The URL can be used to link to this page

Home My WebLink About186-046 • • RECEIVED STATE OF ALASKA OCT ZO17 ALASKA OIL AND GAS CONSERVATION COMMISSION �© WELL COMPLETION OR RECOMPLETION REPORT��G 1a.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned El • Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service 2 • Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 9/17/2017 186-046/317-179 • 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 3/11/1986 50-103-20063-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2'FSL,556'FWL,Sec 1,T11N,R8E, UM 4/7/1986 KRU 2T-16 • Top of Productive Interval: 9. Ref Elevations: KB:44'VL-5 17.Field/Pool(s): 1236'FSL, 1514'FWL,Sec 11,T11N, R8E,UM GL:82 BF: ``' Kupurak River Field/Kuparuk Oil Pool • Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 1160'FSL, 1389'FWL,Sec 11,T11N, R8E, UM Surface ADL 25569 • 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498945 y- 5969983 Zone- 4 8947 MD/6149 TVD- 2667 TPI: x- 494625 y- 5965938 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 494500 y- 5965863 Zone- 4 1804/1598 1550/1436 5. Directional or Inclination Survey: Yes ❑ (attached) No 2 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary n/a 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 Surf 110 Surf 110 24 225 sx CS II 9 5/8 36 J-55 Surf 3811 Surf 2768 12.25 1215 sx AS III,380 sx Class G 7 26 J-55 Surf 8418 Surf 5749 8.5 300 sx Class G, 175 sx AS I 5 18 L-80 8183 8947 5587 6151 6.125 120 sx Class G 24.Open to production or injection? Yes ❑ No 2 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): 2 7/8 8569 8046/5494 Perforations Plugged: 8551/5851 8498-8542 MD 5810-5844 ND 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. 8582-8587 MD 5987-5996 ND Was hydraulic fracturing used during completion? Yes❑ No L 8597-8624 MD 5885-5906 ND oc' - Per 20 AAC 25.283(i)(2)attach electronic and printed information - .'''°`I' -L ';1)1‘t DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED �`��' Surface Top Off Job 1.6 bbls cement down T NES JAN 1 8 2013 Surface Top Off Job 1.6 bbls of cement down IA ¢'+ _rt'r 17'-' Surface Top Off Job 1.6 bbls cement down OA L L Surface Top Off Job 0..75 bbls of Portland Type 1 Cement into OA 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - 791Q //i6//$ yr". i/), /1 Form 10-407 Revised 11/2015 /e f' '/ CONTINUED ON PAGE 2 RBERAS w OCT 1 1 20V ubmit ORIGINIAL onl a • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 1 Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1550 1436 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval NIA -WA- information, including reports,per 20 AAC 25.071. K,,eew.k L <-wt) 8440-• ss�8 fast. Y C-. $SW S8L1 to K tip 4 956(o 58[o C CM f P %BS siT.53 • Formation at total depth: N/A w N/A 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek Ca.263-4131 Email: JiII.Simek@cop.com Printed Name: G.L.AlvordA Title: Alaska Drilling Manager / Signature: `�- Phone: 265-6120 Dat : (a t 1°a) a 1 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2T-16 Plug and Abandonment October 4, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2T-16, commencing operations on August 17, 2017 and completing the Plug and Abandonment on September 18, 2017. The tree was removed and a cement top job was performed to bring cement to surface in tubing and all annuli. The wellhead was then removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. Poloi .a 8r 4 • . , ',;,..i...,4 .‘Z, 4., r`fi °,\ i ,w t➢ ' F • ., .-, '(?-,',,,,,,—*%,"',.i, y a ,' a3 .441: - AA tstr,N. ,t.,,,4 - , z 4 r a 3 ,� �, ',-15, �� yr'sgh2 201'0'44,1.'''� � 'S� � � � _ .4:.:4„ -,.'' �fix.$ �am 3 A � "S , .= _ '4 '' ".1`,(4:4,./141,11;1(---� s' . i *y ra 6s-.� , k im i • P&A WELL EVENTS SUMMARY Date Well Event 9/17/2017 (P&A)WELD MARKER PLATE(STATE INSPECTION WAIVED, CHUCK SCHEVE)/REMOVE STAIRS AND • SHORING BOX/BACKFILL EXCAVATION 9/16/2017 (P&A)CUT AND REMOVE WELLHEAD>3' BELOW ORIGINAL TUNDRA LEVEL/RIG DOWN SCAFFOLDING 9/15/2017 (P&A) EXCAVATED EGRESS/SET STAIRS INTO SHORING/INSTALLED SCAFFOLDING 9/14/2017 (P&A) REMOVE GRADE BEAM, EXCAVATE TO 15', SET SHORING BOX 9/9/2017 (P&A) PUMPED 0.75 BBLS OF PORTLAND TYPE 1 CEMENT INTO OA FOR P&A PREP. 8/17/2017 (P&A)CEMENT TOP JOB ON T/I/O(COMPLETE) 7/25/2017 (P&A PREP) :CHECK TOC OF CEMENT:T TOC=56'2", IA TOC=64', OA TOC=26'5". KUP INJ • 2T-16 ConocoPhillips # Well Attributes Max Angle&MD TD Alaska,Inc, Wellhore APIIUWI Field Name Wellbore Status Incl(") MD(ftKB) Act Min(ftKB) , ,&,y.lF. 501032006300 KUPARUK RIVER UNIT INJ 56.87 2,000.00 8,947.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2T-16,10/5/2017 4:1E08 08 PM SSSV:TRDP Last WO: 41.90 4/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,100.0 4/25/2009 Rev Reason:P&A WELL-SEE NOTES pproven 10/9/2017 411 I Casing Strings Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 54.8 110.0 110.0 62.50 H-40 WELDED .M/'CONDUCTOR;54.7-110.0' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CEMENT PLUG;5/.e face- SURFACE 95/8 8.765 54.8 3,811.0 2,768.9 36.00 J-55 BTC CMT PLUG;54.8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 54.8 8,418.0 5,751.0 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread SAFETY VLV;1,804.1 LINER 5 4.276 8,183.0 8,947.0 6,150.8 16.00 L-80 LTC8rd Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Mel(") Item Den Com (in) TGB PUNCH;2,135.0 8,183.0 5,587.2 46.81 HANGER BAKER MOD A LINER HANGER 5.000 TBG PUNCH;2,145.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD))...Wt(Ib/ft) Grade Top Connection TBG PUNCH;2,167.01 TUBING 27/8 2.441 54.8 8,568.9 5,864.1 6.50 J-55 EUE8rdABMOD CEMENT PLUG-TUBING;54E (ulB\ Completion Details CEMENT PLUG;54.8 ftKB Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) GAS LIFT;3,492.6 1,804.1 1,597.4 55.07 SAFETY VLV CAMCO TRDP-1A-SSA 2.313 8,029.2 5,482.7 47.70 PBR 'BROWN PBR 2.500 8,045.9 5,493.9 47.58 PACKER BROWN HB-1 PACKER 2.750 8,120.8 5,544.7 47.09'NIPPLE AVA BPL PORTED NIPPLE NO GO 2.259 SURFACE;51.8-3,811.U- (Special Size AVA;takes 2.312"BPI or BPC,very snug thru SSSV) GAS LIFT;5,524.9 8,123.1 5,546.3 47.08 XO Reducing XO REDUCING 2.875x2.375,4.706,1.995 2.365 8,480.6 5,797.1 41.33 BLAST RINGS 1.920 GAS LIFT;6,432.9 8,551.5 5,850.9 40.52 PACKER 'BAKER DB PACKER 3.250 GAS LIFT;6,906.9 8,563.6 5,860.1 40.52 NIPPLE CAMCO D NIPPLE 1.812 8,568.0 5,863.4 40.52 SOS 'BROWN SHEAR OUT 2.441 GAS LIFT;7,286.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl I TBG PUNCH;7,374.0 Top OMB) (ftKB) (") Das Com , Run Date ID(in) 54.8 54.8 0.14 CMT PLUG CEMENTED TO SURFACE.CEMENT IN OA TO •9/2/2012 • 0.000 318'. Tec PUNCH;7,412.0 - 2,135.0 1,779.9' 56.55 TGB PUNCH 'TITAN 1.375"x 5,4 SPF,0 DEG PHASING 5/20/2012 2.441 2,145.0 1,785.4 56.53 TBG PUNCH 1.375"HSC LOADED,3 SPF,0 DEG PHASED, '5/10/2012 2.441 GAS LIFT;7,699.6 MILLENIUM HMX BH CHARGES CEMENT PLUG;2,900.0 ftKB _ CEMENT PLUG-TUBING;\ 2,167.0 1,797.6 56.49 TBG PUNCH 1.375"HSC LOADED,3 SPF,0 DEC PHASED, 5/10/2012 2.441 ` 2,900.01608 + MILLENIUM HMX BH CHARGES GAS LIFT;7,986.0 7,374.0 5,049.4 49.69 TBG PUNCH 1.375"TUBING PUNCHES,3 SPF,0 DEG PHASED 4/5/2012 ' 2.441 7,412.0 5,074.0 49.59 TBG PUNCH 1.375"TUBING PUNCHES,3 SPF,0 DEG PHASED 4/4/2012 2.441 PER;8,0282 - PACKER;8,045.9 -. 7,950.0 5,429.7 48.18 CMT PLUG 10/10/2009 0.000 CMT PLUG;7,850.0 2 8,120.8 5,544.7 47.09 SLEEVE AVA BPC SLEEVE 6/9/2001 1.875 • GAS LIFT;8.083.28,184.0 5,587.9 46.80 CMT PLUG 10/10/2009 0.000 SLEEVE;8,120.8 1 Perforations&Slots NIPPLE;8,120.8 it Shot T Dens Top(ND) Bhn(TVD) (shotslf Top(ftKB) Btrn(ftKB) (ftKB) (RKB) _ Sane Date t) Type Com CEMENT PLUG;7,900.01808 8,498.0 8,542.0 5,810.2 5,843.7 C-4,2T-16 9/19/1986 12.0 IPERF 3 3/8"HJ II .iI 8,582.0 8,587.0 5,874.1 5,877.9'A-4,21-16 9/19/1986 4.0 IPERF 3 3/8"HJ II 8,597.0 8,624.0 5,885.5 5,906.0 A-3,2T-16 9/17/1986 4.0 IPERF 3 3/8"HJ II Cement Squeezes Top(ND) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com • PRODUCTION;54.0-8,418.0 7,950.0 8,183.0 5,429.7 5,587.2 CEMENT PLUG 10/10/200 • 9 8,183.0 8,948.0 5,587.2 CEMENT PLUG 10/10/200 IPERF;8,498.0-8,542.0 9 2,900.0 7,950,0 2,214.0 5,429.7 CEMENT PLUG 4/4/2012 a 54.8 2,900.0 54.8 2,214.0 CEMENT PLUG- 9/2/2012 0 TUBING PACKER;8,551.5 v"r 54.8 318.0 54.8 318.0 CEMENT PLUG 9/2/2012 ® 54.8 2,900.0 54.8 2,214.0 CEMENT PLUG- 9/9/2017 NIPPLE;8,563.6 TUBING IA 2,900.0 7,950.0 2,214.0 5,429.7 CEMENT PLUG- 9/9/2017 CMT PLUG;8,184.0 TUBING IA Mandrel Inserts st sos;8,568.0 e6 on Top(ND) Valve Latch Port Size TRO Run N Tap(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com IPERF;8,582.0-8,587.0 i' 3,492.6 2,569.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 2 5,524.9 3,832.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 3 6,432.9 4,434.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1996 IPERF;8,597.0-8,624.0 4 6,906.9 4,745.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 5- 7,286.8 4,993.1 CAMCO KBMG 1 GAS LIFT DMY 'BK 0.000 0.0 6 7,699.6 5,263.5 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 7 7,986.0 5,453.7 MMH 2.875x1 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/18/1986 .5 8 8,083.2 5,519.2 CAMCO KBMG 1 INJ DMY BK 0.000 0.0 9/18/1986 LINER;8,183.0-8,947.0 CEMENT PLUG;8,183.0 ftKB ' KUP INJ 410 2T-16 ConocoPhillips /9- ! 4111 Alaska,Inc. •amu Plaalpi 21-16,10/9/2017 4:18:09 PM Vertical 5560,0 45(actual) :11 ft_. Notes:General&Safety End Date Annotation 6/26/1998 'NOTE:SSSV is NOT locked out and is operational,just has no surface controls. CONDUCTOR;54.7-110.0 4/25/2009 NOTE:TBG DEFORMED,DRIFT w/SLINKY 1.75 SAMPLE BAILER CEMENT PLUG;54.8 ftl(B— CMT PLUG;54.8 12/7/2009 'NOTE:View Schematic w/Alaska Schematic9.0 12/15/2009 NOTE:WELL SUSPENDED SAFETY VLV;1.804.1 9/16/2017 'NOTE:Cut tabs on the T,PC,SC,and conductor and removed wellhead>3'bellow original tundra level 9/16/2017 NOTE:P&A-CUT AND REMOVE WELLHEAD>3'BELOW ORIGINAL TUNDRA LEVEL 9/17/2017 NOTE:WELD MARKER PLATE,(AOGC STATE INSPECTION WAIVED,CHUCK SCHEVE) TGB PUNCH;2,135.0 9/18/2017 NOTE:AOGC STATE INSPECTION WAIVED FINAL INSPECTION--Lou Laubstenstein TOG PUNCH;2,145.0 TOG PUNCH;2,167.0` CEMENT PLUG-TUBING;54.8 CEMENT PLUG;54.8 fIKtl(BB GAS LIFT;3,492.6 SURFACE;54.8-3,811.0—a GAS LIFT;5,524.9 GAS LIFT;8,432.9 GAS LIFT;8,906.9 GAS LIFT;7,288.8 TBG PUNCH;7,374.0 TBG PUNCH;7.412.0 GAS LIFT;7,699.6 CEMENT PLUG;2,900.0 89(9 CEMENT PLUG-TUBING;X 2,900.086(13 GAS LIFT;7,986.0 I I PBR;8,029.2 PACKER;8,045.9 CMT PLUG;7,950.0 GAS LIFT;8,083.2 SLEEVE;8,120.8N 1_ NIPPLE:8.120.8 n'I51 iyv1� CEMENT PLUG;7,950.0(KB 41Oil~ 'I PRODUCTION;54.8-8,418.0 IPERF;8,498.0-8,542.0 I PACKER;8,551.5 III NIPPLE;8,563.6 CMT PLUG;8,184.0 I SOS;8,568.0 IPERF;8,582.0-8,587.0 (PERF;8,597.0-8,624 0 II LINER;8,183.0-8,947.0 CEMENT PLUG;8,183.019(0 • OF Tit, • 9 \ 1//7, • THE STATE Alaska Oil and Gas �►►� T At., ofALASKA Conservation Commission 333 West Seventh Avenue rR GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r-;— O� sgP Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360SCANNE '�' Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-16 Permit to Drill Number: 186-046 Sundry Number: 317-179 Dear Ms. Simek: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P;4-e. /5(, Cath P. Foerster Chair DATED this 1[r"day of May, 2017. RBDMS L. MAY 1 6 2017 • • RECEIVED STATE OF ALASKA ��Y ZC�7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC + 20 AAC 25.280 1.Type of Request: Abandon I�1` Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: P&A 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 186-046 3.Address: Stratigraphic ❑ Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20063-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes ❑ No 0✓ KRU 2T-16 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 ' Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,947' ` 6,149' • 0 0 0 Cemented to Surface None Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 110' 110' Surface 3,778' 9 5/8 3,811' 2,768' Production 7' 7" 8,418' 5,749' Liner 5' 5" 8,947' 6,151' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8498-8624 cemented . 5810-5906 cemented 2.875" J-55 5,864' Packers and SSSV Type: PACKER=BROWN HB-1 PACKER Packers and SSSV MD(ft)and TVD(ft):•8046 MD and 5494 TVD PACKER=BAKER DB PACKER • 8552 MD and 5851 TVD SSSV: =CAMCO TRDP , 1804 and 1599 TVD 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service g . 14.Estimated Date for 5/21/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG 0 Commission Representative. GINJ ❑ Op Shutdown ❑ Abandoned 2. 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well Integrity Engineer Jill.Simek@cop.com Email: @cop.com Contact Phone: (907)263-4131 Authorized Signature: ,40 Date: J/3/' - COMMISSION(USE ONLY Conditions of approval: No i Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: pho 1d do c v -t -f a r, c 1 A 0,-, ,f-,---z X55 C4_, 5 1n eh c- 4.1-,I A-& CC Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No i Subsequent Form Required: / Ifo �' RBDMS s -MAY 1 6 2017 APPROVED BY Approved by: 40` II 4-- COMMISSIONER THE COMMISSION Date: // '9r' s/s 7._ "ile/ UTL 5--pc/L 07- 4,G4INALSubsin Form ane Form 10-403 Revised 4/2017 valid for 12 months from the date of approval. Attachments in Duplicate • • �-' RECEIVED ConocoPhillips MAY 0 4 2017 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 24 April 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon Kuparuk River Unit well 2T-16(PTD#: 186-046). Injector 2T-16 was drilled in 1986 and completed as a selective Kuparuk A & C sand well. It was pre- produced for five months, after which A/C water injection began. 2T-16 remained a WAG (water alternating gas) injection well until it was shut-in in April 2009 due to subsidence-induced casing and tubing damage. Subsidence related symptoms, although not diagnosed as such at the time, were first noticed in January 2000 when pressure gauges could not be run downhole due to tight spots in the tubing, restricting deep access. A surface casing leak was diagnosed on March 23, 2009 when the well failed a mechanical integrity test of the outer annulus(MITOA). Based on the overall subsidence issues at drillsite 2T and the condition of the 2T-16 wellbore,the decision was made to secure the perforations with cement, which was completed on October 10,2009. On October 12,2009,a passing mechanical integrity test of the tubing(MITT)to 2500 psi verified the competency of the cement plug. Since then, two additional cement plugs have been pumped,and the well remains suspended with cement to surface. Remaining resources for well 2T-16 are being recaptured through coiled tubing drilling laterals from well 2T-10,the injector immediately north of well 2T-16. Per this procedure, a P&A will be performed by performing a cement top-off job, if required, followed by excavation and removal of the wellhead. / If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek Well Integrity Engineer CPAI Drilling and Wells Conochips 2T-16 P&A Permit to Drill #: 186-046 The objective of the proposed 2T-16 P&A is to excavate 4 feet below original tundra level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document rewired. 7. Send the casing head w/ stub to materials shop. 3hoto document. 8. Weld '/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2T-16 PTD # 186-046 API # 50-103-20063-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. Js • • Wellbore Schematic: KUP 2T-16 ConocoPhillips Well Attributes Max Angle 8 MD TO 411 We4Dota API MI Fleld Nanw Wal Status !fan MO xPEEl Act B.IP081 rt tom.. COnocoehtlIto 5010:2806380 KUPARUK RIVER UNIT INT 55.87 2,000.00 5,9470 ... -_' .CPLmNnt 826(Ppnl Dae Annotation End DON K83:rd 19) Rig Release Date Wer eaap-$$ra.ta7cetaxa97z9M SSSV TRDP Lost WO: 41.90 411011986 :,pn40.AWS 8.901,000 Depth 16091 End Dale Annotation Last Mod...End Date Last Tay 71M. 3170.0 41252009 Rev Reason ADD CEMENT nnam 1013(2012 n.Vk)ER,78-- , CaskV Strings -rums Description Sang G.. Song ID...lop 10091 Set Depth If.,.Set Depth IN5; String WI.. Smog..3111081Top Tnrd q I I.• CONDUCTOR 16 15.082 32.0 110.0 110.0 62.50 H-40 WELDED CanOp De.Onptmn String 0... String ID...Top)0890) set Depth IL Set Depth(NO) Smog wt...Swag String Top TMd SURFACE 9 516 8 765 32 5 3 811 0 2 767 9 38.00 J-55 BTC I 'tamp Owraiption -Moog 0... 5tron9 dl...Top OMB) Set Depth IL Set Depth(TVO)._Stnng WL..Song_.5b)p Tp Tbrd PRODUCTION 7 6276 32.1 8418.0 5749.4 26.00 J-55 BTC n-M��.. Casmg T Description 5omg Cl.,. String 10...Top 18661 et Depth II...Set CHIT SDDepth MD)_Strep Wt..Strep...mom p TMd R11G,33 a LINER 4.276 6183.0 8947.0 6.150.8 1800 L-80 LTC8rd a4rRUG. Liner Details 5 in,Dann SAFETY tow, .w (190) Top;nu moi... E Top 0`-001 41601item Descriptiontxnent ID im) 8,183 0 5.587.2 46.81 HANGER BAKER MOD A LINER HANGER a 5.000 Teen 0 H, Tubing Strings 'hong Description 1 5111118 C.. String ID..l (IIKB) Set Depth(f..,Set Depth 18)8) � 8109 ...Shing WI.9t ...$ Trp Thrd tel' g TUB.NO 2 7 8 I 1.441 Flop 21 3 8.508.9 5 864.1 6.50 l 1-55 I EUESrdABMOD i Completion Details 180 PtaeQ1, lap Depth 2,181 } IND) '74' op incl CEMENTT[ Nam0). N.D.IS Top(5681 Iltl(6) I') Item DescltiWan Cunmmt 8(ml PWG, GIS LOFT 7 28.3 28.3 0.16 HANGER CIW TUBING HANGER 2.875 3493 1 _1,809.1 1,598.5 56.73 SAFETY VLV CAMCO TRDP-1A-SSA 2.313 8,029.2 5482.8 47.50 P60) BROWN PBR 2.500 8,045.9 5.494.0 47.42 PACKER BROWN 11B-1 PACKER 2.750 8,120.8 5,544 8 47.09 NIPPLE OVA BPL PORTED NIPPLE NO GO 2.259 es (5909,,)Size AVA;takes 2.317 BPI or BPC,very snug ecu SS5V) 8.55601, 8,123.1 5,546.4 47.08 X0 Reducing 00 REDUCING 2.875x2.375,4.709,1 995 2.365 557 8,480,6 5,797.0 40.52 BLAST RINGS 1.920 000 601, 8,5515 5.850.0 40.52 PACKER BAKER DB PACKER 3.250 8,451 8.563.6 5,860 1 40.52 NIPPLE CASCO D NIPPLE 1.812 65510051 4.997 I8,5650 5863.4 40.52 SOS BROWN SHEAR OUT 2.441 �, pNot, tither in (VarfNne retrievable plugs,vales,pumps,fish,stn.) i. 0100) lop Intl ii1GPUNGfi. Top(mo6( IW(B) (`) Desaip000 Cmwnetn Run Date ID(m) 737428 28.3 0.16 CMI PLUG CEMENTED TO SURFACE.CEMENT IN OA TO 318', 9422012 0.000 i 2,135 1,7789 5655 TGB PUNCH TITAN 1.375"0 5,4 SPE,0 DEG PHASING .520/2012 2.441 IMPLINCrt. 740 1i 2,145 1,785.5 1.53 TBG PUNCH 1375"14.8 LOADED 3 SPF.0 DEG PHASED,MILLENIUM 8102012 '2.441 00MX BH CHARGES GARNET 77m 2,187 1,797.6 5649 TOG PUNCH 1375`HSC LOADED,3 SPF,0 DEG PHASED,MIL1ENIUM 5;10/2012 2,441 CEMENT HMX BH CHARGES 60M3.2.982 7,374 5,048 4 4969 160 PINCH 1.375"TUBING PUNCHES 3 SPE,0 DEG PHASED 415/2012 2.441 098tIFT 7,980 g. TB - 7,412 5,074 2 49.3/ G PUNCH 1 375 TUBING PUNCHES PUNCIYES,3 SPE,0 DEG PHASED 7,950 54297 48.18 CARPLUG 4791012 2.441 10/102009 0.000 009,0.01'.0 6,121 5.5448 47-09 SLEEVE AVABPC SLEEVE 099/2001 1875 P+s7KEKaA1rG 8,184 5507.9 46.90 CMT PLUG 10110:2009 0.000 0111 RU6 atmit Perforations$Slots OnSIFT, 17 hot 8,071Tp 1190)809(/784 Dens SLEEVE,8,121 TPp1M®)Bre 6781 MMB) MEZone 170,.. Two Comment AIrPVE,00x1 8.498 8,542 5,810.2 5,843.7 C-4,2T-16 99190986 12.0!PERF 3 398"HJ 11 P 8,582 8,587 5,8741 5,877.9 0-4.21-18 9/19'1986 4.0(PERE-3318"HJ II CEMENT 8.:97 8.624 5 885 5 5,906T A-3,23-16 9)1711986 4.0!PERP 3 318"HJ 11 Motes:General&safety End lite AmoUIXP 606/1998 NOTE:SSSV i0 NOT locked out and a 0peronanel,just hes no surface controls. 42512009 NOTE.TOG DEFORMED.DRIFT kr/SLINKY 1.75 SAMPLE BARER 12/7/2010 NOTE-View Schemevc sei Alaska Sdeeereaic9 0 82.140 Ipp 8,4900,54 1 I I PACKER,ESSI RIPPLE,DAN iii CUT RUG, 8,180 5: Mandrel Details 006.8908 Top Depth lop Port {WD) Brt 00 Valve Latch SUe TRO Ron 801 Top 0068) 5008/ r) Maks Model (80 Sen Type Type 1191 (psi) Run Date Com.,, PERE 0. 1 34SC 92 6 2,589.2 51.92 CAO KBMG 1 GAS LIFT DME BK 0.000 0.0 91180988 2 5,524.9 3,832.3 50.05 CASCO KBMG 1 GAS LIFT DMY BK 0.000 0,0 90001986 3 6,432.8 4.434 0 47.97 CASCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9x191996 8587-6771 4 6,9070 4,7454 4939 CAMEO KBMG 1 GAS LIFT DMY BK 0,000 0.0 90811988 5 7,206.8 4,903.1 48 74 CAMEO KBMG 1 GAS LIFT DMY BK 0.000 00 6 7689,6 5,269.5 4853 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/181988 7 7,986.0 5.453.7 47.99 MMM 287501,5 1 12 GAS LIFT 0005 RK 0.000 0.0 91001986 LINEN 8 8,083.2 5,5192 47.26 CAMCO KBMG 1 INJ DMY BK 0.000 0.0 9/18/1986 8,1le TO(X0100 cBl,e4� RUG,SIM Js STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/29/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 2T-16 Oper.Rep: Ian Ives • PTD No.: 186-046 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ier(specify in commei Onshore/Offshore: Onshore Suspension Date: 10/10/09 Date AOGCC Notified: 08/28/10 Sundry No.: 309-338 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 300 Photos Taken? Yes IA 350 OA 20 SCANNED AUG 1 4 2015 Condition of Wellhead: Wellhead location verified with use of plot plan.Wellhead looked to be in good working condition. IA and OA blinded with gauges. Wellhead has flowline attached with 750 psi.Wellhead is leaning towards pipe rack.Wooden cellar box is dry with no sign of oil. Wellhouse was removed for on-going dirt work. Condition of Surrounding Surface Surface conditions looked good,they were in the process of doing dirt work on the pad. Location: Follow Up Actions None Needed: Attachments: Photos(5) REVIEWED BY: Insp.Supry JP,� Comm PLB 08/2010 2010-0829_Suspend_KRU_2T-16_bn.xlsx # `I I ,� 1 } ill 4. . . . , . .40 .. h,-1 .43-1 re �3 i`1 .' f mom 1 1 1 .t t.' .. O 11 'O N N • t 1 z _ i o cli 4 • ‘i 'aiiiii;Or •• v NI CIO EA 0.1 ll U I C4:Fsa 1 ani op a a as I M V 71- %.,,,,4 N W 00 Or. C'I.ppVN o w cv a,O r ��4Q rI . 0 , • 11111111,11 ;1 s VI I Ili 8111, • 1 t 14 ItIL .i A i I • •, 1, I 14' I',.. •,'M . . ,.. , ,- - i* '1i • 1 (Mt tl•:. ' ) ii-4. - 'Tv tr. MOM Tt rrr AI , i :Al I III k i , liaL 1 ' „ . ,• IF I. - i li 1 II P ,1 -411111111111%,' - i ffifrItifi jeddll ' „ . , . . ; • *-- $f) ,r,,,-::, v.,,,,',,,i. ...-... 4 6,,o.'".1 ,Jak ' t '','•' ' • 1 # ,..; 1 *a I 1 ) , • ', a ,. - .. . , ' iirdat _ . _ . .. _. .....„. -c, ...1 - ......1„,.., , 0 4 .,ri 'ilk ILI 10 „4 p. 3 . , Ell • 0 ' ' ,..*'::: . t• ' % . ‘ .4;t! c•I 1 1 1 a 0.. ,... . , 0 iiiI4 ' , 1 I 4•- ,, 1 4.- . ' '*.4.'f' '.0',`.,'',144''' ' "Cl 0 , . .i. 0 EL. ; 0 v) 1 ,,,, ,..1 " ,.... , . 0 , .„,,. • . 9 es, • , ; If ik 1111111N1h :I 11 . ■ . *3.C. . 4 .illii i , '' ''' .' i t , .1 , . AI_ 1 .i.t, - MINI -4' ill �d S. llii t, fOr -: .., 11 4: i 04 ,e,o; I tillir '. .111%. ;01,91 P2'•- 1 P! WjL . �� . 40 'I 101 i , iiki 1 -1 , ' .,. \‘..ir 0 ;., t . 1r .,) .. (0'‘: --- _ .-...:,; ck, p i . • , , ..: .._ ' ..:. '''‘ '.."* . '''''. il 1 ) i ill :. • f:. /4_L--.s..- . mu ....4...:11: ' 0 1 . dissm.... lik at :.!!1 1: „ , /..g Et 1 ,.: .. ---c ' '''''.. : . 1 tUa Ui �O H M pp O N a Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: Other: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: NOTES: ORGANIZED BY: B(~ER"~L BREN VINCENT SHERYL MARIA LOWELL DATE: [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ Scanned (done) III IIIIIIIIIII II III PAGES: q I- . the time of scanning) SCANNED BY; BEVERLY BREN VINCE~~VlARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: Quality Checked (done) RevlNOTScanned.wpd • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Qo 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service El . Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: September 2, 2012 186 - 046 / 312 - 071 3. Address: 6. Date Spudded: 13. API Number: , P. O. Box 100360, Anchorage, AK 99510 - 0360 March 11, 1986 50 103 - 20063 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2' FSL, 556' FWL, Sec. 1, T11N, RO8E, UM' April 7, 1986 2T - 16• Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 1236' FSL, 1514' FWL, Sec. 11, T11N, RO8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1160' FSL, 1389' FWL, Sec. 11, T11 N, RO8E, UM surface Kuparuk River Oil Pool - 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498945 y 5969983 Zone 4 i • 8947' MD / 6149' TVD ADL 25569 TPI: x - 494625 y - 5965938 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 494500 y 5965863 Zone 4 , 1804' MD / 1599' TVD 2667 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) , 1520' MD / 1415' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 32' 110' 32' 110' 24" 225 sx CS II 9.625" 36# J -55 33' 3811' 33' 2768' 12.25" 1215 sx AS III, 380 sx Class G 7" 26# J -55 32' 8418' 32' 5749' 8.5" 300 sx Class G, 175 sx AS I 5" 18# L -80 8183' 8947' 5587' 6151' 6.125" 120 sx Class G 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2.875" 8569' 8046' MD / 5494' TVD REC EIVED 8552' MD /5851'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. OCT 1 2 2012 Was hydraulic fracturing used during completion? Yes ❑ No 0 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED AQGCC 8624' -7950' 18 bbls 15.8 Class G 2736-7374' 185 bbls 15.8# Class G 0' -2135' 94 bbls 15.7# AS I 0 -318' in 9.625" x 7" annulus 50 bbls 15.7# AS I 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL , OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE MAR 0 fi 2013 SOWED I BbMS OCT 15 2012 �, 1 G Form 10 -407 Revised 10/2012 �� CONTINUED ON REVERSE Submit original only . 7Z ti-47. (zy 28. GEOLOGIC MARKERS (List all formations ands encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1520' 1415 needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 8497' 5808' Base Kuparuk C 8547' 5846' Top Kuparuk A 8566' 5861' Base Kuparuk A 8688' 5953' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS - P4,1n 1 4- 1;, Summary of Daily Operations, schematic '(\ra 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 - 4250 Email: Tyson .M.Wiese@conocophillips.com Printed Name H. Gober Title: Wells Engineering Supervisor Signature I d 9 Phone 263 - 4220 Date /0 /1 1 /1 Z-- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 10/2012 y, f x KUP 2T -16 • • ConocoPhillips 0-4 Well Attributes Max Angle & MD TD Alaska, Inc. Wel lbore API/0W' Field Name Well Status Inci (") MD (ftKB) Act Btm (ftKB) 501032006300 KUPARUK RIVER UNIT INJ 56.87 2,000.00 8,947.0 "` Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "" - SSSV: TRDP Last WO: 41.90 4/10/1986 Well Confio - 2T -16, 1018/2012 2.48.32 PM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag SLM 8,100.0 4/25/2009 Rev Reason: ADD CEMENT ninam 10/8/2012 HANGER, 28 Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd . CONDUCTOR 16 15.062 32.0 110.0 110.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 32.5 3,811.0 2,767.9 36.00 J - 55 BTC ':. Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, PRODUCTION 7 6.276 32.1 8,418.0 5,749.4 26.00 J - 55 BTC 32 -110 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CEMENT PLUG, 33 LINER 5 4.276 8,183.0 8,947.0 6,150.8 18.00 L-80 LTC8rd CMT PLUG, 26 Liner Details i. Top Depth SAFETY VLV. 4S (ND) Top Intl Nomi... 1,804 as Top (ftKB) (ftKB) (°) item Description Comment ID (in) 8,183.0 5,587.2 46.81 HANGER BAKER MOD A LINER HANGER 5.000 TGB PUNCH, 8 Tubing Strings 2,135 7 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd TBG PUNCH. :ii1i TUBING 27/8 2.441 28.3 8,568.9 5,864.1 6.50 J-55 EUE8rdABMOD Alli V Completion Details TBG PUNCH, ` I I Top Depth 2,167 � \`� " (TVD) Top Intl Nomi... CEMENT Top (ftKB) (ftKB) 1) Item Description Comment ID (18) PLUG, 28 28.3 28.3 0.16 HANGER CIW TUBING HANGER 2.875 GAS 3,493 1,804.1 1,598.5 56.73 SAFETY VLV CAMCO TRDP-1A-SSA 2.313 �- 8,0292 5,482.8 47.50 PBR BROWN PBR 2.500 � :'' 8,045.9 5,494.0 47.42 PACKER BROWN HB-1 PACKER 2750 ' 8,120.8 5,544.8 47.09 NIPPLE AVA BPL PORTED NIPPLE NO GO 2.259 SURFACE, t (Special Size AVA; takes 2.312" BPI or BPC, very snug thw SSSV) 32 -3,811 GAS LIFT, T'- 8,123.1 5,546.4 47.08 X0 Reducing X0 REDUCING 2.875x2.375, 4.708, 1.995 2.365 3,323 Irr, 8,480.6 5,797.0 40.52 BLAST RINGS 1.920 Ill ' GAS LIFT, 8,551.5 5,850.9 40.52 PACKER BAKER DB PACKER 3.250 8,433 lirref : 8,563.6 5,860.1 40.52 NIPPLE CAMCODNIPPLE 1.812 GAS LIFT, �ccrere'�'� 8,907 leer/ 8,568,0 5,863.4 40.52 SOS BROWN SHEAR OUT 2.441 ' .^° IF Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, 7,287 Top Depth _ (TVD) Top In<I TBG PUNCH, &`. Top (ftKB) MB) (°) Description Comment Run Date ID (in) 7,374 ��€€ 28 28.3 0.16 CMT PLUG CEMENTED TO SURFACE. CEMENT IN OA TO 318'. 9/2/2012 0.000 1!' 2,135 1,779.9 56.55 TGB PUNCH TITAN 1.375" x 5', 4 SPF, 0 DEG PHASING 5/20/2012 2.441 TBG PUNCH, ; 7.412 2,145 1,785.5 56.53 TBG PUNCH 1.375" HSC LOADED, 3 SPF, 0 DEG PHASED, MILLENIUM 5/10 /2012 2.441 HMX BH CHARGES GAS LIFT, 7,700 2,167 1,797.6 56.49 TBG PUNCH 1.375" HSC LOADED, 3 SPF, 0 DEG PHASED, MILLENIUM 5/10/2012 2.441 CEMENT HMX BH CHARGES PLUG, 2,900 7 ,374 5,049.4 49.69 TBG PUNCH 1.375" TUBING PUNCHES, 3 SPF, 0 DEG PHASED 4/5/2012 Z441 GAS LIFT, 7.986 IF ,, 7,4121 5,0742 49.36 TBG PUNCH 1.375" TUBING PUNCHES, 3 SPF, 0 DEG PHASED 4/4/2012 2.441 7,950 5,429.7 48.18 CMT PLUG 10/10/2009 0.000 PBR, 8,029 IL 8,121 5,544.8 47.09 SLEEVE AVA BPC SLEEVE 6/9/2001 1.875 Ilia PACKER, 5046 ~ 8,184 5,587.9 46.80 CMT PLUG 10/10/2009 0.000 GMT PLUG, 7,,9550 0 ': Perforations & Slots GAS LIFT, Shot 8,083 11. Top (TVD) Btm (ND) Dens SLEEVE, 8,121 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment NIPPLE. 8,121 8,498 8,542 5,810.2 5,843.7 C-4, 2T -16 9/19/1986 12.0 IPERF 3 3/8" HJ II 8,582 8,587 5,874.1 5,877.9 A -4, 2T -16 9/19/1986 4.0 IPERF 3 3/8" HJ II CEMENT 8,597 8,624 5,8855 5906.1 A -3, 2T -16 9/17/1986 4.0 IPERF 33/8" HJ II PLUG, 7,950 Notes: General & Safety N End Date Annotation 6/26/1998 NOTE: SSSV is NOT locked out and is operational, just has no surface controls. 4/25/2009 NOTE: TBG DEFORMED, DRIFT w /SLINKY 1.75 SAMPLE BAILER 12/7/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PRODUCTION, 32 -8,418 5r 1 IPERF, -- [ 8,498-8,542 f I PACKER. 8,551 • ' NIPPLE, 5564 , GMT P 184 �\ 8,184 M Mandrel Details 505, 8588 Top Depth Top Port � (ND) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) 0) Make Model (in) Sery Type Type (in) (psi) Run Date Com... IPERF, 1 3,492.6 2,5692 51.92 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 8,582 - 8,587 2 5,524.9 3,832.3 50.05 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 IPERF, 3 6,432.9 4,434.0 47.97 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1996 8,597 - 8,624 4 6,907.0 4,745.4 49.39 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 5 7,286.8 4,993.1 49.74 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6 7,699.6 5,263.5 48.53 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 7 7,986.0 5,453.7 47.99 MMH 2.875x1.5 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/18/1986 LINER, 8 8,083.2 5,519.2 47.26 CAMCO KBMG 1 INJ DMY BK 0.000 0.0 9/18/1986 8,1835,947 TD (2T -18), 8,947 CEMENT PLUG, 8,183 b 2T-14t Well Work Summary DATE SUMMARY . 3/4/1.2 DRIFTED TBG WITH 3' x 1.5 " ON 1.25" SLINKY TOOLSTRING TO 7' SLM. COMPLETE. 4/4/12 PERFORM MITT AND MITIA W/ LRS. BOTH TESTS PASSED. RIH AND PERFORATE INTERVAL 7412.8' TO 7415.8' W/ 1.375 TUBING PUNCH LOADED 3 SPF, 0 DEGREE PHASED. CIRCULATED 15 BBLS DIESEL AT 0.15 BPM AND 3000 PSI BEFORE HOLES PLUGGED UP. TOOLSTRING WAS STUCK ON BOTTOM AT 7417' BEFORE SHOOTING AND EVENTUALLY WORKED FREE AFTER CIRCULATING FLUID AND PULLING MAX TENSION OF 2800 LBS. 4/5/12 RIH W/ 1.375" X 3' TUBING PUNCH LOADED 3 SPF, 0 DEG PHASED. PUNCH INTERVAL 7374'- 7377'. CIRCULATE 130 BBLS SLICK DIESEL AT 2 BPM AND 2500 PSI DOWN TUBING AND UP THROUGH THE IA 4/14/12 Pumped 185 bbl of 15.8 ppg "G" cement down the tubing, through the tubing punch at 7374' - 7377' taking returns up the IA. Estimated top of cement in the tubing and IA is at 2900',_freeze protected with diesel from 2500' to surface in the tubing and IA. Tot/ 4/17/12 TAGGED TOC w/ 3' x 1.5" STEM @ 2736' SLM. TOOLS HUNG UP w/ ROPE SOCKET IN TRDP @ 1809' SLM. INJECTION TEST ON OA: 1.9 BPM @ 1300 PSI. ATTEMPTED MIT TBG & IA, FAILED. RDMO. STATE REP WAS CALLED, SAID IT WAS GOOD TO GO. WAIVED WITNESS. 4/19/12 (AC EVAL): MITT: PASSED. MITIA: PASSED. 5/4/12 PERFORMED RCBL, TAGGED AT 2734', LOGGED UP TO SSSV, ESTIMATED TOC AT 2202', COULD NOT PULL THROUGH SSSV, PULLED OUT OF WEAK POINT PER CWG REP. * ** **FISH IN HOLE - 40' OAL, MAX O.D. 1.69 ", MAX RIGID LENGTH 15 5/8/12 RECOVER COMPLETE E -LINE TOOLSTING @ 2668' SLM. COMPLETE. 5/10/12 PERFORATE INTERVALS 2145' -2148' AND 2167' -2170' USING 1.375" HSC LOADED 3 SPF, 0 DEGREE PHASED, MILLENIUM HMX BH CHARGES. LOG CORRELATED TO HES CEMENT BOND LOG DATED 04 MAY 2012. 5/16/12 ESTABLISHED INJECTION RATE OF 0.94 BPM AT 2000 PSI DOWN TUBING TAKING RETURNS THROUGH TUBING PUNCH HOLES UP THE INNER ANNULUS TO PRODUCTION. 5/20/12 PERFORATE CIRCULATION HOLES IN TUBING IN TWO RUNS FROM 2135 -2145' WITH 1.375" X 5' TITAN TUBING PUNCH GUNS LOADED 4 SPF, 0 DEG PHASE, 20 HOLES TOTAL. ESTABLISH CIRCULATION RATE BY PUMPING 20 BBLS OF DIESEL TO TUBING AT 2.0 BPM, 1450 PSI, TAKING RETURNS FROM IA TO 2T -17 FLOWLINE. 9/2/12 PUMP 15.7 PPG AS1 CEMENT DOWN TBG TAKING RETURNS UP IA TO SURFACE. GOOD RETURNS OF CEMENT (94BBLS PUMPED.) PUMP 50 BBLS OF 15.7 PPG AS1 CEMENT DOWN OA W/ AGGREGATE & CemNet PER PROCEDURE. ALL SURFACE LINES & VALVES FLUSHED CLEAN OF CEMENT. ALLOW CEMENT TO SET FOR 24 HOURS MINIUM PRIOR TO MIT'S. 9/5/12 MITT- PASSED,MITIA- FAILED,MITOA -DID NOT ATTEMPT. 10/8/12 (AC EVAL) IA DD TEST- PASSED (NO PSI. BUILD UP) • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2T -16 Run Date: 5/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20063 -00 SCANNED APR 0 2 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: — 1 � — i �''L- Signed: I , 0 ,,,,� y 1 • • 1X6-04C3 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 11, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2T -16 Run Date: 5/10/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20063 -00 ;SCANNED APR 0 2 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 1/1(1/0- Signed: • • 2\5 (,0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 9, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 2T -16 Run Date: 5/4/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -16 Data in LAS format, Digital Log Image files 1 CD Rom 50- 103 - 20063 -00 Cement Bond Log 1 Color Log 50- 103 - 20063 -00 scANNED APR 0 2 2013, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: S \ `6 /V2_ Signed: 4 i ��, • 471 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 6, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 NED APR 0 2 2.t 3 SCAN RE: Tubing Punch Record: 2T -16 Run Date: 4/5/2012 The technical data listed below is being submitted herewith. Plse address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20063 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: J' Signed: /1014:11) �./� too o`E • V_ 75 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2T -16 APR 0 2 2013 SCANNED Run Date: 4/4/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -16 Digital Data (LAS), Digital Log file 1 CD Rom 50- 103 - 20063 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com Date: 4/ Signed: I '/1pt° • • 4/\ L ( , a SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION OM SSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tyson Wiese 't 1 f r �..:}E' b d 0 Wells Engineer ti��s ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -16 Sundry Number: 312 -071 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2q day of February, 2012. Encl. STATE OF ALASKA (� ,, A OIL AND GAS CONSERVATION COMMI•N /9.. Q / M�` �' � APPLICATION FOR SUNDRY APPROVALS" /fir ti t 4 /1 t •• 20 AAC 25.280 Type r T e of Request: Aban Z r- Plug for Redrill f Perforate New Pool Repair w ell r Change Approved Program r A,14.I, Suspend ✓ Rug Perforations r Perforate r Pull Tubing (-` Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing j" Other: Secure Well (ri • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -046 ' 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20063 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 2T -16 « 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25569 . 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): 8947 • 6149 • 8723' 5979' 7950', 8184' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 110' 110' RECE JVED SURFACE 3779 9.625 3811' 2768' PRODUCTION 8386 7 8418' 5749' FEB 2 4 2012 LINER 764 5 8947' 6151' Alaska Gil & Gas C cns. Commissi n An61ft:raye Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8498'- 8542', 8582'- 8587', 8597' -8624' 5810'- 5844', 5874'- 5878', 5886' - 5906' 2.875 J - 8568 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN HB -1 PACKER MD= 8046 TVD= 5494 PACKER - BAKER DB PACKER MD= 8551 TVD= 5851 SSSV - CAMCO TRDP-1A SSA MD =1804 TVD= 1599 12. Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program F BOP Sketch r Exploratory Development 1` Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/7/2012 • Oil r Gas r WDSPL r Suspended j 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r 1• +iv Commission Representative: GSTOR r SPLUG J"` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Printed Name Tyson Wiese Title: Wells Engineer Signature 1 Phone: 263 -4250 Date 1I2-3J1b�' r., Commission Use Only n Sundry Number:3I G._rj I Conditions of approval: Test pr Notify Commission so that a representative may witness `� Plug Integrity BOP t t r Mechanical Integrity Test E Location Clearance r / Other: ' " 5 ,.ice.+. s L gri-•, d►'‚ G Subsequent Form Required: / 1) uO • ( APPROVED BY Approved by: - COMMISSIONER THE COMMISSION Date: 2k7/ 7 ! v Form 10 -403 Revised 1/2010 ;Z. "/21/12--- 2 EI®IBS MAR 0 22011 Submit in Duplicate / ORIGINAL 34667,b___ • • 2T -16 Fullbore P &A Permit to Drill #: 186 -046 The objective of the proposed 2T -16 Fullbore P&A is to perforate the 2 7/8" tubing as close to the packer as possible, then cement the tubing, production casing, and surface casing to . further secure the well, until wellhead removal at a later date. Proposed P &A: (further secure, cement to surface) E -line/ Little Red: 1. RIH and detonate 1" Split Shot Cutter at 7,530' KB, or as close to the packer as possible. 2. Pump 110 bbls of Diesel to ensure adequate circ. rate for cementing, and for freeze protect of IA and OA via jumper at surface. Pumping: 1. Ensure an approved sundry has been received from AOGCC. 2. Pump 185 bbl of 15.8# Class G cement through tubing holes, to bring TOC in tubing and IA to 2,900' KB. Perfs below were squeezed off in 2009. Slick Line / Little Red: 1. Notify the slope AOGCC Inspector of the upcoming tag and pressure test of the cement plug, provrding at least 24 hours of notice to schedule the witness. 2. RIH and Tag TOC at 2,900' KB. Record Results. 3. MIT Tubing to 2,500 psi. MIT -IA to 1,500 psi. Record Results. 4. RU LRS to OA and perform Injectivity Test to ensure rates required for cementing. E -line / Little Red: 1. RIH and detonate 1 3/8" Tubing Punch at 2,825' KB. (middle of tubing joint #32 of 54) 2. Pump 20 bbls of Diesel through tubing holes to ensure adequate circulation rates. Pumping: 1. Pump 125 bbls of AS1 cement through holes at 2,825' KB, to fill IA and Tubing to surface. When good IA cement returns are at surface, RU on the OA. 2. Pump 50 bbls of AS1 cement to plug the OA leak at 318' KB, and bring cement to surface. Use LCM during OA cement job to attempt to plug surface casing leak. Little Red: 1. MIT -T with Diesel to 2,500 psi. Record Results 2. MIT -IA with Diesel to 1,500 psi. Record Results. 3. MIT -OA with Diesel to 1.500 psi. Record Results. 4. If cannot get OA to hold cement to surface due to leak, plan to perform the final OA cement plug at a later date, when the wellhead is removed. No reserves (ems ► 4e D welt w as r S v e'd'd Give 712 et._ � eGeSfay , � re�:Ovl/ f h , ° k �,,' // co 9 o�c�,'l`,'O'►a / feevr,' ] ! a te >f Cewcei,if 74P r ' e rgo-, ce P Mt ! to I,ti'o / 0v� Q „c/ aril/ a c�0 f, 2 -/� ( or T -10 TV pro lost 1 / air xloe�ei r of �zr'62 TW 2/22/2012 KU P 4111 + 2T -16 Coflo - ' 'YWI►.- Well Attributes Max Angle & MD TD Alaska Inc Wellbore APUUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 501032006300 KUPARUK RIVER UNIT INJ 56.87 2,000.00 8,947.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: TRDP Last WO: 41.90 4/10/1986 Well Coned. - 27-111. 1131/2012 431 13 PM - Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: SLM 8,100.0 4/25/2009 Rev Reason: WELL REVIEW osborl 1/31/2012 HANGER, 28 Casing Strings :. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 32.0 110.0 110.0 62.50 H - 40 WELDED ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - - SURFACE 95/8 8.765 32.5 3,811.0 2,767.9 36.00 J BTC Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ PRODUCTION 7 6.276 32.1 8,418.0 5,749.4 26.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR. LINER 5 4.276 8,183.0 8,947.0 6,150.8 18.00 L - 80 LTC8rd 32 -110 Liner Details Top Depth r 1111 (ND) Top Incl Nomi... SAFETY VLV, { .o° Top (ftKB) OHO E) Item Description Comment ID (in) 1,804 8,183.0 5,587.2 46.81 HANGER BAKER MOD A LINER HANGER 5.000 GAS LIFT, gpN Tubing Strings 3,483 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 27/8 I 2.441 I 28.3 I 8,568.9 I 5,864.1 1 6.50 I J -55 I EUE8rdABMOD Completion Details , Top Depth (TVD) Top Inc! Nomi... •1 l Top(ftKB) (ftKB) ('1 Rem Description Comment ID (in) SURFACE, 2$.3 28.3 0.16 HANGER CIW TUBING HANGER 2.875 32 - 3,811 1,804.1 1,598.5 56.73 SAFETY VLV CAMCO TRDP -1A -SSA 2.313 ms s 525 8,029.2 5,482.8 47.50 PBR BROWN PBR 2.500 III 8,045.9 5,494.0 47.42 PACKER BROWN HB-1 PACKER 2.750 GAS LIFT, 6,433 IC 8,120.8 5,544.8 47.09 NIPPLE AVA BPL PORTED NIPPLE NO GO 2.259 III (Special Size AVA; takes 2.312' BPI or BPC, very snug thru SSSV) GAS LIFT, 8,123.1 5,546.4 47.08 XO reducing XO reducing 2.875x2.375, 4.708, , 1.995 2.365 6,907 III 8,480.6 5,797.0 40.52 BLAST RINGS 1.920 GAS LIFT, _ _. C 8,551.5 5,850.9 40.52 PACKER BAKER DB PACKER 3.250 7'267 8,5636 5,860.1 40.52 NIPPLE CAMCO D NIPPLE 1.812 III GAS LIFT, 8,568.0 5,863.4 40.52 SOS BROWN SHEAR OUT 2.441 7,700 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth _ (ND) Top Inel GAS LIFT, Top (ftKB) MB) ( °) Description Comment Run Date ID (in) 7.986 7,950.0 5,429.7 48.18 CMT PLUG 10/10/2009 0.000 8,120.8 5,544.8 47.09 SLEEVE AVABPCSLEEVE 6/9/2001 . 1.875 8,184.0 5,587.9 46.80 CMT PLUG 10/10/2009 0.000 PBR, 8.029 - perforations & Slots PACKER. 8.046 ,.- Shot CMT PLUG. Top (TVD) Btm (TVD) Dens 7.950 Top (ftKB) Btm (ftKB) (ftKB) (RKB) Zone Date (sh... Type Comment GAS LIFT, II 8,498.0 8,542.0 5,810.2 5,843.7 C - 4, 2T - 16 9/19/1986 12.0 IPERF 33/6' HJ II 8,083 � ti 8,582.0 8,587.0 5,874.1 5,877.9 A 2T - 16 9/19/1986 4.0 IPERF 3 3/8" HJ II SLEEVE, 8,121 NIPPLE, 8,121 8,597.0 8,624.0 5,885.5 5,906.1 A -3, 2T -16 9/17/1986 4.0 IPERF 3 3/8" HJ II Notes: General & Safety End Date Annotation CEMENT I I 6/26/1998 NOTE: SSSV is NOT locked out and is operational, just has no surface controls. PLUG, 7,950 4/25/2009 NOTE: TBG DEFORMED, DRIFTw /SLINKY 1.75 SAMPLE BAILER 12/72010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PRODUCTION. 32.8,418 ir IPERF,.: 8,498.8,542 -- 1/ i PACKER. 8,551 1 ) .. NIPPLE,8,564 II CMT PLUG. 8,184 SOS. 8,568 Mandrel Details IPERF, - Top Depth Top Port 8,582 -8,587 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (MB) E) Make Model (!n) Sery Type Type ON (psi) Run Date Com... 1 3,492.6 2,569.2 51.92 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 IPERF, 8,597-,624 - 2 5,524.9 3,832.3 50.05 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 3 6,432.9 4,434.0 47.97 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1996 4 6,907.0 4,745.4 49.39 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 5 7,286.8 4,993.1 49.74 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6 7,699.6 5,263.5 48.53 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/1986 7 7,986.0 5,453.7 47.99 MMH 2.875x1.5 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/18/1986 LINER, 8 8,083.2 5,519.2 47.26 CAMCO KBMG 1 INJ DMY BK 0.000 0.0 9/18/1986 1 8,183-8,947 TD(2T -16), 8,947 ' CEMENT PLUG, 8,183 . • 2T -16 Plug & Abandonment (Suspend Well) Current Completion Proposed P &A OA - AS 1 Cement to Surface Surface Casing Leak - 318' KB IA - AS t Cement to Surface ® SSSV – 1,804' KB Tubing Holes – 2,825' KB GLV (DMY) – 3,493' KB Top of Class G Cement 4 ` 95,8" 36# J-55 Surface Casing @ 2900' KB ' 3,811' KB ��_ GLV (DMY) – 5,525' KB GLV (DMY) – 6,433' KB GLV (DMY)- 6,90TKB l GLV(DMY)- 7,287'KB — J GLV (DMY) – 7,700' KB –4— Tubing Holes – 7.530' KB - Past Plug TOC in tubing ` 7,950' KB GLV (DMY) – 7 KB '% ■imi. -1-- PBR – 8,G?9' K6 i �( r �.SI] 1 i.� Baker Packer- 8,046'KB INJV (DMY) – 8.083' KB ,' 3 a D 0 C - - - Si=ding Sleeve @ 8,121' KB - �� : th, T' 26# J-55 Prod. Casing @ 8,418' KB C Sand Perfs- , 8,498' – 8,542 KB " . 1. 3 C Baker DB Packer –8.551 KB s _ _–� A Sand Pe fs: ..., .r,. 8,582' -8,58T KB 8,597' – 8.624' KB .4 ' U. 5" Liner TD @ 8,947' KB TW 1220.11 TW 2/22/2012 Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 9:18 AM To: 'Herrmann, Daniel D' Subject: RE: 2T -05, 2T -11, 2T -16 Rigless P &A Procedure (PTD 186 -097, PTD 186 -046 , PTD 186 -144) Dan, These three wells all have cement plugs that were pumped fullbore in the last couple of years. It appears that they have all been pressure tested ( witnessed by AOGCC inspectors) after this initial plug was pumped. The wells are officially suspended in our database and the work you are proposing will be additional suspension operations to further secure the wells until final wellhead cutoff and site remediation. The proposed tag depths are very close to the top of the packer and will allow sufficient cement to be circulated to safely abandon the wells. Go ahead a submit 403 sundries with as with the tag depths listed below as circulation points for the cementing ... Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office)'' MAR � 444 -3433 (cell) From: Herrmann, Daniel D [mailto:JD.Herrmann @conocophillips.com] Sent: Friday, March 04, 2011 4:05 PM To: Schwartz, Guy L (DOA) Subject: 2T -05, 2T -11, 2T -16 Rigless P&A Procedure Guy, We are looking at P &Aing these wells rigless, but before I wrote the procedures for these 3 wells I wanted to check to make sure the State would be ok with it. We are unable to drift to the top of the packer with our slimhole perforating guns, but we are able to get down close to the packer on each of these wells with varying distances from the packer. Our plan would be to perforate and circulate cement down the tubing taking returns up the IA from our perforations to surface. I have attached the wellbore schematics and here are the depths we can drift down to and there distances from the top of the packer. 2T -05: Drift Depth - 6964' SLM Distance from drift to top of packer -172' SLM 2T -11: Drift Depth - 5350' SLM Distance from drift to top of packer - 375' SLM 2T -16: Drift Depth - 7410' SLM Distance from drift to top of packer - 636' SLM Please let me know what questions and concerns you have. 3/9/2011 Page 2 of 2 • Cheers, Dan Herrmann Wells Engineer 1 ConocoPhillips Alaska Inc. ATO 1586 Office: (907)263 -4619 Cell: (713)703 -5282 jd.herrmann @conocophillips.com 3/9/2011 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Plugged ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other ^ No. of Completions: 1b. Development ^ Q~(+O~iratory ^ Service ~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 10, 2009 12. Permit to Drill Number: 186-046 / 309-338 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 11, 1986 13. API Number: 50-103-20063-00 4a. Location of Well (Governmental Section): Surface: 2' FSL, 556' FVVL, Sec. 1, T11N, R8E, UM 7. Date TD Reached: April 7, 1986 14. Well Name and Number: 2T-16 Top of Productive Horizon: 1236' FSL, 1514' FWL, Sec. 11, T11 N, R8E, UM 8. KB (ft above MSL): 41' RKB GL (ft above MSL): 82' AMSL 15. FieldlPool(s): Kuparuk River Field Total Depth: 1160' FSL, 1389' FWL, Sec. 11, T11 N, R8E, UM 9. Plug Back Depth (MD + TVD): 8723' MD / 5979' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498945 y- 5969983 Zone- 4 10. Total Depth (MD + TVD): 8947' MD 16149' TVD 16. Property Designation: ADL 25569 TPI: x- 494625 y- 5965938 Zone- 4 Total Depth: x- 494500 - 5965863 Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 1804' MD / 1598' TVD 17. Land Use Permit: 2667 18. Directional Survey: Yes ^ No O (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDfTVD: approx. 1550' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drilllLateral Top Window MD/11/D not applicable 23, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 225 sx CS II 9-5/8" 36# J-55 Surf. 3811' Surf. 2768' 12.25" 1215 sx AS III, 380 sx Class G 7" 26# J-55 Surf. 8418' Surt. 5749' 8.5" 300 sx Class G, 175 sx AS I 5" 18# L-80 8183' 8947' 5587' 6151' 6.125" 120 sx Class G 24. Open to production or injection? Yes ^ No ^ If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2.875" x 2.375" 8123' / 8569' 8046' MD l 5494' TVD & 8551' MD / 5851' ND 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 8569' 18 bbls 15.8 ppg Class G 27, PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 26. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes ^ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE STATE OF ALASKA ,", ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ 100g WELL COMPLETION OR RECOMPLETION REPOR A G Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations and ma'7=,...§ encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes 0 No If yes, list intervals and formations tested, Permafrost -Top ground Surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1550' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 8497' 5808' Base Kuparuk C 8547' 5846' Top Kuparuk A 8566' 5861' Base Kuparuk A 8688' 5953' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Nam ~ J. Ennis Title: Wells Engineer ry o~ L ~~ Signature Phone 265-1544 Date snaron ausup-uraKe INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 7!2009 ,,_,r STATE OF ALASKA `"'~ ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 ~ 20Q9 REPORT OF SUNDRY WELL OPERATIONka0i1&GasColns.Commission ~. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ~ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter uspended Well 2. Operator Name: 4. Well Class Before Work: .Permit to ill Number: InC. COnOCOPhIIIIpS Alaska Development ^ Exploratory ^ 186-046 ! , 3. Address: Stratigraphic ^ Service ~ . AP umber: P. O. Box 100360, Anchora e, Alaska 99510 -103-20063-00 . KB Elevation (ft): .Well Name and Nu RKB 117' 2T-16 Property Designation: .Field/Pool(s . ADL 25569 Kuparuk River Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured \ `8947' feet ~ O true vertical 6149' feet lu s (measured) 8569' Effective Depth measured 8723' feet Junk (measured) true vertical 5979' feet ^~ Casing Length Size MD ~.Qi~ YY TVD Burst Collapse Structural ~ CONDUCTOR 110' 16" 110' O 110' SURFACE 3694' "" ~~ 9-5/8" 3 1'V~ 2768' _ _ ~ ~ - PRODUCTION 8301' 7" 4 ~ 5749' LINER 764' 5" 8Z3~7' 6151' `~ - Perforation depth: Measured depth: 8498'-8542', 85 '-587', 8597'-8624' ~i ~2, n ' I~~~ NQ J ~ ~ 20D~ ' ' ' ' true vertical depth: -5906 , 5886 , 5 -5878 -5844 5810 Tubing (size, grade, and measured depth) 2,g7 x x.`375", J-55, 8123' , 8569' MD. , r Packers &SSSV (type & measured depth) (/B ow (H -1' pkr, Baker'DB' pkr @ 8046', 8551' co RDP-tA-SSA SSSV @ 1804' 12. Stimulation or cement squeeze su a Intervals treated (measured) cement plug @ 8569' pump 18 bbls of 15.8 ppg Class G cement Treatment descriptions inclu ng volumes used and final pressure: 13. Representative Daily Average Prod uction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments .Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X .Well Status after work: Oil^ Gas^ WAG GINJ^ WINJ ^ WDSPL^ 17. I her by certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if c.o. Exempt: 309-338 con ct Jim Ennis @ 265-1544 Pri ted Name ~ Title 265-1544 Ph Wells Engineer Date /~ ~ a' Q Signature one: Pre ared Sharo Allsu -Drak 263-4612 Form 10-404 Re ised 04/2006 ~ `~ Submit Original Only . 2T-16 Well Events Summary ~ATE ` SUMMARY 10/10/09 Bullheaded 18 bbl of 15.8 cement down the tubing. Displaced with "nerf' plug• followed by 5 bbl of freshwater and 41 bbl diesel. TOC ~ 7950 ft(TTL @ 8569). 10/12/09 Post cement plug MIT passed. Tested down the tubing to the TOC @~7950' (TTL 8569') to 2500 psi. Ready for AOGCC witnessed test. 10/14/09 BLEED T TO 0 PSI, TUBING DD TEST - PASSED 10/16/09 BLEED IA / OA TO 0 PSI 10/17/09 BLEED IA & OA TO 0 PSI. tcmecoPhillips .'_inRd I~x:. snFeTV v~v, 1.804 GAS LIFT, __ 3A93 SURFACE, 3,811 GAS LIFT. 5,525 GAS LIFf. _ 6.433 cns uFr. GAS LIFT, 7.287 GAS LIFT, ].]00 6fSLIFT. __ 7,986 PBR, 8,029 - ~ACKER.8,046 - INJECTION. 8,083 NIPPLE. 8,121 SLEEVE, 8,121 ~ 'ACKER.8,551 NIPPLE, 8,S6C - SOS, 8,568 TTL,8,569 IPERF. 0,59]-8,626 ~ CEMENT PLUG,l,550 LMER, 8,5d7 TD (PT~i6), ~ 8.907 ~ KUP ~ 2T-16 ~ Well Attribu WellboreAPVUWI tes IFielANama ~ IWellStatus ' Max Mgle 8 MD Incl(°) MD(RKB) i TD I ~,AclBtrn(flKB) 501032006300 ~KUPARUKRIVERUNIT ~INJ I I 56.87 2,00000 8.9470 J IComment ~H2S(ppm) ~'~Data ''~Mnotation''~.EntlDate KB-Grd(k) 'I ~RigReleaseDale -~-1SSSV~ TRDP ~ ~ ~ i ~ 47 90 4 10/1986 . I ~ IA notation Dept~ (flKB) Entl D t Anno[ t n Last Mod By End Date ~ ,LasiTag:SLM ~ I S.1Ut,U 4;2 ~f~H KevN ison~ CEMtNI PWG : _ -_._ Imosbor _ .... ..... . .. . 10~1L2009 ___ .__. __ __. IC.'1SIf1(] S~fIf1 __.._ _ _- --._ 0S ~~ Siring OD String ID Sat Depth Set Depth (ND) String Wt String CasingDescription ~ (~~) (~n) Top(flKB) (ftKB) (ftNB) (Ibs/(t) Grade StringTopThrd CONDUCTOR 16I 15.062 I 0.0 110.0 110.0 62.50 H-00 95/8 8.765 0.0 3,811A 2,767.9 36.00 J-55 SURFACE _ 7 6.151 0 0 8,418.0 5.749.4 26.00 J-55 PNODUCTION I 18.00 L-80 SI 4.157 8,153.0 89470 6.150.8 . .. .. .. . .. . ......._._ Tubing Strings I String OD ~ String ID Set Depih Set Depth (ND~ Shing W~ String TubingDescription ~ (in) (in) Top(NKB) (ftKB) (ftKB) (Ibs/ft) Grade StringTopThN TUBWG ~ 2 718 2441 0.0 8,123A 5,546.3 6.SO lSS EUEBrdABMOD TUBING ~ 2 3/8 1.995 8,123.0 8,569A 5,8642 4J0 JSS EUE8rdABMOD Other In Hole All Jewel : Tubin Run 8 Retrievable, Fish, etc. Top Dep~h- I (TVD) 'Toplncl ~' ~. Top(ftK8) ~flK6~ (°) Dascnption i Commant RunDate ID(in) 1,804 1 598 4~ 56J3 SAFETY VLV ICamco TRDP-IA-SSA (NOT LOCKED OUT, NO SURFACE 9/7811986 2.313 CONTROLS) 3,493 2,569.4I 51.921 I GAS LIFT ICAMCO/KBMG/1/DMY/BK/// Comment STA 1 9l18/1986 2.347 - __ 1 CAMCO/KBMG/1/DMY/BW//Comment: STA2 9/18/1986 j 2.347 6,433 I 4.434.1 47.97 8 9 GAS UFT ICAMCO/KBMG/1/DMV/BK!// Comment STA 3 9l18J7986 2.347 __ _ 6,907 4, 45.4 49. 9 GASLIFT CAMCOIKBMGl1/DMY/BW//Comment STA4 9/1811986 2.347 7,287 4 9932 49J4 GAS LIFT CAMCO/KBMG/1/DMY/8W/! Comment STA S 9118/1986 2.347 7,700 5,263.8 48.53 GASLIFT CAMCO/KBMG/1lDMY/BK///Comment STA6 9/18/1986 2.347 7,986 5,453J 47.99 GAS LIFT MCMURRY HUGHES/2 7/8 X 1 12/tS/DMY/RK/// 10/26/1986 2347 Comment: STA 7 8,029 5,482.6 47.50 PBR Brown 911811986 2.500 8,046 5,494.1 47.42 PACKER Brown'HB-1' PACKER 9118/1986 2.750 8,083 5,519.0 4726 INJECTION CAMCO/KBMG/1/DMYBW// Comment: CLOSED STA 8 911811986 2.347 8,121 5,544.9 47.09 NIPPLE AVA BPL PORTED NIPPLE 9l18/1986 2.312 (Special Size AVA; takes 2.312" BPI or BPC, very snug thru SSSV) 8,121 5,544.9 47.09 SLEEVE AVA BPC S~EEVE 6!9/01 6/92001 1.870 $551 S,SW.S 40.52i PACKER Baker'DB'PACKER 9I78/1986 3250 8,564 5.860.4 40.52 NIPPLE Camco'D' Nipple NO GO 9/18/7986 1.812 I 40.52 SOS Brown I 9118/1986 1_995 8,569 5,8642 . ~ 40.52 TTL _ I ._ 1ELMD TTL @ 8573' during SPIN SURVEY on 0425/90 9I78//986 1.995 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg i~ ~ i21i4j~~ DATE: November 05, 2009 P. I. Supervisor j~ I I FROM: Lou Grimaldi SUBJECT: Wellbore Plug Petroleum Inspector ConocoPhillips Alaska Inc. KRU 2T-16 ~% Kuparuk River Field/Unit PTD #186-046 Tuesday. November 03, 2009; I witnessed the pressure test of a wellbore plug placed to isolate the wellbore from formation on ConocoPhillips Kuparuk River Unit well # 2T-16. The plugs had reportedly been down squeezed from surface prior to my L~ arrival. The tubing was pressured up with diesel to 2720 psi. The following pressures were observed during the test; Pretest Initial 15 min. 30 min. IA 90 90 90 90 OA 40 40 40 40 Tubing 225 2720 ~~ 2660 2650 The test pressure was bled to zero at the conclusion of this test with approximately the same amount returned as was pumped (.5 Bbl's). The plug has apparent integrity although the negative test should help to confirm this. Ian Ives (KRU DHD) was very helpful with information and background on this well. Ian has a good attitude and seems intent on understanding the differences of our requirements between types of test's, why they are p~'Pfof~med and the importance of reliable results. Attachments: None ~~N~®~ E ~ ~ ~ ZOq~ Non-Confidential Wellbore Plug KRU 2T-16 11-03-09 LG.doc 1 of 1 • • ,-'=-`~ @ ~~ ~ " t t+~k,,-pg~„~ ~fl, ~@+-. ,~ t~~A k~~ " p i3 4¢ ~ ~~~ ~ ~ ~ ~ `~ s ~. ` §. d ~~e. q ~ ' :: ~ ~y ..,. ~. ~xd ~~~ a a~~~f~. & ry ~ F ~ tg' ,~~,` L~J d s & b ~ g V'. _ t e ~ ~,~. ~ ~ ~ r+ ~ ~ ~~ . 5 ~ H ~ x°' ~~ ~ 3 " t ~ t ~ ~ ERNOR ~ , ~ .. ' t ~ ~' ¢~ k ~ ~~ ~ ~ ~ ~ ~ ~ ~ a a ~ ~ k ' 1 ~ 4 ~ p p $ ¢ ~ SEAN PARNELL, GO `a - ~ ~ k 1L . y S-.~ ~ G C ~ t;_t t...,: •~ 6 ,r:. ~ 4t«a~ s,~ .. e,.~ri b & :~ Y ~ y~ g ~ ~ ~ .~:s'~ Y ~..5 P. ~~_ & ! ~aa~ c',u' ~~ °+~..4 `L . , @ P b~. i t ~t~, ,a c-c:, - 4 . ~-7~A ~iL tusJV V[n~,7 333 W. 7thAVENUE, SUITE 100 COI~SERQATI01~ COMi-IISSIOl~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ~ ~J~ O `~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-16 Sundry Number: 309-338 :~'~:~~~~~~~ !'~'J`,l ~ ::,~ 2~u~ Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may no* appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ ~ ,~- Cathy . Foerster Commissioner ' ~~~~ er 2009 DATED this _ day of Septemb , Encl. • . STATE OF ALASKA ~ ~ ~~~ ~~~ D~ ALASKA OIL AND GAS CONSERVATION COMMISSION '" ~ APPLICATION FOR SUNDRY APPROVAL - 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ~ Other ~ Alter casing ^ Repair well ^ Plug Perforations ^~ ~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhiliips Alaska, Inc. Development ^ Exploratory ^ 186-046 ~ 3. Address: Stratigraphic ~ Service Q. 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20063-00 ~ 7. If perForating, closest approach in pool(s) opened by this operation to nearest property line 8. Weil Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ~ 2T-16 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pooi(s): ADL 25569 • RKB 117' • Kuparuk River Field / Kuparuk River Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Piugs (measured): Junk (measured): 8947' ' 6149' ' 8723' S979' Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 3694' 9-5/8" 3811' 2768' PRODUCTION 8301' 7" 8418' 5749' LINER 764' 5" gg47' 6151' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8498'-8542', 8582'-8587', 8597'-8624' S810'-5844', 5874'-5878', 5886'-5906' 2.875~~ x 2.375~~ J-55 8123' , 8569' Packers and SSSV Type: Packers and SSSV MD (ft) Brown 'HB-1' pkr, Baker'DB' pkr @ 8046', 8551' Camco TRDP-IA-SSA SSSV @ 1804' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~• 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat September 28, 2009 Oil ^ Gas ^ Plugged ^~ ' Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Na Jlm Ennls Title: Wells Engineer Signature Phone 265-1544 Date \ 1 ~ 1 ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~~'/ - 33 Plug Integrity ~BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Cd~'L T~N ,s'~+S~Da~~Oi'' ~ w' ~~SS P/'GSS~-c. ~d~, Subsequent Form Required: /v , rJQc.J `'~~~,`~~~~ ~~&, ; ~ ! l ,: iu;QG APPROVED BY ~ Approved by: MMISSIONER THE COMMISSION _ Date: Form 10-403 Rev~ed 06/2006 ~ ~ ~ ~ ~ 1 ~~ ~~ ~ .C ~o ( ~ ~Q~1~ Q Submit in Duplicate t•~1• f ~ ~~ ~~, ~.~ ~"D ~, z~~ ~~ ~ •Well 2T-16 Kuparuk Injector • Pump cement plug for well control barrier Nefinrork 10258898 Well History: 2T-16 was originally completed as a single selective Kuparuk water injector in 1986. In April 1996, the well's service was changed to a WAG injector and it injected gas through June 2007. While on water injection, it failed an MITOA in March 2009 and was subsequently SI. Subsequent diagnostics indicate ~ corkscrewed tubing will not allow drift access beyond 2300' SLM. The corkscrewed tubing is believed to be the result of well subsidence. The procedure outlined below will plug the Kuparuk reservoir w/ cement until a workover to restore injection or P&A can occur. TOC for the plug is targeted for 7950' MD. Work accomplished to date: 6/1/09 4 Year State Witnessed MITIA - Passed, (AOGCC - Jeff Jones). Initial T/I/0=(si) 1050/250/100. Pressured up IA to 1690 psi with 2.4 bbls of diesel. T/I/0=1060/1690/100, 15 min T/I/0=1060/1600/100, 30 min T/I/0=1060/1580/100. Bled IA down. Final T/I/0=1060/250/100. 5/20/09 MITIA - passed; Initial T/I/0= 1060/250/110; Initial IA FL @ 108ft. Rigged up LRS to IA and pressured up to 2000psi. with 6.4bbls. of diesel. Start T/I/0= 1060/2000/110; 15min. reading T/I/0= 1060/1870/110; 30min. reading T/I/0= 1060/1850/110; Bled IA to 300psi.10min. fluid; Final T/I/0= 1060/300/110 5/14/09 IA FL @ 180' (600 fps) T/I/0= 1050(si)/250/100 4/25/09 USED 1-1/4" SLINKY TOOL STRING. DRIFTED TBG TO 2300' WITH 5' x 1-3/4" BAILER. DRIFTED TO 8100' WITH 1-3/4" SAMPLE BAILER. PICKUP WEIGHT 1700 LBS AND VERY ERRATIC. COMPLETE. 4/1/09 T-PO (PASSED), T-PPPOT (PASSED), IC-POT (PASSED), IC-PPPOT (PASSED) 3/31/09 MIT-IA ( passed ), IC-POT ( passed ), IC-PPPOT ( inconclusive ).T/I/0= 1260/360/120. Stung into IC-PO with 200 psi, bled to 0 psi with 0 psi buildup during MIT-IA. Attempted to pressure up IC-PO @ 2000 psi ring gasket leaked @ 7:00, bled IC-PO. Pressured up IA with 7.8 bbls diesel T/I/0= 1260/2500/125. 15 min T/I/0= 1260/2400/120. 30 min T/I/0= 1260/2400/120. Bled IA, T/I/0= 1260/350/120. Will need to return and tighten IC-Flange, and test PO. 3/28/09 SCLD; Initial T/1/0= 1240/310/20; Rigged up bleed hose to OA and began charging with lift gas; shot OA FL @ 318ft. (600fps) Waited 15min. shot second FL @ same location; Waited 30min. shot third FL @ same location Final T/I/0= 1240/310/120 3/23/09 MITOA - failed, Initial T/I/0= 1575/300/130. Established a LLR of .2 bpm @ 400 psi. for a total of 20 bbls pumped. Final T/I/0= 1575/300/130 Remaining work: 1: RU SLB cementer. Bullhead 60 bbls fresh water down tbg at max rate below 2500 psi followed by 85 sx Class `G' cement w/ additives. Launch "nerf" cmt plug and displace w/ 5 bbls fresh (? s bws wa er,~2 b~ls 9.6 ppg brine and 12 bbls diesel. SI and record SITP. WOC 24 hours. PT cr~t - ~ plug to 2500 psi. Bleed tbg & IA pressure to zero. 7"~ ~.•! 7 gSo ~~ `I G da~ Y"` Jim Ennis Page 1 9/17/2009 ~- ~ ii ConocoPhillips ( ;' v=zsn~. ~f ~: .. _ T-_'K.~1~_~_^3_:~BQrz42oa5a-,i,ur~.~+n-_. ._. " _.". _" _ _ _ _ - - SdremBtl~ ~ Aetual CONOUCTOR, 110 1 SAFET'VLV, ..__ ~.eoa _ GASLIFf._ . . ..~ 3,493 SURFACE, __.__ 3.811 GAS LIFf. _ . ~ j~ 5.525 ~ GAS LIFT, `~ sp33 ~ GASLIFf, fi~ ~ s,eo~ ,_ ~ 7,700 KUP 2T-16 UNI I ,on: add ~f I L co Set Depth g) (ftK6) 0.0 110 0.0 3,811 0.0 8,418 3.0 8,947 ~ ~ Sat Dep~h g~ (HKB) 0.0 8,123 TRDP-IA-SSA S~a~us STA 2 STA 7 GAS LIFf, _ 7.700 C~AS LIFf, _ ].9% PBR. 8,029 PAqCER, B,OG6 IWECTbN,_ B,Odl NIPP~E.fl.12t .. SLEEVE.8121 -~--- I PRODUCTION 8,018 IPERF, _ ~ 8,69&8,562 C PACKER,A,551 , C NIPPLE, B,S6C ~ -- SOS, 8,568 - --- ~ ~ - - - ~ TiL,8,5fi9- - IPERF,_ ~ 6.582-6.587 IPERF,__ ~ 8,597-8.62a LINER, 8,9d]--. m~2r-as7. _- 8.917 8.121 5, 8.121I 5. 3f8" HJ II 2.347 2.347 2.34i Blm Dans is NOT locked out and is operational, just has no suAaca ~EFORMED, DRIFT wISLINKY 1.75 SAMPLE BAILER Size AVA; takes 2.31 Y BPI or BPC, very snug thru tBtrn(HKB) A,947.0 ~ Release Date 4/10/1986 i oa:e 5/20/2009 nno Too Thrd Thrd 1 1 ~~ age .- ~ ~ 7 ks in adva om Maunder, PE AOGCC ~..c~,a ` ~ ~ ~G.~C~ ~ e-r~ G:~~~ o~ SCv ec-~..\ ~-.) ~ ~.~ Z~- ~ ~ ~ ~ ~-- ~c ' ~ ~ c~ ~J`~~~ . i~'~ G~C r~~~ -T'^~ c`'F `~bS~ cl~_~'c P ~y ~S sJ ~5 -~ ~c~.~ ~c~.~ c~,S~ c~-c s~cJ ~c-~..~ Wc~ `~~. ~S ~o ~.~ -~. c~,~ ~~~ ~ ~~c.~~.~~- ~~- `f S ~ p~~~~~~\ y-~, ~~, ~-~~~.~.~-~~ ~., ~~.~~ So~ ~.~~ ~~~~5 ~ ~~,~~~ ~~ S 'llJ~~~ ~l~Cl ` \ S ~S ~r ~J ~~ ~~ ~ ~ a ~ ~v~ ~~.~5 ~_SE ~, c~ O ~ ~ ~~~C~SC `~t`~C~ C~ce~ Q -~j c~t--~,t~ ~ c~- ~--~ w~ ~ ~ ~ s ~~s.~ ,, ~~ ~ ~ v ~ ~ ~ ~~-'~ ~ ~ a~c~- ~ ~' ~~` ~ c~ h~~ ~ P ~5 ~~`~ ~ ~ v.S~~ `~ a t~ vJfl~ ~ ~ ~' ~ S~- ~ , . ~ 1r~C ~ `D ~ 0 ~~ ~ ~ e S 5~ a~ 9/200 MEMORANDUM To: Jim Regg ~~ ~ j~~ /~ P.I. Supervisor I ! FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-16 KUPARUK RIV UNIT 2T-16 Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv..~ Comm Well Name: KUPARUK RIV UNIT 2T-t 6 API Well Number: 50-103-20063-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608124413 Permit Number: 186-046-0 ~ Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2T-16 5494 jA T 250 Well Type Inj. N TVD ~~ P.T.D 1860460 TypeTest SPT Test psi lsoo :~ pA loo 1690 too 1600 100 1580 100 Interval 4YRTST p~, P ~ Tubing ~ 1050 ]060 1060 1060 - Notes' 2.4 BBLS diesel pumped, 1 well inspected; no exceptions noted. .. . , : 4.. e..' Wednesday, June 10, 2009 Page 1 of 1 RE: KRU DS2T Suspected Surfac~Casing Leaks • Page 1 of 3 Regg, James 6 (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, April 20, 2009 2:48 PM ~~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: RE: KRU DS2T Suspected Surface Casing Leaks Follow Up Flag: Follow up ~~ti z'r- C4 ~~ ~ ~ _ X43 Flag Status: Green ~~ 2T_ ~9 ~~ ~ ~ - ~ I ~ Attachments: 2T-11.pdf l~~-~,t z7- -- i e~ ~'~~ ~~ ~g~ kR<,,l Zi - 11 ~ i~_ o~~ Jim, ~~ -~ t~ Y~,1 z~- - I ~ f"~D On 4/19/09 CPAI shut in wells 2T-04, 2T-09, and 2T-15. Additional diagnostics indicate tubing obstructions exist in these wells preventing mechanical secure. On 4/18/09 CPAI shut in well 2T-11. The path forward for 2T-11 will to harvest a SBHP then attempt to secure with a plug in the AVA sleeve at 5801' md. All of the above wells will remain shut in until they can be repaired. We will not be submitting a request for Administrative Approval to continue, water only injection for these wells. These wells will be shut in long term. Do they need to be carried on the monthly failed injector report? 2T-10 remains online in water only service. We completed a drift, tag, and caliper of the tubing and intend to pursue and AA for continued water injection. 2T-16 remains online in water only service and is scheduled for a drift and tag with subsequent caliper to follow. If our plans change with regard to 2T-16 I'll inform you immediately. Let me know if you have any questions. „' ~~~~~' ~~I~ ~ `' r'fj~~ ,'~:;. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Voice Pager 659-7000 x937 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 03, 2009 3:47 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly 2/23/2010 RE: KRU DS2T Suspected Surfac~Casing Leaks • Page 2 of 3 A; Jackson, Darron B.; Ennis, J ) Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/3112009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications for administrative approval to continue water only injection with a known surface casing leak (OAxForm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom.maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU D52T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. 2/23/2010 RE: KRU DS2T Suspected Surfa~Casing Leaks • Page 3 of 3 Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf» « File: 2T-04 TIO Plot.pdf» « File: 2T-09 TIO Plot.pdf» « File: 2T-10 TIO Plot.pdf» « File: 2T-11 TIO Plot.pdf» « File: 2T-15 TIO Plot.pdf» « File: 2T-16 TIO Plot .pdf» « File: 2T-02 Wellbore Schematic.pdf» « File: 2T-04 Wellbore Schematic.pdf» « File: 2T-09 Wellbore Schematic.pdf» « File: 2T-10 Wellbore Schematic.pdf» « File: 2T-11 Wellbore Schematic.pdf» « File: 2T-15 Wellbore Schematic.pdf» « File: 2T-16 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 2/23/2010 ec-naaPhillps Alaska, Inc. KRU 2T-1 -- - 2T-11 _ API: 501032006500 Well T e: INJ An le TS: 40 de 6330 SSSV Type: TRDP Orig 6/6/1986 Angle @ TD: 40 deg @ 6789 Com letion: sssv Annular Fluid: Last W/O: Rev Reason: PULL BPC Set (1777-1778, oD:3.5o0) _ '-_ , BPI TAG FILL i ~ Reference Lo Ref Lo Date: Last U date: 1/29/2007 Last Ta : 6463' TD: 6789 ftKB Last Ta Date: 1/28/2007 Max Hole An le: 42 de 5400 Casin Strin -ALL STRINGS __ __ ___ _ Descri lion Slze To Bottom TVD Wt Grade Thread Gas Lift d l/D ~ CONDUCTOR 16.000 0 110 110 62.50 H-40 re an ummy valve 1 ~ SUR. CASING 9.625 0 2973 2973 36.00 J-55 (5665-5666, PROD. CASING 7.000 0 6170 5665 26.00 J-55 oD:SSao) LINER 5.000 5976 6789 6789 18.00 L-80 Tubin Strin -TUBING ___ __ ~ Size To Bottom ___ TVD _ Wt Grade Thread 3.500 0 5804 5382 9.30 J-55 EUE 8RD AB-MOD PBR 2.375 5804 6394 5838 4.70 N-80 EUE 8RD AB-MOD (57115712, OD:3.500) 2.875 6394 6396 5839 6.50 Perforations Sum_ma_ry ____ Interval TVD Zone Status Ft SP F Date T e Comment 6331 - 6352 5789 - 5805 C-4 21 12 10/11/1984 IPERF 120 de Ph• 3 3/8" H erJet 6429 - 6435 5864 - 5869 A-4 6 1 10/11/1984 IPERF 180 de Ph• 3 3/8" H erJet 6446 - 6484 5877 - 5906 A-3 - _. 38 . -- 4 .10/11/1984 IPERF - - 90 deg Ph; 3 3/8" H erJet PZS Gas Lift Mandrels/Valve s ' (5725-5 OD:6.151) _ _ _ _ _ _ _ _ --- - ---- ---- St TMD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 5665 5274 Otis LBX DMY 1.5 RO-5 0.000 0 _ 6/17/1987 j In'ection Mandrels/Valves St I MD 'i TVD ,Man Mfr ! Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv ~ Cmnt Injection ,. _ _ 2 5763 5350 Camco ~~, KBUG DMY 1 1.0 BK ! 0.000 ~0 10/12/198 3ndrel/Dummy V l 2 ~. ~ ' Oiher - ~ __ _ lu S e ui etc. - GOMPLETION ~ -~_ i -~~a- - _- -- -- -- a ve (5763-5764 . - De th ~ TVD T e Descri lion ID , oD:5.313) 1777 1777 SSSV Camco TRDP-IA-SSA Control Line Defeated' Not Locked Out 2.812 5711 5310 PBR Baker 3.000 5725 5320 PKR Baker'FHL' 3.000 5801 5379 NIP AVA BPL PORTED NIPPLE 2.750 ~ SLEEVE-0 5801 5379 SLEEVE-O AVA BPI SLEEVE set 1/28/2007 2.310 (5801-5802, 6373 5822 PKR Baker'DB' w/ 5' SBE 3.250 OD:2.750) 6387 5832 NIP Camco 'D' Ni le NO GO 1.812 6395 5838 SOS Camco 2.441 6396 5839 TTL 2.441 part ( -- General Notes (6331352) _..__. "".__" Date NOte ~ 1/27/2007 NOTE: CORKSCREWED TUBING FROM 294' SLM TO TBG BOTTOM? PKR (6373E374, OD:4.151) NIP (6387-6388, OD:2.375) TUBING (6394-6396, OD:2.875, ID:2.441) - i SOS (6395-6396, OD:2.875) i Perf -...".._... --- (6429E435) Pert (6446-6484) _"- RE: KRU DS2T Suspected Surf Casing Leaks • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, April 03, 2009 3:47 PM~~,(~ /~-I3I(T~ To: 'NSK Problem Well Supv' , \ ``' Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPAI mad continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly infector inte rity report. Jim Regg AOGCC ~ xf, ~: 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications fo_r administrative a proval to continue water only injection with a known surface casing leak (OAx orm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU D52T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of 4/3/2009 RE: KRU DS2T Suspected Surf: Casing Leaks • Page 2 of 2 the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf » « File: 2T-04 TIO Plot.pdf » « File: 2T-09 TIO Plot.pdf» « File: 2T-10 TIO Plot.pdf » « File: 2T-11 TIO Plot.pdf » « File: 2T-15 TIO Plot.pdf » « File: 2T-16 TIO Plot .pdf » « File: 2T-02 Wellbore Schematic.pdf » « File: 2T-04 Wellbore Schematic.pdf » « Fiie: 2T-09 Wellbore Schematic.pdf » « File: 2T-10 Wellbore Schematic.pdf » « File: 2T-11 Wellbore Schematic.pdf » « File: 2T-15 Wellbore Schematic.pdf » « File: 2T-16 Wellbore Schematic.pdf » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/3/2009 Well Name 2T-16 Notes: End Date 4;112009 Days 90 Start Date 1 /1 /2009 wHP Annular Communicaton Surveillance IAP 140 3000 QAP WHT 2500 - __ 120 100 2000 80 LL 1500 Q - - - - - d ' . ~ 60 1000 -- - 40 500 - - -- - - -- - -- - 20 0 0 Jan-09 Feb-09 Mar-09 Apr-09 5000 DGI '~-__...._ ..-------- -- -- ---.. - __-- - - - - 4500 MGI 4000 ~ PWI 0 3500 ~SWI m 3000 ~BLPD 2500 0 2000 U ~ 1500 1000 500 0 t KRU 2T-16 ConocoPhillips Alaska, Inc. 2T-16 __ __ _ API: 501032006 300 Well T e: INJ An le TS '41 deg @ 8498 9 @ SSSV Type: TRDP _ _ Orig 4/10/1986 _ _ _ Angle @ TD: 41 deg @ 8947 sssv Com letion_ (lsoa-1aos, Annular Fluid: Last W/O: Rev Reason: Revise Ni le ID Reference Log:: _ _ R_ of Lo Date: _ _ Last U date: 10/28/2005 Last Tag. 8723 ~ TD: 8947 ftK6 Last Tag Date: 6/26/1998 Max Hole An le: 57 de 2000 Casing String -ALL STRINGS -- _ _ Description -- --- Size __ Top Bottom TVD Wt Grade Thread CONDUCTOR _ _ -- - - _ - ' 16.000 0 110 _ .- 110 62.50 H-40 SUR. CASING __ PROD. CASING 9 625_ 0 3811 7 000 0 8418 - - --- --- 2769_ 36.00 J-55 5751 26.00 J-55 _ __ - LINER 5.000 8183 8947 - _ 8947 18.00 L-80 Tubing String -TUBING - _ - - -- - i Size _ Top - j: Bottom TVD _ _ _ Wt _ -- _Grade Thread ~ 2.875 _ 0 T __ 8123 _ 5546 6.50 ~ J-55 EUE 8RD AB-MOD 2.375 _ 8123 ~ 8569__ 5864_ 4.70 _ J-55 EUE 8RD AB-MOD _ Pertorations Summary Interval r TVD Zone Status Ft SPF Date Type Comment - _8498 - 8542 5810 - 584 4 C-4 44 12 9/19/1 -- --- 986 IPERF 3 3/8 HJ II _ _ _ 5874 - 5878 A-4 5 4 9/19/1 8582 - 8587 I - -- - _ 986 I IPERF 3 3/8' HJ II --- - ' --- 8597 - 8624 5885 - 5906 A-3 27 4 9/17/1 ---- --- - 986 ; IPERF__; 3 3/8" HJ II _ Gas Lift MandrelsNalves St MD TVD Man ~ Man Type V Mfr ~ V Type V OD _ Latch j Port TRO Date Viv Mfr _ __ _ Run Cmr 3493 2569 i Camco I KBMG DMY 1.0 BK ~ 0.000 0 9/18/1986 ~_2 5525 3832 Camco, _ KBMG _ ~ DMY __ 1.0 BK 0.000 0 9/18/1986 3 6433 44341 Camco KBMG DMY 1.0 _ BK 0.000 0 9/18/1986 _ 4 6907 4745 Camco - KBMG ! DMY 1.0 BK 0.000 0 9/18/1986 5 7287 4993 Camco KBMG DMY 1.0 - - 0 9/18/1986 BK 0.000 6_i 7700 5264 Camco KBMG DMY 1.0 _ _ BK 0.000 0 9/18/1986 7 7986 5454 McMurry _ 2 7/8 X 1 DMY 1.5 _ _ RK 0.000 0 10/26/1986 ~ Hughes ~ 112_- _ - - In'ec~ion Mandrels_/Valv - es _ St MD ND Man Man Type ', V Mfr V Type V OD ~ ~ _ Latch Port TRO Date Vlv ~ Mfr i, Run _Cmr 8 8083 5519- Camco KBMG ~ DMY 1.0 BK 0.000 0 9/18/1986 Close PBR Other (plugs, equipetc .) -JEWELRY (8029-8030, OD:2.875) - D_ epth ND ! Type ~ - - - - - _ Description _ ID 1804 1597 SSSV Camco TRDP-IA-SSA _ 2 31; 8029 5483_ {' PBR ~ Brown _ _ 2.50( PKR _ _ 8046 5494 1 PKR Brown'HB-1' _ _2.75( (aoas-BOa7. 8121 5545 ' NIP AVA BPL PORTED NIPPLE I 2.31 oDa.151) (Special Size AVA; takes 2.312" BPI or BPC, very snug thru SSSV) 8121 5545 _ _ SLEEVE 8551 } 5850 PKR ~ AVA BPC SLEEVE 6/9/01 Baker'DB' I _ 1.87( + 3.25( I 8.564 5860 NIP - Camco 'D' Nipple NO GO __ 1.81 _ ---- 8568 15863 SOS Brown 1.99E ~ 8569 5864 TTL 1.99E General Notes s~EEVE Date Note (x121-x122. ~ i 16/26/1998' SSSV is NOT locked out and is operational, just has no surface controls. Perf (8498-8542) PKR ---- ''. (8551-8552 OD:4.151) NIP I (8564-8565. OD:2.375) TUBING ~ ill (8123-8569, 'I OD:2.375, ID:1.995) Perf (8582-8587) Perf (8597-8624) MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 0/) / .( I f'...,({ (, 7 ù ì DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-16 KUPARUK RIV UNIT 2T-16 ~ \~\( 0 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed ~ P.I. Suprv..] &-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-16 API Well Number: 50-103-20063-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603144320 Permit Number: 186-046-0 Inspection Date: 6/2/2007 .....-" Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-16 Type Inj. G TVD I 5494 I IA ! 1060 2510 [ 2460 2460 i P.T.D 1860460 TypeTest SPT Test psi I 1500 lOA 110 110 I 110 110 I ,/ Tubing I I Interval 4YRTST P/F P 2150 2150 i 2150 2150 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ,/' ~JUN·212007 Wednesday, June 06, 2007 Page I of I ) MEMORANDUM State of Alaska TO: Jim Regg c ( zJ P.I. Supervisor :Jl2af~[ i ('00>.5' DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-16 KUPARUK RIV UNIT 2T-16 ~ \qj(J Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvJ312- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIY UNIT 2T-16 Insp Num: mitCS050812190nO Rei Insp Num: API Well Number: 50-103-20063-00-00 Permit Number: 186-046-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Welí-!---2T-::ï6-- ¡Type Inj. ! W 1 TVD I 5494 .~~ ,!~_j 1_8.6.~~.60..J!XJ?;T·;;tlS-PT·r··T~~t·p~i '-l- 1373.5 Interval 4YRTST ....:f.m. P Pretest IA 1350 o A 100 Tubing 1650 ........-.--.-__._..1 Initial 2100 15 Min. 30 Min. 45 Min. 60 Min. 100 1650 --..-"'. --...,,---,.--.- __-L.__ ·.1------.· .__-L___ Notes: Pretest pressures observed for 30+ minutes and found stable. 'il. 'ì l\ \\;~\ (' C "\) r~,~" I, ! \... " . \t..ì.f';:)\¡ ,;ÌI (..Ù ~-, .~. '" J~:\'\.'", t~. ". "'\[~?" 'yO "" .~")'.' ... Wednesday, August 17, 2005 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X WI to WAG Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5275' FNL, 4724' FEL, Sec. 1, T11N, R8E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (as/o's 498945, 5969983) 6. Datum elevation (DF or KB feet) RKB 1 17 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2%16 At top of productive interval 1236' FSL, 1514' FWL, Sec. 11, T11N, R8E, UM At effective depth At total depth 4121' FNL, 3892' FEL, Sec. 11, T11N, R8E, UM (as/o's 494498, 5965860) 9. Permit number / approval number 186-046 / 10. APl number 50-103-20063 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8947 feet 6151 feet Plugs (measured) Effective depth: measured true vertical feet Junk (measured) feet Casing Length CONDUCTOR 110' SUR. CASING 3694' PROD. CASING 8301' LINER 764' LINER Perforation depth: Size Cemented Measured Depth 16" 225 sx cs II 110' 9-5/8" 1215 sxAS III & 380 sx Class G 381 1' 7" 300 sx Class G & 175 sx AS I 8418' 5" 12 sx Class G 8947' measured 8498-8542; 8582-8587; 8597-8624 True vertical Depth 110' 2769' 5751' 6151' true vertical 5810-5844; 5874-5878; 5885-5906 Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 2-7/8",6.5#, J-55 Tbg @ 8123' MD; 2-3/8",4.7#, J-55 Tbg ~!M~i:; BROWN 'HB-I' @ 8046' MD; BAKER 'DB' @ 8551' MD; CAMCO TRDP-1A-SSA @ 1804' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 1716 884 Casing Pressure Tubing Pressure 2545 3910 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ___X Oil __ Gas __ Suspended __ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed p~~n~rJ~------~~J~JeffA. Title Production Engineering Supervisor Questions? Call Jeff Spencer 659-7226 Date ,,/~ ~,/-->""-- ~ / Prepared by Robert Christensen 659-7535 RBD IS BF L Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 2T-16 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary I I MEMORANDUM TO: Julie Heusser Commissioner THRU': Tom Maunder ~'~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 24, 2001 SUBJECT: Mechanical Integrity Tests Phillips 2T Pad 2T-02, 05, 11, 15, 16 KRU Kuparuk NON- CONFIDENTIAL P.T.D.I 1861410 Notes: WellI 2T-05 P.T.D.I 1881440 Notes: WellI 2T-11 P.T.D.I 1860970 Notes: P.T.D.I 1860450 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type Inj.I G I T.V.D. 15753I Tubing 13800 13800 13800 13800 I,nterva, I 4 TypetestI P ITestpsil 1438 I CasingI 1950I 2525I 2525I 2525I P/F I -P Ty,~,nj.I S I T.V.D. J5682 J Tubing 12200 12200 J2200 12200 I,nterva, J ,~ Type testl P I Testpsil 1421 ICasingl 1400 I 2375 I 2375 I 2375 I P/F I P Type lnj.I S I T.V.D. 15320 I Tubing I 1200 J 1200 J 1200 11200 I,.ter~a,J 4 TypetestI P ITestpsil 1330 ICasingI 1600I 2190I 2190I 2190I P/F I --P Type lnj.I G I T.V.D. I 5476 I Tubing I 3650 I 3650 I 3650 I 3650 I lntervall 4 Type testI P I Testpsil 1369 ICasingI 750 I 2325 I 2325 I 2325 ] PIE I -P P.T.D.I 1860460 TypetestI P ITestpsil 1374 ICasingI 1300I 2490I 2450I 2450I P/F I -P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS IN J, S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 2T Pad in the Kuparuk river field and witnessed the 4 Year MIT on wells 2T-02, 2T-05, 2T- 11, 2T- 15 and 2T-16. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 5 wells demonstrating good mechanical integrity. M.I.T.'s performed: _5 Attachments: Number of Failures: 0 -- Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. MIT KRU 2T Pad 6-24-01 CS.xIs 6/25/01 : MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE DEPT. OF NATURAL RESOURCES April 12, 1991 DIVISION OF OIL AND C-~AS D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER J. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T11N R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, s E. Eason ector cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 199t Alaska Oil & Gas Cons. Commlss~oa Anchorage STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMI;SSION:~:~: REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown Stimulate __ Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1314' FSL, 1638' FWL, Sec. 11, T11N, R8E, UM At effective depth 1236' FSL, 1514' FWL, Sec. 11, T11N, R8E, UM At total depth 1160' FSL~ 1389' FWL, Sec. 11, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 8 9 4 7' feet true vertical Plugs (measured) 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2T-16 9. Permit number/approval number 86-46 / 7-147 10. APl number 50-103-20063 11. Field/Pool Kuparuk River Oil Pool 6149' feet Cement: 8723'-8947' Effective depth: measured 8723' feet true vertical 5979' feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3779' 9 5/8" Intermediate Production 8386' 7" Liner 7 6 4' 5" Perforation depth: measured 8498'-8542' Cemented Measured depth True vertical depth 225 Sx CS II 1 1 0' 1 10' 1215 Sx AS III & 381 1' 2768' 380 Sx Class G 300 Sx Class G 841 8' 5750' 120 Sx Class G 8947' 61 49' 12 SPF, 60 degree phasing 8582'-8587', 8597'-8624' 4 SPF, 60 degree phasi.r~._ true vertical . ! 5809'-5842', 5872'-5878', 5884'-5904' TVD I//'-~_ Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 8128', 2 3/8" J-55 set from 8128'-8574;~;~/....,,~,~.a/);,_d/]~.//~/-~?..~/! Packers and SSSV (type and measured depth) · HB-1 Pkr @ 8051', DB Pkr @ 8556°, Camco TRDP-1A-SSA @ 1809'"'~ ~,~r,.. 13. Stimulation or cement squeeze summary ~i'l~l-, Convert well from A & C Sand production service to A & C Sand injection service Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injecti~)rt Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 156 83 -0 - 1100 265 Subsequent to operation -0- -0- 2300 1300 2035 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations I 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. Si~ned "~~, ~,. ~ Title ~-~~ ~~.~v~.~ Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE DEPART~IENT OF NATURAL RESOURCES DIVISION OF OIL AND 6AS August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staf'f, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of' the Kuparuk River Unit 2T wells until further notice. Sincerely, ames E. Eason i rector . cc: C.V. Chatterton, Commissioner, AOGCC Judith H. Brady, Commissioner, DNR 1{ IL C E IV [{ b AUG - 5 1 88 C'il L: (;;:-; l",:~::. C:,.,mmic:icn ',,. 1< AllUllOla~l'J ARCO Alaska, lnc Post Office .,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject' Ku!Parukl RiVer Field · 'water- Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1988. The data is provided in the form of separate zone surveys as or spinner logs listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning the information reported, please contact me at (907) 263-4978. Sincerely, ~4. H. Kraly Operations Engineer AttachmentsMHK/SPT'pg'0163 ARCO Alaska, Inc. II II Subsidiary of AtlanticRIchfieldCompan¥ .,q A.- ff' ' s. £ j .. j ?_ cy ~ t.J/ ATTACHMENT 1 PACE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY SURVEY WELL ZONES COMPLETION TAKING WATER INJECTION BWPD 2B-11 21089 11/19/85 2H-O1 20033 03/15/86 2H-O4 20027 03/15/86 50-103 2T-04 20074 03/30/87 2T-0¢ 20071 03/30/87 2T-11 20075 03/30/87 2T-15 20062 03/30/87 2T-16 20063 03/30/87 50-029 3A-02 21431 01/21/87 3A-Oh 21433 01/21/87 3A-10 21457 01/21/87 ~ 21458 01/21/87 d3A-14 21490 0q/14/87 06/16/87 SPINNER 06/05/87 SPINNER 06/07/87 SPINNER 06/13/87 SPINNER 06/16/87 SURVEY 06/21/87 SPINNER 06/16/87 SURVEY 06/16/87 SURVEY 05/25/87 SPINNER 05/87 SURVEY 05/87 SURVEY 05/27/87 ~ 05/87 SURVEY FOLLOWU P A&C S A&C FOLLOWU P A&C S A&C FOLLOWU P A&C S A&C INITIAL A&C SS A&C INITIAL A S A INITIAL A&C SS A&C INITIAL A&C SS A INITIAL A&C SS A INITIAL A&C SS A&C INITIAL A&C SS A INITIAL A S A INITIAL A&C SS A&C INITIAL A S A 3485 1833 59O 2500 1200 1650 RECEIVED Ada - "..,~ ~ · ~' ~.; / Alaska Oil& Gas Cons. Commission Anchorage c,/I ATTACIIMENT 1 PAGE 2 WELL NUMBER KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE ti - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ .50-029 I NJ ECT ION SURVEY SURVEY SURVEY "~2B-11~' 21089 11/19/85 06/16/87 SPINNER FOLLOWUP "~,2H-Ol~ 20033 03/15/86 06/05/87 SPINNER FOLLOWUP ~2H-04--~ 20027 03/15/86 06/07/87 SPINNER FOLLOWUP 50-103 'XJ2T-04'-''/ 20074 03/30/87 06/13/87 SPINNER INITIAL 2T-09 20071 03/30/87 06/16/87 SURVEY INITIAL "x"J2T-11 J 20075 03/30/87 06/21/87 SPINNER INITIAL 2T-15 20062 03/30/87 06/16/87 SURVEY INITIAL 2T-16 20063 03/30/87 06/16/87 SURVEY INITIAL 50-029 '"J3A-02 ~-~ 21431 01/21/87 05/25/87 SPINNER INITIAL 3A-Oh 21433 01/21/87 05/87 SURVEY INITIAL 3A-10 21457 01/21/87 05/87 SURVEY INITIAL ~~ 21458 01/21/87 05/27/87 SPINNER INITIAL 3A-14 21490 04/14/87 05/87 SURVEY INITIAL WELL COMPLETION Amc S Amc S Amc S Amc SS A S Amc SS Amc SS Amc SS Amc SS Amc SS A S Amc SS A S ZONES TAKING WATER Amc Amc Amc Amc A Amc A A A&:C A A Amc A INJECTION BWPD 3485 1833 59O 25OO 1200 1650 RECEIVED AUG Alaska Oil & Gas Cons. Commission Anchcrage ARCO Alaska, Inc. Post Office I~ . ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 Transmittal # 5933 RETURN TO: ARCO Alaska, Inc. Attn: 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. 2T-16 CET/CEL 9-15-86 8181-8720 2T-12A CET/CEL 9-27-86 4595-6644 2A-11 CET/CEL 3-14-86 5800-6564 3A-9 CET 7-26-86 2000-6299 lA-1 CEL/CET 8-29-86 2708-7255 3A-9 CET/CEL (After Squeeze) 7-31-86 1H-3 CET 7-16-86 6891-7617 3K-13 CET/CEL 8-17-86 6849-8455 3K-14 CET/CEL 8-18-86 7215-8844 3I-1 CET/CEL 1-24-86 7588-8887 3F-15 CET/CEL 1-13-86 6600-7384 2128-6039 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Da t e' ~ State (+ sepia) BPAE Chevron Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany ARCO Alaska, Inc. ~..~. Post Office [ 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 9, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Rr. Chatterton' Attached in triplicate are intent 2T-16' Well Action 2T-15 Conversion 2T-16 Conversion If you have any questions, please Sincerely, Commission notices on Kuparuk Wells 2T-15 and Anticipated Start Date March 9, 1987 March 9, 1987 call me at 265-6840. · B.'Smallwood Senior Operations Engineer GBS'pg'O076 Attachments cc' File KOE1.4-9 RECEIVED MAR 1 0 198'1 ~.km?,k:~ Oil & G:-~S Cons. Comm!ssion ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany --~- STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COMN. .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing I] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order LJ Perforate Ii Other×] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 2'FSL, 556'FWL, Sec.1, T11N, R8E, UM At top of productive interval 1314' FSL, 1638' FWL, Sec. 11, T11N, R8E, UM At effective depth 1236' FSL, 1514' FWL, Sec. 11, T11N, R8E, UM At total depth 1160' FSL, 1389' FWL, Sec. 11~ T11N~ R8E~ UM 11. Present well condition summary Total depth: measured 8947' MD feet true vertical 6149' TVD feet Effective depth: measured 8723' MD feet true vertical 5979' TVD feet Casing Length Size Conductor 80' 16" Surface 3779' 9-5/8" xxx~;~l~,e Production 8386 ' 7" Liner measu-7-6''4,uu ' 5" Perforation depth: 8498'-8542' MD 8582'-8587' MD 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit feet 7. Well number 2T-16 8. Permit number Permit #86-46 9. APl number 5o-- 10;~-20063 10. Pool Kupar'uk River' 0il Pool Plugs (measured)5913' ~i'~ ~r~ ~ - 7 ' .~,-~ ..,, ,- ~ Junk (measured) None ~ ~, f~ Cemented Measured de~ g ~Tr~; vedi~al¢-~th 225 SX CSII 110' MD 110' TVD 1215 SX ASIII & 3811' MD 2768' TVD 380 SX Class G 300 SX Class G 8418' MD 5750' TVD 120 SX Class G 8183'-8947' MD 5586'-6149' TVD 8597'-8624' MD true vertical 5809'-5842' TVD 5884'-5904' TVD 5872'-5876' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8569' Packers and SSSV (type and measured depth) HB Packer @ 8046', DB Packer @ 8551', TRDP-1A-$SA SSSV @ 1804' 12.Attachments Description summary of proposal [] Detailed operations program [] Convert well from production service to water in~ection service. 13. Estimated date for commencing operation March 9, 1987 BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed , /.'.i? ~:(,,-~,¢ /} ,,4-~L-*¥~¢~",¢<'~1¢-,~ Title Sr. Operations Engineer Commission Use Only Conditions of approval Approved by ~;,', ~...,.; ,:,: Re~ Form 10-403 Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Locatiqnc!earance[ /' ,!i..: i~ :' :""::: ? ":' ' /' -.,? .//' ",,:-~ Commissioner by order of <] the commission Date. ];' ./' -. Submit in triplicate ADDENDUM WELL: 1/17/87 2T-16 Stimulate Kuparuk "A" sand perfs 8582'-8587' & 8597'-8624' per procedure dated 12/11/86 as follows: Stage #1: Stage #2a: Stage #2b: Stage #3: 50 bbls 145° diesel @ 1/2 to 3/4 BPM, 2100 - 2000 psi 45 bbls 50/50 IPA & diesel @ 3/4 BPM, 2000 psi 65 bbls 50/50 IPA & diesel @ 1/2 BPM, 2000 psi 48 bbls 110° diesel @ 1/2 BPM, 2000 - 2100 psi / Date AL STATE OF ALASKA ALASK AND GAS CONSERVATION ;SI.ON WEI. I,, COMPI,.ETION OR RECOMPL, ETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ~ ?I'), . ~ 7. Permit Number ,, ' · ' ARCO Alaska~ Inc. ,..?, . 86-/+6 .. $. APl Number .... 3. Address '" "~ P. 0. Box 100360~ Aneborage, AK 99510 50- 103-20063 ' 4. Location of well at surface ' 9. Unit or Lease Name 2' FSL, 556' FWL,,Sec, 1, T11N, R8E, UN Kuparuk River Unit, ' 10. Well Number At Top Producing Interval 1236' FSL, 151/+' FWL, Sec.11, T11N, R8E, UN ., 2T-16 11. Field and Pool At Total Depth 1160' FSL, 1389' FWL, Sec.11, TllN, R8E, UN Kuparuk River Field 5. Elevation in feet {indicate KB, DF, etc.) i 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 117'I ADL 25569, ALK 2667 12. Date Spudded03/11/86 13. Date T.D. Reached0/+/07/86 14' Date C°mp" Susp' °r Aband' I 1S' Water Depth' if °fish°re 116' N°' °f c°mpletiOn"/01/17/87* 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 89/+7'MD 61/+9'TVD 8723'ND 5979'TVD YES [~ NO [] 180/+' feet MD, 1550' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL~ FDC/CNL~ Cal~ RFT, CET, GCT 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" 225 sx CS II 9-5/8" 36.0# J-55 Surf 3811' 12~1/4'' 1215 sx AS III & 380 s~ Class G 7" 26.0# J-55 Surf 8418' 8-1/2" 300 sx Class G & 175 ;x AS T 5" 18.0# L-80 8183' ,. 8947' 6-1/8" 120 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) 2-7/8" 8569' 8046' & 8S~1 8498 ' -8542 'MD 5809 ' -5842 'TVD w/12 spf, 60° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8582'-8587'MD 5872'-5876'TVD Pluq f/5913'-6~75~ 350 sx Class G ' 8597'-8624'MD 5884'-5904'TVD 8560'-8562' 75 sx Class G w/4 spf, 90° phasing See a'~a~.h~H Adrl~, Hiram_ Ha~-~rl n!/~9/87, !%r fr-~ct'-'re PRODUCTION TEST 27. ~/n ...... I Meth0d of Operation (Flowing, gas lift, etc.) }ate First Production Date of Test Hours Tested i PRODUCTION FOR el L-BBL GA$-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL " GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE * 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence °f °il' gas °r water' Submit c°re chips' RECEIVED None cO ~ '"' )?i,ai A1t · Not,e: Drilled RR 0/+/10/86. ~ell perforat,ed & t,ubing ra~ 09/18/86. Submit in duplicatable/ Form 10-407 WC2: 030 :DAN I Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MAR"K ERS NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 8497' 8547' 8566' 8688' TRUE VERT. DEPTH 5808' 5846' 5861' 5953' FORMATION TESTS I nclu de interval tested, pressure data. ell fluids recovered and grav,ty, GeR. and time of each phase. Depth 8601.9 8597.9 8584.0 8539.8 8537.0 8525.9 8506.0 ~dro. Press Form. Press 3917.3 3524.6 3913.9 3521.2 3909.5 3524.6 3881.3 3552.7 3880.9 3551.4 3876.6 3550.0 3870.1 3548.0 31. LIST OF ATTACHMENTS Addendum~ dated 01/29/87. 32. I hereby certify that the foregoing is true and correct to the best of my,~nowledge Signed (~_~/~/~,/' /~'f~(,~i.~_.,.? , Tide 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 multipl.e stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas. Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 S UB.$ URFA CE DIRECTIONAL SURVEY l/ oo ~UIDANCE r~ONTINUOUS E~OOL Company Well Name .... Field/Location ARCO ALASKA~ INC. KUPARUK~ NORTH SLOPE SEC I?TllN~R8E~UM) 4LASKA _ Job Reference No. _ 71746 Lo(3aed By: WEST Date J 15-SEP-86 Computed 8¥: KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ~RCO ALASKA, INC. 2 T- 1.5 KUPARJK NORTH SLOPE,ALASKA SgRV~Y 3ATP: 15-S~:P-56 ~NGINEER: To WEST METH02S OF CONPUTATiON TOOL LOCATION: T~NGENTZAL- ~VERASEO DEVIATION AND AZimUTH INTERPCLATiO~: LZNE&R VERTICAL SECTION: HSRIZ. DIST. ?ROJECTED ONTO 4 TARGET ~ZIMUTM gE SOUTH 4~ DES 44 ~i~ w~ST COMPUTATION ARCS ALASKA, INC. 27-16 KUPARUK NORTH SLOPE,ALASKA D~T£: 13-0CT-~6 iNTERPOLATED VALUES FOR EVEN 100 FEET OF COURSE VErTiCAL DOG DEVIATION AZIMUTH SECTION SEV DEG MIN DEG MIN FEET DEG TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 0 N 0 0 E 0.00 0 15 S 51 17 E -0.99 0 23 S 58 21 E -1.16 0 21 S 67 21 : -1.41 0 20 s 36 6 ~ -i.~9 3 i3 S 2i 26 ~ O.iO 6 30 S 3i 44 w 8.53 io 53 S 36 55 w 22.84 15 53 S 43 54 W 46.29 19 9 S 44 59 W 76.37 0.00 0.00 -117.00 100.00 99.99 -17.01 200.00 199.99 82.99 300.00 299.98 182.98 400.00 399.98 282.98 $00.00 499.94 382.94 600.00 599.53 482.53 700.00 698,40 581.40 B00.00 795.52 678.52 900.00 890.84 773.84 21 59 S 48 Z W 111.42 25 37 S *7 34 W 151.77 30 20 S 46 47 W 198.26 35 58 S 47 39 W 252.99 40 11 S 48 55 W 314.97 44 11 S 50 26 W 382.02 47 50 S 51 40 W 453.89 51 23 S 52 33 W 530.04 35 0 S 52 31 W 609.77 56 48 S 52 5~ ~ 592.82 1000.00 '984.47 867.47 1100.00 1075.94 958.94 1200.00 1164.41 1047.41 i300.00 1248.03 1131.03 1400.00 1326.47 1209.47 1500.00 1400.61 1283.61 1600.00 1470.04 1353.04 1700.00 1534.54 1417.64 1800.00 1594.74 1477.74 1900.00 1650.12 1533.12 56 32 S 52 43 W 775.30 56 37 S 52 39 W 859.78 56 25 S 52 41 W 942.97 56 15 S 52 22 W 1026.00 55 59 S 32 14 W 1108.91 55 27 S 52 5 W 1191.43 55 7 S 52 9 W 1273.4~ 54 52 S 52 i0 ~ 1335.25 5~ 26 S 52 6 W 1436.69 53 53 S 51 56 W 1517.67 2000.00 1704.84 15~7.84 2100.00 1759.60 1542.60 2200.00 1814.80 1697.80 2300.00 1870.2~ 1753.24 2400.00 1925.92 1808.92 2500.00 1982.19 1865.19 2600.00 2039.14 1922.14 2700.00 2096.50 1979.50 2800.00 Z154.32 2037.32 2900.00 2212.60 2095.80 5Z 59 S 51 13 W 1598.33 53 ~1 S 50 45 W 1579.15 53 13 S 50 41 W 1759.45 52 42 S 50 30 W 1.~39.21 52 25 S 50 29 W 1918.59 51:3 S 50 19 W 1997.52 51 21 S 50 5 ~ 2075.85 50 58 S 50 5 W 2153.71 50 28 S 50 7 W 2231.12 50 8 ~ 5C 0 W 2307.86 3000.00 2271.77 2154.77 3100.00 2330.58 2213.58 3Z00.00 2390.11 2273.11 3300.00 2450.38 2333.38 3400.00 2511.15 23~4.15 3500.00 2572.50 2455.50 3600.00 2634.62 2517.62 3700.00 2697.36 2580.36 3800.00 2760.63 26~3.63 3900.00 2824.72 2707.72 LEG ERITY /100 O.O0 0.15 0.19 0.13 0.61 5.4~ 3.11 5.67 3.62 3.42 3.36 3.74 6.13 4.90 3.68 3.84 4.00 3.14 3.89 0.27 0.27 0.34 0.16 0.43 0.37 0.51 0.37 0.33 0.41 0.59 0.94 0.52 0.45 0.51 0.96 0.66 0.40 0.32 0.62 O.ZZ PAGE 1 DATE OF SURVEY: 15-SEF-86 KELLY BUS~ING ELEVATION: 117.00 ENGINEER: T. WEST MEASURED DEPTH RECTANGULAR CDORD'INATES NORTH/SOUTH EAST/WEST FEET FEET HORIZ. DEPARTURE OlST. AZIMUTH FEET DEU MIN 0.00 N 0.00 0.25 li 1.09 0.04 S 1.57 0.38 S 2.20 0.61 S 2..56 2.74 S 2.27 10.60 S 2.04 22.87 S 10.31 40.43 S 26.11 62.05 S 47.16 0.00 N 0 0 E 1.12 N 77 5 E 1.57 S 88 2~ E 2.23 S 80 19 = 2.73 S 77 0 ~ 3,56 S 39 3~ ~ 10.80 S 10 53 ' 23.09 S 24 16 48.13 S 32 51 ~ 77.93 S 37 14 W 86.17 S 72.62 113.06 S 102.71 144.82 S 136.58 182.09 S 176.79 223.29 S 223.10 266.67 S 274.24 311.95 S 330.12 358,38 S 390.53 407'19 S 453.93 457.58 S 520.2! 112.69 S 40 7 W 152.75 S 42 15 N 199.14 S 43 20 W 253.79 S 44 9 W 315.64 S ~4 58 W 382.32 S 45 48 ~ 454.20 S 46 37 W 53.0.18 S 47 26 W 609.80 S 4~ 6 W 692.82 S 4~ 39 W 508.11 S 586.94 W 558.87 S 653.46 W 609.39 S 719.80 W 659.97 S 785.88 W 710.80 S 851.5~ W 761.50 S 916.88 W 811.98 S 981.74 ~ 362.22 S 1046.45 W 912.28 S 1110.87 W 962.17 S 1174.83 W 776.32 S 49 7 W 859.85 S 4~ 27 W 943.12 S 49 44 W 1026.24 S 4:9 58 ~ 1109.25 S 50 8 ~ 1191.87 S 50 17 W 1274.02 S 50 24 W 1355.90 S 50 30 1437.46 S 50 36 w 1518.55 S 50 40 W 1012.27 S 1238.17 w 1599.32 1063.29 S 1300.93 W 1680.18 1114.16 S 1363.13 W 1760.53 1164.80 S 1424.80 W 1840.33 1215.34 S 1486.06 W 1919.75 1265.66 S 1546.92 W 1998.71 1315.81 S 1607.12 W 2077.06 1365.79 S 1666.~5 W 2154.94 1415.44 S 1726.27 W 2232.37 1464.72 S 1785.13 W 2309.13 S 50 43 w S 50 44 w S 50 4~+ W S 50 44 w S 5O 43 w S 5O 42 w S 50 41 w S 50 40 w S 30 39 W S 50 37 w FT ARCO ALASKA, INC. 27-16 KUPARUK NORTH SLOPEi~LASKA T MEASURED VER OEP'TH O 4000.00 28 4100.00 29 42OO.00 30 4300.00 30 4400.00 31 4500.00 31 4600.00 32 4700.00 33 4800.00 33 4900.00 34 5000.00 35 5100.00 35 5200.00 36 5300.00 36 5400.00 37 5500.00 38 5600.00 38 5700.00 39 5800.00 40 5900.00 40 6000.00 41 6100.00 42 6200.00 42 6300.00 43 6400.00 44 6500.00 44 6600.00 45 6700.00 ~6 5800.00 46 6900.00 47 7000.00 48 7100.00 48 7200.00 49 7300.00 50 7400.00 50 7500.00 51 7600.00 51 7700.00 52 7800.00 53 7900.00 53 COMPUTATION INTERPOLATED VALUES FOR RUE SUB-SEA TICAL VERTICAL EPTM DEPTH 88.38 2771.38 50.97 2833.97 12.71 2895.71 73.72 2956.72 34.85 3017.85 95.84 3078.84 56.64 3139.64 17.46 3200.46 78.30 3261.30 39.34 3322.34 00.74 3383.74 62.56 3445.66 25.09 3508.09 88.04 3571,04 51.44 3634.44 15.29 3698.29 79.62 3762.62 43.97 3826.97 08.56 3891.56 73.23 3956.23 39.29 4022.29 06,56 4089.56 74.42 4157.42 43.11 4226.11 10.91 4293.91 77.98 4360.98 44.04 4427.04 09.64 4492.64 74.89 4557.39 40.08 4623.08 05.45 4583.45 71.00 4754.30 36.06 4819.06 00.80 4883.80 65.36 4'948,36 30.44 5013.44 96.62 5079.62 62,93 5145.93 29.16 5212.16 95.35 5278.35 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 50 55 S 49 58 W 51 34 S 49 53 W 52 6 S 49 45 W 52 34 S 4'9 42 W 52 21 S 49 38 W 52 30 S 49 34 w 52 32 S 49 31 w 52 32 S 49 32 W 52 29 S 49 38 W 52 17 $ 49 40 W 51 57 S 49 40 W 51 34 S 49 26 W 51 I0 S 49 4 W 50 47 S 45 47 W 50 30 S 48 29 W 50 6 S 48 14 W 49 54 S 48 0 W ~9 55 S 47 54 W 49 43 S a7 34 W 49 32 S 47 3 W 47 52 S 43 52 W 47 25 S 38 58 W 45 54 5 33 57 W 46 53 S 33 55 W 47 33 S 34 5 W 48 21 5 33 31 W 4~ 55 3 3~ 18 W 49 8 S 42 34 W 49 30 S 41 48 W 49 26 S 40 44 W DATE: EV=N 13-007-86 100 FEET VERTICAL SECTION FEET 2384.96 2462.93 2541,58 2620.80 2699.92 2779.17 2858.55 2937,92 3017.28 3096.47 3175.40 3253.91 3332,03 3409.72 3487.06 3564.02 3640,58 3717.11 3793,45 3869.69 '394~.65 4018.02 4089.70 4159.80 4231.00 4302.50 ~375.74 ~450.61 4525.91 4601.10 4575.93 4750.56 ~825.56 ~900.55 4~75.23 5049.20 5122.45 5196.00 5269.55 5343.34 PAGE D~TE OF SURVEY: 15-SEP-~6 KELLY BUSHING ELEVATION: ENGINEER: T. WEST OF MEASURED DEPTH DOGLEG SEVERITY DEG/IO0 0.81 0.80 0.52 0.67 0.32 0.19 0.11 0.14 0.3z, 0.23 0.33 0,54 0.45 0.36 0.42 0.35 0.51 0.22 0.57 1.17 3.41 2.75 1,65 1.10 3.03 4.48 0.60 1.17 1.42 0.42 0,21 1.16 1.60 0.61 1.30 1.~7 0.67 0.96 1.13 117.00 FT RECTANGULAR COORDINATES HORIZ. NORTH/SOUTH EAST/WEST DIST. F=ET FEET FEET 1514.29 S 1844.20 W 2386,25 1564,48 S 1903.90 W .2464.23 1615.22 S 1964.01 W 2542.89 1666.44 S 2024,46 W 2622.11 1717.66 S 2084,7'8 W 2701,23 1769.02 S 2145.14 W 2780.48 1820.51 S 2205.57 W 2859.86 1872,06 S 2265.93 W 2939.22 1923.48 S 2326.38 W 3018.58 197~.76 S 2386.75 W 3097.78 2025.82 S 2446.94 w 3176.71 2076,74 S 2506.72 W 3255.23 2127.72 S 2565.91 W 3333.33 2178.77 S 2624.48 W 3411,01 2229.88 S 2682.52 W 3488.31 2281.03 S 27~0.03 W 3565.23 2332.12 S 2797.05 W 3641.74 2383.39 S 2853.88 W 3718,22 2%34.73 S 2910.40 W 3794.51 2486.31 S 2966.57 W 3870.70 2538.63 S 3020.35 W 3945.55 2594.00 S 3069.41 W 4018.72 2653.21 S 3112.82 ~ 4090.13 2713.84 S 3152.87 W 4159,99 2774.54 S 3194.33 W 4231.06 2836,50 S 3235,10 W 4302.51 2897.05 S 3279,39 W ~375.76 2953.50 S 3329.46 W 4450.67 3009,60 S 3380.41 W 4526.02 3066.56 S 3430.47 W 4601.30 3124.35 S 3479.32 w 4676.24 3182.26 S 3527.77 W 4751.01 3240.70 S 3576.28 W ~826.17 3300.40 S 3623.65 W ~901.38 3361.63 S 3669,29 W 4976.37 3423.28 S 3713.60 ~ 5050.71 3483.59 S 3738.13 W 5124.35 3542.54 S 3304.25 W 5198.26 360i.;30 S 3850.10 W 5272.21 3660.37 S 3896,88 W 534~.40 DEPARTURE AZIMUT, DEG MIN S 5'-3 36 W S 5O 35 H S 50 33 N S 50 32 W S 50 30 W S 50 29 W S 5"3 27 S 50 26 S 50 24 W S 50 23 W S 50 22 w S 50 21 w S 50 20 w S 50 18 W S 5O 15 w S 50 13 W S 50 10 ~ S 50 7 W S 50 5 '~ S 50 1 w S 49 57 W S 49 47 W S 4) 33 w S 49 16 w S 49 1 W S 48 45 w S 4.~ 23 S 45 19 W S ~8 12 w S ~7 56 W S 47 40 w S 47 30 W' S 47 19 W S 47 10 ~ S 47 2 w S 46 54 W $ 46 47 w ~O~PUTATION OATE: ARCO ALASKA, INC. 27-16 KUPARUK NORTH SLOPE,ALAS~ MEASURED VE DEPTH 8000.00 5 : 81oo.oo 5 ...... 8200.00 5 -8~ 0 0.0 0 5 8400.00 5 8500.00 5 8500.00 5 8700.00 5 8800.00 6 8900.00 6 8947.00 6 TRUE SUB-SEA RTICAL VERTICAL DEPTH DEPTH INTERPOLATED VALUES FOR EVEN COURSE VERTIC OEVIATION AZIMOTH SECTI 462.02 53~5.02 529.44 5412.44 597.78 5480.78 666.64 5549.64 736.91 5619.91 810.03 5693.03 886.49 5769.49 962.32 ,5845.32 038.08 5921.08 113.84 5996.84 149.45 6032.45 DEG MIN DEG MIN FEE 6061. 13-0CT-86 100 FEET OF AL DOGLEG ON SEVERITY T DEG/IO0 97 1.15 25 1.49 ooo 2.40 33 2.30 33 5.01 10 1.07 39 0.00 73 0.00 06 0.00 PAGE 3 DATE 0= SURVEY: 15-SEP-86 KELLY BUSHING ELEVATION: 117.00 ENGINEER: T. WEST MEASURED DEPTH RECTANGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET F=ET DEG MiN 3717.5 3772.8 3826.0 3877.6 3926.3 3966.7 4003.6 4038.0 4072.2 4106.4 FT 30 O.O0 4122.45 S 4446.58 W 6063.55 S 47 9 W 6 S 3944.66 W 5420.38 S 46 41 W 4 S 3993.63 W 5493.94 S 45 37 W 9 S 4043.57 W 5566.82 S 46 34 W 6 S'4094.54 W 5639.28 S ~6 33 W 8 S 4146.37 W 5710.42 S 46 33 W 0 S 4199.72 W 5778.25 S 46 37 N 7 S 4253.86 W 5841.64 S 46 44 } 9 S 4309.20 W 5905.54 S 4,5 51 5 S 4364.82 W 5969.~9 S 46 59 W 1 S 4420.44 W 6033.48 S 47 6 ~ ARCO ALASKA, INC. 2T-16 KUPARUK NORTH SLOPE,ALASKA CCMPUTATION DATE: 13-0CT-86 PAGE 4 O&TE OF SURVEY: 15-SEP-86 KELLY BUSHING ELEVATION: 117.00 FT N 0 0 E 0.00 S 48 2 W 111.42 S 52 43 W 776.30 S 51 13 w 1598.33 S 49 58 W 2384.96 S 49 40 W 3175.40 S 43 52 W 3944.65 S 39 54 W 4675.93 S 40 41 W 5416.97 S 58 26 W b061.30 0.00 0.00 -117.00 0 0 1000.00 984.47 867.47 21 59 2000.00 1704.84 1587.84 56 52 3000.00 2271.77 2154.77 53 59 4000.00 2888.38 2771.38 50 55 5000.00 3500.74 3383.74 51 57 6000.00 4139.29 4022.29 47 52 7000.00 4805.45 46~8.45 48 54 8000.00 5462.02 5345.02 47 55 8947.00 6149.45 6032.45 40 44 !NTERP3LATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN 0.00 3.36 0.27 0.94 0.81 0.33 3.41 0.42 1.15 0.00 0.00 N 0.00 E 0.00 N 0 0 E 86.17 S 72.62 N 112.69 S 40 7 W 50~.I1 S 586.94 W 776.32 S 49 7 W 1012.27 S 1238.17 W 1599.30 S 50 43 W 1514.29 S 1844.20 W 23S6.25 S 50 36 W 2025.82 S 2446.94 W ,3176.71 S 50 22 W 253~.63 S 3020.38 ~ 3945.55 S 49 57 3124.35 S 3479.32 W 4576.24 S 48 4 3717.56 S 3944.66 W 5420.38 S 45 41 ~ 4122.46 S 4446.58 W 6063.56 S 47 9 W ENGINEER: T. WEST COMPUTATZON OATE: 13-0CT-85 PAGE 5 ARCO ALASKA, INC. 2T-16 KUPARUK NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 0.00 0.00 17.00 17.00 117.01 117.00 217.01 217.00 317.02 317.00 417.02 417.00 517.09 517.00 617.60 617.00 71~.97 717.00 822.36 817.00 927,75 917,00 1035,26 1017,00 1145.90 1117,00 1262,13 1217,00 1387.59 1317.00 1523.08 1417.00 1671.92 1517.00 1839.61 1617.00 2022.26 1717.00 2203.98 1817.00 2384,04 1917,00 2561,20 2017,00 2735,57 2117,00 2907,15 2217,00 3077,03 2317,00 3244.82 2417.00 3409.56 2517.00 3571.75 2617.00 3731.1~ 2717.00 3887.94 2817.00 4045.58 2917.00 4207.00 3017.00 4370.74 3117.00 4534.80 3217.00 4699.25 3317.00 4863.44 3417.00 5026.37 3517.00 5187.10 3617.00 5345.75 3717.00 5502.66 3817.00 INTERPOLATED VALUES FOR EVEN 100 SUE-SEA COURS: VERTICAL VERTICAL DEVIATION AZIMUTH S-CTION DEPTH DEG MIN DEG MIN FEET -i17.00 0 0 N 0 0 E 0.00 -100,00 1 21 N 64 55 E -0.42 0,00 0 16 S 55 28 E -1,00 100,00 0 24 S 56 Zl E -1.19 ZO0.O0 0 19 S 68 B E -1.45 300.00 0 25 S 24 33 E -1.57 400.00 4 4 S 24 52 W !.0~ 500.00 7 6 S 32 29 W 10.51 500.00 11 51 S 38 59 W 26,52 700.00 16 43 S 44 11 W 52.47 800.00 20 0 S 45 W6 W ~5.59 900.00 23 14 S 48 17 W 125.00 1000.00 27 30 S 46 56 W 172.25 1100.00 34 2 S 47 12 W 231.29 1200.00 39 44 S 48 45 W 306.95 1300.00 45 3 S 50 41 W 398.25 1~00.00 50 30 S 52 30 W 508.25 1500.00 56 13 S 52 41 W 642.46 1600.00 56 51 S 52 41 W 794.91 1700.03 56 24 S 52 41 W 946.28 1800.00 56 2 S 52 14 W 1095.69 1900.00 55 15 S 52 7 W 1241.67 2000.00 54 45 S 52 9 W 1384.27 2100.00 53 56 S 51 55 W 1523.45 2200.00 53 51 S 50 47 W 1660.63 2300.00 52 57 S 50 37 W 1795.28 2400.00. 52 22 S 50 28 W 1926.15 2500.00 51 28 S 50 8 ~ 2053.77 2000.00 50 50 S 50 7 W 2177.91 2700.00 50 5 S 50 1 W 2298.60 2800.00 51 12 S 49 57 W 2420.42 2900.00 52 8 S 49 45 W 2547.11 3000.00 52 14 S 49 38 W 2676.75 3100.00 52 33 S 49 34 W 2~06.79 3200.00 52 32 5 49 32 W 2937.32 3300.00 52 21 S 49 39 W 3067.54 3400.00 51 50 S 49 37 W 31'}6.15 3500.00 51 13 $ 49 7 W 3321.98 3600.00 50 39 S 48 37 W 3445.14 3700.00 50 6 S 48 14 ~ 3556.06 FEET OF DOGLEG SEVERITY DEG/IO0 0.00 i .28 0.18 0.08 0.22 0.76 4.81 3.77 5.57 2.89 3.29 3.76 4.52 5.37 3.49 3.62 2.94 2.42 0.31 0.15 0.22 0.31 0.27 0.72 0.82 0.90 0.75 0.49 0.63 0.48 0.48 3.49 3.92 3.14 0.14 0.18 ~ 58 0.47 0.35 3.35 DATE OF SURVEY: 15-SEP-86 KELLY BUSHING ELEVATION: 117,0'0 FT ENGINEER: T. WEST SUB-SEA DEPTh RECTANGULAR COORDINATES HORIZ, DEPARTURE NORTH/SOUTh EAST/WEST DIST, AZIMUTH FEET ' FEET FEET DEG MIN 0.00 N 0.00 6 0.00 N 0 0 E 0,20 N 0.38 E 0.43 N 62 21 E 0.20 N 1.16 E 1.17 N 80 2 E 0.11 S 1.67 E 1.68 S 86 18 E 0.41 5 2.30 E 2.33 5 79 45 E 0.71 S 2.71 E 2.81 S 75 17 E 3.74 S 1.~5 E 4.17 S 2.5 16 12.36 S 3.14 W 12.75 S 14 16 ~ 25,82 .S 12.52 W 28.74 S 26 2 ~ 44.87 S 30.43 W 54.21 S 34 8 W 68.57 S 53.70 W 87.10 S 38 3 W 95.17 S 82.79 W 126.14 S 41 1 W 126.99 S 117.73 W 173.17 S 42 50 W 167.39 S 160.82 W 232.13 S 43 51 W 218.02 S 217.05 W 307.65 S 44 52 W 276.98 S 2~6.79 W 398.71 S ~5 59 W 345.30 S 373.19 W 508.43 S 47 13 W 427.10 S ~79.96 W 642.47 S 48 20 W 519.42 S 601.77 W 794.93 S ~9 IZ ~ 611.40 S 722.44 W ~46.43 $ 49 45 W 702.70 S 841.11 w 1096.02 S 50 7 W 792.42 S 956.59 W 1242.17 S 50 21 W 880.05 S 1069.41 W 1364.97 S $0 32 ~ 965.74 S 1179.39 w 1524.34 S 50 41 W 1051.58 S 1286.58 W 1661.~5 S 50 44 W 1136.88 S 1390.B7 W 1796.39 S 50 ~4 ~ 1220.16 S 1491.~9 W 1927.31 S 50 43 w 1301.65 S 1590.18 W 2054.98 S 50 41 . 1381.32 S 1685.42 W 2179.15 S 50 39 W 1458.76 S 1778.03 W £299.~7 S 50 37 W 1537.10 S 1871.37 W 2421.71 S 50 36 W 1518.79 S 1968.23 W 25~6.42 S 50 33 w 1702.65 S 2067.12 W 2678.06 S ~0 31 N 17B6.93 S 2166.17 W 2808.10 S 50 28 W 1871.67 S 2265.47 W 2938.63 S 53 26 W 1956.03 S 2364.~9 W 3068.85 S 50 24 W 203~.26 S 2462.76 W 3197.46 $ 50 22 W 2121.14 S 255B.32 W 3323.29 S 50 20 W 2202.14 S 2651.09 W 3446.41 S 50 17 W 22~2.39 S 2741.55 W 3567.27 S 50 13 W COMPUTATION DATE: i3-0CT-86 PAGE 6 ARCO ALASKA, INC. IT-16 KUPARUK NORTH SLOPE,ALASKA TRUE MEASURED VERTiCaL DEPTH DEPTH 5658,11 3917,00 5813,06 4017,00 5966,76 4117,00 6115,41 4217,00 6261,94 4317,00 6409,03 4417,00 6558,90 4517,00 6711,24 4617.00 6864,58 4717,00 7017,60 4817,00 7170.58 4917.00 7325.09 5017.00 7479.50 5117.00 7630.71 5217.00 7781,69 5317.00 7932.58 5417.00 8081.65 5517.00 8227,96 5617,00 8371,88 5717.00 8509,12 5817,00 8640,20 5917,00 8772.17 6017,00 8904,17 6117.00 8947,00 6149.45 iNTERPOLATED VALUES FOR EVE SUB-SEA COURSE V~RT VERTICAL DEVIATION AZIMUT~ .SEC DEPTH ~EG MiN CEG MIN F 3800,00 49 56 S 47 56 W 368 3900.00 49 44 S 47 32 W 380 4000.00 48 15 S 45 15 W 392 4100.00 47 19 S 35 9 W 402 4200.00 46 32 S 33 23 W 413 4300.00 47 35 S 33 57 w 423 4400,00 48 39 S 36 44 w ~34 4500.00 49 10 S 42 33 W 445 4600.00 49 13 S 41 9 W 457 4700.00 48 57 S 39 53 W 468 4800,00 4'9 31 S 39 32 W 480 4900,00 49 48 S 37 3 w 491 5000.00 49 7 S 35 30 W 503 5100,00 48 25 S 38 6 W 514 5200,00 48 27 S 37 54 W 525 5300.00 48 15 S 39 35 W 536 5400.00 47 22 S 42 6 W 547 5500.00 46 36 S 44 13 W 558 5600,00 45 4 S 47 18 W 568 5700,00 40 17 S 56 28 W 578 5800.00 5900.00 40 44 S 58 26 W 594 6000.00 40 44 S 58 25 W 603 6032.45 40 ~4 S 58 26 ~ 606 N 1GO FEET OF ICAL DOGLEG TION SEVERITY EET DEG/iO0 5,06 0,11 3.41 0,64 0.06 3,84 9.20 ~,16 3.0? 0,96 7,45 1,29 5.32 5.15 9.07 0.69 4.47 0,90 9.05 0.17 3,45 1,25 9,34 1,65 4,13 1,24 5,02 1 6,09 0,93 7.33 1,37 6.85 1.47 3.14 1.71 6.47 2.19 0.15 3.39 3,93 1,09 8.82 0,00 3.75 0,00 1,30 0.00 DATE OF SURVEY: 15-SEP-86 KELLY 5USHING ELEVATION: 117.0'0 ENGINEER: T. WEST SUB-SEA DEPTH 2ECT~NGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH E~ST/WEST DIST. AZIMUTH FEET FEET FEET OEG MiN 2361,93 S 2830.08 W 3686,20 S 50 9 2441,45 S 2917.75 W 3804,46 S 50 4 .2521,07 S 3003,07 W 3'921,00 S 49 59 2602,80 S 3076,56 W 402'9,86 S 49 46 2690,79 S 3137,54 W ~133,34 S 49 22 2780.05 S 3198,07 W 4237,50 S 48 59 W 2~72,72 S 3260,26 ~ 43~5,32 S 43 36 2959,75 S 3335,23 W 4459,13 S 48 24 3046,28 S 3412,83 W 4574.63 S 43 14 3134,53 S 3487,83 W 458.9,38 S 45 3 W 3223.38 S 3562.07 W 4804,01 S 47 51 N 3315.62 S 3635,30 W 4920,24 S 47 37 W 3410,68 S 3704.61 w 5035,56 S 47 21 W 3501,70 S 3772,26 ~ 5147,03 S 47 7 W 3591,02 S 3841,65 W 5253,68 S 4~ 55 W 3579,21 S 3912,30 W 5370,53 S 46 45 W 3762,86 S 3984,56 W 5480,49 S 46 38 W 3840,69 S 4057,68 W 5587,10 S 46 34 W 3913.00 S 4131.69 W 5690,56 S 46 33 W 3971,91 S 4204.53 W 5784,03 S 46 37 W 4017,61 S 4276.00 W 5867,31 S 46 47 W 4062,74 S 434'9.34 W 5951,69 S 46 57 W 4107.83 S 4422.76 W 603.5.15 S 47 6 ~ 4122.46 S 4446,58 W 6063.56 S 47 9 ~ ARGC ALASKA, INC. 2T-18 KUPARUK NORTH SLOPE,ALASKA TOP BASE TCP BASE PBTD TD MARKER KUPARUK C KUPARUK C KUPARUK A KUPARUK A C CMPUT ~TI or,.~ INTERPOLATED VALUES FOR MEASURED DEPTH BELOW KB 8497..00 8547.00 8566.00 8688.00 8849.00 8947.00 DATE: 13-0CT-86 CHOSEN HORIZONS FROM KB 5807.73 5846.05 5860.58 5953.23 5075.21 6149.45 PAGE 7 ~ATE OF SURVEY: 15-SEP-86 KELLY BUSHING ELEVATION: 117.0'0 ENGINEER: T. WEST ORIGIN: Z FSL, TVO SUB-SEA 5690.73 572~.05 3743.58 5835.23 5958.21 6032.45 556 SURFACE LOCATION AT FWL, SEC 1, TllN, ROE, UM R~CTANGUL~R COORDINATES NCRTH/SOUTH EAST/WEST 3967.64 S 4198.10 3985.17 S 4225.00 3991.81 S 4235.30 ~033.99 S 4302.52 40B8.99 S 4392.07 4122.46 S 4446.55 COMPUTATION DATE~ i3-CCT-86 PAGE 8 ARCO ALASKA, INC. 2T-16 KUPARUK NGRTH SLOPE,ALASKA MARKER TOP KUP~RUK C B.~SE KUPARUK C TOP KUPARUK A BASE KUPARUK ~ PSTD TD MEASURED D£PTm 8497.00 ~547.00 8566.00 8849.00 8947.00 ~ATE 2~ SURVEY: 15-SEP-86 K~LLY ~USHING ELEVATION: ll?.OO F~ ENGINEER: T. WEST ORIGIN: 2 FSL, TVD SUB-SEA 556 SO FWL, SE RECTA NORT RFACE LOCATION AT C 1, TI1N~ RSE~ UM NGULAR COORDINATES M/SOUTH EAST/WEST 5807.73 5846.05 5860.58 5953.23 6075.21 6149.45 5690.73 5729.05 5743.58 5836.23 5958.21 6032.45 396 395 399 403 ~0~ 7.64 S 4198.10 5.17 S 4225.00 1.81 S 4235.30 3.99 S 4302.52 8.99 S 4392.07 2.46 S 4446.58 FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL OEPARTURE DISTANCE AZIMUTH FEET OEG MIN 8947.00 61~9.45 6032.45 6053.56 S 47 9 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2T- ! 8 F I ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOED iS - SEP - 86 REFERENCE 00007]748 WELL- 2T-16 ("' FSL 556' FWL, SEC 1,TllN,R8E,UM) HORIZONTAL PROJECTION NORTH 2000 1000 - 1000 REF 000071746 SCALE = !/1000 IN/FT -2000 -9000 -4000 -SO00 SOUTH -S000 -6000 WEST -SO00 -4000 -9000 -2000 -I000 0 1000 2000 EAST WELL- 2T-16 (2' FSL, 556' FWL, SEC. 1,TllN,R8E,UM) VERTICAL PROJECTION -4000 -2000 0 0 2000 4000 6000 8000 ] 0000 12000 228. PROJECTION ON VERTICAL PLANE 2~8. - 48. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT ..... STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM;. SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other [] Fee 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 117' 3. Address Unit or Property name 6'Kuparu'k River Unit P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1314' FSL, 1638' FWL, Sec.11, T11N, R8E, UM At effective 1236' FSL, ' FWL, Sec.ll, TllN, R8E, UM At total depth 1160' FSI, 1389' FWL, Sec.11, T11N, R8E, UM 7. Well number 2T-16 8. Approval number 7-34 9. APl number 50-- 103-20063 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3779' 8947 'MD feet 6149 ' TVD feet 8723 'MD feet 5979 ' TVD feet Size 16" 9-5/8" Producti on 8386 ' 7" Liner 764 ' 5" Plugs (measured) 5913'"6375' Junk (measured) None Perforation depth: measured 8498'-8542'MD 8582 ' -8587 'MD true vertical 5809'-5842'TVD 5872 ' -5876 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55 tbg w/tail @ 8569' Packers and SSSV (type and measured depth) HB pkr @ 8046' Cemented 225 sx CS II 1215 sx AS Ill & 380 sx Class G 300 sx Class G 120 sx Class G 8597'-8624'MD 5884'-5904'TVD 12. , DB pkr @ 8551', & TRDP-1A-SSA SSSV ~ 1804' Stimulation or cement squeeze summary See attached Addendum. Intervals treated (measured) Treatment description including volumes used and final pressure Measured depth True Vertical depth 110'MD 110'TVD 3811 'MD 2768 'TVD 8418 'MD 5750 'TVD 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Addendum dated, 01/29/87) Daily Report of Well Operations E~ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85(/~- Title Associ ate Engineer Date (DANI) SW02/032 Submit in Duplicate ADDENDUM WELL: 1/17/87 2T-16 Stimulate Kuparuk "A" sand perfs 8582'-8587' & 8597'-8624' per procedure dated 12/11/86 as follows: Stage #1: Stage #2a: Stage #2b: Stage #3: 50 bbls 145° diesel @ 1/2 to 3/4 BPM, 2100 - 2000 psi 45 bbls 50/50 IPA & diesel @ 3/4 BPM, 2000 psi 65 bbls 50/50 IPA & diesel @ 1/2 BPM, 2000 psi 48 bbls 110° diesel @ 1/2 BPM, 2000 - 2100 psi Drill~S6pervisor ~ / Date STATE OF ALASKA '~ ALASKa, JIL AND GAS CONSERVATION COMM~_ .,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re.enter suspended well ~ Alter casing ~ Time extension [] Change approved program ~, Plugging [] Stimulate ~,,Pull tubing ~ Amend order ~_ Perforate ~ Other 2. Na~r~c~f Opera~or A±asKa, Inc. 3. Ad~.e(~s. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2' FSL, 556' FWL, Sec. 1, TllN, R8E, UM At ~_o3Pl~f, productive interval FSL, 1638' FWL, Sec. 11, TllN, R8E, UM At ~f~ohiVeF~ej_p, th1514' FWL, Sec. 11, TllN, R8E, UM At~.q__t~b(ilel~;~L, 1389' FWL, Sec. 11, TllN, R8E, UM 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-16 8. Permit number ~6-46 9. APl number 50-- 103-20063 10. Pool Kdparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3779 ' Production 8386' Liner 764' 8947'MD feet 6149'TVD feet 8723'MD feet 5979'TVD feet Size 16" 9-5/8" 7!! 5" Plugs (measured) 5913' - 6375'MD Junk (measured) None Cemented Measured depth 225 sx CS II ll0'MD 1215 sx AS III & 380 sx Class G 3811'MD 300 sx Class G 8418'MD 120 sx Class G 8183'-8947'MD Rue Verticaldepth ll0,TVD 2768'TVD 5750'TVD 5586' - 6149' Perforation depth: measured 8498' - 8542'MD 8597' 8582' - 8587'MD true vertical 5809' - 5842'TVD 5884' 5872' - 5876'TVD - 8624'MD - 5904'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8569" Packers and SSSV (type and measured depth) HB-1 pkr @ 8046', DB pkr @ 8551'~ & TRDP-1A-SSA SSSV ¢ ]804' 12.Attachments Description summary of proposal ~ Detailed operations program ] BOP sketch -- 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~) ~ ~L~21...~ Title Associate Engineer Commission Use Only (JG) SA/211 Date I-I1 - 7 Conditions of approval Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance Approved by Commissioner ]VD Approval No.]i? ~._~' .~y Subsequ~t Wor~ ~ - by order of the commission Date //~/~' Form 10-403 Rev 12-1-85 Submit in triplicatu Summary of Proposal Well 2T-16 Stimulation ARCO Alaska, Inc. proposes to change the stimulation plans for Well 2T-16 from a fracture stimulation to stimulation by in'e ' alcohol and ' ~ J ct~on of a mixture · · . diesel. Because of the close s acin .of ~sopropyl faulting Tn the reservoir, fracturi~ ~?- _ g..of, the .reservoir sands and c.ommunication between the A Sand and t~ ~_~.~a n~.gn poten, tial of causin -~ ~ ~ana. ?/ans are to treat the wel~ wTth isopropyl alcohol as an alternate means of stimulation. JHC'sc:O060 STATE OF ALASKA .--- AL/ ,A OIL AND GAS CONSERVATION CO, ,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] Complete 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. Box 100360 Anchorage, AK 4. Location of well at surface 5. Datum elevation (DF or KB) RKB 117' 99510-0360 6. Unit or Property name Kuparuk River Unit 7. Well number .2' FSL, 556' FWL, Sec. At top of productive interval 1314' FSL, 1638' FWL, Sec. At effective depth 1236' FSL, 1514' FWL, Sec. At total depth 1160' FSL, 1389' FWL, Sec. 1, T11N, R8E, UM 11, TllN, R8E, UM 11, T11N, R8E, UM 11, T11N, R8E, UM ?T-16 8. Approval number 77 9. APl number 50-- 103-20063 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3779' 8947'MD 6149'TVD 8723 'MD 5979 ' TVD Size 1 6" 9-5/8" Producti on 8386 ' 7" Liner 764 ' 5" feet feet feet feet Plugs (measured) Junk (measured) 5913' - 6375'MD None Cemented Measured depth 225 sx CS II 1lO'MD 1215 sx AS III & 380 sx Class G 3811 'MD 300 sx C1 ass G 8418'MD 120 sx Class G 8183'-8947'MD True Vertical depth 110'TVD T 2768'TVD 5750'TVD 5586' - 6149' Perforation depth: measured 8498 ' - 8542 'MD 8597 ' - 8624 'MD 8582' - 8587 'MD true vertical 5809' - 5842'TVD 5884' - 5904'TVD 5872' - 5876'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8569' Packers and SSSV (type and measured depth) HB-1 pkr ~ 8046'~ DB pkr @ 8551 '¢ & TRDP-1A-SSA SSSV ~ 1804' 12. Stimulation or cement squeeze summary Intervals treated (measured) 8560' - 8562' Treatment description including volumes used and final pressure RECEIVED OCT 2 9 1986 Alaska 011 & Gas Cons. Commission Anchorage 7~ ~× Class G 13. N/A Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Subsequent to operation 14. Attachments (Comp. Well Hi story) Daily Report of Well Operations ~Z Copies of Logs and Surveys Run :X:~ Gyz'o 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Associate Enqineer Date Submit in Duplicate f r~AM I c:;wn/'1 n~ ARCO Oil and Gas Company Well History - Initial Report - Daily In$tructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska rcounty, pa~Sh or borough North Slope Borough IL~ase~ or Unit ' '-' ADL 25569 ITitle Completion State Field Kuparuk River Auth. or W.O. no. AFE AK0839 Nordic 1 Alaska IWell no, 2T-16 API 50-103-20063 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a,m. · IOate IHour 9/10/86 Complete record for each day reported 9/10/86 IARCO W,I. Prior status 56.24% if a W.O. 0245 hrs. 9/11/86 9/12/86 9/13/86 thru 9/15/86 9/16/86 5" lnr f/8183'-8947' 7829' TOC, Tst BOPE 6.8 ppg Diesel, 11.6 ppg Brine, 12.5 ppg mud Accept rig @ 0245 hrs, 9/10/86. ND lower tree. NU & tst BOPE. 5"L f/8183'-8947' 8054' PBTD, Drl cmt 11.8 ppg mud Tst BOPE. TIH to 250', displ diesel cap. TIH to 2060', displ brine w/12.1 ppg mud. TIH to 7845', C&C mud, wsh fill & drl cmt f/7845'-8054'. 5"L f/8183'-8947' 8190', TOH 12.1 ppg mud C&C mud, DO cmt to TOL@ 8190' TOH. , C&C, tst lnr lap to 1000 psi, 5"L f/8183'-8947' 8723' PBTD, Rn CET 12.1 ppg mud TIH to TOL@ 8190', DO cmt f/8190'-8215'. RIH, drl cmt & CO lnr f/8190'-8723', CBU, tst lnr to 1000 psi, TOH. RU Schl, rn CET f/8723'-8195', RD Schl. TIH w/scrprs to 8723', circ hole 9/17/86 cln. Displ hole w/ll.8 ppg brine. 12.1 ppg & filter brine cln, POOH. 5"L f/8183'-8947' 8723' PBTD, POH w/DP 12.1 ppg mud Fin rn'g CET. Rn GCT f/8723'-surf. Circ, raise brine wt to RU Schl, rn CET log. RU Schl, perf The above is correct For fo~m preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. f/8560'-8562' @ 4 SPF. RIH w/sqz pkr, set @ 8310'. sx C1 "G" cmt. POH. Sqz w/75 5"L f/8183'-8947' 8723' PBTD, POH w/3½" DP 12.1 ppg mud TOH w/3½" DP & pkr. TIH w/4-1/8" bit/5" scrpr, tag cmt @ 8333', drl cmt to 8622' w/stringers to 8723'. Filter brine & cln hole. Tst sqz perfs w/1000 psi; OK. RU & rev circ. RECEIVED Title Drilling Supervisor OCT 2 9 1986 0il & Gas.Cons. Commission Ar~'~raite ARCO Oil and Gas Company Daily WeU 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 Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0839 Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 9/18/86 Date and depth as of 8:00 a.m. 9/19/86 . I,Cou,n. ty or Parish ILease or Unit ITitle A.R.Co. Date Complete record for each day reported North Slope Borough Accounting cost center code State Alaska ADL 25569 JWell no. 2T-16 Completion API 50-103-20063 W.I. rrotal number of wells (active or inactive) on this i Jcost center prior to plugging and I 56.24% Jabandonment of this well IHour IPrior status if a W.O. 9/10/86 J 0245 hrs. I 5"L f/8183'-8947' 8723' PBTD, Rn'g 2-7/8" compl 12.1 ppg mud POH w/DP. RU Schl, perf 8617'-8624', 8597'-8617' 8582'-8587', @ 4 SPF & 8538'-8542', 8518'-8538' & 8498'-8518' ~ 12 SPF, 60° phasing. Make gage ring/JB rn. RIH w/pkr, set @ 8556', RD Schl. RU & RIH w/2-7/8" tbg. 5"L f/8183'-8947' 8723' PBTD, RR Diesel in tbg & ann Fin rn'g 256 jts, 2-7/8", 6.5# J-55 EUE 8RD AB Mod tbg w/SSSV @ 1804', HB-1Pkr @ 8046', DB Pkr @ 8551', "D" Nipple @ 8564', TT ~ 8569'. ND BOPE, NU & tst tree. Displ to diesel. RR @ 2030 hrs, 9/18/86. RECEIVED OCT 2 9 1986 011 & Sas C~ns. C~mmission Anchorage Old TD New TD 8723' PBTD Released rig Date 2030 hrs. Classifications (oil, gas, etc.) Oi't PB Depth 9/18/86 JKind of rg Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date jTitle Drilling Supervisor ARCO Alaska, Inc Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. DATE 09-15-86 TRANSMITTAL ~ 5 762 Please acknowledge receipt and Final Prints' Schl' Open Hole Logs' One * of each 2T-16 5" DIL/SFL-GR 04-08-86 2" DIL/SFL-GR 04-08-86 5" Den/Neu (poro) 04-08-86 2" Den/Neu (poro) 04-08-86 5" Den/Neu (raw') 04-08-86 2" Den/Neu (raw) 04-08-86 Cyberlook 04-08-86 RFT Log 04-08-86 31-15 5" DIL/SFL-GR 04-06-86 2" DIL/SFL-GR 04-06-86 5" Den/Neu-GR (poro) 04-06-86 2" Den/Neu-GR (poro) 04-06-86 5" Den/Neu-GR (raw) 04-06-86 2" Den/Neu-GR (raw) 04-06-86 Cyberlook 04-06-86 Run #1 8413-8938 Run #1 8413-8938 Run #1 8413-8912 Run #1 8413-8912 Run #1 8413-8912 Run #1 8413-8912 Run #1 8420-8850 Run #1 8502-8680 Run #1 0090-7973 Run #1 0090-7973 Run #1 6190-7948 Run =1 6190-7948 Run #1 6190-7948 Run #1 6190-7948 Run #1 6190-7948 Receipt Acknowledged: ...... S~te of AK*bl~ Rathmei4~/ D ~ ~ *bl NSK Flles*bl Drilling*b1 VAult*films ARCO Alatka. Inc. is ii Subsidiary of AtlanticRichfieldComl)anY STATE OF ALASKA ALASKA L~IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHE'R [] 2. Name of OPerator 7. Permit No. ARCO Alaska, Inc. 86-46 3. Address : 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20063 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2T-16 11. Field and Pool Kuparuk River Field · I 6. Lease Designation and Serial No. Kuparuk River 0il Pool I ADL 25569 ALK 2667 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 4. Location of Well Surface: 2' FSL, 556' FWL, $ec.1, TllN, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 117' 12. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in'Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate i-'1 Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well @ 2145 hrs., 3-10-86. Drilled 12-1/4" hole to 3665'~ ran, cmtd and tstd 9-5/8" csg. Drilled 8-1/2" hole to 8612'$ stuck pipe. Sidetracked hole. Drilled 8-1/2" hole to 8426': ran, cmtd and tstd 7" csg Continued drilling to 8947'; ran and cmtd 5" liner f/8183'-8947'. Secured well and released rig @ 1430 hrs., 4-10-86. 14. I hereby certify that the foregoing is true and correct to the best ofmy'knowiedge. Signed ~Co ~ ~ Title Associate Engineer The space below fo remission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 ~o,, 7.~ .~n SN/169 Submit "Intentions" in Triplicate and "SubseQuent Reports" in Duplicate STATE OF ALASKA ALAS, ~, OIL AND GAS CONSERVATION COM~, .oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ,.D Operation Shutdown ,J~ Re-enter suspended well F-; Alter casing Time extension ~ Change approved program ~ Plugging L~ Stimulate C Pull tubing ~ Amend order:' Perforate Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~_ Inc. 117' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchoraoe. AK 99510 Kuoaruk River Unit , 4. Location of well at surface 7. Well number 2'FSL, 556'FWL, Sec.1, T11N, RSE, UM 2T-16 At top of productive interval 8. Permit number 1393'FSL, 1404'FWL, Sec.11, T11N, R8E, UM (approx.) 86-46 At effective depth 9. APl number 1241'FSL, 1340'FWL, Sec.11, T11N, R8E, UM (approx.) 50--103-20063 At total depth 10. Pool 1192'FSL, 1289'FWL, Sec.11, T11N, R8E, UM (approx.) Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 8947 feet Plugs (measured) 5913 ' - 6375 'MD true vertical 6107 feet Effective depth: measured 8849 feet Junk (measured) None true vertical feet 6040 Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" Conductor report 1lO'MD 110'TVD not available. Surface 3779' 9-5/8" 1215 sx AS Ill & 3811 'MD 2774'TVD 380 sx Class G Production 8386' 7" 300 sx Class G 8418'MD 5744'TVD Liner 764' 5" 120 sx Class C 8183'-8947'MD 5582'--6107'TV _ Perforation depth: measured None,., %,~¢¢ ~ i~ S' true vertical None ~,~A~/ ~ Tubing (size, grade and measured depth) None ?:.h:gk.,~'~ (;;:i & [::: ::; L,;;;;3, (,u,.3 ..... Packers and SSSV (type and measured depth) N o n e 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch Wel 1 History 13. Estimatedjune, 1986date for commencing operation CU ~ ' I:~ ~'~ .... (~' ~, ~ ~ ' ~ ~ ~ ~ ~,~, ~ .,,' 14. If proposal was verbally approved ~ ~ ~]% ~- ~, ~'. ~', ? :'~ Name of approver Dat ~~ ,' 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Associ ate Engineer Date Commission Use Only ( DAM ) SA/031 approval Notify commission so representative may witness I Approval Conditions of ~ Plug integrity ~ BOP Test ~ Location clearanceI No. ~ ~/.~. Approved by ~:'¢ ;"~';:;~;('~ ;~ *~t~ ~ .,~-~~-i by order of ....... · -.-'~ ~ uomm~ss~oner the commission Date ,,~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO,Oiland GaS,COmpany Well History- Initial Report- Daily instructions:' Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty. parish or borough North Slope Borough IL,as, or Unit ADL 25569 ITitle Drill Kuparuk River IState Alaska IWell no. 2T-16 Auth. or W.O. no. AFE AK0839 Rowan 34 AP1 50-103-20063 Operator ARCO AlaSka, Inc. Spudded or W.O. begun [Date Spudded 3/10/86 Date and depth as of 8:00 a.m. 3/11/86 3/12/86 3/13/86 3/14/86 3/15/86 thru 3/17/86 Complete record for each day reported 16" ~ ii0' 2145 hrs. IARCO W.I. Prior status 590', (487'), Drlg Wt. 9.6, PV 12, YP 6, PH 9.5, WL 24, Sol 6 Accept rig @ 1345 hfs, 3/10/86. NU diverter sys. 2145 hfs, 3/10/86. Drl 12¼" hole to 590'. Spud well ,@, 56.24% if a W.O. 16" @ 110' 1655', (1065'), Chg BHA Wt. 9.4+, PV 16, YP 21, PH 9.0, WL 14, Sol 5 Drl & surv 12¼" hole to 1655'. 398', .2°, S 8.4E, 398 TVD, 0.38 VS, .69S, -- 771', 14.1°, S45.2W, 767.64 TVD, 40.21VS, 35.53S, 22.30W 1134', 26.3°, S48W, 1106.50 TVD, 168.37 VS, 122.79S, 116.30W 16" @ 110' 3665', (2010'), Surv Wt. 10.3, PV 18, YP 22, PH 8.5, WL 14, Sol 7 Drl & surv 12¼" hole to 3665'. 1913' 52.8° S53.2W, 1672 89 TVD, 691 29 VS s , · · , 2802', 49.9°, S53.3W, 2225.87 TVD, 1384.68 VS, 3625', 46.8°, S53.5W, 2772.95 TVD, 1997.10 VS, 1225.53S, 1581.57W 448.93S, 525. 861.37S, 1086.35W 16" @ 110' 3850', (2017'), TOH to rn 9-5/8" csg Wt. 10.8, PV 24, YP 17, PH 8.5, WL 14, Sol 12 Drl & surv 12¼" hole to 3850', 27 std short trip, circ, TOH f/9-5/8" csg. 1604', 48.1°, S52.SW, 1476.19 TVD, 453.72 VS, 305.08S, 335.92W 2268', 56.3°, S53.6W, 1860.59 TVD, 991.97 VS, 623.21S, 772.87W 3210', 53.3°, S52.2W, 2402.89 TVD, 1759.66 VS, 1083.95S, 1389.92W 3810', 50.5°, SS1.3W, 2773.07 TVD, 2231.11VS, 1376.23S, 1760.68W 9-5/8" @ 3811' 6608', (2752'), Drlg Wt. 9.6, PV 17, YP 14, PH 10.5, WL 16, Sol 6 TOH. RU & rn 95 jts, 9-5/8", 36#, J-55 HF/ERW BTC csg w/FC 3729', FS @ 3811'. Cmt w/1215 sx ~ AS III w/lO#/sx Gilson~ ":~f-' 380 sx C1 "G" w/l% S-1 & .2% D-46. Displ using rig pmps[kb[t~p, plug. CIP @ 2045 hrs, 3/14/86. ND diverter. NU &tst BOPE. TIH, tst csg to 2000 psi DO flt equip + 10' new formatiVelY Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole 6608'. 4225', 52.2°, S50.4W, 3032 4476', 52.4°, S50.2W, 3185 4946', 52.2°, S52.2W, 3473 5419', 50.9°, S50.9W, 3767 5917', 49.4°, S47.6W, 4086 6411', 50.7°, S48.5W, 4403 .25 TVD, 2554.98 VS, 1580~8~S,~'20'12,01W . .... .75 TVD, 2753.57 va, 1707.70S, 2164.81W .16 TVD, 3125.02 va, 1940.71S, 2454.61W .28 TVD, 3494.98 VS, 2171.04S, 2744.70W .38 TVD, 3877.23 VS, 2420.57S, 3034.29W .58 TVD, 4255.89 VS, 2673.72S, 3315.93W The above is correct Signature For form preparation andi~lstrlbutlon, see Procedures Manuel, S'ecflon 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company 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 final 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 Ic°unty °r Parish IState Alaska Alaska North Slope Borough Field ILease orUnit JWoll no. Kuparuk River ADL 25569 2T-16 3/18/86 3/19/86 3/20/86 Date and depth as of 8:00 a.m. 3/21/86 The above is correct 3/22/86' thru 3/24/86 Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 9-5/8" @ 3811' 8218', (1610'), TIH Wt. 10.6, PV 11, YP 6, PH 9.0, WL 10.8, Sol 12 Drl & surv 8½" hole to 8218', raise mud wt to 11.0 ppg, started losing mud. Observe hole, TOH to 3881', circ 10.6 ppg mud around, TOH, chg BHA, TIH. 6876', 49.0°, S45.1W, 4703.40 TVD, 4611.06 VS, 2916.98S, 3574.98W 7464', 50.4°, S45 W, 5083.70 TVD, 5058.57 VS, 3233.80S, 3892.35W 7957', 49.9°, S43.6W, 5399.60 TVD, 5435.92 VS, 3504.67S, 4156.68W 9-5/8" @ 3811' 8612', (394'), Pmp'g 11.2+ kill mud Wt. 11.1, PV 17, YP 11, PH 8.5, WL 10.5, Sol 13 TIH to 5211', circ 10.6 ppg mud. TIH to 6221', circ mud. TIH to 8218', circ 10.6 ppg mud w/LCM pill. Drl to 8612', well flowing on connection @ 8612'. SI well, wt up & pmp 11.2+ ppg kill mud. 9-5/8" @ 3811' 8612', (0'), Pmp'g slug Wt. 11.3, PV 18, YP 9, PH 8.0, WL 10.7, Sol 10 Pmp 11.2 ppg kill mud. M&P LCM pill, spot same @ 6150'. Let formation heal, pmp 11.4 ppg kill mud to bit, observe well. Cont pmp'g kill mud, lost rtns. SI well. Mx & pmp 16.0 ppg slug. 9-5/8" @ 3811' 8612', (0'), Wrk stuck pipe Wt. 11.4, PV 15, YP 8, PH 9.5, WL 10.8, Sol 10 Wrk stuck pipe. RU Schl, perf DC @ 8515', perf gun stuck, POOH w/WL, WL parted @ rope socket, RD Schl. Observe well; stable. Wrk stuck pipe. IDate / ]Title Drilling Superintendent 9-5/8" @ 3811' 8612', (0'), TIH & circ Wt. 11.4, PV 16, YP 9, PH 9.0, WL 11.0, Sol 9 Wrk pipe & observe well. Rn freept, stuck @ 6520'. Perf HWDP f/8365'-8367', att to circ w/o success. RIH, find freept @ 6480', RD freept. RU & shot to BO, BO DP 60' above freept. Att to circ, no rtns. Spot LCM pill, wrk pipe & rotate, att'g to circ w/no rtns. TOH to shoe, able to circ w/ll.4 ppg in, 10.8 ppg out. Circ @ 3672', RIH 5 stds, circ, lost rtns. Mx & spot LCM pill @ 4160', build mud vol, att to circ w/no rtns. Bleed press off DP, TIH w/10 stds, circ 1 complete circ @ 5090'. TIH w/10 more stds. ARCO Oil and Gas Company 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 "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim' 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 Date and dept. as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25569 Complete record for each day while drilling or workover in progress 3~25/86 3/26/86 3/27/86 3/28/86 thru 3/31/86 4/01/86 State Alaska IWell no. 2T-16 9-5/8" @ 3811' 8612', (0'), Wsh & Rm to top of fish Wt. 11.4, PV 18, YP 4, PH 9.5, WL 16, Sol 12 C&C hole, TIH, C&C hole, TOH, PU BHA, TIH, CBU @ shoe, TIH, HIT Bridge @ 6132', PU Kelly to wsh & rm to fish. 9-5/8" @ 3811' 8612', (0'), CBU Wt. 11.4, PV 23, YP 7, PH 9.5, WL 8, Sol 12 Rm to TOF, TOH. TIH w/FTA, att to screw into fsh; hole packing off, CBU, TOH, LD fsh'g tls. TIH w/bit, rm to 6378', CBU. 9-5/8" @ 3811' 5935' PBTD, TIH Wt. 11.4, PV 14, YP 6, PH 11, WL 13.2 Sol 11 TIH to 6378', set 150 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46 @ 6375'. TOH 10 stds, rev circ, kill in plugged, CBU, lost rtns, TOH to 2800', regain rtns, C&C & build vol. TOH, LD 3½" DP. Tst BOPE. TIH w/8½" bit slow to cond & dress top of plug. 6655', (720'), POOH f/MWD Wt. 11.6+, PV 24, YP 10, PH 11, WL 12, Sol 12 RIH slow, break circ every 5 stds, btms up every 10 stds, mud cut f/ll 2 ppg - 10.8 ppg @ 5816' Wsh to 6123' tag soft cmt, wsh to 6222', cond mud & wt up to 11.5+, POOH, well flowing & swabbing· RIH, C&C, raise mud wt to 11.6, POOH to set sidetrac~ plug. RIH to 6217', set 200 sx C1 "G" cmt plug w/.75% D-65 & .2% D-46, TOH. PB @ 5913'. TIH w/BHA, tag cmt@ 5913', C&C, cut mud wt to 11·4 ppg, rtns @ 11.2 ppg. Raise mud wt to 11.6 ppg, drl & surv 8½" hole to 6655', POOH, hole swabbed first 8 stds. 5917',49.4° S47.6W, 4086.38 TVD, 3877.23 VS,2420.54S, 3034.29W 6217',46.7°, S35.1W, 4286.88 TVD, 4098.88 VS,2583.78S, 3185.96W 6527',48.6° S36.5W, 4495 77 TVD, 4322 50 VS,2768 49S, 3321 39W 9-5/8" @ 3811' 6845', (190'), Chg bit Wt. 11.5, PV 19, YP 6, PH 11.5, WL 9.5, Sol 13 TOH, PU turbine, TIH, circ out gas cut mud f/ll.5 - 8.0 ppg, drl to 6821', TOH, hole swabbing. TIH, hole swabbing, fill hole thru DP ann, TOH to chg bit & cln BHA. 6747', 49.6°, S45.2, 4639.50 TVD, 4487.32 VS, 2894.72S, 3429.90W The above is correct Signature IDate. / ., ITitle I Drilling For form preparation and di~ibution see Procedures Manual Secti'~n 10. Drilling, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History--Interim Instructione: 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 final 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 Date and depth as of 8:00 a,m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25569 Complete record for each day while drilling or workover in progress 4/02/86 4/03/86 4~04~86 4/05/86 thru 4/07/86 4/08/86 4/09/86 The above is correct IState Alaska IWell no. 2T-16 9-5/8" @ 3811' 7722', (877'), TOH Wt. 11.4+, PV 20, YP 9, PH 10.0, WL 8.1, Sol 12 Drl & surv 8½" hole to 7722'. 7336', 49.9°, S38.9W, 5020.07 TVD, 4933.80 VS, 3228.58S, 3731.00W 7631', 48.9°, S40.4W, 5212.05 TVD, 5154.97 VS, 3400.99S, 3873.93W 9-5/8" @ 3811' 8426', (704'), Short trip Wt. 11.4+, PV 13, YP 6, PH 9.0, WL 8.2, Sol 13 Chg BHA, TIH, rm f/7644'-7722', drl 8½" hole to 8426' std short trip. 8037', 47.8°, S41.5W, 5482 TVD, 5456 VS, 3630, 4073 8379', 45.2°, S50.4W, 5717 TVD, 5703 VS, 3803, 4251 , CBU, 30 9-5/8" @ 3811' 8426', (0'), Rn'g 7" csg Wt. 11.4+, PV 16, YP 6, PH 9.0, WL 8.1, Sol 13 Fin short trip, C&C, TOH, LD DP. RU & begin rn'g 7" csg. 7" @ 8418' 8586', (160'), Drlg Wt. 12.5, PV 24, YP 7, PH 10, WL 5.6, Sol 14 Rn 205 its, 26#, J-55 BTC csg w/FC @ 8336', FS @ 8418'. Cmt w/300 sx Cl "G". Bumped plug. Tst BOPE. RIH, DO cmt & FC, tst csg to 3000 psi. DO FS & new formation to 8440'. Conduct formation tst to 12.5 ppg EMW. Drl 6-1/8" hole to 8516', gas cut mud f/ll.5 ppg - 10.3 ppg. Circ thru choke & raise mud wt to 12.3 ppg. C&C mud, TOH. RIH, wsh 8516'-8418', drl f/8516'-8586'. 7" @ 8418' 8947', (361'), Prep to log Wt. 12.5, PV 25, YP 10, PH 10, WL 5.4, Sol 17 Drl 6-1/8" hole to 8947', short trip to 8418' , CBU, TOH. RU Schl~ 7" @ 8418' 8947', (0'), TOH to rn lnr Wt. 12.6, PV 26, YP 10, PH 9.5, WL 5.8, Sol 18 Log DIL/GR/SP/SFL f/8938'-8413', cont w/GR to 1500'. Rn FDC/CNL f/8912'-8413', CAL f/8413'-8912'. Rn RFT @ selected intervals, RD. WL. RIH w/BHA to 8887', wsh to TD, short trip, circ, TOH. For form preparation an~'distribution see Procedures Manual 1Bection 10, Drilling, Pages 86 and 87 DrillimgS~pe{intendent.. ,, -.,' , AtlanticRichfieldCompany Daily Well History-Final Report Inetructione: 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 ts not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field rLease or Unit I Well no. Kuparuk River ADL 25569 2T-16 Auth. or W.O. no. JTttle AFE AK0839 I Drill Rowan 34 API 50-103-20063 Operator A_RCO Alaska, Inc. Spudded or W.O. begun IA.R.Co. W.I. 56.24% IDate 3/10/86 Spudded Date and depth as of 8:00 a.m. 4/10/86 4/11/86 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our ~ Prior statue if a W.O. 2145 hrs. I 5" @ 8947' 8947', (0'), LD DC's Wt. 12.5+, PV 24, YP 8, PH 9.5, WL 5.6, So1 17 POH. RU & rn 16 its, 5", 18#, 8RD L-80 csg + mkr it. Cmt w/120 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ'd cmt, did not bump plug. CIP @ 1840 hrs, 4/09/86. Set lnr mechanically @ 8947', POH. RIH to 2000', displ'd hole w/ll.6 ppg brine, POH. Displ'd w/ diesel cap @ 200'. LD DC's. (TOL @ 8183', Mkr Jt @ 8566', LC @ 8849', FC @ 8897', FS @ 8947') 5" @ 8947' 8947', (0'), RR Diesel ND BOPE, NU tbg head adapter & lower master vlv. hrs, 4/10/86. Old TD I New TD , ~eleased rig Date 1430 hrs. RR @ 1430 Classifications (o11, gas, etc.) Oil I PB Dept~ i J KInd of rig 4/10/86 Rotary Type completion (single, dual, etc.) S lng le Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir !Producing Interval Oil or gas Test time Production Oil on teat Gas per day Pump size, SPM X length Choke size T.P. c.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature~ ~"~~/ IlOatey//~'"'~/00'~ -- ' ITM For form preparation and ~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-15-86 TRANSMITTAL # 5628 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes plus Listings: Schl: One copy of each 2T-16 04-08-86 31-14 03-30-86 ~31-15 04-06-86 ~NN-10 04-03-86 -9*** 03-27-86 Run #1 1495. O-@961.0--,~., 0 ,:~c]' ~' 7--5-~P Run ~1 1592 5-8297 00 0 0-7 7 Run ooss.o-a2oo. s ff -3-ope - Run ~l&2 0091. 0-9376. 0~a ***There was previously transmitted on transmittal #5613 a 3N-9 OH LIS tape but it was for Run #1 only. Receipt Acknowledged: State of AK ARCO Alaska. Inc. ,$ · Subsidiary of AHanlicflichfleldCompany - -~-- STATE OF ALASKA ~' O~ , ALASKA ..,L AND GAS CONSERVATION Ct.,~tMISSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER '"' 1. Drilling well ~( Workover operation [] / 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-46 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20063 4. Location of Well 9. Unit or Lease Name atsurface 2' FSL, 556' FWL, Sec.1, T11N, R8E, UM Kuparuk River Unit 10. Well No. 2T-16 11. Field and Pool Kuparuk River Fi eld -5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 117' RKBI ADL 25569 ALK 2'667 For the Month of. March , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2145 hrs, 3/10/86. Drld 12-1/4" hole to 3850'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8612'. Lost circulation; shut in well. Stuck the pipe; perf'd DP & attempted to circulate without success. Spotted pill; established circulation. Unable to recover fish. Set cmt plug f/6375' - 5643' w/350 sx Class G. Drld 8-1/2" hole f/5927' - 6844' as of 3/31/86. 13. Casing or liner ru.n and quantities of cement, results .of pressure tests 16" 62.5#/ft, H-40, weld conductor set ~ 110' Conductor report not available 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3811'. Cmtd w/1215 sx AS Ill & 380 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run CO None 1 6. DST data, perforating data, shows of H2S, miscellaneous data None - , 17. I hereby certify that the foregoing is true and correct to the best of m~ knowledge. SIGNED ¢~~~ TITLE Assoc~ a~e Engineer DATE NOTE--Report o4 his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM2/MR24 Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIV~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL []X COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 86-46 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20063 2' FSL, 556' FWL, Sec.1, T11N, R8E, UM 4. Location of Well Surface: 5. Elevation in feet (indicate KB, DF, etc.) RKB 117' 6. Lease Designation and Serial No. ADL 25569 ALK 2667 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2T-16 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). The subject well is being abandoned and sidetracked due to junk left in the hole. Hole conditions caused thl drillstring to become stuck. Several attempts to free the drillstring proved unsuccessful. The drillstring was backed off above the free point and the junk was left in the hole. Current Well Geometry: o spudded ~ 2145 hrs, 3/11/86 o 16" conductor at 110' o 9-5/8" surface casing at 3810' o 8-1/2" open hole total depth: 8612' o backed off drill string @ 6420' o left fish in hole Verbal approval was received from Mr. Bill VanAllen on 3/26/86 to plug the existing wellbore and sidetrack 2T-16 as follows: 1 , "G" w/2% CaC1 2' WOC. 2. Drill cement plug to prepare for sidetrack. 3. Sidetrack well paralleling existing wellbore. 4. The new bottomhole location will be within the permitted bottomhole target of 2T-16. 14. I hereby/~[tif/~ that the forego, j~is tr~e~pd correct to the best of my knowledge. , Signed ~,Z/, ~,¢_,/~ / Title The spac(e I: e~low for Co/mission use Condition/s Run in hole w/open ended DP, lay cement plug f/6385' - 6000' (385' plug) with approximately 130 sx Class of APproval, if any: Regional Dri 11 ing Engineer Date / / Approved by. cOMMISSIONER the Commissio~ ~ t, i;-:, ;: , Date Form 10-403 Rev. 7-1-80 (HRE) SN/140 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 COMPLETED WELL [] OTHER [] 4. Location of Well Surface: 2' FSL, 556' FWL, Sec.1, T11N, R8E, UN BHL: 1142' FSL, 1117' FWL, Sec.11, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) __ RKB 117': PAD 82' 6. Lease Designation and Serial No. ADL 25569 ALK 2667 7. Permit No. 86-46 8. APl Number 50- 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2T-16 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 [] [] Other [] Pulling Tubing [] Pull 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). Due to lost circulation zone encountered above the Kuparuk Sand, ARCO Alaska, Inc., proposes: 1. Run and cement 7" casing as per drilling permit ~ 8550'MD 2. Drill 6-1/8" hole to original planned TD. Run and cement a 5" production liner at 8350' - 9103 'MD as follows: Pipe: 5", 18.0#, L-80, LTC, 8rd Cement: 100 sx Class G 4. Complete well as per drilling permit. 14. I h~r, eby certify that the'~ore~oing is true and correct to the best of my knowledge. Signed~ ~)~ Title Associate Engineer The space below or Commission us~ Conditions of APproval, if any: Approved by A, pproved Co~H7 ~eturn~d By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 (JFB) SN/139 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · February 19, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AlaSka 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 2T-16 ARCO Alaska, Inc. Permit No. 86-46 Sur. Loc. 2'FSL, 556'Fk%, Sec. l, TllN, RSE, 1/M. Btmhole Loc. l142'FSL, ll17'F%~L, Sec. 11, TllN, RSE, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. i~tru~Y/~ygurs, C. V. Cha~r-tgn/' Chairman of Alaska Oil and Gas Conservation Commission BY O~DER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B~._ ,00360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 February 3, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2T-16 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill 2T-16, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on February 24, 1986. If you have any questions, please call me at 263-4970. ~S~e r e 1 y, : /,- . . '.~, , . .-~, '/J. B.~ K/ewin .~×Regional Drilling Engineer JBK/LWK/tw PD/L228 Enclosures RECEIVED Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 42£-. PERMIT TO DRILL 20 AAC 25.005 '~/4 /' la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE j~]~¢20,,)STRAT,FG,~j~APH iC REDRILL [] DEVELOPMENT OIL J~X ~'// DEEPEN ~ DEVELOPMENT GAS ~ MULTIPLE ZONE ~:~, 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 2' FSL, 556' FWL, Sec.1, TllN, R8E, UM r~ ~'~~ ~ 'T~ ,~] Kuparuk River Unit At top of proposed producing interval ~ ~;~ ~ ~ : : ~ Kuparuk River Field ~¢; ' ' ~ ~ Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 117', PAD 82' ADL 25569 ALK 2667 12. Bond information (see 20 AAC 25.025) Federal Insurance Company - Type 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 1117 feet 2T-17well 25' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9103 ' MD,~ 6098' TVD ~ feet 2560 02/24/86 19. If deviated (see 20 AAC 25.050) J20. Anticipated pressures 2950 psig~__¢0OF 'Surface KICK OFF POINT 450 feet. MAXIMUM HOLE ANGLE 53 OJ(see20AAC25.035 (c) (2) 3387 psig~ 5976 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH OUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 12-1/4" 9-5/8" 36.0¢ J-55/HF-EEW BTC 3545' 35' I 35' 3580'1 2791' 1065 sx AS Ill & I I ~ 380 sx Class G blend 8-1/?' 7" 26.0¢ J-55/HF-EEW BTC 9069' 34 II 34' 91034 6096' 300 sx Class G 22. Describe proposed program: a, nc., proposes to drill a Kuparuk River Field development well to approximately 9103'MD(6096'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 BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to :5000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2950 psi. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3,500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented.tannuli through the permafrost interval. 2T-16 will be 25' away from 2T-17 at the surface. There are no close¢'~wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) · 23. I hereby certif~,44~at the foregoing is true and correct to the best of my knowledge SIGNED /~' TITLE Regional Drilling Engineer DATE The space bel,~ for~,~g~m/l~ission 6s6 CONDITIONS OF APPROVAL Samples required Mud log required I-lYES J~N O J~]YES .~NO Permit number .. Approval date ,o !9/86, Form 10401 (I-7~i) pD/pD~_ / / Rev_ 7-1-80 / / Directional Survey required I APl number [~.YES I-]NO 50- /0_7 - ,¢~0 0 (~ 3 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission February 19, 1986 Submit in triplicate PERMIT TO DRILL 2T-16 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1 Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A /2" or 2-7/8" tubing. subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. Gas Cons. A~chomge ARCO ALASKA. INC. /"1~, PAD 27. WELL NO= 16 PKOPOSED~ ~ ~ ~ - KUPARUK _F_I. ELD ,' __ NORTH SLOPE,.~ ALASKA Z__../,,_ \ /~-~ ._. 0 ...... SURFA~ ......................................................... KOP TVD=450 TMD=450 DEP=O g. . · t5 BUILD 3 I:)E:~ 1000 ~,. ................. PER 1 O0 FT ............... ; .................. ....... _ ' -'2~ 2.1 . . ' . 27'.:: , ' ' : ' ' : ' ' ' 33--BASE PERHAFROST-- TVD-I$61 THD=1636' DEP-356 '~ 39 TOP UGNU SNDS , TVD=I 696 THD=1807 DEP=462 45' ' ' ' ~$ EOC TVD=I 980TMD=222..5 DEP=767 2000 ...... :...::.._ _. "'~Top W S^K SNDS TVD 2251' TMD=2677 DEP-1130 · ......... : ......... : -,~-K_.12..-~TVD=2591 TMD=3246'DEP=1585 "'~./" 9 5/8' CSQ PT . 4000 ......... .............. ~~,. ~ ::: ~'~-; Y '" K-5' _ _ :_TVD=4311 THD=6120 DEP=3888~~, ' - ", AVERAGE ANGLE' ' 5000 T/ZONE:C TVD 5811 'THD=862Z DEP 5897 . .. 'T/ ZONE A TVD 5~66 'THD=SZ19 DEP 5970 ". 6000 ...............TARGET CHTR TVD 5894 _THD=SZ66 DER~6008 B/ KUP SNDS TVD=Sgz6 THD=890~ DEP-6117 TD (LOG PT) TVD=6096 THD=910~ DEP=62Z8 . . .... 7000 I I I I 0 1000 2000 3000 4000 ' VERTICAL SECTION 1 I I 5000 6000 7000 HORI 7-ONTAL PRojEcT/ON S .LE 1. IN. = 1000 FEET PAD 21. WELL NO, .i6' ,PROPOSED'. :-- ..i';·~._:- _-'. ............. .' ........ KUPA~UK F_IELD. NORTH SLOPE, ALASKA.-/ ~]kc X ._ EASTMAN WHIPSTOCK. ................................... WEST-EAST ........................ 5000 4000 ~5000 ..... 2000 ,._ 1 000 0 1000 1 000 ' ! .............. ! I ' ' I I .... SURFACE: LOCATION' ............. . .............. 2' FSL. $~' FWL .................................... SEC._. ! .. T 11 N. ROE ............................... _." 'L": -'-_ ..... -_.-:'-': ........ : :-'F: .... /:-L-.::.'- _' ' . ...... ................. : ............ i ' -. . · _ . _ ............... 1000.,_.,'. - ............. · ............ · .................. ,, . ..... Z , 2000 --I ' ...... r-~ ..- . ;~000,__ ................ . ; .... _ ..... .,.: ............................ : ...... . ..._.- ._:- - ;.. .:. ...... ........ .' :'"' :-. ............. '. .. -.. :- ':' ~_'-:-::: ..... "-:'::'-.-:":-'L: ..... -: ....... 2'.-.,'"'_':L'.'-'~'-:'.:.- .... AhChorago' ..... ........... :.'-:'..TAROT ~NTER ...... ..... 4000 ............ ' ......................... TVD=SS94 ..... T~D=8Z~ ...... ............ DEP=6008 ....... T~GET LOCATION ...... 1320' - FSL. 1320' FWL _ ...... WEST -- 4516 . _ " ' ID LOCATION~ 1142' FSL. 1117' FVL ' -: ........ 5000, SEC. 11. TI1N. R8E ........ : ............. ................................................. ........................................................... . ....................... ....... ~ ........... ..... ...... Alaska-Oil.& ~as L;ul~s. L;or, iinissiori ". ..... "' S 48 DE(:;'44 HI N W ' ~' 6008, ..... CTO .TARGET) ~oo oo i' ~oo 500 isoo ?oo ~oo ~oo ~ooo 100 {~00 "'i J ~00 r. tSO0 ?oo ~00 go0 '1 000 KUPARUK RIVER UNIT 20" -DIVERTER SCHEMATIC i i 8 DE SCR I P T I ON I. IG' C~CTOR. 2. TAt4<O STARTER HEAD. 5. TAI,,I<O SAVER SUB. 4. TANKO LOWER QU]CF-CONNECT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 6. 20" 20eX:) PSI DRILLING SPOOL W/I O" OUTLETS. 7. I0' NCR BALL v~vE~r DIVERTER LINEI~,; VALVDt; OPEN AUTOMATICALLY UPON CLOSURE OF ANN.X. AR PREVENTER. 8. 20" 2000 PSI AI',t~LAR PREVENTER. MAINTENANCE & OPERAT,]ON' RECEIVED I. UPON INITIAL INSTALLATION- CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. 2. CLOSE At, I'gULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 5, CLOSE AIklNULAR PREVENTER IN THE EVENT 'THAT AN IIkFLUX OF WELLBORE " FLUIDS OR GAS IS DETECTED. IF .. NECESSARY, .i CLOSE APPROPRI ATE VALVE TO ACHIEVE DO~I'~IND DIVERSION. DO NOT SHUT IN ~ELL 6 I. 16' - 2000 PSI 2. 11' - 3K)O0 ~I ~. I1' - 3C00 PSI 4. 13-5,/~' - 5000 5. 13-5,/8' - 5000 KILL LINES 6. DIAGRAM #1 DO0 PSI RSRRA BOP STACX TAt,,KO0 STARTIN~ ~ CASING ~ X 13-5/8' - 5C~ PSI SPAC~ SPCX]_ PSI PIF~ P¢~ PSI DRILLZNG ~ W/O-EKE AND 13-5/8' - 5000 PSI ~ RA~ W/PIPE R,N,4S ON TO=, BLIND RAMS Ctg 80TTOVL 13-5/8' - 5OOO PSI ANSLLAR ACC1JVULATOR CAPACITY TEST I. Cl-EQ< AM:) FILL A~TCR RESE:RVOIR TO'~ Lb-VEL WlTN NYDRAli. IC FLUID. 2. ~ THAT A~TCR PRIESSU:~ IS ~ PSI WITN 1500 PSI DOCe~T~ CF ~ RE:GLLATOR. 3. OBSF_RVE TI~E, q-F_N GL__rISE ALL UNITS SI~LE. TAAE(1JSLY AND RE~ ~ TI~CE AND PRES,gJRE R!BCAINING AF-F'c.R ALL UNITS ARE CLOSED WITH CHARGING PLk~ (I~F'. 4. RE~ CN NADC R'EPORT, ~ ACX2F_PTAI3~_E LO/I~R LIMIT IS 45 SE~ CLOSING TI~,~ AN:) 12.00 PSI RE]V~AINING PRE~. 5 4 2 8. 9. · .10. il. 13. Alaska Oii& Gas c, 13-5/8" BOP STACX TEST FILL BOP STACX AN:) C:NCi(E MANIFOLD WITH ARC'TIC Q-ECX THAT ALL LOCX OO't~ ,SCREY~ IN ~ELL.NEAD AR~ FI~LY RETRACTED. SF_AT Tr. ST I::'LLJG IN ~E3..L.J-'F_AD WITN ~ING JT ~ R'LIN IN LOSXDC:V~ S~. LINE VALVES AI:MACENT TO BOP STAEX, ALL OT~ VALVES AhD Q-O<E5 SHOULD BE CPEN, PRESSt. IR~ UP TO 250 PSI AhD HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 300~ PSI AND HOLD FOR !0 MIN. BLF~-n PRES,9.A~ TO 0 PSI. OPEN ANtd.LAR P.~-VENTER AND MANJAL KILL AhD LINE VALVES. ¢.,_OSE TOP PIPE P, AA~ AN~ NCR VALVES ON KILL AN:) CHOKE LINES. TEST TO 250 PSi AND 3000 PSI AS IN STEP OONTIhi. E TESTING ALL VALVES, LINES, AhD C~6KES WITH A 250 PSI LC~ ~ 3000 PSI HI6H. TEST AS IN STEP 4. DO N2T .PR>ESSLRE TEST ANY ~ THAT IS NOT A FULL CLOS]N~ POSITIVE SC_AL C~ FI.NC?ION TE$'[ CNCKE$ TriA-f DO NOT FCI_LY CLOSE. OC~EN TOP PIPE RAM~ AND CLC28E__ BOT'rCM PIPE RAMS. TEST BOTT6~ PIPE RAMS TO 250 PSI AhD 3000 PSI. OPEN BOTTCI~ PIPE RAMS, EACX OUT RUNNIh~ JT AhD (1.OSE BLIND RAM5 At~D TEST TO 250 PSI AhD .3000 PSI, OPEN BLIhD RAMS mN:) R~z'mIEvE TEST PLL~S. ~4AKE SURE MANIFCI_D AND LINES ARE F'dLL. OF FLUID. SET AU. VALVES IN DRILLING POSITION. TEST STA, kDPIPE VALVES, KE'J: I Y, KI:'ll Y C:O(~S, DRILL' PIPE SAFETY VALVE, AN:) INSIgE: BC~ TO 2..50 PSI AN:) 3000 PSI. RE~:RD TEST IN'=a:~ATION ON BLO,¥Olff ~ TEST Fa;~, SIGN, A. hD SEN3 TO DRILLINS SUPERVISDR. PERFCl:~ ~TE BClC'E TEST AFTE~ NIPPLIN3 UP AN:) ~,F_.EKLY TNEREAFq'ER F'Lt, JEWIONALLY OPEAATE BOPE DAILY. 510084001 REV. 2 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2T Pad (Wells 2 - 17) Dear Mr. Chatterton- 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 If JG/tw GRU13/L44 Enclosure RECEIVED F~ ~ ~; 0 5 Alazka Oil & Gas C0:~o. L,u~:;~ ....... ARCO Alaska. Inc. is c, Subsidiary of AtlanticRichfieldCompany i , 5 6 7 I$ 12~ W~, . . I, I 6 i '15. - LOCATED IN PROTRACTED LOCATED IN PROTRACTED .... SEC. I, TIi N,R8E, U.M. SEC. I , TI I N, R8E, U.M. · , :. Z - Y = 5,970,382.43 LAT. 70°19'49.!287" 10 - Y = 5,970,132.65 LAT. 70°19'46.6719" X = 498,944.93 LONG. 158'00'30.807" X = 498,945.27 LONG.150°O0'30.796" . . 402' FSL, 556' FWL OG = 77" PAD = 81.5 152'FSL, 556' FWL OG · 76.0 PAD · 81.7 3 - Y = 5,970,357.42 LAT. 7C~'19'48.882B'' 11 = Y = 5,970,107.71 ' LAT. 70019'46.4267" X = 498,944.91 LONG.I~=DO'30.808" X ~ 498,945.10 LONG.150°O0 ' 30. 801" 377' FSL, 556' FWL OG = 77' PAD = 81.5 127' FSL, 556' FWL OG ~ 75.9 PAD = 81.7 4 - Y = 5,970,332.46 LAT. 7719'~.6372" 12 - Y = 5,970,082.58 LAT. 70~19'46.1794" X = 498,944.84 LONG. 15O=DO'30.809" o X = 498,944.98 LONG.150~O0'30.804" 352" FSL, 556' ~L OG = 77" PAD = 81.6 ~ 102' FSL, 556' FWL ~ · 75.7 PAD - 81.7 5- Y = 5,970,307.52 LAT. 7G~19'~.3919'' ~ 13- Y = 5,970,057.59 ~T. 70°19'45.9336 - X = 498,944.91 LONG. i5~00' 30.808" ~ ~ X = 498,945.08 LONG. 150000. 30.801" 327' FSL, 556' FWL OG = 77" PAD = 81.6 o ~O ~ 77' FSL, 556' FWL OG 6 - Y : 5,970,282.50 LAT. 7~19'~ 1459" ~ ~ 14 - Y ~ 5 970,032.60 LAT. 70°19'45.~79" · ~ ~ t~ o ' · - X = 498,944.95 LONG.150=DO'30 806" ~ = ~ X = 498,944.91 LONG.150°O0'30.806" 302' FSL, 556' FWL OG = 77" PAD = 81.7~ ~ ~ o~" 52' FSL, 556' FWL OG = 75.3 PAD : 81.7 7 - Y = 5,970,257.54 LAT. 70=19'47.9003'' ~ 0 ~ ~ 15 - Y : 5,970,007.69 LAT. 70°19'45.4428'' X = 498,944.95 LONG.150=DO'30.806" ~ ~ ~ X 498,944.93 LONG. 150°O0'30.806" 277' FSL, 556' FWL OG = 77" PAD = 81.6 ~ 27' FSL 556' FWL OG = 75.2 PAD = 81 6 ' 8 - Y = 5,970,232.63 LAT. 7~=19'47.6553" .~ 16 - Y = 5,969,982.85 LAT. 70°19'45.1985" ' X = 498,944.96 LONG. 1~00' 30.806" ~ ~ o X = 498,944.88 LONG. 150°00' 30.807" · 252' FSL, 556' FWL 0G = 76.~ PAD = 81.6 ~ 2' FSL, 556' FWL 0G = 75.1 PAD = 81.7 9 - Y : 5,970.207.62 LAT.' 70~!9'47.4093'' c~ LOCATED IN PROTRACTED · X = 498,945.01 LONG. 15G:DO'30.804" ~ SEC.IZ, Tl l N, ESE, U.M. 227' FSL, 556' FWL OG = 76.3 PAD = 81.6 17 - Y : 5,969,957.72 LAT. 70°19'44.9514.' X : 498,944.94 LONG. 150°00' 30.805" 23' FNL, 556' FWL OG : 75.0 PAD : 81.6 NOTES , . , .~.~,.~ ~ ~ I. ALL COORDI NATES ARE A.S.P., ZONE 4. :; :,,' ' '., ~ ' 2. SECTION LINE DISTANCES ARE TRUE. .~ "' D. HORIZ; POSITIONS BASED ON TEME MON~ ZT-EAST~2T-WEST ~ 2T-MIDDLE PER LHDEASSOC. , 4. VERT. POSITIONS BASED ON TBM's 2T-6 ~ N19+75, EI1+52 PER F.R.B. ~ ASSOC. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-5140 rev. ,,, CERTIFICATE OF SURVEYOR: i ~EREBY CERTIFY THAT t AM PROPERLY R~ISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE Of ALASKA ~D THAT ~.~ Ur I t~S PLAT REPRESENTS A LOCATION SURVEY M~E BY ME OR UNDER MY SUPERVISION, AND ~ TNAT ALL DIMENSIONS AND OTHER DETAILS ~ ~ ~m KUPARUK PROJECT ~ ,~ ~.- _Lq ................... t.~' ~ ~. s;~. DRAWN WM UNILL ~I/L ~l UU~UUU/U~ I,~. ~ECKED SH f ~ 8SSOG, .,~ ~ ~.,., ,~z, AS- BUILT LOCATIONS *. 5~5 Arctic Boulevard, Suite 201, Anchorage,, Alaska ~9503 IIS~LE N.T.S. i · CHECK LIST FOR NEW WELL. PERMITS Lease & Well Company ... ITEM APPROVE DATE (.'..) Fee (2) Loc (2 thru 8) (3) Admin ~ 'L--II-,.~[ 9. t ru 12), o. _X:: (10 and 12) 12. (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. YES NO 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ....................... 3. Is well located proper distance from property line 4. Is well located proper distance from other wells .. 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore pla~ ~?.clud. e.d..., i i 7. Is operator the only affected party .......... 8. Can permit be approved before ten-day wait ................ 22. 23. 24. 25. 26. 27. Doe operat have bond in force s or a ..... .. ....... . ......... ..... ..... Is a .conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... 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., ..................... Wi].l all casing give adequate safety ~n collapse, tension and burst.. I8 tht~ wull to bo kiekud o££ £rom an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ..... ~,- Does BOPE have sufficient pressure rating - Test to ..,~O(DC) ;'sig Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS Additional Remarks: 0 _Geology, A. Engineering WVA~ MTM ~ JAL .. rev: 03/13/85 6.011 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. L i S T ~, ~ - VEi~ZC;IC&T I3N LiSTZN- CORF SEqV!CE N~ME VEqSZJN ~ : Fj&T~ : MAXIMUM L~NGTH : FILE TYPE : PR~ViDUS ~IL~ : -,--,-"' INF:3RM,&TiCN RECORDS '!4 N ,_: ',I C3NTENTS UNIT TYPE S~TE SiZE C3DE C~,~ : ~RC3 .&LaSK~, iN-. O00 030 OlS 065 i.~N : 2T-16 0 O 0 300 00,5 06 =N : KJP~RUK OOJ DO0 008 055 ~N3: 8~ OOO 000 002 065 TS ~ q: 11 N 0 O 0 OO O O 04 O 65 5f'T: I 000 900 002 COJN: N:DqTM 5LOP~ OOO OOO 012 065 ST~T: ALASKA 000 OC.3 306 065 ',iN = q CONTENTS UNiT TYP= 'CTE SIZE CODE tV~ OIO.M02 V~!FIC~!ION ti$71~ ~,~GE 2 JO5 NUMBER AT aCC: 71405 RUN ,u DAT~ LOGG~m: ~ APR 86 LDm: T CASING : 7.000" 9 84!3' - 51T SIZE : 5.1.25" TO 89~?' TYPE FLJZD : LSND DENSITY = 1Z.5 LB/G i~M = !.160 S 71 DF VIS~,DSZTY~ = 45 · 0 S RM'F,. : 0 .850 D 71, O;~ PH = lO.O RMC : 2.Z20 'D 71 DF :LUZO L3SS : 5.~ C3 .i~1 AT '~,~qT : 0.57~ ~ 150 OF ~TRIX S~N~STDNE <~;~-..-,- THIS OATA HAS N2T 8EE~'~ OE TH SHiFTeD - JVERLAYS FiEL~ PRINTS ~::',:?,:~X~ ,-~- -,..,- , ....- ......... ,..,..,. ~, ........... ,.., .... .~..,. .... ,..,. ;~ ~:~ ,,..,..,. ..... .... ,~, .~ .,. ~ ..... ,. ?,~ .,. ¢,: ~k ~;~,,.,,..,.'~ .,. ~,: ,,..,~ %~ ~ "'.,. '~. .,. '~ ::: '*'.,. ~;~ ~;: ~ ~,-" .......... -~- -,- .,- ~,." .......... -,- ~ .,- ,~-"' '"-,- :k - ~'~TrO~ LiSTiNg VO 0!0 MO? V~-~iFI~ :F'~GiNE'.=R CDULD "4DT SET 3OW",,~ TO TS O~,4 M:~IN PASS:. ~DPROX :::'~'-,- >IER,SE mSI?,~TS~ ...... .,..,. ~LU, ZLM~ ILS, A~D SP i,~ "' ,S CH LU~'IBE R 5"' R L'" " ' "' ,.. uGS iNCLUD~D ~,~t~.T!'"i TMiS qAGNfT.LC TAP~: ,,, ,,-"' OUaL rNDU;Tr3~ S~R'TC.a, LLY.~ r-OCUS~-?~_ _~ 3G COIL) :;: 3~TA ,~VAILABLE:., 891P'._ T3 B~13 .... -,- _VP OiO.~OZ V~I~!C~TI~N LiOTiNS ~G~ ~ TyD~ DaTJM 3 P F:" ~'I FI CA TiON '~N £ M $~RVISF_ i ! 4 i 1 66 66 73 ~5 55 ,5 6 F~NTRY 1 0 9,3 K $ JN!T ~P'! apl apl LOC- TYPE CLASS MgD =T O0 000 O0 O O 4 34, M M O 0 22 :O O 1 J 0 a OMMM O0 120 44 0 O 4 MV O0 O!O 31 0 O 4 S~PI O0 310 Ol O 0 4 GAO1 O0 310 Ot 0 0 4 I .'4 O 0 280 01 0 0 4 S/C 3 00 350 02 0 O 4 3 /C 3 3 O 355 01 9 0 4 O0 423 Ol 9 0 4 O0 000 O0 0 O PO O0 SO0 O0 0 O 4 2PS O0 330 31 0 O 4 CPS JO 330 30 0 0 4 g~oi O0 310 91 3 0 4 R'~DR PROCESS CDDE (OCTAL) 6~ O0000000000OO0 53 OOOO0000000000 58 00000000000000 58 OOO000000OO00O 6S OOO00000000000 5a 00000000000000 55 OOO0000OOO0000 58 OOOO0000000000 69 OOOO0000000000 58 00000000000000 5~.. ~'~0300000000000 58 OOO00000000000 6~ OOOOOOO0000000 5~ O0000000000000 68 O00000000OO000 6S OOOOOOOOOO0000 2EPT ~j~ 3~61.OOOO SFLJ 13.4707 ~R -999.2500 3R43 -999.2500 NCNL 8'900. O000 SFLJ -30. 75'~' 7.,, 2.4319 2'9.589'5 NCx_ 5503.J300 SFLJ -31.0539 2.4397 41.1133 NCN_ 5700.0390 SFLJ 2.429~ 37-~3 3.7073 1il.5~93 GR -999.2500 NR&T -999.2500 ~C'~L 3.5350 iLS 193.5273 SR 0.3034 N~aT 2833.5300 FCNL 3.7594 ill 99. :~023 G~: ~ 91:A~ N~~ 2!~5.5300 ~C~L ~.774~ ~D.152~ -O.O'D05 NR~T 2.2756 !LM -999.2500 C&Li -999.2500 RNR~ -999.2500 GR 2.9084 !tM 1Z4.1323 C~Li 1137.5573 SR 2.9t43 iL~ 99.9923 C&tl .3.2~24 RNR~ 571.31£5 GR 3.1331 !t~ 95.!523 C'~L£ i. 933 ;~ RNR ~ 2.9475 -999.2500 -999.2500 -999.2500 2.q944 5.9093 2.4631 -999.2500 3.0081 5.3562 3.2698 -999.2500 3.3352 :5.4109 2.7991 DEPT SP NPdI DEPT 3EPT SP S P 3EPT ~P~i SP 3f~T 3E~T 35,400.4 3 -31 2 30 3500 -Ii3 2 30 2 6Z 83OO -'999 -99 '~ -~99 - 999 -999 -999 8100 -999 -999 -~)99 -?99 - 999 -'~99 7900 - -999 -9 ~ 9 -999 -'~ 99 - 99'9 7 700 .O000 SFLO · 8076 GR ,~41 NC~q' · 97~)5 GR ,797! 9Rd3 ,7129 ,0000 ,1592 NCNL .OOO0 SFLj .2500 GR .2500 3Ra3 .2500 NCNL .0000 .2500 .2500 DRHO .2500 NCNL .0000 SFLj · 2500 Gq .2500 DRH3 . 2503 "" · 0000 SFLj · 2500 G~ .2503 NCNL .2500 SR .2503 DR~3 .2500 NCN: .3000 SFLJ .25 .JO00 S-Lo .2FOO JR~3 7503.0033 S.=LJ - ~9 ~. 2.~0~,, 24i5.5000 13.i$t6 iL3 60,1992 Si -0.0078 NRAT 3117,5000 FCNL 35,.574P ,51.5742 -0.0122 NR~T 2723.5000 ~CNL 2030.6875 ILO 5.3.8867 G~ -0.4529 NR~T 1291.5~75 FCNL -999.2500 ILO -999.2500 GR -999.250C NRAT -9!)9.2500 FSNL -999.2500 iL3 -999.2500 G~ -999.2500 NR~T -999.2500 FCNL -999.2500 ltd -999.2530 GR -999.2500 NR~T -999.2500 :CNL -999.2}00 -9~9.2500 -999.2500 NRAT -'999.2500 ~CNL -9':? 9. £ 530 iLO -999.2500 -999.2500 NR&T -999 · 2500 .z.. -~99. 2500 32 -999.2500 N~&T -9~9.2500 PC~L -999.2500 iL9 -9~9.2500 'R -9~9.2500 NR&T -9~.2500 FC~:L -999.2500 iL3 -9)9.2500 3R i2.0545 iLM 60.1992 CALl 2.6i52 RNRA 12~3.6375 GR 1~..2.:135 !LM 51.5742 CALl 2.6g09 RNR~ 1137.6575 GR 2000.6B75 ILM 63.8867 CALl 4.39'14 RNR~ 322.8906 GR -999.2500 ILM -999.£500 C~tI -999.2500 RN~A -999.2500 GR -999.2:500 -999.2500 CALl -999.2500 RNRA -999.2500 GR -99~.2500 ILM -999.2500 C~LI -999.2'00 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C~LI -~9.. .:~'500 RN~ -999.2300 GR -999.2300 ILM -999.2500 CALl -999.~500 RNR~ -99'9.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 ,RNR~ -~9.2500 OR -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2~00 GR -999.2500 -999.2~J0 C.~Li -999.2500 12.0!76 5.1218 2.5051 -999,2500 14.~6.29 5.3210 2.3928 -999.2500 2030.5875 5.371.8 4,0007 88.3398 -99'9.2500 -999.2500 -999.2500 99.5898 -999.2500 -999.2500 -999.2500 134.5625 -999.2500 -999.2500 -999.2500 15.3.5875 -999.2500 -999.2500 -999.2500 122.8398 -999.2500 -999.2500 -999.2500 79.5273 -999.2500 -999.2500 -999.2500 73.4023 -999.2500 -999.2500 -999.2500 57.3398 -999.2530 -999.2500 SP qPHi RHJ3 NPHi NPqi RHJ3 NPHI S P De~T qPHi JE2T SP SP -'?99. - 99'9. 150 O N C N L 7500.0000 S;Lj -999.2500 -999.2500 OR~O 7400.0000 S~LJ -999.2500 SR -999.2500 DRM3 -999.2500 NCNL 7300.0000 SFLJ -999.2~00 GR -999.2500 Oq43 -999.2500 qCNL 7200.0000 SFLJ -'~ 99.2500 GR -999.2500 DRH3 -999.2500 NCNL '7!00.0000 SFLJ -999.2500 GR -999.2500 OR~C -999.2500 NCNL 7000.0000 SFLJ -999.2500 -999.2500 -999.2500 NCNL 5900. OOOO .SFLJ -99:9.2500 GR -999.250'3 ORW3 -9')9.,2500 NCNL 6800.0000 SFLJ -999.25'~0~ SR -999.2500 OR'iD -~99. 2500 NCNL A7C,J.OO03 SFLj -999.2500 iSR -9'99.2500 OqH] -~.2500 NC'~_ -999.250J -9~9.2500 -9 ,~ -99 -99 -99 -99 -99 -9,~ -9) -99 -99 -99 -9~ -99 -9~ '-9:2 -99 -99 -99 -99 -99 -9~ -99 -9 -99 -99 -99 -9~ -99 -99 -99 - 9 ) -99 -99 -9~ -9) -99 9.2500 ~ $ 0 -,,, :3. 2500 9.25 O0 9.2500 9 25 9.2500 ~00 9.2500 9.2500 9. 2500 9.2500 9.2500 ~500 9.2500 9.2500 9.2500 3.2500 9.2500 9.2500 ~.2500 9.2500 9.2500 9.2500 9.2500 9.2500 9.2500 9.2500 9.2500 :~.2500 9.2500 9.2530 9.2500 ~.250J 9.2500 9.2500 9.2500 9.2500 9.2530 ~.2500 9.2530 9.2500 N R '~. T ~CN~ NR:~T ~CNL NR~T FCNL NR&T GR NR~T =CNL ILD GR NRAT =CNL iLO FCNL IL3 NR&T ILD NR&T :CNL iLD =C'qL -999.2500 R NRA -999. 2500 GR ,-99~.2500 ILM -99'9.2500 C&Li -999.2500 RNR& -99'9.2500 GR -999.2500 iL~ -99~.2500 · CALl -99:9.2500 RNR& -999.2500 GR -999.2500 !LM -999.2500 r~Ll -999.2500 RNR& -999. 250:0 ,~ -999.2500 ILM -999.2500 C~LI -999.2500 RNRq -999.2500 GR -99'9.250,3 -999.2500 CALi -999.2500 RNR& -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNR& -999.2500 GR -999.£500 !L~ -999.2500 C~LI -999.2500 RNRA -999.2500 GR -999.2500 iL~ -999.2500 C&Li -999.25J0 RNa& -999.2503 ,3R -999.2503 -9'~9.2500 C~LI -9'99.2500 -999.2500 -999.2500 IL'4 -929.253:3 C&LZ - 999.2500 5!. t 055 -999.2500 -999.2500 -99'9.2500 75.0898 -999.2500 -999.2500 -999.2500 73.0273 -999.2500 -999.2500 -999.2500 83.0898 -999.2500 -999.2500 -999.2500 59.1055 -999.2500 -999.2500 -999.2500 59.6992 -999.2500 -999.2500 -999.2500 72.0895 -999.2500 -999.2500 -999.2500 85.3398 -999.2500 -999.2500 -999.2500 80.5273 -999.2500 -999.2500 -9~9.2500 52.5273 -999.2500 -~9.2530 -999.2500 76.2148 .,- . ., ...... . L3 -9~.2~:J IL -99~.~500 LV:~ 010.~02 VERIF2C~TI3,,i LISTTN3 P~aE 7 9~T 6300.0000 SRLj SO -999.2500 GR 9H3£ -999.2500 ORHO ~P4i -999.2~00 NCNL SP -999.2500 7HD~ -99'9.2500 ~P~l -~99,'2500 SE~T 6100.0000 SFLJ S? -99'9.2500 GR ~95 -999.2500 OR,D NP~I -999,2500 NCNL 3E~T 6000.0000 SP -999,2500 ~05 -999,2500 ~P~! -99'9.2500 2E?T 5900.0000 SFLJ SP -999.2503 S~ qm.]3 -999.2500 DR~S ~Pfli -999.2~03 NCNL SO -9~9 ~50 ~H35 -99'~.2500 O~] Nm4i -999.2500 NCNL 5700.3000 S~LJ -~99.250J -999.2500 -999.2500 O = :::' T 5500.0000 SFLJ ~ ;"i 35 -999.2500 N~,i -?99,2500 DE~T 5500.0300 SmLj SP, -~99.='500 ~2~ -999.2530 '4P~i -999. !500 -9:)~.2300 G7 -999,2500 NRA. T -~99 PSOO ~rN~ - 9 ~ 9 ·~ ~ "'q.. 00 I L iD - 9 9 '~ . '~ .. =500 GR -999. 2500 -9 ~9. 2500 ~CNL -9~9,2500 ILO '-999,£500 S~ -999,2500 NRAT -9'99.2500 PCNL -999.2500 iLO -999.2500 GR -9~9..2500 NRAT -999.2500 =~ -9!99.2500 ILO -999.2500 GR -999.2500 NR~T -'99'9,.'2500 FC~ -999,2500 .-999,250D -999.2500 NR~T -999,2500 ILO -9;9,2500 Gq -9R9.2500 Ng~T -99?.2530 FCNL -99~.2500 ILO -9~9.2500 GR -9~9,2500 NR~T -959.2500 FCNL -999.2500 iLO -999,2500 GR -9)9,2500 NR&T -999,2500 FC'4L -999,2500 -999,2500 -999,2500 NRAT -999.Z500 IL2 -9~9.Z500 NR~T -'~.,.99._~50, 0 ~ALI -9~9.~500 ~'"' ' ~'" -999.i500 Gq -999,2500 iL~4 -'799.2500 CALl -999.2500 RNR~ -999.2500 OR -999.2500 iLM -999.2500 C&2i -999.2500 RNRA -999.2500 GR -999.2500 !LM -999.2500 CALl -999.2500 RNRA -'999,2500 GR -999,2500 ILM -'~99,2500 C~LZ -999,2500 RNRa -999.2500 GR -999.2500 tLM -999.2500 CALI -999.2500 RNqA -999.2500 GR -999.2500 'iLM -999.2500 CALl -999.2500 RNR& -999.2500 GR -99'9.2500 ILM -999.25,30 C,aLI -~99.2500 GR -999.2500 IL4 -999.2500 CALl -999.2500 -999.2500 GR -99'9.2500 -999.253'3 C&LI -999.2500 -999,2500 ILM -9~9.2500 C~LZ -9~9.2500 RNRA -999.2500 SR -999,2500 -999,2500 87.0898 -999,2500 -999,2500 -999.2500 77,7148 -999.2500 -93'9,.2500 -999.2500 78.1523 -999.2500 -999.2500 -999.2500 72.8398 -999.2500, -999.2500 -999.2500 54.9023 -999.2500 -999.2500 -999.2500 71.5273 -999.2500 -999.2500 -999.2500 71.0273 -9~9.2500 -999.2500 -999.2500 56.5430 -999.2500 -999.2500 -99~.2500 51.3555 -999.2500 -999.2500 -'999.2500 70.3398 -99:9.2500 -999.2500 -999.25O0 54.0273 LYP OlO.H02 V~RZ~IC.aiiDN LISTINS :?~g~ 8 S P NP,iI DE ~T S? NPHI SP NPHi 3~PT NPM! u ~_ P l' SP £? SP u~.PT 3~00,0000 SFLU -999,2500 SR -999.2500 3qH3 -999,2500 NCNL 5300.0000 SSLJ -999.2500 GR -999°2500 DR~] -999,2500 NCNL 5200,0000 SFLJ -999,2500 GR -999,2~00 -999,2500 NCNL 3100.0000 S~LJ -999.2500 SR -999.2500 DRq] -999°2500 NCNL 5000,3300 SSLU -999,2500 -99~.,2500 ~900,0003 SFLJ -999,2500 GR -999,2500 DRH3 -999,2500 NCNL 4300.,0000 SFLJ -:999,2500 G~ -999,2500 DR~3 -999.2500 NCN~ 470J,0300 SFLJ -999,2500 SR - 999.250,3 3 R-~ 2 -999.2500 NCNL ~500.0000 SFLO -~'9~.250J SR ~400,.3000 S;LJ -999.25013 GR -~9'~.2~00 NC'~_ -9~9,2500 -999,2500 -999.2500 -999,2500 FCNL -9~9,2500 -999,2500 GR -'999,2500 NR~T -9'99.2.500 ~CNL -9~39. 1300 iL D -999,2500 SR -9:~9o 2500 NR&T -9~9,2500 FCNL -9~9,2500 iLD -999,2500 GR -999,2500 -999,2500 ¢CNL - ~99.25 O0 IL -999,2500 -99'9.2500 NR ~T -999. ZSOO FC NL -9'~9,2500 -999,2500 GR -9~9,2500 -999,2500 = C !',i L -999,2500 ILO -999,2300 SR -999,2300 NR~T -999.2500 FCNL -9~9,2500 ILD -9~9.2500 GR '-9~9.2500 NR~T -9~9,25g0 FCqL -999.2~30 !LO -999,2500 NR~,T -9~9.2500 ~CNL -999.2500 !LO -999,2500 Gq -999,2500 qR~T -999.2500 =CNL -9~S.Z:O0 ~LD ~03 Gq -999.£300 NR~T -9~9,25]0 FC"~L -999.2500 ILM -999.2500 CALl -999.2300 RNR4 -999.!500 GR -999,2500 iLM -999,2~00 CALl -999,2500 RNR& -999,2500 GR -999,2500 -999,2500 CALl -999,2500 -999,2500 SR -999,2~00 .ILM -999,2500 CALl -999,2500 RNRA -999.2500 GR -999,2500 ILM -999,2500 CALl -999,2500 RNRA -999,2500 GR -999.2~00 IL~ -999.2500 CALl -'999.2500 RNRA -999,2500 GR -9~9.2500 ILM -999.2500 CALl -999.2500 RNR& -999.2500 GR -999,2500 iLM -999,2500 CALl -999,2500 RN2~ -999,1~00 SR -999,2300 ILM -99~,2503 CALl -999,2500 -999,2500 GR -99'9,2500 ZLM -999,2500 .~rALi -9:~ 9.25 }0 RtiR ~ -999,2500 GR -999.2500 -999.2500 -999.2500 84.7148 -999,2500 -999,2500 -999,2500 53,4805 -9~9.2500 -999.2500 -999.2500 63.5742 -999.2500 -999.2500 -999.2500 80.8867 -'999.2500 -999.2500 -999.2500 60.6992 -999.2500 -999.2500 -999.2500 ?0.4548 -999.2500 -999.2500 -999.2500 69.1523 -999,2500 -999.2500 -999.25OO 55,339B -99'9,2500 -999,2500 -999,2500 55,2773 -999,2500 -999,2500 -999,2500 54.9548 -999.2500 -999.2500 -999.2500 85.1523 Vm OiO.MOI VERIFiCa~7tO~ Lic' ,I 3: P T SP SP RH35 SP NPqi SP xiP~i ~PT SP N~fiZ SD S~ se 4300.0000 SFLj -S99.2500 SR - .2500 DRH3 -~99.Z500 NC~L 4200.0000 SFLJ -999.2500 SR -999.2500 O~Z -999.2500 NC~L 4100.0000 SFLj -999.2500 GR -999.2500 3:~d3 -99'9.2500 NC~L 4000.0000 SFL~J -99'9.2500 iS2 -999.2500 DRM3 -999.2500 NC~' 3900.0000 SFLj -999.2500 Gq -999.2500 DRMc] -999.2500 NC~'~_ 3800.0000 S~LJ -'999.2500 GR -999.2500 Dqd3 -99~.Z500 NCNL 3700.0000 SFLj -999.2500 GR -999.2500 DRM3 -999.2500 NCNL ,3600.000J SFLj -'999.2¢33 -999.2500 -999.Z500 NCN_ 3500.0300 S¢Lj -999.2.500 GR -999.2500 DRM'2 -999.2300 NC~ 3-500.J,'~00,~- SF' j - 999.2303 SR -999.2-500 3R-~3 -999.250,.] NCNb. 3300.0J00 SFLJ -999.~500 S2 -99'9.2500 ;qR~J -999.2300 -999.2500 -9~9.2500 :CNL -999. 2500 -!999. 2500 GR -999.2500 NR~T -999 2=00 FCN~ -999.2500 ItD -999.2300 GR -999.2500 NR~T -999.2500 FCNL -999,2500 iLO -999.2300 GR -'999.2500 NR&.T -9~9..2500 FCNL -999.2500 -999.2500 Gq -9)9.2500 NRaT -9.~9.g500 FCNL -999.2500 ILO -999.2300 GR -999.2500 NR~T -999.2500 FCNL -999.2500 IL3 -999.2500 GR -9~9.2500 NRAT -9~9.2500 FCWL -999.2500 -9.99.2300 GR -'9'99.2500 NRST -9~9.2300 FCNL -9~9.2300 -999.!500 GR -999.2500 NRaT -999.2300 FCNL -999.2500 ILJ -99~.2500 GR -999.2500 NR~T -999.25G0 FCNL -999.250J ILS -99'9.2500 5~t -999.2500 NR~T -999.2500 -999.2500 CALl -999.2500 -999.2500 -999.2300 IL~ -999,2500 CALl -9~9,2300 RN'Z& -999.2500 GR -999.2500 C~Li -999.2500 RNR& -999.2500 GR -999.2500 -99'9,2300 CALI -999.2300 RNRa -999.2500 SR -999.2500 ILM -999.2300 CALl -999.2300 RNR~ -999.250'0 GR -999.2300 IL~ -999.2500 CALl -999.2500 RNR~ -999.2300 GR -999.2500 It~ -999.2300 CALl -999.2500 RNR~ -999.2300 3R -999.2300 ILM -999.2500 CALl -999.2500 RNq& -999.2300 SR -'999.2500 ILM -99'9.2530 C&LZ -9'99.2300 RN"R~ -999.2500 GR -999.2300 ILM -999.2300 C~LI -'999.2500 ~NR,~ -99'9.2300 GR -999.2300 iL~ -999.2500 C~Li -999.25CJ RNR& -999.Z300 -999.2500 -999.2500 51.3242 -999.2500 -999.2500 -999.2500 71.2773 -999.2500 -9'99.2500 -999.2500 75.5273 -999.2500 -999,2500 -999.2500 ~5.88,57 -999.2500 -999.2300 -999.2500 50.2930 -999.2500 -999.2500 -999.2500 35.32&2 -999.2500 -999.2500 -999.2500 32.4492 -999.2500 -999.2500 -999.2500 40.1367 -999.2500 -999.2500 -999.2500 39.~92 -999.2500 -999.2500 -999.2500 36.9180 -999.2300 -99'~.2390 -999.25OO ~P ~PHI }E P T ~Pql ]E°T ]EPT ~P ~P~i ~E~T '~P~i )E ~ l ]EOT DZ~T S~ ~E~T - 999. Z 509 NCNL 3200,0000 SFLJ -999.2500 GR -99'9,2500 -999. 2500 NCN 3100.0000 S=tj -99'9.2500 -999, Z 500 D -~99.Z500 NCNL 3000.0000 5~LJ -999. 2500 SR - 999.2500 OR~ ] -999.2~00 NCNL 2900.0000 -999.2500 -99).2500 -999,2500 28 O O. 0000 SFL d -999.2500 - 999.2500 -999.2500 NCN~ 2700.~000 - 999. Z 500 -999. 250',3 '~ 60 O. 3~00 .SFLj -)99.2~OO -~99.2500 - 999.25 O0 NC 2500.0030 -~39.Z530 SR -~99. 2500 -')99. Z 500 2400.0000 S=LJ -9'a9.~503 -999.2500 NC'~' - R 99. Z 500 :3 R -99S. 250? -)9~.ZSOj NC'4~ 'ZZOO.3JO3 S=' J -~ 99. Z 500 S -999.2500 ~CNL -9')9,.2500 iLD -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 -'9'~9.2500 G2 -999.2500 -9~9,2500 FCNL -'999.2500 ZLD -999.2500 GR -999.2500 -99'9.2500 FCNz -9~9.2500 -999.2500 GR -999.2500 NR~T -999,2500 FCNL -999,2500 -999.!500 -999.2500 -~9 2500 -999.2500 ILD -999.2500 SR -999.2500 NR&T -999.250~ -999.25~0 ~CqL -999.2503 GR -999.250~..,~. NR4T -~9.Z500 ZLD -9~9.~500~ GR -999.2500 NR~T -999.2500 $CNL -999.2530 -9~).ZSO0 -999.2500 -999.2-00 -9~).250C iL3 -999.2500 -999.2500 TLM -999.2500 CALl -999.2500 -99'9.2500 GR -999.2500 Ik~ -999.2500 CALl -999.2500 -999.2500 -999.2500 ZLM -999.2500 CALl -999.2500 RNR~ -999.Z500 -999.2590 ILM -999.250~ -999.2500 RNRA -9'99.2500 -999.2500 -999.250~ CILI -999.2500 RNR~ -999.2500 GR -999.2500 IL~ -9~9.2590 C~LI -99'9,2500 RNRA -999,2500 -999.2500 -999,2500 C2LI -999,250~ RNR2 -9'99.2500 GR -999.2500 IL~ -99'9,2500 C~Li -999,2500 -999,2500 GR -999,2500 -999.250J C~Li -999,2500 -999,25S0 -9~'~.25J0 -9~9.25~0 -~99.Z500 it~ 35.7930 -9~9,2500 -999.2500 -9'99.2500 27.8955 -999.2500 -999.2500 -999,2500 25.1768 -999. 2500 -999.25~0 -999.2500 3~.07~2 -999. 2500 -999.~500 -999.~500 39.1992 -999.2500 -999.2500 -999.2500 34.9805 -999.2500 -999.2500 -999.2500 33.3555 -999,2500 -999.2500 -999.2500 27.1611 --999. 2500 -'999. 2500 -'999.2500 31.7393 -999.2500 -999.2500 -99'9. 2500 23.~924 -999, -999,2~00 30.2393 -999.2590 -999.2500 -V'~ u].O.HO~ VER,[?ib~T£,3?~ LiSTeN:} °~;~E !I ~iPMi -999.25J0 3E~T 2100.0000 SFLj ~P -999.2500 ~P~ I - 999.2500 NC N }~PT ZOOO,O00O S~9Lj ~P ~ i -999.2500 D~ ~ T 1 900,0 O00 S~=~ J ~P -~99.2500 ~oH i - 999.25 O0 NC qL J~PT 1300.0000 SFLj RH~]8 -99~.2~0u "~P q I -:~ 99.2500 NC NL ]E°T 1700.0000 SFLJ SP -999.2500 ~HS:.. ~ - ~99,2500 NPqZ -999,2500 NC~WL Df pT l~O0.O000 S~Lj Sm -999.2~00 GR RH35 -999,2500 DRH] "~? ~ i - 99 ~. 2500 NC DEOT i$OO,O-]O0 S~L~ 7H:35 -999.2500 NP~i -999. _~500 ~"~NL OE~T 1495.0000 SFLJ SP -999,250J 7'd3~ -~9~.2500 q P ~ l -'?9'~. 250 O NC -9.~2. 2500 NR~T -999..7500 -999,2S00 ILS -999,7500 SR -999,2500 NR~T -9 '~9 . 2500 FC~L -g~:~.250,q l' D -999,2500 GR -999,2500 -9~9. 2500 ILD -9 ~9, fSO0 -999, 2300 -9'~ 9.25 O 0 PC NL -999. 2500 -999.2500 GR -9)9.2500 N2AT -9~9,2500 -999,2500 iLD -9 ~ 9.250 O G -9 29.2~00 NR AT -9~9,2530 -999. 2500 iL D -9.~9.2500 GR -9)9.2500 NRAT -9'99. 2500 FCNL -9 )9. 2500 ILD -999,2500 -9:~9,2500 -'9)9. 2500 ZL3 -999.2500 -999,2500 N~T -999. ~ 5 ~. 0 =!L= NAM: :EDIT .OOl S~RV"rE-.., NA',IE '. VERSi3N ~ : '~ T ~= : :,d~'~, L'CNGT~., · -=,-E TYPE : '.~':XT :!L= N~'4:~ : -'~99,2503 -799. £ 500 ! L -999.2500 CALl -999.2500 - 999.2500 (;R -929,2500 -999,2~00 CAL~ -9~9,2300 -979,2500 GR -9~9,2500 -999,2500 CAL -9'~ 9.2300 RNR -999,2500 GR -999.2500 ILM -999,2500 -'~9,2500 GR -939,2500 iLM -9~'~9. 2500 CALI -999.2500 -999.2500 -999. 2500 -999.2500 CALl -999.2500 RNR,~ -999.2500 GR -999.2500 ILM -999.2500 C~Li -999.2500 SR -999.2500 -999.~500~ -~9.2500 RNR~ -'~)9.2500 -'9 '99. £ 5 JO 34 · 7305 -999,2590 -999,2500 -999,2500 32,3867 -999,./500 -999,2500 -999.2500 25.5986 -999. 2500 -999,2500 -9~'9:. 2500 31,051~ -999,2500 -9:99.2500 -999. 2500 31.75~9 -999.2500 -999.2500 -999,2500 33.199! -999.2500 -999.2500 -999. 2500 25,7393 -999,250~' -999,2500 -999.2500 25. 6143 -999,2500 -999.2500 -999,2500 20,8174 ~VP 010.H02 V~RIFICATION LISTINS ~ 'TAPE TRAILER ~* SER¥I~E NAME. :EDIT ORIGIN :FSXA :EDIT :TAPE PAGE