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216-053
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 8, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1L-17A KUPARUK RIV UNIT 1L-17A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/08/2024 1L-17A 50-029-22151-01-00 216-053-0 W SPT 5868 2160530 1500 1850 1850 1850 1837 120 130 130 130 4YRTST P Guy Cook 6/1/2024 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1L-17A Inspection Date: Tubing OA Packer Depth 210 2700 2630 2600IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240601184857 BBL Pumped:2.1 BBL Returned:2.3 Monday, July 8, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.07.08 12:16:37 -08'00' MEMORANDUM TO: Jim Regg P.L Supervisor ( 11 C l I6 ( ZL%Zv FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IL -17A KUPARUKRIV DNR' IL -17A Src: Inspector Reviewed By- �i P.I. Supry J r__ Comm Well Name KUPARUK RIV UNIT 1L -17A API Well Number 50-029-22151-01-00 Inspector Name: A -tin McLeod Permit Number: 216-053-0 Inspection Date: 6/4/2020 " Insp Num: mitSAM200605093448 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IL -17A Type Inj x' TpD sa6e Tubing zaoo 2425 2425• 2425 - PTD zl6os3o Type Test sPr Test psi soo IA Sao aIa - 2450 I7as BBL Pumped: BBL Returned: 1.1 OA 60 - 60 60 60 - Interval 4YRTST p/p P - Notes: MIT -IA. S/I for curtailment. Monday, Jane 8, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,November 01,2016 TO: Jim Regg P P.I.Supervisor k\ell )I((°1'4" SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1L-17A FROM: Chuck Scheve KUPARUK RIV UNIT 1L-17A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Sae-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1L-17A API Well Number 50-029-22151-01-00 Inspector Name: Chuck Scheve Permit Number: 216-053-0 Inspection Date: 10/17/2016 Insp Num: mitCS161018061130 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1L-17A - Type Inj 1 '' TVD 5868 - Tubing 1720 -T 1720 1720 . 1720 . I 1720 ------r----------------- - - - 2560 - 2540 - � 2530 PTD 1 2160530 ." Type Test SPT Test psi 1500 _ IA 1060 2600 Interval INITAL P/F P OA 200 280 280 - 280 . 280_ j Notes: scANNE�J APR 2 i` 24 it. Tuesday,November 01,2016 Page 1 of 1 • • 0 j to 9 1 0 o 0 • 0 • N T w O - . 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August 17, 2016 Attn.: Makana Bender U C T 04 20161 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 • N.o i 5/201G,M K.BENDER RE: Multi Finger Caliper : 1L-17A Run Date: 7/29/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1L-17A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22151-01 Multi Finger Caliper (Field Log) 1 color log 50-029-22151-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: (?),,,Q/.t,, I3_e.4tet : � I 0 0 if CU STATE OF ALASKA 701 6 ( e.0 Sialus Ci.av I I 7.-ki 1 "3 ALASKA OIL AND GAS CONSERVATION COMMISSION e--°°t WELL COMPLETION OR RECOMPLETION REPORT ANb e la.Well Status: OilGas O SPLUG E Other El Abandoned 0 Suspended❑ lb.Well Class: /‘iv1f t Oho*. 20AAC 25.105 20AAC 25.110Development fl Exploratory 0 GINJ 0 WINJ El ' WAGS VV WDSI ❑ No.of Completions: Service Q Stratigraphic Test 0 2.Operator Name: / 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. / Aband.: 8/28/2016 216-053 3.Address: - / 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 7/30/2016 50-029-22151-01-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number Surface: 357'FNL, 143'FEL, Sec.31,T11N, R10E, UM 8/17/2016 1L-17A, 1L-17APB1, 1L-17APB2 1 Top of Productive Interval: 9.Ref Elevations: KB: 129' 17. Field/Pool(s): 4181'FNL,3957'FEL,Sec. 31,T11N, R10E, UM GL 87' BF: 88' Kuparuk River Field/Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 1819'FNL, 1271'FEL,Sec 6,T1 ON, R10E, UM N/A ADL 25659) ;t5co((Y 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 539922 y- 5948611 Zone- 4 12,500'MD/5988'TVD ALK 2585 TPI: x- 536143 y- 5944768 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 538854 y- 5941864 Zone- 4 N/A 1558'MD/1470'TVD 5.Directional or Inclination Survey: Yes Q(attached) No u 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) 8349'MD/6012'TVD 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 CANNED JAN 3 12018 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD CASING GRADE AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 16" 62.5 H-40 43 122 43 122 24" 235 SX ASI 9-5/8" 36 J-55 42 4607 42 3571 12-1/4" 650 SX PF Type E,450 SX Class G 7 26 J-55 32.3 8675 32.3 6306 8-1/2" 275 SX Class G 2-3/8" 4.6 L-80 8349 12499 6012 6029 3 Slotted and Blank Liner 24. Open to production or injection? Yes a No El 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" 8081' 8032'MD/5868'TVD Slotted Liner from 8386'-9697'MD/6008'-6007'TVD Slotted Liner from 10776'-12499'MD/6029'-5988'TVD 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. CC)M19Li'floN Was hydraulic fracturing used during completion? Yes E No D , ,,:,.fi. Per 20 AAC 25.283(i)(2)attach electronic and printed information $/Zagj/(tP DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LI- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ..4 Flow Tubing Casino Press: Calculated --Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate ...' Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only f kl toN/s- vT-L 10/3//4 .0 1 DM /� RRIIMC , , CCD 9 0 Ince ( .. SEP 2 7 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT Mb2 &c,9 la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory El GINJ ❑ WINJ 0' WAGE WDSPL❑ No.of Completions: Service ❑✓ • Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 8/28/2016 216-053 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 7/30/2016 50-029-22151-01-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 357'FNL, 143'FEL,Sec.31,T11N,R10E, UM 8/17/2016 1L-17A, 1L-17APB1, 1L-17APB2 i Top of Productive Interval: 9.Ref Elevations: KB: 129' 17. Field/Pool(s): 4181'FNL,3957'FEL,Sec.31,T11N,R10E, UM GL 87' BF: 88' Kuparuk River Field/Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 1819'FNL, 1271'FEL,Sec 6,T10N,R10E, UM N/A ADL 25659) 25(0(041 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 539922 y- 5948611 Zone- 4 12,500'MD/5988'TVD ALK 2585 TPI: x- 536143 y- 5944768 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 538854 y- 5941864 Zone- 4 N/A 1558'MD/1470'TVD 5.Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 8349'MD/6012'TVD 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 TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5 H-40 43 122 43 122 24" 235 SX ASI 9-5/8" 36 J-55 42 4607 42 3571 12-1/4" 650 SX PF Type E,450 SX Class G 7 26 J-55 32.3 8675 32.3 6306 8-1/2" 275 SX Class G 2-3/8" 4.6 L-80 8349 12499 6012 6029 3 Slotted and Blank Liner 24.Open to production or injection? Yes Q 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" 8081' 8032'MD/5868'TVD Slotted Liner from 8386-9697'MD/6008'-6007'TVD Slotted Liner from 10776-12499'MD/6029'-5988'TVD 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. CO MIPLG'noN Was hydraulic fracturing used during completion? Yes❑ No d r.f' I i' Per 20 AAC 25.283(i)(2)attach electronic and printed information 473//,15/(te DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i r_4?'r: L+-- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ....... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only fRil tai3M- v7/_. /°/304. 0 r* RBDMS t,c. SEP 2 8 2016 • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No E 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 El Permafrost-Top surface surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1558' 1470' Attach separate pages to this form,if needed,and submit detailed test information,including reports,per 20 AAC 25.071. Top of Productive Interval 8349' 6012' (Kuparuk C Sand) Formation at total depth: 12500' 5988' (Kuparuk C Sand) 1L1 7APB1 Total Depth(Kuparuk A Sand) 10705' 5995' 1L17APB2 Total Depth(Kuparuk B Shale) 10622' 6014 31. List of Attachments: Summary of daily operations,well schematics and final directional surveys. Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true ant correct to the best of my knowledge. Contact: Mike Callahan_ Email: mike.callahan(a�conocophillips.com Printed Name: Gary Eller V Title: CTD Engineering Team Lead Signature: Phone: (907)-263-4172 Date: Q(2.3 INSTRUCTIONS General: This form and the require ments 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 lb: 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 • 410 Modified by MSC 8-30-16 3-1/2"Camco DS Landing Nipple @ 491'MD(2.875"ID) 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62#H- 40 shoe @J.°. 3-1/2"Camco MMG gas lift mandrel @ 2313'&7890'MD affr- 9-5/8"36#J _� Baker 80-40 Seal Assy @ 7947'RKB 55 shoe @ Baker FHL packer @ 7954'RKB (2.93"ID) 3-1/2"Camco DS Landing Nipple @ 7999'RKB :992' ELM) (2.812"ID) Baker 80-40 Seal Assy @ 8017' RKB (8010'ELM)(2.99"ID) Baker PBR @ 8018-8036'RKB 8011'-8029'ELM) i; 1991 Completion Baker HB Retrievable Packer @ 8032'RKB (8025'ELM)(3.5" ID) 3-1/2"Camco D-Nipple @ 8048' RKB (8041'ELM) (Drilled out to 2.80"ID) 3-1/2"Baker SOS @ 8082' RKB (8075'ELM) KOP @ 8193'MD 1L-17A(southeast) TD @ 12500'MD 1L-17AL1 (northwest) Liner @ 12500'MD Billet @ 8349'MD Hole TD @ 11631'MD Liner TD @ 11600'MD Liner top @ 8050'MD --------- ---------------------- - ----- --------------------- ------ EEgj C-sand perfs _ - `-- ---- ---- ---- - -- --- 8170'-8242'MD] ------ 1L-17A PB2(southeast) TD@10622'MD A-sand perfs Cement Retainer @ 9505'MD 8342'-8370'MD Billet @ 9165'MD v8405' 8420'MD 1L-17A PB1 (southeast) 8446'-8460'MD TD @ 10705'MD 7"26#J-55 shoe Billet @ 9220'MD @ 8675'MD j KUP INJ 1 L-17 ConocoF iiI11ps z( Well Attribt� Max Angle TD Alaska Inc. , Wellbore API/UWI Field Name Wellbore Status ncl C) MD Act Btm(ftKB) CnrwcoPhillips`I 500292215100 KUPARUK RIVER UNIT INJ 49.22 4,400.00 8,700.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date r 1L-17,927/27162:05:54 PM SSSV:NIPPLE Last WO: 12/23/2013 42.01 4/11/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 8,421.0 5/27/2015 Rev Reason:CEMENT SQUEEZE lehallf 9/27/2016 HANGER;38.5 I I I Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - CONDUCTOR 16 . 15.062 43.0 122.0 122.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread . SURFACE 9 5/8 8.921 42.0 4,607.2 3,571.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.3 8,675.3 6,305.6 26.00 J-55 BTC-MOD Tubing Strings Tubing Description String Ma...ID(in) Top(ft513) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 38.5 8,018.41 5,858.7 9.30 L-80 EUE-M M CONDUCTOR;43.0-122.0 .". ,...,Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Mein Item Des Com (in) 38.5 38.5 0.17 HANGER FMC TUBING HANGER 2.992 NIPPLE;491.1 `at St 491.1 490.8 6.08 NIPPLE CAMCO DS LANDING NIPPLE w 2.875"Profile 2.875 7,946.8 5,810.7 47.89 LOCATOR BAKER LOCATOR 2.990 7,947.1 5,810.9 47.89 SEAL ASSY BAKER 80-40 SEAL ASSY,Stick up 7'off NoGo Seals 2.990 Engaged 14.67' GAS LIFT;2,313.4 '_ 7,954.1 5,815.6 47.89 PACKER BAKER FHL PACKER w/PBR(Center element on 2.930 packer 7980.73') 7,998.9 5,845.6 47.91 NIPPLE CAMCO DS LANDING NIPPLE w 2.812"Profile 2.812 8,016.6 5,857.4 47.84 LOCATOR BAKER LOCATOR 2.990 8,017.4 5,858.0 47.84 SEAL ASSY BAKER 80-40 SEAL ASSY.Fully Located 1'Spaced Off 2.990 NoGo Seals Engaged 10.86' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-Original 31/2 2.992 8,018.4 8,082.3 5,901.7 9.30 J-55 EUE8rdABMOD SURFACE;42.0-4,6072-. Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top!noir) Item Des Corn (in) 8,018.4 5,858.6 47.83 PBR BAKER 10'STROKE PBR 3.000 GAS LIFT;7,890.8 8,032.1 5,867.9 47.77 PACKER BAKER HB RETRIEVABLE PACKER 3.500 8,048.4 5,878.9 47.69 NIPPLE CAMCO D NIPPLE NO GO MILLED TO 2.80" 2.800 8,081.6 5,901.2 47.54 SOS BAKER SHEAR OUT SUB 2.992 Run Date ID(in) 7/30/2016 LOCATOR;7,946.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TV81 Top Incl SEAL ASSY;7,947.1 - Top(ftKB) (ftKB) C) Des Com 8,193.0 5,976.6 47.28 WHIPSTOCK Baker 3.5"XL Mono-Bore WS with Cement Slips PACKER;7,954.1 i• 1 MONOBORE NIPPLE:7,998.9 perforations&Slots Shot LOCATOR;8,016.6 Dens 0 Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn SEAL ASSY;8,017.4 8,052.0 8,054.0 5,881.3 5,882.6 A-4,1L-17 4/30/2016 3.0 APERF 2",120 Deg,Phase Big PBR;8,018.4 Hole Charges PACKER;8,032.1 r •r' 8,170.0 8242.0 5,961.0 6,009.9 C-4,1L-17 8/18/1991 6.0 APERF 21/8"Flow Jet Pert 0 ti i deg.ph 4 8,342.0 8,370.0 6,078.1 6,097.3 A-5,1L-17 6/21/1991 4.0 IPERF 4.5"Csg Guns;180 deg. i N.1�..�:i.: ph;Oriented25 deg. NIPPLE;8,048.4 N.N 1j i,01 t- A 04 8,405.0 8,420.0 6,121.1 6,131.3 A-4,1L-17 3/27/2012 6.0 IPERF HES 2.5"Peri Gun,60 0Deg,DP Charges l'''' f�.. 8,446.0 8,460.0 6,149.1 6,158.6 A-4,1L-17 6/21/1991 4.0 IPERF 4.5"Csg Guns;180 deg. ph;Oriented 25 deg. CCW APERF;8,052.08,054.0 : Cement S- Squeezes '.+N'q I -_ Top(TVD) Btm(TVD) y r Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Dale Corn SOS:8,081.6 4 8,462.0 8,525.0 6,160.0 6,203.0 Cement 6/24/2016 45 bbls of 16.50 class G cement 1 , SLOTS;8,051.0-11,599.0^ Pr I Squeeze ALI LATERAL LINER ASSY; _ 8,037.0 8,455.0 5,8712 6,155.2 Cement 6/25/2016 e.oso.6-11.600.o1 y,9k, I I * Squeeze WHIPSTOCK-MONOBORE; 8,142.0` -1T ilr\\It Mandrel Inserts APERF;8,170.0-8,242.0 -' St 1*y ati Cement Squeeze;8,037.0 ftKB . on ?a Top(TVD) Valve Latch Port Size TRO Run ,R� NN/ Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com K, 1 2,313.4 1,997.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/25/2016 6 2 7,890.8 5,773.1 CAMCO MMG 1 12 GAS LIFT DMY RK ' 0.000 0.0'12/29/2013 7:30 IPERF;8,342.0-8,370.0 4 - Notes:General&Safety __ End Date Annotation IPERF;8,405.0-8,420.0 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 s b L IPERF;8,446.0-8,460.0 T r Cement Squeeze;8,462.0 01(13 i' a PRODUCTION;32.3-8,675.3 KUP ROD •1L-17A Co oPhiflips ' 4 Well Attrib Max AnglTD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ft Act Btm(ftKB) CarocoNlfpips 500292215101 KUPARUK RIVER UNIT PROD 98.94 10,690.26 12,500.0 °°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 1L-17A 9/2712016206:35 PM SSSV:NIPPLE Last WO: 42.01 4/11/1991 Velma!schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:CEMENT SQUEEZE lehallf 9/27/2016 HANGER;38.5 I °_ P Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread A LATERAL LINER 23/8 1.992 8,349.0 12500.0 5,988.1 4.60 L-80 ST-L ASSY `"' '° .0' Liner Details 1i'1 iiNominal ID LTop( KB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) 8,349.0 6,012.1 96.15 BILLET Aluminum OH Anchored Billet 1.000 • 9,600.8 6,003.8 89.44 DEPLOY Shorty Deployment Sleeve 1.920 • • • • ...A...^.CONDUCTOR;43.0-122.0 Perforations&Slots . Shot Den • Top(ND) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com NIPPLE;491.1 ns 8,386.0 9,696.0 6,007.7 6,006.6 C-4,1L-17 8/18/2016 SLOTS ALL PERFS IN O .: WELLBORE:Alternating solide/slotted pipe -/.125"x2.5"@4 circumferential adjacent rows GAS LIFT;2,313.4 E 10,776.0 12,499.0 6,028.8 5,988.1 C-4,1L-17 8/18/2016 SLOTS ALL PERFS IN WELLBORE:Alternating • solide/slotted pipe -/.125"x2.5"@4 circumferential adjacent 3 rows SURFACE;420-4,607.2 1 t Notes:General&Safety End Date Annotation NOTE: GAS LIFT;7,890.8 I LOCATOR;7,947. SEAL ASSY;7,947.1 PACKER;7,954.1 NIPPLE;7,998.9 LOCATOR;8,017.4 SEAL ASSY;8,017.4 PBR;8,018.4 PACKER;8,032.1 r•,, al 12 NIPPLE;8,048.4 '� Et. I1 v 4i . i i4 fi,_ APERF;8,052.0-8,054.0— I ; 4 Ny.., a `it- kik SOS;8,081.6 [ Cement Squeeze;8,037.0rtKB 'Si I .!pi APERF;8,170.0-8,2420 WHIPSTOCK-MONOBORE;\ k 6,193.01 PRODUCTION;32.3-8,675.3\ f' SLOTS;8.051.0-11,599.0—�-1�`-- ALI LATERAL LINER ASSY; -•••••• 1� 8,050.6-11,600.0 HI j-- -. SLOTS;8,386.05,696.0 ' j II. SLOTS;10,776.0-12,499.0 1 .:1- --4 A LATERAL LINER ASSY; 8,349.0-12,500.0 KUP W3 1 L-17AL1 ConocoP'hillips 04 Well Attrib Max AngleD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CononoPhillips 500292215160 KUPARUK RIVER UNIT PROD 103.82 8,380.09 11,631.0 .... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1L-17AL1,9/27/20162:07:02 PM SSSV:NIPPLE Last WO: 42.01 4/11/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation _ Last Mod By End Date Last Tag: Rev Reason:CEMENT SQUEEZE lehallf 9/27/2016 ICasing Strings HANGER;38.5 '�.;`_�i I Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I AL1 LATERAL LINER 23/8 1.992 8,050.6 11,600.0 6,015.6 4.60 L-80 ST-L ASSY • Liner Details .,.. Nom(nn) al920 ID Top B (ftl(° (i II (ftK Y 8,050.6) Top(TVD)5,880.3KB) Top net 47.69) DEPLOItem Des Y Shorty deployment sleeveCom 1. I Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm)ftKB) )ftKB) (ftKB) Zone Date ft) Type Com .+'/\CONDUCTOR;43.0.122.0 .....-"11,--. 8,051.0 11,599.0 5,880.6 6,015.6 C-4,1L-17 8/18/2016 SLOTS ALL PERFS IN WELLBORE:Alternating Bolide/slotted pipe -/.125"x2.5"@4 circumferential adjacent NIPPLE;491.1 / - LOWS i 3 9 Notes:General&Safety End Date Annotation NOTE: GAS LIFT;2,313,4 'a I SURFACE;42 0-4807.2----. - GAS LIFT;7,890.8 I LOCATOR;7,946.8 11 SEAL ASSY;7,947.1 a,� PACKER;7,954.1 NIPPLE;7,998.9 111 LOCATOR;8,016.6 SEAL ASSY;8,017.4 Ma PBR;8,018.4 PACKER;8,032.1 I 111111-11 ,y1 I NIPPLE;8,048.4 iii' : I 4 v 6 i i 1 1 1.,.: l APERF;8,052.0-8,054.0 w ri �a it SOS;8,081.6 j• 'T Cement Squeeze;8,037.0 ftKB APERF;8,170.0-8,242.0 .1 _- WHIPSTOCK-MONOBORE;\ + ; e 8,193.0 '}.'� �i�p-- PRODUCTION;32.3-8,675.3--�ri+>- �I_. I -i 1!- i -... SLOT5;8,051.0-11,599.0--` jam' I AL1 LATERAL LINER ASSY; 1 8,050.6-11,000.0 06 !erations Summary (with Timelog Depths) rhe • 1 L-17 ConocoPhillips Rig: NABORS CDR2-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) 7/27/2016 7/27/2016 3.50 MIRU MOVE MOB P Complete ND BOP stack,secure 0.0 0.0 12:00 15:30 stack.Complete RD checklist.While waiting on trucks. 7/27/2016 7/27/2016 0.50 MIRU MOVE MOB P PJSM with NES trucking crew. 0.0 0.0 15:30 16:00 7/27/2016 7/27/2016 3.75 MIRU MOVE MOB P Pull pit module to side,pull sub off'IL- 0.0 0.0 16:00 19:45 18.Prep 1L-17 cellar,spot sub module over 1L-17,set mats,set down.Spot pit module,set mats,set down. 7/27/2016 7/27/2016 1.25 MIRU MOVE RURD P Complete post rig move checklist. 0.0 0.0 19:45 21:00 7/27/2016 7/27/2016 1.00 MIRU MOVE NUND P Nipple up BOPE,change out riser, 0.0 0.0 21:00 22:00 check torque on flange bolts(30 min) all good. 7/27/2016 7/27/2016 1.00 MIRU MOVE RURD P PJSM-Perform pre spud check list, 0.0 0.0 22:00 23:00 circulate surface lines,body test BOPE 4,000 psi. Rig Accept at 23:00 on 07/27/2016 7/27/2016 7/28/2016 1.00 MIRU WHDBOP BOPE P Perform initial BOPE test 250/3,750 0.0 0.0 23:00 00:00 psi.Annular 2,500 psi.Waived witness by AOGCC Jonnie Hill at 20:57 on 07/27/2016 over the phone. 7/28/2016 7/28/2016 11.00 MIRU WHDBOP BOPE P Continue initial BOP test 250/3,750 0.0 0.0 00:00 11:00 psi.Annular 2,500 psi.Witnessed waived by AOGCC Jonnie Hill at 20:57 on 07/27/2016 over the phone. C11 &C3,fail,retest pass. B7 and B8 failed. 7/28/2016 7/28/2016 1.00 MIRU WHDBOP SVRG P Service rig greased stack,choke 0.0 0.0 11:00 12:00 valves,serviced B7&B8. 7/28/2016 7/28/2016 5.00 MIRU WHDBOP BOPE T Continue initial BOP test 250/3,750 0.0 0.0 12:00 17:00 psi.Annular 2,500 psi.Rebuild in place and grease B7&B8,retest , good.TV1 fail,greased,retest good, Koomy test. Note:Nabors 5 hours NPT 7/28/2016 7/28/2016 2.75 MIRU WHDBOP PRTS P PJSM-Load coil and test inner reel 0.0 0.0 17:00 19:45 iron,stripper.Test PDL and TT line good. 7/28/2016 7/28/2016 1.50 MIRU WHDBOP MPSP P PJSM-RU/PT BPV equipment, 0.0 0.0 19:45 21:15 lubricate BPV out, 1,380 psi WHP,off load BPV equipment. 7/28/2016 7/28/2016 0.75 SLOT WELLPR OWFF P PJSM-Install night cap,bleed well to 0.0 0.0 21:15 22:00 0 psi,monitor for flow,no flow for 30 minutes. PJSM-MU BHA over dead well. 7/28/2016 7/28/2016 1.25 PROD1 RPEQPT PULD P MU BHA#1,Pilot hole milling 0.0 62.5 22:00 23:15 assembly,0.9°AKO motor and a HCC 2.80"D331GEB slick gauge mill. inspect pack offs,MU to CoilTrak, surface test. 7/28/2016 7/29/2016 0.75 PROD1 RPEQPT TRIP P RIH while displacing out the wells 62.5 3,800.0 23:15 00:00 diesel freeze protect. 7/29/2016 7/29/2016 1.00 PROD1 RPEQPT DISP P Continue RIH while displacing out the 3,800.0 7,925.0 00:00 01:00 wells diesel freeze protect. 7/29/2016 7/29/2016 0.25 PROD1 RPEQPT DLOG P Tie in to HRZ for plus 21.5 ft 7,925.0 7,984.0 01:00 01:15 correction.PUW 41k. • Page 1126 Report Printed: 8/29/2016 ..ka .01 Operations Summary (with Timelog Depths) 0;: 1 L-17 CooncoPhillips Rig: NABORS CDR2-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) 7/29/2016 7/29/2016 0.75 PROD1 RPEQPT DISP P RIH,Tag top of cement at 8,050',PUH 7,984.0 8,050.0 01:15 02:00displacing well bore to milling fluid, RBIH. 7/29/2016 7/29/2016 13.50 PROD1 RPEQPT MILL P 8,050 ft.Mill cement pilot hole per 8,050.0 8,223.0 02:00 15:30 recommended practice,cement across shakers,several stalls, contacted casing at 8,086 ft,continued milling 1.7 BPM,2600 psi,as per wellplan at ROP 15 to 20 FPH TD pilot hole 8223'ft, PUW 38K 7/29/2016 7/29/2016 3.50 PROD1 RPEQPT REAM P Back-ream transition area up at 1 8,223.0 8,040.0 15:30 19:00 FPM, 180°to 8,070 ft,ream down 5 fpm to 8,092 ft,repeat 3 times,log HRZ for a plus 1 ft correction,dry drift ith 0.5k bobble at 8,091 ft,confirm pilot hole TD 8,223 ft,PUH and back ream tranition area 1 fpm,dry drift transition are with same bobble to 8,139 ft, 7/29/2016 7/29/2016 1.40 PROD1 RPEQPT TRIP P Check for flow(10 min),well dead, 8,040.0 62.5 19:00 20:24 POOH for caliper. 7/29/2016 7/29/2016 0.45 PROD1 RPEQPT OWFF P On surface,check for flow,good while 62.5 62.5 20:24 20:51 performing PJSM-LD BHA over dead well. 7/29/2016 7/29/2016 0.65 PROD1 RPEQPT PULD P LD BHA#1 62.5 0.0 20:51 21:30 7/29/2016 7/29/2016 0.90 PROD1 RPEQPT CTOP P Install nozzle,jet stack,remove 0.0 0.0 21:30 22:24 nozzle.PJSM-MU caliper. 7/29/2016 7/29/2016 1.00 PROD1 RPEQPT PULD P MU BHA#2(Halliburton realtime 24 0.0 22.0 22:24 23:24 short arm caliper)to coil,test caliper. 7/29/2016 7/30/2016 0.60 PROD1 RPEQPT TRIP P RIH with Halliburton caliper. 22.0 2,400.0 23:24 00:00 7/30/2016 7/30/2016 0.95 PROD1 RPEQPT TRIP P RIH with Halliburton caliper. 2,400.0 7,925.0 00:00 00:57 7/30/2016 7/30/2016 0.30 PROD1 RPEQPT DLOG P Tie in at K1 for plus 9 ft correction. 7,925.0 8,215.0 00:57 01:15 continue RIH to depth,open calipers. 7/30/2016 7/30/2016 0.65 PROD1 RPEQPT DLOG P POOH logging 1st caliper pass to 8,215.0 8,000.0 01:15 01:54 8,000 ft at 50 fpm,RBIH to 8,215 ft, POOH logging 2nd caliper pass.RBIH to 8,215 ft, POOH logging 3rd caliper pass, 1st pass questionable.Close caliper.Rush data. 7/30/2016 7/30/2016 1.40 PROD1 RPEQPT TRIP P POOH for whipstock. 8,000.0 22.0 01:54 03:18 7/30/2016 7/30/2016 0.45 PROD1 RPEQPT OWFF P On surface,flow check good while 22.0 22.0 03:18 03:45 performing PJSM-LD BHA over open hole. 7/30/2016 7/30/2016 0.65 PROD1 RPEQPT PULD P LD BHA#2,Halliburton caliper 22.0 0.0 03:45 04:24 7/30/2016 7/30/2016 0.75 PROD1 RPEQPT PULD P PJSM-MU BHA#3 Baker XL Mono- 0.0 73.5 04:24 05:09 Bore Whipstock w/Cement Slip,MU to CoilTrak,surface test. , 7/30/2016 7/30/2016 1.60 PROD1 RPEQPT WPST P RIH with BHA#3,correlate to HRZ, 73.5 8,203.5 05:09 06:45 +10.5 ft,corrected depth 7978'ft,set whiptock at 8193 ft(TOWS)oriented 5°LOHS,set 3.5K down,PUW 411i. 7/30/2016 7/30/2016 2.70 PROD1 RPEQPT TRIP P POOH with BHA#3(whipstock setting 8,203.5 73.5 06:45 09:27 assembly) 7/30/2016 7/30/2016 0.50 PROD1 RPEQPT OWFF P Flow check-good. 73.5 73.5 09:27 09:57 Page 2/26 Report Printed: 8/29/2016 i • 4.1111 Operations Summary (with Timelog Depths) 1 L-17 ConocoYPhimps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(MKS) 7/30/2016 7/30/2016 0.30 PROD1 RPEQPT PULD P LD BHA#3(whipstock setting 73.5 0.0 09:57 10:15 assembly) 7/30/2016 7/30/2016 1.00 PROD1 WHPST PULD P PJSM,MU BHA#4,(Baker 2.80 0.0 74.3 10:15 11:15 Window mill&diamond string reamer w/Xtreme motor at 0.6°AKO), change pack-offs,MU to CoilTrk, surface test. 7/30/2016 7/30/2016 2.50 PROD1 WHPST TRIP P RIH with BHA#4,circulate well over to 74.3 8,193.0 11:15 13:45 8.6 FloPro milling fluid, tie-in to HRZ, +10 ft,dry tag 8193.5 ft,PUW 36K 7/30/2016 7/31/2016 10.25 PROD1 WHPST WPST P Begin milling whipstock from 8192.8 ft 8,193.0 8,197.6 13:45 00:00 per recommended practice and Baker rep,at 1.7 bpm,3350 psi FS,11.2K off-btm Wt, **Top of whipstock at 8193 ft. 7/31/2016 7/31/2016 1.40 PROD1 WHPST WPST P Continue milling window from 8197.6 8,197.6 8,198.6 00:00 01:24 ft per recommended practice and Baker rep.1.7 bpm at 3,265 psi,CWT 8.6k,WOB 2.6k. 7/31/2016 7/31/2016 1.60 PROD1 WHPST WPST P 8,198.6 ft. WOB dropped-1k lbs, 8,198.6 8,202.0 01:24 03:00 continue milling window per RP.2 fph to allow string reamer to clean-up bottom of window. *Btm of Window @ 8,198.6 ft* 7/31/2016 7/31/2016 0.85 PROD1 WHPST WPST P 8,202 ft. Continue milling to 21 ft past 8,202.0 8,214.0 03:00 03:51 TOWS.Gradually increased ROP from 3,6, 10,20 fph 1.70 bpm at 3,365 psi.CWT 10k,WOB 2.6k. 7/31/2016 7/31/2016 1.15 PROD1 WHPST REAM P 8,214 ft. TD rathole,PUW 33k, back 8,214.0 8,214.0 03:51 05:00 ream the window area 30°L/R per RP @ 1 fpm.Dry drift window @ 20 fpm- clean pass through window. 7/31/2016 7/31/2016 1.35 PROD1 WHPST TRIP 'P POOH w/BHA#4(window milling 8,214.0 74.3 05:00 06:21 assembly),open EDC,contimue POOH 7/31/2016 7/31/2016 1.15 PROD1 WHPST PULD P PJSM-PUD BHA#4 74.3 0.0 06:21 07:30 7/31/2016 7/31/2016 1.25 PROD1 DRILL PULD P LD milling assembly/MU build section 0.0 72.2 07:30 08:45 BHA,install into PDL 7/31/2016 7/31/2016 1.00 PROD1 DRILL PULD P PJSM,pressure deploy build section 72.2 72.2 08:45 09:45 BHA 7/31/2016 7/31/2016 1.40 PROD1 DRILL TRIP P RIH with build section assembly,2.2+° 72.2 7,967.0 09:45 11:09 bend motor,HCC bi-center bit,open EDC. 7/31/2016 7/31/2016 0.20 PROD1 DRILL DLOG P Log tie-in to HRZ,+11 ft correction 7,967.0 7,967.0 11:09 11:21 ' 7/31/2016 7/31/2016 0.25 PROD1 DRILL TRIP P RIH,close EDC,get PUW 31K,10.3 7,967.0 8,214.0 11:21 11:36 SOW,establish 1.7 bpm rate 7/31/2016 7/31/2016 1.95 PROD1 DRILL DRLG P Drilling, 1 stall,WOB and weight 8,214.0 8,261.0 11:36 13:33 transfer erratic,PU 3 times off bottom, resume drilling,pull back through window area to 8171 ft,RBIH and resume drilling,drilling still erratic. Page 3/26 Report Printed: 8/29/2016 0 Operations Summary (with Timelog Depths) 1 L-17 Con+o altiips ALnks Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/31/2016 7/31/2016 0.50 PROD1 DRILL DLOG P Log tie-in to HRZ,+2 ft correction,RA 8,261.0 8,261.0 13:33 14:03 marker at 8201 ft. *Correct TOW to 8194 ft&BOW at 8199 ft,based on RA tie-in of+1 ft. 7/31/2016 8/1/2016 9.95 PROD1 DRILL DRLG P 8,261 ft. OBD 1.7 bpm at 3,861 psi 8,261.0 8,410.0 14:03 00:00 FS,BHP 3,991 psi,CWT 10k,WOB 1.6k,Several BHA wipers,restarts, eratic drilling,acts as if balled up bit, pump 10 bbl pill Lo-vis with 1.5% Drillzone,little help,several BHA wipers,reduce pump rate to 1.5 bpm, squat 3k+WOB,9k CWT,to get some motor work,stick/slip,minimum DLS 38°,max 53°,average DLS 47°to end of build called at 8,410 ft.Pump 5x5 sweep 8/1/2016 8/1/2016 2.00 PROD1 DRILL TRIP P POOH for lateral drilling assembly 8,410.0 72.2 00:00 02:00 chasing sweeps to surface. 8/1/2016 8/1/2016 1.50 PROD1 DRILL PULD P PJSM-PUD BHA#5,Bit condition 3-1 72.2 0.0 02:00 03:30 -BT-N-X-I-NO-BHA,pics in folder 8/1/2016 8/1/2016 1.50 PROD1 DRILL PULD P PJSM-MU/PD BHA#6,0.4°AKO 0.0 72.2 03:30 05:00 motor and RB HYC Bi-center bit,MU to CoilTrak,surface test. 8/1/2016 8/1/2016 1.50 PROD1 DRILL TRIP P RIH with BHA#6 lateral drilling 72.2 7,966.0 05:00 06:30 assembly. 8/1/2016 8/1/2016 0.10 PROD1 DRILL DLOG P Tie-in to HRZ,+7.5 ft correction,29.0K 7,966.0 7,935.0 06:30 06:36 PUW 8/1/2016 8/1/2016 0.40 PROD1 DRILL TRIP P Close EDC,continue to RIH 7,935.0 8,410.0 06:36 07:00 8/1/2016 8/1/2016 5.50 PROD1 DRILL DRLG P OBD, 1.7 bpm,losing returns 20 to 30 8,410.0 8,810.0 07:00 12:30 bph from 8465 ft to 8515 ft,adjust MP choke to get back to 1:1,SOW ranging from 5.0K to 10K,WOB , ranging from 0.5 to 2.0K,difficulty maintaining WOB,pump 30 bbl Hi-vis pill with beads in 5 bbl increments. 8/1/2016 8/1/2016 0.90 PROD1 DRILL WPRT P Short wiper trip#1,32K PUW,trap. 8,810.0 8,810.0 12:30 13:24 1045 psi WHP,pumps off for 10 min BHP,3858 psi AP,RBIH 8/1/2016 8/1/2016 0.75 PROD1 DRILL DRLG P OBD 1.4 bpm at 3,440 psi FS,BHP 8,810.0 8,855.0 13:24 14:09 3,890 psi,make 1 BHA wiper trip, RBIH, 8/1/2016 8/1/2016 4.40 PROD1 DRILL DRLG P BOBD 1.66 bpm at 3,830 psi FS, 8,855.0 9,210.0 14:09 18:33 BHP 3,800 psi,CWT 7.6k,WOB.8k, ' ROP 60-120,IA 0,OA 38,still lossing, adjust trip schedule-200 psi to comp losses,losing 8-10 bph 8/1/2016 8/1/2016 0.95 PROD1 DRILL WPRT P Wiper trip to window,PUW 33k.Jog at 9,210.0 8,210.0 18:33 19:30 EOB,perform choke calibration from 8,280 ft to 8,250 ft at 5 fpm,BHP 3,753 psi, 1.60 bpm in, 1.58 bpm out, MW in 8.64 ppg,MW out 8.75 ppg, WHP 473 psi Page 4/26 Report Printed: 8/29/2016 0 •rations Summary (with Timelog •ths) Operations 1 L-17 Ccxmcc Phillips Fdnk.a Rig: NABORS CDR2-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) 8/1/2016 8/1/2016 0.25 PROD1 DRILL DLOG P Log RA for plus 5.5 ft correction.RIH 8,210.0 8,250.0 19:30 19:45 Trap 3,750 psi BHP(12 ppg BHP), close choke and shut down pump, monitor BHP at 8,250 ft bit depth,DPS at 8,207 ft(5,980 ft TVD)monitor 15 minutes,BHP at 3,700 psi(11.9 ppg BHP)and falling slowly. PUW 33k. Make up12.0 ppg trip schedule. 8/1/2016 8/1/2016 0.45 PROD1 DRILL WPRT P Wiper back in hole. 8,250.0 9,210.0 19:45 20:12 8/1/2016 8/2/2016 3.80 PROD1 DRILL DRLG P BOBD 1.65 bpm at 3,697 psi FS,BHP 9,210.0 9,392.0 20:12 00:00 3,845 psi,CWT 7.0k,WOB 1.3k,ROP 45,WHP 437,IA 0,OA 40.Still losing 6-8 bph but appears to healing. 8/2/2016 8/2/2016 5.00 PROD1 DRILL DRLG P OBD 1.70 bpm at 3,927 psi FS,BHP 9,392.0 9,610.0 00:00 05:00 3,880 psi,CWT 8.6k,WOB 1.1k,ROP 56.WHP 433,IA 0,OA 40. 8/2/2016 8/2/2016 0.80 PROD1 DRILL WPRT P 1200'Wiper trip to 8410 ft,PUW 36K, 9,610.0 9,610.0 05:00 05:48 RBIH 8/2/2016 8/2/2016 8.70 PROD1 DRILL DRLG P OBD, 1.67 bpm,3872 psi BHP,9.0K 9,610.0 9,863.0 05:48 14:30 CWT,1.0K WOB,60 ft/hr ROP,pump 5 x 5 sweep. , 8/2/2016 8/2/2016 1.20 PROD1 DRILL WPRT P Wiper trip to window called early per 9,863.0 8,201.0 14:30 15:42 discussion w/town,+4 correction at RA marker,perform choke callibration at 8210 ft,hold 3750 psi BHP(12.38 ppg ECD at window), 1.69 bpm in, 1.66 out,378 pis WHP,3950 psi pump pressure. 8/2/2016 8/2/2016 0.65 PROD1 DRILL WPRT P Wiper trip back in hole 8,201.0 9,863.0 15:42 16:21 8/2/2016 8/2/2016 3.55 PROD1 DRILL DRLG P BOBD 1.68 bpm at 4,050 psi FS,BHP 9,863.0 9,994.0 16:21 19:54 3,920 psi,CWT 7.8k,WOB 1.3k,ROP 38 8/2/2016 8/2/2016 0.40 PROD1 DRILL WPRT P GEO wiper,confer with town,continue 9,994.0 9,994.0 19:54 20:18 to move forward,RBIH. 8/2/2016 8/3/2016 3.70 PROD1 DRILL DRLG P BOBD 1.65 bpm at 4,050 psi FS,BHP 9,994.0 10,075.0 20:18 00:00 3,975 psi,CWT 3.0k,WOB 2.1k,ROP 28 8/3/2016 8/3/2016 0.90 PROD1 DRILL DRLG P Continue drilling ahead 1.68 bpm at 10,075.0 10,090.0 00:00 00:54 4,060 psi FS,BHP 3,942 psi,CWT- 2.5k,WOB 1.1k,ROP 15.Pump 5x5 sweep 8/3/2016 8/3/2016 0.35 PROD1 DRILL WPRT P Wiper up hole to 9,090 ft,PUW 36k. 10,090.0 9,090.0 00:54 01:15 8/3/2016 8/3/2016 0.40 PROD1 DRILL WPRT P Wiper back in hole.RIW 9.0k 9,090.0 10,090.0 01:15 01:39 8/3/2016 8/3/2016 1.55 PROD1 DRILL DRLG P BOBD 1.67 bpm at 4,150 psi FS,BHP 10,090.0 10,139.0 01:39 03:12 3,958 psi,CWT 7.1k,WOB 1.8k,ROP 40,WHP 303,IA 0,OA 46.Two stalls at 10,132 ft&10,139 ft. 8/3/2016 8/3/2016 0.25 PROD1 DRILL DLOG P Confer with town,Solar interference, 10,139.0 10,139.0 03:12 03:27 missed survey at 10,085 ft. PUW 39k, RBIH,good survey obtained at a 45 ft interval. • Page 5/26 Report Printed: 8/29/2016 0 ID Summary (with TimelogDepths) Operations p ) tz$. IL-17 Co€toc6Phillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/3/2016 8/3/2016 5.50 PROD1 DRILL DRLG P BOBD 1.51 bpm at 3680 psi FS,BHP 10,139.0 10,265.0 03:27 08:57 3,940 psi,CWT 6.0k,WOB 1.9k, ROP35.Slow drilling at 10,162 ft. 8/3/2016 8/3/2016 0.25 PROD1 DRILL DRLG P 10,260 ft, 100ft BHA wiper up hole, 10,265.0 10,265.0 08:57 09:12 RBIH 8/3/2016 8/3/2016 2.85 PROD1 DRILL DRLG P BOBD 1.51 bpm at 3680 psi FS,BHP 10,265.0 10,340.0 09:12 12:03 3,940 psi,CWT 7.0k 8/3/2016 8/3/2016 0.50 PROD1 DRILL WPRT P 10,340 ft,wiper up hole,PUW 36k 10,340.0 9,140.0 12:03 12:33 8/3/2016 8/3/2016 0.25 PROD1 DRILL WPRT P 9,140 ft,wiper back in hole,RIW 8k 9,140.0 10,005.0 12:33 12:48 8/3/2016 8/3/2016 0.50 PROD1 DRILL WPRT P 10,005 ft,pumping 1.2 bpm,high side 10,005.0 10,005.0 12:48 13:18 TF,set down 3k DHWOB,PUH,lower pump rate,RBIH,popped thru,turned around,pulled 10 fpm up thru area, 40k CTSW,minus 3k DHWOB,RBIH clean 8/3/2016 8/3/2016 0.25 PROD1 DRILL WPRT P 10,005 ft,continue RIH to bottom, 10,005.0 10,340.0 13:18 13:33 communicate with town on hole conditions 8/3/2016 8/3/2016 4.95 PROD1 DRILL DRLG P 10,340 ft,BOBD 1.51 bpm at 3,900 10,340.0 10,492.0 13:33 18:30 psi,BHP 3966,WHP 262, 1.3= DHWOB,-4k=CTSW IA 0,OA 48. pull 200 ft wiper,PUW 38k. *""Note: 10,380 ft started lossing 15 bpm and slowly healed up to 2-4 bph. 8/3/2016 8/4/2016 5.50 PROD1 DRILL DRLG P 10,492 ft. BOBD for data 1.50 bpm at 10,492.0 10,683.0 18:30 00:00 3,874 psi FS,BHP 3,972 psi,CWT 3k, WOB 1.7k,ROP 45.pulled four 200 ft wipers with PUW's 35 to 38k,pumped 2,10 bbl beaded pills. ""'Note: 19:45 Lossing 10-12 bph, confer with town,following 11.8 ppg trip schedule at 10,540 ft,losing 4-6 bph. 8/4/2016 8/4/2016 3.10 PROD1 DRILL DRLG P 10,683 ft. OBD 1.5 bpm at 3,846 psi 10,683.0 10,705.0 00:00 03:06 FS,BHP 3,930 psi,CWT-3k,WOB 1.2k,ROP 35,WHP 194,IA 0,OA 50. 8/4/2016 8/4/2016 2.90 PROD1 DRILL TRIP T 10,705 ft.Data TD called-POOH, 10,705.0 72.2 03:06 06:00 PUW 33k,Pull heavy at 10,050 ft, work to 10,000 ft,bit stuck momentarily,down on pump,PU slowly through tight area to 9,950 ft, Jog at EOB.Log HRZ for plus 8 ft correction,continue POOH. 8/4/2016 8/4/2016 2.50 PROD1 DRILL PULD T PJSM-PUD/LD BHA#6,checks aren't 72.2 0.0 06:00 08:30 holding do to beads,continue PUD with open EDC,attempt to bleed down thru bleed port,bleed port plugged with beads,line up to confirm coil is bled down to 0 pressure,flush out bleed port,continue PUD,LD drilling BHA 8/4/2016 8/4/2016 0.75 PROD1 DRILL PULD T PU/MU,Coiltrak tools and BOT setting 0.0 0.0 08:30 09:15 tools with Open hole anchored billet. Page 6/26 Report Printed: 8/29/2016 , • • . . ;,..3, 0 Operations Summary (with Timelog Depths) 0 1 L-17 Conoco Phillips �:fxck.3 • Rig: NABORS CDR2-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) 8/4/2016 8/4/2016 1.50 PROD1 STK PULD T PJSM,inspect checks in upper quick, 0.0 72.9 09:15 10:45 upper checks PD Open Hole Anchored Billet 8/4/2016 8/4/2016 1.50 PROD1 STK TRIP T RIH,with BHA#7 open hole anchored 72.9 7,945.0 10:45 12:15 billet 8/4/2016 8/4/2016 0.25 PROD1 STK DLOG T 7945 ft,tie into the HRZ correction of 7,945.0 7,965.0 12:15 12:30 plus 8.5 ft,PUW 31k 8/4/2016 8/4/2016 0.75 PROD1 STK TRIP T 7965 ft,close EDC,continue IH 7,965.0 8,236.0 12:30 13:15 8/4/2016 8/4/2016 1.50 PROD1 STK TRIP T 8,236 ft,Set down 6k DHWOB,3k 8,236.0 72.9 13:15 14:45 CTSW,PUH clean dragging 1.5k, pulling clean 8,228 ft,RBIH,set down again,dragging 1.3-1.0k DHWOB, PUH thru window,open EDC,POOH to surface for a clean out run. 8/4/2016 8/4/2016 1.35 PROD1 STK PULD T PJSM,undeploy setting tools and 72.9 0.0 14:45 16:06 open hole anchored billet. 8/4/2016 8/4/2016 0.40 PROD1 STK PULD T Inspect billet assembly,LD setting 0.0 16:06 16:30 tools, 8/4/2016 8/4/2016 1.65 PROD1 STK BOPE P Function test BOPE.Pressure test DS 0.0 0.0 16:30 18:09 PDL back from Tuboscope.Service Choke and BOP stack 8/4/2016 8/4/2016 1.15 PROD1 STK PULD T PJSM-PU/MU/PD cleanout BHA#8, 0.0 62.6 18:09 19:18 0.4°AKO motor and same HYC Bi- center bit,check packoffs,MU to CoilTrak,surface test. 8/4/2016 8/4/2016 1.60 PROD1 STK TRIP T RIH with BHA#8,EDC open 62.6 7,945.0 19:18 20:54 8/4/2016 8/4/2016 0.45 PROD1 STK DLOG T 7,945 ft. Log at HRZ questionable, 7,945.0 8,092.0 20:54 21:21 close EDC,PUW 31k,tie in at K1 for plus 16.5 ft correction 8/4/2016 8/4/2016 0.75 PROD1 STK TRIP T RIH,clean thru window,zero 8,092.0 9,800.0 21:21 22:06 correction passing RA,clean thru build area,pump 10x10 to/hi,clean to 9,800 ft. 8/4/2016 8/5/2016 1.90 PROD1 STK WPRT T Wiper trip up hole,PUW 30k 10x10 9,800.0 2,560.0 22:06 00:00 out bit,300 ft jog at FOB, PUW 29k, chase sweeps to swab,clean thru window and pilot hole,continue POOH to 2,560 ft as of midnight. 8/5/2016 8/5/2016 0.75 PROD1 STK WPRT T Continue POOH,300 ft jog at 1,000 ft. 2,560.0 62.6 00:00 00:45 POOH to surface 8/5/2016 8/5/2016 2.00 PROD1 STK PULD T PJSM-PUD/LD BHA#8,bit in good 62.6 0.0 00:45 02:45 shape,pics in folder. MU and load BHA#9 in PDL,change out 2 failed lubricator o-rings(30 minutes),stab on well 8/5/2016 8/5/2016 1.40 PROD1 STK PULD T PJSM- PD BHA#9,OH anchored . 0.0 72.9 02:45 04:09 billet,MU to CoilTrak,surface test. 8/5/2016 8/5/2016 2.00 PROD1 STK TRIP T RIH with BHA#9 EDC open. 72.9 7,945.0 04:09 06:09 8/5/2016 8/5/2016 0.25 PROD1 STK DLOG T 7,945 ft,tie into the HRZ correction of 7,945.0 7,966.0 06:09 06:24 plus 9.0 ft.PUW 32 k. Page 7/26 Report Printed: 8/29/2016 • 0 0 Operations Summary (with Timelog Depths) 1 L-17 • Conoc6Phillips Rig: NABORS CDR2-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(EKE) 8/5/2016 8/5/2016 1.25 PROD1 STK WPST T 7,966 ft,continue RIH at 25 fpm,close 7,966.0 9,220.0 06:24 07:39 EDC at 7,975 ft,weight bobble of +1.5k at 8236 ft,seeing weight bobbles of 0.5-3.5k from 8,236 ft to 9,237 ft.,hard set down at 9,237 ft, PUW 34 k,minus 4.5 k-5 k.RBIH, set down 5 k,confer with town team on plan forward,decisoin was made to set TOB at 9,220 ft.Bring pump up to 4740 psi setting tools sheared,set down 5 k.PUW 31 k. , 8/5/2016 8/5/2016 2.25 PROD1 STK TRIP T 9,220 ft.POOH following MP, 9,220.0 72.9 07:39 09:54 pumping 1.0 bpm at 2,472 psi, IA 0, OA 38 8/5/2016 8/5/2016 2.00 PROD1 STK PULD T At surface,PJSM,undeploy/LD setting 72.9 0.0 09:54 11:54 tools. 8/5/2016 8/5/2016 0.75 PROD1 STK PULD T MU/PU kickoff/drilling BHA#9,load 0.0 0.0 11:54 12:39 PDL • 8/5/2016 8/5/2016 1.00 PROD1 STK CTOP T Swap BHI upper quick out due to hrs 0.0 0.0 12:39 13:39 TT 235 hr 8/5/2016 8/5/2016 1.25 PROD1 STK PULD T PD kickoff/drilling BHA 0.0 72.2 13:39 14:54 8/5/2016 8/5/2016 1.50 PROD1 STK TRIP 'T RIH,kickoff/drilling BHA w/0.4 ako 72.2 7,945.0 14:54 16:24 bend motor and RB bi-center bit. 8/5/2016 8/5/2016 0.25 PROD1 STK DLOG T 7,945 ft,tie into the HRZ correction of 7,945.0 7,964.0 16:24 16:39 plus 8.5 ft.PUW 31k 8/5/2016 8/5/2016 0.75 PROD1 STK TRIP T 7,964 ft,continue RIH,clean thru 7,964.0 9,222.0 16:39 17:24 window,dry tag billet at 9,222 ft.PUH 33k,establish drilling parameters,RIH 8/5/2016 8/5/2016 4.35 PROD1 STK KOST T 9,222 ft. Kick off billet per 9,222.0 9,250.0 17:24 21:45 recomended practice,4 stalls before establishing pattern,more stalls at 9,226 ft,9,227 ft and 9,228 ft,PUW's 34k,drill to 9,250 ft,PUH 34k,dry drift billet clean.pump 5x5 sweep.start new mud down hole. 8/5/2016 8/5/2016 1.25 PROD1 DRILL DRLG T 9,250 ft. OBD 1.52 bpm at 3,540 psi 9,250.0 9,296.0 21:45 23:00 FS,BHP 3,800 psi,CWT 9.8k,WOB 1.2k, ROP 37. **Note:New 8.6 ppg mud out bit at 9,260 ft. 8/5/2016 8/6/2016 1.00 PROD1 DRILL DRLG T 9,296 ft. New mud around,PU restart 9,296.0 9,335.0 23:00 00:00 1.65 bpm at 3,550 psi FS,BHP 3,807 psi,CWR 9.8k,WOB 1.1k,ROP 55 8/6/2016 8/6/2016 4.75 PROD1 DRILL DRLG T 9,335 ft. OBD 1.65 bpm at 3,550 psi 9,335.0 9,470.0 00:00 04:45 FS,BHP 3,810 psi,CWR 9.8k,WOB 1.1k,ROP 55,WHP 559,IA 0,OA 43 8/6/2016 8/6/2016 0.35 PROD1 DRILL WPRT T Short wiper to billet,RBIH 9,470.0 9,470.0 04:45 05:06 8/6/2016 8/6/2016 7.00 PROD1 DRILL DRLG T 9,470 ft,OBD 1.64 bpm at 3,770 psi 9,470.0 9,730.0 05:06 12:06 FS,BHP 3,790 psi,CWT 8.9k, WOB.9k,ROP 39 8/6/2016 8/6/2016 0.35 PROD1 DRILL WPRT T 9730 ft,wiper up hole PUW 36 k. 9,730.0 8,215.0 12:06 12:27 8/6/2016 8/6/2016 0.60 PROD1 DRILL DLOG T Tie into the RA correction of plus 6.0 8,215.0 8,240.0 12:27 13:03 ft. Page 8/26 Report Printed: 8/29/2016 • ep 014 O erations SummarY (with Timelo Dpths0 1 L-17 •Coeioc hi dJ.aska Rig: NABORS CDR2-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) 8/6/2016 8/6/2016 0.20 PROD1 DRILL WPRT T Perform choke calibration at 8,233 ft, 8,240.0 8,240.0 13:03 13:15 hold 3,665 psi BHP,(11.8ppg),1.51 bpm in, 1.46 bpm out,361 psi choke pressure,3,523 pump pressure. 8/6/2016 8/6/2016 0.55 PROD1 DRILL WPRT T 8,233 ft,wiper back in hole RIW 10 k 8,240.0 9,730.0 13:15 13:48 8/6/2016 8/6/2016 4.20 PROD1 DRILL DRLG T 9,730 ft,BOBD 1.58 bpm at 3,660 psi 9,730.0 9,850.0 13:48 18:00 FS,BHP 3,785,WHP 350,IA 0,OA 51, New trip schedule to 11.6 at window, NOTE:Changed from highline to gen power @ 14:50 8/6/2016 8/7/2016 6.00 PROD1 DRILL DRLG T 9,850 ft. OBD 1.56 bpm at 3,713 psi 9,850.0 9,921.0 18:00 00:00 FS,BHP 3,776 psi,CWT 3.8k,WOB 1.5k,ROP 8,hard drilling,pump 5x5, 200 ft wiper at 9,892 ft,ROP picked up to 40. 8/7/2016 8/7/2016 2.10 PROD1 DRILL DRLG T 9,920 ft. OBD 1.56 bpm at 3,720 psi 9,920.0 9,980.0 00:00 02:06 FS,BHP 3,845 psi,CWT 7.5k,WOB 1.1k,ROP 37,WHP 305,IA 0,OA 53, pump 5x5. 8/7/2016 8/7/2016 0.50 PROD1 DRILL WPRT T Wiper up hole to 8,900 ft,PUW 35k. 9,980.0 8,900.0 02:06 02:36 8/7/2016 8/7/2016 0.50 PROD1 DRILL WPRT T Wiper back in hole,RIW 10.2k 8,900.0 9,980.0 02:36 03:06 8/7/2016 8/7/2016 3.15 PROD1 DRILL DRLG T 9,980 ft. BOBD 1.56 at 3,746 psi FS, 9,980.0 10,058.0 03:06 06:15 BHP 3,784 psi,CWT 8.0k,WOB 1.7k, ROP 35.Losses-2 bph. 8/7/2016 8/7/2016 0.10 PROD1 DRILL WPRT T 200'wiper up hole,PUW 32k. 10,058.0 9,860.0 06:15 06:21 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T Wiper back in hole,RIW 9.7k. 9,860.0 10,057.0 06:21 06:30 , 8/7/2016 8/7/2016 2.10 PROD1 DRILL DRLG T BOBD, 1.4 BPM @ 3410 psi FS,BHP 10,057.0 10,111.0 06:30 08:36 4090 psi,CTSW 9.7k,WOB 1.3k, ROP 26. 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T 200'wiper up hole,PUW 32k. 10,111.0 9,910.0 08:36 08:45 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T Wiper back in hole,RIW 6.9k. 9,910.0 10,111.0 08:45 08:54 8/7/2016 8/7/2016 2.40 PROD1 DRILL DRLG T BOBD, 1.68 BPM @ 4175 psi FS, 10,111.0 10,202.0 08:54 11:18 BHP 4470 psi,CTSW 6.9k,WOB 1.3k, ROP 16. 8/7/2016 8/7/2016 0.10 PROD1 DRILL WPRT T 200'wiper up hole,PUW 34k. 10,202.0 10,000.0 11:18 11:24 . 8/7/2016 8/7/2016 0.10 PROD1 DRILL WPRT T Wiper back in hole,RIW 7.2k. 10,000.0 10,202.0 11:24 11:30 8/7/2016 8/7/2016 0.50 PROD1 DRILL DRLG T BOBD, 1.61 BPM @ 3900 psi FS, 10,202.0 10,209.0 11:30 12:00 BHP 4355 psi,CTSW 7.2k,WOB 7.2k,ROP 14.Losses-2 bph. 8/7/2016 8/7/2016 3.75 PROD1 DRILL DRLG T PUH,PUW 43k,WOB-5k.Working 10,209.0 10,250.0 12:00 15:45 back to bottom,several stalls,PUWs 40-43k.Losses increased to 1 bpm. Lowered annular pressure target from 11.6 to 11.5 ppg equivalent. 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T 200'wiper after motor stall,PUW 40k. 10,250.0 10,050.0 15:45 15:54 Lost returns while PUH. 8/7/2016 8/7/2016 0.20 PROD1 DRILL WPRT T Wiper back in hole,RIW 8.6k.Full 10,050.0 10,250.0 15:54 16:06 losses, 1.58 bpm @ 3700 psi FS. Page 9/26 Report Printed: 8/29/2016 Operations Summary (with ...... 04111 pTimelog• Depths) 1 L-17 ConoccPhillips Afssk:� Rig: NABORS CDR2-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) 8/7/2016 8/7/2016 0.40 PROD1 DRILL DRLG T BOBD,low ROP,no returns. 10,250.0 10,254.0 16:06 16:30 • 8/7/2016 8/7/2016 0.40 PROD1 DRILL WPRT T 1000'wiper up hole,PUW 43k.Full 10,254.0 9,260.0 16:30 16:54 losses.confer with town.WHP increasing to 900 psi?BHP stable at 3,570 psi,choke closed. 8/7/2016 8/7/2016 1.65 PROD1 DRILL WPRT T Wiper back in hole,RIW 11k,open 9,260.0 10,252.0 16:54 18:33 choke to 400 psi,getting .25 bpm returns pumping 1.3 bpm,confer with town on path forward. 8/7/2016 8/7/2016 4.50 PROD1 DRILL DRLG T BOBD 1.57 bpm at 3,720 psi FS, 10,252.0 10,347.0 18:33 23:03 BHP 3,842 psi,CWT 10k,WOB 1.7k, ROP 20,returns short lived,stall at 10,255 ft,drilling ahead full losses 1.6 bpm at 3,554 psi FS,BHP 3,621 psi, CWT 10k,WOP 1.2k,ROP 24,losing 90+bph Stalls at 10,227 ft, 10,283 ft, 10,287 ft and 10,300 ft 8/7/2016 8/7/2016 0.40 PROD1 DRILL WPRT T Stall at 10,347 ft,PU 37k 100 ft,RBIH, 10,347.0 10,34710 23:03 23:27 stacked at 10,257 ft,10,309 ft and 10,322 ft,lowered pump rate to get to bottom. Note:confer with town,pump 10 bbl 100k LSRV pill. 8/7/2016 8/7/2016 0.40 PROD1 DRILL DRLG T BOBD 1.66 bpm at 3,540 psi FS,BHP 10,347.0 10,353.0 23:27 23:51 3,604 psi,CWT11.0k,WOB 1.0k, . ROP 16 8/7/2016 8/8/2016 0.15 PROD1 DRILL WPRT T PUH slow while Hi-visc pill exits bit, 10,353.0 10,353.0 23:51 00:00 PUW 35k,seen drag at 10,340 ft.Hi- visc pill out, BHP to 3,628 and climbing,RBIH, 8/8/2016 8/8/2016 1.00 PROD1 DRILL DRLG T BOBD 1.6 bpm at 3,573 psi FS,BHP 10,353.0 10,370.0 00:00 01:00 3,643 psi,CWT 11.4k,WOB 0.6k, ROP 22,WHP 750,IA 0,OA 50,BHP droping back to 3,616 psi,pump another 13 bbl 100k Hi-visc pill 8/8/2016 8/8/2016 0.25 PROD1 DRILL WPRT T PU while Hi-visc pill exits bit,RBIH, 10,370.0 10,370.0 01:00 01:15 RIW 11k. 8/8/2016 8/8/2016 1.90 PROD1 DRILL DRLG T BOBD 1.5 bpm at 3,325 psi FS,BHP 10,370.0 10,434.0 01:15 03:09 6,345 psi,CWT 11k,WOB, 1.3k,ROP 22.BHP slowly coming up,stabilized at 3,680 psi.Pump 24 bbl of 100k Hi- viscpill. 8/8/2016 8/8/2016 0.50 PROD1 DRILL WPRT T Short wiper up to 10,350 ft, WHP 834 10,434.0 10,434.0 03:09 03:39 psi to 1072 psi, BHP 3,680 psi to ` 3,606 psi,RBIH,RIW 11.3k. 8/8/2016 8/8/2016 1.75 PROD1 DRILL DRLG T BOBD 1.4 bpm at 3,856 psi FS,BHP 10,434.0 10,480.0 03:39 05:24 3,638 psi,CWT 10k,WOB 1.3k,ROP 18,PU while pill exits bit,BHP to 3,710 psi,RBIH,OBD 1.43 bpm at 3,200 FS,BHP 3,668 psi,CWT 10k, WOB.8 to 1.5k,ROP 10-40 8/8/2016 8/8/2016 1.00 PROD1 DRILL WPRT T 10480 ft,Wiper up hole to window, 10,480.0 8,210.0 05:24 06:24 PUW 41k 8/8/2016 8/8/2016 0.25 PROD1 DRILL DLOG T 8210 ft,Tie into the RA marker 8,210.0 8,228.0 06:24 ' 06:39 correction of plus 9.0 ft, 8/8/2016 8/8/2016 1.00 PROD1 DRILL WPRT T 8228 ft,wiper back in hole RIW 10.2k 8,228.0 10,480.0 06:39 07:39 Page 10/26 Report Printed: 8/29/2016 •rations Summary (with Timelog Depths) 01,411, 1L-17 Conocohillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/8/2016 8/8/2016 4.00 PROD1 DRILL DRLG T 10480 ft,BOBD 1.4 bpm at 3290 psi, 10,480.0 10,622.0 07:39 11:39 BHP 3690,WHP 768, IA 0,OA 62 8/8/2016 8/8/2016 0.80 PROD1 DRILL WPRT T 10,622 ft,do to 100%losses and not 10,622.0 8,210.0 11:39 12:27 being able to obtain objectives, decision was made to POOH,for Plug back,PUW 36k 8/8/2016 8/8/2016 0.25 PROD1 DRILL DLOG T 8,210 ft,Tie into the RA correction of 8,210.0 8,230.0 12:27 12:42 plus 3.0 ft, 8/8/2016 8/8/2016 0.75 PROD1 DRILL WPRT T 8,230 ft,RIH to clean hole down past 8,230.0 9,900.0 12:42 13:27 setting depth. 8/8/2016 8/8/2016 0.75 PROD1 DRILL WPRT T 9900 ft,POOH,chasing 5x5 sweep up 9,900.0 8,048.0 13:27 14:12 to the window,losing 100%returns, pumping 1.4 bpm 8/8/2016 8/8/2016 0.25 PROD1 DRILL TRIP T 8,048 ft,Park and perform static 8,048.0 8,048.0 14:12 14:27 pressure survey,788 psi WHP,3270 psi AP 8/8/2016 8/8/2016 1.25 PROD1 DRILL TRIP T POOH,pumping 1.57 bpm at 3,500 8,048.0 72:2 14:27 15:42 psi 8/8/2016 8/8/2016 2.00 PROD1 DRILL PULD T PJSM-PUD/LD BHA#10,bit 72.2 0.0 15:42 17:42 condition-2-1-CT-N-X-I-NO-FM, reconfigure BHA for IBP run. 8/8/2016 8/8/2016 1.00 PROD1 DRILL WAIT T Wait on Weatherford IBP coming from 0.0 0.0 17:42 18:42 Prudhoe. 8/8/2016 8/8/2016 3.00 PROD1 DRILL PULD T Bring in Weatherford tools,PJSM- 0.0 48.8 18:42 21:42 MU/PD 2.125"IBP,FVS noticed in, BHA needs to be removed,PJSM- Scope change.PUD,and remove FVS from BHA,PJSM-PD IBP MU to CoilTrak,surface test. 8/8/2016 8/8/2016 1.60 PROD1 DRILL TRIP T RIH with BHA#11 EDC open 48.8 7,910.0 21:42 23:18 8/8/2016 8/8/2016 0.35 PROD1 DRILL DLOG T Tie in to HRZ for plus 8 ft correction. 7,910.0 7,970.0 23:18 23:39 8/8/2016 8/9/2016 0.35 PROD1 DRILL TRIP T RIH,clean thru window. 7,970.0 8,640.0 23:39 00:00 8/9/2016 8/9/2016 0.70 PROD1 DRILL TRIP T Continue RIH with IBP BHA#11 EDC 8,640.0 9,858.0 00:00 00:42 open pumping.5 bpm,annulus 3,473 psi 8/9/2016 8/9/2016 1.20 PROD1 DRILL PACK T On depth,shut down pump,close 9,858.0 9,858.0 00:42 01:54 EDC,climatize IBP 40 minutes,BHP 3,460 psi down to 3,275 psi(10.7 ppg equivalent) temp 114°to 128°, differential stable at 395 psi,set IBP in stages,appeares to have set early at 600 psi diff,pinned for 1,800 psi diff. Pick off clean. 8/9/2016 8/9/2016 2.60 PROD1 DRILL TRIP T POOH,attempt to get to 11.4 ppg 9,858.0 48.8 01:54 04:30 equivalent trip schedule,losing-1 bpm coming out of hole,confer with town,stop at 8,040 ft(5,880 ft TVD at DPS)on line 1.5 bpm,hold 3,473 psi at DPS depth(5,880 ft TVD=11.4 ppg EMW)stabilize out at 1.5 bpm in, .9 bpm out, 1 bpm losses.continue POOH while town gets plan forward. 8/9/2016 8/9/2016 2.00 PROD1 DRILL PULD T PJSM-PUD/LD BHA#11, IBP still on 48.8 0.0 04:30 06:30 BHA,inform town 8/9/2016 8/9/2016 1.50 PROD1 DRILL PULD T Inspect/change pac-offs,service INJH, 0.0 0.0 06:30 08:00 Weatherforrd to inspect bands and packer element, Page 11/26 Report Printed: 8/29/2016 0: Operations Summary (with Timelog Depths) 0 1 L-17 CoarocBlips Rig: NABORS CDR2-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) 8/9/2016 8/9/2016 2.00 PROD1 DRILL PULD T PJSM,PD second IBP 0.0 48.8 08:00 10:00 8/9/2016 8/9/2016 1.75 PROD1 DRILL TRIP T RIH,with open EDC pumping 0.5 bpm 48.8 7,940.0 10:00 11:45 at 1700 psi,trying to maintain 11.4 ppg MP schedule. 8/9/2016 8/9/2016 0.25 PROD1 DRILL DLOG T 7940 ft,log HRZ correction of 9.5 ft 7,940.0 7,952.8 11:45 12:00 8/9/2016 8/9/2016 1.50 PROD1 DRILL TRIP T Continue RIH to setting depth,. 7,952.8 9,303.0 12:00 13:30 8/9/2016 8/9/2016 0.50 PROD1 DRILL PACK T At depth, PU to free weight.Close 9,303.0 9,303.0 13:30 14:00 EDC.Temp 110°.Wait for temp to stabilize, 126°.Differential 492 psi. WHP 664 psi. 8/9/2016 8/9/2016 1.50 PROD1 DRILL PACK T Begin staging up to set IBP. 9,303.0 9,303.0 14:00 15:30 Pump Pres:800 psi,Diff:468 psi,bled down-not good Pump Pres: 1500 psi,Diff:492 psi bled towards 0 psi. Pump Pres:2000 psi,Diff:645 psi bled towards 0 psi. Pump Pres:2000 psi,Diff:638 psi, bled towards 0 psi. Pump Pres:2000 psi,Diff: 1005 psi, bled towards 0 psi. Pump Pres:3000 psi,Diff: 1443 psi, bled towards 0 psi. Pumped up to 1800 psi Diff,and tried to pull off tool(req 4000 psi overpull). No indication that it worked. 8/9/2016 8/9/2016 2.25 PROD1 DRILL TRIP T Decision made to POOH w/EDC 9,303.0 48.8 15:30 17:45 closed,sleeve on IBP tool closed, pumping down the backside to maintain 11.4ppg MP schedule. 8/9/2016 8/9/2016 1.75 PROD1 DRILL PULD T PJSM,PUD/LD BHA#12. 48.8 0.0 17:45 19:30 Weatherford IBP tool at surface,outer rubber split down the length of tool, inner bladder hole @ bottom of element. 8/9/2016 8/9/2016 1.00 PROD1 DRILL WAIT T Discuss path forward with town. 0.0 0:0 19:30 20:30 Compare Weatherford(damaged)and Baker tools side by side. 8/9/2016 8/9/2016 3.00 PROD1 DRILL PULD T PJSM,PU/PD BHA#13(BOT 0.0 55.4 20:30 23:30 inflatable cement retainer plug). Attempt to deploy with ball on seat and EDC open.Would have resulted in single barrier deployment.PU and close EDC.Redeploy BHA. 8/9/2016 8/10/2016 0.50 PROD1 DRILL TRIP T Bump up.Reset depth.RIH with BMA 55.4 2,000.0 23:30 00:00 #13 with EDC open. 8/10/2016 8/10/2016 1.25 PROD1 DRILL TRIP T Continue running in the hole with BHA 2,000.0 7,775.0 00:00 01:15 #13,Inflatable cement retainer with ball on seat. 8/10/2016 8/10/2016 1.00 PROD1 DRILL TRIP T While running in the hole at 7775 ft, 7,775.0 7,775.0 01:15 02:15 LEL alarm indicated gas at the shaker. Closed the choke.LEL quickly dropped off. 8/10/2016 8/10/2016 1.25 PROD1 DRILL TRIP T Lined up to the tiger tank,brought 7,775.0 9,905.0 02:15 03:30 pump back online and continued in the hole to ICR set depth.Tied in to the HRZ for a+9.5 ft crrection. Page 12/26 Report Printed: 8/29/2016 >t Operations Summary (with Timelog Depths) 0 • • 1 L-17 C hilhps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (5KB) End Depth(ftKB) 8/10/2016 8/10/2016 0.25 PROD1 DRILL PACK T Wt check=34 Klbs.Close EDC. 9,905.0 9,905.0 03:30 03:45 Stage up pump and shear ball seat at 3600 psi.Pull up to release from ICR. Pins sheared at 46 Klbs CTW. 8/10/2016 8/10/2016 0.75 PROD1 DRILL CIRC T PUH.Circulate gas cut mud out to 9,905.0 8,050.0 03:45 04:30 tiger tank. 8/10/2016 8/10/2016 2.00 PROD1 DRILL TRIP T Continue POOH,slowly circulating 8,050.0 7,450.0 04:30 06:30 bottoms up. , 8/10/2016 8/10/2016 1.00 PROD1 DRILL TRIP T 7450 ft,POOH with setting tools, 7,450.0 55:5 06:30 07:30 BHA#13 8/10/2016 8/10/2016 1.00 PROD1 DRILL PULD T At surface,PJSM,undeploy setting 55.5 0.0 07:30 08:30 tools, 8/10/2016 8/10/2016 0.50 PROD1 DRILL PULD T Reconfigure BHA,with HOT,DGS, 0.0 0.0 08:30 09:00 and FVS 8/10/2016 8/10/2016 1.25 PROD1 STK PULD T PJSM, PD Open Hole Anchored Billet. 72.9 72.9 09:00 10:15 8/10/2016 8/10/2016 1.50 PROD1 STK TRIP T RIH,with open hole anchored billet 72.9 7,940.0 10:15 11:45 BHA#14 8/10/2016 8/10/2016 0.25 PROD1 STK DLOG T Log the HRZ correction of plus 7.5 ft. 7,950.0 7,970.0 11:45 12:00 PUW 30k 8/10/2016 8/10/2016 0.75 PROD1 STK TRIP T 7970 ft,continue RIH thru window 7,970.0 9,176.8 12:00. 12:45 8/10/2016 8/10/2016 0.25 PROD1 STK WPST T 9,165 ft,Set TOB,bring pump up,tool 9,176.8 9,176.8 12:45 13:00 sheared at 4600 psi,PUW 31k, 8/10/2016 8/10/2016 1.75 PROD1 STK TRIP T POOH,pumping 0.68 bpm at 1866 psi 9,176.8 79.0 13:00 14:45 8/10/2016 8/10/2016 1.50 PROD1 STK PULD T PJSM,PUD BHA#14.LD BHA 79.0 0.0 14:45 16:15 components. 8/10/2016 8/10/2016 3.50 PROD1 WHDBOP RURD P Clean and clear rig floor in preparation 0.0 0.0 16:15 19:45 for BOP test.MU nozzle.Flush stack, flush surface lines. Valve crew on location greasing tree valves. Crew change. 8/10/2016 8/11/2016 4.25 PROD1 WHDBOP BOPE P Shell test BOP to 500 psi. Inner reel 0.0 010 19:45 00:00 valve test to 3750 psi.Begin Bi Weekly BOPE test.State witness waived by AOGCC Matt Herrera. Back on MP after Test#9,WHP 670 psi when lining back up on well. 8/11/2016 8/11/2016 4.00 PROD1 WHDBOP BOPE P Complete bi-weekly BOPE test. 0.0 0.0 00:00 04:00 Witness waived by AOGCC Matt Herrera.No failures. 8/11/2016 8/11/2016 0.75 PROD1 STK CIRC P MU injector. Displace coil back to . 0.0 0.0 04:00 _ 04:45 drilling mud. 8/11/2016 8/11/2016 1.50 PROD1 STK PULD T PD,drilling BHA 0.0 72.2 04:45 06:15 8/11/2016 8/11/2016 2.00 PROD1 STK PULD T RIH,with kickoff/drilling BHA#15 with 0.0 7,925.0 06:15 08:15 0.4°ako motor. *`*"Note:7,899.21 ft.stack out weight,PUH clean rotate TF from low side to high side.passed thru clean. 8/11/2016 8/11/2016 0.30 PROD1 STK DLOG T 7,925 ft,tie into the HRZ correction of 7,925.0 7,966.0 08:15 08:33 plus 7.5 ft.PUW 30k Page 13/26 Report Printed: 8/29/2016 0. rations Summary (with Timelog Depths) .1 Operations 1 L-17 CortocoPhil ips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth(ftKB) 8/11/2016 8/11/2016 1.15 PROD1 STK TRIP T Continue RIH 7,966.0 9,165.0 08:33 09:42 "'*"Note:Pressure survey at 8,048 ft. (censor depth 8,005 ft.(5,849 TVD w/130 ft RKB),shut choke in,monitor pressures for 15 min,Annular pressure 3,407,choke pressure 794,= 11.199 ppg. 8/11/2016 8/11/2016 4.20 PROD1 STK KOST T Dry tag TOB @ 9,165 ft PUW 35k, 9,165.0 9,220.0 09:42 13:54 bring pump up kickoff billet,1.54 bpm at 3,400 psi FS,BHP 3,650,WHP 394, IA 0,OA 0 • "*Note:stall motor getting started. 8/11/2016 8/11/2016 0.35 PROD1 STK DRLG T PUH,clean dry drift across billet. 9,220.0 9,220.0 13:54 14:15 Small WOB bobble when PUH through billet @ 0.3 bpm. 8/11/2016 8/11/2016 4.00 PROD1 DRILL DRLG T BOBD, 1.5 bpm @ 3800 psi,CTW 7- 9,220.0 9,434.0 14:15 18:15 9KIbs,WOB 1.1,ROP 40-80 fph. New 8.5ppg FloPro Mud System#3 at the bit @ 9,256'. 8/11/2016 8/11/2016 0.50 PROD1 DRILL WPRT T PUH fora short wiper. 9,434.0 9,434.0 18:15 18:45 8/11/2016 8/11/2016 1.75 PROD1 DRILL DRLG T BOBD, 1.5 bpm @ 4200 psi downhole 9,434.0 9,565.0 18:45 20:30 bore pressure,CTSW 8.1k,WOB 1.1, ROP 100 8/11/2016 8/11/2016 0.50 PROD1 DRILL WPRT T PUH for planned wiper trip to 8420 ft. 9,565.0 9,565.0 20:30 21:00 PUW 34KIbs.Clean trip up and down 8/11/2016 8/12/2016 3.00 PROD1 DRILL WPRT T BOBD, 1.6 bpm @ 3900 psi,CTW 5- 9,565.0 9,681.0 21:00 00:00 6KIbs,WOB 1.3KIbs,ROP variable between30-120 fph. 8/12/2016 8/12/2016 1.00 PROD1 DRILL DRLG T BOBD, 1.8 bpm @ 3900 psi,CTW 9,681.0 9,708.0 00:00 01:00 7KIbs,WOB 2Klbs,ROP variable between 30 fph. 8/12/2016 8/12/2016 0.50 PROD1 DRILL TRIP T GR track showing possible 9,708.0 9,708.0 01:00 01:30 communication fault.MAD pass interval from 9650 to 9700. Could riot get repeatable results.Made decsion to POOH and swap tools. 8/12/2016 8/12/2016 2.00 PROD1 DRILL TRIP T POOH with BHA#15. 9,708.0 72.0 01:30 03:30 8/12/2016 8/12/2016 1.50 PROD1 DRILL PULD T At surface.PUD and LD BHA#15. 72.0 0.0 03:30 05:00 8/12/2016 8/12/2016 1.00 PROD1 DRILL PULD T PU/PD, BHA#16.0.4°AKO motor and 0.0 72.3 05:00 06:00 RB HCC bit. 8/12/2016 8/12/2016 1.50 PROD1 DRILL TRIP T RIH,with BHA#16,open EDC. 72.3 7,925.0 06:00 07:30 8/12/2016 8/12/2016 0.25'PROD1 DRILL DLOG T 7,925 ft,log the HRZ correction of plus 7,925.0 7,964.0 07:30 07:45 7.5 ft.PUW 33k,close EDC 8/12/2016 8/12/2016 0.75 PROD1 DRILL TRIP T Continue RIH to bottom 7,964.0 9,708.0 07:45 08:30 8/12/2016 8/12/2016 0.25 PROD1 DRILL DLOG T 9,708 ft.PUH,log up to 9,615 ft. 9,708.0 9,615.0 08:30 08:45 8/12/2016 8/12/2016 0.25 PROD1 DRILL DRLG T 9,615 ft,RIH to bottom 9,615.0 9,710.0 08:45 09:00 Page 14/26 Report Printed: 8/29/2016 110 . Operations Summary (with Timelog Depths) • 0;4 1 L-17 oP Conochillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/12/2016 8/12/2016 4.50 PROD1 DRILL DRLG T 9,710 ft.,OBD 1.59 bpm at 3660 psi 9,710.0 9,845.5 09:00 13:30 FS,BHP 3718,WHP 294,IA 0,OA 43 ""`Note:7.5 NPT Time Tool Failure BHI 8/12/2016 8/12/2016 2.00 PROD1 DRILL DRLG T 9,845 ft,OBD 1.57 bpm at 3,868 psi, 9,845.5 9,910.0 13:30 15:30 BHP 3755,WHP 291, IA 0,OA 47 8/12/2016 8/12/2016 2.75 PROD1 DRILL DRLG T 9,907 ft,OBD 1.59 bpm at 3,872 psi, 9,910.0 9,960.0 15:30 18:15 BHP 3763,WHP 290,IA 0,OA 48, 6k=CTSW, 1.5k=DHWOB,average ROP 30 fph. 8/12/2016 8/12/2016 0.75 PROD1 DRILL WPRT T PUH for wiper trip to 9196 ft.PUW= 9,960.0 9,960.0 18:15 19:00 37 Klbs. Clean trip up and down. 8/12/2016 8/13/2016 5.00 PROD1 DRILL DRLG T BOBD.1.61 BPM at 4000 psi.WOB 9,960.0 10,052.0 19:00 00:00 1.9 Klbs.BHP 3728 psi.WHP 250 psi. CTSW=4-8 Klbs.ROP 10-30 fph. 8/13/2016 8/13/2016 5.50 PROD1 DRILL DRLG T Drilling ahead.1.61 BPM at 4080 psi. 10,052.0 10,180.0 00:00 05:30 WOB 2 Klbs.BHP 3750 psi.WHP 190 psi.CTSW=4-8 Klbs.ROP 10-20 fph. 8/13/2016 8/13/2016 1.00 PROD1 DRILL WPRT T PUH for wiper trip up hole to 9,210'. 10,180.0 10,180.0 05:30 06:30 PUW=36 k 8/13/2016 8/13/2016 2.00 PROD1 DRILL DRLG T 10,180 ft,BOBD 1.45 bpm at 3680 psi 10,180.0 10,207.0 06:30 08:30 FS,BHP 3740,WHP 204,IA 0,OA 52 8/13/2016 8/13/2016 5.25 PROD1 DRILL DRLG T PUH,bypass filters,pump 15 bbl anti- 10,207.0 10,369.0 08:30 13:45 balling pill(2.5%SkreenKleen/1 ppb alpine beads),continue drilling ahead 1.5 bpm at 3,845 psi FS,BHP 3,728, WHP 205, IA 0,OA 52 8/13/2016 8/13/2016 0.25 PROD1 DRILL WPRT T 10,369 ft,BHA wiper up hole,PUW 10,369.0 10,369.0 13:45 14:00 36k 8/13/2016 8/13/2016 1.75 PROD1 DRILL DRLG T BOBD 1.5 bpm at 3,800 psi,BHP 10,369.0 10,430.0 14:00 15:45 3770,WHP 192, IA 0,OA 52 ROP 35 fph. 8/13/2016 8/13/2016 1.00 PROD1 DRILL WPRT T PUH for tie in wiper trip.36Klbs PUW. 10,430.0 8,215.0 15:45 16:45 Pull heavy through 10,105 ft.Tie in to the RA for a+4.5 ft correction. 8/13/2016 8/13/2016 1.00 PROD1 DRILL WPRT T RBIH.Stack out at 10110 ft.Reduce 8,215.0 10,430.0 16:45 17:45 pumps to minimum rate.Continue running in the hole. 8/13/2016 8/13/2016 4.50 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4200 psi,BHP 10,430.0 10,595.0 17:45 22:15 3780,WHP 165,ROP 30-40 fph. Mud swap,with new mud at the bit at 10514 ft. 8/13/2016 8/13/2016 0.25 PROD1 DRILL WPRT T Short wiper.PUW 36KIbs. 10,595.0 10,595.0 22:15 22:30 8/13/2016 8/13/2016 0.67 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4030 psi,BHP 10,595.0 10,622.0 22:30 23:10 3790,WHP 220,ROP 30 fph. 8/13/2016 8/14/2016 0.83 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4030 psi,BHP 10,622.0 10,641.0 23:10 00:00 3790,WHP 220,ROP 30 fph. 8/14/2016 8/14/2016 1.25 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4030 psi,BHP 10,641.0 10,680.0 00:00 01:15 3790,WHP 220,ROP 30 fph. 8/14/2016 8/14/2016 0.50 PROD1 DRILL WPRT T PUH for wiper trip.PUW=33Klbs. 10,680.0 9,680.0 01:15 01:45 Pull heavy at 10105 ft.-4klbs WOB. Pull through at minimum rate. Page 15/26 Report Printed: 8/29/2016 • • ., 0 0'1Operations Summary (with Timelog Depths) 0 ....... 1L-17 Conoc hiiiiips R.I:xsAx Rig: NABORS CDR2-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) 8/14/2016 8/14/2016 0.50 PROD1 DRILL WPRT T RBIH.reduce pump rate to get 9,680.0 10,680.0 01:45 02:15 through 10,105 ft.COntinue RIH to bottom. 8/14/2016 8/14/2016 3.75 PROD1 DRILL DRLG P BOBD 1.5 bpm at 4100 psi,BHP 10,680.0 10,827.0 02:15 06:00 3805,WHP 290,ROP 30-90 fph. 8/14/2016 8/14/2016 3.30 PROD1 DRILL DRLG P 10,827 ft,OBD 1.5 bpm at 3796 psi, 10,827.0 10,930.0 06:00 09:18 BHP 3795,WHP 295,IA 0,OA 55 8/14/2016 8/14/2016 0.50 PROD1 DRILL WPRT P 10,930 ft,wiper up hole to 10,150 ft, 10,930.0 10,150.0 09:18 09:48 PUW 35 8/14/2016 8/14/2016 0.50 PROD1 DRILL WPRT P 10150 ft.wiper back in hole,RIW 9 k 10,150.0 10,930.0 09:48 10:18 8/14/2016 8/14/2016 7.70 PROD1 DRILL DRLG P 10,930 ft,BOBD 1.5 bpm at 3800 psi 10,930.0 11,180.0 10:18 18:00 FS,BHP 3796,WHP 301, IA 0,OA 56 8/14/2016 8/14/2016 1.50 PROD1 DRILL WPRT P 11,180 ft,tie in wiper up hole,PUW= 11,180.0 8,205.0 18:00 19:30 35KIbs. Pulled heavy from 10115- 10100 ft.Stalled motor.Work BHA down,PUH at minimum rate.Bring rate back up and continue out of the hole. 8/14/2016 8/14/2016 1.25 PROD1 DRILL WPRT P Tie in to the RA for a+5ft correction. 8,205.0 11,180.0 19:30 20:45 RBIH.Minimum rate through high GR section around 10,110 ft. 8/14/2016 8/15/2016 3.25 PROD1 DRILL DRLG P BOBD 1.5 bpm at 3900 psi,BHP ' 11,180.0 11,292.0 20:45 00:00 3800,WHP 280,IA 0,OA 56 Stacking weight,multiple PU's and restarts.Erratic ROP. 8/15/2016 8/15/2016 1.50 PROD1 DRILL DRLG P BOBD 1.5 bpm at 3900 psi,BHP 11,292.0 11,342.0 00:00 01:30 3812,WHP 214, ROP variable between 15 fph and 110 fph. 8/15/2016 8/15/2016 0.50 PROD1 DRILL DRLG P Loss rate increase from 6 BPH to 20 11,342.0 11,367.0 01:30 02:00 BPH. Continue drilling ahead,losses steadily increasing to 60+BPH. 8/15/2016 8/15/2016 6.00 PROD1 DRILL DRLG P Drilling ahead.1.5 bpm at 3887 psi, 11,367.0 11,520.0 02:00 08:00 BHP 3797,WHP 485, ROP variable between 20 fph and 80 fph. Loss rate 60-75 BPH. 8/15/2016 8/15/2016 1.00 PROD1 DRILL WPRT P 11,520 ft,wiper up hole to 10,500 ft, 11,520.0 10,528.0 08:00 09:00 PUW 41k. Pull tight,work pipe from 11,321'to 11,260'(CTSW 50k,WOB- 5k).Close choke,full losses. Cont PUH.Pulled tight,work pipe from 11,156'to 11,145'(not bit stuck). Temporarily detained @ 11,150'(CTSW 55k pull,WOB-9k, CTSW-7.5k push).Worked free.Cont PUH on wiper. 8/15/2016 8/15/2016 0.70 PROD1 DRILL WPRT P 10,500 ft,wiper back in hole.RIW 10,528.0 11,520.0 09:00 09:42 9.4k.RBIH,took weight @ 11,370'but pushed through(loss zone)pumping 1 BPM. PUH to 11,350 to clean the loss zone, still pumping 1 BPM.Pass through clean.Cont.RBIH on full losses. Page 16/26 Report Printed: 8/29/2016 • • 01 Operations Summary (with Timelog Depths) ® 1L-17 CoatocoPhitrps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 8/15/2016 8/15/2016 0.55 PROD1 DRILL DRLG P 11,520 ft,BOBD,CTSW 7.5k,WOB 11,520.0 11,540.0 09:42 10:15 0.8k,ROP 38 FPH, 1.5 BPM,IA 0,OA 55. 1.5 BPM in,0.8 BPM out,partial returns when BOB holding 11.4ppg annular pressure target. 8/15/2016 8/15/2016 1.50 PROD1 DRILL WPRT P 11,540 ft,wiper to the window,PUW 11,540.0 8,209.0 10:15 11:45 34k 8/15/2016 8/15/2016 0.25 PROD1 DRILL DLOG P 8,209 ft,log RA marker correction of 8,209.0 8,231.0 11:45 12:00 plus 5.0 ft. 8/15/2016 8/15/2016 0.25 PROD1 DRILL WPRT P , RIH to 8,251 ft,PUH performing 8,231.0 8,235.0 12:00 12:15 pressure survey logging returns at 0.71 bpm,0.95 bpm,and 1.19 bpm, 0.71 bpm returns/choke 270 psi/0.80 bpm in MM/Annular 3416 psi at SD 8202.5 ft. 0.95 bpm returns/choke 250 psi/1.16 bpm in MM/Annular 3405 psi at SD 8,197.5 ft, 1.2 bpm returns/choke 230 psi/1.49 bpm in MM/Annular 3,440 psi at , 8193.5 ft. 8/15/2016 8/15/2016 1.50 PROD1 DRILL WPRT P 8,235 ft,wiper back in hole.RIW 6 k 8,235.0 11,540.0 12:15 13:45 8/15/2016 8/15/2016 4.25 PROD1 DRILL DRLG P 11,540 ft,BOBD 1.56 bpm at 3,452 11,540.0 11,652.0 13:45 18:00 psi,BHP 3679, IA 0,OA 55 8/15/2016 8/15/2016 5.00 PROD1 DRILL DRLG P BHA wiper.Continue drilling ahead. 11,652.0 11,790.0 18:00 23:00 1.6 bpm at 3,452 psi,BHP 3670, Additional BHA wipers at 11636 ft and 11682 ft.Multiple PU's and restarts. Losses 20 BPH. 8/15/2016 8/15/2016 0.50 PROD1 DRILL WPRT P PUH to 10,785 ft for wiper trip.PUW 11,790.0 11,790.0 23:00 23:30 33 Klbs.RBIH.No issues in or out of the hole. . 8/15/2016 8/16/2016 0.50 PROD1 DRILL DRLG P BOBD 1.56 bpm at 3,500 psi,BHP 11,790.0 11,810.0 23:30 00:00 3700, IA 0,OA 55.ROP 40 fph. 8/16/2016 8/16/2016 8.00 PROD1 DRILL DRLG P Drilling ahead. 1.56 bpm at 3,712 psi, 11,810.0 12,020.0 00:00 08:00 BHP 3745, IA 0,OA 55 ROP 40-90 fph. Multiple BHA wipers and PU's to help improve ROP and weight transfer.30 bph losses. 8/16/2016 8/16/2016 0.75 PROD1 DRILL WPRT P Wiper up hole, PUW 32k.At 11,594', 12,020.0 11,002.0 08:00 08:45 pulled CTSW 40k,WOB-2k. 8/16/2016 8/16/2016 0.50 PROD1 DRILL WPRT P Wiper back in hole,RIW 9k.BOBD. 11,002.0 12,020.0 08:45 09:15 8/16/2016 8/16/2016 8.75 PROD1 DRILL DRLG P Drilling ahead. 1.40 bpm at 3,465 psi, 12,020.0 12,155.0 09:15 18:00 BHP 3750,IA 0,OA 50 ROP 25-50 fph. Multiple BHA wipers and PU's to help improve ROP and weight transfer,losses still @ 30 bph. 8/16/2016 8/16/2016 2.50 PROD1 DRILL DRLG P BHA wiper,pump 5x5 sweep. 12,155.0 12,270.0 18:00 20:30 Continue drilling ahead. 1.55 bpm at 3,505 psi,BHP 3750,IA 0,OA 50 ROP 25-60 fph. BHA wipers and PU's to maintain ROP and weight transfer. Page 17/26 Report Printed: 8/29/2016 • 110 0 Operations Summary (with Timelog Depths) c,-Ita olit 1 L-17 son000Phillipss Rig: NABORS CDR2-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) 8/16/2016 8/17/2016 3.50 PROD1 DRILL DRLG P PUH for tie in wiper trip.PUW=34 12,270.0 12,270.0 20:30 00:00 Klbs. Slight bobble at 11,966 ft,11914 ft, Tie in to the RA for a+6 ft correction. RBIH.Clean trip to bottom.Reduced pump rate across interval from 10,020 to 10,160 ft both in and out. 8/17/2016 8/17/2016 8.90 PROD1 DRILL DRLG P BOBD. 1.40 bpm at 3,600 psi,BHP 12,270.0 12,500.0 00:00 08:54 3750, IA 0,OA 50 ROP 20-60 fph. Multiple BHA wipers and PU's to help improve ROP and weight transfer,losses still @ 30 bph. Many BHA wipers.Drill ahead to called TD @ 12,500'. 8/17/2016 8/17/2016 3.50 PROD1 DRILL WPRT P Pump 10 x 10 Io/hi vis sweeps,chase 12,500.0 74.0 08:54 12:24 to swab,no jogs necessary,hole clean. 8/17/2016 8/17/2016 4.10 PROD1 DRILL DLOG P Tag.Reset depth counter.RBIH,tie-in 74.0 12,500.0 12:24 16:30 to HRZ for+7.5'correction.RIH, • weight check @ 8,070'(34K),continue in hole,tag corrected TD @ 12,500'. Start pumping beaded pill. 8/17/2016 8/17/2016 3.75 PROD1 DRILL DISP P POOH laying in 75bb1 beaded liner pill 12,500.0 100.0 16:30 20:15 followed by 11.4 ppg completion fluid. Painted EOP flags at 9550 ft and 5200 ft. 8/17/2016 8/17/2016 0.75 PROD1 DRILL OWFF P At surface,flow check well.Static. 100.0 100.0 20:15 21:00 8/17/2016 8/17/2016 1.00 PROD1 DRILL PULD P PJSM.PUH and LD BHA#16. Bit 100.0 0.0 21:00 22:00 graded 1-1-TD. 8/17/2016 8/18/2016 2.00 COMPZ1 CASING PUTB P Prep floor to run liner.PJSM.Begin 0.0 960.0 22:00 00:00 picking up first segment of liner.Joint 32 at midnight.Filling hole every 5 joints.Losses average 8 bbls/hr. 8/18/2016 8/18/2016 3.00 COMPZ1 CASING PUTB P Continue picking up first segment of 960.0 2,898.0 00:00 03:00 liner.Non ported bull nose,56 joints 2- 3/8"slotted liner,36 joints of 2-3/8" blank liner,3 joints of slotted liner,and shorty deployment.Fill hole every 10 joints.Losses 10-12 bph. 8/18/2016 8/18/2016 1.00 COMPZ1 CASING OTHR P 248 circulating hours on UQC. BHI is 2,898.0 2,898.0 03:00 04:00 required to change it out before RIH with liner,as circulating hour limit of 250 hrs will be exceeded during trip. Continue to monitor the hole.Losses 10 bph.Pressure test UQC to 4,000 psi. 8/18/2016 8/18/2016 1.35 COMPZ1 CASING PULD P MU BHA#17,liner running BHA.Stab 2,898.0 2,942.0 04:00 05:21 injector. 8/18/2016 8/18/2016 4.55 COMPZ1 CASING RUNL P RIH w/lower liner assembly,tie-in 2,942.0 12,495.0 05:21 09:54 EOP flag for+2.5'correction, weight check @ 10,790'(36K).Had to work pipe,heavy pick-ups,stacking to 10,750'to 11,000',pushing @ 10 fpm, after 11,000',increased to 25-30 fpm. Stack weight @ 12,495',weight check 41K,set back down,release from liner, PUW=32K.PUH,reset bit depth. Page 18/26 Report Printed: 8/29/2016 • • 0 tz Operations Summary (with Timelog Depths) 1 L-17 Conoco 'hitups Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth(ftKB) 8/18/2016 8/18/2016 2.05 COMPZ1 CASING TRIP P POOH.tie-in to RA tag for+6' 12,495.0 64.0 09:54 11:57 correction,corrected TOL @ 9,602'. POOH w/BHA#17. 8/18/2016 8/18/2016 0.25 COMPZ1 CASING OWFF P No flow check 64.0 64.0 11:57 . 12:12 8/18/2016 8/18/2016 1.25 COMPZ1 CASING PULD P PJSM.LD BHA#17,check coil above 64.0 0.0 12:12 13:27 CC,found flat spot(0.062).Perform function test on BOP. 8/18/2016 8/18/2016 2.55 COMPZ1 CASING CTOP P Cut 20'of coil,install CTC and test. 0.0 0.0 13:27 16:00 8/18/2016 8/18/2016 2.50 COMPZ1 CASING PUTB P PJSM.MU upper liner assembly:BN, 0.0 1,253.0 16:00 18:30 40 jts slotted,three pups,OH anchored billet. 8/18/2016 8/18/2016 1.50 COMPZ1 CASING PULD P PU CoilTrak BHA and MU to liner. 1,253.0 1,313.0 18:30 20:00 Strip over and make up injector.Open EDC. • 8/18/2016 8/18/2016 3.00 COMPZ1 CASING RUNL P RIH with upper liner segment.Tie-in to 1,313.0 9,600.0 20:00 23:00 EOP flag for+5.3 ft correction. Continue running in the hole.Tie in to the HRZ for+2 ft correction. Close EDC.RIH.Took weight briefly at 9551 ft.Tagged top of lower segment at 9,600 ft. PU to neutral weight.Confirm anchor orientation of 30°ROHS.Bring up pump.Anchor set with 3,800 psi.Set 5 Klbs down.Confirm set. 8/18/2016 8/19/2016 1.00 COMPZ1 CASING RUNL P PUH.Reset depth to setting sleeve. 9,600.0 2,661.0 23:00 00:00 Continue POOH with liner running tools. 8/19/2016 8/19/2016 0.50 COMPZ1 CASING TRIP P Continue POOH with liner running 2,661.0 100.0 00:00 . 00:30 . tools. 8/19/2016 8/19/2016 0.50 COMPZ1 CASING TRIP P Flow check well.Static. 100.0 100.0 00:30 01:00 8/19/2016 8/19/2016 1.00 COMPZ1 CASING PULD P LD liner running BHA#18.Check CT 100.0 0.0 01:00 02:00 for flat spots. 8/19/2016 8/19/2016 1.00 PROD2 STK PULD P PU/MU build BHA#19,with 2.2°AKO 0.0 72.0 02:00 03:00 motor and RR HCC bit.Surface test. 8/19/2016 8/19/2016 2.00 PROD2 STK TRIP P RIH with BHA#19.RIH wt=11 Klbs. 72.0 7,840.0 03:00 05:00 Tie-in HRZ for+14'correction, continue in hole. 8/19/2016 8/19/2016 1.50 PROD2 STK DISP P Circulate well back to used drilling • 7,840.0 7,840.0 05:00 06:30 mud,close EDC,PUW=29K. 8/19/2016 8/19/2016 2.85 PROD2 STK KOST P RIH,dry tag billet @ 8,347'.PUH,start 7,840.0 8,347.0 06:30 09:21 pumps.Backream uphole to 8,320'@ 1 fpm.RBIH,one stall.Stick drill @ 8,345',wait,repeat till we see WOB. Time drill off billet: 1.53 bpm @ 3,250 PSI,CTW=11.5K,WOB=1.5. Aluminum at shaker,start seeing"C" sand in returns,off billet. 8/19/2016 8/19/2016 4.15 PROD2 DRILL DRLG P Drill ahead All build section:1.54 8,347.0 8,380.0 09:21 13:30 BPM @ 3,360 PSI,BHP=3,560 PSI, CTW=11.4K,WOB=1.7K,ROP=25. Dry drift billet,clean. Page 19/26 Report Printed: 8/29/2016 CA 011 0 !erations Summary (with Timelog •ths) IL-17 ConocoPhiiflps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log• Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/19/2016 8/20/2016 10.50 PROD2 DRILL DRLG P RBIH and continue drilling ahead. 1.51 8,380.0 8,565.0 13:30 00:00 BPM @ 3,280 PSI,BHP=3,590 PSI, CTW=10.5K,WOB=1.5-2K,ROP has been variable between 7 fph to 80+ fph in the build section. Stacking weight.Multiple PU and restarts to keep drilling.DLS over the build section average=52°. 8/20/2016 8/20/2016 2.00 PROD2 DRILL TRIP P POOH with build BHA after section TD 8,565.0 72.0 00:00 02:00 of 8565 ft. PUW=34 Klbs. 8/20/2016 8/20/2016 1.00 PROD2 DRILL PULD P PUD BHA#19. 72.0 0.0 02:00 03:00 8/20/2016 8/20/2016 1.50 PROD2 DRILL PULD P MU,MU,PD BHA#20 with 0.4°+AKO 0.0 72.0 03:00 04:30 motor and RB HCC bit. , 8/20/2016 8/20/2016 2.35 PROD2 DRILL TRIP P RIH w/lateral drilling assembly,tie-in 72.0 8,565.0 04:30 06:51 HRZ for+7'correction,continue in hole. 8/20/2016 8/20/2016 1.65 PROD2 DRILL DRLG P BOBD: 1.55 BPM @ 3390 PSI, 8,565.0 8,630.0 06:51 08:30 BHP=3590 PSI,CTW=10.5K, WOB=1.5K,ROP=20-50.Start pumping new mud system,new mud at bit 8,630'. 8/20/2016 8/20/2016 4.50 PROD2 DRILL DRLG P Drilling 1.57 BPM @ 3,600 PSI, 8,630.0 8,738.0 08:30 13:00 BHP=3586 PSI,CTW=9-10.5K, WOB=1.5K,ROP=20-50. Saw slight decrease in mud density out. Mud appeared aired up.Treated active system with defoamer. 8/20/2016 8/20/2016 5.50 PROD2 DRILL DRLG P Stall and restart at 8738 ft and 8754 ft. 8,738.0 8,960.0 13:00 18:30 Continue drilling ahead.ROP 12 fph to 200+fph. 8/20/2016 8/20/2016 0.75 PROD2 DRILL WPRT P PUH for wiper trip.PUW=31KIbs. 8,960.0 8,960.0 18:30 19:15 Clean trip in and out. 8/20/2016 8/21/2016 4.75 PROD2 DRILL DRLG P Continue drilling ahead.Having 8,960.0 9,247.0 19:15 00:00 trouble building angle.Adjust drilling parameters to try and increase motor DLS output.Vary WOB from 0.9-2.5 Klbs. Increase pump rate as high as 1.7 bpm. Appears formation related. Able to meet adjusted geo targets. 8/21/2016 8/21/2016 4.00 PROD2 DRILL DRLG P Continue drilling ahead.Pumping 1.8 9,247.0 9,360.0 00:00 04:00 BPM at 4107 psi.BHP=3680 psi. CTW=9Klbs,ROP=20-150 fph. 8/21/2016 8/21/2016 0.50 PROD2 DRILL WPRT P PUH for wiper trip.PUW=32 Klbs. 9,360.0 9,360.0 04:00 04:30 RBIH. 8/21/2016 8/21/2016 3.35 PROD2 DRILL DRLG P BOBD: 1.83 BPM @ 4075 PSI,BHP= 9,360.0 9,430.0 04:30 07:51 3670 PSI,CTW=9K,WOB=1.3K, ROP=20-40.At @ 9,430',started losing returns,down to almost nothing, reduce pump rate to 1.60 BPM, continue drilling,returns returning, crude/gas back in returns. 8/21/2016 8/21/2016 0.50 PROD2 DRILL WPRT P Short wiper to stabilize returns, 9,430.0 9,430.0 07:51 08:21 increase pump rate back 1.83 BPM, returns stabilizing. Increase choke press by 20 PSI.Losses currently @ 8 BPH. Page 20/26 Report Printed: 8/29/2016 • Op rations Summary (with Timelog Depths) 0 eat 1L-17 hililips Ai.t.. Rig: NABORS CDR2-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) 8/21/2016 8/21/2016 5.90 PROD2 DRILL DRLG P BOBD: 1.83 BPM @ 4115 PSI,BHP= 9,430.0 9,608.0 08:21 14:15 3690 PSI,CTW=9K,WOB=1K, ROP=20-40. Losing have increased slowly to 15 BPH,continue drilling. Pumped 10 bbl Hi-Vis pills. Experienced more losses. 8/21/2016 8/21/2016 0.50 PROD2 DRILL WPRT P Short wiper to stablize return, 9,608.0 9,608.0 14:15 14:45 PUW=33K.RBIH. 8/21/2016 8/21/2016 6.00 PROD2 DRILL DRLG P BOBD: 1.83 BPM @ 4115 PSI,BHP= 9,608.0 9,760.0 14:45 20:45 3690 PSI,CTW=9K,WOB=1K, ROP=20-40.Losses currently @ 18- 20 bpm. 8/21/2016 8/21/2016 1.50 PROD2 DRILL WPRT P PUH for tie in wiper trip.PUW=32 9,760.0 9,760.0 20:45 22:15 Klbs.Tie in to the RA for a+5 ft correction.RBIH.Clean trip in and out. Observed an increase in cuttings over the shaker. 8/21/2016 8/22/2016 1.75 PROD2 DRILL DRLG P BOBD:1.82 BPM @ 4120 PSI,BHP= 9,760.0 9,766.0 22:15 00:00 3740 PSI,CTW=7K,WOB=1.5K,ROP slowed from 18 fph to 1 fph.Losses @ 18-20 bpm. 8/22/2016 8/22/2016 5.15 PROD2 DRILL DRLG P Drilling ahead at 1.82 BPM @ 4120 9,766.0 9,805.0 00:00 05:09 PSI,BHP=3740 PSI,CTW=7K, WOB=1.5K,ROP at1 to 2 fph. Vary drilling parameters.Able to work up to 8 fph. Losses @ 18-20 bpm. 8/22/2016 8/22/2016 0.25 PROD2 DRILL WPRT P Mini wiper,PUW=35K,RBIH. 9,805.0 9,805.0 05:09 05:24 8/22/2016 8/22/2016 2.00 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3610 9,805.0 9,841.0 05:24 07:24 PSI,BHP=3745 PSI,CTW=6.5K, WOB=1.2K,ROP=10-20.Losses still 15-20 BPH. 8/22/2016 8/22/2016 0.25 PROD2 DRILL WPRT P BHA wiper,PUW=35K,RBIH. 9,841.0 9,841.0 07:24 07:39 8/22/2016 8/22/2016 7.05 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3810 9,841.0 9,944.0 07:39 14:42 PSI,BHP=3765 PSI,CTW=5.5K, WOB=1.3K,ROP=10-15.Losses remain @ 15-17 BPH.GEO up 90 degrees. 8/22/2016 8/22/2016 0.15 PROD2 DRILL WPRT P Mini wiper/weight check,PUW=37K, 9,944:0 9,944.0 14:42 14:51 RBIH. 8/22/2016 8/22/2016 2.40 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3755 9,944.0 9,977.0 14:51 17:15 PSI,BHP=3745 PSI,CTW=5.3K, WOB=1.1 K, ROP=15-20.Losses remain @ 15-17 BPH.GEO up 93 degrees. 8/22/2016 8/22/2016 0.25 PROD2 DRILL WPRT P BHA wiper.PUW=39KIbs. 9,977.0 9,977.0 17:15 17:30 8/22/2016 8/22/2016 2.50 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3760, 9,977.0 10,003.0 17:30 20:00 PSI,BHP=3778 PSI,CTW=3-8K, WOB=1.2K,ROP average 10 fph. Losses remain©15-17 BPI-I. 8/22/2016 8/22/2016 0.50 PROD2 DRILL WPRT P PUH for wiper trip to help improve 10,003.0 8,995.0 20:00 20:30 drilling rate.PUW=38 Klbs.Clean trip up. 8/22/2016 8/22/2016 0.50 PROD2 DRILL WPRT P RBIH.RIH wt=9 Klbs.Clean trip in 8,995.0 10,003.0 20:30 21:00 and out. Page 21/26 Report Printed: 8/29/2016 1 Operations Summary (with Timelog Depths) 01 • e 1L-17 Cc ocoPhillipis Rig: NABORS CDR2-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) 8/22/2016 8/23/2016 3.00 PROD2 DRILL WPRT 'P Continue drilling ahead. ROP between 10,003.0 10,017.0 21:00 00:00 1 fph-2 fph. Difficulty drilling past 10,003 ft.ROP increased after 10,005 ft to 10 fph. 8/23/2016 8/23/2016 4.50 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3760 10,017.0 10,090.0 00:00 04:30 PSI,BHP=3758 PSI,CTW=7K, WOB=1.2K,ROP average 20 fph. Losses @ 15 BPH. Drilling break from10,080-10,088 ft. 8/23/2016 8/23/2016 0.25 PROD2 DRILL WPRT P Mini wiper,PUW=36K,RBIH. 10,090.0 10,090.0 04:30 04:45 8/23/2016 8/23/2016 4.70 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3760 10,090.0 10,157.0 ,04:45 09:27 PSI,BHP=3778 PSI,CTW=6.5K, WOB=1.4K,ROP=10-15. 8/23/2016 8/23/2016 0.25 PROD2 DRILL WPRT P BHA wiper trip, PUW=32K, RBIH. 10,157.0 10,157.0 09:27 09:42 8/23/2016 8/23/2016 1.00 PROD2 DRILL DRLG P Drilling ahead at 1.63 BPM @ 4090 10,157.0 10,172.0 09:42 10:42 PSI,BHP=3780 PSI,CTW=5.8K, WOB=1K,ROP=10. 8/23/2016 8/23/2016 0.25 PROD2 DRILL WPRT P BHA wiper trip,PUW=31K,RBIH. 10,172.0 10,172.0 10:42 10:57 8/23/2016 8/23/2016 7.55 PROD2 DRILL DRLG P Drilling ahead at 1.63 BPM @ 4090 10,172.0 10,253.0 10:57 18:30 PSI,BHP=3780 PSI,CTW=5.8K, WOB=1K,ROP=10.Started pumping new mud system,new mud @ bit ' 10,177',minimal improvement.Drill ahead,pump 10x10 to/hi sweep. 8/23/2016 8/23/2016 2.60 PROD2 DRILL . TRIP P POOH chasing sweeps.PUW 34k, 10,253.0 72.2 18:30 21:06 300 ft jog at EOB 8,621 ft,continue POOH,clean past billet,window and pilot hole,close EDC at 7,940 ft, continue POOH for Bi-weekly BOPE test and BHA Change. 8/23/2016 8/23/2016 1.50 PROD2 DRILL PULD P On surface,tag up,spae out,PJSM, 72.2 0.0 21:06 22:36 PUD/LD BHA#20.Bit condition 2-1- BT-N-X-I-CT-PR. 8/23/2016 8/24/2016 1.40 PROD2 WHDBOP RURD P PJSM-Prep for BOPE test,clean and 0.0 0.0 22:36 00:00 clear floors,pull checks,install nozzle, flush surface lines,coil and jet stack, service tree. 8/24/2016 8/24/2016 1.00 PROD2 WHDBOP RURD P Continue prep for BOPE test,grease 0.0 0.0 00:00 01:00 choke and stack.Test inner reel iron, stripper 250/3,500 psi.fluid pack, shell test. 8/24/2016 8/24/2016 9.50 PROD2 WHDBOP BOPE P Test BOPE 250/3,750 psi,annular 0.0 0.0 01:00 10:30 2,500 psi,witnessed by AOGCC rep. Brian Bixby.Four failures,three fail/pass,greased&retested.Annular bag was replaced w/OEM equip. 8/24/2016 8/24/2016 2.00 PROD2 WHDBOP RURD P RD test equipment,grease valves, 0.0 0.0 10:30 12:30 service injector head,stab on with . checks&nozzel and swap coil back to 8.5 FloPro mud 8/24/2016 8/24/2016 2.89 PROD2 DRILL PULD P MU/PD BHA#21 with 0.5°AKO 0.0 74.8 12:30 15:23 Weatherford 2-3/8",RB HYC bicenter bit Page 22/26 Report Printed: 8/29/2016 • • 0 Operations Summary (with Timelog Depths) i 1 L-17 conn hUI ps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation WE) End Depth(ftKB) 8/24/2016 8/24/2016 1.87 PROD2 DRILL TRIP P RIH with lateral drilling BHA,stop at 74.8 7,930.0 15:23 17:15 2600 ft to establish Weatherford motor parameters,@ 1.55 bpm(60 gpm), 700 psi dp,3740 psi pump pressure. 8/24/2016 8/24/2016 0.25 PROD2 DRILL DLOG P 7940 ft log HRZ tie-in,+7 ft correction 7,935.0 7,977.0 17:15 17:30 8/24/2016 8/24/2016 1.00 PROD2 DRILL TRIP P RIH take two survey checks at min 7,977.0 10,253.0 17:30 18:30 rate and 10 fpm,surveys acceptable, establish free spin at 1.54 bpm,700 psi differential,3762 psi AP 8/24/2016 8/25/2016 . 5.50 PROD2 DRILL DRLG P Drilling ahead at 10253 ft, 1.54 bpm, 10,253.0 10,486.0 18:30 00:00 3830 psi,3763 psi BHP,8.5K CTW, attempt to manage ROP and lateral vibration,lower rate to 1.45 bpm and vary WOB between 1.5 and 2K. 8/25/2016 8/25/2016 0.65 PROD2 DRILL DRLG P Continue drilling AL1 lateral from 10,486.0 10,510.0 00:00 00:39 10,486 ft 1.53 bpm at 3,550 psi FS, BHP 3,775 psi,-0.5k CWT,WOB 1.1k, ROP 33,WHP 267,IA 0,OA 49 8/25/2016 8/25/2016 0.35 PROD2 DRILL WPRT P Wiper trip up hole,PUW 36k. 10,510.0 9,515.0 00:39 01:00 8/25/2016 8/25/2016 0.40 PROD2 DRILL WPRT P Wiper trip in hole,RIW 6k. 9,515.0 10,510.0 01:00 01:24 8/25/2016 8/25/2016 2.85 PROD2 DRILL DRLG P Drilling ahead at 10,510 ft.1.53 bpm 10,510.0 10,618.0 01:24 04:15 at 3,690 psi FS,BHP 3,800 psi,CWT -.5k,WOB 1.95k,ROP 40, 8/25/2016 8/25/2016 0.25 PROD2 DRILL WPRT P BHA wiper,PUW=41K,RBIH. 10,618.0 10,618.0 04:15 04:30 8/25/2016 8/25/2016 2.50 PROD2 DRILL DRLG P Drilling ahead:1.53 bpm at 3,690 psi 10,618.0 10,760.0 04:30 07:00 FS,BHP 3,805 psi,CWT 2k,WOB 1k, ROP=45 8/25/2016 8/25/2016 0.85 PROD2 DRILL WPRT P 1000'wiper trip,PUW=35K,RBIH. 10,760.0 10,760.0 07:00 07:51 Good solids returns across shaker. 8/25/2016 8/25/2016 1.50 PROD2 DRILL DRLG P BOBD:1.54 bpm at 3,780 psi FS, 10,760.0 10,830.0 07:51 09:21 BHP 3,815 psi,CWT 3k,WOB.8k, ROP=35.Trying to GEO steer down, near bit inclination 91 degrees. 8/25/2016 8/25/2016 0.25 PROD2 DRILL WPRT P BHA wiper,PUW=36K,RBIH. 10,830.0 10,830.0 09:21 09:36 8/25/2016 8/25/2016 6.80 PROD2 DRILL DRLG P BOBD:1.54 bpm at 3,780 psi FS, 10,830.0 11,010.0 09:36 16:24 BHP 3,815 psi,CWT 3k,WOB.8k, ROP=35.Try GEO steer up then down cutting upper C4 zone at steeper angle,unsuccessful.GEO steer down at 88 degrees. 8/25/2016 8/25/2016 1.00 PROD2 DRILL WPRT P Wiper trip to window,PUW=35K,tie-in 11,010.0 8,220.0 16:24 17:24 to RA marker,+5 ft correction 8/25/2016 8/25/2016 1.00 PROD2 DRILL WPRT P Wiper trip in hole,RIW=6K 8,220.0 11,010.0 17:24 18:24 8/25/2016 8/26/2016 5.60 PROD2 DRILL DRLG P Drilling ahead at 11010', 1.54 bpm, 11,010.0 11,230.0 18:24 00:00 3630 psi FS,3822 psi BHP,CWT- K, WOB 1K,trying to GEO steer up,max pump rate up to 1.65 bpm,CWT-8k, WOB 2.2k,BHA and mini wipers as needed. Page 23/26 Report Printed: 8/29/2016 :4,., _ s Is Operations Summary (with Timelog Depths) 1L-17 + uulips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X. Operation (EKE) End Depth(EKE) 8/26/2016 8/26/2016 0.75 PROD2 DRILL DRLG P Continue drilling AL1 lateral from 11,230.0 11,260.0 00:00 00:45 11,230 ft 1.54 bpm at 3,620 psi FS, BHP 3,827 psi,CWT-5k,WOB 1.1k, WHP 249, IA 0,OA 58,trouble getting tools to invert up,unable to build inclination,formation pushng tools down,pump 5x5. 8/26/2016 8/26/2016 0.50 PROD2 DRILL WPRT P Wiper trip up hole,PUW 37k. 11,260.0 10,060.0 00:45 01:15 8/26/2016 8/26/2016 0.50 PROD2 DRILL WPRT P Wiper trip in hole,RIW 5k. 10,060.0 11,260.0 01:15 01:45 8/26/2016 8/26/2016 7.55 PROD2 DRILL DRLG P On bottom,back ream 1 fpm HS for 11,260.0 11,510.0 01:45 09:18 15',RBIH drilling ahead 1.54 bpm at 3,649 psi,BHP 3,820 psi,CWT-9k, WOB 2k,pump 50 bbls new mud,able to get from 88°to 91°an get kicked back down,attempt different pump rates,TF's-HS 10°L/R,drill ahead 1.54 bpm at 3640 psi FS,BHP 3,828 psi,CWT-10k,WOB 1.4k,ROP 30- 120 8/26/2016 8/26/2016 1.25 PROD2 DRILL WPRT P Wiper trip,PUW=35k,RBIH. 11,510.0 11,510.0 09:18 10:33 8/26/2016 8/26/2016 2.25 PROD2 DRILL DRLG P BOBD:1.40 bpm at 3,480 psi FS, 11,510.0 11,595.0 10:33 12:48 BHP 3,830 psi,CWT-8k,WOB 1.2K, ROP=20-70.Keep trying GEO up, formation kicking us down,slower , drilling, have encountered the B2. Trying to GEO back up. 8/26/2016 8/26/2016 0.25 PROD2 DRILL WPRT P BHA wiper,PUW=38K,RBIH. 11,595.0 11,595.0 12:48 13:03 8/26/2016 8/26/2016 4.30 PROD2 DRILL DRLG P BOBD: 1.54 bpm at 3,610 psi FS, 11,595.0 11,630.0 13:03 17:21 BHP 3,830 psi,CWT-9k,WOB 1.3K, ROP=10-30. Trying to GEO back up. Mini wiper @ 11,432',PUW=42K, RBIH,continue drilling to progress slowed at 11,631 ft,TD called,pump 10x10 sweep. 8/26/2016 8/26/2016 . 3.50 PROD2 DRILL WPRT P POOH chasing sweep to EOB,open 11,630.0 74.8 17:21 20:51 hole clean,300 ft jog at EOB,clean past billet,window and pilot hole, POOH,jog at 500 ft. 8/26/2016 . 8/26/2016 1.40 PROD2 DRILL TRIP P Tag up,space out,reset counters, 74.8 7,935.0 20:51 22:15 RBIH. 8/26/2016 8/26/2016 0.25 PROD2 DRILL DLOG P Tie in at HRZ for plus 7.5 ft correction, 7,935.0 7,977.0 22:15 22:30 PUW 29k. 8/26/2016 8/27/2016 1.50 PROD2 DRILL TRIP P Continue RIH,stacked at 11,610 ft, 7,977.0 11,610.0 22:30 00:00 PUW 39k,confer with town,pump beaded liner pill. 8/27/2016 8/27/2016 0.40 PROD2 DRILL DISP P Pumping beaded liner pill while 11,610.0 11,600.0 00:00 00:24 reciprocating pipe. 8/27/2016 8/27/2016 1.60 PROD2 DRILL DISP P POOH laying in beaded liner running 11,600.0 3,300.0 00:24 02:00 pill/11.6 ppg completion fluid from 11,600 ft,paint flags at 7,900 ft and 4,400 ft,continue POOH Page 24/26 Report Printed: 8/29/2016 Operations Summary (with Timelog Depths) 1L-17 Conoco mps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/27/2016 8/27/2016 3.00 PROD2 DRILL DISP T Heavy losses(40-45 bph)slow speed 3,300.0 3,150.0 02:00 05:00 and pump rate,losses slowed to 18- 20 bph pumping minimum rate.confer with town,fluids to manage losses coming,perform 5 minute static at 3,120 ft(2,342 ft TVD at DPS)AP 1,566 psi to 1,531 psi,come on line minimum rate,2.5 bbls to get returns. KWF fluid to manage losses off loaded. 8/27/2016 8/27/2016 4.75 PROD2 DRILL TRIP T RIH to window for static,static 3,150.0 8,190.0 05:00 09:45 pressure 20 mins,starting preesure 3,612 PSI,ending pressure 3550', EMD @ 11.5 ppg.Losses still 15-20 bph.Called town,decide to POOH laying in 50 bbl beaded pill from top of window. 8/27/2016 8/27/2016 1.60 PROD2 DRILL DISP P POOH laying in beaded liner pill,paint 8,190.0 97.0 09:45 11:21 EOP flag @ 4,500',continue OOH laying in liner pill. 8/27/2016 8/27/2016 0.50 PROD2 DRILL OWFF P Monitor well for flow,no flow. 97.0 97.0 11:21 11:51 8/27/2016 8/27/2016 1.00 PROD2 DRILL PULD P PJSM.LD BHA#21,bit grade 1-1, 97.0 0.0 11:51 12:51 some balling,pictures on"S"drive. Weatherford motor will be sent to shop for Dyno test.Test top drive. 8/27/2016 8/27/2016 1.00 COMPZ2 CASING PUTB P Prep rig floor for liner run. 0.0 0.0 12:51 13:51 ' 8/27/2016 8/27/2016 4.15 COMPZ2 CASING PUTB P PJSM.MU AL1 liner assembly:BN, 0.0 3,549.4 13:51 18:00 109 jts slotted,shorty deployment sleeve. 8/27/2016 8/27/2016 1.50 COMPZ2 CASING PUTB P PJSM-MU liner assembly to BHA 3,549.4 3,593.6 18:00 19:30 #22,change out check valves,MU BHA to CoilTrak,surface test. 8/27/2016 8/28/2016 4.50 COMPZ2 CASING RUNL P RIH with BHA#22, Plus 3.5 ft 3,593.6 11,148.0 19:30 00:00 correction at flag,sat down at 10,240 ft,start working down,break over at 46k-48k,continue working liner down to 11,148 ft as of midnight. 8/28/2016 8/28/2016 1.35 COMPZ2 CASING RUNL P Continue working liner down from 11,148.0 11,600.0 00:00 01:21 11,148 ft,work thru tight area 11,085 ft to 11,150 ft,PUW 47k,RIH getting good surface weight back,log HRZ for plus 1.5 ft correction.on depth at 11,598 ft(11,600 ft corrected from HZR)release off liner at 1.4 bpm, PUW 29k,top of liner at 8,050 ft,reset counters. 8/28/2016 8/28/2016 3.15 COMPZ2 CASING DISP P Displace well to seawater,POOH, 8,030.0 2,500.0 01:21 04:30 PJSM with LRS,RU LRS,P/T lines and equipment, 8/28/2016 8/28/2016 1.95 COMPZ2 CASING FRZP P Freeze protect from 2,500 ft. POOH. 2,500.0 44.2 04:30 06:27 8/28/2016 8/28/2016 1.45 COMPZ2 CASING PULD P PJSM-PUD BHA#22,LD BHA, 44.2 0.0 06:27 07:54 remove floats,UQC. 8/28/2016 8/28/2016 1.30 DEMOB WHDBOP MPSP P PJSM.Rig up valve crew lubricator, 0.0 0.0 07:54 09:12 set BPVm WHP=1035 PSI.LD surface equipment. 8/28/2016 8/28/2016 1.90 DEMOB WHDBOP RURD P Displace coil to fresh water.LD 0.0 0.0 09:12 11:06 mouseholes. Page 25/26 Report Printed: 8/29/2016 i.;. { • • or Operations Summary (with Timelog Depths) 1L-17 Conoccehillips . Rig: NABORS CDR2-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) 8/28/2016 8/28/2016 4.00 DEMOB WHDBOP RURD P PJSM.remove UQC,start cutting 0.0 0.0 11:06 15:06 1,400'coil,LD cutting equipment, 8/28/2016 8/28/2016 5.40 DEMOB WHDBOP RURD P Install external connector,pull test, 0.0 0.0 15:06 20:30 boot wire,install nozzle,stab on wellhead. Pump corrision inhibitor, chase with freshwater.LD PDL. Blow down coil,stack,and surface lines, complete off loading fluids from rig. 8/28/2016 8/28/2016 2.00 DEMOB WHDBOP NUND P PJSM-Freeze protect tree.ND BOPE, 0.0 0.0 20:30 22:30 torque checked(40 minutes)remove Kill,deployment lines. 8/28/2016 8/29/2016 1.50 DEMOB WHDBOP RURD P Complete rig down checklist. 0.0 0.0 22:30 00:00 Rig Released at 00:00 on 08-29-2016 Page 26/26 Report-Printed: 8/29/2016 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1L-17A 50-029-22151-01 Baker Hughes INTE I1 Definitive Survey Report HUGHES 07 September,2016 ConocoPhillips BAHKES Company: Copnaruk River Unit ) p2 TVD Reference: Reference: We1�1L-17 Project: (1L-17) ocoPhilli s Alaska Inc-Ku Local Co-ordinate ect: Ku (1 L 17) Site:. Kuparuk 11_Pad MD Reference: 1L-17 @ 130.00usfl(1 L-17) Well: 1L-17 North Reference: True ( Wellbore: 1L-17A Survey Calculation Method: Minimum Curvature Design: 1L-17A 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 'f.Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ...._.......,. ,»...., .»»»m».,,»,.....»mom..-„--,,,.,�,�.,»,,......... ... .,_. Well 1 L-17 Well Position a-NI-S 0.00 usft Northing: 5,948,610.93 usft Latitude: 70°16'13.945 N +E/-W 0.00 usft Easting: 539,923.20usft Longitude: 149°40'37.666 W Position Uncertainty 000 usft Wellhead Elevation: usft Ground Level: 000 usft Wellbore 1L-17A Magnetics Model Name .. Sample Date'.. D4f atlon --' .,,, Dip Angle Fitt. BGGM2015 7/1/2016 18.40 80.93 57,492 Design 1L-17A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,155.65 Vertical Section: ' Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) % (usft):1 _ (°) 130.00 0.00 0.00 135.00 i Survey Program Date 97/2016 From- -To Survey Survey (usft) (ask) Survey(Wellbore) Tool Name Description : ',.._ ,t ' Start Data End Date 200.00 8,100.00 1L-17(1L-17) GCT-MS Schlumberger GCT multishot 1/8/2001 8,194.00 9,155.65 1L-17APB1(1L-17APB1) MWD MWD-Standard 7/28/2016 8/3/2016 9,16500 12,472.11 1L-17A(1L-17A) MWD MWD-Standard 8/9/2016 8/17/2016 ~ft oPfii ?Pege2 ZSOl6'F S'5eao..?7Bw ki77Y • • C enocoPh1111ps MI ConocoPhillips Deftnnwe Strwity Report BAK ER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-17 Project Kuparuk River Unit TVD Reference: 1 L-17 rQ 130.00usft(1 L-17) Site: Kuparuk 1 L Pad MD Reference: 1 L-17(d 130.00usft(1 L-17) Well: 1 L-17 North Reference: True Wellbore: 1L-17A Survey Calculation Method: Minimum Curvature Design: 1L-17A Database: EDM Alaska NSK Sandbox Survey .>s Map Map Vertical MD Inc Azi ND TVDSS +N/-S •E/W DLS Northing Fasting Section Survey Tool Name Annotation (usft) (1 11 (usft) (usft) (usft) Na}t) O on (°11001 on 9,155.65 88.99 155.79 5,987 18 5,857 18 459679 3,576.23 5,943,995.69 536371.75 649 72165 MWD(2) TIP 9,165.00 89.06 155.31 5,987.34 5,857.34 4,605.30 -3,57236 5,943,987.20 536,375 67 5.19 73040 MWD(3) KOP 9,195.54 8478 155.60 5,988.98 5,858.98 -4,633.03 3,559.69 5,943,959.54 536,388.48 14.05 758.97 MWD(3) 1. 9,227.30 85.30 154.81 5,991.73 5,861.73 -4,661.76 -3,546.42 5,943,930.88 536,401.90 2.97 788.66 MWD(3) 9,255.63 85.08 153.35 5,994.10 5,86410 -4,687.15 -3,53408 5,943,905.56 536,414.37 5.19 815.34 MWD(3) 9,280.41 85.55 151.54 5,996.13 5,866.13 -4,709.04 -3,52266 5,943,883.73 536,425.91 7.52 838.90 MWD(3) 9,310.29 86.04 150.58 5,998.32 5,868.32 -4,735.12 -3,508.24 5,943,857.73 536,440.47 3.60 867.54 MWD(3) 9,340.74 87.02 149.86 6,000.16 5,870.16 -4,761.50 -3,493.14 5,943,831.44 536,455.70 3.99 896.86 MWD(3) ) 9,370.54 88.10 148.93 6,001.43 5,871.43 -4,787.13 -3,477.99 5,943,805.90 536,470.99 4.78 925.70 MWD(3) Y 9,400.55 88.93 148.13 6,002.21 5,87221 -4,812.71 -3,46233 5,943,780.39 536,486.79 384 954.87 MWD(3) 9,430.38 89.17 147.62 6,002.70 5,872.70 4,837.97 3,446.47 5,943,755.22 536,502.78 1.89 983.94 MWD(3) 9,460.86 89.85 146.24 6,002.96 5,872.96 -4,863.51 -3,429.83 5,943,729.77 536,519.55 5.05 1,013.76 MWD(3) 9,490.75 90.15 144.05 6,002.96 5,872.96 -0,888.04 -3,412.75 5,943,705.34 536,536.76 7.40 1,043.18 MWD(3) is 9,520.45 89.08 142.30 6,003.16 5,873.16 -4,911.81 -3,394.95 5,943,681.66 536,554.68 6.91 1,072.58 MWD(3) 1 9,550.53 89.39 140.66 6,003.56 5,873.56 -4,935.34 -3,376.22 5,943,658.23 536,573.53 5.55 1,102.46 MWD(3) tt d 9,580.67 89.94 140.06 6,003.74 5,873.74 -4,958.55 3,356.99 5,943,635.13 536,592.88 2.70 1,132.47 MWD(3) E E 9,610.44 89.20 138.32 6,003.96 5,873.96 -4,981.08 3,337.54 5,943,61271 536,612.45 6.35 1,162.16 MWD(3) 9,640.39 88.59 137.84 6,004.54 5,874.54 -5,003.36 3,317.53 5,943,590.53 536,632.58 2.59 1,192.06 MWD(3) Jj 9,670.57 87.91 136.58 6,005.46 5,875.46 -5,025.50 -3,297.04 5,943,568.51 536,653.18 4.74 1,222.20 MWD(3) 9,700.39 86.59 134.39 6,006.89 5,876.89 -5,046.74 -3,276.16 5,943,547.38 536,674.17 057 1,251.99 MWD(3) 9,730.34 85.67 132.89 6,008.91 5,878.91 -5,067.36 -3,25454 5,943,526.88 536,695.90 5.87 1,281.86 MWD(3) 9,760.65 85.48 131.62 6,011.25 5,88125 -5,087.68 -3,23217 5,943,506.68 536,718.38 4.22 1,31204 MWD(3) 9,790.28 85.51 130.66 6,013.58 5,883.58 -5,107.11 -3,209.93 5,943,487.37 536,740.72 3.23 1,341.51 MWD(3) 9,820.30 85.05 129.52 6,016.05 5,886.05 -5,126.38 -3,187.04 5,943,46822 536,763.71 4.08 1,371.32 MWD(3) 9,850.29 84.99 128.18 6,018.65 5,888.65 -5,145.12 -3,163.77 5,943,449.61 536,787.07 4.46 1,401.03 MWD(3) 's gR3 9,880.21 84.71 127.17 6,021.34 5,891.34 5,163.33 -3,140.19 5,943,431.52 536,810.75 3.49 1,430.58 MWD(3) S 9,910.24 84.50 125.67 6,024.16 5,894.16 -5,181.08 -3,116.13 5,943,413.90 536,834.90 5.02 1,460.14 MWD(3) 1 9,935.22 84.53 123.99 6,026.55 5,896.55 -5,195.28 -3,095.72 5,943,399.81 536,855.39 6.70 1,484.62 MWD(3) 9,965.17 85.20 122.35 6,029.23 5,899.23 -5,211.60 -3,070.75 5,943,383.63 536,880.44 5.89 1,513.81 MWD(3) € € 9,99522 85.33 120.40 6,03171 5,90171 -5,227.19 -3,045.18 5,943,368.17 536906.08 648 1,54291 MWD(3) ,.......,..�..». ,,.....,.,.,. .«..-,.......,...,...,.«,,..._... ......,,.,�,...»,..,,.»»,. ItfAif!"111'S 3:119..5121,41 `1greS 021 AS.9 .1 Sulk:1:74 • • ConocoPhillips Definitive SurveyBAKER Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-17 II Project: Kuparuk River Unit TVD Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad MD Reference: 1L-17 @ 130.00usft(1L-17) Well: 1L-17 North Reference: True Wellbore: 1L 17A Survey Calculation Method: Minimum Curvature Design. iL 17A Database: EDM Alaska NSK Sandbox Survey ,. ''''''-1 MD Inc'. Art TUU ?VMS +N)S +E1-W Map Map DLS i Vertical ,. _ #. Northing seating Section Surrey T�;Nams 1otatioD I (usrl) (°!': t°i�'.. tow) "to .., (usft) (usft) i„1100,),; ',.. ..,.,,,,, 10,025.35 85.36 11910 6,034.16 5,904.16 -5,242.09 -3,019.11 5,943,353 41 536,932 23 4.30 157189 MWD(3) 10,055.30 8490 117.29 6,036.70 5,906.70 -5,256.19 -2992.81 5,943,339.45 536,958.60 6.21 1,600.45 MWD(3) 10,085.24 8474 115.49 6,039.40 5,90940 -5,269.45 -2,966.10 5,943,326.34 536,985.38 6.01 1,628.71 MWD(3) 10,115.37 83.91 113.90 6,042.38 5,912.36 5,281.97 -2,938.86 5,943,313.96 537,012.68 5.93 1,656.83 MWD(3) I 10,145.20 8273 11276 6,045.85 5,915.85 -5,293.71 -2,911.66 5,943,30238 537,039.95 5.48 1,684.36 MWD(3) 10,180.21 8280 11262 6,050.26 5,92026 -5,307.10 -2,879.62 5,943,289.15 537,072.06 0.44 1,716.49 MWD(3) 10,210.28 84.03 11268 6,053.71 5,923.71 -5,318.61 -2,852.05 5,943,277.79 537,099.68 410 1,74412 MWD(3) :? 10,240.22 85.88 11328 6,056.34 5,926 34 -5,330.25 -2,824.59 5,943,266.30 537,127.20 6.49 1,771.77 MWD(3) ":F 10,270.33 87.02 113.68 6,058.21 5,928.21 -5,342.22 -2,797.03 5,943,254.47 537,154.82 401 1,799.72 MWD(3) ( 10,300.34 88.37 11439 6,059.41 5,929.41 -5,354.44 -2769.64 5,943,242.41 537,182.27 5.08 1,827.72 MWD(3) e 10,330.27 89.66 115.30 6,059.93 5,929.93 -5,367.01 -2,742.49 5,941229.98 537,209.49 5.27 1,855.82 MWD(3) 2 10,360.38 88.96 116.66 6,060.29 5,930.29 -5,380.20 -2,715.42 5,943,216.93 537,236.62 5.08 1,884.28 MWD(3) I 10,390.25 88.62 118.23 6,060.92 5,930.92 -5,393.96 -2,688.92 5,943,203.31 537,263.19 5.38 1,912.75 MWD(3) 10,420.33 89.51 119.08 6,061.41 5,93141 -5,408.38 -2,662.53 5,943,189.03 537,289.65 409 1,941.61 MWD(3) Y 10,450.33 90.37 119.52 6,061.44 5,93144 -5,423.06 -2636.37 5,943,174.49 537,315.89 3.22 1,970.49 MWD(3) iE 10,480.26 91.38 119.68 6,060.99 5,930.99 -5,437.85 -2610.35 5,943,159.85 537,341.99 3.42 1,999.34 MWD(3) P 10,510.38 92.15 119.75 6,060.06 5,930.06 -5,452.77 -2584.20 5,943,145.07 537,368.21 257 2,028.38 MWD(3) 10,540.18 93.38 119.82 6,058.62 5,928.62 -5,467.56 -2558.37 5,943,130.42 537,394.12 413 2,057.10 MWD(3) 2 10,570.29 95.14 120.36 6,056.39 5,926.39 5,482.61 -2,532.39 5,943,115.51 537,420.17 6.11 2,086.12 MWD(3) 10,600.29 95.75 120.34 6,053.54 5,923.54 -5,497.70 -2,506.62 5,943,100.55 537,446.02 2.03 2,115.01 MWD(3) 10,630.25 97.33 121.08 6,050.13 5,920.13 -5,512.90 -2,481.03 5,943,085.49 537,471.69 5.82 2143 86 MWD(3) f 10,660.35 98.82 121.31 6,045.90 5,915.90 -5,528.33 -2,455.54 5,943,070.19 537,497.26 5.01 2,172.80 MWD(3) 10,690.26 98.94 123.30 6041.28 5,911.28 -5,544.13 -2,430.56 5,943,054.54 537,522.32 6.59 2,201.62 MWD(3) 1 10,720.64 98.45 125.16 6036.69 5,906.69 -5,561.02 -2,405.73 5,943,037.78 537,547.23 6.26 2,231.12 MWD(3) & 10,750.31 98.10 126.91 6032.42 5,902.42 -5,578.29 -2381.99 5,943,020.63 537,571.06 5.95 2,260.13 MWD(3) 1 10,780.41 98.26 129.37 6,028.13 5,898.13 -5,596.69 -2,358.56 5,943,002.36 537,594.59 8.11 2,289.70 MWD(3) fg 10,810.13 98.14 131.07 6,023.90 5,893.90 -5,615.68 -2,336.10 5,942,983.49 537,617.15 5.66 2,319.02 MWD(3) 7 H ! 10,840.40 96.25 131.40 6020.10 5,890.10 -5,635.48 -2,313.52 5,942,963.81 537,639.83 6.34 2,348.98 MWD(3) j 10,870.17 9473 13283 6,017.26 5,887.26 -5,655.35 -2291.54 5,942,944.06 537,661.92 7.00 2,378.58 MWD(3) 19900.16 94.73 134.77 6,014.78 5,884.78 -5,676.04 -2,269.96 5,942,923.49 537,683.60 6.45 2408.46 MWD(3) 10,930 33 9467 136.22 6,01231 5,88231 31 5 697 48 -2248 89 a942,902.16 537704 78 4 79 2,438.52 MWD(3) 9F412(016 2'b3.-5OPnr Pege 4 OrDitritieSS 5000.18utd74 • • COnt)COPhillips ConocoPhillips ;' - ,u Survey Replan BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Coordinate Reference: Well 1 L-17 Project: Kuparuk River Unit TVD Reference: 1L-1 7 @ 130.00usft(1 L-17) Site: Kuparuk 1 L Pad MD Reference: 1 L-17(fg 130.00usft(1 L-17) Well: 1 L-17 North Reference: True Wellbore: 1L-17A Survey Calculation Method: Minimum Curvature Design: 1L-17A Database: EDM Alaska NSK Sandbox Survey trtioal MD Inc Azj') ND NDSS ("ft) +uft) N rthing East ng DLS survey Tool Name A(ltlotatlon (ustt) (°I t°1; (usft) {usft) (ua}C) (ustt} i77( {ft} {°1794'} n • 10,960.21 93.35 137.40 6,010.22 5,88022 -5,719.21 -2,228.49 5,942,880.54 537,725 30 5.92 2,468.31 MWD(3) 10,990.30 91.38 139.18 6,008.98 5,878.98 -5,741.65 -2,208.49 5,942,858.21 537,745.41 8.82 2,498,32 MWD(3) 11,020.30 90.86 141.55 6,008.39 5,878.39 -5,764.75 -2,189.36 5,942,835.22 537,764.67 8.09 2,528.19 MWD(3) 11,050.56 90.43 139.90 6,008.05 5,878.05 -5,788.17 -2170.20 5,942,811.90 537,783.94 5.63 2,558.29 MWD(3) 11,080.19 90.18 138.36 6,007.89 5,877.89 -5,810.58 -2,150.81 5,942,789.60 537,803.45 5.27 2,58784 MWD(3) 11,110.27 89.48 13635 6,007.98 5,877.98 -5,832.70 -2,130.44 5,942,767.58 537,823.94 7.08 2,617.90 MWD(3) 11,140.63 89.51 134.79 6,008.25 5,878.25 -5,854.38 -2,109.19 5,942,746.02 537,845.30 5.14 2,648.25 MWD(3) 11,170.19 88.80 13272 6,008.69 5,878.69 -5,874.82 -2,087.84 5,942725.70 537,866.76 7.40 2,677.80 MWD(3) t, 11,199.93 88.25 131.01 6,009.45 5,879.45 -5,894.66 -2,065.70 5,942,705.98 537,889.00 6.04 2,707.48 MWD(3) 11330.26 88.53 128.86 6,010.30 5,880.30 5,914.12 -2,042.45 5,942,686.64 537,912.34 7.15 2,737.68 MWD(3) 11260.66 89.82 127.95 6,010.74 5,880.74 -5,933.00 -2,018.63 5,942,667.89 537,93626 5.19 2,767.88 MWD(3) 11,290.63 90.34 126.88 6,010.70 5,880.70 -5,951.21 -1,994.83 5,942,649.81 537,960.16 3.97 2,797.58 MWD(3) 11,320.04 90.21 124.42 6,010.56 5,880.56 -5,968.35 -1,970.93 5,942,63279 537,984.14 8.38 2,826.60 MWD(3) 11,350.01 91.63 122.91 6,010.08 5,880.08 -5,984.96 -1,945.99 5,942,616.32 538,009.17 6.92 2,855.98 MWD(3) 11,380.08 91.26 120.87 6,009.32 5,879.32 -6,000.84 -1,920.47 5,942,600.58 538,034.77 6.89 2,885.26 MWD(3) 11,410.32 91.60 118.95 6,008.57 5,878.57 -6,015.92 -1,894.27 5,942,585 64 538,061.05 6.45 2,914.44 MWD(3) 11,440.03 9243 120.97 6,007.52 5,877.52 -6,030.74 -1,868.55 5,942,57a 95 538,086.85 7.35 2,943.12 MWD(3) 11,470.03 91.54 123.60 6,006.48 5,876.48 -6,04676 -1,843.20 5,942,555.08 538,11228 9.25 2,972.36 MWD(3) 11,500.00 90.95 125.76 6,005.83 5,875.83 -6,063.80 -1,818.56 5,942,538.16 538,137.00 7.47 3,001.84 MWD(3) 11,530.05 91.20 127.71 6,005.27 5,87527 -6,081.77 -1,794.49 5,942,520.32 538,161.17 6.54 3,031.57 MWD(3) 11,560.09 9203 129.70 6,004.42 5,874.42 -6,100.55 -1,771.06 5,942,501.67 538,184.70 7.18 3,061,41 MWD(3) 11,590.18 93.25 132.34 6,003.03 5,873.03 -6,120.27 -1,748.38 5,942,482.07 538,207.48 9.66 3,091 40 MWD(3) 3 11,620.06 9335 134.58 6,001.31 5,871.31 -6,140.79 -1,726.73 5,942,461.67 538,229.24 7.49 3,121.21 MWD(3) H 11,649,87 92.58 136.60 5,999.77 5,869.77 -6,162.06 -1,705.90 5,942,440.52 538,250.18 724 3,150.98 MWD(3) 11,680.18 92.03 138.80 5,998.55 5,868.55 -6,184.45 -1,685.52 5,942,418.23 538,270.67 7.48 3,181.23 MWD(3) 11,710.45 92.33 140.67 5,997.40 5,867.40 -6,207.53 -1,665.97 5,942,395.26 538,290.34 625 3,211 37 MWD(3) 11,740.34 92.21 142.93 5,996.22 5,866.22 -6,231.00 -1,647.50 5,942,371.89 538,308.94 7.57 3,241.03 MWD(3) 11,770.49 92.43 145.28 5,995.00 5,865.00 -6,255.41 -1,629.84 5,942,347.58 538,326.72 7.82 3,270.77 MWD(3) 11,800.51 93.01 148.21 5,993.57 5,863,57 -6,280.48 -1,613.40 5,942,322.60 538,343.30 9.94 3,300.13 MWD(3) 11,830.51 93.50 151.27 5,991.87 5,861.87 -6,306.35 -1,598.30 5,942,296.81 538,358.52 10.31 3,329.09 MWD(3) 1186037 9319 149.81 5,990.12 5,860.12 -633230 -1,583.64 594227094 538,373.32 499 3357.81 MWD(3) dab-2.tf8.UctiM Pvtge3 COMPASS 5000.9 8aitd;,4 III • ConocoPhillips : - - BAKER conocaphatips f1re +f3 -'" HUGHES Company: ConocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 1L-17 Project: Kuparuk River Unit ND Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad MD Reference: 1L-17 @ 130.00usft(1L-17) Well: 1L-17 North Reference: True Wellbore: 1L-17A Survey Calculation Method: Minimum Curvature Design: 1L-17A Database; EDM Alaska NSK Sandbox Survey Map Map Vertical ',, MD Inc Azi ND NDSS +NI-S +EI-W NorthingEastin DLS Section , 9 Survey Tool Name (usft) (°) (°.).. (usft) (usft) (usft) (usft) (ft) (ft) f°110ff) (ft) Annotation 11,89017 92.27 147.20 5,988.70 5,858.70 -6,357.68 -1,568.09 5,942,245.65 538389.00 9.28 3,38675 MWD(3) 1 11,920.10 91.78 145.48 5,987.65 5,857.65 -6,382.57 -1,551.52 5,942,220.84 538,405.71 5.97 3,416.07 MWD(3) 11,950.34 92.64 143.92 5,986.48 5,856.48 -6,407.24 -1,534.06 5,942,196.28 538,423.30 5.89 3,445.86 MWD(3) Y 11,980.20 92.83 141.46 5,985.06 5,855.06 -6,430.96 -1,515.98 5,942,172.66 538,441.50 8.25 3,475.41 MWD(3) 12,010.31 91.51 138.97 5,983.92 5,853.92 -6,454.07 -1,496.73 5,942,149.64 538,460.87 9.35 3,505.37 MWD(3) 12,040.31 90.77 137.40 5,983.32 5,853.32 -6,476.43 -1,476.73 5,942,127.40 538,480.99 5.78 3,535.32 MWD(3) 12,070.07 90.31 135.66 5,983.04 5,853.04 -6,498.02 -1,456.26 5,942,105 91 538,501.57 6.05 3,565.07 MWD(3) 12,10022 89.94 133.96 5,982.97 5,85297 -6,519.27 -1,43487 5,942,084.78 538,523.07 5.77 3,595.22 MWD(3) 12,130.11 90.58 132.71 5,982.84 5,852.84 -6,539.78 -1,413.13 5,942,064.39 538,544.92 4.70 3,625.09 MWD(3) 12,160.19 91.60 131.14 5,982.26 5,852.26 -6,559.88 -1,390.75 5,942,044.41 538,567.40 6.22 3,655.12 MWD(3) 12190.13 91.44 129.40 5,981.47 5,851.47 -6,579.22 -1,367.92 5,942,025.19 538,590.33 5.83 3,684.95 MWD(3) [g 12,220.27 90.00 128.05 5,981.09 5,851.09 -6,598.08 -1,344.41 5,942,006.46 538,613.94 6.55 3,714.90 MWD(3) 12,250.42 88.71 127.07 5,981.43 5,851.43 -6,616.45 -1,320.51 5,941,988.22 538,637.93 5.37 3,744.80 MWD(3) 12,280.50 88.68 125.78 5,982.12 5,852.12 -6,634.31 -1,296.31 5,941,970.49 538,662.22 4.29 3,774.53 MWD(3) I 12,310.47 88.53 123.82 5,982.85 5,852.85 -6,651.41 -1,271.71 5,941,953.52 538,686.91 6.56 3,804.02 MWD(3) 12 340.28 88.07 121.97 5,983.73 5,853.73 -6,667.59 -1,246.69,2 5,941,937.48 538,712.01 6.39 3,833.15 MWD 3 12,370.08 87.48 120.17 5,984.89 5,854.89 -6,682.96 -1,221.19 5,941,922.25 538,737.59 6.35 3,862.05 MWD(3) I 12,400.25 88.00 118.44 5,986.08 5,856.08 -6,697.71 -1,194.90 5,941,907.63 538,763.96 5.98 3,891.07 MWD(3) I 12,430.20 88.68 117.11 5,986.94 5,856.94 -6,711.66 -1,168.41 5,941,893.83 538,790.52 4.99 3,919.67 MWD(3) 1# 12,460.15 89.14 115.51 5,987.51 5,857.51 -6,724.93 -1,141.57 5,941,880.70 538,817.43 5.56 3,948.03 MWD(3) S 12,47211 89.17 115.13 5,987.69 5,857.69 -6,730.05 -1,130.76 5,941,875.64 538,828.26 3.19 3959.29 MWD(3) 12 50000 89.17 115.13 5,988.09 5,858 09 -6,741.89 -1,105.51 5,941,863.93 538,853.57 0.00 3985.52 PROJECTED to TD it~ft 4$12.11040 Paige* S-MPA SS 90000'!134146174 • . ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1 L-17APB1 50-029-22151-70 Baker Hughes 1NTEQ M r BAKER Definitive Survey Report HUGHES 07 September,2016 • • GPhilIips lit ConocoPhillips BAKER odfirlittve =" HU6HES Company: ConocoPh fillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-17 Project: Kuparuk River Unit TVD Reference: 1L-17 @ 130.O0usft(1L-17) Site: Kuparuk 1L Pad MD Reference: 1L-17 @ 130.00usft(1 L-17) ' Well: 1L-17 North Reference: True Wellbore: 1 L-17APB1 Survey Calculation Method: Minimum Curvature Design: 1 L-17APB1 Database: EDM Alaska NSK Sandbox f Project Kuparuk River Unit North Slope Alaska,United States zz Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level `£ E Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point 1 Map Zone: Alaska Zone 04 Using geodetic scale factor _ ,.,mom-.,,. ............... ,,.,,,,.�...,_ _ «m..,�..< ... ..�. Welt.' 1L•17 'Well Position 4-WS 000usft Northing: 5,948,610.93 usft Latitude: 70°16'13.945 N F +E/-W 000 usft Easting: 539,923.20 usft Longitude: 149°40'37.668 W }Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft ellf bores 1L-17APB7 1 Magnetise Model Name ,, Sample Date Detittgatt011 Dip Angie Field Strength BGGM2015 7/1/2016 16.40 80.93 57.492 �.,.... ,,,, ,,,,,°,.,,,,,,gym. ,,.. ,„., „„ _. r .«..,.., ..,°.,_...,,.,___. ,,., ,„„„„»,, Design 1L-17APB1 -� Audit Notes: Version: 1 0 Phase: ACTUAL Tie On Depth: 8,100.00 t Vertical Section: Depth From(TVD) -1-N/-S +EI-W Direction (usft) (usft) (usft) L130 00 0 00 0.00 135 00 S Survey Program Date 917/2018 ,.. s Ir 3, From To (usft) (usft) Survey(Wellbore) 4,t4Tool Name Description Start Date 200.00 8,100.00 1L-17(1L 17) GCT-MS Schlumberger GCT multishot 1/8/2001 8,194.00 10,677.13 1L-17APB1(1L 17APB1) MWD MWD-Standard 7/28/2016 8/3/2016 9f,2df6,k•Sit47oPltt 'Page 2 02/1tfPVISS SOttO.':1:Build 74 • • ConotoPhivips MEIN ConocoPhillips Da&Ake Su4vey Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 LocalCo-ordinate Reference: Well 1L-17 �m Project: Kuparuk River Unit IVO Reference: 1L-17 @ 130.O0usft(1 L-17) Site: Kuparuk 1 L Pad MD Reference: 1 L-17 @ 130.00usft(1 L-17) Well: 1 L-17 North Reference: True Wellbore: 1L-17APB1 Survey Calculation Method: Minimum Curvature Design: 1 L-17APB1 Database: EDM Alaska NSK Sandbox t Survey .,,, Map Map Vertical 1, MD Inc Azi TVD TVDSS +NIS t•EI-W NorthingEastingOLS Section Survey Tool Name Annotation (usft) (1 (1 (usft) (usft) )usft) (usft) (ft) (ft) rii"') (ft) 1 8,100.00 47.46 223.87 5,913 62 5,78362 -3,660.80 -3,670.73 5,944,931 07 536,272.30 0.48 -7.02 MWD(2) TIP 8,194.00 47.27 224.46 5,977.29 5,847.29 -3,710.41 -3,718.91 5,944,881.21 536,224.39 0.50 -6.01 MWD(2)- KOP : a' 8,215.50 53.40 223.90 5,991.01 5,861.01 -3,722.28 -3,730.43 5,944,869.29 536,212.93 26.58 -5.77 MWD(2) 8,245.21 67.16 222.60 6,005.70 5,875.70 -3,741.04 -3,748.05 5,944,850.43 536,195.41 46.47 -4.96 MWD(2) % 8,275.17 82.99 221.30 6,013.40 5,883.40 -3,762.51 -3,767.34 5,944,828.86 536,176.24 53.00 -3.41 MWD(2) 8,305.28 91.01 21109 6,014.97 5,884.97 -3,786.42 -3,785.48 5,944,804.85 536,158.23 38.07 0.67 MWD(2) ii 8,335.17 94.86 198.56 6,01143 5,883.43 3,813.21 -3,798.45 5,944,778.00 536,145.40 50.22 10.44 MWD(2) 8,365.59 97.70 183.35 6,010.09 5,880.09 -3,842.81 -3,804.19 5,944,748.38 536,139.82 50.56 27.31 MWD(2) g I, 8,390.37 94.98 170.16 6,007.34 5,877.34 -3,867.34 -3,802.79 5,944,723.86 536,141.35 54.02 45.64 MWD(2) BH % 8,410.16 92.73 161.59 6,006.01 5,876.01 -3,886.46 -3,797.97 5,944,704.76 536,146.27 44.67 62.57 MWD(2) 1 y 8,440.56 92.82 160.78 6,004.54 5,874.54 -3,915.21 -3,788.18 5,944,676.07 536,156.21 2.68 89.82 MWD(2) 8,470.33 93.84 160.24 6,002.81 5,87281 -3,943.22 -3,778.27 5,944,648.11 536,166.27 188 116.64 MWD(2) 8,500.39 92.64 159.40 6,001.11 5,871.11 -3,971.39 -3,767.91 5,944,620.00 536,176.77 4.87 143.88 MWD(2) a8,530.13 92.48 160.54 5,999.78 5,869.78 -3,999.30 -3,757.74 5,944,592.14 536,187.10 3.87 170.81 MWD(2) 8,560.49 92.36 163.37 5,998.50 5,868.50 -4,028.14 -3,748.34 5,944,563.36 536,196.64 9.32 197.85 MWD(2) 8,590.75 92.15 165.27 5,997.31 5,867.31 -4,057.25 3,740.17 5,944,534.30 536,204.97 6.31 224.21 MWD(2) 8,619.93 91.54 166.32 5,996.37 5,866.37 -4,085.53 -3,733.01 5,944,506.06 536,212.27 4.16 249.26 MWD(2) d 8,650.77 92.52 165.24 5,995.27 5,865.27 -4,115.40 -3,725.44 5,944,476.23 536,220.00 4.73 275.74 MWD(2) S 8,680.77 94.33 165.41 5,993.48 5,863.48 -4,144.37 -3,717.86 5,944,447.31 536,227.74 6.06 301.59 MWD(2) 8,710.37 92.55 165.30 5,991.71 5,861.71 -4,172.95 -3,710.39 5,944,418.76 536,235.36 6.02 327.08 MWD(2) % 8,74127 9264 164.33 5,990.31 5,860.31 -4,202.74 -3,702.30 5,944,389.02 536,243.61 3.15 353.87 MWD(2) 8,771.41 93.04 163.43 5,988.81 5,858.81 -4,231.66 -3,693.94 5,944,360.15 536,252.12 3.26 380.23 MWD(2) 8,800.63 94.76 165.50 5,986.83 5,856.83 -4,259.75 -3,686.14 5,944,332.11 536,260.07 9.20 405.61 MWD(2) aa 8,830.95 92.55 164.46 5,984.89 5,854.89 -4,288.97 -3,678.29 5,944,302.93 536,268.07 8.05 431.81 MWD(2) % 8,860.79 88.31 163.29 5,984.67 5,854.67 -4,317.63 -3,670.01 5,944,274.32 536,276.50 14.74 457.94 MWD(2) F, 8,890.86 90.43 166.07 5,985.00 5,855.00 -4,346.62 -3,662.07 5,944,245.37 536,284.60 11.63 484.06 MWD(2) 8,920.41 89.42 164.60 5,985.04 5,855.04 -4,375.21 -3,654.59 5,944,216.83 536,292.23 6.04 509.56 MWD 12) 8,950.53 88.49 163.46 5,985.59 5,855.59 -4,404.16 -3,646.30 5,944,187.92 536,300.67 4.88 535.89 MWD(2) 8,980.11 89.97 162.02 5985 98 5,855.98 -4 432.41 -3,637.52 5,944,159.73 536,309.59 6.98 562.07 MWD(2) L9,010.45 89 72 161.40 5,986.07 5 856.07 -4,461.21 j,..,::-„3_,628.00 5,944,130.98 536 319.27 2.20 589.17 MWD(2) tr/F17Bhb 1.459. Fflti Atte:9 C1246044SS 500171 Buie 14 • • conotoPhMwe ConocoPhillips ,; „ey Report Reams Company: ConocoPhillips(Alaska)Inc-Kup2 Local Co-ordinate Reference: Well 1L-17 Project: Kuparuk River Unit ND Reference: 11L-17 @ 130.00usft(1L-17) Site: `Kuparuk 1 L Pad MD Reference: '.1L-17(41 130.00usft(1L-17) Well: 1L-17 North Reference: True Wellbore: 1L-17APB1 Survey Calculation Method: Minimum Curvature t Design: 1L-17APB1 Database: EDM Alaska NSK Sandbox Survey .. ..... .............�.-� ,.,,..,�.�.„ Map Map Vertical MD Inc Azi ND TVDSS +N/-S *68-WDLS ; (°) Own)) (usft'. usff Northing Fasting Section Survey Tool Name Annotation (obft) {°) ( ) Nsft) (ft) (ft) (°7100') ) 9,035.83 89.85 160.29 5,986.16 5,856 16 -4,485.19 -3,619.68 5,944,107 05 536,327.72 440 61201 MWD(2) 9,064.83 90.74 160.41 5,986.01 5,856.01 -4,512.50 -3,609.92 5,944,079.79 536,337 62 310 638.22 MWD(2) `y 9,095.91 89.82 158.97 5,985.86 5,855.86 -4,541.64 -3,599.14 5,944,050.71 536,348.56 5.50 666.45 MWD(2) 9,125.46 88.07 157.52 5,986.41 5,856.41 -4,569.08 -3,588.19 5,944,023.33 536,359.65 7.69 69360 MWD(2) 9,155.65 88.99 155.79 5,987.18 5,857.18 -4,596.79 3,576.23 5,943,995.69 536,371.75 6.49 721.65 MWD(2) 8 9,185.91 89.23 15423 5,987.65 5,857.65 -4,62421 -3,563.45 5,943,968.34 536,384.68 5.22 750.08 MWD(2) y 9,215.15 89.91 153.31 5,987.87 5,857.87 -0,650.44 -3,550.52 5,943,942.18 536,397.74 3.91 777.76 MWD(2) i 9,245.39 90.21 151.75 5,987.84 5,857.84 -0,677.27 -3,536.57 5,943,915.43 536,411.83 5.25 806.59 MWD(2) I 9,275.45 89.75 149.95 5,987.85 5,857.85 -4,70352 -3,521.93 5,943,889.26 536,426.61 a18 835.51 MWD(2) 9,305.47 87.88 146.84 5,988.47 5,858.47 -4,729.08 -3,506.21 5,943,863.78 536,442.47 1209 864.70 MWD(2) I 5 9,335.41 87.58 14457 5,989.65 5,859.65 -4,753.79 3,489.35 5,943,839.16 536,459.45 7.64 894.10 MWD(2) -1 $ 9,365.31 88.31 14357 5,990.73 5,860.73 -4,777.99 -3,471.82 5,943,815.06 536,477.11 414 923.60 MWD(2) I 9,395.29 88.68 141.42 5,991.51 5,861.51 -4,801.76 -3,45357 5,943,791.39 536,495.48 727 953.31 MWD(2) 9,425.30 89.42 139.98 5,99201 5,862.01 -4,824.98 -3,43457 5,943,768.27 536,514.61 5.39 983.17 MWD(2) 9,455.28 89.66 139.26 5,99225 5,862.25 -4,847.82 -3,415.15 5,943,745.54 536,534.15 2.53 1,013.05 MWD(2) 9,485.28 87.45 137.45 5,993.01 5,863.01 -4,870.23 3,395.22 5,943,723.24 536,554.19 9.52 1,042.99 MWD(2) 9,515.59 85.21 136.51 5,994.95 5,864.95 4,892.34 -3,37458 5,943,701.24 536,574.94 8.01 1,073.22 MWD(2) 9,545.51 84.62 135.06 5,997.60 5,867.60 -4,913.70 -3,353.80 5,943,679.99 536,595.84 5.21 1,103.01 MWD(2) 9,575.29 82.86 133.32 6,000.85 5,870.85 4,934.33 -3,332.58 5,943,659.47 536,617.17 8.29 1,132.61 MWD(2) 9,605.27 83.60 131.55 6,004.38 5,874.38 -4,954.42 -3,310.61 5,943,639.51 536,639.24 6.36 1,162.35 MWD(2) 9,635.47 84.40 130.08 6,007.54 5,877.54 -4,974.05 -3,287.88 5,943,620.00 536,662.07 5.52 1,192.30 MWD(2) 9,665.16 85.14 127.69 6,010.25 5,880.25 -4,992.61 -3,26486 5,943,601,56 536,685.18 8.39 1,221,70 MWD(2) 9,695.57 84.90 126.59 6,012.89 5,882.89 5,010.90 3,240.71 5,943,583.40 536,709.43 3.69 1,251.71 MWD(2) 9,725.77 84.56 124.52 6,015.66 5,885.66 5,028.39 -3,216.25 5,943,566.05 536,733.98 6.92 1,281.37 MWD(2) 9,755.62 83.45 123.47 6,018.78 5,888.78 5,044.98 -3,191.64 5,943,549.58 536,758.68 5.11 1,310.51 MWD(2) 9,785.64 81.69 122.28 6,022.66 5,892.66 -5,061 14 -3,166.64 5,943,533.56 536,783.76 7.06 1,339.62 MWD(2) I 9,810.69 80.41 121.09 6,026.56 5,896.56 -5,07414 -3,145.58 5,943,520.68 536,804.88 6.94 1,363.69 MWD(2) 6.07 1,387 9,835.33 79.41 119.96 6,030.87 5,900.87 5,086.46 -3,124.69 5,943,508.47 536,825.84 .18 MWD(2) 9,875.59 78.91 118.64 6,038.45 5,908.45 -5,105.81 -3,090.21 5,943,489.30 536,860.42 3.45 1,425.25 MWD(2) B 9,905.69 80.17 118.41 6,04391 5,913.91 -5,119.95 -3,06420 5,943,475.31 536,886.50 4.25 , 1,453.63 MWD(2) [ 9,935.72 81.56 118.45 6,048.68 5,918.68 -5,13406 -3,038.13 5,943,461.33 536,912.65 4.63 1,48205 MWD(2) 16846 11:*$.7104Ik7 `fie 41 COMFXSS Wr011ibeigd i4 • • ConocoPhillips Definitore Survey Report MUGHES Company: ConocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 1L-17 Project Kuparuk River Unit TVD Reference: 1 L-17 @ 130.00usft(1L-17) Site: Kuparuk'IL Pad MD Reference: 1 L-17 @ 1 30.00usft(1 L-17) Well: 1L-17 North Reference: True Wellbore: 1L-17APB1 Survey.Calculation Method: Minimum Curvature Design: 1 L-17APB1 Database: EDM Alaska NSK Sandbox Survey Map Map DLS Vertical MD Inc Azi TVD TVDSS +NI-S +50W (usftj (0) (^) (usft (usft) Northing Fasting Section Survey Tool Name Annotation j {usft) {Usf!) (ft) (ft) (*now) (ft) 1 9,965 57 82 37 118 26 s 9,995.69 83.64 11875 5295 5,922.85 -5,148.10 -3,01212 5,943,447.43 536,938.73 279 1,510.37 MWD(21 6,056.52 5,926.52 -5,162.37 -2,985.85 5,943,433.31 536,965.07 4.52 1,539.03 MWD(2) ) 10,025.58 85.57 118.80 6,059.33 5,929.33 -5,176.69 -2959.76 5,943,419.12 536,991.23 6.46 1,567.60 MWD(2) I 10,055.57 87.18 118.17 6,061.23 5,931.23 -5,190.96 -2,933.46 5,943,404.99 537,017.60 5.76 1,596.30 MWD(2) t 10,100.63 88.71 119.41 6,062.84 5,932.84 -5,212.65 -2,893.99 5,943,383.52 537,057.18 4.37 1,639.54 MWD(2) 10,130.61 90.34 119.89 6,063.09 5,933.09 -5,227.48 -2,867.94 5,943,368.83 537,083.31 5.67 1,668.45 MWD(2) 10,169.01 92.36 119.83 6,062.18 5,932.18 -5,246.59 -2,834.65 5,943,349.89 537,116.70 5.26 1,705.50 MWD(2) 10,207.02 96.18 120.35 6,059.36 5,929.36 -5,265.59 -2,801.86 5,943,331.07 537,149.58 10.14 1,742.12 MWD(2) 10,235.58 97.54 120.55 6,055.94 5,925.94 -5,279.96 -2,777.42 5,943,316.83 537,174.10 4.81 1,769.57 MWD(2) 10,266.11 97.44 122.55 6,051.96 5,921.96 -5,295.80 -2,751.62 5,943,301.13 537,199.97 6.50 1,799.00 MWD(2) 10,296.01 97.01 124.64 6,048.20 5,918.20 -5,312.21 -2,726.92 5,943,284.85 537,224.77 7.08 1,828.08 MWD(2) 10,325.94 94.58 125.96 6,045.18 5,915.18 -5,329.42 -2,702.62 5,943,267.78 537,249.15 9.23 1,857.43 MWD(2) 10,355.41 90.18 124.26 6,043.96 5,913.96 -5,346.35 -2678.54 5,943,250.98 537,273.32 16.00 1,886.43 MWD(2) 10,385.37 91.32 124.65 6,043.57 5,913.57 -5,363.30 -2,653.83 5,943,234.16 537,298.11 4.02 1,915.88 MWD(2) 10,415.41 93.44 125.33 6,042.32 5,912.32 -5,380.51 -2,629.25 5,943,217.08 537,322.79 7.41 1,945.43 MWD(2) 10,445.12 94.70 125.48 6,040.21 5,910.21 -5,397.67 -2,605.09 5,943,200.04 537,347.03 4.27 1,974.65 MWD(2) 01 10,475.49 96.30 123.93 6,037.30 5,907.30 -5,414.88 -2,580.24 5,943,182.97 537,371.97 7.32 2,004.39 MWD(2) I 10,505.89 96.58 122.91 6,033.89 5,903.89 -5,431.52 -2,555.03 5,943,166.47 537,397.27 3.46 2,033.99 MWD(2) 10,535.73 98.31 122.24 6,030.02 5,900 02 -5,447.45 -2,530.10 5,943,150.67 537,422.28 6.21 2,062.88 MWD(2) 10,565.63 98.87 122.09 6,025.56 5,895.56 -5,463.19 -2,505.07 5,943,135.07 537,447.39 1.94 2,091.71 MWD(2) 10,595.55 100.43 122.69 6,020.54 5,890.54 -5,478.99 -2,480.16 5,943,119.40 537,472.38 5.58 2,120.49 MWD(2) 10,625.57 102.55 123.00 6,014.56 5,884.56 -5,494.95 -2,455.45 5,943,103.58 537,497.17 7.13 2149.25 MWD(2) 10,655.55 103.92 123.37 6,007.70 5,877.70 -5,510.92 -2,431.03 5,943,087.74 537,521.68 4.72 2177.81 MWD(2) 10,677.13 105.63 123.49 6,002.19 5,872.19 -5,522.41 -2,413.61 5,943,076.33 537,539.15 7.94 2,198.26 MWD(2) -E 10,705.00 105.63 123.49 5,994.69 5,864.69 -5,537.22 -2,391.23 5,943,061.65 537,561.61 0.00 2,224.55 PROJECTED to TD % Li § >,.�.......... ......,,... ..,,..,....Po-,r..o.. ,... ....m. .m AmA.....m..a. ..,.m.............. .......,.,,,..A, ..,....,,, ......m.»�..>.�.. '11::5940RAf 1ftsla 5 :CCalte SS 8000.:1 Bade 74 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1 L-17APB2 50-029-22151-71 Baker Hughes INTEO HIM BAKER Definitive Survey Report HUGHES 07 September,2016 • • C4:)/locoPhffips as ConocoPhillips ;,, Survey ReportRHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-17 Project: Kuparuk River Unit IVO Reference: 1L-17 @ 130.00ustt(1 L-17) Site: Kuparuk 1L Pad MD Reference: 1 L-17 @ 130.00usft(1 L-17) Well: IL-17 North Reference: True Wellbore: 1L-17APB2 Survey Calculation Method: Minimum Curvature Design: 1L-17APB2 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 Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1L-17 Well Position .NIS 0.00 usft Northing: 5,948,610 93 usft Latitude: 70°16'13.945 N +E/-W 0.00 usft Easting: 539,923.20usft Longitude: 149°40'37.666 W S Position Uncertainty 0 00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore. 1L-17APB2 .1M ti _ .. T(IOdel Name'. ;, Sample Date': Declination Dip Angle Fier St:(ength (°) trtT) i BGGM2015 7/1/2016 18.40 80.93 57,492 Design 1L-17APB2 'Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9215.15 €Vertical Section: Depth From(TVD), ; *#,,ite,..:„ •EJ-W Direction LY21(611,x i `O 130.00 0.00 0.00 135.00 Survey Program Date 9/7/2016 From 7aSurvey tey (alit) -- (Us1t) Surrey re) Tool Name Description-i SUott Dot* Endue 200.00 8,100 00 1L-17(1L-17) GCT-MS Schlumberger GCT multishot 1/8/2001 8,194.00 9,215.15 1L-17APB1(1L-17APB1) MWD MWD-Standard 7/28/2016 8/3/2016 9,222.00 10,590.60 1L-17APB2(1L-17APB2) MWD MWD-Standard 8/4/2016 8/8/2016 tr/7720119 3e2. +Page2 COMPASS 5000'I aiarid.74 • • ConocoPhillips ..,,_e Bert BIL Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1 L-17 Project: Kuparuk River Unit TVD Reference: 1 L-17 @ 130.00usft(1L-17) Site: Kuparuk 1 L Pad MD Reference: 1 L-17 @ 130.00usfl(1 L-17) Well: 1 L-17 North Reference: True ',i''( Wellbore: 1L-17APB2 Survey Calculation.Method: Minimum Curvature Design: 1 L-17APB2 Database: EDM Alaska NSK Sandbox e Survey _. _.. __ • -11" MD Inc Pali TVD. TVDSS +N/-S +E/-W NMlh ng Fasting D7 8 fort (usft) r) r) ' tuaft (um) (usft) (usft) ) .Maw-( 'r fttl Survey ToolNattre Annotation 9715.15 89.91 153.31 5,987.87 5,857.87 -4,65044 -3,550.52 5,943,942.18 536,397.74 3.91 777.76 MWD(21 TIP 9,222.00 89.98 15296 5,987.88 5,857.88 -4,656.55 -3,547.43 5,943,936.09 536,400.87 5.21 78427 MWD(3) KOP Y 9,260.67 9212 154.71 5,987.17 5,857.17 -4,691.25 -3,53038 5,943,901.48 536,418.10 7.15 820.86 MWD(3) 9,290.78 9409 15485 5,985.54 5,855.54 -4,71845 -3,517.57 5,943,874.35 536,431.05 656 849.15 MWD(3) 9,320.72 92.15 15443 5,983.91 5,853.91 -4,74546 -3,50477 5,943,847.41 536,444.00 6.63 877.30 MWD(3) 1 9,350.70 9028 15299 5,983.27 5,853.27 -4,77233 -3,491.49 5,943,820.61 536,457.41 7.87 90569 MWD(3) 9,380.72 89.02 151.70 5,983.45 5,853.45 -4,798.92 -3,477.56 5,943,794.10 536,471.49 601 934.35 MWD(3) y 9,410.63 88.22 149.55 5,984.17 5,854.17 -4,82498 -3,46289 5,943,768.13 536,486.29 7.67 963.14 MWD(3) 9,440.63 88.16 146.70 5,985.12 5,855.12 -4,85044 -3,447.06 5,943,742.75 536,502.25 9.50 992.34 MWD(3) ( 9,47058 88.04 144.76 5,986.12 5,856.12 -4,875.17 -3,430.21 5,943,718.11 536,519.24 6.49 1,021.75 MWD(3) 9,50084 88.03 142.01 5,987.15 5,857.15 -4,899.45 -3,412.17 5,943,693.94 536,537.40 9.08 1,051.66 MWD(3) 9,530.90 88.59 140.06 5,988.04 5,858.04 -4,922.81 -3,393.28 5,943,670.68 536,556.42 6.75 1,081.54 MWD(3) 9,561.58 88.19 137.60 5,988.90 5,858.90 -4,945.89 -3,373.09 5,943,647.70 536,576.72 8.12 1,112.14 MWD(3) 9,590.94 86.96 135.27 5,99014 5,860.14 -4,967.14 -3,352.87 5,943,626.56 536,597.05 8.97 1,141.46 MWD(3) 9,610.73 86.41 134.26 5,991.29 5,861.29 -4,981.06 -3,338.85 5,943,612.72 536,611.15 5.80 1,161.22 MWD(3) 9,640.74 86.07 132.36 5,993.26 5,863.26 5,001.60 -3,317.06 5,943,592.30 536,633.04 6.42 1,191.15 MWD(3) 9,671.01 85.11 129.86 5,995.59 5,865.59 -5,021.44 -3,294.32 5,943,572.58 536,655.88 8.82 1,221.26 MWD(3) 1 9,700.13 84.34 127.93 5,998.26 5,868.26 5,039.64 -3,271.76 5,943,554.50 536,678.54 7.11 1,250.09 MWD(3) 9,731.26 84.49 126.82 6,001.29 5,871.29 -5,058.45 -3,247.13 5,943,535.82 536,703.26 3.58 1,280.79 MWD(3) 9,760.64 84.46 128.95 6,004.12 5,874.12 -5,076.41 -3,224.06 5,943,517.99 536,726.43 7.22 1,309.81 MWD(3) 9,790.77 8490 131.25 6,006.92 5,876.92 -5,095.73 -3,201.11 5,943,498.79 536,749.48 7.74 1,339.70 MWD(3) 9,820.68 84.34 133.68 6,009.72 5,879.72 -5,115.83 -3,179.14 5,943,478.81 536,771.55 8.30 1,369.45 MWD(3) 9,850.46 85.11 135.59 6,012.46 5,882.46 5,136.67 -3,158.04 5,943,458.09 536,792.76 6.89 1,399.10 MWD(3) 1 9,880.58 85.95 136.13 6,014.81 5,884.81 -5,158.22 -3,137.13 5,943,436.65 536,813.78 3.31 1,429.12 MWD(3) 9,912.30 87.39 134.88 6,016.65 5,886.65 5,180.80 3,114.94 5,943,414.19 536,836.09 6.01 1,460.79 MWD(3) 1. 9,940.57 87.51 133.64 6,017.91 5,887.91 5,200.51 -3,094.71 5,943,394.59 536,856.42 4.40 1,489.03 MWD(3) 9,970.54 88.46 131.92 6,018.96 5,888.96 -5,220.86 -3,072.73 5,943,374.36 536,878.51 6.55 1,518.95 MWD(3) 1. 10,000.61 88.96 129.47 6,019.64 5,88964 -5,240.46 304994 5943354.89 536,901.40 8.31 154893 MWD(3) 10,030.59 89.02 127.00 6,020.17 5,890.17 -5,259.01 3026 40 5943 336.46 536,925.04 8 24 1 578 69 MWD(3) 10 060 58 88.96 12519 6,020 69 5,890 69 5 276 67 -3 002 17 5,943 318.93 536949.36 6 04 1608 32 MWD(3) 3,11)70t6 12112. POPSCOMO,all SS 5000.1 Berk/A4 • • ConocoPtsaps ConocoPhillips Definitive Survey ni HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-17 Project: Kuparuk River Unit TVD Reference: 1 L-17 Q 130.00usft(1 L-17) Site: Kuparuk 1L Pad MD Reference: 1 L-17 @ 130.00usf(1 L-17) Well: '1L-17 North Reference: True Wellbore:. 1 L-17APB2 Survey Calculation Method: Minimum Curvature Design: IL-17APB2 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi NO 1VOSS +N14 '+Ef-tAt Map Map DLS Section Survey Tool Name Annotation '..(u ) l°) (°) (us) toot lust (ashy (ft) (ft) 01001 tom) 10,090 51 89.39 123.18 6,021.12 3891.12 5,293.48 -2977.41 5,943,302.25 536,974.20 6.87 1,637.71 MWD(3) 10,120.54 91.35 121.21 6020.93 6890.93 -5,309.48 -2,952.00 5,943,286.39 536,999.69 9.25 1,666.99 MWD(3) 10,150.82 89.82 119.90 6,020.62 5,890.62 -5,324.87 -2925.93 5,943,271.14 537,025.84 6.65 1,69631 MWD(3) 10,180.50 89.26 118.91 6,020.86 5,890.86 -5,339.44 -2900.08 5,943,25670 537,051.77 3.83 1,724.89 MWD(3) 10,210.86 89.17 117.22 6021.28 5,891.28 -5,353.73 -2,873.29 5,943,242.56 537,078.63 5.57 1,753.93 MWD(3) 10,240.58 88.77 11472 6,021.81 5,891.81 -5,36674 -2846.58 5,943,229.70 537,105.41 8.52 1,782.02 MWD(3) 10,270.60 89.11 11263 6,022.37 5,892.37 -5,378.79 -2,819.09 5,943,217.79 537,132.96 7.05 1,809.98 MWD(3) 10,300.71 89.29 110.29 6,022.79 5,892.79 -5,389.80 -2791.07 5,943,206.93 537,161.03 7.79 1,837.58 MWD(3) 10,330.64 90.65 110.87 6022.80 5,892.80 -5,400.32 -2763.05 5,943,196.56 537,189.10 4.94 1,864.83 MWD(3) 10,360.74 8846 11261 6,023.04 5,893.04 -5,41147 -2735.10 5,943,185.56 537,217.11 9.29 1,892.48 MWD(3) 10,390.56 87.48 115.01 6,024.09 5,894.09 -5,423.50 -2707.83 5,943,173.68 537,24444 8.69 1,920.27 MWD(3) ) 10,420.86 88.19 116.71 6,025.24 5,895.24 -5,436.71 -2,680.59 5,943,160.62 537271.75 6.08 1,948.87 MWD(3) 10,450.54 90.40 118.40 6,025.60 5,895.60 5,450.44 -2654.28 5,943,147.03 537298.13 9.37 1,977.18 MWD(3) 10,481.03 92.21 119.74 6,024.91 5,894.91 -5,465.24 -2,627.64 5,943,13236 537,324.84 7.39 2,006.49 MWD(3) 10,510.82 9446 121.62 6,023.17 5,893.17 5,480.42 -2,602.07 5,943117.33 537,350.49 9.84 2,035.30 MWD(3) ) 10,540.78 93.26 122.71 6,021,16 5,891.16 -5,496.33 -2576.76 5,943,101.55 537,375.88 5.41 2,064.45 MWD(3) 10,570.59 95.26 126.48 6,018.94 5,888.94 -5,513.20 -2,55230 5,943,084.81 537,400.43 14.28 2093.68 MWD(3) ^) 10,590.60 93.62 127.14 6,017.39 6887.39 -5,525.16 -2536.32 5,943,072.94 537,416.47 8.83 2113.42 MWD(3) 10,622.00 9362 127.14 6,01541 588541 554400 251134 594305416 537,441.54 000 214447 PROJECTED to TD 0K0181..1i2.4PM e4f 1,06/ SS SDOD.3%BPhil::14 21 6053 RECEIV , i 27 59 3 SEP 2 7 2016 PRINT DISTRIBUTION LIST BAKER HUGHES AOGCCPlease sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED /24/2016 WELL NAME 1L-17A 700 G Street. M.K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE August 27,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE September 23,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PHIN TS #OF COPIES #OF COPIES #OF COPIES U 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 ConocoPhillips Alaska Inc. I 0 0 I 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 0 0 I Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 1 1 1 Attn:Makana Bender ,333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *5* 0 I 1 1 I Attn:Sean Clifton 1550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I 1 1 I 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. • Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 NIM 0 0 In or) to t, N `V 111 Ai iitogo Eim,Ed N 0- 0 I a � O o. Cr co 0 C) Q w IX I— >, 0 Z 0) i 74D / N to V O °' a _ O O E ♦+ C -se N a) C f IC co ti N iii= IR0- U V O aQ. 9 CO acn V Y Y 2 CO 0 0 4 t 0 • • • a IF W= Z a WV m coq oo t CD m ■MO CO O rn N Q .4- . .c m ® N. >. WQ CO O O N OOh o `. 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COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE August 27,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE September 23,2016 Revision STATUS Final Replacement: No Details: Requested by: --- COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PRINTS #OF COPIES #OF COPIES #OF COPIES 1 BP North SlopeI 0 I 0 0 EOA,PBOC,PRB-20(Office 109) Il D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 0 I 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 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 5*Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 .1 1 1 I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 M • • III L[? 4 cn to Lo gli r- c� (Na W ►lam_ Immo 41 m N 0- Li— N o la `s' < r /0 /A ii Ri 0 CD QLLJ Ce ._ cn — •- — s •- _ _c co P" .c �cto a. aaa ~ CD 0 N V O , ._ L C) -J _ �+ O LL. 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N 0) O) M M N N- c0 M O Q CO CO cO N CO (O O O CO O O) V M V ,- Q CON. CO (O N N .- 0 0) u) (O N N O O O) N. N (O c() (O (n N (O N cO N N (0 co: N NZ (O COO) N COON O O M O O N (0 CO Q r O M COO) N N r 0 C C D y T W O O . .- . N N N N CO CO M Q Q Q N N N co co co co r r 0 3 cP O) 0000000000000000000000 O (O 0 Co o• d _ a a) m a U o v a` cn m m 3 3 a Nan rn • 4110 • • 216053 FIRIIIRECEND27 59 6 BAKER SEP 2 7 201v PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY Ae'bk'Iti3}rs Alaska,Inc. ConocoPhillips Alaska,Inc. Tom Osterkamp DATA LOGGED WELL NAME 1L-17APB2 700 G Street. / /201(0 K. BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE August 27,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE September 23,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PHIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope I Q ( Q Q EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 Q Q Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 EaoconMobil,Alaska 0 I 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 41'State of Alaska -AOGCC 1 f 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 is) cn to • 0 to in N (V iiii I►l kilo Q= m N CL M C5 I V C. _ Li.1 c-1 9, ...... ...• W W a F- ,, cn Q 0 Z •- ._ � 'Ec- m 0 V 10r7 = /V O > a _ ■_ NLO 's _ m .0 N L - E — ix U O aQ. r,1- o (▪13 CD n 0 • 0 • i ,.0,_ � � o _ an 6..10 111 en 0 0 �_ co b c v > �: a >• m O C Z 0 N NCO r _N (n• W CO ro Q a O 0 C o 0 N ... 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O • • i • 1L-17A 216-053 27551 LA 1 L_17AL1 216-054 27552 1L 17APB1 216-05327560 1L-17APB2 216-053 27561 SEP09 2016 Letter of Transmittal AGC ram Date: p DATA LOGGEL BAKER September 8, 2016 R tAt. ,6 HUGHES M.K BENDEh 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): i G 1L-17APB1 1L-17APB2 1L-17A 1L-17AL1 (4) 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com 1 • • LA'1 v•-• LnO CD In C . N cv . ril II z `W; gl CI 111 o N re til o c N Et Q. 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C (O O 6 6 fl M 6 V n _ N O N M M m M m O V N M V) V m O vN V) Z n (n ui vi (n vi vi u? u) vi "9 v) v) vi v) vi c vi v) in + 8 N M N m co /- N- 0) O V T V O N- m V m C) 0) CO CO N m CO - CO O O N CO O O) CO V NNN NNNNC) mNC) mma )(n '(0 N m m m 0( m Om m m C) m m m m m m m (n (0 (0 ui 6a) (0 6 (0 6 6 6 (n (n (0 In 6- ([1 6i xa CV Cl T, Z g N CO m CV co N m N- m coON O N N 0) n m OV) M V .- C] o CJ N N N CO 'C 0 (r) V M , m r v) Y i�. t N N N N N N N N N N N N N N N N O O O O O O O O O O O O O O O O O O O u IIS co co coco m m co co co co co co co co m co co co co C CD _;;;;-5;;;;;;141;f7;11''"1;', t(; 41t1 (q i�`,m O N N M 0) N- 0 .7 N m 'C V i 1- N 0) 0) N I� m N m 0 O (0 V N. m r V `• D -6co co g �III 9�I�J I I F3 N N 0) CD I� 7 (V O O N (n t0 CD Cn N N N N N O. j d Awa 1 N N ir1 co g `� Y O d 3 °k II e U � i(iPi O) coN m N. f� � O) (O O m coO NOmmN N - W W i� iIi1( 41 MMm �N a) I- � CCNm VV 'CO: V7NNmm I aAlaaCC) a � . ,,-,x,,,7_,—:__-_;,,,„0, i , eF �arIs1II�h X11 ,03 ',III", �I.i i • ISTD 21(—o5-3 Loepp, Victoria T (DOA) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Wednesday,August 10, 2016 1:39 PM To: Loepp,Victoria T(DOA) Cc: Herring, Keith E Subject: KRU 1L-17A Follow Up Flag: Follow up Flag Status: Flagged Victoria, I wanted to inform you that we had to PB the A lateral and re-drill due to geological stability. The 1L-17APB2 was drilled to 10622' MD and PB to 9165' MD. Thanks, Keith Herring CTD Engineer ConocoPhillips Alaska, Inc. 700 G Street,ATO—664 907.263.4321 Office 907.570.2410 Cell 1 .1.,OF T� • • y�.\����/j7 s, THE STATE Alaska Oil and Gas Fes;,;-���� of Conservation Commission - __ ALASI�:A it _ _ 333 West Seventh Avenue �'4/5'41-1111*- 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OA'ALAS*P' Fax: 907.276.7542 www.aogcc.alaska.gov Gary Eller CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-17A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-053 Surface Location: 357' FNL, 143' FEL, SEC. 31, T11N, R10E, UM Bottomhole Location: 1872' FNL, 1240' FEL, SEC. 6, T1ON, R10E, UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced service 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, Pte.,7� Cathy P. Foerster Chair DATED this /S day of April, 2016. Eiv STATE OF ALASKA *KA OIL AND GAS CONSERVATION COMSION MAR 3 0 2016 PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG 0. Service-Disp Plc.c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone Pi Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑� % Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone L Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket D . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 ' ' gij 1L-17A 3.Address: 6.Proposed Depth: 12.Field/Pool(s): PO Box 100360 Anchorage,AK 99510 MD: 12500' - TVD: 5987' , Kuparuk River Field/ • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): .jl% Kuparuk Oil Pool , Surface: 357'FNL,143'FEL,Sec 31,T11 N,R10E,UM . ADL 25659 I A 5(04,4 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4095'FNL,3901'FEL,Sec 31,T11 N,R10E,UM ALK 2585 6/15/2016 Total Depth: 9.Acres in Property: �rl14.Distance to Nearest Property: 1872'FNL, 1240'FEL,Sec 6,T1 ON,R10E,UM , 2/0 q�f 2. 15490' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 129'+ 15.Distance to Nearest Well Open Surface: x-539922 y- 5948611 Zone-4 , GL Elevation above MSL(ft): 87' to Same Pool: 115'to 1 L-24A 16.Deviated wells: Kickoff depth: 8193' feet -, 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 101 degrees , Downhole: 3790 psi Surface: 3295 psi 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" 2-3/8" 4.7# L-80 ST-L 4260' 8240' 5977' 12500' 5987' N/A 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): 8700' 6322' N/A 8586' 6244' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 122' 16" 235 sx ASI 122' 122' Surface 4608' 9-5/8" 650 sx Type E,450 sx Class G 4608' 3571' Intermediate Production 8675' 7" 275 sx Class G 8675' 6305' Liner Perforation Depth MD(ft): 8170'-8424',8342'-8370',8405'- Perforation Depth TVD(ft): 5961'-6010',6078'-6097',6121'-6131'&6149'- 8420'&8446'-8460' 6158' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard AnalysisL Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date �- 7' _ 22. I hereby certify that the foregoing is true and the procedure approved herein will not son Burke 265-6097 be deviated from without prior written approval. Contact jason.burkeCa�cop.com Email Printed Name' Gary ElI-, Title CTD Supervisor N \\, Signature Phone 263-4172 Date 3-2 - _\b Commission Use Only Permit to Drill API Number: Permit Approval /^ See cover letter for other Number: a'(— O53 50- O�9— R..151—o/--010P Date: 4J�'J1 corequirements. 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: V Other: 5 0 to ¢e-5 f to 375-0 p 5 jq Samples req'd: Yes❑ No lZ Mud log req'd:Yes❑ No /41-vrn r/AaY 1 v r VL frr"• fr'S t /7) ZSU0 p5r H2S measures: Yes II/. No❑ Directional svy req'd:Yes V.No El Spacir exception req'd: Yes[i] NoAi Inclination-only svy req'd:Yes❑L No IZr Post initial injection MIT req'd:Yes© No❑ APPROVED BY `���� Approved by ,At� //^�� COMMISSIONER THECOMMISSIONDate:` L 4"P'fi� o% Y It a6" Submit Form and Form 10-401(Revised 11/2015) i L,plI Mohths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate VVV !ll��� A (IN ConocoPhillips RECEIVED Alaska P.O. BOX 100360 MAR 3 0 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC March 22, 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 dual-lateral out of the Kuparuk Well 1L-17 using the coiled tubing drilling rig, Nabors CDR2-AC. ✓ CTD operations are scheduled to begin in July 2015. The objective will be to drill laterals KRU 1 L-17A and 1 L- 17AL1 targeting the Kuparuk C-sand. A separate sundry application is attached to plug the KRU 1L-17 (191- 043) perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A/C-sand perforations in 1L-17. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 1L-17 (191-043) — Operations Summary in support of the 10-403 sundry application — 10-401 Applications for 1L-17A& 1L-17AL1 — Detailed Summary of Operations — Directional Plans for 1L-17A& 1L-17AL1 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-265-6097. Sincerely, Jason Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • Kuparuk CTD Laterals NABORS ALASKA 1 L-17A & 1 L-17AL1 �.IJ 5r `° '2 RC °""� Application for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 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 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 1 L-24A& 1 L-24AL1 7 Attachment 2: Current Well Schematic for 1 L-24 7 Attachment 3: Proposed Well Schematic for 1 L-24A& 1 L-24AL1 7 Page 1 of 7 March 8, 2016 II PTApplication: 1L-17A & 1 L-17AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 L-17A& 1 L-17AL1. All laterals will be classified as "Service-WAG"wells. / 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 1L-17A& 1 L-17AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. 37q% — Pipe rams, blind rams and the CT pack off will beressure tested to 250 psi and to 3, 50 psi. Using the maximum formation pressure in the area of 37 2 psi in 1L-16 (i.e. 12.3 ppg EMW), the maximum potential surface pressure in 1L-17, assuming a gas gradient of 0.1 psi/ft, would be 3295 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 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 1L-17 was measured to be 3452 psi (11.2 ppg EMW) on 1/14/2014. The maximum downhole pressure in the 1L-17 vicinity is to the north in the 1L-16 injector at 37 psi (12.3 ppg EMW) from May of 2014. The 1 L-17AL1 sidetrack will be drilled northwest could encounter formation pressure from 1L-16. 3740 Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Wells on 1L pad have injected gas, so there is a chance of encountering free gas while drilling the 1 L-17 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 1 L-17 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 L-17 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 March 17, 2016 • PTDDpplication: 1L-17A & 1 L-17AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name MD MD TVDSS TVDSS Liner Details 1L-17A 8240' 12500' 5848' 5858' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2-3/8", 4.7#, L-80, ST-L slotted liner; 1 L-17ALI 8045' 11800' 5875' 5862' deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (ppf) TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 122' 0' 122' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 4607' 0' 3571' 3520 2220 Production 7" 26.0 J-55 BTC-MOD 0' 8675' 0' 6305' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE-M 0 8018' 0 5858' 10160 10530 Tubing 3-1/2" 9.3 J-55 EUE-8rdAB 0 8082' 0 5901' 6990 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-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 CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud ($.6 ppg) — Drilling operations: Chloride-based FloVis mud (8.6 ppg).,/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 11.8 ppg NaBr completion fluid in order 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 5,000 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". In the 1L-17 laterals we will target a constant BHP of 11.8 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. Page 3 of 7 March 17, 2016 • PTDitplication: 1L-17A & 1 L-17AL1 Pressure at the 1L-17 Window(8193' MD, 6106' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.2 ppg) 3556 psi 3556 psi Mud Hydrostatic(8.5 ppg) 2699 psi 2699 psi Annular friction (i.e. ECD, 0.090 psi/ft) 737 psi 0 psi Mud + ECD Combined 3436 psi 2699 psi (no choke pressure) (underbalanced -120 psi) (underbalanced -857 psi) Target BHP at Window(11.8 ppg) 3746 psi 3746 psi Choke Pressure Required to Maintain Target BHP 310 psi 1048 psi 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 well 1L-17 is a Kuparuk A/C-sand injector equipped with 3-1/2"tubing and 7"production casing. The CTD sidetrack will utilize two laterals to target the C4 sand to the southeast and northwest of 1L-17. The laterals will support nearby producers 1L-13 and 1 L-23. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2"tubing tail at 8052' MD and the"D" nipple at 8048' MD will be milled out to a 2.80" ID. The existing A-sand and C-sand perforations will be squeezed with cement and the 3-1/2"tubing tail will be cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand and C-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8200' MD and set a mechanical whip-stock in the 2.80"pilot hole to kick off at 8193' MD. Both laterals will be completed with 2-3/8" slotted liner from TD with the second lateral liner top located inside the 3-1/2"tubing tail. The 1L-17A southeastern lateral will exit the cement pilot hole at 8193' MD and TD at 12500' MD, targeting the C4 sand. It will be completed with 2-3/8"slotted liner from TD up to 8240'MD with an aluminum billet for kicking off the 1L-17AL1. Page 4 of 7 March 17, 2016 PTDtpplication: 1L-17A & 1 L-17AL1 The IL-17AL1 lateral will drill to the northwest to a TD of 11800' MD targeting the C4 sand. It will be completed with 2-3/8" slotted liner from TD up to 8045' MD,back into the 3-1/2"tubing tail with a deployment sleeve. Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3'/2"tubing tail at 8052' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out"D"nipple and cement squeeze the A-sand and C-sand perforations up to the holes in the tubing tail. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1L-17A Sidetrack(C4 sand- Southeast) i. Drill 2.80" high-side pilot hole through cement to 8225' MD ii. Caliper pilot hole iii. Set top of whip-stock at 8193' MD iv. Mill 2.80"window at 8193' MD. v. Drill 3"bi-center lateral to TD of 12500' MD. vi. Run 2%" slotted liner with an aluminum billet from TD up to 8240' MD. 3. 1 L-17ALI Lateral (C4 sand-Northwest) i. Kick off of the aluminum billet at 8240' MD. ii. Drill 3"bi-center lateral to TD of 11800' MD. iii. Run 2%" slotted liner with deployment sleeve from TD up to 8045' MD. 4. Freeze protect, set BPV,ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Pre produce for less than 30 days / 5. Return to injection 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 using 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. Page 5 of 7 March 17, 2016 • PTDDpplication: 1L-17A & 1 L-17AL1 - 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 slick-line. - 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 1L-17 laterals will be displaced to an overbalancing fluid (11.8 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide secondary well control while running 2-3/8" 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. / • 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 Plans - 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 ` tance•-:- 1L-17A 15490' 1 L-17AL1 19500' - Distance to Nearest Well within Pool 1 ater lINamW Distance 1lVirell 1L-17A 115' 1L-24A 1L-17AL1 640' 2E-11 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 1 L-24AL1, 1 L-24A, 1 L-24, 1 L-23 & 1 L-25A are within 1/4-mile of the 1 L-17A well. 2E-11 is within 1/4-mile of the 1L-17AL1 well • See Attached AOR sheet Page 6 of 7 March 17, 2016 PTDDpplication: 1L-17A & 1 L-17AL1 17.Attachments Attachment 1: Directional Plans for 1L-17A & 1L-17AL1 laterals Attachment 2: Current Well Schematic for 1L-17 Attachment 3: Proposed Well Schematic for 1L-17A & 1L-17AL1 laterals Page 7 of 7 March 17, 2016 • i ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk IL Pad 1L-17 1L-17A Plan: 1 L-17A_wp05 Standard Planning Report 18 March, 2016 BAKER HUGHES • ConocoPhillips • I PI�� ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-17 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad North Reference: True Well: 1L-17 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-17A Design: 1 L-17A_wp05 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 1L Pad Site Position: Northing: 5,949,190.90 usft Latitude: 70°16'19.650 N From: Map Easting: 539,916.78 usft Longitude: 149°40'37.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.30 ° Well 1L-17 Well Position +N/-S 0.00 usft Northing: 5,948,610.93 usft Latitude: 70°16'13.945 N +El-W 0.00 usft Easting: 539,923.20 usft Longitude: 149°40'37.666 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 L-17A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 7/1/2016 18.40 80.93 57,492 Design 1L-17A_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,100.00 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 188.98 3/18/2016 9:07::37AM Page 2 COMPASS 5000.1 Build 74 1110 ConocoPhillips • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-17 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad North Reference: True Well: 1L-17 Survey Calculation Method: Minimum Curvature Wellbore: 1L-17A Design: 1L-17A wp05 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (usft) (') (0) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (^) Target 8,100.00 47.46 223.87 5,783.62 -3,660.80 -3,670.73 0.00 0.00 0.00 0.00 8,193.00 47.27 224.46 5,846.62 -3,709.88 -3,718.39 0.51 -0.20 0.63 113.84 8,214.00 51.47 224.46 5,860.29 -3,721.26 -3,729.56 20.00 20.00 0.00 0.00 8,301.84 91.00 224.46 5,887.99 -3,779.45 -3,786.66 45.00 45.00 0.00 0.00 8,371.84 101.16 194.43 5,880.41 -3,839.19 -3,820.59 45.00 14.52 -42.90 290.00 8,441.84 91.85 164.10 5,872.30 -3,907.83 -3,819.54 45.00 -13.29 -43.33 255.00 8,550.00 91.70 159.78 5,868.94 -4,010.59 -3,786.03 4.00 -0.14 -4.00 268.00 8,900.00 92.86 145.81 5,854.97 -4,320.85 -3,626.55 4.00 0.33 -3.99 275.00 9,100.00 90.10 153.33 5,849.79 -4,493.11 -3,525.38 4.00 -1.38 3.76 110.00 9,400.00 86.42 141.90 5,858.93 -4,745.88 -3,365.08 4.00 -1.23 -3.81 252.00 9,700.00 84.42 130.03 5,882.96 -4,960.49 -3,157.63 4.00 -0.66 -3.96 260.00 9,850.00 76.44 123.11 5,907.90 -5,048.57 -3,039.07 7.00 -5.32 -4.61 220.00 10,050.00 88.63 130.06 5,933.86 -5,166.59 -2,880.33 7.00 6.10 3.47 30.00 10,200.00 93.07 139.58 5,931.62 -5,272.15 -2,774.08 7.00 2.96 6.35 65.00 10,400.00 92.98 125.56 5,921.02 -5,406.92 -2,627.36 7.00 -0.05 -7.01 270.00 10,580.00 97.19 137.48 5,905.00 -5,525.47 -2,493.35 7.00 2.34 6.62 70.00 10,780.00 93.40 123.94 5,886.45 -5,654.98 -2,342.74 7.00 -1.89 -6.77 255.00 11,000.00 89.86 138.94 5,880.14 -5,800.11 -2,178.40 7.00 -1.61 6.82 103.00 11,250.00 89.87 121.44 5,880.72 -5,960.82 -1,988.16 7.00 0.00 -7.00 270.00 11,450.00 92.28 135.23 5,876.95 -6,084.53 -1,831.70 7.00 1.21 6.90 80.00 11,650.00 93.42 121.26 5,866.95 -6,207.89 -1,675.23 7.00 0.57 -6.99 275.00 12,050.00 90.68 149.15 5,852.34 -6,488.80 -1,396.45 7.00 -0.69 6.97 95.00 12,400.00 88.55 124.74 5,854.74 -6,742.60 -1,159.33 7.00 -0.61 -6.97 265.00 12,500.00 88.31 117.74 5,857.48 -6,794.41 -1,073.92 7.00 -0.23 -7.00 268.00 3/18/2016 9:07.37AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips _._:a__ : ' ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-17 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad North Reference: True Well: 1L-17 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-17A Design: 1L-17A wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E!W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (0/100ft) (°) (usft) (usft) 8,100.00 47.46 223.87 5,783.62 -3,660.80 -3,670.73 4,188.99 0.00 0.00 5,944,931.07 536,272.30 TIP 8,193.00 47.27 224.46 5,846.62 -3,709.88 -3,718.39 4,244.91 0.51 113.84 5,944,881.74 536,224.90 KOP 8,200.00 48.67 224.46 5,851.30 -3,713.59 -3,722.04 4,249.14 20.00 0.00 5,944,878.01 536,221.28 8,214.00 51.47 224.46 5,860.29 -3,721.26 -3,729.56 4,257.89 20.00 0.00 5,944,870.31 536,213.80 End 20 dls,Start 45 dls 8,300.00 90.17 224.46 5,888.01 -3,778.13 -3,785.37 4,322.78 45.00 0.00 5,944,813.14 536,158.29 8,301.84 91.00 224.46 5,887.99 -3,779.45 -3,786.66 4,324.28 45.00 0.00 5,944,811.82 536,157.01 4 8,371.84 101.16 194.43 5,880.41 -3,839.19 -3,820.59 4,388.59 45.00 -70.00 5,944,751.90 536,123.40 5 8,400.00 97.65 182.09 5,875.79 -3,866.63 -3,824.56 4,416.30 45.00 -105.00 5,944,724.45 536,119.58 8,441.84 91.85 164.10 5,872.30 -3,907.83 -3,819.54 4,456.22 45.00 -107.03 5,944,683.28 536,124.82 End 45 dls,Start RSM 8,500.00 91.77 161.78 5,870.46 -3,963.40 -3,802.48 4,508.44 4.00 -92.00 5,944,627.81 536,142.16 8,550.00 91.70 159.78 5,868.94 -4,010.59 -3,786.03 4,552.49 4.00 -92.07 5,944,580.71 536,158.87 7 8,600.00 91.87 157.78 5,867.39 -4,057.17 -3,767.94 4,595.67 4.00 -85.00 5,944,534.23 536,177.20 8,700.00 92.21 153.79 5,863.82 -4,148.30 -3,726.97 4,679.28 4.00 -85.06 5,944,443.33 536,218.66 8,800.00 92.54 149.80 5,859.68 -4,236.33 -3,679.76 4,758.87 4.00 -85.20 5,944,355.56 536,266.32 8,900.00 92.86 145.81 5,854.97 -4,320.85 -3,626.55 4,834.05 4.00 -85.37 5,944,271.33 536,319.97 8 9,000.00 91.48 149.57 5,851.18 -4,405.29 -3,573.16 4,909.12 4.00 110.00 5,944,187.18 536,373.81 9,100.00 90.10 153.33 5,849.79 -4,493.11 -3,525.38 4,988.40 4.00 110.14 5,944,099.63 536,422.05 9 9,200.00 88.87 149.52 5,850.69 -4,580.90 -3,477.56 5,067.65 4.00 -108.00 5,944,012.10 536,470.33 9,300.00 87.64 145.71 5,853.74 -4,665.30 -3,424.04 5,142.65 4.00 -107.97 5,943,928.00 536,524.29 9,400.00 86.42 141.90 5,858.93 -4,745.88 -3,365.08 5,213.04 4.00 -107.85 5,943,847.74 536,583.67 10 9,500.00 85.73 137.95 5,865.78 -4,822.20 -3,300.87 5,278.41 4.00 -100.00 5,943,771.76 536,648.28 9,600.00 85.07 133.99 5,873.80 -4,893.86 -3,231.61 5,338.37 4.00 -99.73 5,943,700.48 536,717.91 9,700.00 84.42 130.03 5,882.96 -4,960.49 -3,157.63 5,392.64 4.00 -99.41 5,943,634.25 536,792.23 End RSM,Start 7 dls 9,800.00 79.09 125.45 5,897.30 -5,021.05 -3,079.44 5,440.24 7.00 -140.00 5,943,574.11 536,870.74 9,850.00 76.44 123.11 5,907.90 -5,048.57 -3,039.07 5,461.13 7.00 -139.34 5,943,546.81 536,911.25 12 9,900.00 79.48 124.89 5,918.33 -5,075.91 -2,998.54 5,481.80 7.00 30.00 5,943,519.69 536,951.92 10,000.00 85.58 128.35 5,931.34 -5,135.03 -2,919.02 5,527.78 7.00 29.63 5,943,460.99 537,031.74 10,050.00 88.63 130.06 5,933.86 -5,166.59 -2,880.33 5,552.92 7.00 29.18 5,943,429.64 537,070.60 13 10,100.00 90.12 133.23 5,934.41 -5,199.81 -2,842.98 5,579.89 7.00 65.00 5,943,396.63 537,108.12 10,200.00 93.07 139.58 5,931.62 -5,272.15 -2,774.08 5,640.60 7.00 64.97 5,943,324.66 537,177.39 14 10,300.00 93.05 132.57 5,926.28 -5,344.02 -2,704.85 5,700.78 7.00 -90.00 5,943,253.16 537,247.00 10,400.00 92.98 125.56 5,921.02 -5,406.92 -2,627.36 5,750.80 7.00 -90.37 5,943,190.69 537,324.82 15 10,500.00 95.35 132.16 5,913.75 -5,469.44 -2,549.74 5,800.44 7.00 70.00 5,943,128.58 537,402.75 10,580.00 97.19 137.48 5,905.00 -5,525.47 -2,493.35 5,846.98 7.00 70.48 5,943,072.85 537,459.43 16 10,600.00 96.83 136.12 5,902.56 -5,539.94 -2,479.77 5,859.15 7.00 -105.00 5,943,058.46 537,473.09 10,700.00 94.96 129.34 5,892.29 -5,607.39 -2,406.74 5,914.37 7.00 -105.17 5,942,991.41 537,546.47 3/18/2016 9:07:37AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ' " _,� ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-17 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad North Reference: True Well: 1L-17 Survey Calculation Method: Minimum Curvature Wellbore: 1L-17A Design: 1 L-17A_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/_W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (nett) (usft) (°/100ft) (°) (usft) (usft) 10,780.00 93.40 123.94 5,886.45 -5,654.98 -2342.74 5,951.39 7.00 -105.86 5,942,944.16 537,610.72 17 10,800.00 93.09 125.31 5,885.32 -5,666.33 -2,326.31 5,960.03 7.00 103.00 5,942,932.90 537,627.20 10,900.00 91.49 132.13 5,881.32 -5,728.79 -2,248.40 6,009.57 7.00 103.08 5,942,870.86 537,705.43 11,000.00 89.86 138.94 5,880.14 -5,800.11 -2,178.40 6,069.09 7.00 103.35 5,942,799.91 537,775.81 18 11,100.00 89.87 131.94 5,880.38 -5,871.32 -2,108.28 6,128.47 7.00 -90.00 5,942,729.09 537,846.30 11,200.00 89.87 124.94 5,880.61 -5,933.45 -2,030.01 6,177.62 7.00 -89.98 5,942,667.38 537,924.89 11,250.00 89.87 121.44 5,880.72 -5,960.82 -1,988.16 6,198.12 7.00 -89.97 5,942,640.24 537,966.87 19 11,300.00 90.48 124.89 5,880.57 -5,988.16 -1,946.32 6,218.59 7.00 80.00 5,942,613.12 538,008.86 11,400.00 91.69 131.78 5,878.68 -6,050.13 -1,867.94 6,267.57 7.00 80.01 5,942,551.57 538,087.56 11,450.00 92.28 135.23 5,876.95 -6,084.53 -1,831.70 6,295.89 7.00 80.14 5,942,517.36 538,123.98 20 11,500.00 92.58 131.74 5,874.83 -6,118.91 -1,795.47 6,324.18 7.00 -85.00 5,942,483.19 538,160.39 11,600.00 93.15 124.76 5,869.82 -6,180.70 -1,717.09 6,372.99 7.00 -85.15 5,942,421.82 538,239.09 11,650.00 93.42 121.26 5,866.95 -6,207.89 -1,675.23 6,393.31 7.00 -85.50 5,942,394.85 538,281.09 21 11,700.00 93.11 124.75 5,864.10 -6,235.08 -1,633.38 6,413.63 7.00 95.00 5,942,367.88 538,323.08 11,800.00 92.46 131.73 5,859.24 -6,296.87 -1,554.98 6,462.42 7.00 95.20 5,942,306.52 538,401.79 11,900.00 91.76 138.70 5,855.55 -6,367.76 -1,484.63 6,521.46 7.00 95.54 5,942,236.01 538,472.51 12,000.00 91.05 145.67 5,853.10 -6,446.68 -1,423.38 6,589.85 7.00 95.80 5,942,157.42 538,534.18 12,050.00 90.68 149.15 5,852.34 -6,488.80 -1,396.45 6,627.25 7.00 95.97 5,942,115.45 538,561.32 22 12,100.00 90.37 145.66 5,851.88 -6,530.92 -1,369.52 6,664.64 7.00 -95.00 5,942,073.48 538,588.47 12,200.00 89.76 138.69 ' 5,851.77 -6,609.86 -1,308.24 6,733.05 7.00 -95.03 5,941,994.88 538,650.17 12,300.00 89.15 131.72 5,852.73 -6,680.77 -1,237.82 6,792.10 7.00 -95.04 5,941,924.34 538,720.95 12,400.00 88.55 124.74 5,854.74 -6,742.60 -1,159.33 6,840.92 7.00 -94.97 5,941,862.94 538,799.76 23 12,500.00 88.31 117.74 5,857.48 -6,794.41 -1,073.92 6,878.76 7.00 -92.00 5,941,811.58 538,885.44 Planned TD at 12500.00 3/18/2016 9:07:37AM Page 5 COMPASS 5000.1 Build 74 4111 ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-17 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad North Reference: True Well: 1 L-17 Survey Calculation Method: Minimum Curvature Wellbore: 1L-17A Design: 1L-17A wp05 Targets Target Name -hit/misstarget Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1L-17A TO2 0.00 0.00 5,873.00 -10,202.941,136,306.24 5,944,436.00 1,676,156.00 70°0'37.162 N 140°34'27.306 W -plan misses target center by 1137385.27usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1L-17AL1_Fault1 0.00 0.00 0.00 -9,362.701,135,147.57 5,945,270.00 1,674,993.00 70°0'47.015 N 140°34'56.605 W -plan misses target center by 1136239.49usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 1L-17A T05 0.00 0.00 5,935.00 -11,496.271,137,283.49 5,943,148.00 1,677,140.00 70°0'23.174 N 140°34'5.101 W -plan misses target center by 1138367.12usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1 L-17A_T03 0.00 0.00 5,851.00 -10,789.571,136,601.16 5,943,851.00 1,676,454.00 70°0'31.034 N 140°34'21.443 W -plan misses target center by 1137682.09usft at 12500.O0usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1L-17 CTD Polygon Sou 0.00 0.00 0.00 -9,905.861,136,296.82 5,944,733.00 1,676,145.00 70°0'40.061 N 140°34'26.304 W -plan misses target center by 1137390.07usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Polygon Point 1 0.00 0.00 0.00 5,944,733.00 1,676,145.00 Point2 0.00 -166.35 -127.89 5,944,565.99 1,676,018.01 Point3 0.00 -369.34 -133.96 5,944,362.99 1,676,013.01 Point 4 0.00 -974.04 176.90 5,943,760.01 1,676,327.05 Point 5 0.00 -1,227.86 327.59 5,943,507.02 1,676,479.07 Point6 0.00 -1,497.40 615.20 5,943,239.03 1,676,768.07 Point7 0.00 -2,114.23 1,331.04 5,942,626.07 1,677,487.10 Point 8 0.00 -2,675.76 1,992.17 5,942,068.11 1,678,151.14 Point 9 0.00 -2,889.25 2,270.08 5,941,856.11 1,678,430.15 Point 10 0.00 -3,103.01 2,410.97 5,941,643.13 1,678,572.16 Point 11 0.00 -3,439.37 2,852.25 5,941,309.14 1,679,015.17 Point 12 0.00 -3,160.14 3,004.74 5,941,589.15 1,679,166.16 Point 13 0.00 -2,871.00 2,604.21 5,941,876.13 1,678,764.15 Point 14 0.00 -2,647.16 2,448.37 5,942,099.12 1,678,607.14 Point 15 0.00 -2,427.65 2,165.49 5,942,317.11 1,678,323.12 Point 16 0.00 -1,893.25 1,530.23 5,942,848.08 1,677,685.10 Pointl7 0.00 -1,301.71 869.26 5,943,436.05 1,677,021.07 Point 18 0.00 -1,077.31 607.41 5,943,659.03 1,676,758.06 Point 19 0.00 -848.49 456.59 5,943,887.03 1,676,606.04 Point20 0.00 -268.90 165.61 5,944,465.01 1,676,312.02 Point2l 0.00 -204.14 211.95 5,944,530.01 1,676,358.01 Point22 0.00 0.00 0.00 5,944,733.00 1,676,145.00 1L-17A_T04 0.00 0.00 5,884.00 -11,257.571,136,968.72 5,943,385.00 1,676,824.00 70°0'25.952 N 140°34'13.013 W -plan misses target center by 1138051.39usft at 12500.Oousft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1 L-17A_Faultl 0.00 0.00 0.00 -11,496.271,137,283.49 5,943,148.00 1,677,140.00 70°0'23.174 N 140°34'5.101 W -plan misses target center by 1138382.19usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 1L-17A T07 0.00 0.00 5,881.00 -12,060.681,137,913.57 5,942,587.00 1,677,773.00 70°0'16.772 N 140°33'49.636 W -plan misses target center by 1138999.66usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1L-17A_T09 0.00 0.00 5,853.00 -12,828.231,138,756.59 5,941,824.00 1,678,620.00 70°0'8.084 N 140°33'29.001 W -plan misses target center by 1139846.48usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1L-17A_T01 0.00 0.00 5,889.00 -10,075.11 1,136,340.92 5,944,564.00 1,676,190.00 70°0'38.353 N 140°34'25.775 W -plan misses target center by 1137419.57usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1L-17A Fault2 0.00 0.00 0.00 -12,257.891,138,137.55 5,942,391.00 1,677,998.00 70°0'14.529 N 140°33'44.124 W 3/18/2016 9:07:37AM Page 6 COMPASS 5000.1 Build 74 • ConocoPhillips • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-17 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad North Reference: True Well: 1L-17 Survey Calculation Method: Minimum Curvature Wellbore: 1L-17A Design: 1 L-17A_wp05 -plan misses target center by 1139239.62usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 1L-17A_T08 0.00 0.00 5,882.00 -12,257.891,138,137.55 5,942,391.00 1,677,998.00 70°0'14.529 N 140°33'44.124 W -plan misses target center by 1139224.57usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1L-17 CTD Polygon Non 0.00 0.00 0.00 -9,907.871,136,298.81 5,944,731.00 1,676,147.00 70°0'40.038 N 140°34'26.256 W -plan misses target center by 1137392.07usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Polygon Point 1 0.00 0.00 0.00 5,944,731.00 1,676,147.00 Point 2 0.00 154.54 -290.22 5,944,883.98 1,675,855.99 Point3 0.00 246.14 -591.77 5,944,973.97 1,675,553.99 Point4 0.00 428.63 -872.85 5,945,154.95 1,675,271.97 Point 5 0.00 1,042.51 -1,407.68 5,945,765.93 1,674,733.95 Point6 0.00 1,251.57 -1,604.61 5,945,973.92 1,674,535.93 Point 7 0.00 1,457.90 -1,853.55 5,946,178.91 1,674,285.93 Point8 0.00 1,798.91 -2,038.78 5,946,518.89 1,674,098.91 Point 9 0.00 2,353.09 -2,441.91 5,947,070.87 1,673,692.88 Point 10 0.00 2,198.43 -2,699.75 5,946,914.86 1,673,435.89 Point 11 0.00 1,647.29 -2,303.60 5,946,365.89 1,673,834.92 Point 12 0.00 1,310.31 -2,124.36 5,946,029.90 1,674,015.93 Point 13 0.00 1,047.72 -1,827.70 5,945,768.91 1,674,313.95 Point 14 0.00 852.74 -1,644.70 5,945,574.92 1,674,497.96 Point 15 0.00 172.48 -1,040.21 5,944,897.94 1,675,105.99 Point 16 0.00 -27.36 -694.22 5,944,699.96 1,675,453.00 Point 17 0.00 -130.01 -381.73 5,944,598.98 1,675,766.00 Point 18 0.00 -298.24 -150.58 5,944,431.99 1,675,998.02 Point 19 0.00 -306.36 61.40 5,944,425.00 1,676,210.02 Point 20 0.00 -202.15 214.96 5,944,530.01 1,676,363.01 Point 21 0.00 0.00 0.00 5,944,731.00 1,676,147.00 1L-17A_T06 0.00 0.00 5,922.00 -11,703.431,137,498.42 5,942,942.00 1,677,356.00 70°0'20.848 N 140°33'59.888 W -plan misses target center by 1138582.92usft at 12500.O0usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point 1L-17A_T10 0.00 0.00 5,858.00 -13,090.831,139,052.23 5,941,563.00 1,678,917.00 70°0'5.101 N 140°33'21.738 W -plan misses target center by 1140143.54usft at 12500.00usft MD(5857.48 TVD,-6794.41 N,-1073.92 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 12,500.00 5,857.48 2 3/8" 2.375 3.000 3/18/2016 9:07:37AM Page 7 COMPASS 5000.1 Build 74 • • ConocoPhillips Vail ConocoPhilhps Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-17 Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-17 @ 130.00usft(1L-17) Site: Kuparuk 1L Pad North Reference: True Well: 1L-17 Survey Calculation Method: Minimum Curvature Wellbore: 1L-17A Design: 1 L-17A_wp05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,100.00 5,783.62 -3,660.80 -3,670.73 TIP 8,193.00 5,846.62 -3,709.88 -3,718.39 KOP 8,214.00 5,860.29 -3,721.26 -3,729.56 End 20 dls,Start 45 dls 8,301.84 5,887.99 -3,779.45 -3,786.66 4 8,371.84 5,880.41 -3,839.19 -3,820.59 5 8,441.84 5,872.30 -3,907.83 -3,819.54 End 45 dls,Start RSM 8,550.00 5,868.94 -4,010.59 -3,786.03 7 8,900.00 5,854.97 -4,320.85 -3,626.55 8 9,100.00 5,849.79 -4,493.11 -3,525.38 9 9,400.00 5,858.93 -4,745.88 -3,365.08 10 9,700.00 5,882.96 -4,960.49 -3,157.63 End RSM,Start 7 dls 9,850.00 5,907.90 -5,048.57 -3,039.07 12 10,050.00 5,933.86 -5,166.59 -2,880.33 13 10,200.00 5,931.62 -5,272.15 -2,774.08 14 10,400.00 5,921.02 -5,406.92 -2,627.36 15 10,580.00 5,905.00 -5,525.47 -2,493.35 16 10,780.00 5,886.45 -5,654.98 -2,342.74 17 11,000.00 5,880.14 -5,800.11 -2,178.40 18 11,250.00 5,880.72 -5,960.82 -1,988.16 19 11,450.00 5,876.95 -6,084.53 -1,831.70 20 11,650.00 5,866.95 -6,207.89 -1,675.23 21 12,050.00 5,852.34 -6,488.80 -1,396.45 22 12,400.00 5,854.74 -6,742.60 -1,159.33 23 12,500.00 5,857.48 -6,794.41 -1,073.92 Planned TD at 12500.00 3/18/2016 9:07:37AM Page 8 COMPASS 5000.1 Build 74 4111 • I.-- Baker Hughes INTEQ Nei ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc,-Kup2 Local Co-ordinate Reference: Well 1 L-17 Project: Kuparuk River Unit TVD Reference: 1L-17 @ 130.00usft(1L-17) Reference Site: Kuparuk 1L Pad MD Reference: 1L-17 @ 130.00usft(1L-17) Site Error. 0.00 usft North Reference: True Reference Well: 1L-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1L-17A Database: OAKEDMP2 Reference Design: 1 L-17A_wp05 Offset TVD Reference: Offset Datum Reference 1L-17A_wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,100.00 to 12,500.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,437.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/17/2016 i From To (usft) (usft) Survey(Wellbore) Tool Name Description 1 i 200.00 8,100,00 1L-17(1L-17) GCT-MS Schlumberger GCT multishot 8,100.00 12,500.00 1L-17A_wp05(1L-17A) , MWD MWD-Standard 1 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (') 12,500.00 5,987.48 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 1L Pad 1L-13-IL-13-IL-13-IL-13 Out of range 1L-13-1L-13A-1 L-13A_wp04 Out of range 1L-13-1 L-13AL1-1 L-13AL1_wp04 Out of range 1L-17-1L-17-1 L-17 8,200.00 8,200.00 0.08 3.98 -3.36 FAIL-Major Risk 1L-17-1 L-17AL1-1 L-17AL1_wp04 8,249.99 8,250.00 0.33 0.30 0.07 Pass-Minor 1/10 IL-18-1L-18-IL-18 Out of range 1L-18-1L-18A-1 L-18A_wp03 Out of range 1L-18-1L-18AL1-1 L-18AL1_wp02 Out of range 1L-23-1 L-23-1 L-23 9,734.12 8.625.00 787.93 278.87 513.44 Pass-Major Risk 1L-24-1L-24-1L-24 12,438.20 9,175.00 341.85 25.29 341.62 Pass-Minor 1/10 1L-24-1L-24A-1 L-24A_wp03 12,473.29 9,100.00 290.93 19.67 290.71 Pass-Minor 1/T0 i 1L-24-1L-24AL1-1 L-24AL1_wp01 11,866.77 9,600.00 117.97 15.22 117.74 Pass-Minor 1/10 I 1 L-25-1 L-25A-1 L-25A Out of range Offset Design Kuparuk 1L Pad- 1 L-17-1L-17-1L-17 Offset Site Error. 0.00 usft Survey Program: 200-GCT-MS 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 +NIS +EI-w Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (9 (usft) (usft) (") (usft) (usft) (usft) 8,125.00 5,930.53 8,125.00 5,930.53 0.09 0.17 -174.29 -3,674.06 -3,683.51 2-11/16 0.00 1.17 -1.07 FAIL-Major Risk,CC 8,150.00 5,947.46 8,150.00 5,947.46 0.18 0.35 -174.27 -3,687.27 -3,696.31 2-11/16 0.00 2.11 -1.93 FAIL-Major Risk 8,175.00 5,964.41 8,175.00 5,964.40 0.26 0.52 -174.22 -3,700.44 -3,709.14 2-11/16 0.00 3.07 -2.79 FAIL-Major Risk 8,200.00 5,981.30 8,200.00 5,981.36 0.33 0.70 45.10 -3,713.55 -3,722.00 2-11/16 0.08 3.98 -3.36 FAIL-Major Risk,ES,SF 8,224.77 5,996.63 8,225.00 5,998.34 0.33 0.87 43.85 -3,726.63 -3,734.86 2-11/16 2.06 5.05 -2.81 FAIL-Major Risk 8,248.07 6,007.71 8,250.00 6,015.35 0.34 1.05 44.02 -3,739.68 -3,747.73 2-11/16 8.31 6.53 1.86 Pass-Major Risk 8,268.68 6,014.27 8,275.00 6,032.39 0.34 1.22 44.07 -3,752.70 -3,760.59 2-11/16 18.67 7.81 10.94 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/17/2016 10:56:58AM Page 2 COMPASS 5000.1 Build 74 ii Sit • • 1111,killirat) m W2 41 m o�' 0'4c M M1 0 Js ' — - — O cv 10 � 1 „.,:,r:i....:1::::::1-.;:i:...27 I/ //////:_,7 : 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A O O O O O O O O O O O O O O O O O O O O O O C o O(c1 - 0) -4 ' 0000000000000000000000 AO cos •CD.+ 0 01 0)0)(10101 C)CT C.CT C.CT CT(n(n.A A.A A A A A p•A Co 1=- • ""-""" —iL-17._T03 co.co 01 co N CO O CO CO V C)Cn A W NCO C1(T Co co N N C1 4.44 -I?N COO(OO CT 4,C.a0,CD OD C. C.(n CAN CT-P-aG Z(D AO boo co.-.0.,OON�N WOANOCb.A--4A co 01 0 ti(D N W C.->O W(D(10)(O L,0)O A O- N 0l N Co CD(DN ONN>O N D Co CCO OO NCO A AO CT CO N CO CO CD-a Co,0.. tn O4. CD O N 4, /11` o jam. O O ET ET co ND O C O CO^1 C)C n A C J N 00 0)0 CO V j C T?0 Ta 7? O \I o, 0. Q� U0 Cap L' °N° m (p CT o m w(o m 3 CD O O. d CL a. p 61-• 3 C� - 0 o 1 17A_ 1• -, v m ((°i m c= K, C/] a a 4, o �9 (-n , w O cod O N N O 0. o -0 m m r CD corn 8 ---` L 17 _TOS South(-)/North(+)(250 usft/in) 1' xi co o, m 00 Ca A O N O N 8 al 00 0 IN 8 J 0 0 8 J 8 O- O 0 0 o O o 0 o O o 0 0 0 0 0 0 0 Ko m 1/40 co ,� .r 4 m D ° r.. -- -IL-1 _T06 /8. • r D 0r0o 1. o ,co o VI o 1a. r Y > D N an 4- E. N O a- NCrO� O, t O O. o O. (r ,• . OT 0 .--co - O. CI�- T o J N Flip" p--1 17A_ 08 N) -- la a a 0)v O E CD J o I 3 m F �,..o m• m r-3' C° m pD : N: r �, �' r P.,� m A a� : .... r. :�C3�`2 z O r In,. P a s f m T A 0`^ O o. IH o0 2 o.- . z C N o _ T N O f'.- -.....„ - m'Sv m o N '-'1L-17._T09 N ' v 0. J O O r 0. y 10 .1 N O, 0 - J C A W A W v- N. \ ,! soo i ^d L-17"_T10 0. IY _ W O ` - 0. 0,a � ( a ; � _; CONS O A J (11 fatN ' ` -3i]" A III 0 i- 00 o• a r N r N >. > O A N I. O 6 v-- KUP 1 L-17 ConocoPhillips ; Well Attrib Max AngleD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) corronoWAIfips 500292215100 KUPARUK RIVER UNIT INJ 49.22 4,400.00 8,700.0 ••. ..- Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1L-17,329/20167:24:38 PM ' SSSV:NIPPLE Last WO: 12/23/2013 42.01 4/11/1991 . Vertigl schematic tactual( Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,421.0 5/27/2015 Rev Reason:TAG,MANDREL ORIENTATION hipshkf 6/7/2015 ICasing Strings HANGER;38.5 j. f { Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 122.0 122.0 62.50/1-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.921 42.0 4,607.2 3,571.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread o..,... "a'PRODUCTION 7 6.276 32.3 8,675.3 6,305.6 26.00 J-55 BTC-MOD .,..,..,...�.,,...,.,,...,..,,.r..... 47' dTubing Strings L Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection - TUBING WO 31/2 2.992 38.5 8,018.4 5,858.7 9.30 L-80 EUE-M _ Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 38.5 38.5- 0.17 HANGER FMC TUBING HANGER 2.992 M CONDUCTOR;43.0-1220N./Vs-M., 491.1 490.8 6.08 NIPPLE CAMCO DS LANDING NIPPLE 2.875"Profile 2.875 7,946.8 5,810.7 47.89 LOCATOR BAKER LOCATOR 2.990 7,947.1 5,810.9 47.89 SEAL ASSY BAKER 80-40 SEAL ASSY,Stick up 7'off NoGo Seals 2.990 NIPPLE;497.1 g Engaged 14.67' 7,954.1 5,815.6 47.89 PACKER BAKER FHL PACKER w/PBR(Center element on 2.930 packer 7980.73') 7,998.9 5,845.6 47.91 NIPPLE CAMCO DS LANDING NIPPLE w2.812"Profile 2.812 8,016.6 5,857.4 47.84 LOCATOR BAKER LOCATOR 2.990 8,017.4 5,858.0 47.84 SEAL ASSY BAKER 80-40 SEAL ASSY.Fully Located 1'Spaced Off 2.990 GAS LIFT;2313.4 Ff NoGo Seals Engaged 10.86' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection TUBING-Original 31/2 2.992 8,018.4 8,082.3 5,901.7 9.30 J-55 EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Tap(noir) Item Des Corn (in) 8,018.4 5,858.6 47.83 PBR BAKER 10'STROKE PBR 3.000 8,032.1 5,867.9 47.77 PACKER BAKER HB RETRIEVABLE PACKER 3.500 8,048.4 5,878.9 47.69 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,081.6 5,901.2 47.54 SOS BAKER SHEAR OUT SUB 2.992 SURFACE;420-4,607.2 - Perforations&Slots Shot Den Top(TVD) Btm(ND) (shots/ s GAS UFT;7,890.8 II Top(ftKB) etm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Cent 8,170.0 8,242.0 5,961.0 6,009.9 C-4,1L-17 8/18/1991 6.0 APERF 21/8"Flow Jet Perf;0 deg.ph 8,342.0 8,370.0 6,078.1 6,097.3 A-5,1L-17 6/21/1991 4.0 IPERF 4.5"Csg Guns;180 deg. ph;Oriented 25 deg. CCW LOCATOR;7,946.8 8,405.0 8,420.0 6,121.1 6,131.3 A-4,1L-17 3/27/2012 6.0 (PERF HES 2.5"Perf Gun,60 Deg,DP Charges SEAL ASSY;7,947.1 8,446.0 8,460.0 6,149.1 6,158.6 A-4,1L-17 6/21/1991 4.0 (PERF 4.5"Csg Guns;180 deg. 1Mt ph;Oriented 25 deg. PACKER;7,954.1 CCW 90-o'P Mandrel Inserts St NIPPLE;7,998.9 El t o t N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn LOCATOR;8,016.60 l 1 2,313.4 1,997.3 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 1/11/2014 4:30 2 7,890.8 5,773.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/29/2013 7:30 SEAL ASSY;8,017.4 - Notes:General&Safety PRO;8,018.4 End Date Annotation PACKER;8.0321 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 2. NIPPLE;8,048.4 e9 SOS;8,081.6 -4 APERF;8,170.0-0.242.D--. IPERF;8,342.0.0,370.0- 4 IPERF;8.405.0-8.420.0-. IPERF;8,446.0.0,460.0- PRODUCTION;32.3.8,675.3 41, • 1L-17 Proposed CTD Schematic 3-1/2"Camco DS Landing Nipple @ 491'MD(2.875"ID) 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62#H-40 shoe @ 122'MD 3-1/2"Camco MMG gas lift mandrel @ 2313'&7890'MD 9-5/8"36#J-55 shoe Baker 80-40 Seal Assy @ 7947'RKB(7940'ELM) @ 4607'MD Baker FHL packer @ 7954'RKB(7947'ELM)(2.93"ID) 3-1/2"Camco DS Landing Nipple @ 7999'RKB(7992'ELM) (2.812"ID) Baker 80-40 Seal Assy @ 8017'RKB(8010'ELM)(2.99"ID) j","., Baker PBR @ 8018-8036'RKB(8011'-8029'ELM) 1991 Completion Baker HB Retrievable Packer @ 8032'RKB(8025'ELM)(3.5" ID) 3-1/2"Camco D-Nipple @ 8048'RKB (8041'ELM) (2.75"min ID. Will be drilled out to 2.80"ID) 3-1/2"Baker SOS @ 8082'RKB(8075'ELM) 1L-17AL1 WPO(north-west) KOP@8193'MD TD@11,800'MD Liner top @ 8075'MD C-sand perfs 8170'-8242'MD --� -------------------------------------------------------- -- A-sand perfs 8342'-8370'MD 8405-8420'MD 8446'-8460'MD 1L-17A WP04(south-east) TD @ 12,500'MD Billet @ 8240'MD 7"26#J-55 shoe @ 8675'MD 0 0 .$7.. \ '-',_i D } / k 43 id k j § § s § k § ; 5 § 7 7 IL' ; m ! t k q $ ti� fl - ( m m Cr % - $1 } ) ( \ ) ( \ )_ 0 2! \ \ / \ . / ti D 0 • \\ / -- - - Q. - - mE / < 2 ¢( * El !! = , Z } 6 - !* R* - 3 §> ELa 6' : - z ! }\ \ \ !} \\ v _ 4 4 ; 5 } { - ( ( 2 ( - ) E : ` §C { / '\ \/ a« g a; g Vi - \ z k ) & » ; / - . 0" t 2 e 5 , | : ! (! - - - I ( . B\ � LI ,f 73 y. \ \ { \\/ \ \\ 5. $ g § \ \ \ / `I ; - - - - « • Loepp, Victoria T (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Thursday,April 14, 2016 9:13 AM To: Loepp,Victoria T(DOA) Cc: Eller,J Gary;Samuell,John G Subject: RE: KRU 1L-17A(PTD 216-053)Anti-collision Victoria We have risked these well bores as minor risk, meaning the risk is purely economic, no HSE risk is evident. As far as a deep plug, we do not intend to set one because the 1L-24, 1L-24A and 1L-24AL1 will be drilled in the A sand package. The 1L-17A&AL1 will be drilled in the C sand. There is a 50'thick section of impermeable B shale separating the two sands in this area. Let me know if this is satisfactory. Thanks C I'Y �c� R e 5 P Lid 2x 3 0h5I Jason 24'' �� 3G1`� ' -J cir ) ird Isr A- Ste( ConocoPhillips Jason Burke CID Engineer- Greater Xuparuk Area 700GSt#1210 Anchorage,AK 99501 (0):(907)-265-6097 (4):(907)-231-4568 Jason.Burke@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,April 13, 2016 3:10 PM To: Burke,Jason<Jason.Burke@conocophillips.com> Subject: [EXTERNAL]KRU 1L-17A(PTD 216-053)Anti-collision Jason, KRU 1L-24, 1L-24A and 1L-24AL1 fail major risk on the anti-collision analysis. Will a deep plug be set or will this well be SI at surface to mitigate this risk while drilling the 1L-17A? If not,why not? 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 aC�alaska.gov 1 • • Bettis, Patricia K (DOA) From: Burke, Jason <Jason.Burke@conocophillips.com> Sent: Thursday, April 07, 2016 8:22 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1L-17A (PTD 216-053): Permit to Drill Application 3790 psi, sorry for the confusion C noca hif i riS Jason Burke CID 'Engineer - Greater!Kupartiii Area 700 r7 St#1210 Anchorage, 2'4 99501 (0): (907)-265-6097 (.Ni): (907)-231-4568 Jason.Burke@conocophillips.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, April 06, 2016 3:44 PM To: Burke,Jason <Jason.Burke@conocophillips.com> Subject: [EXTERNAL]KRU 1L-17A(PTD 216-053): Permit to Drill Application Good afternoon Jason, On Form 10-401, Box 17, the maximum downhole pressure is listed as 3790 psi. In the Application for Permit to Drill Document, page 2, the maximum formation pressure in the area is stated as 3702 psi. Please advise which pressure is correct. 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, April 06, 2016 3:44 PM To: Burke,Jason (Jason.Burke@conocophillips.com) Subject: KRU 1L-17A (PTD 216-053): Permit to Drill Application Good afternoon Jason, On Form 10-401, Box 17,the maximum downhole pressure is listed as 3790 psi. In the Application for Permit to Drill Document, page 2,the maximum formation pressure in the area is stated as 3702 psi. Please advise which pressure is correct. 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(a alaska.gov. 1 • • 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: KL PTD: a)G - 053 Development ( 'Service Exploratory Stratigraphic Test Non-Conventional FIELD: Xurkrui._ POOL: lL ��/�E✓ c� � �►U �',I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving 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 AOGCC must be in no greater Dry Ditch Sample than 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 Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC 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 2/2015 • 0 Nco , °) o , o a , cn U) _o of 0' , 0, ai' ru c co� g rQ F. 0 . 0' c' 2 0 Z C' @ m: CU W• tocn t: c. w: O c a) N m: o , as, o 3 .4- E O a s a)) '0 as ` c: a2cu U, ' r' c:co a ,� t, _: w 3 a): V: o: �: N, ,`°n: , of a 2 �: 3: 3, y, 3, a NLF- CO. V. y: N ° Ev p co, 0 V, , , N a ,, •0 o o: ,_ E, a 0 y, 2 0 c: �, , U> E , a , 5, v? a N o �: ° o O �: 4 m v, �, a +l) c,d d' 'N QY a c ,- c, . D' �: N. 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