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216-171
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Conklin, Amy A To:Guhl, Meredith D (OGC) Cc:Taylor, Jenna; Hobbs, Greg S Subject:RE: [EXTERNAL]API Gravities from two older 10-407s Date:Wednesday, October 12, 2022 5:43:44 PM Attachments:image001.png image002.png Hi Meredith, Please use API Gravity of 22 for 2G-13A and for 3M-14A, please use 20.9. Please let me know if you need any additional information. Thanks, Amy From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Monday, October 10, 2022 2:51 PM To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: [EXTERNAL]API Gravities from two older 10-407s CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Jenna and Amy, Not sure who is the best person to send this question to, since the 10-407s are older, but thought you might know, so figured I’d start with you. The API Gravities reported as part of the production test data on these 10-407s are incorrect. Could you provide the correct gravity please? 1. PTD 213-184, KRU 2G-13A: 2. PTD 216-171, KRU 3M-14A: Thanks so much for your help with this. If I should contact someone else, please let me know. Cheers, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-17_22018_KRU_3M-14A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22018 KRU 3M-14A 50-029-21726-01 Caliper Survey w/ Log Data 17-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:216-171 T36660 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.25 14:12:26 -08'00' By Samantha Carlisle at 7:47 am, Aug 29, 2022 KRU 3M-14A SFD C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-16_22017_KRU_3M-14A_LeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22017 KRU 3M-14A 50-029-21726-01 Leak Detect Log 16-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 216-171 T36641 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.24 11:18:39 -08'00' • • O 0 0 a N O .N E C (D (� • • V CNC 01 u_ 0 T Z N QQO O 7❑J dY w ❑ .-,N .0 mm Q o) UCNI _ m 2 Z N- r- < Co a) ' N- r o O u, e (n N (N V 0 0 "O "O N N T T ^d o = r CO to a a 2 o o W m m LL Q Q N Z Z) o u7 a Z Z c-) c c U) c c U) Z Z - vi > a) — J ' F- W it (n LL W (n ' ' N (n (n T3 TS Y Z7 > 0 0 0 0 m 2 2 F- 2 2 ~ 0 0 c O i U E. co F- LU W ...... 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CO I C Z co a c 0 D D D D D £ D 5, ti > 1 N co co co co N N N N co C > .f0 I } m 73 r ~ IN N N N N N - W E a I �O N N N N N coco 1 co co co co co m W p III N a m W o c ` 2 m ' E ZO Et •cc 0 Y W m .. a z o no Q o g Q o 0 0 c U w1 U 0 0 0 0 0 p rn -� y 0- 1 m m V o_ S o i s Q m v E a o LI" 2 m d a 2 w w w w w _ 3 z 0 d 0 0 0o c G 1 0 00 21 61 71 /tom PRINT DISTRIBUTION LIST 2 8 2 2 6 BAKER MAY 1 ,� mg HUGHES p/��/'!gyp^► Please sign and return one copy of this transmittal form to: COMPANY /'"''lllod6cAC Alaska,Inc. ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED WELL NAME 3M-14A 700 G Street. 5/3l/201` Anchorage,Alaska 99510 M.K.BENDER FIELD Kuparuk River Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska LOG DATE April 6,2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(@,bakerhughes.com TODAYS DATE May 19,2017 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO* LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF F'KIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 IConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 I 1 1 'Attn:Makana Bender 1333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Resource Evaluation 1550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 [***Stamp"confidential"on all material deliver to DNR 6!BP Exploration(Alaska)Inc. 1 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • to e- N cp N NI ri, NN all 11114g2 m W : U > © U W 7,1 0 LU x Q CC N 0- M I CS C t RS 0 0- ca 0 w W IX a I- ,, •� coa_ . s = , _c Cl) a a = V O 0 0 're NM ♦•+ _v Y N Lc 0 o N >' co V O a a1- 0 CO CD 2 0YYRLi) m ci N 0 0 0 • • Q ® N. 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C '° O` CND CO N 0 N M L Ol > .d._ y c N N N 6 o) ao all .0 0 co 2 m s c co co co CO CO CO CO 0. ) N C r2 v 0 O 00000 p ui o Z .- (o ro (n m (o co- co V ' cu N U y o _ ► CL.N 3 O6y U CL p C o ° °' w RU % n in o U W-- V wN y 1 N . el CO O I- N N M 0p Q — ce t m m co oo coo N °n' m m >> J F- R Z O) W m u) (O N (O R 0) N O N 0 (O co co. N N N N N N N M Z 7 ,i. (V N N N N N t ou) 0o co co o) m cco co N .- CO CD. ' (0 W N N . N N 3 (O CO- (O to to (O (O k d Y O y 0 CO N N. N N N U 1- 7 (O (O (O (O (O (O (O C )N co r coM co coO YO ') m M Q U N N R M O O N d 4a ' VI L E M CL8 2 2 a s O N N r r C M (Mn a, n co CO. O. U t U Y Y 2 co N S ,C:4 ,C4ani v g m m Ci.. o O0 O N O r,) 0 0 a C C t 0 . m 0)) aco N) 0 0 o N N U a .. rno £ •'o ci d d y 3 a ti a in 3 3 O CO 0 • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 9, 2017 RECEIVED Commissioner-State of Alaska MAY 0 9 2017 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 AOGCC Anchorage, Alaska 99501 Dear Commissioner: Please find attached for your review completion reports for 3M-14 and 3M-14A. CTD operations did not go as planned on 3M-14. Unstable hole conditions were encountered immediately outside of the window and did not permit drilling 3M-14A past the build section of the wellbore. The CTD plan for the well included a swell packer and liner top packer to isolate and abandon 3M-14. Well 3M-14 was shut in prior to CTD operations due to rock production. This rock production occurred even after a 4-1/2" scab liner was previously ran and perforated. When 3M-14A encountered unstable hole conditions liner was ran to maintain production from the reservoir. The swell packer was not ran as originally planned. Even though the swell packer was not ran the 10-407 for 3M-14 is being submitted as abandoned for administrative and production tracking purposes If you have any questions or require additional information, please contact me at 907-263-4372. Sincere) William R. Long Coiled Tubing Drilling Engineer } RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 9 2017 la.Well StatuWELOil❑L CO❑MPLET SPLUGO❑N OReRr ❑ECOMPLAbandoned ❑ETIONenRded EPORT lb.Well cANlass: W 20AAC 25.105 20AAC 25.110 Development 2 • Exploratory❑ GINJ ❑ WINJ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or , , 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: /?,1I� 216-171 / 3.Address: 7.Date Spudded: i, 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 -415/2017 Lt ISO' 50-029-21726-01 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 950'FNL, 1598'FEL,Sec.25,T13N, R8E,UM 4/6/2017 KRU 3M-14A Top of Productive Interval: 9. Ref Elevations: KB:64 17. Field/Pool(s): 3995'FNL,812'FEL,Sec 24,T13N,R8E,UM GL:27 BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: rig 3881'FNL,788'FEL,Sec 24,T13N,R8E,UM 6975/6267 , ADL 255221 2.5S-Z3 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 506270 y- 6016548 Zone- 4 7073/6300 - 2558 TPI: x- 507053 y- 6018784 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 507077 y- 6018898 Zone- 4 N/A 1720/1720 5.Directional or Inclination Survey: Yes 0 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 6930/6231 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 GR/Res 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 62.58 H-40 38 121 38 121 24 200 sx CS III 9 5/8 36 J-55 37 3473 37 3377 12 1/4 1389 sx AS III,371 sx Class G 7 26 J-55 35 7224 35 6481 8 1/2 300 sx Class G, 175 sx CS I 4 1/2 12.6 L-80 6599 7127 5953 6398 6 1/2 175 sx CS I 2 3/8 4.6 L-80 6526 6975 5893 6267 3 N/A 24.Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 6502 6509/5879 SLOTTED LINER @ 6526 MD and 5893 ND-6975 MD and 6267TVD 6599/5953 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 4,18111- Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1,\--- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/26/2017 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/26/2017 24 hrs Test Period -♦ 64 32 947 - 500 Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 160 psio 1119 24-Hour Rate �► 64 32 947 233 Form 10-407 Revised 11/2015 V7-1-- �o/ 6 CONTINUED ON PAGE 2Submit ORIGINIAL only-, i% 6ilW/2- -€ 67r(7 RBDMS v AY 1 5 2017 1- III • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1720 1720 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 6930 6231 information, including reports,per 20 AAC 25.071. TPI Formation Kuparuk C sand TD 7073 6303 Formation at total depth: Kuparuk A Sand 31. List of Attachments: Daily Operations Summary,Definitive Survey,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 AAC 25.070. /(.�— 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: William Long(a)263-4372 Email: William.R.Long(d)cop.com Printed Name: J.Ohlinaer Title: Staff CTD Engineer Signature: off7.r Phone: 2651102 Date: /�/�0�, INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • 3M-14 Final CTD Schematic Modified by WRL 1-May-17 3W 9.3#L-80 EUE 8rd-Mod tubing DS-nipple at 542' (ID=2.875") 3'W Camco gas lift mandrels @ 2523',4115',5272',6113', 16",62.5#,H-40 at & 6423' MD '" 121'MD ��<ia 11.100. Baker Seal Assembly @ 6479'MD "� Baker PBR @ 6486'MD illil Baker FHL Packer @ 6509'MD 9-5/8",36#,J-55 D-nipple at 6560'MD(2.813"min ID) at 3473'MD 'NMI Baker 80-40 Seal Assembly 6605'MD Liner Top Packer @ 6524'MD ►_ -_I 4-1/2"scab liner assembly Northern Solutions ZXP liner-top packer at 6599'MD 1.78"R Nipple in Seal Assembly ".'I V" FlexLock liner hanger at 6617'MD Baker 80-40 SBE 6627'MD ' 4-1/2",12.6 ppf,L-80,IBT-Mod scab liner 6599'-7217'MD I' II II Top of Whipstock @ 6930'MD `\ Baker Gen II 3-1/2"x 4-1/2" \\ ' Rocks in 4-1/2"liner at 6948'MD ••:::::". .. y' ` 3M-14A TD @ 7073'MD A-sand perfs(sgz'd) ":.17' % � � 2-3/8"4.6#L-80 STL Slotted Liner @ 6975'MD 6940'-6976'MD (6'Seal Bore Deployment Sleeve,Solid Bull Nose) A-sand reperf Multiple Hole Washout/Ledges Below 6956'-6976'RKB ,.' r. • Casing damage in 7" w. 4 .`:13.1 7",26#,J-55 at C-t.t; .in.1...—._7'224'MD , z KUP POD 3M-14A 'ConocoPhilhhps 3 Well Attribu Max Angll TD AIt3u,k�1.Inc. WellboreAPI/UWI Field Name Wellbore Status ncl(°) MD(ft I Act Btm(ftKB) CONOKE higtps 500292172601 KUPARUK RIVER UNIT PROD 83.78 7,044.82 7,073.0 ... A Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-14A,519/20174,04,38 PM SSSV.NIPPLE 125 4/4/2013 Last WO: 41.90 6/5/1987 Verlicalaclamapp.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag' Rev Reason.SIDETRACK,SET LINER TOP pproven 5/9/2017 A 14 PACKER HANGER;32.5Vi Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I 1 CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H-40 welded I`� � � -1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 37.0 3,473.1 3,376.7 36.00 J-55 BTC CONDUCTOR;38.0-121.0 Casing Description OD(in) ID(in) Top IRKS) Set Depth(ftKB) Set Depth(TVD)...WtlLen(L..Grade Top Thread PRODUCTION 7 6.276 34.8 7,224.0 26.00 J-55 BTC Illi Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread NIPPLE;541.7 SCAB LINER 41/2 3.958 6,598.8 7,127.0 12.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(TVD)(8KB) Top'noir) Item Des Com (in) 6,598.8 5,953.3 33.55 PACKER Baker"2RH"ZXP Liner Top Packer w/10'Tie-back 4.300 Ext,5"BTC BxP GAS LIFT;2,523.3 - 6,617.4 5,968.8 33.47 HANGER BAKER HYDRUALIC FLEX-LOCK LINER HANGER 4.400 • 6,627.2 5,977.0 33.42 SBE Baker 80-40 SBE,20'Long,5"BTC 4.000 Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth IND)...Wt/Len(I...Grade Top Threatl li LINER A 2 3/8 1.992 6,526.0 6,975.0 6,266.7 4.60 L-80 STL Liner Details SURFACE;37.03,473.1-. L Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 6,526.0 5,892.7 33.61 Deployment Seal bore deployment sleeve(6') 1.920 Sleeve GAS LIFT;4,115.1 - Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 32.8 6,502.4 5,873.0 9.30 L-80 EUE oll Completion Details GAS LIFT,5,272.2 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) I'i 32.8 32.8 0.00 HANGER FMC,GEN IV Tbg hanger w/3 1/2"TBG Pup. 2.992 541.7 541.7 0.31 NIPPLE 2.875"Landing Nipple w/'DS'Profile 2.875 6,479.7 5,854.1 33.74 SEAL ASSY Baker 80-40 GBH-22 Production Seal Assembly 2.990 GAS LIFT;6,113.2 II' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..ISet Depth(TVD)(...Wt(Ib/ft) Grade Top Connection PACKER ASSY 3.98 2.980 64862 6,643.5 5,990.6 EUE I I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT.6,423 6,486.2 5,859.5 33.70 PBR BAKER PBR 4.000 6,509.3 5,878.7 33.62 PACKER BAKER'FHL'PACKER 2.980 6,559.8 5,920.8 33.58 NIPPLE CAMCO 2.812"Landing Nipple w/'DS'Profile 2.812 6,605.6 5,959.0 33.52 SEAL ASSY BAKER 80-40 GBH-22 Production Seal Assembly w/2-ft 2.980 space out SEAL ASSY;6,4797 PBR,6,486.2 1�' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl �- Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) PACKER,6,509.3 6,524.0 5,891.0 33.61 PACKER NS LINER TOP PKR w/POSITIVE TEST SEAL 4/13/2017 1.780 ill ASSY(1.78"ID/8.25'OAL LIH AFTER PULLING RSG) liall IAD, Mandrel Inserts St PACKER;6,524.0 5-sni.I ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,523.3 I r 1 1 0. 1 10:00 NIPPLE;6,559.8I3,905.61 0.1881 1 11 1 1 1 1 11 4 6,113.2 li: ,, r OV RD02 0.250 11 1 11 1 * • _ V 80 • 0.000 11 1 1 4 'WNotes:General&Safety `/ VEnd Date Annotation SEAL ASSY;6,605.6 4 kiy IVOTE %?,; !V Liner Cement,6,598 8 ftKB KB y r W >1 Iy LINER A;6,526.0-6,975 0 I I B SCAB LINER;6,598.8-7,127.0 1 PRODUCTION;346-7,224.0 L KUP P OD 3M-14 °moo:Phillips m Well Attribu Max Anglo TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ft Act Btm(ftKB) Cmoc 4'II is s�( 500292172600 KUPARUK RIVER UNIT PROD 35.63 5,800.00 7,244.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-14,5/9/20171144.39 AM SSSV:NIPPLE 125 4/4/2013 Last WO: 12/19/2012 41.90 6/5/1987 Vertical schamaac(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date a , Last Tag:SLM 6,919.0 9/19/2016 Rev Reason:PLUG 8 ABANDON pproven 5/9/2017 HANGER,32.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) `t I 1 i Top (ftKB) (ftTop KB)(TVDp(°)) ToIncl Corn 1 Des CoRun Date ID(in) _,�_ 6,933.8 6,234.5 32.37 WHIPSTOCK BAKER GEN II DELTA 3 1/2"x 4 1/2'WHIPSTOCK, 10/7/2016 3.500 TOP OF WHIPSTOCK:6933.8', WHIPSTOCK CONDUCTOR.38 0-121 0 ORIENTATION:0 DEG,OAL-12.97 RA TAG 7.35' FROM TOP 11 7,127.0 6,398.5 31.50 FISH ESP motor parts,remnants of ESP motor pushed 12/3/2012 NIPPLE 541.7 downhole to 7127 RKB w/workover 12/3/2012- should be fill to 7244'drillers TD(FRAC or formation sand)6/10/2005-ESP motor parts,remnants of la ESP motor pushed downhole to 7010 w/workover 6/10/2006 GAS LIFT;2sz33 - Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn I ll 6,940.0 6,942.0 6,239.8 6,241.4 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab SQZ liner 2012 6,944.0 6,945.0 6,243.1 6,244.0 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab SURFACE;37.63,473.1-. SQZ liner 2012 6,948.0 6,949.0 6,246.5 6,247.4 A-2,3M-14 8/16/1998 1.0 CMT Covered by CMT Scab SQZ liner 2012 GAS LIFT;4,115.1 6,954.0 6,992.0 6,251.6 6,283.7 A-1,3M-14 8/16/1987 4.0 CMT Covered by CMT Scab SQZ liner 2012 III 6,956.0 6,976.0 6,253.3 6,270.2 A-1,3M-14 2/21/2013 2.0 RPERF HSC 25"w/180 degree phasing,Millenium II HMX charges GAS LIFT;5,272.2 } Cement Squeezes I Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 6,598.8 7,127.0 5,953.3 6,398.5 Liner Cement 12/7/2012 Notes:General&Safety GAS LIFT;6,113.2arl End Date Annotation 7/2/2006 NOTE:WORKOVER I._ 7/28/2006 NOTE:PER CALIPER LOG 6/27/2006,SEVERE 7"CASING DAMAGE @ 6942'-6946' 8/17/2006 NOTE:RECOVERED ROCKS TO 1.5"DURING TAG GAS LIFT,6,423.2 7/21/2008 NOTE:SAND 8 PEBBLES OBSERVED @ 6930' IR 10/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 12/19/2012 NOTE:WORKOVER SET CEMENTED 4.5"SCAB LINER TO COVER 7"PROD CSG DAMAGE II SEAL ASSY 6,479.7, l-7., PBR,6,486.2 PACKER;6,509.3 10 NIPPLE;6559.8 Iii 4: SEAL ASSY;6,605.6 gin. ( V V. V Liner Cement 6598.8 ftKB Pi V SCAB LINER;6,598.8-7,127.0 PRODUCTION;34.8-7,224.0. ' 4 LINER A.8,526.68,975.0 .. V WHIPSTOCK;6,933.8 1 CMT SQZ;8,94008,942.0 ;?; 41 y,CMT SQZ;6,944.08,945.0 % R CMT SQZ;6948.66,9450� 4: '/, V P. V RPERF;6,956.0-6,978.0 'l CMT SQZ;6,954 0-6,992.0-• llleil 7.'0. `Pt V 'Pg C y/4 kl 5 06 FISH;7,1270 Operations Summary (with Timelog Depths) 3M-14 ConocoPhiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ItKB) End Depth(EKE) 4/2/2017 4/2/2017 3.00 MIRU MOVE RURD P PJSM with truck drivers.Get rig 0.0 0.0 00:00 03:00 jacked up and sows hooked up. 4/2/2017 4/2/2017 4.00 MIRU MOVE MOB P Pull modules off of 1 E-20.Stage sub 0.0 0.0 03:00 07:00 and pits on access road and wait on feild wide change out. Halfway house and shop remain on 1E pad. 4/2/2017 4/2/2017 8.00 MIRU MOVE MOB P Mobilize sub and pits to 3M pad.Sub 0.0 0.0 07:00 15:00 and pits spotted at 15:00 hrs. 4/2/2017 4/2/2017 6.50 MIRU WHDBOP RURD P Crew working through rig up checklist. 0.0 0.0 15:00 21:30 Move shop and halfway house from 1E pad.Spot on 3M pad.String up highline.Establish comms. 4/2/2017 4/2/2017 1.50 MIRU WHDBOP NUND P NU BOPE and fill stack. 0.0 0.0 21:30 23:00 4/2/2017 4/3/2017 1.00 MIRU WHDBOP BOPE T Rig accept at 23:O0hrs. 0.0 0.0 23:00 00:00 Start initial BOPE test to 4600 psi. State witness waived by Chuck Sheive. 4/3/2017 4/3/2017 9.00 MIRU WHDBOP BOPE P Continue testing BOPE to 4600 psi 0.0 0.0 00:00 09:00 (2,500 psi on the annular).State witness waived by Chuck Shieve.2" lower pipes fail/Pass after cycle 4/3/2017 4/3/2017 3.00 MIRU WHDBOP RURD T Rehead the UQC.e-line would not 0.0 0.0 09:00 12:00 test.Troubleshoot.Problem with high pressure bulkhead.Remove,fix and replace same. 3 hrs Nabors downtime. 4/3/2017 4/3/2017 1.00 MIRU WHDBOP RURD P Rehead UQC.eline test good.PT to 0.0 0.0 12:00 13:00 4000 psi. 4/3/2017 4/3/2017 1.50 MIRU WHDBOP MPSP P RU valve crew lubricator.PT to 2,500 0.0 0.0 13:00 14:30 psi.Equalize pressure. Pull BPV.RD lubricator. 4/3/2017 4/3/2017 2.00 PROD1 WHPST PULD P PJSM.PU and PD BHA#1,window 0.0 0.0 14:30 16:30 milling assembly.Make up 2.80"DSM, 2.79"no-go string reamer,to 1.0°AKO Weatherford motor.Tie-in to the K1 for a+1 foot correction. 4/3/2017 4/3/2017 3.80 PROD1 WHPST TRIP P RIH with milling BHA pumping 0.0 6,900.0 16:30 20:18 seawater,displacing out diesel FP. Chase seawater with 9.6 ppg milling fluid. 4/3/2017 4/4/2017 3.70 PROD1 WHPST WPST P RIH.Dry tag pinch point at 6,933 ft. 6,900.0 6,936.6 20:18 00:00 PUH.Bring up pump to 1.7 bpm.RBIH and mill window per program. 4/4/2017 4/4/2017 10.00 PROD1 WHPST MILL P Continue milling window per 6,936.6 6,946.1 00:00 10:00 procedure, 1.7 BPM @ 4250 PSI FS, BHP=4100 4/4/2017 4/4/2017 1.50 PROD1 WHPST MILL P 6946.1 Call Bottom of window,time 6,946.1 6,947.5 10:00 11:30 mill 2 more feet to let string reamer work,1.7 BPM @ 4230 PSI FS, BHP=4087 4/4/2017 4/4/2017 1.80 PROD1 WHPST MILL P 6947.5,Started getting dark returns 6,947.5 6,951.0 11:30 13:18 added WHP and prep to take returns out-Never had to.Continue milling. 4/4/2017 4/4/2017 3.80 PROD1 WHPST REAM P Reached end of rat hole start reaming 6,951.0 6,951.0 13:18 17:06 passes,HS,30R,30L,180°.Attempt dry drift,PUW=31K Page 1/7 Report Printed: 5/3/2017 r i Operations Summary (with Timelog Depths) 3M-14 Conor hithips P,i:xk.s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/4/2017 4/4/2017 0.40 PROD1 WHPST REAM P Dry drift,tag at 6947'MD,ream down, 6,951.0 6,951.0 17:06 17:30 PUH attempt dry drift again,tag at 6947'MD,4K WOB to 6949'MD. Bring pumps up and get right through. 4/4/2017 4/4/2017 1.50 PROD1 WHPST REAM P PUH,ream down,backream up at 180 6,951.0 6,951.0 17:30 19:00 LS,dry drift,tag at 6947',tack 4K to 6949'MD again. Continue to dress window to obtain good dry drift:Begin back ream up LS, ream down HS,back ream up LS, back ream up a bit faster,dry drift at 20'fpm,tag at 6949'MD.Begin back ream up LS,ream down HS,back ream up LS. 4/4/2017 4/4/2017 1.00 PROD1 WHPST REAM P Attempt dry drift and tag at 6949.5' 6,951.0 6,951.0 19:00 20:00 MD,bring up pumps and get right through.RIH to 6951,ream up at 330 ROHS,ream down HS,ream up at 30 ROHS.Attempt dry drift and tag at 6949.9'MD,bring up pumps and get right by.Attempt to RIH with pumps off,again tag weight,bringing pumps on and can go right down. 4/4/2017 4/4/2017 1.50 PROD1 WHPST DLOG P Swap from choke A to choke B,obtain 6,951.0 6,931.0 20:00 21:30 SBHP at 6930'MD.Trap 12.8 ppg, shut in choke,shut down pumps,BHP stabalized at 3972 psi.Using TVD at annular sensor of 6190'TVD gives EMW of 12.35 ppg. Circulate bottoms up. 4/4/2017 4/4/2017 2.20 PROD1 WHPST KLWL P POOH,swap well to KWF(13.1 ppg 6,931.0 77.0 21:30 23:42 Potassium Formate),tag up. 4/4/2017 4/5/2017 0.30 PROD1 WHPST OWFF P Check well for flow,PJSM 77.0 77.0 23:42 00:00 4/5/2017 4/5/2017 1.30 PROD1 WHPST PULD P LD BHA#1 over a dead well,blow 77.0 0.0 00:00 01:18 down 4/5/2017 4/5/2017 1.80 PROD1 DRILL PULD P PJSM,PU BHA#2,build drilling 0.0 72.0 01:18 03:06 assembly(2.6 degree AKO,RB Hughes bit) 4/5/2017 4/5/2017 1.50 PROD1 DRILL TRIP P RIH with BHA#2,tie into K1 fora+.5' 72.0 6,830.0 03:06 04:36 correction,displace well to 9.6 ppg PowerPro 4/5/2017 4/5/2017 0.20 PROD1 DRILL DLOG P Tie into K1 for a+.5'correction, 6,830.0 6,853.0 04:36 04:48 4/5/2017 4/5/2017 1.60 PROD1 DRILL CIRC P Displace well to 9.6 PPG PwrPro, 6,853.0 6,923.0 04:48 06:24 close EDC 4/5/2017 4/5/2017 1.00 PROD1 DRILL DRLG P RIH to drill,dry tag©6951',PUH, 6,923.0 6,979.0 06:24 07:24 bring pumps on 1.5 BPM @ 4020PSI FS,BHP=4122,TF jumping around with tool on tray. 4/5/2017 4/5/2017 0.50 PROD1 DRILL TRIP P PUH to discuss directional plan.We 6,979.0 6,830.0 07:24 07:54 are behind plan at near bit inc.Pull up to tie in while discussing situation with town 4/5/2017 4/5/2017 0.10 PROD1 DRILL DLOG P Log K1 for+.5' 6,830.0 6,855.0 07:54 08:00 4/5/2017 4/5/2017 0.20 PROD1 DRILL TRIP P Trip in hole and log RA marker© 6,855.0 6,969.0 08:00 08:12 6937.5',TOWS=6930.15 Page 2/7 Report Printed: 5/3/2017 • • � Operations Summary (with Timelog Depths) 3M-14 ConocoPhitlips rikr.t a Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKB) End Depth(EKE) 4/5/2017 4/5/2017 0.20 PROD1 DRILL TRIP P RIH to drill 6,969.0 6,979.0 08:12 08:24 4/5/2017 4/5/2017 0.70 PROD1 • DRILL DRLG P Tag up and drill ahead from 6979',1.5 6,979.0 6,921.0 08:24 09:06 BPM @ 3943 PSI FS,BHP=4128, Started stacking out at 6985. High DHWOB but no differential pressure. BHA is in a bind.PUH attempt to get back on bottom.WOB reacting in both direction.Unable to get to bottom.Pull up above window 4/5/2017 4/5/2017 0.50 PROD1 DRILL CIRC P Back in cased hole,Open EDC and 6,921.0 6,914.0 09:06 09:36 circ bottoms up.Getting back more cuttings then drilled 4/5/2017 4/5/2017 1.20 PROD1 DRILL TRIP P Close EDC and RBIH to drill,Tough 6,914.0 6,920.0 09:36 10:48 going with high WOB after passing window.Stacked out @ 6972 unable to work past.PUH,Get hung up in window.Work up into cased hole. looks OK trip back in.Pushing hard past bottom of window and stack out @ 6970.Work to get back to cased hole.Motor stalling against side of hole 4/5/2017 4/5/2017 0.60 PROD1 DRILL CIRC T Discuss plan forward,decide to trip for 6,920.0 6,898.0 10:48 11:24 crayila mill,Circulate 13.1 PPG K- Formate 4/5/2017 4/5/2017 1.30 PROD1 DRILL TRIP T trip out on KWF. 6,898.0 65.0 11:24 12:42 4/5/2017 4/5/2017 1.30 PROD1 DRILL PULD T Flow check well-Good.Lay down 65.0 0.0 12:42 14:00 BHA#2 4/5/2017 4/5/2017 1.00 PROD1 DRILL PULD T M/U BHA#3 with 1.5°motor and 0.0 63.0 14:00 15:00 crayola mill,Make up to coil and surface test tool 4/5/2017 4/5/2017 1.70 •PROD1 DRILL TRIP T RIH BHA#3 63.0 6,825.0 15:00 16:42 4/5/2017 4/5/2017 0.10 PROD1 DRILL DLOG T Log K1 for+.5'correction 6,825.0 6,850.0 16:42 16:48 4/5/2017 4/5/2017 1.00 PROD1 DRILL CIRC T Displace well to 9.6 ppg PowerPro. 6,850.0 6,933.0 16:48 17:48 4/5/2017 4/5/2017 0.70 PROD1 DRILL REAM T Begin to perform reaming passes with 6,933.0 6,939.0 17:48 18:30Crayola mill as per procedure.Stall twice getting started at 6933.5'MD. Begin time milling to get started at 6933'MD,HS. 4/5/2017 4/5/2017 4.00 PROD1 DRILL REAM T Stalled twice at 6939'MD.PU&RIH 6,939.0 6,940.0 18:30 22:30 to continue time reaming.Observed increased WOB(.45K)with little motor work at 6939.15'.Continue to work area slowly to clean up window, stroking pump often to relax coil and avoid stalls. 4/5/2017 4/5/2017 0.60 PROD1 DRILL REAM T Continue down reaming at 6940'MD, 6,940.0 6,949.0 22:30 23:06 taking small bites and letting motor work drill off. Begin increasing ROP as motor work allows. 4/5/2017 4/6/2017 0.90 PROD1 DRILL REAM T Back ream up-hole HS from 6949'to 6,949.0 6,949.0 23:06 00:00 6927'MD.Observe negative WOB at -6939'MD.Ream down-hole HS to 6949'MD.Much cleaner down-hole pass than first with slight WOB bobble at 6939'MD. Page 3/7 Report Printed: 5/3/2017 a , • • Operations Summary (with Timelog Depths) 3M-14 Con coPhiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start lime End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/6/2017 4/6/2017 2.50 PROD1 DRILL REAM T Continue dressing window.Ream up- 6,949.0 6,925.0 00:00 02:30 hole 330 ROHS,down-hole HS,up- hole 30 ROHS,down-hole HS,and up -hole LS. Observed a bit more motor work reaming up-hole low-side. 4/6/2017 4/6/2017 2.30 PROD1 DRILL CIRC T Dry drift window HS,clean up and 6,926.0 6,972.0 02:30 04:48 down.RIH towards drilled depth of 6986'MD at 18 fpm and 1.7 bpm, WOB stacking of 5K at 6971'MD. PUH&RBIH at minimum rate,stack 6K WOB at 6972'MD. PU from 6972'MD,bring rate to 1.7 bpm and slowly PUH to circulate out OH,repeat.Significant sand over shakers from bottoms up.Continue circulating until shakers clean up(4 bottoms up). 4/6/2017 4/6/2017 0.20 PROD1 DRILL DLOG T Obtained SBHP at window to ensure 6,972.0 6,925.0 04:48 05:00 12.8 ppg will kill the well.Observed trend down to 12.7 ppg EMW. 4/6/2017 4/6/2017 2.00 PROD1 DRILL CIRC T Displace well to 12.8 ppg KWF,POOH 6,925.0 63.0 05:00 07:00 4/6/2017 4/6/2017 1.30 PROD1 DRILL PULD T At surface,PJSM,lay down BHA#3, 63.0 0.0 07:00 08:18 Inspect pipe above CTC. 4/6/2017 4/6/2017 0.80 PROD1 DRILL PULD T PJSM,M/U BHA#4 with 2.71°AKO 0.0 62.0 08:18 09:06 motor and new HCC Bi center,M/U to coil and surface test 4/6/2017 4/6/2017 1.40 PROD1 DRILL TRIP T RIH,EDC open 62.0 6,830.0 09:06 10:30 4/6/2017 4/6/2017 0.20 PROD1 DRILL DLOG T Log K1 for-.5' 6,830.0 6,850.0 10:30 10:42 4/6/2017 4/6/2017 0.10 PROD1 DRILL TRIP T trip in to 6911' 6,850.0 6,911.0 10:42 10:48 4/6/2017 4/6/2017 1.00 PROD1 DRILL CIRC T At 6911,Displace to 9.6 PPG Pwr Pro 6,911.0 6,911.0 10:48 11:48 4/6/2017 4/6/2017 0.20 PROD1 DRILL TRIP T Trip in to drill,tag up at 6973 and 6,911.0 6,985.0 11:48 12:00 ream down to 6985 4/6/2017 4/6/2017 3.00 PROD1 DRILL DRLG P 6985',drill ahead,1.5 BPM @ 4330 6,985.0 7,073.0 12:00 15:00 PSI FS,BHP=4232,At 7055 bring rate up to 1.7 BPM @ 4626 PSI FS, BHP=4248.Call EOB due to high DLS.AVG 56°.Landed at 6234'TVD. Near bit @ 93°when we left bottom 4/6/2017 4/6/2017 2.50 PROD1 DRILL TRIP P 7073'PUH to 6903',Open EDC and 7,073.0 64.0 15:00 17:30 start KWF down coil-Continue out displacing. 4/6/2017 4/6/2017 0.70 PROD1 DRILL PULD P Tag up,30 minute flow check,PJSM, 64.0 0.0 17:30 18:12 LD BHA#4 over a dead well(2.7+ degree AKO build assembly) 4/6/2017 4/6/2017 1.30 PROD1 DRILL PULD P PJSM,PU BHA#5(2.3+degree AKO 0.0 72.0 18:12 19:30 turn assembly,same bit as BHA#4), tag up. 4/6/2017 4/6/2017 1.20 PROD1 DRILL TRIP P RIH with BHA#5,turn drilling 72.0 6,820.0 19:30 20:42 assembly,Start 9.6 ppg PowerPro down coil Page 4/7 Report Printed: 5/3/2017 • • "«_ Operations Summary (with Timelog Depths) Pl 3M-14 conocodhiiiaps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/6/2017 4/6/2017 0.30 PROD1 DRILL DLOG P Log K1 for-1'correction,momentary 6,820.0 6,850.0 20:42 21:00 difficulty tying in with no values recieved from gamma tool,restart system,good. 4/6/2017 4/6/2017 1.50 PROD1 DRILL TRIP P Continue RIH to bottom,displacing 6,840.0 7,073.0 21:00 22:30 well to 9.6 ppg PowerPro. Experienced position error code when closing EDC,follow trouble-shooting procedure,recallibrate,open&close EDC for verfication of correct functionality. Stacking up to 7K WOB when RIH at —6972'MD. 4/6/2017 4/7/2017 1.50 PROD1 DRILL CIRC T Unable to work BHA past 6972'MD. 7,073.0 6,880.0 22:30 00:00 Attempted.3 bpm at 30 fpm.Confer with town as this is the 3rd BHA to stack at this depth(2nd BHA did not include Res tool).Decision made to attempt RIH at 1 bpm at 35 fpm, 1.25 bpm at 35 fpm,each time coming off pumps and PU to avoid begining to side-track.Continue to stack up to 7K WOB and unable to get by. PUH into cased hole and open EDC to begin circulating as town discusses situation. 4/7/2017 4/7/2017 0.30 PROD1 DRILL DLOG T Decision made to kill the well and 6,925.0 6,925.0 00:00 00:18 allow town to dicuss plan forward. Obtain SBHP to ensure 12.8 ppg flluid will kill well 4/7/2017 4/7/2017 6.00 PROD1 DRILL TRIP T Continue to circulate bottoms up 6,925.0 72.0 00:18 06:18 prepping to pump KWF.Displace well to KWF,POOH as per town request 4/7/2017 4/7/2017 1.30 PROD1 DRILL PULD T At Surface,flow check, PJSM lay 72.0 0.0 06:18 07:36 down BHA#5 4/7/2017 4/7/2017 0.70 PROD1 DRILL BHAH T M/U BHA#6, 0.0 0.0 07:36 08:18 4/7/2017 4/7/2017 1.20 PROD1 DRILL PULD T PJSM,P/U BHA#6 with 2.71°mortor 0.0 62.6 08:18 09:30 and RR HCC bi center,M/U to coil and surface test 4/7/2017 4/7/2017 1.50 PROD1 DRILL TRIP T Trip in well,EDC open 62.6 6,830.0 09:30 11:00 4/7/2017 4/7/2017 0.20 PROD1 DRILL DLOG T Log K1 for-.5' 6,830.0 6,851.0 11:00 11:12 4/7/2017 4/7/2017 0.10 PROD1 DRILL TRIP T Continue in to 6912 6,851.0 6,912.0 11:12 11:18 4/7/2017 4/7/2017 1.30 PROD1 DRILL CIRC T Displace well to 9.6 PPG PwrPro, 6,912.0 6,912.0 11:18 12:36 Close EDC 4/7/2017 4/7/2017 0.30 PROD1 DRILL TRIP T Trip in,clean pass through window, 6,912.0 6,981.0 12:36 12:54 set down at 6971,stack out two more times at different speeds.Wash down through tight spot to 6981 4/7/2017 4/7/2017 0.40 PROD1 DRILL WPRT T PUH to 6955 clean back down to 6,981.0 7,000.0 12:54 13:18 6985,wash down to 7000 Page 5/7 Report Printed: 5/3/2017 IP 0 ='- 'Arell'elf. Operations Summary (with Timelog Depths) 3M-14 cf Conocophitlips 7,1 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/7/2017 4/7/2017 1.80 PROD1 DRILL WPRT T 7000',PUH to 6964,PUW=25K clean 7,000.0 7,024.0 13:18 15:06 back down to 7000',wash down to 7010.At 7008 looks like more steady state drilling then washing, 1.5 BPM @ 4160 PSI FS,BHP=4210.Getting sand back entire time on bottom. 4/7/2017 4/7/2017 0.30 PROD1 DRILL WPRT T PUH wiper trip while restarting 7,024.0 6,953.0 15:06 15:24 database for MWD 4/7/2017 4/7/2017 0.50 PROD1 DRILL WPRT T RBIH,stack out @ 6973 stall @ 6975, 6,953.0 6,913.0 15:24 15:54 try to wash by stack out at 6974. Attempt to get by at min rate.No good 4/7/2017 4/7/2017 1.60 PROD1 DRILL WPRT T PUH through window,Open EDC and 6,913.0 6,930.0 15:54 17:30 jet 4 1/2 liner,1.7 BPM 4/7/2017 4/7/2017 2.50 PROD1 DRILL CIRC T Decision made to run liner.Displace 6,930.0 72.0 17:30 20:00 well to KWF 4/7/2017 4/7/2017 1.00 PROD1 DRILL TRIP T RBIH to log K1 for a-1'correction, 72.0 6,830.0 20:00 21:00 paint EOP flag 4/7/2017 4/7/2017 2.30 PROD1 DRILL TRIP T POOH,tag up 6,830.0 65.0 21:00 23:18 4/7/2017 4/8/2017 0.70 PROD1 DRILL PULD T Flow check,PJSM,Begin LD BHA#6 65.0 0.0 23:18 00:00 4/8/2017 4/8/2017 0.50 PROD1 CASING PULD T Complete LD BHA#6 0.0 0.0 00:00 00:30 4/8/2017 4/8/2017 2.30 COMPZI CASING PULD T PJSM,PU BHA#7(Non-Ported bull- 0.0 494.0 00:30 02:48 nose,11 joints slotted liner,seal bore deployment sleeve),stab on,tag up, open EDC. 4/8/2017 4/8/2017 3.20 COMPZI CASING RUNL T RIH with liner,tie into EOP flag, 494.0 6,973.0 02:48 06:00 weight check,get to set depth of 6973' MD,close EDC,bring up pumps, release off liner.BOL=6973'MD, TOL=6524'MD 4/8/2017 4/8/2017 0.90 DEMOB MOVE DISP P POOH displacing well to seawater, 6,973.0 2,500.0 06:00 06:54 diesel freeze protect from 2500'. - 4/8/2017 4/8/2017 1.20 DEMOB MOVE CIRC P PJSM,R/T LRS and load 30 BBIs 2,500.0 2,500.0 06:54 08:06 freeze protect diesel in coil,Chase FP with seawater,R/D LRS 4/8/2017 4/8/2017 0.70 DEMOB MOVE FRZP P Continue out of well laying in diesel 2,500.0 42.0 08:06 08:48 4/8/2017 4/8/2017 1.60 DEMOB MOVE PULD P PJSM,PUD BHA#7,Liner running 42.0 0.0 08:48 10:24 tools 4/8/2017 4/8/2017 2.00 DEMOB MOVE WWWH P Skid injector back to floor,Pull checks, 0.0 0.0 10:24 12:24 UQC, M/U nozzle and stab on.Jet stack and flush rig 4/8/2017 4/8/2017 1.60 DEMOB WHDBOP MPSP P PJSM,Rig up and set BPV 0.0 0.0 12:24 14:00 4/8/2017 4/8/2017 1.50 DEMOB MOVE CTOP P PJSM,Boot wire for slack mgmt,Stab 0.0 0.0 14:00 15:30 on well and reverse circulate 4/8/2017 4/8/2017 1.00 DEMOB MOVE CTOP P PJSM,Unstab injector and rig CT 0.0 0.0 15:30 16:30 cutter to injector,Cut 76'pipe to find wire.Trim total 100' 4/8/2017 4/8/2017 3.00 DEMOB MOVE CTOP P Prep coil and install coil connector, 0.0 0.0 16:30 19:30 pull test to 35K,pressure test UQC to 4000 psi 4/8/2017 4/8/2017 2.00 DEMOB MOVE RURD P Flush and blow down lines,methanol 0.0 19:30 21:30 freeze protect well to upper swab (visually verified). Page 6/7 Report Printed: 5/3/2017 i • 41, Operations Summary (with Timelog Depths) •• 3M-14 ConocoPhillips at;rk;a Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/8/2017 4/9/2017 2.50 DEMOB CASING NUND P Grease valves,ND BOPE,continue 0.0 0.0 21:30 00:00 rig down check list. **Rig released at 24:00,4-8-17 Page 7/7 Report Printed: 5/3/2017 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3M Pad 3M-14A 50-029-21726-01 Baker Hughes INTEQ rani Definitive Survey Report HUGHES 02 May,2017 4111 . ConocoPhillips Ni%l111 ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc-Kup2 Local Co-ordinate Reference: Well 3M-14 Project: Kuparuk River Unit ND Reference: 3M-14 @ 63.00usft(3M-14) Site: Kuparuk 3M Pad MD Reference: 3M-14 @ 63.00usft(3M-14) Well: 3M-14 North Reference: True Wellbore: 3M-14A Survey Calculation Method: Minimum Curvature Design: 3M-14A Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level I Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point 1. Map Zone: Alaska Zone 04 Using geodetic scale factor ii Well 3M-14 Well Position +N/-S 0.00 usft Northing: 6,016,548.62 usft Latitude: 70'2T 23.186 N I +E/-W 0.00 usft Fasting: 506,270.30usft Longitude: 149°56'55.779 W „ Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0 00 usft rl Wellbore 3M-,4A 1, Magnetics Model Name - - _ Sample Date ? Deatteitelt,,,, - = Dip Angle Field(Strength l BGGM2016 3/1/2017 1772 81.00 57,547 Design :3M-14A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,900.00 .. .men Vgrgca(Sgation: Depth From(ND) +N!-S +E/-W (usft) (usft) .. (usft) (y) ....-. 1 36 60 0 00 0.00 200.00 Survey Program ' Date 4/11/2017 "` '' From. To -Survey Survey Description i :(usft) (usft) Survey(WellboreTool Name _ -Start Date End Date 3 100.00 6,900.00 3M-14(3M-14) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/15/2001 t 6930.00 7,044.80 3M-14A(3M-14A) MWD MWD-Standard 4/4/2017 4/8/2017 i 52/2017 2:00:01P161 Page 2 COMPASS 5000 1 Build 74 • • ConocoPhillips ConocoPhillips Definitive Survey Report H RAKE Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3M-14 Project: Kuparuk River Unit ND Reference: 3M-14 @ 63.00usft(3M-14) Site: Kuparuk 3M Pad MD Reference: 3M-14©63.00usft(3M-14) Well: 3M-14 North Reference: True Wellborn: 3M-14A Survey Calculation Method: Minimum Curvature Design: 3M-14A Database: EDM Alaska NSK Sandbox Survey Vertical MD Inc<. ASTVD TVDSS +N14 ��„ t9OtibinS E8itirig DLS section Survey Tool Name Annotation (usft) ri' ei 1. .lofty, {al Iwoo polo.: .. '.. 0 (.Hoo') ) 6,900 00 3248 1530 6,205.99 6,142.99 2,219.05 780.26 6,018,768.10 507,048.61 0.39 -2,352.09 MWD(2) TIP 6,930.00 32.38 15.36 6,231.31 6,168.31 2,234.56 784.51 6,018,783.62 507,052.85 0.35 -2,368.12 MWD(2) KOP j 6,950.93 36.63 14.50 6,248.56 6,185.56 2,246.02 787.56 6,018,795.08 507,055.89 20.43 -2,379.93 MWD(2) 6,981.02 47.94 13.00 6,270.78 6,207.78 2,265.66 79234 6,018,814.72 507,060.65 37.73 -2,400.02 MWD(2) 2 7,010.34 6404 11.50 6,287.13 6,224.13 2,289.34 797.45 6,018,838.40 507,065.74 5207 -2,42402 MWD(2) 7,044.80 83.78 10.33 6,296.63 6,233.63 2,321.69 803.67 6,018,870.75 507,071.94 57.38 -2,456.55 MWD(2) 7,073.00 83.78 10.33 6,299.69 6,236.69 2,349.27 808.70 6,018,898.33 507,076.94 0.00 -2,484.18 PROJECTED to TD &2/2017 2:00,b1PM Paps 3 COMPASS 5000.1 Build 74 ACEIVED • MAY 04 2017 Letter of Transmittal FAIN AOGCC BAKER Date: DATA LOGGED May 4, 2017 M.K.BENDR HUGHES To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3M-14A 2 1 6 1 7 1 2 8 1 7 1 2Z-29L1PB1 2 1 6 0 4 5 2 8 1 7 0 2Z-29L1 21 6045 28 1 69 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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T Q ' -Fr r N. U cet c'' (0 x0 333,o J z o '01 0 0400 10100400 000' 00 10 I 0...914 a7 7 V4Y iii O (O() O CO M (D N • V 0)(n O N (N N MN WN N N NNN NZ N N N tv fn m M !D) N r (D (OD N co (n r 7 (+) (0 3 O N (N W N N N N v ((1 (5 (5 (5 (5 (5 (5 s }m M N r , N (D N {Y 9iI • N N N N N 83 N U • d � ) co- O co ( L x Yr.,b W o 8i (0D o 8. (N M 00 Q -o } 0 v 6 d N =Li- 00 1 > ; '.. Y • £ m m it 00 a-NVV V OMW N°- -N v M M M N v m ro roc a a OS YY M ()U ya OOm O M N O N-OM NmO rU 0 rn o0 0 0T ,O O (D (0 N- r rim T AU o C O U � o ad+ d N d 7 . • 0 ti1//7711,4' 6. THE STATE Alaska Oil and Gas OfALASKA/e Conservation Commission Sf - 333 West Seventh Avenue 1, .- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS Fax: 907.276.7542 www.aogcc.alaska.gov Gary Eller Principal CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3M-14A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-171 Surface Location: 950' FNL, 1598' FEL, Sec. 25, T13N, R8E, UM Bottomhole Location: 477' FNL, 1531' FEL, Sec. 25, T13N, R8E, UM Dear Mr. Eller: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair, Commissioner DATED this 4ay of December, 2016. STATE OF D AIL OIL AND GAS CON ERVAT ON COMMON IVE PERMIT TO DRILL DEC 2 8 2016 20 AAC 25.005 1 a.Type of Work: 1b.Proposed Well Class: Exploratory-Gas E Service- WAG ❑ Service-Disp ❑ lc.Specify if 0, •.•.-+ fo Drill 111 Lateral 111 Stratigraphic Test ❑ Development-Oil 0+ Service- Winj ❑ Single Zone 0 ' Coalbed Gas �IGas Hydrates ❑ Redrill O. Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 , Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc ` Bond No. 59-52-180 • KRU 3M-14A 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9600 " TVD: 6278. 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): es Kuparuk River Field/Kuparuk Oil Pool Surface: 950'FNL, 1598'FEL,Sec.25,T13N,R8E,UM ADL 25522 a .2,3 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: FNL 4046',536'FEL,Sec.24,T13N,R8E,UM ALK 2558 1/15/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: FNL 477', 1531'FEL,Sec.25,T13N,R8E,UM 2560 6800' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 64 15.Distance to Nearest Well Open Surface:x- 506270 y- 6016548 Zone-4 $ GL Elevation above MSL(ft): 27 , to Same Pool: 1879'to 3M-18 16.Deviated wells: Kickoff depth: 6931' feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 103 degrees, Downhole: 4728 psig , Surface: 4108 psig e 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 7,500 6,245' 9,600 6278' Slotted 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 7129' 6400' 7124' 7224' 6481' 7127' Casing Length Size Cement Volume MD TVD Conductor/Structural 83' 16" 200 sx CS3 121' 121 Surface 3436' 9-5/8" 1389 sx AS III&371 sx Class G 3473' 3377' Scab Liner 528' 4-1/2" 175 sx CS I 7127' 6399' Production 7189' 7" 300 sx Class G&175 sx CS I 7224' 6481' Perforation Depth MD(ft): Perforation Depth ND(ft): 6940'-6976',Reperf:6956'-6976' 6240'-6270,Reperf:6253'-6270 20. Attachments: Property Plat ❑ BOP Sketch Q Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 12/12/2016 22.I hereby certify that the foregoing is true and the procedure approved herein will not Jeff Connelly @ 263-4112 be deviated from without prior written approval. Contact Email jeff.s.connelly@cop.com Printed Name G.Eller \ Title Principal CTD Engineer Signature 0, 1i Phone 263-4172 Date 12/12/2016 Commission Use Only Permit to Drill_ ' / A Number: Permit Approval See cover letter for other Number: o'1G - �' 50-0 9,9-.27.2c-0/ -f Date: /.2/3g//ea) requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: IX Other: 8d�few f0 ��OO r -SetSamples req'd: Yes Nog Mud log req'd:Yes❑ No j ' rl r1, t/1 ow-�J re-l /rl ` /pct f-0 Z 5-0 0 pS �measures: Yes No EI Directional Directional svy req'd:Yes[(�No❑ Spacing e�fception req'd: Yes❑ NoL✓� Inclination-only svy req'd:Yes❑ No LJ r*kt Z l 2.56.1, Post initial injection MIT req'd:Yes❑ No I / n APPROVED BY Approved by: '/ COMMISSIONER THE C M IS ION Date:/2 -(� ii '' 11.4976:- !--2-7-44,71/-d r AL Submit Form and 0 10-401(Revised11/2015) Thispermit is for 24 months fro Rt� 5.005 Form p�r' ( (g)) Attachments in Duplicate I4TL)2/21]/4® 110"." • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 28, 2016 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to,drill a quad-lateral out of KRU 3M-14 (PTD# 187-051) using the coiled tubing drilling rig, Nabors CDR2-AC The work may begin as soon as January 1, 2017. The CTD objective will be to drill four laterals (3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3), targeting the Kuparuk A-sand. The final CTD completion will fully isolate the 3M-14 mother bore, which suffers from damaged 4W liner and rock production. There is insufficient room to properly abandon the 3M-14 mother bore with a plug or cement, so ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for alternate plugging which will isolate/abandon 3M-14 via swell packer and liner-top packer of the final CTD completion. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point of the laterals to be anywhere along the length of the parent borehole instead of being limited to 500' from the original point. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3 — Sundry Application Form (10-403) for abandonment of 3M-14 • — Detailed Summary of Operations — Directional Plans for 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4172. Si cerely, Gary Eller ConocoPhillips esiled Tubing Drilling Team Lead • Kuparuk CTD Laterals NA ORALASKA ( t= 3M-14A, 3M-14AL1 3M-14AL2 and 3M-14AL3, l) ConocoPhillips Application for Permit to Drill Document 211c 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(0)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 3M-14A, 3M-14AL1, 3M-14AL2,and 3M-14AL3 7 Attachment 2: Current Well Schematic for 3M-14 7 Attachment 3: Proposed Well Schematic for 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3 7 Page 1 of 7 December 28, 2016 • PTD ApplicalTSn: 3M-14A, AL1, AL2, and AL3 1. Well Name and Classification (Requirements of 20 AAC 25.0050 and 20 AAC 25.005(b)) The proposed laterals described in this document are 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3. 3. Blowout Prevention Equipment Information (Requirements of 20 AA C 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4600 psi. Using the maximum formation pressure in the area of 3M-26 (i.e. 14.67 ppg EMW), he maximuni potential surface pressure in 3M-14, assuming a gas gradient of 0.1 psi/ft, would be 4108 psi/See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 3M-14 was measured to be 4092 psi (12.62 ppg EMW) on 11/29/2016. The maximum downhole pressure in the vicinity is 3M-26 at 4728 psi4(14.67 ppg EMW) measured 7/23/2016, although we have been back-flowing 3M-26 and 3M-06 in order to reduce formation pressure in the area. Since this back-flow began in July we have seen a steady reduction in the formation pressure at 3M-14, so that we now believe the measured formation pressure in 3M-14 represents the highest pressure we expect to encounter during drilling. The lowest downhole pressure in the 3M-14 vicinity is to the northeast in the 3Q-02 injector at 4069 psi (12.51 ppg EMW) measured 8/6/2014. Potential Gas Zones (Requirements of 20 AA C 25.005(c)(4)(b)) MI gas injection has occurred in the area, there is the potential of encountering free gas while drilling the 3M-14 laterals. If significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems in the 3M-14 laterals will be shale instability at large fault crossings. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3M-14 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 December 28, 2016 • PTD ApplicaZ4@'in: 3M-14A, AL1, AL2, and AL3 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3M-14A 7500' 9,600' 6,182' 6,215' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3M-14AL1 7200' 9,650' 6,204' 6,200' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3M-14AL2 6,981' 10,250' 6,207' 6,206' 2%', 4.7#, L-80, ST-L slotted liner; aluminum billet on tip 3M-14AL3 6575' 10,250' 6,058 6,175' 2%', 4.7#, L-80, ST-L slotted liner; up into 3.5" tubing Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (PO) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 38' 121' 38' 121' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 37' 3473' 37' 3377' 3520 2020 Production 7" 26.0 J-55 BTC 35' 7224' 35' 6481' 4980 4330 Scab Liner 4-1/2" 12.6 L-80 IBTM 6599' 7127' 5953' 6399' 8430 7500 Tubing 3-1/2" 9.3 L-80 EUE 33' 6502' 33' 5873' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (8.6 ppg) — Drilling operations: Chloride-based FloVis mud (9.6 ppg expected). This mud weight will not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 13.0 ppg potassium formate completion fluid to provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3"Blowout Prevention Equipment Information". Page 3 of 7 December 28, 2016 • PTD Applica'lTun: 3M-14A, AL1, AL2, and AL3 In the 3M-14 laterals we will target a constant BHP of 12.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3M-14 Window(6931' MD, 6232' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.6 ppg) 4083 psi 4083 psi Mud Hydrostatic(9.6 ppg) 3111 psi 3111 psi Annular friction (i.e. ECD, 0.080 psi/ft) 555 psi 0 psi Mud + ECD Combined 3666 psi 3111 psi (no choke pressure) (underbalanced (underbalanced -420 psi) —970 psi) Target BHP at Window(12.8 ppg) 4148 psi 4148 psi Choke Pressure Required to Maintain Target 480 psi 1040 psi BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU 3M-14 is a Kuparuk A-sand production well that was worked over to install 4W scab liner to remediate rock production from the perfs, but it didn't take long for the 4W scab liner to become damaged and rock production to resume so that the well is still not capable of production. Four CTD laterals will be drilled from the 3M-14 parent well-bore, two to the south and two to the north, to serve as a replacement wellbore and isolate section producing rocks. The mother completion will be isolated/abandoned using a 2%" swell packer and liner top packer—insufficient room exists to plug the mother completion with cement or a mechanical plug. ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method which will not risk migration of fluids between strata. Page 4 of 7 December 28, 2016 111 PTD Applicain: 3M-14A, AL1, AL2, and AL3 The 3M-14A lateral will exit through tae 4'/2"scab-liner and 7"casing via whipstock at 6931' MD and TD at 9600' MD,targeting the Al sands. It will be completed with 2%"slotted liner from TD up to 7500' MD with an aluminum billet for kicking off the 3M-14AL1 lateral. The 3M-14AL1 lateral will drill south to a TD of 9650' MD targeting the A2 sands. It will be completed with 2%" slotted liner from TD up to 7200' MD with an aluminum billet for kicking off the 3M-14AL2 lateral. The 3M-14AL2 lateral will drill north to a TD of 10250' MD targeting the Al sand. It will be completed with 2%" slotted liner from TD up to 6981' MD with an aluminum billet for kicking off the 3M-14AL3 lateral. The 3M-14AL3 lateral will drill north to a TD of 10250' MD targeting the Al sands. It will be completed with 2%" slotted liner from TD up to 6575' MD up into the 3.5"tubing. A 2%" swell packer and a 31/2" liner-top packer will be used along with blank 2%"liner to isolate/abandon the original 3M-14 completion, mitigating against future rock production. Pre-CTD Work 1. RU Slickline: Obtain static bottom-hole pressure 2. RU E-line: Drift tubing and tag fill/rocks at 6954' MD 3. RU E-line: Set Baker Hughes whipstock at 6931' MD. 4. Prep site for Nabors CDR3-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3M-14A Lateral(A sand-south) / a. Mill 2.80"window at 6931' MD. I. b. Drill 3"bi-center lateral to TD of 9600' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 7500' MD. 3. 3M-14AL1 Lateral(A sand-south) a. Kick off of aluminum billet at 7500' MD. b. Drill 3"bi-center lateral to TD of 9650' MD. c. Run 2%"slotted liner from TD up to 7200' MD. 4. 3M-14AL2 Lateral(A sand-north) a. Kick off of aluminum billet at 7200' MD. b. Drill 3"bi-center lateral to TD of 10250' MD. c. Run 23/8"slotted liner from TD up to 6981' MD. 5. 3M-14AL3 Lateral(A sand-north) a. Kick off of aluminum billet at 6981' MD. b. Drill 3"bi-center lateral to TD of 10250' MD. c. Run 2%"slotted liner from TD up to 6575' MD. Liner will include a swell packer,blank 2%" liner, and a sealbore deployment sleeve to isolate/abandon the mother completion. 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CDR2-AC. Page 5 of 7 December 28, 2016 • PTD Applica un: 3M-14A, AL1, AL2, and AL3 Post-Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install liner-top packer onto the 23/8"liner 4. Install GLV's. 5. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process.A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse Liner Running — The 3M-14 laterals will be displaced to an overbalanced fluid prior to running liner. See "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. Page 6 of 7 December 28, 2016 • PTD Applicaen: 3M-14A, AL1, AL2, and AL3 • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section./ — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3M-14A 6800' 3M-14AL1 6800' 3M-14AL2 5230' 3M-14AL3 5230' — Distance to Nearest Well within Pool Lateral Name Distance Well 3M-14A 1879' 3M-18 3M-14AL1 1879' 3M-18 3M-14AL2 1146' 3M-18 3M-14AL3 1146' 3M-18 16. Attachments Attachment 1: Directional Plans for 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3 Attachment 2: Current Well Schematic for 3M-14 Attachment 3: Proposed Well Schematic for 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3 Page 7 of 7 December 28, 2016 e 0 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3M Pad 3M-14 3M-14A Plan: 3M-14A wp06 Standard Planning Report 08 December, 2016 r' 1 BAKER HUGHES • • ConocoPhillips FAIN ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3M-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3M-14 @ 63.00usft(3M-14) Site: Kuparuk 3M Pad North Reference: True Well: 3M-14 Survey Calculation Method: Minimum Curvature Wellbore: 3M-14A Design: 3M-14A_wp06 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3M Pad Site Position: Northing: 6,016,202.17usft Latitude: 70°27'19.780 N From: Map Easting: 506,126.99 usft Longitude: 149°56'59.998 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.05 ° Well 3M-14 Well Position +N/-S 0.00 usft Northing: 6,016,548.62 usft Latitude: 70°27'23.186 N +EI-W 0.00 usft Easting: 506,270.30 usft Longitude: 149°56'55.779 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3M-14A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2016 3/1/2017 17.72 81.00 57,547 Design 3M-14A_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,900.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) -26.40 0.00 0.00 200.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (0) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 6,900.00 32.48 15.30 6,142.99 2,219.05 780.26 0.00 0.00 0.00 0.00 6,931.00 32.38 15.36 6,169.16 2,235.08 784.66 0.34 -0.32 0.19 162.19 6,951.00 36.58 15.36 6,185.64 2,246.00 787.65 21.00 21.00 0.00 0.00 7,091.93 100.00 15.36 6,235.15 2,365.91 820.59 45.00 45.00 0.00 0.00 7,230.00 101.67 78.73 6,206.31 2,453.43 914.27 45.00 1.21 45.90 82.00 7,445.00 88.64 175.34 6,180.73 2,338.09 1,063.52 45.00 -6.06 44.94 90.00 7,895.00 90.93 206.76 6,182.49 1,901.98 978.35 7.00 0.51 6.98 86.00 8,110.00 89.60 221.75 6,181.50 1,724.78 857.67 7.00 -0.62 6.97 95.00 8,360.00 89.01 204.26 6,184.55 1,515.96 722.03 7.00 -0.23 -7.00 268.00 8,610.00 88.76 221.76 6,189.44 1,307.17 586.39 7.00 -0.10 7.00 91.00 8,910.00 88.84 200.76 6,195.79 1,052.21 431.63 7.00 0.03 -7.00 270.00 9,110.00 88.88 214.76 6,199.79 875.70 338.73 7.00 0.02 7.00 90.00 9,260.00 88.53 204.26 6,203.20 745.38 264.96 7.00 -0.23 -7.00 268.00 9,600.00 87.45 228.05 6,215.31 472.99 65.95 7.00 -0.32 7.00 93.00 12/8/2016 5:27:52PM Page 2 COMPASS 5000.1 Build 74 • S ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3M Pad 3M-14 3M-14A 3M-14A_wp06 Travelling Cylinder Report 08 December, 2016 r' 1 BAKER HUGHES Baker Hughes INTEQ Conoco • 0 Phillips Travelling Cylinder Report BAKER•• HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3M-14 Project: Kuparuk River Unit TVD Reference: 3M-14 @ 63.00usft(3M-14) Reference Site: Kuparuk 3M Pad MD Reference: 3M-14 @ 63.00usft(3M-14) Site Error: 0.00 usft North Reference: True Reference Well: 3M-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3M-14A Database: OAKEDMP2 Reference Design: 3M-14A_wp06 Offset TVD Reference: Offset Datum Reference 3M-14A_wp06 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,900.00 to 9,600.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,156.34 usft Error Surface: Elliptical Conic Survey Tool Program Date 12/8/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 6,900.00 3M-14(3M-14) BOSS-GYRO Sperry-Sun BOSS gyro multishot 6,900.00 9,600.00 3M-14A_wp06(3M-14A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C') 3,489.00 3,389.72 95/8" 9-5/8 12-1/4 9,600.00 6,278.31 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 3M Pad 3M-02-3M-02-3M-02 Out of range 3M-05-3M-05-3M-05 Out of range 3M-06-3M-06-3M-06 Out of range 3M-13-3M-13-3M-13 Out of range 3M-14-3M-14-3M-14 6,949.97 6,950.00 0.67 2.07 -1.24 FAIL-Major Risk 3M-14-3M-14AL1-3M-14AL1_wp03 7,440.02 7,425.00 0.09 1.01 -0.70 FAIL-Minor 1/10 3M-14-3M-14AL2-3M-14AL2_wp06 7,224.65 7,225.00 2.63 0.49 2.24 Pass-Minor 1/10 3M-14-3M-14AL3-3M-14AL3_wp00 7,025.00 7,025.00 0.10 0.33 -0.23 FAIL-Minor 1/10 3M-15-3M-15-3M-15 Out of range 3M-16-3M-16-3M-16 Out of range 3M-17-3M-17-3M-17 Out of range 3M-18-3M-18-3M-18 Out of range 3M-18-Plan:3M-18A-3M-18A(wp03) 7,170.00 7,249.97 484.57 184.32 300.85 Pass-Major Risk 3M-19-3M-19-3M-19 Out of range 3M-20-3M-20-3M-20 Out of range 3M-26-3M-26-3M-26 Out of range Offset Design Kuparuk 3M Pad- 3M-14-3M-14-3M-14 Offset Site Error: 0.00 usft Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 6,925.00 6,227.09 6,925.00 6,227.09 0.08 0.15 175.07 2,231.98 783.815 0.00 1.26 -1.08 FAIL-Major Risk,CC 6,949.97 6,247.81 6,950.00 6,248.21 0.10 0.30 -164.97 2,244.88 787.355 0.67 2.07 -1.24 FAIL-Major Risk,ES,SF 6,974.17 6,265.89 6,975.00 6,269.35 0.10 0.45 -164.87 2,257.75 790.905 4.73 3.43 1.33 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/8/2016 3:21:11PM Page 2 COMPASS 5000.1 Build 74 I, Ell o 0 V p N o .d 8 0 `{ yr ? 2 co C :N - = R 'k�" Q� :o 2 5 dO M O O o £0.J WI-NI£ Nn v 0 O :o a N b r O en O Ora O F- oU V \ A �§ � WG W 0 -z ` � Q v �, aiOr U g Su g C M O Y-.g O� Omwvdm�3 a .� . :o-Lo= o i a Alto,. i GG -= u I w N W' 4NI-' O'' - :o 0 V u-LI Z''"yr p- V�J �_ o P-1- .-1 „, y ry ^ F 'O wl .K -N a a V^ ^ N ^e. 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Comment H2S(ppm) Date Annotation End Date KB-Grd(5) "Rig Release Date 3M-14,3/31201692254 AM SSSV:NIPPLE 125 4/4/2013 Last WO: 12/19/2012 41.90 6/5/1987 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..._..______.-....__............__._._..._............... ..Last Tag:SLM 6,926.0 3/302016 Rev Reason:TAG lehallf 3/312016 HANGER;32.8 -Casing Strings IF Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread Ii CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H-40 welded - --ami Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread SURFACE 95/8 8.921 37.0 3,473.1 3,376.7 36.00 J-55 BTC CONDUCTOR;38.0-121.0 aCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread -- PRODUCTION 7 6.276 34.8 7,224.0 6,481.2 26.00 J-55 BTC VI Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread NIPPLE;5417 V3 SCAB LINER 4 1/2 3.958 6,598.8 7,127.0 6,398.5 12.60 L-80 IBTM Liner Details Nominal ID -..- Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) p��� 6,598.8- 5,953.3' 33.55'PACKER Baker"2RH"ZXP Liner Top Packer w/10'Tie-back 4.300 .IEGAS LIFT;2,523.3 c Ext,5"BTC BxP 6,617.4 5,968.8 33.47 HANGER BAKER HYDRUALIC FLEX-LOCK LINER HANGER 4.400 1.. 6,627.2 5,977.0 33.42 SBE Baker 80-40 SBE,20'Long,5"BTC 4.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth IND)(...Wt(Iblft) Grade Top Connection SURFACE;37,D-3,473.1-• TUBING WO 31/2 2.992 328 6,502.4 5,873.0 9.30 L-80 EUE - Completion Details Nominal ID GAS LIFT;4,115.1 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 32.8 32.8' 0.04 HANGER FMC,GEN IV Tbg hanger w/3 1/2"TBG Pup. 2.992 541.7 541.7 0.31 NIPPLE 2.875"Landing Nipple w/'DS'Profile 2.875 „AE 6,479.7 5,854.1 33.74 SEAL ASSY Baker 80-40 GBH-22 Production Seal Assembly 2.990 GAS LIFT;5,272.2 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection PACKER ASSY 3.98 2.980 6,486.2 6,643.5 5,990.6 EUE Completion Details Nominal ID Top(ftKB) _Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) GAS UFT;6,113.2-Iea' 6,486.2 5,859.5 33.70 PBR BAKER PBR 4.000 6,509.3 5,878.7 33.62 PACKER 'BAKER'FHL'PACKER 2.980 6,559.8 5,920.8° 33.58'NIPPLE CAMCO 2.812"Landing Nipple w/'DS'Profile 2.812 6,605.6 5,959.0 33.52'SEAL ASSY 'BAKER 80-40 GBH-22 Production Seal Assembly w/2-ft 2.980 GAS LIFT;6,423.2 1. E space out Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB( (°) Des Com Run Date ID(in) _ 7,127.0 6,398.5 31.50 FISH ESP motor parts,remnants of ESP motor pushed 12/3/2012 downhole to 7127 RKB w/workover 12/3/2012- SEAL ASSY.6,479.7 t*4 should be fill to 7244'drillers TD(FRAC or formation PBR;6,486.2 I sand)6/10/2005-ESP motor parts,remnants of ESP motor pushed downhole to 7010 w/workover PACKER;6.509.3 6/10/2006 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotan NIPPLE;6,559.8 US Top(ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date t) Type Com 6,940.0 6,942.0 6,239.8 6,241.4 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab SQZ liner 2012 6,944.0 6,945.0 6,243.1 6,244.0 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab I1 ® Lr SQZ liner 2012 6,948.0 6,949.0 6,246.5 6,247.4 A-2,3M-14 8/16/1998 1.0 CMT Covered by CMT Scab 1, 4 SQZ liner 2012 SEAL ASSY;6,605.6 i'.. 6,954.0 6,992.0 6,251.6 6,283.7 A-1,3M-14 8/16/1987 4.0 CMT 'Covered by CMT Scab in SQZ liner 2012 It ilit 6,956.0 6,976.0' 6,253.3 6,270.2 A-1,3M-14 2/21/2013 2.0 RPERF 'HSC 2.5"w/180 degree phasing,Millenium II HMX charges Cement Squeezes 0 Top KBl Olin(ND) CMT 502;6,9400-6,942. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 6,598.8 7,127.0 5,953.3 6,398.5 Liner Cement 12/7/2012 CMT Soz;6,944.0-6.945.0 - Mandrel Inserts -. St atl CMT SO2;6,948.0-6,949.0-- - - N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) _ Run Date Com - - 1' 2,523.3 2,520.6 Camco MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,270.0 5/222013 10:00 ."r 2 4,115.1 3,905.6 Camco MMG 1 1/2-GAS LIFT GLV R-20 0.188 1,268.0.5/222013 5:00 3 5,272.2 4,863.3 Camco MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,277.0 5/22/2013 7:00 RPERF;6,956.0-6,976.0 OMT SW;6,954.0-6,992.0-� �. 4 6,113.2 5,551.4 Camco MMG 11/2 GAS LIFT OV RD02 0.250 0.0-5/22/2013 1:00 0 5 6,423.2 5,807.2 Camco MMG 1 1/2 GAS LIFT DMY RK - 0.000 0.0 12/17/2012 6:30 Notes:General&Safety End Date Annotation 7/2/2006 NOTE:WORKOVER 7/28/2006 NOTE:PER CALIPER LOG 6/27/2006,SEVERE 7"CASING DAMAGE @ 6942'-6946' 8/17/2006 NOTE:RECOVERED ROCKS TO 1.5"DURING TAG 1 7/21/2008 NOTE:SAND&PEBBLES OBSERVED @ 6930' 10/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 SCAB LINER;6,598.8-7,127.0AL 12/19/2012 NOTE:WORKOVER SET CEMENTED 4.5"SCAB LINER TO COVER 7"PROD CSG DAMAGE FISH;7,127.0 PRODUCTION;34.6-7,224.0 • • mir _c 2 ) co o 0 p N 2 o2 II b O O II Lo O II N r p J o co 2 a) a) II II tic La co o aI II 0 N 3 N c7 co it C w N r 3a II II o0a U N 3 >-- r J V N O N C 03 Lo En Q O r C O) V -o To (0 N I' C O \ cocndN 4) c')N m o p Y — in 1 11 (y m -O c N Y .cam 0 N in m Y115CC al EC F-- o \` a r- o r i' m o co a� ,r °) ooa -0 Lo H ci a aa\\YLO vi E E(o�� m II @ V CO cc co a) a) @ @N w o =Y �ifl© ctQ �Y mca W N w� Nis o y mW J O 0 II v m r N o coo c o.�co Q 2 op o .o o N C1 _ m o( Q a co .o o.c Q co in v II N U a) a) <0 (0 U , E 4)0]2 O U BYO .N- O O) co Ilk n �� co CL aw n 000 �_ C N N N ,a N fV—J N CV - U C II - N U U) \ N N N N x (ll al O C a O ) N r) 0 M CO 4)CO 0 CO v N IL co - Y = _ a) = /` cLO I p 3 D 0 cnNa / \Hico co p CD NN a) C Ya` 0 // itia � 9i c_ 6 S: 91111e _V w � II II I td E m a v CrKI rij p pa m I c75 CO oo p ifl CI or tw� II II 1 U Nin -o- a(9 .o o -p Lop my co co w II It o a`) a) ia �M No Lo ul� O 3 II C O a)m Q Q m O N o a 0- i0 N W II II J 6p p _ Q O L 0 m d' C (A- d a n II r 0\rn 'V OL( II (+)Q-N CO Ln.3 N M O O M cor 4) sa N F N a II 0 p a a) t J Z coo II II 06 oo \ o co i_N ® ® -t.,-,. J • • Bettis, Patricia K (DOA) From: Connelly,Jeff <Jeff.S.Connelly@conocophillips.com> Sent: Wednesday, December 28, 2016 3:16 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3M-14A Permit to Drill Application (PTD 216-171) Patricia, The mud weight planned for use on 3M-14 CTD will indeed be 9.6 ppg.Thank you for following up on this. Regards, Jeff From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday, December 28, 2016 3:10 PM To: Connelly,Jeff<Jeff.S.Connelly@conocophillips.com> Subject: [EXTERNAL]KRU 3M-14A Permit to Drill Application (PTD 216-171) Good afternoon Jeff, On page 3, item No. 8 Drilling Fluids Program, it is stated that the 9.6 ppg mud will be used for the drilling operations. In the past,this mud weight has been 8.6 ppg. Would you please verify the mud weight to be used to drill KRU 3M-14A. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, December 28, 2016 3:10 PM To: 'Jeff.s.connelly@conocophillips.com' Subject: KRU 3M-14A Permit to Drill Application (PTD 216-171) Good afternoon Jeff, On page 3, item No. 8 Drilling Fluids Program, it is stated that the 9.6 ppg mud will be used for the drilling operations. In the past, this mud weight has been 8.6 ppg. Would you please verify the mud weight to be used to drill KRU 3M-14A. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, December 28,2016 10:34 AM To: Eller,J Gary Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 3M-14 (187-051)CTD Sidetrack Thanx for the heads up- From: Eller,J Gary[mailto:J.Gary.Eller@conocophillips.com] Sent:Wednesday, December 28,2016 10:32 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Starck, Kai<Kai.Starck@conocophillips.com>; Haggerty-Sherrod,Ann(Northland Staffing Services)<Ann.Haggerty- Sherrod@contractor.conocophillips.com> Subject: RE: KRU 3M-14(187-051)CTD Sidetrack Victoria— I have four 10-401's and one 10-403 headed over to you today for KRU 3M-14. In related news, Nabors CDR2 is in the midst of a difficult workover on well 3M-24. We are going to make one last effort to retrieve a packer that has given us substantial trouble already. If we recover the packer, then we'll proceed according to our original plan. But if we fail, we plan to suspend that workover and move Nabors CDR2-AC to well 3M-14 to drill these laterals. That means there is the possibility that we will want to begin CTD operations on 3M-14 as early as January 1, 2017,so I request expedited approval of these drilling permits (at least the first one, 3M-14A). I'm sorry to rush you like that, but events have conspired against us. Thanks much for your help. -Gary Eller From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, December 28,2016 8:26 AM To: Eller,J Gary<J.Garv.Eller@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3M-14(187-051)CTD Sidetrack Hi Gary, We will still need a plug for redrill 10-403 for the motherbore to review the proposed abandonment.We will also approve the alternate plug placement approval as a part of that 10-403. Please submit the 10-403 plug for redrill with the PTDs even though the abandonment procedure will be accomplished during the CTD sidetrack. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp&:alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 1 recipient of this e-mail,please delete it,witt first saving or forwarding it,and,so that the A•C is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Eller,J Gary Finailto:J.Gary.Eller@conocophillips.com] Sent:Tuesday, December 27,2016 3:15 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Burke,Jason<Jason.Burke@conocophillips.com>;Connelly,Jeff <Jeff.S.Connelly@conocophillips.com>;Starck, Kai<Kai.Starck@conocophillips.com> Subject: KRU 3M-14(187-051)CTD Sidetrack Victoria—In just a few days, ConocoPhillips will be submitting 10-401's for CTD sidetrack/laterals from KRU 3M-14 (187- 051). Well 3M-14 is a rock producer that is incapable of production, and the CTD sidetrack will restore this lost productivity. The attached schematic shows that following the sidetrack, the new CTD borehole will be completed with 2- 3/8"swell packer and liner-top packer in order to permanently isolate the existing, rock-producing perfs of KRU 3M-14. I wanted to contact you because the abandonment of the motherbore, 3M-14, is unusual in that we are unable to mechanically abandon the perforated, rock-producing interval prior to CTD sidetrack. There is just sufficient room above the compromised 4W scab liner for a single whipstock exit, and we do not have room for a cement plug or other mechanical isolation. However, the final CTD completion with swell packer and liner-top packer will permanently isolate the mother completion. It is ConocoPhillips intention to do the following: • We will submit the 10-401s as a sidetrack of 3M-14(i.e. 3M-14A)since the mother completion will be fully isolated/abandoned. • The 10-401s will address the completion plan which will isolate/abandon KRU 3M-14(187-051). We recognize that this isolation method does not meet the requirements of 20 AAC 25.112(c), but we believe it meets the intent of accomplishing the sidetrack and restoring production without risking migration of fluids to other zones. • Since there are no pre-CTD operations that need to be performed to abandon 3M-14, we do not intend to submit a 10- 403 for the isolation/abandonment; that will be addressed in the 10-401s. We do plan to submit a 10-407 post-CTD for the abandonment of 3M-14 (187-051)as permitted under the 10-401s. Please contact me if you'd like to discuss this further. « File: 3M-14 proposed PTD schematic.pdf» J. Gary Eller CTD Team Lead ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: /C:/ (A, 2mi- PTD: a t (0 - ) ( Development _Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: gL'l tnk {\ .U' POOL: (14 R.1116f I 1I < ?l/4r &) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . Production in API number are should continue to be reported as a function of the original API number stated between 60-69) above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the Pilot Hole pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - - from records, data and logs acquired for well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving Spacing Exception a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than Dry Ditch Sample 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for(name of Non- well) until after (Company Name) has designed and implemented a water well Conventional Well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 11110 • To N • 0 Q N 0 CI- a o `m 2 3 9 a) 70- E Q o �; �, > CI .c , , ; C c 3. 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