.4 VIS: 52 C.O. BHA, RIH W/ OPEN HOLE REAMER, CIRC.HOLE CLEAN, POOH F/ CSG, RUN 90 JTS 9 5/8 36# J55 BTC CSG, CMT W/ 1100 SX LEAD + 450 SX TAIL, BUMPED PLUG, NO CMT TO SURFACE, ND DIVERTER, NU BOP, TEST BOPE. DAILY:S200,766 CUM:$347,863 ETD:S347,863 EFC:$1,201 DRLG MW: 9.1 VIS: 33 CHANGED RAMS, TEST RAMS & KELLY TO 3000PSI, INSTALL WEAR BUSHINGS, PU BHA, TIH, CUT DRLG LINE, TIH , DRLG F.E. AND CMT + 10' NEW HOLE, TEST FMTN., DRLG F/3593 T/ 5319. DAILY:S72,794 CUM:$420,657 ETD:S420,657 EFC:$1,201 CIRC. TO SHORT TRIP MW: 9.5 VIS: 34 DRLG F/ 5319 T/ 8468, CIRC BEFORE SHORT TRIP. DAILY:S53,189 CUM:$473,846 ETD:S473,846 EFC:$1,201 DRLG MW:10.1 VIS: 36 POOH TO SHOE, CIRC AND TEST FORMATION TO 10.6 EMW, DRLG 8468 - 9127. DAILY:S70,483 CUM:$544,329 ETD:S544,329 EFC:$1,201 SHORT TRIP MW:10.1 VIS: 36 DRLG F/9127 T/ TD.,CIRC, SHORT TRIP,CIRC.,POOH &LD TURBINE, RUN LOGS IN 8.5" HOLE, TIH, CIRC, SHORT TRIP - TIGHT SPOT ON BOTTOM DAILY:S112,468 CUM:$656,797 ETD:S656,797 EFC:$1,201 MONITOR WELL MW: 9.9 VIS: 34 TIH, REAM TO BOTTOM, CIRC, SPOT DIESEL PILL, POOH LDDP,RUN 231 JTS 7"26# J55 BTC CSG, SET @ 9129, PBTD 9047, ATTEMPT TO CIRC-LOST RETURNS, CMT W/ 250SX CLASS G CMT, 52 BBLS SLURRY, DISP W/ BRINE,BUMPED PLUG TO 3500,OK, WELL FLOWING AFTER BUMPED PLUG, MONITORING WELL. DAILY:S228,590 CUM:$885,387 ETD:S885,387 EFC:$1,201 The above is correct Signatur~....~ For form preparatiolFl~nd distribution~----~ see Procedures Mah~l, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D consecutively las they are prepared for each well. INumbor all daily well history f .... I iPage no. ARCO O,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time+ On workovers when an oHicial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District State ARCO ALASKA INC. /AK ! Field KUPARUK RIVER UNIT Auth. or W.O. no. AK4290 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. County or Parish NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 T tie KRU 2K-17 IWell no 11/23/89 ( TD: 9047 PB: 9047 SUPV:CD A.RCo. W.I. 55.8533 Date 11/14/89 Complete record for each day reported DOYON 14 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this wetl our Prior status if a W.O. 18:30 RIG RELEASED MW: 9.9 NaC1 MONITORED FLOWING WELL ON ANNULUS SIDE, GIVING BACK MUD FROM CHARGED FORMATION PU STACK INSTALL CSG SLIPS & PACK-OFF, TEST TO 3000#,OK RIG RELEASED @1230HRS ON 11/22/89 DAILY:S20,550 CUM:$905,937 ETD:S905,937 EFC:$905,937 Old TD I New TD PB Depth Released rig I Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method I Official reservo r name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signaturi~ ~ Date / ~,.// sFeOer fpOr~ced u res M ant~aln, dsed~:~n u~o, n, -- 0- 0 Drilling, Pages 86 and 87, AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each wall. Page no. DIvIMon of AtlantfcRIchfleldCompany ARCO Alaska, Inc. Date: December 8, 1989 Transmittal #: 7623 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 7 OH Edit Tape and Listing 1 1 - 2 0 - 8 9 # 7 3 5 5 5 2 K - 2 2 OH Edit Tape and Listing 1 1 - 3 0 - 8 9 # 7 3 5 7 3 Receipt Acknowledged te' DISTRIBUTION: Lynn Goettinger State of Alaska RECEIV£D DEC ! 1_ 1989 Alaska Oil & Gas Cons. Comml~lo~ Anchorage ARCO Alaska, Inc. Date: November 28, 1989 Transmittal #: 7617 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-1 7 2" Dual Induction- SFL 1 1 -20-89 975-91 33 2K-1 7 5" Dual Induction- SFL 1 1 -20-89 975-91 33 2K-1 7 RawFDC 1 1 -20-89 8500-91 09 2K-1 7 5" Cyberlook 1 1 -20-89 8500-9050 2K-1 7 Porosity FDC 1 1 -20-89 8500-91 09 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Date' - ..... RECEIVED i',!ov 2 9 t989 Aiaska 0il & 6as Cons. uu,,,,,,o Anchorage Franzen Vendor Package(Johnson) NSK State of Alaska(+Sepia) November 9, 1989 Telecopy: (907)276-7542 P. J. Archey Regional Drilling Engineer ARCO Alaska, Inc. ?. O, Box 100360 Ax'~chorage, Alaska 99510-0360 Re ~ Kupar~ River Unit 2K- 17 ARCO Alaska, Inc. Permit No. 89-119 Sur. Loc. 169'FNL, 94'FEL, Sec. 11, T10N, RSE, UM. Btmxhole Loc. l158'FSL, l146'FEL, Sec. 12, T10N, RSE, UM. Dear Mr. Archey: 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 ail other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. BY O~ER OF THE CO~E~ISSION dlf Enclosure cc: Department oE Fish & Game, l~abitat Section w/o enci. DePartment of Environmental Conservation w/o encl. STATE OF ALASKA ALA3r,,A OIL AND GAS CONSERVATION COMMIS,51ON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil _~X Re-Entry ~ Deepen --I Service _ Development Gas w Single Zone ~ Multiple Zone _ 2_. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 154, Pad 118' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25588 ALK 2674 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 169' FNL, 94' FEL, Sec. 11 , T10N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1320' FSL, 1320' FEL, Sec. 12, T10N, R8E, UM 2K-17 #U630610 At total depth 9. Approximate spud date Amount 1158' FSL, 1146' FEL, Sec 12, T10N, R8E, UM 1 1-29-89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K-18 9132 MD 1146' @ TD feet 25' at SURFACE feet 2560 6429 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1000 feet Maximum hole angle 52° Maximum surface 1744 psig At total depth (TVD) 6429' 3400 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~ Weight Grade Couplin~ Length IVD TVD IVD TVD linclude stac~e data) i24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 3452' 35' 35' 3452' 2946' 1100 Sx AS III HF-ER~I 450 Sx Class G 8.5 7" 26.0# J-55 BTC 9132 35' 35' 9132' 6429 250 Sx Class G & HF-ER~! Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured} true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vedical depth Structural Intermediate Production Liner i'~,,, '~'~: i j i'i'~ Perforation depth: measured true vertical ~.~;~.~,~!~;~-.:,, ii~)ii ~i~, ??J.S (;0''.'~,S," ..... ' ...... ' 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~ned ¢")~ ~~ Title Area Drilling Engineer Date / Commission Use Onl~ ~-.//¢ 50-/¢ ~ ~ / 11/09/89 other requirements Conditions of approval Samples required ~Y N o Mud log required ~ Y e s ~ N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ~Yes __ No Required working pressure for B~PE ~2M; ~ 3 M; 5 M' ~ 1 0 M' ~ 1 5 M b~ ordor o~ Approved by ~ ~- ~ - ~/~~~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 / in triplicate HO~ ZONTAL PROJECT I OF'-' SCALE 1 IN, - 1000 FEET ARCO ALASKA, Ino. Ped 2K. Well No, 17 Propo,ed Kuperuk Field. North Slope. Ale,k, 1 000 1000 . O 1 000 _ 2000 _ ;~000 _ 4000 . WEST-EAST 0 1 000 2000 5000 4000 I , I I I , I 5'URFA~ LOCAT I ON, 169' FNL, 94' FEI. SEC. 11. TIOfl. RSE SUI~"ACE / TARGET CENTER TI,ID=~I ~'OUTH 3791 EAST 4054 TARGET LOCATION' 1,320' F~L. 1320' FEL SEC. 12. TION. R~E' TD LOOAT I Off' 1158' I~L, 114~' FEL SEC. 12. TION. RSE 5000 I S 46 DEG 55,HIN E 5550' (TO TARGET) ARCO ALASKA. Pad 2K. Well No~ 17' Propoeed Kuparulr Field. North Slope. Alaeke 0 . RKB ELEVAT[O#, 154° 1000 _ 2000. m 3000. rtl o 4000 _ l'rl $000 _ 6000 _ 7'000 ,,. KOP TVD=IO00 Ti'ID=lO00 DEP=O BUILD 3 DE{) PER 1 O0 FT B/ PERPIAFROST TVD=1424 TPID=1428 DEP=48 $ T/ UONU SNDS TVD-1546 TMD=1554 DEP=80 21 27' 33 39 T/ W SAK SNDS TVD=2173 THD=2263 DEP=403 s~ EOC TVD-2509 THD-27'39 DEP-7'39 B/ W SAK SNDS TVD-27'46 THD-3126 DEP-I044 9 5/8" CSG PT TVD-2946 THD-3452 DEP-1302 K-1 0 TVD-3204 THD-3873 DEP-1634 (-5 TVD=4642 THD=621 8 DEpm3487' AVERAGE ANGLE 52 DEG 11 HIN T/ ZONE C TVD=6144 TPID=8668 DEP=5422 T/ ZONE A TVD=6181 TPID=87'28 DEP=$469 TARGET CNTR TVD-6244 TtID-8831 DEP-$$$O B/ KUP SNDS TVD=6306 TMD=8932 DEP-$630 TD (LOG PT) TVD=6429 TMD-g132 DEP-5788 I I I I 1000 2000 3000 4000 VERTICAL SECTION I 5000 I 6000 150 100 50 0 50 100 150 I I I I I I 200 150 100 5O 5O 100 150 200 . .......... - .... i _ 200 I 2700 300 700 _ 150 ~o xL, oo I ~ to.% I . ~oo ~oo ?o -,~o ! oo,?o I ~ ,;~,~o~ ~oo _~o 1100 I ,soo ~ 700 [ ~ laO0 ~ . % 0 I ~ 700 ' ~ 1 ~00 7OO "~700 J ~ /5 O0 ~ 1500 x 50 / / a 700 l'g / / I , I ,,~- J~oo I ~oo 1500 1700 J ..... ,/ ....... . ,,, , , 1 SO 100 SO 0 SO 100 lSO DRILLING FLUID PROGRAM (2K-17) Spud to 9-5/8" Drill out to ~urface casing weight UD Density 8.8-9.0 8.7-9.2 PV 15-30 5-15 YP 20-40 8- 1 2 Viscosity 70-80' 35-40 Initial Gel 5-15 2-4 10 Minute Gel 15-30 4-8 APl Filtrate 10-15 10-20 pH 9-1 0 9.5-10.5 % Solids 10 +/- 4-7 Weight up to TD 10.2 11-16 8-12 35-50 3-5 5-12 5 8.5-10.0 <12-15% Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface .pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2K-17 is 2K-18. As designed, the minimum distance between the two wells would be 25' at the surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-I/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. MUD CLEANER SHALE SHAKERS STI STIR STIR TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC .I DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL WI10' OUTLETS 5. 10' HCR BALL VALVES WI10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVEN3E~ VALVES CAN BE REMOI~_LY CON3R~ IFn TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSI~.M AS A VARIANCE FROM 20AAC25.035(b) MAINTI~NANCE & OPERATION 3 1. UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. ?_ CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 7 , 6 , ,13,5/8" 5000 F,.,I BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILLACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4, DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BO-I-]'OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 ARCO Alaska, Inc. Post Office Box ~100360 Anchoraa¢,. Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Conductor As-Built Location Plat - 2K Pad (Wells I - 24) /7 Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM'hf Enclosure RECEIVED DEC 1 1988 Alaska Oil & Gas Cons. Cornmissim] Anchorage GRU13/010 ARCO Al,~ska, Inc. is a Subsidiary of Alh3nlicRichfieldCm~Ip..3ny o, ,..-J WELLS I - 12 ARE LOCATED IN~.~ / ~: SECTION 2, T. I0 N., R. 8 E., 3s ~ UMIAT MERIDIAN. d i ~1 UMIAT MERIDIAN. II ~ 12 ~ ~ ~t' ' '~ VICI ~ITY MAP ~RACTED ~tes: ~ ~ .~S SECTION CORNER , ~4:~ I. CO0~INATES ARE ASR ZONE 4. I ~: 2. ALL DISTANC~ SHOWN ARE TRUE. .~ ~ SECTION II 19 SECTION ~ I ~, . ~:Zt ~. ELEVATIONS ARE B.P.M.S.L. ' * EIVED 4. O.G. ELEVATIONS FROM REC 5. HORIZONTAL POSITION BASED ON ~-K CONTROL 2 ~ DEC l 1988 ~' 58REFERENCE, 59, 65 S os.FIELD ,~K, L 88-40, p~. 55,56, wellASP's Al~s~ ~ uit & ~a~ {:~.,h~. ~ ..... ~ ..... .... ~ ............ i DiSt Dist. O.G. ~d ~ .... Y X ~~ ~ ~NGITUDE , FS.L. EE.L. Elev. , Elev. I 5,938,600.18 498,310.17 70°14'36.519" 150°00'49."~33'' i 296' 94' 114.0 118.5 2 I 5,938,575.14 ~ 498~310.28 70° 14' 36.273" 150°00'49.130'' 271, 113.9 36.029 150°00'49.128'' 246 113.8 3 5~938~550.30 i 498,310.35 70° 14' 4 5~938~525.46 ~ 498~310.06 70o14' 35.784" ~ 150°00'49.136" 222' 113.8 5 5,938~500.19 498,310.12 70o14' 35.536" 150°00'49.134'' 196' I 113.8 II II I I 6 5,938,475.14 498,310.33 70014'35.289 150° 00' 49.1~,, 176, 113.8 7 5~938,450.~6 498,310.36 70°14'35.046'' 150°00'49.1 14 113.8 4 .... 12~, ~ 113.8 8 5,938,425.30 498,310.18 70° 14, 3~.799 150o00 49.132" ' 9 5,938,400.30 498,309.98 70°1 34.553" 150°00'49.13T'' 9 i 113.8 I0 5,958,375.19 498~510.14 70014'34.306'' 150°00 49.133" 71 ~ 113.9 I ! 5,938,350.22 498,310.14 70°14' 34.061 " 150°00'49.133'' 46' ~' 113.9 12 . 5~938~3Z5.20 498~310.17 70014' 33.815" 150°00~49.131" 21' 94' 113.9 118.5 i : EN.L. 13 5,938~235.31 498~310.37 70° 14' 32.930" 150 °00' 49.125" 69, 94' 113.7 118.5 14 5,938,210.14 498,310.16 70°1~',32.683'' 150°00'49.131''. 99,4 113.7 '!5 5,938~185.12 498,310.16 70°1 32.437" 150°00'49.131'' ' II 113.8 4' 16 5,938,160.11 , 498,310.20 70°14, 32. 191" 150° 00' 49. 130'' ~44' 113.8 17 5,938~ 135.21 498,310.18 70°1 31.946" 150°00'49.130'' 169' 113.9 0~, I 19 ~ 5~938~085.20 498~310.27 70°1~ 31.454" 15000 49.12T" 21~ I 114.0 20 5,938,060.14 498,310.22 70°14' 31.~07'' 150° 00'49. 128'' 244' 114.1 i ii ii 21 5,9 38,035.16 498,310.16 70° 14, 30.962 150° 00'49. 130 269' 114.0 22 5,938,010.40 498,3~0.19 70Ol4 30.718" 150° 00'49. 129" 294' 94' ' 114.0 . .... 150° 00'49. 132" 344'... 9 . .I 13.9 118.5 24 5~937~960.29 498,310.08 j 70°14'30.225'' " OF. I TO PRACTICE LAND SURVEYING IN THE~~,~~ %~t~ ~ ~~ ~~. ~T~TE OF ~L~SK~ AND THaT T~I~ ~..,,..,.. ........ , ........ ~ .... BY ME OR UNDER MY DIRECT SUPER- · ~- · DRILL SITE 2.K ~w. ~mo.m~,s~ .:.~, CONDUCTOR AS BUILTS VISION AND THAT ALL DIMENSIONS ~.~j... ~-6~g ." AND OTHER DETAILS ARE CORRECT ~' ~Y I ~*~' '~';~,',~,'On ~'"11/~1/08 t~e'~*'''hsx6'2''.d4' ' , ~ , , ~ , , ,,, , , ,,, , , , , ,,' ,, ,, ,, , .Well ... ASP,s Alas; a uiI & f~.~;s C:~.,,,:.,. t;c,,T,,"~;~,s:;;;: Dist. Dist. O.G. Pod "' No. 'Y' 'X' I~]~l~d~ LONGITUDE F.S.L. F.E.L. Elev. Elev. I 5,938,600.18 498,310.17 70° 14'36.519 " 150° 00'49."i33'' 296' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70° 14' 36.273" 150°00'49.130'' 271' 113.9 3 5,938,550.30 498,310.35 70° 14' 36.029" 150 °00'49.128'' 246' 113.8 4 5,938,525.46 498,310.06 70o14' 35.784" 150°00'49.136" 222' 113.8 5 5,9:58,500.19 498,310.12 70°14' 35.536" 150° 00'49.134'' 196' 113.8 6 5,938,475.14 498,310.33 70o14'35.289'' 150°00'49.128" 171' 113.8 7 5,938,450.36 498,310.36 70°14'35.046'' 150°00'49.127'' 146' 113.8 8 5,938,425.30 498,310.18 70° 14' 34.799'' 150°00' 49.132'' 121' 113.8 9 5,938,400.30 498,309.98 70°14'34.553'' 150°00'49.137'' 96' 113.8 I0 5,958,375.19 498,510.14 70014'34.306'' 150°00' 49. 133'' 71' 113.9 I ! 5,938,350.22 498,310.14 70°14' 34.061 " 150°00'49.133'' 46' 1' 113.9 12 5,938,325.20 498,310.17 70°14' 33.815" 150°00'49.131" 21' 94' 113.9 118.5 EN.L. 13 5,938,235.31 498,310.37 70° 14' 32.950" 150 °00' 49.125'' 69' 94' 113.7 118.5 ,4 5,938,2,0.,4 498,3,0.,6 70 o , 4' 32. 683'' ,50o 00' 49. ,$, " 94' 15 5,938,185.12 498,310.16 70Ol4' 32.437" 150°00'49.131" 119' 113.8 16 5,938, 160.11 , 498,310.20 70°14' 32. 191" 150° 00' 49. 130'' ~44' 113.8 17 5,938, 135.21 498,310.18 70o14' 31.946" 150°00'49.130'' 169' 113.9 18 5,938, 110.19 498,310.29 70°14'31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.20 498,310.27 70014' 31.454" 150 °O0' 49. 127''' 219' 114.0 20 5,938,060.14 498,310.22 70°14'31.207" 150° 00'49. 128'' 244' 114.1 21 5,9 38,035.16 498,310.16 70° 14' 30.962'' 150°00'49.130" 269' 114.0 22 5,938,010.40 , 498,310.19 70°14'30.718'' 150°00'49.129" 2941 94' 114.0 23 5,937,985.32j 498,310.13 70°14'30.471'' 150°00'49.130'' 319' 95' 114.0 ..... 150° 00'49. 132" 344'... 95' I..I 13.9 118.5 24 5,937,960.29 498,310.08 70 °14' 30.225" CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc (~Plhru 8'f (8) (3) Admin ,/~/~S_ //~/~ 9. ~(9 thru i~3~ 10. ~.~. //- $-~ 11. (10 ~d 13) 12. 13. (4) Cas~ (14 thru 22) (5) BOPE ~ ~,~, ,';-,~-,~, (23 thru 28) .. Company ,~.zru<~ Lease & Well No. ~Z~ YES NO Is the permit fee attached .......................................... 7-,--, ~s 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is weL~i.located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. /~, Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate .................. ~ ................... 7~- Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. ~oes BOPE have sufficient pressure rating - Test to 3OO~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. , (6) OTHER {2~9/_ ~//~ thru' 31) - (6) Add: ~.~/~'//-&-e~ Geology: Engineerin~: DWJ~ LCS BEW rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of Seabed conditions presented-- Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE · Additional Remarks: O Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information., information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ~~ /~/_~ RECEIVED ~aska Oil & Gas Cons, Commlss{O_~ Anchorage ALA~KA. CC~PUTING CENTER COMPANY NAME WE[~L NAME FIELD BOROUGH TATE PI NU~OER REFERENCE ARCO ALASKA, INC, 2K".17 KUPARUK NORTH SbOPE ALASKA 50-103-20121-00 73555 HICROFILHED IS Tape Verification Listing ChlUmberger AlasKa Computing Center 5-D5C-1989 13:00 $*** REEL HEADER SERVICE NAME : EDIT DATE : 89/12/ 5 REEL NAME : 73555 CONTINUATION # : PREVIOUS REEL COMMENT I ARCO ALASKA~ INC,,KUPARUK,2~ - 17,50-103-20121-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 89/12/ 5 ORIGIN : FblC TAPE NAME : 73555 CONTINUATION # I 1 PREVIOUS TAPE COMMENT I ARCO AbASKA~ INC,~KUPARUK~2K FILE NAME : EDIT ,001 SERVICE : FLIC V~RSION : 001A04 DATE ~ 89/~2! 5 MAX AEC SIZE 6 FILE TYPE : LO L~ST FILE PAGE: SCHLUMBERGER ~ELL SERVICES COMPANY NAME: ARCO ALASKA, XNC, WELLI 2K - ],7 F)ELD! KUPARUK BOROUGHI NORTH &LOPE STATEI ALASKA AP! NU~BERI 50e103~20~21-00 LOCATIONI 169' FNL & 94' FEb SECTIONI tl TOWNSHIP: 1ON RANGEI BE PERMANENT DATUm: MSL EI~£VATION: 0 LOG :MEASURED f'ROM RKB 154 AB~VB PERNANENT DATUM Tape Verification Listing chlumberger AlasKa Computing Center 5-DEC-1989 13:00 PAGEI ELEVATIONS DATE LOGGED: RUN NUMBER: TD DRILLER: TD LOGGER: CASING 154 Obi 113 20-NOV-1989 ONE 9145 9143 9 5/8" LB a DRILLER DEPTH OF '- TO 3563 AND LOGGER DEPTH OF -- TO 3562 BlT SIZE 1: 8 1/2" TYPE FLUID IN HOLE: WEIGHTED POLYMER DENSITY~ 10,1 VISCOSITY: 37 PH: 9 FLUID LOSS{ 3.799999 NUD RESISTIVITY: FILTRATE RESISTIVITY{ MUD CAKE RESISTIVITY: 3.55 e 73 3,71 ~ 60 2,85 ~ 60 TIME CIRCULATION ENDED: 10:30 NOVEMBER 20 TIME LOGGER ON BOTTOM{ 17157 NOVEMBER 20 MAXIMUM TEMP RECORDED: 152 bOGGING DISTRICT: bOGGING ENGINEER: WITNESS: TOOL NUMBERS: I£~-BD 1347 DIS-EC t457 CNC-A 2122 PGC-JA PRUDHOE BAY A FRITZKE D~XON/bOWEN/KINNEVAN NLM-BC 1338 DIC-DA I308 SGC"JC 3533 PGS-HB 508 FIELD REMARKS{ i I/2" STANDOFFS AN[) A 2' HOLE FINDER USED ON THE DIL.~ MATRIX DENSITY = 2.65 G/CC., F~UID DENSITY . 1.0 G/CC. NEUTRON MATRIX = SAND, HOLE CORRECTION m CALIPER, PAD ELEVATION = MAXI~4!J~! DEVIAIIOI~ . 55 D~.GREES ~, 384~'.. , ASS ACO, z u NOt P~ESEN~ED, ~Rb SHIFTED AT ~209'~. O~B ~EFE~ENCE NO{ 73555 LDP/ANA: ~, SINES FILE - EDIT,O01 IS Tape Yerlfication Listing chlummerger Alaska Computing Center · . 5-DEC-1989 .. 13=00 ARCO AbA$1kA~ 1NC, KUPARUK 2K - 17 50-103-20121-00 MAIN PASS LOG DATA DATA SAMPLED L:VERY -.5000 FEET TYPE U$~:~ NA~E DIT-D ,D)L DUAb INDUCTION SFb FDC ,FDC FORMATION DENSITY CNT-A/D/H ,C~L COMPENSATED NEUTRON GR ,CSG GAMMA RAY TABLE TYPE ) CONS TUNX VALU DEFI , CN FN WN TOWN RANG COUN STAT NATi bA?I bONG WITN SON' PDAT FT¸ FT FT FT FT FT FT FT ARCO ALASKA, INC, KUPARUK 2K " 17 169 ~ FNb & Il BE NORTH ShOPE At,ASKA USA XON/L, OW[,N/KZNNEVAN 548374 0 10~0 ~OVEMB~R 20 Company Name Fleld Name Wel! Name APl Serial Number Field Location Section. Township Range. County S~ate or Province Nation Latitude w~tnes~ Name . Service,Order Number Permanent datum 5og Measured From ottgm bog Interval op :)Jog ':lnte~ 'al Time Ctrculet)[on stopped I$ Tape verification 5isting chlumberger Alaska Computing Center 5,.DEC-198q 13:00 ,PAGE{ 4 TUNI VASU DEFY TbAB 17157 NOVEMBER 20 Time boq~er At Bottom STEN DEGF '999,25 T~BLE TYPE { CURV DEFX DEPT @epth Channel Name l~P Deep Induction Standard Processed Resistivity lL~ Hedium Induction Standard Processed Resistivity. SF~U S~L Resistivity (unaveraged) SP Spontaneous Potential GR Gamma.Ray Tension DPH! Density POrOSity RHOB Bul~ Density DRHO Delta RHO FFDC Far FDC Count Rate NFD~ ~ea FDC Count Ra~e C~x Cai[ per GR Gam~a Ray TENS Tension NPH! Neutron Porosity TNPH Thermal Neutron Porosity TNR~ Calibrated Thermal Neutron ~atio NBOR ~eutron Porosity outputFro~ an APpllca'tion Program RCNT RCNT ReFT RCFT CNTC CNTC CFTC CFTC GR Gamma Ray CA ! Caliper TE~8 Tension GR Gamma Ray ,TENS Tension DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 § 66 15 ?ape Verification ListinO Chlumberoer AlasKa Computing Center 5-DEC-1989 X3~O0 PAGE, TYPE REPR CODE YALUE 6 73 7 65 9 65 l~ 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ~mw#mmmmmm~mmmmmm~mmm~mm~m~mm ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl API APX APX FILE NUMB NUMB SXZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS FDC LB 5 54 14 O7 NPH! CNL PU ~TNP. CNL PU 548374 07 TNRA CN5 548374 07 NPOR~b PU 5483~4 07 ReNT UNb CPS 5483.4 07 RCFT tnb CPS ,48374 07 CNTC CNL CPS 54837~ 07 CFTC CNL CPS 548374 07 GR CNL GAPX 548374 07 CAL! CNL IN 548374 07 T~NS CNL LB 548374 07 G. CSG GAPI 548374 07 TF~8 CSG LB 548374 07 000 O0 0 I I I 4 120 46 0 ! 1 I 4 120 44 0 1 1 1 4 220 Ol 0 1 1 ! 4 01o 01 0 1 1 1 4 310 01 0 1 1 1 4 635 21 0 ! 1 I 4 635 21 0 I 1 I 4 350 02 0 I I I 4 356 01 0 1 1 1 4 354 02 0 I I ! 4 354 Ol 0 I I 1 4 280 01 0 I 1 I 4 310 Ol 0 1 I 1 4 635 21 0 1 1 I 4 890 O0 0 ! 1 1 4 890 O0 0 I 1 I 4 42O 01 0 1 I 1 4 890 O0 0 I 1 I 4 420 Ol 0 1 I 1 4 420 O1 0 1 4 4 0 1 0 42{)2 0 1 ! 4 O1 O ! I 1 4 310 ol 0 1 1 1 4 280 Ol 0 I I I 4 635 21 0 1 I 1 4 310 Ol 0 1 I 1 4 6{ 5 21 0 I 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 :0000000000 0000000000 0000000000 68 00000000.00 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 O0000~gO00 68 00000 000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 00000000 0 68 '0.0000000~0 68 0000000000 68 :0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** Tape Verification Listing chlumberger AlasKa Computing Center 5-DEC-198g 13100 PAGEI DFPT SP DXL RHOB FDC CRb! FDC yNp~ CNb RCFT CNL CAb! CNI, DEPT RHOBeFDC CALIeFDC TNPH'C,b CAhI,CN[, DEPT. SP.;Plb RHOB.FDC CAb! FDC T~H CN~ RCFT CNL CAb! CNb PEP?. SP.DIL RHOB.FDC C~LI,FDC TNPH.CNL eCF?,.C~b CALI,,CNL DEP?, SP,PIb R~O~,FDC CAbI,FDC RCFT,CNb CALI.CNL D~PT RHOB'FDC TNPH,CNb ~CFT,CNL CALI'CNL RHO~,FDC CALI,FDC TNP~,CNL RC~T,CNL 9169,000 473 60~ 47 44~ 8,609 9100,000 -62,000 2,4~4 8,875 443,748 8.875 9000 000 -65 500 2 473 8 469 35 139 671 080 8 469 8900,000 -81,500 ,226 ~,297 28.096 959,049 8,297 .500 246~ 8492 27 847 912429 O 492 8709,000 -~2,500 2,385 9;125 4(),123 479'270 9,125 ~600,00~ -93,5oo 29,427 ,266 44,276 451'575 ILD.DIL GR,DIL GR DC CNTC TENS Nb ILO,DIL GR,DIL DRHO,FDC GR.FDC TNRA,CNL CNTC,CNL TEN$'CNL ILD DIL GR DRHO FDC GR FDC ?NRA CNL CNTC CNL TENS CNL ILD~DIL GR,DIL DRHO~FDC GR,FDC TNRA,CNL ~NTC,CNL TENS,CN5 ILD,DI6 GR,DI5 DRHOeFDC GR,FDC TNRA,CNL C~TC,CN5 TENS,CNL !LD,DIL GR.,DI5 DRHO'FDC GR,FDC TNRA,CNL CNTC,CNL TENS.CNL ILD,DI5 GR'DI6 DRHO,FDC GR,FDC TNRA,CNL CNTC,CNL 2 728 106 563 0 060 106 563 3 359 1763 834 1805 000 3.348 109,30~3 OO9 3 6084 000 4 669 10] 313 205 2341 157 5920 000 4~,~3~ O25 2,673 2644,933 6012,000 75 ~2475 2 ] 573 019 ooo 13~'890 0 138 125 172~ 414 763 5752 000 2,433 119'563 0,01.9 119,563 3;6~9 ~769'706 ILM DI6 TENS DI6 FFDC FDC TENS FDC NPOR CNL CFTC CN6 GR CSG IL~,DI6 TENS,DIL FFDC,FDC TEN$,FDC NPOR,CNb CFTC,CNb GR,CSG ILMeDI6 TENS,DIL FFDC,FDC TENS,FDC CFTC, L GR,CSG iLM,DIL TENS,DI6 FFDC.FDC TEN$,FDC NPOR,;CNL CFTC,CNL GR,CSG 'F~DC,FDC TEN$,FDC N~OR,CNL CFTC,CNL GR,CSG IL~,DIL TENS:~Ib FFDC DC TENS,FDC NPOR,CN5 CFTC,CN5 GR,CSG ILM,DI5 TENS,DiL FFDC.FDC TENS,FDC NpoR,CNL CFTC,CNL 2 866 1805 000 5O2 250 1BO~ 000 ~ 409 535204 -999 250 3,473 6084.000 512;500 6084,000 40'743 532,356 -999,250 4,888 5920,000 459,250 5920,000 37,160 775,~68 -999,250 3~.,620 601 ,000 846'000 ,ooo -999,250 5728 466 000 ooo ~084 002 999 250 1,962 5752,000 563,'000 5752'000 40,826 .512,805 999,250 2 521 5608 000 5O8 5O0 5608 000 44 6.41 487 989 SFLU,DIL DPHI,FOC NFDC,FDC NPHI,CNL RCNT,CNL GReCNL TENS,CSG SFLU,DIL NFDCeFDC N~H~eCNL RCN~eCNL GR,CNb TENSeCSG srbU,p~b DPH~'FDC NFDC,FD~ NPHZ,:CN~ RCNTeCNL TEN& DPHI,FDC NFDC,rDC NPfIZ,CNL RCN~eCNE GR,CNb TENS,CSG SrbU,.DZb OeHi,,FOC NFDC,FDC RCNT,CNL GR,'CNL TENS,CSG 8FbU,DI~ DPHI.,FDC NFDC,FDC NPHI,CNL RCNT,CNL GR;CNL TENS,CSG DPHI. DC NFDC FDC NPHI CNL RCNT ~R CNL 2,987 !0,726 6~9,500 40,457 1737,294 .106,5~3 999,250 3,703 14,294 " 185 ~ 10 ,3ti -999,250 582,, 6~8'}99 . 44.,${i .999'250 0,,~06 16 3~2i9 9,290 IS ?a~e Yerification Listing ChlUm er~er Alaska Computinq Center CALI.CNL 9,266 TENS.CNL DEPT SP RHOB FDC CAb! FOe TNPH CNL CALI CNL gSO0 000 -93 000 2 412 9 156 44 937 460 451 9 156 I[..D GR DRHO FDC GR FDC TNRA CNL CNTC CNn TENS CNL DEPT, R~OB,FDC ~L',FDC RCFT.CNL CALI,CNb 8400 000 -92 500 2 349 9 383 45 651 453 774 9 383 GR,DIL DRHO,FDC GR,FDC TNRA,CNL CNTC'CNL TENS,CNL SP RHOB CAb! RCFT DIL FDC FD¢ CNb 8300,000 -98,500 2,448 9,641 38,989 596,653 9,641 ILD GR DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNb D~PT SP RHOB RCFT FDC FDC CNL CNL 8~0,000 462 9,742 51 928 V,74~ ILD DIL CR DIb DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNL DEPT RHOB,FDC , C N L RCFI,'CN~ C~ 'tNt 8100,000 -54;500 474 33,887 616,448 10,203 IbD,DIL DRHO,FDC GR,FDC TN~'CNL CNTC'CNb TENS,CNb DEPT, SP,DIb RHOB.FDC C~LI FDC TNPH CNL RCFT CNL CALI CNb 8~00,000 59,500 2,470 I0"047 8,846 599,209 10,047 IbD GR DRHO FDC GR FDC TNRA CNL CNTC CNb TENS CNL DEPT ~HOB TNPH 7900,000 DIL =51,500 FDC 2,0353 FDC 9, 78 CNb 46,929 ILO DIL GR DRHO FDC GP FDC TNRA CNL 5-D~C-1989 13:00 5608.000 GR,CSG 3,585 146,125 0 025 146 125 3 590 1906 199 5528 000 2,404 317,500 0,005 3 1784'1 2 5592,000 3 7{2 155 625 0 040 155 25 1987 2 5 5384 000 3 4,1 152 75 2011 92 5424 O0 4 406 109 875 0 007 lO9 875 3 202 2119 834 5620 000 117 B 0 0.37 117 938 3 178 211~ 574 51 000 134 5 002 134 5 IL~,DIh TENS.DIL FFDC,FDC TENS,FDC NPO~,CNL CFTC,CNL GR,CSG IbM,DIb TENS DIb FFDC FDC TENS FDC NPOR CNh CFTC CNb G~ CSG IbM DIb TENS DIb FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG ILM DIL T~NS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG IL~ DIL TENS DIL FFDC FDC TENS FDC NPOR CNb · CFTC CNL GR TENS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG IL~ DIL TENS FFDC FDC TENS FDC NPOR CNL -999,250 TENS.CSG 3 659 SFLU 5528 000 DPHI FDC 535 000 NFDC FDC 5528 000 NPH! 45 677 RCNT CNL 520 461 GR tnb -999 250 TENS CSG 2,529 SFbU,DIL 5592,000 DPHX,FDC 594,000 NFDC,FDC 5592,000 NPHI,CNL 46,571 RCNT,CN~ 480.143 GR,CN~ -999'250 3 875 SFLU 5384 000 DPH! 509 500 NFDC 5384 000 NPH! 38 412 RCNT 599 -999 250 DFIL DC FDC CNL, 3 951 SFLU DIb FD 4 0 NFDC 5424 ~0 O0 N'PHI tnb 37 775 R~CNT CNL 609 4 ~R CNL 4 367 SFLU 562~ $~0 DPH! 43 0 N~DC 5620 000 N~MI 36 144 RCNT 702 345 G~ -999 250 TEN IL 4 962 SFL~,DIL 5131 000 DPH ,FDC 47 500 NFDC,FDC 5132 000 NPHI,CN~ 68 RCNT~CNb 61~ ~72 GR,CN~ -999 250 TENS,CSG 3 589 SFLO 5000 000 DPH] 629 500 NFDC 5000 000 NPHI 46 815 RCNT ~IL DC FDC CNL CNL PAGEI -999,250 -9 ,d{ Ill IS Tape Verification L1st~,nq chlumberger AlasKa Computing Center PCFT,CNL 410,020 CNTC,CNL CALI,CNL 9,078 TENS,CNL DEPT RHOB TNPH RCFT CAL! FDC FDC CNL CNL 7800 000 -58 500 2 423 9 641 4O 383 5]2 600 9 64! ILO GR OIL DRHO FDC GR FDC TN~A CNL C~TC CML TENS CML DEPT, RHOB,FDC CALX.FDC TNPH.CNL RCFT.CNL CALI.CNb 7700 000 '5O 000 2 441 9 648 ]6 8]6 592 121 9 648 ILO,OIL GR.DIL DRHO.FDC GR.FDC ~NRA,CNL C~TC,CNL TENS,CML DEP? TNPH~CNL RCFT 7600 000 -49 000 2 456 9 930 34 275 621 776 9 9]0 ILO GR DRHO FDC GR FDC TNRA CNL CNTC CML TENS CNL DEPT SP:DIL RHOB,FDC CA I,FDC TN~'CNL RCF,'CNL 75OO 000 -6! 5OO ~ 466 9 32 573 659 220 9 813 ILD,DIL GR,DIL DRHO;FDC GR,FDC NRA,C~L MTC,CNL TENS,CML DEPT, SP,DIL RHOB'FDC CALi,FDC CaL~,CNL 7400 -62 2 10 33 695 10 ,000 '000 ,36~ ,445 '817 II, D,DI~ GR,DI~ DRMO;FDC GR,FDC TMRA.CNL c~c;c~ TENS,CML DEPT, SP.DIL R~OB.FDC C~SI'FDC NP~,CNL 7300 000 '62 500 2 331 9 586 36 285 650 841 9 586 GR DRHO G~ CgTC TENS OIL 'FDC ,FDC ,CNb ,C~h DEPT, SP,vIL RHOB,FDC CAL! ;FDC 7200,000 -67'500 ,384 I L D, D I L G R; D I ~ DRHO:FDCGR DC 5-DEC-1989 13:00 1876 651 CFTC.CNL 5000:000 GR.CSG 3 734 130 875 0 023 130 875 3 457 2038 413 5O48 000 .873 12 .125 0'037 122,125 3' 23 2214, 77 4964,000 3 O62 126 3 o 126 81~3 3 081 2 55 266 5}80 000 4.6'51 120~688 0;954 120.688 3 2266:~76 5068'000 4,213 95 0 95,750 ~;o~4 244~:~ 8 4972. O0 3 547 o 8 90 $ OUO 3,690 104,438 0.0t3 ].04.438 IbM TENS DIL FFDC FOC TENS FDC NPOR CML CFTC CNL GR CSG IbM OIL TENS DIL FFDC FOC TENS FPC NPOR CNL CFTC CNL GR CSG !LM,DIL TENS,OIL FFDC FDC TENS:FDC NPOR,CNL CFTC,CNb GR;CSG IbM TENS DXL FFDC FOC TENS FDC NPOR CML CFTC CNL CR CSG ILM,DIL TENS,OIL FFDC;FDC TENS;FDC NPOR,CNL CF~C,CN5 GR,CSG ILM TENS FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG 496 349 _ GR,CNb -999:250 TEN$,CSG 3 782 SFLU 5048 000 DPHI FDC 519 000 NFDC FDC 5048 000 NPH! CN 41 082 RC~T CNb 599 137 GR CNb -999 250 TEN8 CSG 2,898 8FbU,Olg 4964,000 DPHX'FDC 513.~ NFDC.'FDC 4964. NPHXeCN~ 37,300 RCNT,CNb 696,298 GR,CNb -999,250 TENS,CSG 3 127 SFLU.,DIL 8O 000 DPHT,FDC 5181 500 NFDC..FDC 5180 000 NPHX ~ 135 032 RCNT 7~. )66 CNL -99~ GR TENS CSG !50 DX ,794 SFLU,FD~ 50 ;000 DPHI, 7~,042 GR', 999,250 :TENS;CSG 4 4972 597 4972 35 808 -999 5028 627 5028 36 734 -999 IbM,OIL 3,742 T~NS,Dib 4888,000 FFDC,FOC 556,500 TEN$,FDC 4888,000 DPHX.:FDC 500 NFDC;:FDC O0 NPH~,CNb GR,CNL TENS,CSG 585 SFLU,DIL 000 DPHI,FD¢ 500 NrDC,FOC 000 205 RCNT'CNL SFLU,DIL DPHItFD~ N~DC,FDC NPHi,CN~ PAGEI 8 '999, 3,745 -13,75~ 603,000 40,71S .130,e?S 999,2~0 ~9444 .s2o,6m 631,000 ,2: 424 60 IS Te~e verification Llstin~ ehlU~berc_er Alasi<a Computinq Cen~er 5-D~C=lg89 13~00 TNPH,CNL 37.864 TNRA.CNL 3 ~22 NPOR,CNL RCFT,CNL 634,215 CNTC,CNL 2253:.46 CFTC,CN5 000 GR,CSG CALI,CN5 90563 TENSoCNL 4888, - 7100 000 -69 000 2 335 g 672 33 489 650 541 g 672 ILD.DI5 GR,DIL DRHO,FDC GR.FDC TNRA.CNL CNTC,£NL TENS,CNL DEPT SP:DIL RHOB,~DC CALI,FDC TNPH,~NL RCFT,CNL FDC FDC 7000,000 -70,000 2,404 10,563 38'872 532,809 10,563 I~D.OI5 GR,DIL DRHO,FDC GR'FDC TNRA,CNL CNTC,CNL TENS,CN5 DEPT RHOB CALl acrT CALl. OIL FDC FDC 6900 000 -77 000 2 433 10 445 42 101 475 469 10 445 ILL, TNRA, CNTC, TENS, DIL DIL FDC FDC CNL CNb CNb DEPT CALl T~PH R~FT CALl 6800 2 10 42 459 10 ,000 ,500 ,399 .023 .879 ,778 ,023 ILD.DIL GR,DIL DRHO,FDC GR,FDC TNRA,CNL CNTC'CNL TENS,CNL DEPT CALI,WDC TNPH,CNL RCFT,CNL CALI,CNL DIE, FDC FDC CNL CNL CNL 6~00,000 56;500 2'332 9,141 _41'060 508,452 90141 I LD GR DRHO TNRA CNTC TENS DI [~ FDC FDC CNL CNL CNL DEPT SP TNPH RCFT CALl 6600 000 -64 000 2 449 9 141 29 348 841 472 9 141 ILD,DIL GR*DIL DRHO,FDC GR,FDC TNRA'CNL CNTC~CNL TENS,CNL DEPT. sp;utu RHOB,FDC C~LI,FDC TNPH,CNb RCFT,CNL CALI'CNL 3 844 102 000 0 005 102 000 2 966 2328 5 13 4500, 0 4 000 134 225 0 O38 134 125 3 636 19~.5 2,%2 4648 000 4,220 134,000 0.031 1.3~,000 '525 1897,640 4520,000 i:o 151 250 3 397 1943'314 4612,000 4,747 152,000 o,oio 15~'000 ,738 2620~541 4380;000 IbM DIL TENSDIb FFDCFDC TENS FDC NPOR CNb CFTC CNb OR CSG Ib~ OIL TENS DTL FFDC FDC TENS FDC NPOR CNL CFTC CNb GRCSG IL~ TENS FFDC FDC TENS FDC NPORCNL CFTCCNL GR CSG 'IL~ TENS DIL 'FFDC FDC TENSFDC NPOR CHh CFTC CNL GR CSG TENS,DIL FFDC,FDC TENS,FDC NPOR,CNb CFTC,CN~ GR,CSG ~L~,DIL FFDC;FDC TENS,FDC NPOR,CN5 CFTC;CN5 GR,CSG 37,268 RC~T,CNL 695,130 GRoCN~ -999,250 TENS,CS 3,868 SFLU,DIL 468!!000 DPHI.FDC 61 500 NFDC,FDC 468 000 NPH~,CNL 3!i~41 RCNT,CNL 78 06 GR.CNL -99 250 TENS,CSG 4 594 srbu,ozb 4500 000 DPHI.'FDC 503 250 NFDC,FDC 4500 000 NPHI.CN~ 40 359 RCNT,CNL 584 997 GRtCN -999 250 TENS,CS~ 3'971 SFLU,DIb 8,099 DPH[,'.FDC 4~4;00U NFDCtFDC 648;000 NPHI'CNL 44,587 RCNT.CNL 540.757 GR;CN~ 999.250 TENSeCSG 4,229 SFLU.DIL 4520,000 DPMItFDC 561,000 NFDC,FDC 4520;000 NPHI'CNL 40,233 RCNT,CN~ .53!;!I9 GR'CNb 999,250 ?EN$,CSG !,721 SFLU,D2~ 4612,000 DPHi,:FD¢ 673.500 ~FDC;FDC 4612;000 NPHZ.;CNL 41,714 RCNT,CNL 567;8I~ GR,CN~ -999,250 TENS,CSG 4380 471 4380 29 978 -999 093 000 DPHI:,FDC ~0 NFDC,~Df 0 NPH~,CN~ 3 RCNT.CNL ~7 GR;CNb PAGEI 2249,728 ],857 619'tt9 4.000 4,_081 141V 6 555,5~t0 tm ,60t ,166 , 0 40, :5,995 29 l l)? 52.,0( -999,2~ Tape Verification Listing chlumberger AlasKa Computing Center DEPT SP OIL RHOB FDC RCFT CNb SP DIL RNOB FDC CALIFDC TNPH CNL ReFT DEPT RHO~,FDC CAL ,FDC TNPH,CNL RCFT'CNL C4LI,CNL DEPT SP DIL RHOB FDC CALl FDC TNPH CNL RCFT CNL CALl CNL DEPT RHOB TNPH,CNL RCFT'CNL DEPT, RHOB,FDC TNPH,C~L RCFT,CNb DEPT RNOB'FDC C4~I,FDC RCFT'CN~ 6500 000 -59 5O0 2 347 9 25O 36 366 630 )68 9 25O 6400 000 "61 000 2 3~7 9 063 41 129 508 452 9 063 6300 000 -76 000 2 355 9 078 29 939 687 574 9 078 6200 000 -78 5OO 2 369 9 047 34 872 6100,000 - 4;5oo ~,358 9,195 654~79i 9,195 6000,000 -83'000 ,339 37 '484 ,92~ 613,399 9,484 5900 000 -82 5OO 2 3~? 9 O78 36 874 621 024 9 078 ILD DIL GRiDIL DR~O FDC GR,FDC T~RA,CNL CNTC.CNL TENS,CNb ILD,DI5 GR.OIL ORHO.FDC GR,FDC TNRA.CN5 CNTC,CNL TENS.CNL i~D.DI5 DRHO,FDC GR.FDC TNRA,CNL C~TC.CNL TENS,CNL ILD,DIL GR,DIL DRHO,FDC GR~FDC TNRA,CNL CNTC,CNL TEN'S,CNL ILD.DIL GR~DI5 DRHO,FDC GR,FDC T~RA'CNL CNTC'.CNL TENS,CN5 ILD DIL GR DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNb DRHO,FDC GR,FDC TNRA'CNL C TC,C b TEN$,CN~ 5-DgC-1989 13:00 2,328 13].,500 0 0~1 131 500 2 9BO 2158 433 4388 000 11~ '017 ,063 0,018 1!8,063 200~ '206 ,372 4420,000 5,410 -0 09 159 ~5 2 5 ~280,000 4 0 004 85 938 2 984 2186 808 4168 000 3,967 lo2,o o 0;036 102'000 3;004 17,547 ~34'000 2 892 -0 ~168 000 O4 0 0t2 124 4~8 3 3840 000 IL~.DIL TENS.DIS FFDC.FDC TENS'FDC NPOR,CNL CFTC,CNL GR.CSG IL~ OIL TENS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG IL~ DIL T~N$ OIL FFDCFDC TENS FDC NPOR CNL CFTC CNL GR CSG IL~.DIL .TEN$.DIL FFDC'FDC T~NS;FDC NPOR,CN5 CFTC, Nb GR,~$G IL~,~IL TENS,D~L FFDC,FDC TENS;FDC NPOR'CNL CFTC,CN5 GR,CSG Ih~ OIL TENS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG ILM.DI5 TEN$,DI5 FFDC,FDC TEN$'FDC NPOR,CNL CFTC,CN5 GR,CSG 4388 607 4388 37 688 -999 2 371 SFLU 000 DPHI 000 NFDC 000 NPH! 901 RCNT 996 GR 250 TENS 2 4420 664 4420 41 586 -999 FDC FDC CNL CNL CH ,0 5 SFLU,DIL 00 NFDC;FDC ,0 PHX,¢N~ RCNT.CNL 5.769 SFLU,DIL 4280,000 DPHI,FDC 566,000 NFDC,FDC 4280"000 3~,548 RCNT,CNL 999'~50 GR, TENS, 4.045 SFLU DI~ 4168'000 DPH! FDC 564,000 NFDC FDC 4168'000 NPH! CNL 33'703 RCNT CNL 722,0~1 GR;.CNL -999.250 TENS'CSG SFLU.DIL DPHZ'FDC NFDC,.FDC NPHI.,CNL RCNT,CN~ GR;~N~ TEN$,CSG SFLU.,DIL DPHI;~FDC NFDC,FDC NPHI,CNL RCNT,CNL GR,CNL TENS;.CSG DII, FDC FDC CNL CNL CNL CSG 3¸ 4, AO 62 000 4034,000 34,162 -99 250 2"796 4168,000 600. 0 39.654 639.019 -999,250 3,027 SFLU 3840,000 DPHt~ 623'500 NFDC 3840.000 NPH! 36'153 RCNT 645'132 -999.250 TENS PAGEI 10 369 6tO,,500 32,693 .052,44 6,0 4 2076,i$, I59,t{~ -999,25 596,500 ,85,938 -999,260 3,Se9 t 02 :; 000 IS Tape Verif~¢at£on Ltstln~ eh!u bm e~ge~ AlasKa Computing Cente~ 5-DEC-1989 13:00 DEPT SP OIL RHOB FDC CALl FDC TNPH CNL RCFT CNL CALl CN5 DEPT ~P DIb RHOB FDC RCFT CNL CaLl CN5 DEPT, SP,DI RHOB,FD~ TNPH,CN~ RCFT,CN CALI,CN~ DEPT, SP,DIL RHOB.FDC TNPH,CNL RCFT,CNL CALI,CNL D~PT, SP,DIL RHOB,FDC CALI,FDC TNPH*CN5 RC~T,CN5 CALI,CNL RHOB FDC CALIFDC TNPH CN5 RCFT CNb CALl CN5 DEPT SP CALl FDC TNPH CNL ~CFT 5800 000 -81 000 2 329 9 078 38 3U5 502 365 9 07~ 57OO 000 -81 500 2 354 8 492 32 21.2 621 024 8 492 5600 000 -79 000 2 272 9 102 38 235 603 518 9 102 5~00,000 9,227 35,798 5400 000 -82 000 2 287 9 45] 31 O62 671 9 45] 5300,000 -77'000 2,~12 9, 50 40,092 552,913 9,250 520O 000 -79 500 2 328 9 047 36 262 642 053 ILD,DIL GR,DIL DRHO,FDC GR,FD~ TNRA,CNL CNTC;CNL TENS;CN5 ILD,DIL GR,DIL DRHO,FDC GR,FDC TNRA;CNL CNTC,CNL TENS.CNL ISD GR OIL DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CN5 ILO,OIL GR,DIL DRHO,FDC GR'FDC T~RA;CNL CNTC,CNL TENS,CN5 ILD,DIL DRHO,~DC GR,FDC TNRA,CNL CNTC.CNL TENs'cN5 GR OIL DRHO FDC GR FDC TNRA CNL CNTC CN5 TENS CN5 GR DRHO FDC GR FDC TNRA CN5 CNTC CNL 3 074 109 668 0 021 109 6~8 3 437 0o8 39 0 3,466 103.938 0,~47 i03, ~8 . 1 205~'~94 3984,000 89 004 3 500 106 625 0001 10~ 625 ]01 00o ],771 112'375 0,000 112,~15 4 98O 1 :ooo 3 97; 0 FFDC FDC TENS FDC NPOR CNL CFTC CNb GR CSG FFDC,FDC TENS,FDC NPOR,CNL CFTC,CNL GR,CSG ILM DIE TENS OIL FFDC FDC TENS FDC CFTC CN5 GR CSO TENS.OIL FFDC'FDC TENS,FDC NPOR,CN5 CFTC,CNL GR,CSG IL~ DIL :TENS FFDC FDC TENS FDC NPOR CNL CFTC GR CSG IL~ OIL TENS DIb FFDC FDC TENS FDC NPOR CFTC CNL GR CSG 3 O08 SFLU 3934i000 DPHI 651 000 NFDC 934,000 NPHI 35.370 RCNT 656,{49 GR 999, 50 TENS 3.384 ]984,000 834'500 3984,000 .7 777 99992~0 ¸9 703,000 3724,000 39. 7 637,~7 -999,~50 FDC ,FDC ,CNL ,CNL ,CN~ ,C$~ SFLU,D]L DPHI,FD¢ NFDC,FD¢ NPHf,CN~ RCNT,CNL GR,CNE TENS,CSG SFbU,DI~ DPHI,FDC NFD¢,FDC NPHI,CNE RCNT, NE TEN$'CSG 3.399 SFbU,DXL ]830,000 DPHI,,FDC 588,000 NFDC,FDC 3830.000 NP~Z,CNE 36,636 RCNT'CN~ 669.207 GR'CNL '-999'250 TENS,CSG 3870,000 DPHI' 684,500 NFDC FDC 3870,000 ~PHI,.CNL 730,876 RCNT CNL 63,518 GR;CN~ -999'250 TENS,CSG 3,~55 3614, O0 663,§00 3614,000 39*953 .629;328 999,250 3,288 Ih~,blh 3 86'875 TENS~DIL 3544 0,037 FFDC,FDC 677 86;875 TENS,FDC 3544 2066'232 CFTC'CNb 662 SFbU,DZb DPHXe~DC NFDCeFDC RCNT'CN~ GR.CNL TEN$,CSG SFLU,DIL ~FDC,~Df NPHX;CN~ RCNT'CN~ GR.CNL 1t7 000 50O 000 433 9O0 4909 .I09,689 ggt,2$O ,000 ggg,2$O Tame Verification Listing eblUmberger Alaska Computing Center CRb],CN4 9,047 DEPT SP TNPR 5i00,000 ItD,DIL OIL -82,000 GR,DIb FOC 2,310 DRHO,FDC FDC 9,281 GR,FDC CNL 38,173 TNRA,CNb CNL 521,080 C~TC,CN6 CNL g.28i TENS,C~b DEPT, SP,DIb RHOBeFDC CAL],FDC TNPHeCNb CALI,CNL 5000 000 -84 500 2 317 9 250 38 868 53O 970 9 250 ILO.OIL GR,DIL DRHO,FDC GR,FDC ~RA,CNL CNTC,CNL TENS'CN5 DEPT SP RHOB CAb! TNPH RCFT FDC FDC 4900,000 -81,000 2,266 9,383 40,906 559,956 9,383 ~LD DIL GR OIL DRHO FDC GR FDC TNRA CNL CNTC CNL TE~S CNL D~PT RNOB roc ~NpH CNL RCFT CNL CAb! CNL 4~00,000 :ooo 889 454'730 9'266 ILD DRHO THRA CNTC TE~$ OIL FDC FDC CNL DEPT RHOB,FDC CALt,roc TNPM,CNL ~CFT,CNb C~Li,CNL 4700 000 -85 000 2 259 9 336 4 002 48~ 184 9 336 ILD,DIL DRHO,FDC GR,FDC TNRA,C~L C~TC,C L TENS,CNL DEPT, HSP,DIL R. OB.FDC C~b];FDC TNPM,CNb CALI'CN! 4600,000 2,236 8'016 43.194 42~,346 ,016 ILO GR OIL DRHOFDC GR FDC T~R~ CNL C~TC C~b TENS C~L DE PT RHOB TNpH FDC FDC CNL 4500.000 '87,000 2,198 9,477 44,849 ILO GR DRHO FDC GR FDC T{',{RA CNL 5-D~:C-1989 13:00 3544,000 GR,CSG 3 142 111 938 0 010 lll 938 3 O38 1950 004 3454 000 006 114 313 3 3350 000 O5 063 3' 56 3360,0 0 3,293 100,000 0,011 100,000 3'762 1993,832 3280'000 3,450 91'750 01004 1;75o 3,535 1905,859 3310,000 3,!31 109,375 0,1~5 109 5 l?bO &O 3 552 3 7 Ib~,DIb TEN$,QIL FFDC,FDC TENS,FDC NPOR,CNL CFTC'CNb GR,CSG IbM,OIL TENS.DIL ~FDC,FDC TENS,FDC NPOR,CNb CFTC,CNb GR,CSG -999,250 TENS,C$G 3,044 SFLU DIL 3454.000 DPHX FDC 662,000 NFDC FDC 454,000 NPH! CNb 39,560 RCNT tnb 600,371 GR CNL 999,250 TENS CSG 3,298 SFLU,DIb 3350,000 DPHXeF 679.000 NFDC.F~ 3350,000 NPHX,CN~ 41, b 604'~ RCNT.CN GR;CNL -999,250 TENSeCSG ILM,DIL 3,041 SFLU,DI~ TEN$,DIL 3360,000 DPHI.,FDC FFDC,FDC 716,500 NFDC,FDC TENSeFDC 3360'000 NPHZeCNb CFTC,CNb .581,557 GR,CSG 999,250 TENS;CSG IbM,OIL 3,144 SFLU,FD TENS'DIb 3280,000 DPHI, FFDC,FDC ?36'500 NFDC TENS,FDC 3~80,000 NPHI' N NPOR,CNL 47,056 CFTC,CNL 5 ,155 ~LM,DIL TENS,DIL FFDC'FDC TENS,FDC ~POR,CNb :CFT~ CNL GR,CSG lb~ OIL TENS DIG FFDC FDC NPOR CNL CFTCCN5 GR CSG IL~ DIL TENS FFDC FDC TENS FDC NPOR CNL 3*285 O0 331~,000 4 '604 -99 50 2~988 3140 000 1005 500 O? .499 304 999 250 3 443 3~64 000 037 000 1'6.4 000 45 526 '$FI.,U,DI~ NFDC.FuC ~CNT GE tnb SFLU,DXb DPH~'FDC RCNT'N' TENS 8FbU, P lb DPHX,FDC NFDC'FD¢ NPHX,CNb PAGEII 12 '999,250 2,68t 20,581 633,000 .111,938 999,250 3,039 20,20t 6se,999 4t,ea~ less,es9 ~998, · :23,:~, ~4 188t,9'{~ '.~tO0,O00 ,,.{t.o I8 Tape Verlflcation hist!nE chlumberger AlasKa Co~putlno Center RCFT.CNL CALI.CNL DEPT TNPH CNL RCFT CNh CAb! CNn DEPT. RNOB FDC TNPH,CNn ~FT.,CN5 cAnY,cNn DEPT. $P.Dlb RNOB,FDC C~nY.FDC RCF?,C~n CALI.C.L DEPT,D R OB,FDC C~nI,FDC TNPB,CNh RCFT,CN~ DEPT RHO~,FDC CALI,FDC RCFT,CN~ DEPT. S P, D I L RBOB,FDC ¢~Y.FDC TNPB,CN~ RC.FT;CN[, DEPT SP RHOB FDC CAb! FDC 426 650 4400 00a -86 009 ~ 226 8 672 43 341 515 320 8 672 4300 000 -85 500 2 155 8 7~9 41 534 35! 8 4200.000 -89.000 2,{44 8,820 41,249 505,542 8,820 4100.000 -89,000 2,0~7 4 696 472,657 9;32~ 4000 000 -93 000 ~7 449 218 9 3900 000 -96 500 2 183 9 328 44 634 443 355 9 328 3800,000 '96,§00 2.206 10'0~9 CNTC.CNL TENS.CNn ILD DIn, GR DIL DRHO FDC GR FDC TNRA CNL CNTC CNn TENS CNL ILD,DI5 GR,DI5 DRHO,FDC GR,FDC TNRA,CN~ CNTC,C~b TENS,CNn ILD DRHO FDC GR FDC TNRA CNL CNTC CNn TENS CNh ILD.DiL DRHO,FDC GR'FDC TNRA,CNL CNTC,CNn TENS,CNn GR.FDC TNRA,CN5 CNTC,C~L TENS,CNn D IL,DIn GR,DIE DR}~O,FDC GR,FD~ C,TC.C~L. TENS,CNn 5-DEC-1989 i3{00 CFTC,CS5 GR,CSG I 113 I :ooo 3 708 104 438 0 O7 104 434 3 361 1902 952 2930 000 5.771 96,375 0.007 96.37~ 205~'653 2800 "668 .000 5 . 8 186 4,822 '.055 112 625 3 569 [7.96 958 282O 000 i. 254 12 '938 ;045 12~,938 1948'373 3060'000 4,380 I11~563 '0.006 111,563 4,036 187 ,Obi 268~'000 5,~09 87, 50 0,027 87,~50 IL~,DIL TENS,Din FFDC,FDC TENS,FDC NPO~'CNL CFTC,C~n GR.CSO IbM,DIn TENS,DIn FFDC,FDC TENS,FDC NPOR'CNL CFTC,CNn GR,CSG IbM Din TENS Din FFDC FDC TENSFDC NPOR CNn CFTC,CNn GR.CSG lb~ Din TENS OIL FFDC FDC TENS FDC NPOR CNn CFTC CNn GR CSG !bM,DIn TENS,DIn FFDC,FDC TENS,FDC ~POR,CN~ CFTC,CNn GR,CSG TENS FFDCFDC TENS FDC NPOR CNn CFTC CNn GR CSG 486,583 GR,¢N~ -999,250 TENS,CS 3 575 SFLU DXL 2930 000 DPH! FDC 946 500 NFDC gOC 2930 000 .PHI 4~_!~2~ RCNT CNn 53 GR CNn -999 250 TENS CSO 5,927 SFLU.DIn 2800,000 DPH[,FDC 964;000 NFDC,FDC 2800,000 NPHX,CNn 43,644 RCNT,CNn 594,701 GR,CNL ~999,250 TEN$,CSG 5.159 8FLU,DIL 2874,000 DPHX,:FDC 10i7~000 NFDC,.FDC 2974.000 4!,333 RCNT, .544,055 _ GR,CN~ 999,250 TENS,CSG 4.383 SFbU,DI~ 2820,000 DPHI,FDC 2 2,000 NFDC,FDC i8~0 NPHX,CNL ,000 2 4~, 18 RCN?,CNL 49~, 41 GR,CNL -99 , 50 ~TEN$,CSG 4-013 3~60'000 80.500 3060'000 45,852 538,255 -999,250 SFLU,DIb DPH. i.,FDC .FDC,FDC NPHI,CN~ RCNT,.CN~ TENS,CSG 4,~ 2680, DPHX.~FDC 871,500 NFDC':FDC 2680,000 ~PHX~CNL 46,333 999, T ILD.[)IL ILk.DIE 4,788 SrnU,PIn GR'DIL TENS ~Ib 2490;000 DPHI.,FDC DRHO,FDC FFDC:~- DC 894,000 NFDC'FDC GR,FDC TENS,FDC 2490,000 NPHX,CNL PAGEI i] 10 63 25,65 7~9,000 40,409 19{4,505 '999,250 $'4 ~ . 96,315 9~9,~$0 S,O02 3,9 ~ l 6,937 O, 67 iS Te~e Yerifica~iou Listina chlum~erge~ Alaska Co~putin~ Center T~PH.CNL 38.269 RCFT.CNL 525.484 CAGI.CNL 10,039 DEPT SP DIL RHOB FDC CAL! FDC ReFT CNG DEPT SP:DIL RHOB,FDC CAbI,FDC TNPH,CNL RCFTeCNb DEPT R~OB FDC CALl 'FDC TNPH CNG RCFT CNG C~L! CNG DFPT RHOB..FDC T~PH,CNL RCFT,CNL DEPT, BP,DIG RHO~.FDC C~LI,FDC DEPT 8P DIS RHOB FDC C~! FDC RCFT CNL CAhl CNG 3700 000 -94 50O 2 230 10 234 41 449 10 234 3600 000 -88 500 2 20O 9 891 4O 45O 411 780 9 891 3500.000 -63,500 1,939 9,016 59.843 280,885 9.0~6 400,000 999,250 ~999,250 999;~50 -999,250 -999.250 -999,250 3300.000 -999,250 -999'250 -999.250 -999,250 -999'~50 -999'250 3200 000 -999 250 ~999 250 -999 250 -999 250 -999 250 -999 250 TNRA.CNb CNTC.CN5 TENS.CNL DRHO DC GR.FDC TNRAi~NL CNTC NL TENS Nb XGD GR DZL DRHO FDC GR FDC TNRR CNG CNTC CNG TENS CNL ILD.DIL GR,DI5 DRHO.FDC GR,FDC TNRA,CNI. CNTC,CNL TENS,CNG ILD,DIL ORHU.FDC GR.FDC TNRA.CNL CNTC;CNb TEN~'CNL GR,DI~ DRHO~FDC GR,FDC TNRA.CNL CNTC,CNb TENS.CNG lSD GR DIG DRMO FDC GRFDC TNRA CNL C~TC CN5 TENS CNG 5-DEC-1989 13:00 3 482 1937i132 2490 000 4 121 99 625 0 O20 99 625 3 631 1771 423 2460 000 ,604 7 ,563 0,015 76,563 1774, 0 2444,000 I0.1~3 60'5 4 ~0,444 60'594 4'466 1308,149 2340.000 -999 250 ~999 250 ~999 250 -999 250 ~999 250 "999 250 '999 250 "999,250 "999'250 '999'250 '999'250 "999'2~0 "999,250 "999;250 '999.250 "999,250 '999,250 '99~:250 250 .250 NPOR.CNL CFTC,CNG TENS FFDC~FDC TENS FDC NPOR CFTC GR XLM,DIL TEN~,DIL FFDC~FDC TENS,FDC NPOR,CNL CFTC,CNG GR',CSG Ib~'DIb TENS,DIG FFDC,~DC TEN$,FDC NPOR.'CNb CFTCeCNb GR,CSG IbM'DIG .TENS,DIL FFDC,FDC TEN$,FDC N~OR,CN5 CFTC,CNG GR.CSG TENS,DIG FFDC,FDC TEN$'FDC NPOR,CNb CFTC,CNG GR,CSG IbM,DIG EN~,DIb FDC,FDC TENS,FDC NPOR.CNG CFTC,CNG GR,C$~ 39 640 RCNT.CNb 589iX20 GR,CNL -999 250 TEN$,CSG 3,~2 SFLU,DIL 2460, 0 DPHX,FDC 827,500 NFDC,FDC 2460.000 NPHIeCNL 43.405 RCNT'CN~ 508.~5 GR.CNb 90, 8 TENS,CSG 4.130 SFbU,DIL 2444.000 DPHX,FDC 881,500 NFDC,FOC 2444,000 NPHXeCNL 40,261 RCNT.CNL 519~201 G~,C~ · 90.188 TENS,CSG 2000 000 SFLU,Plb 2340 000 DPHT,FDC 540 500 NFDC,FDC 2340 000 NPHX, eCNL 59 793 RCN~,CNL 297 808 GR,CN5 60 469 TENS,CSG '999.250 SFbU,DIL - 9,~50 NFDC'FDC -9~.250 NPH~.,CNL ,250 RCN~,CNb -9 9,250 GE,CNG '9~0,531 TEN$~CSG -999 250 SFLU,DIL '-999 250 DPH~,'FDC -999 250 NFD-~FDC .-gg~ 250 NPHX:,CN~ .gE 250 RCNTeCNb 625 TENS;CSG -999,250 SFbU,DIL · -999,250 DPHI,FDC -999'250 NFDC,FDC '999;.250 NPH['CN~ '999'250 RCNT,CN~ -999,'250 GR;CNL 49~28! TEN$,CS~ PAGEI 14 1850,884 3,264 4},004 695,S00 "l!l 1754~ 2434:0 o 08 0 60,, -9 u -999'250 -999,,,~9 ~999t~50 ~999,250 -9g'9'2'! -g99,2$0 IS Ta~e Verifica~io~ Lis~ipO chlo~ber~er Ala$~e Co~pu~i~'~O Center 3100 000 -999 250 -999 25O -999 250 -999 250 -999 25O -999,250 3000,000 "999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2900 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2800 000 -999 250 -999 250 -999:250 -999 ~50 -999 50 -999 250 2700 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 GR,OIL DRHO.FDC GR,FDC TNRA.CNL CNTC.CNL TEN$.CN[~ ILD,DIL DRHO,FDC OR,FDC TNRA.CNL CNTC,CNL TENS,CNL ILD DIL GR DRHO FDC GR FDC TNRACNL CNTC TENS CN5 ILD.DIL GR,DIL DRHO,FDC GR,FDC TNRA.CNL C~TC,CNb TENS.CNL DRHO,FDC GR,~DC TNRA.CNL CNTC'CNL TENS'CNL 5-DEC-1989 13:00 -999 250 -999 0 '999 250 "999 250 '999 50 '999 ~50 "999 250 '999 250 '999 250 "999 250 =999 250 -999 250 '999 250 "999,250 "999,~50 '999, 50 '999,~0 "999t 0 '999.~0 -999. 0 "999,250 "999 '99ge25U '999'250 "999e250 -9'99.250 '999.250 '999;250 "999,250 '999'250 -999,250 2600.000 ILD,DiL "999,250 -999.250 GR;DTL '999;250 -999,250 DR~O'FDC "999~250 '999.250 G~.FDC '99~,~0 -999.250 TN"A,CNL -99~iZ:0 "999,250 CNTC'C~b '99 250 "999.250 TENS~CNL '99 250 2500.000 'ILD.DI5 "999'2§0 GR.DIL '999,250 DRHO.FDC -999,2~0 GR.FDC '999,250 TNRA,CNL -999.250 CNTC'CNL -999;250 TEN'S.CB~b -999 250 "999 ~50 "999 250 -999 250 "999 250 "999 250 "999 250 lL~ TENS OIL FFDC FDC TENS FDC NPOR CNL CFTC CNb GR CSG ILM,DIb TENS.'DIb FFDC,FDC TEN$;FDC NPOReCNL CFTC~CNb GR,CSG IL~,DIL TEN$.DXL FFDC,FDC TENS.FDC NPOR,CNb CFTC,CNb GR,CSG XL~,DIb TENS,DX5 FFDC.FDC NPOR,CN~ CFTC,<N~ GR,CSG IL~,DIL TENS,DIL FFDC,FDC TEN$~FDC NPOR,CNL CFTC~CNL GR,CSG ILM,DIL TEN$,DIL FFDC,FDC TENS,FDC NPOR,CNL CFTC.CN~ GR'CSG TENS,DI5 FFD~,FDC TENS,FDC NPOR,CNb CFTC.CNb GR,CSG -999 -999 -999 -999 -999 -999 59 250 SFLU DIL 250 DPHI FDC 250 NFDC FDC 250 NPHI CNL 250 RCNT CNL 250 GR CNb 781 TENS CSG -999 250 SFLU -999 250 DPH! -999 -999 -999 -999 59 -999 -999 -999 -999 -999 -999 49 ,DIL ,'FDC 250 NFDC,FDC 0 NPHI,CNL ~0 RCNT.CNb 50 GR,CNb 81 TEN$,CSG i50 DPHI,FDC ~ SFLU.DI~ NFDC,FDC 250 NPHXeCN~ 250 RCNTeCN~ .-999,250 SFLU,DI~ -999,250 DPHI,FDC -999.250 NFDC,FDC -999,250 NPHX,CNL -999,250 RCNT'CNL .-999,250 GR.CNL 60,28~ -999,~50 -999,:150 DPH[:~FDC ~999, 50 NFDC'FDC -999' 50 -999, 50 RCNT,CNL -999:.~50 GR'CNb 57. 38 TENS~:CS~ -999.25'0 -99 NFDC,FDC -999~250 NPHI~CN5 -999'~50 RCNT~CNL -999 250 SFLU,DIL -999 250 DPHI'FDC -999 250 NFDC~FDC -999 250 NPHI~CNL -999 250 RCNT,CNL -999;:250 ,GR,CNL ]7,844 :999, 50 999,~50 "999'250 '999, 2030, '999,250 -999,250 -999,250 -999,250 "999 '999 '999 '-999,250 9, '999,2S0 1870,000 -999,250 '-999;,250 "999':250 .%~ts~uuu -999,250 m999,250 -9:99,250 lS Te~e Verlficetioa hlsti~g cblu~berger Ales~a Com~utlng Center 5-DEC-19~9 13:00 PAGE{ 16 OEPT RHOB FDC C[~! FDC T~PH CNL DEPT, RHOB'FDC CAbI,FDC TNPH,CNL RCFT,CNb CALI,C~L DEPT SP DIG CAbl TNPH CNG RCFT CAb! DEPT SP OIL RHOBFDC CA~!FDC T~PH C~b RCFT DEPT, RHOB,FDC CAL!,FDC TNPH;C~b RCFTtCNL DEPT, HSP,DIb R .OB'FDC CALI,FDC TNPH,CNL DEPT, SP,DIL RHOB,.FDC T~PH,C~L RCFT,CN~ !400.000 999,250 .999,250 -99 250 -99 250 2300 000 -999 250 -909 250 -999 250 -999 250 -999 250 -999 250 2200,000 -999,250 -999,250 -999.,250 -999,250 '999,250 -999,250 2100.000 -999'250 -g99.250 -999.250 -999~250 -999;250 -999.250 2000,000 "999.250 "999;250 '999.;250 "999'250 '999.~56 1900 000 "999 250 '999 250 '999 250 :-999 250 -999 250 ''999 250 1800 000 -999 250 -999 250 -999 250 -999 250 -999 250 GR DRHO FDC GR FDC TNRA C~L CNTC CNG TENS CNL IbD,OIL GR,DIb DRHO,FDC GR,FDC TN~A.CN5 CNTC.CN5 TENS.C~L ILO DIG DRHO FDC GR FDC TNRA CNL CNTC CNG TENSCNL GR.DIL DRHO.FDC ~GR.FDC TNRA.CNL CNTC.CN5 TENS..CNL ILD'DIL GR,OIL DRHO.FDC GR,FDC TNRA.CNL CNTC.CN5 TE~S.CNL ILDeDIL GR'DIL DRHO.FDC GR.FDC TNRA'CN5 CNTC,CNP TENS.CNL ILD.5II.. GR,DIL DRHO'FDC GR.~C C~TC'CN~ -999 250 -999 250 -999 250 -999 250 =999 250 -999 250 -999 250 =99~ 250 -99 ~250 -999,250 -999,)50 -999~ 50 -999,250 '999.250 -999 250 -99 250 -99~ 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 '999 250 '999 250 -999 250 '999 250 '999 250 '99~,250 -99 ,250 "999'250 '999,250 '999,250 '999.250 '999'250 '999" 0 '999:.~0 "999' 0 'ggg' 0 -999 250 "999 250 -999 250 -999 250 '999 250 -999 250 FFDC,FDC t'ENS,FDC NPOR.CNL CF~'C.CN5 GR,CSG Ib~ DIG TENS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNG OR CSO ILM,DIL TENS,DIG FFDCeFDC TE~$,FDC NPOR, Nb TC, . CFGR,CSG ILM.DIL TENS,DIG FFDC.FDC TENS:'FDC NPQR,CNL CFTC;CNG GR;CSG ILM,DIL TENS'DIb FFDC,FDC TENS'FDC NPOR'CN5 CFTC.CNG GR.CSG IbM.DIG T~NS,DIG FFDCmFDC TENS.FDC NPORZCNL GR.CSG IbM,OIL TENS,DIG FFDC.FDC T~NS,FDC NPOR.CNL CFTC.CN~ -999 250 SFLU DIG -999.:250 DPHI FDC '999 250 NFDC FDC -999~2~ NPHI CNL -999,2~u RCNT CNG -999,250 GR CNL 29'969 TENS CSG -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 41 531 SFLU,DIL DPHI',FDC NFDC,FDC NPHI.CNL RCNT,CNL OR,CNG TENS,CSG -999,250 SFLU,FD~ -999,250 DPHI. :999,250 NFDC FDC 999,250 NPH~ CNL -999,25~ RCNT CNL -999,250 GR CNG 20'938 TENS CSG -999.250 SFLUeDIL -999,.250 DPHI'FDC -999,250 NFDC~FDC -999,250 NPH~,CNL -999;250 RCNT;CNL '250 GR,CNL '9~.03, TE.S.CSG -99 ;250 NFDC FDC -999 ~0 NPHI CNL -999~.~0 RCNT C~b "999,250 GR ~28;047 TENS -999,250 -999,250 -999:':250 NFDC,FD¢ -999,250 :999,25 48,969 TENS'CSG -999,250 SFLU,DI~ -999'250 DPHI,FDC '999,250 NFDC,FD¢ :999,2~9 NPHI,CNL .999,250 RCNT.CNb 999.~50 GReCNL "999,250 '999,250 '999,250 '"999l' SO -999,)50 "999' 250 1780,000 -9, 0 -999, 0 199~.00080 "9'.tlo -999" 0 -999,250 w999~2~0 -999,'2~0 '999,e '999' -999' -999, 1.7 l:O,O00 -999,250 -9 9,,: :0 :.,I, :e999 ~:2'50 - 999 ;: 25 0 -999,250 IS Tspe Verification LlstinO chlumberger ~l~$ka Co~putinq Center 5-DEC-19BQ 13:00 CALY,CN!:, -999,250 TENS,CNL '999,250 GR,CSG 1700,000 IbD,OIb OIL '999,250 G~,DIL FDC '999,250 DRH ,FDC CNL -999,250 TNR CNL CNL -999,250 CNTC'CNL CNa, -999,250 TENS,CNL D~PT SP RHOB TNPH CALl 1600 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 GR'DIb ORHO,FDC GR,FDC TNRA,CNL CNTC,CNL TENS,CN5 DEPT, SP,DIL RHOB,FDC Ca~Y;FD¢ TN~H,CN~ RCFT,CNL CALI,CNL OIL FDC FDC CNb 1500 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILO OIL DRHO FDC GR FDC TNRA CNL CNTC TENS CNL CaLl TNP~ RCFT CALX OIL FDC FDC C~L 1400,000 -999,250 -99~:250 '99 250 '99 250 -999,250 GR DRHO GR TNRA CNTC TENS , DIE, ,OIL ,FDC , FDC , CNb ,CNL DEPT RHOB CALl RCFT 1300 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 GR,DIL DRHO'FDC GR,FDC TNRA;CNL CNTC'CNb TENS'CNL DEPT, SP'DIL RHOB,FDC CALX,FDC TNPH,.CNI., CILI,CNI, 1200,000 -999'250 -999'250 "999,250 '999,250 -999'250 ILO,OIL GR,DIL ORHO;FDC GR,FDC TNRA~C~[, TENS'CNb DEPT, BP,DX5 RNOB'FDC Ci~X,FDC TNPH,CNL RCFT,CNL CALI,CWI, 110,~,000 OIL -99:150 FDC -999 50 CN[, -999 50 ILO.OIL DRMO FDC TNR~ CNb DEPT CALX, TNPH -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 '999 250 '999 0 '999 250 46,344 TEN$,CSG lb~,Olb -999,250 SFLU,DXL TEN ,OIL -999,250 DPHI,FDC FFDC,FDC '999,250 NFDC,FDC ?ENS.FDC -999,~0 NPHX.CNL NPOR,CNL -999, 0 RCNT,CN~ CFTCeCNb -999,250 GR,CNL GR,CSG 48,063 TENSeCSO ILS,OIL TENS,OIL FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG '999,~50 XLM,DI5 '99~ ~iO TENS.DI~ -99 : 0 FFDC,FDC '999, 0 TENS,FDC -99~:~50 NPOR.CNb '99 50 CFTC,CNL '999,250 GR,CSG '999 250 IL~,DIL ''999 250 'TENS,OIL '999 250 FFDC'FOC '999 250 TENS'FDC '999 250 NPOR'CNL '999 250 CFTC;CNb -999 250 GR'CSG -999,250 XL~,DIL .-999,250 TENS'OIL -999'250 FF~C,FDC -999'~50 TE~S,FDC -999,250 NPOR,CN5 -999,250 CFTC'CNb -999;250 G~,CSG TENS'OIL FFDC,FDC TENS,FDC CFTCgCNL .GR~CSG TENS FFDC FDC TENS FDC NPOR ' 99,250 '999,250 '999'250 '999,250 '999,250 '999'250 "999, 0 '999, 0 '999,50 '999'250 -999,250 SrbU,Olb -999,250 DPHX,FDC -999,250 NFDC,FDC -999,250 NPHI,CNL -999,250 RCNT,CNL -999,250 GR,C~{L 30,203 TENS,C$O -999'250 SFLU,DIL -999.250 DPHI,FDC -999;250 NFDC,FOC -999'250 NPMI,CNL -999,250 RCNT,CNL -999,250 ,GR,CNL 31,188 TEN$,CSG -999'250 SFLU,D'~L '999,250 DPHI,FDC .999,'25 NPHI,CNL -999'250 ~CNT,CNL -999'2~0 GR,CNL 46'438 TENS,CSG '999,250 SFLU,,DIL -999,250 DPHI'FgC -999,250 NFDC;FDC -999 ~50 NPHI.,CNL -999:50 RCNTeCNL -9~9: 0 O0 TEN$.CSG -999 ~50 DPHI,FDC -999:50 NFDC,FDC -999,250 -999 !50 RCNT,CNh -999i, 50 GR'CNL 45 88 -999,250 SFLtI,DIL -999'250 DPHI.~FDC -999'250 NFDC,FDC -99_9, _250 NPMI. eCNL -999'250 RCNT,CNL PAGEI 1585,000 '999.250 -999,250 "999,250 -999.250 "999.250 "999"250 15i$,-000 "999.250 "999.,250 "999,250 t -,,, -999, :-999,250 ~475.000 -999.250 '99v, '999, ~90,000 '999,250 "999,250 -999,2~0 ~)05,.0 -999,250 :'999.250 :'999'2~0 '"999~250 '"999,250 1265,o00 -999,;250 .m999,250 -999~2~0 ~999,250 ,-999~25o '999,250 ~?0,:0:00 '999,~ "999'250 IS Ta~e Verification Listing chlum erger AlasKa Co,mputtnq Center DEPT CAL~ TNP RCFT CAL! FOC FDC CNL CNL i000 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 DRHO,FDC GR'FPC TNRA,CNL C~TC,CN5 TEN$,CNL DEPT, SP,DIL RHOB,FDC CALI,FDC TNPH,CNL RCFT,CNL CALI.C~{L 968 500 -999 250 -999 250 -990 250 -999 250 -999 250 -999 250 GR,DIL D~HO,FDC GR,FDC TNRA,CNL CNTC,CNL TEN$,CNL END OF DATA 5-DEC-1989 13:00 -999 250 CFTC,CNb -999]250 GR,CSG -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999, 0 -999.2 0 -99~.250 "99~ 0 '99 :250 ILM,DI5 TEN~,DI5 FFDC;FDC TEN$,FDC NPOR,CNL CFTC,CNL GR,CSG IbM TEN$ DIL FFDC FDC TENS FDC NPOR CNL CFTC GR CSG -999,250 GR.CNL 35.344 TEN$,C~G :999, 50 SFLU.DIL .999,~50 DPHI,FDC .999,250 NFDC,FDC .999,250 NPH~eCNL 999, ,CNL .999,~50 RCWT 50 GR,CN~ · 44,969 TENS,CS~ -999 250 SFLU,DIL -999 250 DPHI,FDC -999 250 NFDC.FDC -999 250 NPHI,CNL -999 250 RCNT.ii~ -999 250 GR, b PAGEI 18 '999,250 itlO,O00 '999,250 '999 ;" .ooo 09 -~99, " 99, ' ~0 **** FILE FIbE NA~E ~ EDIT ,OOi $~RVICE { FLIC V~R~]ON ~ 001A04 DATE J 89/~2/ 5 MAX REC SIZE : 1096 FILE TYPE LAST FILE **** FILE HEADER **** FIE~ NA~E : EDIT .002 SERVICE : FhIC VERSION J 001A04 DATE : ~9/12/ 5 MAX RECSIZE : 1096 FILE TYPE : LO baST , * FILE - EDIT,O02 ARCO ALASKA, INC. * KUPARUK * 2K - 17 ?ape verification Listlnq cblumbe, rqer AlasKa Computtn,~. Center 5-DF, C-1989 13:00 50-103-20121-00 HIGH RESOLUTION DATA SAMPLED EVERY -,1000 FEET DATA INCbUOED - TOOL EXTENSION TYPE USED FDC ,FDH CNT-A/D/H ,CNA TOOL NAME FORMATIO~ DENSITY COMPENSATED NEUTRON PAGEI 19 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC, Company Name FN KUPARUK Field Name WN 2K - I7 Well Name RPIN 50-103=20121~00 APl Serial Number FL 169' FNb & 94' FEb field Location SEC? il Section TOWN iON Townsht'p RANG 8E Range COUN NO~TH SLOPE County :STA~~ ALASKA State or Province ATI USA ~ation_ ~AT! Latitude Longitu~e LONGwITN PI~ON/LOWEN/KINNEVAN Wit6ess' Name SON 54374 Service orderNumber ~Sb Permanent datum .PD~T FT ~e Log ~eesured From APD FT 154, EK8 FT 154 EOF FT 153} EGL FT 113 TDD FT STE~ DEGF 999,25 IS Tape Verification Listlnc~ c~lum~eroer AlasKa Computlnq Center 5-DEC-I989 13:00 TABLE TYPE : CURV DEFI DEPT Depth Channel Name D~HI Density Porosity RHO8 ~ul~ Density DRHO Delta RHO FFDC Far FDC Count Rate NFDC Near FDC Count Rate CAhI Caliper OR Gamma Ray T~N$ Tension T~PH Thermel Neutron' Porosity TNRA Calibrated Thermal Neutron Ratio NPOR Neutron Porosity Output From an APplication Proqram RCNT RCNT RCFT RCFT CNTC CNTC CFTC CFTC GR Gamma Ray CAL! Call er TENS Tension PAGEI 2O DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE RgPR CODE VALUE I 66 2 66 0 3 73 80 4 66 ? 9 65 r 11 66 I3 12 68 !3 66 0 14 65 FT 15 66 68 16 66 0 66 5-DEC-1989 13~00 ** SET TYPE - CHAN m* N~ME SERV UNIT SERVICE &PI APl AP[ APl FILE NUmB NUMB SIZE BEPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SA~P ELE~ CODE (HEX) D~PT FT 548374 OO DPH! FOH PU 548374 07 R~O8 FDH G/C3 548374 07 DRHO FDH G/C3 548374 07 FFDC FDH C~S 548374 07 NFDC FDH CPS 548374 07 C[~I FDM IN 548374 07 G~ FDM GAPI 548374 07 T~N$ FDN LB 548374 07 N~H! CNH PU 548374 07 TNPW CNH PU 548]74 07 TNR, C~. 548374 07 NPO~ CNH ~U 548374 07 RCN? ON, CPS 548374 000 O0 0 2 1 I 4 68 0000000000 635 21 0 2 1 1 4 68 0000000000 350 02 0 2 1 1 4 68 0000000000 356 O1 0 2 1 1 4 68 0000000000 354 02 0 2 1 1 4 68 0000000000 354 Ol 0 2 1 1 4 68 0000000000 2~0 01 0 2 1 I 4 68 0000000000 310 Ol 0 2 1 1 4 68 0000000000 635 21 0 2 1 1 4 68 0000000000 890 O0 0 2 1 1 4 68 0000000000 890 O0 0 2 1, 1 4 68 0000000000 4~0 O1 0 2 I I 4 68 0000000000 890 O0 0 2 I 1 4 68 0000000000 420 O1 0 2 1 1 4 68 0000000000 420 Ol 0 2 1 t 4 68 0000000000 420 01 0 2 I 1 4 68 0000000000 420 O1 0 2 1 I 4 68 0000000000 310 O1 0 2 1 t 4 68 0000000000 2SO O1 0 2 1 1 4 68 0000000000 635 21 0 2 1 1 4 68 0000000000 PAGE{ 21 DATA DEPT FFDC~FDH NPOI~, C ~H CFTC ,CNH DEPT, FFDC,~DI-I TENS,I~DH NPO~ ,CNM CFTC,CNH DEPT FFDC TENS NPOR CNH CFTC CNH DEPT, FFDC,FDH TENS,FDH NPO~,CNH CFTC,CNH 9177.000 1439 000 1655 000 44 590 510 855 9100,000 471.75.~ 5884,000 43'286 517'0~5 9000,000 4'81:250 60:~ 000 ~5 340 7~ :836 777 500 6008 000 28 914 1032 567 DPHI.FDH NFDC.FDH NPHI*CNH RCNT,CNH GR,CNH DPHI FDH NFDC,.FDH NPHI.CNH RCNT..CNH GR.CNH DPHIFDH NFDC FDH ~P~I CN~ RCNT CNH GR CNH DPMI.FDH NFDC ~DH NPHI.CNM RCNT'CNH GR'C~ 31 566 94 44 000 868 1818 037 1!1 938 1 4 .500 5.280 180 '55 11~ 5 ,500 11,494 , 0 96. 5 23,381 685.~0 29' 0 2649 ' 369 44,750 RHOB. FDH CALl FDH TNPH CNH ~CFT CNN CAL! CNH RHOB FDH CALl FDH TNPH CNH RCFT CNH CALI CNH RHOB FD~ CAbI FDH RCFT CALI CNH RHOB,FDM CALI,FDH TNPH,CNH ~CF?'CN. CALI'CNH 2,129 DRHO FDH 6,590 GR~FDH 44.590 TNRA'CNH 452,863 CNTC.CNH 6.590 TENS,CNH TNRA,CNH ?ENS,CNH 2,460 DRHO'FDH TNRA;CNH 588 CNTC'CNH 438 TENS,CNH 2,264 DRHO.FDH 8'352 GR;FDH 29'229 TNRA,CNH 930,~46 C~TC,CNH 8,352 '0.,444 3,6~9 o'o , i18434~094 5884,000 60i2,000 0'029 44:,750 272:~ ''~00 ,i29 600~;.000 TS Tape Veriftcat~,on Listing chlumberger Alaska Computlr~g C.nter 5-DFC-t989 13:00 22 DEPT FFDC FDH TENS FDH NPOR CNH CFTC CNH DEPT FFDC FDH DEPT, FFOC'FDH TENS,FDN NPOReCNfl CFTC,CNH DEPT FFDC FDH TENS FDH NPOR CNH CFTC CNH DEPT, H FFDC,FD... TENS.FOB NPOR.CNH CFTC.CN~ 8800,000 493,500 5640,000 29,699 1003,484 8700.000 607,500 5764,000 40'460 507,]72 ~600 000 504 500 5578 000 46 325 465 781 8500,000 519,000 5420,000 40,375 556.439 8491 600 556 000 53OO 000 42 149 538 7~5 ENO OF DATA DPHI FDH NFDC FDM )iPHI CNN RCNT CNH GR DPHI.FDM NFDC'FDH qPHI'CNM RCNT'CNH DPHI FDH NFDC FDM NPHI CNH RCNT CNH GR CNH DPHI FDH NFDC FDH RCMT CNH GP CNH DPHI,FDH NFDC,FD~ RC~? NH GR,CNH 11 527 609 o00 27 873 2480 402 70 938 17 204 639 000 42 I76 1660 848 141 500 14.591 69,000 548.499 1746,~122 114, 3 11,478 62 .000 42,717 142. 0 15.638 622 500 43 686 1843 379 ~ 46 875 RHOB, FDH CALI,FOH TNPH'CNH RCFT,CNH CAI. I,CNH RHOB FDH CALl FDH TNPH CNH RCFT CNH CALl CNH AH08 FDH CALl FDM T~PH CNH RCFT CNH RHOB,FDH PH,CNH RCFT ~ CAbI,CN~ RHOB.FDH CALI,FDH TNPH, CNH RCFT,CNM CALl ;CNH 2 460 DRHO 8 477 GR 29 024 TNRA 958 49~ CUTC 8 47 TENS ,FDH ,FDH ,CNH ,CNH 2,366 DRHO,FDH 4[. 4 TNRA: NH 465,171 CNTC 9. 34 TENS: NH 2,409 DRHO,FDH 69:289 GR.FDH 4 323 TNRA,CNH 3991:605 CNTC,CNH 289 TENS,CNH 2,444 DRHO,FDH 9,172 39 TN~''FDH 9, TENS,CNH :~, 392 DRHO,FOH ,,648 TNRA~CNH ,150~ CNTC;CNH ,18 TENS,CNH 0 040 70 938 2 595 94 2634, Od~ 5640 0 03' 14t 50~ 5764 00~ -0,00~ ii4,{i{ 3'854 748,036 5528,000 14' 26:ooo 0,0 0 14§,8~5 ~ · 5:82 1864.::02(~O0 5300, **** FILE TRAILER **** FILE NAME ~ EDIT .002 SERVICE I FLIC VERSION : 001A04 DATE I 89/12/ 5 ~RX REC SiZE : t096 FILE TYPE : LO LAST FILE : ,$** TAPE TRAILER **** · SERVICE NAM,s : EDIT DATE : 89/12/ 5 ORIGIN ~ FLIC TAPE WA~E : 73555 CONTINUATION # PREVIOUS TAPE COMMENT = A~CO ALASKA, INC,,KUPARUK,2K - 17,50~103-20t21-00 IS Ta~e Verification blstino eh]um erger AlasKa Com~uting Center 5-DEC-Ig@9 13100 **** REEb TRAILER **** SERVICE NAM~ : EDIT DITF ~ 89/12/ 5 ~EEL ~A~E ~ 73555 CONTINUATION # ~ PR£V~OUS REEL ~ CO~ENT ~ ARCO ALASKa, INC,,KUPARUK,2K ' 17,50'103'20121'00
