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215-139
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Oil 0 Gas SPLUG❑ Other 0 Abandoned 0 Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q + Exploratory 0 GINJ 0 WINJ❑ WAG❑ WDSPL 0 No.of Completions: Service 0 Stratigraphic Test 0 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: •9/22/2015 -215-139 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360,Anchorage,AK 99501 •8/30/2015 •50-029-21009-60 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 268'FSL,818'FWL,Sec.29,T12N,R10E,UM • 9/4//2015 •KRU 1G-12L1 Top of Productive Interval: 9.KB(ft above MSL): 99' 17. Field/Pool(s): 3981'FNL, 1112'FEL,Sec.32,T12N,R10E, UM GL(ft above MSL): 63' Kuparuk River Field/Kuparuk River Oil Poo Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3400'FSL,4738'FWL,Sec.32,T12N,T10E, UM 11311'MD/6627'TVD ADL 25640 ^ 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 540599 y- 5980918 Zone- 4 •11360'MD/6701'TVD 2571 TPI: x- 543986 y- 5976687 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 544537 y- 5978792 Zone- 4 no SSSV 1500'MD/1442'TVD 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑ 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) 8772'MD/6582'TVD 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit ail 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 Ci Li 23 2015 AOGCC, 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 65# H-40 38' 100' 38' 100' 20" 212 sx CS II 10.75" 45.5# J-55 37' 2550' 37' 2302' 13.5" 1010 sx AS III,250 sx AS I 7" 26# J-55 32' 9096' 32' 6821' 8.5" 975 sx Class G,250 sx AS I 2.375" 4.6# L-80 8765' 11311' 6578' 6696' 3" slotted liner 24.Open to production or injection? Yes El No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5"&5.5" 8610'and 8796' 8257'MD/6201'TVD, slotted liner from 8766-11311'MD/6578'-6696'TVD 8472'MD/6362'TVD,8603'MD/6459'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes 0 No 0 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 9/29/2015 gas lift oil Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 10/11/2015 12 hours Test Period �►681 1393 20 176 Bean 1193 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 1Q1 157 24-Hour Rate - 1292 1541 40 23 deg. q g Form 10-407 Revised 5/2015 V7-1- //2 4,/i 6. CONTINUED ON PAGE 2 RBDMNOV 0 5 2015 Submit ORIGINIAL onIG OJZ// _‘6 TI411)F7 28.CORE DATA Conventional Ce): Yes ❑ No Q Sidewall Cores.s ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1500' 1442' Attach separate pages to this form, if needed,and submit detailed test information,including reports,per 20 AAC 25.071. Kuparuk B1 8780' 6589' Kuparuk A6 8796' 6600' Kuparuk A5 8812' 6609' Kuparuk A4 8837' 6622' none Formation at total depth: Kuparuk A4 31. List of Attachments: Daily Operations Summary,schematic,definitive survey Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. (2,C)(� Contact: Ron Phillips Email: Ron.L.Phillips.cop.com Printed Name: Dan Venhaus Title: CTD Engineering Supervisor Signature: .4Phone: 263-4372 Date: /0-2 I —IS 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 lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only KUP PROD 1GT-12L1 ✓ a Conor IiIIips Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) »e+rinpc. 500292100960 KUPARUK RIVER UNIT PROD 95.57 11,040.16 11,311.0 .,. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-12L1,10/1/20154:31:47 PM SSSV:NONE 90 12/16/2013 Last WO: 40.99 10/2/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,31 3 Last Tag:SLM 8,831.0 7/25/2015 Rev Reason:ADD LATERALS L1&L1-01(both smsmith 10/1/2015 HANGER i AI'` 1 off main wellbore) Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L1 LINER 2 3/8 1.992 8,765.5 11 311.0 6,696.2 4.60 L-80 ST-L `' Liner Details Nominal ID m0K Top(ftKB) Top(005)(ftKB) Top Incl(°) Item Des Com (7n) 8,765.5 6578.0 43.16 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 -A-MCONDUCTOR 38.0-7500•' Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SURFACE;37.2-2,550.0- e 8,766.4 11,310.6 6.578.6 6.696.2 9/5/2015 SLOTS Slotted Liner Notes:General&Safety GAS LIFT;2,842.6 End Date Annotation NOTE • GAS LIFT;4,681.5 GAS LIFT;5,973.7 GAS LIFT;6,922.1 GAS LIFT;7,624.0 I in GAS LIFT;8,170.2 LOCATOR;8,226.9 SEAL ASSY;8,227.2 PBR;8,234.3 PACKER;8,257.3 • NIPPLE;8,309.8 are GAS LIFT;8,3622 BLAST JOINT;8,382.2 IPERF;8,385.0-8,458.0-\ BLAST JOINT;8,402.9 PACKER;8.472.1 NIPPLE;8,496.3 GAS LIFT;8,513.9 MB BLAST JOINT;8,533.6 T IPERF;8,537.0-8,589.0 . BLAST JOINT;8,553.3 LOCATOR;8,802.8 �F+' PACKER;8,803.3-, r :-_, SEAL ASSY;8,803.6 SBE;8,608.6 ^. NIPPLE;8,625.9 WEAR SOCK;8,889.1 Il . I WHIPSTOCK;8,738.o II II SLOTS;8,728.8-11,240.0 � ,I L1-01 WINDOW;8,743.0- I :�,I 8,748.0 PRODUCTION;32.1-9,096.4 I I II L1-01 LINER;8,728.6-11,240.0 - - SLOTS;8,768.4-11,310.8 LI LINER;8,765.5-11,311.0 KUP PROD • 1G-12 ConocoPhillips a ' Well Attributes Max Angle&MD TD AlaiK:<: m.:. Wellbore API/UWI Field Name Wellbore Statusncl 7) MD(0KB) Act Btm(ftKB) r�n000waeipr 500292100900 KUPARUK RIVER UNIT PROD j 54.10 3,500.00 9,116.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-12,10/1/20154:32:21 PM SSSV:NONE 90 12/16/2013 Last WO: 2/25/2015 40.99 10/2/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,31 3 �..- <� Last Tag'SLM 8,831.0 7/25/2015 Rev Reason:ADD LATERALS L1&L1-01(both smsmith 10/1/2015 off main wellbore) 14 :,to Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 38.0 100.0 100.0 65.00 H-40 WELDED I, (.. Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Lan(1...Grade Top Thread :,,,. SURFACE 10 3/4 9.950 37.2 2,550.0 2,302.1 45.50 J-55 BTC ` + Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)..Wt/Len(I...Grade Top Thread aati II' L1-01 WINDOW 7 6.276 8,743.0 8,748.0 6,565.3 .AN CONDUCTOR;38.0-100.0"' Casing Description OD(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L1 WINDOW 7 6.276 8,778.0 8,783.0 6,591.0 Casing Description OD(in) ID(in) Tap(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.1 9,096.4 6,821.2 26.00 J-55 BTC SURFACE;37.2-2550.0- Tubing Strings Tubing Description !String Ma...ID(in) Top(ftKB) Sat Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection GAB LIFT;2,842.8 � � TUBING WO-Upper Itri31/21 2.9921 31.21 8,610.01 6,463.81 9.301 L-80 I EUE-Mod 1 I Completion Details Nominal ID Top(ftKB) lop(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;4,861.5 I 31.2 31.2 0.17 HANGER McEVOY TUBING HANGER 2.950 6,226.9 6,178.0 40.78 LOCATOR LOCATOR 2.990 8,227.3 6,178.3 40.78 SEAL ASSY BAKER 80-40 PBR SEAL ASSEMBLY 2.990 GAS LIFT;5273.7 8,234.3 6,183.6 40.79 PBR BAKER 80-40 PBR 4.000 8,257.3 6,201.0 40.83 PACKER BAKER FHL RETRIEVABLE PACKER 2.910 8,309.8 6,240.7 41.02 NIPPLE X NIPPLE 2.812 GAS LIFT;6,922.1 8,382.2 6,294.9 41.89 BLAST JOINT Blast Joint 3 1/2"EUE Mod XO Joint EUE Box x TCII Pin 2.992 it8,402.9 6,310.3 42.10 BLAST JOINT Blast Joint 31/2"EUE Mod TCI(Threads 2.992 GAS LIFT;7,624.0 II 8,472.1 6,361.7 42.01 PACKER BAKER FHL RETRIEVABLE PACKER 1920 lb 6,496.3 6,379.7 41.98 NIPPLE X NIPPLE 2.812 GAS LIFT;8,1702II 8,533.6 6,407.3 42.24 BLAST JOINT BLAST JOINT XO JOINT(EUE BOX x TCII PIN) 2.992 8,553.3_ 6,421.9 42.35 BLAST JOINT BLAST JOINT TCII THREADS 2.992 8,602.8 6,458.5 42.60 LOCATOR LOCATOR 3.000 IllE LOCATOR;8,226.9 6,459.1 42.60 SEAL ASSY BAKER SEAL ASSEMBLY GBH-22,80-40 2.980 SEAL ASSY;8,227.2 -�-"' PBR;8234.3 Tubing Description I String Me...I ID(in) (Top(ftKB) (Set Depth(ft..1 Set Depth(TVD)(...I Wt(Ibkt) (Grade (Tap Connection PACKER;8,257.3 TUBING WO-Lower 51/2 4.950 8,6033 8,7960 6,600.5 14.00 H-40 STC Completion Details I 111 gialli Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Intl(") Item Des Com (In) NIPPLE;6,309.8 8,603.3 6,458.8 42.60 PACKER BAKER FB-1 PERMANENT PACKER 5.380 IIII 8,606.6 6,461.3 42.60 SBE 80-40 SEAL BORE EXTENSION 4.000 rS 6,611.0 6,464.5 42.61 XO Reducing Crossover sub 475 Stub Acme x 3-12"EUE 2.950 GAS LIFT;8,382.2 8,625.9 6,475.4 42.61 NIPPLE X NIPPLE 2.812 BLAST JOINT;9,382.21 8,668.3 6,506.7 42.63 XO Enlarging BerCrossover 3 1/2"EUE Box x51/2"STC Pin 4.500 11(PERF;9,385.0-8,458.0 Ported) BLAST JOINT;8,402.0 8,669.1 6,507.3 42.63 WEAR SOCK WEARSOCK JOINT 4.950 8,795.5 6,600.2 42.75 BEVELED BEVELED SHOE 4.500 PACKER;8,472.1 - SHOE in NIPPLE;0.49sa_ 'a Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;8,513.9 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,738.0 6,557.9 42.69 WHIPSTOCK 3 1/2"X 5 1/2"Baker Gen II whipstock,TOWS 8,738- 9/5/2015 3.500 ft,3°LOHS,RA tags at 8,745.35-5,BOWS 8,751-ft BLAST JOINT;8,533.8 (PERF:9,537.0-8.509.0 8,770.0 6,581.4 42.72 WHIPSTOCK 3.5"x 5.5"BAKER WHIPSTOCK,ORIENTATION 3 7/28/2015 3.500 BLAST JOINT;8,553.3 r I DEG LOHS.RA TAGS @ 8777.35'.TOP @ 8770, BOTTOM @ 8785' Perforations&Slots LOCATOR;6,602.8 Shot 1i.1. Dens PACKER;8,803.3-, Top(TVD) Btu.(TVD) (shots/f i SEAL ASSY;8,603.6 N.7±-.). Top(ftKB) etm(ftKB) (ftKB) (kKB) Zane Date t) Type , Com SBE:8,6066 •=, 8,385.0 8,458.0 6,297.0 6,351.3 C-4,C-3,1G- 12/25/1983 12.0 (PERF 5"DA Pert Gun,120 deg 12 pH M. 8,537.0 8,589.0 6,409.9 6,448.3 C-1,UNIT B, 12/25/1983 12.0 IPERF 5"DA Peri Gun,120 deg NIPPLE;8,625.9 1G-12 pH 8,812.0 8,830.0 6,612.3 6,625.5 A-5,A-4,1G- 6/23/1984 4.0 APERF 21/8"RigidJet,90 deg. IR 12 pH 8,830.0 8,850.0 6,625.5 6,640.2 A-4,1G-12 8/13/1993 4.0 APERF 2.5"Titan HC,180 deg I iE pH;27 deg.CCW WEAR SOCK;8,889.1 I 8,850.0 8,864.0 6,640.2 6,650.4 A-4,1G-12 6/23/1984 4.0 APERF 2 1/8"RigidJet,90 deg. WHIPSTOCK;9,739.01I pH L1-01 WINDOW;8,743.0- I 8,748.0 ( Mandrel Inserts ' WHIPSTOCK 8,770.0 all LI WINDOW;6,778.OA,763A - I N (I Top(TVD) Valve Latch PoSize TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Cam I 1 � 1 2,842.6 2,504.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,244.0 9/25/2015 BEVELED SHOE;8,795.5 3 2 4,681.5 3,693.9 CAMCO MMG 11/2 GAS LIFT GLV RK - 0.188 1,250.0 9/25/2015 3 5,973.7 4,588.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,251.0 9/252015 APERF;8,912.0.9,830.0 4 6,922.2 5,235.6 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 9/252015 APERF;8,830.0-8,850.0- 5 7,624.0 5,736.3 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/14/2015 6 8,170.2 6,135.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 9/24/2015 APERF;8,850.0.8,864.0 7 8,362.2 6,280.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 7/21/2015 8 8,513.9 6,392.8 CAMCO MMG 1 1/2 GAS LIFT DMY 'RK 0.000 0.0 3/14/2015 Notes:General&Safety End Date Annotation PRODUCTION;32.1-9,096.4-__ 12/30/2003 NOTE WAIVERED WELL: IA x OA ANNULAR COMMUNICATION SLOTS;8,728.6-11,240.0-- L1-01 LINER;8,728.6-11,240.0 '- KUP PROD • 1G-12 ConocoPhiHIps le4t Alaska,mi.:, COnMORtYN11JS 15-12,10/1/20154:32:23 PM Pert:cal schematic tactual) HANGER, ._.........._....._......._. .. HANGEERR ;31.J /< I'•j Notes:General&Safety End Date Annotation 9/17/2010 NOTE View Schematic w/Alaska Schematic9 0 vann IIL„_. In For .A.A./CONDUCTOR;38.0-100.0• I'l': SURFACE;37.2-2,550.0- GAS LIFT;2,842.6 GAS LIFT;4,681.5 GAS LIFT;5,973.7 GAS LIFT;6,922.1 GAS LIFT;7,624.0 GAS LIFT;8,170.2 LOCATOR;8226.9 dIJNIF SEAL ASSY,8,227.2 PBR;8,234.3 PACKER;8,267.3 r' I is NIPPLE,8,309.8 GAS LIFT;8,362.2 BLAST JOINT;8,382.2.- I IPERF;8,385.0-8,458.0 L BLAST JOINT;8,402.9 PACKER;8,472.1 ' IOW NIPPLE;8,496.3 GAS LIFT;8,513.9 BLAST JOINT;8,533.6 - IPERF;8,537.0-8,589.0-\ I at BLAST JOINT;8,553.3 s LOCATOR;8,602.8 + t. PACKER;8,803.3 SEAL ASSY;8,803.8 t- SBE;8,606.6 42. NIPPLE;8,625.9 tri WEAR SOCK;8,669.1 WHIPSTOCK 8,738.0 I L1-01 WINDOW;8,743.0- I 8,770.0 I11 WHIPSTOCK;8,770.0 L1 WINDOW;8,778.0-8,783.0 I I.' BEVELEDSHOE;8,795.5 APERF;8,812.0-8,830.0 APERF;8,830.0-8,B50.0� APERF;8,850.0-8,864.0 PRODUCTION;32.1-9,096.4, SLOTS;8,728.6-11,240.0 L1-01 LINER;8,728.6-11,240.0 ! • N N 0) co ;4- r- CD I\0) a co a - (a V' N V 2 M O )p M m N c) V 03 03 (0 No co N _ E (0 O m a L(1 a) 0 c N a c N co 0 0 a u) u o_ E a - E 0 oo c m N O N _ cV [7 N E V _E to O V v 0, L m m E E w0 N o N- d) (]� N, O O ¢ a0 �(] C l..) ~ �. 7 N 0 7-1 7 �O CO 'Ll. "2 — �Ln - -0 n 2 a 7, an N NN p O Np 2 om 0 3� a W m a)O a - a) a o,---c - m O O) D 0 lO N c0 0 N ,t O N J U) W %I N cG N 2 0f c) (0 m m m 0 m ,._ m a) Ch O-c•-c) 00 oa a o a a o o a a I-N M (m YJ •E E J .2 E o— 1 I 0) 0.6 mu_ X 0 u. X 0 J m X 1 I N 01,/ N W N N N N N c) N N I I NYY Y Y Y I 01 c1 7 `- (0 00 (0 71 M Mi cam 07 a7 m m C) m m co 1 a I I I II a aoco b 11 Iao ao I 1 a)m iii iiii 11 co a a a 11 m N I O Y 11 y ro I 1 Q ao 11 /� /1 _ . Lr ' J - u a<< r., .� „i. ti e ,),,,,, , i;" IIS ' !I f `; , ,,,a Ill I PI !.1! o I__ 0 \ co 0 11 II b,; N� v \\1 11 I1-� 't- . N 11 1 CI �uoi a� am \II \\ // It CD N "0 'c a0 02 11 �_��co C ,pd.p d.� min mr` X00 11 F.,...@.) m p II w m 1L © -c-'.)- Um '/3ro 00 nm0.0 o 11 N (r) 0) n co-—(o f i ✓' o // II - 0 CO Noc 0 0 c ,n— !f ✓ j-2 N (0 / a J=0 O ON 0-0 Y J (n N U N v �'N L aI 0 j 0 m c .-I-NQa 0 0 • Daily Operations Summary • &Wells 1G-12 ConocoPhinips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Daily Operations Start Date Last 24hr Sum 8/28/2015 RDMO from 1G-11.MIRU on 1G-12.Begin initial BOP test. Rig accepted at 21:00 on 8/28/15 8/29/2015 BOP test completed.All pressure tests complete. Repair external hydraulic leaks to BOP lower blind bonnet. Retest repairs,good. MU BHA#1. RIH. Encountered heavy returns of degradeable plug from 6,500-ft.Circuate out plug material. 8/30/2015 Circulate out plug material. Mill window TOW at 8,776.3-ft to BOW at 8,782-ft. Drilled rathole to 8,796-ft.Window back reamed and drifted clean. POOH.RIH. Drilled build section from 8,796-ft to 8,818-ft.Drilling in progress. 8/31/2015 Drill build section from 8,818-ft to 9,150-ft. POOH. RIH with BHA#3. Drill L1 lateral from 9,150-ft to 9,484-ft. Drilling in progress. 9/1/2015 Drill L1 lateral from 9,484 ft to 10,506 ft. 9/2/2015 Drill L1 lateral from 10,506 ft to 10,957 ft 9/3/2015 Drill L1 lateral from 10,957 ft to 11,239 ft 9/4/2015 Drill L1 lateral from 11,239 ft to 11,360 ft.perform swab wiper,Confirm TD 11,360 ft,displace well to 11.4 ppg competion fluid,check well for flow, LD drilling BHA#3 9/5/2015 MU BHA#4 L1 liner assembly with 82 jts of slotted liner,and shorty deployment sleeve, RIH,release from liner at 11,311 ft,TOL 8,765.5 ft, POOH, PU/MU WS BHA#5, RIH set TOWS at 8,738 ft, POOH, PU/MU BHA#6, RIH,tie into the K1 correction of minus 3.0 ft, Start displaceing well to drilling fluid. 9/6/2015 Mill Window from 8,743.4 ft to 8,749 ft,TOWS 8,738 ft, POOH, Drill rate hole down to 8,763 ft, PU/MU Build BHA#7, RIH,tie into the K1 correction of minus 3.0 ft, 9/7/2015 Drilled build section from 8,763 ft to 8,996 ft, POOH,undeploy/LD build BHA#7, PU/MU/Deploy lateral BHA#8, RIH,drill L1-01 lateral from 8,996 ft to 9,107 ft. USR failed, POOH,undeploy Lateral BHA#8, PU/MU/Deploy Lateral BHA#9 9/8/2015 Drilled the Lateral section from 9,107 ft to 9,638 ft, POOH to inspect lateral drilling BHA#9, Found bit to be balled up with 3 chipped cutters, PU new bi-center bit and new motor, MU and deploy BHA#10, RIH 9/9/2015 Drilled the Lateral section from 9,638 ft to 10,133 ft. 9/10/2015 Drilled the L1-01 Lateral section from 10,133 ft to 10,655 ft. Drilling up through the lower A3 silt at 10-30 fph, pumping sweeps and jetting 5 1/2 tail pipe. 9/11/2015 Drilled the L1-01 lateral section from 10655 ft to 10677 ft, Performed wiper up into the tubing due to annular pressure spikes on bottom drilling, temporarily detained at the 3.5"x5.5",free pipe, pull wiper up to 6000 ft chasing 5x5 sweeps, RBIH,stacked out 8804 ft, POOH, PU/MU clean out BHA with D331, RIH and cleaned out down to 10677 ft,lower pump rate to 0.75 bpm to pass thru to current TD, Perform swab wiper to clean hole, RBIH to 9000 ft, displaced well to 11.8 ppg completion fluid in preparation of bi-weekly BOPE test while POOH, LD Cleanout BHA 9/12/2015 Finished LD cleanout BHA, perform rigs bi-weekly BOPE test, PU/MU drilling BHA#12 with 3.0"inch bi-center bit and aggitator. RIH and drill from 10677 ft to 10879 ft. 9/13/2015 Drilled the L1-01 lateral section from 10879 ft to 11460 ft with wipers every 200 ft,up into the casing,jetting 5.5"big tail pipe, became stuck on wiper from 11460 ft at 10022 ft,worked pipe,maintaining annular with test pump 9/14/2015 Stuck coil,working pipe at 10019 ft,pull max on coil 82k, BHA#12 parted at the HOT,leaving TOF @ 10004.51 ft, pump sweeps, POOH, LD damaged drilling BHA,PU/MU/Deploy open hole anchored billet,set down at 8800 ft, POOH for cleanout BHA. 9/15/2015 LD OH anchored billet. Make clean-out run with D331 mill to 9,930'. Rerun OH anchored billet to 9,911,set billet.POOH for kick-off assembly. PUD BHA#15, PD BHA#16.RIH w/KO assembly,dry tag billet,start kick-off,in progress. 9/16/2015 Kick-off OH anchored billet @ 9,901,dry drift clean. Drill ahead build section to called TD @ 10,260'. POOH for drilling assembly, PUD BHA#16, PD BHA#17. RIH w/drilling assembly,drill ahead L1-01 lateral from 10,260'to 10,460',drilling in progress. 9/17/2015 Drill ahead L1-01 lateral from 10,460'to10,496'. POOH due to high differential pressure. PUD BHA#17, PD BHA#18. RIH w/drilling assembly. Drill ahead from 10,496'to 10,656',drilling in progress. 9/18/2015 Drill ahead L1-01 lateral from 10,656'to 10,959',encountered several ankerite stringers,drilling in progress. 9/19/2015 Drill ahead L1-01 lateral from 10,959'to 11,573'.Pumped new mud system,new mud @ bit 11,553'.Drilling in progress. 9/20/2015 Drill ahead L1-01 lateral from 11,553'to 12,011'.Town called for early wiper to 11,200,slight overpull© 11,750,town called @ 12,011'. Pump sweeps chase to swab,jet 5.5"liner to 8,669'. 9/21/2015 Chase sweeps to swab valve, reset depth. RBIH to 11,250'. POOH laying in liner pill/completion fluid. Paint EOP flags.No flow check at surface. MU L1-01 liner assembly. MU BHA#19, RIH w/liner assembly to set depth @ 11,240',release from liner,TOL @ 8,728'. PUH,circulate well to seawater. POOH to 2,500',freeze protect with diesel. POOH. PUD BHA#19, LD BOT&MWD. Hold PJSM with FMC. 9/22/2015 Set BPV,LD FMC equipment. Flush stack and surface lines with inhibited freshwater. ND BOPE. Secure stack and wellhead.Complete rig move checklist.Rig released at 07:00. Page 1/1 Report Printed: 11/3/2015 KUP PROD 1G-12L1-01 Conoco Phi lips L* Well Attributes Max Angle&MD TD Alaska in( Wellbore API/UWI Field Name Wellbore Statusncl 7) MD(ftKB) Act Btm(ftKB) CanocoPl4KlP: 500292100961 KUPARUK RIVER UNIT PROD I 104.35 10,110.27 11,240.0 •-- Comment 1125(ppm) Date Annotation End Date KBGrd(ft) Rig Release Date 1G-12L1-01,10/1/2015 4.3258 PM SSSV NONE 90 12/16/2013 Last WO 40.99 10/2/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;31 3 �-(of Last Tag:SLM 8,831.0 7/25/2015 Rev Reason:ADD LATERALS L1&L1-01(both smsmith 10/1/2015 off main wellbore) Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L1-01 LINER 23/8 1.992 8,728.7 11,240.0 6,489.6 4.60 L-80 ST-L Liner Details Nominal ID ® Top(TVD)(ftKB) Tap Incl 7) Item Des Gem On) -III 1 � 6,551.0 42.68 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 ✓,AJ CONDUCTOR,38.0-100.0• • Perforations&Slots Shot Dens SURFACE;37.2-2,550.0 Top(TVD) Bern(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,728.7 11,240.0 6,551.0 6,489.6 9/21/2015 SLOTS Slotted Liner GAS LIFT;2,842.6 Notes:General&Safety End Date Annotation NOTE GAS LIFT;4,681.5 GAS LIFT;5,973.7 GAS LIFT;6,822.1 GAS LIFT;7,624.0 GAS LIFT;8,170.2 LOCATOR;8,228.9 SEAL ASSY;8,227.2 PER;8,234.3 PACKER;8,257.3 NIPPLE,8,309 8 GAS LIFT,8,362.2 BLAST JOINT;8,382.2-� IPERF;8,385.0-8,458.0 BLAST JOINT;8,402.9 PACKER;8,472.1 NIPPLE;8,496.3 GAS LIFT;8,513.9 BLAST JOINT;8,533.6 IPERF;8,537.0-8,588.OL� s BLAST JOINT;8,553.3 LOCATOR;8,602.8 j L, PACKER;8,603.3 _ SEAL ASSY;8,603.6 SBE;8,606.6 NIPPLE;8,625.9 111 WEAR SOCK;8,669.1 WHIPSTOCK;8,738.0-\ L1-01 WINDOW;8,743.0- I _ 8,748.0 g : WHIPSTOCK;8,770.0 L1 WINDOW;8,778.0-8,783.0 ••i BEVELED SHOE;8,795.5 I APERF;8,812.0-8,830.0- APERF;8,830.0-8,850.0-- APERF;8,850.0-8,864.0 PRODUCTION;32.1-9,096.4L�= SLOTS;8,728.6-11,240.0- I1L L1-01 LINER;8,728.6-11,240.0 • 0 N N 0) O ;a- r.-- co n 0 N 0 O V N V O M M h co co p � � co O � N N _ g 65 0^ (6 c0 0 U CO N _ in m N _t] C 2 6 C_ N N 0 0 m N N 0 C - _E C .0 b E c0 N O N O N 63 O N 6S E d' -E L to m e ro E ' To E 090 N a m o_ _ E 00 O 0 N O Q a0 -E0 C 0 F- = 0 U 0 U o V co _Ti 7 N 7 0 0 O >- -o N M� a n - a (n m 0 _ a N O (0 O o�D\ 8.- LU Ol Nom p a_ �_ o) a co V _ -0 - cu U 0 (6 l5 a0 U 61 OS 0 O N J 7-(!7 LU 2 cc'a-) m 2 Zr, @ 2 mY m @� 0 d0 N U N �' m N a0('7 C J0 co oN a a 0 a a- o O O. a H N M E- vJ .c E J E E 3 7 I I GO ai (D 07L- X U u X 0 J w X I I (V CV N YY N N Y CV (V Y Y N i t co a) co co Ns- co `- 7 63 67 M M� 00<0 co M M co 00 m A t I 0 0 I I N 0 I I 0 bo o I I c) I1 0 ii_ iii CO I I v m !/ hj Ia03a. I —d; 0 s,s,,1 ....� // II . AV'ASM \\I, .4(73 T T \‘‘ \\i !!! 1 U) 2 \\ rl I\ .Oc 0 'n0 a a co 6�71 �N 02 Iii ,—, NO) oo - N� ga 11 ..... S co N V M �, 2 NOp1� 11 1�� p@(4. I/ O M Ue ion OD c N,- /, V" N J N 63 I O N Q Y 1-a=0 0 J (n N U ,5�1 67 N v a,L a 0 0 9 c HNaa • Daily Operations Summary Welts 1G-12 Conocohi��ps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Daily Operations Start Date Last 24hr Sum 8/28/2015 RDMO from 1G-11. MIRU on 1G-12. Begin initial BOP test.Rig accepted at 21:00 on 8/28/15 8/29/2015 BOP test completed.All pressure tests complete. Repair external hydraulic leaks to BOP lower blind bonnet. Retest repairs,good. MU BHA#1. RIH.Encountered heavy returns of degradeable plug from 6,500-ft.Circuate out plug material. 8/30/2015 Circulate out plug material. Mill window TOW at 8,776.3-ft to BOW at 8,782-ft. Drilled rathole to 8,796-ft.Window back reamed and drifted clean. POOH.RIH. Drilled build section from 8,796-ft to 8,818-ft.Drilling in progress. 8/31/2015 Drill build section from 8,818-ft to 9,150-ft. POOH. RIH with BHA#3. Drill L1 lateral from 9,150-ft to 9,484-ft. Drilling in progress. 9/1/2015 Drill L1 lateral from 9,484 ft to 10,506 ft. 9/2/2015 Drill L1 lateral from 10,506 ft to 10,957 ft 9/3/2015 Drill L1 lateral from 10,957 ft to 11,239 ft 9/4/2015 Drill L1 lateral from 11,239 ft to 11,360 ft.perform swab wiper,Confirm TD 11,360 ft,displace well to 11.4 ppg competion fluid,check well for flow, LD drilling BHA#3 9/5/2015 MU BHA#4 L1 liner assembly with 82 jts of slotted liner,and shorty deployment sleeve, RIH,release from liner at 11,311 ft,TOL 8,765.5 ft, POOH, PU/MU WS BHA#5, RIH set TOWS at 8,738 ft, POOH, PU/MU BHA#6, RIH,tie into the K1 correction of minus 3.0 ft,Start displaceing well to drilling fluid. 9/6/2015 Mill Window from 8,743.4 ft to 8,749 ft,TOWS 8,738 ft, POOH, Drill rate hole down to 8,763 ft, PU/MU Build BHA#7, RIH,tie into the K1 correction of minus 3.0 ft, 9/7/2015 Drilled build section from 8,763 ft to 8,996 ft, POOH,undeploy/LD build BHA#7, PU/MU/Deploy lateral BHA#8, RIH,drill L1-01 lateral from 8,996 ft to 9,107 ft.USR failed,POOH,undeploy Lateral BHA#8,PU/MU/Deploy Lateral BHA#9 9/8/2015 Drilled the Lateral section from 9,107 ft to 9,638 ft, POOH to inspect lateral drilling BHA#9, Found bit to be balled up with 3 chipped cutters,PU new bi-center bit and new motor,MU and deploy BHA#10,RIH 9/9/2015 Drilled the Lateral section from 9,638 ft to 10,133 ft. 9/10/2015 Drilled the L1-01 Lateral section from 10,133 ft to 10,655 ft. Drililng up through the lower A3 silt at 10-30 fph, pumping sweeps and jetting 5 1/2 tail pipe. 9/11/2015 Drilled the L1-01 lateral section from 10655 ft to 10677 ft, Performed wiper up into the tubing due to annular pressure spikes on bottom drilling, temporarily detained at the 3.5"x5.5",free pipe,pull wiper up to 6000 ft chasing 5x5 sweeps, RBIH,stacked out 8804 ft, POOH, PU/MU clean out BHA with D331, RIH and cleaned out down to 10677 ft, lower pump rate to 0.75 bpm to pass thru to current TD, Perform swab wiper to clean hole, RBIH to 9000 ft, displaced well to 11.8 ppg completion fluid in preparation of bi-weekly BOPE test while POOH, LD Cleanout BHA 9/12/2015 Finished LD cleanout BHA, perform rigs bi-weekly BOPE test, PU/MU drilling BHA#12 with 3.0"inch bi-center bit and aggitator. RIH and drill from 10677 ft to 10879 ft. 9/13/2015 Drilled the L1-01 lateral section from 10879 ft to 11460 ft with wipers every 200 ft,up into the casing,jetting 5.5"big tail pipe, became stuck on wiper from 11460 ft at 10022 ft,worked pipe,maintaining annular with test pump 9/14/2015 Stuck coil,working pipe at 10019 ft,pull max on coil 82k, BHA#12 parted at the HOT, leaving TOF @ 10004.51 ft, pump sweeps, POOH, LD damaged drilling BHA, PU/MU/Deploy open hole anchored billet,set down at 8800 ft,POOH for cleanout BHA. 9/15/2015 LD OH anchored billet. Make clean-out run with D331 mill to 9,930'. Rerun OH anchored billet to 9,911,set billet. POOH for kick-off assembly. PUD BHA#15, PD BHA#16.RIH w/KO assembly,dry tag billet,start kick-off,in progress. 9/16/2015 Kick-off OH anchored billet @ 9,901, dry drift clean. Drill ahead build section to called TD @ 10,260'. POOH for drilling assembly, PUD BHA#16, PD BHA#17.RIH w/drilling assembly,drill ahead L1-01 lateral from 10,260'to 10,460',drilling in progress. 9/17/2015 Drill ahead L1-01 lateral from 10,460'to10,496'. POOH due to high differential pressure. PUD BHA#17, PD BHA#18. RIH w/drilling assembly. Drill ahead from 10,496'to 10,656',drilling in progress. 9/18/2015 Drill ahead L1-01 lateral from 10,656'to 10,959',encountered several ankerite stringers,drilling in progress. 9/19/2015 Drill ahead L1-01 lateral from 10,959'to 11,573'. Pumped new mud system,new mud @ bit 11,553'.Drilling in progress. 9/20/2015 Drill ahead L1-01 lateral from 11,553'to 12,011'.Town called for early wiper to 11,200,slight overpull @ 11,750,town called @ 12,011'. Pump sweeps chase to swab,jet 5.5"liner to 8,669'. 9/21/2015 Chase sweeps to swab valve,reset depth. RBIH to 11,250'. POOH laying in liner pill/completion fluid.Paint EOP flags.No flow check at surface. MU L1-01 liner assembly. MU BHA#19, RIH w/liner assembly to set depth @ 11,240', release from liner,TOL @ 8,728'.PUH,circulate well to seawater. POOH to 2,500',freeze protect with diesel.POOH. PUD BHA#19,LD BOT&MWD. Hold PJSM with FMC. 9/22/2015 Set BPV,LD FMC equipment. Flush stack and surface lines with inhibited freshwater.ND BOPE.Secure stack and wellhead.Complete rig move checklist. Rig released at 07:00. Page 1/1 Report Printed: 11/3/2015 r,- KUP PROD • 1G-12L1 ConocoP fillips ro+k . Well Attributes Max Angle&MD TD Alaska<Mc. Wellbore API/UWI Field Name Wellbore Status II ncl(°) MD(ftKB) Act Btm(ftKB) ca,o, yp, 500292100960 KUPARUK RIVER UNIT PROD 95.57 11,040.16 11,311.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-12L1,10/1/20154'32:39 PM SSSV:NONE 90 12/16/2013 Last WO: 40.99 10/2/1983 Veftical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ata Last Tag:SLM 8,831.0 7/25/2015 Rev Reason:ADD LATERALS L1&L1-01(both smsmith 10/1/2015 HANGER '1 off main wellbore) mr Casing Strings ` - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WUlen(I...Grade Top Thread L1 LINER 2 3/8 1.992 8,765.5 11,311.0 6,696.2 4.60 L-80 ST-L 11 H f,, Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Corn (in) 111 8,765.5 6,578.0 43.16 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 M/CONDUCTOR 36.5-100.b- II Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (0501911 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SURFACE:37.2-2,550.0— 1 8766.4 11,310.6 6,578.6 6,696.2 9/5/2015 SLOTS Slotted Liner Notes:General&Safety GAS LIFT;2,842.6 4End Date Annotation II NOTE li it GAS LIFT;4581.5 la All GAS LIFT;5,973.7 . I GAS LIFT;6,922.1 GAS LIFT;7,624.0 ilt II GAS LIFT;8,170.2 •- It it LOCATOR;8,226.9 SEAL ASSY;8,227.2 =_ PBR;8,234.3 -� PACKER;8,257.3 '" NIPPLE 8,309 8 GAS LIFT;8,3622 all 1.1 BLAST JOINT;8,3822. — I (PERF;8,385.0-8,458.0 BLAST JOINT;8,402.9��_ 8 PACKER;8,472.1 MB NIPPLE;8,496.3 IE II GAS LIFT;8,513.9 II BLAST JOINT;8,533.6 IPERF;8,537.0-8,589.0_. I BLAST JOINT;8,553.3 l LOCATOR;8,602.8 AI PACKER;8,603.3. ■1'� SEAL ASSY;8,803.6 - - SeE;8,806.8 a •ilr NIPPLE;8,625.9 ar • WEAR SOCK;8,669.14 it WHIPSTOCK;8,738.0,,\ I ' I L1-0i WINDOW;8,743.0-8 ,<�I. i 8,748.0 : PRODUCTION;32.1-9,096.4 I L1-01 LINER;8,728.6-11240.0 _ it _ SLOTS:8,766.4-11,310.8 _ I Ll LINER;8765.5-11,311.0 0 0 N N O V 1"-- a) to p m p 2 co 2 V N d co co h coio h p N R m au co N N LU ( G NE WE H N _ UCN @ p p a A _ E a _ O a N O N -O - c O O •Cco r a - m Ea V N o V E L (O Ci) a pp Nro 4 12 v N. U 22 o - t.') Q 2 m r co o>. a ��ui a a v Tel V � aaO c a CO MmNo O m V O a r2J U- °3 .°3 o aoa a@ 3p w w Mo Irm co Y ro ao o ro VIco_. 2 t Ucoth 00 O a H CO N� N = 1 1 o Uo6 COu X 0 Li. X U J lL X I I N (V i} 43ft/ N N Cli, N N _N.N N - N CO 1- m m (0 1 co ren moo M M m co CO 00 to M I I _. ----- p p I I I I I p m b I I N. ao a0I1 alm iii jjg1hj 1 am iiii Htri I I k q a a, /� n� g 1— Q / C.) 1, — , , X\ ‘X 4/i +coTT \\/ / 'E 1! A‘ \1 /\ !!! ' CU p \\ 11 11 o O Ico tb N2 y� N \\\ II II �p a '03 am p0 IIS �_�, Nm w N A @ o N Um Uao o N -- // 0 c0 N v o)r,(4.,1 O M // Ue cos O❑ c a� 11 u a2 / r - 1,- m m 00�mL2.. `,11-O-O- _I (7) N U ) p 6 N V W L 0) o a M C 3 .-1--N Q 4- s • • Drii Wig Daily Operations Summary &Wens 1G-12 Phillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Daily Operations Start Date Last 24hr Sum 8/28/2015 RDMO from 1G-11. MIRU on 1G-12.Begin initial BOP test.Rig accepted at 21:00 on 8/28/15 8/29/2015 BOP test completed.All pressure tests complete. Repair external hydraulic leaks to BOP lower blind bonnet. Retest repairs,good. MU BHA#1. RIH.Encountered heavy returns of degradeable plug from 6,500-ft.Circuate out plug material. 8/30/2015 Circulate out plug material.Mill window TOW at 8,776.3-ft to BOW at 8,782-ft. Drilled rathole to 8,796-ft.Window back reamed and drifted clean. POOH. RIH. Drilled build section from 8,796-ft to 8,818-ft.Drilling in progress. 8/31/2015 Drill build section from 8,818-ft to 9,150-ft. POOH. RIH with BHA#3. Drill L1 lateral from 9,150-ft to 9,484-ft. Drilling in progress. 9/1/2015 Drill L1 lateral from 9,484 ft to 10,506 ft. 9/2/2015 Drill L1 lateral from 10,506 ft to 10,957 ft 9/3/2015 Drill L1 lateral from 10,957 ft to 11,239 ft 9/4/2015 Drill L1 lateral from 11,239 ft to 11,360 ft.perform swab wiper,Confirm TD 11,360 ft,displace well to 11.4 ppg competion fluid,check well for flow, LD drilling BHA#3 9/5/2015 MU BHA#4 L1 liner assembly with 82 jts of slotted liner,and shorty deployment sleeve, RIH, release from liner at 11,311 ft,TOL 8,765.5 ft, POOH, PU/MU WS BHA#5, RIH set TOWS at 8,738 ft, POOH, PU/MU BHA#6, RIH,tie into the K1 correction of minus 3.0 ft,Start displaceing well to drilling fluid. 9/6/2015 Mill Window from 8,743.4 ft to 8,749 ft,TOWS 8,738 ft, POOH,Drill rate hole down to 8,763 ft, PU/MU Build BHA#7, RIH,tie into the K1 correction of minus 3.0 ft, 9/7/2015 Drilled build section from 8,763 ft to 8,996 ft, POOH,undeploy/LD build BHA#7, PU/MU/Deploy lateral BHA#8, RIH,drill L1-01 lateral from 8,996 ft to 9,107 ft.USR failed,POOH,undeploy Lateral BHA#8, PU/MU/Deploy Lateral BHA#9 9/8/2015 Drilled the Lateral section from 9,107 ft to 9,638 ft, POOH to inspect lateral drilling BHA#9, Found bit to be balled up with 3 chipped cutters, PU new bi-center bit and new motor, MU and deploy BHA#10, RIH 9/9/2015 Drilled the Lateral section from 9,638 ft to 10,133 ft. 9/10/2015 Drilled the L1-01 Lateral section from 10,133 ft to 10,655 ft. Drililng up through the lower A3 silt at 10-30 fph, pumping sweeps and jetting 5 1/2 tail pipe. 9/11/2015 Drilled the L1-01 lateral section from 10655 ft to 10677 ft, Performed wiper up into the tubing due to annular pressure spikes on bottom drilling, temporarily detained at the 3.5"x5.5",free pipe,pull wiper up to 6000 ft chasing 5x5 sweeps, RBIH,stacked out 8804 ft, POOH, PU/MU clean out BHA with D331, RIH and cleaned out down to 10677 ft, lower pump rate to 0.75 bpm to pass thru to current TD, Perform swab wiper to clean hole, RBIH to 9000 ft, displaced well to 11.8 ppg completion fluid in preparation of bi-weekly BOPE test while POOH, LD Cleanout BHA 9/12/2015 Finished LD cleanout BHA, perform rigs bi-weekly BOPE test, PU/MU drilling BHA#12 with 3.0"inch bi-center bit and aggitator. RIH and drill from 10677 ft to 10879 ft. 9/13/2015 Drilled the L1-01 lateral section from 10879 ft to 11460 ft with wipers every 200 ft,up into the casing,jetting 5.5"big tail pipe,became stuck on wiper from 11460 ft at 10022 ft,worked pipe,maintaining annular with test pump 9/14/2015 Stuck coil,working pipe at 10019 ft, pull max on coil 82k, BHA#12 parted at the HOT,leaving TOF @ 10004.51 ft, pump sweeps, POOH, LD damaged drilling BHA,PU/MU/Deploy open hole anchored billet,set down at 8800 ft, POOH for cleanout BHA. 9/15/2015 LD OH anchored billet. Make clean-out run with D331 mill to 9,930'. Rerun OH anchored billet to 9,911,set billet.POOH for kick-off assembly. PUD BHA#15, PD BHA#16.RIH w/KO assembly,dry tag billet,start kick-off, in progress. 9/16/2015 Kick-off OH anchored billet @ 9,901, dry drift clean. Drill ahead build section to called TD @ 10,260'. POOH for drilling assembly, PUD BHA#16, PD BHA#17.RIH w/drilling assembly,drill ahead L1-01 lateral from 10,260'to 10,460',drilling in progress. 9/17/2015 Drill ahead L1-01 lateral from 10,460'to10,496'. POOH due to high differential pressure. PUD BHA#17, PD BHA#18. RIH w/drilling assembly. Drill ahead from 10,496'to 10,656',drilling in progress. 9/18/2015 Drill ahead L1-01 lateral from 10,656'to 10,959',encountered several ankerite stringers,drilling in progress. 9/19/2015 Drill ahead L1-01 lateral from 10,959'to 11,573'. Pumped new mud system,new mud @ bit 11,553'.Drilling in progress. 9/20/2015 Drill ahead L1-01 lateral from 11,553'to 12,011'.Town called for early wiper to 11,200,slight overpull @ 11,750,town called @ 12,011'. Pump sweeps chase to swab,jet 5.5"liner to 8,669'. 9/21/2015 Chase sweeps to swab valve, reset depth. RBIH to 11,250'. POOH laying in liner pill/completion fluid. Paint EOP flags.No flow check at surface. MU L1-01 liner assembly. MU BHA#19, RIH w/liner assembly to set depth @ 11,240',release from liner,TOL @ 8,728'. PUH,circulate well to seawater. POOH to 2,500',freeze protect with diesel. POOH. PUD BHA#19, LD BOT&MWD. Hold PJSM with FMC. 9/22/2015 Set BPV,LD FMC equipment. Flush stack and surface lines with inhibited freshwater. ND BOPE. Secure stack and wellhead.Complete rig move checklist.Rig released at 07:00. Page 1/1 Report Printed: 11/3/2015 RECEIVED 0 erations Summary (with TimelogDpths) _ DEC 1 S 2015 1G-12 Conoco`Milfips AOGCC Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 8/28/2015 8/28/2015 4.00 MIRU MOVE RURD P RD checklist completed on 1G-11. 0.0 0.0 08:00 12:00 8/28/2015 8/28/2015 4.00 MIRU MOVE MOB P PJSM with Peak.RDMO 1G-11 to 1G- 0.0 0.0 12:00 16:00 12 8/28/2015 8/28/2015 5.00 MIRU MOVE 'RURD P Start rig up,start working post move 0.0 0.0 16:00 21:00 check list. 8/28/2015 8/28/2015 1.00 MIRU WHDBOP NUND P Nipple up BOP,no loose bolts found 0.0 0.0 21:00 22:00 on tree(1/2 hour)hook up Kill Tank to rig, Note:Rig accepted at 21:00 8/28/2015 8/28/2015 1.00 MIRU WHDBOP NUND P Prep for BOP test,function test BOP's, 0.0 0.0 22:00 23:00 shell test,secure stack,grease HCR valves,set up test pump. 8/28/2015 8/29/2015 1.00 MIRU WHDBOP BOPE P Begin BOPE test 250/3800 psi, 0.0 0.0 23:00 00:00 annular 250/2500 psi 8/29/2015 8/29/2015 7.50 MIRU WHDBOP BOPE P Continue BOP test 250/3800 psi, 0.0 0.0 00:00 07:30 annular 250/2500 psi. 8/29/2015 8/29/2015 3.20 MIRU WHDBOP PRTS P BOPE test completed.fluid pack coil. 0.0 0.0 07:30 10:42 Test inner reel&packoffs, 8/29/2015 8/29/2015 1.30 MIRU WHDBOP MPSP P FMC on location.PJSM,get equip to 0.0 0.0 10:42 12:00 the rig floor.PJSM,pull BPV(well on vaccum)PJSM.RDMO FMC&BPV equip. 8/29/2015 8/29/2015 3.00 MIRU WHDBOP PRTS P Test PDL&Tiger Tank lines. 0.0 0.0 12:00 15:00 8/29/2015 8/29/2015 1.00 SLOT WELLPR SFTY P Conduct pre-spud in the dog house. 0.0 0.0 15:00 16:00 Roll into TGSM for picking up BHA#1 8/29/2015 8/29/2015 2.50 SLOT WELLPR EQRP T Leaky Hydralic line leading to BOPE. 0.0 0.0 16:00 18:30 All External to BOPE.Replace 0 ring to outside of lower 2"bonnet,tested good but leak began on o-ring closest to BOP ram body on bonnet to lower 2"blind ram o-ring,had to open door to replace o-ring. 8/29/2015 8/29/2015 1.00 SLOT WELLPR PRTS T PJSM-Shell test BOPE 250/3,800 0.0 0.0 18:30 19:30 psi,test lower blind ram 250/3,800 psi. 8/29/2015 8/29/2015 0.75 SLOT WELLPR SFTY P Conduct pre-spud for night crew.Roll 0.0 0.0 19:30 20:15 into TGSM for picking up BHA. 8/29/2015 8/29/2015 0.75 PROD1 WHPST PULD P MU BHA#1,0.6°AKO motor and 0.0 73.5 20:15 21:00 HCC DSM,MU to coiltrak,surface test. 8/29/2015 8/29/2015 2.15 PROD1 WHPST TRIP P RIH with BHA#1,bring returns in at 73.5 8,210.0 21:00 23:09 7,900-ft. 8/29/2015 8/29/2015 0.20 PROD1 WHPST DLOG P Tie in to K1 for 0-ft correction,PUW 8,210.0 8,250.0 23:09 23:21 32k,getting heavy returns of degradeable partical plug over shaker. 8/29/2015 8/30/2015 0.65 PROD1 WHPST TRIP P PUH slowly until returns clean up. 8,250.0 8,000.0 23:21 00:00 8/30/2015 8/30/2015 1.15 PROD1 WHPST TRIP P RIH to 8,755-ft,bottoms up with heavy 8,000.0 8,755.0 00:00 01:09 plug material returns Page 1/19 Report Printed: 12/18/2015 Iperations Summary (with Timelog epths) 1G-12 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time;' End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/30/2015 8/30/2015 0.50 PROD1 WHPST CIRC P PUH slowly and continue to circulate 8,755.0 8,776.3 01:09 01:39 out plug material.23 bbls of plug material recovered to cuttings box. RBIH.dry tag pinch point at 8,777-ft, PUW 32k.pump hi/lo sweeps 8/30/2015 8/30/2015 1.00 PROD1 WHPST DISP P Swap well over to 9.1 ppg milling fluid. 8,776.3 8,776.3 01:39 02:39 8/30/2015 8/30/2015 9.35 PROD1 WHPST WPST P Begin milling window exit per milling 8,776.3 8,782.0 02:39 12:00 schedule and Baker rep. 8/30/2015 8/30/2015 3.00 PROD1 WHPST DRLG P Start drilling rat hole. 8,782.0 8,796.0 12:00 15:00 8/30/2015 8/30/2015 1.00 PROD1 WHPST REAM P Back ream window.3L, 18L,12R,little 8,796.0 8,796.0 15:00 16:00 MW @ 8783'.Dry drift window,small bobble @ btm of window.Pump sweep. 8/30/2015 8/30/2015 1.80 PROD1 WHPST TRIP P POOH to surface. 8,796.0 72.5 16:00 17:48 8/30/2015 8/30/2015 0.60 PROD1 WHPST OWFF P On surface,bleed WHP to 0 psi, 72.5 72.5 17:48 18:24 monitor for flow,no flow 30 minutes. PJSM-laying down BHA 8/30/2015 8/30/2015 0.50 PROD1 WHPST PULD P Lay down BHA#1 72.5 0.0 18:24 18:54 8/30/2015 8/30/2015 1.10 PROD1 DRILL PULD P PJSM-MU Drilling build section BHA 0.0 72.1 18:54 20:00 #2,2.37°AKO motor and a RB 3.25" HCC short shank Bi-center bit.difficult to get thru tree with high AKO.MU to Coiltrak,surface test. 8/30/2015 8/30/2015 1.70 PROD1 DRILL TRIP P RIH with BHA#2 72.1 8,210.0 20:00 21:42 8/30/2015 8/30/2015 0.15 PROD1 DRILL DLOG P Tie in at K1 for minus 1-ft correction. 8,210.0 8,250.0 21:42 21:51 PUW 30k 8/30/2015 8/30/2015 0.50 PROD1 DRILL TRIP P Continue in hole. 8,250.0 8,796.0 21:51 22:21 8/30/2015 8/31/2015 1.65 PROD1 DRILL DRLG P 8,796-ft, OBD 1.5 bpm at 3,484 psi, 8,796.0 8,818.0 22:21 00:00 BHP 3,873 psi,CWT 11.63,WOB 2.0k,WHP 80,IA 123,OA 481 8/31/2015 8/31/2015 8.25 PROD1 DRILL DRLG P 8,818-ft, OBD 1.5 bpm at 3,444 psi, 8,818.0 9,150.0 00:00 08:15 BHP 3,878 psi,CWT 10.5k,WOB 2.5k,WHP 78,IA 290,OA 488 8/31/2015 8/31/2015 2.00 PROD1 DRILL TRIP P TD build @ 9150'.POOH 9,150.0 72.1 08:15 10:15 8/31/2015 8/31/2015 0.50 PROD1 DRILL OWFF P OOH,bleed WHP from 550 psi to 0 72.1 72.1 10:15 10:45 psi.Watch for 30 minutes,no build up. Open to shaker,no flow.PJSM for laying down BHA with high bend motor. 8/31/2015 8/31/2015 0.75 PROD1 DRILL PULD P Lay down BHA#2 72.1 0.0 10:45 11:30 8/31/2015 8/31/2015 1.25 PROD1 DRILL PULD P PJSM,Pick up BHA#3 0.0 72.2 11:30 12:45 8/31/2015 8/31/2015 3.00 PROD1 DRILL TRIP P RIH w/drilling BHA Log K-1 @-1' 72.2 9,150.0 12:45 15:45 corr.Log RA marker @ 8780' 8/31/2015 9/1/2015 8.25 PROD1 DRILL DRLG P Drill ahead 1.45 BPM @ 3458 psi BHP 9,150.0 9,484.0 15:45 00:00 3921 psi. NOTE:Mud swap,new 9.1 ppg flo pro @ bit 9,258' 9/1/2015 9/1/2015 0.95 PROD1 DRILL DRLG P 9,484-ft, OBD 1.53 bpm at 3,500 psi, 9,484.0 9,540.0 00:00 00:57 BHP 3,936 psi,CWT 9.2k,WOB 2.5k, ROP 60, IA 539,OA 504. Page 2/19 Report Printed: 12/18/2015 J iterations Summary (with Timelog pths) 1G-12 01 Conoco` Phillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/1/2015 9/1/2015 0.30 PROD1 DRILL WPRT P Wiper to window,PUW 32k. 9,540.0 8,820.0 00:57 01:15 9/1/2015 9/1/2015 0.60 PROD1 DRILL WPRT P Wiper back in hole,RIW 13.4k. 8,820.0 9,540.0 01:15 01:51 attempt to get pump 1 primed while RIH. 9/1/2015 9/1/2015 12.15 PROD1 DRILL DRLG P 9,540-ft, OBD 1.51 bpm at 3,531 psi, 9,540.0 9,940.0 01:51 14:00 BHP 3,950 psi,WHP 13,IA 497,OA 503 Note: Mud swap,New 9.2 ppg Power Pro SF @ bit 9,880' OBD 1.70 bpm at 3,566 psi,BHP 3,950 psi 9/1/2015 9/1/2015 0.50 PROD1 DRILL WPRT P Wiper trip,PUW 30k 9,940.0 9,150.0 14:00 14:30 9/1/2015 9/1/2015 0.25 PROD1 DRILL WPRT P Wiper back in hole,RIW 12k 9,150.0 9,940.0 14:30 14:45 9/1/2015 9/1/2015 6.25 PROD1 DRILL DRLG P 9,940-ft,OBD 1.73 bpm at 3,580 psi, 9,940.0 10,340.0 14:45 21:00 BHP 3,935 psi,WHP 75,IA 563,OA 506 9/1/2015 9/1/2015 0.50 PROD1 DRILL WPRT P 10340 ft,Wiper up hole to 8805 ft. 10,340.0 8,805.0 21:00 21:30 PUW 32k 9/1/2015 9/1/2015 0.25 PROD1 DRILL DLOG P 8805 ft,Tie into the RA marker 8,805.0 8,824.0 21:30 21:45 correction of plus 1.5 ft. 9/1/2015 9/1/2015 0.50 PROD1 DRILL WPRT P 8805 ft,Wiper back in hole,RIW 12k 8,824.0 10,340.0 21:45 22:15 9/1/2015 9/2/2015 1.75 PROD1 DRILL DRLG P 10340 ft,BOBD 1.7 bpm at 3319 psi, 10,340.0 10,506.0 22:15 00:00 BHP 4041,WHP 71, IA 746,OA 514 9/2/2015 9/2/2015 2.50 PROD1 DRILL DRLG P 10506 ft,OBD 1.7 bpm at 3734 psi, 10,506.0 10,740.0 00:00 02:30 BHP 4034,WHP 66, IA 759,OA 515 9/2/2015 9/2/2015 0.50 PROD1 DRILL WPRT P 10740 ft,Wiper up hole to 9740 ft. 10,740.0 9,740.0 02:30 03:00 PUW 32k 9/2/2015 9/2/2015 0.50 PROD1 DRILL WPRT P 9740 Wiper back in hole,RIW 9,740.0 10,740.0 03:00 03:30 9/2/2015 9/2/2015 3.25 PROD1 DRILL DRLG P 10740 ft,BOBD 1.7 bpm at 3120 psi, 10,740.0 10,794.0 03:30 06:45 BHP 4029,WHP 62, IA 810,OA 513 *"*Note:Bleed down IA from 810 psi to 120 psi,OA from 513 psi to 146 psi 9/2/2015 9/2/2015 1.00 PROD1 DRILL WPRT P Wiper up hole,PUW 30k 10,794.0 8,775.0 06:45 07:45 9/2/2015 9/2/2015 0.75 PROD1 DRILL CIRC P Pump 5 X 5 sweep and jet big tail pipe 8,775.0 8,775.0 07:45 08:30 Note: Set down 3k at bottom of window 9/2/2015 9/2/2015 0.25 PROD1 DRILL DLOG P Tie into RA marker for+1.0'correction 8,775.0 8,817.0 08:30 08:45 9/2/2015 9/2/2015 0.85 PROD1 DRILL WPRT P Wiper in hole,RIW 11k 8,817.0 10,794.0 08:45 09:36 9/2/2015 9/2/2015 5.25 PROD1 DRILL DRLG P 10,794-ft,BOBD 1.4 bpm at 2,847 psi, 10,794.0' 10,823.0 09:36 14:51 BHP 4,020 psi,WHP 123,IA 34,OA 305 9/2/2015 9/2/2015 1.25 PROD1 DRILL DRLG T 10823 ft,PUH to reset depth and log, 10,823.0 10,823.0 14:51 16:06 CANRIG brought down data transfer accidently,requiring PUH and reset of BHI counters to Nabors counter. MaddPass 10814 ft-10826 ft,rezero counters minus 3.0 ft. Page 3/19 Report Printed: 12/18/2015 • 0 111Iterations Summary (with Timeloglitths) 1G-12 Conor*iiilhps Alaska Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase - Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/2/2015 9/2/2015 3.75 PROD1 DRILL DRLG P BOBD 1.6 bpm at 2900 psi,BHP 10,823.0 10,863.0 16:06 19:51 4062,WHP 62, IA 124,OA 307 9/2/2015 9/2/2015 1.50 PROD1 DRILL DRLG P 10863 ft,Drilling break 1.5 bpm at 10,863.0 10,955.0 19:51 21:21 2966,BHP 4062,WHP 62,IA 123,OA 306 9/2/2015 9/2/2015 1.00 PROD1 'DRILL WPRT P 10955 ft,stack out trouble getting 10,955.0 8,950.0 21:21 22:21 weight on bit,losing surface weight, pump 5/5 sweep,perform wiper up to 8950 ft to clean hole,sumps at 9800 ft -9500ftand 9150 ft-8950 ft. 9/2/2015 9/2/2015 0.50 PROD1 DRILL WPRT P 8950 ft,Wiper back in hole RIW 13k 8,950.0 10,955.0 22:21 22:51 9/2/2015 9/3/2015 1.15 PROD1 DRILL DRLG P 10955 ft,BOBD 1.7 bpm at 3327 psi, 10,955.0 10,957.0 22:51 00:00 BHP 4055,WHP 73,IA 111,OA 307 9/3/2015 9/3/2015 2.50 PROD1 DRILL DRLG P 10957 ft,OBD 1.7 bpm at 3317 psi, 10,957.0 10,970.0 00:00 02:30 BHP 4017,IA 164,OA 307 9/3/2015 9/3/2015 0.50 PROD1 DRILL DRLG P 10970 ft,Drilling Break drilling ahead 10,970.0 10,995.0 02:30 03:00 at 65 fph, 1.6 bpm at 3583 psi,BHP 4009,WHP 18, IA 180,OA 307 9/3/2015 9/3/2015 2.70 PROD1 DRILL DRLG P 10995 ft,slow ROP 6-9 fph, 1.6 bpm 10,995.0 11,003.0 03:00 05:42 at 3500 psi,BHP 4013,WHP 18,IA 179,OA 305 9/3/2015 9/3/2015 4.50 PROD1 DRILL DRLG P 11003 ft,drilling break,drilling ahead 11,003.0 11,090.0 05:42 10:12 at 10 to 20 fph, 1.7 bpm at 3,517 psi, BHP 4,088 psi,WHP 17,IA 186,OA 308 9/3/2015 9/3/2015 0.75 PROD1 DRILL WPRT P 11,090 ft,wiper up hole,PUW 30k 11,090.0 9,500.0 10:12 10:57 9/3/2015 9/3/2015 0.75 PROD1 DRILL WPRT P 9,500 ft,wiper back in hole,RIW 10k 9,500.0 11,090.0 10:57 11:42 9/3/2015 9/3/2015 8.50 PROD1 DRILL DRLG P 11,090 ft, BOBD 1.7 bpm at 3,600 psi, 11,090.0 11,234.0 11:42 20:12 BHP 4,048 psi,WHP 0, IA 182,OA 308,Several BHA wipers, 11152 ft, Looks like we are out of the interface between the A4/A5,drilling ahead 100 fph-150 fph. 9/3/2015 9/3/2015 0.50 PROD1 DRILL WPRT P 11234 ft,wiper up hole to 10235 ft. 11,234.0 10,235.0 20:12 20:42 PUW 32k 9/3/2015 9/3/2015 0.50 PROD1 DRILL WPRT P 10235 ft.Wiper back in hole.RIW 11k 10,235.0 11,234.0 20:42 21:12 9/3/2015 9/4/2015 2.80 PROD1 DRILL DRLG P 11234 ft,BOBD 1.6 bpm at 3460 psi, 11,234.0 11,239.0 21:12 00:00 BHP 4113,WHP 0,IA 198,OA 307 9/4/2015 9/4/2015 1.75 PROD1 DRILL DRLG P 11239 ft,OBD 1.6 bpm at 3413 psi, 11,239.0 11,240.0 00:00 01:45 BHP 4080,WHP 0,IA 162,OA 307, several BHA wipers,pump 20 bbls lube pill,no success. 9/4/2015 9/4/2015 1.00 PROD1 DRILL WPRT P 11239 ft,Wiper up hole to 8950 ft, 11,240.0 8,950.0 01:45 02:45 PUW 32k 9/4/2015 9/4/2015 0.75 PROD1 DRILL WPRT P 8950 ft,Wiper back in hole,RIW 13k 8,950.0 11,239.0 02:45 03:30 9/4/2015 9/4/2015 9.00 PROD1 DRILL DRLG P 11239 ft,BOBD 1.75 bpm at 3814 psi, 11,239.0 11,360.0 03:30 12:30 BHP 4126,WHP 0,IA 167,OA 305, 1 365-ft and 1 500--ft wiper trips, pumped 20bbl new mud pill,slow from 11,353-ft. 9/4/2015 9/4/2015 3.50 PROD1 'DRILL WPRT P 11,360-ft,TD called,pump 10x10 11,360.0 72.2 12:30 16:00 sweep and chase to swab,PUW 31k, Jet BTP 8,765-ft to 8,665-ft,POOH Page 4/19 Report Printed: 12/18/2015 Aerations Summary (with Timelog epths) 0;i 1G-12 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End.Depth(ftKB) 9/4/2015 9/4/2015 1.85 PROD1 DRILL TRIP P At surface,reset counters,RBIH. 72.2 8,820.0 16:00 17:51 9/4/2015 9/4/2015 0.25 PROD1 DRILL DLOG P 8820 ft,Tie into the K1 marker 8,820.0 8,249.0 17:51 18:06 correction of minus 3.0 9/4/2015 9/4/2015 0.30 PROD1 DRILL TRIP P 8249 ft,Continue RIH 8,249.0 8,700.0 18:06 18:24 9/4/2015 9/4/2015 0.15 PROD1 DRILL TRIP P 8700 ft,WC 32k 8,700.0 8,694.0 18:24 18:33 9/4/2015 9/4/2015 0.15 PROD1 DRILL TRIP P 8694 ft,Continue RIH 8,694.0 8,784.0 18:33 18:42 9/4/2015 9/4/2015 1.50 PROD1 DRILL TRIP P 8784 ft,set down PUH,change tool 8,784.0 11,360.0 18:42 20:12 face 10°LOHS,RBIH clean,bobble at 8811 ft,and 8842 ft.Continue RIH 9/4/2015 9/4/2015 0.20 PROD1 DRILL TRIP P Confirm TD 11360 ft,PUH,circulate 11,360.0 11,360.0 20:12 20:24 11.4 ppg beaded completion pill down coil. 9/4/2015 9/4/2015 3.00 PROD1 DRILL DISP P POOH,pumping 11.4 ppg completion 11,360.0 72.0 20:24 23:24 fluid with beads. """"Note:Painted EOP flags at 8600 ft,and 6000 ft. 9/4/2015 9/4/2015 0.50 PROD1 DRILL OWFF P At Surface,perform no flow check, 72.0 72.0 23:24 23:54 PJSM for laying down drilling BHA#3 9/4/2015 9/5/2015 0.10 PROD1 DRILL PULD P Lay down BHA#3 72.0 72.0 23:54 00:00 9/5/2015 9/5/2015 0.50 PROD1 DRILL PULD P Continue LD drilling BHA,flushing BHI 72.0 0.0 00:00 00:30 tools, """"Note:HCC,Bi-center Bit Grade:2 -1-bt-n-x-i-ro-td 9/5/2015 9/5/2015 0.50 PROD1 DRILL PULD P Perform Function test 0.0 0.0 00:30 01:00 9/5/2015 9/5/2015 0.50 COMPZ1 CASING PUTB P Prep for PU L1 liner assembly 0.0 0.0 01:00 01:30 9/5/2015 9/5/2015 0.35 COMPZ1 CASING SFTY P PJSM,with rig crew and BOT rep 0.0 0.0 01:30 01:51 9/5/2015 9/5/2015 5.60 COMPZ1 CASING PUTB P MU L1 liner assembly bull nose,75 jts 0.0 2,589.7 01:51 07:27 slotted,PJSM with new rig crew and BOT rep.MU last 7 jts slotted(82 total jts)and shorty deployment sleeve to BHA#4,MU to Coiltrak,surface test. 9/5/2015 9/5/2015 2.70 COMPZ1 CASING RUNL P RIH with BHA#4 on L1 liner 2,589.7 11,311.0 07:27 10:09 assembly,tie in to flag at 6,000-ft for minus 5-ft correction,PUW 33k,S.O. of 100 to 200 lbs at 8,784-ft,8811-ft and 8840-ft.RIW at 11,300-ft=9.6k. 9/5/2015 9/5/2015 0.20 COMPZ1 CASING RUNL P 11,311-ft, On depth,PUW 40k,WOB 11,311.0 8,765.0 10:09 10:21 -10.9k,RBIH to set depth,release off liner, 1.4 bpm at 3,076 psi,PUW 32k, WOB-1.9k,reset depth 9/5/2015 9/5/2015 1.75 COMPZ1 CASING TRIP P POOH,tie in to K1 for 0-ft correction. 8,765.0 44.2 10:21 12:06 9/5/2015 9/5/2015 0.50 COMPZ1 CASING OWFF P On surface,monitor well for flow. 44.2 44.2 12:06 12:36 PJSM-laying down BHA. 9/5/2015 9/5/2015 0.40 COMPZ1 CASING PULD P Lay down BHA#4,check pipe above 44.2 0.0 12:36 13:00 CTC Page 5/19 Report Printed: 12/18/2015 • 1111tperations Summary (with Timelog epths) 1G-12 Con000`iPhiillips Akv,t, Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/5/2015 9/5/2015 0.85 PROD2 RPEQPT PULD T PJSM-MU BHA#5 Baker Gen II 3 0.0 74.9 13:00 13:51 1/2"x 5 1/2"Whipstock 9/5/2015 9/5/2015 2.75 PROD2 RPEQPT TRIP T RIH with BHA#5,EDC open.Tie in to 74.9 8,751.0 13:51 16:36 K1 for minus 3.5-ft correction, continue in hole. 9/5/2015 9/5/2015 0.20 PROD2 RPEQPT WPST T 8,751-ft,Pump off,close EDC,PUW 8,751.0 8,751.0 16:36 16:48 35k,On depth,3°LOHS,release off whipstock at 2,200 psi,stack 4k, TOWS 8,738-ft. 9/5/2015 9/5/2015 1.50 PROD2 RPEQPT TRIP T POOH 8,751.0 61.9 16:48 18:18 9/5/2015 9/5/2015 0.50 PROD2 RPEQPT OWFF T Perform No flow,PJSM for LD setting 61.9 61.9 18:18 18:48 tools 9/5/2015 9/5/2015 1.00 PROD2 RPEQPT PULD T LD L1-01 WS setting tools 61.9 0.0 18:48 19:48 9/5/2015 9/5/2015 1.50 PROD2 WHPST PULD T MU L1-01 window milling assembly, 0.0 73.4 19:48 21:18 test coiltrak tools 9/5/2015 9/5/2015 1.85 PROD2 WHPST TRIP T RIH,L1-01 window milling assembly, 73.4 8,220.0 21:18 23:09 HCC 2.80"mill,and string reamer 2.79"no-go,0.6°AKO motor and 10 ft pup joint. 9/5/2015 9/5/2015 0.25 PROD2 WHPST DLOG T 8220 ft,Tie into the K1 marker 8,220.0 8,241.0 23:09 23:24 w/correction of minus 3.0 ft. 9/5/2015 9/5/2015 0.49 PROD2 WHPST TRIP T 8241 ft,Continue RIH to 8700 ft 8,241.0 8,700.0 23:24 23:53 9/5/2015 9/6/2015 0.11 PROD2 WHPST DISP T 8700 ft, Displace well to 9.2 ppg 8,700.0 8,700.0 23:53 00:00 PowerVis. 9/6/2015 9/6/2015 1.10 PROD2 WHPST DISP T Continue displacing well to 9.2 ppg 8,700.0 8,743.8 00:00 01:06 drilling fluid. """"Note:Lost 69 total bbls of 11.4 ppg NaBr 44 bbls to formation 21 Left in hole 4 bbls to displacement 9/6/2015 9/6/2015 0.50 PROD2 WHPST TRIP T 8744 ft, Dry tag pinch point,PUH, 8,743.4 8,743.4 01:06 01:36 pumps on 9/6/2015 9/6/2015 5.50 PROD2 WHPST WPST T Start milling window as per RP and 8,743.4 8,748.8 01:36 07:06 BOT rep. 1.47 bpm at 3185 psi,BHP 3939,WHP 121, IA 0,OA 284 Note: BOW 8,748.75' 9/6/2015 9/6/2015 3.10 PROD2 DRILL DRLG T 8748 ft,drill rat hole, 1.45 bpm @ 8,748.8 8,763.0 07:06 10:12 3,195 psi,BHP 3,940 psi,WHP 130, IA 0,0A294 9/6/2015 9/6/2015 2.80 PROD2 DRILL REAM T Back ream window. HS,30L,30R, 8,763.0 8,763.0 10:12 13:00 Dry drift,window was clean,Pump sweep. 9/6/2015 9/6/2015 2.25 PROD2 DRILL TRIP T POOH,PUW 30k 8,763.0 72.2 13:00 15:15 9/6/2015 9/6/2015 1.25 PROD2 DRILL PULD T PJSM-Pressure undeploy and LD 72.2 0.0 15:15 16:30 window milling BHA#6 9/6/2015 9/6/2015 2.50 PROD2 DRILL PULD T PJSM-MU build drilling BHA. 1.5° 0.0 72.1 16:30 19:00 AKO motor and HYC short shank bi- center bit,pressure deploy BHA#7, MU to Coiltrak,surface test. 9/6/2015 9/6/2015 1.75 PROD2 DRILL TRIP T RIH,pumping min rate,with MP.0.2 72.1 8,210.0 19:00 20:45 bpm at 1450 psi, IA 0,OA 286 9/6/2015 9/6/2015 0.25 PROD2 DRILL DLOG T 8210 ft,tie into the K1 marker 8,210.0 8,230.0 20:45 21:00 correction of minus 4.0 ft. Page 6/19 Report Printed: 12/18/2015 • ►2t 1111 Aerations Summary (with Timelog epths) 0 1G-12 ConocahitIps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth. Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 9/6/2015 9/6/2015 1.00 PROD2 DRILL TRIP T 8230 ft,displace well from milling fluid 8,230.0 8,763.0 21:00 22:00 to used mud. 9/6/2015 9/6/2015 1.85 PROD2 DRILL DRLG T 8763 ft,OBD 1.45 bpm at 3263 psi, 8,763.0 8,790.0 22:00 23:51 BHP 3988,WHP 131 9/6/2015 9/7/2015 0.15 PROD2 DRILL TRIP T 8790 ft,PUH to log RA marker, 8,790.0 8,200.0 23:51 00:00 9/7/2015 9/7/2015 0.10 PROD2 DRILL DLOG T 8200 ft,Tie into the K1 marker 8,200.0 8,233.0 00:00 00:06 correction of plus 1.0 ft. 9/7/2015 9/7/2015 0.15 PROD2 DRILL TRIP T 8233 ft,RIH 8,233.0 8,762.0 00:06 00:15 9/7/2015 9/7/2015 0.25 PROD2 DRILL DLOG T 8762 ft,Log RA marker,8745 ft. 8,762.0 8,776.0 00:15 00:30 9/7/2015 9/7/2015 1.80 PROD2 DRILL DRLG T 8221 ft,Continue drilling build section, 8,776.0 8,865.0 00:30 02:18 1.45 bpm at 3263 psi,BHP 3989, WHP 134, IA 0,OA 290,DHWOB 3k, ROP 54 fph. 9/7/2015 9/7/2015 3.85 PROD2 DRILL DRLG P 8865 ft,OBD 1.45 bpm at 3263,BHP 8,865.0 8,996.0 02:18 06:09 3989,WHP 134,IA 0,OA 390 9/7/2015 9/7/2015 2.20 PROD2 DRILL TRIP P POOH 8,996.0 72.1 06:09 08:21 9/7/2015 9/7/2015 1.70 PROD2 DRILL PULD P PJSM-Pressure undeploy and LD 72.1 0.0 08:21 10:03 build BHA#7 NOTE:Bit condition 1-1-BU-G-X-I-CT- BHA 9/7/2015 9/7/2015 1.85 PROD2 DRILL PULD P PJSM-MU lateral drilling BHA#8. 0,0 72.1 10:03 11:54 0.5°AKO motor and HYC short shank bi-center bit,pressure deploy BHA#8, MU to Coiltrak,surface test. 9/7/2015 9/7/2015 1.50 PROD2 DRILL TRIP P RIH with BHA#8 72.1 8,220.0 11:54 13:24 9/7/2015 9/7/2015 0.10 PROD2 DRILL DLOG P 8220 ft,Tie into the K1 marker 8,220.0 8,236.7 13:24 13:30 correction of minus 3.0 ft. 9/7/2015 9/7/2015 0.50 PROD2 DRILL TRIP P 8,236 ft,RIH,weight check PUW 33k, 8,236.7 8,996.0 13:30 14:00 RIW 11k 9/7/2015 9/7/2015 2.85 PROD2 DRILL DRLG P 8,996 ft,OBD 1.6 bpm @ 3475 psi, 8,996.0 9,106.7 14:00 16:51 BHP 3,975 psi,WHP 240,IA 0,OA 285 **Note: New 9.2 ppg Power Pro mud at the bit @ 8,996' 9/7/2015 9/7/2015 0.50 PROD2 DRILL DLOG T 9,106.7 ft,Geo wiper,mad pass to 9,106.7 9,106.7 16:51 17:21 troubleshoot MWD """Note:Trouble time for Resistivity Failure.(BHI) 9/7/2015 9/7/2015 1.75 PROD2 DRILL TRIP T 9107 ft,POOH due to Resisivity failure 9,106.7 72.0 17:21 19:06 ""'Note:Trouble time for USR failure.(BHI) 9/7/2015 9/7/2015 0.25 PROD2 DRILL SFTY T Tagged up,and spaced out,PJSM for 72.0 72.0 19:06 19:21 Updeploying BHA#8 9/7/2015 9/7/2015 1.75 PROD2 DRILL PULD T Pressure undeploy and LD lateral 72.0 0.0 19:21 21:06 BHA#8. 9/7/2015 9/7/2015 1.75 PROD2 DRILL PULD T PJSM,Deploy L1-01 lateral assembly, 0.0 72.0 21:06 22:51 BHA#9,test tools successfully,reset counters. Page 7/19 Report Printed: 12/18/2015 ° �erations Summary (with Timelogpths) .0.14 , 1G-12 conocoPhilltps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth ". Start Time End Time r'Dur(hr) _ Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/7/2015 9/8/2015 1.15 PROD2 DRILL TRIP T RIH,w/0.5°AKO,RR short shank 72.0 5,724.0 22:51 00:00 NOV-reed hycalog bi-center bit, 2.7"x3.25". 9/8/2015 9/8/2015 0.50 PROD2 DRILL TRIP T Continue RIH with L1-01 latreral BHA, 5,724.0 8,220.0 00:00 00:30 BHA#9 9/8/2015 9/8/2015 0.25 PROD2 DRILL DLOG T 8220 ft,Tie into the K1 marker 8,220.0 8,246.0 00:30 00:45 correction of minus 3.0 ft,Close EDC. PUW 32k 9/8/2015 9/8/2015 0.25 PROD2 DRILL TRIP T 8246 ft,Continue RIH through 8,246.0 9,105.0 00:45 01:00 window, 9/8/2015 9/8/2015 0.32 PROD2 DRILL DRLG T 9105 ft,Perform a MADD PASS up to 9,105.0 8,955.0 01:00 01:19 8955 ft, 9/8/2015 9/8/2015 0.25 PROD2 DRILL TRIP T 8955 ft,Trip RIH to bottom 8,955.0 9,107.0 01:19 01:34 "*"Note:End of USR downtime,Total of 8 hours. 9/8/2015 9/8/2015 6.75 PROD2 DRILL DRLG P 9107 ft,BOBD 1.7 bpm at 3565 psi, 9,107.0 9,510.0 01:34 08:19 BHP 3973,WHP 254,IA 0,OA 287 9/8/2015 9/8/2015 0.35 PROD2 DRILL WPRT P 9,510 ft,Wiper up hole,PUW 32k 9,510.0 9,000.0 08:19 08:40 9/8/2015 9/8/2015 0.25 PROD2 DRILL WPRT P 9,000 ft,Wiper in hole,RIW 12k 9,000.0 9,510.0 08:40 08:55 9/8/2015 9/8/2015 2.35 PROD2 DRILL DRLG P 9,510 ft,BOBD 1.7 bpm at 3,600 psi, 9,510.0 9,608.0 08:55 11:16 BHP 4,025,WHP 240,IA 26,OA 292 9/8/2015 9/8/2015 2.60 PROD2 DRILL DRLG P 9,608 ft,OBD 1.57 bpm at 3,500 psi, 9,608.0 9,628.0 11:16 13:52 BHP 4,040,WHP 260,IA 47,OA 295 **Note: Brought rate down due to high lateral vibrations 9/8/2015 9/8/2015 0.50 PROD2 DRILL WPRT P 9,628 ft,Wiper up hole,PUW 30k,jet 9,628.0 8,680.0 13:52 14:22 big tailpipe 9/8/2015 9/8/2015 0.50 PROD2 DRILL WPRT P 8,680 ft,Wiper in hole,RIW 12k 8,680.0 9,628.0 14:22 14:52 9/8/2015 9/8/2015 2.20 PROD2 DRILL DRLG P 9,628 ft,BOBD 1.53 bpm at 3220 psi, 9,628.0 9,638.0 14:52 17:04 BHP 4020,WHP 260,IA 59,OA 295 ""Note: Tried different pump rates and WOB unable to reduce lateral vibrations. Higher than expected lateral vibrations off bottom. 9/8/2015 9/8/2015 2.00 PROD2 DRILL TRIP T 9,636 ft,POOH to inspect BHA 9,638.0 72.0 17:04 19:04 9/8/2015 9/8/2015 0.25 PROD2 DRILL SFTY T At Surface,PJSM for undeploy 72.0 72.0 19:04 19:19 9/8/2015 9/8/2015 1.35 PROD2 DRILL PULD T Undeploy lateral drilling BHA#9 72.0 0.0 19:19 20:40 9/8/2015 9/8/2015 0.75 PROD2 DRILL PULD T Inspect Lateral BHA#m9,Found 3 0.0 0.0 20:40 21:25 chipped cutters,bit is balled up on one side.Confir with town on plan forward. Decision was made to PU new motor and new bi-center bit. """"Note:Bit grade 3-1-bt-n-xf-i-bu-pr 9/8/2015 9/8/2015 0.25 PROD2 DRILL SFTY T PJSM,for deploying lateral BHA, 0.0 0.0 21:25 21:40 BHA#10 Page 8/19 Report Printed: 12/18/2015 or Aerations Summary (with Timelog epths) 1.0 1G-12 Con000`f'hil ips AGmA: Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(ftKB) 9/8/2015 9/8/2015 1.25 PROD2 DRILL PULD T Pressure deploy BHA#10,test coiltrak 0.0 72.1 21:40 22:55 tools. 9/8/2015 9/9/2015 1.08 PROD2 DRILL TRIP T Tag up,reset counters,RIH with L1- 72.1 4,547.0 22:55 00:00 01 lateral drilling BHA#10 9/9/2015 9/9/2015 0.65 PROD2 DRILL TRIP T 4547 ft,Continue RIH with lateral 4,547.0 8,220.0 00:00 00:39 drilling BHA 9/9/2015 9/9/2015 0.25 PROD2 DRILL DLOG T 8220 ft,Tie into the K1 marker 8,220.0 8,245.0 00:39 00:54 correction of minus 4.5 ft. 9/9/2015 9/9/2015 0.50 PROD2 DRILL TRIP T 8245 ft,Continue RIH 8,245.0 9,636.0 00:54 01:24 9/9/2015 9/9/2015 2.50 PROD2 DRILL DRLG P 9636 ft,OBD 1.7 bpm at 3460 psi, 9,636.0 9,682.0 01:24 03:54 BHP 3992,WHP 174,IA 0,OA 289 """"Note:Vibration levels between 3-4 9/9/2015 9/9/2015 6.00 PROD2 DRILL DRLG P 9,682 ft,OBD 1.2 bpm at 2650 psi, 9,682.0 9,692.0 03:54 09:54 BHP 4030,WHP 290, IA 25,OA 292, ROP 4-5 fph **Note: Capable of lowering vibration levels with lower pump rate and maintaining 3k WOB. Vibration levels 2-3 9/9/2015 9/9/2015 5.00 PROD2 DRILL DRLG P 9,692 ft,OBD 1.68 bpm at 3825 psi, 9,692.0 9,910.0 09:54 14:54 BHP 4055,WHP 210, IA 95,OA 294, ROP 25-80 fph 9/9/2015 9/9/2015 0.30 PROD2 DRILL WPRT P 9,910 ft,wiper up hole,PUW 32k 9,910.0 9,040.0 14:54 15:12 9/9/2015 9/9/2015 0.35 PROD2 DRILL WPRT P 9,040 ft,wiper in hole,RIW 11k 9,040.0 9,910.0 15:12 15:33 9/9/2015 9/10/2015 8.45 PROD2 DRILL DRLG P 9,910 ft,BOBD 1.7 bpm at 3810 psi, 9,910.0 10,133.0 15:33 00:00 BHP 4030,WHP 155, IA 100,OA 295, Drilling with short BHA wipers,and different flow rates to limit vibration levels on coiltrak tools. 9/10/2015 9/10/2015 3.50 PROD2 DRILL DRLG P 10133 ft,OBD 1.45 bpm at 3366 psi, 10,133.0 10,214.0 00:00 03:30 BHP 4051,WHP 175, IA 111,OA 294 9/10/2015 9/10/2015 0.75 PROD2 DRILL WPRT P 10214 ft,Wiper up hole PUW 32k, 10,214.0 9,232.0 03:30 04:15 pump 5x5 sweep 9/10/2015 9/10/2015 0.50 PROD2 DRILL WPRT P 9232 ft,Wiper back in hole RIW ilk 9,232.0 10,214.0 04:15 04:45 9/10/2015 9/10/2015 7.25 PROD2 DRILL DRLG P 10214 ft,BOBD 1.65 bpm at 3760, 10,214.0 10,400.0 04:45 12:00 BHP 4050,WHP 177, IA 168,OA 295, ROP 20-40 fph 9/10/2015 9/10/2015 2.25 PROD2 DRILL DRLG P 10400 ft,BOBD 1.65 bpm at 3760, 10,400.0 10,565.0 12:00 14:15 BHP 4070,WHP 90, IA 280,OA 300, ROP 50-100 fph 9/10/2015 9/10/2015 1.50 PROD2 DRILL WPRT P 10565 ft,Wiper up hole PUW 30k, 10,565.0 8,675.0 14:15 15:45 pump 5x5 sweep,jet big tail pipe ""Note: ECD Survey at the window 11.9 ppg,choke 120 psi, WHP 90 psi, BHP 4,000 psi, 10 fpm,8,776 ft ""Note: In Big tail pipe 8680-8690' observed negative DHWOB, motorwork,and overpull 9/10/2015 9/10/2015 0.25 PROD2 DRILL WPRT P 8675 ft,Wiper in hole,RIW 11k 8,675.0 8,765.0 15:45 16:00 Page 9/19 Report Printed: 12/18/2015 Oil It erations Summary (with Timelog•pths) 1G-12 conooa'hillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code _ Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/10/2015 9/10/2015 0.15 PROD2 DRILL DLOG P 8765 ft,Tie into the RA fora plus 1.0 ft 8,765.0 8,783.0 16:00 16:09 correction 9/10/2015 9/10/2015 0.35 PROD2 DRILL WPRT P 8,783 ft,Wiper in hole,stack weight 8,783.0 10,236.0 16:09 16:30 9/10/2015 9/10/2015 0.60 PROD2 DRILL WPRT P 10,236 ft,Wipe up hole,PUW 38k 10,236.0 9,015.0 16:30 17:06 9/10/2015 9/10/2015 1.00 PROD2 DRILL ‘WPRT P 9,015 ft,Wipe in hole,RIW 9k 9,015.0 10,565.0 17:06 18:06 *"`Note:stack weight at 9,730 ft, 10,120 ft, 10,195 ft,and 10,240 ft. lower pump rate to pass through. 9/10/2015 9/10/2015 2.00 PROD2 DRILL DRLG P 10,565 ft,BOBD 1.64 bpm 3359,BHP 10,565.0 10,606.0 18:06 20:06 4034,WHP 78,IA 225,OA 297 9/10/2015 9/10/2015 1.00 PROD2 DRILL WPRT P 10,606 ft,Wiper up hole to check hole 10,606.0 10,000.0 20:06 21:06 stability due to increase in annular pressure. 9/10/2015 9/10/2015 0.50 PROD2 DRILL WPRT P 10,000 ft,Wiper back in hole,RIW 6k, 10,000.0 10,606.0 21:06 21:36 lower pump rate to 0.78 bpm at 2050 psi, 9/10/2015 9/10/2015 0.75 PROD2 DRILL DRLG P 10,606 ft,BOBD 1.5 bpm at 3500 psi, 10,606.0 10,624.0 21:36 22:21 BHP 4153,WHP 78, IA 127,OA 295 9/10/2015 9/10/2015 0.25 PROD2 DRILL DRLG P 10624 ft,New mud at bit 10,624.0 10,624.0 22:21 22:36 9/10/2015 9/11/2015 1.40 PROD2 DRILL DRLG P 10624 ft,BOBD 1.5 bpm at 3560 psi, 10,624.0 10,655.0 22:36 00:00 BHP 4081,WHP 300, IA 8,OA 291 9/11/2015 9/11/2015 1.00 PROD2 DRILL DRLG P 10655 ft,OBD 1.5 bpm at 3351 psi, 10,655.0 10,677.0 00:00 01:00 BHP 4104,WHP 295, IA 5,OA 291 9/11/2015 9/11/2015 1.50 PROD2 DRILL WPRT P 10677 ft,annular pressure spikes to 10,677.0 8,730.0 01:00 02:30 4500 psi,Wiper up hole PUW 32k, pump 5x5 sweep,jet big tail pipe **Note: In Big tail pipe 8680-8690' observed negative DHWOB, motorwork,and overpull,set down+ 9k,work pipe free,pump additional 5x5 sweep,sweep 10 bbls above BHA,open EDC,wiper up hole to 6000 ft. 9/11/2015 9/11/2015 1.50 PROD2 DRILL 'WPRT P 8730 ft,wiper up hole chasing sweep 8,730.0 6,000.0 02:30 04:00 to 6000 ft pumping 2.2 bpm.PUW 30k 9/11/2015 9/11/2015 0.50 PROD2 DRILL WPRT P 6000 ft.RIW 14k 6,000.0' 8,220.0 04:00 04:30 9/11/2015 9/11/2015 0.25 PROD2 DRILL DLOG P 8220 ft,Tie into the K1 marker 8,220.0 8,245.0 04:30 04:45 correction of plus 3.0 ft. 9/11/2015 9/11/2015 0.25 PROD2 DRILL WPRT P RIH to 8730 ft,Close EDC,Orient TF 8,245.0 8,730.0 04:45 05:00 to 15°LOHS 9/11/2015 9/11/2015 1.00 PROD2 DRILL WPRT P 8730 ft,PUW 30k,wiper in hole 8,730.0 8,800.0 05:00 06:00 through window **Note: Unable to work past 8800 ft 9/11/2015 9/11/2015 1.50 PROD2 DRILL TRIP T 8,800 ft,POOH to PU 1.5°AKO motor 8,800.0 72.2 06:00 07:30 and D331 mill 9/11/2015 9/11/2015 1.50 PROD2 DRILL PULD T PJSM,Pressure Un-deploy and LD 72.2 0.0 07:30 09:00 BHA#10 "Note: Bit grade 2-2-BT-A-X-I-BU-HP Page 10/19 Report Printed: 12/18/2015 Aerations Summary (with Timelog epths) 3 1G-12 Conoco`Phiillps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code : Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/11/2015 9/11/2015 1.50 PROD2 DRILL PULD T PJSM-MU BHA#11. 1.5°AKO motor 0.0 62.4 09:00 10:30 and D331 mill. Pressure deploy BHA #11,MU to Coiltrak,surface test. 9/11/2015 9/11/2015 1.75 PROD2 DRILL ,TRIP T 'Tag up,reset counters,RIH with 62.4 8,210.0 10:30 12:15 BHA#11,EDC closed and pumping 1.5 bpm 9/11/2015 9/11/2015 0.25 PROD2 DRILL DLOG 'T 8210 ft,Tie into the K1 marker 8,210.0 8,227.0 12:15 12:30 correction of minus 4.0 ft. 9/11/2015 9/11/2015 0.75 PROD2 DRILL WPRT T 8227 ft,RIH with EDC closed and 8,227.0 8,996.0 12:30 13:15 pumping 1.5 bpm **Note: Orient to as drilled toolface, set down at 8807 ft with small amount of motorwork and annular pressure spike of 4500 psi, PUH,work back down able to get to EOB 9/11/2015 9/11/2015 0.25 PROD2 DRILL WPRT T 8996 ft,at EOB wipe up hole at as 8,996.0 8,760.0 13:15 13:30 drilled toolface and pumping 1.5 bpm, PUW 30k 9/11/2015 9/11/2015 1.25 PROD2 DRILL WPRT T 8760 ft,Wipe in hole at as drilled 8,760.0 10,677.0 13:30 14:45 toolface and pumping 1.5 bpm **Note: Set down at 10175 ft with light motorwork and in order to get by 10280 ft had to drop rate to 0.75 bpm. 9/11/2015 9/11/2015 3.75 PROD2 DRILL WPRT T 10677 ft,Wipe up hole pumping at 10,677.0 62.4 14:45 18:30 1.85 bpm, PUW 33k "Note: Packed off at 10,140 ft with 7k overpull,jog big tailpipe due to packoff event 9/11/2015 9/11/2015 0.25 PROD2 DRILL TRIP T Tag up at surface,reset counters, 62.4 62.4 18:30 18:45 9/11/2015 9/11/2015 0.25 PROD2 DRILL TRIP T RIH,stop at 510 ft,close in choke to, 62.4 510.0 18:45 19:00 open EDC,pump 1.8 bpm,opening choke to managed pressure schedule, observed no vibration levels on sensor,close in choke,close EDC, bring pump online. 9/11/2015 9/11/2015 1.10 PROD2 DRILL TRIP T RIH,following manage pressure 510.0 8,210.0 19:00 20:06 schedule. 9/11/2015 9/11/2015 0.25 PROD2 DRILL DLOG T 8210 ft,Tie into the K1 marker 8,210.0 8,847.0 20:06 20:21 correction of minus 4.0 ft. 9/11/2015 9/11/2015 0.50 PROD2 DRILL TRIP T 8830 ft,and 8850 ft,stack out weight, 8,847.0 9,030.0 20:21 20:51 High Side TF PUH,Run back through clean to 9030 ft. 9/11/2015 9/11/2015 0.65 PROD2 •DRILL DISP T Line up and circulate 11.8 ppg 9,030.0 9,030.0 20:51 21:30 completion fluid down coil. 9/11/2015 9/11/2015 1.50 PROD2 DRILL DISP T POOH,displacing well to 11.8 ppg 9,030.0 62.4 21:30 23:00 completion fluid,pass through window clean and XO 3.5"x5.5" 9/11/2015 9/11/2015 0.50 PROD2 DRILL SFTY T At Surface,check well for flow,PJSM 62.4 62.4 23:00 23:30 for LD clean out BHA,BHA#11 9/11/2015 9/12/2015 0.50 PROD2 DRILL PULD 'T LD Cleanout BHA#11 62.4 24.1 23:30 00:00 9/12/2015 9/12/2015 1.00 PROD2 DRILL PULD T Continue LD cleanout BHA#11,tools 24.1 0.0 00:00 01:00 OOH,4 bbls to fill the hole. Page 11/19 Report Printed: 12/18/2015 or �'perations Summary (with Timelog epths) 1G-12 ConocaP'hillps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(ftKB) 9/12/2015 9/12/2015 0.75 PROD2 DRILL PULD P Install swizzle stick and stab INJH 0.0 0.0 01:00 01:45 onto well to jet BOP stack.Close swab valve 9/12/2015 9/12/2015 0.50 PROD2 DRILL CTOP P Valve crew on location service tree 0.0 0.0 01:45 02:15 valves. 9/12/2015 9/12/2015 0.75 PROD2 WHDBOP RURD P Prep for BOP test,grease and 0.0 0.0 02:15 03:00 function rig Valves,Set up test pump, perform shell test 9/12/2015 9/12/2015 9.00 PROD2 WHDBOP BOPE P Begin BOPE test 250/3800 psi, 0.0 0.0 03:00 12:00 annular 250/2500 psi. ****Note:Witness waived by Lou Grimaldi by phone 8:29pm 9/11/15 9/12/2015 9/12/2015 0.50 PROD2 DRILL DISP P Displace coil back to 11.8 ppg 0.0 0.0 12:00 12:30 completion fluid 9/12/2015 9/12/2015 0.50 PROD2 DRILL SFTY P Conduct no flow check. PJSM to PU 0.0 0.0 12:30 13:00 and MU BHA#12 9/12/2015 9/12/2015 1.00 PROD2 DRILL PULD T PU and MU BHA#12-Agitator,0.5° 0.0 78.2 13:00 14:00 AKO motor,and Hycalog 2.7 x 3"bi- center bit. MU to Coiltrak and surface test. **Note: Replaced flow sub and installed checks. 9/12/2015 9/12/2015 2.00 PROD2 DRILL TRIP T Tag up,reset counters,RIH with L1- 78.2 8,225.0 14:00 16:00 01 lateral drilling BHA#12 **Note: Surface tested agitator 9/12/2015 9/12/2015 0.25 PROD2 DRILL DLOG T 8225 ft,Tie into K1 marker for a minus 8,225.0 8,243.1 16:00 16:15 5.0 ft correction 9/12/2015 9/12/2015 0.25 PROD2 DRILL TRIP T 8243 ft,Continue RIH with L1-01 8,243.1 8,700.0 16:15 16:30 lateral drilling BHA#12 9/12/2015 9/12/2015 2.00 PROD2 DRILL DISP T Displace well to 9.1 ppg Flo-Pro, 8,700.0 8,700.0 16:30 18:30 Weight check PUW 30k 9/12/2015 9/12/2015 0.75 PROD2 DRILL TRIP T 8700 ft,PUW 28k,RIH to bottom 8,700.0 10,678.0 18:30 19:15 9/12/2015 9/13/2015 4.75 PROD2 DRILL DRLG P 10678 ft,BOBD 1.63 bpm at 3850 psi, 10,678.0 10,879.0 19:15 00:00 BHP 4089,WHP 374,IA 0,OA 242, PUW 34k 9/13/2015 9/13/2015 1.75 PROD2 DRILL DRLG P 10879 ft,OBD 1.52 bpm at 3610 psi, 10,879.0 10,892.0 00:00 01:45 DIFF 770,BHP 4115,WHP 392, IA 21,OA 239 9/13/2015 9/13/2015 0.75 PROD2 DRILL WPRT P 10892 ft,wiper up hole to 9390 ft. 10,892.0 9,390.0 01:45 02:30 PUW 36k 9/13/2015 9/13/2015 0.50 PROD2 DRILL WPRT P 9390 ft,wiper back in hole,RIW 12k 9,390.0 10,892.0 02:30 03:00 9/13/2015 9/13/2015 4.00 PROD2 DRILL DRLG P 10892 ft,BOBD 1.6 bpm at 3900 psi, 10,892.0 11,050.0 03:00 07:00 BHP 4067,WHP 299,DIFF 800,IA 35,OA 237 9/13/2015 9/13/2015 1.35 PROD2 DRILL WPRT P 11050 ft,wiper up hole,PUW 33k 11,050.0 8,680.0 07:00 08:21 **Note: 14k overpull at 10,022' 9/13/2015 9/13/2015 0.50 PROD2 DRILL 'CIRC P 8730 ft,Jet big tai 1pipe at 1.6 bpm 8,680.0 8,730.0 08:21 08:51 9/13/2015 9/13/2015 0.15 PROD2 DRILL DLOG P Tie into RA for a plus 3.0 ft correction 8,730.0 8,787.7 08:51 09:00 9/13/2015 9/13/2015 1.00 PROD2 DRILL WPRT P 8787 ft,Wipe back in hole,RIW 11k 8,787.7 11,050.0 09:00 10:00 9/13/2015 9/13/2015 4.75 PROD2 DRILL DRLG P 11050 ft,BOBD 1.6 bpm at 4050 psi, 11,050.0 11,250.0 10:00 14:45 BHP 4137,WHP 345,IA 17,OA 226 Page 12/19 Report Printed: 12/18/2015 d Iperations Summary (with TimelogSpths) 0 1G-12 Cortoilllps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth. Start Time ' End Time Our(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(ftKB) 9/13/2015 9/13/2015 0.50 PROD2 DRILL WPRT P 11250 ft,Wiper up hole,PUW 33k 11,250.0 10,150.0 14:45 15:15 9/13/2015 9/13/2015 0.50 PROD2 DRILL WPRT P 10150 ft,Wiper in hole,RIW 10k 10,150.0 11,250.0 15:15 15:45 9/13/2015 9/13/2015 5.00 PROD2 DRILL DRLG P 11250 ft,BOBD 1.6 bpm at 4160 psi, 11,250.0 11,460.0 15:45 20:45 BHP 4128,WHP 195,IA 90,OA 223 9/13/2015 9/13/2015 0.75 PROD2 DRILL WPRT P 11460 ft,Wiper up hole PUW 30k 11,460.0 10,022.0 20:45 21:30 9/13/2015 9/13/2015 1.00 PROD2 DRILL WPRT T 10022 ft,Slowed down from 40 fpm to 10,022.0 10,022.0 21:30 22:30 24 fpm,set to DTF,pulled 34k,RBIH set down 7.6k DHWOB,motor stalled, shut down pump,worked pipe,moved up hole 10017k,no downward movement,lost swab on pump#2, switch over to pump#1.Notified town Cody P. 9/13/2015 9/14/2015 1.50 PROD2 DRILL WPRT T Conference call with town team, 10,022.0 10,022.0 22:30 00:00 decision was made to pressure up on the annular to 11.3 ppg(3830 psi), work pipe in hole, 9/14/2015 9/14/2015 1.00 PROD2 DRILL WPRT T Stuck at 10022 ft,unable to move coil 10,022.0 10,022.0 00:00 01:00 up or down,keeping annullar pressure at 3780 to 3820 psi, 9/14/2015 9/14/2015 1.50 PROD2 DRILL WPRT T Maintain annular pressure 3780- 10,022.0 10,022.0 01:00 02:30 3820psi,stacked out at 10022 ft. minus 5k DHWOB 9/14/2015 9/14/2015 2.00 PROD2 DRILL WPRT T Maintain annular pressure 3800 psi, 10,022.0 10,022.0 02:30 04:30 work pipe from 30k to-10k,no success 9/14/2015 9/14/2015 3.00 PROD2 DRILL WPRT T Maintain annular perssure 3650- 10,022.0 10,022.0 04:30 07:30 3800 psi,work pipe from 51k to-10k. **Note: Meeting with town and decision to pull 80k was made 9/14/2015 9/14/2015 0.25 PROD2 DRILL WPRT T PJSM-Pulling over on coil string 10,022.0 10,022.0 07:30 07:45 hazards Pull 77k,roll pump in tension,turn TF RIH to-10k,Pull 78k,roll pump in tension,turn TF RIH to-10k,TF maxed out to right, Pull 80k,orient to left and fish came free 9/14/2015 9/14/2015 3.00 PROD2 DRILL TRIP T POOH using managed pressure and 10,022.0 47.5 07:45 10:45 monitoring hole conditions "Note: Pumped 5 x5 sweep and Jet 5 1/2"big tail pipe 9/14/2015 9/14/2015 1.25 PROD2 DRILL PULD T PJSM-Pressure un-deploy and LD 47.5 0.0 10:45 12:00 BHA#12 **Note: BHA#12 parted at lower HOT sub,leaving bi-center bit,motor, agitator,and FVS in hole. Length of fish 17.49 ft. TOF at 10,004.51' 9/14/2015 9/14/2015 1.50 PROD2 STK PULD T PJSM,P/U BHA#13 Anchored billet, 0.0 72.9 12:00 13:30 Load into PDL 9/14/2015 9/14/2015 1.00 PROD2 STK SVRG T Service INJH 72.9 72.9 13:30 14:30 Page 13/19 Report Printed: 12/18/2015 Operations Summary (with Timelog tths) ►ti 1G-12 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 9/14/2015 9/14/2015 2.50 PROD2 STK SVRG T Mechanic servicing and inspecting 72.9 72.9 14:30 17:00 injector,inspect coil and coil connector. Found serveral broken keeper pins on chains. Replace keepers **"*Note:Nabors Downtime 2.5 years. 9/14/2015 9/14/2015 1.75 PROD2 STK PULD T PJSM, PD Anchored billet BHA,BHA# 72.9 72.9 17:00 18:45 13 9/14/2015 9/14/2015 1.75 PROD2 STK TRIP T RIH,BHA#13 Open Hole Anchored 72.9 8,200.0 18:45 20:30 Billet 9/14/2015 9/14/2015 0.25 PROD2 STK DLOG T 8200 ft,PUW 27k,RIW 11k,Tie into 8,200.0 8,245.0 20:30 20:45 the K1 marker correction of minus 5.0 ft, 9/14/2015 9/14/2015 0.25 PROD2 STK TRIP T RIH 8,245.0 8,600.0 20:45 21:00 9/14/2015 9/14/2015 1.00 PROD2 STK TRIP T 8600 ft,Close EDC,No pumping until 8,600.0 8,807.0 21:00 22:00 on depth,set down 4k 8750 ft,weight fell back to 1.3k,continue RIH,set down at 8800 ft-8807 ft,2-5k,PUW 29k ""Note:Call town engineer for plan forward,POOH 9/14/2015 9/15/2015 2.00 PROD2 STK TRIP T 8807 ft,POOH,with open EDC 8,807.0 1,812.0 22:00 00:00 9/15/2015 9/15/2015 0.50 PROD2 STK PULD T Continue POOH with open hole 1,812.0 72.9 00:00 00:30 anchored billet. 9/15/2015 9/15/2015 0.25 PROD2 STK SFTY T PJSM for undeploy OH anchored 72.9 72.9 00:30 00:45 BHA#13 9/15/2015 9/15/2015 1.00 PROD2 STK PULD T Undeploy OH Anchored billet BHA# 72.9 0.0 00:45 01:45 13 9/15/2015 9/15/2015 0.75 PROD2 DRILL PULD T Deploy cleanout BHA,BHA#14 0.0 62.4 01:45 02:30 9/15/2015 9/15/2015 1.25 PROD2 DRILL TRIP T Tag up reset counters,RIH with 62.4 8,210.0 02:30 03:45 cleanout BHA 1.5°ako motor and D331 mill, 9/15/2015 9/15/2015 0.25 PROD2 DRILL DLOG T 8210 ft,Tie into the K1 marker 8,210.0 8,220.0 03:45 04:00 correction of minus 4.5 ft 9/15/2015 9/15/2015 0.90 PROD2 DRILL TRIP T 8220 ft,Close EDC, Continue RIH, 8,220.0 9,930.0 04:00 04:54 Clean trip through window and to clean out depth of 9930' 9/15/2015 9/15/2015 3.50 PROD2 DRILL TRIP T Pump 5X5 sweeps and POOH, Pump 9,930.0 62.9 04:54 08:24 second set of sweeps for 5 1/2" tubing.Observed some annular packing at tubing tail,8665' 9/15/2015 9/15/2015 1.20 PROD2 DRILL PULD T Tag up and space out, PJSM,PUD 62.9 0.0 08:24 09:36 BHA#14 FCO BHA with 1.5°motor and D-331 9/15/2015 9/15/2015 2.00 PROD2 STK PULD T PJSM,M/U and deploy BHA#15, 0.0 72.9 09:36 11:36 Anchored billet 9/15/2015 9/15/2015 1.00 PROD2 STK SVRG T Service rig,Flush chain lubrication 72.9 72.9 11:36 12:36 system 9/15/2015 9/15/2015 0.50 PROD2 STK PULD T M/U coil and surface test tools,Tag up 72.9 72.9 12:36 13:06 and set counters 9/15/2015 9/15/2015 1.80 PROD2 STK TRIP T Trip in well,EDC open pumping 72.9 8,237.0 13:06 14:54 minimum rate 9/15/2015 9/15/2015 0.30 PROD2 STK DLOG T Log K1 for-4'correction,PUW=30K 8,237.0 8,250.0 14:54 15:12 Page 14/19 Report Printed: 12/18/2015 iterations Summary (with Timelog•pths) A 1G-12 Conon hiIhps Alexi;+•. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/15/2015 9/15/2015 1.60 PROD2 STK TRIP T Continue in well,clean pass through 8,250.0 9,911.8 15:12 16:48 window.Clear trip to 9911.75.Orient to 10R.See tool shift at 4100 PSI.Set down 3K 9/15/2015 9/15/2015 1.75 PROD2 STK TRIP T Trip out,Open EDC in 5 1/2 Tubing 9,911.8 65.5 16:48 18:33 9/15/2015 9/15/2015 1.25 PROD2 STK PULD T PJSM.PUD BHA#15,LD setting tool 65.5 0.0 18:33 19:48 9/15/2015 9/15/2015 1.00 PROD2 STK PULD T PJSM.PU motor/bit.PD BHA#16 0.0 72.2 19:48 20:48 9/15/2015 9/15/2015 2.30 PROD2 STK TRIP T RIH w/KO/build assembly HCC RB 72.2 9,901.0 20:48 23:06 bit,tie-in to K1 for-4'correction, continue in hole.Dry tag billet @ 9,901' 9/15/2015 9/16/2015 0.90 PROD2 STK KOST T Several attempts to get started on 9,900.5 9,900.5 23:06 00:00 billet,several stalls,string weight stacking 9/16/2015 9/16/2015 1.00 PROD2 STK KOST T Several more stalls,pump 5 x5 9,900.5 9,900.5 00:00 01:00 sweeps 9/16/2015 9/16/2015 1.50 PROD2 STK KOST T Start milling off billet,off billet @ 9,900.5 9,902.0 01:00 02:30 9,902'. 9/16/2015 9/16/2015 1.00 PROD2 DRILL DRLG T Drill ahead build section: 1.50 BPM @ 9,902.0 9,925.0 02:30 03:30 3,650 PSI,BHP=4,230 PSI,CTW- 11.5K.Drift billet. 9/16/2015 9/16/2015 3.80 PROD2 DRILL DRLG T Drill ahead: 1.48 BPM @ 3,790 PSI, 9,925.0 10,100.0 03:30 07:18 BHP=4,185 PSI,CTW=10.5K, WOB=2.4K,good ROP for forty feet, ROP=15. 9/16/2015 9/16/2015 1.30 PROD2 DRILL WPRT T 10,100 wiper trip to 9000',PUW=29K 10,100.0 10,100.0 07:18 08:36 9/16/2015 9/16/2015 2.00 PROD2 DRILL DRLG T 10,100',Drill1.53 BPM @ 3752 PSI 10,100.0 10,190.0 08:36 10:36 FS,BHP=4188 9/16/2015 9/16/2015 0.90 PROD2 DRILL DRLG T 10,190 bring pump rate up to 10,190.0 10,260.0 10:36 11:30 1.65BPM,FS 3850 9/16/2015 9/16/2015 3.20 PROD2 DRILL TRIP T 10,260',Call end of build,Pump 5X5 10,260.0 71.9 11:30 14:42 sweeps,Mild packing in window,RIH to relieve packing,Circulate,Trip up at 20 FPM came through clean.Mild pack off,jog in,PUH slower and come through clean.AVG DLS 13.2° 9/16/2015 9/16/2015 1.60 PROD2 DRILL PULD T At surface,tag up and space out. 71.9 0.0 14:42 16:18 PJSM,PUD BHA#16 9/16/2015 9/16/2015 1.00 PROD2 DRILL PULD T PJSM.PD BHA#17 0.0 78.2 16:18 17:18 9/16/2015 9/16/2015 2.75 PROD2 DRILL TRIP T RIH w/Lateral drilling assembly.New 78.2 10,260.0 17:18 20:03 agitator,new HCC bit,and.5 AKO motor.Close EDC,test agitator at surface.Tie-in to K1 for-6'correction, continue in hole.Bring pump online high differential pressure.Start pumping new mud system. 9/16/2015 9/16/2015 3.10 PROD2 DRILL DRLG T Drill ahead: 1.30 BPM @ 4,340 PSI, 10,260.0 10,460.0 20:03 23:09 BHP=4.110 PSI,CTW=10.5K, WOB=2K,ROP=65.New mud at bit @ 10,293'.Still high differential pressure. 9/16/2015 9/17/2015 0.85 PROD2 DRILL WPRT T Wiper trip to 9,000'.MAD pass for 10,460.0 10,460.0 23:09 00:00 resistivity relog. Page 15/19 Report Printed: 12/18/2015 r Iterations Summary (with Timelog•pths) 3 1G-12 Conoc4billips Akzo:. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth, Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)'. 9/17/2015 9/17/2015 0.40 PROD2 DRILL WPRT T RBIH after wiper/MAD pass. 10,460.0 10,460.0 00:00 00:24 9/17/2015 9/17/2015 3.50 PROD2 DRILL DRLG T DOBD: 1.30 BPM @ 4,095 PSI,BHP= 10,460.0 10,485.0 00:24 03:54 4,150 PSI,CTW=8.5K,WOB=1.8K, ROP is low,ankerite?Continue dealing with high differential pressure. Make short wiper trip,call town for direction. 9/17/2015 9/17/2015 0.45 PROD2 DRILL WPRT T Short wiper uphole.Town engineer, 10,485.0 10,485.0 03:54 04:21 keep drilling,RBIH. 9/17/2015 9/17/2015 2.50 PROD2 DRILL DRLG T DOBD: 1.18 BPM @ 3,740 PSI,BHP= 10,485.0 10,496.0 04:21 06:51 4,135 PSI,CTW=9.5K,WOB=2.4K, ROP=8.Ankerite!High differential pressure! 9/17/2015 9/17/2015 3.60 PROD2 DRILL WPRT T 10496,Pull off bottom for free spin, 10,496.0 73.0 06:51 10:27 PUW=32K,Diff pressure anywhere from 900 to 1650 PSI,Trip out to investigate.Open EDC @ 8234.All diff went to zezo 9/17/2015 9/17/2015 1.00 PROD2 DRILL PULD T At surface,Tag up and space out, 73.0 0.0 10:27 11:27 PJSM PUD BHA#17 9/17/2015 9/17/2015 1.00 PROD2 DRILL OTHR T Test tool string to identify cause of 0.0 0.0 11:27 12:27 high differential pressure.No rubber in bit,Able to move aire through motor and agitator.Break coil track below EDC and move fluid and air though- all normal.Configure new BHA with new bit-motor-and agitator 9/17/2015 9/17/2015 0.60 PROD2 DRILL PULD T PJSM, PD BHA#18 with.5°motor, 0.0 78.0 12:27 13:03 new Hyc bi center,new agitator,M/U to coil and surface test 9/17/2015 9/17/2015 2.10 PROD2 DRILL TRIP T Trip in well with BHA#18,Surface test 78.0 8,220.0 13:03 15:09 motor and agitator @ 200',Diff pressure 738 PSI @ 1.5BPM,Pump pressure 4K,Continue in 9/17/2015 9/17/2015 0.20 PROD2 DRILL DLOG T Log K1 for-5'correction 8,220.0 8,250.0 15:09 15:21 9/17/2015 9/17/2015 1.10 PROD2 DRILL TRIP T Continue in well,Clean pass through 8,250.0 10,496.0 15:21 16:27 window,build,and billet 9/17/2015 9/18/2015 7.55 PROD2 DRILL DRLG T 10496',Drilling on ankerite, 1.4 BPM 10,496.0 10,656.0 16:27 00:00 @ 3750 PSI FS,BHP=4170,broke free from ankerite 10,511'.ROP up to 65.Found ankerite again @ 10,653'. 9/18/2015 9/18/2015 7.30 PROD2 DRILL DRLG T Continue drilling ahead on ankerite @ 10,656.0 10,690.0 00:00 07:18 10,656'. 1.50 BPM @ 4,180 PSI, BHP=4,190 PSI,CTW=6K,WOB=2.4, ROP=5. 9/18/2015 9/18/2015 0.80 PROD2 DRILL WPRT T Wiper to 9950',PUW=28K 10,690.0 10,690.0 07:18 08:06 9/18/2015 9/18/2015 1.80 PROD2 DRILL DRLG T 10690',Drill, 1.4BPM @ 3850PSI FS, 10,690.0 10,698.0 08:06 09:54 BHP=4160 9/18/2015 9/18/2015 0.10 PROD2 DRILL WPRT T BHA Wiper to 10672,PUW=27K,Low 10,698.0 10,698.0 09:54 10:00 ROP Ankorite in samples 9/18/2015 9/18/2015 3.30 PROD2 DRILL DRLG T 10698',Drill, 1.5 BPM @ 4118 PSI 10,698.0 10,711.0 10:00 13:18 FS,BHP=4160 9/18/2015 9/18/2015 2.20 PROD2 DRILL DRLG T Drilling Break,ROP 40 FPH, 1.5 BPM 10,711.0 10,760.0 13:18 15:30 @ 3980PSI FS,BHP=4188 9/18/2015 9/18/2015 0.20 PROD2 DRILL WPRT T BHA wiper, 100',PUW=27K 10,760.0 10,760.0 15:30 15:42 Page 16/19 Report Printed: 12/18/2015 Iperations Summary (with Timelogipths) 0 1G-12 ConocoPhilltps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/18/2015 9/18/2015 4.15 PROD2 DRILL DRLG T 10760',Drill, 1.48 BPM @ 4000PSI 10,760.0 10,890.0 15:42 19:51 FS,BHP=4160 9/18/2015 9/18/2015 2.40 PROD2 DRILL WPRT T Wiper to 8,675',PUW=28K,jet 5.5" 10,890.0 10,890.0 19:51 22:15 liner max rate,tie-in to RA tag for+.5' correction,RBIH. 9/18/2015 9/19/2015 1.75 PROD2 DRILL DRLG T Drill ahead: 1.48 BPM @ 4,255 PSI, 10,890.0 10,959.0 22:15 00:00 BHP=4,205 PSI,CTW=6K,WOB=2K, ROP=40. 9/19/2015 9/19/2015 3.50 PROD2 DRILL DRLG T Drill ahead: 1.47 BPM @ 4,245 PSI, 10,959.0 11,090.0 00:00 03:30 BHP=4,215 PSI,CTW=5.5K, WOB=2K,ROP=40. 9/19/2015 9/19/2015 0.85 PROD2 DRILL WPRT T Wiper to 9,990',PUW=29K,RBIH. 11,090.0 11,090.0 03:30 04:21 9/19/2015 9/19/2015 2.60 PROD2 DRILL DRLG T Drill ahead: 1.46 BPM @ 4,270 PSI, 11,090.0 11,180.0 04:21 06:57 BHP=4,210 PSI,CTW=6K, WOB=1.8K,ROP=45. 9/19/2015 9/19/2015 0.10 PROD2 DRILL WPRT T BHA Wiper,PUW=33K 11,180.0 11,180.0 06:57 07:03 9/19/2015 9/19/2015 2.70 PROD2 DRILL DRLG T 11180',Drill, 1.5 BPM @ 4144 PSI 11,180.0 11,290.0 07:03 09:45 FS,BHP=4218 9/19/2015 9/19/2015 2.30 PROD2 DRILL WPRT T 11290',Wiper to 8675 with sweeps, 11,290.0 11,290.0 09:45 12:03 PUW=28K,Tie into RA for+1.5'.5 1/2 looked clear 9/19/2015 9/19/2015 3.40 PROD2 DRILL DRLG T 11290',Drill, 1.48 BPM @ 4173 PSi 11,290.0 11,363.0 12:03 15:27 FS,BHP=4244 9/19/2015 9/19/2015 0.30 PROD2 DRILL WPRT T Stacking,can not get it to drill,-6K 11,363.0 11,363.0 15:27 15:45 surface weight,pull 500'wiper, PUW=28K 9/19/2015 9/19/2015 5.25 PROD2 DRILL DRLG T BOBD,1.48 BPM @ 4214 PSI FS, 11,363.0 11,490.0 15:45 21:00 BHP=4215,BHA wiper @ 11,421' 9/19/2015 9/19/2015 1.00 PROD2 DRILL WPRT P Wiper to 10,290',PUW=29K,RBIH. 11,490.0 11,490.0 21:00 22:00 9/19/2015 9/20/2015 2.00 PROD2 DRILL DRLG P BOBD: 1.45 BPM @ 4,240 PSI. 11,490.0 11,573.0 22:00 00:00 BHP=4,230 PSI,CTW=5K,WOB=2K, ROP=40.Started pumping new mud. New mud at bit 11,553'. 9/20/2015 9/20/2015 4.00 PROD2 DRILL DRLG P Drill ahead: 1.47 BPM @ 4,130 PSI, 11,573.0 11,690.0 00:00 04:00 BHP=4,225 PSI,CTW=2.5K, WOB=1.8K,ROP=35.BHA wiper @ 11,685'. 9/20/2015 9/20/2015 2.40 PROD2 DRILL WPRT P Wiper for tie-in,PUW=30K,jet 5.5" 11,690.0 11,690.0 04:00 06:24 liner,Tie in for+1',RBIH. 9/20/2015 9/20/2015 4.50 PROD2 DRILL DRLG P 11690',Drill, 1.45 BPM @ 4130 PSI 11,690.0 11,820.0 06:24 10:54 FS,BHP=4175 9/20/2015 9/20/2015 0.20 PROD2 DRILL WPRT P 11820,Stacking,BHA Wiper, 11,820.0 11,820.0 10:54 11:06 PUW=28K 9/20/2015 9/20/2015 3.00 PROD2 DRILL DRLG P 11820,Drill ahead, 1.45 BPM @ 4150 11,820.0 11,890.0 11:06 14:06 PSI FS,BHP=4215,ROP=30FPH 9/20/2015 9/20/2015 2.00 PROD2 DRILL WPRT P Wiper trip to 9950 with sweeps, 11,890.0 11,890.0 14:06 16:06 Overpull @ 11760 with slight pack off, RBIH to pull up through to clean up, slight overpull @ 11750 no packing. Overpull 11595 come through.Clean up to 9950,Trip back in at full rate. Slight stacking @ 10612&10650. Had to cut rate tp 1 BPM and work down below 11,705 to TD Page 17/19 Report Printed: 12/18/2015 Operations Summary (with Timelo • the ) y 1G-12 Conoco hillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/20/2015 9/20/2015 4.00 PROD2 DRILL DRLG P 11890',Drill, 1.46 BPM @ 4100PSI 11,890.0 12,011.0 16:06 20:06 FS,BHP=4223,ROP=18FPH. Negative CTW 3-4K.,ROP=20. Decide to pull early wiper to 11,200, per town. 9/20/2015 9/21/2015 3.90 PROD2 DRILL WPRT P Wiper trip to 11,200',PUW=29.5K, 12,011.0 8,716.0 20:06 00:00 another slight over pull @ 11,750'. Town call TD.Make wiper trip to swab,pump 10 X10 to/hi vis sweeps, chase to swab,jet 5.5"liner. 9/21/2015 9/21/2015 1.50 PROD2 DRILL WPRT P Continue wiper to swab,Pump#2 8,716.0 4,350.0 00:00 01:30 blew swab,swap to pump#1,started have issues with Pump#1. 9/21/2015 9/21/2015 1.00 PROD2 DRILL WPRT T Troubleshoot pump#1 issues,call out 4,350.0 4,350.0 01:30 02:30 electrician.While redressing pump# 2.Pump#2 back online. 9/21/2015 9/21/2015 0.50 PROD2 DRILL WPRT P Continue wiper to swab.Tag up,reset 4,350.0 72.5 02:30 03:00 depth. 9/21/2015 9/21/2015 1.40 PROD2 DRILL TRIP P RBIH to 11,250 72.5 8,220.0 03:00 04:24 9/21/2015 9/21/2015 0.20 PROD2 DRILL DLOG P 8220 Tie in for-4.5'correction 8,220.0 8,249.0 04:24 04:36 9/21/2015 9/21/2015 1.20 PROD2 DRILL TRIP P 8249 continue trip in hole,Close EDC 8,249.0 11,245.0 04:36 05:48 @ 8703.Clean pass through window and billet,Stack weight @ 10612 and 10650 9/21/2015 9/21/2015 3.20 PROD2 DRILL TRIP P Trip out pumping 11.8 beaded liner 11,245.0 78.0 05:48 09:00 running pill followed with 11.8 completion fluid.Paint eop flags @ 8600 and 6100 9/21/2015 9/21/2015 1.00 PROD2 DRILL PULD P At surface,30 minute flow check, 78.0 0.0 09:00 10:00 PJSM lay down BHA#18 9/21/2015 9/21/2015 1.00 COMPZ2 CASING PUTB P Rig up to run liner,PJSM to P/U liner 0.0 0.0 10:00 11:00 9/21/2015 9/21/2015 2.90 COMPZ2 CASING PUTB P M/U BHA#19 with non ported 0.0 2,511.0 11:00 13:54 bullnose,81 jts slotted liner,shorty deployment sleeve 9/21/2015 9/21/2015 1.00 COMPZ2 CASING PULD P PJSM,R/D floor from liner running, 2,511.0 2,555.6 13:54 14:54 P/U coil trak and make up to liner,M/U to coil and surface test 9/21/2015 9/21/2015 1.20 COMPZ2 CASING RUNL P Run in hole with liner 2,555.6 8,656.0 14:54 16:06 9/21/2015 9/21/2015 0.10 COMPZ2 CASING DLOG P Correct at EOP Flag,-6.9,PUW=35K 8,656.0 8,656.0 16:06 16:12 9/21/2015 9/21/2015 1.15 COMPZ2 CASING RUNL P Continue in well,Set down in window, 8,656.0 11,240.0 16:12 17:21 PU,pass through window,no correction at K1 marker,continue in hole to set depth @ 11,240', PUW=35K,pump on,release from liner.PUH. 9/21/2015 9/21/2015 1.50 COMPZ2 CASING DISP P Reset depth to 8,722'.Circulate well to 11,240.0 8,722.0 17:21 18:51 seawater,recovered 220 bbls 11.8 Br. 9/21/2015 9/21/2015 1.00 COMPZ2 CASING TRIP P Continue OOH. 8,722.0 2,500.0 18:51 19:51 9/21/2015 9/21/2015 0.75 COMPZ2 CASING FRZP P PJSM.Rig-up LRS,test.Pump 30 2,500.0 2,500.0 19:51 20:36 bbls diesel for freeze protect.Rig down LRS. 9/21/2015 9/21/2015 1.40 COMPZ2 CASING TRIP P Continue OOH,tag sripper,space-out. 2,500.0 45.5 20:36 22:00 Page 18/19 Report Printed: 12/18/2015 0..i. gil. Iiit erations Summary (with Timelo l the 9 p ) 1G-12 Corx:di hilIips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/21/2015 9/22/2015 2.00 COMPZ2 CASING PULD P PJSM. PUD BHA#19.LD BOT& 45.5' 0.0 22:00 00:00 MWD,remove QTS. PJSM with FMC. 9/22/2015 9/22/2015 1.00 DEMOB WHDBOP MPSP 'P Set BPV,WHP=405 psi.LD FMC 0.0 0.0 00:00 01:00 equipment. 9/22/2015 9/22/2015 1.00 DEMOB WHDBOP CTOP P Performed agitator circulation test, 0.0 0.0 01:00 02:00 agitators from previous runs.BHA#18 agitator#0212-0001, 1.5 BPM 2,500 psi.BHA#17 agitator#0212-0038, bought pump up,we had 4,500 psi at 1.4 BPM,so we shut it down before we blew a pop-off. 9/22/2015 9/22/2015 2.00 DEMOB WHDBOP RURD 'P Flush stack&surface line with 0.0 0.0 02:00 04:00 inhibited freshwater,clean pits. 9/22/2015 9/22/2015 2.00 DEMOB WHDBOP NUND -P ND BOPE.Check tree bolts,50 0.0 0.0 04:00 06:00 minutes, 15 loose bolts,load tree with methanol,secure wellhead.Final WHP 405 psi. 9/22/2015 9/22/2015 1.00 DEMOB WHDBOP RURD P Complete rig move checklist 0.0' 0.0 06:00 07:00 Note:Rig released @ 07:00 hrs Page 19/19 Report Printed: 12/18/2015 • • IF le Ma mum gal %- o_o_ m I C ognift. L. CO 0 0. RS o w w ce a H >, U. 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Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep 1 I 1 I 1 I 1 Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC 1 1 2 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR I I I TOTALS FOR THIS PAGE: 0 3 4 6 5 0 TOTALS FOR ALL PAGES: 0 3 4 6 5 0 al • • CNI r- III PO LO 0.1 IA 1111 ill Z „KIS. imigz a= CO %- 0- =0- I Ci V a p co 00) Q LIJ Ce a. u) Z W 11111=111111 •II i. - CO% i MI E _CW ■^� y 0- D O W O LO 0 N O L 2 oYY � N 0 a N N C. 0 Q .Q. 7 G (Q W fn V Y Y ,- to CO 0 r 4 • • • S li § z y.�§ z c §■ - E _ >a ) & i ( ! a 2 ] Co / \ \ / ) 0 co ;( § % � 3 \ § \ R i 4c \ & & 5 co0. \ \ EP. j E \ { \ \ { \ H E § \ { ) - - ° ) $ ( ) ( / § A - / \ _ E ; f { j o t \ �CD � I # [ I- & .. 3 f \ Z I 2 ; EE ; # t / § / ± _ � ■ 2 a .. ,— _c / § ) k zcv I > \ ] n \ § K & - 6 f CD Z o a 20 CD k 1- 2 z k COk .. 2 0 z \ ( z \ c ) in 1-2 \ 0 t - j & ) ■ co COco ) Lrs CO E « 2 of \ /) } n \ \ E % \ES E• § k= txo t (;_b = 0 oe = § ] - � ) )\ ' 0 0 } \ 2 CO 0 » ƒ c | Lo / } \ } ƒ \ \ 2 9 k \ as \ E \ 00 ) ƒ � ) ) 7 ) a ; m a m e = ± J - - - a \ } / \ \ \ » / ZE ) & Q ) ui 0 atm - § • F c 5 .. - CO . c J K \ % ƒ t 7 0 CO o O. $ $ . { { \ § _ : a & # a 7 # E - - « § 0- a I & a 0- £ A £ & & 0. & 2 0 ■ > ) a •-... r • 0 a • ! 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VO O O O o O O O 0 0 0 O - 0 r '- ,- ‘- , ` ,- ,- ,- '- '- '- '- ' N.- • O` w N N N 7 ✓ a u) S 3 a Un • rn • • Letter of Transmittal RECEIVED BAKER Date. )ATA LOGGED September 24, 2015 SEP 2 5 2015 9K BENDER HUGHES AOGCC To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1G-12L1 2 ! 11 3 9 1 6 1 7 3 1G-12L14Bk-01%1 2 1 5 1 40 26 275 1G-12L1-01 21 5 1 4 0 2 6 2 7 4 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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O = > 000 G ° WNNWppccWa) z,-,- C (OV O W0 O W7 ON) aO) O WO NW N V N M V WV zU Y Q to v V u) co N- O O CO O W CO r 0 V V 0 co co (0 CO N (0 CO M CO N 0 CO U N (0 W CO V r r CO (0 CO O u) O O 7 O O 7 M 0 r N W O O O O O O O Cl CJ CV O O O CJ CJ CJ O d d O O O O d N O Oi O Li; ❑ N (%"43 °,8 r rV rr O M W O N) O W O V r O M W M N M M WM © E 0 0 O O O O 0 0 O 0 O O 0 (6 O ` ' Q Q 0) r r r �- r r �— r r r r r r 0 F. £ y0 N m N y = r t U d i7) aS ❑ CO N • • ®FTit v7, THES TATES • Alaska Oil and Gas NASKA Conservation Commission - of 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-12L1 ConocoPhillips Alaska, Inc. Permit No: 215-139 Surface Location: 268' FSL, 818' FWL, Sec. 29, T12N, R10E, UM Bottomhole Location: 1803' FNL, 482' FEL, Sec. 32, T12N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 183-132, API No. 50-029- 21009-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this day of August, 2015. liii! RECEIVED STATE OF ALASKA AUG 112015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil Q • Service-Winj ❑ Single Zone ❑• lc.Specify if well is proposed for: Drill ❑ + Lateral C Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill El Reentry[ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: - U Blanket i- Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. • Bond No. 59-52-180 • KRU 1G-12L1 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11400'+ TVD: 6704'. Kuparuk River Field . 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:268'FSL,818'FWL,Sec.29,T12N, R10E, UM • ADL 25640 • Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1269'FSL, 1095'FEL,Sec.32,T12N, R10E, UM 2571 8/20/2015 Total Depth: 9.Acres in Property: 14.Distance to 1803'FNL,482'FEL,Sec. 32,T12N, R10E, UM - 2459 • Nearest Property: 19500 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 99 feet 15.Distance to Nearest Well Open Surface:x- 540599 y- 5980918 Zone- 4 • GL Elevation above MSL: . 63 feet to Same Pool: 1G-11 ,640' 16.Deviated wells: Kickoff depth: -, 8770 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 93° deg. Downhole:4075 psig . Surface:3429 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 2535' 8865' 6629' 11400' 6704' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9116 6836 none 9014 6760 none Casing Length Size Cement Volume MD TVD Conductor/Structural 62' 16" 212 sx CS II 100' 100' Surface 2513' 10.75" 1010 sx AS III,250 sx AS I 2550' 2302' Production 9064' 7" 975 sx Class G,250 sx AS I 9096' 6821' Perforation Depth MD(ft): Perforation Depth TVD(ft): 8385-8458,8537-8589,8812-8864 6297-6351,6410-6448,6612-6650 20.Attachments: Property Plat El BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact (pn Phillips @ 265-6312 Email Ron.L.Phillipscop.com Printed Name D. V haus Title CTD Engineering Supervisor Q' Signature `j/yr Phone:263-4372 Date o — LS Commission Use Only Permit to Drill API Number: I Permit Approval ISee cover letter Number: OC IS^ 13 950-Dag- ,2 1 Do 9_Go_00 Date: IS--\C(—‘6 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales: [i IOP 1�cSf fa 38GD Fs-Other: Samples req'd: Yes ❑ No [ Mud log req'd: Yes❑ No[]P i 4 h n(JICI r pre-Vlv,fir` 15 f Jo z measures: Yes R'No ❑ Directional svy req'd: Yes11161 No❑ Spacing eh-el-St/CT{req'd: Yes ❑ No L Inclination-only svy req'd: Yes❑ No V APPROVED BY THE ��//� /� Approved by: COMMISSIONER COMMISSION Dat — r! .I��� Form 10-401(Re se10/2012) 1(fl P )li1isr lic1fcf j tor from the date of approval(20 AAC 25.005(g)) IP�1� /7//c- ConocoPhillips p Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AUG 1 1 2015 August 06, 2015 AOGCC Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual-lateral out of the Kuparuk Well 1G-12 using the coiled tubing drilling rig, Nabors CDR2-AC. CTD operations are scheduled to begin late August 2015. The objective will be to drill laterals KRU 1G-12L1 & 1G-12L1-01 targeting the KuparukA4-sands. I Attached to this application are the following documents: - 10-401 Applications for 1G-12L1 & 1G-12L1-01 - Detailed Summary of Operations - Directional Plans for 1G-12L1 & 1G-12L1-01 - Current CTD Schematic - Proposed CTD Schematic If you have any questions or require additional information please contact me at 907-265-6312. Sincerely, alr* �. Ron Phillips ConocoPhillips Alaska Coiled Tubing Drilling Engineer i • Kuparuk CTD Laterals NABORS ALASKA CDA 1G-12L1 & 1G-12L1-01 ��� ConocoPhitps Application for Permit to Drill Document 214C 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)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 3 (Requirements of 20 AAC 25.005(c)(5)) 3 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 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 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. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1G-12L1 & 1G-12L1-01 7 Attachment 2: Current Well Schematic for 1G-12 7 Attachment 3: Proposed Well Schematic for 1G-12 CTD Laterals 7 Page 1 of 7 8/6/2015 IIP P1Application: 1G-12L1 & L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1G-12L1 & 1G-12L1-01. Laterals will be classified as "Development—Oil" well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Two laterals, one to the north and one to the south, will target the A4 sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1G-12L1 & 1G-12L1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — 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 4075 psi'in well 1G-05, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3429 psi.' See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Expected Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 1G-12 in July 2015 indicated a reservoir pressure of 2546 psi @ 6631' TVD or 7.4 ppg EMW. The highst pressure in an offset well is at the 1G-05 well to the east with 4075 psi @ 6459' TVD or 12.1 ppg EMW. Using the 1G-05 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3429 psi. All the surrounding wells are between 6.3 ppg and 8.4 ppg, except for the 1 G-05 injector. It is not expected that reservoir pressure as high as 1 G-05 will be encountered while drilling the 1G-12 laterals because of the 2300' offset distance, but the 1G-05 injection pressure of 12.1 ppg represents the maximum realistic pressure we expect to see while drilling the 1G-12 laterals. The 1G-05 is SI, a RWO replaced the tubing March 2015 and the well is scheduled for a CTD sidetrack after the 1G-12 well is drilled. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled. Gas injection has been performed on 1G pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) Exposed shale while drilling the 1G-12 laterals, especially at fault crossings, has the potential to cause hole problems. Managed pressure drilling equipment will be used to keep pressure on the well bore to minimum of 11.4 ppg, which has historically kept shale sections stabilized at Kuparuk. There is a risk of differential sticking and losses since we're drilling parallel to the 1H-04 well which last tested at 6.3 ppg EMW (2083 psi @ 6386' TVD) in May 2015. Close approaches The 1G-12L1 lateral has no close approach issues but at TD will drill within 563' of the 1G-11 and 655' of the 1G-11A (planned for August 2015). The 1G-12L1-01 lateral also has no close approach issues but will drill within 256' of the 1A-03. The A-sand perfs are isolated in both the 1G-11 and 1A-03. Page 2 of 7 8/6/2015 IIP PTIkpplication: 1G-12L1 & L1-01 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 1G-12L1 8,865' 11,400' 6,534' 6,605' 2'/', 4.7#, L-80, ST-L slotted liner; with aluminum billet 1G-12L1-01 8,765' 12,350' 6,396' 6,325' 2%", 4.7#, L-80, ST-L slotted liner with deployment sleeve Existing Casing/Liner Information Category OD Weight Grade Conn. Top Btm Top Btm Burst Collapse (PPOMD MD TVD TVD psi psi Conductor 16" 65.0 H-40 Welded 0' 100' 0' 100' 1640 630 Surface 10 3/4" 45.5 J-55 BTC 0' 2550' 0' 2302' 3580 2090 Prod 7" 26.0 J-55 BTC 0' 9096' 0' 6821' 4980 4320 Casing Tubing 3 1/2" 9.3 L-80 EUE 8rd 0' 8670' 0' 6537' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Used chloride weighted FloVis water based mud (9.1 ppg) — Drilling operations: Chloride weighted PowerVis water based mud (9.2 ppg). This mud weight will hydrostatically overbalance the reservoir pressure. — Completion operations: Liner running operations will be done with 11.4 ppg Sodium Bromide weighted completion fluid to maintain well bore stability during completion operations. Page 3 of 7 8/6/2015 41) PTpplication: 1G-12L1 & L1-01 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole 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 packoff and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". The targeted MPD BHP will be 11.4 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1G-12 Window (8770' MD, 6581' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (7.4 ppg) 2532 psi 2532 psi Mud Hydrostatic(9.2 ppg) 3148 psi 3148 psi Annular friction (i.e. ECD, 0.060 psi/ft) 526 psi 0 psi Mud + ECD Combined 3674 psi 3148 psi (no choke pressure) (overbalanced (overbalanced -1142 psi) -616 psi) Target BHP at Window(11.4 ppg) 3901 psi 3901 psi Choke Pressure Required to Maintain 227 psi 753 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. Page 4 of 7 8/6/2015 PT•pplication: 1G-12L1 & L1-01 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 1G-12 is a Kuparuk A/C-sand producer(development)well equipped with 3'/2"tubing. Two laterals from well 1G-12 will be drilled, one to the north(1G-12L1)and one to the south(1G-12L1-01)to increase offtake and improve sweep in immature A sand pattern. CTD operations will target the Kuparuk A4 sands. Well 1G-12 was completed in the Kuparuk A&C-sand in 1983 as a selective, gas lifted producer.A RWO was completed in early 2015 replacing the completion with a selective large tailpipe completion. This will allow for continued selective production from the Kuparuk A&C sands. The tubing head was also upgraded from 3,000 psi rated head to a 5,000 psi rated head . Prior to CTD operations,a whipstock will be set with E-line at 8770'. Both laterals will exit through the 5%"and 7"liner at 8,770' MD and will target the A4 sands one to the north and one to the south. Both laterals will be completed with 23/8" slotted liner from TD with the final liner top located just 5' above the whipstock at 8765'. Pre-CTD Work 1. Slickline: Set a PX plug in X-nipple, install a Spartek gauge, MIT-T and pull PX plug. 2. E-line: Set a whipstock at 8770'. 3. Pump: Perform injectivity test. 4. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1G-12L1 Sidetrack(A4 sand-north) / a. Mill 2.80"window at 8,770' MD b. Drill 3.25"bi-center lateral to TD of 11,400' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 8,865' MD 3. 1G-12L1-01 Lateral(A4 sand-south) a. Kick off of the aluminum billet at 8,865' MD b. Drill 3.25"bi-center lateral to TD of 12,350' MD c. Run 23/8" slotted liner from TD up to 8,765' MD,just 5' above the whipstock. 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CDR2-AC. Post-Rig Work 1. Pull BPV. 2. Obtain static BHP. Install GLV's. 3. Return to production. Page 5 of 7 8/6/2015 • Ppplication: 1G-12L1 & L1-01 Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, 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 slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 23/" liner. - The 1G-12 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 8/6/2015 P�pplication: 1G-12L1 & L1-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plan - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire openhole section./ - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral,Name Distance''. 1G-12L1 19,500' 1G-12L1-01 20,700' - Distance to Nearest Well within Pool (measured to offset well) Lateral Name Distance Well Dtrectior ai Plan 1G-12L1 563' 1G-11 wp03__ 1G-12L1-01 590' 1A-03 wp04 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) NA- 1G-12 is a production well.' 17. Attachments Attachment 1: Directional Plans for 1G-12L1 & 1G-12L1-01 Attachment 2: Current Well Schematic for 1G-12 Attachment 3: Proposed Well Schematic for 1G-12 CTD Laterals Page 7 of 7 8/6/2015 1G-12 Post-RWO Schematic Modified by RLP 743-15 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Camco MMG gas lift mandrels at 2843',4682',5974',6922', 7624',&8170' 16"65#H-40 shoe @ 100'MD tn.'" 10-3/4"45.5#J-55 shoe @ 2550'MD Baker 80-40 PBR at 8234'MD(3"ID) Baker FHL packer at 8257'MD(4.0"ID) 3-1/2"X-nipple at 8310'MD(2.812"min ID) C4-sand perfs 3-1/2"Camco MMG production mandrel at 8362' 8385'-8458'MD Baker FHL packer at 8472'MD(4.0"ID) 3-1/2"X-nipple at 8496'MD(2.812"min ID) 3-1/2"Camco MMG production mandrel at 8514' C1-sand perfs 8537'-8589'MD Baker Locator&80-40 Seal Assembly at 8603'MD Baker FB-1 packer @ 8604'MD(4.0"ID) 3-1/2"X-nipple 8626'MD(2.812"min ID) 5-1/2",14 ppf,H-40 Big Tail Pipe with wear sox 8670'-8796'MD • 01 A-sand perfs 8812'-8864'MD 7"26#J-55 shoe @ 9096'MD • 1G-12 Proposed CTD Schematic Modified by RLP 7-13-15 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Camco MMG gas lift mandrels at 2843',4682',5974',6922', 7624',&8170' 16"65#H-40 shoe @ 100'MD TOM- 10-3/4"45.5#J-55 shoe @ 2550'MD Baker 80-40 PBR at 8234'MD(3"ID) Baker FHL packer at 8257'MD(4.0"ID) 3-1/2"X-nipple at 8310'MD(2.812"min ID) C4-sand perfs ■ 3-1/2"Camco MMG production mandrel at 8362' 8385'-8458'MD •___ Baker FHL packer at 8472'MD(4.0"ID) 3-1/2"X-nipple at 8496'MD(2.812"min ID) 3-1/2"Camco MMG production mandrel at 8514' Cl-sand perfs Baker Locator&80-40 Seal Assemblyat 8603'MD 8537'-8589'MD Baker FB-1 packer @ 8604'MD(4.0"ID) 3-1/2"X-nipple 8626'MD(2.812"min ID) 5-1/2",14 ppf,H-40 Big Tail Pipe with wear sox 8670'-8796'MD I' o Q KOP @ 8770'MD Top of liner @ 8765'MD 1G-12 L1-01 wp03(south) ,1* TD @ 12350MD /1 1G-12 L1 wp03(north) TD@11400'MD Billet @ 8865 MD A-sand perfs 7"26#J-55 shoe 8812'-8864'MD @ 9096'MD • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 10-12 1G-12L1 Plan: 1 G-12L1_wp03 Standard Planning Report 15 July, 2015 r/qtr BAKER HUGHES 1.7 • Baker Hughes INTEQ • FAINConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 1G-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-12 @ 99.00usft(1G-12) Site: Kuparuk 1G Pad North Reference: True Well: 1G-12 Survey Calculation Method: Minimum Curvature Wellbore: 1G-12L1 Design: 1 G-12L1_wp03 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: 540,089.12 usft Longitude: 149°40'27.705 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.31 ° Well 1 G-12 Well Position +N/-S 0.00 usft Northing: 5,980,917.68 usft Latitude: 70°21'31.671 N +E/-W 0.00 usft Easting: 540,598.71 usft Longitude: 149°40'12.903 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1G-12L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 10/1/2015 18.85 81.00 57,501 Design 1G-12L1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 8.700.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 0.00 7/15/2015 3:19:23PM Page 2 COMPASS 5000.1 Build 74 . , • Baker Hughes INTEQ 0FAIN BAKER Planning Report HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 1G-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-12 @ 99.00usft(1G-12) Site: Kuparuk 1G Pad North Reference: True Well: 1G-12 Survey Calculation Method: Minimum Curvature Wellbore: 1G-12L1 Design: 1 G-12L1_wp03 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 8,700.00 42.65 145.31 6,430.98 -4,166.87 3,306.88 0.00 0.00 0.00 0.00 8,770.00 42.72 145.44 6,482.43 -4,205.93 3,333.84 0.16 0.10 0.19 51.59 8,785.00 44.52 145.44 6,493.29 -4,214.45 3,339.71 12.00 12.00 0.00 0.00 8,875.00 85.02 145.44 6,530.86 -4,280.11 3,384.94 45.00 45.00 0.00 0.00 9,026.50 90.00 77.35 6,538.34 -4,331.93 3,517.71 45.00 3.29 -44.94 272.00 9,106.50 92.94 41.46 6,536.22 -4,291.91 3,585.43 45.00 3.67 -44.87 275.00 9,176.50 90.86 37.02 6,533.90 -4,237.74 3,629.66 7.00 -2.97 -6.34 245.00 9,276.50 90.12 30.06 6,533.04 -4,154.44 3,684.87 7.00 -0.74 -6.96 264.00 9,406.50 88.55 21.09 6,534.56 -4,037.31 3,740.93 7.00 -1.21 -6.90 260.00 9,606.50 86.66 7.21 6,542.96 -3,844.04 3,789.67 7.00 -0.94 -6.94 262.00 9,756.50 86.72 17.72 6,551.65 -3,698.02 3,821.95 7.00 0.04 7.01 90.00 10,056.50 86.93 356.69 6,568.45 -3,402.53 3,859.32 7.00 0.07 -7.01 270.00 10,206.50 86.08 7.18 6,577.62 -3,253.10 3,864.36 7.00 -0.57 6.99 95.00 10,306.50 86.10 0.16 6,584.45 -3,153.60 3,870.75 7.00 0.03 -7.02 270.00 10,506.50 86.22 14.19 6,597.90 -2,956.11 3,895.61 7.00 0.06 7.02 90.00 10,726.50 89.52 359.14 6,606.13 -2,738.41 3,921.02 7.00 1.50 -6.84 282.00 10,946.50 90.01 14.53 6,607.04 -2,520.63 3,947.11 7.00 0.23 7.00 88.20 11,196.50 90.31 357.03 6,606.33 -2,272.87 3,972.19 7.00 0.12 -7.00 271.00 11,400.00 90.30 11.28 6,605.24 -2,070.43 3,986.90 7.00 0.00 7.00 90.00 7/15/2015 3:19:23PM Page 3 COMPASS 5000.1 Build 74 Iv' • Baker Hughes INTEQ . EntConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 1G-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-12 @ 99.00usft(1G-12) Site: Kuparuk 1G Pad North Reference: True Well: 1G-12 Survey Calculation Method: Minimum Curvature Wellbore: 1G-12L1 Design: 1 G-12L1_wp03 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) (°/100usft) (°) (usft) (usft) 8,700.00 42.65 145.31 6,430.98 -4,166.87 3,306.88 -4,166.87 0.00 0.00 5,976,769.20 543,927.80 TIP 8,770.00 42.72 145.44 6,482.43 -4,205.93 3,333.84 -4,205.93 0.16 51.59 5,976,730.30 543,954.97 KOP 8,785.00 44.52 145.44 6,493.29 -4,214.45 3,339.71 -4,214.45 12.00 0.00 5,976,721.81 543,960.89 End 12 dls,Start 45 dls 8,800.00 51.27 145.44 6,503.34 -4,223.61 3,346.02 -4,223.61 45.00 0.00 5,976,712.68 543,967.25 8,875.00 85.02 145.44 6,530.86 -4,280.11 3,384.94 -4,280.11 45.00 0.00 5,976,656.40 544,006.47 4 8,900.00 85.51 134.16 6,532.93 -4,299.11 3,401.00 -4,299.11 45.00 -88.00 5,976,637.49 544,022.62 9,000.00 88.89 89.23 6,538.08 -4,335.02 3,491.44 -4,335.02 45.00 -87.07 5,976,602.07 544,113.25 9,026.50 90.00 77.35 6,538.34 -4,331.93 3,517.71 -4,331.93 45.00 -84.75 5,976,605.30 544,139.50 5 9,100.00 92.73 44.38 6,536.54 -4,296.66 3,581.01 -4,296.66 45.00 -85.00 5,976,640.91 544,202.60 9,106.50 92.94 41.46 6,536.22 -4,291.91 3,585.43 -4,291.91 45.00 -85.81 5,976,645.68 544,206.99 End 45,Start 7 dls 9,176.50 90.86 37.02 6,533.90 -4,237.74 3,629.66 -4,237.74 7.00 -115.00 5,976,700.09 544,250.93 7 9,200.00 90.69 35.38 6,533.58 -4,218.78 3,643.54 -4,218.78 7.00 -96.00 5,976,719.13 544,264.71 9,276.50 90.12 30.06 6,533.04 -4,154.44 3,684.87 -4,154.44 7.00 -96.02 5,976,783.68 544,305.68 8 9,300.00 89.84 28.44 6,533.05 -4,133.93 3,696.36 -4,133.93 7.00 -100.00 5,976,804.25 544,317.05 9,400.00 88.63 21.54 6,534.40 -4,043.36 3,738.57 -4,043.36 7.00 -100.00 5,976,895.04 544,358.77 9,406.50 88.55 21.09 6,534.56 -4,037.31 3,740.93 -4,037.31 • 7.00 -99.91 5,976,901.10 544,361.10 9 9,500.00 87.65 14.61 6,537.66 -3,948.40 3,769.56 -3,948.40 7.00 -98.00 5,976,990.15 544,389.24 9,600.00 86.72 7.66 6,542.58 -3,850.47 3,788.83 -3,850.47 7.00 -97.78 5,977,088.18 544,407.98 9,606.50 86.66 7.21 6,542.96 -3,844.04 3,789.67 -3,844.04 7.00 -97.44 5,977,094.62 544,408.79 10 9,700.00 86.68 13.76 6,548.39 -3,752.30 3,806.65 -3,752.30 7.00 90.00 5,977,186.44 544,425.27 9,756.50 86.72 17.72 6,551.65 -3,698.02 3,821.95 -3,698.02 7.00 89.62 5,977,240.79 544,440.27 11 9,800.00 86.72 14.67 6,554.14 -3,656.32 3,834.07 -3,656.32 7.00 -90.00 5,977,282.55 544,452.16 9,900.00 86.77 7.66 6,559.83 -3,558.43 3,853.39 -3,558.43 7.00 -89.83 5,977,380.53 544,470.95 10,000.00 86.86 0.65 6,565.39 -3,458.91 3,860.63 -3,458.91 7.00 -89.43 5,977,480.08 544,477.65 10,056.50 86.93 356.69 6,568.45 -3,402.53 3,859.32 -3,402.53 7.00 -89.04 5,977,536.45 544,476.04 12 10,100.00 86.67 359.73 6,570.88 -3,359.12 3,857.97 -3,359.12 7.00 95.00 5,977,579.85 544,474.45 10,200.00 86.11 6.72 6,577.18 -3,259.54 3,863.58 -3,259.54 7.00 94.83 5,977,679.45 544,479.52 10,206.50 86.08 7.18 6,577.62 -3,253.10 3,864.36 -3,253.10 7.00 94.39 5,977,685.89 544,480.27 13 10,300.00 86.10 0.62 6,584.00 -3,160.08 3,870.70 -3,160.08 7.00 -90.00 5,977,778.93 544,486.10 10,306.50 86.10 0.16 6,584.45 -3,153.60 3,870.75 -3,153.60 7.00 -89.55 5,977,785.41 544,486.11 14 10,400.00 86.13 6.72 6,590.78 -3,060.53 3,876.34 -3,060.53 7.00 90.00 5,977,878.50 544,491.20 10,500.00 86.21 13.74 6,597.47 -2,962.40 3,894.05 -2,962.40 7.00 89.56 5,977,976.72 544,508.38 10,506.50 86.22 14.19 6,597.90 -2,956.11 3,895.61 -2,956.11 7.00 89.09 5,977,983.01 544,509.91 15 10,600.00 87.60 7.79 6,602.94 -2,864.51 3,913.40 -2,864.51 7.00 -78.00 5,978,074.71 544,527.19 10,700.00 89.11 0.95 6,605.81 -2,764.90 3,921.00 -2,764.90 7.00 -77.65 5,978,174.34 544,534.25 10,726.50 89.52 359.14 6,606.13 -2,738.41 3,921.02 -2,738.41 7.00 -77.46 5,978,200.83 544,534.13 16 7/15/2015 3:19:23PM Page 4 COMPASS 5000.1 Build 74 • Baker Hughes INTEQ • FAINConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 1G-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-12 @ 99.00usft(1G-12) Site: Kuparuk 1G Pad North Reference: True Well: 1G-12 Survey Calculation Method: Minimum Curvature Wellbore: 1G-12L1 Design: 1 G-12L1_wp03 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) (°/100usft) (°) (usft) (usft) 10,800.00 89.68 4.28 6,606.64 -2,664.96 3,923.21 -2,664.96 7.00 88.20 5,978,274.28 544,535.92 10,900.00 89.91 11.28 6,607.01 -2,565.94 3,936.73 -2,565.94 7.00 88.16 5,978,373.36 544,548.91 10,946.50 90.01 14.53 6,607.04 -2,520.63 3,947.11 -2,520.63 7.00 88.14 5,978,418.73 544,559.04 17 11,000.00 90.08 10.78 6,607.00 -2,468.43 3,958.84 -2,468.43 7.00 -89.00 5,978,470.98 544,570.48 11,100.00 90.20 3.78 6,606.76 -2,369.30 3,971.51 -2,369.30 7.00 -89.00 5,978,570.17 544,582.61 11,196.50 90.31 357.03 6,606.33 -2,272.87 3,972.19 -2,272.87 7.00 -89.02 5,978,666.60 544,582.77 18 11,200.00 90.31 357.28 6,606.31 -2,269.37 3,972.02 -2,269.37 7.00 90.00 5,978,670.10 544,582.58 11,300.00 90.31 4.28 6,605.77 -2,169.44 3,973.37 -2,169.44 7.00 90.00 5,978,770.02 544,583.39 11,400.00 90.30 11.28 6,605.24 -2,070.43 3,986.90 -2,070.43 7.00 90.04 5,978,869.10 544,596.38 Planned TD at 11400.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 11,400.00 6,605.24 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates • Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,700.00 6,430.98 -4,166.87 3,306.88 TIP 8,770.00 6,482.43 -4,205.93 3,333.84 KOP 8,785.00 6,493.29 -4,214.45 3,339.71 End 12 dls,Start 45 dls 8,875.00 6,530.86 -4,280.11 3,384.94 4 9,026.50 6,538.34 -4,331.93 3,517.71 5 9,106.50 6,536.22 -4,291.91 3,585.43 End 45,Start 7 dls 9,176.50 6,533.90 -4,237.74 3,629.66 7 9,276.50 6,533.04 -4,154.44 3,684.87 8 9,406.50 6,534.56 -4,037.31 3,740.93 9 9,606.50 6,542.96 -3,844.04 3,789.67 10 9,756.50 6,551.65 -3,698.02 3,821.95 11 10,056.50 6,568.45 -3,402.53 3,859.32 12 10,206.50 6,577.62 -3,253.10 3,864.36 13 10,306.50 6,584.45 -3,153.60 3,870.75 14 10,506.50 6,597.90 -2,956.11 3,895.61 15 10,726.50 6,606.13 -2,738.41 3,921.02 16 10,946.50 6,607.04 -2,520.63 3,947.11 17 11,196.50 6,606.33 -2,272.87 3,972.19 18 11,400.00 6,605.24 -2,070.43 3,986.90 Planned TD at 11400.00 7/15/2015 3:19:23PM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-12 1G-12L1 1G-12L1_wp03 Travelling Cylinder Report 15 July, 2015 BAKER HUGHES • 0 ConocoPhillips PIMConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-12 Project: Kuparuk River Unit TVD Reference: 1G-12 @ 99.00usft(1G-12) Reference Site: Kuparuk 1G Pad MD Reference: 1G-12 @ 99.O0usft(1G-12) Site Error: 0.00 usft North Reference: True Reference Well: 1G-12 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1G-12L1 Database: EDM Alaska ANC Prod Reference Design: 1G-12L1_wp03 Offset TVD Reference: Offset Datum Reference 1G-12L1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,700.00 to 11,400.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,330.10 usft Error Surface: Elliptical Conic Survey Tool Program Date 7/15/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 8,700.00 1G-12(1G-12) BOSS-GYRO Sperry-Sun BOSS gyro multishot 8,700.00 11,400.00 1 G-12L1_wp03(1G-12L1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ( ) 11,400.00 6,704.24 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-11 -1G-11-1G-11 11,369.62 8,208.00 562.85 258.83 310.29 Pass-Major Risk 1G-11 -1G-11A-1G-11A_wp02 11,335.43 7,950.00 655.38 261.03 407.23 Pass-Major Risk 1G-12-1G-12-1G-12 8,750.00 8,750.00 0.00 2.43 -2.43 FAIL-Major Risk 1G-12-1G-12L1-01 -1G-12L1-01_wp04 8,874.98 8,875.00 0.34 0.43 -0.04 FAIL-Major Risk Offset Design Kuparuk 1G Pad- 1G-11 -1 G-11 -1 G-11 Offset Site Error: 0.00 usft Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) Ii (usft) (usft) ("1 (usft) (usft) (usft) 11,369.62 6,70440 8,208.00 6,918.27 72.35 48.28 -103.18 -2,016.40 3,467.68 2-11/16 562.85 258.83 310.29 Pass-Major Risk,CC,ES,SF 11,370.77 6,704.39 8,200.00 6,911.41 72.35 48.23 -102.32 -2,013.99 3,464.33 2-11/16 563.72 258.55 310.85 Pass-Major Risk 11,374.31 6,704.37 8,175.00 6,890.00 72.36 48.09 -99.63 -2,006.47 3,453.86 2-11/16 567.13 257.66 313.55 Pass-Major Risk 11,377.80 6,704.36 8,150.00 6,868.58 72.36 47.94 -96.98 -1,998.94 3,443.39 2-11/16 571.57 256.79 317.65 Pass-Major Risk 11,381.22 6,704.34 8,125.00 6,847.16 72.37 47.79 -94.37 -1,991.42 3,432.92 2-11/16 577.03 255.94 322-92 Pass-Major Risk 11,384.59 6,704.32 8,100.00 6,825.74 72.38 47.65 -91.81 -1,983.89 3,422.44 2-11/16 583.48 255.09 329.45 Pass-Major Risk 11,387.90 6,704.30 8,075.00 6,804.33 72.38 47.50 -89.32 -1,976.37 3,411.97 2-11/16 590.89 254.26 337.24 Pass-Major Risk 11,400.00 6,704.24 8,000.00 6,740.19 72.41 47.06 -82.05 -1,953.61 3,380.46 2-11/16 618.63 251.37 368.26 Pass-Major Risk 11,400.00 6,704.24 8,025.00 6,761.52 72.41 47.21 -84.12 -1,961.27 3,391.00 2-11/16 608.51 251.58 357.58 Pass-Major Risk 11,400.00 6,704.24 8,050.00 6,782.91 72.41 47.35 -86.26 -1,968.85 3,401.50 2-11/16 599.33 251.79 348.07 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 7/15/2015 9:27:22AM Page 2 COMPASS 5000.1 Build 74 .• .... , aloofJ 4x' go ' _311111111.1...— . x o la m J xxsx II1N o gi x N m JN o a C7 a o p a 6 4 v 8 I 0. 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C CO I-4)o O 0)00 c-4)CD N-O)O,-N to O co M 6 a N N C 0 0 0 N O O 0 0(O C O O C O 0 O6 O O O >.O ,r a a 00O)00,0,0000000000000000a)a)O ^ • O U \ oh • W O 0 o 0 0 0 0 0 0 0 0 0 0 0 0 O o 0 0 0 0 a + O 0 0 0 4)4)4)4)4)4)CO 4)4)4)4)4)4)4)0 • O O o 4)4)CO c0 CO CO CO CO CO O CO CO CO CO CO CO O O O 0• $ W O O� O 00 •O OJ )11' O N-0 0 6 N o N-N-O O 4)4)0 0 o N C 0)O a N N en en b b 00 N b st,N 00 CC b h0 N U r n N O N CO O N M CC)ti O x000 CO CO 000)OOOO OO p_O__O O_ O1 O U,_N co cr 4)C O h-co 0 co 0-NMC 00 C O I-00 0 0 z6 T (n O (uyusn 06) gpdou InopLaA anu V • I Bettis, Patricia K (DOA) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Monday, August 17, 2015 9:52 AM To: Bettis, Patricia K (DOA) Cc: Loepp, Victoria T (DOA);Venhaus, Dan E; Phillips, Ron L; Burke,Jason Subject: RE: KRU 2E-15L1 & 1G-12L1 Good morning, Patricia! The exclusion of information on emergency KWF in the KRU 2E-15 (184-189) and 1G-12 (183-132) CTD applications was intentional. ConocoPhillips' sent an e-mail to Victoria Loepp on July 21, 2015 stating our intention to no longer include information on the emergency KWF in Kuparuk CTD drilling applications . At Victoria's request, Dan Venhaus (ConocoPhillips CTD Supervisor), Kai Starck, and myself met with Jim Regg, Guy Schwartz, and Victoria on August 4, 2015 to discuss this. The discussion concluded in less than an hour to the satisfaction of the AOGCC representatives present. Subsequently, the CTD applications for KRU 1G-11A and AL1 (215-125 &215-126)were approved by the Commission without reference to emergency KWF. I hope that gives you sufficient information to proceed, and I would be glad to discuss this some more with you if that would be beneficial. -Gary Eller From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, August 14, 2015 2:35 PM To: Eller, J Gary Subject: [EXTERNAL]KRU 2E-15L1 Good afternoon Gary, What weight of KWF and volume of KWF will be available for emergency purposes while drilling this lateral? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If delete it,without first savingor forwardingit,and so that the AOGCC is aware unintended recipient of this a mail please e you are an P , of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettisCalaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,August 13, 2015 3:55 PM To: Ron.L.Phillips@conocophillips.com Subject: KRU 1G-12L1: Permit to Drill Application (215-139) Good afternoon Ron, What weight KWF and volume of KWF will be available for emergency purposes while drilling this lateral? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • 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: /'Qk , 1 (r-12.(x( PTD: oZ's' )35 /Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: gyafiAA 1 t,�i/,�� POOL: gyarcd< ?i Li i I Kyr-91 /r1\/4 Vi/ 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. )$3-131, , API No. 50-1Act -a a is 9 - 00 - 00 . / (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 6 0 N co) O O a) a . co N a) 0 �j. . o *-" a) l0 O. c F1. (� E' . , , . . To 0, , c o; O F E> ta a Co c 0) oi ay a° o . ; . . w. N 0) c 'c. rn 0 0, O. m. a . aU. 3 , . �, a o. co N - 7 _ o o . . c„ 3 ai _ . . o 3 . O) aN C7 . c a) . . -a aa)). o w. O 4 F- O. U aN) E , a). v, a E. mi> _a 0 z. °� C' N, W , Ei. D. c) a �. . , �, (T, 0� �. �� 4 m a u) 0 1 W. 'O. N >' 0, N 0. to co a' oni ar c 3'. co a. v. N' a 3; 3. , - 0 �. a) D. c. C. CO , co, N. '3. 2. �� >, C, D °O 0. m , E Y, 4. TY -i Y. a) 07 a . E. Y Co C. 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