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Home My WebLink About184-130WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Conon. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2G-14 Run Date: 11/18/2019 184139 3 159 4 November 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21161-01 RECEIVED DEC 0 9 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: ! q Signed: ' STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 0 1 2015 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil IDGas[1] SPLUG SPLUG ❑ Other ❑ Abandoned E • Suspended 1b.Well Class:A0GG 20AAC 25.105 20AAC 25.116 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No.of Completions: Service 0 - Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 5/26/2015 184-130/315-139 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510 10/2/1984 50-029-21161-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 243'FNL, 88'FEL, Sec.6,T1ON, R9E,UM 10/7/1984 KRU 2G-14 - Top of Productive Interval: 9. KB(ft above MSL): 140' 17.Field/Pool(s): 4106'FNL,3864'FEL,Sec.6,T1ON, R9E, UM GL(ft above MSL): 102' Kuparuk River Field/Kuparuk River Oil Poo• Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4265'FNL,4012'FEL,Sec.6,T1ON, R9E, UM 8296'MD/5968'TVD ADL 25667• 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 508610 y- 5943345 Zone- 4 8750'MD/6296'ND ALK 2588 TPI: x- 504704 y- 5939479 Zone- 4 12. SSSV Depth MD/ND: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 504692 y- 5939319 Zone- 4 2055'MD/1920'ND 3410'MD/2814'ND 5. Directional or Inclination Survey: Yes ❑(attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 not applicable (ft MSL) not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary SCANNED SEP 0 9 2015 NONE 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 62.5# H-40 38' 110' 38' 110' 24" 202 sx Cold Set II 9.625" 36# L-80 34' 3327' 34' 2760' 12.25" 1060 sx Permafrost E,370 sx PF C 7" l 26# J-55 33' 8724' 33' 6278' 8.5" 335 sx Class G,250 sx PF C 24.Open to production or injection? Yes ❑ No 0 , 25.TUBING RECORD t If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 1 Size and Number): 3.5" 8374' 8345'MD/6003'ND perfs squeezed off:8452'-8470'MD / 6081'-6094'ND and 8490'-8532'MD / 6109'-6139'ND 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. V.lWas hydraulic fracturing used during completion? Yes❑ Noll Per 20 AAC 25.283(i)(2)attach electronic and printed information .a; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 8296-8724 15 bbls 16.5 ppg Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): _ well suspended Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ...* Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate l , Form 10-407 Revised 5/2015 V77- 4/ Z/!,)--CONT INNUECD O PAGE 2 RBDM414 !. . Submit ORIGINIAL only, 4 'r/�/,Y I . F 9ttl J 28.CORE DATA Conventional Core(s). Yes ❑ No ❑.r Sidewall Cores. Yes ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25 071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30 FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 3410' 2814' Attach separate pages to this form, if needed,and submit detailed test information,including reports,per 20 AAC 25 071. Top Kuparuk B 8383' 6030' Top Lower Sand 8434' 6067' Base Lower Sand 8610' 6194' NONE Formation at total depth: Kuparuk B 31. List of Attachments: Summary of Daily Operations,schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070 32. I hereby certify that the foregoing is true and correct • ,e best of my knowledge. Contact: Jason Burke @ 265-6097 �IOP''' mail: Jason Burke@cop.com Printed Name: Dan Venhaus Title: CTD Engineering Supervisor Signature: 4Z-1_ Phone: 263-4372 Date: 6 -(S INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells.Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05 030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only r (3L ! KUP INJ 2G-14 ConocoP lillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) CanowiNFq 500292116100 KUPARUK RIVER UNIT INJ 53.97 4,200.00 8,750.0 ... .l Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 25-14.6/2320151:0747 PM SSSV:LOCKED OUT Last WO: 40.98 10/10/1984 • Vertical schemer..(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 8,296.0 5/20/2015 Rev Reason:CEMENT PLUG, lehallf 5/232015 iPERFORATIONS,TAG Casing Strings HANGER,32.0 �I F Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ,..1 1 CONDUCTOR 16 15.062 38.0 110.0 110.0 625011-40 WELDED 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE I Casing Description 9 5/8 8.921_ 34.0 3,327.0 2,760.0 36.00 L-80 _BUTT OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.. Grade Top Thread " '' "- "' 4°'PRODUCTION 7 6.276 32.9 8,724.0 6,278.3 26.00 J-55 BUTT .A.h/CONDUCTOR;38.0-110.0- Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(.. Wt(lb/ft) Grade Top Connection TUBING 312 2.992 32.0 8,373.9 6,024.4 9.30 J-55 EUE8rd SAFETY vl.v,2,054.0 Completion Details IIITop Nominal ID (ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) 32.0 32.0 0.01 HANGER McEVOY TUBING HANGER 3.500 2,054.8 1,920.4 40.30 SAFETY VLV BAKER FVL(LOCKED OUT 6/18/2001) 2.810 GAS LIFT;2.104.2 *, ; 8,330.9 5,993.3 44.14 PBR BAKER PBR 2.810 8,344.6 6,003.2 44.01 PACKER BAKER FHL PACKER 3.000 8,361.6 6,015.5 43.84 NIPPLE CAMCO'D'NIPPLE(Milled out 5/13/2015) 2.800 8,373.2 6,023.8 43.74 SOS BAKER SHEAR OUT SUB 3.000 SURFACE;34.0-3,327.0-• Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;4,420.3 M f. Top(ftKB) (ftKB) (°) Des Corn Run Date ID On) 8,455.0 6,083.1 43.45.WHIPSTOCK Baker 3.5"XL Monobore Whipstock with OH Anchor 5/26/2015 GAS LIFT;6,185.8 MONOBORE FM. Perforations&Slots GAS LIFT;7,473.1 Shot Dens • Top(ND) Btm(TVD) (shots/f IlijTop(ttK8) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;8289.2 8,357.0 8,359.0 6,012.1 6,013.6 A-4,2G-14 4/20/2015 3.0 APERF 2"HSC 120 deg,bh charges 8,452.0 8,458.0 6,081.0 6,085.3 A-5,2G-14 929/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH PBR;8.330.9 8,458.0 8,459.0 6,085.3 6,086.1 A-5,2G-14 929/1985 4.0 RPERF 2 1/8"BarKone II;0 deg PACKER;8,3446 pH JJ 8,458.0 8,459.0 6,085.3 6,086.1 A-5,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg pH APERF;8.357.0.8,359.0— 8,459.0 8,466.0 6,086.1 6,091.1 A-5,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH f 8,459.0 8,460.0 6,086.1 6,086.8 A-5,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg NIPPLE;8,361.6 N,-g`aaa,,,,,, pH 3, G11 ,k 8,465.0 8,466.0 6,090.4 6,091.1 A-5,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg I pH SOS;8,373.2 ' 8,466.0 8,467.0 6,091.1 6,091.9 A-5,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH 8,467.0 8,470.0 6,091.9 6,094.0 A-5,2G-14 '929/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH Liner All Lateral;8962.4- 9,940 ,362.4- - �/+.. 8,467.0 8,468.0 6,091.9 6,092.6 A-5,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg 9,940,0 "y.`n pH RPERF;8,452.0.8,458.0 8,490.0 8,495.0 6,108.6 6,112.2 A-4,20-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,458.0.6459 0 pH RPERF;8.458.0-8,459.01 ( - RPERF 6459.0.64W. — hW, 8,495.0 8,498.0 6,112.2 6,114.4 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone ll;O deg WHIPSTOCK-MONOBORE;1 His pH 8,466.0 RPERF;e.459.0-6486.0— 8,495.0 8,496.0 6,112.2 6,112.9 A-4,2G-14 929/1985 5.0 RPERF 2 1/8"BarKone II;0 deg i,•, _ pH RPERF;8,465.0-8,466.0— 8,498.0 8,499.0 6,114.4 6,115.1 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg v,J-. pH RPERF;8,486.0-8,487.0 '?:,,, 8,498.0 8,499.0 6,114.4 6,115.1 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,467.0-8,468.0— "2 pH RPERF;8,467.0.8,470.0 '^ 8,499.0 8,503.0 6,115.1 6,118.0 A-0,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg ✓'ry.`n - pH Y,J;,.. 8,499.0 8,499.0 6,115.1 6,115.1 A-0,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg pH RPERF;8,490.0-6 ; .495.0— :::.-" ''.,,,-.1" ^s 8,502.0 8,503.0 6,117.3 6,118.0 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg pH RPERF;8,4950-6,496,0— .. A. 8,503.0 8,508.0 6,118.0 6,121.6 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,4950-8.498.0 * JVD:.. n pH RPERF:8,498.0-8,4990 _ RPERF;8.498.0-6.499.0 � 8,508.0 8,511.0 6,121.6 6,123.8 A-0,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,499 0--11:-Z:-::::-1 pH RPERF;8,499.0-8,503.0 ....0.a 8,511.0 8,516.0 6,123.8 6,127.4 A-4,20-14 9/29/1985 4.0 RPERF 21/8"BarKone II;0 deg [a„^„ RPERF;8.502.0.8,503.0— pH RPERF;6503.0-8.508.0— ss: 8,515.0 8,516.0 6,126.7 6,127.4 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg ^ pH RPERF;8,508.0-6,511.0— ^ - 8,516.0 8,526.0 6,127.4 6,134.7 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8.511.0-8.5160— pH RPERF;8.515.0-8,516.0— -: �� ..,;y,v-f 8,526.0 8,530.0 6,134.7 6,137.6 A-4,20-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8.516.0-8,526,0— pH � 8,530.0 8,532.0 6,137.6 6,139.1 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 de RPERF;8,526.0-8,530.0— ,m H g RPERF;8,530.0.8,532.0— p Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 8,296.0 8,724.0 5,968.4 6,278.3 Cement Plug 5/17/2015 15 Ebbs 16.5 ppg PRODUCTION;33.08,724.0 *e,- $ KUP INJ 2G-14 ConocoPhillips -, Alaska,Inc. rn., rmu pn ••• 2G-14.6/2320151:07:47 PM Vertical schematic(actual) s Mandrel Inserts HANGER;32.0 1�� _ St It D ati [ 1 on Top(ND) Valve Latch Port Size TRO Run N Top(RKB) (Po(B) Make Madel OD(in) Sery Type Type (in) (pe0 Run Date Com I f 2,104.2 1,957.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/20/2001 5:30 F • �o-1to I 2 4.420.3 3,427.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/20/2001 2:00 N1 CONDUCTOR:38 0•' 3 6,165.8 4,552.8 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/202001 9:30 4 7,473.1 5,413.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/20/2001 4:30 5 8,289.2 5,963.5 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0.6/19/2001 8:00 SAFETY VLV 2.0546 Notes:General&Safety IEnd Date Annotation 4/17/1994 NOTE:SSSV acts as CHECK VALVE;DO NOT run WL Tool String Past SSSV.(4/17/94) 620/2009 NOTE:VIEW SCHEMATIC w/Alaska Schemalic9.0 GAS LIFT:2,104.2 : SURFACE;39.63,327.0—. GAS LIFT;4,420.3 GAS LIFT;6,165.8 GAS LIFT;7,473.1 1 Ip GAS LIFT;8,289.2 i y: _4 PBR;8,330.9 PACKER;8,344 6 APERF;8,357.0.8,359.0— titi NIPPLE; . - Rill Iul 1 SOS;8,373.2 a 14,4 „,. ti` Liner AL1 Lateral;8,362.4 9,940.0 sr,. RPERF;8 452 0-8458.0 — 01Ai t RPERF;8,458.0-8,459.0 ' ) . RPERF 8,458.0-8,459.0 j RPERF 8,459.0-8,460 0 Viiii WHIPSTOCK-MONOBORE;1 8,455.0 _ -S. _. RPERF;8,459.0-8,466.0— RPERF;8,465.0-8,466.0— I ' RPERF;8,466.0.8,467.0 " t,'" t'siii RPERF;8,487.0-8,468.0 RPERF;8,467.0-8,470.0—. . vu RPERF;8,490.0-8,495.0— T"M,O RPERF;8,495.0-8,496.0— w~i. RPERF;8,495,0.8,4980y..,�,,,'� RPERF;8,498.0-8,4990 ,,,,,,,.*:3._ RPERF;8,498.0-8,499.0 RPERF;8,499.0i,,f RPERF;8,499.0-8,503.0— , RPERF;8,502.0-8.503 0— RPERF;8,503.0-8,508.0— ��-`�. RPERF;8,508,0-8,511.0 :,ii-C,... ,- ,.. : RPERF;8,511.0-8,516.0— ...-v% *_ RPERF;8,515.0-8,5160— .,;:�2t ,ir i., � RPERF;8,516.0-8.526.0— 'H RPERF;8,526.0-8,530.0— • ''''I i''. RPERF;8,530.0-8532.0 I I PRODUCTION;33.0-8,724.0 • 0 , C II) s 0 th ,:r 6 m Z g a co o o >- (o 0 m 0C° y N U) oN 6 w O j MO) O N y nO°° 0O O cc Y 0 V Na O L N It •0 cii 1- S a O II L Oo N 2N ❑- QC O N P�..O co F ¢ in C Nv in m II co- o 7Ma fl.c‘i D Q N ON N © 'D itit N m co OI N _� 2 ? m1) u_C7 2pp 0_U t 0p 16 O d O_J.0 0) N m• * E N J _ E Y N co m n of U Pi u_ �U S r Na NN N N . N: N co co M y 05 co m m P5 PM 's I 111 1 11 A _--' '''''' Ill i 73 _ __ 0 ofPT V - N N a ami a o o t M 13 m2cn oo-(N' (nO O J N co -a -CO 03 * 20 (CON C2 C (O V A0 M� O N N d £N y(OO r---co (O y GJ y Q U� Qm P�0 (OLm .-1-?t N_ Cy) U) 2r "1. PRE AND POST RIG WELL WORK SL'' 'ARY PRE RIG WELL WORK DATE SUMMARY 2/24/2015 (PRE-CTD): MITIA(PASSED TO 3000 PSI), MITOA(PASSED TO 1800 PSI), T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), FT LDS (ALL FUNCTIONED PROPERLY). 2/25/2015 (PRE-CTD) : TREE VALVE DDT: SV, MV, SSV(PASSED), TREE VALVE PT: SV, MV (PASSED), SSV(FAILED). 3/23/2015 MEASURED BHP @ 8500' RKB: 3843 PSI. COMPLETE. 4/20/2015 PERFORMED A TUBING PUNCH FROM 8357-8359 WITH A 2"2' 120 PHASE, 3 SPF, BH HSC. LRS PERFORMED SW INJECTIVITY TEST DOWN TUBING 0.43 BPM AT 1180 PSI, 0.5 BPM AT 1190 PSI, 1 BPM AT 1250 PSI, 1.25 BPM AT 1350 PSI, 1.5 BPM AT 1450 PSI. 4/21/2015 PUMP 150BBLS SW FOR INJECTIVITY TEST FOLLWED BY 30BBLS DSL FOR FP (JOB COMPLETE) 5/5/2015 MEASURE BHP @ 8500' RKB (3748 PSI). JOB COMPLETE 5/13/2015 Mill Nipple. Late start due to rig move and wait on hardline to be rigged up. RIH to D Nipple © 8,362'and painted EOP flag. Milled nipple out with 2.80"tapered mill. Mill gauged 2.80". Will have to jet w/Schmoo-B-Gone in morning. Well freeze protected. Job in progress. 5/14/2015 Pump 25 bbls 16.5 ppg cement and squeeze into A-Sand Perfs. Unsuccessful attempt to to hold requested squeeze pressure (2,200 psi). Contaminate down to 8,400' and wash mandrels and jewerly while POOH. Restart in morning. 5/15/2015 Tag TOC @ 8,526' RKB corrected. Perform FCO to clean any residual contaminated cement from 8,300' down to tag. After initail gel pill returned to surface with slug of cement fluids were clean remaider of FCO.Reciprocated pipe at very slow speeds numerous times through cement area down to TOC. Well freeze protected and ready for cement in morning. Job in progress. 5/16/2015 Second attempt at cement plug unsuccessful. Pushed cement away and washed up 7" casing and tubing jewerly while POOH. Will return in morning and pump cement with Syntec fiber. Job in progress. 5/17/2015 Pump 15 bbls 16.5 ppg cement with middle 8 bbls containing 1 ppb CemNet fiber. Obtained squeeze pressure while squeezing 7.5 bbls behind 7" casing. Washed down to just above target depth of 8,352' RKB corrected. POOH washing tubing jewerly while maintaining overbalance on well. Well freeze protected and ready for Slickline in 72 hrs. 5/19/2015 (PRE CTD)TREE VALVE TEST, JOB POSTPONED DUE TO VALVES LEAKING BY. 5/20/2015 TAGGED CMT WITH 2" BAILER @ 8296' SLM, EST. 8336' RKB. COMPLETE. 5/20/2015 (PRE-CTD): TREE VALVE PPT: MV(PASSED), SSV(PASSED), SV(PASSED). TREE VALVE DDT: MV(PASSED), SSV(PASSED), SV(PASSED). ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 2G-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 5/22/2015 10:00:00 AM Rig Release: 6/1/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/21/2015 24 hr Summary Mob to 2G Pad 15:00 18:00 3.00 0 0 MIRU MOVE MOB P MOB to 2G 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Crew change-Continue to 2G pad- hold @ 2A for additional matting21:00 to 23:30 05/22/2015 MIRU,to 2G-14,tested BOPE 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Continue to 2G-14,Arrive on location @ 1:00AM 01:00 02:00 1.00 0 0 MIRU MOVE MOB P Check status on 2G-14, Remove Jeeps, Pull tree cap flange 02:00 06:30 4.50 0 0 MIRU MOVE MOB P Spot sub and pits. Soft pad conditions need cat to move fore and aft 06:30 10:00 3.50 0 0 MIRU MOVE MOB P Rig modules spotted, MIRU 10:00 12:00 2.00 0 0 MIRU WHDBONUND P Rig Accept© 10:00, Nipple up stack 12:00 22:45 10.75 0 0 MIRU WHDBO BOPE P Start full BOPE Test, Test witness waived by John Crisp,AOGCC. BOP test pressure low 250/high 4300 psi /Annular 2500 psi 22:45 00:00 1.25 0 0 MIRU WHDBO BOPE P Fluid pack coil, test inner reel valve and pac off.swab valves. 05/23/2015 Completed BOP test, MU, RIH with 0.9°and D331. Mill cement pilot hole. 00:00 00:45 0.75 0 0 MIRU WHDBO CTOP T Replace blind rams, IA 700, OA 0 00:45 01:45 1.00 0 0 MIRU WHDBO BOPE T Retest Lower blind rams, 01:45 02:30 0.75 0 0 MIRU WHDBO CTOP P Test PDL's and kill tank line 02:30 04:00 1.50 0 0 MIRU WHDBO MPSP P PJSM, Load, MU,and PT FMC lubricator. Pull TWC 04:00 06:30 2.50 0 62 PROD1 RPEQP1 PULD P PJSM, PU BHA#1 pilot hole milling assembly, deploy, hole dead. Deploy ""Note: coil wall thickness 0.179" good. 06:30 08:54 2.40 62 8,270 PROD1 RPEQP1 TRIP P RIH, swap hole to milling fluid(9.34 ppg), flud @ the bit 09:25. 08:54 09:06 0.20 8,270 8,325 PROD1 RPEQP1 DLOG P Log GR tie in,did not get correlation 09:06 10:00 0.90 8,325 8,230 PROD1 RPEQP1CIRC P Circulate well to 9.3 PPG milling fluid while analyzing logs 10:00 10:54 0.90 8,230 8,325 PROD1 RPEQP1 DLOG P log GR tie in tagged @ 8325, PUW=30K,-1'correction Page 1 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:54 13:24 2.50 8,325 8,362 PROD1 RPEQP1MILL P Motored down to 8361. did get samples of green cement. Stalled @ 8361,Assumed milled out D nipple. Stall 4 times to get started 13:24 14:00 0.60 8,362 8,380 PROD1 RPEQP1MILL P 8362 past D nipple Mill down to 8380 and stalled at 7"contact. Found hard cement @ 8365, 2K WOB @ 25FPH 14:00 14:30 0.50 8,380 8,380 PROD1 RPEQP1WPRT P Wipe up hole to 8200', PUW=32K 14:30 16:36 2.10 8,380 8,430 PROD1 RPEQP1MILL P 8380', Mill pilot hole, 1.42 BPM @ 3295 PSI FS, ROP=25 FPM @ 2.1K DHWOB 16:36 17:06 0.50 8,430 8,430 PROD1 RPEQP1WPRT P Wiper trip to 8200, PUW=28K 17:06 19:36 2.50 8,430 8,485 PROD1 RPEQP1MILL P 8430', Mill, 1.43 BPM @ 3360 PSI FS, BHP=3700 19:36 19:51 0.25 8,485 8,280 PROD1 RPEQP1DLOG P 8280ft, tie into the K1 zero ft correction. 19:51 20:06 0.25 8,280 8,485 PROD1 RPEQP1MILL P Dry run through cement pilot hole down to 8396', 1k weight bobble at 8380' looks to be where we contacted the 7 inch. PUH, back ream from 8685'at 1 fph up to 8370' 20:06 22:06 2.00 8,485 8,370 PROD1 RPEQP1MILL P 8396', PUH, back ream from 8685'to 8370'@ 1 fph, to clean up transition area. Dry run to bottom seeing 300 lbs or motor work. Looks good 22:06 23:36 1.50 8,370 62 PROD1 RPEQPITRIP P POOH 23:36 00:00 0.40 62 62 PROD1 RPEQP1 SFTY P PJSM, simops, Check well for flow 05/24/2015 LD milling BHA#1, MU milling BHA#2 with bi-center bit, RIH milled TOC 8336' to 8512', POOH, LD milling BHA#2, RIH milled from 8485'-8512', POOH, early due to stalling motor. RU HAL caliper, RIH, stacked out on master valve, discussed plan forward., 00:00 00:30 0.50 62 0 PROD1 RPEQPI PULD P LD milling BHA 00:30 01:00 0.50 0 63 PROD1 RPEQPI PULD P MU second milling BHA with 0.6° ako motor and used Reed-Hycalog bi-center bit,2.7x3.0 01:00 02:30 1.50 63 8,285 PROD1 RPEQP1TRIP P RIH,with BHA#2 02:30 02:45 0.25 8,285 8,285 PROD1 RPEQPI DLOG P 8285',tie into the K1 marker correctiono of minus 1.0' 02:45 03:00 0.25 8,285 8,485 PROD1 RPEQP1TRIP P Continue in hole through cement pilot hole pumping min rate. 03:00 05:30 2.50 8,485 8,513 PROD1 RPEQP1 MILL P 8485', OBD cement pilot hole 20° ROHS down to 8505',turned tool face down to 180°from 8505'to 8520', 1.4 bpm at 3126 psi, IA 7, OA 0 ****Note: 3 stalled getting started, total of 12 stalls,with level 2-3 severity lateral vibration. Max ROP 34 fph with a stall 05:30 07:42 2.20 8,513 76 PROD1 RPEQP1TRIP P POOH, check well for flow, looks good and dead, Painting EOP flag 8200'for tie in on next trip. Page 2 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:42 08:18 0.60 76 76 PROD1 RPEQPI OWFF P At surface, PJSM to lay down BHA #2, perform no flow test 08:18 09:24 1.10 76 0 PROD1 RPEQP1PULD P Lay down BHA#2, Pilot hole bi center test 09:24 10:24 1.00 0 0 PROD1 RPEQP1CIRC P Make up nozzle and jet stack, during stack jetting swabs are closed with tangos open WHP climbed to 630 PSI. Opened up to tiger tank and bled off WHP. Shut back in and pressure began to rise 10:24 10:36 0.20 0 5 PROD1 RPEQP1PULD P Pop off well to double check torque on nozzle, stab on injector 10:36 13:00 2.40 5 8,274 PROD1 RPEQP1TRIP P RIH with Nozzle to kill well 13:00 14:30 1.50 8,274 14 PROD1 RPEQP1TRIP P Trip out pumping 12PPG completion fluid 14:30 15:06 0.60 14 0 PROD1 RPEQPI OWFF P At surface, PJSM, 30 Min no flow, LD BHA#3 15:06 15:18 0.20 0 0 PROD1 RPEQPI PULD P LD BHA#3 Nozzle 15:18 15:36 0.30 0 0 PROD1 RPEQP1PULD P PJSM, P/U HES Caliper, Suspend job and shut master for welding project in pitts 15:36 16:06 0.50 0 25 PROD1 RPEQP1PULD P PJSM, M/U coil to caliper stab on well with master shut. Stabbed on for master opening 16:06 16:12 0.10 25 33 PROD1 RPEQP1TRIP P Trip in hole, tag up on master valve, command given to open, confirmation not received. Lost communication with tool 16:12 17:00 0.80 33 0 PROD1 RPEQP1PULD T PUH and unstab, Caliper parted at knuckle joint. Vac stack out and see caliper at swab valve level 17:00 18:30 1.50 0 0 PROD1 RPEQPI FISH T Group huddle to indentify time line and operational errors, Formulate plan forward. Make notifications 18:30 21:00 2.50 0 0 PROD1 RPEQP1FISH T PJSM, nipple down BOP stack from upper swab to check for tool,tool seemed to be bound up in lower combi cavity, Change of scope, PJSM, remove BOP lower 2"ram doors, Cut centrilizer with sawsaw, hook up steel cable to fish from rig floor, pull to surface. inspection showed that all was returned except one 1/4"keeper from end of bow spring. 21:00 23:00 2.00 0 0 PROD1 RPEQPI FISH T PJSM, nipple up stack, inspect and install lower combi's, install doors, fluid pac stack and surface lines for testing Combi rams 23:00 00:00 1.00 0 0 PROD1 RPEQPI BOPE T Test lower 2"combi's 250 psi low/ 4300 psi high 05/25/2015 RIH, caliper cement pilot hole, crossover broke leaving caliper in hole, RU SL- fish caliper, RU SL attemp dummy WS down to 8355', RD SL, RU and RIH w/coil and dummy WS,tie into the K1 00:00 00:45 0.75 0 0 PROD1 RPEQP1PULD T Finish testing lower 2-3/8"combi's, RD testing equipment. Page 3 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 01:45 1.00 0 0 PROD1 RPEQPI PULD T PJSM,with Haliburton e-line.for making up caliper to calibrate. Then make up tools to BHI upper quick. 01:45 02:00 0.25 0 26 PROD1 RPEQP1PULD T MU caliper tools in hole, stab INJH "'*'Note: 10 hrs downtime for Nabors damaged caliper 02:00 05:06 3.10 26 8,228 PROD1 RPEQPI TRIP P RIH with caliper at 60 fpm 05:06 05:30 0.40 8,228 8,226 PROD1 RPEQPI DLOG P Tie into flag for-1.4', Log GR tie in with HAL GR log for-1'correction 05:30 05:42 0.20 8,226 8,502 PROD1 RPEQPI TRIP P RIH to log cement pilot hole 05:42 05:54 0.20 8,502 8,250 PROD1 RPEQPI DLOG P Caliper cement pilot hole, 8502 to 8250 05:54 06:00 0.10 8,250 8,502 PROD1 RPEQP1TRIP P Close fingers, RIH to make second pass 06:00 06:12 0.20 8,502 8,246 PROD1 RPEQP1 DLOG P Make second caliper pass 8502 to 8246, Close fingers 06:12 07:36 1.40 8,246 31 PROD1 RPEQP1TRIP P POOH 07:36 08:06 0.50 31 31 PROD1 RPEQPI OWFF P At surface, 30 Min flow check, PJSM to lay down caliper 08:06 08:30 0.40 31 0 PROD1 RPEQP1PULD P Break off injector, caliper tool not on. Camera adapter failed 08:30 11:30 3.00 0 0 PROD1 RPEQPI WAIT T Make notifications, Plan forward to rig up slick line to fish caliper 11:30 12:00 0.50 0 0 PROD1 RPEQPI SFTY T PJSM with HAL S/L Rig up to fish caliper 12:00 15:00 3.00 0 0 PROD1 RPEQPI PULD T Rig up slick line 15:00 17:06 2.10 0 0 PROD1 RPEQP1TRIP T RIH with slick line 17:06 17:36 0.50 0 0 PROD1 RPEQPI PULD T At surface with fish, LD tools 17:36 18:21 0.75 0 0 PROD1 RPEQPI PULD P MU Dummy WS on Haliburton slick line, 18:21 20:21 2.00 0 0 PROD1 RPEQPI TRIP P RIH, set down at 8355'SLMD, jarred down 2 times, PU 1k heavy, POOH 20:21 21:21 1.00 0 0 PROD1 RPEQP1PULD P RD slickline 21:21 21:36 0.25 0 0 PROD1 RPEQPI SFTY P PJSM for MU dummy WS to coil. 21:36 22:21 0.75 0 71 PROD1 RPEQPI PULD P I MU, BHI tools and dummy WS. 22:21 23:51 1.50 71 8,295 PROD1 RPEQPI TRIP P RIH,with coil 23:51 00:00 0.15 I 8,295 8,295 PROD1 RPEQPI DLOG P 8295',tie into the K1 marker no correction of 0.0 ft 05/26/2015 LD BHA#6, P/U BHA#7,set whipstock @ 8,455'. POOH for milling assembly. LD BHA#7, P/U BHA#8. Mill exit window @ 8,457'to 8,463', mill rathole to 8,478', back ream window,window clean. Start OOH, in progress. 00:00 00:45 0.75 8,295 8,485 IPROD1 RPEQP1TRIP P Continue RIH with dummy down to 8485', 00:45 02:03 1.30 8,485 71 PROD1 RPEQP1TRIP P POOH 02:03 02:33 0.50 71 0 PROD1 RPEQP1PULD P PJSM, check well for flow, LD dummy WS 02:33 03:18 0.75 0 74 PROD1 RPEQPI PULD P MU BOT WS setting tools Page 4 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:18 05:30 2.20 74 8,295 PROD1 RPEQP1TRIP P RIH with Open hole anchored WS EDC Open 05:30 05:36 0.10 8,295 8,305 PROD1 RPEQP1 DLOG P Log tie in for-1, PUW=31K, Shut EDC 05:36 06:00 0.40 8,305 8,465 PROD1 RPEQP1TRIP P Continue in with whipstock, Slight stacking 1200-1500LBS DHWOB, Get to setting depth, Orient to 5° LOHS, See tool shift @ 3800, Set down 2K after set,TOWS=8455 06:00 07:36 1.60 8,465 74 PROD1 RPEQP1TRIP P Trip out after setting whipstock 07:36 08:06 0.50 74 74 PROD1 RPEQP1 OWFF P On surface, 30 min flow check, PJSM lay down BHA#7 08:06 09:00 0.90 74 0 PROD1 RPEQP1 PULD P Break off injector and reconfig BHA 09:00 09:18 0.30 0 73 PROD1 WHPST PULD P Make up injector to BHA#8 with .6° motor, 2.80"DSM and 2.79"string reamer 09:18 10:54 1.60 73 8,295 PROD1 WHPST TRIP P RIH EDC open 10:54 11:00 0.10 8,295 8,322 PROD1 WHPST DLOG P Log K1 for no correction 11:00 12:12 1.20 8,322 8,318 PROD1 WHPST CIRC P Roll well to 9.3PPG used milling fluid, close EDC 12:12 12:48 0.60 8,318 8,457 PROD1 WHPST TRIP P RIH and dry tag TOWS @ 8457, 12:48 13:48 1.00 8,457 8,457 PROD1 WHPST WPST P Start milling window following revised procedure, 1.41 BPM @ 3270 PSI FS, BHP=3685. Did not stall contacting whipstock @ 10 FPH call pinch point @ 8456.9' 13:48 14:48 1.00 8,457 8,458 PROD1 WHPST WPST P Made one foot, Increase Diff pressure and WOB per procedure, Good metal on ditch magnets 14:48 18:39 3.85 8,458 8,462 PROD1 WHPST WPST P Continue as per well plan @ 1 fph, good metal in return, mill off casing, not much WOB. 18:39 22:27 3.80 8,462 8,478 PROD1 WHPST WPST P Mill @ 2-3 fph, dress BOW with string mill,good pressure and WOB, continue milling ©6 fph to rathole TD. 22:27 23:27 1.00 8,478 8,478 PROD1 WHPST REAM P Make several back reaming passes @ 5L,35L, and 25R. Dry drift window,window clean. 23:27 00:00 0.55 8,478 8,300 PROD1 WHPST TRIP P Start OOH,saw small overpull @ 8,415'. RBIH with no issue, continue OOH. 05/27/2015 Trouble getting high bend motor through tree, able to free BHA. RIH w/nozzle to 8,440', POOH laying KWF. LD BHA#9, MU BHA#10, displace fluid to used mud system,drill build section from 8,477'to EOB @ 8,556',displace back to KWF. POOH, LD BHA#10, PU BHA#11. RIH w/drilling assembly,displace fluid to new mud system. Start drilling A lateral from 8,556'to 8,640',drilling in progress. 00:00 01:00 1.00 8,300 77 PROD1 WHPST TRIP P Continue OOH with BHA#8 01:00 02:30 1.50 77 0 PROD1 WHPST PULD P PJSM. PUD BHA#8 Page 5 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:30 2.00 0 76 PROD1 DRILL PULD T PJSM. PD BHA#9, made several attempts get 2.3 AKO motor through tree, all the normal tricks, unable to move BHA, can not close master. Call town, prep to bullhead KWF annulus. 04:30 05:30 1.00 76 0 PROD1 DRILL PULD T Got tool free. Pull into PDL, Bleed off and inspect 05:30 07:30 2.00 15 8,440 PROD1 DRILL TRIP T Tool look good, M/U BHA#9 Nozzle trip in to displace to 12.0PPG completion fluid 07:30 09:12 1.70 8,440 14 PROD1 DRILL TRIP T POOH on 12 PPG Fluid 09:12 09:48 0.60 14 14 PROD1 DRILL OWFF T At surface, 30 Min flow check, PJSM to P/U Build section BHA in PDL 09:48 10:42 0.90 14 63 PROD1 DRILL PULD P Unstab injector and break off nozzle. Run BHA#10 in well. Inspect motor/ AKO setting,All good, M/U to coil and surface test. 10:42 12:54 2.20 63 8,285 PROD1 DRILL TRIP P Trip in hole with BHA#10, 2.3°AKO and RR Hughes bi center 12:54 13:00 0.10 8,285 8,314 PROD1 DRILL DLOG P Log K1 for-1.5'correction 13:00 13:36 0.60 8,314 8,422 PROD1 DRILL CIRC P Trip to 8420 and circulate well to 9.3PPG used flo pro 13:36 13:54 0.30 8,422 8,477 PROD1 DRILL TRIP P Close EDC and trip in to drill, Clean pass through window 13:54 14:54 1.00 8,477 8,557 PROD1 DRILL DRLG P 8477', Drill ahead, 1.41 BPM @ 3300 PSI FS, BHP=3705 14:54 17:12 2.30 8,557 73 PROD1 DRILL TRIP P Call EOB, PUW=31K, PUH to 8315 open EDC and swap well to 12PPG fluid 17:12 17:42 0.50 73 73 PROD1 DRILL OWFF P At surface, start 30 Min no flo check 17:42 19:27 1.75 73 73 PROD1 DRILL PULD P PJSM. LD BHA#10, motor AKO 2.3. PJSM. PU/MU BHA#11. 19:27 22:27 3.00 73 8,557 PROD1 DRILL TRIP P RIH w/lateral drilling assembly,while displace well over to new mud system 9.3 ppg Pow Vis. No correction at K1 marker, log RA tag @ 8,464', continue in hole. 22:27 23:36 1.15 8,557 8,640 PROD1 DRILL DRLG P BOBD: 1.42 bpm @ 3,150 psi, BHP=3,610 psi, CTW=8.5K, WOB=2.3K, ROP=80. 23:36 00:00 0.40 8,640 8,470 PROD1 DRILL DLOG P Trip for Mad pass, Mad pass @ 6 fpm. Start back in hole. 05/28/2015 Complete mad pass, continue drilling A lateral from 8,640'to TD @ 9,940'.Wiper trip to swab at max rate. RBIH for corrected TD @ 9,940'. Start OOH laying in beaded liner pill. 00:00 00:09 0.15 8,470 8,640 PROD1 DRILL DLOG P Complete mad pass, RBIH. 00:09 02:24 2.25 8,640 8,890 PROD1 DRILL DRLG P BOBD: 1.52 bpm @ 3,480 psi, BHP=3,740 psi, CTW=8.2K, WOB=1.6K, ROP=120. 02:24 02:39 0.25 8,890 8,890 PROD1 DRILL WPRT P Wiper to window, PUW=27K, RBIH. 02:39 05:36 2.95 8,890 9,140 PROD1 DRILL DRLG P BOBD: 1.45 bpm @ 3,420 psi, BHP=3,710 psi, CTW=7.2K, WOB=2.4K, ROP=115. Found fault @ 9,125',slowed progress. Page 6of9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:36 06:12 0.60 9,140 9,140 PROD1 DRILL WPRT P Wiper trip to 8480, PUW=29K 06:12 12:54 6.70 9,140 9,440 PROD1 DRILL DRLG P 9140', Drill, 1.4 BPM @ 3025 PSI FS, BHP=3710 12:54 13:54 1.00 9,440 9,440 PROD1 DRILL WPRT P 9440 Wiper to window with tie in, PUW=29K,Tie in to RA marker for +2'correction. 13:54 17:00 3.10 9,440 9,740 PROD1 DRILL DRLG P 9440', Drill ahead, 1.45BPM @ 3060 PSI FS, BHP=3830 17:00 17:54 0.90 9,740 9,740 PROD1 DRILL WPRT P 9740 Wiper trip to 8940. PUW=30K 17:54 19:48 1.90 9,740 9,940 PROD1 DRILL DRLG P BOBD: 1.43 BPM @ 3,320 PSI, BHP=3,785 PSI, CTW=7.5K, WOB=2.8K, ROP=105. Called TD @ 9,940'. Pump 10 bbl to/hi vis sweeps. 19:48 21:48 2.00 9,940 76 PROD1 DRILL WPRT P Chase sweeps to swab at max rate, tag up, reset depth. 21:48 23:51 2.05 76 9,440 PROD1 DRILL DLOG P RBIH for corrected TD,tie-in to K1 for -1'correction, continue in hole,tag TD @ 9,440'. 23:51 00:00 0.15 9,440 9,420 PROD1 DRILL CIRC P POOH laying in beaded liner pill. 05/29/2015 POOH laying in completion fluid. LD BHA#11. MU A liner assemby. RIH w/BHA#12, release from liner @ 9,940', TOL @ 8,439'. POOH. LD BHA#12. Function test BOP. MU BHA#13. RIH w/drilling assembly, dry tag billet @ 8,439'. Kick-off billet,drill ahead AL1 lateral, drilling in progress. 00:00 02:15 2.25 19,420 ' 83 PROD1 DRILL CIRC P Continue OOH, laying in beaded liner pill/completion fluid. Paint EOP flags @ 8,600'and 7,200'. 02:15 02:45 0.50 83 83 PROD1 DRILL OWFF P Monitor well for flow. 02:45 03:45 1.00 0 0 PROD1 DRILL PULD P PJSM. LD BHA#11. Prep rig floor to run liner. 03:45 06:15 2.50 0 1,185 COMPZ CASING PUTB P PJSM. PU/MU A lateral liner assembly: Bull nose, 36 jts slotted, two solid pups, anchored billet. MU BHA#13. 06:15 07:51 1.60 1,185 8,366 COMPZ CASING RUNL P RIH w/BHA#12 Liner assembly 07:51 07:57 0.10 8,366 8,363 COMPZ CASING DLOG P Tie into upper pipe flag @ 7200 EOP for-3" 07:57 08:51 0.90 8,363 9,940 COMPZ CASING RUNL P Weight check 30K, Close EDC, Trip in hole. Clean pass through window and trip to bottom @ 9940 08:51 08:57 0.10 9,940 9,475 COMPZ CASING RUNL P Tag up @ 9940, PUW=32.5K, set back down oriented to 150R, Pumps on see tool shift @ 4100PSI 08:57 10:33 1.60 9,475 71 COMPZ CASING TRIP P PUH to 9475 take liner length out of counters, 8374', Trip out 10:33 11:09 0.60 71 71 COMPZ CASING OWFF P At surface, 30 min flow check 11:09 11:39 0.50 71 0 COMPZ CASING PULD P Break off injector, Lay down liner running tools 11:39 12:09 0.50 0 0 PROD2 DRILL BOPE P Vac out stack and perform BOPE function test Page 7 of 9 Time Logs _I Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:09 13:15 1.10 0 72 PROD2 DRILL PULD P M/U BHA#13, Drill by AL1 lateral with .8°AKO motor and RR Bi Center. Change out pack offs. Change out floats in UQC, service floats in lower FVS. Stab on injector and surface test 13:15 14:45 1.50 72 8,305 PROD2 DRILL TRIP P RIH, EDC open 14:45 15:45 1.00 8,305 8,320 PROD2 DRILL DLOG P Log K1 for-1'correction 15:45 16:09 0.40 8,320 8,350 PROD2 STK CIRC P RIH to 8350 and displace 12.0 to 9.3 PPG fluid 16:09 16:15 0.10 8,350 8,839 PROD2 STK TRIP P Trip in and dry tag liner top billet @8839 16:15 17:09 0.90 8,839 8,840 PROD2 STK KOST P Mill off liner top billet, 1.53 BPM @ 3200 PSI FS, BHP=3745, TF=180° 17:09 17:48 0.65 8,840 8,842 PROD2 STK KOST P Milled 1'speed up to 2 FPH, WOB=1.35,Aluminum in samples 17:48 22:03 4.25 8,842 9,090 PROD2 DRILL DRLG P Drill ahead: 1.54 BPM @ 3,545 PSI, BHP=3,790 PSI, CTW=9K, WOB=1.8K, ROP=35. PUH for dry drift, clean both directions. Continue drilling, start pumping new mud system, new mud around @ 9,027'. 22:03 22:48 0.75 9,090 9,090 PROD2 DRILL WPRT P Wiper to window, PUW=29K, RBIH. 22:48 00:00 1.20 9,090 9,139 PROD2 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,480 PSI, BHP=3,830 PSI, CTW=7.8K, WOB=1.65K, ROP=35. 05/30/2015 Drill ahead AL1 lateral from 9,139'to called TD @ 9,940'. Pumped sweeps, chase to swab. RBIH for corrected TD @ 9,940'. POOH laying in liner pill/completion fluid. LD BHA#13. Prep rig floor for liner run. 00:00 03:45 3.75 9,139 9,340 PROD2 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,560 PSI, BHP=3,840 PSI, CTW=7.5K, WOB=1.95K, ROP=50. 03:45 04:30 0.75 9,340 9,340 PROD2 DRILL WPRT P Wiper to window, PUW=29K, RBIH. 04:30 07:54 3.40 9,340 9,640 PROD2 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,650 PSI, BHP=3,825 PSI, CTW=8.5K, WOB=1.45K, ROP=75. 07:54 08:54 1.00 9,640 9,640 PROD2 DRILL WPRT P 9640,Wiper trip to window with tie in for+1.5'correction, PUW=30K, Clean trip up and down 08:54 13:12 4.30 9,640 9,877 PROD2 DRILL DRLG P 9640', Drill, 1.5 BPM @ 3385PSI FS, BHP=3875 13:12 13:18 0.10 9,877 9,877 PROD2 DRILL WPRT P BHA Wiper, PUW=29K 13:18 14:12 0.90 9,877 9,940 PROD2 DRILL DRLG P 9877', Drill 1.5 BPM @ 3358 PSI FS, BHP=3885 14:12 16:30 2.30 9,940 72 PROD2 DRILL WPRT P 9940', Call TD' Pump 10 X 10 sweeps, Chase to swab, PUW=29K 16:30 18:27 1.95 72 72 PROD2 DRILL WPRT P Tag up and reset counters. 18:27 19:51 1.40 72 9,940 PROD2 DRILL DLOG P RBIH, tie-in to K1, no correction.Tag corrected TD©9,940'. 19:51 22:39 2.80 9,940 72 PROD2 DRILL CIRC P Pump beads, POOH laying in liner pill/completion fluids. Paint EOP flags @ 8,200'&6,700', continue OOH. 22:39 23:09 0.50 72 72 PROD2 DRILL OWFF P Monitor well for flow, no flow. Page 8 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:09 00:00 0.85 72 0 PROD2 DRILL PULD P PJSM. LD BHA#13. Prep floor for liner run. 05/31/2015 Run AL1 liner assembly to 9,940', release from liner,TOL @ 8,362'. Circulate well to seawater, freeze protect with diesel from 2,500'. PUD BHA#14, Set BPV. Inhibit/Flush/blow down coil. Cut 2,500'of coil. ND BOP stack. 00:00 00:45 0.75 0 0 COMPZ CASING PUTB P Finish rig floor prep. PJSM. 00:45 04:48 4.05 0 1,622 COMPZ CASING PUTB P MU AL1 liner assembly: bull nose, 51 jts slotted, 3 solid pups,shorty deployment sleeve. MU BHA#14. 04:48 06:06 1.30 1,622 8,324 COMPZ CASING RUNL P RIH w/AL1 liner assembly,tie-in for 06:06 06:12 0.10 8,324 8,321 COMPZ CASING DLOG P Tie into flag for-.3, PUW=30K, DHWOB=-5K 06:12 06:54 0.70 8,321 9,940 COMPZ CASING RUNL P Continue in with AL-1 Liner, Tag bottom @ 9940, PUW=30K, DHWOB=-1.5K Pumps on 1.3 BPM @ 4100 PSI, PUH, PUW=27K, DHWOB=3.4K 06:54 07:30 0.60 9,940 8,350 COMPZ CASING DISP P PUH to 9928, Subtract liner length, 8350, Start seawater down coil 07:30 10:06 2.60 8,350 8,350 COMPZ CASING FRZP P Trip out, Lay in Diesel from 2500' 10:06 11:30 1.40 8,350 0 COMPZ CASING PULD P PJSM. Tag up and space out, PUD BHA#14 11:30 13:12 1.70 0 0 DEMOB WHDBO MPSP P PJSM, Set BPV 13:12 15:00 1.80 0 0 DEMOB WHDBO RURD P Pump flush, inhibitor,amd flush through CT 15:00 16:00 1.00 0 0 DEMOB WHDBO RURD P PJSM, R/U and blow down coil string. Bleed off 16:00 22:30 6.50 0 0 DEMOB WHDBO CTOP P PJSM, R/U to trim 2500'CT and discard, prep floor for move. 22:30 00:00 1.50 0 0 DEMOB WHDBO NUND P PJSM. Start ND BOP stack/cellar., RIG Release Midnight Page 9 of 9 2f- '4 PRE AND POST RIG WELL WORK Sl'""MARY DATE SUMMARY POST RIG WELL WORK 6/5/2015 (STANDBY FOR VALVE CREW TO PULL BPV) MAKE SEVERAL MAGNET RUNS TO LINER TOP @ 8362' RKB; MEASURED BHP @ 8362' RKB (3634 PSI) IN PROGRESS. 6/6/2015 SET CATCHER ON LINER TOP @ 8362' RKB; PULLED DV'S @ 4420' & 2104' RKB; SET OV @ 4420' RKB & GLV @ 2104' RKB (GOOD IA DDT); PULLED CATCHER @ 8362' RKB. JOB COMPLETE. 2S$.63 WELL LOG TRANSMITTAL DATA LOGGED (0/ 4/2015 M BENDER To: Alaska Oil and Gas Conservation Comm. May 27, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 R F;?+ti:a ' E 0 JUN 0 4 201 RE: Multi Finger Caliper(MFC) : 2G-14 /.OGCC Run Date: 5/25/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-14 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21161-00 SCANNED JU1 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: / / ' ,� ‘,$4- t3o 25Z 6t? WELL LOG TRANSMITTAL DATA LOGGED Cj/11./201 5 M K BENDER To: Alaska Oil and Gas Conservation Comm. April 22, 2015 Attn.: Makana Bender •r *" °x 0 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 0 1 7 i3 ,(1,C)OCC RE: Perforation Record: 2G-14 Run Date: 4/20/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21161-00 NEa 0r 2 7 n IS Sat 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: OF ?Ai THE STATE Alaska Oil and Gas ww��\\I%%s� 4 °fALASK Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS v. Fax. 907.276.7542 www.aogcc.alaska.gov Gary Eller SCOW i, ?— CTD " 'CTD Engineer 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-14 Sundry Number: 315-139 Dear Mr. Eller: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this / ! day of March, 2015 Encl. STATE OF ALASKA AL .:A OIL AND GAS CONSERVATION COMM. ,SON APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon Rug for Redrill r , Fbrf orate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations ! s Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Wet r Stimulate r Alter casing r Other: I- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 184-130- 3.Address: 6.API Number: Stratigraphic r Service r- P.O. Box 100360,Anchorage,Alaska 99510 50-029-21161-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception', Yes r No I✓ KRU 2G-14 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25667 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft)• Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8750 • 6297 • 8645' • 6220'• none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 3293 9.625 3327' 2760' RECEIVED PRODUCTION 8691 7 8724' 6278' MAK l 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): 8452-8470,8490-8532 • 6081-6094,6109-6139 3.5 J-55 8374 Packers and SSSV Type. Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER FHL PACKER • MD=8345 TVD=6003 SAFETY VLV-BAKER FVL • MD=2055 TVD=1920 12.Attachments: Description Sur mary of Proposal ' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2015 Oil r Gas r WDSPL r Suspended F • 16.Verbal Approval: Date: WINJ r GINJ r WAG I— Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoi is true and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 \%k Email: litlik Printed Name Gary Eller Title: CTD Engineer Signature Phone:263-4172 Date 3 I\\ 1\5 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 16-13'7 Plug Integrity r BOP Test rt Mechanical Integrity Test r Location Clearance r Other: Qcp rC5 f- fo 4306p5/ (EPSP /5 392 D/J5 4-111-1'14 c/r 13rc VC✓7fzr 1-«t to Z 5--- 17p U Ljlt��n�rI- �t�� ftwCc C� ta�cproe5 /cf PC 2 ,a A-A--c z5. /� 2- /1"; Spacing Exception Required? Yes ❑ No IX Subsequent Form Required: / — 4, -7-- I- n APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: .19 -! , Approved application IS valid for 12 months t o the date of approval. -i`t-/S Form 10-403(Revised 10/2012) 3/ .3J Submit Form and Attachments in Duplicatet� 3/0/15- ORIGINAL i 4, ,/'',//‹ RBDMS.M A r, - 7 2015 ti KRU 2G-14 CTD Summary for Perfing & Plugging Sundry (10-403) Summary of Operations Well 2G-14 is a Kuparuk A-sand injection (service)well equipped with 3'/2"tubing and 7" production casing. Two laterals from well 2G-14 will be drilled,both to the south to support A sand production from 2K-07, 2K-15, and 2K-26. Operations will target the A4 and A5 sand intervals. Prior to CTD operations,the existing A-sand perfs in will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in this manner. Immediately prior to cementing the A-sand perfs,the D-nipple at 8362' MD will be milled out to a 2.80"ID and the tubing tail will be perforated. Both of these operations are needed to prepare the well for CTD operations. After plugging off the existing A-sand perfs with cement pre-rig,the Nabors CDR2-AC drilling rig will drill a pilot hole to 8475' and set a whipstock in the 2.80"pilot hole at the planned kickoff point at 8455' MD Both laterals will be completed with 23/8" slotted liner from TD with the final liner top located inside the 3'/2"tubing tail. Pre-CTD Work 1. E-line: Shoot 2' of holes in the 3'/2"tubing tail at 8357' MD. 2. Coil: Mill out Camco D-nipple at 8362' MD to 2.80" 3. Coil: Cement squeeze the A-sand perfs bringing cement up into the tubing tail. 4. Slickline: Drift tubing,tag top of cement and pressure test. 5. Prep site for Nabors CDR2-AC, including setting BPV p5p r3 3FZd125, earn PTD Rig Work 215-O:5-1 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2 zz-!4 4 L / 2. 2G-14A Sidetrack(A4 sand -south) / a. Drill 2.80"high-side pilot hole through cement to 8475' MD Th`5 b. Caliper pilot hole c. Set whipstock at 8455' MD 5 J d. Mill 2.80"window at 8455' MD e. Drill 3"bi-center lateral to TD of 9940' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 9150' MD 3. 2G-14AL1 Lateral(A5 sand-south) a. Kick off of the aluminum billet at 9150' MD b. Drill 3"bi-center lateral to TD of 9940' MD c. Run 2%" slotted liner from TD up to 8368' MD, inside the 3'/2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. Backflow well to clean up CTD laterals 4. Conduct MIT-IA 5. Return to injection ck 1Jf bt (off /letoy v No rescives �c eu• ecetfa/y, r� w, w,'i� Sloth � 65ck ,��fv e 1t;7 �1flore thus /ha�� taih�''�./ 1.0 c�o0�l P ''�►r' � 3�' //s Page 1 of 1 A1C%Sfi�n J e March 12,2015 vra KUP INJ 2G-14 ti COt10C0P11llIp5 Well Attributes Max Angle&MD TD Alaska.In0c. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) c..,,p,,,,,,,p" 500292116100 KUPARUK RIVER UNIT INJ53.97 4,200.00 8,750.0 ••• Comment H2S(ppm) Date 'Annotation End Date KB-Grd(0) Rig Release Date 25-14,1/720154:24:36 PM SSSV:LOCKED OUT Last WO: 40.98 10/10/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,595.0 1/3/2015 Rev Reason:TAG lehallf 1/7/2015 ■ 'OIL CasingStrings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;32.0 CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED 74.. .. Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).,, Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 34.0 3,327.0 2,760.0 36.00 L-80 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread PRODUCTION 7 6.276 32.9 8,724.0 6,278.3 26.00 J-55 BUTT Tubing Strings .A.A..,CONDUCTOR;38.0-110.0• Tubing Description String Ma...ID ye) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...WI(115/ft) Grade Top Connection TUBING 1 3 121 2.9921 32.01 8,373.91 6,024.41 9.301 J-55 I EUE8rd Completion Details • • Nominal ID SAFETY VLV;2,054.8 Top(ftKB) Top(TVD)(ftKB) Top Inal(") Item Des Com (in) 32.0 32.0 0.01 HANGER -McEVOY TUBING HANGER 3.500 2,054.8 1,920.4 40.30 SAFETY VLV BAKER FVL(LOCKED OUT 6/18/2001)"'SSSV acts as 2.810 CHECK VALVE;DO NOT run WL Tool String Past SSSV"' GAS LIFT;2,104.2111 8,330.9 5,993.3 44.14 PBR BAKER PBR 2.810 8,344.6 6,003.2 44.01 PACKER BAKER FHL PACKER 3.000 8,361.6 6,015.5 43.84 NIPPLE CAMCO'D'NIPPLE 2.750 8,3732 6,023.8 43.74 SOS BAKER SHEAR OUT SUB 3.000 • Perforations&Slots SURFACE;34.0-3927.0-4, 4, Shot Dens GAS LIFT;4,420.3 Top(TVD) Btm(TVD) (shots lf Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date t) Type Com 8,452.0 8,458.0 6,081.0 6,085.3 A-5,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH GAS LIFT;6,165.8 1 8,458.0 8,459.0 6,085.3 6,086.1 A-5,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg • pH • 8,458.0 8,459.0 6,085.3 6,086.1 A-5,2G-14 929/1985 5.0 RPERF 2 1/8"BarKone II;0 deg GAS LIFT;7,473.1 pH • 8,459.0 8,466.0 6,086.1 6,091.1 A-5,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg GAS LIFT;8,289.2III pH 8,459.0 8,460.0 6,086.1 6,086.8 A-5,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg pH 8,465.0 8,466.0 6,090.4 6,091.1 A-5,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg pH PBR;8,330.9 _ 8,466.0 8,467.0 6,091.1 6,091.9 A-5,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg PACKER;8,344.6 a•: pH 11• 8,467.0 8,470.0 6,091.9 6,094.0 A-5,2G-14 929/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH NIPPLE;8.3616 8,467.0 8,4681' 6,091.9 6,092.6 A-5,2G-14 929/1985 5.0 RPERF 2 1/8"BarKone II;0 deg i ill pH 8,490.0 8,495.0 6,108.6 6,112.2 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg SOS;8,373.212 pH 8,495.0 8,498.0 6,1122 6,114.4 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH - .- 8,495.0 8,496.0 6,112.2 6,112.9 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8.452.0-8.458.0— pH RPERF;8,468.0$459.0 8,498.0 8,499.0 6,114.4 6,115.1 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 de RPERF;8.458.08.459.01�f deg pH RPERF;0.459.08,460.0— $49$.0 8,499.0 6,114.4 6,115.1 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8.459.0-8,4660—i — pH 8,499.0 8,503.0 6,115.1 6,118.0 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,465.08,466.0 pH _ s RPERF;8.466.08.4670— 8,499.0 8,499.0 6,115.1 6,115.1 A-4,2G-14 929/1985 5.0 RPERF 2 1/8"BarKone II;0 deg - — pH RPERF;8,467.0-8.468.0— RPERF;8,467.08,4700' i 8,502.0 8,503.0 6,117.3 6,118.0 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg pH 8,503.0 8,508.0 6,118.0 6,121.6 A-4,2G-14 929/1985 4.0 RPERF 2 1/8"BarKone II;0 deg pH 8,508.0 8,511.0 6,121.6 6,123.8 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,490.08.495.0— pH RPERF;8,4950-8,496.0— 8,511.0 8,516.0• 6,123.8• 6,127.4 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8.495.08.498.0 _ — pH 8,515.0 8,516.0 6,126.7 6,127.4 A-4,2G-14 9/29/1985 5.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,498.0$499.0 -- — H RPERF;8.498.08499.0, p RPERF;8.499.0-- — 8,516.0 8,526.0 6,127.4 6,134.7 A-4,2G-14 9/29/1985 4.0 RPERF 2 1/8"BarKone II;0 deg • RPERF;8.499.0-8,503.0-4 -- pH IL-RPERF 8,502.0-85030— " — 8,526.0 8,530.0 6,134.7 6,137.6 A-4,2G-14 929/1985 5.0 RPERF 2 1/8"BarKone II;0 deg I -4 .-- pH RPERF;8.503.08.508.0 8,530.0 8,532.0 6,137.6 6,139.1 A-4,2G-14 929/1985 4.0 RPERF 2 1/8"BarKone II;0 deg RPERF;8,508.08,511.0— pH RPERF;8,511.08,5160—— Mandrel Inserts • RPERF;8,515.08,516.0— — St • — —_ ati RPERF;8.51608.526.0— N Top(TVD) Valve Latch Port Sue TRO Run Top(ftKB) (ftKB) Make Model OD(in) Seri Type Type (in) (psi) Run Date Corn RPERF:8.526.0-8.5300—- — f 2,104.2 1,957.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/20/2001 5:30 - ._ 2 4,420.3 3,427.6 MMH FMHO 1 GAS LIFT DMY BK 0.000' 0.0 6202001 2:00 RPERF;8,530.08,5320— 3 6,165.8 4,552.8 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/20/2001 9:30 - .- 4 7,473.1 5,413.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/20/2001 4:30 5 8,289.2 5,963.5 MMH FMHO 1 GAS LIFT DMY 'BK 0.000 0.0 6/19/2001 8:00 Notes:General&Safety End Date Annotation 4/17/1994 NOTE:SSSV acts as CHECK VALVE;DO NOT run WL Tool String Past SSSV. (4/17/94) PRODUCTION;330-8,724.0--.. Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task onsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the P tncia r Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" V/ boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Ratrici or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Jma~Project Well History File Covel~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Org,anizing RE$CAN Well History Fii~ Identifier DIGITAL DATA OVERSIZED (Scannable). [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: Other, NoHype Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds BY: BEVERLY BREN Project Proofing VINCEN~MARIA BY: BEVERLY BREN VINC~ARIA Scanning Preparation ~, x 30 = LOWELL LOWELL [] Other III IIIllllllll II III BY; BEVERLY BREN VINCEN~ARIA LOWELL Production Scanning Stage '/ PAGE COUNT FROM SCANNED FILE: L/~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: //~ YES NO YES NO Stage 2 IF NO IN STAGE '!, PAGE(S) DISCREPANCIES WERE FOUND: DUE TO QUALITY, GRAY$CALE OR COLOR IMAGES) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; General Notes or Commehts about this file: Is~ Quality Checked MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r� DATE:Monday,May 07,2012 P.I.Supervisor I��% 5J 1 Z/(v SUBJECT:Mechanical Integrity Tests ( l CONOCOPHILLIPS ALASKA INC 2G-14 FROM: John Crisp KUPARUK RIV UNIT 2G-14 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry J.C.A2.— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2G-14 API Well Number 50-029-21161-00-00 Inspector Name: John Crisp Permit Number: 184-130-0 Inspection Date: 5/1/2012 Insp Num: mitJCr120503091403 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell' 2G-14 - Type Inj ! W'TVD 6004 - I IA 1 1150 2900 - 2810 j 2770 - TD 1841300 - Type Test SPT'Test psi 1501 , , OA 670 860 850 840 - Interval 1 14YRTST P/F P Tubing 2150 ,- 2160 2240 2300 Notes: 2.9 bbls pumped for test. - SCANNED MAR 1 3 2014 Monday,May 07,2012 Page 1 of 1 MEMORANDUM To: Jim Regg P.I. Supervisor ~~C'/~/~ S (/ 3105 L~ FROM: John Crisp Petroieum Inspector State of Alaska • .~laska Oil and Gas Conservation Commission DATE: Wednesday, May 07, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA I1VC 2G-la KUPARUK RIV L`NIT 2G-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~Z- Comm Well Name: KUPARUK R[V UNIT 2G-14 IIISp Num: mitJCr080s040946s9 Rel Insp Num: API Well Number: ~0-029-2 1 1 6 1-00-00 Inspector Name: John Crisp Permit Number: t84-I3o-o Inspection Date: ~%?%2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - -- -- r -- - i-- -~~ - Well i zG Ia ;Type Inj. ~' ~~ TVD i 6004 ! IA soo sloo Bozo z9so ~i _ _ ~_ T _ __ __ __ _ _ ___ i p T ~ 1salsoo ~TypeTest SPT' Test psi OA s -- -_ -_- , 1~~1 ~ 130 _440 a40 ~_ 440 _-- ~ -- Interval aYxrsr p~F P ~ Tubing ~', z6zs ', z6zs z6zs ! z6zs I NOteS: 3 bbl's pumped for test Wednesday, May 07, 2008 Page f oY t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Aht~tðtm'r & ß&stpns. CG.~bnissior: Anc6õtage Time Extension -0 .I Re-enter Suspended Well 0 ) 1. Operations Performed: Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 140' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth measured 8750' 6297' true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size 16" 9-5/8" 110' 3187' 8587' 7" Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8374' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' pkr= 8345' SSSV= SSSV SSSV= 2055' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: ) RECEIVED FEB 2 7 2006 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Stimulate 0 Waiver 0 Exploratory 0 Service 0 5. Permit to Drill Number: 184-130/ 6. API Number: 50-029-21161-00 9. Well Name and Number: 2G-14 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool feet feet feet Plugs (measured) Junk (measured) feet MD TVD Burst Collapse 110' 3327' 8727' 110' 2760' 6280' 8452 ~~ANlN\ED fEB 2, [; 200b 6081 RBDMS 8Ft F E8 .2 ~ì' 2006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ 0 WDSPLD 17. J hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact MJ Loveland I Marie McConnell MJ Loveland , /' ~Ti~l~nl'> ~ Problem Wells Supervisor Signature.¿- h;:?../ / ,,>/?~ ,/~ \ N ÃL53 7224 Date ~H6'qt\ Form 10-404 R¿12004 - 0 R \ G Submit Original Only Printed Name ) 2G-14 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary 1I28/20061SET PLUG IN TUBING TAIL @ 8362' RKB. 2/18/2006 Removed top half of conductor Tanka head. Repaired Braidenhead thread leak with three pass seal weld. 2/23/2006IMITOA to 1800 psi, - Passed IPull TTP and normal up well for water injection 01/20/06 SChlumberger NO. 3663 Schlumberger -DCS RECE\VED 2525 Gambell Street, Suite 400 Com pany: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman A TTN: Beth JAN 2 4 2006 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~OI&Gascons.~ Field: Kuparuk ~ Well Job # Log Description Date BL Color CD ,~/ 1 E-03 11144062 PROD PROFILE WIDEFT 01/14/06 1 1F-14 11144063 PRODUCTION PROFILE 01/15/06 1 28-14 11141241 PRODUCTION PROFILE 12/31/05 1 2G-14 1f:,4- I~'O 11166751 SBHP SURVEY 01/12/06 1 1 E-06 11154118 PROD PROFILE WIDEFT 01/11/06 1 2X-05 11141246 INJECTION PROFILE 01/05/06 1 3A-04 11166752 INJ PROFILE/WFL 01/13/06 1 38-05 11154115 INJECTION PROFILE 01/09/06 1 2X-18 11154114 SBHP SURVEY 01/08/06 1 2X-18 11154117 PROD PROFILE WIDEFT 01/10/06 1 2H-09 11154103 PROD PROFILE WIDEFT 12/29/05 1 1G-11 11154113 PROD PROFILE WIDEFT 01/07/06 1 2X-04 11141245 INJECTION PROFILE 01/04/06 1 2Z-13 11141242 PROD PROFILE WIDEFT 01/01/06 1 1 C-20 11133212 SCMT 12/25/05 1 2C-11 11144065 PROD PROFILE WIDEFT 01/17/06 1 .~ 2N-339 N/A BHP SURVEY 12/01/05 1 20-04 N/A BHP SURVEY 12/03/05 1 2U-13 11166753 PROD PROFILE WIDEFT 01/14/06 1 1 E-05 11166747 PROD PROFILE W/DEFT 12/25/05 1 2M-01 11154119 PROD PROFILE W/DEFT 01/19/06 1 SIGNED: 2)CANNED JAN 2: 5 2005 DATE: ~~o 7f ) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test I!- A. \2-\ lOt- Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.akous; and Jim_Reg~dmin.state.akous OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inco KRU 2G-14 04/16/04 Brake 1 Rogers NA Packer Depth Pretest Initial 15 Min. 30 Mino Well2G-14 I Type Inj Is I T.V.D. I 6004 I Tubing I 25001 25001 25001 2500lnterval 0 PoToD. 1841300 Type Test P Test psi 1501 Casing 1610 3100 3050 3050 P/F P Notes: Diagnostic - waiver compliance weill I Type Inj I I T.V.D. I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I TVDo I Tubing I PoT.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I ToVoD. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I TV.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: Test Details: I Interval I P/F Interval I P/F Intervall P/F Intervall P/F TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 2G-14 04-16-04.xls 4/21/2004 ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 September 13, 1994 Mr. David W.. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr, Johnston:. Attached in duplicate is a Report of Sundry Well Operations (Form 10-404) notice in the Kuparuk field. The SSSV passed a closure test on 4/17/94 and injection valve was not ran, so the variance is not needed. WELL ACTION 2G-14 Variance (SSSV) ('Passed Closure test on 4/19/94 ) If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (atch only) RECEIVED SEP I 5 1994 At~sk~ Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate Plugging Repair well Perforate Other X 2. Name of Operator ARCO Alaska,. Inc. ;3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 243' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 1174' FSL, 1416' FWL, Sec. 6, T10N, R9E, UM At effective depth 1056' FSL, 1306' FWL, Sec. 6, T10N, R9E, UM At total depth 1015' FSL, 1268' FWL, Sec. 6, T10N, R9E, UM Present well condition summary Total Depth: measured true vertical 875O 6296 feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 140 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-14 9. Permit number/Approval number 84-130/94-081 10. APl number 50-029-21161 11. Field/Pool K. uparuk River Field/Oil Pool Cmt. plug @ 8645--8750' feet . Effective depth: measured 8 6 4 5 true vertical 6 2 2 0 feet Junk (measured) None feet Casing Length Size Structural Conductor I 1 0' 1 6" Surface 3 2 91 ' 9 - 5 / 8" Intermediate Production 8 6 9 2' 7" Liner Perforation depth: measured 8452'-8470', true vertical 6081 '-6094', Cemented Measured depth True vertical depth 202 SX CS II 115' 115' 1060 SX Perm. E & 3327' 2759' 370 Sx Perm. C 335 Sx Class G & 8724' 6277' 175 Sx Perm. C 8490'-8532' 6109'-6139' Tubing (size, grade, and measured depth) 3 1/2", 9.3#/ft., J-55 with tail @ 8374' Packers and SSSV (type and measured depth) PKR: Baker 'FHL' @ 8345'; SSSV: Baker 'FVL' @ 2055' '13. Stimulation or cement squeeze summary RECEIVED $ EP I 5 Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. Commissi Anchorage; 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 650 2050 psi 4000 psi . ..Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. 820 2000 psi 3950 psi status of well classification as: Water Injector__ Oil w Gas Suspended__ Service WAG Injector~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date 9/1 3/94 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, inc. WELL DATE DAY TIME DESCRIPTION OF WORK CONTRACTOR/KEY PERSON RECE""::D Irt. KUPARUK RIVER UNIT WELL SERVICE REPORT Gas Cons. Commission Anchor~,: AFC/CC OPERATION AT REPORT TIME ~ COMPLETE ~-] INCOMPLETE FIELD EST: ACCUMULATED COST $ 5781. LOG ENTRY PAGE 1 OF - . x-- ~- z~ ~ ., -~, ' - '-' ~ /] ..................... ' - -~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Relx)rt °F °F miles knot~//',////z///,~.,//~"~/~~2 AR3B-7031 "'~'/ -"'- ..... /-- -29m;~186 REMARKS CONTINUED: ACCUM. SERVICE COMPANY SCA # DAILY TOTAL TOTAL.FIELD ESTIMATE , ~., ~ ~ ~.DO ~ ~. ARCO Alaska, Inc. Post Office Bo:z'; Ancho~'age, A~aska 995'~0 03~0 Teiephone 907 276 !215 March 18, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well 2G-14 Action Variance (Inj-valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments FTR031895 (w/o atch) RECEIVED N1AR 2 7) 1994 Gas Cons. Commission Anchorage AR3B-6003-93 ;'42 2~;~) ! · -- STATE OF ALASKA ,~-..-,SKA OIL AND GAS CONSERVATION COM,...SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown B Re-enter suspended well __ Alter casing __ Repair well _ Plugging_ Time extension _ Stimulate__ Change approved program .. Pull tubing __ Vadance X Perforate __ Other 2. Name of Operator ARCO Alaska, In(;. 3. Address p. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 243' FNL, 88' FEL, Sec. 6, TI ON, R9E, UM At top of productive interval 1174' FSL, 1416' FWL, Sec. 6, TION, R9E, UM At effective depth 1056' FSL, 1306' FWL, Sec. 6, TION, R9E, UM At total depth 1015' FSL, 1268' FWL, Sec. 6, TION, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8750 6296 feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 140 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-14 9. Permit number 84-130 10. APl number 50-029-21 161 11. Field/Pool Kuparuk River Field/Oil Pool Cmt. plug @ 8645--8750' Effective depth: measured 8 6 4 5 true vertical 6220 feet Junk (measured) None feet Casing Length Structural Conductor 11 O' Surface 3 2 91 ' Intermediate Production 8 6 9 2' Liner Perforation depth: measured 8452'-8470', true vertical 6081'-6094', Tubing (size, grade, and measured depth) Size 16" 9-5/8" 7" Cemented Measured depth True vertical depth 202 Sx CS II 115' 115' 1060 Sx Perm. E & 3327' 2759' 370 Sx Perm. C 335 Sx Class G & 8724' 6277' 175 Sx Perm. C RECEIVED 8490'-8532' 6109'-6139' 3 1/2", 9.3#/ft., J-55 with tail @ 8374' Packers and SSSV (type and measured depth) PKR: Baker 'FHL' @ 8345'; SSSV: Baker 'FVL' @ 2055' MAP, 2 5 1994 Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~ Detailed operation program _ Install sub-surfacer spring controlled safety valve in a WAG injection well. 14. Estimated date for commencing operation I15. Status of well classification as: March 1994 ] oi~ t Gas . 16. If proposal was verbally approved Name of approver Date approved Service .,WAG Injector 17. I hereby ¢'~ify that. the^foregoing is, true and correct to the best of my knowledge. Sicjned ',"''~) ~~. ~ Title Senior Encjineeer FOR COMMISSION USE ONLY BOP sketch Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance w Mechanical Integrity Test _ Subsequent form require 10- Ho% IApproval No. Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY RUSSELL A. DOUGLA.~;.q Commissioner Date SUBMIT IN TRIPLICATE Approved Copy Returned Attachment 1 Request for Variance Kuparuk Well 2G-14 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to install a downhole, spring-controlled, injection valve in Injection Well 2G-14. This injection valve will act as a one-way check valve allowing downward injection of water and gas, while preventing upward flow of the injected fluid. The injection valve is capable of preventing uncontrolled upward flow by automatically closing if such an event should occur. This valve does not require a hydraulic control line from the surface to the subsurface valve. Its fail-safe design as normally-closed provides the same level of protection. The sub-surface safety valve (SSSV) in Kuparuk Well 2G-14 has a control line that can not hold pressure. The suspected downhole control line leak was discovered on 2/19/94 and numerous attempts to fix the problem have been unsuccessful. Installation of the injection valve would alleviate the problem. Attachment 2 shows a schematic of the proposed injection valve. RECEIVED MAR 2 3 199~ A~ask~ Oil & Gas Cons. Commission Anchorage Attachment 2 Injection Valve Schematic TOP SUB ORIFICE ~SPRING ~GUIDE SEAT SEAT INSERT FLAPPER VALVE AND SPRING ASSEMBLY Otis MC In/ection Valve ~AP, 2 ~ 199~ Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate __ Plugging Pull tubing Alter casing Repair well Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4, Location of well at surface 243' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 4106' FNL, 3864' FEL, Sec. 6, T10N, R9E, At effective depth 4224' FNL, 3974' FEL, Sec. 6, T10N, R9E, At total depth 4265' FNL~ 4012' FEL~ Sec. 6, T10N~ R9E, 12. Present well condition summary Total Depth: measured 8 7 5 0' true vertical 6296' 5. Type of Well: Development --~ Exploratory _ Stratigraphic Service .~ ~ UM UM UM 6. Datum elevation (DF or KB) RKB 140 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-14 9. Permit number/approval number 84-130 / '~- 2 10. APl number 5o-029-211 61 11. Field/Pool Kul3aruk River Oil Pool feet feet Plugs (measured) Cement: 8645'-8750' Effective depth: measured 8 6 4 5' feet true vertical 6220' feet Junk (measured) Casing Length Size Structural Conductor I 1 0' I 6" Surface 332 7' 9 5/8" Intermediate Production 8 72 4' 7" Liner Perforation depth: measured 8452'-8470', 8490'-8532 true vertical 6081 '-6094', 61 09'-61 39' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 8373' Packers 'and SSSV (type and measured depth) Baker FH @ 8345', Baker FVL @ 2055' Cemented Measured depth True vertical depth 202 Sx Cold Set II 1 1 5' 1 1 5' 1060 Permafrost E & 4348' 3127' 370 Sx Permafrost C 335 Sx Class G 1 0 0 5 2' 6 2 6 7' 175 Sx PFC 4 SPF 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 425 325 2O 1425 215 Subsequent to operation 0 0 4500 1375 1700 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc,' Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WEL, L IPBDT~ ~NTRACTOR REMARKS FIELD-DISTRICT-STATE OPERA~ION AT R~PORT TIME (._,ow ~1 d~_ IDAYS I DATE t I '3-)_-90 O13o - In~.fL~ ~/~.:~ t~ ~o %000 ~¥, oqoo - roo~ ~/ GL.V 0~%o I 000 101~ ?oo~ 'V ~- v Pooh r--] CHECK THIS BLOCK IF SUMMARYCONTINUED ON BACK A / .. ~ Weather ITemp. I Chill Factor Visibility Iw,ndvo,. Isigne{ / //r'~ ~/ __ ~ Report °F °F males knotsI ///.~. [/~// ARCO Alaska, Inc Post Office b~j.~. 1O~}SGO A~chorage, A~aska 995i 'Yeieph©.,~e 907 275 12~5 April 11, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 2G-14 Change of Service May, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer RECEIVED CC: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPI. I ATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program .~ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc, . 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 243' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 4106' FNL, 3864' FEL, Sec. 6, T10N, R9E, UM At effective depth 4224' FNL, 3974' FEL, Sec. 6, T10N, R9E, UM At total depth 4265. FNL, 4012' FEL, Sec. 6~ T10N~ R9E~ UM 12. Present well condition summary Total Depth: measured 8 7 5 0' true vertical 6 2 9 6' 5. Type of Well: Development Exploratory Stratigraphic Service feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 140 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-14 9. Permit number 84-130 10. APl number 5o-02~)-21 1 ~1 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cement- 8645'-8750' Effective depth: measured 8645' feet true vertical 6 2 2 0' feet Junk (measured) None Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 33 2 7' 9 5/8" Intermediate Production 8 7 2 4' 7" Liner Perforation depth: measured 8452'-8470' , true vertical 6081 '-6094' , Tubing (size, grade, and measured depth 3 1/2" J-55 set at 8373' Packers and SSSV (type and measured depth) Baker FH @ 8345', Baker FVL ~ 2055' Cemented Measured depth 202 Sx Cold Set II 1060 Permafrost E & 370 Sx Permafrost C 335 Sx Class G 175 Sx PFC 115' 4348' 8490'-8532 4 SPF 6109'-6139' True vertical depth 115' 3127' 10052' 6267' APR 1 ? 1990 qaska Oil & Gas Cons. Commiss~r~ Anchora~ 13. Attachments Description summary of proposal Detailed operation program ~ BOP sketch Convert well from oil producer to water alternatinFgas (WAG) injector. (Wellbore schematic attached). 14. Estimated date for commencing operation ~ '! 15. Status of well classification as: May. 199(}.. | Oil __ Gas __ Suspended _ 16. If proposal was verbally approved / Name of approver Date approved ! Service Water ~nd Gas Inj~(;;:tor 7. I he,~~ ,~h~ f~l~ueo and correct to the best of my knowledge. Signed Title Sr. Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test__ Location clearance__ Mechanical Integrity Test~_~" Subsequent form require 10- IApproval Noz~/i ,-~ ~ Approved by the order Commission Form i0-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH Annraved COPY ' 'Returned Commissioner ,.411tho SUBMIT IN TRIPLICATE WELL 2G-14 PRODUCER APl # 500292116100 SURFACE LOCATION: 243' FNL, 88' FEL, SEC 6, T10N, R9E, UM TOP KUPARUK: 4106' FNL, 3864' FEL, SEC 6, T10N, R9E, UM DEPTHS: REFERENCED TO 0' RKB ALL DEPTHS MD-RKB (RKB=36') TREE: MCEVOY GEN II 5000 PSI SPUD: 10/2/84 COMPLETION: 11/3/84 16": 62.5# H-40 @ 110' J 9 5/8": 36# L-80 @ 3327' BAKER PBR: 2.813" ID @ 8331' BAKER FH PKR: @ 8345' CAMCO D NIPPLE: 2.75" ID BAKER SHROUT: @ 8362' @ 8373' B A6- A5 A4 A3 7": 26# J-55 @ 8724' · VOLUME: 0.0383 BBL/FT '////////L PBTD: 8645' L SSSV: BAKER FVL ID 2.813" @ 2055' GLMI: 2104' / 1.0" MMH / 1/4" GLV GLM2: 4420' / 1.0" MMH / 1/4" GLV GLM3: 6166' / 1.0" MMH / 1/4" GLV GLM4: 7473' / 1.0" MMH / 1/4" GLV GLM5: 8289' / 1.0" MMH / 3/16" OV 3.5" 9.3# J-55, TT @ 8374' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACROSS KUPARUK = 43 DEGREES MAX. HOLE ANGLE = 54 DEGREES @ 4200' VOLUME TO TOP PERF = 75 BBLS 8452'-8470' 4 SP..Ct~ask,1.~ij & Gas Cons. Anchora~ 8490'-8532' 4 SPF FILL TAGGED AT 8592' ON 9/27/85 REVISION' 3/28/90 Messrs. Sloan and Kralick 4/1 0/90 Page 3 Well 2G-14 Waterflood/WAG Conversion Sequence of Events 1. Obtain 24 hour well test. 2. SI well and obtain AEPBU (or 48 hour WHP-FL if necessary). 3. Slickline work. a) Tag fill to ensure that all perfs are uncovered. If any are covered, consult with Operations Engineering to evaluate a CTU cleanout. b ) Replace all gas lift valves with dummy valves. 4. Perform MIT test. a) Notify the State at least two days prior to the required annulus test. 5. Contact Terry Palisch to confirm Sundry and Ballot approval before converting Well 2G-14 to water injection. No BOPs or workover fluids required. Last BHP -- 3359 psi ARCO Alaska, Inc. Date: March 24, 1989 Transmittal #: 7447 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 30-16 '.--30-10 · -"- 30-13 ....,,,,,30-03 .-,, 30-15 · ..,~ 2G- 14 ~ 2G-13 "',,,,,, 2G-09 "'~' 1E-03 '"""' 1 E-05 30-18 ""'" 3 H - 1 0 '~'3A-03 """" 3 H - 04 ~2B-1 4 '""~,, 3 O- 13 e,,,,,, 30 _ 10 "~- 30-16 ~"1B-07 "'""'~1B-03 "~' 1B-05 '"'""~1B-07 ~1B-07 "~"~ 1 L- 0 8 ~,,~1 L- 0 4 ~'~3 H- 1 0 "~,,- 3 M - 0 1 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re )ort 3ort 3ort 3ort 3orr 3ort 3ort 3ort 3ort Kuparuk Fluid Level Re3ort Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Kuparuk Fluid Level Re3ort Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re Kuparuk Fluid Level Re 3ort 3ort 3orr 3ort 3orr 3ort 3ort 3ort 1-3-189 2-04-89 2-08-89 1 -09-89 3-04-89 3-11-89 3-11-89 3-11-89 3-09-89 3~09-89 3-09-89 3-09-89 3-09-89 3-04-89 3-13-89 2-08-89 2-04-89 1 -31 -89 3-31 -88 1 -27-88 1 -27-88 4-27-88 1 -27-88 2-12-88 2-12-88 7-89 Sand'A' Sand'A' Sand'A' Sand'A' Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing Tubing Ca., ' ~g ~ O- 0 9 Kuparuk Fluid Level Report 3 - 1 8 - 8 9 Casing "'""~30 - 1 8 Kuparuk Fluid Level Report 3 - 1 8 - 8 9 Casing ~ O - 1 8 Kuparuk Fluid Level Report 3 - 1 7 - 8 9 Casing ~OB- 0 9 Kuparuk Fluid Level Report 3- 1 7- 8 9 Casing - 1 3 Kuparuk Fluid Level Report 3 - 1 7 - 8 9 Casing Receipt Acknowledged: ........................... Date: ............ DI~TRIBt. ITION: D&M State of Alaska SAPC Chevron Unocal Mobil Ancn0rage ARCO Alaska, Inc. Post Office L_, )360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed 2C-2 Per fora te 9 / 28 / 85 2G-1 3 Reper forate 9 / 28 / 85 2G-1 4 Reper~orate 9/28/85 2G-15 Reper forate 9/30/85 2G-1 6 Reper forate 9/30/85 on the If you have any questions, please call me at 263-4212. T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) .'CEIv£D oc'r 1985 ,~1~ Ctl ~, ,~as Cons. Comrnisslor~ AnChorage ARCO Alaska, Inc. Is a Subsidiary of AtlanlicRichfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Nam~of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, 4. Location of Well SURFACE LOCAT ! ON. 243 ' FNL, T10N, RgE, UM ALAS KA 99510 5. Elevation in feet (indicate KB, DF, etc.) 1 40' (RKB) 88' FEL, SEC. 6, I 6 . Lease Designation and Serial No. ADL 25667 7. Permit No. 84-130 8. APl Number 50- 029-21161 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2(3-14 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~} Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On September 28, reperforated for psi, the well was Interval (MD). 1985, the "A" sands of Kuparuk well 2G-14 were production. After testing the lubricator to 3000 shot with a wireline conveyed gun. 8452'-8470' 8490'-8532' (4 SPF) RECEIVED Alaska 0ii & Gas Cons., Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed J/'f//~ ~---~.~- Title KUPARUK OPERAT J ONS CO0ta,13 i NA1 fOR' The space below for Commission use Conditions of Approval, if any: Date 10/9/85 Approved by By Order of COMMISSIONER the Commission Date Form 10-403 ¢~o~, 7.1_Rn Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 23, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive -Anchorage, AK 99501 Dear Mr. Chatterton: Attached is our notice of intention to perforate Kuparuk field wells 2G-13, 2G-14, 2G-15 and 2G-16. If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD:ps:File Attachment (In Triplicate) RECEIVED Alaska OiJ & Gas Cons. Commission Anchorage · ,¢lr-t'% al~=U~ In,- ie ~, ~l,h,:id|~rv n! &tl~,nticRichlieldComOal3V STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~( OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 243' FNL, 88' FEL, Sec.6, TION,R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 1401, PAD 104' 12. 6. Lease Designation and Serial No. ADL 25667 ALK 2588 7. Permit No. 84-130 8. APl Number 50- 029-21161 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2G-14 11. Field and Pool Kuparuk River Field Kuparuk River 0il Po01 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 2G-14 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. Proposed Intervals (MD)' 8452-8470' (4 SPF) 8490-8532' ANTICIPATED STATE DATE 9/25/85 RECEIVED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Coo d n to The space below for Commission use 9/23/85 Conditions of Approval, if any: Approved by Approved Copy p, eturned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate R~v 7-1-R0 'ARCO Alaska, Inc ....... Post Office J00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 3, 1985 Mr.- C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 2D-2 2D-7 2G-14 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/LI03 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany R£CEIVED U N 0 ]985 ~.~s Co~m. Commission Anchorage STATE Of ALASKA ...... ALASKA ._ AND GAS CONSERVATION CL ,IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,. 2. Name of OPerator 7. Permit Number ARCO Alaska, Inc. 84-130 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21161 4. Location of well at surface 9. Unit or Lease Name 243' FNL, 88' FEL, Sec.6, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 1~). Well Number 4106' FNL, 3864' FEL, Sec.6, T10N, R9E, UM 2G-14 , At Total Depth 11. Field and Pool 4265' FNL, 4012' FEL, Sec.6, T10N, PgE, UN Kuparuk River Field ,, "5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oil Pool 140' RKBI ADL 25667, ALK 2588 , , 'i2. Date Spudded 13, Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/02/84 10/07/84 11/03/84 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8750'MD,6296'TVD 8645'MD,6220'TVD YES [] NO [] 2055 feet MD] 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL/GR, BHCS/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD .., SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 sx Cold Set II I, 9-5/8" 36.0# L-80 Surf 3327' 12-1/4" 1060 sx Permafrost E & 370 sx Permafrost C -' ·7,, 26.0# J-55 Surf 8724' 8-1/2" 335 sx Class G & 250 s; PF "C" · '"~4. 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) 8530' - 8526' 8495' 3-1/2" 8373' 8345' ' 8516' 8467' - 8466' w/1 spf, 8511' - 8508' 8459' - 8458'~ 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8503' ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8499' - 8498' See attached Adde~dum~ dated 4/12/85. , , , 27. N/A PRODUCTION TEST Date First Production t Method of Operation (Flowing, gas lift, etc.) . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (~orr) Press. 24-HOUR RATE I~ 28. COP E DATA None - ~ ~ ~.!aska 0ii & G~'~ C0rls~ c0mmissio[~ Form 10-407 GRU6/WC3~ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. . ' ~ GEOLOGIC. MARInER'S : '. ~ ' 'm." " FORMATION TEsTs NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk B 8383' 6030' Top Lower Sand 8434' 6067' Base Lower Sand 8610' 6194' N/A 31. LIST OF ATTACHMENTS Arlrl~ndum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,) (~f~k-~/ _)~/~/~ Title Associate 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". ADDENDUM WELL: 10/11/84 1/19/85 2/11/85 3/22/85 3/25/85 3/26/85 2G-14 Arctic Pak w/250 sx PF "C", followed by 59 bbls Arctic Pak. Tag fill w/SL @ 7580'. Rel'd well to Production. Suspended frac att due to diesel contamination. Frac well in 5 stages w/total of 275 bbls gelled diesel & 11,400# of 20/40 mesh, leaving 2700# in casing. RIH, tag sand @ 8190'. RU CTU + N2. CO to 8610' w/total of 550 bbls diesel. RIH w/wt bar & CCL. Tag fill @ 8591' (61' rathole). Turn well over to Production. Drilling ~uperintendent 06 ARCO Alaska, Inc?--._. Post Offic6 00360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 May 23, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the 2D-15 2V-SA 1E-24 2X-14 2G-14 DS 6-5 2G-15 following wells: If you have any questions, Sincerely, Gruber Associate Engineer JG/tw GRU9/L01 Enclosures please call me at 263-4944. RECEIVED ,qY2 a Alaska Oil & Gas Cons. Commission Ancllorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~:- .... STATE Of ALASKA ...... , ALASKA . .~_ AND GAS CONSERVATION CC AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .._ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-130 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21161 · 4. Location of well at surface 9. Unit or Lease Name 243' FNL, 88' FEL, Sec.6, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 4106' FNL, 3864' FEL, Sec.6, TION, RgE, UM 2G-14 At Total Depth 11. Field and Pool 4265' FNL, 4012' FEL, Sec.6, T10N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 140' RKB ADL 25667, ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. N°. of Completions 10/02/84 1 0/07/84 11/03/84 N/A feet MSL 1 , 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8750'MD,6296'TVD 8645'MD,6220'TVD YES [] NO [] 2055 feet MDI 1500' (approx) 22. :type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL/GR, BHC5/GR, Gyro [- ,, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 sx Cold Set II 9-5/8" 36.0# L-80 Surf 3327' 12-1/4" 1060 sx Permafrost E & 370 ~,~; Porrrl~frost C 7" 26.0# J-55 Surf 8724' 8-1/2" 335 sx Class G & 250 s; PF "(;" 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) 8530' - 8526' 8495' 3-1/2" 8373' 8345' .. 8516' 8467' - 8466' w/1 spf, 8511 ' - 8508' 8459' - 8458' 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8503' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8499' - 8498' See attached Addendum, dated 4/2/I~5, 27. N/A PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTIONI FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO '1 TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alaska Ol! & ~;'.'s ~ ...... O~ Form 10-407 GRU6/WC34 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk B Top Lower Sand Base Lower Sand GEOI"OGIC MARI~EF~s' MEAS. DEPTH TRUE VERT. DEPTH FORMATION TEST~ 8383' 8434' 8610' 6030' 6067' 6194' Include nterval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum 32. hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date ~5--/-~-~-- 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". F~rm 18-4~7 ADDENDUM WELL: 10/11/84 1/19/85 2/11/85 3/22/85 2G-14 Arctic Pak w/250 sx PF "C", followed by 59 bbls Arctic Pak. Tag fill w/SL @ 7580'. Rel'd well to Production. Suspended frac att due to diesel contamination. Frac well in 5 stages w/total of 275 bbls gelled diesel & 11,400# of 20/40 mesh, leaving 2700# in casing. Driliin~ Superintendent ARCO Alaska, Inc. Post Office Bo...~)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner state of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton' Enclosed are revised Well Completion Reports wells: 2A-2 2D-5 2E-14 2A-3 2D-14 2E-16 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the when each well was Arctic Packed. If you please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures for the following cement quantity used have any questions, RECEIVED APR 2 2 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfleldCompany STATE OF ALASKA ALASKA _ AND GAS CONSERVATION CC IlSSION WELL COMPLETION OR RECOMPLETION EPORT AND LOG 1. Status of Well Classification of Service Well REV I S I ON OIL [~XX GAS [] SUSPENDED I-] ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-130 ,, 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21161 4. Location of well at surface 9. Unit or Lease Name 243' FNL, 88' FEL, Sec.6, T10N, RDE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 4106' FNL, 3864' FEL, Sec.6, T10N, RDE, UM 2G-14 , AtTotal Depth 11 FieldandPool 4265' FNL, 4012' FEL, Se¢.6, T10N, RDE, UM Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667, ALK 2588 , , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/02/84 10/07/84 11/03/84 N/A feet MS L 1 i · 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8750'MD,6296'TVD 8645'MD,6220'TVD YES [~ NO []I 2055 feet MD. 1500' (approx) 2~. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL/GR, BH.CS/GR~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .... , 16" 62.5# H-40 Surf 110' 24" 202 sx Cold.Set 11 9-5/8" 36.0# L-80 Surf 3327' 12-1/4" 1060 sx Permafrost E & 370 sx Permafrost C ....7" 26.0# J-55 Surf 8724' 8-1/2" 335 sx Class G & 250 s:c PF "C" 2z{. 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) ,,, 8530' - 8526' 8495' 3-1/2" 8373' 8345' 8516' 8467' - 8466' W/1 spf, 8511' - 8508' 8459' - 8458' 90° phasing 2~'. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,, 8503' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8499' - 8498' N/A i , 27. N/A PRODUCTION TEST Date First Production t Method of Operation (Flowing, gas lift, etc.) · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure cALcuLATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) "- Press. 24-HOUR RATE ~! 2'~. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water, Submit core chips. Form 10-407 JMM2/WC19 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29'. . 30. · . i · , . .~ ~. . · GEoLOGIc'MA'RKERs ' ~ '' ~"' ' : ' " ' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk B 8383' 6030' Top Lower Sand 8434' 6067' Base Lower Sand 8610' 6194' N/A 31. LIST OF ATTACHMENTS , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, I, Post Offk. : 100360 Anchorage, Alaska 99510~0360 Telephone 907 276 1215 ~!arch 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells- 2G-9 2G-10 2G-13 2G-14 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L51 Enclosures Alaska Oil & t;a~ Co;is. [,'oinmissiol] Ancllorage ARCO Alaska. Inc. is a Subsidiary o! AllanlicRichfieldCompan¥ STATE OF ALASKA -- ALASKA _AND GAS CONSERVATION Ct,. AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-130 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21161 4. Location of well at surface 9. Unit or Lease Name 243' FNL, 88' FEL, Sec.6, T10N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 4106' FNL, 3864' FEL, Sec.6, T10N, RgE, UM 2G-14 At Total Depth 11. Field and Pool 4265' FNL, 4012' FEL, Sec.6, T10N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667, ALK 2588 , 12. Date Spudded10/02/84 13. Date T.D. Reachedl 0/07/84 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 1/03/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8750'MD,6296'TVD 8645'MD,6220'TVD YES [] NO []I 2055 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL/GR, BHCS/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 sx Cold Set II 9-5/8" 36.0# L-80 Surf 3~27' 12-1/4" 1060 sx Permafrost E & 370 sx Permafrost C 7" 26.0# J-55 Surf 8724' 8-1/2" 335 sx Class G & 250 s~ Permafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8530' - 8526' 8495' 3-1/2" 8373' 8345' 8516' 8467' - 8466' w/1 spf, 8511' - 8508' 8459' - 8458' 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 8503! DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8499' - 8498' N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 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-APl (c°rr) Press. 24-HOUR RATE ~ ,, 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · · . Form 10-407 GRUS/WC19 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGiC.MARKERS, .i" . ! :' FORMATION TESTS ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk B 8383' 6030' Top Lower Sand 843/+' 6067' Base Lower Sand 8610' 6194' N/A -- 31. LIST OF ATTACHMENTS AHH~,nH~,m 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date j- 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". ADDENDUM WELL: 10/11/84 1/19/85 2/11/85 2G-14 Arctic Pak w/250 sx PF "C", followed by 59 bbls Arctic Pak. Tag fill w/SL @ 7580'. Rel'd well to Production. Suspended frac att due to diesel contamination. Drilling ~uperintendent Date ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date:02/07/85 Transmittal No:5031 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 chorage, AK 99510 itted herewith are the following items. Please acknowledge receipt ~/and return one signed copy of this transmittal. FINAL PRINTS OPEN HOLE SEPIAS/LOGS (One sepia and one log each) Schlumberger 2G-14 5" BHC Sonic-GR 2" BHC Sonic-GR 5" Density/Neutron (Porosity) 2" Density/Neutron (Porosity) 5'~ DiL/SFL/GR 2" DIL/SFL/GR 5" Density/Neutron · (Raw Data) 2" Density/Neutron (Raw Data) 5" Cyberlook 10/08/84 Run H1 10/08/84 Run H1 10/08/84 Run H1 10/08/84 Run H1 ~n/Og,/gd Run #! ~/ J~ ~ · 10/08/84 Run #1 10.08.84 Run #1 10/08/84 Run #1 10/08/84 Run Hi 815078730 8150-8730 3328-8701 3328-8701 3328-8729 3328-8729 3328-8701 3328-8701 8150-8700 Receipt Acknowledged: B. Currier BPAE Chevron DISTRIBUTION Drilling W, Pasher State of AK Geology G. Phillips Sohio Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files ARCO Alsska, Ii' Posl Offi~.,~ O°x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 2, 1985 Mr. C. V. Chatterton Commi s s ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-14 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I haven't received a copy of the well history summarizing the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L30 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .~-- STATE OF ALASKA .... , - ~ ALASt1 ,. _AND GAS CONSERVATION ,...,., ,IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL {~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2'i Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-130 '3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21161 4. Location of well at surface L©£A7 IOJx~$i 9. Unit or Lease Name 243' FNL, 88' FEL, Sec.6, T10N, R9E, UI~ VE~I~:i~t) t Kuparuk River Unit At Top Producing Interval Surf. i~ t~ 10. Well Nu~nber 4106' FNL, 3864' FEL, Sec.6, T10N, RgE, UM B.H. 2G-14 At Total Depth 11. Field and Pool 4265' FNL, 4012' FEL, Sec.6, T10N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667, ALK 2588 12. Date Spudded 13.'DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 10/02/84 10/07/84 11/03/84J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-I-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 8750'MD,6296'TVD 8645'MD,6220'TVD YES [] NO []I 2055 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL/GR, BHCS/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 sx Cold Set II 9-5/8" 36.0# L-80 Surf 3327' 12-1/4" 1060 sx Permafrost E & 370 sx Permafrost C 7" 26.0# J-55 Surf 8724' 8-1/2" 335 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) 8530' - 8526' 8495' 3-1/2" 8373' 8345' 8516' 8467' - 8466' w/1 spf, 8511 ' - 8508' 8459' - 8458' 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8503! DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8499' - 8498' N/A - .- . 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None I Form 10~407 GRU3/WC29 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk B Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 8383' 8434' 8610' TRUE VERT. DEPTH 6030' 6067' 6194' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS W~ll Hi.~nry~ C, yrn_~e, nple. R,,rv~y (? e. npies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed :)(.~/ir)q,/~,_.-- ~-L~- .b'~..~_.. Title A$soO! ~te En§~ ~r 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". AtlanticRichfieldCompany Daily Well History-Initial Report Instructions: Prepare and submit the "Initial ReiN3~t" on the fi~t 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 I County or Parish I Alaska Field I Lease or Unit Kuparuk River Auth. or W.O. no. ITM I AFE 901091 North Slope Borough ADL 25667 Drill State Alaska IWell no. 2G-14 Doyon 9 Operator ARCO Alaska, Inc. API 50-029-21161 IA.R.Co's W.I. Prior status if a W.O, Spudded or W.O. begun IDate Spudded Complete record for each day reported Date and depth as of 8:00 a.m. lO/O2/84 10/03/84 10104184 lO/O5/84 Hour 10/02/84 0200 hfs 16" @ ±110' 530', (420'), DD Wt. 9.6, PV 18, YP 26, PH 8.5, WL 12.8, Sol 7 Accept rig @ 2300 hrs, 10/1/84. NU diverter sys. 0200 hrs, 10/~/84. DD 12¼" hole to 530'. 16" @ ±110' 3100', (2570'), Drlg Wt. 9.7, PV 22, YP 36, PH 8.5· WL 11.6, Sol 9 DD & surv 12¼" hole to 3100'· 712', 5.6°, S41.6W, 711TVD, 10 VS, 7S, 6W 1192' 22.6° S42 7W, 1174 TVD, 130 VS, 98S, 86W · · · 1748' 30 3° S41 6W, 1673 TVD, 373 VS, 280S, 247W 2212' 46 9° S42 3W, 2035 TVD, 661VS, 496S, 438W , · · · 2647' 50° S45 8W, 2324 TVD, 986 VS, 730S, 664W , , · Spud well @ 16" @ ±110' 3350', (250'), Rm'g hole Wt. 10, PV 30, YP 38, PH 8.0, WL 10.8, Sol 11 Drl & surv 12¼" hole to 3350', short trip to 1300', pmp hi vis sweep, POOH. RU & att to rn 9-5/8" csg; unable to get past 1716', POH, LD csg & RD csg tls. RIH w/BHA to 1525', wsh & rm to 1700' 2964', 49.5°, S42.9W, 2528 TVD, 1228 VS, 903S, 833W 3182', 49°, S43.7W, 2671TVD, 1393 VS, 1023S, 947W 16" @ ±110' 3350', (0'), POH to rn 9-5/8" Wt. 10.2, PV 42, YP 58, PH 8.5, WL 8.8, Sol 13 Wsh & rm to 2128', POH, LD 20 its. Rm to 2358', RIH to 2490', single out to 2238'. RIH to 2680', wsh & rm to 2900', RIH to btm @ 3350', no fill. M&P hi vis sweep, att to POH; unable to pull past 2 tl its. RIH to btm, raise vis to 300, POH. RIH, cond, circ hi-vis mud, POH to rn 9-5/8" csg. 56.24% The above is correct Signature For ~orm properatlon and dili~ibution, _se.e...P roc_edu res_ ~Manual_, _Section 10, Date 11/01/84 ITitle Drilling Superintendent ARCO Oil and Gas Company 4~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field I County or Parish ISfate Alaska North Slope Borough Lease or Unit Kuparuk River ADL 25667 Alaska IWell no. 2G-14 Date and depth as of 8:00 a.m. 10/06/84 thru 10/08/84 10/09/84 10/10/84 Complete record for each day while drilling or workover in progress 9-5/8" @ 3327' 8750', (5400'), Short trip f/logs Wt. 10.2, PV 16, YP 10, PH 9.0, WL 5.6, Sol 10 RU & rn 9-5/8", L-80, 36#, BTC csg w/FS @ 3327', FC @ 3245'. Cmt w/lO60 sx PF "E", followed by 370 sx PF "C". Displ using rig pmp, bump plug. CIP @ 1425 hrs, 10/5/84. Perform 50 sx top job. ND diverter sys. NU & tst BOPE. RIH w/8½" BHA to 3243', tst csg to 1500 psi. DO FC, cmt, FS + new hole to 3360'. Establish leak off @ 12.5 EMW. Drl & surv 8½" hole to 8750'. 3405', 49.5°, S42.1W, 2816 TVD, 1561VS, 1146S, 1061W 4341', 51.3°¥ S41.4W, 3399 TVD, 2293 VS, 1690S, 1553W 5307', 50.3°, S44.2W, 4015 TVD, 3037 VS, 2234S, 2066W 6421', 47.6°, S49.7W, 4778 TVD, 3874 VS, 2797S, 2681W 7225', 50.8°, S46W, 5278 TVD, 4478 VS, 3200S, 3132W 7701', 48.5°, S46.9W, 5586 TVD, 4840 VS, 3450S, 3395W 8526', 43.1°, S41.2W, 6162 TVD, 5430 VS, 3868S, 3811W 9-5/8" @ 3327' 8750', (0'), C&C f/csg Wt. 10.2, PV 16, YP 9, PH 9.0, WL 5.7, Sol 11 Fin wiper trip to 9-5/8" shoe, wsh & rm 8514'-8750', C&C, POH. RU & rn DIL/SFL/GR/SP/CAL/FDC/CNL/GR f/8729'-3328', rn BHCS f/8730'-8150'. RIH to 8514', wsh & rm to 8750' 8750', 43°, S44-1/2W, 6326 TVD, 5583 VS, 3980S, 3915W 7" @ 8724' 8645' PBTD, (0'), Inj't mud into ann Wt. 10.1, PV 15, YP 8, PH 9.0, WL 6.4, Sol 11 Rm to 8750', C&C f/csg. POH. LDDP.RU & rn 221 jts, 7", 26#, J-55 ERW BTC csg w/ FS @ 8724', FC @ 8645', mkr jt @ 8448'-8488'. Cmt w/335 sx Cl "G" w/5% KCl, 1% CFR-2, .3% Halad-24. Displ w/332 bbls 10.2 ppg brine, bump plug. Tst csg to 3000 psi; OK. ND BOPE, NU & tst tree to 3000 psi. WOC while inj't mud into ann. The above is correct Signature For form p~eparation [~d distribution see Procedures Manu~l Section 10, Drilling, Pages 86 and 87 IOate 11/01/8t Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District [County or Parish Alaska Field Lease or Unit Kuparuk River Auth. or W,O. no. ITitle I AFE 901091 North Slope Borough ADL 25667 Drill Accounting cost center code State Alaska Well no. 2G-14 DoYon 9 API 50-029-21161 Operator [ A.R.Co. W.I. ARCO Alaska, Inc.i 56.24% Spudded or W.O. begun Date Spudded 10/02/84 10/11/84 Complete record for each day reported 7" @ 8724' 8645' PBTD, RR 10.2 ppg NaCl RR @ 0730 hrs, 10/10/84. Date and depth as of 8:00 a,m. I otal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well our I Prior status if a W.O, I 0200 hrs Old TD I New TD PB Depth 8645 t PBTD Released rig i Date Kind of rig 0730 hrs J 10/10/84 Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well ne. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date : corrected The above is correct Signature~f~'J~ ~ I Date For form preparation and dist~bution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 11/01/84 ITM Drilling Superintendent i ':: ,i / ~1%. , . . -. 1 5'7 ?~ ? 'i '2 /. · 0 , .5 '. .].b 1, ,,)e Z, 14 3.9) 2,4? t' . '/0 2,iq~: .. 2.93 3.2~ .,.-.ii .,. 34 (;,. I 1 ..~,()0 r, L!.O0 C 0.00 :'~ ~'.t;' ,5' 0.23 F ().2g 5 1,i'{ ~' ], .. . ,.: . 37 E I,'17 !.~a~ ,C 1.87 E: 2.52 ,3,9~ F, i.19 F' 4,10 S (..:~.20 5: 3,54. > 1.0,8~ 8 i.~'l 5, :12,72 ~ 25.25 , ~,) ~:.'18 ,:?:, 25,9! W 46,64 8 .50.12 $ 42.67 t~ 73.72 8 35 2] :a gb.27 F, 62.91 W t05.97 $ 36 25 ~. t. 13..3~ S ~'1.28 '~ 143,9q 8 37 35 1,4~.29 5 t14,78 w' 184.37 8 38 30 w ]~',.5.*:'8~ 1o. 3.69 ~ 229,20 S 3~ 49 W ~!.2~,'~5 ~. !73.33 ~ 274,5B S 39 8 W 2a'7.~:~I, ,.., ¢ '203,59. w. 320.10. . S 39 29 W i~i,b3 F 234.29 :~': 366,~6 S ]9 46 ~ 1;t,{::.6 e . ..... :, 267.5~ k: 416,08 8 ~0 0 w .35q.2t 5 303.92 :~,: 470,53 8 40 14 w 3¢3.6! :,: 530,08 8 40 24 w 3~6.59 w 594,5i 433,30 W 663,92 S 40 ~4 W a.~3.41 w 73'1.43 535,43 W 813,22 S 41 10 W 587,~4 t,~889,19 5 41 21 w ~,~..0,36 t,~. 9.65,7. 3 o~' 4I 32 W 693. 6 W 1042,47 8 41 4i 7,~6 05 i,~1118,99 7 <'~8,52 W ! 195,30 5 4! !':...~0u,35 S', 903,09 W t ~47,'70 8 42 4 ~.~ ~~ [~ ..- . , ~ · .... ':' 9~ ~'-' 5~ :~ 1499.14 $ 42 10 W ~t(~E,,la '.' ~,'::57 93 ~? 157.4,5.4 5 42 12 w , ,.2~,~, ~ .. *. I~ ~"'~0 34 c ~16'] 72 '~,,; 17~0.18 8 42 1.6 ~ ? ~'~: ..~] ~ t2!7 02 w !209,02 8 42 16 w ...... ,,. ~2; . i39~:,'.q. 0 ...~ 1..27(l. ,5! ~ .!888,26 8 42 1.7 ~.,~5:< 79 e ~ 374. !7 ~, 1967,99 S ,.2 17 .> ..~ ~ ~ 5 , ~ .... ; I , f. . . 13 ~.P b '/ 3.1 ,)I 'i 4 ~ 9 2 t z, '1 · ,~ ~':~ ,1., , ',2 5 t'.. :;i 3 l 0, .,., , ,4 i 5 · 5' ?67. 7 b 1 ?, 7' '.){' 9, ? ;,, .i ~;:. 2 . ',,r ~ 2 ? 7 I., ? dT:!. 3017. 17 5; .1.909.67 ~.: 2832,67 8 42 23 w 2~,* ~:, ! 963..~-8 w 2909,66 8 42 26 w ~ ~' 2<~17.~2 ¢ 2986.67 3 42 30 ~ 38 ~:- 2072.3g t~ 3063,66 5 42 33 ~ 72 ~: 2126.~6 ~' 3i40.54 5 42 37 W 9r) ,$ 7!~5~1.,8! ~. 3216,88 5 42 42 w O! 5 7237,31 ~ 3292.67 6 42 4~ t~' 3~;; F '.:~292,81 ~,, 3368,22 8 42 53 ~ 7t ~::, 234t~.~]5 w 3443.64 $ 42 59 ~ ~7 $ 7~.,r) 3,87 ~,,;' 35!8'92 5 43 5 ~ ~g 5 2459,40 !~: 3593.78 S 43 11 ~ r,O $ 2514.77 ~ 3668,27 5 43 '1~ ~q ~,9 S 2570,{)2 ;,: 3742,61 S ,i3 22 ~ 3'1 $ 7'~25.71 ~.~ 3817.70 $ 43 27 ~' ~/;2 $ 2681,i8 ~, 3892,47 S 43 32 ¢~ ~5 5 273b,10 '~ 3966,29 $ 43 37 :~ 37 S 2790,70 ~ 4039.38 S 43 41 h f.>9 S '2'84t~.,48 ~ ,1,1!2,fl6 5 43 47 ~ 4.0 S 2902,66 W 4186,90 S 43 53 ~ ~3~;~5 2~5a,89 ;,~'4262,26 8 43 57 ~ !55 ~" 3r'7(~' ........ ......... ,9~5: t~ 4413,27 5 44 5 ~ 18 ~:= '!1.27 34 er 4~9,57 s 44 9 W ..... :, . .. 73 ~ 4566 37 G 4~ 12 ~ i~6 <: '~ 9 :k~ 29 " 44: i..4 ~ >239 g 4643, 69 ~' '~ 2 c,'s* .... ~.,. ..... .Tfi ~, 4719,91 $ 44 17 ~ 50 ~''' '~3~':'i. O1 w d. 796,22 S 44 19 W ~..~ .., ...., ~ , :-3~!& 3.4C>5,22 ~ .4.871,65 ,S 44 20 W 3() 5 ~45',,:~,66 ~ 4946,49 8 44 21 ~ 5'I ' 'i511. 27 ~,,:5020,60 ' .44 22 W .? , ::'L.~-".t ?:E: ! FEjE:"I' BEG ,~ I N r . -. /, .) 'i <' ) . tj {" 3,3? ,, 1.2] ,.), C~ 0 4.W2 ,S 5,.0! ,5 2. 17 S ,..,, ,. 1. 3 7 7 .*)'! W '13.72 $ 35 2l w .61 ~. 530,,0~ .85 ~' 1271.54 8 42 0 W ,9B ,67 3(:'!4.83 3562.13 .. '?2' } . ,4 '/) 4: 4 ~ ::r; 0 R l Z. FEET AZI ,,._,. ,)<'; (.i, (,1, !',) Fi ,, .:~.' '" 02 r..:' · ,_' . ',.:. s 5:: ().99 1.S~ :': 1.61 ~ 'IR S {},0::l ~.~ !.>~:,,30 ,"', ~ 7.~0 ','.' ,i ')'. ':~ 7:::': 33,24 72,31 ~'; 52.32 ~:,~.54 ;1: :13:5.99 09..43 (:., i'70.'21 () , U ('} 0.00 0.03 2.06 2.92 5,78 15.9~ 33.51 89,25 i26.44 169,89 218.74 269,87 ,] .2. 0.95 :373,34 432,40 501,11 ~',, 90 0 E ,',51 4 E S 49 25 E 549 31F: S 51 25 E 540 5 E $ 25 21 ~ S ~2 4 ~ $ 34 42 S 35 53 537 4,4 538 1.5 w o 38 46 539 S 39 3O S 39 48 S 40 578.24 S 404(, w '190,87 $ 41 7 ~' 907.93 5 4~ 24 ~ 1027,6J 6 41 39 ~' ~.1&6.42 S 41 51 W !26~,37 S 41 59 ~ ~..381.75 $ 42 6 ~,~ ~,49'1,469 S 42 10 ~' ~.61.3. 3 S 42 13 ~, :!..'!39.41 $ 42 !O ~ 1868,32 $ 42 17 ~' 2134.77 S 42 16 ~ 2272'05 $ 42 1~ ~ 24:01,41 $ 42 15 ~ 2645.99 S 42 !9 ~ }, - - f /1 (' P h C ~: 6 k' ~]I, ~, :~' ~-; {; ~,:.. ~; f i'.l (] ['; h [< V A 'J' I i._} f,t: I 4 {3. t) 0 [" bO g 2671.9! ~,",4148.27 8 43 5u ,~ 4? .c 2957.34 ~ A260,1~ S 43 5'! ~ 93 5 3042.b0 v~ 4375.26 S 44 3 ~ 56 F~ 3!79,92 ~' 4~}93,0~ S 44 9 w 72 $ 72:i~,31 ;:~ 4613,60 $ 44 !3 't] S 33hr "7 ~; 4733 03 5 44 17 b q f:; q3 ~:9 50 4849' ..... . ..... .72 $ 44 20 w: 6g f4 .?470,22 ~ 4962.71 8 44 22 ,x ~ ....... , 76 8 44 22 75 ~, 3(:)20,~6 W 5177,47 S 44 22 q 7 74 , 3913. 38.37.2o S 3751.4'i 3~62.74 S 3775.60 3051.28 $ 3858.33 4021.R5 3 3924.06 P A r; ,E; 8 1.40,00 8..37 ~67,74 951 ,2~ 968,~2 Sugge~e~ form to be insertcd in each "Active" well folder to d:eck for tin~ly ccxrrpliance with our- rcgulations. Operator,/Well Nan~ and Numke~ z Reports and Materials to be received by: D~te _Required Date Received Remarks Inclina~on S~ey ~ ARCO Alaska, In~' Post Of!i,, 360 Anchorage, ,,~aska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P,O, Box 100360 T~ranAnchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL' s/Schlumberger/FINALS · "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/8h ~n 1 "OCT" Z0/0?/Sh " "OCT" 10/07/$2 " "GCT/JB/GA" 9/31/8~ " "GCT/JB/Ring 9/17/$2 " "GA/JB/GCT" 9/19/84 " " 9/!7/84 " "OCT" 7/21/82/ " "OCT" 9/21/$~ "OCT/O^/O~" 9/Z~/8~ " " ~/15/'8~ " "OCT/JC" 10/12/8~ " 10/~5/8~ " " ~0/~2/8~ " " lO/13/84 " "OOT/~/O^" 10/22/8~ " " lO/22/8~ " "~/Sn" 8/~0/8~. , " " 8/2o/8~ .aun 3 "GCT/JB" zo/~/8~ Nun " zo/1~/8~ " " zo/o5/8~ " "GCT" 10/05/84 " "Perf ~" 9/10/8h Run 2 5 z/2"/?Ps/~" 11/05/84 Run 1 Acoustic "VDL/Signature/GR'' /cat Receipt Acknowledged: DISTRIBUTION 6597 - 8292 :.2B-3~' 7000 - 8h60 .... 2B-!6 4950 - 700h --2B-13 5750 - 8h08 .2B-lb 5700 - 7970 -2B-!5,~ 5328 - 682h '2B-2 7250 - 9182 '2B-4 5055 - 6h87 -2B-i'W 6200 - 7866 .-2D-5a 6800 - 895h - 2D-6 505h - 6650 -2D-7~~ 5597 - 8084 -2D-8 5650 - 7951 ~2G-9 58h0 - 852h --2G-11~ 49h0 - 6765 -' 2G-10~- 5730 - 7950 ~2G-12 5790 - 781h 2G-13~'' 5989 - 8624 '-2G-lb~/ 8650 - 9334 --ZF-6'// 8650 - 9562 1F-6 5692 - 67h2 ~lY-5,/' 5150 - 7252 1L-1~/ 4500 - 6550 -~lL-2 6800 - 7518 1L-~/ / 7000 - 8210 .... iL-3~~ 7961 - 89hl ..... 2V-SA 6100 - 6992 .-iE-24 · · B. Currier BPAE Drilling W. Pasher Geology' //~(.~ G. Phillips Sohio Chevron Mobil Phillips 0il Union D & M NSK Ops, . J, Rathmell Well Files ARCO Alaska, I[ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 21, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Reports Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells' 2G-14 1L-1 2D-3 2X-16 2G-15 1L-16 2D-2 2X-15 2G-16 1L-15 2D-1 2X-14 2E-16 2W-5 WSP #2 Sincerely, /~e; Drilling Engineer JBK/SH/tw HILL/05 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA - ALASK~ OIL AND GAS CONSERVATION L,,..,'MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well F)(]x Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-130 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21161 9. Unit or Lease Name 243' FNL, 88' FEL, Sec. 6, TION, R9E, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 140' RKB, PAD 104' 6. Lease Designation and Serial No. ADL 25667 ALK 2588 10. Well No. 2G-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of October , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0200 hfs, 10/02/84. Drld 12-1/4" hole to 3350'. Ran, cmted & tested 9-5/8" csg. Performed 50 sxs top job. Drld 8-1/2" hole to 8750'TD as of 10/07/84. Ran logs. Ran, cmtd & tstd 7" csg. PBTD is 8645'. Secured well + RR ~ 0730 hrs, 10/10/84. 13. Casing or liner rgn and quantities of cement, results of pressure tests 9-5/8" L-80 36#, BTC csg w/shoe ~ 3327' 7" 26# J-55 HF-ERW BTC csg w/shoe @ 8724' Cmtd w/1060 sxs PF '"E" + 370 sxs PF "C". Cmtd w/335 sxs Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP/Cal/FDC/CNL/GR f/8729' - 3328' BHCS f/8730' - 8150' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ' /.,,'¢-,~,~_.,/~-I'~¢',,~,~f/ / °''"""-T/,,fN' lilLE ........ DATE ~ NOTE--Re o~. th~/~./~m is'required for each calendar month, regardless of the status of operations, and must be' filed ~n duplicate with the Alaska Oil and Gas COnserv~n Commission by the 15th of the succeeding month, unless otherwise directed. Fnrm 113-4fl~ t.,,' H I LL/NR23 Submit in duplicate ARCO Alaska, ir~ Post Offi, x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: -. ARCO ALASKA, INC. _ · ATTN:.~ Records Clerk ~07 Box 100360 /AnchOrage, AK 99510 · L//-Transmitted herewith are the following items. and return one signed copy of this transmittal. Date: 11/07/84 Transmittal No: 4%38 Please acknowledge receipt OH LIS TAPES/Schlumberger -~69612 1L-1 10/08/84 Run 1 ~/69613 1L-2 10/01/84 Run 2 ~ #69591 2B-13 10/03/84 Run 1 /#69596 2G-12 9/23/84 " /#69594 2G-14 10/08/84 " "~'#69595 2D-3 10/08/84 " f #69623 2D-2 10/16/84 " 3188 - 6643.5 2795 - 7105.5 ?_, 2883 - az~8' /cat Receipt Acknowledged: B. Currier Drilling BPAE Geology Chevron Mobil D & M NSK Ops. Date: DISTRIBUTION W. Pasher G. Phillips Phillips 0il J. Rathmell State of AK Sohio Union Well Files .. MEMORANDUM TO: THRU: FROM: State of Alaska ALASKA OIL Ai,]D GAS CONSERVATION COMI~ISSION C. V n C~ai~''--~'~ ~ Lonnie C. Smith' ~ Co~ssioner ~ ~ ~ SUB05CI~ Bobby Petrole,~ InSpector DA/E: October 8, 1984 FILE NO: D. 3I. 65 Witness BOPE Test on ARCO's 2G-14, Sec. 6, TI 0N,R9E,U~'[, Permit No. 84-130, 1984: The BOPE test began at 8:45 pm and was pm. As the attached BOPE test report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's 2G-14. Attachment 02-001A/Rev, 10/79) b&G. #4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~--~.. ~~~ Operato~ Well ~~ - ,.ocat o,,: Sec Drillin8 Contractor~~~ Ri Location, General~Well Sig~[ General HousekeePing~Rig Representative Permit # ~ ~-:~ /-~.'~ ~,- FCasing Set @ 7 f t sentative . / ACCUMULATOR SYSTEM Full Charge Pressure ~-~-~ psig Reserve Pit .Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor ~'~ Gas Detectors Pressure After Closure,/A~g>O psig Pump incr. clos. pres. 200 psig -- mink/ sec. Full Charge Pressure Attained: ~ min/~ sec. N2 ~ ~/~ ~'~. ~~ psi~ Controls: Master Remote C,f.~ Blinds switch cover Kelly and Flo/or Safety Valves BOPE S tack Annular Preventer ip e Rams P Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves ? Check Valve Test Pressure Upper Kelly / Test Pressure Lower KellM / Test Pressure Ball Type / Test Pressure Inside BOP. / Test Pressure Choke Manifold~~ Test Pressure c~ ~ No. Valves No. flanges ~ ~_ Test Results: Failures Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: /~ : Adjustable Chokes ~ zdrauicall~ rated choke Test Time / hrs. days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector July 31, 1984 Mr. J. B. Kewtn Area Drilling Engineer AiRCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2G-14 ARCO Alaska, Inc. Permit No. 84-130 Sur. Loc. 243'FNL, 88'FEL, Sec. 6, T10N, R9E, UM. Btmhole Loc. l148'FSL, 1084'FWL, Sec. 6, T10N, RgE, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a rm~d log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the'digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05,870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code'). Pre. or to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited, bv AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title !8, Alaska A~inistrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to comment, g installation of the blowout prevent.ion Mr. Jeffrey B. K~win Kuparuk River Unit 2G- 14 -2- July 31, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the.shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. ~hatterton Chat~an of Alaska Oil and Gas ~onservatton ~o~ission BY ORDER OF THE COMMISSION b~ Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. : Post Office B, i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2G-14 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2G-14, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on August 27, 1984, your earliest approval will be appreciated. If you have any'questions, please call me at 263-4970. Sincerely, J.'B. Ke~qn ~ Area Dr/~lling Engineer JBK/JG/tw GRU8/L61 Attachments RECEIVED J U L 2 5 1984 .Alaska Oil & Gas Cons. Commisslor~ Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA U~L AND GAS CONSERVATION CO,~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~X REDRILL [] DEEPEN [] lb. TYpe of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATI~j~APH lC SINGLE ZONE [~(X /r'.~ MULTIPLE.ONE [] --- .~ j/. eli Kuparuk R~ver Unit 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 243' FNL, 88' FEL, Sec.6, T10N, R9E, UM At top of proposed producing interval 1387' FSL, 1320' FWL, Sec. 6, T10N, RgE, UN At total depth 1148' FSL, 1084' FWL, Sec. 6, TION, R9E, UM 2G-14 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 140', PAD 104' I ADL 25667 ALK 2588 12. Bond information (see 20 AAC 25.025) Federal Insurance Company IType Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 243 feet 2C-13weII 60' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8653' MD, 6330' TVD feet 2501 08/27/84 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 48 o (see 20AAC25.035 (c) (2) 2757 ps,g@ 80°F Surface 31_6_5_ . ps,g@. 6195__ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE -~ .H_o. le Casing Z~" 1 ..... 12-1/4" 9-5/8" U-1/Z" Weight 62.5# 36. O# 26. O# CASING AND LINER Grade CouplingI Length H-40 / Welq J-55 HF1ERW BTC/ MD TOP TVD 80 36' I 36' 3299 35' I 35' 33' I 33' I MD BOTTOM TVD -116~1 116' 3334~ 2750' 8653'1 6330' t t (include stage data) ± 200 cf 930 Sx Permafrost E & 370 sx Permafrost C 300 sx Class G 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8653' MD (6330' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2757 psi. Pressure calculations are based on virgin reservoir pressure. Surfac,e pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be le_ft, io_~Jncemente_d annul~ t. brouqh the permafrost interval. 2G-14 will be .60' away from 2G-13 at the them down the 7" x 9-5/8" .annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. This well will be completed by the workover rig, using 3-½", 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space'belowl/or Commis~e /' CONDITIONS OF APPROVAL DATE Samples required Mud Icg required ~]YES I~NO E~YES ~.NO Permit number Approval date APPROVED BY ~ /¢//~_ ~ Form 10-401 L"~'~ U~"i~ ~-~ll~F~ Directional Survey required APl number [~YES []NO 50-- O"L,q-Z // /-.* I SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE~ 3'I_, '1984 by order of the Commission Submit in triplicate Permit to Drill 2G-14 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, the well will be fracture stimulated. RECEIVED 3 U L 2 5 ~984 .... ._.~, . .~., , , ~ , .,.,.. [LD. - iIORTH ~1:, ~TSKA - - ~ '~: '~:~ [ASTH~N ~H~[PSTO~, [lie. , , .... i ....... l t '~ ..... t ; ..... ~ ~ , r ~oo . ~0°o ~o0' ~ooo ~ ~ooo ~ ~ ~ooo ~ .1 DO0 ~ ~ ~ , ~ , ~ ~ ....... ..,~ ~ ,. , i ,,_ ~ .... ~ ~~~ ~ .... ~- i . . , .... ~ . . . ~.. , ~00 ,,~. ..,. ~ . , . ~ . _ ~ ..... ......... ~ .... i :, - i -- ~ ~ .......... - ' R-E ''I .... { ' ,- i ............. ~. : · , Ala~'ka Oil ~ Gas Cm s. Gomm~ission · .li '' ~-T,.;~.. ........................ J~- ~'.~ jj~ ' ~'',~:. ~''.. · ...... 1 .~ . ~ -~ .................... , i ........................................... · ~ .......................... : . ; . ; ~. , . "ELL PATH~'EXTE~ND~BE:yOND 't':~ r ....................... ~"~' ' ................................................. :.L_:..L_ ..L.:_Z: ...... : ......... :_ .L ....... : ..... :__. ......... ~ ............... ............ ~ ...... ' .......... ~ . . , ,--::: - .... ...................... ~ . . ; : J; ........ ~ . ~ ; . ................ i , . , .... ; ; ; ,., ~.i .... ........ ~ ....... ; .... ~ : , ~ ~ , ........... ~ ' ' ' ~ ............ ; ~ ' ' · ~ ' ~ ~ : t ~ ...... ; ~ ~ ; ; ..... .;.,~ ..... : ........ ~ ~ ~ ~ ,, : : ~ : ~ . ,, : : ~ : ~ ~. : : : ::::: : : : :: : : : : : : : : ' : ........... ~-.~;...~ .............. ~ .: : ...... ~ .... ~ ........... ,,.. ~ ............................................. ..... ~ .................. . ............................ ~::: ................... , ; . · .. :: ......... ::.::'.:: :::. :::. :: :::: ................................ ....... , ............. I ANNUL~ 9 PIPE BLIND - ~ PIPE , S I{D 2 DIAGRAM 41 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill -lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" -.5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC 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 AF'FER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. . 10. ~11. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND ld'~¥]~$ )J~PSTRE/6u~vI 01~ CHO]<]~S. DON~'T TE'ST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0 s. ~~'PRESSURE DOWNSTREAM O1~ CHOKE ISOLATION VALYES. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P,~MS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY · OPERATE BOPE DAILY. R E [ ElY E D J U L 2 5 1984 Alaska Oil & Gas Cons. Commission Anchorage Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect atty. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves~ hydraulically actuated~ w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. n i im Maintenance & 0Deration 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid Plow to surface is detected. If necessary~ manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED J U L 2 ig84 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office b,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2G Pad Wells 5-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUB/L26 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ & .5 .6 m? .B DS. 2G I HEREBY CERTIFT THAT I AM PROPERLY ]tEGISTE::ED A1TI) SU~.V~r:Z~o x~ TH: STATS OF- A LA SEA AND THAT TI-I 1 S PLAT UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE OF A 49th I~WO 97.76- $ $! ¸DS LOCATED III ~I~CTIOII 32,T1 ~. ¥-'5944~95.0~ I.AT- 70-15-31.5000 ~-- 503929.92 LONG-149-55-,40.152 236 FWL 607 FSL $, Y-5944 t35,21 X- )0~929.90 236 F~FL ?, Yo~4407~.12 X- ~08929.94 7-3 ~ FW'L 427 LOCATi~ IM $£CT1011 5,TIIN,RgE,U,NL 9. Y-,594~465.24 LAT- 70-1~-24.52t$ ~- 50~g6g.gl LONG-t4g-55-Sg,02'l lO, ¥-59~405.10 I, AT- 272 F~L 183 FNL ~- 50596g,92 LONG, 272 FWL 243 I2. Y-Sg4~&5.17 L, AT- 70-15-Z2.5500 ' I- ~0~g69.84 LONG-149-55-~9.0.~2 ?.72 t:W/L 30.3 ~ LOC&lED IR SECTIOI 6.TION,RgE.0.hL t3,. Y.~C~,32~5.15 I. AT-'70-I5-22.55q 85 ~ 303 LA, T- 70- tS-.~0.gt 15 LONG- I q9-55-40. I .5't7 LAT- 70-15-~30.~3204 LONG- 149-55q O, 164 487 FSL LA.T- 70- 15-29.72gg LONG- ! 4 ~ AS- BUILT ,~et,' 6, Z · $( CONDUCTORS 5' 16 , ~¢mle' None 14, Y-5943~45.15 LAT- 70-15-23,1441 I,,5081~09.90 l, ONr.,.,| 49-55- 49.502 CHECK LIST FOR NEW WELL PERMITS / Company,,~ '['~-: ,: Lease & Well No. ti' ITEM (1) Fee (2) Loc APPROVE DATE (2' thru 8) (8)) , (3) Admin ,, (9: thru 11) (10 and 11) (12 thru 20) (5) BOPE :/J~/ (21 thru 24) (6) Add: 1. Is the permit fee attached .......................................... Be 6. 7. 8. I 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO REMARKS 2. Is well to be.located in a defined pool ............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ............... Is operator the only affected party .................................... Can permit be approved before ten-day wait .......................... 'i15i Does operator have a bond in force .................................. Is a conservation order needed tllllllllItllllIIltItl'lllllll'lltll'I ',,:'.~. Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... /~Q-~ Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~~ psig .. ,~T~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional r~quirements ............................................. ,,/-/:/t Geology: Engineering: HWE i"' LC'S,~.~:L. BEW / , rev: ~2/0a/~3 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE : ? :::: ~ ,.. .... ~ ,,.. /: .: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ., No special'effort has been made to chronologically organize this category of information. TAPE VM~IFICATIO~ LISTING .. ~ T' PAGE VP 010,H02 V~TR][FICA..'IO~4 blSTIN(J ATE :84/10/2! RIGIN : EEL NA~ : ONTINUATION ~ :01 REVIOUS REEL OMMENTS : TAPE H~ADEF: ** ERVICF NAME] :EDIT ,ATE :84110121 IRIGIN 10000 'APE ~"A..R -,9594 IObS T'&PE . ~(]M~ENTS : ** RECORD TYPE 137 ** ?ERSION ~ : )ATE ~ ~AXIMU~ LENGTH ~IL~ TYPE ~REVIOUS FILE ,001 1024 INFORMATION RECORDS ** ~NEM CONTE~TS iN : ARCO al,ASK ~;~ : 2G-14 vN : I<IJPAR!]K RJKNG: qE tOWN: 10~ ~ECT: 6 COUN: N, SLOPE 5TAT t ALASKA CTRY: UMA ** COresoft'TS ** TYPE 000 000 O00 000 000 O00 000 000 CATE 000 000 000 000 000 000 000 000 CO0 SIZE 016 006 008 002 004 012 o 06. 003 CODE 065 065 065 065 065 065 065 O65 065 LVP OlO.H02 VERIFICATIO~ LISTING PAGE ALASKA DIVISION COMPUTING CENTER TAPE DENSITY = 800 BPI JOB # 69594 BASE lOG: DIL, , ~UN ~ 1 DATE bOGGI~.:D 8 OCT 84 BOTTO~ LOG INTERVAL- 8729 FT, TOP LOG IMTERVAL : 3328 FT. CASING-LOGGE~ z 9 625 IN, BlT SIZE ~ B~50o Ia. TYPE HOLf FLUID = ×C POLY, DEMSITY = 10.~0 VISCOSITY : 38.00 3328 , C 5VP 010 J402 VERIFICATI(]N LISTIN,, PAGE PM = 9,00 FLUID LOSS = 5.20 "~' ~' ' 4 500 ~a 68 F ~A.220~ ~ 1~5 F = DSTO~E [.,DP: T HALSTEAD DATA F'OR~AT RECO}<D ** ~NTRY BL[]CK$ TYPE SIZE REPR CODE ENTRY ~ I 66 0 4 1 66 ! 8 4 73 60 9 4 65 ,lin ~6 ~ 6O 1 0 I ~6 0 DATUM SPECIFICATION BLUCKS ~NE~ SKRVICE SERVICE UNIT API AP1 API API FILM $]Z~i SPL REPR II') ORDER ~ LOG TYPE CLASS MOD NO, 9EPT VT 00 000 00 O 0 4 SFLU DIE, OH~ OO 220 01 0 0 4 IUD DIE, OH~ O0 120 46 0 0 4 IL~ OIL OH~ 00 120 44 0 0 4 $? OIL ~¥ O0 010 O1 0 0 4 GR OIL GAPI O0 310 Ot 0 0 4 DT ~HC US/F O0 520 B0 0 0 4 GB BNC GAPI O0 310 O1 0 0 4 GR FDN CAPI O0 ]~0 O] 0 0 4 CALl FDN IN O0 280 O1 0 0 4 RHO~ FD~ ~/C3 O0 ]50 02 0 0 4 ORHO FDN ~/C3 O0 356 0! 0 0 4 NRAT FDN OO ~20 O1 0 0 4 RNRA FDN O0 000 O0 0 0 4 NP~I FDN PU 00 890 00 0 0 4 NCNL FDN CPS 00 330 31 0 0 4 FCNL ~UN CPS O0 ~30 30 0 0 4 CODE (OCTAI,~) 68 00000000000000 68 00000000000(00 6~ 00000000000(00 6~ 00000000000000 68 00000000000000 68 00000000000000 68 O0000000000OO0 68 00000000000000 6~ 00000000000000 6~ 00000000000000 68 00000000000000 ~8 00000000000000 68 00000000000000 68 00000000000000 6~ 00000000000000 68 00000000000000 6~ 00000000000000 DATA VERIFICATION LISTING PAGE 4 -1419 792 ~EPLr 8700 rCNL 449 DEPT 8600 ~P -1! ~.R 110 gRAT 3 FCNL 610 5000 SFLU 5938 G~ 0000 CALl 1699 RaRA 0000 0000 SF'Lg ~000 5977 ~NRA 7500 0000 SFLU 9453 GR 0000 CALl ]984 PNRA 0000 )EPT 8~00,0000 SF!,U ~P 65,4375 Gk .~ 59;1875 CAI, I ~RAT 2 7500 ~NRA rCNL ~98~5000 )EPT 8400,0000 SFI.,U $P -1!,8234 GR ~qR 88. 000 CALl ~RAT 2,7813 RNRA FCNL 764,0000 OEPT 8300.0000 SFLU 5P 27,4375 GR ~R ~33,8750 CAI,.,i NRAi 3.7461 R~IRA FCNL 418.0000 DEPT 8200,0000 SFL, U SP -19,0781 GR GR 134,5000 CALl NRAT 3,6953 RNRA FCNL 472.5000 O~PT 8000,0000 SP 13.8125 GR GR 248.3750 CII. T NRAT 99~,2500 RI~RA rc t 299 . soo 3,1055 IbD -1.4i~,0000 BT ,5000 RHOB 3,4551 NJ. HI 6 !602 0000 DT 6406 RHOB 2227 RPHI 22 6406 ILD 59 1875 DT 8 9844 PHOB 3 0332 NPHI 6 5469 ILD 88~0000 DT 9,3828 RHOB 3.0313 ~PHI 1,9473 133,8750 DT 9,2422 RHOB 4,3516 NPHI 2,7168 ILD 134,5000 DI 9.6641 RHO~ 3.912! ~PHI 4,1055 214'2500 DT 9.3594 RHOB -999.2500 N?HI 4 5820 II.,D 248i3750 DT 9 1562 RHO~ -999,2500 NPHI 47,~063 IbM 2 '999,2500 GR -,999 -32768~0000 .[)Rid[:) -32768 37.1582 NCNb -30384 8145 25OO 0000 0000 2,9785 99,6875 (;~ 4~:0762 DRHO 066.4 NCNb 3,1035 89~9375 0000 5 0078 39,5996 NCnb 5,382[~ 91,1 ,~'5 o o~1821 2576,0000 9375 IL~ 91'1250 GR 2754 DRHD 29.5410 NCNb t9,3750 6A,2187 2726 '02t5 .OOO0 4.9648 Ib~ 89,4375 GR 2,4512 DRHO 29.5410 NCNb 5.1406 89,0625 0,0098 2316,0000 ].7285 112,8125 GR 2.3457 DRHO 46,5820 NCNb 1,8594 12~,7500 ,0352 1819,0000 2,3848 I[,g 106.1250 GR 2.3555 DRHO 45,0195 NCNb 2,6152 156,5000 0,0225 1849,0000 3,0566 ILk '999.2.500 GR -q99.2500 DRHO -999,2500 NCNb 2,9609 -999,2500 -999.2500 -999,2500 2,9219 IL~ -999.2500 GR -999.2500 DRHO -999.2500 NCNb 3,7441 2999.2500 999,2500 -999,2.%00 bYP o10,N02 VERIFICATION LISTING PAGE 5 )EPT 7900,0000 SFLU ~.P '18,9219 GR -.,R 150,1.250 CALl -999 )EPT '7800. 0000 SFLU 5P 3,6172 GR gR ! 17.4175 CALI NRAT -999.2500 RNR~ ~CNI., -999. ~500 DEPT 7600 SP -9 GR 113 NRAT ~999 FCNL -999 0000 SFI~U 0313 ~R 68'~5 C.aI, I 2 .. 0 o P N R A 2500 DEPT 7500.0000 8FLU SP -7 1602 ~R GR 132,5000 CALl NRAT -999.2500 RNRA FCNL -999.~500 D~:PT 7400 SP -24 GR !29 NRA. T -999 FCNL -099 0000 SFLU 171.9 GR 5000 ClI. l 2500 RNRA 2500 DEPT 7300 00OO SFLU SP -7:523~ GR Gg !26,7500 CaLl NRAT -999 2500 ~NRA FCNL -999:2500 DEPT 7200.0000 SP -2 2~83 GR N~AT -999.~500 ~r,JRA FCNL -900,2500 OEPT SP NRAT FCNL 7100.O000 SF!iU -15.32~1 GE 103.3125 CII.,I -999.2509 ~N~A -9o9.250© 4 0039 I. L9 150,12..~0 DT 9,7500 ~ao~ -999,2500 NPH! 4,5000 !17,4375 DT ! O' 1328 ~N'OB -999,2500 NPHi 5,4453 ILO 6, ~625 DT o;~o31 RHO~ -999.~500 NP~I 4,7539 ILD 1l~,6875 BT 4375 RHOB -999'2500 NPHI , · 4 2461 ' DT 132.5000 9,9375 RHOB -999.2500 NPHI 3 8926 II,D 129,5000 DT 5781 RHOS I0,. '999.2500 ~PHI 3 4492 1LD 126!7500 DT 10 5038 ~HO~ -999 2500 NPHI 2.5000 ILD I18.5000 DT 9.9297 -q9~,2500 NPHI 3.2051 ILO 1(i)3.3125 DT 9,9062 RHOB -99g,2500 NPhI 3.9961 '999,2500 6R 'gg9.2500 D~HO '999,2500 NCNL 3.7090 Ih~ -999.2500 NC.:b 4,9414 Ib~ -999,2500 GR '999.2500 DRHO '999,2500 NCNb 3,9199 It,~ -999,2500 GR -999.2500 NCNL 4,0313 :999,2500 900,2500 DRHO -9~,25oo ~CNL 4.0352 IbM -ggg,2500 GR -999,2500 DRHO -999.2500 NCNb 3,6250 IbM -999,2500 GR -999,2500 DRHO -999.2500 NCNb 2.4023 Ib~ -999.2500 GR -999.2500 DRHO -999,2500 NCNL 3,4160 IL~ '999.2500 GN '999.2500 DRHO -999,P500 NCbil~ 3,9883 -999,2500 -999,2500 -999,2500 4,!445 2999,2500 999,2500 999,2500 5,0742 -999,2500 -999.2500 -999,2500 4,1562 -999,2500 -999.2500 '999.2500 4,t602 -999,250fi '999,2500 -999,2500 3 9766 -999i2500 -999 2500 -999 2500 3 6953 999:2500 :999,2500 -999,2500 2 4609 '999,2500 -999,2500 -999.2500 3,5020 -999,2500 -999,2500 -999,2500 bVP 010 M02 VE~IFIC~ITION LIS .... ING PAGE 3'EPT 6900,0000 SFLU ~'P -38,~500 G~ .IR -q99,2500 CALl RAT '999 2500 RNRA CNL '099'2500 . ,EP7 6700 0000 SFLU SP -43,5000 GR ~R -99~.2500 CAbI aRAT -999,2500 ~NRA FCNL -999,2500 DEPT 6600 , 0000 8FI.,U SP ...4 ~, 5938 Ga GR -999. 2500 CAI, I ~RAT ,,999,2500 ~NRA FeN'I, -999. 2500 DEPT 6500. ()000 SFLLI SP '27 ,7500 GR -099.2500 CALl 2500 RNRA NRAT FCNL sp 3:~ 7500 OMPT 6300,a000 SF'LU SP -38.0938 GR GP -q9q,2500 C~I.I NRAT -q99,2500 RNPA OEt"T 6200 . fi000 S~;'L!..t SP 31 ~ 125 GR NRAT -o99. 2500 ReORA ~CNL -QqQ, 2500 3 '1092 II,,D . 97;4375 DT ,.9~9,2500 P}'{OB 999,2500 NP[~I 2,8398 107, '999, '999.2500 3,4141 ILD 143,7500 DT ~ '99~.2500 RHOP -999.2500 NPHI 4.1602 131..,1250 BT -~9q'2500 -999,2500 NPH1 4. 2344 T!,D 1'17,1250 DT 9q9 2500 -999.2500 NPH! 2.3691 TI,D 130,8750 DT -999,2500 ~HOB -q99,2500 tJPH1 I 668q ILD ! ~23,7500 DT -999,2500 RHOB -999,2500 NPH1 2.1289 IbP 115.6250 PT -999,2500 -999,2500 3.0t95 142,3750 DT -999,2500 -909.2500 qPHI 3.2852 !bM -999,2500 999,2500 DRHO -999,2500 ..,CNL 3.0254 -999.2500 GR '999'2500 DRHO -999,2500 NCNb 3.5918 IbM -999.2500 GR -999 , 2500 -999,2500 NC:. b 3.9180 IbM -.999,2500 GR 999,2500 DRHI-} -999 25(0 ~CNL 3.4551 IbM '999,2500 GR -999.2500 DRHO -999,2500 NCNb 9.0~71 IbM -999.2500 GR -999,~500 DR~O -999,2500 NCNb 1,8457 Ib~ -999,2500 GR -999.2500 DRHO -999,2500 NCNb 2,0313 -999,2500 GR 'g9q,2500 DRHO -999,2500 NCNL 2,6914 ll,a -999,2500 GR -999,2500 DRMO -999.2500 NCNb 3 .3730 -999 2500 -999 2500 -999 25(1t0 3 0664 1999 2500 999 2500 -999 2500 3,6465 -999,2500 -999,2500 -999,2500 4,0 ,] 13 -.999,2500 999~2500 -999.2500 3.6992 -999,2500 -999.2500 -999,2500 2 084O -999,2500 -999,~500 -999,2500 ,867~ -99 ,2500 -999,2500 -999,2500 2.0977 '999,2500 99,2500 2..8672 2999i2500 999 2500 -999. 2500 ,¥P OlO.H02 VF. RIFICATION t,IS]~'ING PAGE 7 )~2PT 6100. 0000 SFLU ~P .'29,3594 GR ;R 999,2500 CALI tRAT -999,~500 RNRA )EPT 6000,000() SFLU ;a -999 · .,500 C.aI., I 0 1EPT 5900. 0000 SFI, l.! ;P -35,7188 GR ;R -999,~500 CAbI RA.[ ,,999,250(1 RNRA ~CNL -999,2500 )EPT 5~00. C) O00 SFLU iP -40,4688 GR ~R -q99,2500 CAI, T RA~' -999 500 R~RA ~CNL -999" , 50O 0000 SFLIi )EPT 5700, .... ~P -40.5938 GR ~9 -o99. 2500 CALI qRAT -999. 2500 ~NRA ?CNI_, -gq 9. 2500 )EPT 5600. 0000 ~P -37. 2500 GR ~N -~99.P500 C ~t,..i qRAT -999,2500 ~CNL -999.~500 )EPT ~OOiO000 SFLU SP 34-6250 GR ~R 999 2500 CALX ~4RAT -999.2500 ~NPA FCNI~ -09q. PSO0 OEPT 5300,0000 SP -30. 0000 dR dR -999.75n0 NRAT 999 2500 ' 3. 6250 It,D 108 1250 DT '999' ' .2500 rHOB -999,2500 NPHI 98 -999 -999 ,2500 NPHI 2,8008 ILO !55,7500 DT -999 ~, 2500 -999. 2500 NP),iI 3.2051 I!.,D 88,6250 DT -999.2500 NPHI 3 , 3457 I LD 1. 07. 5000 DT i999, soo 2.8633 lbD 108 4375 DT -~99:2500 RMOB -9o9'2500 k~PHI 3,0078 IbO 104,1250 DI' -999,2500 RHO[% -999.2500 NPHI 3,1133 !LD 122.5625 DT '999.2500 ~HOB '999,2500 NPHI 2,6875 89.4375 DT -999.2500 -999.2500 NPHI 3.6875 ILM GR -999,2500 NCNb 3.3730 Ib~ 99' 2500 DAN[) -999,2:)00 N 2.8965 999,2500 GR 999. ~500 DRHCi ,, 9~9,2500 NCNb 3. 3008 999.2$00 GR 999,~500 DRHO -999'2500 NCNb 3.4785 !bM -999,25O0 GR -99~.2500 ORHO -999.2500 NCmb 3.0879 IbM -999.2500 GR -999.2500 DRHO -999.2500 NCNb 3.1875 -999.2500 GR -099,2500 DRHO -999.2500 NCNL 3.1992 Ib~ -999.2500 GR -999.~500 DRHO -999,2500 NCNb 4.0117 IbM -999.2500 GR -999,250o DRHO -999.2500 NCNb 3 .7227 · ,999 2500 -999 2500 -999 2500 3,2969 '999,2500 '999,2500 -999.2500 2.8926 -999 2500 -999' ,2500 '999,~500 3,3672 :999,2500 999,9500 -999. 2500 3.5547 -999,2500 -999.2500 -999.2500 3.0781 -999.2500 -999,2500 -999.2500 3.2090 -999.2500 -999.2500 -999.2500 3.2324 -999,2500 -999.2500 -999.2500 3,7363 -999.2500 -999.2500 '999.2500 5)EPT 5.. 0~ :oooo ~P !CML '999' . ,~500 <:aLI, ~RAT -999,2500 RNHA =CNL '999,2500 )EPT 5000 >~RAT ,,999 PCN'I~ DEPT 4900 R -Q99 NRAT -999 0000 S F L ti 4688 GR ~500 c~t,I 2500 RNRA 2500 0000 SFLU 6250 GR 2500 CAI, I 2500 RNRA 2500 DEPT a~00,OO00 SFLU SP '-37,2500 GR gr -999,2500 CALl NRAT -999 2500 RNRA FCNI -999' ' , ,2500 DEPT 8:700.O0OO SFLU SP -36 3750 GR GR -Q99~2500 C~L! NRAT -999,2500 ~NRA FCNL -999.2500 DEPT 4600.0000 SFLU SP -3~,!250 GR GR -o99,2500 CALl NRgT -~99,2500 RNRA FCNL -999,2500 DEPT 4400. 0000 SFLO ~87 Ga SP -37, .. 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