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216-025
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O N N N N N d W N 0 0 Cl) N D O 1.0 N H cFc co fa 0 cE , a7 Z c co O N V o co d Q O CO Q O 0 :+ C U : U U U U U I p 2 a� m J m a co U 11 V a o 0 1, O. n@ 0 E O. o d 0 0 0 0 o d u- o 2 0 I O o aoi m to o o 4 a 2 w W w w J 3 ? 0 a 0 O 0 O V • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 2 , Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 • Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/23/2016 216-025/316-072 • 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 3/17/2016 50-103-20124-61 • 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 369'FNL,95 FEL,Sec 11,T1ON,R8E, UM 3/20/2016 KRU 2K-25L1-01 Top of Productive Interval: 9.Ref Elevations: KB:154 17. Field/Pool(s): 1151 FNL,967 FEL,Sec 13,T1ON, R8E, UM GL: 118 BF: 119 Kupurak River Field/Kuparuk Oil Pool Total Depth: 4304 FNL, 1270 FEL,Sec 13,T1ON, R8E,UM 10. Plug Back Depth MD/TVD: 18. Property Designation: 13270/6370 4,6L, 2.J5 ge ADL 25605 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Per{nit: Surface: x- 498310 y- 5937935 Zone- 4 13485/6428 2679 TPI: x- 502720 y- 5931874 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 502419 y- 5928721 Zone- 4 none 1935/1545 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL)I 10234/6336 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary CE GR/Res APR 2 2 2016 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.5 H-40 35 115 35 115 24 191 sx AS II 9 5/8 36 J-55 35 4082 35 2918 12 1/4 1300 sx AS III,450 sx Class G 7 26 L-80 33 2319 33 1927 8.5 1008 sx 15.7 ppg AS 1 7 26 J-55 2316 10230 1926 6518 8.5 300 sx Class G 4 1/2 11.6 L-80 7565 10127 4878 6453 6.276 309 sx Class G 2 3/8 4.6 L-80 9915 13270 6319 6370 3 slotted liner 24.Open to production or injection? Yes r] No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): 3 1/2 7604 7577/4884 Slotted Liner @ 9915-13270' COMPLET'nr'' 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. !-z F?r.- Was hydraulic fracturing used during completion? Yes❑ No I 3/L31/c,. Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LL 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/1/2016 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/1/2016 18hrs Test Period 1260 720 5454 178 Beans 540 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 243 1171 24-Hour/Rate •••� 1680 960 7272 TBD Form 10-407 Revised 11/2015 VTL 4! " CONTINUED ON PAGE 2 Submit ORIGINIAL o y 4�/�e� . -ma c/ J,cr RBDMS L L. APR 2 b 2016 • • 28.CORE DATA Conventional Core(s): Yes ❑ No 111 Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 111 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1935 1545 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval 10234 6336 information,including reports,per 20 AAC 25.071. A4 13325 6227 TD(Kuparuk A4) 13485 6428 Formation at total depth: Kuparuk A4 31. List of Attachments: Daily Operations Summary, Definitive Survey,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, 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. Contact: Ron Phillips Cud 265-6312 Email: ron.l.phillips(c�cop.com r` Printed Name: Jason Burke Title: Sr.CTD Engineer / Si nat Phone: 265-6097 Date: 4- Z Z-J 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. 4 1/2 11.6 Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Slotted Liner Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only KUP P D 2K-25 ~} �fF�i. Conoc hillip5 . . O Atka Ino Wellbore APW Wl Field Name Wellbore Status ncl 0 MD(RK) Act Btm(Po(B) LawcoRhohyu', 501032012400 KUPARUK RIVER UNIT PROD __ 57.91 3,300.00 10,264.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-25,a22/2n166:3144 AM SSSV:NONE Last WO: 1/31/2016 36.00 1/26/1990 Vodocal mbselatc(aahIW,f Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,647.0 2/7/2016 Rev Reason:Add Laterals;GLV C/O lehallf 4/8/2016 HANGER;31.1 ++j. .asIng Strngs Caning D script n 00 (In) ID(in) Top(ftK8) Set Depth(RKB) Set Depth(TVD) WtlLen p.Grade Top Thread 'w CONDUCTOR 16 15.062 35.0 115.0 1150 6250 H-40 WELDED I 4i1.. { �,.; - '� ✓ Casing Description OD(In) ID(in) Top(RKB) Set Depth(MB) Set Depth(ND)...WtlLen(I...Grade Top Thread . ugc SURFACE 9 5/8 8.765 35.0 4,082.1 2,918.5 36.00 J-55 BTC Casing Descdption OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...WVLen(I...Grade Top Thread * \ PRODUCTION 7"Tie 7 6.276 33.0 2,319.0 1,927.6 26.00 L-80 Hydril 563 * \ back RWO 2016 1 Casing Description OD lin) 'DI D(in) Top 7,3B1)6 RKB) Set Depth(RKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread ,, ' ' PRODUCTION 7 6.276 2,316.0 10,230.1 6,518.0 26.00 J-55 BTC Casing Description 00(in) ID lin) Top(fIKB) Set Depth(tIKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread < l LINER 41/2"RWO 2016 4 1/2 4.000 7,565.1 10,127 0 6,453 1 11.60 L-80 IBTM 'i 'a Liner bails M CONDUCTOR;35.0.115.0 ti � Nominal ID Top(ftK6) Top(TVD)(RKB) Top Inel(°) Item Des Com (in) ::. r; 7,565.1 4,877.8 54.96 SLEEVE 2RH ZXP wtih HD Liner Top Packer(11.54'tie back 5.250 ' sleeve) s r',; 7,576.6 4,884.4 54.93 PACKER 2RH ZXP wtih HD Liner Top Packer(11.54'tie back 4.310 PRODUCTION T'Tie back 0 • i, sleeve) RWO 2018,330-2,319.0 7,583.7 4,888.5 54.91 HANGER Double Grip Flex Lock Liner Hanger 4.390 7,593.5 4,894.1 54.88 SBE Seal Bore Extension,5"TKC Pin x 5"BTC Pin 4.000 GAS LIFT;3,308.2 7,612.7 4,905.2 54.64 XO Reducing Crossover Sub,5"BTCM Box x 4-1/2"IBT Pin 3.930 10,096.2 6,433.7 50.69 COLLAR Float Collar,Weatherford,4-1/2",12.68,L-80,IBTM 2.000 Boxx Pin Tubing Description String Ma ID(in) lion(RKB) Set Depth(ft..Set Depth(TVD)(..Wt pb/ft) Grade Top Connection SURFACE.35.6-0,0821 TUBINGBRWO 2016 I 3 1/21 2.992 31.1 7,604.21 4,900.3 9 30 L-80 CEUE 8rd Mod omt ett(nt D( its Nominal ID GAS LIFT;5,287.4 `. Top(RKB) Top(TVD)MEI) Top Inel(°) Item Des Corn (in) 31.1 31.1 0.07 HANGER Cameron Tubing Hanger,CXS,7-1/16"x 3-1/2"EUE 8rd 2.920 Box Box,3"HBPVG al 7,518.7 4,851.2 55.10 NIPPLE Nipple,HES,2.813"X,SN: 11X28127 2.812 GAS LIFT;0703.0 : 7,568.2 4,879.5 54.95 LOCATOR Locator Sub,GHB-22(bottom of locator spaced out 7.29') 2.990 7 569.3 4,880.2 54.95 SEAL ASSY Seal Assembly,80-40 2.990 111 Perfar'a#ons„&s MOS, , . , GAS LIFT;7,457.6 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(RKB) Btm(RKB) (ftK8) (RKB) Zone Date fU Type Corn 9,778.0 9,792.0 6,234.5 6,243.1 C-4,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. NIPPLE;7,518.7 Ph 9,860.0 9,880.0 6,284.9 6,297.3 A-4,2K-25 2/24/2016 6.0 APERF 2.5",60 deg.Phasing Millenium II charges) 9,860.0 9,880.0 6,284.9 6,297.3 A-5,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. PH 9,912.0 9,948.0 6,317.1 6,339.6 A-4,2K-25 5/17/1990 4.0 IPERF 4.5"HLS CSG Guns;180 LOCATOR;7,588.2 deg.Ph 9,918.0 9,938.0 6,320.9 6,333.4 A-4,2K-25 2/24/2016 6.0 APERF 2.5';60 deg.Phasing Millenium II Charges) SEAL ASSY;7,568.399180 99440 63209 63371 A-42K-25 11/20/1993 3.0 RPERF 2 " nerJet;Oriented ':; __.,± , . , . , . , . , 41/85 deg.ECW Cement Squeezes ^I\ S� Top(TVD) Btm(TVD) ... . . ;:,1+y <, Top(RKB) Stitt(MB) (RKB) (RKB) Des Start Date Com t'* r.;;,1'r47,',1 33.0 2,319.0 33.0 1,927.6 Cement 7"x 1/16/2016 {ri � 9.625"Annulus f/ VI 2,319-h to "1, j+ surface M VI %%/, 7,576.0 10,127.0 4,884.0 6,453.1 Liner Cement 1/27/2016 PT cement line to 250/5000 psi(good test).Pump 15 - bbls 14.5 ppg mud push at 3 BPM=1700 psi followed APERF;9,880.0.9,880.0-� -`�+ � by 64 bbls 15.8 ppg cement at 3 BPM=1600 psi,drop e, the dart,and chase with 10 bbls of fresh water.Swap to the dg pumps,displace the DP with 11.1 ppg brine ,.4 at 5 BPM=3300 psi,slow pumps to 3 BPM=2300 4 +*� psi,and bumped the plugs at 3200 psi.Check the float and the float is holding. Swap to SLB cementers, w, d pressure up 4800 psi to set the liner hanger,and set Y`"r down 50K to ensure liner hanger is set. PU 65K and SLOTS,9,0150-13.265.5 rotate 15 turns to the right with 4K tt-lbs free torque at wnipamck;9,921.0L� -0. 140K hook load to release the liner running tool. Bring L1-01 LINER;8,9147-13,270.0 `,� the pump on line at 3 BPM=1570 psi and 4 BPM= APERF;5,018.D-9,930.D�� 1 y" -.A, 1900 psi.Pull packoff and dog sub out.Circulate 40 +N ',i,;',4 bbls to clear any cement off the top of the liner top . %� packer then slow the pumps to 2 BPM=1200 psi.SO r y SOK to set the ZXP liner top packer(saw indicating T *r shear),PU,and set down 80K again. PU,rotate at 15 ;4 y. RPM=5K ft-lbs free torque,SO 50K,stop the rotary, , and PU off ZXP liner top packer. . _'a Mandrel Inserts Ai Bt kW i .<y .� on TOD(ND) Valve Latch Port Sim TRO Run LINER 4112'RWO 2016; N, Top(RKB) MKS) Make Model OD(int Sery Type Type ON (psi) Ron Date Com 7,565.1-10,127.0 1 3,308.2 2,494.6 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,285.0 3/27/2016 2 5,287.4 3,598.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,265.0 3/27/2016 3 6,703.8 4,386.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,245.0 3/27/2016 4 7,457.6 4,816.3 Camco MMG 1 1/2 GAS LIFT OV RKP 0.250 0.0 3/26/2016 PRODUCTION,2, .6 10318,230.1 w KUP PaiD • 2K-25 ConocoPhillips A` t`' -' Alaska.Inc„ CorwcoPhi3I p; ' 1 28-25,4/22/2016 9;31,44 AM Vw4wl sdomR4E.(9E4a1) HANGER;31.1 moms: safety x End Date Annotation i + , ;1111 NOTE: k *' x 11 ti _A_A.CONDUCTOR;35.0-115.0 1, 1g, n{' „ :ir, PRODUCTION 7'Tie beck ''i 0.` RWO 2016;33.0-2,319.0 GAS LIFT,3,308.2 1, S. SURFACE;35.0-4,082.1- I GAS LIFT;5,287.4 it GAS LIFT;6,703.8 if II Ilt GAS LIFT;7,457.6 NIPPLE;7,518.7 I LOCATOR;7,568.2 0'; SEAL ASSY;7,569.3 t `d • IF a 4a ti d W i+ • a,; ro� APERF;9,860.09,880.0-. -4.,1 ,..,,,,,:,:l dy k h. St SLOTS;9,915.0-13,269.0 n Y�'d Whipstock,9,921.0 NS i i 1'+, L1-01 LINER;9,914.7-13,270.0, +' APERF;8,918.0-9,938.0 .4 £J • RV ±y tid V _il1 P. 1 dy LINER 4112'RWO 2016; 7,565.1-10,127.0 PRODUCTION;2,316b 10,230.1 r.` KUP P OD 2K-25L1-01 CQnc�cc f illi M wen x Ang[ D rn Alaska Wellbore API!UWI yField Name Wellbore Status ncl(°) MD( Act Btm(ftKB) ��pc ,yl, 501032012461 KUPARUK RIVER UNIT PROD 98.66 10,070.18 13,485.0 "• Comment 142.3(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-25L1-01 4/18/2018 3:21.;30PM SSSV:NONE Last WO: 1/312016 40.09 1/26/1990 Va'V'i sctnmati'{acWal) -Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason'Add Laterals lehallf 4/8/2016 HANGER;31.1 casing String° Casing Description OD(in) ID(10) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVlen(I...Grade Top Thread L1-01 LINER 2 3/8 1.992 9,914.7 13,270.0 6,369.7 4.60 L-80 ST L E Liner Iaiis NominallD Top(ftKB) Top(TVD)(ftKB) Top Indy) Item Des Com (in) 9,914.7 6,318.8 51.44 DEPLOY Shorty Deployment Sleeve 1.900 Pei#oranons&Slots Shot Dens 4 Top(TVD) Btm(TVD) (shots/ Top(ftKB) Bon(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,915.0 13,269.0 6,319.0 6,369.5 A-4,2K-25 3/22/2016 SLOTS Alternating Solid/slotted pipe-125"x25"@ 4 -"vti CONDUCTOR,35.0-115.0- circumferential rows Notes:General&Safety End Date Annotation NOTE: 0 � PRODUCTION T Tia back y, RWO 2018;33.0.2,319.0 GAS LIFT,3,308.2 SURFACE,35.0-4,082.1-. GAS LIFT;5,287.4 GAS LIFT,8,703.8 GAS LIFT;7,457.6 e NIPPLE.7,518.7 • • s' • LOCATOR;7,568.2 a3 � SEAL ASSY;7,569.3 I�i g t.c. 4 yv APERF;9,860.0-9,880.0 4 ^e a I.� 15 I PRODUCTION;10,23 1 10,230.1 #4i LINER 471./578511°0, ;!0 1/?RWO 2016, 7,585.1-10,127.0 _ t: Whipstock;9,921.0 j 1 - - BLOTS;9,915.0.13,289.0 L1-01 LINER;9,914.7-13,270.0 • • 2K-25 Final CTD Schematic Modified by RLP 4-12-16 16",62.5#,H-40 at 115'MD =� NM` 9-5/8",36#,J-55 - at 4082'MD _As El C-sand perfs(sgz'd) 9778'-9792'MD Al 1 A-sand perfs(sgz'd) - I 9860'-9880'MD 9912'-9948'MD i A-sand reperf post-RWO -_ 9860'-9880' 9918'-9938' w CTD KOP @ 9,921'MD ',;. '' 2K-25L1-01,TD=13,485'MD,PBTD=13,270'MD 23/4"slotted liner with top at 9,915'MD - ! sss''''s's'''' ‘=„„,::::,=:::: -----------------,--. . .......r.:tz: - ------- 2K-25L1,TD=13,375 MD,PBTD=13,342'MD h1tlR1"`°'""` 2'/."slotted liner with billet at 10,234'MD 7",26#,J-55 at ;","""`°�!'i;a"! 10,230'MD �+ek�rt� <<H� erations Summary (with Timelogiths) } 2K-25 ConocoPhittips 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 MKS) End Depth(ftKB) 3/5/2016 3/5/2016 3.00 MIRU MOVE RURD P Prep for move 3G to 2K 0.0 0.0 03:00 06:00 3/5/2016 3/5/2016 0.50 MIRU MOVE SFTY P Safety meeting with Northern Energy 0.0 0.0 06:00 06:30 services-new rig move contractor 3/5/2016 3/5/2016 1.00 MIRU MOVE MOB P Hook up to move to 2K 0.0 0.0 06:30 07:30 3/5/2016 3/5/2016 8.00 MIRU MOVE MOB P Move rig modules to 2K-pad. 0.0 0.0 07:30 15:30 3/5/2016 3/5/2016 3.75 MIRU MOVE MOB P Spot rig modules over 2K-25.Send 0.0 0.0 15:30 19:15 trucks for shop.on previous location. 3/5/2016 3/6/2016 4.75 MIRU MOVE RURD P RU interconnect,RU steam lines, 0.0 0.0 19:15 00:00 walkways&stairways.Spot shop. 3/6/2016 3/6/2016 2.00 MIRU MOVE RURD P Complete post rig move checklist. 0.0 0.0 00:00 02:00 3/6/2016 3/6/2016 2.00 MIRU WHDBOP NUND P PJSM.NU BOP stack.Check tree 0.0 0.0 02:00 04:00 flage bolts,found two loose bottom of SSSV flange and three loose below master.30 mins to tighten.Load stack and shell test to 4,400 psi.Test swabs &tangos. Rig accept:02:00 on 3/6/16 3/6/2016 3/6/2016 10.00 MIRU WHDBOP BOPE P Perform initial BOPE test 250/4400 0.0 0.0 04:00 14:00 psi,annular 2500 psi.Test witnessed by AOGCC(Brian Bixby). 3/6/2016 3/6/2016 1.50 SLOT WHDBOP RGRP T Replace lower blind shears-swap out 0.0 0.0 14:00 15:30 C-8 retest, NAD-NPT 3/6/2016 3/6/2016 3.85 MIRU WHDBOP PRTS P R/D test equipment,Pressure test 0.0 0.0 15:30 19:21 PDL's and TT line.load coil,test inner reel iron. 3/6/2016 3/6/2016 2.20 MIRU WHDBOP MPSP P PJSM.RU Lubricator,Pull TWC, 0.0 0.0 19:21 21:33 WHP=1,300 psi.LD Lubricator. 3/6/2016 3/7/2016 2.45 SLOT WELLPR PULD P PJSM.PU/MU/PD BHA#1.Check 0.0 66.5 21:33 00:00 pack-offs,install checks. 3/7/2016 3/7/2016 2.90 SLOT WELLPR TRIP T RIH w/Baker underremer assembly, 66.5 9,850.0 00:00 02:54 tie-in K1 marker for+5.5'correction, PUW=35K @ 9,800',continue in hole. 3/7/2016 3/7/2016 2.35 SLOT WELLPR UREM T Start under reaming©1.48 bpm,not 9,850.0 9,950.0 02:54 05:15 seeing much,get PUW=35K @ 9,900', nothing at shaker.Increase pump rate to 1.70 BPM,continue UR,ROP=30. Saw little DH weight @ 9,940', PUW=36K,ROP=8,getting some cement at shaker,one stall @ 9,944', PUW=36K,under reaming complete @ 9,950'. 3/7/2016 3/7/2016 2.50 SLOT WELLPR TRIP T POOH for WS assembly 9,950.0 69.0 05:15 07:45 3/7/2016 3/7/2016 1•.50 SLOT WELLPR PULD T At surface,PJSM PUD BHA#1,Under 69.0 0.0 07:45 09:15 reamer 3/7/2016 3/7/2016 1.50 PROD1 WHPST PULD P PJSM,Make up BHA#2 Whipstockm 0.0 74.8 09:15 10:45 M/U to coil track and surface test 3/7/2016 3/7/2016 2.20 PROD1 WHPST TRIP P RIH with whipstock 74.8 9,650.0 10:45 12:57 3/7/2016 3/7/2016 0.20 PROD1 WHPST DLOG P Log K1 for+5'correction 9,650.0 9,711.0 12:57 13:09 Page 1/12 Report Printed: 4/5/2016 perations Summary (with Timelog• ths) .ter; 2K-25 ConocoPhitrps � Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Tribe Log Start Depth Start Time < End Time Dur(hr) '; Phase Op Cade Actively Code', Time P-T-X Operation MKS), End Depth MKS) 3/7/2016 3/7/2016 0.40 PROD1 WELLPR TRIP P Continue in well,PUW=38K @ 9933', 9,711.0 9,932.0 13:09 13:33 Close EDC at 9831 3/7/2016 3/7/2016 0.10 PROD1 WHPST TRIP P At set depth,orient to high side, 9,932.0 9,932.0 13:33 13:39 Pumps on see tool shift at 3700 PSI, Set 6K down of whipstock, TOWS=9920 3/7/2016 3/7/2016 2.10 PROD1 WHPST TRIP P Trip out of well 9,932.0 76.0 13:39 15:45 3/7/2016 3/7/2016 1.40 PROD1 WHPST PULD P At surface,PJSM,PUD BHA#2 76.0 0.0 15:45 17:09 whipstock setting tools 3/7/2016 3/7/2016 2.35 PROD1 WHPST PULD P PJSM.PU/MU/PD BHA#3 0.0 76.5 17:09 19:30 3/7/2016 3/7/2016 2.75 PROD1 WHPST TRIP P RIH w/window milling assembly 76.5 9,924.0 19:30 22:15 (Weatherford).Tie-in to K1 marker for +5'correction,continue in hole. Weight check 38K @ 9,883'.Dry tag pinch point @ 9,924'. 3/7/2016 3/7/2016 1.40 PROD1 WHPST DISP P PUH.Displace well to used 8.6 ppg 9,924.0 9,923.2 22:15 23:39 FloPro,RBIH. 3/7/2016 3/8/2016 0.35 PROD1 WHPST WPST P Start time milling as per WP.Pumping 9,923.2 9,924.0 23:39 00:00 1.50 BPM @ 4020 PSI,BHP=3,930 PSI,CTW=7K,WOB=.2K. 3/8/2016 3/8/2016 14.10 PROD1 WHPST WPST P Continue time milling window exit as 9,924.0 9,946.0 00:00 14:06 per WP.1.50 BPM @ 3,905 psi,BHP= 3930 psi,CTW=7K,WOB=.5K, ROP=1.drill off at bottom of window at 9,931.7 ft.Mill rathole to 9,946 ft. 3/8/2016 3/8/2016 2.00 PROD1 WHPST REAM P 9,946 ft.TD rathole,back ream 9,946.0 9,946.0 14:06 16:06 window area 30°UR,dry drift window clean,open EDC,pump 5x5 sweep. 3/8/2016 3/8/2016 3.15 PROD1 WHPST TRIP P POOH for build assembly,at surface, 9,946.0 66.5 16:06 19:15 space out. 3/8/2016 3/8/2016 1.60 PROD1 WHPST PULD P PJSM.PUD BHA#3,LD BHA. 66.5 0.0 19:15 20:51 3/8/2016 3/8/2016 1.20 PROD1 DRILL PULD P PJSM.PU/MU/PD BHA#4 0.0 72.5 20:51 22:03 3/8/2016 3/9/2016 1.95 PROD1 DRILL TRIP P RIH w/Build drilling assembly,2.2 72.5 9,465.0 22:03 00:00 AKO motor,RB HCC bit. 3/9/2016 3/9/2016 0.55 PROD1 DRILL TRIP P Continue in hole with build assembly, 9,465.0 9,946.0 00:00 00:33 tie-in to K1 marker for+4.5'correction. RIH. 3/9/2016 3/9/2016 2.70 PROD1 DRILL DRLG P Drill ahead:1.55 BPM @ 3,995 PSI, 9,946.0 10,040.0 00:33 03:15 BHP=3,930 PSI,CTW=8.5K, WOB=2K,ROP=35.Started pumping new mud system @ 10,020'. 3/9/2016 3/9/2016 3.00 PROD1 DRILL TRIP P POOH for lateral drilling assembly. 10,040.0 72.2 03:15 06:15 PJSM-PUD BHA 3/9/2016 3/9/2016 1.50 PROD1 DRILL PULD P On surface,PUD/LD BHA#4,Bit 72.2 0.0 06:15 07:45 condition 1-1-NO-A-X-I-NO-BHA, Service injector. 3/9/2016 3/9/2016 1.40 PROD1 DRILL PULD P PJSM-MU/PD BHA#5,0.5°AKO 0.0 72.2 07:45 09:09 motor and a New Halliburton B-308 Bi- center bit,Check pack-offs,MU to CoilTrak,surface test. Page 2/12 Report Printed: 4/5/2016 ,„�a, ,, *erations Summary (with Timelog gitths) 2K-25 ConocoPttilliips 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 (ttKB) End Depth(ftKB) 3/9/2016 3/9/2016 2.50 PROD1 DRILL TRIP P RIH with L1 lateral drilling assembly, 72.2 10,040.0 09:09 11:39 tie in to K1 for plus 4 ft.correction, PUW 33k,RBIH,close EDC,Log RA marker at 9,928 ft.,TOWS 9,921 ft. continue in hole. 3/9/2016 3/9/2016 1.20 PROD1 DRILL DRLG P 10,040 ft. OBD 1.49 bpm at 3,618 psi 10,040.0 10,050.0 11:39 12:51 FS,BHP 4,002 psi,WHP 514,CWT 8.0k,WOB 1.4k,ROP 9,IA 334,OA 0, PUW 35k,restart bit. 3/9/2016 3/9/2016 3.05 PROD1 DRILL DRLG P 10,050 ft. BOBD 1.6 bpm at 3,757 psi 10,050.0 10,142.0 12:51 15:54 FS,BHP 3,930 psi,WHP 490,CWT 6.2k,WOB 2.4k,ROP 25 to 34 fpm. 3/9/2016 3/9/2016 0.80 PROD1 DRILL DRLG P 10,142 ft. OBD 1.6 bpm at 4,094 psi, 10,142.0 10,169.0 15:54 16:42 BHP 3,940 psi,WHP 500,Increase WOB to 3.0k,CWT 3.6k,ROP 36 to 38 fpm.stall at 10,169 ft.PUW 34k. 3/9/2016 3/9/2016 1.20 PROD1 DRILL DRLG P 10,169 ft. BOBD 1.5 bpm at 3,551 psi 10,169.0 10,210.0 16:42 17:54 FS,BHP 3,928 psi,WHP 488,CWT 4.9k,WOB 2.5k,ROP 36.Stall at 10,210'. 3/9/2016 3/9/2016 1.00 PROD1 DRILL WPRT T Wiper to 4.5".Work on injector issues, 10,210.0 9,860.0 17:54 18:54 Right angle drive coupler to motor came loose.Make repairs and test. 3/9/2016 3/9/2016 0.35 PROD1 DRILL TRIP P RBIH.Tie-in to RA for+1'correction. 9,860.0 10,210.0 18:54 19:15 3/9/2016 3/10/2016 4.75 PROD1 DRILL DRLG P BOBD:Trouble getting restarted. 10,210.0 10,335.0 19:15 00:00 Several restarts.1.50 BPM @ 3,960 PSI,BHP=3,975 PSI,CTW=7.5K, WOB=2.4K,ROP=35-40.Crossed fault @ 10,210'.Drill into upper silt zone,bit performance slow. 3/10/2016 3/10/2016 9.10 PROD1 DRILL DRLG P Drill ahead:1.58 BPM @ 3,985 PSI, 10,335.0 10,610.0 00:00 09:06 BHP=3,965 PSI,CTW=5.5K, WOB=2.4K,ROP=25.Slow drilling in upper silt zone,trouble getting BHA to drop. Note;Bled IA down from 990 psi to 160 psi. 3/10/2016 3/10/2016 1.25 PROD1 DRILL WPRT P Wiper trip to window,PUW 35k,jet 4- 10,610.0 7,650.0 09:06 10:21 1/2"liner to 7,650 ft. 3/10/2016 3/10/2016 0.60 PROD1 DRILL WPRT P Wiper back in hole. 7,650.0 9,640.0 10:21 10:57 3/10/2016 3/10/2016 0.10 PROD1 DRILL DLOG P Tie in to K1 for plus 4 ft.correction. 9,640.0 9,670.0 10:57 11:03 3/10/2016 3/10/2016 0.45 PROD1 DRILL WPRT P Wiper in hole,clean thru window,RIW 9,670.0 10,610.0 11:03 11:30 9.6k 3/10/2016 3/10/2016 5.50 PROD1 DRILL DRLG P 10,610 ft. BOBD 1.6 bpm at 3,798 psi 10,610.0 10,810.0 11:30 17:00 FS,BHP 3,984 psi,CWT 5.4k,WOB 2.0k,ROP 30. 3/10/2016 3/10/2016 0.75 PROD1 DRILL WPRT P Wiper up hole to 9,970 ft,PUW 38k, 10,810.0 10,810.0 17:00 17:45 RBIH. 3/10/2016 3/10/2016 6.00 PROD1 DRILL DRLG P 10,810 ft.BOBD:1.54 BPM @ 4,125 10,810.0 11,010.0 17:45 23:45 PSI,BHP=4,035 PSI,CTW=6.5K, WOB=2.6K,ROP=35. 3/10/2016 3/11/2016 0.25 PROD1 DRILL WPRT P Wiper to window,PUW=36K. 11,010.0 11,010.0 23:45 00:00 Page 3/12 Report Printed: 4/5/2016 filtrations Summary (with Timelog gkths) rte + i 2K-25 ConocoPhitlips 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 MB) 3/11/2016 3/11/2016 0.60 PROD1 DRILL WPRT P Continue wiper to window,RBIH. 11,010.0 11,010.0 00:00 00:36 3/11/2016 3/11/2016 5.65 PROD1 DRILL DRLG P 11,010 ft.BOBD:1.54 BPM©4,150 11,010.0 11,210.0 00:36 06:15 PSI,BHP=4,045 PSI,CTW=5.5K, WOB=2.6K,ROP=35. 3/11/2016 3/11/2016 1.20 PROD1 DRILL WPRT P Wiper trip to window,PUW 36k,jet 4- 11,210.0 7,650.0 06:15 07:27 1/2"liner 3/11/2016 3/11/2016 1.15 PROD1 DRILL WPRT P Wiper back in hole,plus 4.5 ft. 7,650.0 11,210.0 07:27 08:36 correction at K1,RIW 8.8k,clean thru window 3/11/2016 3/11/2016 5.15 PROD1 DRILL DRLG P 11,210 ft. OBD 1.52 bpm at 3,913 psi 11,210.0 11,410.0 08:36 13:45 FS,BHP 4,039 psi,WHP 345,CWT 6.2k,WOB 2.45k,ROP 40,IA 298,OA 0 3/11/2016 3/11/2016 0.80 PROD1 DRILL WPRT P Wiper to 10,410 ft.PUW 36k,RBIH 11,410.0 11,410.0 13:45 14:33 3/11/2016 3/11/2016 5.85 PROD1 DRILL DRLG P 11,410 ft. OBD 1.50 bpm at 3,869 psi 11,410.0 11,610.0 14:33 20:24 FS,BHP 4,057 psi,WHP 311,CWT 5.7k,WOB 2.5k,ROP 40, IA 385,OA 0 3/11/2016 3/11/2016 0.65 PROD1 DRILL -WPRT P 1000'wiper trip,PUW=33K,RBIH. 11,610.0 11,610.0 20:24 21:03 3/11/2016 3/11/2016 1.75 PROD1 DRILL DRLG P 11,610 ft. OBD 1.50 bpm at 3,925 psi 11,610.0 11,676.0 21:03 22:48 FS,BHP 4,070 psi,WHP 305,CWT 4.9k,WOB 2.4k,ROP 45.Pumped new mud system,new mud around© 11,648',continue drilling.No increase in bit performance,no ROPchange over 50.Decide to POOH for HYC bit. 3/11/2016 3/12/2016 1.20 PROD1 DRILL -TRIP P Start OOH for new bit. 11,676.0 7,664.0 22:48 00:00 3/12/2016 3/12/2016 2.00 PROD1 DRILL 'TRIP P Continue to 00H for bit change. 7,664.0 72.5 00:00 02:00 3/12/2016 3/12/2016 1.40 PROD1 DRILL PULD P PJSM.PUD BHA#5,LD Halliburton 72.5 0.0 02:00 03:24 bit,some balling,three jets plugged. 3/12/2016 3/12/2016 1.10 PROD1 DRILL PULD P PJSM.PU/MU/BHA#6 0.0 72.5 03:24 04:30 3/12/2016 3/12/2016 2.95 PROD1 DRILL TRIP P RIH w/drilling assembly,RB HYC bit, 72.5 11,678.0 04:30 07:27 tie-in for plus 5 ft.correction at K1, close EDC,PUW above window 30.5k,clean thru window,no indication of problems thru high gama area. 3/12/2016 3/12/2016 1.45 PROD1 DRILL 'DRLG P 11,678 ft. BOBD 1.55 bpm at 3,789 11,678.0 11,749.0 07:27 08:54 psi FS,BHP 4,070 psi,CWT 6.7k, WOB 1.4k,ROP 60,WHP 500, IA 25, IA 0. Note:07:50 took 10 bbls outside,slug of crude at surface. 3/12/2016 3/12/2016 0.55 PROD1 DRILL WPRT P GEO wiper,PUW 35k,RBIH 11,749.0' 11,749.0 08:54 09:27 3/12/2016 3/12/2016 2.10 PROD1 'DRILL DRLG P 11749 ft. BOBD 1.55 bpm at 4,167 11,749.0 11,880.0 09:27 11:33 psi,BHP 4,136 psi,CWT 6.5k,WOB 1.65,ROP 65,WHP 570,IA 127,OA 0 3/12/2016 3/12/2016 0.75 PROD1 DRILL WPRT P Wiper trip to 10,990 ft,PUW 34k, 11,880.0 11,880.0 11:33 12:18 RBIH. Page 4/12 Report Printed: 4/5/2016 iterations Summary (with Timelog•pths) r" 2K-25 ConocoPhi€lips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/12/2016 3/12/2016 3.00 PROD1 DRILL DRLG P 11,880 ft. OBD 1.55 bpm at 4,109 11,880.0 12,080.0 12:18 15:18 psi,BHP 4,158 psi,CWT 6.6k,WOB 1.65k,ROP 65,WHP 565,IA 204,OA 0. 3/12/2016 3/12/2016 0.85 PROD1 DRILL WPRT P Wiper trip to 10,890 ft,PUW 36k, 12,080.0 12,080.0 15:18 16:09 RBIH. 3/12/2016 3/12/2016 3.35 PROD1 DRILL DRLG P 12,080 ft. OBD 1.55 bpm at 4,186 12,080.0' 12,280.0 16:09 19:30 psi,BHP 4,164 ps,CWT 4.5k,WOB 1.7k,ROP 65,WHP 525,IA 260,OA 0. 3/12/2016 3/12/2016 3.50 PROD1 DRILL WPRT P Wiper for tie-in,PUW=37K,jet 4.5",tie 12,280.0 12,280.0 19:30 23:00 -in K1 for+6'correction,RBIH. 3/12/2016 3/13/2016 1.00 PROD1 DRILL DRLG P 12,280 ft. OBD 1.53 bpm at 4,155 12,280.0 12,347.0 23:00 00:00 psi,BHP 4,190 ps,CWT 1.5k,WOB 1.8k,ROP 70,WHP 495,IA 305,OA 0. 3/13/2016 3/13/2016 3.25 PROD1 DRILL DRLG P Continue drilling: 1.53 BPM @ 3,975 12,347.0 12,457.0 00:00 03:15 PSI,BHP=4,215,CTW=1K, WOB=1.4K,ROP=65.At 12,450', surface weight-4K,losing weight transfer,started pack-off.Pull wiper early,pump sweeps. 3/13/2016 3/13/2016 1.15 PROD1 DRILL WPRT P 1,000'wiper trip,PUW=36K,RBIH. 12,457.0 12,457.0 03:15 04:24 3/13/2016 3/13/2016 2.35 PROD1 DRILL DRLG P Drill ahead:1.54 BPM @ 4,190 PSI, 12,457.0 12,640.0 04:24 06:45 BHP=4,250 PSI,CTW=3.5K, WOB=1.5K,ROP=65.Pump 5x5 sweep 3/13/2016 3/13/2016 0.75 PROD1 DRILL WPRT P Wiper to 11,740 ft.PUW 36k,RBIH. 12,640.0 12,640.0 06:45 07:30 3/13/2016 3/13/2016 4.40 PROD1 DRILL DRLG P 12,640 ft. OBD 1.53 bpm at 4,186 12,640.0 12,840.0 07:30 11:54 psi,BHP 4,264 psi,CWT 3.7k,WOB 1.7k,ROP 50,WHP 473, IA 329,OA 0.Surface weight in the negitive, pump 20 bbl beaded pill,chase with 30 bbl 8.5 spacer,20 bbl beaded pill, continue. 3/13/2016 3/13/2016 3.40 PROD1 DRILL WPRT P Wiper to window,PUW 36k,jet 4-1/2" 12,840.0 12,840.0 11:54 15:18 liner,RBIH,K1 tie in for plus 6.5 ft. correction,sat down at 10,480 ft.PUW 35k,end of high gama area,took weight 2k WOB at 11,489 ft. 3/13/2016 3/13/2016 7.00 PROD1 DRILL DRLG P 12,840 ft. OBD 1.52 bpm at 4,202 12,840.0 13,120.0 15:18 22:18 psi,BHP 4,315 psi,CWT -5k,WOB 1.4k,ROP 58,WHP 472,IA 274,OA 0.Surface weight in the negitive quickly,pump 20 bbl beaded pill, chase with 30 bbl 8.5 spacer and repeat.Pumped one 20 bbl lube pill, improvement of 6K surface weight and doubled ROP was short lived. 3/13/2016 3/13/2016 1.10 PROD1 DRILL WPRT P !,500'wiper trip,PUW=39K,RBIH. 13,120.0 13,120.0 22:18 23:24 3/13/2016 3/14/2016 0.60 PROD1 DRILL DRLG P 13,120 ft.BOBD 1.54 bpm @ 4,355 13,120.0 13,148.0 23:24 00:00 psi,BHP=4,525 psi,CTW=-6K, WOB=1.3K,ROP=40. Page 5/12 Report Printed: 4/5/2016 � Iterations Summary (with Timelog •Pths) 2K-25 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time,I End Time Dur(hr) Phase Op Code Activity Code C Time P-T4( Operation (5Ke) End Depth(ftKB) 3/14/2016 3/14/2016 3.10 PROD1 DRILL DRLG P 13,147 ft 1.54 bpm @ 4,355 psi, 13,148.0 13,246.0 00:00 03:06 BHP=4,525 psi,CTW=-6K, WOB=1.3K,ROP=30.Pump another 20 bbl lube pill,improved CTW by 3K and ROP increased from 25 to 40, again it was short lived. Observed slight pit gain.Bumped up annular pressure by 175 psi. 3/14/2016 3/14/2016 0.50 PROD1 DRILL WPRT P Try short 500'wiper,PUW=40K, 13,246.0 13,246.0 03:06 03:36 RBIH. 3/14/2016 3/14/2016 2.90 PROD1 DRILL DRLG P 13,246 ft 1.53 bpm @ 4,455 psi, 13,246.0 13,375.0 03:36 06:30 BHP=4,520 psi,CTW=-5K, WOB=1.3K,ROP=40. 3/14/2016 3/14/2016 3.85 PROD1 DRILL WPRT P 13,375 ft. TD L1 lateral early,PUW 13,375.0 9,903.0 06:30 10:21 42k,wiper to swab,10x10 sweep in coil already.Jet 4 1/2"liner to 7,650 ft. Jog back in hole. 3/14/2016 3/14/2016 0.30 PROD1 DRILL DLOG P 9,903 ft. DPS parked at 9,860 ft MD, 9,903.0 9,903.0 10:21 10:39 6,284.9 ft TVD,adjust choke to 12.2 EMW at 3,987 psi,WHP 465 psi.Shut in for static BHP,BHP increased from 4,064 to 4,088 psi in 15 minutes,12.5 ppg EMW at window. 3/14/2016 3/14/2016 2.35 PROD1 DRILL WPRT P Wiper to swab,reset counters. 9,903.0 72.2 10:39 13:00 3/14/2016 3/14/2016 2.10 PROD1 DRILL TRIP P RBIH with BHA#6 72.2 9,640.0 13:00 15:06 3/14/2016 3/14/2016 0.20 PROD1 DRILL DLOG P Tie in to K1 for plus 7 ft correction. 9,640.0 9,668.0 15:06 15:18 3/14/2016 3/14/2016 1.70 PROD1 DRILL TRIP P Continue in hole,clean thru window, 9,668.0 13,350.0 15:18 17:00 no problems thru high gama area 10,480 ft,stacking 7k CWT at 11,010 ft at 40 fpm,PUW 33k,RBIH with no problem at 30 fpm,stacking 2k CWT at 11,095 ft 40 fpm. 12,700 ft to bottom CWT 3k and reduced pump tp.8 bpm. 3/14/2016 3/14/2016 2.85 PROD1 DRILL CIRC P 13,350 ft.Circulate bottoms up.Wait 13,350.0 13,350.0 17:00 19:51 for completion fluid to be weight up to 12.8 ppg. 3/14/2016 3/14/2016 4.00 PROD1 DRILL DISP P POOH laying in beaded liner 13,350.0 75.0 19:51 23:51 pill/completion fluid.Paint EOP flags @ 10,099'and 6,700',continue OOH. 3/14/2016 3/15/2016 0.15 PROD1 DRILL OWFF P Start no flow check. 75.0 75.0 23:51 00:00 3/15/2016 3/15/2016 0.40 PROD1 DRILL OWFF P No check complete 75.0 75.0 00:00 00:24 3/15/2016 3/15/2016 0.60 PROD1 DRILL PULD P PJSM.LD BHA#6 75.0 0.0 00:24 01:00 3/15/2016 3/15/2016 1.00 PROD1 DRILL SEQP P Function test BOPE,prep floor to run 0.0 0.0 01:00 02:00 liner. 3/15/2016 3/15/2016 5.70 COMPZ1 CASING PUTB P PJSM.MU lower liner segment:Bull 0.0 3,095.3 02:00 07:42 nose,106 jts slotted,shorty deployment sleeve. 3/15/2016 3/15/2016 1.30 COMPZ1 CASING PULD P PJSM-MU L1 liner assembly to BHA 3,095.3 3,139.5 07:42 09:00 #7,Change out pack-offs,MU to CoilTrak,surafce test. 3/15/2016 3/15/2016 1.60 COMPZ1 CASING RUNL P RIH with L1 liner assembly,2 ft 3,139.5 9,839.5 09:00 10:36 correction at flag. Page 6/12 Report Printed: 4/5/2016 erations Summary (with Timelog glikths) 2K-25 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time f End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 3/15/2016 3/15/2016 0.60 COMPZI CASING RUNL T BHI reloading data base due to 9,839.5 9,839.5 10:36 11:12 program issues. 3/15/2016 3/15/2016 1.30 COMPZ1 CASING RUNL P 9,839.5 ft.PUW 39k,Continue RIH 9,839.5 13,060.0 11:12 12:30 with L1 liner assembly,stack 8k RIH 25 fpm at bottom of window at 9,932 ft,PU clean,RIH 35 fpm,stack 8k at same,PU clean,RBIH 45 fpm and passed bottom of window with slight bobble,sat down at 13,060 ft.work liner 3/15/2016 3/15/2016 1.10 COMPZ1 CASING RUNL P 13,060 ft.Stacked out,shorty at 9,965 13,060.0 13,337.0 12:30 13:36 ft,CTC at 9,920 ft,PU and work liner assembly down to 3/15/2016 3/15/2016 0.30 COMPZ1 CASING RUNL P 13,337 ft. On depth,PU untill 13,337.0 10,242.0 13:36 13:54 breakover at 42k,on line 1.2 bpm, RBIH to 13,337 ft to release off liner, PUW 31k,lost 8k on WOB,re set counters, 3/15/2016 3/15/2016 2.45 COMPZ1 CASING TRIP P POOH for OH anchored billet 10,242.0 44.5 13:54 16:21 assembly. 3/15/2016 3/15/2016 0.50 COMPZ1 CASING OWFF P On surface,monitor well for flow. 44.5 44.5 16:21 16:51 PJSM-LD BHA 3/15/2016 3/15/2016 0.50 COMPZ1 CASING PULD P LD liner running BHA#7. 44.5 0.0 16:51 17:21 3/15/2016 3/15/2016 1.00 COMPZI CASING RUNL P PJSM-MU OH Anchored Billet BHA 0.0 72.8 17:21 18:21 #8,MU to CoilTrak,surface test. 3/15/2016 3/15/2016 1.75 COMPZI CASING RUNL P RIH with Open Hole Anchored Billet 72.8 6,700.0 18:21 20:06 3/15/2016 3/15/2016 0.50 COMPZ1 CASING RGRP T Notice differential across high 6,700.0 9,650.0 20:06 20:36 pressure screen,lock out valves, clean upper screen of beads, Continue RIH 3/15/2016 3/15/2016 0.25 COMPZ1 CASING RUNL P 9650 ft,log the K1 marker correction 9,650.0 9,686.0 20:36 20:51 of plus 6.0 ft,PUW 37k 3/15/2016 3/15/2016 1.50 COMPZ1 CASING RUNL T Continue IH,RIH thru window 15 fpm, 9,686.0 9,936.0 20:51 22:21 high side TF,set down at 9932'3k DHWOB,PUW 39k,minus 1.7k DHWOB,RBIH 10 fpm 135°ROHS, set down again 3k DHWOB,PUW 38k,minus 1.6k DHWOB,TF 270° ROHS,set down again 2.8k DHWOB, PUW 38k,Confer with town team, decision was made to POOH for crayola mill 3/15/2016 3/16/2016 1.65 COMPZ1 CASING RUNL T POOH,with open EDC,pumping.43 9,936.0 3,229.0 22:21 00:00 bpm 3/16/2016 3/16/2016 0.65 COMPZI CASING TRIP T Continue POOH,with BHA#8 3,229.0 72.8 00:00 00:39 3/16/2016 3/16/2016 0.50 COMPZ1 CASING OWFF T Check well for flow,PJSM with rig 72.8 0.0 00:39 01:09 crew and BOT rep, 3/16/2016 3/16/2016 0.35 COMPZ1 CASING PULD T LD BHA#8 0.0 0.0 01:09 01:30 3/16/2016 3/16/2016 0.80 COMPZ1 CASING PULD T MU milling BHA#9,good surface test 0.0 62.8 01:30 02:18 Coiltrak tools. 3/16/2016 3/16/2016 2.35 COMPZI CASING TRIP T Tag up,reset counters,RIH with 62.8 9,640.0 02:18 04:39 milling BHA with 0.7°bend motor and 2.80 OD crayola mill. 3/16/2016 3/16/2016 0.45 COMPZ1 CASING DLOG T Tie in to K1,PU and restart for plus 9,640.0 9,670.0 04:39 05:06 5.5 ft correction. Page 7/12 Report Printed: 4/5/2016 8 , ' .. erations Summary (with TimelogSPths) 2K-25 ConocoPhiilips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK nine Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 3/16/2016 3/16/2016 1.60 COMPZ1 CASING DISP T RIH to just above window,start 9,670.0 9,923.0 05:06 06:42 displaceing to out completion fluid to milling fluids,8.6 ppg out bit at 9,906 ft.finish displacing,RBIH. 3/16/2016 3/16/2016 1.60 COMPZ1 CASING REAM T 9,923 ft. Dress window HS,slight 9,923.0 9,937.0 06:42 08:18 motor work top and bottom of window at 9,932 ft.Back ream 45°L,slight motor work at 9,932 ft and 9,924 ft, call from town. 3/16/2016 3/16/2016 0.75 COMPZ1 CASING DLOG T Log RA at 9,928.5 ft,.5 to.75 ft lower, 9,937.0 9,937.0 08:18 09:03 PUH to 9,640 ft.tie in to KI,minus.25 ft,RBIH,Re-log RA at 9,928 ft. 3/16/2016 3/16/2016 3.10 COMPZ1 CASING REAM T 9,937 ft.Back ream window 45°R,90° 9,937.0 9,945.0 09:03 12:09 UR,slight motor work at top&bottom of window 9,923 ft&9,932 ft. moderate motor work at 180°LS 9,932 to 9,930 ft,back reamed twice, dry drift window clean to 9,945 ft. 3/16/2016 3/16/2016 2.00 COMPZ1 CASING TRIP T POOH for anchored billet assembly. 9,945.0 62.8 12:09 14:09 PJSM-PUD BHA 3/16/2016 3/16/2016 1.60 COMPZ1 CASING PULD T PUD,trouble with checks holding/LD 62.8 0.0 14:09 15:45 BHA#8 motor&mill, 3/16/2016 3/16/2016 1.75 COMPZ1 CASING PULD T PJSM-MU/PD OH anchored billet 0.0 72.8 15:45 17:30 assembly BHA#10,MU to CoilTrak, surface test. Note:Anchor setting pins shear @ , 16.9k,release shear sleeve set shear @ 23k to 28k. 3/16/2016 3/16/2016 2.75 COMPZI CASING TRIP T RIH with BHA#10 72.8 9,650.0 17:30 20:15 3/16/2016 3/16/2016 0.25 COMPZ1 CASING DLOG T Log the K1 marker correction of plus 9,650.0 9,691.0 20:15 20:30 11.0 ft. 3/16/2016 3/16/2016 0.50 COMPZ1 CASING TRIP P 9691 ft.Continue RIH thru window 9,691.0 10,247.0 20:30 21:00 3/16/2016 3/16/2016 0.25 COMPZI CASING TRIP P 10247 ft.tag TOL,PUW 36k,pickup to 10,247.0 10,235.0 21:00 21:15 breakover 32k,bring pump up to shear 4600 psi,WHP 840,BHP 4283, IA O,OA O 3/16/2016 3/16/2016 2.25 COMPZ1 CASING TRIP P 10235 ft,POOH pumping 0.65 bpm 10,235.0 72.8 21:15 23:30 3/16/2016 3/17/2016 0.50 COMPZ1 CASING PULD P At surface,space out,PJSM,PUD/LD 72.8 72.8 23:30 00:00 BOT setting tools 3/17/2016 3/17/2016 1.00 COMPZ1 CASING PULD P Continue PUD setting tools. 72.8 0.0 00:00 01:00 3/17/2016 3/17/2016 1.50 PROD2 STK PULD P PJSM with rig team,PD,L1-01 lateral 0.0 72.2 01:00 02:30 BHA 3/17/2016 3/17/2016 0.50 PROD2 STK PULD P Rehead BHI Upper Quick 72.2 72.2 02:30 03:00 3/17/2016 3/17/2016 0.50 PROD2 STK PULD P Continue PD drilling BHA#11. 72.2 72.2 03:00 03:30 3/17/2016 3/17/2016 2.20 PROD2 STK TRIP P RIH 72.2 7,650.0 03:30 05:42 3/17/2016 3/17/2016 0.15 PROD2 STK DLOG P Tie in to K1 for plus 8 ft.correction. 7,650.0 7,670.0 05:42 05:51 3/17/2016 3/17/2016 0.85 PROD2 STK TRIP P RIH,PUW above window 32k,clean 7,670.0 10,234.0 05:51 06:42 thru window,dry tag top of liner at 10,236 ft,PUW 34k. Page 8/12 Report Printed: 4/5/2016 ' IIerations Summary (with Timelog •Pths) .�- 2K-25 ConocoPhitlips , 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 (5KB) End Depth MKS) 3/17/2016 3/17/2016 2.75 PROD2 STK KOST P 10,234.4 ft. Kick off billet per 10,234.0 10,246.0 06:42 09:27 recommended practice 1.48 bpm at 4,026 psi,BHP 4,190 psi,WHP 507, IA 0,OA 0,aluminum across shaker. 3/17/2016 3/17/2016 5.30 PROD2 DRILL DRLG P 10,246 ft. OBD 1.48 bpm at 4,250 10,246.0 10,630.0 09:27 14:45 psi,BHP 4,155 psi,WHP 449,IA 0, OA 0. Drift billet area clean,Begin mud swap. Note:New mud out bit at 10,333 ft. 3/17/2016 3/17/2016 0.80 PROD2 DRILL WPRT P Wiper trip to 9,950 ft,PUW 33k,RBIH, 10,630.0 10,630.0 14:45 15:33 RIW 8.2k. 3/17/2016 3/17/2016 4.50 PROD2 DRILL DRLG P 10,630 ft. OBD 1.56 bpm at 3,887 psi 10,630.0 11,030.0 15:33 20:03 FS,4,202 psi,WHP 684, IA 7,OA, CWT 6.8k,WOB 1.4,ROP 110 3/17/2016 3/17/2016 1.25 PROD2 DRILL WPRT P 11030 ft,Wiper up hole PUW 33k 11,030.0 7,650.0 20:03 21:18 3/17/2016 3/17/2016 0.35 PROD2 DRILL WPRT P 7650 ft.Wiper back in hole RIW 8k 7,650.0 9,940.0 21:18 21:39 3/17/2016 3/17/2016 0.25 PROD2 DRILL DLOG P 9940 ft.log the RA correction of plus 9,940.0 9,954.5 21:39 21:54 2.5 ft. 3/17/2016 3/17/2016 0.65 PROD2 DRILL WPRT P 9955 ft,continue wiper in hole.RIW 8k 9,954.5 11,030.0 21:54 22:33 3/17/2016 3/17/2016 0.70 PROD2 DRILL DRLG P 11030 ft,BOBD 1.5 bpm at 4010 psi, 11,030.0 11,084.0 22:33 23:15 BHP 4262,WHP 708, IA 59,OA 0 3/17/2016 3/17/2016 0.61 PROD2 DRILL WPRT P 11084 ft. differential spike,loss of 11,084.0 10,250.0 23:15 23:51 DHWOB,PU clean 33k,differential still 250 psi high,pump sweep,PUH to 10250 ft. 3/17/2016 3/18/2016 0.14 PROD2 DRILL WPRT P RBIH to bottom,differential still 200 10,250.0 10,541.0 23:51 00:00 psi high 3/18/2016 3/18/2016 0.25 PROD2 DRILL WPRT P 10541 ft,Continue RIH to bottom 10,541.0 11,085.0 00:00 00:15 3/18/2016 3/18/2016 4.75 PROD2 DRILL DRLG P 11085 ft,BOBD 1.4 bpm at 4062 psi, 11,085.0 11,431.0 00:15 05:00 BHP 4253,WHP 671, IA 92,OA 0 3/18/2016 3/18/2016 0.55 PROD2 DRILL WPRT P 11431 ft.Wiper up hole to 10240 ft. 11,431.0 10,310.0 05:00 05:33 PUW 35k 3/18/2016 3/18/2016 0.55 PROD2 DRILL WPRT P 10310 ft.Wiper back in hole RIW 10,310.0 11,431.0 05:33 06:06 3/18/2016 3/18/2016 5.90 PROD2 DRILL DRLG P 11,431 ft. BOBD 1.44 bpm at4,010 11,431.0 11,830.0 06:06 12:00 psi FS,BHP 4,325 psi,WHP 690, IA 170,OA 0,CWT 1.9k,WOB 2.0k, ROP 72 3/18/2016 3/18/2016 1.50 PROD2 DRILL WPRT P Wiper to window,PUW 35k,Jet 41/2" 11,830.0 7,660.0 12:00 13:30 liner to 7,660 ft. 3/18/2016 3/18/2016 0.60 PROD2 DRILL WPRT P 7,660 ft. RBIH,RIW 9k 7,660.0 9,640.0 13:30 14:06 3/18/2016 3/18/2016 0.15 PROD2 DRILL DLOG P Tie in to K1 for a plus 4.5 ft. 9,640.0 9,663.4 14:06 14:15 correction. 3/18/2016 3/18/2016 0.95 PROD2 DRILL WPRT P 9663.4 ft.Continue wiper in hole,RIW 9,663.4 11,830.0 14:15 15:12 9k 3/18/2016 3/18/2016 6.75 PROD2 DRILL DRLG P 11,830 ft. BOBD 1.41 bpm at 3,835 11,830.0 12,230.0 15:12 21:57 psi FS,BHP 4,310 psi,WHP 660, IA 224,OA 0,CWT 3.3k,WOB 1.8k, ROP 83 *"""Note:12134 ft,New Mud at the bit 3/18/2016 3/18/2016 0.60 PROD2 DRILL WPRT P 12230 ft,Wiper up hole PUW 32k 12,230.0 11,230.0 21:57 22:33 Page 9/12 Report Printed: 4/5/2016 /it !It erations Summary (with Timelog ths) — 2K-25 ConoeoPhitiipp 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)r" End Depth(ftKB) 3/18/2016 3/18/2016 0.50 PROD2 DRILL WPRT P 11230 ft,Wiper back in hole RIW 7k 11,230.0 12,230.0 22:33 23:03 3/18/2016 3/19/2016 0.96 PROD2 DRILL DRLG P 12230 ft,BOBD 1.48 bpm at 3900 psi, 12,230.0 12,303.0 23:03 00:00 BHP 4331,WHP 747, IA 399,OA 0 3/19/2016 3/19/2016 6.15 PROD2 DRILL DRLG P 12303 ft,OBD 1.5 bpm at 4300 psi, 12,303.0 12,630.0 00:00 06:09 BHP 4380,WHP 777, IA 409,OA 0 3/19/2016 3/19/2016 1.95 PROD2 DRILL WPRT P Wiper to window,PUW 35k,Jet 4 1/2" ' 12,630.0 7,660.0 06:09 08:06 liner to 7,660 ft. 3/19/2016 3/19/2016 0.45 PROD2 DRILL WPRT P RBIH 7,660.0 9,940.0 08:06 08:33 3/19/2016 3/19/2016 0.15 PROD2 DRILL DLOG P Log RA for a plus 4.5 ft correction. 9,940.0 9,965.7 08:33 08:42 3/19/2016 3/19/2016 0.95 PROD2 DRILL WPRT P Wiper back in hole,RIW 8k. 9,965.7 12,630.0 08:42 09:39 3/19/2016 3/19/2016 6.15 PROD2 DRILL DRLG P 12,630 ft. OBD 1.55 bpm at 4,223 psi, 12,630.0 12,880.0 09:39 15:48 BHP 4,385 psi,WHP 785,IA 410,OA 0,CWT 0.5k,WOB 1.8k,ROP 60, BHA wipers. 3/19/2016 3/19/2016 0.35 PROD2 DRILL WPRT P Wiper trip 1,000 ft.PUW 35k. 12,880.0 11,880.0 15:48 16:09 3/19/2016 3/19/2016 0.50 PROD2 DRILL WPRT P Wiper back,RIW 5k,attempt to clear 11,880.0 12,880.0 16:09 16:39 bit jets 3/19/2016 3/19/2016 6.60 PROD2 DRILL DRLG P 12,880 ft. OBD 1.50 bpm at 4,290 12,880.0 13,200.0 16:39 23:15 psi,BHP 4,377 psi,WHP 616,IA 472, OA 0,CWT-3.3k,WOB 1.5k,ROP 60. 3/19/2016 3/20/2016 0.75 PROD2 DRILL WPRT P 13200 ft,wiper up hole PUW 35k 13,200.0 11,449.0 23:15 00:00 3/20/2016 3/20/2016 0.50 PROD2 DRILL WPRT P 11449 ft,Continue wiper up hole 11,449.0 10,300.0 00:00 00:30 3/20/2016 3/20/2016 0.95 PROD2 DRILL WPRT P 10300 ft,Wiper back in hole.RIW 7k 10,300.0 13,200.0 00:30 01:27 3/20/2016 3/20/2016 4.40 PROD2 DRILL DRLG P 13200 ft,BOBD 1.48 bpm at 3800 psi, 13,200.0 13,400.0 01:27 05:51 340 psi diff, BHP 4398,WHP 560,IA 501,OA 0 3/20/2016 3/20/2016 1.10 PROD2 DRILL WPRT P 13400 ft,TD L1-01 lateral,pump 13,400.0 12,332.0 05:51 06:57 10x10 sweep,PUW 34k.chase sweep.Call from town at Geo's need 100 ft more drilled. 3/20/2016 3/20/2016 0.50 PROD2 DRILL WPRT P 12,332 ft. RBIH,RIW 5k 12,332.0 13,400.0 06:57 07:27 3/20/2016 3/20/2016 0.80 PROD2 DRILL DRLG P 13,400 ft. OBD 1.46 bpm at 4,035 psi 13,400.0 13,449.0 07:27 08:15 FS,BHP 4,005 psi,WHP 600,IA 500, OA 0,CWT 3.6k,WOB 1.3k,ROP 60 3/20/2016 3/20/2016 0.90 PROD2 DRILL WPRT T PUH due to no clean surveys, 13,449.0 13,449.0 08:15 09:09 interference,PUW 34k.confer with town,RBIH 3/20/2016 3/20/2016 1.40 PROD2 DRILL DRLG P 13,449 ft. OBD 1.43 bpm at 4,002 psi 13,449.0 13,485.0 09:09 10:33 FS,BHP 4,506 psi,WHP 605, IA 527, OA 0,CWT-0.1k,WOB 1.8k,ROP 50 3/20/2016 3/20/2016 4.45 PROD2 DRILL WPRT P 13,485 ft.TD L1-01 lateral,pump 13,485.0 72.2 10:33 15:00 10x10 sweep,PUW 34k.Jet/Jog 4 1/2"liner,open EDC.PJSM-PUD BHA. Page 10/12 Report Printed: 4/5/2016 1 'orations Summary (with Timelog pths) 2K-25 ConocoPhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Ttte Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ttKB) 3/20/2016 3/20/2016 3.50 PROD2 DRILL PULD P Tag up,space out.PUD BHA#11, 72.2 0.0 15:00 18:30 floats not holding,PJSM-close EDC, annular(2nd barrier)continue PUD/ LD BHA#11,Bit condition- 3/20/2016 3/20/2016 1.50'PROD2 DRILL RURD P Install nozzle,Jet BOPE stack,grease 0.0 0.0 18:30 20:00 choke valves,tree, 3/20/2016 3/21/2016 4.00 PROD2 DRILL BOPE P Start bi-weekly BOPE test,250 psi 0.0 0.0 20:00 00:00 low/4400 psi high,witness waived by Chuck Scheve with State of Alaska. 3/21/2016 3/21/2016 3.00 PROD2 WHDBOP BOPE P Continue bi-weekly BOPE test,250 0.0 0.0 00:00 03:00 psi low/4400 psi high,witness waived by Chuck Scheve with State of Alaska. 3/21/2016 3/21/2016 1.00 PROD2 DRILL PULD P Stab INJH onto stump,displace coil 0.0 0.0 03:00 04:00 back to drilling mud. 3/21/2016 3/21/2016 3.05 PROD2 DRILL PULD P PJSM,PD drilling/cleanout BHA 0.0 62.6 04:00 07:03 3/21/2016 3/21/2016 2.10 PROD2 DRILL TRIP P RIH with BHA#12 62.6 9,640.0 07:03 09:09 3/21/2016 3/21/2016 0.15 PROD2 DRILL DLOG P Tie in to K1 for plus 5 ft correction. 9,640.0 9,664.2 09:09 09:18 3/21/2016 3/21/2016 1.40 PROD2 DRILL TRIP P RIH,Close EDC just above window, 9,664.2 13,270.0 09:18 10:42 PUW 33k,clean thru window,billet, pump sweep,no problems,RIW 5k at 13,270 ft. 3/21/2016 3/21/2016 1.50 PROD2 DRILL WPRT P 13,270 ft sweep at bit,PUW 32k, 13,270.0 13,270.0 10:42 12:12 circulate sweep out,take returns outside to clean up crude across shaker at bottoms up.sweeps out, bring back in.Pump beaded pill,RBIH from 13,000 ft. 3/21/2016 3/21/2016 4.00 PROD2 DRILL WPRT P 13,270 ft.POOH laying in beaded liner 13,270.0 62.6 12:12 16:12 pill/completion fluid to surface,paint EOP flags at 9,800 ft and 6,400 ft. 3/21/2016 3/21/2016 3.25 PROD2 DRILL OWFF T At surface,check well for flow,PJSM 62.6 62.2 16:12 19:27 for LD cleanout BHA, well is flowing shut in and monitor,45 min,WHP 20 psi,confer with town,decision was made to check well for flow again to rule out trip gas,bring pump up to fill lines,shut pump down,check well for flow,still flowing,shut in and montior, 30 min,WHP 25. 3/21/2016 3/21/2016 2.25 PROD2 DRILL TRIP T RIH,weighting up completion fluid 62.2 9,850.0 19:27 21:42 from 12.8 ppg to 13.0 ppg. 3/21/2016 3/21/2016 0.75 PROD2 DRILL DISP T Circulate well to 13.0 ppg 9,850.0 9,850.0 21:42 22:27 3/21/2016 3/22/2016 1.56 PROD2 DRILL TRIP T POOH,while displacing well to 13.0 9,850.0 5,227.0 22:27 00:00 ppg """Note:5200 ft.check well for flow, continue POOH 3/22/2016 3/22/2016 1.25 PROD2 DRILL TRIP T Continue POOH to surface. 5,227.0 62.2 00:00 01:15 3/22/2016 3/22/2016 0.50 PROD2 DRILL OWFF T OOH,check well for flow,no flow, 62.2 62.2 01:15 01:45 PJSM for LD BHA 3/22/2016 3/22/2016 - 0.58 PROD2 DRILL PULD P LD cleanout BHA 62.2 0.0 01:45 02:19 3/22/2016 3/22/2016 0.68 COMPZ2 CASING PUTB P PJSM,prep to run liner, 0.0 0.0 02:19 03:00 Page 11/12 Report Printed: 4/5/2016 � �m 1erations Summary (with Timelog ths) 3:2, 2K-25 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 (ftK8), End Depth(ftKB) 3/22/2016 3/22/2016 5.15 COMPZ2 CASING PUTB P MU L1-01 liner assembly with non- 0.0 3,355.3 03:00 08:09 ported bull nose,and 115 jts of slotted liner. 3/22/2016 3/22/2016 0.90 COMPZ2 CASING PULD P PJSM-MU L1-01 liner assembly to 3,355.3 3,399.5 08:09 09:03 BHA#13,MU to Coil Trak,surface test,tag up. 3/22/2016 3/22/2016 1.50 COMPZ2 CASING TRIP P RIH with BHA#13 L1-01 liner 3,399.5 9,800.1 09:03 10:33 assembly. 3/22/2016 3/22/2016 0.10 COMPZ2 CASING DLOG P Correct to 6400',EOP,-.8,PUW=35K 9,800.1 9,799.3 10:33 10:39 3/22/2016 3/22/2016 1.30 COMPZ2 CASING TRIP P Continue in with liner 9,799.3 12,970.0 10:39 11:57 3/22/2016 3/22/2016 0.10 COMPZ2 CASING DLOG P Make two attempts to tie in @ 6 fpm. 12,970.0 12,970.0 11:57 12:03 Liner setting down,PUW=42K, Continue in with liner no tie in 3/22/2016 3/22/2016 2.00 COMPZ2 CASING TRIP P Continue in well with liner,had to work 12,970.0 13,271.0 12:03 14:03 from 13000'down 3/22/2016 3/22/2016 0.80 COMPZ2 CASING CIRC P At 13271,Pump off liner, 1.1BPM @ 13,271.0 9,893.0 14:03 14:51 3450 PSI,remove liner length left in hole 9893.98,Circ 13.0 3/22/2016 3/22/2016 0.75 COMPZ2 CASING OWFF P S/D and perform static test, 9,893.0 9,893.0 14:51 15:36 BHP=4292,4300 psi after 30 min, works out to 13.1 PPG,Town called last lateral,Order seawater 3/22/2016 3/22/2016 6.00 COMPZ2 CASING WAIT T 9893 ft,wait on seawater.7pm truck is 9,893.0 9,893.0 15:36 21:36 on location.PJSM,off load into pits, ciruclate SW 3/22/2016 3/22/2016 1.50 COMPZ2 CASING DISP P POOH,displacing well to SW 9,893.0 2,500.0 21:36 23:06 3/22/2016 3/23/2016 0.90 DEMOB WHDBOP FRZP P LRS on location,PJSM,spot in 2,500.0 2,500.0 23:06 00:00 equipment,P/T line to 4000 psi, circulate freeze protect 3/23/2016 3/23/2016 1.00 COMPZ2 CASING TRIP P POOH 2,500.0 45.1 00:00 01:00 3/23/2016 3/23/2016 1.50 COMPZ2 CASING PULD P PJSM,PUD L1-01 liner setting BHA. 45.1 0.0 01:00 02:30 3/23/2016 3/23/2016 2.00 DEMOB WHDBOP MPSP P PJSM,load BPV equipment,PT 0.0 0.0 02:30 04:30 lubricator to 2500 psi,set BPV,load out eqiupment. *""Note:WHP 1420 psi 3/23/2016 3/23/2016 1.50 DEMOB WHDBOP RURD P Install nozzle,stab INJH, jet stack, 0.0 0.0 04:30 06:00 and flush surface lines 3/23/2016 3/23/2016 4.00 DEMOB MOVE RURD P Complete offloading fluids from rig, 0.0' 06:00 10:00 Run R/D Checklist,RIG RELEASE 10:00 Page 12/12 Report Printed: 4/5/2016 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-25L1-01 50-103-20124-61 Baker Hughes INTEQ 1�I Definitive Survey Report HUGHES 23 March,2016 • • II; ConocoPhillips ETA ConocoPhillips Definitive Survey Report BAKER iIES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-25 Project:; Kuparuk River Unit TVD Reference: 2K-25 @ 154.00usft(2K-25) .Site; 'Kuparuk 2K Pad MD Reference 2K-25 l/154.00usft(2K-25) Well2K-25 North Referenre; True Wellbore:l """ 2K-25L1 Survey Calculation Method: Minimum Curvature I i Design: 2K-25L1 Database: :'EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level , Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point 't Map Zone: Alaska Zone 04 Using geodetic scale factor , s Weil 2K-25 Well Position +N/-S 0.00 usft Northing: 5,937,935.20 usft Latitude: 70°14'29.979 N +Ei-W 0.00 usft Easting: 498,310.13usft Longitude: 150°0'49.130 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft .Wellbore'.. 2K-25L1-01 r s P s Magnetics Model Name -,Sample Date pectination Dip Angie Field Strength (1 (+) (nT} I BGGM2015 4/1/2016 18 35 8n89 57,486 Design 2K-25L1-01 °.'�N Audit Notes: I Version: 1.0 Phase: ACTUAL lie On Depth: 10,220.15 Vertical Section: Depth Front(ND} +Nf-S +Et-W Direction (sniff) ( "' (nen) (°) r 154.00 0.00 0.00 180n0 Survey Program Date 3/22/2016 { From To Survey Survey (usft).: (usft}- Survey(Wellbore) Total Name Description Start Date End Date 200.00 9,900.00 2K-25(2K-25) Copy of GYD-CT-CMS - Gyrodata cont.casing m/s 1/12/2001 9,921.00 10,220.15 2K-25L1(2K-25L1) MWD MWD-Standard 3/6/2016 3/14/2016 ., 10,234.00 13,445.42 2K-25L1-01(2K-25L1-01) MWD MWD-Standard 3/15/2016 3/20/2016 323/2016 9:53:06AM Page 2 COMPASS 5000.1 Build 74 • • ConocoPhillips EhIlI ConocoPhillips Definitive Survey Report SAUCER E5 Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: -Well 2K-25 -! Project: ;.Kuparuk River Unit TWD Reference: 2K-25(d 154.00usft(2K-25) Site: Kuparuk 2K Pad MD Reference; '.2K-25(d;154.00usft(2K-25) Well: 2K-25 North Reference: '.True • Wellbore:l 2K-25L1 Survey Calculation Method: Minimum Curvature Design: 2K-25L1 Database: '.EDM Alaska NSK Sandbox SurveyMa MD! Inc Axl TVD TVDSS *Ni-S •Et-W P Map - OLS Vertical Northing Eesting Section Survey Tool Name Annotation {uett} {°I {°} lusny (Atari) {uan} {uatt} {ft} (It) {n°°} (ft) 12220.15 9658 162.95 6,337.15 6183.15 -6,047.67 4,407.63 5,931,887.15 502,715.96 10.50 604767 MWD(2) TIP 12234.00 96.51 164.38 6335.57 6,181.57 -6,060.87 4,411.50 6931,873.94 502,719.83 10.27 6,060.87 MWD(3) KOP 12265.51 94.61 161.10 6,332.52 6,178.52 -6,090.82 4,420.81 5,931,844.00 502,729 13 11.99 6,090.82 MWD(3) 10,295.52 9246 159.90 6,330.67 6,176.67 -6,119.05 4,430.80 5,931,815.77 502,739.12 8.20 6,119.05 MWD(3) 10,325.41 91.01 157.80 6,329.77 6,175.77 -6,146.91 4,441.58 5,931,787.91 502,749.89 8.54 6,146.91 MWD(3) (: 10,35531 88.43 15726 6,329.91 6,175.91 -6,174.54 4,453.01 5,931,760.28 502761.31 8.82 6,174.54 MWD(3) 10,385.52 86.56 157.57 6,331.23 6,17723 -6202.40 4,464.60 5,931,732.42 502,772.89 6.27 6,202.40 MWD(3) 10,415.55 84.93 159.25 6,333.46 6,17946 -6,230.25 4,475 62 5,931,704.57 502,783.90 7.78 6,230.25 MWD(3) 10,445.66 8474 162.50 6,336.17 6,18217 -6,258.58 4,485.44 5,931,676.25 502,793.72 10.77 6,258.58 MWD(3) 12475.55 83.91 165.16 6,339.13 6,185.13 -6287.14 4,493.73 5,931647.68 502,802.00 9.28 6,287.14 MWD(3) 10,505.60 84.78 167.40 6,342.09 6,18809 -6,316.19 4,500.82 5,931618.64 502,809.08 7.96 6,316.19 MWD(3) 10,535.41 86.71 170.59 6,344.30 6190.30 -6,345.36 4,506 49 5,931,589.46 502,814.75 12.48 6,345.36 MWD(3) 10,565.81 89.45 17285 6,345.32 6191.32 -6,375.43 4,510.86 5,931559.40 502819 11 11.68 6,375.43 MWD(3) 12596.15 88.99 173.34 6345.73 6,191.73 -6405.54 4,51451 5,931,529.29 502,822.75 2.22 6,405.54 MWD(3) 10,630.66 89.02 17587 6,346.33 6,192.33 -6439.89 4,517.75 5,931,494.94 502825.99 7.33 6,439.89 MWD(3) 10,660.68 89.36 178.47 6,346.76 6,192.76 -6469.87 4,519 24 5,931,464.97 502,827.46 8.73 6,469.87 MWD(3) 10,690.69 91.14 182.06 6,346.63 6,192.63 -6,499.87 4,519.10 5,931,434.96 502,827.32 13.35 6,499.87 MWD(3) 10,720.68 90.80 184.33 6,346.12 6,19212 -6,529.81 4,51743 5,931,405.03 502,825.64 7.65 6,529.81 MWD(3) 10,750.74 91.78 186.81 6,345 44 6,19144 -6,559.72 4,51451 5,931,375.13. 502822.72 8.87 6,559.72 MWD(3) 10,780.59 9240 189.13 6,344.35 6,190.35 -6589.26 4,510.37 5,931,345.59 502,818.58 8.04 6,589.26 MWD(3) 10,810.66 92.86 191.56 6,342.97 6,188.97 -6,618.80 4,504.98 5,931,316.05 502,813.18 8.22 6,618.80 MWD(3) 10,840.61 9273 192.45 6,341.51 6,187.51 -6,648.06 4,498.76 5,931,286.79 502806.95 3.00 6,648.06 MWD(3) 10,870.71 91.97 189.21 6,34028 6,186.28 -6,677.60 4,493.11 5,931,25726 502801.29 11.05 6,677.60 MWD(3) 12900.61 9233 186.94 6,339.16 6,185.16 -6,707.18 4,486.91 5,931,227.68 502,797.09 7.68 6,707.18 MWD(3) 10,930.55 9203 184.58 6,338.02 6,184.02 -6,73695 4,485.91 5,931,197.92 502,79408 7.94 6,736.95 MWD(3) 10,960.57 91.87 181.89 6,336.99 6,18299 -6,766.90 4,48422 5,931,167 97 502,792.38 8.97 6,766.90 MWD(3) 12990.53 91.11 180.05 6,336.22 6,182.22 -6,796.84 4,483.71 5,931,138.03 502,791.87 6.64 6,796.84 MWD(3) 11,020.45 90.12 181.61 6,335.89 6,181.89 -6,826.76 4,483.28 5,931,108.12 502,791 43 6.17 6,826.76 MWD(3) 11250.53 89.54 182.53 6,33598 6,181.98 -6,856.82 4,482.19 5,931,078.07 502,790.34 3.62 6,856.82 MWD(3) 11280.32 9043 184.59 6335.99 6181.99 -6886.55 4,480 34 5,931248.34 502,788.48 7.53 6886.55 MWD(3) 3,23/2016 9:53:O6AM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips -4111 ConocoPhillips Definitive Survey Report BHUtillIES AICER -- ,Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Ca-ordlnafe Reference: Well 2K-25 Project: Kuparuk River Unit WO Reference: ':2K-25 @ 154.00usft(2K-25) She; Kuparuk 2K Pad MD Reference: '.2K-25 @ 154.00usft(2K-25) Weil; 2K-25 Made Reference; True Wellbore:': 2K-25L1 Survey Calculation Method: ':Minimum Curvature Design: 2K-25L1 Database: ':.EDM Alaska NSK Sandbox Survey.. MDinc AZi 1VLiTVDSS +Nf$ +EON Northing East]. OLS DLS Section survey Toad Name Annotation (ustrt i"1 t°1 1000 l 1 ,(u�tt 4 k �OD Ft+# t°110G} tiN I 11,110.37 9037 187.54 6,335.78 6,181.78 -6,916.42 447717 5,931,01846 502,78530 9.82 691642 MWD(3) 11,140.43 90.37 190.31 6,335.59 6,181.59 -6,946.12 4,472.50 5,930,988.78 502,780.63 9.21 6,946.12 MWD(3) 11,170.55 91.17 19281 6,335.18 6,181.18 -6,975.62 4,466.47 5,930,959.28 502,774.59 8.71 6,97562 MWD(3) 11,20059 91.57 194.82 6,33446 6,18046 -7,00478 4,459.30 5,930,93a 12 502,767.41 6.82 7,004.78 MWD(3) 11,230.47 91.90 197.00 6,333.56 6,179.56 -7,033.50 4,451 11 5,930,901.40 502759.22 7.38 7,033.50 MWD(3) 11,26053 91.50 200.31 6,332.67 6,178.67 -7,061.97 4,441.50 5,930,87295 502,749.60 11.09 7,061.97 MWD(3) 11,29052 92.15 20225 6,331.71 6,177.71 -7,089.89 4,43062 5,930,845.02 502,738.72 6.82 7,089.89 MWD(3) 11,320.68 9230 200.42 6,330.54 6,176.54 -7,117.97 4,419.66 5,930,816.96 502,727.75 6.08 7,117.97 MWD(3) 11,350.61 9147 198.43 6,329.56 6,175.56 -7,146.18 4,409.71 5,930,788.75 502,717.80 7.20 7,146.18 MWD(3) 11,380.60 89.29 195.85 6,329.36 6,175.36 -7,174.83 4,400.87 5,930,760.10 502,708.96 11.26 7,174.83 MWD(3) 11,41051 88.65 194.14 6,329.90 6,175.90 -7,203.71 4,393.14 5,930,731.22 502,701.21 610 7,203.71 MWD(3) 11,440.68 88.80 192.82 6,330.57 6,176.57 -7,233.04 4,386.11 5,930,701.90 502,694.18 440 7,23304 MWD(3) 11,470.52 88.86 189.58 6,331.18 6,177.18 -7,262.31 4,380 31 5,930,67264 502,688.38 1086 7,262.31 MWD(3) 11,50057 89.23 187.52 6,331.68 6,177 68 -7,292.02 4,375.85 5,930,642.93 502,683.90 6.96 7,292.02 MWD(3) 11,530.66 89.29 185.12 6,33207 6,178.07 -7,321.92 4,37253 5,930,613.03 502,680.59 7.98 7,321.92 MWD(3) 11,56062 87.18 18256 6,332.99 6,178.99 -7,351.79 4,37053 5,930,583.16 502,678.57 11.07 7,351.79 MWD(3) 11,590.52 85.88 179.90 6,334.80 6,180.80 -7381.63 4,369.89 5,930,55333 502,677.93 9.89 7,38163 MWD(3) 11,620.39 85.05 177.49 6,337.16 6,183.16 -7,411.39 4,370 57 5,930,52357 502,678.60 8.51 7,411.39 MWD(3) 11,650.46 84.18 175.57 6,339.98 6,185.98 -7,44128 4,37238 5,930,493.69 502,680.40 6.98 7,441.28 MWD(3) 11,680.46 83.29 173.22 6,343.26 6,189.26 -7,470.95 4,375.29 5,930,464.01 502,683.31 8.33 7,470.95 MWD(3) 11,710.58 85.27 171.35 6,346.26 6,19226 -7,50065 4,379.31 5,930,43432 502,687.32 9.02 7,500.65 MWD(3) 11,740.54 87.88 170.25 6,348.05 6,194.05 -7,53017 4,384 09 5,930,404.80 502,69210 9.45 7,530.17 MWD(3) 11,77054 88.00 17239 6,349.13 6,195.13 -7,559.80 4,388.62 5,930,375.17 502,696.61 7.14 7,559.80 MWD(3) 11,800.52 88.07 174.85 6,350.16 6,196.16 -7,589.58 4,391.95 5,930,345.40 502,699.94 8.20 7,589.58 MWD(3) 11,830.47 88.86 177.26 6,350.96 6,196.96 -7,619.44 4,394.01 5,930,315.54 502,701.99 8.47 7,619.44 MWD(3) 11,860.53 90.74 179.93 6,351.06 6,197 06 -7,649.49 4,394.74 5,930,285.49 502,702.72 1086 7,649.49 MWD(3) 11,890.47 9233 181.07 6350.26 6,196.26 -7,679.42 4,394.48 5,930,255.57 502,702.45 6.53 7,679.42 MWD(3) 2 11,92080 93.04 183.37 6,348.84 6,194.84 -7,709.69 4,393.31 5,930,225.30 502,70127 7.93 7,709.69 MWD(3) 1 I 11,95059 92.06 185.83 6,347.51 6,193.51 -7,739.35 4,390.92 5,930,195.64 502,698.88 8.88 7,739.35 MWD(3) g 11,98009 9273 188.81 6,346.28 6,19228 -7,768.58 4,387.17 5,930,166.41 502,695.12 10.35 7,768.58 MWD(3) 12,010.43 9264 191.58 6,344.86 6,190.86 -7,798.40 4,381.80 5,930,136.59 502,689.75 9.12 7,798.40 MWD(3) 31232016 9:59:06AA4 Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips iird'ill ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips(Alaska)Inc.-Kup2 LoCal Coordinate Reference: Well 2K-25 Project: Kuparuk River Unit ND Reference: 2K-2512)154 00usft(2K-25) s ,Site: Kuparuk 2K Pad MD Reference: 2K-25 @ 154.00usft(2K-25) z Well: 2K-25 North Reference: '.True Wellborn: 2K-25L1 Survey Calculation Method: '.Minimum Curvature • Design. 2K 25L1 Database: EDM Alaska NSK Sandbox .Sunray i. p MD'. Inc Aol - -SVD TVDSS +N!-S +L(.W N� Fastrg OLS Sadion Survey Tool Name Annotation (usft) (°) i°) , Wag) tushf NIRO tu#t) (ft) (ft) (°N001 (ft) , 12,040.42 9319 194.03 6,34333 6,189 33 -7,827.61 4,375.17 5,930,107.39 502,683.10 8.36 7,827.61 MWD(3) i 12,070.31 93.59 196.97 6,341.57 6,18757 -7,856.36 4,367.19 5,930,078.65 502,675 13 9.91 7,856.36 MWD(3) 12,100.36 9292 199.50 6,339.86 6,185.86 -7,884.85 4,357.81 5,930,05a 16 502,665.73 8.70 7,88485 MWD(3) 12,130.52 9221 201.17 6,338.51 6,18451 -7,913.10 4,347.34 5,930,021.92 502,655.26 6.01 7,91310 MWD(3) 12,160.76 91.93 204.06 6,337.42 6,183.42 -7,940.99 4,335.72 5,929,99403 502643.63 9.60 7,940.99 MWD(3) 12,190.87 90.55 206.10 6,336.77 6,182.77 -7,968.26 4,32296 5,929,966.77 502630.87 8.18 7,968.26 MWD(3) 12,220.48 90.80 203.88 6,336.42 6,18242 -7,995.09 4,310.45 5,929,93a 94 502,618.36 7.54 7,995.09 MWD(3) 12,250.38 89.85 203.20 6,336.25 6,182.25 -8,022.50 4,298.51 5,929,91254 502,606.41 3.91 8,022.50 MWD(3) 12,280.35 89.26 199.48 6,336.48 6,18248 -8,050.41 4,287.60 5,929,884.63 502,595.50 1257 8,050.41 MWD(3) I. 12,310.45 89.17 196.88 6,336.89 6,18289 -8,079.00 4,278.22 5,929,856.04 502,586.11 8.64 8,079.00 MWD(3) 12,340.45 88.80 194.73 6,337.42 6,183.42 -8,107.86 4,270.05 5,929,827.19 502,577.93 7.27 8,107.86 MWD(3) 12,370.25 87.94 189.60 6,338.27 6,18427 -8,136.97 4263.77 5,929,798.09 502,571.65 17.45 8,136.97 MWD(3) 12,400.32 87.39 188.35 6,339.50 6,18550 -8,166.65 4,259.08 5,929,768.41 502,566.96 454 8,166.65 MWD(3) 12,430.47 86.53 185.66 6,341.10 6,187.10 -8,196.53 4,255.41 5,929,738.54 502,56328 9.35 8,196.53 MWD(3) 12,460.42 8597 18265 6,34306 6,189.06 -8,226.33 4253.25 5,929,708.74 502,561.11 10.20 8,226.33 MWD(3) 12,490.34 85.64 179.82 6,345.25 6,191.25 -8,256.16 4,252.60 5,929,678.91 502,560.46 9.50 8,256.16 MWD(3) 12,520.37 85.23 177.12 6,347.64 6,193.64 -8,286.08 4,25340 5,929,648.99 502,561.25 9.07 8,286.08 MWD(3) 12,550.31 8548 175.39 6,350.06 6,196.06 -8,31586 4,25535 5,929,619.22 502,563 19 582 8,315.86 MWD(3) 12,580.30 8554 177.35 6,35241 6,19841 -8,345.70 4,25724 5,929,589.38 502,565.08 6.52 8,345.70 MWD(3) 12,610.45 86.65 179.15 6,354.46 6,200.46 -8,375.76 4,258.16 5,929,559.32 502,565.99 7.00 8,375.76 MWD(3) 12,640.49 88.96 181.10 6,355.61 6,201 61 -8,40578 4,258.10 5,929,529.31 502,565.92 10.06 8,40578 MWD(3) 12,670.40 90.77 183.08 6,35568 6,201 68 -8,435.66 4257.01 5,929,499.43 502,564.82 8.97 8,435.66 MWD(3) 12,700.37 90.52 183.81 6,35535 6,201.35 -8,46558 4,255.21 5,929,469.52 502,563.01 257 8,465.58 MWD(3) 12,730.46 90.77 186.69 6,355.01 6,201.01 -8,495.54 4252.45 5,929,439.56 502,560.25 9.61 8,495.54 MWD(3) § 12,760.29 90.40 189.51 6,354.70 6,200.70 -8,525.06 4,248.25 5,929,410.04 502,556.04 9.53 8,525.06 MWD(3) 12,790.27 90.64 19232 6,35443 6,200.43 -8,554.50 4,24257 5,929,380.61 502,550.36 9.41 8,554.50 MWD(3) 12,820.33 90.95 195.50 6,354.01 6,200.01 -8,583.67 4,235.35 5,929,351.44 502,543.13 10.63 8,58367 MWD(3) 12,850.30 91.66 198.13 6,35333 6,19933 -8,612.35 4,226.68 5,929,322.77 502,534.46 9.09 8,61235 MWD(3) 12,880.40 91.29 200.41 6,352.56 6,198.56 -8,640.75 4,216.75 5,929,294.37 502,52452 7.67 8,640.75 MWD(3) 12,910.37 91.04 202.90 6,351.95 6,197.95 -8,668.60 4,205.70 5,929,266.53 502,513.46 835 8,668.60 MWD(3) 12,940.15 90.52 205.11 6,351 54 6,197.54 -8,695.80 4,193.58 5,929,23a 33 502,501.34 7.62 8,695.80 MWD(3) 3/23/2098 9;53;06AM Page 5 COMPASS 5000.1 Build 74 i 0 ConocoPhillips //i�1 COtIOCOPhiliips Definitive Survey Report BAKERE IES Company:.. ConocoPhillips(Alaska)Inc.-Kup2 LocalCoordinate Reference: , Well 2K-25 i Project: Kupanik Rivet Unit TUR Reference: 2K-25 @ 154.00usft(2K-25) Site: Kuparuk 2K Pad MD Reference: 2K-25 @ 154.00usft(2K-25) Wall: 2K-25 North Reference: = True WtrIlbore: 2K-25L1 Survey Calculation Method: Minimum Curvature Dasipnl 2K-25L1 Database: '.EDM Alaska NSK Sandbox Survey t MD Inc All TVD '151955 +N/-S +E/-W N East ng OLS .'Section 1 " lusts) (1 (1 iusft) (68tk)" tum) tum) te} (e) (°noo, •section Survey Teel Nacre Annotation 12,970.36 90.64 207.16 6,351.23 6,197.24 -8,722.91 4,180.28 5,929,212 22 502,488.03 6.80 8,722.91 MWD(3) 13,000.30 91.11 204.80 6,350.78 6,196.78 -8,749.82 4,167.16 5,929,185.32 502,474.92 8.04 8,749.82 MWD(3) 13,030.37 90.86 203.00 6,350.26 6,196.26 -8,77731 4,154.98 5,929,157.84 502,462.73 6.04 8,777.31 MWD(3) 13,060.43 89.97 200.86 6,350.04 6,196.04 -8,805.19 4,143.76 5,929,129.96 502,451.50 7.71 8,805.19 MWD(3) 8 13,090.37 88.25 197.38 6,350.51 6,196.51 -8,833.47 4,133.96 5,929,10168 502,441 69 1296 8,833.47 MWD(3) 13,121 07 86.74 194.84 6,351 85 6,197.65 -8,862.93 4,125 45 5,929,072.23 502,433.18 9.62 8,86293 MWD(3) 13,150.36 85.42 193.47 6,353.85 6,199.85 -8,89127 4,118.30 5,929,043.90 502,426.02 6.49 8,891.27 MWD(3) 13,180.31 83.73 190.94 6,356.68 6,202.68 -8,920.41 4,112.00 5,929,014.76 502,419.71 10.13 8,920.41 MWD(3) 13,210.36 8237 189.05 6,360.32 6,206.32 -8,949.78 4,106.82 5,928,985.39 502,414.53 7.71 8,949.78 MWD(3) 13,240.23 81.09 186.61 6,364.62 6,210.62 -8,979.06 4,102.79 5,928,956.12 502,410.50 9.15 8,979.06 MWD(3) 13,270.30 79.34 184.86 6,369.73 6,215.73 -9,008.54 4,099.83 5,928,926.64 502,407 53 8.17 9,008.54 MWD(3) 13,300.29 77.88 182.03 6,375.65 6,221.65 -9,037.89 4,098.06 5,928,897.30 502,405.75 10.45 9,037.89 MWD(3) 13,330.33 76.74 179.86 6,382.25 6,228.25 -9,067.19 4,097.63 5,928,868.00 502,405.31 8.58 9,067.19 MWD(3) 13,370.29 75.12 176.50 6,391.97 6,237.97 -9,105.92 4,098.92 5,928,82927 502,406.60 8.68 9,10592 MWD(3) 13,400.47 74.42 173.51 6,399.90 6,245.90 -9,134.92 4,101.46 5,928,800.27 502,409.13 9.84 9,134.92 MWD(3) 13,445.42 69.55 17244 6,413.80 6,259.80 -9,177.34 4,106.68 5,928,757.86 502,414.34 11.07 9,177.34 MWD(3) 13,485.00 69.55 17244 6,427.62 6,273.62 -9,214.10 4,111.56 5.928,721.10 502,419.21 0.00 9,21410 PROJECTED to TD z. 3,2312016 9:53:06AM Page 6 COMPASS 5000.1 Build 74 11 6025 RECEIVE.I • 27046 APR 18 2O1t PRINT DISTRIBUTION LIST BAKER HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. Tom Osterkamp DATA LOGGED /01/201 700 G Street. '1 . WELL NAME 2K-25L1-01 M.K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE March 15,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE April 14,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PRINTS #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope I 0 0 I 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 0 I 0 I Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 0 I 0 I Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 I 1 I 1 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 1 I 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I 1 1 I 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • • 0 ■ to su ►i/a_ kr, Loweo ED o c C, SZ N N C 74.1 el N 0- Z • cic t c O cn ca. ce Q W 0 Z CD ._ c. TO s = = co 0 a = . Cl) �a V O 14;) a 4 _ .� crs O v N N p :hiL„� N � O C O Y Y N c_ t 0 = L L J M �� L tuV O co. Q. 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MAR 2 4 201bLetter of Transmittal Rau BAKER Date. DATA LOGGED iLlt/2014 March 23, 2016 BENDER HUGHES To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): I I 2K-25L1 21 6023 26 .7I 2K-25L1-01 2 6 9 7 5 21 6025 (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh(@BakerHughes.com • • .... 01 IMI VIS_ 11' `W; N O g_! CO it N N M AME: .414 ill cNi C �. c or ...... t co O 0. WCe a I— >, Q Z )'' 0 = E hi ON O O L m- N CO � N N C O Ne� do L V �. c. 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C O (0 N N Co N PIC (O 7 Co CD Cf) C N M el O) C CO C N N CO N co M N r C N- M O M co. r C CO CO `C fl- Q ,.Aiib V O O ai W O C0 t7 N Q7 O Cn V m Cn ; t O Y Y N N N .:M rn M cc. aD m m aD m m 0 0 # Q F OMM M O) N- N 0>Q { }5MO rM M Mr rO M M CO M O N. C COO - CCNTV tIh,l OOOOO OOO OO OOOOCO g) r 6rO O O O N) C.,2 ~ N N N M M M S� qO) M M M C) M (7 M MCF � Nhh _ V. rn g 03 -0 Z. .slqel f}L V OF TMJ S • 0.e,`,I � THE STATE Alaska Oil and Gas ti s O a T A 1f1 Conservation Commission : �1 1111 1 s JL��1 1 Loa, i, 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF 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 2K-25L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-025 Surface Location: 369' FNL, 95' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 4262' FNL, 1243' FEL, SEC. 13, T1ON, R8E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 190-012, API No. 50-103- 20124-00-00. 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 P. Foerster Chair DATED this (7 a day of February, 2016. RECEIVED STATE OF ALASKA A OIL AND GAS CONSERVATION COM•ON v----RtJI SED FEB 0 8 2016 PERMIT TO DRILL 20 AAC 25.005 la.Typ c .Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Ake Drill Lateral..Q Stratigraphic Test ❑ Development-Oil 0, Service- Winj ❑ Single Zone Q . Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q- Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc + Bond No. 59-52-18D • KRU 2K-25L1-01 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13,400' . TVD: 6,355'• Kuparuk River Field- 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): A Kuparuk Oil Pool ,, Surface: 369'FNL,95'FEL,Sec.11,T1ON,R8E,UM ' ADL 25605,I a.c5$3 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1051'FNL,1012'FEL,Sec. 13,T1ON,R8E,UM 2679 2/20/2016 Total Depth: 9.Acres in Property: 710 14.Distance to Nearest Property: 4262'FNL,1243'FEL,Sec. 13,T1ON,R8E,UM 2Wf 41),53 1015' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 154 . 15.Distance to Nearest Well Open Surface:x- 498310 y- 5,937,935 Zone- 4 ' GL Elevation above MSL(ft): 118 - to Same Pool: 2K-24,2588' 16.Deviated wells: Kickoff depth: .10,122' feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 1 1000 degrees Downhole: 4806 psig • Surface: 4170 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 3,380' 10,020' 6,360' 13,400' 6,355' 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): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 10,264 6539' none 10,230 6518 none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 191 sx AS II 115' 115' Surface 4,047' 9-5/8" 1300 sx AS III&450 sx Class G 4,082' 2,919' Production 10,197' 7" 300 sx G 10,224' 6,514' Scab liner 2,562' 4-1/2" 309 sx Class G 10,133' 6,457' Perforation Depth MD(ft): Planned pre-rig Perforation Depth TVD(ft): Planned pre-rig 9918'-9938',9860'-9880' 6321'-6333',6285'-6297' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 2// /a.0/L 22. I hereby certify that the foregoing is true and the procedure approved herein will not R.Phillips @265-6312 be deviated from without prior written approval. Contact Email ron.l.phillips(a)cop.com Printed Name D.Venhaus Icovec J ,e24/ Title CTD Engineering Supervisor Signature : fi1,1�" r __/„:-..---___ __,,.. , J Phone 263-4372 Date ,,/f6:/ Commission Use Only Permit to Drill _ API Number: / Permit Approval See cover letter for other Number: a)(2- OaS 50-'al-�O rag-�.I —Qo Date: 3 .01(0 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: 5c fie-5-t fa 411)O /75-I 5 Samples req'd: Yes❑ Nog Mud log req'd:Yes❑ NolZ fi✓a✓) vla ✓ rjrCVCvi ✓ ,/ tryt to z SGUpst S measures: Yes d No❑ Directional svy req'd:Yes[ ' No❑ Spacing exception req'd: Yes❑ No Inclination-only svy req'd:Yes❑ No l Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY / Approved by: — COMMISSIONER THE COMMISSION Date-I 7—/(r/(, 1'K �l 1 ire vn- z' G/IL Submit Form and Form 10-401(Revised 11/2015) /3ife1fl3 1ajçor 4 I[ nths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate NpV S ! ConocoPhillips RECEIVED Alaska P.O. BOX 100360 FEB ® 8 201 6 ANCHORAGE,ALASKA 99510-0360 AOGCC February 5, 2016 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a tri-lateral out of the KRU 2K-25 (190-012) using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin February 20, 2016. The CTD objective will be to drill three laterals(2K-25L1, 2K-25L1-01 &2K-25L1-02), targeting the Kuparuk A-sand intervals. Note the current A and C sand perforations were cemented behind a 4-1/2" scab liner during the RWO in January 2016 and the A sand perforations will be re-perforated to monitor the bottom hole pressure prior to CTD moving over this well to re-drill. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401)for 2K-25L1, 2K-25L1-01 &2K-25L1-02 — Detailed Summary of Operations — Directional Plans for 2K-25L1, 2K-25L1-01 &2K-25L1-02 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-265-6312. Sincerely, 152P"' Ron Phillips Coiled Tubing Drilling Engineer • • S ALASKA Kuparuk CTD Laterals NABOB , Drng, &We1� 2K-25L1, 2K-25L1-01 & 2K-25L1-02 CIA Conoco '° 5 Application for Permit to Drill Document 211C 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 2K-25 laterals 7 Attachment 2: Current Well Schematic for 2K-25 7 Attachment 3: Proposed Well Schematic for 2K-25 laterals 7 Page 1 of 7 February 5,2016 PTD Application: 2KSL1, 2K-25L1-01 & 2K-25L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2K-25L1, 2K-25L1-01 &2K-25L1-02. All laterals will be classified as"Development-Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2K-25L1, 2K-25L1-01 &2K-25L1-02. 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 4,400 psi. Using the maximum formation pressure in the area of 4,806"psi in 2K-24 (i.e. 14.5 ppg EMW), the maximum potential surface pressure in 2K-25, assuming a gas gradient of 0.1 psi/ft, would be 4,170 psi./ See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 2K-25 was measured to be 4483 psi (14.2 ppg EMW) on 4/09/2011. Wells 2K- 23 and 2K-24 are shut-in and we are monitoring the pressure decline, targeting below 12.0 ppg EMW. From this we expect the formation pressure to be 12.0 ppg EMW while drilling. The maximum downhole pressure in the 2K-25 vicinity is to the west in the 2K-24 injector at 4,806 psi (14.5 ppg EMW)from Nov 2015. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) None of the offset injection wells to 2K-15 have ever injected gas, so there is a low probability of encountering free gas while drilling the 2K-15 laterals. Nevertheless, if significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems in the 2K-25 laterals will be shale instability across faults. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2K-25 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 February 5,2016 • PTD Application: 2KKL1, 2K-25L1-01 & 2K-25L1-02 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 2%", 4.7#, L-80, ST-L slotted liner; 2K-25L1 10,122' 13,400' 6,193' 6,240` aluminum billet on top 2K-25L1-01 10,020' 13,400' 6,206' 6,201' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2K-25L1-02 9,915' 11,800' 6,165' 6,131' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (PO TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 115' 0' 115' 1,640 670 Surface 9-5/8" 36 J-55 BTC 0' 4,082' 0' 2,918' 3,520 2,020 Production 7" 26.0 J-55 BTC 0' 10,224' 0' 6,514' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 0 7,620' 0 4,909' 10,160 10,540 Scab liner 4-1/2" 11.6 L-80 BTC 7,571' 10,133' 4,881' 6,457' 7,780 6,350 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.3 ppg) — Drilling operations: Chloride-based FloVis mud (9.3 ppg). While this mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 12.2 ppg NaBr completion fluid in order to provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2K-25 laterals we will target a constant BHP of 12.2 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 February 5,2016 PTD Application: 2KKL1, 2K-25L1-01 & 2K-25L1-02 Pressure at the 2K-25 Window(9,920' MD,6322'TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12 ppg) 3945 psi 3945 psi Mud Hydrostatic(9.3 ppg) 3057 psi 3057 psi Annular friction(i.e. ECD, 0.080 psi/ft) 794 psi 0 psi Mud + ECD Combined 3851 psi 3189 psi (no choke pressure) (underbalanced -94 (underbalanced psi) -888 psi) Target BHP at Window(12.2 ppg) 4011 psi 4011 psi Choke Pressure Required to Maintain Target BHP 160 psi 953 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 7 February 5,2016 • PTD Application: 2KSL1, 2K-25L1-01 & 2K-25L1-02 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2K-25 was originally drilled and completed in 1990 as an 'A' and 'C' sand,gas lifted producer in Kuparuk. In 2002,the well was converted to injection. In 2010, communication between the tubing and IA was reported and the well was suspended in 2011. A rig work-over was performed, cementing a 4-1/2" scab liner from 7,571' to 10,133' and replacing the existing tubing and packers with new 3%2"tubing completion. Three laterals will be drilled two to the south and one to the north of the parent well with the laterals targeting the Kuparuk A4 and A5 sands. A thru-tubing whip-stock will be set pre-rig inside the 4'/2" scab liner at the planned kick off point of 9,920' MD. The 2K-25L1 lateral will exit through the 4'/2"liner and 7"casing at 9,920'MD and TD at 13,400' MD, targeting the Kuparuk A4 sands to the south. It will be completed with 2%"slotted liner from TD up to 10,122' MD with an aluminum billet for kicking off the 2K-25L1-01 lateral. ✓ The 2K-25L1-01 will also drill south to a TD of 13,400' MD,but invert to target the A5 sands. It will be completed with 2%"slotted liner from TD up to 10,020' MD with an aluminum billet for kicking off the 2K-25L1-02 lateral. The 2K-25L1-02 will drill north to a TD of 11,800' MD targeting the A4 and A5 sands. It will be completed with 2%"slotted liner from TD up to 9,915' MD with the liner top just inside the 4-1/2"liner 5' above the top of whipstock. Pre-CTD Work 1. Pull the BPV,re-perforate the Kuparuk A-sands and drift for a whipstock. 2. Set a whipstock,perform a SBHP test and set a BPV. 3. Prep site for Nabors CDR2-AC. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2K-25L1 Lateral(A4 sand south) a. Mill 2.80"window at 9,920' MD. b. Drill 3"bi-center lateral to TD of 13,400' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 10,122' MD. 3. 2K-25L1-01 Lateral(A5 sand south) a. Kick off of the aluminum billet at 10,122' MD. b. Drill 3"bi-center lateral to TD of 13,400' MD. c. Run 2%"slotted liner from TD up to 10,020' MD. 4. 2K-25L1-02 Lateral(A4/5 sands north) a. Kick off of the aluminum billet at 10,020' MD. b. Drill 3"bi-center lateral to TD of 11,800' MD. c. Run 2%" slotted liner from TD up to—9,915' MD,just above the whipstock 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's . 3. Return to production. Page 5 of 7 February 5,2016 • PTD Application: 214 L1, 2K-25L1-01 & 2K-25L1-02 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2K-25 laterals will be displaced to an overbalancing fluid (12.2 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA C 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (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 February 5,2016 • PTD Application: 21cL1, 2K-25L1-01 & 2K-25L1-02 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 2K-25L1 1,015' 2K-25L1-01 1015' 2K-25L1-02 791' - Distance to Nearest Well within Pool Lateral Name Distance Well. 2K-25L1 2,529' 2K-24 2K-25L1-01 2,588' 2K-24 2K-25L1-02 2,505' 2K-24 16. Attachments Attachment 1: Directional Plans for 2K-25 laterals Attachment 2: Current Well Schematic for 2K-25 Attachment 3: Proposed Well Schematic for 2K-25 laterals Page 7 of 7 February 5,2016 • • ConocoPhinips NADConversion Kuparuk River Unit Kuparuk 2K Pad 2K-25 2K-25L1-01 Plan: 2K-25L1-01_wp02 Standard Planning Report 05 February, 2016 BAKER HUGHES ~~f • ConocoPhillips •• Fait" COflOCOPIt;Ihips Planning Report BAKER HUGHES Database: EDMAIaskaANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-25 @ 154.00usft(2K-25) Site Kuparuk 2K Pad North Reference: ' True Well: 2K-25 Survey Calculation Method: Minimum Curvature Wellbore: 2K-25L1-01_wp02 Design: 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 2K Pad Site Position: Northing: 5,938,600.18 usft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17 usft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.01 ° Well 2K-25 Well Position +N/-S 0.00 usft Northing: 5,937,935.20 usft Latitude: 70°14'29.979 N +El-W 0.00 usft Easting: 498,310.13 usft Longitude: 150°0'49.130 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K-25L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (`) () (nT) BG GM201 4/1/2016 18.35 80.89 57,486 Design 5 2K-25L1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,122.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 180.00 2/5/2016 10:27:10AM Page 2 COMPASS 5000.1 Build 74 y,. • ConocoPhillips • 'Ail1 • Planning ReportCO1000PhBAI(ER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion Kuparuk TVD Reference: Mean Sea Level Project: River Unit Kuparuk 2K MD Reference: 2K-25 @ 154.00usft(2K-25) Site: Pad North Reference: True Well: 2K-25 Survey Calculation Method: Minimum Curvature :Neil bore: 2 K-2 5 L 1-01_w p 02 Design: Plan Sections Measured7'VD Below Dogleg Build Tum Depth Inclination Azimuth System +N/-S +El-W Rate Rate Rate TFp (usft) (°) (°) (usft) (Haft) (usft) (°/100usft) (flOUusft) (°/100usft) (°) Target 10,122.00 97.69 155.48 6,193.02 -5,960.91 4,367.35 0.00 0.00 0.00 0.00 10,192.00 100.12 159.79 6,182.18 -6,024.84 4,393.66 7.00 3.47 6.16 60.00 10,262.00 100.08 164.77 6,169.90 -6,090.47 4,414.63 7.00 -0.05 7.11 90.00 10,416.00 89.66 162.00 6,156.85 -6,237.28 4,458.47 7.00 -6.77 -1.80 195.00 10,716.00 87.18 182.86 6,165.23 -6,532.88 4,497.79 7.00 -0.83 6.95 97.00 10,866.00 87.22 172.35 6,172.57 -6,682.36 4,504.05 7.00 0.03 -7.01 270.00 11,016.00 87.27 182.86 6,179.79 -6,831.84 4,510.31 7.00 0.03 7.01 90.00 11,166.00 89.36 193.15 6,184.21 -6,980.11 4,489.45 7.00 1.39 6.86 78.70 11,366.00 89.38 179.15 6,186.42 -7,178.45 4,468.07 7.00 0.01 -7.00 270.00 11,666.00 89.42 200.15 6,189.60 -7,472.53 4,418.04 7.00 0.01 7.00 90.00 11,916.00 89.45 182.65 6,192.08 -7,716.63 4,368.81 7.00 0.01 -7.00 270.00 12,216.00 89.48 203.65 6,194.91 -8,007.12 4,300.93 7.00 0.01 7.00 90.00 12,566.00 89.74 179.15 6,197.32 -8,347.59 4,232.25 7.00 0.07 -7.00 270.50 12,816.00 89.75 196.65 6,198.44 -8,594.25 4,198.00 7.00 0.00 7.00 90.00 13,116.00 89.77 175.65 6,199.72 -8,890.85 4,166.02 7.00 0.01 -7.00 270.00 13,216.00 89.77 182.65 6,200.12 -8,990.78 4,167.49 7.00 0.00 7.00 90.00 13,400.00 89.77 195.53 6,200.86 -9,172.08 4,138.47 7.00 0.00 7.00 90.00 2/5/2016 10:27:10AM Page 3 COMPASS 5000.1 Build 74 1.-- . ConocoPhillips •• Fail COt1OCOPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-25©154.00usft(2K-25) Site: Kuparuk 2K Pad North Reference: True Well: 2K-25 Survey Calculation Method: Minimum Curvature We!tbere: 2K-25L1-01_wp 02 Design: Planned Survey Measured TVD BelowVertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (o) (°) (usft) (usft) (usft) (usft) (°/t00usfC) () (usft) (usft) 10,122.00 97.69 155.48 6,193.02 -5,960.91 4,367.35 5,960.91 0.00 0.00 5,931,973.91 502,675.71 TIP/KOP 10,192.00 100.12 159.79 6,182.18 -6,024.84 4,393.66 6,024.84 7.00 60.00 5,931,909.98 502,702.00 Start 7 dls 10,200.00 100.12 160.36 6,180.77 -6,032.25 4,396.34 6,032.25 7.00 90.00 5,931,902.57 502,704.68 10,262.00 100.08 164.77 6,169.90 -6,090.47 4,414.63 6,090.47 7.00 90.10 5,931,844.35 502,722.95 3 10,300.00 97.51 164.08 6,164.09 -6,126.64 4,424.71 6,126.64 7.00 -165.00 5,931,808.18 502,733.02 10,400.00 90.74 162.28 6,156.90 -6,222.05 4,453.56 6,222.05 7.00 -165.11 5,931,712.77 502,761.85 10,416.00 89.66 162.00 6,156.85 -6,237.28 4,458.47 6,237.28 7.00 -165.24 5,931,697.55 502,766.75 4 10,500.00 88.94 167.83 6,157.87 -6,318.34 4,480.32 6,318.34 7.00 97.00 5,931,616.49 502,788.58 10,600.00 88.11 174.79 6,160.45 -6,417.10 4,495.41 6,417.10 7.00 96.93 5,931,517.73 502,803.65 10,700.00 87.30 181.74 6,164.45 -6,516.91 4,498.44 6,516.91 7.00 96.75 5,931,417.93 502,806.66 10,716.00 87.18 182.86 6,165.23 -6,532.88 4,497.79 6,532.88 7.00 96.47 5,931,401.97 502,806.01 5 10,800.00 87.19 176.97 6,169.35 -6,616.74 4,497.92 6,616.74 7.00 -90.00 5,931,318.11 502,806.12 10,866.00 87.22 172.35 6,172.57 -6,682.36 4,504.05 6,682.36 7.00 -89.71 5,931,252.50 502,812.23 6 10,900.00 87.23 174.73 6,174.22 -6,716.10 4,507.87 6,716.10 7.00 90.00 5,931,218.76 502,816.05 11,000.00 87.26 181.74 6,179.03 -6,815.87 4,510.95 6,815.87 7.00 89.88 5,931,119.00 502,819.10 11,016.00 87.27 182.86 6,179.79 -6,831.84 4,510.31 6,831.84 7.00 89.55 5,931,103.03 502,818.46 7 11,100.00 88.43 188.63 6,182.94 -6,915.33 4,501.91 6,915.33 7.00 78.70 5,931,019.56 502,810.04 11,166.00 89.36 193.15 6,184.21 -6,980.11 4,489.45 6,980.11 7.00 78.48 5,930,954.78 502,797.57 8 11,200.00 89.36 190.77 6,184.59 -7,013.36 4,482.40 7,013.36 7.00 -90.00 5,930,921.53 502,790.51 11,300.00 89.37 183.77 6,185.70 -7,112.49 4,469.75 7,112.49 7.00 -89.97 5,930,822.42 502,777.84 11,366.00 89.38 179.15 6,186.42 -7,178.45 4,468.07 7,178.45 7.00 -89.90 5,930,756.47 502,776.14 9 11,400.00 89.38 181.53 6,186.79 -7,212.44 4,467.86 7,212.44 7.00 90.00 5,930,722.48 502,775.93 11,500.00 89.39 188.53 6,187.87 -7,311.99 4,459.10 7,311.99 7.00 89.97 5,930,622.94 502,767.14 11,600.00 89.41 195.53 6,188.92 -7,409.73 4,438.26 7,409.73 7.00 89.90 5,930,525.22 502,746.29 11,666.00 89.42 200.15 6,189.60 -7,472.53 4,418.04 7,472.53 7.00 89.83 5,930,462.43 502,726.06 10 11,700.00 89.42 197.77 6,189.94 -7,504.68 4,407.00 7,504.68 7.00 -90.00 5,930,430.28 502,715.00 11,800.00 89.43 190.77 6,190.94 -7,601.53 4,382.36 7,601.53 7.00 -89.98 5,930,333.45 502,690.35 11,900.00 89.44 183.77 6,191.93 -7,700.66 4,369.71 7,700.66 7.00 -89.91 5,930,234.33 502,677.67 11,916.00 89.45 182.65 6,192.08 -7,716.63 4,368.81 7,716.63 7.00 -89.84 5,930,218.36 502,676.77 11 12,000.00 89.45 188.53 6,192.89 -7,800.19 4,360.63 7,800.19 7.00 90.00 5,930,134.81 502,668.57 12,100.00 89.46 195.53 6,193.84 -7,897.93 4,339.79 7,897.93 7.00 89.94 5,930,037.09 502,647.72 12,200.00 89.48 202.53 6,194.76 -7,992.40 4,307.20 7,992.40 7.00 89.88 5,929,942.63 502,615.11 12,216.00 89.48 203.65 6,194.91 -8,007.12 4,300.93 8,007.12 7.00 89.81 5,929,927.92 502,608.83 12 12,300.00 89.54 197.77 6,195.62 -8,085.65 4,271.23 8,085.65 7.00 -89.50 5,929,849.40 502,579.12 12,400.00 89.61 190.77 6,196.37 -8,182.50 4,246.59 8,182.50 7.00 -89.45 5,929,752.57 502,554.46 12,500.00 89.69 183.77 6,196.98 -8,281.63 4,233.93 8,281.63 7.00 -89.40 5,929,653.45 502,541.78 12,566.00 89.74 179.15 6,197.32 -8,347.59 4,232.25 8,347.59 7.00 -89.35 5,929,587.50 502,540.08 13 12,600.00 89.74 181.53 6,197.47 -8,381.59 4,232.04 8,381.59 7.00 90.00 5,929,553.50 502,539.87 12,700.00 89.74 188.53 6,197.93 -8,481.14 4,223.27 8,481.14 7.00 89.99 5,929,453.96 502,531.08 2/5/2016 10:27:10AM Page 4 COMPASS 5000.1 Build 74 �s.� • ConocoPhillips •• FA�� Conoco Phillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion 'IVO Reference: Mean Sea Level Project; Kuparuk River Unit MD Reference: 2K-25 @ 154.00usft(2K-25) Site: Kuparuk 2K Pad North Reference: True Well; 2K-25 Survey Calculation Method: Minimum Curvature Wellbore; 2K-25L1-01_wp02 Design: Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Fasting (usft) (.) (0) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 12,800.00 89.75 195.53 6,198.37 -8,578.88 4,202.44 8,578.88 7.00 89.96 5,929,356.24 502,510.22 12,816.00 89.75 196.65 6,198.44 -8,594.25 4,198.00 8,594.25 7.00 89.93 5,929,340.87 502,505.78 14 12,900.00 89.75 190.77 6,198.81 -8,675.82 4,178.09 8,675.82 7.00 -90.00 5,929,259.31 502,485.86 13,000.00 89.76 183.77 6,199.23 -8,774.95 4,165.44 8,774.95 7.00 -89.97 5,929,160.19 502,473.19 13,100.00 89.77 176.77 6,199.65 -8,874.89 4,164.96 8,874.89 7.00 -89.94 5,929,060.27 502,472.68 13,116.00 89.77 175.65 6,199.72 -8,890.85 4,166.02 8,890.85 7.00 -89.92 5,929,044.30 502,473.74 15 13,200.00 89.77 181.53 6,200.06 -8,974.79 4,168.07 8,974.79 7.00 90.00 5,928,960.37 502,475.78 13,216.00 89.77 182.65 6,200.12 -8,990.78 4,167.49 8,990.78 7.00 89.98 5,928,944.39 502,475.19 16 13,300.00 89.77 188.53 6,200.46 -9,074.34 4,159.30 9,074.34 7.00 90.00 5,928,860.83 502,466.98 13,400.00 89.77 195.53 6,200.86 -9,172.08 4,138.47 9,172.08 7.00 89.98 5,928,763.11 502,446.13 Planned TD at 13400.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (1 (1 13,400.00 6,200.86 2 3/8" 2-3/8 3 Plan Annotations Measured Virticai Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 10,122.00 6,193.02 -5,960.91 4,367.35 TIP/KOP 10,192.00 6,182.18 -6,024.84 4,393.66 Start 7 dls 10,262.00 6,169.90 -6,090.47 4,414.63 3 10,416.00 6,156.85 -6,237.28 4,458.47 4 10,716.00 6,165.23 -6,532.88 4,497.79 5 10,866.00 6,172.57 -6,682.36 4,504.05 6 11,016.00 6,179.79 -6,831.84 4,510.31 7 11,166.00 6,184.21 -6,980.11 4,489.45 8 11,366.00 6,186.42 -7,178.45 4,468.07 9 11,666.00 6,189.60 -7,472.53 4,418.04 10 11,916.00 6,192.08 -7,716.63 4,368.81 11 12,216.00 6,194.91 -8,007.12 4,300.93 12 12,566.00 6,197.32 -8,347.59 4,232.25 13 12,816.00 6,198.44 -8,594.25 4,198.00 14 13,116.00 6,199.72 -8,890.85 4,166.02 15 13,216.00 6,200.12 -8,990.78 4,167.49 16 13,400.00 6,200.86 -9,172.08 4,138.47 Planned TD at 13400.00 2/5/2016 10:27:10AM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-25 2K-25L1-01_w p02 Travelling Cylinder Report 05 February, 2016 r' 1 BAKER HUGHES Baker Hughes INTEQ • i 1 ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-25 Project: Kuparuk River Unit TVD Reference: 2K-25 @ 154.00usft(2K-25) Reference Site: Kuparuk 2K Pad MD Reference: 2K-25 @ 154.00usft(2K-25) Site Error: 0.00 usft North Reference: True Reference Wall:, 2K-25 Survey Calculation Method: Minimum Curvature Weil Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 2K-25L1-01 Database: OAKEDMP2 Reference Design: 2K-25L1-01_wp02 Offset TVD Reference: Offset Datum Reference 2K-25L1-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,122.00 to 13,400.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,524.60 usft Error Surface: Elliptical Conic Survey Tool Program Date 1/4/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 9,900.00 2K-25(2K-25) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 9,900.00 10,122.00 2K-25L1_wp04(2K-25L1) MWD MWD-Standard 10,122.00 13,400.00 2K-25L1-01_wp02 MWD MWD-Standard (2K 25L1 01) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (••) 13,400.00 6,354.86 23/8" 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 2K Pad 2K-22-2K-22AL1-2K-22AL1 Out of range 2K-22-2K-22AL1-01-2K-22AL1-01 Out of range 2K-25-2K-25-2K-25 10,126.43 10,200.00 154.14 8.71 147.39 Pass-Major Risk 2K-25-2K-25L1-2K-25L1_wp04 10,125.00 10,125.00 0.01 0.40 -0.37 FAIL-Minor 1/10 2K-25-2K-25L1-02- 10,128.14 10,150.00 58.62 0.61 58.02 Pass-Minor 1/10 2K-25L1-02 wp03 Offset Design Kuparuk 2K Pad- 2K-25-2K-25-2K-25 Onset siteerror: 0.00 usft' SurveyProgram: 200-Copy of GYD-CT-GMS Rule Assigned:Major Risk Offset Weil Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Tootface+ Offset Mieilbore Centre casing Centre to No eo All4weble Warning Depth Depth Depth Depth azimuth +Na-s +E/-W Hole Site Centre Distance Deviation (usft} (weft) lush) (sett) (usR) (trent (`) (usft) (usft); f") fustt) (ustt) (usa) 10,126.43 6,346.42 10,200.00 6,499.03 0.16 1.72 -26.17 -5,986.20 4,373.06 2-11/16 154.14 8.71 147.39 Pass-Major Risk,CC,ES,SF 10,141.99 6,344.22 10,225.00 6,514.75 0.18 1.86 -24.91 -6,004.03 4,380.82 2-11/16 172.44 9.23 165.41 Pass-Major Risk 10,157.24 6,341.93 10,250.00 6,530.47 0.19 2.01 -23.61 -6,021.85 4,388.58 2-11/16 190.89 9.74 183.63 Pass-Major Risk 10,165.64 6,340.60 10,264.00 6,539.27 0.20 2.09 -22.87 -6,031.83 4,392.93 2-11/16 201.29 10.03 193.90 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/5/2016 3:55:27PM Page 2 COMPASS 5000.1 Build 74 I ■ � • W NO A0 0 W' ]--o o m 0 o � N O O O N No j= om N1 as m.oS s i�x o-1 _ mv f_. m Ww a. zsNosF _ _ P ` Z Ff NSOZ to l'IS 'NZ I I oo �8 " 1 ' � _ 3 F ��N _ 0 - OM NwN m N O, -VV I 1 N O W /1 c O o ill N - ! oo J N 1 I 1 -p .. 1 ao O 1 0 Wa2 0 0 0 0 0 0 0 0 o o 0 o o 0 0 11 - 0 0 -c o 0 0 0 0 0 0 0 0 0 0 000 0 0 0 --- ------ -- — W 0 d0' .1. 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O00 CD CV CA m o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o � +—T m 00 1. 0 0 0 I` ti 0 0 Cr;0 0 0 0 0 0 0 - ------ 0 U0N o0(010 N 1`00 N 0[)00 N 0-N-r_0- =t0 N rn o_o co o0 00 00 00 00 a0 a0 a0 a0 00 00 a0 0o ry w o — —1 O O O O O O O o 0 0 0 0 0 o O O o 0 O o 0 o O 0 O 0 J 0 "N NN 0_01(01 CO CO O CO(0(00000000 a O O V 'o r rn O IC N 0 t0 O c-(O(0(O (0 O '0 '0 1 '0 '0 '0 N 01-c00c-M(00 N 0100'-04 0 () V O o 0 0 0 0 N N N M M M C O 01 N 60CD 0NM00n OI-aOOOa-NM V(O CO N.z o u) (ut sn OSi) 12d0Q inoi.an°nu V KUP IIII 2K-25 �tocoPhill1 s a Weil Atbt Max Angie ID lk Alaska Inc, Wellbore APW WI Field Name Wellbore Status nal(°) MD(f KB) Act Btm(ftKB) t35325 501032012400 KUPARUK RIVER UNIT INJ 57.91 3,300.00 10,264.0 °°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2K-25 2/8/201e 1.1:3928 AM SSSV:LOCKED OPEN _ Last WO: 40.09 1/26/1990 Varfmal sdwmabc{aoNafi Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:TOC(SLM)9,603.0 3/12/2015 Rev Reason:CHEM CUT pproven 12/14/2015 Hanger,31.1 `.j':. 'acing$Yrfnga 3.3T�",T7"; i. ,) Casing Deacrtptlon OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread ''?4. " CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED I Casing Description OD(in) ID(in) Top(ftKB) Set Deptl1(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread l 1 SURFACE 95/8 8.765 35.0 4,082.1 2,918.5 36.00 J-55 BTC ii Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WeLen(I...Grade Top Thread 7"Production Tie back 7 6.276 33.0 2,319.0 1,927.6 26.00 L-80 Hydril 563 RWO 2016 Casing Description 00 lid) ID(tel Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread PRODUCTION 7 6.276 2,316.0 10,230.1 6,518.0 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread 4-1/2"Liner RWO 2016 4 1/2 4.000 7,565.1 10,127.0 6,453.1 11.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) ten.CONDUCTOR;35.0-115.0- 7,565.1 4,877.8 54.96 Hanger 2RH ZXP wtih HD Liner Top Packer(11.54'tie back 4.310 ggg sleeve) 7,583.7 4,888.5 54.91 Hanger Double Grip Flex Lock Liner Hanger 4.390 7,593.5 4,894.1 54.88 SBE(Seal Seal Bore Extension,5"TKC Pin x 5"BTC Pin 4.000 I i Bore . , Extension) 7"Praducffin Tie back Rwo 2016;33.0.2,319.0 I SI 7,612.7 4,905.2 54.64 XO Reducing Crossover Sub,5"BTCM Box x 4-1/2"IBT Pin 3.930 (Casing) Mandrel;3,315.1 0-r Tubing 1 gs Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(fL.Set Depth(ND)(...Wt(lb/ft) Grade Top Connection Tubing RWO 2016 31/2 2.992 31.1 7,620.3 4,909.6 9.30 L-80 EUE 8rd Mod Comp "•n Details I ......Nominal ID.. Top(ftK8) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.07 Hanger Cameron Tubing Hanger,CXS,7-1/16"x 3-1/2"EUE 8rd 2.920 Box Box,3"HBPVG SURFACE;as 0-4,082.1-. 7,534.7 4,860.3 55.05 Nipple- Nipple,HES,2.813"X,SN: 11X28127 2.812 2.813"'X' 7,584.3 4,888.8 54.91 Locator Locator Sub,GHB-22(bottom of locator spaced out 7.29') 2.990 Mandrel;5,298.6 tow IF 11 7,585.4 4,889.4 54.90 Seal Seal Assembly,80-40 2.990 Assembly Perforations&Slots Mandrel;6,718.1 +II 111 ........ Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,778.0 9,792.0 6,234.5 6,243.1 C-4,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. Ph Mandrel;7,473.6 9,860.0 9,880.0 6,284.9 6,297.3 A-5,2K-25 12/9/1993 6.0 APERF 21/8"EnerJet;90 deg. Si PH 9,912.0 9,948.0 6,317.1 6,339.6 A-4,2K-25 5/17/1990 4.0 IPERF 4.5"HLS CSG Guns;180 II deg.Ph Nipple-2813"'X';7,534.7 - 9,918.0 9,944.0 6,320.9 6,337.1 A-4,2K-25 11/20/1993 3.0 RPERF 21/8"EnerJet;Oriented Nipple-2 8131'X',7,534.7 i 45 deg CW Cement Squeezes Top(ND) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 9,575.0 9,730.0 6,108.4 6,204.9 CSG Cement 4/13/2011 CEMENT PLUG MILLED w/2.36"REAMER TO 9692' -I i3 Plug 9,615.0 9,700.0 6,133.5 6,186.4 TBG Cement 4/17/2011 Locator;7,584.3 Plug 1I s I Mandrel Inserts seal Assembly;7,585.4 A a I N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com I BB. 1 3,315.1 2,498.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 1/28/2016 I ti 2 5,298.6 3,604.8 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 1/28/2016 3 6,718.2 4,394.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 1/28/2016 APERF,9,778.09,792.0 4 7,473.6 4,825.4 Camco MMG 1 1/2 GAS LIFT SOV RKP 0.000 1/28/2016 Notes:General&Safety ' End Date Annotation 2/11/2010 NOTE:LEAK FOUND BETWEEN GLM#3 @ 7557'8 GLM#4 @ 8450' APERF;9,860.09,880.0-- 5/8/2010 NOTE:PACKER LEAK @ 9654',LLR=0.5 gpm @ 3000 psi 5/9/2010 NOTE:Confirmed Tubing Leaks @ 8087',8187',8244'w/Eline LDL 11/5/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 (PERF;9,912.0-9,9480 RPERF;9,918.09,944 0, I_1) 4-1/2'Liner RWO 2010;7,565.1- 10,127.0 PRODUCTION;2,316.0- 10,230 1 ,316.010,230.1 0 • O 0 2 m rr �b ,, , ON N N r Q N P NCD O ii j� `'p e1 o_ A = H N eM-1.. II ;; M _ X > L t6 rr a N- y OG CO , Q 11 .� ;; ;; 11 co m U Q 42 1,r 1" Ja 01 `8 p re O— C iI ii _ CyY,7 II ii=tCO Va .O N It p Y C rr ,r g p — Q'10 to r a 8 Y : '''=ppp i i II i i y� it te r� m g ixx r, c QL y .Mal O= ;; II OTA p ©, r C 0-0 N'C 01Itri ;; N�1 C Q" L t MOND .�-.m Nl�l ;, 00 '� M co ce N s N N CO C D = to 7 t6 § Ec� 3L W �C .4t V X r-- 8_c o N 2 3 '„• 8 0 d t 8 n 2 p 0l g�� `� y rn n . 2.1 t�� -ac,� ��} Xa m =Y� a� 3 .a Y A 2m M NY f/� `� ` CN� O � p i-: of U X v °> a� `m �'I-W Z 'r ~0 1, �•1, r N .1C i s x U.c r M M Cr) M m i N p j r PI la 4, ; Cr a G N ,.ttfi:;=4;0wgt1:.44*x ;qt,W=;,'tz tzar{,xtztt 7 !=4;t444,W r ttt;t44V' "4* 1111 it V i�+'.{i r vv;�;{:.{ifi:46.,.{zi{r;r,{:{;t, ziv-AS{4rk{.• o-mvz zi:,, {r,rtj :r...'S i G[ N '' „ /n r, a ' Q. r; o ., 0 Qp 0 Ln 2 ,q N ,� §- 2.,t,p 10 0 C = MN `CN to00 �: .=w �2 1 0 e� &n X22 c- V7 •-a) Nio tiI'� C�rd Tim W� a 3 a ,; O N0 16 N 111 le ooh t8 c e- N 4g N W X wr N N RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMA ION F_B 0 3 2016 PERMIT TO DRILL ` 20 AAC 25.005 Tt,) '' .>�� 1 a.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if w: is proposed for: Drill D Lateral Q Stratigraphic Test ❑ Development-Oil ❑� Service- Winj ❑ Single Zone Q Coalbed Gas M Gas Hydrates ❑ Redrit❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geotherm. 0 Shale Gas 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well ame and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 KRU 2K-25AL1 3.Address: 6.Proposed Depth: 12.F-Id/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13,400' TVD: 6,355' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk Oil Pool Surface: 369'FNL,95'FEL,Sec. 11,T1ON,R8E,UM ADL 25605 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1051'FNL,1012'FEL,Sec. 13,T1ON,R8E,UM 2679 2/20/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4262'FNL,1243'FEL,Sec. 13,T1ON,R8E,UM 2560 1015' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 154 15.Distance to Nearest Well Open Surface:x- 498310 y- 5,937,935 Zone- 4 GL Elevation above MSL(ft): 118 to Same Pool: 2K-24,2588' 16.Deviated wells: Kickoff depth: 10,122' feet 17.Maximum Potential Pressures• psig(see 20 AAC 25.035) Maximum Hole Angle: 100° degrees Downhole: 4806 psig Surface: 4170 psig 18.Casing Program: Specifications Top - Setting Dept - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD D TVD (including stage data) 0 3" 2.375" 4.7# L-80 ST-L 3,380' 10,020' 6,. 0' e,r13,400' 6,355' slotted liner ,ALJ. 19. PRESENT WELL CONDITION SUMMARY(To be completed for R..rill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effe Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 10,264 6539' none 10,230 6518 none Casing Length Size I - Cement Volume MD TVD Conductor/Structural 80' 16" 19 -AS II 115' 115' Surface 4,047' 9-5/8" k'•I'4 sx AS III&450 sx Class G 4,082' 2,919' Production 10,197' 7" 6''0 sx G 10,224' 6,514' Scab liner 2,562' 4-1/2" > 09 sx Class G 10,133' 6,457' , Perforation Depth MD(ft): Planned pre-rig Perforation Depth TVD(ft): Planned pre-rig 9918'-9938',9860'-9880' 6321'-6333',6285'-6297' 20. Attachments: Property Plat ❑ BOP Sketch Prof Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch /A Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date /000/6 ^ 22.I hereby certify that the foregoing is true and the proced e approved herein will not R. Phillips @265-6312 i�t be deviated from without prior written approval. Contact Email ron.l.phillips()a cop.com Printed Name D.Venhaus Title CTD Engineering Supervisor Signatu•- /`rte, (f jn ))A , V-r;•/1.,;,V,k_3`7 Phone 263-4372 Date /21/& Commission Use Only Permit to Drill API umber: Permit Approval See cover letter for other Number: 50- Date: requirements. Conditions of approval: If box i checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other: Samples req'd: Yes❑ No❑ Mud log req'd:Yes❑ No❑ H2S measures: Yes 0 No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ I Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: n Submit Form and Form 10-401(Revised 11/2015) This permit is valid for 24 0 r t a f r val(20 AAC 25.005(g)) Attachments in Duplicate • ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 2, 2016 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a tri-lateral out of the KRU 2K-25 (190-012) using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin February 20, 2016. The CTD objective will be to drill three laterals (2K-25A, 2K-25AL1 &2K-25AL2), targeting the Kuparuk A-sand intervals. Note the current A and C sand perforations were cemented behind a 4-1/2" scab liner during the RWO in January 2016 and the A sand perforations will be re-perforated to monitor the bottom hole pressure prior to CTD moving over this well to re-drill. Attached to this application'are the following documents: — Permit to Drill Application Forms (10-401) for 2K-25A, 2K-25AL1 &2K-25AL2 — Detailed Summary of Operations — Directional Plans for 2K-25A, 2K-25AL1 &2K-25AL2 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-265-6312. Sincerely, Ron Phillips Coiled Tubing Drilling Engineer • S KuparukNA80AS ALASKA CTD Laterals 2K-25A, 2K-25AL1 & 2K-25AL2 IJvi ConocoFhdles Application for Permit to Drill Document 2nC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 2K-25A laterals 7 Attachment 2: Current Well Schematic for 2K-25 7 Attachment 3: Proposed Well Schematic for 2K-25A laterals 7 Page 1 of 7 February 2,2016 • S PTD Application: 2K-25A, 2K-25AL1 & 2K-25AL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2K-25A, 2K-25AL1 &2K-25AL2. All laterals will be classified as"Development-Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2K-25A, 2K-25AL1 &2K-25AL2. 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 4,400 psi. Using the maximum formation pressure in the area of 4,806 psi in 2K-24 (i.e. 14.5 ppg EMW), the maximum potential surface pressure in 2K-25, assuming a gas gradient of 0.1 psi/ft, would be 4,170 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 2K-25 was measured to be 4483 psi (14.2 ppg EMW) on 4/09/2011. Wells 2K- 23 and 2K-24 are shut-in and we are monitoring the pressure decline, targeting below 12.0 ppg EMW. From this we expect the formation pressure to be 12.0 ppg EMW while drilling. The maximum downhole pressure in the 2K-25 vicinity is to the west in the 2K-24 injector at 4,806 psi (14.5 ppg EMW)from Nov 2015. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) None of the offset injection wells to 2K-15 have ever injected gas, so there is a low probability of encountering free gas while drilling the 2K-15 laterals. Nevertheless, if significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems in the 2K-25 laterals will be shale instability across faults. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2K-25 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 February 2,2016 PTD A lication pp 2K-25A, 2K-25AL1 & 2K-25AL2 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 2K-25A 10,122' 13,400' 6,193' 6,240` 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2K-25AL1 10,020' 13,400' 6,206' 6,201' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2K-25AL2 9,915' 11,800' 6,165' 6,131' 23/ 4.7#, L-80, ST-L slotted liner; aluminum billet on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (ppf) TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 115' 0' 115' 1,640 670 Surface 9-5/8" 36 J-55 BTC 0' 4,082' 0' 2,918' 3,520 2,020 Production 7" 26.0 J-55 BTC 0' 10,224' 0' 6,514' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 0 7,620' 0 4,909' 10,160 10,540 Scab liner 4-1/2" 11.6 L-80 BTC 7,571' 10,133' 4,881' 6,457' 7,780 6,350 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.3 ppg) — Drilling operations: Chloride-based FloVis mud (9.3 ppg). While this mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 12.2 ppg NaBr completion fluid in order to provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2K-25 laterals we will target a constant BHP of 12.2 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 February 2,2016 • • PTD Application: 2K-25A, 2K-25AL1 & 2K-25AL2 Pressure at the 2K-25 Window(9,920' MD, 6322' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12 ppg) 3945 psi 3945 psi Mud Hydrostatic(9.3 ppg) 3057 psi 3057 psi Annular friction (i.e. ECD, 0.080 psi/ft) 794 psi 0 psi Mud + ECD Combined 3851 psi 3189 psi (no choke pressure) (underbalanced -94 (underbalanced psi) -888 psi) Target BHP at Window(12.2 ppg) 4011 psi 4011 psi Choke Pressure Required to Maintain 160 psi 953 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 February 2,2016 • PTD Application:pp 2K-25A, 2K-25AL1 & 2K-25AL2 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2K-25 was originally drilled and completed in 1990 as an 'A' and 'C' sand, gas lifted producer in Kuparuk. In 2002,the well was converted to injection. In 2010, communication between the tubing and IA was reported and the well was suspended in 2011. A rig work-over was performed, cementing a 4-1/2" scab liner from 7,571' to 10,133' and replacing the existing tubing and packers with new 3'/2"tubing completion. Three laterals will be drilled two to the south and one to the north of the parent well with the laterals targeting the Kuparuk A4 and A5 sands. A thru-tubing whip-stock will be set pre-rig inside the 4'/2" scab liner at the planned kick off point of 9,920' MD. The 2K-25A sidetrack will exit through the 4%2"liner and 7"casing at 9,920'MD and TD at 13,400' MD, targeting the Kuparuk A4 sands to the south. It will be completed with 2%" slotted liner from TD up to 10,122' MD with an aluminum billet for kicking off the 2K-25AL1 lateral. The 2K-25AL1 will also drill south to a TD of 13,400' MD, but invert to target the A5 sands. It will be completed with 2%" slotted liner from TD up to 10,020' MD with an aluminum billet for kicking off the 2K-25AL2 lateral. The 2K-25AL2 will drill north to a TD of 11,800' MD targeting the A4 and A5 sands. It will be completed with 2%" slotted liner from TD up to 9,915' MD with the liner top just inside the 4-1/2"liner 5' above the top of whipstock. Pre-CTD Work 1. Pull the BPV,re-perforate the Kuparuk A-sands and drift for a whipstock. 2. Set a whipstock,perform a SBHP test and set a BPV. 3. Prep site for Nabors CDR2-AC. Ri2 Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2K-25A sidetrack(A4 sand south) a. Mill 2.80"window at 9,920' MD. b. Drill 3"bi-center lateral to TD of 13,400' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 10,122' MD. 3. 2K-25AL 1 Lateral(A5 sand south) a. Kick off of the aluminum billet at 10,122' MD. b. Drill 3"bi-center lateral to TD of 13,400' MD. c. Run 2%"slotted liner from TD up to 10,020' MD. 4. 2K-25AL2 Lateral(A4/5 sands north) a. Kick off of the aluminum billet at 10,020' MD. b. Drill 3"bi-center lateral to TD of 11,800' MD. c. Run 2%" slotted liner from TD up to—9,915' MD,just above the whipstock 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's 3. Return to production. Page 5 of 7 February 2, 2016 PTD Application: 2K-25A, 2K-25AL1 & 2K-25AL2 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2K-25 laterals will be displaced to an overbalancing fluid (12.2 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • 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 February 2, 2016 PTD Application: 2K-25A, 2K-25AL1 & 2K-25AL2 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 2K-25A 1,015' 2K-25AL1 1015' 2K-25AL2 791' - Distance to Nearest Well within Pool Lateral Name Distance Well 2K-25A 2,529' 2K-24 2K-25AL1 2,588' 2K-24 2K-25AL2 2,505' 2K-24 16. Attachments Attachment 1: Directional Plans for 2K-25A laterals Attachment 2: Current Well Schematic for 2K-25 Attachment 3: Proposed Well Schematic for 2K-25A laterals Page 7 of 7 February 2,2016 11111 MI • • mggeft, ill W2 g H . I i 1 1 -o 10 ! I - f f _m �eogg — ( CO m a2 i U>N ]E O O 1 10 N 0 • 1n O N N8 O J Nm -I CO• (LI -1 d ry O N N off, N i -11.02g- i 3 '5 ,4 , , 5 TN . NI.,,,,,„,„,„,„„„_ _____ m_ ,_.- MI O F, w�P - • ---- ,-- 1w�1� may/} ®:., jI }II 1` Q N -_-:o yM Ai "SOS__ -moi M O _O C .. a `ma N C'N NI — - N M3 4,14O ` d .NNNMr - --N 0 Y Y N N G , - - 0 d , ,4 0 3x al -- , ®-_ • all % o E YL o N x o mum � QN 0 o a o o O a o 0 o O o 0 0 oo o N Y. O O o 0 0 h N ' N O N , O r ' 1 W 1 O r O q v v c .? .? a a L7,,,,_ O I•i- 3 (ui/gsn OSZ)(+)ggiIoNJ(-)q nos N • i C011000PtliiiipS NADConversion Kuparuk River Unit Kuparuk 2K Pad 2K-25 2K-25AL1 Plan: 2K-25AL1_wp02 Standard Planning Report 05 January, 2016 BAKER HUGHES lir' ConocoPhillips Ir�`. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-25 @ 154.00usft(2K-25) Site: Kuparuk 2K Pad North Reference: " True Weil: 2K-25 Survey Calculation Method: Minimum Curvature Wellbore: 2K-25AL1 Design: 2K-25AL1_wp02 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 2K Pad Site Position: Northing: 5,938,600.18 usft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17 usft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.01 ° Well 2K-25 Well Position +N/-S 0.00 usft Northing: 5,937,935.20 usft Latitude: 70°14'29.979 N +El-W 0.00 usft Easting: 498,310.13 usft Longitude: 150°0'49.130 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Welibore 2K-25AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 4/1/2016 18.35 80.89 57,486 Design 2K-25AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,122.00 Vertical Section: Depth From(TVD) ', +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 180.00 1/5/2016 10:27:10AM Page 2 COMPASS 5000.1 Build 74 tr- ConocoPhillips r/111. ConocoPhdlips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-25 @ 154.00usft(2K-25) Site: Kuparuk 2K Pad North Reference True Well: 2K-25 Survey Calculation Method: Minimum Curvature Welihore: 2K-25AL1 Design: 2K-25AL1_wp02 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) (°1100usft) (1100usft) (°) Target 10,122.00 97.69 155.48 6,193.02 -5,960.91 4,367.35 0.00 0.00 0.00 0.00 10,192.00 100.12 159.79 6,182.18 -6,024.84 4,393.66 7.00 3.47 6.16 60.00 10,262.00 100.08 164.77 6,169.90 -6,090.47 4,414.63 7.00 -0.05 7.11 90.00 10,416.00 89.66 162.00 6,156.85 -6,237.28 4,458.47 7.00 -6.77 -1.80 195.00 10,716.00 87.18 182.86 6,165.23 -6,532.88 4,497.79 7.00 -0.83 6.95 97.00 10,866.00 87.22 172.35 6,172.57 -6,682.36 4,504.05 7.00 0.03 -7.01 270.00 11,016.00 87.27 182.86 6,179.79 -6,831.84 4,510.31 7.00 0.03 7.01 90.00 11,166.00 89.36 193.15 6,184.21 -6,980.11 4,489.45 7.00 1.39 6.86 78.70 11,366.00 89.38 179.15 6,186.42 -7,178.45 4,468.07 7.00 0.01 -7.00 270.00 11,666.00 89.42 200.15 6,189.60 -7,472.53 4,418.04 7.00 0.01 7.00 90.00 11,916.00 89.45 182.65 6,192.08 -7,716.63 4,368.81 7.00 0.01 -7.00 270.00 12,216.00 89.48 203.65 6,194.91 -8,007.12 4,300.93 7.00 0.01 7.00 90.00 12,566.00 89.74 179.15 6,197.32 -8,347.59 4,232.25 7.00 0.07 -7.00 270.50 12,816.00 89.75 196.65 6,198.44 -8,594.25 4,198.00 7.00 0.00 7.00 90.00 13,116.00 89.77 175.65 6,199.72 -8,890.85 4,166.02 7.00 0.01 -7.00 270.00 13,216.00 89.77 182.65 6,200.12 -8,990.78 4,167.49 7.00 0.00 7.00 90.00 13,400.00 89.77 195.53 6,200.86 -9,172.08 4,138.47 7.00 0.00 7.00 90.00 1/5/2016 10:27:10AM Page 3 COMPASS 5000.1 Build 74 1,, ConocoPhillips • /dill�oPhilhtps Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion ND Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 2K-25 @ 154.00usft(2K-25) Site;r Kuparuk 2K Pad North Reference: True Well: 2K-25 Survey Calculation Method: Minimum Curvature Wellbore: 2K-25AL1 Design: 2K-25AL1_wp02 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-5 +E/_W Section Rate Azimuth Northing Easting (usft) (°1 (°) lust') (usft) (usft) (usft) (°l1DOusft) (°) (usft) (usft) 10,122.00 97.69 155.48 6,193.02 -5,960.91 4,367.35 5,960.91 0.00 0.00 5,931,973.91 502,675.71 TIP/KOP 10,192.00 100.12 159.79 6,182.18 -6,024.84 4,393.66 6,024.84 7.00 60.00 5,931,909.98 502,702.00 Start 7 dls 10,200.00 100.12 160.36 6,180.77 -6,032.25 4,396.34 6,032.25 7.00 90.00 5,931,902.57 502,704.68 10,262.00 100.08 164.77 6,169.90 -6,090.47 4,414.63 6,090.47 7.00 90.10 5,931,844.35 502,722.95 3 10,300.00 97.51 164.08 6,164.09 -6,126.64 4,424.71 6,126.64 7.00 -165.00 5,931,808.18 502,733.02 10,400.00 90.74 162.28 6,156.90 -6,222.05 4,453.56 6,222.05 7.00 -165.11 5,931,712.77 502,761.85 10,416.00 89.66 162.00 6,156.85 -6,237.28 4,458.47 6,237.28 7.00 -165.24 5,931,697.55 502,766.75 4 10,500.00 88.94 167.83 6,157.87 -6,318.34 4,480.32 6,318.34 7.00 97.00 5,931,616.49 502,788.58 10,600.00 88.11 174.79 6,160.45 -6,417.10 4,495.41 6,417.10 7.00 96.93 5,931,517.73 502,803.65 10,700.00 87.30 181.74 6,164.45 -6,516.91 4,498.44 6,516.91 7.00 96.75 5,931,417.93 502,806.66 10,716.00 87.18 182.86 6,165.23 -6,532.88 4,497.79 6,532.88 7.00 96.47 5,931,401.97 502,806.01 5 10,800.00 87.19 176.97 6,169.35 -6,616.74 4,497.92 6,616.74 7.00 -90.00 5,931,318.11 502,806.12 10,866.00 87.22 172.35 6,172.57 -6,682.36 4,504.05 6,682.36 7.00 -89.71 5,931,252.50 502,812.23 6 10,900.00 87.23 174.73 6,174.22 -6,716.10 4,507.87 6,716.10 7.00 90.00 5,931,218.76 502,816.05 11,000.00 87.26 181.74 6,179.03 -6,815.87 4,510.95 6,815.87 7.00 89.88 5,931,119.00 502,819.10 11,016.00 87.27 182.86 6,179.79 -6,831.84 4,510.31 6,831.84 7.00 89.55 5,931,103.03 502,818.46 7 11,100.00 88.43 188.63 6,182.94 -6,915.33 4,501.91 6,915.33 7.00 78.70 5,931,019.56 502,810.04 11,166.00 89.36 193.15 6,184.21 -6,980.11 4,489.45 6,980.11 7.00 78.48 5,930,954.78 502,797.57 8 11,200.00 89.36 190.77 6,184.59 -7,013.36 4,482.40 7,013.36 7.00 -90.00 5,930,921.53 502,790.51 11,300.00 89.37 183.77 6,185.70 -7,112.49 4,469.75 7,112.49 7.00 -89.97 5,930,822.42 502,777.84 11,366.00 89.38 179.15 6,186.42 -7,178.45 4,468.07 7,178.45 7.00 -89.90 5,930,756.47 502,776.14 9 11,400.00 89.38 181.53 6,186.79 -7,212.44 4,467.86 7,212.44 7.00 90.00 5,930,722.48 502,775.93 11,500.00 89.39 188.53 6,187.87 -7,311.99 4,459.10 7,311.99 7.00 89.97 5,930,622.94 502,767.14 11,600.00 89.41 195.53 6,188.92 -7,409.73 4,438.26 7,409.73 7.00 89.90 5,930,525.22 502,746.29 11,666.00 89.42 200.15 6,189.60 -7,472.53 4,418.04 7,472.53 7.00 89.83 5,930,462.43 502,726.06 10 11,700.00 89.42 197.77 6,189.94 -7,504.68 4,407.00 7,504.68 7.00 -90.00 5,930,430.28 502,715.00 11,800.00 89.43 190.77 6,190.94 -7,601.53 4,382.36 7,601.53 7.00 -89.98 5,930,333.45 502,690.35 11,900.00 89.44 183.77 6,191.93 -7,700.66 4,369.71 7,700.66 7.00 -89.91 5,930,234.33 502,677.67 11,916.00 89.45 182.65 6,192.08 -7,716.63 4,368.81 7,716.63 7.00 -89.84 5,930,218.36 502,676.77 11 12,000.00 89.45 188.53 6,192.89 -7,800.19 4,360.63 7,800.19 7.00 90.00 5,930,134.81 502,668.57 12,100.00 89.46 195.53 6,193.84 -7,897.93 4,339.79 7,897.93 7.00 89.94 5,930,037.09 502,647.72 12,200.00 89.48 202.53 6,194.76 -7,992.40 4,307.20 7,992.40 7.00 89.88 5,929,942.63 502,615.11 12,216.00 89.48 203.65 6,194.91 -8,007.12 4,300.93 8,007.12 7.00 89.81 5,929,927.92 502,608.83 12 12,300.00 89.54 197.77 6,195.62 -8,085.65 4,271.23 8,085.65 7.00 -89.50 5,929,849.40 502,579.12 12,400.00 89.61 190.77 6,196.37 -8,182.50 4,246.59 8,182.50 7.00 -89.45 5,929,752.57 502,554.46 12,500.00 89.69 183.77 6,196.98 -8,281.63 4,233.93 8,281.63 7.00 -89.40 5,929,653.45 502,541.78 12,566.00 89.74 179.15 6,197.32 -8,347.59 4,232.25 8,347.59 7.00 -89.35 5,929,587.50 502,540.08 13 12,600.00 89.74 181.53 6,197.47 -8,381.59 4,232.04 8,381.59 7.00 90.00 5,929,553.50 502,539.87 12,700.00 89.74 188.53 6,197.93 -8,481.14 4,223.27 8,481.14 7.00 89.99 5,929,453.96 502,531.08 1/5/2016 10:27:10AM Page 4 COMPASS 5000.1 Build 74 • ,- ConocoPhillips • .sal ConocoPhilkps Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2K-25 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-25 @ 154.00usft(2K-25) Site: Kuparuk 2K Pad North Reference: True Well: 2K-25 Survey Calculation Method: Minimum Curvature Wellbore: 2K-25AL1 Design: 2 K-25A L 1_w p 02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Ni-S +El-W Section Rate Azimuth Northing Easting (usft) (°) (o) (usft) (usft) (usft) (usft) (l100usft) (°) (usft) (usft) 12,800.00 89.75 195.53 6,198.37 -8,578.88 4,202.44 8,578.88 7.00 89.96 5,929,356.24 502,510.22 12,816.00 89.75 196.65 6,198.44 -8,594.25 4,198.00 8,594.25 7.00 89.93 5,929,340.87 502,505.78 14 12,900.00 89.75 190.77 6,198.81 -8,675.82 4,178.09 8,675.82 7.00 -90.00 5,929,259.31 502,485.86 13,000.00 89.76 183.77 6,199.23 -8,774.95 4,165.44 8,774.95 7.00 -89.97 5,929,160.19 502,473.19 13,100.00 89.77 176.77 6,199.65 -8,874.89 4,164.96 8,874.89 7.00 -89.94 5,929,060.27 502,472.68 13,116.00 89.77 175.65 6,199.72 -8,890.85 4,166.02 8,890.85 7.00 -89.92 5,929,044.30 502,473.74 15 13,200.00 89.77 181.53 6,200.06 -8,974.79 4,168.07 8,974.79 7.00 90.00 5,928,960.37 502,475.78 13,216.00 89.77 182.65 6,200.12 -8,990.78 4,167.49 8,990.78 7.00 89.98 5,928,944.39 502,475.19 16 13,300.00 89.77 188.53 6,200.46 -9,074.34 4,159.30 9,074.34 7.00 90.00 5,928,860.83 502,466.98 13,400.00 89.77 195.53 6,200.86 -9,172.08 4,138.47 9,172.08 7.00 89.98 5,928,763.11 502,446.13 Planned TD at 13400.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (*")+ 13,400.00 6,200.86 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth', Depth +N/-5 *El W (usft) (usft) (usft) (usft) Comment 10,122.00 6,193.02 -5,960.91 4,367.35 TIP/KOP 10,192.00 6,182.18 -6,024.84 4,393.66 Start 7 dls 10,262.00 6,169.90 -6,090.47 4,414.63 3 10,416.00 6,156.85 -6,237.28 4,458.47 4 10,716.00 6,165.23 -6,532.88 4,497.79 5 10,866.00 6,172.57 -6,682.36 4,504.05 6 11,016.00 6,179.79 -6,831.84 4,510.31 7 11,166.00 6,184.21 -6,980.11 4,489.45 8 11,366.00 6,186.42 -7,178.45 4,468.07 9 11,666.00 6,189.60 -7,472.53 4,418.04 10 11,916.00 6,192.08 -7,716.63 4,368.81 11 12,216.00 6,194.91 -8,007.12 4,300.93 12 12,566.00 6,197.32 -8,347.59 4,232.25 13 12,816.00 6,198.44 -8,594.25 4,198.00 14 13,116.00 6,199.72 -8,890.85 4,166.02 15 13,216.00 6,200.12 -8,990.78 4,167.49 16 13,400.00 6,200.86 -9,172.08 4,138.47 Planned TD at 13400.00 1/5/2016 10:27:10AM Page 5 COMPASS 5000.1 Build 74 • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-25 2K-25AL1 2K-25AL1_wp02 Travelling Cylinder Report 04 January, 2016 r' 1 BAKER HUGHES • Baker Hughes INTEQ • ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-25 Project Kuparuk River Unit TVD Reference: 2K-25 @ 154.00usft(2K-25) Reference Site: Kuparuk 2K Pad MD Reference: 2K-25 @ 154.00usft(2K-25) Site Error: 0.00 usft North Reference: True Reference Well: 2K-25 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 2K-25AL1 Database: OAKEDMP2 Reference Design: 2K-25AL1_wp02 Offset TVD Reference: Offset Datum Reference 2K-25AL1_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.O0usft Error Model: ISCWSA Depth Range: 10,122.00 to 13,400.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,524.60 usft Error Surface: Elliptical Conic Survey Tool Program Date 114/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 9,900.00 2K-25(2K-25) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 9,900.00 10,122.00 2K-25A_wp04(2K-25A) MWD MWD-Standard 10,122.00 13,400.00 2K-25AL1_wp02(2K-25AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C')+ 13,400.00 6,354.86 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 2K Pad 2K-22-2K-22AL1-2K-22AL1 Out of range 2K-22-2K-22AL1-01-2K-22AL1-01 Out of range 2K-25-2K-25-2K-25 10,126.43 10,200.00 154.14 8.71 147.39 Pass-Major Risk 2K-25-2K-25A-2K-25A_wp04 10,125.00 10,125.00 0.01 0.40 -0.37 FAIL-Minor 1/10 2K-25-2K-25AL2-2K-25AL2_wp03 10,128.14 10,150.00 58.62 0.61 58.02 Pass-Minor 1/10 Offset Design Kuparuk 2K Pad- 2K-25-2K-25-2K-25 Offset site Error 0.00 us* Survey Program: 200-Copy of GYD-CT-CMS 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 Oa Allowable warning Depth Depth Depth Depth Azimuth +fd/-s +gb401 Hole Size Centre Distance Deviation (usft) (usft) tusft) tusft) fusR) lush) ' t°) tush) (usC)' (") (usft) (usft) NSR) 10,126.43 6,346.42 10,200.00 6,499.03 0.16 1.72 -26.17 -5,986.20 4,373.06 2-11/16 154.14 8.71 147.39 Pass-Major Risk,CC,ES,SF 10,141.99 6,344.22 10,225.00 6,514.75 0.18 1.86 -24.91 -6,004.03 4,380.62 2-11/16 172.44 9.23 165.41 Pass-Major Risk 10,157.24 6,341.93 10,250.00 6,530.47 0.19 2.01 -23.61 -6,021.85 4,388.58 2-11/16 190.89 9.74 183.63 Pass-Major Risk 10,165.64 6,340.60 10,264.00 6,539.27 0.20 2.09 -22.87 -6,031.83 4,392.93 2-11/16 201.29 10.03 193.90 Pass-Major Risk 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These materials may be found in the original hard file or check the parent folder to view it in digital format. • 410 TRANSMITTAL LETTER CHECKLIST WELL NAME: c2/(— .2$L —0/ PTD: cV2 —01S ✓Development Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: g,„f.A..4; /� ILkf POOL: '44104ANA �IVEJ f/ yD&RJ. 21\AAr Ell 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. 190'OI 2 , API No. 50-103 - a0I 1 / -Oa - c)o. (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 e • N , , O, O . a) d , m U) _o vi p. �, c, a, % v , C ns, �, . Q 0 3�0 ' 0- a)' �� ❑ N, 0 c o, c c, Z @ v a1 c oE o > O 0 d �' a co 0) 2 0. a U. 3 c 0, a) v 0) CO C atS, a .0 y 0 "c. c -- o c : v' � c �� �� o � g, D , O .0 • ` 0. d co rN w, , 0Ci1 �' 0' ` 0 t �' d O. .0, N , I- J 00� C, � 8 CO 0- 't N 4� Fii V. O, U 2. p, a E to o, S ZI co > •�C,,, • EO c, a). d 0 , In N, a� �; D, CO CO LO . o . E ai a, 4 m, 0 p Q, a, 0 c N m E o :? :: �'. 0 y 0 . 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