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217-065
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Y a) 1 C• U n c -6. j g m O Q Z E 0 C > I 0• c c O 2 0 E pa coC)) v Z Cl) (n 11 m a`) `m (5 }p N n O N a) Q Q Q N N `L - m 2 2 a is 0 Z p N co 0 J J la I, E L. Qe >_ (O 6 .. ii, > oo WO CO - vvvvco 00 o0 op I u� E a 0 3 NN N N CO CO N 0 o O (A N O. N Q C N = a) ',,, 1III d Q ces M (/� 10 0 d' F (6 1''. 0 0 U C I d Oc.0 in Z Q 0 0 Z 0 CO 0 C 0 U 0) 00 0 0 0 0 ` 2 N U cy) J N O- 0 co C�7 rn m 0 O E •o o 2 0. E a) w I E E OQ a W J J W W °� LL I Z 0 0` 0 0 0 TD o 0 1 0 ;3 RECEIVED • STATE OF ALASKA • JUL j i 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LiiMGCC 1a.Well Status: Oil Ell Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0• Exploratory❑ GINJ ❑ WINJ❑ WAG❑ 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.: 6/30/2017 217-065 • 3.Address: 7. Date Spudded: c.%- 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 61.3 017 640 50-029-21024-01-00 - 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 4971'FNL,4839'FEL,Sec 29,T12N, R10E, UM 6/14/2017 • KRU 1G-15A/1G-15APB1 . Top of Productive Interval: 9. Ref Elevations: KB:97 17. Field/Pool(s): 4355'FNL, 1666'FEL,Sec 30,T12N, R10E, UM GL:56 BF: Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2757'FNL,2311'FEL,Sec 30,T12N,R10E, UM N/A ADL 25640 . 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 540221 y- 5980956 Zone- 4 9863/6489 • • 931813000 TPI: x- 538109 y- 5981561 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MDlTVD: Total Depth: x- 537450 y- 5983155 Zone- 4 N/A 1642/1642 5. Directional or Inclination Survey: Yes E (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) 7017/6519 • 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 Surf 114 Surf 114 24 212 sx CS II 10 3/4 45.5/55.5 J-55/L-80 Surf 2200 Surf 2200 13 1/2 1100 sx Permafrost E&250 sx Permafrost C 7 26 J-55 Surf 7502 Surf 6935 8 1/2 750 sx Class G&250sx Permafrost C 2 3/8 4.7 L-80 7860 9545 6448 6459 3 Slotted Liner 24.Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 4 1/2 x 3 1/2 7116 5671/5384 6558/6126 SLOTTED LINER @ 7871 -7879 MD and 6448-6448 ND 6670/6222 SLOTTED LINER @ 7881 -9545 MD and 6448-6459 ND 7086/6578 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. ._,.-,MPLEI ION Was hydraulic fracturing used during completion? Yes❑ No 2 ()ATE Per 20 AAC 25.283(i)(2)attach electronic and printed information (or /1 ,. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED - L L- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 7/4/2017 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 7/6/2017 10.27 Test Period 1330 879 2184 176 bean 660 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 228 1155 24-Hour Rate ....► 2847 1441 5022 21 For 110$73Rpv7sed 5/2017 V72- 8h`1CONTINUED ON PAGE 2 RBDMS C, -- AUG - 2017 Submit ORIGINIAL only. • • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS • NAME MD ND Well tested? Yes LI No ❑ Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1642 1642 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 7755 6464 information, including reports,per 20 AAC 25.071. Formation @ TPI-Kuparuk C TD 9863 6493 1G-15APB1 9150 6460 TD Formation at total depth: Kuparuk C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.oer 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. �/� Authorized Name: J.Ohlinger Contact Name: William Long a263-4372"7 e- Authorized Title: Staff D Engineer Contact Email: William.R.LongAcop.com Authorized Contact Phone: 265-1102 Signature: Date: 7/11//7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • • • • • 1G-15A CTD Schematic II�� rP1-, 911-17 -997:-1T s`!" le 4-1/2"Cameo DB nipple @ 496'MD(3.75"min ID) 11 16"626 H-40 shoe 4-1/2"12.68 L-80 EUE 8rd Tubing to surface 1 C 114'MD 4-1/2"Cameo gas lift mandrels @ 2586',3823',4909',5617'MD r_ ' Baker Premier Packer @ 5671'MD(3.875"ID) 4-1/2"Cameo DB nipple @ 5684'MD(3.75"min ID) 10-3/4"40#J-55 shoe—.wen' III . 4-112"Cameo gas lift mandrel @ 5727'MD @ 2202'MD Crossover 4.5"x 3.5"@ 6524'MD Baker 80-40 POR @ 6542'MD — Baker FHL Packer @ 6558'MD Otis X-Nipple @ 6597'MD(2.813"ID) Irl Overshot @ 6630'MD I' Otis SBR @ 6644'MD(2.813"ID,X-pmftle) Otis Packer @ 6670'MD 3-1/2"Otis production mandrels @ 6708'and 6777'MD BLAST JOINTS across Perfs 3-1/2"Otis production mandrel @ 7045'MD Otis WD Packer @ 7086'MD(4.0"ID) C-sand perfs(sqz'd) / Otis Mill Out Ext.@ 7089'MD 6834'-6838'MD 6843'-6880'MD 3-1/2"Cameo D landing nipple @ 7105'MD 6890'-6898'MD I,- " , 2.75"min ID 6954'-7007'MD _" - CA-2 Plug Installed -.. . -' ," 10'of sand on plug ii . x- -Cement spotted between GLM5. _, / -Squeezed into C-sand perfs. 1G-15AL1 (C3/C4 sand) -Milled out for whipstock. ;, " j TD 3 8"9625'MD 2-318"Slotted Liner,Bottom @ 9598' Aluminum Billet on OH Anchor @ 7835' Baker Monobore XL s'• ---_..-___-._-- Whi stock Tray on OH �. / �_ - - - _ :.+�.. P Y .,3 � / _� - .r. .- -- --�� 1G-15AD (Cl sand) Anchor @ 7017'MD r {;�- ,4%. 9863'MD Baker Monobore XL rmaw -y "®� �`-' -iti---- 2-3/0"Slotted Liner Whipstock Tray on OH7•?,..--t- , I / _ C= .. Aluminum Billet on Anchor @ 7860' Anchor @ 7033'MD - Bottom of Liner @ 9545' A-sand perfs(plugged) - '-'•-.,,,......-m...._=G FISH •�--- �-^' -�'�•=----�-� �. Lower Halt Weatherford Motor 7193'-7230'MD I.w>lMoen and Rotor @ 9564' ; I `k'- 1G-16AL2(Ctsand) TD @ 9424'MD 1G-15APB1(C1 sand Plug Back) 2-3/8"Slotted Liner,Bottom @ 8462' TD @ 9150'MD 2-3/8"Solid Liner,Bottom @ 7786' Halliburton Swell Packer @ 7056' 26#J-55 Faulted Out of Zone 7" shoe .7502'MD Seal Bore Deployment Sleeve @ 6612' Hole Collapse in Build L KUP PROD 1G-15 ConocoPhillips 4 Well Attribt• Max Anglia) TO Alcl�ki , .Irii; Wel!boreAPIIUWField Name Wellbore Status ncl(°) MD Act Btm(ftKB) conocoPhilips'X 500292102400 KUPARUK RIVER UNIT PROD 38.12 5,325.00 7,533.0 ... Comment H2S(ppm) Date Annotation . End Date KB-Grd(tt) -Rig Release Date 15-15,7/31/2017 9:37:52 AM SSSV:NIPPLE 450 7/31/2015 Last WO: 7/7/2004 41.00 10/29/1983 Vertical schemes°(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;31.3Last Tag:SLM 7,166.0 10/25/2014 Rev Reason:SIDETRACK,SET PACKER jennalt 7/19/2017 1135141 Ca Is ng Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(1...Grade Top Thread ,1CONDUCTOR 16 15.060 36.0 114.0 114.0 63.00 H-40 WELDED 4U,,,,,,,,,,,,,,"„,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,a' „u ,.,,,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wilen(I...Grade Top Thread SURFACE 10 3/4 9.950 36.5 2,202.3 . 2,202.1 40.00 J-55 BTC ,�Casing Description 01)(in) ID(in) Top(ftKB) Set Depth(ftKB) •Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;36.0.114.0-4 PRODUCTION 7 6.276 34.2 7,502.2 6,934.4 26.00 J-55 BTC NIPPLE;496.5 Tubing Strings Tubing Description Shing Ma...ID(in) Top(CAB) Set Depth(fL..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING _41/2 3.958 31.3 6,543.9 6,113.7 12.60 L-80 IBT-MOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) SURFACE;36.52,202.3 31.3 31.3 0.00 HANGER MCEVOY TUBING HANGER 3.958 496.5 496.5 0.58 NIPPLE CAMCO DB-8 LANDING NIPPLE 3.813 GAS LIFT;5585.9 - 5,671.2 5,384.0 35.56 PACKER BAKER PREMIER PACKER 3.875 5,683.8 5,394.3 35.56 NIPPLE CAMCO DB NIPPLE 3.750 . 6,523.5 6,096.2 30.68 XO Reducing CROSSSOVER 4.5 x 3.5 3.500 GAS LIFT;3,622.8 t. 6,532.3 6,103.7 30.61 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 1998 31/2 2.992 6,542.0 - 6,637.3 6,194.2 9.30 L-80 EUE8RMOD GAS LIFT;4,908.7-1 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 0 Item Des Corn (in) GAS LIFT;5,617.5 6,542.0 6,112.1 30.51 PBR BAKER 80-40 PBR 2.813 6,558.4 6,126.2 30.39 PACKER BAKER FHL RETRIEVABLE PACKER 2.969 6,597.1 6,159.6 30.55 NIPPLE OTIS X LANDING NIPPLE SELECTIVE PROFILE(SET 2.813 PACKER;5,671.2 8/10/99) - 0. 6,630.1 6,188.0 30.61 OVERSHOT OVERSHOT,NO SEALS,MAX OD 5.99"SET 8/10/1998 2.930 NIPPLE;5,683.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;5,7266 TUBING 1984 4 1/2 2.867 6,630.0 7,115.7 6,603.3 9.30 J-55 FL4S Completion Details Nominal ID . Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Corn (in) 6,643.8 6,199.8 30.56 SBR OTIS SBR 2/2.813 X-PROFILE SET 8/10/1998 2.813 SEAL ASSY;6,532.3 6,669.9 6,222.3 30.64 PACKER OTIS RRH PACKER 2.970 6,815.8 6,347.9 30.67 BLAST CARBIDE BLAST RINGS(3) 2.867 PBR;6,542.0 RINGS PACKER;8,558.4ig 6,928.0 6,443.9 31.65 BLAST CARBIDE BLAST RINGS(3) 2.867 NIPPLE;8,597.1 1 tl RINGS 7,084.0 6,576.3 31.75 LOCATOR OTIS LOCATOR 3.000 ,.:.II•.. 7,085.5 6,577.6 31.74 PACKER OTIS WD PACKER 4.000 Packer,6,611.0 II;r 7,089.2 6,580.7 31.73 MILL EXT OTIS MILL OUT EXTENSION 4.410 OVERSHOT;6,830.1, 1it 7,105.2 6,594.4 31.65 NIPPLE CAMCO D NIPPLE NO GO 2.750 TUBING;6,630.0 I i- I SBR;6,643.6 I7,114.9 6,602.5 31.59 WLEG OTIS WIRELINE RE-ENTRY GUIDE,ELMD TTL @ 7111 3.000 during PPROF on 3/9/2006 PACKER;6,669.9 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PRODUCTION;6,707.5 11.t. Top(ND) Top Incl la Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) PRODUCTION;6,777.1 f'. 6,611.0 6,171.6 30.60 Packer BAKER 35 KB LINER TOP PACKER("'2500 MAX 7/3/2017 1.870 iit PSI"")(9CR)W/2-3/8"STINGER(12'OAL/2.77" ( MAXO.D./3"G-FN), . 7,018.0 6,520.2 32.04 WHIPSTOCK WS#2 6/8/2017 0.000 • (PERF;6,834.08,838,0 -THRU TBG IPERF;8,843.08,880.0 7,032.0 6,532.1 31.98 WHIPSTOCKTHRUTBG WS#1 6/1/2017 0.000 IPERF;8,890.08.895.0 7,095.2 6,585.8 31.70 SAND DUMP BAILED 10'OF SAND ON PLUG 10/25/2014 0.000 7,105.2 6,594.3 31.65 PLUG 575"CA-2 PLUG 10/25/2014 0.000 Cement Squeeze;6,800.08K13 _ 7,510.0 6,941.1 30.92 FISH DROPPED 1"HFCV,BEK LATCH TO BOTTOM 1/14/2009 0.000 IPERF;6,954.0-7,037.0--. Perforations&Slots "AL2'Lateral Liner;8,611.5 Shot 8,482.0N N Dens WHIPSTOCK-THRUTBG; \II. Top(TVD) Btm(TVD) (shots) 7.018.0 A Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com ' 6,834.0 6,838.0- 6,363.5 6,367.0 C-4,1G-15 1/31/1984 12.0 IPERF 120 degPhasing;5"DA t WHIPSTOCK-THRUTBG; 9 7,032.0 �I` 1- 6,843.0 6,880.0 6,371.3 6,402.9 C-4,10-15 1/31/1984 12.0 IPERF 120 deg Phasing;5"DA � PRODUCTION;7,045.1 W- 6,890.0 6,895.0 6,411.5 6,415.7 C-3,10-15 1/31/1984 12.0 IPERF 120 deg Phasing;5"DA .( 6,954.0 7,007.0 6,466.0 6,510.9 C-1,1G-15 1/31/1984 12.0 IPERF 120 deg Phasing;5"DA LOCATOR;7,084.0 t r.. . 7,193.0 7,230.0 6,669.3 6,701.0 A-5,A-4,A-3, 5/23/1984 8.0 APERF 90 deg Phasing;2 1/16" OEM 4 1G-15 RigidJet PACKER;7,085.5 ` Cement Squeezes MILL EXT;7,089.2 SIT / Top(ND) Btm(ND) SAND;7,095.2. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn NIPPLE;7,105.3 1 PLUG;7,105.2, ;%// 6,800.0 7,095.0 6,334.3 6,585.6 Squeeze Cement 5/8/2017 BATCHECEMNETDUP 30 BBLS CEMENT,15 BBLS FBER,PARKED AT 7080' UM EDITH �u CEMENT WLEG;7,114.9 ■, Mandrel Inserts APERF;7,193.0-7,230.0 f a t ti N Top(TVD) Valve Latch Port Size TRO Run Top((KB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,585.9 2,585.7 CAMCO KBG-2 1 GAS OFT GLV BK 0.188 1,260.0 5/3/2008 2 3,822.8 3,821.6 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0'5/3/2008 3 4,908.7 4,777.2 CAMCO KBG-2 1 GAS LIFT DMY BK-3 0.000 0.0 7/7/2004 PRODUCTION;34.2-7,502.2 4 5,617.5 5,340.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 7/13/2004 FISH;7,510.0 r KUP PROD 1G-15 Co aPhillips ' ° • • Alaska,Inc. CannmPhillips 1G-15,7/31/2017 9:37:53 AM Vedical echematm(actual) HANGER;31.3 ,, tlt MI 1an.re nse 4L 21 at ���i,. RI"50 °nl Top(TVD) Valve Latch Port See TRO Run pp 10,1,,, Top(kKB) (kd ) ry (in) (psate Com 5 65726.6 5,429.1KB) CAMCOMake KBG-2Moel OD(in1 GASSeLIFT DMYTypo BK-3Type 0.000 0.0i) 717/Run200D4 coNDucroR;3s.aila.o11111 u----6777.1 6,314.6 OTIS Him PROD OPENIii 0.000 0.0 5/007 17 7 1111 NIPPLE;496.5 8 7,045.4 6,543.5 OTIS SPM 1 PROD HFCV BRK 0.000 0.0 3/24/2014 ' Notes:General&Safety End Date Annotation 3/10/1998 NOTE:Ran KINLEY Caliper Log from 6444'RKB to Surface on 3/10/98 . SURFACE;36.5-2,202.3 11/8/1998 NOTE:ORIGINAL COMPLETION BELOW 6630' 7/7/2004 NOTE:EXISTING COMPLETION PLUS ORIGINAL COMPLETION,BELOW 6542' GAS LIFT;2,585.9 L,--� 7/7/2004 NOTE:TREE: McEVOY/GEN 1 RETROFITTED TO CAMERON GEN 4 I. 9/21/2010 NOTE:Mandrels @ 6707-7045-MACCO SLOTTED DPI-IF 9/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;3,822.8 3/24/2014 NOTE:BROKEN LATCH AT 7045'RKB GAS LIFT;4,908.7 li Ii GAS LIFT;5,617.5 III PACKER,5,671.2 — NIPPLE;5,683.8 WM.GAS UFT;5,728.8 V SEAL ASSY;6,5323 PBR;8,542.0 PACKER;8,558.4 NIPPLE;0,597.1 9.J. Packer;6,611.0 , OVERSHOT;8,630.1. rte. TUBING;6,630.0 77771111 SBR;6,643.8 II_,� PACKER;6,669.9 PRODUCTION;6,707.5 p PRODUCTION;8,777.1 1 IPERF;6,834.08,838.0-- a 1 IPERF;6,843.0-6,880.0— S IPERF;6,890.0-6,895.0-- M 0 'PL Cement Squeeze;8,000.0 kK8 � k IPERF;8,954.0-7,007.0—� k �I R "AL2"Lateral Liner,8,611.5- ` 0 8 IN 8,4620 4 WHIPSTOCK-THRUTBG; .GIl 7,018.0 l WHIPSTOCK-THR7 OT3B2 ti'L.s 1 PRODUCTION;7,045.4 ,--' I. 1 LOCATOR;7,084.0 s rEM Om o PACKER;7,085.5 O. .. MILL EXT;7,089.2 �t�—I''), SAND;7,095.2, NIPPLE;7,105.3 PLUG;7,105.2 —,f. WLEG;7,114.9 =I` APERF;7,193.0-7,230.0 I PRODUCTION;34.2-7,502.2 FISH;7,510.0 UP PROD 1G-15A Conoco Phillips 1 I Attributes • Max Angle&MD ID Alaska,irk; Wellbore API/UWI Field Name Wellbore Status Incl(°) MD INKS) Act Btm(ftKB) CoruxoPtnlGps, 500292102401 KUPARUK RIVER UNIT PROD 103.26 7,305.64 9,863.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-15A,7/31/2017 9:38:59 AM SSSV:NIPPLE 450 7/31/2015 Last WO: 41.00 10/29/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;31.3 Last Tag: Rev Reason:SIDETRACK,SET PACKER jennalt 7/19/2017 ia Casing Strings iCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread I "A"Lateral Liner 2 3/8 1.992 7,860.0 9,545.0 6,459.0 4.70 L-80 ST L l' lwmmwnmuuummm.,Iummnunuuwuwn'/wL ui u_b Liner Details Nominal ID j,.,_,ti Top INKS) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;36.0-114.0-4 l 7,860.0 6,448.4 94.31 ALUMINUM OH Anchor&Aluminum Billet 1.920 NIPPLE;496.5 O BILLET 7,879.9 6,447.2 92.92 SHORTY Shorty Deployment Sleeve DEPLOYMENT ppp SLEEVE Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl SURFACE;36.5-2,202.3 Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 7,055.0 6,549.7 43.27 Barrier- HES Swell packer 6/29/2017 1.683 0.000 GAS LIFT;2,585.9 Packer 9,564.0 6,461.5 82.48 FISH Weatherford rmotor parted at AKO junction,Left 2,2' 6/14/2017 of motor tip,.65'Si center bit GAS LIFT;3,822.8 f Notes:General&Safety End Date Annotation NOTE: GAS LIFT;4,908.7 11 GAS LIFT;5,617.5 g PACKER;5,671.2 ; ;�" NIPPLE;5,683.8 GAS LIFT;5,726.6 I 1 SEAL ASSY;6,532.3 — PBR;6,542.0— ik _. PACKER;6,558.4 ' ' NIPPLE;6,597.1 Packer,6,611.0 -.xji` OVERSHOT; 1, Ft TUBING;6,630.0 SBR;6,643.8 PACKER;6,669.9 IMI PRODUCTION;6,707.5 ;,.1$ RR PRODUCTION;6,777.1 1II: ¢ II _ IPERF;6,834.0-6,838.0 — IPERF;6,843.0-6,880.0 —_ IPERF;6,890.0-6,895.0— ¢ _ Cement Squeeze;6,800.0 ftKB p St 0 111 IPERF;6,954.0-7,007.0 0 IIII ¢ ';i PRODUCTION;34.2-7,502.2 4 tX0p ------\ KU PR*® 1 G-15ALI ono oPhiflips 0 Well Attri Max Ang D TO AlaSIC( Ill Wellbore API/UWI Field Name Wellbore Status ncl(°) MD Act Btm(ftKB) canocoPhilllps'4 500292102460 KUPARUK RIVER UNIT PROD I 103.76 8,150.46 9,625.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-15AL1,7/31/20179:39.34 AM 450 7/31/2015 Last WO: 41.00 10/29/1983 Vertical schemer=(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;31.3x(1 Last Tag: Rev Reason:SIDETRACK,SET PACKER jennalt 7/19/2017 45 LiIP Casing Strings [� { Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I "ALLateral Liner 2 3/8 1.992 7,835.0 9,603.2 6,369.2 4.70 L-80 ST L ' mw Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Corn (ie) 0 r'" 7,835.0 6,451.0 97.44 ALUMINUM OH Anchor 8 Aluminum Billet 1.920 CONDUCTOR;38.0114.11 BILLET NIPPLE;498.5 7,856.7 6,448.7 94.74 SHORTY Shorty Deployment Sleeve DEPLOYMENT SLEEVE ONotes:General&Safety End Date Annotation SURFACE;36.5-2,2023 4 L NOTE GAS LIFT;2,585.9 I, �1 GAS LIFT;3,822.8 GAS LIFT;4,9087 GAS LIFT;5,817.5 PACKER;5,571.2 NIPPLE;5,683.8 M GAS LIFT;5,728.8 SEAL ASSY,6,532.3 PBR;6,542.0 PACKER;6,558.4 NIPPLE;6,597.1 Ill E_ la Packer;6,611.0 r.flhr OVERSHOT;6,630.1` t' 11 TUBING;6,630.0 /, SBR;6,643.8 1 I e. PACKER;6,669.9 M PRODUCTION;6,707.5 •k PRODUCTION;8,777.1 f S W _ IPERF;6,834.06,838.0 k — b '_ IPERF;6,843.06,880.0- . S. — IPERF;6,890.06,895.0--. 0 Cement Squeeze;6,800.0 ftKB 4t r IPERF;6,954.0-7,007.0— I ` I PRODUCTION;34.2-7,502.2--- l I I Barrier-Packer,7,055.0 43 ,n m'1 kt "AL2'Lateral Liner,6,611.5- 5462 0 6,462.0 \Srre I I I "AL1'Lateral Liner,7,835.0- 9,803.2—''-- SCUP 400 1 G-15AL2 ono oPhillips 4 Well Attrib Max AngIOD TD Alaska,lilt", Wellbore API/UWI Field Name Wellbore Status ncl(°) MD Act Btm(ftKB) cmocoehalips 500292102461 KUPARUK RIVER UNIT PROD 103.26 7,305.64 9,424.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-15AL2,7/31/20179:40.11 AM 450 7/31/2015 Last WO: 41.00 10/29/1983 Vertical achemabc(actual) Annotation Depth(01(B) End Date Annotation Last Mod By End Date HANGER;31.3 • Last Tag: Rev Reason:SIDETRACK,SET PACKER jennalt 7/19/2017 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread "AL2"Lateral Liner 2 3/8 1.992 6,611.5 8,462.0 6,424.2 4.70 L-80 ST-L Liner Details •••••••,•••"^`••YBJWt•"^^""""""' C ilttt�+l auk Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(1 Item Des Com (in) 6,611.5 6,172.0 30.60 SBR Deployment Sleeve w/6'Sealbore Receptical(PBR) 1.000 CONDUCTOR;38.0-114.0 NIPPLE;486.5 7,055.7 6,550.2 43.58 SWELL PACKER Swell Packer-Halliburton 1.686 7,826.1 6,452.2 97.69 DEPLOYMENT Shorty Deployment Sleeve 1.992 SLEEVE 0 Notes:General&Safety End Date Annotation SURFACE;36.5-2,202.3-J NOTE: GAS LIFT;2,585.8 s_. GAS UFT;3822.8 GAS LIFT;4,908.7 GAS LIFT;5,617.5 PACKER;5,671.2 NIPPLE;5,683.8 GAS LIFT;5,726.6 r SEAL ASSY;6,532.3 PBR;6,542.0 PACKER;6,558.4 - - I NIPPLE;6,597.1 - a j�a Packer,6,611.0 1 Alla, 4 a OVERSHOT;6,630.1, TUBING;8,630.0 SBR;6,643.8 PACKER;8,669.8 ;Ls PRODUCTION;6,707.5 PRODUCTION;6,777.1 F'ycj IPERF;6,834.0-6,838.0- al t 1 IPERF;6,843.0-6880.0- MERE; ,843.08,880.0IPERF;8,890.0-6,895.0- 1 Cement Squeeze;8,800.0 ftKB IPERF;fi,954.0.7,007.0� I i t PRODUCTION;34.2-7,502.2-. 90 Brinier-Packer,7,055.0 ALD'Lateral Liner,6,611.5- 8,462.0 Aerations Summary (with Timelog IIepths) ..: 1G-15 rocoPhiliips • Ai.rka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log . Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/30/2017 5/30/2017 6.00 MIRU MOVE MOB P Jack up/Move to 1G-pad 0.0 0.0 12:00 18:00 5/30/2017 5/30/2017 2.00 MIRU MOVE MOB P RU tree and configure single swab 0.0 0.0 18:00 20:00 setup,secure cellar floor. 5/30/2017 5/30/2017 1.50 MIRU MOVE MOB P Spot Sub Module,and lower stack 0.0 0.0 20:00 21:30 5/30/2017 5/31/2017 2.50 MIRU MOVE MOB P PJSM,Spot Pit Sub,became stuck in 0.0 0.0 21:30 00:00 middle of pad,call for additional dozer support,back pit module up dress pad,lay plywood on outside premiter, second dozer on location,spot in Pit Module. 5/31/2017 5/31/2017 1.00 MIRU MOVE MOB P Finish spotting in Pit Module.PU 0.0 0.0 00:00 01:00 plywood,work on post rig move checklist. 5/31/2017 5/31/2017 8.00 MIRU MOVE MOB P Tighten Tree and BOP bolts,secure 0.0 0.0 01:00 09:00 stack,install tango valves,RU MP line,perform post move checklist, changeout risers,grease all surface valves,valve crew serviced wellhead 5/31/2017 5/31/2017 9.50 MIRU WHDBOP BOPE P Start initial full BOPE test,250 psi 0.0 0.0 09:00 18:30 low/3,800 psi high,fail pass on R2,. Lower blind shear ram Fail,Test witness waived by Guy Cook, AOGCC, RIG ACCEPT,fluid pack stack,good shell test,re-test lower blind shear rams good test. 5/31/2017 5/31/2017 1.50 MIRU WHDBOP CTOP P PJSM,fluid pack stack,shell test, re- 0.0 0.0 18:30 20:00 test lower blind shear rams,stab INJH,test inner reel valve and stripper good tests 5/31/2017 5/31/2017 1.00 MIRU RIGMNT CTOP P Perform slack management,bring 0.0 0.0 20:00 21:00 pumps 1 &2 up to 2.2 bpm @ 4,100 psi,heard wire move,shut down pump,restarted heard wire move again,shut down,restart no movement,shut down pump,bleed pump pressure off,unstab INJH 5/31/2017 6/1/2017 3.00 MIRU RIGMNT CTOP P PJSM,RU rig floor for cutting coil,cut 0.0 0.0 21:00 00:00 coil found wire at 212'.***212'of slack in reel***Continue trimming coil, 1,200'of coil cut 6/1/2017 6/1/2017 1.80 MIRU RIGMNT CTOP P Test e-line(good test),Dress and 0.0 0.0 00:00 01:48 Install CTC, Pull Test 35 k. 6/1/2017 6/1/2017 1.80 MIRU RIGMNT CTOP P Rehead BHI UQ,test a-line(good 0.0 0.0 01:48 03:36 test),PT CTC to 4,000 psi,PT tiger tank line,and PDL. 6/1/2017 6/1/2017 0.50 SLOT RIGMNT SFTY P PJSM,Check well for flow(no-flow), 0.0 0.0 03:36 04:06 unstab INJH 6/1/2017 6/1/2017 0.80 SLOT RPEQPT PULD P MU BHA#1 w/dummy WS. 0.0 71.1 04:06 04:54 6/1/2017 6/1/2017 1.50 SLOT RPEQPT TRIP P RIH,pumping 1.5 bpm pumping slack 71.1 6,465.0 04:54 06:24 forward,w/dummy WS 6/1/2017 6/1/2017 0.40 SLOT RPEQPT DLOG P Log HRZ for correction of minus 2.5' 6,465.0 6,535.0 06:24 06:48 6/1/2017 6/1/2017 0.10 SLOT RPEQPT TRIP P Continue in well 6,535.0 6,648.0 06:48 06:54 6/1/2017 6/1/2017 0.20 SLOT RPEQPT DLOG P Log K1 marker,inconclusive no 6,648.0 6,693.0 06:54 07:06 correction 6/1/2017 6/1/2017 0.10 SLOT RPEQPT TRIP P PUH to make CCL Pass 6,693.0 6,659.0 07:06 07:12 Page 1/37 Report Printed: 7/3/2017 • ; 5 gperations Summary (with Timelogepths) 1G-15 t~: Con000Philliips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/1/2017 6/1/2017 0.60 SLOT RPEQPT DLOG P Set tool to CCL mode,Log down,set 6,659.0 7,090.0 07:12 07:48 down @ 7090,Sensor depth 7030 6/1/2017 6/1/2017 0.40 SLOT RPEQPT CIRC P Complete swapping coil to milling fluid 7,090.0 7,080.0 07:48 08:12 6/1/2017 6/1/2017 1.20 SLOT RPEQPT TRIP P Trip out displacing to milling fluid 7,080.0 85.0 08:12 09:24 6/1/2017 6/1/2017 0.70 SLOT RPEQPT PULD P Tag up,flow check,back off injector, 85.0 0.0 09:24 10:06 L/D BHA#1 6/1/2017 6/1/2017 0.80 PROD1 WHPST PULD P P/U BHA#2,whipstock with open hole 0.0 74.0 10:06 10:54 anchor,Hook up to coil and surface test.Change out pack offs 6/1/2017 6/1/2017 1.70 PROD1 WHPST TRIP P RIH,EDC open,Min rate 74.0 6,465.0 10:54 12:36 6/1/2017 6/1/2017 0.30 PROD1 WHPST DLOG P Log HRZ for-3'correction 6,465.0 6,505.0 12:36 12:54 6/1/2017 6/1/2017 0.50 PROD1 WHPST TRIP P Continue in to setting depth, 6,505.0 7,043.0 12:54 13:24 PUW=31K,Reset on depth,oriented to high side.Close EDC.Pressure up and see tool shift @ 3350 PSI,Set down 3K.Looks good 6/1/2017 6/1/2017 1.30 PROD1 WHPST TRIP P POOH,EDC open 7,043.0 69.0 13:24 14:42 6/1/2017 6/1/2017 0.75 PROD1 WHPST PULD P At surface,PJSM,Lay down tools 69.0 0.0 14:42 15:27 from dead well 6/1/2017 6/1/2017 1.00 PROD1 WHDBOP RURD T PJSM,RU air,blow down surface 0.0 0.0 15:27 16:27 lines,and BOPE 6/1/2017 6/1/2017 2.00 PROD1 WHDBOP RURD T PJSM,Nipple down BOPE and MP 0.0 0.0. 16:27 18:27 line 6/1/2017 6/2/2017 5.55 PROD1 WHDBOP RURD T MU new configuration on cellar floor, 0.0 0.0 18:27 00:00 install single swab setup. 6/2/2017 6/2/2017 5.50 PROD1 WHDBOP RURD T Continue with re-contig in cellar. 0.0 0.0 00:00 05:30 Torque all connections,MU MP line 6/2/2017 6/2/2017 3.00 PROD1 WHDBOP RURD T Fliuid pack surface lines,perform shell 0.0 0.0 05:30 08:30 test.Call ut grease crew to service swab two.Chart test,PT TT line. 6/2/2017 6/2/2017 1.40 PROD1 WHPST PULD P PJSM,P/U BHA#3 window milling 0.0 74.0 08:30 09:54 BHA with.6°motor,2.79 string reamer,and 2.80 dimond window mill. M/U to coil and surface test 6/2/2017 6/2/2017 1.40 PROD1 WHPST TRIP P Trip in well,EDC open,Pumping 74.0 6,460.0 09:54 11:18 , 6/2/2017 6/2/2017 0.20 PROD1 WHPST -DLOG P Log HRZ for-3'correction 6,460.0 6,489.0 11:18 11:30 6/2/2017 6/2/2017 0.30 PROD1 WHPST TRIP P Continue in well,wt chk @ 6988'is 6,489.0 7,032.0 11:30 11:48 33K,Dry tag TOWS @ 7032 6/2/2017 6/2/2017 7.70 PROD1 WHPST MILL P 7032',Pumps on @ 1.7 BPM @ 2870 7,032.0 7,039.0 11:48 19:30 PSI FS,BHP=3155.Mill first section of window 7033 to 7039'per procedure 6/2/2017 6/2/2017 0.50 PROD1 WHPST REAM P Ream window exit as per procedure, 7,039.0 7,039.0 19:30 20:00 PUW 30 k/RIW 15 k 6/2/2017 6/2/2017 1.50 PROD1 WHPST TRIP P POOH,pumping 1.8 bpm at 2,490 psi 7,039.0 74.3 20:00 21:30 6/2/2017 6/2/2017 0.50 PROD1 WHPST OWFF P At surface,PJSM,check well for flow 74.3 74.3 21:30 22:00 ' 6/2/2017 6/2/2017 0.50 PROD1 WHPST PULD P LD milling BHA on dead well,mills 74.3 0.0 22:00 22:30 gauged 2.80 go/2.79 no-go. Page 2/37 Report Printed: 7/3/2017 44.6' -.,I,.„, , Aerations Summary (with Timelogepths) '-7!,:,,,,,,,,.,..,,,,,i1G-15 CocoPhittips` Com Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/2/2017 6/2/2017 0.50 PROD1 WHPST `PULD P PU/MU Second milling BHA#4 0.0 76.8 22:30 23:00 6/2/2017 6/3/2017 1.00 PROD1 WHPST TRIP P Tag up,Surface test Coiltrak Tools 76.8 5,000.0 23:00 00:00 (good test),reset counters,start trip sheet,RIH,pumping 0.32 bpm at 632 psi 6/3/2017 6/3/2017 0.25 PROD1 WHPST TRIP P Continue IH 5,000.0 6,444.0 00:00 00:15 6/3/2017 6/3/2017 0.50 PROD1 WHPST DLOG P Log the HRZ correction of minus 3.5', 6,444.0 6,994.0 00:15 00:45 PUW 30 k 6/3/2017 6/3/2017 0.25 PROD1 WHPST TRIP P Continue RIH 6,994.0 7,039.0 00:45 01:00 6/3/2017 6/3/2017 3.40 PROD1 WHPST MILL P Start milling second stage of dual 7,039.0 7,043.0 01:00 04:24 string exit. 1.8 bpm at 3,280 psi,BHP 3,165,WHP 0,IA 415,OA 70 6/3/2017 6/3/2017 4.70 PROD1 WHPST MILL P 7043',Call BOW,1.8 BPM @ 4105 7,043.0 7,058.0 04:24 09:06 PSi FS,BHP=3850,Mill rathole to 7058 6/3/2017 6/3/2017 2.50 PROD1 WHPST REAM P Start reaming passes,HS,30R,30L, 7,058.0 7,026.0 09:06 11:36 Low side.Dry drift-good,PUW=30K 6/3/2017 6/3/2017 1.30 PROD1 WHPST TRIP P Trip out for build BHA 7,026.0 73.0 11:36 12:54 6/3/2017 6/3/2017 2.00 PROD1 WHPST PULD P Tag up,space out,PJSM,PUD BHA 73.0 0.0 12:54 14:54 #4 second window milling run,Mill out of hole @ 2.79 no go 6/3/2017 6/3/2017 1.50 PROD1 DRILL PULD P PJSM,PD BHA#5(Pre Loaded), 0.0 72.2 14:54 16:24 Build BHA with 2.3°AKO motor and reconditioned Hughes Bi Center 6/3/2017 6/3/2017 1.50 PROD1 DRILL TRIP P Trip in hole,EDC open,pumping min 72.2 6,445.0 16:24 17:54 rate 6/3/2017 6/3/2017 0.25 PROD1 DRILL DLOG P Log the HRZ correction of minus 4.0', 6,445.0 6,487.0 17:54 18:09 6/3/2017 6/3/2017 0.50 PROD1 DRILL TRIP P Continue IH, RIW 19 k,PUW 30 k 6,487.0 7,058.0 18:09 18:39 6/3/2017 6/3/2017 1.00 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4,000 psi, BHP 7,058.0 7,109.0 18:39 19:39 3,913,WHP 695,IA 419,OA 73, DHWOB 1.1 k,CTWS 14 k,ROP S3 fph 6/3/2017 6/3/2017 0.40 PROD1 DRILL DRLG P Discuss with town low DLG, 10'lower 7,109.0 7,109.0 19:39 20:03 then plan,still showing low DLG, talked to town team again,30'lower then plan ok'd by Town Geo. 6/3/2017 6/4/2017 3.95 PROD1 DRILL DRLG P Continue Drilling ahead,1.8 bpm at 7,109.0 7,238.0 20:03 00:00 3,830 psi,BHP 3,881,WHP 617, IA 426,OA 96 6/4/2017 6/4/2017 3.00 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4,060'psi,BHP 7,238.0 7,280.0 00:00 03:00 3,963,WHP 627,IA 428,OA 95, DHWOB 3.5 k,CTSW 11 k,ROP 6 fph 6/4/2017 6/4/2017 2.90 PROD1 DRILL DRLG P OBD, 1.77 bpm at 4,198 psi,BHP 7,280.0 7,360.0 03:00 05:54 3,939,WHP 623,IA 434,OA 94, DHWOB 2.5 k,CTSW 11.6 k,ROP 24 fph 6/4/2017 6/4/2017 1.30 PROD1 DRILL TRIP P Call end of build,trip out,PUW=31K, 7,360.0 63.0 05:54 07:12 Avg DLS=33° 6/4/2017 6/4/2017 1.60 PROD1 DRILL PULD P At surface,Tag up and space out, 63.0 0.0 07:12 08:48 PJSM,PUD BHA#5,Bit balled up, Clay build up on BHA and CTC Page 3/37 Report Printed: 7/3/2017 � , • • :7 Operations Summary (with Timelog Depths) ,,,,..„,,,----,,--46,- 1G-15 Cono illips� �" r,.'sks Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/4/2017 6/4/2017 1.50 PROD1 DRILL PULD P PJSM,PD BHA#6 lateral BHA with 0.0 80.8 08:48 10:18 RB HYC Bi center,.75+WFT motor, and agitator,Check pack offs,Change floats in UQC,M/U to coil and surface test 6/4/2017 6/4/2017 1.30 PROD1 DRILL TRIP P RIH BHA#6,stop at 300'close EDC 80.8 6,465.0 10:18 11:36 and test agitator.Vibrating on at surface,Open EDC and continue in well 6/4/2017 6/4/2017 0.20 PROD1 DRILL DLOG P Log HRZ for-4'correction 6,465.0 6,488.0 11:36 11:48 6/4/2017 6/4/2017 0.30 PROD1 DRILL TRIP P Continue in well,6988 stop and close 6,488.0 7,070.0 11:48 12:06 EDC,PUW=28.5K 6/4/2017 6/4/2017 0.10 PROD1 DRILL DLOG P Log RA marker @ 7040',TOWS=7033 7,070.0 7,095.0 12:06 12:12 6/4/2017 6/4/2017 0.20 PROD1 DRILL TRIP P Continue in well to bottom, 7,095.0 7,360.0 12:12 12:24 6/4/2017 6/4/2017 3.50 PROD1 DRILL DRLG P 7360',Drill,1.75 BPM @ 4349 PSI 7,360.0 7,760.0 12:24 15:54 FS,BHP=3895,RIW=10.5K 6/4/2017 6/4/2017 0.50 PROD1 DRILL WPRT P 7760',Wiper trip to 7100,PUW=32K, 7,760.0 7,760.0 15:54 16:24 Clean trip up and down 6/4/2017 6/4/2017 2.50 PROD1 DRILL DRLG P 7760',Drill,1.7 BPM @ 4660 PSI FS, 7,760.0 8,040.0 16:24 18:54 BHP=4007,WHP=628,RIW=13.3K 6/4/2017 6/4/2017 1.60 PROD1 DRILL DRLG P Having trouble building angle,lower 8,040.0 8,200.0 18:54 20:30 pump rate 1.5 bpm,trough 180° oppostie from DTF,continue drilling ahead without success,pump 5x5 sweep. 6/4/2017 6/4/2017 1.75 PROD1 DRILL TRIP T POOH,pumping 1.8 bpm at 3,624 psi, 8,200.0 80.8 20:30 22:15 following MPS,filling out trip sheet. • 6/4/2017 6/4/2017 1.25 PROD1 DRILL PULD T PJSM, PUD/LD Lateral Drilling BHA# 80.8 0.0 22:15 23:30 6 6/4/2017 6/4/2017 PROD1 DRILL PULD T MU Drilling BHA#7 with BHI motor 0.0 23:30 23:30 and agitator. 6/5/2017 6/5/2017 1.00 PROD1 DRILL PULD T Continue PD,"A"Lateral Drilling 0.0 78.2 00:00 01:00 BHA#7 6/5/2017 6/5/2017 1.50 PROD1 DRILL TRIP T RIH,Lateral Drilling BHA#7(1.2°ako 78.2 6,465.0 01:00 02:30 motor) 6/5/2017 6/5/2017 0.25 PROD1 DRILL DLOG T Log the HRZ correction of minus 4.0' 6,465.0 6,510.0 02:30 02:45 6/5/2017 6/5/2017 0.75 PROD1 DRILL TRIP T Continue RIH to bottom,7,100'close 6,510.0 8,030.0 02:45 03:30 EDC,35 k,set down 7,130',7,896', and 8,030'. 6/5/2017 6/5/2017 0.25 PROD1 DRILL REAM T PUH at 5 fpm back reaming 8,030.0 7,880.0 03:30 03:45 6/5/2017 6/5/2017 0.75 PROD1 DRILL TRIP T RBIH,pumping 1.3 bpm at 3,440 psi, 7,880.0 8,200.0 03:45 04:30 BHP 3,905,WHP 460, IA 400,OA 75, work past 8,156'. 6/5/2017 6/5/2017 1.10'PROD1 DRILL DRLG P BOBD 1.82 bpm at 4,870 psi,BHP 8,200.0 8,268.0 04:30 05:36 3,970,WHP 576,IA 419,OA 76, 6/5/2017 6/5/2017 0.60 PROD1 DRILL WPRT P Pull 400'wiper,PUW=30K 8,268.0 8,268.0 05:36 06:12 6/5/2017 6/5/2017 2.30 PROD1 DRILL DRLG P 8268',Drill, 1.8 BPM @ 4650 PSI FS, 8,268.0 8,367.0 06:12 08:30 BHP=3990 6/5/2017 6/5/2017 0.30 PROD1 DRILL DRLG P 8367 could be fault,started loosing 8,367.0 8,376.0 08:30 08:48 fluid @.2 BBI/Min.Healed up fairly quickly losses stabilized-5 BPM Page 4/37 Report Printed: 7/3/2017 • 1. ply AI ,., , Operations Summary (with TimelogDepths) 1G-15 ConocoPhi€hers ' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 6/5/2017 6/5/2017 0.10 PROD1 DRILL WPRT P BHA Wiper trip,PUW=33K 8,376.0 8,376.0 08:48 08:54 6/5/2017 6/5/2017 4.20 PROD1 DRILL DRLG P 8376',Drill, 1.8 BPM @ 4650 PSI FS, 8,376.0 8,485.0 08:54 13:06 BHP=3950 6/5/2017 6/5/2017 0.20 PROD1 DRILL WPRT P Pull mini wiper,low ROP—25 FPH, 8,485.0 8,485.0 13:06 13:18 PUW=29K 6/5/2017 6/5/2017 1.30 PROD1 DRILL DRLG P 8485',Drill, 1.8 BPM @ 4540 PSI FS, 8,485.0 8,512.0 13:18 14:36 BHP=3976,Slight losses 6/5/2017 6/5/2017 0.80 PROD1 DRILL WPRT P 8512 pull 1000'wiper,PUW=29K. 8,512.0 8,512.0 14:36 15:24 Better hole conditions,set down @ 8075 and 8240 6/5/2017 6/5/2017 5.70 PROD1 DRILL DRLG P 8512',Drill,1.8 BPM @ 4582 PSi FS, 8,512.0 8,643.0 15:24 21:06 BHP=3956,Low ROP,RIW=-4K,few pick ups 6/5/2017 6/5/2017 0.20 PROD1 DRILL WPRT P 8643 Mini Wiper,PUW=34K 8,643.0 8,643.0 21:06 21:18 6/5/2017 6/5/2017 1.20 PROD1 DRILL DRLG P 8643',Drill, 1.8 BPM @ 4840 PSI FS, 8,643.0 8,668.0 21:18 22:30 BHP=4010,Possible plugged bit nozzle 6/5/2017 6/5/2017 0.70 PROD1 DRILL WPRT P Wiper up hole,pulled heavy 43 k 8,668.0 7,100.0 22:30 23:12 6/5/2017 6/6/2017 0.80 PROD1 DRILL WPRT P Wiper back in hole,RIW 12 k 7,100.0 8,583.0 23:12 00:00 6/6/2017 6/6/2017 0.10 PROD1 DRILL WPRT P Finished wiper in hole,RIW 9 k 8,583.0 8,668.0 00:00 00:06 6/6/2017 6/6/2017 2.00 PROD1 DRILL DRLG P BOBD 1.8 bpm at 4,711 psi,BHP 8,668.0 8,708.0 00:06 02:06 3,982,WHP 511,IA 437,OA 108, ' DHWOB 2 k,CTSW minus 5 k,ROP 30 fph,pump 24 bbl pill of drill zone, balled up bit suspected. 6/6/2017 6/6/2017 0.12 PROD1 DRILL WPRT P 100 ft wiper up hole PUW 32 k 8,708.0 8,586.0 02:06 02:13 6/6/2017 6/6/2017 0.12 PROD1 DRILL WPRT P Wiper back in hole,RIW 4 k 8,586.0 8,708.0 02:13 02:20 6/6/2017 6/6/2017 2.00 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,747 psi,BHP 8,708.0 8,738.0 02:20 04:20 3,949,WHP 513,IA 439,OA 111, DHWOB 1.7 k,CTWS 5 k,ROP 28 fph 6/6/2017 6/6/2017 1.25 PROD1 DRILL DRLG P Pump 20 bbl pill of Alpine beads,drill 8,738.0 8,767.0 04:20 05:35 zone,and flo-vis.OBD 1.8 bpm at 5,129 psi,BHP 4,028,WHP 524,IA 436,OA 111,DHWOB 2.1 k,CTSW 0, ROP 42 fph 6/6/2017 6/6/2017 2.25 PROD1 DRILL TRIP T POOH,pump 5x5 sweep 8,767.0 3,550.0 05:35 07:50 6/6/2017 6/6/2017 0.50 PROD1 DRILL TRIP T Pump 10x10 sweep,RBIH to confirm 3,550.0 6,445.0 07:50 08:20 hole conditions. 6/6/2017 6/6/2017 0.25 PROD1 DRILL DLOG T Log the HRZ correction of plus 7.0' 6,445.0 6,510.0 08:20 08:35 6/6/2017 6/6/2017 0.25 PROD1 DRILL TRIP T Continue RIH,RIW 15 k,close EDC. 6,510.0 7,000.0 08:35 08:50 PUW 28 k 6/6/2017 6/6/2017 0.75 PROD1 DRILL TRIP T Continue RIH clean to 8,350' 7,000.0 8,350.0 08:50 09:35 6/6/2017 6/6/2017 0.12 PROD1 DRILL TRIP T POOH,at 50 fpm pumping 1.8 bpm at 8,350.0 8,240.0 09:35 09:42 4,950 psi,BHP 3970,WHP 548, IA 433,OA 104,clean up 8,240'area. 6/6/2017 6/6/2017 0.25'PROD1 DRILL TRIP T Decision was made to go back drilling, 8,240.0 8,767.0 09:42 09:57 RBIH to bottom Page 5/37 Report Printed: 7/3/2017 • 4 ` � <;, Operations Summary (with Timelog Depths) ►fit t ;. 1G-15 ConocoPhillips ALxks Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/6/2017 6/6/2017 5.50 PROD1 DRILL DRLG P BOBD,1.8 bpm at 5,070 psi,BHP 8,767.0 8,903.0 09:57 15:27 4,090,WHP 607,IA 436,OA 108 6/6/2017 6/6/2017 2.10 PROD1 DRILL DRLG P BOBD 1.82 bpm at 5,126 psi,BHP 8,903.0 8,950.0 15:27 17:33 4,085,WHP 583,IA439,OA 111, DHWOB 1.5 k,CTSW-4 k,ROP 30 fpm 6/6/2017 6/6/2017 4.60 PROD1 DRILL DRLG P OBD 1.77 bpm, CT 5,032 psi,BHP 8,950.0 9,044.0 17:33 22:09 4,194,WHP 700, IA 440,OA 117, WOB 1.1,ROP 27-17 fUhr. Picked off bottom a few times to restart,clean, PU Wt 29 k lbs. Was taking influx— bbls/hr,increased choke—100 psi, generated new tripping shcedule for 12.0 ppg EMW @ the window,slight losses. ROP's slowy decreasing to —11 fUh,CT pressure up to 5251 psi over last hour,off bottom free spin 1065 psi. 6/6/2017 6/6/2017 0.70 PROD1 DRILL WPRT P PU Wt 27 k lbs,Pull—2000'wiper 9,044.0 7,058.0 22:09 22:51 through the build section to 7058',saw some spots of motor work to 300 psi from 8814,to 7298',Neg WOB spikes to-1 k from 7914-7239'. CT wt . climbed to—31 k lbs. 6/6/2017 6/6/2017 0.50 PROD1 DRILL WPRT P RBIH,RIH Wt 12k lbs falling off to 8k 7,058.0 9,044.0 22:51 23:21 lbs @ 9022' slight S/D at 8660'and agin near bottom,adjusted pump rate to get back to bottom. 6/6/2017 6/7/2017 0.65 PROD1 DRILL DRLG P Rate @ 1.80 bpm,CT 5126 psi,Free 9,044.0 9,045.0 23:21 00:00 spin diff 930 psi. OBD,CT 5198 psi,CT Wt 0 k lbs, WOB 2.55 k lbs,ROP 6.5 ft/hr Returns 1 for 1 holding 4200 psi annular. 6/7/2017 6/7/2017 0.40 PROD1 DRILL DRLG P Rate @ 1.80 bpm,CT 5126 psi,Free 9,044.0 9,045.0 00:00 00:24 spin diff 930 psi. OBD,CT 5198 psi,CT Wt 0 k lbs, WOB 2.55 k lbs,ROP 6.5 ft/hr Returns 1 for 1 holding 4200 psi annular. 6/7/2017 6/7/2017 2.80 PROD1 DRILL DRLG P Slight drilling break from 9050-9060', 9,044.0 9,085.0 00:24 03:12 ROP increased from 7 to 40 ft/hr. Geos requested to turn straight up, another drilling break at 9078-9088',7 fUhr to 60+and back down to 15 ft/hr. Drilling ahead,CT WT-3 k lbs,WOB 2.0 k lbs Holding 4200 psi annular, WH 675 psi. Returns 1 for 1. 6/7/2017 6/7/2017 2.25 PROD1 DRILL DRLG P OBD,1.85 bpm,CT 5474 psi,CT wt- 9,085.0 9,110.0 03:12 05:27 1 k lbs,WOB 1.87 k lbs,ROP—10 ft/hr 6/7/2017 6/7/2017 0.20 PROD1 DRILL WPRT P BHA wiper up hole,PUW 31 k 9,110.0 9,110.0 05:27 05:39 6/7/2017 6/7/2017 2.25 PROD1 DRILL DRLG P BOBD 1.8 bpm at 5,054 psi,BHP 9,110.0 9,150.0 05:39 07:54 4,211,WHP 860,IA 440,OA 118 Page 6/37 Report Printed: 7/3/2017 r .a• • 4.,„1.0,,,,,•;,,•••,, Operations Summary (with Timelog flielpths) • ' .; 4 _, 1G-15 ConocoPhillips`` Rt.rka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/7/2017 6/7/2017 3.80 PROD1 DRILL WPRT P Plug back TD,pump 5x5 sweeps, 9,150.0 7,015.0 07:54 11:42 wiper up hole,PUW 29 k,work problem areas. Problem areas: 8,260'-8,230',motor work 500 psi diff 7,960'-7,940',motor work 150 psi diff 7200'-7260',motor work 500 psi diff 6/7/2017 6/7/2017 0.12 PROD1 DRILL WPRT P Pull up thru window,perform Pressure 7,015.0 7,015.0 11:42 11:49 Survey above window,sensor depth 6,970',6,507'TVD,showing 11.76 pp9 6/7/2017 6/7/2017 0.75 PROD1 DRILL TRIP P PUW 26 k,RBIH to 8,300',start new 7,015.0 8,300.0 11:49 12:34 mud down the coil. 6/7/2017 6/7/2017 0.75'PROD1 DRILL TRIP P POOH,while swapping to new mud 8,300.0 7,000.0 12:34 13:19 6/7/2017 6/7/2017 1.25 PROD1 DRILL TRIP P Above window,open EDC,continue 7,000.0 78.2 13:19 14:34 POOH 6/7/2017 6/7/2017 2.00 PROD1 DRILL PULD P At surface,PJSM,undeploy drilling 78.2 78.2 14:34 16:34 BHA#7,checks failed,PJSM for undeploy with failed check valves, close EDC. 6/7/2017 6/7/2017 0.50 PROD1 DRILL BOPE P Perform Function test 0.0 0.0 16:34 17:04 6/7/2017 6/7/2017 2.00 PROD1 DRILL PULD P PU anchored billet,stab PDL w BHA 0.0 60.0 17:04 19:04 #8. 6/7/2017 6/7/2017 1.50 PROD1 DRILL PULD P On the well,inspect checks in upper 60.0 81.0 19:04 20:34 quick,inspect stripper, test tools, Crew change,finish up PD BHA, 6/7/2017 6/7/2017 1.00 PROD1 DRILL TRIP P Bump up,space out,RIH,pumping 81.0 6,475.0 20:34 21:34 0.33 bpm 6/7/2017 6/7/2017 0.20 PROD1 DRILL DLOG P Log the HRZ for a-6.5'correction 6,475.0 6,498.0 21:34 21:46 6/7/2017 6/7/2017 0.50 PROD1 DRILL TRIP P Continue to RIH,Wt Ck @ 6940'28k 6,498.0 7,103.0 21:46 22:16 lbs,Pumps down,Close EDC,orient Billet 20°ROHS,continue to RIH.S/D 7k lbs @ 7103'@ 30 ft/min,PU,RBIH @ 20 ft/min S/D same spot 4.25k lbs, PU,orient to highside,RBIH S/D 1.8 k lbs same spot. 6/7/2017 6/8/2017 1.74 PROD1 DRILL TRIP T PUH,billet above the window,open 7,103.0 2,975.0 22:16 00:00 EDC,online w pumps min rate.POOH w BHA#8. 6/8/2017 6/8/2017 0.70 PROD1 DRILL TRIP T PUH,billet above the window,open 2,975.0 75.0 00:00 00:42 EDC,online w pumps min rate.POOH w BHA#8. 6/8/2017 6/8/2017 1.00 PROD1 DRILL PULD T PJSM,Bump up,space out,pumps 75.0 0.0 00:42 01:42 down,pressure trapped, PUD/LD BHA#8 open hole anchored whipstck. Bottom pup packed full of up to 1/2" chunks of shale. Sample delivered to Geo,opinion is these are old shales that have been in the well for some time and not from the area we set down in. - 6/8/2017 6/8/2017 0.40 PROD1 DRILL CTOP T clean clear floor 0.0 0.0 01:42 02:06 Page 7/37 Report Printed: 7/3/2017 k t `� !perations Summary (with Timelogipths) „, *' 1G-15 Conoccehiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/8/2017 6/8/2017 1.70 PROD1 DRILL PULD T PU/PD BHA#9,clean out BHA, 1.2° 0.0 78.0 02:06 03:48 AKO motor w D331 bit.stab injector, test tools,bump up,set counters/ Well jug tight during PUD/PD. Total vol pumped on managed pressure line ' 0 bbls. 6/8/2017 6/8/2017 1.20 PROD1 DRILL TRIP T RIH w BHA#9 78.0 6,436.0 03:48 05:00 6/8/2017 6/8/2017 0.20 PROD1 DRILL DLOG T Tie into HRZ for-4.5'correction, 6,436.0 6,473.0 05:00 05:12 6/8/2017 6/8/2017 2.75 PROD1 DRILL TRIP T Close EDC,Wt Ck 25 k lbs,contiue to 6,473.0 8,100.0 05:12 07:57 RIH,Clean problem areas,7,120', 7,233',7,672',7,700',and 8,050', pump 10x10 sweep 6/8/2017 6/8/2017 1.25 PROD1 DRILL WPRT T POOH,cleaning 8,050', 8,100.0 7,240.0 07:57 09:12 6/8/2017 6/8/2017 0.50 PROD1 DRILL WPRT T PUW 50 k,work pipe free,RBIH thru 7,240.0 7,240.0 09:12 09:42 tight area,PUW 40 k,call town team, decision was made to POOH for WS. 6/8/2017 6/8/2017 3.00 PROD1 DRILL WPRT T POOH,performing sweeps,perform 7,240.0 62.5 09:42 12:42 jogs at 6,500',4,500',2,500',500'. 6/8/2017 6/8/2017 1.50 PROD1 DRILL PULD T At surface, PJSM,PUD cleanout BHA 62.5 0.0 12:42 14:12 6/8/2017 6/8/2017 0.31 PROD1 DRILL PULD T LD cleanout BHA,mill gauged 2.79 no 0.0 0.0 14:12 14:30 -go 6/8/2017 6/8/2017 1.75 PROD1 RPEQPT PULD T PU/MU/PD 3-1/2"XL Monobore WS 0.0 72.4 14:30 16:15 w/RA tags 6/8/2017 6/8/2017 1.70 PROD1 RPEQPT TRIP T RIH,with WS setting BHA#10 72.4 6,442.0 16:15 17:57 6/8/2017 6/8/2017 0.40 PROD1 RPEQPT DLOG T Tie into the HRZ for a+6',have been 6,442.0 6,473.0 17:57 18:21 seeing-4-6'. PUH and relog for zero correction. 6/8/2017 6/8/2017 0.40 PROD1 RPEQPT WPST T Continue to RIH,PU Wt 27k lbs @ 6,473.0 7,028.0 18:21 18:45 6977',Zero WOB,Park bit depth @ 7028.76',PU to neutral weight,27k lbs,Tool face @ high side,S/D pumps,Close EDC,WH @ 1033 psi, on line w the pump,Circ pressure broke over at 5600 psi. Slack off coil weight and S/D 6.7 k lbs,PU 30 k lbs. Set top of WS @ 7018. 6/8/2017 6/8/2017 1.50 PROD1 RPEQPT TRIP T POOH 7,028.0 60.0 18:45 20:15 6/8/2017 6/8/2017 1.20 PROD1 RPEQPT PULD T PJSM,Bump up,Space out,PUD 60.0 0.0 20:15 21:27 BHA#10 6/8/2017 6/8/2017 1.40 PROD1 WHPST PULD T PU&PD BHA#11,tubing window 0.0 74.0 21:27 22:51 mill asembly,0.6°AKO inteq motor, bump up,test tools. 6/8/2017 6/9/2017 1.15 PROD1 WHPST TRIP T RIH, 74.0 6,444.0 22:51 00:00 6/9/2017 6/9/2017 0.20 PROD1 WHPST DLOG T Tie into the HRZ for-2'correction. 6,444.0 6,475.0 00:00 00:12 6/9/2017 6/9/2017 0.50 PROD1 WHPST TRIP T PU Wt 25k,down on pumps,close 6,475.0 7,018.0 00:12 00:42 EDC,continue to RIH. 6/9/2017 6/9/2017 0.10 PROD1 WHPST WPST T Zero WOB,tag top of WS @ 7018', 7,018.0 7,000.0 00:42 00:48 S/D 4 k lbs,PU Wt 30 k lbs, Page 8/37 Report Printed: 7/3/2017 • • Operations Summary (with Timelog Depths) /4- � r- 1G-15 Conoco illips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/9/2017 6/9/2017 0.30 PROD1 WHPST WPST T Set Rate @ 1.74 bpm,CT 4000 psi, 7,000.0 7,018.6 00:48 01:06 free spin diff 408 psi,WH 806 psi. Zero WOB,motor work started at 7018.6' 6/9/2017 6/9/2017 0.90 PROD1 WHPST WPST T Mill Exit window,WOB 1.9 k lbs,200 7,018.6 7,019.6 01:06 02:00 psi motor work 6/9/2017 6/9/2017 5.25 PROD1 WHPST WPST T Mill exit window in 3.5"WOB 2.6 k lbs, 7,019.6 7,024.6 02:00 07:15 ROP-0.8-1.0 ft/hr Zero vol counter4,pump 5 bbl red pill, 123 bbl theoretical round trip estimating 2 bbl surface lines,pumped 11 bbls.Saw dye back at 113 bbls pumped. 10 bbls early. WOB started to fall off @ 2.2-2.5' milled. 6/9/2017 6/9/2017 0.50 PROD1 WHPST WPST T Back ream window area,(clean) 7,024.6 7,024.6 07:15 07:45 6/9/2017 6/9/2017 1.25 PROD1 WHPST WPST T POOH,pumping 1.94 bpm at 3863 7,024.6 74.2 07:45 09:00 psi,following MP schedule 6/9/2017 6/9/2017 1.50 PROD1 WHPST PULD T At surface,space out,PJSM, 74.2 0.0 09:00 10:30 Undeploy milling BHA#11,changeout motor 6/9/2017 6/9/2017 1.25 PROD1 WHPST PULD T PD second milling BHA#12 0.0 76.8 10:30 11:45 6/9/2017 6/9/2017 1.50 PROD1 WHPST TRIP T RIH,with 1.25°WFT motor,string 76.8 6,445.0 11:45 13:15 reamer,and window fat radius mill 6/9/2017 6/9/2017 0.25 PROD1 WHPST DLOG T Log the HRZ correction of minus 5.0', 6,445.0 6,465.0 13:15 13:30 PUW 25 k 6/9/2017 6/9/2017 0.25 PROD1 WHPST TRIP T RIH,to dry tag 6,465.0 7,024.6 13:30 13:45 6/9/2017 6/9/2017 6.00 PROD1 WHPST MILL T OBM, 1.8 bpm at 4,300 psi,BHP 7,024.6 7,033.6 13:45 19:45 4,059,WHP 840,IA 422,OA 83 WOB fell off from 1.4 k to 0.25 k @ 7027.2',continue to drill ahead to 7033.60'. Catch a sample,consult w Geo,-30%shale,call TD of rat hole. 6/9/2017 6/10/2017 4.25 PROD1 WHPST REAM T PUH,back reaming above Whipstock, 7,033.6 7,031.6 19:45 00:00 make reaming passes,initial @ HS as drilled,back down,up at 30 ROHS, down small spike in motor work @ 7023',up at 330 ROHS,pumps off, WOB spike to 3k lbs @ 7024.6'on the trip in. Pumps up to 1.86 bpm,back ream out 180 ROHS,some motor work @ 7027',RBIH HS,Clean.back ream out LS. Dry drift high side,WOB spike 1.87 k lbs @ 7023.9' Up on the pumps,Back ream out of hole HS, down HS,up 45 ROHS,down HS,up 315 ROHS.dry drift,same bump at 7023.1'1.2k lbs. Back ream HS,dry drift at 30 ft/min,clean,Back ream out HS,dry drift again©30 ft/m,saw string weight slack off but no WOB. 6/10/2017 6/10/2017 0.10 PROD1 WHPST REAM T Bottom has been creaping up,7031' 7,031.6 7,033.6 00:00 00:06 compared to 7033'TD. Remill to previous TD of 7033.6',pump 5x5 sweep. Page 9/37 Report Printed: 7/3/2017 Ait" Operations Summary (with Timelog Depths) epi- 4 ` . `' 1G-15 conocoPhiiiips'.- Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation • (ftKB) End Depth(EKE) 6/10/2017 6/10/2017 0.30 PROD1 WHPST REAM T PUH on last reaming pass HS. 7,033.6 7,017.0 00:06 00:24 6/10/2017 6/10/2017 0.20 PROD1 WHPST TRIP T Open EDC,struggled to get 7,017.0 6,967.0 00:24 00:36 differential pressure low enough to open. 6/10/2017 6/10/2017 1.40 PROD1 WHPST TRIP T POOH,pumping 2.2 bpm,pulling 100 6,967.0 75.0 00:36 02:00 ft/min(75%is 109 ft/min). Lots of metal at the shaker the whole trip out. Jog near surface. 6/10/2017 6/10/2017 1.70 PROD1 WHPST PULD T PJSM,bump up,space out,PUD& 75.0 0.0 02:00 03:42 LD BHA#12. 6/10/2017 6/10/2017 0.80 PROD1 WHPST CTOP T Install nozzle,stab injector,jet stack, 0.0 0.0 03:42 04:30 unstab,prep. 6/10/2017 6/10/2017 1.50 PROD1 WHPST PULD T PJSM,PU&PD BHA#13. A lat build 0.0 75.0 04:30 06:00 assembly W 2.5°AKO,stab injector, inspect stripper elements. 6/10/2017 6/10/2017 1.25 PROD1 DRILL TRIP T RIH,with build section BHA#13,2.6° 75.0 6,445.0 06:00 07:15 ako motor 6/10/2017 6/10/2017 0.25 PROD1 DRILL DLOG T Log the HRZ correction of minus 3.5', 6,445.0 6,480.0 07:15 07:30 PUW 24 k,close the EDC. 6/10/2017 6/10/2017 0.50 PROD1 DRILL TRIP T Continue IH,thru window. 6,480.0 7,033.0 07:30 08:00 6/10/2017 6/10/2017 4.00 PROD1 DRILL DRLG T OBD, 1.8 bpm at 4,270 psi,BHP 7,033.0 7,215.0 08:00 12:00 3908,WHP 665,IA 419,OA 81 6/10/2017 6/10/2017 0.35 PROD1 DRILL WPRT T TD Build section,wiper up to the 7,215.0 7,004.0 12:00 12:21 window,PUW 27 k • 6/10/2017 6/10/2017 1.50 PROD1 DRILL TRIP T Open EDC,POOH,pumping 2.2 bpm 7,004.0 72.2 12:21 13:51 at 4,200 psi,following MP,tracking trip sheet. 6/10/2017 6/10/2017 1.25 PROD1 DRILL PULD T PJSM,PUD build section BHA 72.2 0.0 13:51 15:06 6/10/2017 6/10/2017 1.25 PROD1 DRILL PULD T PU/PD latreral drilling BHA#14,test 0.0 80.8 15:06 16:21 tools(good test) 6/10/2017 6/10/2017 1.25 PROD1 DRILL TRIP T RIH,w/lateral drilling BHA with WFT 80.8 6,445.0 16:21 17:36 motor and New Duraforce Edge Bit 6/10/2017 6/10/2017 0.20 PROD1 DRILL DLOG T Log the HRZ correction of-5.5', 6,445.0 6,478.0 17:36 17:48 6/10/2017 6/10/2017 0.40 PROD1 DRILL TRIP T Close EDC,Wt check 27 k lbs,PU, 6,478.0 7,215.0 17:48 18:12 continue to RIH,pumps off @ 6970', window clean at 35 ft/min. Claystop @ 2.5%,KCI @ 6% 6/10/2017 6/10/2017 0.20 PROD1 DRILL DLOG T log RA tag,7023'. Right below 7,215.0 7,082.0 18:12 18:24 ambient high gamma signature, suspect scale from Iperf. 6/10/2017 6/10/2017 0.10 PROW DRILL TRIP T Continue to RIH,set rate. 7,082.0 7,215.0 18:24 18:30 6/10/2017 6/10/2017 2.50 PROD1 DRILL DRLG T 1.80 bpm,CT 4716 psi,free spin diff 7,215.0 7,445.0 18:30 21:00 1140 psi. OBD,-70 ft/hr, 1.5 k WOB,CT 5340 psi Decent stall @ 7233',picked up, worked through hard spot. PU and restart,27k lbs,PU to reset MWD computer,RES tool not turned on,27 k lbs Pass possiible fault 32 as indicated on RES @ 7370' Average 92 ft/hr over interval, Page 10/37 Report Printed: 7/3/2017 010 r • • 4 A V4` Operations Summary (with Timelog Depths) I G-15 ConocoPhitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/10/2017 6/11/2017 3.00 PROD1 DRILL DRLG T OBD,CT 5470 psi,Annular 4202 psi, 7,445.0 7,782.0 21:00 00:00 Wh 795 psi,WOB 1.5 k lbs,ROP 115 ft/hr,CT Wt 10.2 k lbs. Sailed 5x5 sweep with good results at the shaker and per Wellworc. @ 7670'ROP climbed to-150 ft/hr, look to be into sand by 7710'. Pump another 5x5 sweep.Ct wt 7.9 k lbs, WOB 1.67k lbs,ROP 147 ft/hr. In sand,Ct wt, 10.6 k lbs,ROP 150 ft/hr, WOB 0.8 K lbs `*3 hrs on bottom 337 ft drilled, 112 ft/h over the interval 6/11/2017 6/11/2017 0.20 PROD1 DRILL WPRT T Wiper trip,567',PU Wt 27k,Pull off 7,782.0 7,050.0 00:00 00:12 bottom 2 bbls after sweeps exit the bit and chase up hole. 6/11/2017 6/11/2017 0.10 PROD1 DRILL DLOG T Log the RA Tag for a Zero correction. 7,050.0 7,080.0 00:12 00:18 6/11/2017 6/11/2017 0.40 PROD1 DRILL WPRT T Wiper back in hole,RIH Wt 14 k lbs, 7,080.0 7,782.0 00:18 00:42 slow down to log the bypassed Res. 6/11/2017 6/11/2017 1.70 PROD1 DRILL DRLG T Set rate at 1.81 bpm,CT 5300 psi, 7,782.0 7,958.0 00:42 02:24 Free spin diff 1300 psi,RIH wt 12 k lbs.WH 701 psi. OBD,CTWt10.3klbs,WOB 1.3k lbs,ROP 150 ft. Good returns to the shaker from trip/sweeps. WellWorc cuttings ration went from 0.99 to 1.12 as sweeps landed. ROP eratic from 280-40 ft/hr. "Drilled 176'in 1.7 hrs for 103 ft/hr average rate 6/11/2017 6/11/2017 0.70 PROD1 DRILL DRLG T Started loosing returns,0.5 bpm loss 7,958.0 8,030.0 02:24 03:06 rate,@ 7958'. Losses increased to 0.75 bpm by 7991',healed slowly to 0.25 bpm by 8010'. OBD,CT 5291',WH 800 psi,CT Wt 7.8 k lbs,WOB 1.0 k lbs,ROP 122 ft/hr 6/11/2017 6/11/2017 0.90 PROD1 DRILL DRLG T Losses grew to 89%@ 8030'. Closed 8,030.0 8,096.0 03:06 04:00 choke and drilled ahead with 100% losses. started building 40 bbl ultra high vis pill. WOB fell off,Pu to restart,34k lbs. Drill ahead 30 feet,PU ,Wt 33 k lbs, reduce rate to 1.52 bpm,RBIH CT 4300,free spin diff 950 psi,CT wt 8.7 k lbs,WOB 1.74 k lbs,ROP 163 ft/hr Atempt to open choke w WH @ 1000 psi,holding 11.44 ppg at the window returns stabilized at 0.55 bpm,or 37% shut in choke. Page 11/37 Report Printed: 7/3/2017 .. • • 0,,,„.....„.„.„ . Operations Summary (with Timelog Depths) } 1G-15 Co€►or_ophiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/11/2017 6/11/2017 0.70 PROD1 DRILL DRLG T Getting sticky,PU 100 feet,PU Wt 33 8,096.0 8,146.0 04:00 04:42 k lbs,RBIH.Pill exiting the nozzle, built WH to 1030, 12.5 ppg EMW at the window. Open choke targeting 11.8 ppg at the window,returns stabilized at 1.5 bpm in,0.4 bpm out. S/I choke,Pu Wt 30 k lbs,drilled ahead squeezing away until 12.4 ppg at the window,1040 psi WH.Opened choke,rates stabilized at 1.5 bpm in, 1.0 bpm out. Pick up Wt 30 k lbs. 6/11/2017 6/11/2017 1.75 PROD1 DRILL DRLG T OBD with partial returns. 1.5 bpm in 1 8,146.0 8,278.0 04:42 06:27 bpm out. CT 4543 psi,WH 630 psi,CT Wt 4.5 k lbs,WOB 1.8 k lbs,ROP 100 ft/hr.• ""8,185'close choke"** 6/11/2017 6/11/2017 0.50 PROD1 DRILL WPRT T Wiper up hole.PUW 36 k 8,278.0 7,060.0 06:27 06:57 6/11/2017 6/11/2017 0.50 PROD1 DRILL WPRT T Wiper back in hole,RIW 12 k 7,060.0 8,278.0 06:57 07:27 6/11/2017 6/11/2017 2.00 PROD1 DRILL DRLG T BOBD, 1.8 bpm at 5,165 psi,BHP 8,278.0 8,477.0 07:27 09:27 3,939,WHP 525, IA 422,OA 88,0.5 bpm losses(35%loss rate) 6/11/2017 6/11/2017 0.50 PROD1 DRILL WPRT T Wiper up hole,PUW 35 k 8,477.0 7,700.0 09:27 09:57 6/11/2017 6/11/2017 0.40 PROD1 DRILL WPRT T Wiper back in hole,RIW 12 k 7,700.0 8,477.0 09:57 10:21 6/11/2017 6/11/2017 3.50 PROD1 DRILL DRLG T BOBD, 1.8 bpm at 4,415 psi,BHP 8,477.0 8,648.0 10:21 13:51 3494,WHP 302,IA 411,OA 80 6/11/2017 6/11/2017 1.00 PROD1 DRILL WPRT T Wiper up hole,PUW 36 k,perform job 8,648.0 7,000.0 13:51 14:51 below window 7,075'to 7,200' 6/11/2017 6/11/2017 0.45 PROM DRILL WPRT T Open EDC,Wiper up hole above 7,000.0 6,440.0 14:51 15:18 cross-over 6/11/2017 6/11/2017 0.25 PROD1 DRILL DLOG T Log the HRZ correction of plus 2.5' 6,440.0 6,482.0 15:18 15:33 6/11/2017 6/11/2017 1.20 PROD1 DRILL WPRT T RIH,back to bottom,closing the EDC 6,482.0 8,648.0 15:33 16:45 at 7,000". 6/11/2017 6/11/2017 1.70 PROD1 DRILL DRLG T BOBD, 1.8 bpm at 4,830 psi,BHP 8,648.0 8,721.0 16:45 18:27 3,610,WHP 380(closed choke),IA 402,OA 65 6/11/2017 6/11/2017 4.10 PROD1 DRILL DRLG T OBD,Wh 403 psi, 10.5 ppg EMW @ 8,721.0 8,850.0 18:27 22:33 the window. CT Wt-2 k lbs,WOB 2.99 k lbs,ROP 20-100 ft/hr. A couple heavyier pick ups when up against suspect siderite lenses,-43- 47 k lbs. **31.4 fUhr while on bottom 6/11/2017 6/11/2017 0.40 PROD1 DRILL WPRT T Wiper trip(1138'),PU Wt 45 k lbs, 8,850.0 7,712.0 22:33 22:57 motor work and neg WOB from 8300- 8260' 6/11/2017 6/11/2017 0.50 PROD1 DRILL WPRT T RBIH,RIH Wt 14 k until 8544 where it 7,712.0 8,786.0 22:57 23:27 dropped to ilk lbs. Multiple setdowns,8627-8720' 6/11/2017 6/11/2017 0.20 PROD1 DRILL WPRT T PU,ream throuth tight spots,to 8506', 8,786.0 8,850.0 23:27 23:39 turn around RBIH. Minor Stack outs @ 8644,8737,and 8820'. Page 12/37 Report Printed: 7/3/2017 Operations Summary (with Timelog Depths) rkE x ConocoPhiilips Vl.xkx Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKB) 6/11/2017 6/12/2017 0.35 PROD1 DRILL DRLG T set rate @ 1.78 bpm,closed choke, 8,850.0 8,858.0 23:39 00:00 WH 523 psi,ECD©window 11.0 ppg,CT 4364 psi,feee spin 1240 psi. OBD,CT wt 0.1 k lbs,WOB 1.88 k lbs, ROP 34 fUhr **22.8 ft/hr while on bottom 6/12/2017 6/12/2017 1.20 PROD1 DRILL DRLG T OBD,Variable ROP,15-100+fUhr. 8,858.0 8,894.0 00:00 01:12 Hard spot @ 8879'. High WOB,low motor work. Broke free drilled ahead • 6/12/2017 6/12/2017 1.00 PROD1 DRILL DRLG T Drilling ahead,Differential motor work 8,894.0 8,900.0 01:12 02:12 increased&WOB fell off 8899',PU 34 k lbs,atempted to RBIH and found bottom @ 8887',PU 42 k lbs,RBIH find bottom at 8879' Multiple pick ups and set downs,2.25 k lbs WOB with little to no motor work stack out at 8878'.Pick up RBIH 7 th time,slowly start makinjg hole. Drill ahead. Differential sticking BHA from DPS down,51 '? 6/12/2017 6/12/2017 5.10 PROD1 DRILL DRLG T OBD drilling ahead CT wt-0 k lbs, 8,900.0 9,024.0 02:12 07:18 WOB 0.7 k lbs, ROP 20-100 fUhr. Pumped hi-vis pill w/5%LVT- (Alpine Pill) pre CT Wt-6.3 k WOB 0.38 k lbs, ROP 37.5 ft/hr. Pick up and restart. post CT Wt 4.2-0 k lbs, 1.4-1.2 k WOB,ROP 80-127 ft/hr Effects of pill lasted-30 min ROP 69 ft/hr during that time. Pumped another 10 bbl pill BHP has climbed slowly over the last two hours from 10.6 to 11.2 EMW @ the window. 6/12/2017 6/12/2017 0.25 PROD1 DRILL DRLG T Wiper up hole,PUW 33 k 9,024.0 7,700.0 07:18 07:33 6/12/2017 6/12/2017 0.25 PROD1 DRILL WPRT T Wiper back in hole,RIW 6 k,work. 7,700.0 9,024.0 07:33 07:48 pipe thru fractured section 8288'- 8,890' 6/12/2017 6/12/2017 3.10 PROD1 DRILL WPRT T BOBD, 1.78 bpm at 3,585',BHP 9,024.0 9,050.0 07:48 10:54 3,693,WHP 655,IA 413,OA 77 6/12/2017 6/12/2017 1.00 PROD1 DRILL TRIP T POOH for BHA check,PUW 32 k,lay 9,050.0 7,000.0 10:54 11:54 in high-vis pill up to 7,000',didn't see much advantage from pumping. 6/12/2017 6/12/2017 1.25 PROD1 DRILL TRIP T Continue POOH,closed choke. 7,000.0 80.8 11:54 13:09 pumping 1.5 bpm following MP. 6/12/2017 6/12/2017 1.25 PROD1 DRILL PULD T At surface,PJSM,PUD drilling BHA# 80.8 0.0 13:09 14:24 14 6/12/2017 6/12/2017 1.00 PROD1 DRILL_ SVRG P Service rig,install and test hydraulic 0.0 0.0 14:24 15:24 fittings. 6/12/2017 6/12/2017 1.50 PROD1 DRILL PULD T PU/MU/PD BHA#15 0.0 80.8 15:24 16:54 6/12/2017 6/12/2017 1.25 PROD1 DRILL TRIP T RIH,with drilling BHA#15 with WFT 80.8 6,445.0 16:54 18:09 motor and new bi-cneter bit 6/12/2017 6/12/2017 0.40 PROD1 DRILL DLOG T Log the HRZ correction of plus 23' 6,445.0 6,485.0 18:09 18:33 6/12/2017 6/12/2017 1.25 PROD1 DRILL CIRC T Continue RIH,Circ 80 bbls of Flo-pro 6,485.0 6,950.0 18:33 19:48 down the back side,2.0 bpm at 6/12/2017 6/12/2017 0.75 PROD1 DRILL TRIP T RIH thru window 6,950.0 9,050.0 19:48 20:33 Page 13/37 Report Printed: 7/3/2017 • • Operations Summary (with Timelog Depths) } 5h �Y , IN r , ' 1G-15 ConocoPhillips _ wts,ka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/12/2017 6/12/2017 3.00 PROD1 DRILL DRLG T OBD, 1.8 bpm at 4,785 psi,BHP 9,050.0 9,113.0 20:33 23:33 3792,WHP 691,IA 405,OA 70, DHWOB 1.2 k,CTSW 2 k,ROP 26 FPH 6/12/2017 6/12/2017 0.25 PROD1 DRILL WPRT T Wiper up hole,PUW 38 k 9,113.0 8,613.0 23:33 23:48 6/12/2017 6/13/2017 0.20 PROD1 DRILL WPRT T Wiper back in hole,trouble getting to 8,613.0 8,192.0 23:48 00:00 bottom PBUH to clean up hole. 6/13/2017 6/13/2017 1.20 PROD1 DRILL WPRT T Struggle to get back to bottom. 8,192.0 9,113.0 00:00 01:12 Pumped 5x5 sweep,Set downs at 8360,8553,CT running weight fell off sharply @ 8517'. PU and restart. Weights and running speeds improved significantly as sweeps exited the bit+ -8672'. Continue to RIH. 6/13/2017 6/13/2017 1.20 PROD1 DRILL DRLG T 1.78 bpm. Ct-5k=/-,WOB 0.5 k lbs, 9,113.0 9,150.0 01:12 02:24 ROP 20 ft/hr.free spin diff 1145 psi. 5x5 lube/LVT pill exits,WOB climbed steadily to+/-1.5 K WOB,ROPS variable,50-20 ft/hr. Drilled ahead,built full pit of alpine pill, 1.5%776,W/2 ppb beads. **31 ft/hr over the interval on bottom 6/13/2017 6/13/2017 2.60 PROD1 DRILL DRLG P Passed 9150'off trouble time from 9,150.0 9,294.0 02:24 05:00 plug back 1.78 bpm. CtWt 0-5 k/-,WOB 0.5- 1.5 k lbs,ROP 20-50 ft/hr.free spin diff 1140 psi.Drilled ahead,built full pit of alpine pill, 1.5%776,W/2 ppb beads.pumping pills as needed. CT Wt back to 7 k lbs post beads, Last PU 34 k lbs,had been consistently 43 k prior to lubes/beads. **55 ft/hr over the interval on bottom 6/13/2017 6/13/2017 1.30 PROD1 DRILL DRLG P Drilling ahead 9,294.0 9,400.0 05:00 06:18 CT Wt-2 k lbs,WOB 0.8 k lbs,ROP 80 ft/hr. "*82 ft/hr over the last interval on bottom 6/13/2017 6/13/2017 0.80 PROD1 DRILL WPRT P Wiper trip(1650') PU Wt 36k lbs 9,400.0 7,750.0 06:18 07:06 6/13/2017 6/13/2017 0.70 PROD1 DRILL WPRT P Turn around RIH Wt vastly improved, 7,750.0 9,400.0 07:06 07:48 15k tapering to 11 k lbs by 8926'. CT Wt tapered off to 11 k lbs by 9150'. Hole clean less one WOB bobble at 8365'@ Falut A. 6/13/2017 6/13/2017 1.10 PROD1 DRILL DRLG P 1.80 bpm,CT 4175 psi,WH 600 psi, 9,400.0 9,450.0 07:48 08:54 ECD 11.1 ppg @ the window. Closed choke. OBD,CT Wt 0-5 k lbs,WOB 2.2 k lbs,ROP 40 ft/hr. drilling break at 9445'. ***45 ft/hr over the last interval on bottom 6/13/2017 6/13/2017 0.20 PROD1 DRILL DRLG P Missed two surveys,PU to grab 9,450.0 9,450.0 08:54 09:06 surveys,PU Wt,34k lbs. Page 14/37 Report Printed: 7/3/2017 • Operations Summary (with Timelog�pths) ConocoPhillips 53:'nka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log • Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/13/2017 6/13/2017 2.40 PROD1 DRILL DRLG P 1.80 bpm,CT 4175 psi,WH 600 psi, 9,450.0 9,607.0 09:06 11:30 ECD 11.1 ppg @ the window. Closed choke. OBD,CT Wt 0-5 k lbs,WOB 2.2 k lbs,ROP 40 ft/hr. drilling break at 9445',hard stuff @ 9539'. Geos asking to point down. Heavy vibrations,DD asked to reduce pump rate,little change in vibrations @ 1.6 bpm,WH from 430 to 300 psi in ten minutes,EDC dropped to 9.9 ppm EMW. Increased rate to 1.82 bpm. Last two pick ups,55 k lbs&60 k lbs. "**65 ft/hr over the last interval on bottom 6/13/2017 6/13/2017 1.50 PROD1 DRILL WPRT P Wiper,third for tie in,PU 60 k lbs. 9,607.0 7,040.0 11:30 13:00 Neg WOB spike @ 9482'. Start pulling heavy coil wt©8687,weigth fell off then increased @ 8392,8386'. atempt to RBIH,S/D-5 k lbs,Work pipe to 60 k up,-10 down,rotate tool face,bit free.Pump 10 bble beaded pill. Work pipe and vary pump speed. Pull free pror to pill coming out. Continue to POOH. 6/13/2017 6/13/2017 0.20 PROD1 DRILL DLOG P Tie into RA tag for+7' 7,040.0 7,098.0 13:00 13:12 6/13/2017 6/13/2017 1.50 PROD1 DRILL WPRT P Wiper back in hole. Carry 15 k CT Wt 7,089.0 9,607.0 13:12 14:42 to 8464'where it fell off rapidy to 7k by 8867'. Multiple set downs and snubbing by 9100'. PU slowly until bead pill reaches the bit. RBIH,CT Wt 9 k lbs as we ran past 9100'. 6/13/2017 6/13/2017 0.20 PROD1 DRILL DRLG P 1.78 bpm,free spin diff 1030 psi. CT 9,607.0 9,621.0 14:42 14:54 Wt-2 k lbs,WOB 1.5 k lbs,ROP 60 ft/min Lost WOB and all motor work. 6/13/2017 6/13/2017 0.20 PROD1 DRILL' WPRT P PU Wt 48 k lbs,pull heavy 41 -45 k 9,621.0 9,621.0 14:54 15:06 lbs,Turn around at 9300'as pill exiting the nozzle. RBIH. RIH Wt 10- 6/13/2017 6/13/2017 2.20 PROD1 DRILL DRLG P 1.78 bpm,free spin diff 1030 psi. CT 9,621.0 9,756.0 15:06 17:18 Wt-2 k lbs,WOB 1.5 k lbs,ROP 60 ft/min Lost WOB and all motor work.PU,Wt 54 k lbs,PUH,RBIH,drill ahead. 1.82 bpm,free spin diff 1250 psi,CT Wt-3 k lbs,WOB 1.9 k lbs,ROP 29 ft/ hr. Missed 2 surveys 9700',PU 42 k lbs, RBIH, 6/13/2017 6/13/2017 0.50 PROD1 DRILL DRLG P RBIH,set rate 1.74 bpm, 1150 free 9,756.0 9,791.0 17:18 17:48 spin,CT 3850 psi. 6/13/2017 6/13/2017 0.70 PROD1 DRILL WPRT P Wiper trip,PUW=48K 9,791.0 8,500.0 17:48 18:30 Page 15/37 Report Printed: 7/3/2017 Operations Summary (with TimelogDepths) 10-15 • Conoca"ttiiUips 'J.r.ka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/13/2017 6/13/2017 1.70 PROD1 DRILL WPRT P Wiper in-hole,working to get to 8,500.0 9,791.0 18:30 20:12 bottom,pumped beaded pill to aid getting to bottom,stacking weight at —9575',re-orient TF in attempt to get by 9575',experience difficulty passing 9564'.beads begin exiting bit,difficulty passing 9585'&9607',continue to adjust TF.RIW=9.5K (note:ECD down to 10.3 ppg), 6/13/2017 6/13/2017 1.80 PROD1 DRILL DRLG P BOBD, FS=1079 psi pumping 1,78 9,791.0 9,852.0 20:12 22:00 bpm,bounced off something hard at 9790'with—60°DLS average over 20' section,annular suddently dropped at 9841'from 3700 psi to 3550'psi, ECD dropped to as low as—9.2 ppg. 6/13/2017 6/13/2017 1.30 PROD1 DRILL WPRT P Pulled short WT to 9650',begin 9,852.0 9,852.0 22:00 23:18 building 40 bbl 100K LSRV pill to aid in increased losses,WHP=345 psi, rate=1.43 bpm,annular=3422 psi, difficulty getting started drilling at ' 9852',PUW=48K,begin pumping 40 bbl 100K LSRV pill. 6/13/2017 6/14/2017 0.70 PROD1 DRILL DRLG P BOBD,CWT=-5K,WOB=2K,rate= 9,852.0 9,860.0 23:18 00:00 1.74 bpm,ECD=9,86 ppg,ROP=48 fph,PU to avoid differential sticking at 9858', 100K LSRV pill exits bit,helps to increase annular pressure,though still low at 3482 psi(10.5 ECD at 9860') 6/14/2017 6/14/2017 1.60 PROD1 DRILL DRLG P Continue drilling with low ROP, 9,860.0 9,863.0 00:00 01:36 lube/bead pills having limited success, continual PU's to make any progress, CWT=-10K,WOB=.8K,rate=1.8 bpm,annular=3500 psi,WHP=490 psi,difficulty getting started at 9862', attempting various rates 6/14/2017 6/14/2017 1.10 PROD1 DRILL DRLG P Continue to attempt to make progress 9,863.0 9,864.0 01:36 02:42 at 9863',drilling on hard spot with motor work indicated.begin pumping increased lube pill(1.5%/1.5% 776/LoTorq,2 ppb beads,LVT) 6/14/2017 6/14/2017 0.30 PROD1 DRILL WPRT P Wiper up to 9550 while waiting for pill 9,864.0 9,550.0 02:42 03:00 to come around, PUW=44K 6/14/2017 6/14/2017 1.40 PROD1 DRILL WPRT P Increased lube pill entirely out bit, 9,850.0 9,865.0 03:00 04:24 experience difficulty getting back to. bottom past 9855',stacking weight, attempting various TF's,run in speeds,rates with no success. Another lube/bead pill begins exiting bit with no success,have good RIW, though lose it all when approaching 9855',differential is extremely low. Work to bottom but can not drill past 9852' 6/14/2017 6/14/2017 1.30 PROD1 DRILL WPRT P Consult with town,pump sweeps and 9,865.0 8,437.0 04:24 05:42 start wipering out of hole for BOP test. Page 16/37 Report Printed: 7/3/2017 • fid • f • 'S gdi ' ' Operations Summary (with Timelog epths) :: ,' ,:t 1G-15 ConocoPhiiii ps ' Rig: NABORS CDR3-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) 6/14/2017 6/14/2017 1.70 PROD1 DRILL WPRT T While POOH chasing sweeps pull 8,437.0 8,420.0 05:42 07:24 heavy at 8437',RBIH,stack out,work pipe,-8 k down and able to RIH but , unable to POOH with multiple attempts to 73 K lbs. Hanging up at 8420 bit depth. Coil connector right at A default where we were stuck yesterday. Pump pills and continue to work pipe,pop free at-66k while POOH at 55 ft/min. 6/14/2017 6/14/2017 2.00 PROD1 DRILL WPRT P Continue to POOH. Build section 8,420.0 66.0 07:24 09:24 clean with regard to CT wt and WOB. No noticeable motor work,but very low diff too. Pause at the window,S/D pumps,observe EDC fall to 10.1 ppg in-1 minute. Assume 10.5 is adequate kill weight. Online w/ pumps,continue to POOH. 6/14/2017 6/14/2017 1.80 PROD1 DRILL PULD P PJSM, Bump up,space out. PUD and 66.0 0.0 09:24 11:12 LD BHA#15. weatherford motor parted at the AKO. Left-2.2'tip of 2 3/8"WFT Motor 0.75°AKO(T22505) plus NOV Bi Center bit 0.65'(A226202)down hole 6/14/2017 6/14/2017 1.50 PROD1 DRILL PULD P Jet stack,test inner reel valve-Good, 0.0 0.0 11:12 12:42 note,can not pump managed pressure while jetting stack. (Inner real valve satisfies flood up and shell test) 6/14/2017 6/14/2017 0.50 PROD1 DRILL CTOP P Unstab injector,complete greasing 0.0 0.0 12:42 13:12 stack,instal night cap,flood up. 6/14/2017 6/14/2017 1.20 PROD1 WHDBOP BOPE P Test 1 Swab#1,low good,bump, 0.0 0.0 13:12 14:24 regrease,retest,pass 6/14/2017 6/14/2017 0.40 PROD1 WHDBOP BOPE P Test 3,no double swab,i.e.no test 0.0 0.0 14:24 14:48 #2. Lower blind shear,BOP TV2, bump once,low high good. 6/14/2017 6/14/2017 0.20 PROD1 WHDBOP BOPE P Test 4,TV1,low/high good 0.0 0.0 14:48 15:00 6/14/2017 6/14/2017 0.40 PROD1 WHDBOP BOPE P Test 5,upper blind,B1&5,C 4,5,8 0.0 0.0 15:00 15:24 &12,R1 and bleeder 1,low/high good . hydraulic leak on blind ram,bleed down,mechanic on call. 6/14/2017 6/14/2017 1.80 PROD1 WHDBOP BOPE P line up to pump managed presure, 0.0 0.0 15:24 17:12 pump managed pressure 6/14/2017 6/14/2017 1.80 PROD1 WHDBOP BOPE P Test 5,upper blind,B1&5,C 4,5,8 0.0 0.0 17:12 19:00 &12,R1 and bleeder 1,low/high good 6/14/2017 6/14/2017 0.60 PROD1 WHDBOP BOPE P Test 6,Charlie 3,6,7,&1,Bravo 2 0.0 0.0 19:00 19:36 &6&Tango 2,low/high good Test 7,Manual Choke D&Super Choke C,1500 psi test,good 6/14/2017 6/14/2017 0.20 PROD1 WHDBOP BOPE P Test 8,Charlie 2, 10&Tango 1,good 0.0 0.0 19:36 19:48 Page 17/37 Report Printed: 7/3/2017 ,....._ .,r,.:,,,.,.;„„.t. ,_ • °`` � Operations Summary (with Timeloggepths) )„ � '44,--i. ` 1G-15 ConocoPhiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/14/2017 6/14/2017 0.60 PROD1 WHDBOP BOPE P Test 9,Romeo 2,Bleeder 2,Charlie 1 0.0 0.0 19:48 20:24 &9,low test bleeding off,second low test good,high good. Note:Begin building liner running pill/KWF to 10.5 ppg as per town discussion. 6/14/2017 6/14/2017 0.50 PROD1 WHDBOP BOPE P Test 10,Bravo 4&8,Romeo 3& 0.0 0.0 20:24 20:54 Bleeder 3,low/high,good 6/14/2017 6/14/2017 0.80 PROD1 WHDBOP BOPE P Test 11,Bravo 3&Bravo 7,Liine up 0.0 0.0 20:54 21:42 to pummp managed pressure,install test joint. 6/14/2017 6/15/2017 2.30 PROD1 WHDBOP BOPE P Test 12-16,difficulty getting low test 0.0 0.0 21:42 00:00 on test 14 as pressure rises requiring reducing MP rate momentarily, complete BOPE test at midnight. 6/15/2017 6/15/2017 1.70 PROD1 DRILL CTOP P LD test joint,MU nozzle,stab on,blow 0.0 0.0 00:00 01:42 -down well control choke,change out UQC,perfrom slack management 6/15/2017 6/15/2017 1.70 PROD1 DRILL PULD T PJSM,PU/PD BHA#16 Clean-out 0.0 62.0 01:42 03:24 Assembly(.6°AKO X-Treme motor, D331 ridge-set w/back cutters),tag up 6/15/2017 6/15/2017 1.20 PROD1 DRILL i TRIP T RIH with BHA#16,EDC open, 62.0 6,415.0 03:24 04:36 6/15/2017 6/15/2017 0.30 PROD1 DRILL DLOG T Tie for-6.5'correction 6,415.0 6,461.0 04:36 04:54 6/15/2017 6/15/2017 0.40 PROD1 DRILL TRIP T Continue RIH,close EDC after step 6,461.0 6,951.0 04:54 05:18 rate test. Perform step rate test at window: 2.25 bpm=10.32 ECD 1.75 bpm=10.28 ECD 1.25 bpm=10.0 ECD 1.00 bpm=9.8 ECD 6/15/2017 6/15/2017 2.80 PROD1 DRILL TRIP T Continue to RIH,pass window clean, 6,951.0 9,564.0 05:18 08:06 build clean,continue to RIH in open hole, 1.3 bpm @ 50 fUmin. See-1 k WOB spike at 8354 A fault,continue to RIH,S/D 9566',PU 41 k lbs,RBIH S/D 1.7 k WOB @ 9569',consult W town,RBIH,S/D 3rd time 9564,PU 38 k lbs,PUH above A Fault @ 8350'. RIH pumping 1.8 bpm @ 50 fUmin, slight CT bobble,PU through zone, clean,RBIH 1.2 bpm 50 ft/min,saw slight bobble W 2 k CT Wt slack off @ 8464'. Continue to RIH. 6/15/2017 6/15/2017 0.60 PROD1 DRILL DISP T POOH from fish laying in 34 bbl 10.5 9,564.0 7,912.0 08:06 08:42 ppg beaded liner running pill to above the top of loss zone,7958'. 6/15/2017 6/15/2017 0.80 PROD1 DRILL TRIP P Paint EOP,end of pipe flag @ 7,912.0 5,262.0 08:42 09:30 7912.37'(Yellow),continue to POOH, paint window flag @ 5262.45(White) 6/15/2017 6/15/2017 1.00 PROD1 DRILL TRIP P Continue to POOH pumping 8.7 ppg 5,262.0 55.0 09:30 10:30 Power pro lite W 2.5%clay stop. Page 18/37 Report Printed: 7/3/2017 • • Operations Summary (with Timelog Depths) '�' ` z 1G-15 ConocoPhillips ALv,ka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/15/2017 6/15/2017 1.10 PROD1 DRILL PULD P Bump up,space out,open bleeder on 55.0 0.0 10:30 11:36 stack to half drum,fill hole till returns to drum,observe flow,well on a vac. PJSM,hole fill in—30 min 1.6 bbls, Lay down BHA#16 over a dead well. 6/15/2017 6/15/2017 0.40 COMPZI CASING PUTB P Prep floor for liner running,PJSM. 0.0 0.0 11:36 12:00 6/15/2017 6/15/2017 2.40 COMPZ1 CASING PUTB P PU and make up 42 joints of (2 3/8", 0.0 1,665.0 12:00 14:24 4.6#,L-80,ST-L Slotted Liner),over a ported bull nose and topped with a shortly deployment sleeve. (1665.13') Filling the hole every 5 joints. 6/15/2017 6/15/2017 0.40 COMPZ1 CASING PULD P PU BHA#17,coil track and Baker 1,665.0 1,709.0 14:24 14:48 hydraulic GS,close rams,stab injector,open up,EDC closed. Total hole fill 13.3 bbls 6/15/2017 6/15/2017 1.40 COMPZI CASING RUNL P RIH W liner,line up 8.7 pg beaded 1,709.0 7,162.0 14:48 16:12 liner running pill. Tie into flag for- 11.68'correction. 6/15/2017 6/15/2017 1.30 COMPZI CASING RUNL T While RIH @ 50 ft/min,stick became 7,162.0 7,162.0 16:12 17:30 unresponsive. Atempted to dial down torque to injector to stop forward progress,unsucessfull. Set injector brake to stop forward motion. Pulled up hole so that bottom of liner is above the window and parked.Built new liner running pill. Install new stick. 6/15/2017 6/15/2017 3.00 COMPZ1 CASING RUNL T Test/adjust new stick while POOH, 7,162.0 6,959.0 17:30 20:30 RIH. New stick does not appear to solve the issue while RIH,trouble shoot HMI inputs to understand the issue better(injector string weight set points&WOB set points appear to intermitently work to stop forward progress of pipe),set brakes&reboot HMI without success in solving the issue.A set point of coil speed=30 fpm works,when setting coil speed= 40 fpm,the brake is required to stop forward progress of pipe,which apprears successful every test.Await mechanic to begin to trouble-shoot encoders at Nabors request,reboot PLC's(programable logic controller), test,issue resolved. 6/15/2017 6/15/2017 0.60 COMPZ1 CASING CIRC P Pumping 40 bbl liner pill down 6,959.0 6,959.0 20:30 21:06 backside 6/15/2017 6/15/2017 2.10 COMPZ1 CASING RUNL P Continue to RIH with liner,weight 6,959.0 8,300.0 21:06 23:12 check at window,PUW=32K, observing increased WOB and negative CWT,PU&work liner at —8750', again at—8765'with PUW= 50K,again at 8780',8795',&8800', difficulty working pipe past 8826', begin building 2 50 bbl liner running pills to pump down back-side,PUH slowly Page 19/37 Report Printed: 7/3/2017 Operations Summary (with Timelog Depths) S' , ,.. '.,':•44,,:,,- i � 1G-15 6.Cor occehiilips Rig: NABORS CDR3-AC Joh: 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) 6/15/2017 6/16/2017 0.80 COMPZ1 CASING RUNL P Pump at.65 bpm down coil in attempt 8,300.0 8,500.0 23:12 00:00 to work liner down while awaitinig liner pill(pumps off when PUH to not release off GS),unsuccessful,begin pumping 50 bbl pill down back-side at 23:50 hrs. 6/16/2017 6/16/2017 0.40 COMPZI CASING CIRC P Pumping 100 bbl liner pill down back- 8,500.0 7,961.0 00:00 00:24 side 6/16/2017 6/16/2017 0.90 COMPZ1 CASING RUNL P Liner pill to window,RBIH with liner at 7,961.0 9,545.0 00:24 01:18 50 fpm,continue to bull-head at reduced rate while RIH to get pill to fractures at-7950'(.9 bpm),-15K CWT at 7960'when begin RIH, 15K CWT at 8600', 13K CWT at 8875. Arrive at set depth,weight check= 40K,RBIH to set depth,bring up pumps,release off liner,PUW=32K 6/16/2017 6/16/2017 1.70 COMPZ1 CASING TRIP P POOH to LD BHA#17,tag up 9,545.0 27.0 01:18 03:00 6/16/2017 6/16/2017 1.50 COMPZ1 CASING PULD P PJSM,flow check,open bleeder, 27.0 0.0 03:00 04:30 flowing,shut-in choke,WHP rises, well is flowing with 8.64 ppg fluid in the hole,PUD BHA#17 6/16/2017 6/16/2017 1.00 COMPZ1 CASING PULD P PU BHA#18 27.0 0.0 04:30 05:30 • 6/16/2017 6/16/2017 1.00 COMPZ1 CASING PULD P PD BHA#18,inspect pack offs. 0.0 81.0 05:30 06:30 6/16/2017 6/16/2017 1.60 COMPZI CASING RUNL P Bump up,set counters,RIH 81.0 6,445.0 06:30 08:06 6/16/2017 6/16/2017 0.20 COMPZ1 CASING DLOG P Tie into the HRZ for a-7'correction 6,445.0 6,473.0 08:06 08:18 6/16/2017 6/16/2017 0.20 COMPZ1 CASING RUNL P Comtinue to RIH, 6,473.0 6,949.0 08:18 08:30 6/16/2017 6/16/2017 0.50 COMPZ1 CASING RUNL P Park,Pumps down,close EDC,High 7,949.0 7,880.0 08:30 09:00 side anchored billet,line up across the top pumping managed pressure,PU Wt 30 k lbs,continue to RIH. 6/16/2017 6/16/2017 0.20 COMPZ1 CASING RUNL P SD @ 7880'.tool highside,Line up 7,880.0 7,880.0 09:00 09:12 down the coil,PU to neutral CT wt- 30 k lbs,roll the pumps against a closed choke. CT pressure broke back @ 3800 psi,Slack off CT weight WOB climed to 6.7 k lbs,Anchors set and holding. 6/16/2017 6/16/2017 1.60 COMPZ1 CASING TRIP P Line up across the top pumping 7,880.0 71.0 09:12 10:48 managed presure,POOH W BHA#18. 6/16/2017 6/16/2017 1.10 COMPZ1 CASING PULD P PJSM,Bump up,Checks holding, 71.0 0.0 10:48 11:54 PUD BHA#18,LD 6/16/2017 6/16/2017 1.30 PROD2 STK PULD P PU BHA#19 AL1 lateral drilling 0.0 71.0 11:54 13:12 assembly,PJSM,PD BHA,check . pack offs. 6/16/2017 6/16/2017 1.20 PROD2 STK TRIP P Bump up,set counters,RIH,park @ 71.0 4,832.0 13:12 14:24 1026',close EDC,Test agitator- good,open EDC, continue to RIH. Page 20/37 Report Printed: 7/3/2017 • Operations Summary (with TimelogDepths) 1G-15 ConocoPhitiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/16/2017 6/16/2017 7.60 PROD2 STK RGRP T Storage reel locked outwhile running 4,932.0 4,767.0 14:24 22:00 in hole.confer with town,create plan forward Plan Forward: Complete welding pins(good),replace all bolts on off-reel side(good), inspect goose-neck(good),inspect flange bolts from master valve up (good),PUH and inspect pipe(good), RIH and PUH at various speeds while evaluating injector&software(good). Continue with CTD operations. 6/16/2017 6/16/2017 0.40 PROD2 STK TRIP P Continue RIH 4,767.0 6,415.0 22:00 22:24 6/16/2017 6/16/2017 0.10 PROD2 STK DLOG P Tied into HRZ for a-6'correction 6,415.0 6,500.0 22:24 22:30 6/16/2017 6/16/2017 0.40 PROD2 STK TRIP P Continue RIH,close EDC 6,500.0 6,950.0 22:30 22:54 6/16/2017 6/17/2017 1.10 PROD2 STK WAIT T Difficulty stopping forward progress of 6,950.0 6,950.0 22:54 00:00 pipe,similar issue from yesterday, reboot PLC's and rectifier,no success, continue to test&troubleshoot,open EDC Notice fluid leak at R5 flange,tightend flange bolts,resolved. 6/17/2017 6/17/2017 5.00 PROD2 STK WAIT T Continue to trouble-shoot coil RIH 6,950.0 6,959.0 00:00 05:00 issue,replace reel motor encoder. ARP is on the way to CDR3 from lower 48 6/17/2017 6/17/2017 1.50 PROD2 STK WAIT T Start up pumps after total rig sut down 6,950.0 6,959.0 05:00 06:30 during testing.pumping 1.36 bpm, Duovis 2.5%clay stop in 6%KCL, zero wellhead and 2882 annular,built to 3433 psi annular and 500 psi WH at depth. Swap from pumping down the coil to over the top,lined up managed pressure and staged down to target of 40 psi WH,stabilized rate of—0.8 bpm and annular of 3275 psi. Changed out three encoders,one was the main. 6/17/2017 6/17/2017 1.70 PROD2 STK WAIT T PUH to 5800'at various rates from 20 6,950.0 6,427.0 06:30 08:12 ft/min to 80 ft/min. No stick issues. RBIH at variable speeds to 100 ft/rnin while observing the Bonitron (contactor to the resistor that loads the VFD drives when they are stopped) observed cooler fan not turning on. No stick issues. 6/17/2017 6/17/2017 1.20 PROD2 STK WAIT T Swap back to high line power,PU to 6,427.0 5,800.0 08:12 09:24 5800'. Page 21/37 Report Printed: 7/3/2017 • A . °',` R Operations Summary (with Timeloggepths) d'. z 1G-15 ConocoPhillips 'd ka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/17/2017 6/17/2017 1.20 PROD2 STK WAIT T RBIH at various speeds to 6400',no 5,800.0 6,195.0 09:24 10:36 issues, PUH to 5800'repeat,saw issue RIH @ 60ft/hr and saw the dead stick issue. Continue to RIH and atempt to stop. From 60 ft/sec if the stick is brought abruptly to neutral the RIH speed is dropping but not at a quick enough rate,the break sets after 7 sec. From 60 ft/min approx 50fUmin in 7 sec. When pulling the stick back slowly the RIH speed responded appropriatly. When running at 40 ft/min and changing the set point in. the HDMI controller to 30 ft/min it took 20 sec to change. 6/17/2017 6/17/2017 2.10 PROD2 STK WAIT T Verified comms between the stick and 6,195.0 6,195.0 10:36 12:42 the encoders. Took more readings and contacted Peter w/AARP. Wait on ARP. While pulling up hole on the last trip lost Nabors depth control,still have Baker depth control. 6/17/2017 6/17/2017 3.30 PROD2 DRILL WAIT T POOH @ 70 ft/min,error,"dynamic 6,195.0 5,797.0 12:42 16:00 break resistor alert"park coil at 6088'. clear fault,RIH,stick operating normally,POOH to gain some space, RBIH,stick worked as it should with quick soft stop of injector travel and reel. Continued to RIH and POOH w various effects. Typical stop times 4-5 sec from 50-100 ft/min speed typical travel past neutral stick is approx 5' 6/17/2017 6/17/2017 1.00 PROD2 STK WAIT T S/D pumps,close EDC,line up down 5,797.0 5,995.0 16:00 17:00 the coil at 0.8 bpm,—880 psi diff. Set auto drill parameters to kick out at 800 psi,auto drill functioned as it should. Restarted,lowered pump rate auto drill engaged,increased pump rate above set kick out and kicked out • instantly. S/D pumps,open EDC,Line up down the back side on managed pressure holding—400 psi WH©0.8 bpm and annular of 2900 psi. Update town and decide to move forward with drilling. Trip in hole to tie in. 6/17/2017 6/17/2017 0.20 PROD2 STK TRIP P Trip to logging point 5,995.0 6,445.0 17:00 17:12 6/17/2017 6/17/2017 0.20 PROD2 STK DLOG P Tie into the HRZ fora+4.5'. 6,445.0 6,465.0 17:12 17:24 6/17/2017 6/17/2017 1.40 PROD2 STK TRIP P Continue to RIH,weight check at 6,465.0 7,860.0 17:24 18:48 window 31K,dry tag TOB at 7860' Page 22/37 Report Printed: 7/3/2017 • 'I x..,„i,l,„,,,7,..„ ..,,,,t„, t,::,.._:::, . , , _ Operations Summary (with Timelog Ppths) rbc; -., 1G-15 ConocoPhitlips §s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/17/2017 6/17/2017 2.20 PROD2 STK KOST P Kicking off billet at 7860',30°ROHS, 7,860.0 7,870.0 18:48 21:00 pumping 1.6 bpm,difficulty getting started on billet FS=900 psi,CWT= 16.7K,WOB=.7K,WHP=640 psi,dp =—900 psi,WHP increases to 644 psi, WHP increases to 800 psi,drops back to 685 psi,pump 5 bbl of excess liner pill to aid in weight transfer. Note:Pre-load PDL while KO billet, 6/17/2017 6/17/2017 0.60 PROD2 DRILL DRLG P Off billet drilling ahead,CWT=12.6K, 7,870.0 7,900.0 21:00 21:36WOB=1.7K,ROP—80 fph,PUW from 7900 is 32K,dry drift billet area up& down,clean 6/17/2017 6/18/2017 2.40 PROD2 DRILL WAIT T PU into cased hole,shut-down pumps 7,900.0 6,910.0 21:36 00:00 in attempt to hold 500 psi WHP(per town request to see if drilling on open choke is possible),WHP did not hold at 500 psi,open EDC,bring pumps back up,replace Bonitron breaker relay in attempt to resolve injector/reel issues,test. 6/18/2017 6/18/2017 1.00 PROD2 DRILL WAIT T Continue with Bonitron breaker relay 6,910.0 6,910.0 00:00 01:00 replacement.Begin testing PUH& RIH at various speeds.The replacement appears to have solved the issue,reducing the voltage over the relay below the limp-mode of —980V down to—920V,shifting the entire volatage range down.RIH and PUH speeds of up to 100 fpm, stopping&stick control operate as expected during testing. Close EDC,begin RIH to resume CTD ops 6/18/2017 6/18/2017 0.50 PROD2 DRILL TRIP P RIH,tie-in for+2'correction,stall 6,910.0 7,900.0 01:00 01:30 getting down to bottom at 7889', 6/18/2017 6/18/2017 2.00 PROD2 DRILL DRLG P BOBD,pumping 1.8 bpm,CWT=10K, 7,900.0 8,020.0 01:30 03:30 WOB=1.5K,FS=1100 psi,WHP= 647 psi,began sending 5 bbl pill (1.5%776),ROP from 50-250 fph. Note:PU off bottom to get/check surveys&tools at 2:15&3:15 am, one survey indicates possible—30° DLS. 6/18/2017 6/18/2017 2.80 PROD2 DRILL DRLG P BOBD,pumping 1,8 bpm,CWT= 8,020.0 8,124.0 03:30 06:18 9.5K,WOB=1.3K,WHP=631 psi, ROP=150 fph,rig geologist believes likely in the Siderite cap b/w fractures, variable ROP requiring PU's,PUW's= —33K,squatting down to 0.1K,begin sendiing 5 bbl pill at 8049'. 6/18/2017 6/18/2017 0.60 PROD2 DRILL WPRT P PU,pull wiper early to pump lube pill 8,124.0 6,958.0 06:18 06:54 down our backside,PO Wt 43k lbs, Page 23/37 Report Printed: 7/3/2017 • Operations Summary (with Timelog Depths) +tet , 1G-15 Conoco6Phiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/18/2017 6/18/2017 0.60 PROD2 DRILL DISP P Pull above window,line up down the 6,958.0 7,043.0 06:54 07:30 back side,Pump 47 bbls of liner running pill,lubes and beads,down the coil by 4.5"tubing annulus. Beaded lub pill extends from surface to—4150'. 6/18/2017 6/18/2017 0.20 PROD2 DRILL DLOG P RBIH,tie into the RA tag for a+2 foot 7,043.0 7,067.0 07:30 07:42 correction. 6/18/2017 6/18/2017 0.50 PROD2 DRILL TRIP P Continue to RIH to bottom. See WOB 7,067.0 8,124.0 07:42 08:12 spikes at 7185'2.8k,7538'1 k,7631' 3.34 k lbs,small weight bobble @ 7860'when passing the window. 6/18/2017 6/18/2017 0.30 PROD2 DRILL DRLG P Set rate 1.78 bpm,choke still closed, 8,124.0 8,130.0 08:12 08:30 WH994 ,CT4390 psi,Free spin diff 1022 psi. BOBD,WOB.8 k lbs,ROP 24 ft/hr Drill ahead 6',in that time well head climbed to 1100 psi and held breifly then continued to 1400 psi. 6/18/2017 6/18/2017 1.30 PROD2 DRILL WPRT P PU Wt 33 k lbs,PUH,WH increased 8,130.0 6,894.0 08:30 09:48 the 1500,dropping rate to maintain pressure,cracked choke and bring rate back up to 1.8 bpm,continue to POOH. Saw some over pull to 48 CT Wt,clean was 38-40k starting @ 7945' Work pipe and continue to POOH to the window. 6/18/2017 6/18/2017 0.60 PROD2 DRILL CIRC P Park above the window. S/D pumps 6,894.0 6,850.0 09:48 10:24 and observe pressures,WH 870 Annular 3787,in—4 min pressures fell to 505 WH and 3398 psi annular. On line with the pumps holding 400 psi and pumping 0.5 bpm,consult with town regarding choke position. 6/18/2017 6/18/2017 1.10 PROD2 DRILL CIRC P Open EDC and test rate returns. 6,850.0 6,840.0 10:24 11:30 Crack choke targeting 10.0 ppg heavy while increasing to drilling rate. 1.80 bpm in,1.6 bpm out holding 10.2 ppg EDC,505psi WH and 3389 psi annular. 6/18/2017 6/18/2017 0.50 PROD2 DRILL TRIP P Open EDC,pump 5x5 sweep and 6,840.0 8,130.0 11:30 12:00 chase down coil,close EDC,RIH, minor WOB spikes from 0.5 k to 1k @ 7090,7163,7155,7189'. No motor work 6/18/2017 6/18/2017 0.20 PROD2 DRILL WPRT P Tag bottom,PU 33 k lbs,Bring pumps 8,130.0 8,130.0 12:00 12:12 to 1.80 bpm, 1.60 bpm out,PUH slowly to 8090' observing pressures. All good,RBIH. 6/18/2017 6/18/2017 3.30 PROD2 DRILL DRLG P 1.8 bpm in,1.6 bpm out,WH 180, 8,130.0 8,410.0 12:12 15:30 annulus 3347 psi,CT 4125 psi,free spin diff 1012 psi OBD,CT Wt 6.2 k lbs,WOB 1.9 k lbs, ROP 70 fUhr,monitored pressures, slowly visc'd up the duo vis system and drilled ahead. Losses still—1/8 bpm.PU Wt 33-35 k lbs. **85 ft/min ROP over interval on bottom,note held rate to 75-85 for first hour,hit hard stuff&drilled last section @ 200fUhr Page 24/37 Report Printed: 7/3/2017 • Operations Summary (with Timelog epths) 1G-15 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/18/2017 6/18/2017 0.50 PROD2 DRILL WPRT P PU on1370',wiper to just below 8,410.0 7,055.0 15:30 16:00 window to clean up and verify build status. Pu 30 k lbs. 6/18/2017 6/18/2017 0.20 PROD2 DRILL WAIT T Upon attempting to RBIH,storage reel 7,050.0 7,055.0 16:00 16:12 locked out. 6/18/2017 6/18/2017 5.80 PROD2 DRILL WAIT T PUH above window,park,S/D pumps, 7,055.0 6,965.0 16:12 22:00 attempt to open EDC,diff not comming down,attempt to jog, storage reel locked out,open EDC, atempt to RBIH,reel locked out 3rd time. Pump bottoms up @ 2.22 bpm in,2.06 bpm out. Remain parked circulating,confer with town,decison made to POOH,continue parked at 6965'allowing electrician time to prepare to POOH. Nabors in contact with Peter from ARP,Peter indicated that he has modified the existing"code"to brake/lock-out the storage real 2seconds after the injector,given an over voltage lock-out situation.ARP will install the modified logic to CDR3 tomorrow for testing(6/19). Additionally,Nabors attempting to aquire a replacement Bonitron (Bonitron headquarters currently closed).Rate In=.5 bpm,Rate out =.4 bpm. 6/18/2017 6/19/2017 2.00 PROD2 DRILL TRIP T Begin POOH at 5 fpm to LD BHA, 6,965.0 6,519.0 22:00 00:00 tripping on 10 ppg schedule,stop at 6912',allow Nabors&ARP time to gather data,continue POOH at 5 fpm, increase POOH speed to 10 fpm at 6880', increase speed to 15 fpm at 6,600'. Unable to continue to POOH at 6819'(stuck pipe,likely packed-oft), increase rate to 1.67 bpm,unable to orient,gain ability to orient,believe packed-off betwee EDC and HOT at thihs point,confer with town 6/19/2017 6/19/2017 0.30 PROD2 DRILL TRIP T Confer with town,decision made to 6,519.0 6,526.0 00:00 00:18 RIH at 1 fpm in attempt to become un- stuck,bring down pumps,close EDC 6/19/2017 6/19/2017 2.40 PROD2 DRILL TRIP T Begin POOH,bring rate up to 1.5 6,526.0 61.0 00:18 02:42 bpm,observe no rate out,followed by sudden rate out,and pressure drop, indicating pack-off released,continue POOH at 15 fpm,bring speed up to 30 fpm,pump 10 bbl hi-vis sweep, increase POOH speed to 60 fpm once bottoms up reached,tag-up,space out 1.2'at 1 fpm as discussed with town, open EDC 6/19/2017 6/19/2017 1.40 PROD2 DRILL PULD T PJSM,PUD BHA#19,checks not 61.0 0.0 02:42 04:06 holding. Page 25/37 Report Printed: 7/3/2017 • Operations Summary (with Timelog!pths) 1G-15 ConocoPhiilips • Fd.xka Rig: NABORS CDR3-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) 6/19/2017 6/19/2017 10.40 PROD2 DRILL WAIT T Nabors&ARP troubleshoot, 0.0 0.0 04:06 14:30 replace/troubleshoot Bonitron,upload new logic to CDR3 braking system Replacement Bonitrons identified in Houston,shipping arrangements being made. 6/19/2017 6/19/2017 2.60 PROD2 DRILL WAIT T PJSM,check checks in Upper Quick, 0.0 4,112.0 14:30 17:06 RU nozzle,Stab on,PT,open up the well,line up down the coil pumping managed pressure. Prepare to creep in hole,service side VFD high DC buss voltage alarm at drillers HMI screen,no alert on either remote screens. Investigation shows programming change of High voltage was transposed,actual high voltage is sub side. Noted that alarms are not showing on all screens,action item. Continue to RIH,staging up speeds to 100 fUmin,stopping as we go. When stopping from 100 ft/min saw high voltage alarm. Continue on into hole observing voltage,4112'13.38 k lbs CT Wt,voltages continued to climb, saw up to 971 volts with no attempt to break voltage to resistor. Terminate testing and POOH. BT#1 not functioning as it should. 6/19/2017 6/19/2017 1.40 PROD2 DRILL WAIT T POOH,pop off. 4,112.0 0.0 17:06 18:30 6/19/2017 6/20/2017 5.50 PROD2 DRILL WAIT T Wait on parts 0.0 0.0 18:30 00:00 6/20/2017 6/20/2017 12.30 PROD2 DRILL WAIT T Wait on parts,2 Bonitron brake 0.0 0.0 00:00 12:18 transitor units enroute to Anchorage, arrive in Anchorage at 8:00 am, Lyndon delivered the parts to Security Aviation who will deliver to Dead horse by—12:00 noon. 6/20/2017 6/20/2017 1.00 PROD2 DRILL WAIT T Parts enroute from Deadhorse to rig. 0.0 0.0 12:18 13:18 6/20/2017 6/20/2017 2.20 PROD2 DRILL WAIT T Parts arrive at rig,install Bonitron, 0.0 15.0 13:18 15:30 PJSM, pull night-cap,PU nozzle&. stinger,RIH to test new Bonitron. 6/20/2017 6/20/2017 1.70 PROD2 DRILL TRIP T RIH to begin testing at 20 fpm,come 15.0 6,000.0 15:30 17:12 up to 30 fpm,up to 40 fpm,up to 50 fpm,up to 80 fpm,up to 100 fpm and perform slow deceleration at 1000', continue braking tests at 40,60,80,& 100 fpm(operating as expected, chopping voltage to resistor).Continue to RIH to 4000'at 100 fpm.Begin testing braking at 40,60,80,&100 fpm,30 second run for each speed, then brake(functioning as expected), continue down to 6000'at 100 fpm, test braking at 40,60,80,&100 fpm (good tests) 6/20/2017 6/20/2017 1.30 PROD2 DRILL TRIP T Test-PASS,Trip out for drilling BHA 6,000.0 0.0 17:12 18:30 Page 26/37 Report Printed: 7/3/2017 !perations Summary (with Timelogtepths) il - rst 4 > ; 1G-15 ConocoPhitlmps "I'ii Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/20/2017 6/20/2017 0.50 PROD2 DRILL PULD T At surface,PJSM,Lay down pup joint 0.0 0.0 18:30 19:00 and nozzle 6/20/2017 6/20/2017 1.50 PROD2 DRILL PULD T PJSM,PD BHA#22,AL1 lateral BHA 0.0 78.2 19:00 20:30 with.8°AKO motor,RB HYC Bi center,and agitator.Make up to coil and surface test,Check pack offs,Tag up and set counters 6/20/2017 6/20/2017 1.60 PROD2 DRILL TRIP T RIH BHA#22,test agitator at 200'- 78.2 6,440.0 20:30 22:06 Good,Test HOT @ 2300-Good 6/20/2017 6/20/2017 0.10 PROD2 DRILL DLOG T Log HRZ for-5'correction 6,440.0 6,477.0 22:06 22:12 • 6/20/2017 6/20/2017 0.80 PROD2 DRILL TRIP T Continue in well,Clean pass through 6,477.0 8,089.0 22:12 23:00 window 6/20/2017 6/20/2017 0.70 PROD2 DRILL I TRIP .P Stack out and pick up,work pipe 8,089.0 8,416.0 23:00 23:42 gently to bottom,END NAD NPT,23 Hrs for today 6/20/2017 6/21/2017 0.30 PROD2 DRILL WPRT P Tag bottom @ 8416,Pull wiper to 8,416.0 7,760.0 23:42 00:00 window,PUW=32K 6/21/2017 6/21/2017 1.30 PROD2 DRILL WPRT P Continue wiper trip to window.Tight 7,760.0 8,415.0 00:00 01:18 spot @ 7350 RIH 6/21/2017 6/21/2017 0.10 PROD2 DRILL DRLG P 8415',Drill, 1.78 BPM @ 4470 PSI 8,415.0 8,425.0 01:18 01:24 FS, BHP=3500,ROP=175FPH 6/21/2017 6/21/2017 0.30 PROD2 DRILL WPRT P 8425', Hit hard spot,Lost all returns, 8,425.0 8,425.0 01:24 01:42 PUH,PUW=45K,PUH to 8310.RBIH to drill 6/21/2017 6/21/2017 1.70 PROD2 DRILL DRLG P 8425',Drill 1.7 BPM @ 4230 PSI FS, 8,425.0 8,454.0 01:42 03:24 BHP=3348.Returns slowing came back to 1.78 in to 1.30 Out.ROP=20 FPH 6/21/2017 6/21/2017 4.00 PROD2 DRILL DRLG P 8454',Drilling break,ROP=110- 8,454.0 8,659.0 03:24 07:24 125FPH, 1.79 IN,1.33 OUT, WHP=165,ECD 10.3 6/21/2017 6/21/2017 0.60 PROD2 DRILL DRLG P Continue drilling ahead,begin adding 8,659.0 8,662.0 07:24 08:00 1%lube to system once past 8650'(fault zone),Rate In=1.8 bpm, Rate Out=1.4 bpm,CWT=.47K, WOB=1.7K,WHP=238 psi,pump 5x5 sweep at 8660',observing ' significant vibrations drilling on hard spot,reduce rate to 1.6 bpm in attempt to reduce vibration,PUW= 35K, 6/21/2017 6/21/2017 0.40 PROD2 DRILL TRIP P Notice haze by the reel on monitor in 8,662.0 8,662.0 08:00 08:24 doghouse(possibly sun glare),PU, send crew to inspect(mechanic& electrician),notice residual oil on heater,thought to be cause,noticable oder,though no visual,continue drilling, 6/21/2017 6/21/2017 1.60 PROD2 DRILL DRLG P BOBD,pumping 1.8 bpm,Rate Out= 8,662.0 8,714.0 08:24 10:00 1.4 bpm,sweep exits bit, FS=1050 psi,CWT=6.5K ,WOB=2.5K,WHP =223 psi,PU for BHA wiper,PUW= 31K,increase mud system to 1%776 from no lube&begin sending 6/21/2017 6/21/2017 0.50 PROD2 DRILL DRLG P Mud w/increased lube at the bit,BHA 8,714.0 8,756.0 10:00 10:30 wiper,PUW=47K, pumping 1.8 bpm, -78%returns,continue drilling,CWT =3.3K,WOB=.5K Page 27/37 Report Printed: 7/3/2017 • Z Operations Summary (with Timelog Depths) 1G-15 y ConocoPhiftlps nl.mka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 6/21/2017 6/21/2017 0.40 PROD2 DRILL WPRT P Stuggling with weight transfer,pull 8,756.0 7,900.0 10:30 10:54 early wiper,PUW=48K,PUH at 35 fpm to keep up AV's, 6/21/2017 6/21/2017 0.50 PROD2 DRILL WPRT P Wiper back in-hole,RIW=14K,PUN 7,900.0 8,756.0 10:54 11:24 100'right before bottom to allow , electrician to gather data,PUW=34K 6/21/2017 6/21/2017 1.40 PROD2 DRILL DRLG P BOBD, FS=1010 psi,CWT=5K, 8,756.0 8,778.0 11:24 12:48 WOB=2.2K,Rate In=1.8 bpm,Rate Out=1.45 bpm,WHP=210 psi,dp= 1300 psi,low ROP spots with Siderite showing over shakers. 6/21/2017 6/21/2017 1.70 PROD2 DRILL DRLG P Broke out of hard spot,continue 8,778.0 8,907.0 12:48 14:30 drilling with—80%returns,CWT=7K, WOB=1.4K,ROP=165 fph,WHP= 260 psi,hard spots knocked near bit Inc down from 95°to 87.5°(25°DLS), continue to try and break through. 6/21/2017 6/21/2017 1.00 PROD2 DRILL DRLG P Continue drilling ahead at 8907', 8,907.0 8,970.0 14:30 15:30 continue to get knocked down(near bit inc.)attempting to break through hard layer,CWT=6K,WOB=.9K, difficulty making our build,confer with geology,decision made to put it into turn to stay within polygon,difficulty making turn getting bounced off of hard lithology,continual PU's—47K to keep moving, 6/21/2017 6/21/2017 3.00 PROD2 DRILL TRIP T Confer with town,decision made to 8,970.0 58.2 15:30 18:30 POOH for high AKO motor, PUW= 34K,7080'motor work in the build„ RBIH to 7400',slight bobble at 7230' on way back in,at 6400'RBIH 300', Open EDC,bring rate to 2.2 bpm. 6/21/2017 6/21/2017 1.50 PROD2 DRILL PULD T At surface,PJSM PUD BHA#22,Bit 58.2 0.0 18:30 20:00 out 1-2 Chipped tooth,Balled up,30 min reconfig BHA,Not pre loaded running same coil track,AVG DLS=9.6°with.8°motor 6/21/2017 6/21/2017 1.10 PROD2 DRILL PULD T PJSM,PD BHA#22 AL1 lateral 0.0 78.2 20:00 21:06 section with 1.1°AKO motor,RB HYC bit and RR agitator.M/U to coil and surface test 6/21/2017 6/21/2017 1.30 PROD2 DRILL TRIP T Trip in well,Test orienter-Good,Test 78.2 6,420.0 21:06 22:24 Agitator-Good 6/21/2017 6/21/2017 0.20 PROD2 DRILL DLOG T Tie into HRZ for-3.5' 6,420.0 6,472.0 22:24 22:36 6/21/2017 6/21/2017 1.30 PROD2 DRILL TRIP T Continue in well,Stack out at 7548 6,472.0 8,975.0 22:36 23:54 and 8180' 6/21/2017 6/21/2017 PROD2 DRILL DRLG P 8975'Drill, 1.8 BPM @ 4480 PSI FS, 8,975.0 8,994.0 23:54 23:54 BHP=3510,Return rate=l.5, WHP=245 6/22/2017 6/22/2017 0.70 PROD2 DRILL DRLG P 8994',Drill 1.8 BPM @ 4480 PSI FS, 8,994.0 9,039.0 00:00 00:42 BHP=3510, DHWOB=1.4K,RIW=-4K, ROP=150.Initial surveys 3°avg, Reduce rate,put as much WOB as practical.Pump low vis lubed pill @ 9039'to gain WOB, little result. 6/22/2017 6/22/2017 0.10 PROD2 DRILL WPRT P BHA Wiper,PUW=36K 9,039.0 9,039.0 00:42 00:48 Page 28/37 Report Printed: 7/3/2017 � .. i Operations Summary (with TimelogDepths) . , 1G-15 Conoco"hi[Ilps ' M1{.xA.g Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ItKB) 6/22/2017 6/22/2017 0.50 PROD2 DRILL DRLG P 9039', Drill, 1.7 BPM @ 4575 PSI FS, 9,039.0 9,061.0 00:48 01:18 BHP-3450,RIW=O,DHWOB=.8.Low DLS. Low DHWOB.Pump beaded pill 6/22/2017 6/22/2017 0.70 PROD2 DRILL WPRT P PUH waiting on beaded pill.Close to 9,061.0 9,061.0 01:18 02:00 edge of polygon,PUW=45K 6/22/2017 6/22/2017 0.80 PROD2 DRILL DRLG P 9061',Drill,1.7 BPM @ 4575 PSI FS, 9,061.0 9,151.0 02:00 02:48 BHP=3500,RIW=-6K with DHWOB- 1.3K,ROP=105,At 9112 reduce pump rate to 1.45BPM to increase DLS,Avg DLS to 9151 15.2° 6/22/2017 6/22/2017 0.20 PROD2 DRILL WPRT P Stacked out,Pull BHA Wiper, 9,151.0 9,151.0 02:48 03:00 PUW=36K 6/22/2017 6/22/2017 4.00 PROD2 DRILL DRLG P 9151',Drill 1.7 BPM @ 4070 PSI FS, 9,151.0 9,361.0 03:00 07:00 BHP=3467 6/22/2017 6/22/2017 0.60 PROD2 DRILL WPRT P Wiper up-hole, PUW=42K 9,361.0 8,200.0 07:00 07:36 6/22/2017 6/22/2017 0.70 PROD2 DRILL WPRT P Wiper in-hole,begin pumping 10 bbl 8,200.0 9,361.0 07:36 08:18 beaded pill,observe some WOB at -9240&9275',PU at 9281',PUW= 39K,RIW=11K at 9300' 6/22/2017 6/22/2017 3.00 PROD2 DRILL DRLG P BOBD,pill begins exiting bit, 9,361.0 9,422.0 08:18 11:18 significant gain in weight transfer,FS =1005 psi,CWT=3.5K,WOB= 1.2K,dp=1172 ps,WHP=192 psi, continue pumping 10 bbl beaded pills as required,low ROP&vibrations through hard drilling. 6/22/2017 6/22/2017 1.60 PROD2 DRILL DRLG P Continue drilling at 9,422',CWT= 9,422.0 9,482.0 11:18 12:54 1.2K,WOB=1K,WHP=212 psi, returns-86%,variable ROP,2-135 fph,observed vibrations,continue pumping beaded pills as required. 6/22/2017 6/22/2017 3.10 PROD2 DRILL DRLG P Rate Out dropped to to.83 bpm at 9,452.0 9,570.0 12:54 16:00 9482',drilled ahead&returns began to recover quickly to 1.45 bpm out, CWT=-.6K,WOB=2K,Annular= 3569 psi,variable ROP 6/22/2017 6/22/2017 0.10 PROD2 DRILL WPRT P Pull 100'wiper trip,PUW=35K 9,570.0 9,570.0 16:00 16:06 6/22/2017 6/22/2017 1.10 PROD2 DRILL DRLG P OBD,CWT=-.2K,WOB=1.26,Rate 9,570.0 9,601.0 16:06 17:12 In=1.8 bpm,Rate Out=1.55 bpm, Annular=3556,continue to pump 10 bbl beaded pills as required 6/22/2017 6/22/2017 1.60 PROD2 DRILL WPRT P 9601',Wiper to 7900',PUW=39K 9,601.0 9,601.0 17:12 18:48 6/22/2017 6/22/2017 0.30 PROD2 DRILL DRLG P 9601', Drill, 1.78 BPM @ 4690 PSI 9,601.0 9,622.0 18:48 19:06 FS,BHP=3510 6/22/2017 6/22/2017 0.30 PROD2 DRILL DRLG P 9622'Stall and stuck,worked free 9,622.0 9,622.0 19:06 19:24 58K,BHA wiper. 6/22/2017 6/22/2017 2.50 PROD2 DRILL DRLG P Work pipe trying to get back to 9,618.0 9,618.0 19:24 21:54 bottom.Sticky coming off bottom. Stalling near bottom Unsuccessfull. even with lower pump rates, PUW's=58K.Work down to 9618 6/22/2017 6/22/2017 0.30 PROD2 DRILL WPRT P Pull 300'wiper,still unable to get to 9,618.0 9,618.0 21:54 22:12 drilling,work to bottom and stall 6/22/2017 6/22/2017 1.50 PROD2 DRILL WPRT P Pull wiper to window with tie in,work 9,618.0 7,050.0 22:12 23:42 tight area @ 7700 to 7480' Page 29/37 Report Printed: 7/3/2017 Iterations Summary (with Timelog'pths) � 1G-15 ConocoPhillips ', roLnsks , Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/22/2017 6/22/2017 0.10 PROD2 DRILL DLOG P Log RA for+13',Clean encoder wheel 7,050.0 7,071.0 23:42 23:48 6/22/2017 6/23/2017 0.20 PROD2 DRILL WPRT P Continue wiper back in hole 7,071.0 7,260.0 23:48 00:00 6/23/2017 6/23/2017 1.10 PROD2 DRILL WPRT P Continue wiper trip in hole from 7,260.0 9,617.0 00:00 01:06 window 6/23/2017 6/23/2017 0.10 PROD2 DRILL DRLG P 9617',Drill, 1.6 BPM @ 3960 PSI FS, 9,617.0 9,625.0 01:06 01:12 BHP=3525,Hard to maintain drilling, RIW-8K,Hard to maintain differential pressure,Depth difference is due to 13 foot correction at tie in 6/23/2017 6/23/2017 1.50 PROD2 DRILL WPRT P Stall,PUW=58K,try different pump 9,625.0 9,625.0 01:12 02:42 rates,beaded pill,different run speeds.Unable to get steady state drilling 6/23/2017 6/23/2017 3.50 PROD2 DRILL WPRT P Geo's call TD,Pump 10 X 10 Sweeps, 9,625.0 59.0 02:42 06:12 Chase to swab,Encounter overpull 8119',RBIH and work area.Packing off @ 7650 area continue out 6/23/2017 6/23/2017 1.70 PROD2 DRILL, WPRT P RBIH to confirm TD,tie in for-5.5' 59.0 7,010.0 06:12 07:54 correction 6/23/2017 6/23/2017 0.30 PROD2 DRILL DLOG P Static at window,allow annular to drop 7,010.0 7,010.0 07:54 08:12 to 3282 psi to confirm 9.9 gradient(bit depth MD=7010',pressure tool depth =6962'MD,TVD at tool depth= 6376').Build liner pill&KWF to 10.1 ppg per liner running procedure. 6/23/2017 6/23/2017 1.70 PROD2 DRILL WPRT P Continue RIH to confirm TD,set down 7,010.0 9,625.0 08:12 09:54 9K at 7090'(3 tries to get by),set down 5K WOB at 7117', PUH to 7037',RBIH,set down 5K at 7539', —10K-12K CWT to TD,confirm TD at 9625',PUW=64K,send liner running pill 6/23/2017 6/23/2017 3.30'PROD2 DRILL DISP P POOH,laying in 10.1 ppg liner running 9,625.0 78.0 09:54 13:12 pill&KWF to surface,paint EOP flags at 7868.19'&5178.19' 6/23/2017 6/23/2017 1.50 PROD2 DRILL PULD P PJSM,flow check,good,LD BHA#23, 78.0 0.0 13:12 14:42 electrician troubleshoot fan for dynamic brake,bit came out 2-2 6/23/2017 6/23/2017 3.60 COMPZ2 CASING PUTB P PJSM, PU BHA#24 AL1 Liner 0.0 1,790.7 14:42 18:18 Running Assembly Run#1 (non-ported bullnose,44 jnts slotted liner,shorty deployment sleeve), BOP drill:Kick While Running Liner(3 min),excellent execution,M/U to coil and surface test tool 6/23/2017 6/23/2017 1.10 COMPZ2 CASING RUNL P Trip in with AL1 lower liner segment, 1,790.7 6,904.9 18:18 19:24 EDC closed 6/23/2017 6/23/2017 0.10 COMPZ2 CASING DLOG P Correct-14 at flag,PUW=32K, 6,904.9 6,891.0 19:24 19:30 DHWOB=-6.3 6/23/2017 6/23/2017 1.20 COMPZ2 CASING ' RUNL P Continue in hole,Work pipe in 8800' 6,891.0 9,598.0 19:30 20:42 area.Clean past. Page 30/37 Report Printed: 7/3/2017 ' w A Operations Summary (with Timelog Depths) ',1 1G-15 , , CtxmooPhiilips ,, Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/23/2017 6/23/2017 0.20 COMPZ2 CASING RUNL P At set depth,Kick on pumps to 9,598.0 7,824.0 20:42 20:54 release.Drag liner uphole on first attemp,RBIH to depth.Pumps on 1.6 BPM in 1.5 BPM out,Release off liner, PUW=31K,DHWOB=.6.Remove liner length from counters left in hole 6/23/2017 6/23/2017 1.60 COMPZ2 CASING TRIP P Trip out keeping hole full 7',824.0 45.0 20:54 22:30 6/23/2017 6/23/2017 1.40 COMPZ2 CASING PULD P At surface,PJSM,Lay down BHA#24, 45.0 82.8 22:30 23:54 P/U BHA#25 with ported bull nose, 1 9.92'pup-drilled,and OH anchor billet,Check pack offs,Make up injector and surface test tools 6/23/2017 6/24/2017 0.10 COMPZ2 CASING TRIP P RIH BHA#25,EDC open 82.8 144.0 23:54 00:00 6/24/2017 6/24/2017 1.20 COMPZ2 CASING TRIP P Continue in with BHA#25,ported 144.0 6,455.0 00:00 01:12 bullnose,drilled 9.9'pup,OH anchored billet 6/24/2017 6/24/2017 0.10 COMPZ2 CASING DLOG P Log HRZ for-4.5'correction 6,455.0 6,474.0 01:12 01:18 6/24/2017 6/24/2017 0.80 COMPZ2 CASING TRIP P Continue in well,Wt check @ 6996 for 6,474.0 7,856.0 01:18 02:06 31K,Shut EDC,Continue in,Tag up @ 7856,Orient to 150°ROHS,See tool shift @ 4100 PSI,Set down 2.5K- Good,Est TOL=7834' 6/24/2017 6/24/2017 1.60 COMPZ2 CASING TRIP. P Trip out of well 7,856.0 81.1 02:06 03:42 6/24/2017 6/24/2017 0.80 COMPZ2 CASING PULD P Surface,PJSM,Lay down BHA#25 81.1 0.0 03:42 04:30 6/24/2017 6/24/2017 0.80 PROD3 STK PULD P PJSM,M/U BHA#26(1°heavy AKO 0.0 83.0 04:30 05:18 motor,agtitator,B8 bit) 6/24/2017 6/24/2017 1.60 PROD3 STK TRIP P RIH 83.0 6,420.0 05:18 06:54 6/24/2017 6/24/2017 0.20 PROD3 STK DLOG P Tie for-4.5'correction 6,420.0 6,466.0 06:54 07:06 6/24/2017 6/24/2017 0.70 PROD3 STK TRIP P Continue RIH,dry tag TOB at 7835', 6,466.0 7,835.0 07:06 07:48 PUW=33K 6/24/2017 6/24/2017 1.10 PROD3 STK DISP P Displace well to 8.7 ppg drilling fluid 7,835.0 7,835.0 07:48 08:54 (PowerPro). 6/24/2017 6/24/2017 2.10 PROD3 STK KOST P KO billet 180°ROHS,pumping 1.6 7,835.0 7,846.0 08:54 11:00 bpm, Rate Out=1.57 bpm,FS=924 psi,aluminum over shakers observed, past slips and off billet at 7846'. 6/24/2017 6/24/2017 3.00 PROD3 DRILL DRLG P Drilling ahead,PU to dry drift billet 7,846.0 8,011.0 11:00 14:00 area,clean, pumping 1.8 bpm,Rate Out=1.73 bpm,FS=925 psi,CWT= 12K,WOB=1K,difficulty getting it surveys,PU slowly allwing DD time to speak with town, Baker town indicates keep drilling ahead to aquire survey. 6/24/2017 6/24/2017 4.60 PROD3 DRILL DRLG P Continue drilling ahead,CWT=7.8K, 8,011.0 8,212.0 14:00 18:36 WOB=2.2K,BHP=3497 psi,able to get clean surveys,variable ROP 2- 220 fph. 6/24/2017 6/24/2017 0.30 PROD3 DRILL WPRT P Wiper up-hole to 7474,PUW=37K 8,212.0 7,474.0 18:36 18:54 Page 31/37 Report Printed: 7/3/2017 ' perations Summary (with Timelogepths) ° 1G-15 ConocoPhillips Rig: NABORS CDR3-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) 6/24/2017 6/24/2017 0.40 PROD3 DRILL WPRT P RBIH,Stack out @ 7544,work pipe, 7,474.0 7,040.0 18:54 19:18 stack out @ 7534,Pull wiper up to window 6/24/2017 6/24/2017 0.10 PROD3 DRILL DLOG P Log RA marker for+3.5' 7,040.0 7,058.0 19:18 19:24 6/24/2017 6/24/2017 0.90 PROD3 DRILL WPRT P RBIH,Shot check shots 7,058.0 8,214.0 19:24 20:18 6/24/2017 6/24/2017 0.50 PROD3 DRILL DRLG P 8214'Drill 1.77 BPM @ 5230 PSi FS, 8,214.0 8,214.0 20:18 20:48 BHP=3470.Entered high differential S/D pumps and pick up.High diff remaining off bottom.Back to normal free spin.Stall on bottom,PUH still in high diff.Suspect motor problems, Unable to drill ahead 6/24/2017 6/24/2017 1.70 PROD3 DRILL TRIP T POOH for BHA inspection 8,214.0 68.8 20:48 22:30 6/24/2017 6/24/2017 1.10 PROD3 DRILL PULD T At surface,Tag up and space out, 68.8 0.0 22:30 23:36 PJSM PUD BHA#26,During PUD FVS not holding,Review undeploy with failed FVS procedure,Shut EDC and continue PUD. 6/24/2017 6/25/2017 0.40 PROD3 DRILL BHAH T Investigate BHA,Bit out clear,Motor 0.0 0.0 23:36 00:00 drained normally.Valve in FVS stuck open-beads.Agitator operated normally with water/air in mouse hole 6/25/2017 6/25/2017 0.30 PROD3 DRILL BHAH T Continue to inspect/reconfigure BHA 0.0 0.0 00:00 00:18 6/25/2017 6/25/2017 1.00 PROD3 DRILL PULD T PJSM,PD BHA#27,surface test tool 0.0 78.2 00:18 01:18 6/25/2017 6/25/2017 1.50 PROD3 DRILL TRIP T Trip in well,BHA#27 with HYC bi 78.2 6,445.0 01:18 02:48 center with duraforce XD cutters,.9° AKO motor and RB agitator.Shallow test agitator-good 6/25/2017 6/25/2017 0.10 PROD3 DRILL DLOG T Log HRZ for-4'correction, 6,445.0 6,458.0 02:48 02:54 PUW=31.5K • 6/25/2017 6/25/2017 0.60 PROD3 DRILL TRIP T Continue in well,Clean trip through 6,458.0 8,214.0 02:54 03:30 window and to bottom 6/25/2017 6/25/2017 2.80 PROD3 DRILL DRLG P 8214', Drill, 1.8 BPM @ 4475 PSI FS, 8,214.0 8,400.0 03:30 06:18 BHP=3460,experience partial losses at-8300' 6/25/2017 6/25/2017 2.30 PROD3 DRILL DRLG P Experience total losses at 8400', 8,400.0 8,467.0 06:18 08:36 returns begin to come back to-.9 bpm relatively quickly,continue drilling ahead to heal losses,experienced almost total losses again at 8430', began to heal to 1 bpm returns,again went to total losses at 8462',close choke,annular down to 2897 psi 6/25/2017 6/25/2017 1.10 PROD3 DRILL DRLG P Difficulty getting to bottom past 8465', 8,467.0 8,467.0 08:36 09:42 multiple stalls,up to dp=1500 psi, multiple attempts&PU's to get started,PUW up to 60K Page 32/37 Report Printed: 7/3/2017 Aerations Summary (with Timelogepths) 1G-15 Conoc Iilltps ' 5(.ssA? Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/25/2017 6/25/2017 1.00 PROD3 DRILL DRLG P OBD,CWT=1.4K,WOB=2.7K, 8,467.0 8,471.0 09:42 10:42 reduce rate to 1.6 bpm,drilling on total losses w/closed choke,Annular= 3040 psi,ROP at—1-2 fph,PUW 65K at 8470', passes thorugh 8463' continue to see increased FS, DD's thought is tight spot around BHA at 8463'(FS=925 psi below 8463',FS above 8463'=—725 psi) 6/25/2017 6/25/2017 1.90 PROD3 DRILL DRLG P OBD,pumping 1.6 bpm, CWT=- 8,471.0 8,480.0 10:42 12:36 7.5K,WOB=2.7K,total losses, Annular=3094 psi,PUW=49K at 8471.6',FS=750 psi above 8463', differential jumps to over 1900 psi when passing 8463',though still off bottom,low ROP observed,PUW= 65K from 8480' 6/25/2017 6/25/2017 2.00 PROD3 DRILL DRLG P Continue drilling through difficult 8,480.0 8,495.0 12:36 14:36 interval,WHP=135 psi,Annular= 3115 psi,PU's require multiple atttempts to pass restriction at 8463', confer with town,plan is to remain on closed choke,drilling on Duo-Vis systems. 6/25/2017 6/25/2017 1.90 PROD3 DRILL DRLG P Continue drilling,CWT=-8.5K,WOB 8,495.0 8,507.0 14:36 16:30 =2.3K,pumping 1.75 bpm,Annular= 3011 psi,WHP=30 psi,PU from 8495,PUW=62 K,continue to have extreme difficulty working past 8463'. RIH shows-8K CWT when bit is at 8480'and will"break"through resulting in 12K positive CWT,attempt mutlple TF's at min rate, 6/25/2017 6/25/2017 0.60 PROD3 DRILL DRLG P Unable to get by 8462',confer with 8,507.0 8,507.0 16:30 17:06 town,decision made to to attempt to get to bottom for 1.5 more hours,then begin to POOH. 6/25/2017 6/25/2017 3.20 PROD3 DRILL DRLG P 8507',Break out, 1.78 BPM @ 3659 8,507.0 8,780.0 17:06 20:18 PSI FS,BHP=3138,Choke closed 6/25/2017 6/25/2017 0.40 PROD3 DRILL WPRT P Pull Wiper to billet 7900',Slow down 5 8,780.0 7,900.0 20:18 20:42 FPM through 8490 to 8440 Small motor work bumps through this area, 8490&8470 6/25/2017 6/26/2017 3.30 PROD3 DRILL WPRT P 7900'RBIH Set down in 8458-8460 7,900.0 8,455.0 20:42 00:00 area.Work pipe at different speeds, toolfaces,and pump rates.Confer with town about possible redrill/sidetrack in this area.Proceed to drill our way through,Pumped beaded lube pill with little effect 6/26/2017 6/26/2017 0.30 PROD3 DRILL WPRT P Continue to work pipe 8,455.0 8,445.0 00:00 00:18 6/26/2017 6/26/2017 3.10 PROD3 DRILL WPRT P Unable to work pipe through,Go to 8,445.0 8,775.0 00:18 03:24 drilling mode, 1.76 BPM @3780 PSI FS,BHP=3290,Multiple stalls and pick ups,Drill 30 to 70 ROHS.Break through @ 8520,wipe to 8775 6/26/2017 6/26/2017 0.60 PROD3 DRILL WPRT P Pump 5 X 5 Sweeps,chase sweeps, 8,775.0 8,424.0 03:24 04:00 PUH through area,Overpull with motor work @ 8467 turn around able to RIH,come back up through Page 33/37 Report Printed: 7/3/2017 perations Summary (with Timelog IIepths) . >• ° ' 1G-15 ConocoPhillilss .. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/26/2017 6/26/2017 0.30 PROD3 DRILL WPRT P RBIH,Set down @ 8456,Work pipe, 8,424.0 8,456.0 04:00 04:18 vary speeds and rates 6/26/2017 6/26/2017 2.20 PROD3 DRILL DRLG P Go back to drilling mode, 1.8 BPM @ 8,456.0 8,526.0 04:18 06:30 3780 PSI FS,BHP=3208,working pipe to get to bottom 6/26/2017 6/26/2017 0.50 PROD3 DRILL WPRT P Get through tight spot,back ream up- 8,526.0 8,440.0 06:30 07:00 hole. 6/26/2017 6/26/2017 0.90 PROD3 DRILL WPRT P Work pipe back through restriction, 8,440.0 8,780.0 07:00 07:54 confer with town,drill ahead 6/26/2017 6/26/2017 4.00 PROD3 DRILL DRLG P OBD,CWT=6K,WOB=1.5K,BHP 8,780.0 9,012.0 07:54 11:54 3267 psi,average ROP=58 fph 6/26/2017 6/26/2017 2.40 PROD3 DRILL DRLG P Continue drilling ahead,CWT=-1.5K, 9,012.0 9,092.0 11:54 14:18 WOB=1.5K 6/26/2017 6/26/2017 0.20 PROD3 DRILL WPRT P Wiper up-hole, PUW=39K 9,092.0 8,552.0 14:18 14:30 6/26/2017 6/26/2017 0.30 PROD3 DRILL WPRT P Wiper in-hole,RIW=10K,sticky 8,552.0 9,092.0 14:30 14:48 working through 8948' 6/26/2017 6/26/2017 3.80 PROD3 DRILL DRLG P BOBD,CWT=-3K,WOB=1.2K,BHP 9,092.0 9,200.0 14:48 18:36 =3280 psi,ROP variable,5-200+ ROP 6/26/2017 6/26/2017 3.60 PROD3 DRILL DRLG P Continue drilling,CWT=.1K,WOB= 9,200.0 9,297.0 18:36 22:12 1K,Rate In=1.78 bpm,pumping pills, some PU's required. 6/26/2017 6/27/2017 1.80 PROD3 DRILL DRLG P Drilling ahead,CWT=-4K,WOB 9,267.0 9,328.0 22:12 00:00 =.2K,Rate In=1.8 bpm,BHP=3295 psi,WHP=182 psi,observe some vibrations,with low ROP 6/27/2017 6/27/2017 0.60 PROD3 DRILL DRLG P 9328',Drill, 1.7 BPM#3750 PSI FS, 9,328.0 9,347.0 00:00 00:36 BHP=3293 6/27/2017 6/27/2017 0.30 PROD3 DRILL WPRT P Stacking, Pull 100'wiper,PUW=44K 9,347.0 9,347.0 00:36 00:54 6/27/2017 6/27/2017 1.30 PROD3 DRILL DRLG P 9347',Drill, 1.70 BPM @ 3730 PSI 9,347.0 9,364.0 00:54 02:12 FS,BHP=3268 6/27/2017 6/27/2017 0.10 PROD3 DRILL WPRT P 100'Wiper,PUW=49K 9,364.0 9,364.0 02:12 02:18 6/27/2017 6/27/2017 1.00 PROD3 DRILL DRLG P 9364',Drill, 1.8 BPM @ 3730 PSI FS, 9,364.0 9,381.0 02:18 03:18 BHP=3313 6/27/2017 6/27/2017 0.30 PROD3 DRILL WPRT P Pull short wiper to 9364,Slight trouble 9,381.0 9,381.0 03:18 03:36 getting to run in hole 6/27/2017 6/27/2017 2.40 PROD3 DRILL DRLG P 9381',Drill, 1.77 BPM @ 3989 PSI 9,381.0 9,413.0 03:36 06:00 FS,BHP=3331,WHP=232 6/27/2017 6/27/2017 1.90 PROD3 DRILL WPRT P Pull heavy off bottom,65K,Can't get 9,413.0 9,413.0 06:00 07:54 back to bottom,wipe up to 8510,work back to botom 6/27/2017 6/27/2017 1.60 PROD3 DRILL DRLG P 9413,Trying to get drilling called TD, 9,413.0 9,412.0 07:54 09:30 PUH and circulate 10 X 10 sweeps down followed by liner running pill 6/27/2017 6/27/2017 1.70 PROD3 DRILL WPRT P PUH pumping beaded liner running 9,412.0 8,828.0 09:30 11:12 pill,Pull heavy and hang up—8424. Work pipe down, Pump down backside and RIH,Pull up through' tight area 6/27/2017 6/27/2017 0.80 PROD3 DRILL WPRT P 8228,Paint 8150'EOP flagg-yellow- 8,828.0 5,518.0 11:12 12:00 Continue up hole 6/27/2017 6/27/2017 0.60 PROD3 DRILL CIRC P 5518, In casing,bullhead 65 BBIs 5,518.0 5,518.0 12:00 12:36 mud down CT by Tubing annulas 6/27/2017 6/27/2017 0.30 PROD3 DRILL WPRT P Trip in hole 5,518.0 6,435.0 12:36 12:54 Page 34/37 Report Printed: 7/3/2017 i S * .:.,;.„,.,„x4 Operations Summary (with Timelog Depths) 0.. & ' %. 1G-15 ConocciPhillips .' A;.r.ke Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 6/27/2017 6/27/2017 0.40 PROD3 ' DRILL DLOG P Log HRZ for tie in,+21.5'correction- 6,410.0 6,439.0 12:54 13:18 Check injector counter-Good 6/27/2017 6/27/2017 0.40 PROD3 DRILL WPRT P Continue in well 6,439.0 7,729.0 13:18 13:42 6/27/2017 6/27/2017 0.10 PROD3 DRILL OTHR T RIH @ 50 FPM reel tripped out, 7,729.0 7,729.0 13:42 13:48 Inspect injector,gooseneck,and CT, RIW=31 K before trip 6/27/2017 6/27/2017 0.20 PROD3 DRILL TRIP T PUH to cased hole 7,729.0 6,902.0 13:48 14:00 6/27/2017 6/27/2017 1.70 PROD3 DRILL RGRP T Trouble shoot PLC's,Reset PLC's, 6,902.0 6,902.0 14:00 15:42 Reload control program 6/27/2017 6/27/2017 0.30 PROD3 DRILL RGRP T PUH 500'to start testing control 6,902.0 6,902.0 15:42 16:00 program,Trip in hole brake and control as designed, 2 Hrs NAD NPT 6/27/2017 6/27/2017 2.00 PROD3 DRILL TRIP P Good testing,Resume ops,Trip in to 6,902.0 9,524.0 16:00 18:00 bottom 6/27/2017 6/27/2017 0.50 PROD3 DRILL CIRC P PUH,pump liner pill 9,524.0 9,524.0 18:00 18:30 6/27/2017 6/27/2017 0.50 PROD3 DRILL TRIP P POOH,laying in liner pill 9,524.0 8,400.0 18:30 19:00 6/27/2017 6/27/2017 0.15 PROD3 DRILL TRIP P Continue POOH,painting EOP TD 8,400.0 6,440.0 19:00 19:09 flag(Yellow)@ 8,278' 6/27/2017 6/27/2017 0.25 PROD3 DRILL DLOG P Log the HRZ,plus 3'ft. 6,440.0 6,458.0 19:09 19:24 6/27/2017 6/27/2017 1.00 PROD3 DRILL TRIP P Continue POOH,painting EOP 6,458.0 70.6 19:24 20:24 Window Flag(White)@ 5,878' 6/27/2017 6/27/2017 1.90 PROD3 DRILL DISP P Bullhead fliuds from surface,PJSM for 70.6 70.6 20:24 22:18 unstabbing INJH and LD tools,check well for flow,pump 5 bbls no returns 6/27/2017 6/27/2017 1.00 PROD3 DRILL PULD P Unstab INJH,LD tools,fill hole with 70.6 0.0 22:18 23:18 hole fill pump,(52 bbl loss rate) 6/27/2017 6/27/2017 0.50 COMPZ3 CASING PUTB P Prep rig floor for liner 0.0 0.0 23:18 23:48 6/27/2017 6/28/2017 0.20 COMPZ3 CASING SFTY P PJSM for PU liner 0.0 0.0 23:48 00:00 6/28/2017 6/28/2017 2.00 COMPZ3 CASING PUTB P PU/MU 28 jts of slotted liner,(52 bph 0.0 1,131.6 00:00 02:00 loss rate) ***Kick while tripping drill 3 min 36 sec*** 6/28/2017 6/28/2017 0.50 COMPZ3 CASING PULD P MU GS,and BHI Coiltrak tools.(14 k 1,131.6 1,155.5 02:00 02:30 tw) 6/28/2017 6/28/2017 0.50 COMPZ3 CASING PULD P Move over,inspect pac-offs,inspect 1,155.5 1,155.5 02:30 03:00 UQ check valves,MU INJH to tools, close slips,strip down INJH onto • stump. 6/28/2017 6/28/2017 0.25 COMPZ3 CASING RUNL P Open slips,tag up,reset counters, 1,155.5 1,155.5 03:00 03:15 RIH w/AL2 lower liner segment 28 jts of slotted liner,with ported bullnose. 6/28/2017 6/28/2017 1.70 COMPZ3 CASING RUNL P RIH,with AL2 lower liner assembly 28 1,155.5 6,997.0 03:15 04:57 jts slotted liner,correct to the EOP flag minus 7.7'.Continue in hole. 6/28/2017 6/28/2017 1.80 COMPZ3 CASING RUNL P 6997,Initial setdown,Work pipe down, 6,997.0 8,201.0 04:57 06:45 RIH @ 8201 6/28/2017 6/28/2017 0.10 COMPZ3 CASING RUNL P Continue in well clean to 8464 8,201.0 8,464.0 06:45 06:51 Page 35/37 Report Printed: 7/3/2017 • s Operations Summary (with Timelog Depths) ,, 1G-15 C.onocoPhillips °`` r,l.r.ks Rig: NABORS CDR3-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) 6/28/2017 6/28/2017 2.90 COMPZ3 CASING RUNL P Work pipe in attempt to pass 8464 8,464.0 8,464.0 06:51 09:45 while pumping 43 BBI beaded liner pill down back side 6/28/2017 6/28/2017 1.60 COMPZ3 CASING RUNL P Beaded pill around liner/BHA work 8,464.0 8,464.0 09:45 11:21 pipe 6/28/2017 6/28/2017 0.60 COMPZ3 CASING RUNL P Mix and pump 150 BBI beaded liner 8,464.0 8,464.0 11:21 11:57 pill 6/28/2017 6/28/2017 1.00 COMPZ3 CASING RUNL P Tubing&open hole full of beaded liner 8,464.0 8,464.0 11:57 12:57 lube pill-Work pipe down. Hold in compression pumping beaded pill past liner.Wary pump rates,Work pipe 6/28/2017 6/28/2017 0.30 COMPZ3 CASING RUNL P Pull up hole 150'RBIH to bottom- 8,464.0 8,464.0 12:57 13:15 work pipe,Hold in compression , 6/28/2017 6/28/2017 1.70 COMPZ3 CASING RUNL T POOH with liner, Paint EOP flag @ 8,464.0 1,146.3 13:15 14:57 6200' 6/28/2017 6/28/2017 3.00 COMPZ3 CASING PULD T At surface,PJSM,lay down 12 joints 1,146.3 0.0 14:57 17:57 liner 6/28/2017 6/28/2017 0.50 COMPZ3 WHDBOP CTOP P MU nozzle,remove check valves, 0.0 0.0 17:57 18:27 stab onto well,jet stack 6/28/2017 6/28/2017 1.00 COMPZ3 WHDBOP CTOP P Grease crew here,service well head 0.0 0.0 18:27 19:27 and swab valves,grease stack and valves. 6/28/2017 6/28/2017 0.65 COMPZ3 WHDBOP CTOP P swap coil over to fresh water.PJSM 0.0 0.0 19:27 20:06 for BOP testing 6/28/2017 6/28/2017 2.41 COMPZ3 WHDBOP CTOP P Swab#2 leaking,call grease crew out 0.0 0.0 20:06 22:30 to service valve again.close SSV, good shell test. 6/28/2017 6/29/2017 1.49 COMPZ3 WHDBOP BOPE P Start bi-weekly test,test witnessed by 0.0 0.0 22:30 00:00 Matt Herrera,250 psi low/3,800 psi high 6/29/2017 6/29/2017 8.50 COMPZ3 WHDBOP BOPE P Continue bi-weekly test,test 0.0 0.0 00:00 08:30 witnessed by Matt Herrera,250 psi low/3,800 psi high/2,500 psi annular, 2 Hrs trouble time for Fail Pass on lower 2"BS,Cl,Replace R2 6/29/2017 6/29/2017 2.00 COMPZ3 CASING CTOP P Install checks in UQQ,Stab on well 0.0 0.0 08:30 10:30 and roll coil back to drilling fluid 6/29/2017 6/29/2017 1.70 COMPZ3 CASING PUTB P PJSM, M/U AL2 lower liner 0.0 688.1 10:30 12:12 segment,ported bullnose, 16 JTS slotted liner,shorty deployment sleeve.Make up to coil and surface test tools. 6/29/2017 6/29/2017 1.80 COMPZ3 CASING TRIP P RIH BHA#29 688.0 7,650.0 12:12 14:00 6/29/2017 6/29/2017 0.10 COMPZ3 CASING DLOG P Tie into RA marker for-6.3(-9.3 at 7,650.0 7,676.0 14:00 14:06 flag,+3 at RA)Hi lube 50 BBI pill with LVT down backside 6/29/2017 6/29/2017 1.50 COMPZ3 CASING TRIP P Continue in well,Clean trip,Tag up 7,676.0 8,462.0 14:06 15:36 and work pipe,Pill coming past BHA, work pipe,relax,work pipe 6/29/2017 6/29/2017 2.00 COMPZ3 CASING TRIP P Pump off liner,trip out of well,Paint 8,462.0 44.2 15:36 17:36 6500 and 5700'EOP flags 6/29/2017 6/29/2017 1.00 COMPZ3 CASING PULD P At surface,PJSM,LD setting tools and 44.2 0.0 17:36 18:36 BHI Coiltrak. 6/29/2017 6/29/2017 1.00 COMPZ3 CASING PUTB P Prep RF for liner,PJSM 0.0 0.0 18:36 19:36 6/29/2017 6/29/2017 2.25 COMPZ3 CASING PUTB P MU AL2 Upper Liner section. 0.0 1,214.6 19:36 21:51 Page 36/37 Report Printed: 7/3/2017 • . ' s,, Operations Summary (with Timelog Depths) , 1G-15 r, ConocoPhi€lips Ai.nka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/29/2017 6/29/2017 0.50 COMPZ3 CASING PULD P PU/MU BHI CoilTrak tools,space out, 1,214.6 1,258.8 21:51 22:21 close rams,strip down INJH,MU union,surface test tools 6/29/2017 6/29/2017 1.25 COMPZ3 CASING RUNL P RIH,with AL2 upper liner segment 1,258.8 6,971.4 22:21 23:36 with PBR and Haliburton Swell Packer 6/29/2017 6/29/2017 0.25 COMPZ3 CASING RUNL P Correct to the EOP flag at 5,700', 6,971.4 6,971.4 23:36 23:51 correction of minus 12.54',PUW 33 k 6/29/2017 6/30/2017 0.15 COMPZ3 CASING RUNL P Continue IH 6,971.4 7,206.0 23:51 00:00 6/30/2017 6/30/2017 0.30 COMPZ3 CASING RUNL P Continue IH,tag TOL at 7825.7',PUW 7,206.0 7,825.7 00:00 00:18 33 6/30/2017 6/30/2017 0.20 COMPZ3 CASING RUNL P Bring pump up to 1.5 bpm at 3,732',1 7,825.7 6,575.0 00:18 00:30 bpm returns,PUW 28 k,PUH 6/30/2017 6/30/2017 0.30 DEMOB WELLPR CTOP P 15 min,static survey,sensor depth 6,575.0 6,575.0 00:30 00:48 6,561',AP 3,108',MW 9.9 ppg,TVD 6,031' 6/30/2017 6/30/2017 2.10 DEMOB WELLPR DISP P Displace well to SW while POOH 6,575.0 2,500.0 00:48 02:54 6/30/2017 6/30/2017 0.10 DEMOB WELLPR FRZP P Pump 30 BBI freeze protect 2,500.0 2,500.0 02:54 03:00 6/30/2017 6/30/2017 0.60 DEMOB WELLPR TRIP P POOH laying in diesel freez protect 2,500.0 29.0 03:00 03:36 6/30/2017 6/30/2017 1.50 DEMOB WELLPR PULD P PJSM,PUD BHA#30 29.0 0.0 03:36 05:06 6/30/2017 6/30/2017 0.70 DEMOB WHDBOP GLEN P M/U nozzle,stab on well.Jet BOP- 0.0 0.0 05:06 05:48 flush surface lines 6/30/2017 6/30/2017 1.00 DEMOB WHDBOP GLEN P Unstab injector from well,Install test 0.0 0.0 05:48 06:48 joint and function rams while pumping through R valves 6/30/2017 6/30/2017 0.70 DEMOB WHDBOP OTHR P Run bore scope down through BOPE 0.0 0.0 06:48 07:30 to visually inspect rams 6/30/2017 6/30/2017 2.00 DEMOB WHDBOP WWSP P PJSM,Rig up lubricator and set BPV 0.0 0.0 07:30 09:30 6/30/2017 6/30/2017 4.50 DEMOB MOVE MOB Empty pits,Nipple down stack,work 0.0 09:30 14:00 R/D check list. RIG RELEASE 14:00 Page 37/37 Report Printed: 7/3/2017 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-15A 50-029-21024-01 Baker Hughes INTEQ nruEzHES a GE company Definitive Survey Report 14 July,2017 I • • . ConocoPhillipsER 0 ConocoPhillips Definitive Survey ReportUGwa Company: ConocoPhillips(Alaska)Inc.-KupI Local Co-ordinate Reference: Well 1G-15 Project: Kuparuk River Unit TVD Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad MO Reference: 1G-15 0 97.00usft(Doyon 9) Well: 1G-15 North.Reference: True Wellbore: 1G-15 Survey Calculation Method: Minimum Curvature Design: 1G-15 Database: EDT Alaska 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 .p.; ,• r�: .:,,.*.�.r.^ _� ..;,.^..r ,. .. „„*;m. ,. ^^^^-°' µms.°, Well 1G-15 Well Position .NIS 0.00 usft Northing: 5,980,955.66 usft Latitude: 70°21'32.064 N 4E1-W 0.00 use Basting: 540,220.88 usft Longitude: 149°40'23.944 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 56.00 usft......I( IWellbore !1G 15A t .... iii MaQf�hce Mifde)Name :; f ;„, � z ° fpngia Field. gtll BGGM2016 8/1/2017 17.52 80.96 57,541 70 ,. ,,, ,,,...,., _ ;;..,a.....,„..„�.,_,. ....�..».,. IG-15A mp F Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 7,000 00 Vertical Section: Depth From(TVD) +N1-S +51.w Direction l (usft) , i ) (astt) ,> ;r) ,z 1 41.00 0.00 0.00 330.00 i - „••,%%,;.•, A .yg ',,,,,,', ',"i.',"",.4-.. c' .. z / r ,: From To • T,''''',%:,',,''''',,,',! ! d 3 *,,1----),:i,.,-,-,-,:„' S 1 (us t) (unt) Suimyllbor z •*.. Nanta, .. fk _ ,Start.Date End Date 100.00 6,673.00 16-15(GyroData)(1G-15) GYD-CT-CMS Gyrodata cont casing m/s 10/7/2009 10/7/2009 6,700.00 7,000.00 1G-15(1G-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 11/13/1983 11/13/1983 7,017.00 7,046.25 1G-15A MWD-INC(1G-15A) MWD-INC_ONLY MWD-INC_ONLY_FILLER 6/8/2017 6/9/2017 7,075.80 9,815.00 1G-15A MWD(1G-15A) MWD MWD-Standard 6/9/2017 6/14/2017 7/142017 2:07:55PM Page 2 COMPASS 5000.14 Build 85 ill • ConocoPhillips e ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-15 Project: Kuparuk River Unit TVA Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad MD Reference: 1G-15 @ 97.00usft(Doyon 9) • Weil: 1G-15 North Reference: True Wellbore[ 1G-15 Survey Calculation Method: Minimum Curvature Design: 1G-15Aataaaa0j/ EDT Alaska Sandbox Survey / \v MD Inc Azi TVD IIIVI' ' * � r � Ttfq. N ALS SuvtYT9el r>y (usft) O () (usft) (usft) V,, (aft) (n14 I 700000 32.12 298.90 6,504 99 6,407.99 737.47 -1,447.70 5,981,685.28 538,769.38 072 1,362.52 MWD-INC_ONLY(3) TIP 7,017.00 32.05 298.94 6,519.39 6,422.39 741.84 -1,455.61 5,981,689.60 538,761.46 0.43 1,370.26 MWD-INC_ONLY(3) KOP 7,046.25 39.26 296.16 6,543.15 6,446.15 749.69 -1,470.73 5,981,697.37 538,746.30 25.26 1,384.61 MW0.1NC_ONLY(3) Interpolated Azimuth 7,075.80 52.80 294.24 6,563.62 6,466.62 758.68 -1,489.94 5,981,706.26 538,727.04 4605 1,402.01 MWD(4) First Clean Survey 7,106.46 68.12 295.07 6,578.69 6,481.69 769.79 -1514.10 5,981,717.23 538,702.82 50.02 1,423.71 MWD(4) 7,133.59 80.96 287.30 6,585.91 6,488.92 I 779.16 -1,538.43 5,981,726.47 538,678.44 54.75 1,443.99 MWD(4) 1 I 7,166.31 96.43 280.76 6,586.66 6,489.66 787.06 -1,570.06 5,981,734.20 538,646.78 51.31 1,466.64 MWD(4) 7,190.29 99.16 269.03 6,583.40 6,486.40 789.09 -1,593.68 5,981,736.10 538,623.14 49.78 1,480.21 MWD(4) I 7,215.45 102.99 259.58 6,578.55 6,48155 786.66 -1,618.22 5,981,733.54 538,598.62 39.87 1,490.37 MWD(4) ' 9I 7,245.57 101.97 256.28 6,572.04 6,475.04 780.51 -1,646.97 5,981,727.23 538,569.90 11.22 1,499.42 MWD(4) I7,275.56 102.79 253.19 6,565.61 6,468.61 772.80 -1,675.23 5,981,719.37 538,541.69 10.43 1,506.87 MWD(4) t 7,305.65 103.26 250.06 6,558.83 6,461.83 763.56 -1,703.04 5,981,709.99 538,513.93 10.25 1,512.78 MWD(4) ( £ 7,335.70 102.85 246.43 6,552.04 6,455.04 752.71 -1,730.23 5,981,698.99 538,486.81 11.85 1,516.98 MWD(4) t 7,365.58 102.75 242.93 6,545.42 6,448.42 740.25 -1,756.56 5,981,686.39 538,460.54 11.43 1,519.35 MWD(4) 7,395.38 102.06 238.98 6,539.01 6,442.01 726.12 -1,782.00 5,981,672.13 538,435.18 13.15 1,519.84 MWD(4) €€€€) 7,425.64 103.25 235.08 6,532,38 6,435.38 710.06 -1,806.76 5,981,655.94 538,410.51 13.18 1,518.31 MWD(4) g 7,455.76 102.02 236.22 6,525.79 6,428.79 693.48 -1,831.03 5,981,639.23 538,386.34 5.51 1,516.08 MWD(4) 7,485.60 101.36 239.82 6,519.74 6,422.74 678.00 -1,855.81 5,981,623.62 538,361,64 12.02 1,515.07 MWD(4) 7,515.80 101.70 243.43 6,513.71 6,416.71 663.94 -1,881.84 5,981,609.42 538,335.69 11.77 1,515 91 MWD(4) I 7,545.47 101.42 246.75 6,507.76 6,410.76 651.70 -1,908.20 5,981,597.04 538,309.40 11.00 1,518.49 MWD(4) 7,570.64 102.24 249.59 6,502.60 6,405.60 642.54 -1,931.07 5,981,587.76 538,286.58 11.51 1,521.99 MWD(4) 7,601.24 102.54 253.68 6,496.03 6,399.03 633.13 -1,959.43 5,981,578.19 538,258.28 13.09 1,528.02 MWD(4) 7,630.56 102.52 257.17 6,489.67 6,392.67 625.93 -1,987.12 5,981,570.85 538,230.62 11.62 1,535.63 MWD(4) 7,660.70 10287 261.32 6,483.04 6,386.04 620.44 -1016.00 5,981,565.20 538,201.78 13.48 1,545.32 MWD(4) 7,690.51 101.52 265.13 6,476.74 6,379.74 617.00 -2,044.93 5,981,561.62 538,172.87 13.29 1,556.81 MWD(4) 7,720.98 101.75 268.91 6,470.59 6,373.59 615.45 -1074.73 5,981,559.90 538,143.08 1217 1,570.36 MWD(4) 1 7,752.02 101.45 273.87 6,464.35 6,367.35 616.19 -2,105.11 5,981,560.48 538,112.70 15.68 1,586.19 MWD(4) 7,781.54 99.95 278.38 6,458.86 6,361.86 619.29 -1133.95 5,981,563.42 538,083.85 15.85 1,603.29 MWD(4) 7,811.20 98.10 282.67 6,454.21 6,357.21 624.64 -2,162.74 5,981,568.62 538,055.03 15.59 1,622.32 MWD(4) 4 7,83544 97.43 286.53 645093 6,353.93 630.69 -1185.97 5,981,574.55 538,031.77 16.02 1639.18 MWD(4) 7/142017 2:07:55PM Page 3 COMPASS 5000.14 Build 85 • • ConocoPhillips • ea ConocoPhillips Definitive Survey Report '1 Company: ConocoPhillips(Alaska)Inc.-Kup) Local Co-ordinate Reference: Well 1G-15 Project: Kuparuk River Unit TVI)Reference: 1G-15 @ 97.00usft(Doyon 9) Li Site: Kuparuk 1G Pad MD Reference: 1G-15 @ 97.00usft(Doyon 9) Well: 1G-15 North Reference: True Wellbore: 1G-15 Survey Calculation Method: Minimum Curvature Design: 1G-15 Database: EDT Alaska Sandbox Survey MD' Inc Azi ND TVDSS +N!-S +El-W Map Map DGS Vertical Northing �Easting :&oration surveyTaal Name Annotation {usff (°) (°) (usig (usft) ,(usft) (usn) r(ftJ (ft) (1,001 fin - , ., 7,864.92 93.69 29025 6,448.08 6351.08 639.95 -2,213.81 6981,583.65 536003 89 17.85 1,661.12 MWD(4) t 7,89526 9212 293.28 6.446 54 6,349 54 651.18 -2,241.94 6981694.73 537,975.69 1124 1,684.91 MWD(4) 7,925.13 96.24 298.61 6,444.36 6,347.36 664.21 -2268.72 5,981,607.61 537,948.85 2251 1,709.58 MWD(4) 7,954.70 94.73 295.18 6,441.53 6,344.53 677.52 -2,294.96 5,981,62a 78 537,922.54 1262 1,734.23 MWD(4) 7,985.18 94.64 291.56 6,439.04 6,342.04 689.57 -2,32285 5,981,632.68 537,894.60 11.84 1,758.60 MWD(4) 8,015.52 88.16 287.49 6,438.30 6,341.30 699.69 -2,351.41 5,981,642.65 537,865.98 25.22 1,781.66 MWD(4) 8,044.87 89.88 285.33 6,438.80 6,341.80 707.98 -2,379.56 5,981,650.79 537,837.79 9.41 1,80291 MWD(4) 1 8,075.09 92.24 283.22 6,43824 6,34125 715.43 -2,408.84 5,981,658.08 537,808.47 10.47 1,824.00 MWD(4) 8,108.18 8929 279.97 6,437.80 6,340.80 72208 -2,441.24 5,981,664.55 537,776.04 13.26 1,845.96 MWD(4) 8,140.17 88.86 284.60 6,438.32 6,341.32 728.89 -2,472.49 5,981,671.19 537,744.76 14.53 1,867.48 MWD(4) 8,170.46 89.48 287.85 6,438.76 6,341.76 737.35 -2,501.56 5,981,679.49 537,715.64 10.92 1,889.34 MWD(4) 8,200.63 90.55 29260 6,438.75 6,341.75 747.77 -2,529.86 5,981,689.77 537,68729 16.14 1,912.52 MWD(4) ( 8,230.71 91.29 297.52 6,438.27 6,34127 760.51 -2,557.10 5,981,702.35 537,659.99 16.54 1,937.17 MWD(4) (I 8,261.50 90.83 302.46 6,437.70 6,340.70 775.89 -2,583.75 5,981,717.59 537,633.25 16.11 1,963.82 MWD(4) 8,291.52 91.57 301.51 6,437.07 6,340.07 791.79 -2,609.21 5,981,733.35 537,607.71 4.01 1,990.32 MWD(4) 8,321.10 91.72 29726 6,436.22 6,339.22 806.29 -2,634.97 5,981,747.72 537,581.88 14.37 2,015.76 MWD(4) 8,351.80 91.17 300.18 6,435.44 6,338.45 821.04 -2,661.88 5,981,762.32 537,554.89 9.68 2,041.98 MWD(4) 8,381.23 89.11 304.19 6,435.37 6,338.37 836.71 -2,686.78 5,981,777.85 537,529.91 15.32 2,068.01 MWD(4) 8,410.90 90.92 309.27 6,435.37 6,338.37 854.45 -2710.55 5,981,795.46 537,506.05 18.18 2095.25 MWD(4) 8,441.43 90.40 313.39 6,435.01 6,338.01 874.61 -2733.47 5,981,815.49 537,483.02 13.60 2124.17 MWD(4) 8,471.14 90.18 318.15 6,434.86 6,337.86 895.89 -2,754.19 5,981,83666 537,462.19 1604 215296 MWD(4) 8,501.30 90.61 321.01 6,434.66 6,337.66 918.85 -2,773.74 5,981,859.51 537,442.52 9.59 2,182.62 MWD(4) 8,531.85 91.57 32249 6,434.07 6,337.07 942.83 -2792.65 5,981,863.39 537,423.48 5.77 2212.84 MWD(4) 8,561.27 87.76 321.53 6,434.25 6,33725 966.01 -2810.76 5,981,906,47 537,405.26 13.35 2,241.97 MWD(4) 8,590.86 90.49 319.83 6,434.70 6,337.70 988.90 -2,829.50 5,981,929.26 537,386.39 10.87 2,271.16 MWD(4) 8,620.63 95.38 325.39 6,433.17 6,336.17 1,012.50 -2,847.54 5,981,952.76 537,368.22 24.85 2,300.63 MWD(4) 8,650.86 93.29 329.97 6,430.89 6,333.89 1,037.97 -2,863.65 5,981,978.14 537,351.98 16.61 2,330.74 MWD(4) 8,680.68 94.27 336.81 6,428.92 6,331.92 1,064.56 -2,876.97 5,982,004.65 537,338.52 23.12 2,360.42 MWD(4) 8,710.62 94.03 34244 642675 6,329.75 1,092.54 2,887.37 5,982,032.57 537,327.97 18.77 2,389.85 MWD(4) 8 741 25 92.64 345.49 6 424.97 6,327.97 1,121.92 -2,895.81 5 982,061.91 537,319.37 10.93 2 419.52 MWD(4) 8,770.20 91.04 348.16 6.424 04 6,327.04 1,150.09 -2,902.41 5,982,090.04 537,312.63 10.75 2 447 21 MWD(4) 7/14/2017 2:07:55PM Page 4 COMPASS 5000.14 Build 85 I i • ConocoPhillipsrtR 0 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 G-15 Project: Kuparuk River Unit TVD Reference: ,1G-15 @ 87.00usft(Doyon 9) Site: Kuparuk 1G Pad MD Reference: 1G-15 @ 97.00usft(Doyon 9) Well: 11G-15 North Reference: True Wellbore:: 1G-15 Survey Calculation Method: Minimum Curvature Design: 1G-15 Database: EDT Alaska Sandbox Survey ., .'=,din,. � '. i. . 4, 1 , Map Map Vertical MD Inc Azi ND NOSS +N1-S +Ef•W Northing Easting DLS Section Survey Tool Name Annotati0n (usft) C) C) (usft) (usft) (usft) (usft) )t) (ft) Ci100') (ri) . 8,800.17 94.98 352.44 6,422 46 6,325.46 1,179.58 -2,907.45 5,982,119.50 537,307.43 19.39 2,475.27 MWD(4) 8,83036 91.54 357.32 6,420.75 6,323.75 1,209.59 -2,910.13 5,982,14949 537,304.56 19.75 2,502.60 MWD(4) 8,860.46 92.30 357.74 6,419.74 6,32274 1,239.64 -2911.43 5,982,179.53 537,303.12 2.88 2,52928 MWD(4) 8,890.17 93.75 0.88 6,418.17 6,321.17 1,269.30 -2,911.79 5,seQ,20a 19 537,302.61 11.63 2,555.14 MWD(4) 8,920.14 95.26 3.88 6,41582 6,318.82 1,299.15 -2910.55 5,982,239.04 537,303.69 11.18 2,580.37 MWD(4) 8,950.07 92.00 5.83 6,413.92 6,316.92 1,328.91 -2,908.02 5,982,268.81 537,306.05 12.68 2,604.88 MWD(4) 8,980.00 91.57 7.47 6,412.99 6,315.99 1,358.62 -2904.56 5,982,298.53 537,309.36 5.66 2,628.88 MWD(4) 9,010.77 89.72 4.18 6,41264 6,315.64 1,389.23 -2901.43 5,982,329.15 537,31232 12.27 2,653.82 MWD(4) 9,044.52 85.23 359.87 6,41413 6,317.13 1,422.91 -2900.24 5,982,362.83 537,313.33 18.43 2,682.39 MWD(4) 1 9,075.34 87.70 3.11 6,416.03 6,319.03 1,453.65 -2,899.44 5,982,393.58 537,313.96 13.20 2,708.62 MWD(4) • z 9,105.34 84.81 5.27 6,417.99 6,320.99 1,483.50 -2,897.25 5,982,423.44 537,315.99 12.02 2733.38 MWD(4) 9,129.62 86.55 7.73 6,419.82 6,322.82 1,507.55 -2,894.51 5,982,447.50 537,318.60 12.39 2752.84 MWD(4) 9,160.30 85.18 11.36 6,422.03 6,325.03 1,537.72 -2,889.44 5,982,477.70 537,323.51 12.62 2776.43 MWD(4) 9,190.43 86.81 14.91 6,424.14 6,327.14 1,566.99 -2882.61 5,982,50699 537,330.18 12.94 2798.36 MWD(4) 9,220.22 85.36 16.70 6,426.17 6,329.17 1,595.58 -2,874.52 5,982,535.63 537,338.12 7.72 2,819.07 MWD(4) 9,250.66 84.03 1932 6,42898 6,331.98 1,624.41 -2865.15 5,982,56450 537,347.33 9.62 2839.35 MWD(4) 9,285.22 85.08 2294 6,43227 6,335.27 1,656.49 -2,852.75 5,982,596.65 537,359.56 10.86 2,860,94 MWD(4) 9,310.52 84.40 2453 6,434.58 6,337.58 1,679.55 -2842.61 5,982,619.76 537,369.58 6.81 2,875.84 MWD(4) 9,340.41 85.91 2477 6,437.11 6,340.11 1,706.62 -2,830.19 5,982,646.89 537,381.85 5.11 2893.07 MWD(4) 9,368.93 85.94 21.87 6,439.14 6,34214 1,732.74 -2,818.93 5,982,673.07 537,392.97 10.14 2,910.06 MWD(4) 9,39996 85.95 20.87 6,44133 6,34433 1,761.56 -2807.65 5,982,701.95 537,404.09 3.21 2929.38 MWD(4) 1 9,431.19 84.15 1973 6,44403 6,347.03 1,790.74 -2,796.85 5,982,731.18 537,414.73 6.82 2,94926 MWD(4) 9,463.29 81.67 18.10 6,44799 6,350.99 1,820.87 -2786.53 5,982,761.37 537,424.89 9.22 2970.19 MWD(4) 9,489.96 82.51 13.62 6,451.66 6,35466 1,846.28 -2,779.31 5,982,786.81 537,431.97 16.93 2,888,58 MWD(4) 9,516.39 82.23 13.08 6,455.17 6,358.17 1,871.77 -2,773.26 5,982,812.33 537,437.88 2.29 3,007.63 MWD(4) 9,548.95 82.48 9.31 6,459.50 6,36250 1,903.42 -2,767.00 5,982,844.01 537,443.98 11.50 3,031.91 MWD(4) : 9,579.96 82.49 645 6,463.56 6,366.56 1,933.87 -2762.78 5,982,874.48 537,448.03 9.14 3,056.17 MWD(4) 9,606.47 81.83 401 6,467.17 6,370.18 1,960.02 -2,760.39 5,982,90064 537,450.28 9.45 3,077.62 MWD(4) 9,643.79 80.91 3.01 6,47277 6,375.78 1,996.85 -2758.13 5,982,93747 537,452.34 3.62 3,108.38 MWD(4) 9,67980 80 80.78 0.53 6,47797 6380 07 2,023.50 -2757.31 5,982,964.12 537 45302 9.08 3131.05 MWD(4) 970136 82.43 358.58 648153 6384.54 2053.73 -2757.54 5,982,994.35 53745262 8.31 3157.35 MWD(4) 7/142017 2:07:55PM Page 5 COMPASS 5000.14 Build 85 • ConocoPhillips ER #1 ES ConocoPhillips `'�`t p Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Ku p1 Local Co-ordinate:Reference: Well 1G-15 Project: Kuparuk River Unit TVD Reference: 1G-15(g 97.00usfl(Doyon 9) Site: Kuparuk 1G Pad MD Reference: 1G-15(§97.00usfl(Doyon 9) Well: 1G-15 North Reference: True Wellbore;' 1G-15 Survey Calculation Method: Minimum Curvature Design: 1G-15 Database: EDT Alaska Sandbox Survey • MD Inc �; ,TVD TVr,111)5., +NIS +91.W Eesdng DLS Saetate y i/ (" .: c w„s.=i... (!t) °I1O0) (ft) SuveyTaoli�0.ti1M / 973052 83.11 35640 6,48521 638821 208262 2,758.81 5,983,02324 537,451.20 7.77 318301 MWD(4) 9,758.06 81.79 354.06 6,488.82 6,39182 2,109.83 -2,761.08 5,983,050.43 537,448.79 9.69 3,207.70 MWD(4) 9,785.23 82.12 357.04 6,492.63 6,395.63 2,136.65 -2763.17 5,983,077.23 537,446.56 10.93 3,231.97 MWD(4) 9,815 00 9522 416 6,493.32 6,39E32 2166 32 -2,762.85 5,983,106.90 537 446.71 5006 3,25712 MWD(4) 9,86300 9522 416 6,488.95 6,39195 221400 -2,759.38 5,983,154.59 537,449.92 0.00 3,29707 PROJECTED to TD 7/142017 2:07:55PM Page 6 COMPASS 5000.14 Build 85 • lr ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1 G-15APB1 50-029-21024-70 Baker Hughes INTEQ BAGHEs ` � dUGE company Definitive Survey Report 14 July,2017 • III ConocoPhillips 0 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc-Kup1 Local Co-ordinate Reference: Well 1 G-15 ,:- Project: Kuparuk River Unit ND Reference: 1G-15 @ 97 00usft(Doyon 9) Site: Kuparuk 1G Pad MD Reference: 1G-15 @ 97.00usft(Doyon 9) Well; 1G-15 North Reference: True Wellbore: 1G-15 Survey Calculation Method: Minimum Curvature Design: 1G-15 Database. EDT Alaska Sandbox , ....„..„.„.........„,..., .t.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 r..Well 10-15 1 I Well Position .I.N/-S 0.00 usft Northing: 5,980,955.66usft Latitude: 70°2132.064 N 1 l -1.E./..IN 0.00 usft Easting: 540,220.88usft Longitude: 149.40'23.944 W I Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 56.00 usft • Magnetics Model Name , Somata Nate , ,-;:;:t.-,-.,--,:',,,,,,,':,ili', -4, - . -- ---„,„;-_--,,- ,r) ---,,,„. . . ,.-by..z.g4,,,,,,. .;)„,,,,.., .;„,•.r.„,,,ak ;;;;,...0- ,,ty,,,,; ,u.,.<.•'.,,,,,., 1 • ---,-..0--A:1,''.",. '''.A.,..1:•.,,,,To,.;,:',•,,,,..„ ,' ' ;.:-T',,,-,...;:a4'..le',A,,'.,'"',' , '',:',,•,•,•,,,,''-,z:z.,e,f,,....,,,,,-,',:zz's1...,.....4 '„:,,,...,,•.' BGGM2016 8/1/2017 17E2 8E96 57 541.70 = Design , 1G-15APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7000 00 ' ' .'`'-t -til.t.tt''1tt'\ttt1, : ttl.:t-,/t,''''tf1t.t)..-41.t..11(tittiite.,-1'..` Vertical Section: Depth From(ND) ':'''".1-.*,..' *.., Vg.eN/^a ":t •''";#4,', :"F'ii-PYia-irtt.,,7),;".,e':''akiVt4iti4zil:';i-izzz.,, (astt) :,..',,..'',,4‘,4,,'..,„:„`a,,I.4...,i',',,,.'(sett). - ---,..--;'..,...",--%,,%,;,.1,2.1:' :W :a 'InP'.":""":',..,.".....',,,,,:illit.t.:....,r,.;:,..;.:::.17;:ezz!,::::::::: ,,,,:;),;•:,,)>,:„,-,;,,..,-;,.-•'-r.,,,,, - -- ,,,,,*,----Atr,n,-,',1-,,,,;.4.;:i..-:,-----4-::::--,,,,-7, ,,,4, •-<„,,,....,-,!n;?,).-;-;,•;.1...,,,,,-,7,,,,,•,' --, '',.-- --- 41 00 0.00 0.00 330.00..„ Survey Program Date 7/12/2017 , ,,-;:::;,,,,,:" ‘,...;1:,,,,,,,,...•,71,,:',' " ' ..,,,,,, From To .."t,:jj ' Stsrtrey Survey (usft) (usft) Survey(Wellbore) : : ' ' Tani Nam. 14,0;, Desatiption Start Date End Date 100E0 6E73E0 1G-15(GyroData)(1G-15) GYD-CT-CMS Gyrodata cont.casing m/s 1017/2009 10/7/2009 6,700E0 7,000.00 1G-15(1G-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 11/13/1983 11/13/1983 t 7,033E0 7,084.73 1G-15APB1 MWD-INC(1G-15APB1) MWD-INC_ONLY MWD-INC_ONLY_FILLER 6/1/2017 6/3/2017 ) 7,114.84 9,103E8 1G-15APB1 MWD(1G-15APB1) MWD MWD-Standard 6/3/2017 6/7/2017 7/14/2017 2:00:33PM Page 2 COMPASS 5000.14 Build 85 • • ConocoPhillipsBILESAAEs $ ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-15 Project:. Kuparuk River Unit TVD Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad MD Reference: 1G-15 fa 97.00usft(Doyon 9) Well: 1G-15 North Reference: True Wellbore: 1G-15 Survey Calculation Method: Minimum Curvature - Design 1G15 Database: EDT Alaska Sandbox Survey ..,.. Map Map Vertical I,; MD Inc Azi TVD TVD5S -i-NIS +E!-W Northing Easting DLS Section Survey Tool Name Annotation ' (usft) (") (') (usft) (usC) (usft) (usft) Northing (13) ('1100`! II 7,000 00 32.12 298.90 6,504 99 6,407.99 737.47 -1,447.70 5,981,685 28 538,769 38 0.72 1,362 52 MWD-INC_ONLY(3) TIP 7,033.00 31.97 29697 6,53296 6,435.96 745.95 -1,463.03 5,981693 67 538,754.02 0.47 1,377.52 MWD-INC_ONLY(3) KOP 17,058.00 377 084.73 4620 298.56 6 573.51 6 476.51 761.11 -1 491.10 5.08 298.00 6,553.55 6,456.55 75269 -1,475.48 5,981,700.35 538,741.53 20.56 1,389.59 MWD-INC_ONLY(3) Interpolated Azimuth _ ,881,708.67 538,725.86 34.15 1,404.69 MWD-INC ONLY(3) Interpolated Azimuth 7114.84 54.36 299.04 6592.73 6495.73 77226 -1511.37 5,981,719.72 538,705.53 27.13 1424.48 MWD(4)4 First Clean Survey 7,144,77 64.34 292.75 6,607.98 6,510.98 783.42 -1,534.52 5,981,730.75 538,682.33 37.91 1,445.72 MWD(4) 7,175.03 7273 288.52 6,619.05 6,522.05 793.30 -1,560.86 5,981,740.49 538,655.94 30.62 1,467.45 MWD(4) 7,205.19 82.89 286.12 6,625.41 6,528.41 802.05 -1,588.96 5,981,749.09 538,627.79 34.57 1,489.08 MWD(4) 7,235.18 9243 285.79 6,626.64 6,529.64 810.28 -1,617.74 5,981,757.16 538,598.97 31.83 1,510.59 MWD(4) 7,265.45 101.76 281.50 6,622.90 6,525.90 817.37 -1,646.89 5,981,764.09 538,569.79 33.87 1,531.31 MWD(4) 7,295.33 105.96 272.72 6,615.73 6,516.73 820.97 -1,675.64 5,981,767.54 538,541.03 31.80 1,548.80 MWD(4) § 7,325.39 104.59 261.76 6,607.79 6,510.79 819.57 -1,704.55 5,981,765.99 538,512.12 35.46 1,562.04 MWD(4) 7,357.63 106.18 252.30 6,599.22 6,502.22 812.61 -1,734.80 5,981,758.87 538,481.91 28.71 1,571.15 MWD(4) 7,385.76 10694 249.44 6,591.20 6,494.20 803.78 -1,780.27 5,981,749.90 538,456.49 10.11 1,576.23 MWD(4) 7,415.74 107.51 246.71 6,582.32 6,485.32 793.09 -1,786.84 5,981,739.07 538,429.99 8.90 1,580.25 MWD(4) 7,445.70 108.00 244.11 6,573.18 6,476.18 781.22 -1,812.78 5,981,727.06 538,404.11 8.43 1,58294 MWD(4) 7,475.59 108.32 241.19 6,563.86 6,466.86 768.17 -1,838.00 5,981,713.88 538,378.96 9.34 1,584.26 MWD(4) ' 7,505.53 108.08 238.50 6,554.51 6,457.51 753.89 -1,862.59 5,981,699.46 538,354.45 8.57 1,584.18 MWD(4) 7,535.74 107.52 239.82 6,545.27 6,448.27 739.14 -1,887.29 5,981,684.58 538,329.84 4.55 1,583.76 MWD(4) 7,565.69 106.70 242.79 6,536.46 6,439.46 725.40 -1,912.40 5,981,670.71 538,304.81 9.86 1,584.41 MWD(4) 7,595.80 105.59 245.68 6,528.09 6,431.09 712.83 -1,938.44 5,981,658.00 538,278.83 9.93 1,586.55 MWD(4) 7,631.36 105.00 250.23 6,518.70 6,421.70 699.96 -1,970.22 5,981,644.97 538,247.12 12.45 1,591.30 MWD(4) 7,669.16 105.11 254.87 6,508.88 6,411.88 689.02 -2,005.04 5,981,633.84 538,212.37 11.86 1,59923 MWD(4) 7,699.18 103.94 257.27 6,501.35 6,404.35 682.03 -2,033.24 5,981,626.69 538,184.21 8.66 1,607.27 MWD(4) 7,731.02 104.06 262.82 6,493.64 6,396.64 67069 -2,063.65 5,981,621.19 538,153.83 16.92 1,617.86 MWD(4) 7,761.00 104.28 266.47 6,486.30 6,389.30 673.98 -2,092.59 5,981,618.32 538,124.91 11.83 1,629.97 MWD(4) 7,790.65 103.90 269.93 6,479.08 6,382.08 673.07 -2,121.33 5,981,617.27 538,096.18 11.39 1,643.56 MWD(4) 7,827.24 102.61 273.18 6,470.69 6,373.69 674.04 -2,156.92 5,981,618.04 538,060.58 9.34 1,66220 MWD(4) 7,863.96 99.37 271.69 6,463.69 6,366.69 675.57 -2,192.93 5,981,619.38 538,024.57 9.68 1,681.53 MWD(4) 7,895.54 96.09 268.70 6,459.44 6,362.44 675.67 -2,224.22 5,981,619.31 537,993.29 14.00 1,697.26 MWD(4) 7/14/2017 2:00:33PM Page 3 COMPASS 5000.14 Build 85 • • ConocoPhillipsR 0 ConocoPhillips Definitive Survey Report Company:; ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-15 Project: Kuparuk River Unit TVD Reference: 1G-15(o]97.00usft(Doyon 9) Site: Kuparuk 1G Pad MD Reference: --'.1G-15 @ 97.00usft(Doyon 9) Well: 1G-15 North Reference: True ''.Wellbore: 10-15 ,Sureey Calculation Mbtbod: Minimum Curvature Design: 1G-15 4,- EDT Alaska Sandbox Survey MD Inc Azi TVD T11t SS +1418 1 OLS o" t et) NIA Nen j�f� Survey Tool Nan* Mr/ ' (ate) (�)< (�) �w Yfl>� (a1� �y ��. /u i✓ n,fc �',^,�i/, J". 7,927.90 95.04 26489 6,456.30 6,359.30 673.87 -2,256.37 5,981 617.34 537,961.15 1216 1,71177 MWD(4) 7,956.64 90.37 265.57 6,454.93 6,357.93 671.47 -2,285.17 5,981,614.78 537,932.37 16.31 1,724.09 MWD(4) 7,987.16 90.68 267.56 6,454.66 6,357.66 669.65 -2,31543 5,981,612.81 537,902.12 6.64 1,737.65 MWD(4) 8,017.14 91.14 269.94 6,454.18 6,357.18 669.00 -2345.40 5,981,611.99 537,872.16 8.08 1,752.07 MWD(4) 8,047.14 90.09 27220 6,453.86 6,356.86 669.56 -2,375.39 5,981,612.39 537,84217 8.31 1,767.55 MWD(4) 8,077.63 90.12 27266 6,453.80 6,356.80 670.85 -2,405.85 5,981,613.52 537,811.70 1.51 1,783.90 MWD(4) g 8,107.38 89.85 272.20 6,453.81 6,356.81 67211 -2,435.57 5,981,614.62 537,781.97 1.79 1,799.85 MWD(4) 8,138.08 92.09 27294 6,453.29 6,356.29 673.49 -2466.24 5,981,615.83 537,751.31 7.68 1,816.38 MWD(4) 8,169,44 91.54 273.82 6,452.30 6,355.30 675.34 -2,497.53 5,981,617.51 537,720.01 3.31 1,833.62 MWD(4) S 8,197.02 92.74 276.60 6,451.27 6,354.27 677.84 -2,524.97 5,981,619.87 537,692.56 10.97 1,849.51 MWD(4) 8,224.97 97.74 280.80 6,448.71 6,35171 68204 -2,55247 5,981,623.92 537,665.04 23.32 1,866.90 MWD(4) 8,255.23 88.43 283.96 6,447.09 6,350.09 688.52 -2,581.94 5,981,630.24 537,635.53 32,48 1,887.25 MWD(4) 8,286.62 91.94 290.82 6,446.99 6,349.99 687.89 -2,611,88 5,981,639.45 537,605.55 24.55 1,910.33 MWD(4) 8,314.54 94.83 29720 6,445.34 6,348.34 709.22 -2,637.32 5,981,650.64 537,580.05 25.05 1,932.87 MWD(4) 8,348.94 93.81 306.45 6,442.74 6,345.74 72729 -2,666.43 5,981,668.55 537,550.84 26.98 1,963.07 MWD(4) 1 8,378.66 86.00 310.51 6,442.79 6,345.79 745.77 -2,689.68 5,981,686.90 537,527.50 29.61 1,990.69 MWD(4) 8,408,80 88.09 31720 6,444.34 6,347.34 766.61 -2,711.37 5,981,707.63 537,505.70 23.22 2,019.58 MWD(4) 8,438.72 8526 322.42 6,446.08 6,349.08 789.42 -2730.63 5,981,730.33 537,486.32 19.82 2,048.97 MWD(4) 8,469.20 84.65 328.38 6,448.76 6,351.76 81440 -2,747.87 5,961,755.21 537,468.95 19.58 2,079.22 MWD(4) 8,498.70 85.98 334.47 6,451.17 6,354.17 840.20 -2,761.92 5,981,780.94 537,454.76 21.06 2,108.60 MWD(4) 8,528.64 85.08 340.38 6,453.51 6,356.51 867.75 -2,773.38 5,981,808.42 537,443.16 19.91 2,138.19 MWD(4) 8,556.88 84.89 345.79 6,455.98 6,358.98 894.66 -2,781.56 5,981,835.28 537,434.83 19.10 2,165.58 MWD(4) B§ 8,588.67 82.98 351.41 6,459.34 6262.34 925.63 -2787.81 5,981,866.22 537,42842 18.58 2,195.52 MWD(4) 5618.61 80.31 356.36 6,463.69 6,366.69 95507 -2,790.97 5,881,885.64 537,425.10 18.63 2,222.60 MWD(4) 8,648.66 81.40 214 6,468.47 6,371.47 984.72 -2791.35 5,981,92529 537,424.56 19.33 2,248.47 MWD(4) I 8,678.67 81.61 7.30 6,472.91 6,375.91 1,014.29 -2,788.91 5,981,954.87 537,426.84 17.02 2272.86 MWD(4) 8,708.65 83.39 13.30 6,476.83 6,379.83 1,043.52 -2783.60 5,981,984.12 537,43200 20.71 2295.52 MWD(4) ( l 8,738.84 81.70 17.47 6,480.75 6,383.75 1,072.38 -2,775.66 5,982,013.01 537,43978 1480 2,316.54 MWD(4) l 5768.65 81.31 22.45 6,485.15 6,388.15 1,100.08 -2765.60 5,982,040.77 537,449.69 16.57 2,335.50 MWD(4) I §.) 8,798.64 85.98 2236 6,488.47 6,391.47 1,127.63 -2,754.24 5,982,068.37 537,460.90 1557 2353.68 MWD(4) I8,828.68 90.15 23.23 6,489.48 6,392.49 1,155.30 -2742.61 5,982,096.10 537,47238 14.18 2371.83 MWD(4) 1 7/14/2017 2:00:33PM Page 4 COMPASS 5000.'14 Build 85 • s ConocoPhillipsGHES 4) s ConocoPhilli p Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-15 s Project: Kuparuk River Unit TVD Reference: 1G-15 l 97.00usft(Doyon 9) Site: Kuparuk 1G Pad MD Reference: 1G-15 @ 97.00usft(Doyon 9) Weil: 10-15 North Reference: True _.Wellbore:f 1G-15 Survey Calculation Method: Minimum Curvature Design. 1G-15 Database: EDT Alaska Sandbox Survey •MD. Inc Az) INV =tVDSS +Ni-S +Et-611 .. ci Map DLs Vertical,.., /i Fasting Section Survey Tool Name :•• Ain it; 0410 CI (1 jV" (aeRj kik} (n) (^noa) (n) .,1 8,858.67 89.54 28.78 6,489.57 6,392.57 1,182.24 -2729.47 5,982,123.11 537,485.37 18.62 2,388.59 MWD(4) 8,888.68 91.72 33.23 6,489.24 6,392.24 1,207.96 -2714.01 5,982,148.91 537,500.69 16.51 2,403.13 MWD(4) 0918.79 92.46 38.20 6,488.14 6,391.14 1,232.38 -2696.45 5,982,173.42 537,518.11 16.68 2,415.50 MWD(4) 8,948.64 93.50 43.50 6,486.58 6,389.58 1,254.92 -2676.96 5,982,196.07 537,537.48 18.07 2,425.28 MWD(4) 8,978.68 93.78 48.69 6,484.68 6,387.68 1,275.70 -2655.37 5,982,216.96 537,558.96 1727 2,432.48 MWD(4) 9,008.55 94.00 54.52 6,482.65 6,385.65 1,294.20 -2632.03 5,982,235.59 537,582.20 19.49 2,436.83 MWD(4) 1 9,039.04 94.24 59.71 6,480.46 6,383.46 1,310.71 -2,606.50 5,982,252.23 537,607.64 17.00 2,438.36 MWD(4) 9,068.60 98.52 61.30 6,477.17 6,380.17 1,325.17 -2,580.93 5,982,266.82 537,633.12 15.43 2,438.10 MWD(4) 9,103.88 10283 63.72 6,470.64 6,373.64 1,341.17 -2,550.19 5,982,282.99 537,663.78 13.95 2,436.59 MWD(4) 9,150.00 102.83 63.72 6,460.40 6,363.40 1,361.08 -2509.87 5,982,303.12 537,703.98 0.00 2,433.67 PROJECTED to TD i 7/142017 2:00:33PM Page 5 COMPASS 5000.14 Build 85 • • Letter of Transmittal Date: DATA LOGGED UGH ES July 28, 2017 JULz ND 31 2017 tn K.BENDER pp aGECO )aty AOGC To: From: Makana Bender Yosha Ragbirsingh / Michael Soper AOGCC Baker Hughes, a GE Company 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): 1G-15APB1 2 1 7 0 6 5 2 8 4 5 1 CD i n 217-065 1G-15A � � X 0 6 5 2 8 5 0 1G -15AL1 0 7 0 5 2 1G-15AL2 2 1 7 0 7 1 2 8 4 5 3 1C-04A 2 1 7 0 7 8 2 8 4 4 8 1C-04A L1 21 7083 28 44 9 (6) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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C > U VI 0- 3.6 `o as ' ' 0 Q N W O 0 O 7 N M M O 0iii O u7 I� N c(') Ii O N N 0 0 S U Y D U U U S °— (00000) 00000 O cn V ('(O (00 W 3 2 2m CD m o 0 O co N 0 V N. 0 c0+) (00 0 LOO I N C d .. ❑ N 0 (O O 0) 0) O co O O ca V C >, C N a0 0) N CO Oi Oi O. N O ^O U 0 O Y 0, N y 5 U a fn 'S ❑ Cl) • • • • 217065 BA ER ® PRINT DISTRIBUTION LIST 28429 UGHES a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. ConocoPhillips Alaska, Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED WELL NAME 1G-15A RECEIVED 700 G Street. -1/21/2o-i 1 RECEIVED M.K. BENDER Anchorage,Alaska 99510 FIELD Greater Kuparuk Area to acknowledge receipt of this data. 'it 252017 COUNTY North Slope Borough AOGCC TYPE GR-RES BHI DISTRICT Alaska AOGCC --- LOG DATE June 27, 2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(c bakerhughes.com TODAYS DATE July 21, 2017 Revision STATUS Final Replacement: No Details: Rev. 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N W /00 Cco COO 00) j Y 0 = CO 0 N 00) cco 3 S 7 a cl a v Ci v W to to tD (D 4 C 0 ) . s to Q -OtD• a• r V a VI L E - C)_ O CO 0 u) up cn N N N �_ C O 0_ r V .-. S U Y Y U` (7 U' C ?.. m co co a) rn a LO � oi LO V CV LO O N CO O O O q). .0 C r2' 3 ai ai ai a) O)I \ O c m .. n a+ m 1. 0 U E •'o °� m "' Z 0- v a ra 3 3 y S41021 7065 ' BAKER 0 28430 UGHES PRINT DISTRIBUTION LIST a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration AlaskaConocoPhillips Alaska, Inc. IR EC E IVE I- Ricky Elgarico.ATO 3-334. DATA LOGGED 1/13/201 700 G Street. y WELL NAME iG 15APB1 M. K.BENDER JUL 2 5 2011 Anchorage,Alaska 99510 FIELD Greater Kuparuk Area to acknowledge receipt of this data. COUNTY North Slope Borough AOGCC LOG TYPE GR- RES BHI DISTRICT Alaska --- LOG DATE June 27,2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(c�bakerhughes.com TODAYS DATE July 21,2017 Revision STATUS Final Replacement: No Details: Rev. 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J 5 DNR-Division of011&Gas *** 0 0 1 1 0 LAttn:Resource Evaluation 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 **Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 1 1 1 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 • • LC) LC) O ® M () co th N N W a no.Z.o WOW T m CI W ~ 0 T. N > o V !JI N 0 C' 0 ' v CC C cct O i ^ as as W C Q i— ` 0z 0:D a.— •— t — .— r o a = aAp � 2 ti 7,V O °' a =O 0mo 47, N. C O a N a) c o N >, U O a s - o (13 W -) V Y Ym O va • • z ' OD u 1 mi IF:--,‘,..,,, , , ,,t , _ d' ". M CO co o y y r s Z M o 0 0 N 0 3 k' . W ;•I'''.9 co co CO Q. } 0 2, 6 I. t , r, `epi `' P _ O t o ` m -0) u Y.. M ®® s N� O O I ° M 2 ° N_ \ p p Z t ^ CO NN. 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O N O CD CO V CO V 0 Y Q v O O CO OO CO OO Ucsi O OO rOOr CO N CD a CO CD v v v v a v U v C l6 co co M O O O N 0 N N co r N N IO cD IO r C) r r '7C O C) O 6 O V O) C) C) N N v N CO CO 7 IO O CO CO CO - a`). d N _c LE /\ a Y Y _ U 2 O N L IO 7 N CO O O O V' N C) M 0 co c0 •- ,— C d O N r V IO r 0 N N O O • Di C3 0 '0 UCt. corn rn o) rnoo ZS Y Y M O M U r0 co CO r O O o 0 O o O O IOC) 00 O N O Cl)Oof O IOO N _' _ .. O N O O O O O O O O O N .. O C >. 7 O co co co co O) 47 W O) 47 a m a a) m o V p o m m el 3 v ✓ Q. in 3 o m • i of Tjf eSPt' 4% THE STATE Alaska Oil and Gas 4 of Conservation Commission 15 } == LAsKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 FO. ALAS� Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-15A ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-065 Surface Location: 4971' FNL, 4839' FEL, SEC. 29, T12N, R10E, UM Bottomhole Location: 2792' FNL, 2156' FEL, SEC. 30, T12N, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, '14--V- ( Cathy P. Foerster Chair DATED this rZ day of May, 2017. RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 01 2017 PERMIT TO DRILL, 20 AAC 25.005 a la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp $ lc.Specify if well is proposed for: Drill ❑ Lateral ❑., Stratigraphic Test ❑ Development-Oil ❑✓ . Service- Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ • Single Well ❑ 11.Well We and Number: ConocoPhillips Alaska Inc Bond No. 5952180 '. 1G-15A 3.Address: 6. Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9875 • TVD: 6406 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Field/Kuparuk Oil Pool Surface: 4971'FNL,4839'FEL,Sec 29,T12N,R10E, UM ADL025640 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4262'FNL, 1015'FEL,Sec 30,T12N, R10E,UM 931813000 5/12/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2792'FNL,2156'FEL,Sec 30,T12N,R10E,UM 2459 . 2965' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 97 . 15.Distance to Nearest Well Open Surface:x- 540221 y- 5980956 Zone- 4 . GL Elevation above MSL(ft): 56 • to Same Pool: 321'(1G-08AL2-02) 16. Deviated wells: Kickoff depth: 7033 feet ., 17. Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 103 degrees • Downhole: 371-6"--50,',.4a/Surface: 3097 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 2600' 14000' 6469' 16600' 6501' 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): 7533' 6963' 7105' 7095' 6586' 7510' Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 212 sx CS II 114' 114' Surface 2166' 10-3/4" 1100 sx Permafrost E&250 sx 2202' 2202' Intermediate Permafrost C Production 7468' 7" 750 sx Class G&250 sx Permafrost 7502' 6934' Liner C Perforation Depth MD(ft): 6834'-7230' Perforation Depth TVD(ft): 6364'-6701 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements2 21. Verbal Approval: Commission Representative: Date 2( Itpr-2017 22. I hereby certify that the foregoing is true and the procedure approved herein will not Long(263-4372) be deviated from without prior written approval. Contact Email William.R.Long@COP.com Printed Name James Ohlinger Title Staff CTD Engineer Signature 5:07:4440t. Phone 265-1102 Date 4//8//7 Commission Use Only Permit to Drill API Number: Permit Approval , See cover letter for other Number: Q)�- O(-S� 50-0a.9-al 0211 -Q/ -Gq Date: 5 a 17 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [+f Other: 90 p fif51 38 Gpy/7 lSamples req'd: Yes No[ ' Mud log req'd:Yes❑ No V 4�i1 ri U I ✓pr-f V/It 17" fits ✓ fd Z5-00175,1,HzS measures: Yes NoDirectional svy req'd:Yes V No Spacing exception req'd: Yes❑ No ii.. Inclination-only svy req'd:Yes❑ No Post initial injection MIT req'd:Yes❑ No APPROVED BY Approved by: / 3‹.-1-14-7---- COMMISSIONER THE COMMISSION Date:5-/a_77 `► , 43/1 (64f3�- v7"1- 579/17 R Submitsn Form and Form 10-401(Revised 1 15) � eGtIN &L onths from the date of approval(20 AAC 25.005(8)) Attachments in Duplicate • ConocoPhilli s p Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 MAY 0 1 2017 April 28, 2017 „ Commissioner-State of Alaska AOGCC � 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 three laterals out of the Kuparuk well 1G-15 well using the coiled tubing drilling rig, Nabors CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500'from the original point. The work is scheduled to begin May 12, 2017. The objective will be to drill laterals KRU 1G-15A, 1G-15AL1, and 1G-15AL2 targeting the Kuparuk C-sands. Attached to this application are the following documents: — 10-401 Applications for 1G-15A, 1G-15AL1, and 1G-15AL2 — Detailed Summary of Operations — Directional Plans for 1G-15A, 1G-15AL1, and 1G-15AL2 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, // William Long ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • Kuparuk CTD Laterals 1G-15A, 1G-15AL1, & 1G-15AL2 ConocoMaps . 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 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 1G-15A, 1 G-15AL1, and 1G-15AL2 laterals 7 Attachment 2: Current Well Schematic for 1G-15 7 Attachment 3: Proposed Well Schematic for 1G-15A, 1 G-15AL1, and 1 G-15AL2 laterals 7 Page 1 of 7 April 25, 2017 ! i PTD Application: IG-15A, 1G-15AL1, & 1G-15AL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(t) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1G-15A, 1G-15AL1, and 1G15-AL2. All laterals will be classified as"Development-Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 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 CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,800 psi. Using the maximum formation pressure in the area of 3589 psi in 1G-04 (i.e. 10.9 ppg_EMW),Ithe maximum potential surface pressure in 1G-15, assuming a gas gradient of 0`'f psi/ft, would be 3097 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 1G-15 was measured to be 2575 psi (7.8 ppg EMW) on 5/01/2016. The maximum downhole pressure in the 1G-15 vicinity is the 1G-04 at 3589 psi or 10.9 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1G-15 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 1G-15 laterals will be differential sticking and shale stability. The relaxation method will be used to free differentially stuck pipe. Managed pressure drilling practices will used to prevent hole collapse due to shale stability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1G-15 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 April 25, 2017 • • PTD Application: IG-15A, 1G-15AL1, & 1G-15AL2 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 Liner Details MD MD TVDSS TVDSS 1G-15A 7,033' 9,875' 6,410' 6,406' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1G-15AL1 8,000' 10,000' 6,354' 6,341' 2%", 4.7#, L 80, ST-L slotted liner; aluminum billet on top 1G-15AL2 7,900' 9,850' 6,359' 6,441' 2%", 4.7#, L 80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (PPO TVD TVD psi psi Conductor 16" 63 H-40 Welded 36' 114' 36' 114' 1640 670 Surface 10-3/4" 40 J-55 BTC 37' 2202' 37' 2202' 3130 1580 Production 7" 26 J-55 BTC 34' 7502 34' 6934' 4980 4320 Tubing 4-1/2" 12.6 L-80 IBT-Mod 31' 6544' 31' 6114' 8430 7500 Tubing 3-1/2" 9.3 J-55 8rd EUE 6542' 7115' 6112' 6603' 6980 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power-Vis milling fluid (8.6 ppg) — Drilling operations: Water based Flo-Pro drilling 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: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg sodium bromide completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3"Blowout Prevention Equipment Information". In the 1G-15 laterals we will use MPD to maintain formation overbalance. We will target an EMW at the window of 11.4 ppg. 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 April 25, 2017 • • PTD Application: IG-15A, 1G-15AL1, & 1G-15AL2 Pressure at the 1G-15 Window (7033' MD, 6533' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off C-sand Formation Pressure(7.8 ppg) 2653 psi 2653 psi Mud Hydrostatic(8.6 ppg) 2922 psi 2922 psi Annular friction (i.e. ECD, 0.080 psi/ft) 563 psi 0 psi Mud + ECD Combined 3484 psi 2922 psi (no choke pressure) (overbalanced —831 psi) (overbalanced —268 psi) Target BHP at Window(11.4 ppg) 3873 psi 3873 psi Choke Pressure Required to Maintain 389 psi 951 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Summary of Operations Background KRU well 1G-1 5 is a Kuparuk A/C-sand producer equipped with 4-1/2"x 3-1/2"tubing and 7"production casing. The CTD sidetrack will target the C sands. The laterals will access stranded resources in an isolated fault block. Prior to CTD operations we will pump cement on top of a plug set at 7105' and squeeze off the C sand perfs abandoning both A and C sand intervals. ConocoPhillips has previously submitted an application for sundry approval for the pre-CTD plug for redrill operations. Following the cement squeeze, cement will be milled out in tubing and a whip-stock will be set. Following this Nabors CDR3-AC will drill laterals to recover additional resources in the C sand. Each lateral will be lined with 2-3/8" slotted liner. The final liner will utilize solid liner near the original wellbore to isolate production from the already drained high water cut region of the original wellbore. This final liner will be brought up into the production tubing. Page 4 of 7 April 25, 2017 • • PTD Application: 1G-15A, 1G-15AL1, & 1G-15AL2 Pre-CTD Work 1. Slick-line: Pull gas lift valves and leave mandrels open at 7045' and 6777' to place cement behind tubing. 2. Coiled Tubing: Pump cement from 7090' to 6800', squeeze C sand. 3. Coiled Tubing: Mill and under-ream cement in tubing. 4. Slick-line: Drift whip-stock down to set depth. 5. E-line: Set whip-stock Rig Work 1. MIRU Nabors CDR3-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. MIRU Nabors CDR3-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 3. 1G-15A Sidetrack i. Mill 2.80"window through production tubing and casing at 7033'. ii. Drill lateral with bi-center bit and run 23/8"slotted liner with an aluminum billet 4. 1 G-15AL 1 Lateral i. Kick off the aluminum billet in 1G-15A. ii. Drill lateral with bi-center bit and run 2%"slotted liner with an aluminum billet 5. 1G-15AL2 Lateral i. Kick off the aluminum billet in 1G-15AL1. ii. Drill lateral with bi-center bit and run 2%" slotted liner in open hole and solid liner inside production casing 6. Freeze protect, set BPV,ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work 1. Pull BPV. 2. Return to production. Page 5 of 7 April 25, 2017 • • PTD Application: 1G-15A, 1G-15AL1, & 1G-15AL2 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. — 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 — 1G-15 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 23/" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA C 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 (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. f • 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). Page 6 of 7 April 25, 2017 • • PTD Application: 1G-15A, 1G-15AL1, & 1G-15AL2 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) Lateraal Name Diistancet 1G-15A 2695' 1 G-15AL1 2676' 1 G-15AL2 2748' - Distance to Nearest Well within Pool j,ateraFNar + v Dista — ='Well 1G-15A 321' 1G-08AL2-02 1 G-15AL1 630' 1G-08AL2 1 G-15AL2 536' 1G-08AL2 16. Attachments Attachment 1: Directional Plans for 1G-15A, 1 G-15AL 1, and 1 G-15AL2 laterals. Attachment 2: Current Well Schematic for 1G-15 Attachment 3: Proposed Well Schematic for 1G-15A, 1 G-15AL 1, and 1 G-15AL2 laterals. 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gi.daQ jeat-aA aniy U • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 10-15 1G-15A Plan: 1 G-15A_wp05 Standard Planning Report 26 April, 2017 r' 1 BAKER HUGHES • • 1.-- ConocoPhillips NM ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1G-15 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad North Reference: True Well: 1 G-15 Survey Calculation Method: Minimum Curvature Wellbore: 1G-15A Design: 1 G-15A_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 1G Pad Site Position: Northing: 5,981,540.78 usft Latitude: 70°21'37.826 N From: Map Easting: 540,089.12usft Longitude: 149°40'27.705 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.31 ° Well 1G-15 Well Position +N/-S 0.00 usft Northing: 5,980,955.66 usft Latitude: 70°21'32.064 N +E/-W 0.00 usft Easting: 540,220.88 usft Longitude: 149°40'23.944 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 56.00 usft Wellbore 1G-15A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2016 8/1/2017 17.52 80.96 57,541 Design 10-15A_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,000.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) -56.00 0.00 0.00 330.00 4/26/2017 1:08:21PM Page 2 COMPASS 5000.1 Build 74 • • ConocoPhillips ;;4 " ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1G-15 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad North Reference: True Well: 10-15 Survey Calculation Method: Minimum Curvature Wellbore: 1G-15A Design: 1 G-15A_wp05 il Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,000.00 32.12 298.90 6,410.11 700.64 -1,442.99 0.00 0.00 0.00 0.00 7,033.00 31.97 298.97 6,438.08 709.11 -1,458.32 0.47 -0.45 0.21 166.12 7,058.00 38.22 298.97 6,458.52 716.07 -1,470.89 25.00 25.00 0.00 0.00 7,128.62 70.00 298.97 6,499.40 743.43 -1,520.30 45.00 45.00 0.00 0.00 7,199.44 98.00 283.51 6,506.77 768.38 -1,585.18 45.00 39.54 -21.83 330.00 7,269.44 103.08 251.86 6,493.65 765.80 -1,653.00 45.00 7.25 -45.21 282.00 7,395.00 103.40 236.39 6,464.73 712.65 -1,762.61 12.00 0.26 -12.33 273.00 7,520.00 103.19 251.80 6,435.82 659.68 -1,871.67 12.00 -0.16 12.33 89.00 7,635.00 103.04 237.63 6,409.59 611.97 -1,972.65 12.00 -0.13 -12.32 271.00 7,805.00 102.21 258.52 6,372.03 550.46 -2,125.62 12.00 -0.49 12.29 90.00 7,905.00 92.94 266.21 6,358.85 537.39 -2,223.70 12.00 -9.27 7.69 140.00 8,090.00 92.72 288.44 6,349.60 560.80 -2,405.81 12.00 -0.12 12.01 90.00 8,290.00 89.65 312.25 6,345.42 661.11 -2,577.10 12.00 -1.54 11.91 97.00 8,490.00 85.63 335.94 6,353.78 821.74 -2,693.49 12.00 -2.01 11.84 100.00 8,700.00 83.91 1.19 6,373.24 1,025.01 -2,734.68 12.00 -0.81 12.02 95.00 8,875.00 84.32 22.29 6,391.38 1,194.46 -2,699.45 12.00 0.23 12.06 90.00 9,050.00 88.25 1.62 6,402.83 1,364.35 -2,663.55 12.00 2.25 -11.81 280.00 9,125.00 89.83 352.76 6,404.09 1,439.17 -2,667.23 12.00 2.10 -11.82 280.00 9,300.00 89.84 13.76 6,404.59 1,612.91 -2,657.34 12.00 0.01 12.00 90.00 9,430.00 89.85 358.16 6,404.94 1,741.81 -2,643.90 12.00 0.00 -12.00 270.00 9,605.00 89.86 19.16 6,405.40 1,913.85 -2,617.71 12.00 0.01 12.00 90.00 9,875.00 89.88 346.76 6,406.03 2,179.91 -2,603.97 12.00 0.01 -12.00 270.00 4/26/2017 1:08:21PM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips Vara ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1G-15 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad North Reference: True Well: 10-15 Survey Calculation Method: Minimum Curvature Wellbore: 1G-15A Design: 1 G-15A_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) (usft) (usft) (°/100ft) (°) (usft) (usft) 7,000.00 32.12 298.90 6,410.11 700.64 -1,442.99 1,328.27 0.00 0.00 5,981,648.47 538,774.29 TIP 7,033.00 31.97 298.97 6,438.08 709.11 -1,458.32 1,343.27 0.47 166.12 5,981,656.86 538,758.92 KOP 7,058.00 38.22 298.97 6,458.52 716.07 -1,470.89 1,355.58 25.00 0.00 5,981,663.75 538,746.32 End 25 dls,Start 45 dls 7,100.00 57.12 298.97 6,486.68 731.04 -1,497.93 1,382.06 45.00 0.00 5,981,678.58 538,719.20 7,128.62 70.00 298.97 6,499.40 743.43 -1,520.30 1,403.98 45.00 0.00 5,981,690.84 538,696.76 4 7,199.44 98.00 283.51 6,506.77 768.38 -1,585.18 1,458.03 45.00 -30.00 5,981,715.44 538,631.75 5 7,200.00 98.05 283.26 6,506.69 768.51 -1,585.73 1,458.41 45.00 -78.00 5,981,715.57 538,631.21 7,269.44 103.08 251.86 6,493.65 765.80 -1,653.00 1,489.70 45.00 -78.03 5,981,712.50 538,563.96 End 45 dls,Start 12 dis 7,300.00 103.24 248.10 6,486.69 755.62 -1,680.96 1,494.86 12.00 -87.00 5,981,702.17 538,536.06 7,395.00 103.40 . 236.39 6,464.73 712.65 -1,762.61 1,498.48 12.00 -87.86 5,981,658.76 538,454.65 7 7,400.00 103.41 237.00 6,463.57 709.98 -1,766.67 1,498.19 12.00 89.00 5,981,656.07 538,450.60 7,500.00 103.29 249.34 6,440.40 666.16 -1,853.31 1,503.56 12.00 89.14 5,981,611.79 538,364.20 7,520.00 103.19 251.80 6,435.82 659.68 -1,871.67 1,507.13 12.00 92.00 5,981,605.22 538,345.88 8 7,600.00 103.17 241.94 6,417.53 629.12 -1,943.20 1,516.44 12.00 -89.00 5,981,574.28 538,274.52 7,635.00 103.04 237.63 6,409.59 611.97 -1,972.65 1,516.31 12.00 -91.25 5,981,556.97 538,245.17 9 7,700.00 102.92 245.63 6,394.97 581.90 -2,028.33 1,518.11 12.00 90.00 5,981,526.61 538,189.65 7,800.00 102.26 257.91 6,373.09 551.45 -2,120.84 1,537.99 12.00 91.80 5,981,495.66 538,097.32 7,805.00 102.21 258.52 6,372.03 550.46 -2,125.62 1,539.52 12.00 94.49 5,981,494.64 538,092.54 10 7,900.00 93.40 265.84 6,359.12 537.73 -2,218.72 1,575.05 12.00 140.00 5,981,481.42 537,999.52 7,905.00 92.94 266.21 6,358.85 537.39 -2,223.70 1,577.24 12.00 141.00 5,981,481.05 537,994.55 11 8,000.00 92.88 277.63 6,354.01 540.56 -2,318.37 1,627.32 12.00 90.00 5,981,483.71 537,899.87 8,090.00 92.72 288.44 6,349.60 560.80 -2,405.81 1,688.58 12.00 90.58 5,981,503.48 537,812.33 12 8,100.00 92.57 289.63 6,349.14 564.06 -2,415.26 1,696.12 12.00 97.00 5,981,506.69 537,802.87 8,200.00 91.05 301.54 6,345.97 607.15 -2,505.24 1,778.43 12.00 97.06 5,981,549.29 537,712.67 8,290.00 89.65 312.25 6,345.42 661.11 -2,577.10 1,861.09 12.00 97.43 5,981,602.85 537,640.52 13 8,300.00 89.44 313.43 6,345.50 667.91 -2,584.44 1,870.64 12.00 100.00 5,981,609.61 537,633.15 8,400.00 87.38 325.26 6,348.28 743.60 -2,649.45 1,968.70 12.00 99.99 5,981,684.95 537,567.74 8,490.00 85.63 335.94 6,353.78 821.74 -2,693.49 2,058.39 12.00 99.66 5,981,762.84 537,523.29 14 8,500.00 85.52 337.14 6,354.55 830.89 -2,697.46 2,068.30 12.00 95.00 5,981,771.97 537,519.27 8,600.00 84.60 349.15 6,363.19 926.05 -2,726.31 2,165.14 12.00 94.91 5,981,866.97 537,489.91 8,700.00 83.91 1.19 6,373.24 1,025.01 -2,734.68 2,255.02 12.00 93.87 5,981,965.87 537,481.00 15 8,800.00 84.05 13.25 6,383.76 1,123.49 -2,722.21 2,334.07 12.00 90.00 5,982,064.40 537,492.95 8,875.00 84.32 22.29 6,391.38 1,194.46 -2,699.45 2,384.16 12.00 88.73 5,982,135.49 537,515.32 16 8,900.00 84.85 19.33 6,393.74 1,217.72 -2,690.61 2,399.89 12.00 -80.00 5,982,158.80 537,524.03 9,000.00 87.08 7.51 6,400.80 1,314.58 -2,667.52 2,472.22 12.00 -79.72 5,982,255.77 537,546.60 9,050.00 88.25 1.62 6,402.83 1,364.35 -2,663.55 2,513.34 12.00 -78.89 5,982,305.56 537,550.31 4/26/2017 1:08:21PM Page 4 COMPASS 5000.1 Build 74 • • ✓ ConocoPhillips VAIN ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1G-15 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad North Reference: True Well: 1 G-15 Survey Calculation Method: Minimum Curvature Wellbore: 1G-15A Design: 1 G-15A_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) (usft) (usft) (°/100ft) (°) (usft) (usft) 17 9,100.00 89.30 355.71 6,403.90 1,414.31 -2,664.72 2,557.18 12.00 -80.00 5,982,355.50 537,548.87 9,125.00 89.83 352.76 6,404.09 1,439.17 -2,667.23 2,579.98 12.00 -79.87 5,982,380.35 537,546.23 18 9,200.00 89.83 1.76 6,404.31 1,514.01 -2,670.81 2,646.58 12.00 90.00 5,982,455.16 537,542.24 9,300.00 89.84 13.76 6,404.59 1,612.91 -2,657.34 2,725.50 12.00 89.97 5,982,554.12 537,555.18 19 9,400.00 89.85 1.76 6,404.86 1,711.82 -2,643.87 2,804.42 12.00 -90.00 5,982,653.09 537,568.11 9,430.00 89.85 358.16 6,404.94 1,741.81 -2,643.90 2,830.40 12.00 -89.97 5,982,683.08 537,567.93 20 9,500.00 89.85 6.56 6,405.13 1,811.69 -2,641.02 2,889.48 12.00 90.00 5,982,752.97 537,570.43 9,600.00 89.86 18.56 6,405.38 1,909.12 -2,619.32 2,963.01 12.00 89.98 5,982,850.50 537,591.60 9,605.00 89.86 19.16 6,405.40 1,913.85 -2,617.71 2,966.30 12.00 89.95 5,982,855.24 537,593.19 21 9,700.00 89.86 7.76 6,405.63 2,006.09 -2,595.64 3,035.15 12.00 -90.00 5,982,947.59 537,614.77 9,800.00 89.87 355.76 6,405.87 2,105.86 -2,592.58 3,120.02 12.00 -89.97 5,983,047.37 537,617.29 9,875.00 89.88 346.76 6,406.03 2,179.91 -2,603.97 3,189.84 12.00 -89.94 5,983,121.35 537,605.50 Planned TD at 9875.00 4/26/2017 1:08:21PM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips 1l 1 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 G-15 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-15 @ 97.O0usft(Doyon 9) Site: Kuparuk 1G Pad North Reference: True Well: 1G-15 Survey Calculation Method: Minimum Curvature Wellbore: 1G-15A Design: 1 G-15A_wp05 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape , (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1G-15A_T09 0.00 0.00 6,406.00 -4,191.041,137,521.68 5,982,873.00 1,677,637.00 70°6'47.849 N 140°30'54.117 W -plan misses target center by 1138975.17usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_Faultl 0.00 0.00 6,475.00 -5,635.921,138,401.02 5,981,433.00 1,678,524.00 70°6'32.527 N 140°30'35.290 W -plan misses target center by 1139861.62usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Polygon Point 1 6,475.00 0.00 0.00 5,981,433.00 1,678,524.00 Point 2 6,475.00 1.00 1.00 5,981,434.01 1,678,524.99 1G-15A_T06 0.00 0.00 6,373.00 -5,345.471,137,391.46 5,981,718.00 1,677,513.00 70°6'36.833 N 140°31'2.821 W -plan misses target center by 1138850.51 usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_T04 0.00 0.00 6,373.00 -5,818.821,138,004.99 5,981,248.00 1,678,129.00 70°6'31.334 N 140°30'47.373 W -plan misses target center by 1139466.63usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_T03 0.00 0.00 6,440.00 -5,704.241,138,272.64 5,981,364.00 1,678,396.00 70°6'32.052 N 140°30'39.246 W -plan misses target center by 1139733.63usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_T02 0.00 0.00 6,487.00 -5,615.161,138,445.13 5,981,454.00 1,678,568.00 70°6'32.663 N 140°30'33.943 W -plan misses target center by 1139905.63usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_T08 0.00 0.00 6,405.00 -4,608.871,137,481.43 5,982,455.00 1,677,599.00 70°6'43.852 N 140°30'57.072 W -plan misses target center by 1138936.80usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_Fault2_M 0.00 0.00 0.00 -5,665.661,138,350.85 5,981,403.00 1,678,474.00 70°6'32.312 N 140°30'36.849 W -plan misses target center by 1139829.65usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Rectangle(sides W1.00 H1,000.00 D0.00) 1G-15A_Fault2 0.00 0.00 6,460.00 -5,665.661,138,350.85 5,981,403.00 1,678,474.00 70°6'32.312 N 140°30'36.849 W -plan misses target center by 1139811.63usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Polygon Point 1 6,460.00 0.00 0.00 5,981,403.00 1,678,474.00 Point2 6,460.00 1.00 1.00 5,981,404.01 1,678,474.99 1G-15A_Faultl_M 0.00 0.00 0.00 -5,635.921,138,401.02 5,981,433.00 1,678,524.00 70°6'32.527 N 140°30'35.290 W -plan misses target center by 1139879.65usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Rectangle(sides W1.00 H1,000.00 D0.00) 1G-15 CTD Polygon 0.00 0.00 0.00 -5,793.331,138,659.20 5,981,277.00 1,678,783.00 70°6'30.618 N 140°30'28.610 W -plan misses target center by 1140138.71 usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Polygon Point 1 0.00 0.00 0.00 5,981,277.00 1,678,783.00 Point2 0.00 55.78 -144.72 5,981,332.00 1,678,638.00 Point3 0.00 -101.68 -437.59 5,981,172.98 1,678,346.01 Point4 0.00 -184.40 -681.06 5,981,088.96 1,678,103.01 Point5 0.00 -176.07 -931.04 5,981,095.95 1,677,853.01 Point6 0.00 -56.69 -1,187.43 5,981,213.94 1,677,596.01 Point 7 0.00 236.57 -1,417.90 5,981,505.93 1,677,363.99 Point8 0.00 493.79 -1,454.54 5,981,762.92 1,677,325.97 Point9 0.00 1,093.44 -1,375.34 5,982,362.93 1,677,401.94 Point 10 0.00 2,131.83 -1,238.80 5,983,401.94 1,677,532.89 Point 11 0.00 2,102.20 -932.92 5,983,373.95 1,677,838.90 Point 12 0.00 935.54 -1,022.14 5,982,206.95 1,677,755.95 Point 13 0.00 328.80 -1,083.37 5,981,599.95 1,677,697.99 Point 14 0.00 122.77 -894.45 5,981,394.95 1,677,887.99 Point15 0.00 135.52 -658.35 5,981,408.97 1,678,124.00 Point 16 0.00 347.91 -164.17 5,981,623.99 1,678,616.98 4/26/2017 1:08:21PM Page 6 COMPASS 5000.1 Build 74 • . y. ConocoPhillips Ma. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1G-15 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-15 @ 97.00usft(Doyon 9) Site: Kuparuk 1G Pad North Reference: True Well: 1G-15 Survey Calculation Method: Minimum Curvature Wellbore: 1G-15A Design: 1 G-15A_wp05 Point 17 0.00 242.32 133.30 5,981,520.01 1,678,914.98 Point 18 0.00 0.00 0.00 5,981,277.00 1,678,783.00 1G-15A_T01 0.00 0.00 6,508.00 -5,607.771,138,559.19 5,981,462.00 1,678,682.00 70°6'32.567 N 140°30'30.659 W -plan misses target center by 1140019.64usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_T07 0.00 0.00 6,403.00 -5,006.81 1,137,462.29 5,982,057.00 1,677,582.00 70°6'40.017 N 140°30'59.338 W -plan misses target center by 1138919.58usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point 1G-15A_T05 0.00 0.00 6,346.00 -5,702.321,137,541.56 5,981,362.00 1,677,665.00 70°6'33.147 N 140°31'0.083 W -plan misses target center by 1139002.56usft at 7000.00usft MD(6410.11 TVD,700.64 N,-1442.99 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,875 00 6,406.03 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 7,000.00 6,410.11 700.64 -1,442.99 TIP 7,033.00 6,438.08 709.11 -1,458.32 KOP 7,058.00 6,458.52 716.07 -1,470.89 End 25 dls,Start 45 dls 7,128.62 6,499.40 743.43 -1,520.30 4 7,199.44 6,506.77 768.38 -1,585.18 5 7,269.44 6,493.65 765.80 -1,653.00 End 45 dls,Start 12 dls 7,395.00 6,464.73 712.65 -1,762.61 7 7,520.00 6,435.82 659.68 -1,871.67 8 7,635.00 6,409.59 611.97 -1,972.65 9 7,805.00 6,372.03 550.46 -2,125.62 10 7,905.00 6,358.85 537.39 -2,223.70 11 8,090.00 6,349.60 560.80 -2,405.81 12 8,290.00 6,345.42 661.11 -2,577.10 13 8,490.00 6,353.78 821.74 -2,693.49 14 8,700.00 6,373.24 1,025.01 -2,734.68 15 8,875.00 6,391.38 1,194.46 -2,699.45 16 9,050.00 6,402.83 1,364.35 -2,663.55 17 9,125.00 6,404.09 1,439.17 -2,667.23 18 9,300.00 6,404.59 1,612.91 -2,657.34 19 9,430.00 6,404.94 1,741.81 -2,643.90 20 9,605.00 6,405.40 1,913.85 -2,617.71 21 9,875.00 6,406.03 2,179.91 -2,603.97 Planned TD at 9875.00 4/26/2017 1:08:21PM Page 7 COMPASS 5000.1 Build 74 III • Baker Hughes INTEQ Hall ConocoPhiHips Travelling Cylinder ReportBA MKECR ES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 G-15 Project: Kuparuk River Unit TVD Reference: 1G-15 @ 97.00usft(Doyon 9) Reference Site: Kuparuk 1G Pad MD Reference: 1G-15 c 97.00usft(Doyon 9) Site Error: 0.00 usft North Reference: True Reference Well: 1G-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1G-15A Database: OAKEDMP2 Reference Design: 1 G-15A_wp05 Offset TVD Reference: Offset Datum Reference 1G-15A_wp05 Filter type: GLOBAL FILTER APPLIED:All welipaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,000.00 to 9,875.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,183.40 usft Error Surface: Elliptical Conic Survey Tool Program Date 4/26/2017 I i From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,000.00 1G-15(1G-15) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,000.00 9,875.00 1 G-15A_wp05(1G-15A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (1 2,200.00 2,199.80 10 3/4" 10-3/4 13-1/2 9,875.00 6,503.03 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 1G Pad 1G-06-1 G-06-1 G-06 Out of range 1G-08-1 G-08A-1G-08A 9,875.00 7,050.00 1,024.43 154.33 879.15 Pass-Major Risk 1G-08-1G-08AL1-1G-08AL1 9,875.00 7,050.00 1,023.79 154.22 878.61 Pass-Major Risk 1G-08-1G-08AL1-01-1G-08AL1-01 9,875.00 7,050.00 1,023.79 154.22 878.61 Pass-Major Risk 1G-08-1G-08AL2-1 G-08AL2 7,030.68 9,875.00 396.92 175.34 235.71 Pass-Major Risk 1G-08-1G-08AL2-02-1G-08AL2-02 7,065.28 9,800.00 321.44 166.98 167.05 Pass-Major Risk 1G-08-1 G-08AL2PB1-1 G-08AL2PB1 7,150.00 9,450.00 424.03 163.39 262.96 Pass-Major Risk 1G-13-1G-13-1G-13 Out of range 1G-15-1G-15-1G-15 7,113.55 7,100.00 29.99 4.76 28.02 Pass-Major Risk 1G-15-1G-15AL1-10-15AL1_wp04 8,024.97 8,025.00 0.93 7.35 -0.26 FAIL-Minor 1/10 1G-15-1G-15AL2-1 G-15AL2_wp01 7,925.00 7,925.00 0.40 0.76 -0.16 FAIL-Minor 1/10 1G-16-1 10-16-10-16 Out of range Plan:1G-19-1G-19-1G-19(wp02) 8,815.75 7,050.00 892.90 116.19 777.17 Pass-Major Risk Offset Design Kuparuk 1G Pad- 1G-08-1G-08A-1 G-08A Offset Site Error: 0.00 usft Survey Program: 101-FINDER-MS,4755-MWD+IFR-AK-CAZ-SC Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E1-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (') (usft) (usft) ("1 (usft) (usft) (usft) 9,841.31 6502.96 6,825.00 6,028.58 34.48 10.77 57.45 2321.02 -1,528.81 5 1,179.27 148.19 1,043.14 Pass-Major Risk 9,850.00 6,502.98 6,850.00 6,047.65 34.54 10.84 57.04 2,330.24 -1,542.07 5 1,161.21 149.63 1,023.43 Pass-Major Risk 9,850.00 8,502.98 6,875.00 6,066.75 34.54 10.91 57.71 2,339.45 -1555.31 5 1,143.30 149.73 1,005.04 Pass-Major Risk 9,850.00 6,502.98 6,900.00 6585.87 34.54 10.99 58.39 2,348.64 -1,568.54 5 1,125.67 149.83 986.92 Pass-Major Risk 9,850.00 6502.98 6,925.00 6,105.01 34.54 11.07 59.09 2,357.80 -1,581.76 5 1,108.30 149.93 969.06 Pass-Major Risk 9,859.10 6,503.00 6,950.00 6,124.22 34.61 11.14 58.74 2,368.80 -1,594.99 5 1,091.06 151.45 950.06 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/26/2017 10:37:29AM Page 2 COMPASS 5000.1 Build 74 III • • W ►r : wage by `4 a: 1 U C J.: }fl o ';^.73- O Tal- apo n - ----'''.2 a, m a,.. cif c c �, a J v` co 0 z.w.. ME _ - r J _:.:*6*/ tr = o ` rr w y WK � FQ_ - _.. w U r %' g ` o a m I 1 9_ ,-- .. r i f Jr ,01111411° ..ado ax -42',.: tit • o -`q� I .. 7 87o O 1- _ ", ��- Q O F o� �o e co fp 00 J Zi � �bqm 12 1i i116 ; 03 ozgsu — N [�] , / Y `lO L N 3 I O 0001 I edC . MN pr ®®d z>o �. 4.1.-4---q.; icy. --t-t+-i- t O, ®® o Y. Q h , 2 Y Y.-.-o1-1' _ .•_. � oy3c°O¢ °goy r 3' O. c- 9 L _ 8S6y. v U -..__.__. -} -.. -— ___ ---_ v 1 o I U _, o 09 •/_� O o O O o O O O O O O O O O O O O O O O O O V 0 y m r, O N N O O W O O O n O Tn O .- M O N N O Gl `O Q N O N(ui/gsn OSl) (+)gpoN/(-)Ipnas 0 Ucp r O 0 0 1111i • • ikaWo `w_ liii , r 0 o ,'' w-d z �g'g g �? t ! - -ern LL 000, ; 10 zzAL F, t � G - 6> _ ,til� _ G v'-�i v..ti T a o Y 0 4. o o 0 < 2 • .... bti _ of n \)0 °00,t, Y.. F + c n. LL m m E �' � T. .000 o + S a �m °a < -,mac _ ! p a y FZ <V 1 ¢ Y ... '5':'� -� .4 ._..._.. :: o°� � ODDS Y �, O ,, a r• i�' 60 _4 M a' N Jy , _ 16y _. -000 . 66 O1 } . E , .- a a, —tc _ _ - — - - _. o .r _ � V. � vi m Ts Q O .n a \ o U' U •¢ -o -- U00 -„ _ e. - --- " �\ --. r $$q Ssy d ZrgiA 7 3 U'0--. ,`,. i' ," ' 0009 5 \ �` o a. 3c� a 4 '�° ° x oohs. g' '�' - o Y c a '+ :000 \CI a —✓H d a 0._ _ de F, o- >I a 0 0 0 o 0 0 o O o 0 0 o o o 0 0 O O 0 0 ! b o 2 'co I S 6 . 606 .0 0 0 0 0 0 0 o .'o aia r r b b h Cl, K M 03 rn N N .. b N 'I ,tV O (u!pjsn occ) (+) poN/(-)u1nog } } - o' Y o u - ' 0 th— KUP PROD • 1G-15 . EiribiIlk ConocoPhillips " e Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Held Name Wellbore Status ncl(0 MD(ftKB) Act Btm(ftKB) C,,,,, ut,ul„, 500292102400 KUPARUK RIVER UNIT PROD 38.12 5,325.00 7,533.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 1G-15,10/26/20141,14:05 PM SSSV:NIPPLE 380 8/14/2012 Last WO: 7/7/2004 41.00 10/29/1983 - Vertical schematic(actual) -- Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ---------------------- -- -------Last Tag:SLM 7,166.0 10/25/2014 Rev Reason:TAG,SET PLUG,DUMP BAIL hipshkf 10/26/2014 HANGER;312 W 9 SAND ON PLUG _ Casing Strings [ r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1.Grade Top Thread CONDUCTOR 16 15.060 36.0 114.0 114.0 63.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread ,.•'„" ' ' ' '. gnat 10 3/4 9.950 36.5 2,202.3 2,202.1 40.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ti��_ 1:SURFACE PRODUCTION 7 6.276 342 7,502.2 6,934.4 26.00 J-55 BTC CONDUCTOR;36.0-114.0 Tubing Strings NIPPLE;496.4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)I...Wt(I blft) Grade Top Connection TUBING 41/2 3.958 31.3 6,543.9 6.113.7 12.60 L-80 IBT-MOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(^) Item Des Com (in) 31.3 31.3 0.00 HANGER MCEVOY TUBING HANGER 3.958 SURFACE,36.5.2,202.3 496.4 496.4 0.58 NIPPLE CAMCO DB-8 LANDING NIPPLE 3.813 5,671.1 5,384.0 35.56 PACKER BAKER PREMIER PACKER 3.875 GAS LIFT;2,585.9_ .- 5,683.8 5,3942 35.56 NIPPLE CAMCO DB NIPPLE 3.750 6,523.5 6,096.2 30.68 XO Reducing CROSSSOVER 4.5 x 3.5 3.500 E-- 6,532.2 6,103.7'• 30.61'SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 GAS LIFT;3822.8 ag,, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 1998 31/2 2.992 6,542.0 6,637.3 6,194.2 9.30 L-80 EUEBRMOD Completion Details Nominal ID GAS LIFT,4,905.7 1Ell Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Corn (in) 6,542.0 6,112.1 30.51 PBR BAKER 80-40 PBR 2.813 6,558.4 6,1262 30.39 PACKER BAKER FHL RETRIEVABLE PACKER 2.969 6,597.1 6,159.6 30.55 NIPPLE OTIS X LANDING NIPPLE SELECTIVE PROFILE(SET 2.813 GAS LIFT;5,817.4 1118/10/99) -- 6,630.1 6,188.0 30.61 OVERSHOT- OVERSHOT,NO SEALS,MAX OD 5.99"SET 8/10/1998 2.930 141 PACKER;5,671.1 Tubing Description String Ma...ID(in) Top(060) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 1984 41/2 2.867 6,629.9 7.115.7 6,603.2 9.30 2-55 FI4S NIPPLE;5.683.8 'LA Completion Details Nominal ID - •- Top(ftKB) Top(ND)(ftKB) Top Incl('1 Item Des Com (In) GAS LIFT;5,726.6+,'. . 6,643.7 6,199.7 30.56 SBR OTIS SBR 2/2.813 X-PROFILE SET 8/10/1998 2.813 6,669.9 6,222.3' 30.64'PACKER OTIS RRH PACKER 2.970 6,815.7 6,347.8' 30.67'BLAST RINGS CARBIDE BLAST RINGS(3) 2.867 46 ---' 6,928.0 6,443.9' 31.65'BLAST RINGS CARBIDE BLAST RINGS(3) 2.867 SEAL ASSY;6,532.2 7,084.0 6,576.3 31.75 LOCATOR OTIS LOCATOR 3.000 PBR;6,542.0 OM A 7,085.5 6,577.6 31.74'PACKER OTIS WD PACKER 4.000 PACKER,6,558.4 �■I 7,089.1 6,580.6' 31.73 MILL EXT OTIS MILL OUT EXTENSION 4.410 NIPPLE;6,5571R_ 7,105.2 6,594.3 31.65 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,114.8 6,602.5 31.59 WLEG OTIS WIRELINE RE-ENTRY GUIDE,ELMD TTL @ 7111 3.000 OVERSHOT 6 630 1, t. during PPROF on 3/9/2006 TUBING,6,629.9 SBR;8,643.7 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PACKER;6,669.9 Top(ND) Top Incl Top(ftKB) (ftKB) (7 Des Com Run Date ID(in) �, _11 7,095.2 6,585.8 31.70 SAND DUMP BAILED 10'OF SAND ON PLUG 10/25/2014 0.000 PRODUCTION;6,707.5 _ - 7,105.2 6,594.3 31.65'PLUG 2.75"CA-2 PLUG 10/25/2014 0.000 PRODUCTION;6,777.1 Ile 7,510.0 6.941.1 30.92 FISH DROPPED 1"HFCV,BEK LATCH TO BOTTOM 1/14/2009 0.000 UM Perforations&Slots IPERF;6.834.0-6,838.0- Shot Dens IPERF;6.843.0E,880.0� Top(ND) Rho(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date II Type Com 6,834.0 6,838.0 6,363.5 6,367.0 C-4,1G-15 1/31/1984 12.0 IPERF 120 deg Phasing;5"DA IPERF;6.890.06,895.0- _ 6,843.0 6,880.0 6,371.3 6,402.9 C-4,1G-15 1/31/1984 12.0 IPERF 120 deg Phasing;5"DA III 6,890.0 6,895.0' 6,411.5 6,415.7 C-3,1G-15 1/31/1984 12.0 IPERF 120 deg Phasing;5"DA 6,954.0 7,007.0 6,466.0 6,510.9 C-1,1G-15 1/31/1984 12.0 IPERF 120 deg Phasing;5"DA IPERF;6.9540-7,007.0- _- 7,193.0 7,230.0' 6,669.3 6,701.0 A-5,A-4,A-3, '5/23/1984 8.0 APERF 90 deg Phasing;2 1/16" 1G-15 RigidJet a_ Mandrel Inserts St i PRODUCTION;7.045.3 ati on Top(TVD) Valve Latch Port Size TRO Run LOCATOR;7,084.0 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 10 1' 2,585.9 2,585.7 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,260.0 5/3/2008 PACKER;7,085.5 2 3,822.8 3,821.6 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 5/3/2008 MILL EXT;7,089.1 ` /` 3 4,908.7 4,777.2 CAMCO 'KBG-2 1 GAS LIFT DMY BK-3 0.000 0.0 7/7/2004 4 5,617.4 5,340.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 7/13/2004 SAND;7.095.2, NIPPLE;7,11052 5 5,726.6 5,429.1 CAMCO KBG-2 1 GAS LIFT DMY BK-3 0.000 0.0 7/7/2004 PLUG;7,1052, ////, 6 6,707.5 6,254.6 OTIS SPM 1 PROD HFCV BEK 0.000 0.0 3/26/2014 u 7 6,777.1 6,314.5 OTIS SPM 1 PROD HFCV BEK 0.000 0.0 3/25/2014 WLEG;7,114.8 -i 8 7,045.3 6,543.4 OTIS SPM 1 PROD HFCV BRK 0.000 0.0 3/24/2014 Notes:General&Safety APERF;7,193.0-7,230.0- - End Date Annotation 3/10/1998 NOTE:Ran KINLEY Caliper Log from 6444'RKB to Surface on 3/10/98 11/8/1998 NOTE:ORIGINAL COMPLETION BELOW 6630' I 7/7/2004 'NOTE:EXISTING COMPLETION PLUS ORIGINAL COMPLETION,BELOW 6542' 7/7/2004 "NOTE:TREE: McEVOY/GEN 1 RETROFITTED TO CAMERON GEN 4 PRODUCTION;34.2-7.502.2- - 9/21/2010 'NOTE:Mandrels @ 6707-7045-MACCO SLOTTED DPHF FISH;7,510.0 KUP PROD • 1G-15 ConocoPhillips Alaska.Inc. ,...-711, 1G-15 10/2620141:14:06 PM Vertical schematic(actual) HANGER.31.2 AllilUillr Notes:General&Safety ] l End Date Annotation !f 9/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 .3/24/2014 NOTE:BROKEN LATCH AT 7045 RKB _ II CONDUCTOR;36.0-114.0—a. NIPPLE;496.4 _ SURFACE,36.9-2.202.3—. T 1 GAS LIFT;2585.9 GAS LIFT;3,822.8 GAS LIFT;4,908.7 GAS LIFT;5,617.4 PACKER;5.671.1 NIPPLE;5,683.8 GAS LIFT:5,726.6 SEAL ASSY;6,532.2 PBR;6,542.0 PACKER;6,558.4 III NIPPLE;6,597.1 amt.- OVERSHOT' OVERSHOT;6,630.1- = 111 TUBING;6,629.9 SBR;6,643.7 l PACKER;6,669.9 PRODUCTION;6,707.5 IC in PRODUCTION;6,777.1 IE MI IPERF,6,834.0.6,838.0 (PERF;6,8430-6,880.0 (PERF;6,890.0.6,895.0 - i IPERF;6,954.0-7,007.0- 1 PRODUCTION;7,045.3 LOCATOR;7,084.0 PACKER;7,0855 MILL EXT;7,089.1 /7 SAND;7.095.2, NIPPLE;7,105.2 PLUG;7.105.2 it WLEG;7.114.8 ILO APERF;7,193.0-7.230.0 1 PRODUCTION;34.247,502.2 FISH;7510.0-4 • • L 0 0 zoo o22 O O o rn J O N.g c?o m L a z❑2 �2o ono a 3�m ❑ Q° U3 � ❑ m �om LI-) 0 0 N _ Z O r O v -c a2 dU c_ a E cro 'Nt 30 Nira CO CO Cs) r E ��� n e o v = io m _ o. O Co _ in co a • O 0 0 a 0 X co x o a o Q -1-� N N- rn ❑ _M D @L© o o \li co a rn :n m - p 0 M tn moa) a co m c❑ cuV a 'O `n g C cD N N 0 c.- c co_ cu co =o n co w E n E g v� 2a --p CO 3 CO cow m — /ec/�o� F2 0.' c a) c oo c ��N-` o .a W 4 U .— 5_ VJd co O 2 r O N O r 2 t.v CO O ca m 2 a) O V O N 0 a m rn a ❑ m x m Udco 3o )J 0 .6- a vw 00to a co m 2 12 2 - w It • 0 0 v Od �Ud @� n? a m= o �a� 0 co 0 E E E '�� n ©a) 2O V a E E- v It m 2 m m a) d= aY -� O cu- 3 U U a U U o co o_ Z2 mm OF_O ❑= Un 00 N V (V ,di (V NNs N N N NaN NN(~j(V v v v m v v U mm OO OO c;)mr') 00 c), . vi ''''''N':--1 I \\IL \\\:\\. \ r r::::',,,...',...c.1"." , p��n - �'l l' "fin r a<t k?•J t,'a' ��'a s' 1111 i:iu iirYi . ,� 1SN� C.) CZ L 7ri d 0 I a ❑ a N0-000❑ -2 rn U s 'tc�)mrno o _. - yo n °cc)cco c N 'C M o v c- r Q. ❑ oir�ivrnu�i Y 3U It m aD CO 2 c ch C a) _2 a- 000OCD CD COO N O N N V N •Q r r w r co NN` th g OT V • • Bettis, Patricia K (DOA) From: Long, William R <William.R.Long@conocophillips.com> Sent: Monday, May 1, 2017 4:07 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1G-15A: Permit to Drill Application (PTD 217-065) Good afternoon Patricia, The correct number for maximum potential pressure downhole in 1G-15A is 3716 psig. (Form 10-401, Box 17 for 1G- 15A,AL1, &AL2) The reason for the discrepancy between the pressure on page 2 of the Application for Permit to Drill Document and the form 10-401 is the difference in TVD between the planned well and the depth the pressure was recorded at in the offset well. Please let me know if there is any additional information I can provide. Thanks, William R. Long Sr CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000(cell) William.R.Long@ConocoPhillips.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, May 01, 2017 3:03 PM To: Long, William R<William.R.Long@conocophillips.com> Subject: [EXTERNAL]KRU 1G-15A: Permit to Drill Application (PTD 217-065) Good afternoon William, On Form 10-407, Box 17, it states that the maximum downhole pressure is 3716 psi. On page 2 of the Application for Permit to Drill Document, it states that the maximum formation pressure in the KRU 1G-15 vicinity is the 1G-04 at 3589 psi. For Form 10-407, Box 17, what is the correct number for the maximum dowhole pressure? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 1 • 333 West 7th Ave.,Ste 100 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. 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: K Rt... I G - SA- PTD: Al - OGS- v Development Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: bfer POOL: gya4rtix kVEt!') /L w ,i1/tAr 8, 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 N m 0 , a) a p o E co, E. : > o p o. Z; c , ; E CU O ., V o v. N. o. , , @, W• U Oc • r ': a p 0O ° �, co 0 w, c E O aa) a o , , , , a ci co N. w„ .coco rn o E. 2o. L 0. S 3 " E0>: �. o. m. 3. aa) .3: 0 a o3. N. a _: c co �: o w N, o , ; , v. 3. o ;N . a o E a 71 .o. _ ° o, 0) o a 1- ; O, . a E •0 a E. o _ li , Y w CO o; ; (5' 8: E P; 5, ao m, °CD N, crI Vii; p, c. a co. �, T °. ° M. a. N, Y 'v. co a Q; CO m �' te' o, m' n. E y, 2, N. fl. 3 m, a s w r Y; 3 m �, �: 2 a 3. Y c �; �, �; c ° a 3. 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