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Home My WebLink About217-136MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 8, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-114 KUPARUK RIV UNIT 1H-114 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/08/2025 1H-114 50-029-23584-00-00 217-136-0 W SPT 3732 2171360 1500 1052 1052 1050 1049 90 220 220 220 4YRTST P Austin McLeod 8/20/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1H-114 Inspection Date: Tubing OA Packer Depth 210 2000 1970 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250823131214 BBL Pumped:1.3 BBL Returned:1.2 Wednesday, October 8, 2025 Page 1 of 1            TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard Drive data drop 1H-111 50-029-23581-00 217133_1H-111_IPROFWFL_03JUL2023 1H-114 50-029-23584-00 217136_1H-114_IPROF_17Oct23 1H-115 50-029-23605-00 218053_1H-115_IPROF RSTWFL_09May2022 1H-116 50-029-23594-00 218012_1H-116_IPROFWFL_05Jul2023 1H-117 50-029-23602-00 218032_1H-117_PPROF-WFL_06July23 218032_1H-117_WFL_18Oct23 1H-119 50-029-23591-00 217178_1H-119_WFL_07Jul2023 1J-102 50-029-23317-00 206110_1J-102_RPPG_18Jul2023 1J-107 50-029-23366-00 207107_1J-107_PPROF_10May2022 1J-162 50-029-23360-00 207080_1J-162_LDL_03May2022 1J-170 50-029-23310-00 206062_1J-170_Temp-Pres_11Jul2023 1J-176 50-029-23364-00 207099_1J-176_LDL_11May2022 4of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38340 T38341 T38342 T38344 T38343 T38345 T38346 T38347 T38348 T38349 T38350 2/29/2024 1H-114 50-029-23584-00 217136_1H-114_IPROF_17Oct23 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϭϳϭϯϲϬͲ^Ğƚ͗ϯϲϮϲϲJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 H-114 KUPARUK RIV UNIT 1H-114 Sre: Inspector Reviewed By:e� P.I. Supry Comm Well Name KUPARUK RIV UNIT 1H -I 14 API Well Number 50-029-23584-00-00 Inspector Name: Bob Noble Permit Number: 217-136-0 Inspection Date: 8/2/2021 Insp Num: mitRCN210802131016 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IH -114 - Type In' �W TVD 3732 Tubin 1050 - 1050 - YP J ' 1050- IOSO - PTD 2171360 - -Type Test SPT- -- Test psi 1500 IA 250 1860 - 1800 1780 BBL Pumped: 1 - BB � TL Returned t j aas OA495:::-[ a9s 495 Interval —� avRTST !p/F P V Notes: Wednesday, August 4, 2021 Page I of I Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax Delivered to: } 41 AOGCC ,It ATTN: Natural Resources Technician II -� Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 y Anchorage, AK 99501 2LI KUPARUK RIVER I WL 11-1-111 50-029-23-00 DWUJ-00160 1H•114 50.029-23584581-00 DWUJ-00161 1 H-119 50-029.23591.00 DWUJ-00162 1H-115 50-029-23605-00 DWUJ-00163 11-1-1086 50-029-23608.02 I DWUJ-00164 1H-116 I Name I Signature Please return via courier or sign/scan and email a copy Al - WL WL WL Date lumberger and OPAL Schlumberger -Private WFL IPROF 117136 69 TRANSIVIRTALIDATE 24 -Jan -20 24Ja n20 -JW 02 FINAL FIELD I 10 -Jan -20 1 FIELD 15 -Jan -20 1 FIELD 16 -Jan -20 1 FIELD 17 -Jan -20 1 FIELD 18Jan-20 1 FIELD 19 -Jan -20 1 FIELD 0 -Jan -20 1 20 -Jan -20= 7 ( A Transmittal Receipt signature confirms that a package (box, Z10 envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: r~ Jf AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision \y 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 312G® • • 27 -Sep -19 27Sep19-JW01 Schlumberger -Private Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 s011h Anchorage, AK 99501 21 71 36 TRANSMITTAL DATE TRANSMITTAL $I � . • , NAME API # ORDERSERVICE It FIELDWELL NAME DESCRIPTIONDELIVERABLE DESCRIPTIONDATA TYPE DATELOGGED Prints CD's 1H-114 50.029-23584.00 EOSH•00071 KUPARUK RIVER WL IPROF FINAL FIELD 15 -Jul -19 1 1H-111 50.029-23581.00 EAI8.00022 KUPARUK RIVER WL IPROF-WFL FINAL FIELD 17 -Jul -19 1 11-1-105 50.029-20727-01 Ell 18-00075 KUPARUK RIVER WL IPROF-WFL FINAL FIELD 19 -Jul -19 1 11-1-113 50-029.23588-00 E118-00076 KUPARUK RIVER WL IPROF-WFL FINAL FIELD 20 -Jul -19 1 1H-116 50.029-23594-00 E118-00077 KUPARUK RIVER WL (PROF-WFL FINAL FIELD 21 -Jul -19 1 3M-19 50-029.21737-00 E118-00078 KUPARUK RIVER WL Caliper FINAL FIELD 22 -Jul -19 1 3G -07A 50.103-20127-01 E118-00079 KUPARUK RIVER I WL PPROF FINAL FIELD I 23 -Jul -19 1 3G-11 50-103-20133.00 E118.00081 KUPARUK RIVER WL [PROF FINAL FIELD 25Jul-19 1 3M-13 50-029-21720-00 E118-00084 KUPARUK RIVER WL Caliper FINAL FIELD 28 -Jul -19 1 113.116AL1 50-029.22457-60 EDEA -00009 KUPARUK RIVER Memory PPROF FINAL FIELD 28 -Jul -19 1 1A-17 50-029.22102-00 E118-00085 KUPARUK RIVER WL LDL FINAL FIELD 29 -Jul -19 1 1C-121 50-029-23015-00 E118-00086 KUPARUK RIVER WL [PROF FINAL FIELD 1 -Aug -19 1 3N -14A 50-029-21589.01 EOSH-00074 KUPARUK RIVER WL LDL,Caliper FINAL FIELD 2 -Aug -19 1 3G-08 50.103-20128.00 EOSH-00075 KUPARUK RIVER I WL LDL,Caliper FINAL FIELD 3 -Aug -19 1 2N-317 50-103.20266-00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 IRECEEIVED 15 return via courier or sign/scan and email a copy to and CPAI. Schlumberger -Private SCANNED AUG 0 7 2019 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Auditor - ConocoPh'Mips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7a' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: 6� 1 %- /-�Cp R,ECOVEO MAY 0 8 2019 ,AQG..` C Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10.404) Kuparuk Field Date 6/612019 1J & 1H Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of Cement top off cement date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal U-180 50029233290000 2061500 20'9" 2.80 115" 5/4/2019 5 5/5/2019 11-1-101 50029235850000 2171380 210" 0.70 9" 5/4/2019 2.2 5/5/2019 1H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 50029235930000 2180030 2'2.5" 045 9" 5/4/2019 2.2 5/5/2019 1H-104 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 5/5/2019 1 H-1088 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 1H-109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 1H-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2 5/5/2019 1H-111 50029235810000 2171330 2' 0.35 9" 5/4/2019 2.2 5/5/2019 1H-113 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 1.7 5/5/2019 1H-114 50029235840000 2171360 1111" 0.25 7.5" 5/4/2019 1.8 5/5/2019 1H-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 2 5/5/2019 1H-116 50029235940000 2180120 17" 0.25 7" 5/4/2019 1.7 5/5/2019 1H-117 50029236020000 2180320 111" 0.35 7" 5/4/2019 1.7 5/5/2019 1H-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 1H-119 50029235910000 2171780 3' 0.80 8" 5/4/2019 1.8 5/5/2019 Originated: Schlumberger PTS-PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: -r ,w:f� AOGCC �N ATTN: Natural Resources Technician II --7 Alaska Oil & Gas Conservation Commision `y! 333 W. 7th Ave, Suite 100 "bh Anchorage, AK 99501 2 17 136 TRANSMITTALDATE r TRANSMITTAL# � WELLNAME 1E-104 --TO ,. AP 50-029-23234-00 •r - SERVICE ORDER EA77-00006 FIELD NAME DESCRIPTION KUPARUK RIVER SERVICE WL DELIVERABLE DESCRIPTION (PRO DATA FINAL FIELD Color DATE LOGGEU 20 -Feb -19 r 1 1A -05 1A-07 1H-118 2A-17 2V-04 1H-114 3C -15A -029-20627.00 50-029-20658-00 50.029-23578.00 50-103-20193-00 50.029-21041-00 50-029-23584-00 50-029.21426.01 EOSH-00028 EOSH-00029 EOSH-00030 EA77-00009 EA77-00010 EOSH•00031 EA77-00011 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WLSiCaliper WL WL WL WL WL IPROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 16 -Mar -19 17 -Mar -19 18 -Mar -19 18 -Mar -19 19 -Mar -19 19 -Mar -19 20•Mar•19 1 1 1 1 1 1 1REGE 8 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X-1 package have been verified to match the media noted above. The Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this via courier or sign/scan and email a copy t chlumberger and CPAI. point. :Center@slb.com Tom Osterkij p onocoohillips com Schlumberger -Private 14) • 0 M 4 COp �" p r r r r r .- P x fl s- QU 0 v E Ntmro : *CV o4c _I "--cow ; 1' N U 0. a c OC O OC >, a-+ 0 4 in _CUE Q': U-1 CO oo co 00 0o WWWWWW N N Oa 6' m Q O w f6 a ' a a a a a a a E s -6 Li O N J 2 2 a a a a a a a a a 47_ r ~ co M M r h O r N M 4 N O U C Z Q c v > E \6 v Q 6 O c i H CD} 0 0 0 0 0 0 0 0 0 0 0 C I- p 01 1Wil ..4 ....i ( il C O y W W W W W W W W W W W v U `- LL LL LL LL LL LL LL LL LL LL LL +� N a) N -0 Q J J J J J J J J J J J n' > 4- .- a) v) c H_ `~ 0 Z Z Z Z Z Z Z Z Z Z Z cl) O N LL LL LL LL LL LL LL LL LL LL LL K .-., > C ro N @ C 61) Oo O _0 A CN U 0 Z a N u > - N 0 C O@ E to .0 O r:7 Q N 0_ Q OC 0_ /r` C =O 0 t a O LL O O 7 .a LL LL LL -1 � a 73 0 - -- X 3 3 3 &. c' g w U 0 en a CO C ° •-_, > I, N to W 4- O � 0 a Q N. _.• W a ..... — ..c - a GI Z ro W Z O >•h> O W D IS Z Y L - a J J 0 J 6 J J J J J J C o < 44m < w 3 3 C 3 � 3 3 3 3 3 3 v L'.4 11:1 110 a) CLCCCeCtIXCLo: CtI7LCLCe 0 wwwwwuwwwwww m 0 W > > > > > > > > > > > z Q w w w 0_ 0: ce0C 0C w m ce N a Z Y Y Y Y Y Y Y Y Y Y Y ' - 0 > > > > > > > > > > > .c II 0: 0C W De 0: CC 0: 0C W 0: a) w Q Q Q Q Q Q Q Q Q Q Q >' o oe LLaaaaaaaaaaa a e— DD > > 7 > > > > > > a 0 0 Y Y Y Y Y Y Y Y Y Y Y ' c o Usi up w op O) 0) N O o0 N M co X V7 Es a @1 in co 0 ccV co '� O 0 o 0 o 0 co co co co co co d Y ILI V daodoacnchcncndh ,Q > C003 2 m 2 00 0 o O O c) C W w 00p00000000 CO CC X `, CE rovl o 4- 0 0 0 0 0 0 0 0 0 0 0 0 c n 0 0 0 0 0 0 0 0 0 0 0 00 Iz. 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I c o 0 J v C..2 >" E Q r 0 E O C ta I— = r- I— Ho 0 Z N CO c CD > N O w E CO1 11 - o E ce y = 11 '.� V/ Q as p ti CO C c c O G I _ Q d co :p Ta 6 0 II Q a o c > Oil d 0 0 m E 2 p Z d V- II• N \tiG / V N V O O Co pj W 4 >, m ~ W E a I 0 d N W .t w t N d ce O C ` = .. reN `Z N w co .CE (1) 0 O ) C CO Q N F C co Z c N O w C ✓ � Q 'O (DE20 � < O p 9.J tN C C t6 U U ,-,,Ce ° a E a OE E a O g EcO H ' E E Q d LLo 0UcG m Z 0 d 0 > j 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg `1". DATE: Friday,December 22,2017 P.I.Supervisor \ `e Z f c Z Z-l/7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1H-114 FROM: Brian Bixby KUPARUK RIV UNIT 1H-114 Petroleum Inspector Src: Inspector Reviewed By:�-� P.I.Supry 3812--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-114 API Well Number 50-029-23584-00-00 Inspector Name: Brian Bixby Permit Number: 217-136-0 Inspection Date: 12/20/2017 Insp Num: mitBDB171220145312 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-114 Type Inj r W TVD 3732 Tubing 990 ' 1000 1004 ' 1003 - PTD 2171360 Type Test; SPT Test psi 1500 IA 290 1780 - 1760 ' 1750 BBL Pumped: 1.3 1BBL Returned: 1 OA 182 - 254 - 241 238 - Interval I INITAL - P/F P Notes: Friday,December 22,2017 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b.Well Class: 20nnc25.105 2oMc25.110 Development❑ Exploratory❑ GINJ El WINJ❑ WAG WDSPL❑ No.of Completions: Service(] , Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 11/20/2017 217-136 . 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 11/6/2017 50-029-23584-00-00, 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 259'FSL,784'FEL,Sec 28,T12N, R10E,UM 11/12/2017 . KRU 1H-114 , Top of Productive Interval: 9. Ref Elevations: KB:92.94 17. Field/Pool(s): 1934'FSL,2697'FEL,Sec 27,T12N, R10E,UM GL:54.10 BF: Kuparuk River Field/West Sak Oil Poole Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 2750'FSL,2701'FEL,Sec 27,T12N, R10E,UM N/A ADL 25639 r 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- 549555.50' y- 5980961.86 Zone- 4 7121/4128 i 80-261 TPI: x- 552907 y- 5982660 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 552896 y- 5983476 Zone- 4 N/A 1686/1638 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL)I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/CBL RECEIVED DEC 1 2 2017 ACC 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20 78.67 B 39 119 39 119 42 Existing 10 3/4 45.5 L-80 40 1830 40 1767 13 1/2 895 sx 11.0 ppg Extended G, 296 sx 15.8 noa Class G 7 26 L-80 37 7111 37 4124 8 3/4 562 sx 15.8 ppg Class G 24.Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 3 1/2 6942 6192/3732,6365/3805, PERFORATIONS @: 6487/3857 6219-6322 MD and 3743-3787 , -',.::_ " 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. 6390-6465 MD and 3816-3848 Was hydraulic fracturing used during completion? Yes❑ No 0 6506-6542 MD and 3866-3881 I2411- 6637-6678 MD and 3922-3939Per 20 AAC 25.283(i)(2)attach electronic and printed information ,-.,.0;;,:.:'., " DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 6740-6785 MD and 3966-3985 L 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A INJECTION ONLY-NOT PRE-PRODUCED Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-407 Revised�5I� V/L 1/2, //g, ,,CONTINUED ON PAGE 2 RBD lA pg., 1 ?, 20�ubmit ORIGINIAL only/ • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1686 1638 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 6219 3744 information, including reports,per 20 AAC 25.071. Formation @ TPI-West Sak Ugnu C 4803 3105 TD 7121 4128 Formation at total depth: West Sak 31. List of Attachments: Daily Operations Summary, Definitive Survey,Cement Report,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. Authorized Name: G.L.Alvord Contact Name: Jamal Cherry Authorized Title: Alaska Drilling Manager Contact Email: jamal.m.cherryacop.com Authorized ��ry^+� f Contact Phone: 265-6028 Signature: (-Vtek Date: 12-1 i k 2..i 7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • Wellhead/Tubing Hanger/Tree, 1H-114 Injector Well Design Ci 13-38"x 4-''/x"IBTM,5M p Wellbore Schematic z Q Insulated Conductor Crossover below TH: 4-1/2 x 3-1/2"Tubing O20"Casing EE it -._10-3/4"45.5#,L-80 HYD563 @ 1840 ft MD 3-1/2",9.3#,L-80,EUE-AB RA/PIP Tags @ 2,995'&6,027'MD" 3-1/2"MMG with SOV 5 C Feed Through Packer#3:6192'MD I 5 Multi Drop Gauge Mandrel - "D"Sand Perforations:6219'-6322'MD R 2.812"Cameo DS Nipple /', S Upper MMG-W Lower MMG-W ` Feed Through Packer#2:6365'MD " "B"Sand Perforations:6390'-6465'MD Multi Drop Gauge Mandrel- Upper MMG-W d -„----"-------\ � Lower MMG-W Feed Through Packer#1:6487'MD--IP ". 101,‘ .0„.. ., A4 perfs:6506'-6542'MD Single Gauge Mandrel- °°,10`• A3 perfs:6637'-66678'MD 2.813"Cameo XNipple \4 A2 perfs:6740'-6785'MD Upper MMG-W Lower MMG-W �_,& aBaker WlV % /_Top of float collar i Scraper/Magnet Assy t�7"26#,L-80,HYD563/TXP c# @7121'MD a Dumb iron muleshoe KUP INJ 1H-114 ConocoPhi lips & Well Attrit Max An D TD Alilsk it 1L, Wellbore API/UW Field Name Wellbore Status ncl e) MD ) Act Btm(ftKB) Corp81F 500292358400 WEST SAK INJ 70.32 3,049.53 7.121.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-114,12/13720178:55:06 AM SSSV:NONE LAST WO: 38.84 11/20/2017 Vertical schsmaec(apnlall.. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date LAST TAG: REV REASON:NEW WELL jennalt 12/12/2017 HANGER;32.9 _ Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.200 39.0 119.0 119.0 78.67 8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread uwwu Surface 10 3/4 9.950 40.5 1,829.9 1,767.2 45.50 L-80 Hydril 563 / Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Production 7 6.276 37.5 7,110.6 4,123.8 26.00 L-80 TXP BTC Tubing Strings Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ibt t) Grade Top Connection Upper Completion I 31/21 2.992 32.9 6,942.5 4,052.3 9.30 L-80 EUE-m Completion Details Nominal ID I Top(ftKB) Top(TAD)(ftKB) Top loci TI Item Des Com (in) 32.9 32.9 0.09 HANGER Vetco MB228 4-1/2"Tubing hanger w/parent bowl OD= 3.900 I I 13.45" CONDUCTOR;390-119.0 • 6,191.6 3,731.6 64.28 PACKER HES Feed Through Packer#3 (ser#SG3539499-02) 2.920 (Assy#10) 6,205.2 3,737.6 64.48 GUAGE SGM#3,(SN:C15GM-0752)multi drop gauge,annulus 2.913 pressure 6,221.7 3,744.6 64.71 NIPPLE Camco 2.813 DS nipple EUE 8rd-Mod(SN#3651-2) 2.813 (Assy#9) 6,365.2 3,805.3 64.52 PACKER HES Feed Through Packer#2 (SN:SG3531900-08) 2.920 Surface;40.5-1,829.9 (Assy#7) 6,378.9 3,811.2 64.54 GUAGE SGM#2 EUE 8rd-Mod,(SN:C15GM-0754)Multi drop 2.913 gauge,annulus pressure I 6,486.8 3,857.5 64.67 PACKER HES feed through Packer#1 (SN:SG3539499-01) 2.920 GAS LIFT:2519.6 t. (Assy#4) 1 6,500.5 3,863.3 64.67 GAUGE SGM#1 EUE 8rd-Mod(SN:)single gauge,annulus 2.913 pressure(SN:C15GM-0727) 6,516.4 3,870.1 64.68 NIPPLE Camco 2.813"X nipple @ 7497'MD(2.813")(SN:C- 2.813 3573285) 6,931.3 4,047.5 64.53 WIV 3 1/2"Baker WIV EUE-MOD 0.001 6,933.7 4,048.5- 64.55 Casing Baker Trailblazer CSG scrapper/brush/Mag combo 2.510 Scraper (Assy#1) PACKER;6,191.5 -7, 6,938.7 4,050.7 64.57 Mule Shoe 31/2"Muleshoe tubing tail 3.000 11i1 Perforations&Slots GUAGE;6,205.2 ::11: Shot Dens Top(TVD) BM((TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zane Date ft) Type Com NIPPLE;6,221.7 =I 6,219.0 6,322.0 3,743.5 3,786.9 WS D,1H- 11/17/2017 6.0 (PERF All shots fired 114 GAS LIFT;6,227.1 l ' 6,390.0 6,465.0 3,816.0 3,848.1 WS B,1H- 11/17/2017 6.0 (PERF All shots fired (PERF;6,219.0-6,322.0 III 114 GAS LIFT;6,266.6 1, 6,506.0 6,542.0 3,865.7 3,881.1 WS A4,1H- 11/17/2017 6.0 (PERF All shots fired III 114 6,637.0 6,678.0 3,921.7 3,939.2 WS A3,1H- 111172017 6.0 (PERF AU shots fired 114 PACKER,6,3652 ® 6,740.0 6,785.0 3,965.7 3,984.9 WS A2,1H- 11/17/2017 6.0 (PERF All shots fired 114 III Mandrel 6,378.9 Inserts III of at Top(TVD) Valve Latch Port Size TRO Run GAS LIFT;6,3955 N Top(ftKB) (ftKB) Make Madel OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,519.6 2,265.9 Camco MMG 11/2 SOV RKP 11/19/2017 (PERF;8,380.08,485.0 I 2 6,227.1 3,746.9 Camco MMG- 11/2 INJ W DMY RK 11/19/2017 GAS LIFT;6,435.8 3 6,266.7 3,763.6 Camco MMG- 1 1/2 INJ DMY RK 11/19/2017 II W 4 6,395.5 3,818.4 Cameo MMG- 1 1/2 INJ DMY RK 11/19/2017 W 5 6,435.8 3,835.7 Cameo MMG- 1 1/2 INJ DMY RK 11/19/2017 PACKER;6,466.8 W 6 6,522.3 3,872.7 Camco MMG- 11/2 (NJ DMY RK 11/19/2017 GAUGE;6,500.5 III 7 6,562.5 3,889.9 Camco MMG- 11/2 INJ DMY RK 11/19/2017 W NIPPLE;8,516.4 -I Notes:General&Safety (PERF;6,506 0-6,542.0%____ II End Date Annotation GAS LIFT;6,522.3 *' 12/12/2017 I NOTE I GAS LIFT;6,562.5 I.: I IPERF;6,637.0-6,678.0 IPERF;6,740.0-6,785.0 I WIV;6,931.3 I s. Casing Scraper;6,933.7 i 1 Praducaon;37.5-7,110.6 I gperations Timelo a theSummary (with9 p ) rpt '; v'. 1H-114 Ccormoithprs Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKD) 11/5/2017 11/5/2017 1.50 MIRU MOVE MOB P Rig release from 1H-111 at 08:00 hrs. 0.0 0.0 08:00 09:30 Rig down from 1H-114.Pull power, pump,pit,and pipeshed modules and rockwasher off 1H-114 and stage on pad. 11/5/2017 11/5/2017 0.75 MIRU MOVE MOB P Skid rig floor and raise sub stompers. 0.0 0.0 09:30 10:15 SIMOPS:Install tow tongue and cross members. 11/5/2017 11/5/2017 0.50 MIRU MOVE MOB P Pull sub off well and stage on pad. 0.0 0.0 10:15 10:45 11/5/2017 11/5/2017 0.50 MIRU MOVE `MOB P Shuffle rig mats from 1H-111 to 1H- 0.0 0.0 10:45 11:15 114 for spotting sub. 11/5/2017 11/5/2017 0.75 MIRU MOVE MOB P Spot sub over 1H-114. 0.0 0.0 11:15 12:00 11/5/2017 11/5/2017 0.50 MIRU MOVE MOB P Skid rig floor and lower sub stompers. 0.0 0.0 12:00 12:30 SIMOPS:Remove tow tongue and cross members. 11/5/2017 11/5/2017 3.25 MIRU MOVE MOB P Spot pit,pump,power,rockwasher, 0.0 0.0 12:30 15:45 and pipsehd modules. SIMOPS:Connect electrical interconnects. 11/5/2017 11/5/2017 2.25 MIRU MOVE RURD P Rig up interconnects. 0.0 0.0 15:45 18:00 11/5/2017 11/5/2017 1.00 MIRU MOVE RURD P Install rail from rig floor to skate. 0.0 0.0 18:00 19:00 11/5/2017 11/5/2017 1.00 MIRU MOVE RURD P Finish rig acceptance list and prep to 0.0 0.0 19:00 20:00 take on water for building mud. Rig accepted @ 20:00 hrs. 11/5/2017 11/5/2017 1.00 MIRU MOVE SLPC P Slip and cut 58'of drilling line and 0.0 0.0 20:00 21:00 calibrate system.SIMOPS-Build spud mud. 11/5/2017 11/6/2017 3.00 MIRU MOVE NUND P Remove studs from bottom of diverter 0.0 0.0 21:00 00:00 Tee.Disconnect and secure knife valve.Hoist surface annular with diverter Tee and install the 4 x missing studs. Re-install diverter Tee and attach knife valve.Torque flanges. SIMOPS-Build spud mud. 11/6/2017 11/6/2017 1.50 MIRU MOVE NUND P Nipple up flow riser and secure 0.0 0.0 00:00 01:30 annular.Hook up hydraulic lines and function test. 11/6/2017 11/6/2017 1.00 MIRU MOVE BOPE P Perform diverter test,witness waived 0.0 0.0 01:30 02:30 by AOGCC rep Brian Bixby. Use 1 x joint 5"HWDP.Observe knife valve open in 6 seconds and annular close in 24 seconds.Perform accumulator test.Initial pressure at 2950 psi.After functioning 1950 psi.Observe system build 200 psi in 8 seconds with 2 x electric pumps,attain full system pressure in 40 seconds with 2 x electric pumps and 2 x air pumps.6 x backup nitrogen bottle average 2150 psi.Test all gas and PVT alarms-no issues. Page 1/17 Report Printed: 11/28/2017 Operations Summary (with Timelog!epths) 1H-114 Corioc4hillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/6/2017 11/6/2017 4.50 MIRU MOVE BHAH P Rack back HWDP stands,jar stand, 0.0 93.0 02:30 07:00 and NMDC stand per SLB.Tag up at 93'MD.Make up Baker VM-3 mill- tooth bit with 4 x 18's(re-run from 1H- 111),mud motor with 1.83°bend and 13-3/8"near-bit straight stab, 12-1/8" NM stab,and XO.RIH w/1 x stand 5" HWDP to 90'MD,PUW 47k,SOW 54k. 11/6/2017 11/6/2017 2.25 MIRU MOVE RURD P Rig up Sperry wireline and gyro tool. 93.0 93.0 07:00 09:15 Fill surface lines and pressure test to 3500 psi-good test. Hold pre-spud with rig crew. 11/6/2017 11/6/2017 0.50 SURFAC DRILL DDRL P Cleanout conductor from 93'to 119' 93.0 135.0 09:15 09:45 and drill 13-1/2"surface hole from 119' to 135'MD, 135'TVD.Pump at 450 gpm,430 psi on-btm,367 psi off-btm, 30%F/O,40 rpm,2k Tq on-btm, 1K tq off-btm.5-10k WOB,PUW 47k,SOW 54k,ROT 47k. 11/6/2017 11/6/2017 1.25 SURFAC DRILL BHAH P Pull OOH from 135'to 41'MD and 135.0 135.0 09:45 11:00 make up 8-1/4"arcVision,8-1/4" MWD,and 8-1/4"UBHO per SLB from 41'to 104'.Scribe MWD to motor, TFO 143°.RIH with NMDC stand to 135'MD. 11/6/2017 11/6/2017 1.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 135'to 135.0 200.0 11:00 12:00 200'MD,200'TVD.Pump at 450 gpm, 544 psi on-btm,473 psi off-btm,30% F/O.Rotate at 40 rpm with 2k Tq on- btm, 1k Tq off-btm. 15k WOB.PUW 63k,SOW 71k,ROT 68k.ADT 0.83 hrs,Bit 14.93 hrs,Jars 117.23 hrs. 11/6/2017 11/6/2017 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 200'to 200.0 624.0 12:00 18:00 624'MD,624'TVD. Pump at 450 gpm, 1048 psi on-btm,880 psi off-btm,34% F/O.Rotate at 40 rpm with 3k Tq on- btm, 1k Tq off-btm.24k WOB.PUW 73k,SOW 80k,ROT 79k.Max gas 25 units.AST 1.13,ADT 3.67 hrs,Bit 18.6 hrs,Jars 120.9 hrs.Kicked off at 397'MD. Note:Sperry wireline RIH and take gyro readings as needed per well plan. Page 2/17 Report Printed: 11/28/2017 xsz' Operations Summary (with Timelog epths) 1H-114 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X OperationMKS) End Depth(ftKB)f 11/6/2017 11/7/2017 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 624'to 624.0 1,041.0 18:00 00:00 1041'MD, 1037'TVD.Pump at 500 gpm, 1100 psi on-btm,870 psi off-btm, 34%F/O,ECD 10.20 ppg.Rotate at 40 rpm with 3k Tq on-btm, 1k Tq off- btm.25-30k WOB.PUW 91k,SOW 96k,ROT 88k.Max gas 35 units.AST 2.41 hrs,ADT 4.24 hrs,Bit 22.84 hrs, Jars 125.14 hrs. Note:Sperry wireline RIH and take gyro readings as needed per well plan.Final gyro run once bit depth at 950'MD.Good MWD surveys obtained from 681'onwards. No downhole losses observed while drilling. 11/7/2017 11/7/2017 8.75 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1,041' 1,041.0 1,840.0 00:00 08:45 to 1,840'MD, 1,775'TVD.Pump at 520 gpm, 1,367 psi on-btm, 1,078 psi off-btm,34%F/O,ECD 10.54 ppg. Rotate at 40 rpm with 5k Tq on-btm, 2k Tq off-btm.34k WOB. PUW 107k, SOW 96k,ROT 104k.Max gas 544 units.AST 3.66 hrs,ADT 6.08 hrs,Bit 28.92 hrs,Jars 131.22 hrs. 11/7/2017 11/7/2017 0.75 SURFAC CASING CIRC P Rotate and circulate from 1,840'MD- 1,840.0 1,840.0 08:45 09:30 1,708'MD at 520 GPM, 1,171 PSI DPP. 35%F/O,40 RPM with 2K TQ. 3,181 STKS pumped. 11/7/2017 11/7/2017 0.25 SURFAC CASING OWFF P Observe well for flow(Static). 1,840.0 1,840.0 09:30 09:45 11/7/2017 11/7/2017 3.00 SURFAC CASING BKRM P BKRM OOH from 1,840'MD to 764' 1,840.0 764.0 09:45 12:45 MD. Up WT=87K,DWN WT=93K while rotating=87K. 11/7/2017 11/7/2017 0.25 SURFAC CASING OWFF P Observe well for flow prior to POOH 764.0 764.0 12:45 13:00 on elevators. (Static). 11/7/2017 11/7/2017 3.00 SURFAC CASING BHAH P POOH on elevators standing back 764.0 0.0 13:00 16:00 HWDP from 794'-574'MD. Continue laying down HWDP to 175'MD. LD Surface BHA Monitoring disp via TT. Clean and clear rig floor. 11/7/2017 11/7/2017 1.00 SURFAC CASING RURD P Rig up GBR Volant tool on rig floor. 0.0 0.0 16:00 17:00 11/7/2017 11/7/2017 1.00 SURFAC CASING SFTY P PJSM on running casing. 0.0 0.0 17:00 18:00 11/7/2017 11/7/2017 1.00 SURFAC CASING PUTB P M/U 10-3/4"shoe track consisting of 0.0 120.0 18:00 19:00 DavisLynch shoe and DavisLynch double valve float collar f/non-rotating plugs. P/U 14.83'pup,4.83'pup and Joint#4.Test floats,good. 11/7/2017 11/7/2017 3.50 SURFAC CASING PUTB P RIH with 10 3/4"45.5#L-80 casing as 120.0 1,820.0 19:00 22:30 per tally f/190'MD to 1780'MD. Make up torque= 19.4-26 FT/LB. Monitor disp via pit 1.Zero remakes/ Zero Rejects 11/7/2017 11/7/2017 0.50 SURFAC CASING HOSO P MU/Vetco casing hanger and landing 1,820.0 1,820.0 22:30 23:00 joint, 122K up/91K DWN WT. Page 3/17 Report Printed: 11/28/2017 • Operations Summary (with Timelog!epths) eft 1H-114 ConocoPhitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time Sod Time Our(hr) Phase Op Code Activity Code Time P-TA Operation (ftKB) End Depth(rtK8)' 11/7/2017 11/8/2017 1.00 SURFAC CEMENT CIRC P Circulate mud around at 213 GPM, 1,820.0 1,820.0 23:00 00:00 113 PSI staging up to 700 SPM. While conditioning mud. 11/8/2017 11/8/2017 1.00 SURFAC CEMENT CIRC P Continue to stage pumps up to 7 1,820.0 1,830.0 00:00 01:00 bpm= 130 psi. 11/8/2017 11/8/2017 0.50 SURFAC CEMENT RURD P Install cement hose on Volant tool and 1,830.0 1,830.0 01:00 01:30 R/U SLB pressure sensor to mud manifold. 11/8/2017 11/8/2017 1.00 SURFAC CEMENT CIRC P Pump 70 bbls of 10.5 ppg maker pill 1,830.0 1,830.0 01:30 02:30 w/ 5 ppb NutPlug M and 1 gallon of red dye.Maker pill returned to shaker —3200 stokes,pill had a very faint red tint w/Nutplug observed at shakers. 11/8/2017 11/8/2017 1.75 SURFAC CEMENT CIRC P Circulation and condtion mud for 1,830.0 1,830.0 02:30 04:15 cement job as per MI.Pumped©7 bpm=230 psi. Conditioned mud to 9.7 ppg out,60 FV and 20 YP.P/U= 117K,S/O=112K. 11/8/2017 11/8/2017 0.25 SURFAC CEMENT SFTY P Hold PJSM for cementing surface 1,830.0 1,830.0 04:15 04:30 casing,discussed muster areas,spill champs,fluid transfers and proper line ups. 11/8/2017 11/8/2017 4.00 SURFAC CEMENT CMNT P Cement 10-3/4"surface casing.Pump 1,830.0 1,830.0 04:30 08:30 5 bbls of CW-100 chem wash,shut down and pressure test line to 4000 psi.Line up to SLB and pump 35 bbls of CW-100 @ 5.5 bpm=62 psi followed by 75.8 bbls of 10.5 ppg MPII,shut down and batch up lead cement.Drop bottom plug and pump 304.3 bbls of 11.0 ppg LiteCRETE lead cement,observed MPII at shakers 278 bbls of lead away, pumped tub down and swab to tail. Pumped 61.3 bbls of 15.8 ppg tail cement. Dropped top plug and kicked out with 10 bbls of fresh water.Rig pumped 156 bbls of Spud mud @ 7 bpm=600 psi to bump plugs,plug bumped @ 1560 strokes.Pressure up to 500 psi over FCP(1000 psi)hold for 5 min,bled off and checked floats, good.86 bbls of lead cement returned to surface. 11/8/2017 11/8/2017 0.50 SURFAC CEMENT RURD P Blow down cement lines and manifold 0.0 0.0 08:30 09:00 11/8/2017 11/8/2017 3.00 SURFAC CEMENT RURD P RD Volant running tools and all casing 0.0 0.0 09:00 12:00 running wquipment. clean rig floor pull dump valves from WH. 11/8/2017 11/8/2017 3.00 SURFAC CEMENT NUND P LD mouse hole and ND surface riser, 0.0 0.0 12:00 15:00 knofe valve,diverter T and lines. Clean mud pits/cement lines. 11/8/2017 11/8/2017 2.00 SURFAC WHDBOP NUND P Install GE MB 222A wellhead as per 0.0 0.0 15:00 17:00 GE Page 4/17 Report Printed: 11/28/2017 erations Summary (with Timelo a �� . 41!p9 the p ) r.. _ 1H-114 cc hitlips .'acxk:;a Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKFO End Depth MKS) 11/8/2017 11/8/2017 1.00 SURFAC WHDBOP NUND T Verify alignment with laser,alignment, 0.0 17:00 18:00 good.Begin to torque bolts on wellhead.Wellhead shifted out of alignment-2 deg after bolts torqued. Un-torque bolts and re-align.Begin torqueing bolts on wellhead,wellhead shifted 1.5 deg out of alignment.Un- torque bolts and re-align again. Torque bolts on wellhead,alignment good. 11/8/2017 11/8/2017 0.25 SURFAC WHDBOP NUND P Test wellhead to 1600 psi as per 0.0 18:00 18:15 Vetco,good. 11/8/2017 11/8/2017 0.75 SURFAC WHDBOP NUND P Install sweep OA on wellhead and 18:15 19:00 install double valves. 11/8/2017 11/8/2017 3.00 SURFAC WHDBOP NUND P Install spacer spool/set BOP stack 0.0 0.0 19:00 22:00 and install choke/kill hoses. Flow riser and torque all connections. 11/8/2017 11/8/2017 0.50 SURFAC WHDBOP RURD P Pick up 7"test joint and MU head pin. 0.0 0.0 22:00 22:30 Prep TIW and dart valve for testing. Fill BOP system with fresh water and purge air. 11/8/2017 11/8/2017 1.00 SURFAC WHDBOP NUND P Perform body test and prep test joints 0.0 0.0 22:30 23:30 for upcoming test. 11/8/2017 11/9/2017 0.50 SURFAC WHDBOP BOPE P Begin BOPE testing with Brian Bixby 0.0 0.0 23:30 00:00 of AOGCC on site for witness. 11/9/2017 11/9/2017 4.00 SURFAC WHDBOP BOPE P Perform BOPE test with AOGCC Brian 0.0 0.0 00:00 04:00 Bixby witness. Test Annular&Ram#3 w/3.5"test jt, Test Annular&Ram#1 w/7"test jt.Test Ram#3 w/5"test jt.Test lea 4" XT FOSV&Dart.Test lea 4.5"IF FOSV&Dart.Test all gas&H2S sensors.Tested PVT and flow alarms, both audio&visual.Functioned BOP equipment from both the primary and remote controls.Acc test performed with 2ea.elec triplex,and 2ea air pumps. All gas alarms checked and passed. 6 BTL avg=2,116 PSI. 0 failures and total 4.5 hrs test time. 11/9/2017 11/9/2017 1.00 SURFAC WHDBOP RURD P Pull test joint and break out test plug. 0.0 0.0 04:00 05:00 Install wear bushing 12.25"ID. BD choke-Kill. slign choke and suck out stack. 11/9/2017 11/9/2017 2.00 SURFAC CEMENT BHAH P PU/MU production BHA to 275'MD 0.0 275.0 05:00 07:00 Monitor disp via TT. 11/9/2017 11/9/2017 1.00 SURFAC CEMENT TRIP P Trip in hole with 5"DP from derrick 275.0 1,600.0 07:00 08:00 275'-1,600'MD. 11/9/2017 11/9/2017 1.00 SURFAC CEMENT CIRC P RU testing equipment and circulate 1,600.0 1,600.0 08:00 09:00 BU at 500 GPM. 32%F/O with 1,107 PSI DPP. 2,876 STKS pumped. 11/9/2017 11/9/2017 1.50 SURFAC CEMENT PRTS T Prepare to test casing to 3,000 PSI. 1,600.0 1,600.0 09:00 10:30 No communication to pressure system. After troubleshooting found IA valve packed off with gravel. Purge and clear. 11/9/2017 11/9/2017 1.00 SURFAC CEMENT PRTS P -Pressure test casing and chart same 1,600.0 1,600.0 10:30 11:30 to 3,000 PSI. (PASSED). 36 STKS to pressure up. 3.5 BBLS bled back. Page 5/17 Report Printed: 11/28/2017 °4q Itperations Summary (with TimeloggPepths) Pte. 1H-114 Conoco PhifflI Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Tune P-T-X ()pennon (ftK8) End Depth(ftK8) 11/9/2017 11/9/2017 0.50 SURFAC CEMENT —RURD P BD all lines used for testing IE.TD, 1,600.0 1,600.0 11:30 12:00 MPD,Kill. 11/9/2017 11/9/2017 0.75 SURFAC CEMENT WASH P. Wash down from 1,600'MD-1,717' 1,600.0 1,717.0 12:00 12:45 MD to top of cement W/550 GPM AT 926 PSI DPP. 32%F/O,80 RPM 1- 4K TQ. UP WT=89K. DWN WT= 88K. ROT=89K. 11/9/2017 11/9/2017 1.75 SURFAC CEMENT COCF P Drill cement track and shoe from 1,717.0 1,840.0 12:45 14:30 1,717'MD to 1,840'MD. 450-550 GPM with 760-950 PSI DPP. 32-36% F/O. 40-80 RPM with 1-8K TQ. 5- 22K DWN WT. 11/9/2017 11/9/2017 1.00 SURFAC CEMENT DRLG P Drill 8.75"hole from 1,840'-1,860'MD 1,840.0 1,860.0 14:30 15:30 1,794 TVD. with 550 GPM @ 692 PSI DPP 35%F/O. 80 RPM with 2-5K TQ. UP WT=89K,DWN WT=88K. ROT =89. Pump bottoms up 1,404 STKS until clean and prep for FIT. 11/9/2017 11/9/2017 1.00 SURFAC CEMENT FIT P RU to perform FIT. 12.2 EMW 1,860.0 1,860.0 15:30 16:30 obtained with 240 PSI. 5 STKS to 200 PSI. .3 BBLS bled back. 11/9/2017 11/10/2017 7.50 PROD1 DRILL DDRL P Drill 8.75"hole from 1,860'MD-2,544' 1,860.0 2,544.0 16:30 00:00 MD 2,285'TVD. with 605 GPM 980 PSI DPP. 32%F/O, 160 RPM 4-8K TQ. 7K WOB. UP WT=103K DWN WT=94K. ROT=95K. 3K TQ. ECD =10.57 PSI. OBP=950 PSI. Max gas units=2,300. ADT-5.5 TBH- 5.66,TJR-47.62 11/10/2017 11/10/2017 2.50 PROD1 DRILL DDRL P DDrill 8-3/4"hole f/2544'MD to 2745' 2,544.0 2,745.0 00:00 02:30 MD,TVD=2381'.Pump @ 605 gpm= 1010 psi on,950 psi off w/32%FO. Rotate @ 160 rpm's w/4-8K Tq on, 3K off.P/U=103,S/O=94K,ROT= 95K,WOB=7K, ECD=10.57 ppg, Max gas=33 units.ADT=1.22,Total bit hrs=6.88,Total Jar hrs=48.84. 11/10/2017 11/10/2017 2.00 PROD1 DRILL CIRC T Hole packed off and stalled out when 2,745.0 2,745.0 02:30 04:30 drilling coal beds(observed on offset well log)P/U and overpull 10K to pull free of coal,Slowly stage pump rate and rotary up f/60 gpm=100 psi to 600 gpm=958 psi.P/U and back ream f/2745'MD to 2640'MD,torque dropped of 3K @ 2665'MD.Regained full circulation and pipe movement. Page 6/17 Report Printed: 11/28/2017 •0 O Operations Summary (with Timelo tepths) p 9 1H-114 Coto hillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our{hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftK8) 11/10/2017 11/10/2017 7.50 PROD1 DRILL DDRL P DDrill 8-3/4"hole f/2,745'MD,TVD= 2,745.0 3,043.0 04:30 12:00 2,381'-3,043'MD 2,400 TVD.Pump @ 605 gpm= 1002 psi on, w/34% FO.Rotate @ 130 rpm's w/4-8K Tq on,2K WOB,3K off bottom pressure 994 PSI. UP WT=112K,DWN WT= 86K,ROT=101K,ECD= 10.18 ppg, Max gas=33 units.ADT=5.87,Total bit hrs= 12.75,Total Jar hrs=50.34. SPR's @ 2,825'MD 2,410'TVD. 9.0 PPG MW. Time-0652 MP 1)20 SPM-120 PSI 30 SPM- 140 PSI MP 2)20 SPM-120 PSI 30 SPM- 140 PSI 11/10/2017 11/10/2017 6.00 PROD1 DRILL DDRL P DDrill 8-3/4"hole f/3,043'MD 2,400 3,043.0 3,176.0 12:00 18:00 TVD-3,176'MD 2,536'TVD.Pump @ 540 gpm=850 psi on, w/34%FO. Rotate @ 150 rpm's w/3-6K Tq on, 1- 7K WOB,off bottom pressure 845 PSI.UP WT=112K, DWN WT=86K, ROT=101K, ECD=10.11 ppg,Max gas=34 units.ADT=5.08,Total bit hrs= 17.83,Total Jar hrs=55.42. 11/10/2017 11/11/2017 6.00 PROD1 DRILL DDRL P DDrill 8-3/4"hole f/3,176'MD 2,536' 3,176.0 3,768.0 18:00 00:00 TVD-3,768'MD 2,739'TVD.Pump @ 700 gpm=1,340 psi on, w/35%FO. Rotate @ 150 rpm's w/5-8K Tq on, 6K WOB,off bottom pressure 1,330 PSI.UP WT= 117K,DWN WT=92K, ROT=103K,ECD=10.35 ppg,Max gas=600 units.ADT=4.51,Total bit hrs=22.34,Total Jar hrs=59.93. SPR's @ 3,206'MD 2,546'TVD. 9.0 PPG MW. Time-1840 MP 1)20 SPM-190 PSI 30 SPM- 230 PSI MP 2)20 SPM-180 PSI 30 SPM- 220 PSI 11/11/2017 11/11/2017 6.00 PROD1 DRILL DDRL P DDrill 8-3/4"hole f/3,768'MD 2,739' 3,768.0 4,439.0 00:00 06:00 TVD-4,439'MD 2,968'TVD.Pump @ 700 gpm=1,400 psi on, w/35%FO. Rotate @ 160 rpm's w/8K Tq on,4K WOB,off bottom pressure 1,390 PSI. UP WT= 127K,DWN WT=97K, ROT=110K,6.5 TQ ECD=10.44 ppg, Max gas=328 units.ADT=3.84,Total bit hrs=26.18,Total Jar hrs=63.77. Page 7/17 Report Printed: 11/28/2017 Operations Summary (with TimeUogfepths) 1H'114 ^^="c"iP`=°p= Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Ow(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 11/11/2017 11/11/2017 6.00 PROD1 DRILL DDRL P DDrill 8-3/4"hole f/4,439'MD 2,968' 4,439.0 5,006.0 06:00 1e:00 TVD 5,006'Mon.1o1'TVD.Pump 750 gpm=1,704 psi on, w/35%FO. Rotate @ 160 rpm's w/5-10K Tq on, /oxvvoe.off bottom pressure 1,6on PSI.uPvvT~1nnK. ovvwvvT~ 103K,ROT=115K,7 TQ ECD=10.79 ppg,Max gas=178 units.ADT=5.65, Total bit hrs=31.83,Total Jar hrs= 69.42. SPR's @ 4,4osmou.000TVD. o.o PPG MWTime 0600 MP 1)30 SPM 180 PSI 40 SPM 220 PSI mP2)noSPM 180 PSI 40 SPM 220 PSI 11/11o017 11/11/2017 6.00 PROD1 DRILL DDRL P oom|u'nw^hole no.00n MD 3,191' 5,006.0 5.391.0 12:00 18:00 TVD 5.391'mo3.372TVD. Pump @ nmgpm=1,704psi on, w/35%FO. Rotate @ 150 rpm's w/8K Tq on,3K WOB,off bottom pressure 1,464 PSI. upvvT~1noK.ovvmvvT~1oan ROT=11mK,anJECo=1o.4nppg Max gas=85 units.ADT=3.81,Total bit hrs=35.64,Total Jar hrs=73.23. 11/11/2017 11/12o017 6.00 PROD1 DRILL DDRL P oom|o-3w^hole vs.uormoo.or2' 5.391.0 5,820.0 18:00 00:00 TVD o.000'won.000TVD.Pump 6g mmgpm=1,445psi on, w/m%FO. Rotate @ 150 rpm's w/10K Tq on, 1m\vvoa.off bottom pressure 1.4*o PSI.upvvT~1s7x. ovvmvvT~ 1onx.ROT=1oux.o.yTQsCo~ 10.48 ppg, Max gas=62 units.ADT= 4.65,Total bit hrs=40.29,Total Jar hrs=77.88. spn'o@o.4ro'mou.*1o'TVD. o.1 PPG MW. Time 18:48 MP 1)30 SPM 250 PSI 40 SPM 300 PSI MP 2)30 SPM 240 PSI 40 SPM 300 PSI 11/12/2017 11/12o017 6.00 PROD1 DRILL DDRL P oom/x'aw''hole no.xco'moo.00u' 5,820.0 6,332.0 00:00 06:00 TVD n.anu'mon.rno'TVD.Pump @ 707 gpm=1,755 psi on, w/34%FO. Rotate @ 160 rpm's w/oxTq on,9K WOB,off bottom pressure 1,740 PSI. upvvT~1srK.ovvwvvT~1oow ROT=128K, 10TOsoo~10.73 ppg, Max gas=209 units.ADT=3.81,Total bit hrs=44.10,Total Jar hrs=81.69. Page onr Report Printed: 11u8/2017 k' • Operations Summary (with Timelog Depths) 1H-114 c onocaphitiiEss Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKE), 11/12/2017 11/12/2017 6.00 PROD1 DRILL DDRL P DDRLI 8-3/4"hole f16,332'MD 3,793' 6,332.0 6,751.0 06:00 12:00 TVD-6,751'MD 3,971'TVD.Pump @ 700 gpm=1,811 psi on, w/33%FO. Rotate @ 160 rpm's w/2-12K Tq on,5 -10K WOB,off bottom pressure 1,808 PSI.UP WT=163K,DWN WT= 109K,ROT=129K, 10TQ ECD=10.73 ppg,Max gas=326 units.ADT=4.42, Total bit hrs=48.52,Total Jar hrs= 86.11. SPR's @ 6,422'MD 3,830'TVD. 9.1 PPG MW. Time-0710 MP 1)30 SPM-220 PSI 40 SPM- 260 PSI MP 2)30 SPM-220 PSI 40 SPM- 260 PSI 11/12/2017 11/12/2017 6.00 PROD1 DRILL DDRL P DDRL 8-3/4"hole 1/6,751'MD 3,971' 6,751.0 7,121.0 12:00 18:00 TVD-7,121'MD 4,128 TVD.Pump @ 700 gpm=1,909 psi on, w/33% FO. Rotate @ 160 rpm's w/6-14K Tq on, 10-12K WOB,off bottom pressure 1,898 PSI. UP WT=170K,DWN WT =136K,ROT=110K, 10TQ ECD= 10.78 ppg,Max gas=296 units.ADT= 4.92,Total bit hrs=53.44,Total Jar hrs=91.03. SPR's @ 7,117'MD 4,128'TVD. 9.2 PPG MW. Time-1745 MP 1)30 SPM-250 PSI 40 SPM- 300 PSI MP 2)30 SPM-250 PSI 40 SPM- 300 PSI 11/12/2017 11/12/2017 1.00 PROD1 CASING CIRC P CBU X 2. Recip f/7,118-7,023'MD. 7,121.0 7,121.0 18:00 19:00 PUmp 50 BBL hi vis chase to surf. 2,120 PSI DPP,UP WT 170/DWN WT=111K/ 11/12/2017 11/12/2017 0.75 PROD1 CASING OWFF P OWFF. 2 BBLS static loss. (GOOD) 7,121.0 7,121.0 19:00 19:45 11/12/2017 11/12/2017 0.50 PROD1 CASING SVRG P Service top drive TQ tube clamp and 7,121.0 7,121.0 19:45 20:15 service head. 11/12/2017 11/13/2017 3.75 PROD1 CASING BKRM P BKRM OOH from 7,.121'MD-5,668' 7,121.0 5,668.0 20:15 00:00 MD @ 700 GPM. 1,690 PSI DPP. 33% F/O. 140 RPM with 7-10K TQ. UP WT= 145K. DWN WT=99K. Monitor well via pits 1&6. Ream 5820-5780 X3/5760-5730 MD X4. 11/13/2017 11/13/2017 9.50 PROD1 CASING BKRM P BKRM OOH from 5,668'MD-1,790' 5,668.0 1,790.0 00:00 09:30 MD paying attention to areas of interest 5,334-5,376'MD/4,675- 4,691'MD,4,046'-4,064'MD,3,992'- 4,009'MD,3,558'-3,576'MD,3,040'- 3,075'MD,2,801'-2,811'MD,2,743'- 2,770'MD,2,441'-2,446'MD,2,368- 2,374'MD,2,340'-2,347'MD,2,277'- 2,283'MD,2,244'-2,255'MD,2,126'- 2,130'MD,2,026'-2,034'MD respectivly. UP WTs vary due to depths but most were washed X2- some X4. Page 9/17 Report Printed: 11/28/2017 i v 4. • �' Operations Summary (with Timelog Depths) 1 H-114 C nocoPhiiii ps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time] End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ttKB) End Depth(ftKB) 11/13/2017 11/13/2017 0.50 PROD1 CASING CIRC P CBU from 1,790'MD cycle to 1,693' 1,790.0 1,790.0 09:30 10:00 MD. at 700 GPM 1,155 PSI DPP. 33%F/O,80 RPM with ECD 9.78 PPG. 1.7K TQ. UP WT=91K DWN WT=92K. ROT WT=93K. 11/13/2017 11/13/2017 0.50 PROD1 CASING OWFF P OWFF(Static). Pump slug and prep 1,790.0 1,790.0 10:00 10:30 to POOH. 11/13/2017 11/13/2017 1.50 PROD1 CASING TRIP P POOH on elevators from 1,790'-275' 1,790.0 275.0 10:30 12:00 MD. LD 5"DP 1 by 1. Monitor disp via TT. 11/13/2017 11/13/2017 2.00 PROD1 CASING BHAH P Lay down BHA from 275'to surface 275.0 0.0 12:00 14:00 via DD. UP WT=58K, DWN wt-64K. Monitor disp via TT. 11/13/2017 11/13/2017 4.00 COMPZN CASING RURD P Clean/Clear rig floor. Lay down tools 0.0 0.0 14:00 18:00 off floor. Wash stack. Pull wear bushing,MIRU GBR pipe handeling equipment. RU to run 7"563 hysril 563/TXP 26#L-80 casing. Confirm pipe count in shed and location of PIP markers. Bring casing hanger to rig floor and cross overs. 11/13/2017 11/13/2017 1.25 COMPZN CASING PUTB P PJSM/MU 7"26#TXP casing 0.0 168.0 18:00 19:15 shoetrack Baker Lock all connections TQ turn/17.5K FT/LBS. Fill and check floats. (Good). 11/13/2017 11/13/2017 3.25 COMPZN CASING PUTB P Continue to RIH with 7"TXP casing 168.0 1,816.0 19:15 22:30 from 168'MD to 1,816'MD TQ turn connections to joint#25. Fill on fly and every ten. 11/13/2017 11/13/2017 0.75 COMPZN CASING CIRC P Stage up pump to 6 BPM at shoe. 1,816.0 1,816.0 22:30 23:15 FCP=57 PSI,21%F/O.UP WT= 85K,DWN WT=87K. Pumped a total of 2,160 STKS. MW in/out 9.2 PPG. 11/13/2017 11/14/2017 0.75 COMPZN CASING PUTB P Continue to RIH from 1,816'MD- 1,816.0 2,305.0 23:15 00:00 2,305'MD. Sill on flly and every ten joints top off. Monitor desp via pits 3- 5. DWN WT=90K. 11/14/2017 11/14/2017 0.75 COMPZN CASING PUTB P Continue to RIH from 2,305'MD- 2,305.0 2,756.0 00:00 00:45 2,756'MD Filing on fly and topping off every ten connections. UP WT= 101K,DWN WT=92K. Monitor disp. 11/14/2017 11/14/2017 3.75 COMPZN CASING PUTB T Tagged up and unable to work past 2,756.0 2,789.0 00:45 04:30 suspected ledge at 2,756'MD. Stage up pumps to 8 BPM 185 PSI,26% F/O. Attempt to wash thru obstruction area. 2,756-2,789'MD. 4 BPM=100 PSI, 16%F/O,5 BPM=113 PSI,6 BPM= 140 PSI 20%,7 BPM=165 PSI,24%F/O. 11/14/2017 11/14/2017 0.25 COMPZN CASING PUTB T Spot 20 BBL high vis pill to assist well 2,789.0 2,789.0 04:30 04:45 cleaning. 6 BPM @ 140 PSI,20% F/O,Recip from 2,789'to 2,779'MD. UP WT= 103K,DWN WT=92K. Page 10/17 Report Printed: 11/28/2017 S • Operations Summary (with Timelog Depths) 1H-114 ConacOPhiffips ?` Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Cur(hr) Phase Op Code Activity Code Time P-T-X Operation ((S) End Depth(ftKE) 11/14/2017 11/14/2017 1.25 COMPZN CASING PUTB T Continue to work through tight area 2,789.0 2,808.0 04:45 06:00 from 2,789'-2,808'MD. 2 BPM (packed off),work free and re- establish circulation at 2 BPM 90 PSI, 11%F/O,UP WT=105 DWN WT= 93K 11/14/2017 11/14/2017 2.00 COMPZN CASING PUTB T Continue to work through tight area 2,808.0 2,830.0 06:00 08:00 from 2808-2830'MD. 4 BPM/121 PSI, 15%F/O,Up WT=104K,DWN WT=92K. 11/14/2017 11/14/2017 4.00 COMPZN CASING PUTB T Worked and cycled pipe from 2,820- 2,830.0 3,075.0 08:00 12:00 to 2,820 and lost hole. Pump 20 BBL high vis sweep to assist. change rate to 5 BPM @ 19%F/O, 150 PSI DPP. Able to wash down to 3,075'MD with UP WT 111K,DWN WT=90K. 11/14/2017 11/14/2017 6.00 COMPZN CASING PUTB P Continue to wash 7"26#L-80 TXP 3,075.0 4,637.0 12:00 18:00 casing as per taly from 3,075 MD to 4,637'MD, wash down at 4 BPM,211 PSI, 16%F/O.UP WT=116K DWN WT=80K. 11/14/2017 11/15/2017 6.00 COMPZN CASING PUTB P Continue to wash 7"26#L-80 TXP 4,637.0 5,791.0 18:00 00:00 casing as per taly from 4,637'MD to 5,791'MD, wash down at 4 BPM,290 PSI, 17%F/O.UP WT= 142K DWN WT=85. 20 BBL high vis pill pumped at 5,000'MD. 11/15/2017 11/15/2017 4.00 PROD1 CASING PUTB P Continue to RIH with 7"26#L-80 HYD 5,791.0 7,069.0 00:00 04:00 563 casing from 5,792'MD to 7,069' MD washing down each joint @ 4 BPM,310 PSI with 17%F/O. UP WT =175K DWN WT=92K. 11/15/2017 11/15/2017 0.50 COMPZN CASING SEQP P MU casing hanger and landing joint. 7,069.0 7,110.6 04:00 04:30 Wash down at 2 BPM and mark landing joint with detail. 255 PSI, 10% F/O. Land hanger.(GOOD). 11/15/2017 11/15/2017 1.00 COMPZN CEMENT CIRC P Circulate And condition fluids while 7,110.6 7,110.6 04:30 05:30 reciprocating from 7,105'MD-7,092' MD. Stage pumps up to 8 BPM @ 425 PSI,24%F/O. UP WT= 175K DWN WT=97K. 11/15/2017 11/15/2017 0.50 COMPZN CEMENT RURD P Blow down top drive and rig up 7,110.6 7,110.6 05:30 06:00 cement hose/line/T's etc.etc. 11/15/2017 11/15/2017 3.25 COMPZN CEMENT CIRC P Stage pumps up to 8 BPM,initial 7,110.6 7,110.0 06:00 09:15 circulating pressure=584 PSI with a final circ pressure of 500 PSI. UP WT =173K and DWN WT=96K. Pumped 7,589 stks. Pump 40 BBL nut plug gauge pill at same rate surf/surf 4990 stks, Actual volume pumped=518.6 bbls. 11/15/2017 11/15/2017 0.75 COMPZN CEMENT SFTY P Perform prejob safety meeting while 7,110.0 7,110.0 09:15 10:00 continuing to circulate at slower rate of 5 BPM 304 PSI. 16%F/O. UP wT= 188K, DWN WT=98K. 1108 stks pumped while waiting for SLB to stage up. Total volume pumped before cement job was 1565 bbls. Page 11/17 Report Printed: 11/28/2017 • 0 '10 Operations Summary (with Timelog Depths) 0 1H-114 c_otohiliips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 11/15/2017 11/15/2017 2.50 COMPZN CEMENT CMNT P Flush lines and PT SLB to 4K. 7,110.0 7,110.0 10:00 12:30 (GOOD).Pump 30.8 BBLS mud push at 1-4 BPM due to weight challenges 50-235 PSI DPP. 6-15%F/O. Load btm plug and pump 116.2 BBLS 15.8 PPG cement @ 4.5 BPM ICP=216 FCP=89. Flush lines to the floor w/ 8 bbls of water.Load top plug and KO with 10 BBLS of fresh water displace with 9.0 PPG brine at 8 BPM. ICP= 132 PSI FCP=1270 PSI. 24%F/O. reduce rate at 2,400 STKS to 3 BPM ICP 780 PSI, FCP 900 psi. 12%F/O. Bump plug at 2560 STKS.Full returns through out job.Pressure up to 1,400 PSI for 5 min. CIP=12:21. 11/15/2017 11/15/2017 0.75 COMPZN CEMENT PRTS P Pressure test casing to 3,500 PSI 7,110.0 7,110.0 12:30 13:15 chart same for 30 MIN. PT good. 39 STKS pressure up with 3.9 BBLS bled back. 11/15/2017 11/15/2017 1.25 COMPZN CEMENT RURD P RD/BD TD. and all circ lines. RD 7,110.0 7,110.6 13:15 14:30 Volant tool and bale extensions/ elevators etc. LD landing joint. kick out GBR equipment. 11/15/2017 11/15/2017 2.00 COMPZN CEMENT RURD P Drain stack and install 5"elevators. 7,110.6 7,110.6 14:30 16:30 PU two joints and MY packoff running tool. Engage packoff and set packoff in 10.75"X 7 packoff assy wellhead and RI LD screws. Test packoff to 5,000 PSI and witnessed. 11/15/2017 11/15/2017 0.50 COMPZN WELLPR RURD P Install 9"wear bushing and RILD 7,110.6 7,110.2 16:30 17:00 screws. 2 ea. 11/15/2017 11/15/2017 1.50 COMPZN WELLPR RURD P CO 4 1/2"saver sub to XT/39. 7,110.2 17:00 18:30 11/15/2017 11/15/2017 0.25 COMPZN EVALWB SFTY P PJSM with eline crew. 18:30 18:45 11/15/2017 11/15/2017 1.50 COMPZN EVALWB RURD P Rig up eline sheeves and tool to rig 18:45 20:15 floor. Set same. 11/15/2017 11/15/2017 2.75 COMPZN EVALWB ELOG P RIH with SLB eline CBL system to flat 20:15 23:00 collar tagging up at 6,985'ELMD. Crew performing PM's. 11/15/2017 11/16/2017 1.00 COMPZN EVALWB ELOG P Eling begin logging up at 23,12 hrs. 23:00 00:00 11/16/2017 11/16/2017 6.25 COMPZN EVALWB QEVL P Continue CBL logging at 100 PSI with 0.0 0.0 00:00 06:15 simops of celler cleaning/ housekeeping/load DP&PKR in shed. 11/16/2017 11/16/2017 3.25 COMPZN EVALWB QEVL P Begin next pass. First log showed RA 0.0 . 0.0 06:15 09:30 tags on depth. Casing tally-2'off. Begin second run at 500 PSI. Continue standard sim ops. 11/16/2017 11/16/2017 0.50 COMPZN EVALWB QEVL P Rig back SLB equipment and have 0.0 0.0 09:30 10:00 them stby for tie in logging later today with perf guns. 11/16/2017 11/16/2017 0.25 COMPZN WELLPR SFTY P PJSM with LRS and rig crew for Ann 0.0 0.0 10:00 10:15 freeze protect. Page 12/17 Report Printed: 11/28/2017 itperations Summary (with Timelog Depths) 1H-114 c nocoPhiilips Ai.P:nk;a Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKE), 11/16/2017 11/16/2017 1.75 COMPZN WELLPR FRZP P PT LRS lines to 2,500 PSI. Begin 0.0 0.0 10:15 12:00 isotherm injection into 10 3/4"X 7"ann with 100 BBLS of water flush. Pump rate at 4 BPM with ICP of 550 PSI/ final 670 PSI. Sim ops with sending HES gun equipment to rig floor. 11/16/2017 11/16/2017 2.00 COMPZN WELLPR FRZP P Inject 100 BBLS of isotherm into 10 0.0 0.0 12:00 14:00 3/4"X 7"Ann with ICP of 520 PSI and a FCP of 850 PSI. Shut in casing valve and replumb for completion. 11/16/2017 11/16/2017 0.25 COMPZN PERF SFTY P PJSM with HES personnel and rig 0.0 0.0 14:00 14:15 crew with gun handling. 11/16/2017 11/16/2017 1.75 COMPZN PERF BHAH P PU HES 3.125 6 SPF Millennium guns 0.0 705.0 14:15 16:00 as per tally. 11/16/2017 11/16/2017 4.50 COMPZN PERF TRIP P RIH with 3.125"6SPF Millennium 705.0 6,874.0 16:00 20:30 guns from 705'MD-6,874'MD Up WT=127K. DWN WT=74K. Monitor Disp via TT. Fill on fly topping off every ten stands. at 4,788'stop filling pipe for underbalance shot of guns. 11/16/2017 11/16/2017 0.25 COMPZN PERF RURD P Lay down two singles in prep for eline 6,874.0 6,808.0 20:30 20:45 tie in run. UP WT=127K DWN WT 74K. 11/16/2017 11/16/2017 0.25 COMPZN PERF SFTY P PJSM with SLB over logging run. 6,808.0 6,808.0 20:45 21:00 11/16/2017 11/16/2017 0.50 COMPZN PERF ELOG P RU SLB for logging run. 6,808.0 6,808.0 21:00 21:30 11/16/2017 11/16/2017 1.50 COMPZN PERF ELOG P RIH with eline logging tools for tie in 6,808.0 6,808.0 21:30 23:00 run and begin logging tie in strip. POOH. 11/16/2017 11/16/2017 0.50 COMPZN PERF ELOG P RD eline and all tools. 6,808.0 6,808.0 23:00 23:30 11/16/2017 11/17/2017 0.50 COMPZN PERF RURD P Overlook tie in log and prepare for 6,808.0 6,808.0 23:30 00:00 corrections,Sim ops with riggin up bail extensions and circulating equipment. 11/17/2017 11/17/2017 0.50 COMPZN PERF ELOG P Continue rigging up surface 6,808.0 6,808.0 00:00 00:30 equipment and run correlation log. 11/17/2017 11/17/2017 2.25 COMPZN PERF PERF P LD bottom single stand#65 and pull 6,808.0 6,788.9 00:30 02:45 dbl for re-positioning of 9.96'pup joint for proper spaceout to put guns on depth and set packer at 6142.98'MD as per HES rep. Bottom shot© 6,785'MD. Rotate three turns to right and set 20K down. Rig up 2"HP hose to TIW with closed ann and fire off pert guns by pumping down IA to 3,000 PSI and allow to set for 1-3 min for ignition of firing head. Bleed dwn press quickly and confirm fire by sonic mic on pipe.Raise IA press to 500 PSI and PU three feet opern bypass vent. Noted pressure drop confirming vernt open. Page 13/17 Report Printed: 11/28/2017 • r Operations Summary (with Timelog Depths) ►may 1H-114 Conacciftliifips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/17/2017 11/17/2017 1.50 COMPZN PERF CIRC P Circulate down IA taking initial returns 6,788.9 6,788.9 02:45 04:15 through Super Choke to pits @ 3.5 BPM,200 PSI until crude sample pulled then diverted to outside flowback tanks. Crude noted at surface in 350 STKS. Allow full BU to flow back tank then shut down for 30 min hesitationto allow for migration. Performed another BU to purge all crude from system. Returned a total of 100 BBLS to tanks prior to rolling back to pits on the fly for a complete Surface to Surface cycle. 11/17/2017 11/17/2017 0.50 COMPZN PERF RURD P BD and RD circulation lines and equip. 6,788.9 6,788.9 04:15 04:45 BD choke systems to flow back tanks. 11/17/2017 11/17/2017 0.25 COMPZN PERF MPSP P PU 20;'to release packer and slack off 6,788.9 6,788.9 04:45 05:00 confirming packer released. RD bail extensions. 11/17/2017 11/17/2017 1.25 COMPZN PERF CIRC P Circulate 2X bottoms up to verify no 6,788.9 6,788.9 05:00 06:15 gas and or crude migrations. Max gas =860 units with trace crude diverter outside. 11/17/2017 11/17/2017 0.25 COMPZN PERF RURD P Lay down pup joint and MU stand. 6,788.9 6,685.0 06:15 06:30 Rack back to 6,685'MD. BD top drive. 11/17/2017 11/17/2017 0.50 COMPZN PERF OWFF P OWFF 6,685.0 6,685.0 06:30 07:00 11/17/2017 11/17/2017 2.00 COMPZN PERF TRIP P POOH on elevators from 6,685'to 6,685.0 705.0 07:00 09:00 705'MD. Monitoring Disp via TT. 11/17/2017 11/17/2017 1.75 COMPZN PERF BHAH P PJSM/lay down packer and perf guns 705.0 0.0 09:00 10:45 according to HES rep. Monitor disp via TT. 11/17/2017 11/17/2017 0.75 COMPZN PERF BHAH P Clean rig floor and handeling tools. 0.0 0.0 10:45 11:30 11/17/2017 11/17/2017 0.50 COMPZN WELLPR BHAH P PJSM with Baker rep and pick up 0.0 51.0 11:30 12:00 Scrapper BHA. 11/17/2017 11/17/2017 3.50 COMPZN WELLPR TRIP P RIH with scrapper BHA with 4"DP 51.0 6,116.0 12:00 15:30 stands out of derrick. UP WT=124K, Monitor Disp via trip trank. 11/17/2017 11/17/2017 2.50 COMPZN WELLPR WASH P Wash down from 6,116'MD-6,981' 6,116.0 6,981.7 15:30 18:00 MD at 5 BPM 425 PSI DPP. 19% F/O. 20 FPM recip each stand 1-2X accross perfs. Tag landing collar with 1 BPM @ 6,981.7'MD. UP WT= 134K-DWN WT=85K. 11/17/2017 11/17/2017 1.00 COMPZN WELLPR CIRC P Circulate bottoms up and pump 50 6,981.7 6,981.7 18:00 19:00 BBL high vis pill while recip from 6,980'-6,902'MD. at 7 BPM 850 PSI at 23%F/O. Max gas units=530. 3,386 STKS pumped UP WT=134K DWN WT=85K. 11/17/2017 11/17/2017 0.50 COMPZN WELLPR OWFF P OWFF. BD Top drive. 6,981.7 6,981.7 19:00 19:30 11/17/2017 11/18/2017 4.50 COMPZN WELLPR PULD P POOH laying down 4"DP from 6,981.7 2,700.0 19:30 00:00 6,981.7'MD-2,700'MD Monitor disp via TT. 11/18/2017 11/18/2017 2.25 COMPZN WELLPR PULL P Continue pulling and laying down 4" 2,700.0 54.0 00:00 02:15 DP with scrapper asym to surface. Page 14/17 Report Printed: 11/28/2017 • S Operations Summary (with Timelog Depths) 1H-114 cc® t,ftii Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS) 11/18/2017 11/18/2017 0.75 COMPZN WELLPR BHAH P LD cleanout/scrapper BHA from 54'. 54.0 0.0 02:15 03:00 11/18/2017 11/18/2017 0.75 COMPZN WELLPR BHAH P Clean rig floor from pull. Pull wear 0.0 0.0 03:00 03:45 bushing sim/ops. 11/18/2017 11/18/2017 3.25 COMPZN RPCOMP RURD P Load and R/U tbg running equipment. 0.0 0.0 03:45 07:00 RU SLB spooling unit along with GBR tongs. Load pipe shed and verify count. PU Cannon clamps to rig floor. Load pup joints and hngr to rig floor. Lay out running oder and confirm third party clamp count, 300 3.5"full, 12 3.5"half,2 4.5"half, 1 3.5"X 4.5"X/O. 11/18/2017 11/18/2017 0.50 COMPZN RPCOMP SVRG P Service top drive 0.0 0.0 07:00 07:30 11/18/2017 11/18/2017 1.00 COMPZN RPCOMP WAIT T Waiting on HES rep to confirm tools 0.0 0.0 07:30 08:30 and tally. Contacted late. 11/18/2017 11/18/2017 1.50 COMPZN RPCOMP PUTB P PJSM for running completion. PU and 0.0 492.0 08:30 10:00 RIH with 3.5"9.3#L-80 EUE 8 rnd tubing completion as pre tally to 492' MD. Monitor well via TT. 11/18/2017 11/18/2017 2.50 COMPZN RPCOMP PUTB P Splice in tech wire thru HES feed 492.0 492.0 10:00 12:30 through packer and single gauge carrier. Test to 5000 PSI. 11/18/2017 11/18/2017 0.50 COMPZN RPCOMP PUTB P RIH from 492'MD-614'MD and MU 492.0 614.0 12:30 13:00 feed through packer#2. Simops with housekeeping and rig maintenance. 11/18/2017 11/18/2017 4.00 COMPZN RPCOMP PUTB P Splice TEC wire to HES feed through 614.0 614.0 13:00 17:00 packer#2&Multi-pass guage guage carrier.Test above to 5000 psi..Sim Ops:Housekeeping per condition audit.Prep cellar on well 1H-101. 11/18/2017 11/18/2017 1.00 COMPZN RPCOMP PUTB P RIH from 614'MD-756'MD and MU 614.0 756.0 17:00 18:00 feed through packer#3. Run TEEC wire through packer.Test to 5000 psi. Simops with housekeeping and rig maintenance. 11/18/2017 11/18/2017 4.50 COMPZN RPCOMP PUTB P Continue to splice TEC wire to HES 756.0 756.0 18:00 22:30 feed through packer#3 and multi-pass guage carrier.Test to 5000 psi. Monitor well on the trip tank. 11/18/2017 11/19/2017 1.50 COMPZN RPCOMP PUTB P Continue to RIH w/3-1/2"9.3 ppf L-80 756.0 3,178.0 22:30 00:00 completion from 756'MD-3178'MD. Torque is 2240 ft lbs.Installing Cannon clamps over all collars. Monitor well on the trip tank. 11/19/2017 11/19/2017 5.50 COMPZN RPCOMP PUTB P Continue to RIH w/3-1/2"9.3 ppf L-80 3,178.0 6,984.8 00:00 05:30 completion from 3178'MD-6984.8' MD.Torque is 2240 ft lbs. Installing Cannon clamps over all collars. Monitor well on the trip tank.Tagged 7"Float collar @ 6984.8'MD w/5k. 11/19/2017 11/19/2017 0.50 COMPZN RPCOMP RURD P PU 5'to 6,979 MD laying down joint 6,984.8 6,979.0 05:30 06:00 212 and make up head pin/circ hose. 11/19/2017 11/19/2017 1.00 COMPZN RPCOMP ELOG P Wait on decision to pump CI 9 ppg 6,979.0 6,979.0 06:00 07:00 brine and spot SLB a-line unit/PU tools and sheaves. Re-calculate volume to pump at this time. Page 15/17 Report Printed: 11/28/2017 DA Operations Summary (with Timelog Depths) 1H-114 ConocoPtaitlips I:. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr; Phase Op Code Activity Code Time P-T-X Operation {MKS) End Depth(EKE) 11/19/2017 11/19/2017 1.50 COMPZN RPCOMP CRIH P Pump 210 BBLS of CI 9 ppg brine at 6,979.0 6,979.0 07:00 08:30 3 BPM 177 PSI, 10%F/O. 2,105 total STKS. BD/RD/CMT hose. 11/19/2017 11/19/2017 0.25 COMPZN RPCOMP RURD P LD Joint 211 to 6,946.66'MD. Set in 6,979.0 6,947.0 08:30 08:45 slips. 6,947.66' 11/19/2017 11/19/2017 4.00 COMPZN RPCOMP ELOG P RU and RIH with SLB eline to 6,936' 6,947.0 6,856.1 08:45 12:45 MD(Wellbore isolation valve). Logged tie in pass to gather both 7" RA tags. Log adjusted to lower RA @ 6029.5'MD. RD all e-line related tools. 11/19/2017 11/19/2017 3.25 COMPZN RPCOMP HOSO P Lay down joints 210,209,and 208. 6,856.1 6,909.6 12:45 16:00 Change seal in jt#207.MU 6.15'3 1/2"9.3#L-80 Pup X/0(4-1/2"Hyd 563 box x 3-1/2"EUE pin)and 40.7"4 1/2"Hyd 563 joint and RIH. MU hanger and landing joint. PU to orient hanger with well head. 11/19/2017 11/19/2017 0.50 COMPZN RPCOMP THGR P Terminate TEC wire thru hanger,drain 6,909.6 6,909.6 16:00 16:30 stack,R/D and lower handling equipment. 11/19/2017 11/19/2017 1.50 COMPZN RPCOMP THGR P RIH landing hanger and confrim 6,909.6 6,942.5 16:30 18:00 landed inspected through tubing port. RILDS,LD TEC wire spool. Clamps and handling equipment. 11/19/2017 11/19/2017 0.50 COMPZN RPCOMP THGR P Test upper and lower hanger seals to 6,942.5 6,942.5 18:00 18:30 5000 psi f/15 minutes each.Test witnessed by CPAI rep Granville Rizek. 11/19/2017 11/19/2017 2.00'COMPZN RPCOMP PRTS P Drop 1.5"Baker ball.Pump down w/9 6,942.5 0.0 18:30 20:30 ppg CI brine.@ 2.5 bpm w/155 psi. Ball on seat @ 500 strokes.Pressure up to 4000 psi to set packers and test tubing to 4000 psi f/30 minutes.Chart test.(good).Bled tubing down to 2000 psi,pressured up IA to 3500 psi f/30 minute test-charted(good). Bleed both IA and tubing to zero psi. Pressure up on the IA to shear valve in mandrel @ 2519.56'.Sheared w/1870 psi. Confirmed shear by pumping 2 bpm of brine w/170 psi.Flush surface lines w/fresh water. 11/19/2017 11/19/2017 0.50 COMPZN RPCOMP OWFF P Rig down test equipment.Blow down 0.0 0.0 20:30 21:00 lines. Drain stack.Monitor well to be static 11/19/2017 11/19/2017 0.75 COMPZN WHDBOP MPSP P Set 4"Type"H"back pressure 0.0 0.0 21:00 21:45 valve.Test to 2500 psi f/10 minutes (Charted)(Good). 11/19/2017 11/20/2017 2.25 COMPZN WHDBOP NUND P Nipple down 13-5/8"BOPE stack. 0.0 0.0 21:45 00:00 11/20/2017 11/20/2017 ' 0.50 COMPZN WHDBOP NUND P Continue to nipple down 13-5/8" 0.0 0.0 00:00 00:30 BOPE equipment.Clean wellhead. 11/20/2017 11/20/2017 1.50 COMPZN RPCOMP PRTS P Nipple up Vetco Horizontal tree.Test 0.0 0.0 00:30 02:00 hanger void to 5000 psi.Test witnessed by CPAI rep Rock Rauchenstein. 11/20/2017 11/20/2017 1.00 COMPZN RPCOMP NUND P Terminate TEC wire and test same. 0.0 0.0 02:00 03:00 Page 16/17 Report Printed: 11/28/2017 VA Operations Summary (with Timelog Depths) 0 1H-114 ConoccWhillips 71 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log _ Start Depth Start Time End Time Dur(hr) Phase Op Cade Activity Code' Time P-T-X Operation (ftKB) End Depth MKS) 11/20/2017 11/20/2017 1.50 COMPZN RPCOMP PRTS P Rig up to test the tree to 250 and 5000 0.0 0.0 03:00 04:30 psi.Tested to 250 and 5000 psi,each test 15 minutes.Charted test.Good. 11/20/2017 11/20/2017 1.50 COMPZN RPCOMP FRZP P Rig up Little Red Services.Pressure 0.0 0.0 04:30 06:00 test lines to 3000 psi(good).Pump 10 bbls of diesel down the IA taking returns from the tubing.Pumping 2 bpm w/150 psi. 11/20/2017 11/20/2017 3.00 COMPZN RPCOMP FRZP P Shut down pumping.Blow down lines 0.0 0.0 06:00 09:00 to the cuttings tank.Rig up squeeze manifold in the cellar for pumping diesel out of 7"x 3-1/2"tubing IA.Wait on a vac truck to bring over 9 ppg brine.Sim Ops:Perform maintenance on NOV top drive.Disconnect shock hoses on sub levels.Spot tree and well head equipment f/1H-102. 11/20/2017 11/20/2017 3.00 COMPZN RPCOMP FRZP P Hook up brine truck to Little Red 0.0 0.0 09:00 12:00 Services.Pressure test lines to 1500 psi.Pump 15 bbls of 9 ppg brine down the tubing taking returns from the annulus to the cuttings box.Pumping 1 bpm w/750 psi.Little red pump 64 bbls of diesel down the IA @ 1.5 to 2.5 bpm w/500 to 1100 psi.Chase with 2 bbls of diesel.Line up and pump 16 bbls of diesel down the tubing taking returns from the IA to the cuttings box. Pumped @ 2bpm w/700 psi.Pump an additional 15 bbls of diesel thru manifold to the cuttings tank to thin outhe isotherm in the cuttings tank. Blow down and rig down squeeze manifold and hoses.Continue to suck out the cuttings tank. Sim Ops:Blow down steam,raise and secure pipe skate rail on rig floor. 11/20/2017 11/20/2017 2.50 COMPZN WI-IDBOP MPSP P Pickup lubricator to the floor.Install 0.0 0.0 12:00 14:30 flanges and guages on the tree.Stab the lubricator on the Vetco tree. Prressure test lubricator to 1000 psi w/ diesel. Install 4"Type"H" backpressure valve.Rig down and lay down the lubricator. Sim Ops:Unplug and move pipe shed,stage at the end of the pad. Swap rig to cold start and disconnect electrical interconnects. 11/20/2017 11/20/2017 1.50 DEMOB MOVE RURD P Secure tree and clean cellar area. 0.0 0.0 14:30 16:00 Well was shut in with OA=100 psi, IA= 50 psi,Tubing=0 psi. Sim Ops:Hook up and move motor complex,pump complex,and pit complex.Attatch sub moving tongue and cross supports. Rig released at 1600 hrs 11/20/2017 to move to 1H-101. Page 17/17 Report Printed: 11/28/2017 • 04 0' i 3 2,! I ° Y: is 1 NADConversion Kuparuk River Unit k4' ' Kuparuk 1H Pad 1H-114 i I ,,FS ConocoPhillips s, ,,, 1 r Definitive Survey Report k 10 1 20 November, 2017 re) I 44 NAD 27, si 41 4, it ,, • • a �µ ConocoPhillips 0 Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-114 Project: Kuparuk River Unit TVD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1H-114 Survey Calculation Method: Minimum Curvature Design: 1H-114 Database: OAKEDMP2 Project ::'.„,„',:,- Kuparuk River Unit,North Slope Alaska,United States t Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1H-114 Well Position +N/-S 0.00 usft Northing: 5,980,961.86 usft Latitude: 70°21'31.575 N +El-W 0.00 usft Easting: 549,555.50 usft Longitude: 149°35'51.007 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usft Wellbore • 1H-114 Magnetics Model Name Sample Date Declination Dip Angie Meldtrength . ,,,,i;:,;',',.', (°) (o) B G G M 2017 11/20/2017 17.39 80.94 57,485 Design 1H-114 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 38.84 Vertical Section ,,,; Depth Frwrr►(TVD) +N/-S +E/-W Direction ( ) (usft) (usft) (0) 38.84 0.00 0.00 53.27 Suf Tram I:faPrrr To ‘ f tuft) {USR V,-. , !bore �rl )) ••l'oo _.:ll+fa L ctiotiolt .,.. _ �,��.>.x,..,. . , i `(,,• - .,a... '� , Date 115.00 588.00 1H-114 Srvy 1-HAL_Gyro(1H-114) GYD-GC-SS Sperry gyro single shots 11/6/2017 9:09:1 642.82 1,754.25 11-1-114 Srvy 2-SLB_MWD_GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/7/2017 9:11:( 1,818.43 1,818.43 1H-114 Srvy 3-SLB_MWD-Inc_Only_Fil MWD-INC_ONLY MWD-INC_ONLY_FILLER 11/9/2017 9:05:1 1,911.46 7,053.77 1H-114 Srvy 4-SLB_MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 11/9/2017 9:05:1 " 9 � r Map Map Vertical AAD Inc,,-,'%41' 4 WD '1"VDSS +if$ +E/-W V `florthing Easting DLS Section: tum) €r (usft) '(usft) (itsflt) (om) '''--2' ft n oo' Survey Tool Name 38.84 0.00 0.00 38.84 -54.10 0.00 0.00 5,980,961.86 549,555.50 0.00 0.00 UNDEFINED 115.00 0.30 353.84 115.00 22.06 0.20 -0.02 5,980,962.06 549,555.48 0.39 0.10 GYD-GC-SS(1) 212.00 0.53 38.44 212.00 119.06 0.80 0.23 5,980,962.66 549,555.72 0.39 0.66 GYD-GC-SS(1) 309.00 0.84 35.94 308.99 216.05 1.73 0.93 5,980,963.60 549,556.41 0.32 1.78 GYD-GC-SS(1) 401.00 0.90 47.71 400.98 308.04 2.76 1.86 5,980,964.63 549,557.34 0.20 3.14 GYD-GC-SS(1) 495.00 1.16 32.64 494.96 402.02 4.06 2.92 5,980,965.94 549,558.39 0.40 4.76 GYD-GC-SS(1) 588.00 1.18 70.15 587.95 495.01 5.18 4.32 5,980,967.07 549,559.79 0.81 6.56 GYD-GC-SS(1) 642.82 1.78 84.02 642.75 549.81 5.46 5.70 5,980,967.35 549,561.17 1.27 7.83 MWD+IFR-AK-CAZ-SC(2) 681.97 2.80 89.83 681.87 588.93 5.52 7.26 5,980,967.43 549,562.73 2.67 9.12 MVVD+IFR-AK-CAZ-SC(2) 752.85 3.82 97.34 752.63 659.69 5.23 11.34 5,980,967.16 549,566.80 1.56 12.21 MWD+IFR-AK-CAZ-SC(2) 775.62 4.35 99.13 775.34 682.40 4.99 12.94 5,980,966.94 549,568.41 2.39 13.36 MWD+IFR-AK-CAZ-SC(2) 11/20/2017 2:25:11PM Page 2 COMPASS 5000.14 Build 85 • Schlumberger • Definitive Survey Report Company: NADConversion A ;Local Co•ordiinate Reference: Well 1H-114 Project: Kuparuk River Unit " 1H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 r \ True Wellbore: 1H-114 Minimum Curvature Design: 1 H-114 _ OAKEDMP2 Survey MD Inc Azi TVD TVDSS +N/-S +EI-W Northing East (usft) (0) (°) (usft) (usft) (usft) (usft) (ft), (ft) 870.15 7.89 103.45 869.32 776.38 2.91 22.79 5,980,964.93 549,576.27 3.77 20.01 MWD+IFR-AK-CAZ-SC(2) 964.27 11.97 106.42 962.01 869.07 -1.35 38.45 5,980,960.77 549,593.95 4.37 30.01 MWD+IFR-AK-CAZ-SC(2) 1,059.57 14.60 107.87 1,054.75 961.81 -7.83 59.36 5,980,954.42 549,614.91 2.78 42.89 MWD+IFR-AK-CAZ-SC(2) 1,153.75 14.74 108.68 1,145.86 1,052.92 -15.31 82.01 5,980,947.10 549,637.60 0.26 56.57 MWD+IFR-AK-CAZ-SC(2) 1,249.49 18.99 107.56 1,237.46 1,144.52 -23.91 108.41 5,980,938.67 549,664.05 4.45 72.58 MWD+IFR-AK-CAZ-SC(2) 1,343.44 21.86 104.92 1,325.50 1,232.56 -33.03 139.89 5,980,929.76 549,695.59 3.21 92.36 MWD+IFR-AK-CAZ-SC(2) 1,438.12 23.71 102.62 1,412.79 1,319.85 -41.73 175.50 5,980,921.30 549,731.26 2.17 115.70 MWD+IFR-AK-CAZ-SC(2) 1,532.29 25.06 101.27 1,498.55 1,405.61 -49.76 213.54 5,980,913.51 549,769.34 1.55 141.38 MWD+IFR-AK-CAZ-SC(2) 1,627.62 24.31 101.16 1,585.17 1,492.23 -57.51 252.59 5,980,906.03 549,808.44 0.79 168.05 MWD+IFR-AK-CAZ-SC(2) 1,720.86 25.22 99.85 1,669.84 1,576.90 -64.62 290.99 5,980,899.17 549,846.89 1.14 194.58 MWD+IFR-AK-CAZ-SC(2) 1,754.25 26.55 99.80 1,699.88 1,606.94 -67.11 305.36 5,980,896.78 549,861.26 3.98 204.60 MWD+IFR-AK-CAZ-SC(2) 1,818.43 27.46 97.75 1,757.06 1,664.12 -71.54 334.16 5,980,892.53 549,890.09 2.03 225.03 MWD-INC ONLY(3) 1,830.00 27.87 97.54 1,767.31 1,674.37 -72.26 339.48 5,980,891.86 549,895.42 3.61 228.87 NOT an Actual Survey 103/4"x 13-1/2w 1,911.46 30.73 96.20 1,838.34 1,745.40 -77.01 379.05 5,980,887.37 549,935.02 3.61 257.74 MWD+IFR-AK-CAZ-SC(4) 2,006.44 35.82 92.56 1,917.73 1,824.79 -80.87 430.98 5,980,883.85 549,986.96 5.75 297.05 MWD+IFR-AK-CAZ-SC(4) 2,101.04 40.23 89.10 1,992.24 1,899.30 -81.63 489.22 5,980,883.48 550,045.20 5.18 343.27 MWD+IFR-AK-CAZ-SC(4) 2,196.79 44.00 88.40 2,063.26 1,970.32 -80.21 553.40 5,980,885.32 550,109.36 3.97 395.56 MWD+IFR-AK-CAZ-SC(4) 2,290.97 48.10 86.38 2,128.61 2,035.67 -77.09 621.11 5,980,888.89 550,177.05 4.62 451.70 MWD+IFR-AK-CAZ-SC(4) 2,385.73 52.37 84.57 2,189.21 2,096.27 -71.30 693.70 5,980,895.15 550,249.59 4.74 513.33 MWD+IFR-AK-CAZ-SC(4) 2,480.80 56.11 83.32 2,244.76 2,151.82 -63.15 770.40 5,980,903.81 550,326.22 4.08 579.68 MWD+IFR-AK-CAZ-SC(4) 2,575.28 59.84 82.99 2,294.85 2,201.91 -53.60 849.91 5,980,913.89 550,405.67 3.96 649.12 MWD+IFR-AK-CAZ-SC(4) 2,669.64 63.15 84.01 2,339.88 2,246.94 -44.23 932.29 5,980,923.81 550,487.97 3.63 720.75 MWD+IFR-AK-CAZ-SC(4) 2,764.81 64.64 83.52 2,381.75 2,288.81 -34.94 1,017.24 5,980,933.65 550,572.85 1.63 794.38 MWD+IFR-AK-CAZ-SC(4) 2,858.67 65.88 84.20 2,421.03 2,328.09 -25.83 1,102.00 5,980,943.33 550,657.54 1.48 867.76 MWD+IFR-AK-CAZ-SC(4) 2,954.28 67.97 81.07 2,458.51 2,365.57 -14.54 1,189.21 5,980,955.19 550,744.66 3.72 944.41 MWD+IFR-AK-CAZ-SC(4) 3,049.53 70.32 79.17 2,492.42 2,399.48 0.75 1,276.89 5,980,971.05 550,832.23 3.09 1,023.82 MW1J+IFR-AK-CAZ-SC(4) 3,143.87 70.06 77.45 2,524.40 2,431.46 18.73 1,363.80 5,980,989.61 550,919.01 1.74 1,104.23 MWD+IFR-AK-CAZ-SC(4) 3,239.57 69.94 74.02 2,557.14 2,464.20 40.88 1,450.94 5,981,012.34 551,005.99 3.37 1,187.32 MWD+IFR-AK-CAZ-SC(4) 3,333.07 69.88 69.60 2,589.27 2,496.33 68.29 1,534.34 5,981,040.29 551,089.20 4.44 1,270.55 MWD+IFR-AK-CAZ-SC(4) 3,427.90 69.94 69.59 2,621.84 2,528.90 99.34 1,617.81 5,981,071.89 551,172.46 0.06 1,356.02 MWD+IFR-AK-CAZ-SC(4) 3,522.39 70.09 69.23 2,654.14 2,561.20 130.57 1,700.93 5,981,103.66 551,255.37 0.39 1,441.32 MWD+IFR-AK-CAZ-SC(4) 3,616.87 69.89 70.15 2,686.47 2,593.53 161.38 1,784.19 5,981,135.02 551,338.41 0.94 1,526.47 MWD+IFR-AK-CAZ-SC(4) 3,711.38 69.97 71.18 2,718.90 2,625.96 190.77 1,867.95 5,981,164.97 551,421.97 1.03 1,611.18 MWD+IFR-AK-CAZ-SC(4) 3,806.13 70.04 72.26 2,751.30 2,658.36 218.70 1,952.50 5,981,193.45 551,506.32 1.07 1,695.64 MWD+IFR-AK-CAZ-SC(4) 3,900.72 69.91 73.26 2,783.69 2,690.75 245.04 2,037.37 5,981,220.35 551,591.01 1.00 1,779.42 MWD+IFR-AK-CAZ-SC(4) 3,995.36 69.53 72.61 2,816.49 2,723.55 271.09 2,122.24 5,981,246.95 551,675.69 0.76 1,863.02 MWD+IFR-AK-CAZ-SC(4) 4,090.05 69.78 72.06 2,849.42 2,756.48 298.03 2,206.83 5,981,274.45 551,760.10 0.61 1,946.93 MWD+IFR-AK-CAZ-SC(4) 4,184.60 70.13 71.13 2,881.82 2,788.88 326.07 2,291.11 5,981,303.05 551,844.18 1.00 2,031.25 MWD+IFR-AK-CAZ-SC(4) 4,279.49 69.96 69.52 2,914.21 2,821.27 356.10 2,375.09 5,981,333.63 551,927.96 1.60 2,116.51 MWD+IFR-AK-CAZ-SC(4) 11/20/2017 2:25:11PM Page 3 COMPASS 5000.14 Build 85 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-114 Project: Kuparuk River Unit ND Reference: 1 H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1 H-114 Survey Calculation Method: Minimum Curvature Design: 1 H-114 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,374.75 70.19 65.84 2,946.68 2,853.74 390.11 2,457.92 5,981 368 18 552,010.55 3.64 2,203.24 MWD+IFR-AK-CAZ-SC(4) 4,468.89 69.71 62.05 2,978.97 2,886.03 428.94 2,537.35 5,981,407.53 552,089.71 3.82 2,290.12 MWD+IFR-AK-CAZ-SC(4) 4,563.31 68.49 59.48 3,012.66 2,919.72 472.01 2,614.32 5,981,451.11 552,166.39 2.85 2,377.56 MWD+IFR-AK-CAZ-SC(4) 4,658.90 67.70 57.00 3,048.32 2,955.38 518.68 2,689.72 5,981,498.27 552,241.47 2.54 2,465.91 MWD+IFR-AK-CAZ-SC(4) 4,752.53 67.13 54.27 3,084.29 2,991.35 567.47 2,761.08 5,981,547.53 552,312.50 2.76 2,552.27 MWD+IFR-AK-CAZ-SC(4) 4,846.72 65.85 50.58 3,121.87 3,028.93 620.11 2,829.52 5,981,600.62 552,380.58 3.84 2,638.61 MWD+IFR-AK-CAZ-SC(4) 4,941.55 63.98 47.27 3,162.08 3,069.14 676.52 2,894.27 5,981,657.44 552,444.95 3.73 2,724.23 MWD+IFR-AK-CAZ-SC(4) 5,035.90 62.94 44.96 3,204.24 3,111.30 735.02 2,955.10 5,981,716.34 552,505.39 2,45 2,807.97 MWD+IFR-AK-CAZ-SC(4) 5,130.83 62.14 42.01 3,248.03 3,155.09 796.12 3,013.06 5,981,777.82 552,562.94 2.88 2,890.97 MWD+IFR-AK-CAZ-SC(4) 5,224.94 61.93 37.58 3,292.17 3,199.23 859.96 3,066.25 5,981,842.00 552,615.69 4.16 2,971.78 MWD+IFR-AK-CAZ-SC(4) 5,319.30 61.24 33.54 3,337.09 3,244.15 927.45 3,114.50 5,981,909.80 552,663.50 3.84 3,050.81 MWD+IFR-AK-CAZ-SC(4) 5,414.84 61.82 32.36 3,382.63 3,289.69 997.92 3,160.18 5,981,980.57 552,708.70 1.24 3,129.57 MWD+IFR-AK-CAZ-SC(4) 5,509.84 63.65 28.41 3,426.17 3,333.23 1,070.76 3,202.86 5,982,053.68 552,750.90 4.17 3,207.33 MWD+IFR-AK-CAZ-SC(4) 5,604.44 62.90 24.03 3,468.73 3,375.79 1,146.53 3,240.19 5,982,129.68 552,787.72 4.21 3,282.56 MWD+IFR-AK-CAZ-SC(4) 5,627.65 62.74 23.72 3,479.33 3,386.39 1,165.41 3,248.55 5,982,148.62 552,795.95 1.37 3,300.55 MWD+IFR-AK-CAZ-SC(4) 5,699.33 66.03 22.86 3,510.31 3,417.37 1,224.77 3,274.09 5,982,208.14 552,821.10 4.72 3,356.53 MWD+IFR-AK-CAZ-SC(4) 5,721.59 66.99 22.30 3,519.19 3,426.25 1,243.62 3,281.93 5,982,227.04 552,828.81 4.89 3,374.08 MWD+IFR-AK-CAZ-SC(4) 5,793.80 64.56 20.17 3,548.81 3,455.87 1,304.98 3,305.79 5,982,288.56 552,852.26 4.31 3,429.90 MWD+IFR-AK-CAZ-SC(4) 5,888.74 62.34 15.07 3,591.27 3,498.33 1,385.87 3,331.52 5,982,369.61 552,877.45 5.34 3,498.90 MWD+IFR-AK-CAZ-SC(4) 5,983.39 61.88 9.17 3,635.58 3,542.64 1,467.61 3,349.08 5,982,451.45 552,894.47 5.53 3,561.86 MWD+IFR-AK-CAZ-SC(4) 6,051.96 61.78 5.07 3,667.96 3,575.02 1,527.58 3,356.57 5,982,511.46 552,901.56 5.27 3,603.72 MWD+IFR-AK-CAZ-SC(4) 6,078.33 61.79 3.73 3,680.43 3,587.49 1,550.74 3,358.35 5,982,534.64 552,903.19 4.48 3,619.01 MWD+IFR-AK-CAZ-SC(4) 6,173.22 64.02 0.92 3,723.65 3,630.71 1,635.13 3,361.76 5,982,619.04 552,906.04 3.53 3,672.21 MWD+IFR-AK-CAZ-SC(4) 6,268.53 65.38 0.27 3,764.38 3,671.44 1,721.29 3,362.65 5,982,705.19 552,906.36 1.55 3,724.45 MWD+IFR-AK-CAZ-SC(4) 6,362.99 64.52 359.60 3,804.38 3,711.44 1,806.87 3,362.56 5,982,790.76 552,905.70 1.11 3,775.55 MWD+IFR-AK-CAZ-SC(4) 6,456.87 64.65 359.22 3,844.67 3,751.73 1,891.66 3,361.68 5,982,875.53 552,904.27 0.39 3,825.56 MWD+IFR-AK-CAZ-SC(4) 6,551.61 64.70 359.28 3,885.19 3,792.25 1,977.28 3,360.56 5,982,961.14 552,902.58 0.08 3,875.87 MWD+IFR-AK-CAZ-SC(4) 6,645.12 64.74 358.31 3,925.12 3,832.18 2,061.82 3,358.78 5,983,045.65 552,900.24 0.94 3,925.00 MWD+IFR-AK-CAZ-SC(4) 6,741.28 64.67 358.11 3,966.21 3,873.27 2,148.72 3,356.07 5,983,132.52 552,896.95 0.20 3,974.79 MWD+IFR-AK-CAZ-SC(4) 6,835.04 64.77 359.11 4,006.25 3,913.31 2,233.47 3,354.01 5,983,217.25 552,894.34 0.97 4,023.83 MWD+IFR-AK-CAZ-SC(4) 6,930.30 64.53 1.00 4,047.04 3,954.10 2,319.55 3,354.09 5,983,303.33 552,893.85 1.81 4,075.38 MVVD+IFR-AK-CAZ-SC(4) 7,023.44 64.96 1.47 4,086.78 3,993.84 2,403.77 3,355.91 5,983,387.55 552,895.11 0.65 4,127.20 MWD+IFR-AK-CAZ-SC(4) 7,053.77 64.82 1.21 4,099.65 4,006.71 2,431.23 3,356.55 5,983,415.00 552,895.57 0.90 4,144.13 MWD+IFR-AK-CAZ-SC(4) 7,110.60 64.82 1.21 4,123.83 4,030.89 2,482.65 3,357.64 . 5,983,466.42 552,896.31 0.00 4,175.75 NOT an Actual Survey 7"x 8 314"' 7,121.00 64.82 1.21 4,128.25 4,035.31 2,492.05 3,357.84 5,983,475.83 552,896.45 0.00 4,181.54 PROJECTED to TD 11/20/2017 2:25:11PM Page 4 COMPASS 5000.14 Build 85 • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. E YesLINe I have checked to the best of my ability that the following data is correct: 1,;_l Surface Coordinates ElDeclination & Convergence DRS Survey CorrectionsDigatallY signed by Vincent O Visara ncent crr.Virecent Osara, ET, Survey Tool Codes orSchlumberger, ou,Schlumberger, Osaraernail,=aosara,s1b.com.c SLB DE: •ate.2017 1120 14 31 51-0q. Client Representative: Jamal Cherry Digitally signed by Jamal Cherry Date:2017,11.21 11:56:47-0900` Date: 20-Nov-2017 a • • 0 Cement Detail Report t 1H-114 ConocoPhillips String: Conductor Cement Job: DRILLING ORIGINAL, 11/5/2017 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 11/6/2016 10:00 11/6/2016 11:00 1H-114 Comment AFC poured 10 x yards of cement for conductor.Cement is 564/3520 cmt/aggregate ratio per yard.Total of 5.5 sacks mixed. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement 39.0 119.0 No No No 0 Pump nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment AFC poured 10 x yards of cement for conductor.Cement is 564/3520 cmt/aggregate ratio per yard.Total of 5.5 sacks mixed. Cement Fluids&Additives Flu Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/4/2017 • Cement Detail Report S 1H-114 hhips A1.rosk.a String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/5/2017 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 11/8/2017 04:45 11/8/2017 08:30 1H-114 Comment Cement 10-3/4"surface casing. Pump 5 bbls of CW-100 chem wash,shut down and pressure test line to 4000 psi. Line up to SLB and pump 35 bbls of CW-100 @ 5.5 bpm=62 psi followed by 75.8 bbls of 10.5 ppg MPII,shut down and batch up lead cement. Drop bottom plug and pump 304.3 bbls of 11.0 ppg LiteCRETE lead cement,observed MPII at shakers 278 bbls of lead away, pumped tub down and swab to tail. Pumped 61.3 bbls of 15.8 ppg tail cement. Dropped top plug and kicked out with 10 bbls of fresh water. Rig pumped 156 bbls of Spud mud @ 7 bpm=600 psi to bump plugs, plug bumped @ 1560 strokes. Pressure up to 500 psi over FCP(1000 psi)hold for 5 min,bled off and checked floats,good.86 bbls of lead cement returned to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 43.0 1,840.0 No 86.0 Yes Yes Q Pump Mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 6 550.0 1,050.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 40 bbls,CW-100,75.8 bbls MP II ,304 bbls of 11.0 ppg Lead and 61 bbls of 15.8 ppg tail. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MP II Mud Push 76.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead LiteCRETE 43.0 1,340.0 895 Extended G 304.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 77.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Additive Type Concentration Conc Unit label Dispersant D230 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail 1,340.0 1,840.0 296 G 61.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.12 15.80 113.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.05 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D255 0.35 %BWOC Page 1/1 Report Printed: 12/4/2017 Cement Detail Report 01 1H-114 C ,ocoPhillips String: Production casing cement Job: DRILLING ORIGINAL, 11/5/2017 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production casing cement 11/15/2017 10:00 11/15/2017 12:21 1H-114 Comment Blow down top drive and rig up cement hose/line/T's etc.etc.Stage pumps up to 8 BPM,initial circulating pressure=584 PSI with a final circ pressure of 500 PSI. UP WT= 173K and DWN WT=96K. Pumped 7,589 stks. Pump 40 BBL nut plug gauge pill at same rate surf/surf 4990 stks, Actual volume pumped= 518.6 bbls. Perform prejob safety meeting while continuing to circulate at slower rate of 5 BPM 304 PSI. 16%F/O. UP wT= 188K, DWN WT=98K. 1108 stks pumped while waiting for SLB to stage up. Total volume pumped before cement job was 1565 bbls. Flush lines and PT SLB to 4K.(GOOD). Pump 30.8 BBLS mud push at 1-4 BPM due to weight challenges 50-235 PSI DPP. 6-15%F/O. Load btm plug and pump 116.2 BBLS 15.8 PPG cement @ 4.5 BPM ICP=216 FCP=89. Flush lines to the floor w/8 bbls of water. Load top plug and KO with 10 BBLS of fresh water displace with 9.0 PPG brine at 8 BPM. ICP= 132 PSI FCP= 1270 PSI. 24%F/O. reduce rate at 2,400 STKS to 3 BPM ICP 780 PSI, FCP 900 psi. 12%F/O. Bump plug at 2560 STKS. Full returns through out job. Pressure up to 1,400 PSI for 5 min. CIP= 12:21. Pressure test casing to 3,500 PSI chart same for 30 MIN. PT good. 39 STKS pressure up with 3.9 BBLS bled back.RD/BD TD. and all circ lines. RD Volant tool and bale extensions/elevators etc. LD landing joint. kick out GBR equipment. Cement Stages Stage#i Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Production casing cement 3,790.0 7,121.0 Yes 0.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 5 4 900.0 1,400.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,983.0 Wireline Comment Blow down top drive and rig up cement hose/line/Ts etc.etc.Stage pumps up to 8 BPM, initial circulating pressure=584 PSI with a final circ pressure of 500 PSI. UP WT= 173K and DWN WT=96K. Pumped 7,589 stks. Pump 40 BBL nut plug gauge pill at same rate surf/surf 4990 stks, Actual volume pumped= 518.6 bbls. Perform prejob safety meeting while continuing to circulate at slower rate of 5 BPM 304 PSI. 16%F/O. UP wT= 188K, DWN WT=98K. 1108 stks pumped while waiting for SLB to stage up. Total volume pumped before cement job was 1565 bbls. Flush lines and PT SLB to 4K.(GOOD). Pump 30.8 BBLS mud push at 1-4 BPM due to weight challenges 50-235 PSI DPP. 6-15%F/O. Load btm plug and pump 116.2 BBLS 15.8 PPG cement @ 4.5 BPM ICP=216 FCP=89. Flush lines to the floor w/8 bbls of water. Load top plug and KO with 10 BBLS of fresh water displace with 9.0 PPG brine at 8 BPM. ICP= 132 PSI FCP= 1270 PSI. 24%F/O. reduce rate at 2,400 STKS to 3 BPM ICP 780 PSI, FCP 900 psi. 12%F/O. Bump plug at 2560 STKS. Full returns through out job. Pressure up to 1,400 PSI for 5 min. CIP= 12:21. Pressure test casing to 3,500 PSI chart same for 30 MIN. PT good. 39 STKS pressure up with 3.9 BBLS bled back. RD/BD TD. and all circ lines. RD Volant tool and bale extensions/elevators etc. LD landing joint. kick out GBR equipment. TOC confirmed by ELINE LOG on 11/16/2017.TOC 3786'. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 3,786.0 7,121.0 562 G 116.2 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.12 15.80 3.62 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud push 2,960.0 3,786.0 MP 30.8 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label D047 Antifoam 0.05 gal/sx Additive Type Concentration Conc Unit label 0065 Dispersant 0.2 %BWOC Additive Type Concentration Conc Unit label D255 Fluid Loss 0.4 %BWOC Page 1/1 Report Printed: 12/4/2017 • • 11 7 1 36 RECEIVED • 28 8 2 1 DEC 042017 S chlui'nberg er AOGCC Transmittal#: 04DEC17-SPO1 Drilling & Measurements DATA LOGGED Product Delivery v2.../.04/2011 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well Name: 1H-114 Date Dispatched: 4-Dec-17 Service Order#: 17AKA0022 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 13-Nov-17 VISION Service 2" MD x x 2"TVD x x 5" MD x x 5"TVD x x Digital Data N/A Contents on CD LAS/DLIS Data x Surveys 2 Contents on CD Directional Survey Nad27 x x Directional Survey Nad83 x x CD 1 Contents on CD Data: DLIS/LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkampt conocophillips.com AlaskaPTSPrintCenter(a�slb.com Attn:Tom Osterkamp Attn:Stephanie Pacillo Received By: /544t.4it( ,A ';t✓ • i 21 7 1 36 28821 RECEIVED DEC 0 4 2017 AOGCC FINAL NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-114 ConocoPhillips Definitive Survey Report 20 November, 2017 NAD 27 ConocoPhillips p • III Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 114114 Project: Kuparuk River Unit TVD Reference: 114114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1H-114 Survey Calculation Method: Minimum Curvature Design: 1H-114 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1H-114 Well Position +N/-S 0.00 usft Northing: 5,980,961.86 usft Latitude: 70°21'31.575 N +E/-W 0.00 usft Easting: 549,555.50 usft Longitude: 149°35'51.007 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usft Wellbore 1H-114 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2017 11/20/2017 17.39 80.94 57.485 Design 1H-114 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 38.84 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 38.84 0.00 0.00 53.27 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 115.00 588.00 1H-114 Srvy 1-HAL_Gyro(1H-114) GYD-GC-SS Sperry gyro single shots 11/6/2017 9:09:1 642.82 1,754.25 1H-114 Srvy 2-SLB_MWD_GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/7/2017 9:11:1 1,818.43 1,818.431H-114 Srvy 3-SLB_MWD-Inc_Only_Fil MWD-INC_ONLY MWD-INC_ONLY_FILLER 11/9/2017 9:05:1 1,911.46 7,053.77 1H-114 Srvy 4-SLB_MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/9/2017 9:05:1 1 •Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 38.84 0.00 0.00 38.84 -54.10 0.00 0.00 5,980,961.86 549,555.50 0.00 0.00 UNDEFINED 115.00 0.30 353.84 115.00 22.06 0.20 -0.02 5,980,962.06 549,555.48 0.39 0.10 GYD-GC-SS(1) 212.00 0.53 38.44 212.00 119.06 0.80 0.23 5,980,962.66 549,555.72 0.39 0.66 GYD-GC-SS(1) 309.00 0.84 35.94 308.99 216.05 1.73 0.93 5,980,963.60 549,556.41 0.32 1.78 GYD-GC-SS(1) 401.00 0.90 47.71 400.98 308.04 2.76 1.86 5,980,964.63 549,557.34 0.20 3.14 GYD-GC-SS(1) 495.00 1.16 32.64 494.96 402.02 4.06 2.92 5,980,965.94 549,558.39 0.40 4.76 GYD-GC-SS(1) 588.00 1.18 70.15 587.95 495.01 5.18 4.32 5,980,967.07 549,559.79 0.81 6.56 GYD-GC-SS(1) 642.82 1.78 84.02 642.75 549.81 5.46 5.70 5,980,967.35 549,561.17 1.27 7.83 MWD+IFR-AK-CAZ-SC(2) 681.97 2.80 89.83 681.87 588.93 5.52 7.26 5,980,967.43 549,562.73 2.67 9.12 MWD+IFR-AK-CAZ-SC(2) 752.85 3.82 97.34 752.63 659.69 5.23 11.34 5,980,96716 549,566.80 1.56 12.21 MWD+IFR-AK-CAZ-SC(2) 775.62 4.35 99.13 775.34 682.40 4.99 12.94 5,980,966.94 549,568.41 2.39 13.36 MWD+IFR-AK-CAZ-SC(2) 11/20/2017 2:25:11PM Page 2 COMPASS 5000.14 Build 85 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-114 Project: Kuparuk River Unit TVD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1 H-114 Survey Calculation Method: Minimum Curvature Design: 1H-114 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 870.15 7.89 103.45 869.32 776.38 2.91 2279 5,980,964.93 549,578.27 3.77 20.01 MWD+IFR-AK-CAZ-SC(2) 964.27 11.97 106.42 962.01 869.07 -1.35 38.45 5,980,960.77 549,593.95 4.37 30.01 MWD+IFR-AK-CAZ-SC(2) 1,059.57 14.60 107.87 1,054.75 961.81 -7.83 59.36 5,980,954.42 549,614.91 2.78 42.89 MWD+IFR-AK-CAZ-SC(2) 1,153.75 14.74 108.68 1,145.86 1,052.92 -15.31 82.01 5,980,947.10 549,637.60 0.26 56.57 MWD+IFR-AK-CAZ-SC(2) 1,249.49 18.99 107.56 1,237.46 1,144.52 -23.91 108.41 5,980,938.67 549,664.05 4.45 72.58 MWD+IFR-AK-CAZ-SC(2) 1,343.44 21.86 104.92 1,325.50 1,232.56 -33.03 139.89 5,980,929.76 549,695.59 3.21 92.36 MWD+IFR-AK-CAZ-SC(2) 1,438.12 23.71 102.62 1,412.79 1,319.85 -41.73 175.50 5,980,921.30 549,731.26 2.17 115.70 MWD+IFR-AK-CAZ-SC(2) 1,532.29 25.06 101.27 1,498.55 1,405.61 -49.76 213.54 5,980,913.51 549,769.34 1.55 141.38 MWD+IFR-AK-CAZ-SC(2) 1,627.62 24.31 101.16 1,585.17 1,492.23 -57.51 252.59 5,980,906.03 549,808.44 0.79 168.05 MWD+IFR-AK-CAZ-SC(2) 1,720.86 25.22 99.85 1,669.84 1,576.90 -64.62 290.99 5,980,899.17 549,846.89 1.14 194.58 MWD+IFR-AK-CAZ-SC(2) 1,754.25 26.55 99.80 1,699.88 1,606.94 -67.11 305.36 5,980,896.78 549,861.26 3.98 204.60 MWD+IFR-AK-CAZ-SC(2) 1,818.43 27.46 97.75 1,757.06 1,664.12 -71.54 334.16 5,980,892.53 549,890.09 2.03 225.03 MWD-INC_ONLY(3) 1,830.00 27.87 97.54 1,767.31 1,674.37 -72.26 339.48 5,980,891.86 549,895.42 3.61 228.87 NOT an Actual Survey 10 3/4"x 13-1/2" 1,911.46 30.73 96.20 1,838.34 1,745.40 -77.01 379.05 5,980,887.37 549,935.02 3.61 257.74 MWD+IFR-AK-CAZ-SC(4) 2,006.44 35.82 92.56 1,917.73 1,824.79 -80.87 430.98 5,980,883.85 549,986.96 5.75 297.05 MWD+IFR-AK-CAZ-SC(4) 2,101.04 40.23 89.10 1,992.24 1,899.30 -81.63 489.22 5,980,883.48 550,045.20 5.18 343.27 MWD+IFR-AK-CAZ-SC(4) 2,196.79 44.00 88.40 2,063.26 1,970.32 -80.21 553.40 5,980,885.32 550,109.36 3.97 395.56 MWD+IFR-AK-CAZ-SC(4) 2,290.97 48.10 86.38 2,128.61 2,035.67 -77.09 621.11 5,980,888.89 550,177.05 4.62 451.70 MWD+IFR-AK-CAZ-SC(4) 2,385.73 52.37 84.57 2,189.21 2,096.27 -71.30 693.70 5,980,895.15 550,249.59 4.74 513.33 MWD+IFR-AK-CAZ-SC(4) 2,480.80 56.11 83.32 2,244.76 2,151.82 -63.15 770.40 5,980,903.81 550,326.22 4.08 579.68 MWD+IFR-AK-CAZ-SC(4) 2,575.28 59.84 82.99 2,294.85 2,201.91 -53.60 849.91 5,980,913.89 550,405.67 3.96 649.12 MWD+IFR-AK-CAZ-SC(4) 2,669.64 63.15 84.01 2,339.88 2,246.94 -44.23 932.29 5,980,923.81 550,487.97 3.63 720.75 MWD+IFR-AK-CAZ-SC(4) 2,764.81 64.64 83.52 2,381.75 2,288.81 -34.94 1,017.24 5,980,933.65 550,572.85 1.63 794.38 MWD+IFR-AK-CAZ-SC(4) 2,858.67 65.88 84.20 2,421.03 2,328.09 -25.83 1,102.00 5,980,943.33 550,657.54 1.48 867.76 MWD+IFR-AK-CAZ-SC(4) 2,954.28 67.97 81.07 2,458.51 2,365.57 -14.54 1,189.21 5,980,955.19 550,744.66 3.72 944.41 MWD+IFR-AK-CAZ-SC(4) 3,049.53 70.32 79.17 2,492.42 2,399.48 0.75 1,276.89 5,980,971.05 550,832.23 3.09 1,023.82 MWD+IFR-AK-CAZ-SC(4) 3,143.87 70.06 77.45 2,524.40 2,431.46 18.73 1,363.80 5,980,989.61 550,919.01 1.74 1,104.23 MWD+IFR-AK-CAZ-SC(4) 3,239.57 69.94 74.02 2,557.14 2,464.20 40.88 1,450.94 5,981,012.34 551,005.99 3.37 1,187.32 MWD+IFR-AK-CAZ-SC(4) 3,333.07 69.88 69.60 2,589.27 2,496.33 68.29 1,534.34 5,981,040.29 551,089.20 4.44 1,270.55 MWD+IFR-AK-CAZ-SC(4) 3,427.90 69.94 69.59 2,621.84 2,528.90 99.34 1,617.81 5,981,071.89 551,172.46 0.06 1,356.02 MWD+IFR-AK-CAZ-SC(4) 3,522.39 70.09 69.23 2,654.14 2,561.20 130.57 1,700.93 5,981,103.66 551,255.37 0.39 1,441.32 MWD+IFR-AK-CAZ-SC(4) 3,616.87 69.89 70.15 2,686.47 2,593.53 161.38 1,784.19 5,981,135.02 551,338.41 0.94 1,526.47 MWD+IFR-AK-CAZ-SC(4) 3,711.38 69.97 71.18 2,718.90 2,625.96 190.77 1,867.95 5,981,164.97 551,421.97 1.03 1,611.18 MWD+IFR-AK-CAZ-SC(4) 3,806.13 70.04 72.26 2,751.30 2,658.36 218.70 1,952.50 5,981,193.45 551,506.32 1.07 1,695.64 MWD+IFR-AK-CAZ-SC(4) 3,900.72 69.91 73.26 2,783.69 2,690.75 245.04 2,037.37 5,981,220.35 551,591.01 1.00 1,779.42 MWD+IFR-AK-CAZ-SC(4) 3,995.36 69.53 72.61 2,816.49 2,723.55 271.09 2,122.24 5,981,246.95 551,675.69 0.76 1,863.02 MWD+IFR-AK-CAZ-SC(4) 4,090.05 69.78 72.06 2,849.42 2,756.48 298.03 2,206.83 5,981,274.45 551,760.10 0.61 1,946.93 MWD+IFR-AK-CAZ-SC(4) 4,184.60 70.13 71.13 2,881.82 2,788.88 326.07 2,291.11 5,981,303.05 551,844.18 1.00 2,031.25 MWD+IFR-AK-CAZ-SC(4) 4,279.49 69.96 69.52 2,914.21 2,821.27 356.10 2,375.09 5,981,333.63 551,927.96 1.60 2,116.51 MWD+IFR-AK-CAZ-SC(4) 11/20/2017 2:25:11 PM Page 3 COMPASS 5000.14 Build 85 III • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-114 Project: Kuparuk River Unit ND Reference: 1 H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1H-114 Survey Calculation Method: Minimum Curvature Design: 1H-114 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,374.75 70.19 65.84 2,946.68 2,853.74 390.11 2,457.92 5,981,368.18 552,010.55 3.64 2,203.24 MWD+IFR-AK-CAZ-SC(4) 4,468.89 69.71 62.05 2,978.97 2,886.03 428.94 2,537.35 5,981,407.53 552,089.71 3.82 2,290.12 MWD+IFR-AK-CAZ-SC(4) 4,563.31 68.49 59.48 3,012.66 2,919.72 472.01 2,614.32 5,981,451.11 552,166.39 2.85 2,377.56 MWD+IFR-AK-CAZ-SC(4) 4,658.90 67.70 57.00 3,048.32 2,955.38 518.68 2,689.72 5,981,498.27 552,241.47 2.54 2,465.91 MWD+IFR-AK-CAZ-SC(4) 4,752.53 67.13 54.27 3,084.29 2,991.35 567.47 2,761.08 5,981,547.53 552,312.50 2.76 2,552.27 MWD+IFR-AK-CAZ-SC(4) 4,846.72 65.85 50.58 3,121.87 3,028.93 620.11 2,829.52 5,981,600.62 552,380.58 3.84 2,638.61 MWD+IFR-AK-CAZ-SC(4) 4,941.55 63.98 47.27 3,162.08 3,069.14 676.52 2,894.27 5,981,657.44 552,444.95 3.73 2,724.23 MWD+IFR-AK-CAZ-SC(4) 5,035.90 62.94 44.96 3,204.24 3,111.30 735.02 2,955.10 5,981,716.34 552,505.39 2.45 2,807.97 MWD+IFR-AK-CAZ-SC(4) 5,130.83 62.14 42.01 3,248.03 3,155.09 796.12 3,013.06 5,981,777.82 552,562.94 2.88 2,890.97 MWD+IFR-AK-CAZ-SC(4) 5,224.94 61.93 37.58 3,292.17 3,199.23 859.96 3,066.25 5,981,842.00 552,615.69 4.16 2,971.78 MWD+IFR-AK-CAZ-SC(4) 5,319.30 61.24 33.54 3,337.09 3,244.15 927.45 3,114.50 5,981,909.80 552,663.50 3.84 3,050.81 MWD+IFR-AK-CAZ-SC(4) 5,414.84 61.82 32.36 3,382.63 3,289.69 997.92 3,160.18 5,981,980.57 552,708.70 1.24 3,129.57 MWD+IFR-AK-CAZ-SC(4) 5,509.84 63.65 28.41 3,426.17 3,333.23 1,070.76 3,202.86 5,982,053.68 552,750.90 4.17 3,207.33 MWD+IFR-AK-CAZ-SC(4) 5,604.44 62.90 24.03 3,468.73 3,375.79 1,146.53 3,240.19 5,982,129.68 552,787.72 4.21 3,282.56 MWD+IFR-AK-CAZ-SC(4) 5,627.65 62.74 23.72 3,479.33 3,386.39 1,165.41 3,248.55 5,982,148.62 552,795.95 1.37 3,300.55 MWD+IFR-AK-CAZ-SC(4) 5,699.33 66.03 22.86 3,510.31 3,417.37 1,224.77 3,274.09 5,982,208.14 552,821.10 4.72 3,356.53 MWD+IFR-AK-CAZ-SC(4) 5,721.59 66.99 22.30 3,519.19 3,426.25 1,243.62 3,281.93 5,982,227.04 552,828.81 4.89 3,374.08 MWD+IFR-AK-CAZ-SC(4) 5,793.80 64.56 20.17 3,548.81 3,455.87 1,304.98 3,305.79 5,982,288.56 552,852.26 4.31 3,429.90 MWD+IFR-AK-CAZ-SC(4) 5,888.74 62.34 15.07 3,591.27 3,498.33 1,385.87 3,331.52 5,982,369.61 552,877.45 5.34 3,498.90 MWD+IFR-AK-CAZ-SC(4) 5,983.39 61.88 9.17 3,635.58 3,542.64 1,467.61 3,349.08 5,982,451.45 552,894.47 5.53 3,561.86 MWD+IFR-AK-CAZ-SC(4) 6,051.96 61.78 5.07 3,667.96 3,575.02 1,527.58 3,356.57 5,982,511.46 552,901.56 5.27 3,603.72 MWD+IFR-AK-CAZ-SC(4) 6,078.33 61.79 3.73 3,680.43 3,587.49 1,550.74 3,358.35 5,982,534.64 552,903.19 4.48 3,619.01 MWD+IFR-AK-CAZ-SC(4) 6,173.22 64.02 0.92 3,723.65 3,630.71 1,635.13 3,361.76 5,982,619.04 552,906.04 3.53 3,672.21 MWD+IFR-AK-CAZ-SC(4) 6,268.53 65.38 0.27 3,764.38 3,671.44 1,721.29 3,362.65 5,982,705.19 552,906.36 1.55 3,724.45 MWD+IFR-AK-CAZ-SC(4) 6,362.99 64.52 359.60 3,804.38 3,711.44 1,806.87 3,362.56 5,982,790.76 552,905.70 1.11 3,775.55 MWD+IFR-AK-CAZ-SC(4) 6,456.87 64.65 359.22 3,844.67 3,751.73 1,891.66 3,361.68 5,982,875.53 552,904.27 0.39 3,825.56 MWD+IFR-AK-CAZ-SC(4) 6,551.61 64.70 359.28 3,885.19 3,792.25 1,977.28 3,360.56 5,982,961.14 552,902.58 0.08 3,875.87 MWD+IFR-AK-CAZ-SC(4) 6,645.12 64.74 358.31 3,925.12 3,832.18 2,061.82 3,358.78 5,983,045.65 552,900.24 0.94 3,925.00 MWD+IFR-AK-CAZ-SC(4) 6,741.28 64.67 358.11 3,966.21 3,873.27 2,148.72 3,356.07 5,983,132.52 552,896.95 0.20 3,974.79 MWD+IFR-AK-CAZ-SC(4) 6,835.04 64.77 359.11 4,006.25 3,913.31 2,233.47 3,354.01 5,983,217.25 552,894.34 0.97 4,023.83 MWD+IFR-AK-CAZ-SC(4) 6,930.30 64.53 1.00 4,047.04 3,954.10 2,319.55 3,354.09 5,983,303.33 552,893.85 1.81 4,075.38 MWD+IFR-AK-CAZ-SC(4) 7,023.44 64.96 1.47 4,086.78 3,993.84 2,403.77 3,355.91 5,983,387.55 552,895.11 0.65 4,127.20 MWD+IFR-AK-CAZ-SC(4) 7,053.77 64.82 1.21 4,099.65 4,006.71 2,431.23 3,356.55 5,983,415.00 552,895.57 0.90 4,144.13 MWD+IFR-AK-CAZ-SC(4) 7,110.60 64.82 1.21 4,123.83 4,030.89 2,482.65 3,357.64 5,983,466.42 552,896.31 0.00 4,175.75 NOT an Actual Survey 7"x83/4" 7,121.00 64.82 1.21 4,128.25 4,035.31 2,492.05 3.357.84 5,983,475.83 552,896.45 0.00 4,181.54 PROJECTED to TD 11/202017 2:25:11PM Page 4 COMPASS 5000.14 Build 85 • Final Definitive Survey Verified and Signed-off Alf targets and/or well position objectives have been achieved. Yes 7 No t have checked to the best of my ability that the following data is correct: _j Surface Coordinates 2] Declination & Convergence D GR5 Survey Corrections Digasily aped bvVincent Osara n Survey Tool Codes ats,SdaV i n e e n t "" •�us Osa ra rmaa=v+>x ` SLB DE: � Dote 2017.1120 14-3131-MD' Jamal C h e r r Digitally signed by Jamal Cherry Client RepresentativeY Date:2017.11.21 11:56:47-09'00' Gate 20-Nov-2017 • • 217136 RECEIVED 28 8 2 1 DEC 042017 AOGCC FINAL \ J ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H-114 ConocoPhillips Definitive Survey Report 20 November, 2017 NAD 83 ConocoPhillips • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1H-114 Project: Kuparuk River Unit TVD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1H-114 Survey Calculation Method: Minimum Curvature Design: 1H-114 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1H-114 Well Position +N/-S 0.00 usft Northing: 5,980,713.67 usft Latitude: 70°21'30.529 N +E/-W 0.00 usft Easting: 1,689,587.12 usft Longitude: 149°36'2.223 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usft Wellbore 1H-114 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BG G M 2017 11/20/2017 17.39 80.94 57,484 Design 1H-114 Audit Notes: , Version: 1.0 Phase: ACTUAL Tie On Depth: 38.84 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 38.84 0.00 0.00 53.27 Survey Program Date 11/20/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 115.00 588.00 1H-114 Srvy 1-HAL_Gyro(1H-114) GYD-GC-SS Sperry gyro single shots 11/6/2017 9:09:: 642.82 1,754.25 1 H-114 Srvy 2-SLB_MWD_GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/7/2017 9:11:t 1,818.43 1,818.43 1H-114 Srvy 3-SLB_MWD-Inc_Only_Fil MWD-INC_ONLY MWD-INC_ONLY_FILLER 11/9/2017 9:05:: 1,911.46 7,053.771H-114 Srvy 4-SLB_MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/9/2017 9:05:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 38.84 0.00 0.00 38.84 -54.10 0.00 0.00 5,980,713.67 1,689,587.12 0.00 0.00 UNDEFINED 115.00 0.30 353.84 115.00 22.06 0.20 -0.02 5,980,713.87 1,689,587.10 0.39 0.10 GYD-GC-SS(1) 212.00 0.53 38.44 212.00 119.06 0.80 0.23 5,980,714.48 1,689,587.35 0.39 0.66 GYD-GC-SS(1) 309.00 0.84 35.94 308.99 216.05 1.73 0.93 5,980,715.41 1,689,588.04 0.32 1.78 GYD-GC-SS(1) 401.00 0.90 47.71 400.98 308.04 2.76 1.86 5,980,716.45 1,689,588.96 0.20 3.14 GYD-GC-SS(1) 495.00 1.16 32.64 494.96 402.02 4.06 2.92 5,980,717.75 1,689,590.01 0.40 4.76 GYD-GC-SS(1) 588.00 1.18 70.15 587.95 495.01 5.18 4.32 5,980,718.88 1,689,591.41 0.81 6.56 GYD-GC-SS(1) 642.82 1.78 84.02 642.75 549.81 5.46 5.70 5,980,719.17 1,689,592.79 1.27 7.83 MWD+IFR-AK-CAZ-SC(2) 681.97 2.80 89.83 681.87 588.93 5.52 7.26 5,980,719.24 1,689,594.35 2.67 9.12 MWD+IFR-AK-CAZ-SC(2) 752.85 3.82 97.34 752.63 659.69 5.23 11.34 5,980,718.97 1,689,598.42 1.56 12.21 MWD+IFR-AK-CAZ-SC(2) 775.62 4.35 99.13 775.34 682.40 4.99 12.94 5,980,718.75 1,689,600.03 2.39 13.36 MWD+IFR-AK-CAZ-SC(2) 11/20/2017 1:13:11PM Page 2 COMPASS 5000.14 Build 85 III 4111 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 11-1-114 Project: Kuparuk River Unit TVD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1H-114 Survey Calculation Method: Minimum Curvature Design: 1H-114 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 870.15 7.89 103.45 869.32 776.38 2.91 22.79 5,980,716.74 1,689,609.89 3.77 20.01 MWD+IFR-AK-CAZ-SC(2) 964.27 11.97 106.42 962.01 869.07 -1.35 38.45 5,980,712.58 1,689,625.57 4.37 30.01 MWD+IFR-AK-CAZ-SC(2) 1,059.57 14.60 107.87 1,054.75 961.81 -7.83 59.36 5,980,706.23 1,689,646.53 2.78 42.89 MWD+IFR-AK-CAZ-SC(2) 1,153.75 14.74 108.68 1,145.86 1,052.92 -15.31 82.01 5,980,698.90 1,689,669.22 0.26 56.57 MWD+IFR-AK-CAZ-SC(2) 1,249.49 18.99 107.56 1,237.46 1,144.52 -23.91 108.41 5,980,690.47 1,689,695.68 4.45 72.58 MWD+IFR-AK-CAZ-SC(2) 1,343.44 21.86 104.92 1,325.50 1,232.56 -33.03 139.89 5,980,681.56 1,689,727.21 3.21 92.36 MWD+IFR-AK-CAZ-SC(2) 1,438.12 23.71 102.62 1,412.79 1,319.85 -41.73 175.50 5,980,673.10 1,689,762.88 2.17 115.70 MWD+IFR-AK-CAZ-SC(2) 1,532.29 25.06 101.27 1,498.55 1,405.61 -49.76 213.54 5,980,665.32 1,689,800.96 1.55 141.38 MWD+IFR-AK-CAZ-SC(2) 1,627.62 24.31 101.16 1,585.17 1,492.23 -57.51 252.59 5,980,657.83 1,689,840.06 0.79 168.05 MWD+IFR-AK-CAZ-SC(2) 1,720.86 25.22 99.85 1,669.84 1,576.90 -64.62 290.99 5,980,650.97 1,689,878.51 1.14 194.58 MWD+IFR-AK-CAZ-SC(2) 1,754.25 26.55 99.80 1,699.88 1,606.94 -67.11 305.36 5,980,648.58 1,689,892.88 3.98 204.60 MWD+IFR-AK-CAZ-SC(2) 1,818.43 27.46 97.75 1,757.06 1,664.12 -71.54 334.16 5,980,644.33 1,689,921.71 2.03 225.03 MWD-INC_ONLY(3) 1,830.00 27.87 97.54 1.767.31 1,674.37 -72.26 339.48 5,980,643.65 1,689,927.04 3.61 228.87 NOT an Actual Survey 103/4x13-112" 4 1,911.46 30.73 96.20 1,838.34 1,745.40 -77.01 379.05 5,980,639.16 1,689,966.63 3.61 257.74 MWD+IFR-AK-CAZ-SC(4) 2,006.44 35.82 92.56 1,917.73 1,824.79 -80.87 430.98 5,980,635.64 1,690,018.58 5.75 297.05 MWD+IFR-AK-CAZ-SC(4) 2,101.04 40.23 89.10 1,992.24 1,899.30 -81.63 489.22 5,980,635.27 1,690,076.82 5.18 343.27 MWD+IFR-AK-CAZ-SC(4) 2,196.79 44.00 88.40 2,063.26 1,970.32 -80.21 553.40 5,980,637.10 1,690,140.98 3.97 395.56 MWD+IFR-AK-CAZ-SC(4) 2,290.97 48.10 86.38 2,128.61 2,035.67 -77.09 621.11 5,980,640.67 1,690,208.67 4.62 451.70 MWD+IFR-AK-CAZ-SC(4) 2,385.73 52.37 84.57 2,189.21 2,096.27 -71.30 693.70 5,980,646.93 1,690,281.21 4.74 513.33 MWD+IFR-AK-CAZ-SC(4) 2,480.80 56.11 83.32 2,244.76 2,151.82 -63.15 770.40 5,980,655.59 1,690,357.84 4.08 579.68 MWD+IFR-AK-CAZ-SC(4) 2,575.28 59.84 82.99 2,294.85 2,201.91 -53.60 849.91 5,980,665.66 1,690,437.29 3.96 649.12 MWD+IFR-AK-CAZ-SC(4) 2,669.64 63.15 84.01 2,339.88 2,246.94 -44.23 932.29 5,980,675.57 1,690,519.59 3.63 720.75 MWD+IFR-AK-CAZ-SC(4) 2,764.81 64.64 83.52 2,381.75 2,288.81 -34.94 1,017.24 5,980,685.41 1,690,604.47 1.63 794.38 MWD+IFR-AK-CAZ-SC(4) 2,858.67 65.88 84.20 2,421.03 2,328.09 -25.83 1,102.00 5,980,695.08 1,690,689.16 1.48 867.76 MWD+IFR-AK-CAZ-SC(4) 2,954.28 67.97 81.07 2,458.51 2,365.57 -14.54 1,189.21 5,980,706.95 1,690,776.29 3.72 944.41 MWD+IFR-AK-CAZ-SC(4) 3,049.53 70.32 79.17 2,492.42 2,399.48 0.75 1,276.89 5,980,722.80 1,690,863.85 3.09 1,023.82 MWD+IFR-AK-CAZ-SC(4) 3,143.87 70.06 77,45 2,524.40 2,431.46 18.73 1,363.80 5,980,741.35 1,690,950.64 1.74 1,104.23 MWD+IFR-AK-CAZ-SC(4) 3,239.57 69.94 74.02 2,557.14 2,464.20 40.88 1,450.94 5,980,764.08 1,691,037.62 3.37 1,187.32 MWD+IFR-AK-CAZ-SC(4) 3,333.07 69.88 69.60 2,589.27 2,496.33 68.29 1,534.34 5,980,792.02 1,691,120.83 4.44 1,270.55 MWD+IFR-AK-CAZ-SC(4) 3,427.90 69.94 69.59 2,621.84 2,528.90 99.34 1,617.81 5,980,823.62 1,691,204.09 0.06 1,356.02 MWD+IFR-AK-CAZ-SC(4) 3,522.39 70.09 69.23 2,654.14 2,561.20 130.57 1,700,93 5,980,855.39 1,691,287.00 0.39 1,441.32 MWD+IFR-AK-CAZ-SC(4) 3,616.87 69.89 70.15 2,686.47 2,593.53 161.38 1,784.19 5,980,886.75 1,691,370.04 0.94 1,526.47 MWD+IFR-AK-CAZ-SC(4) 3,711.38 69.97 71.18 2,718.90 2,625.96 190.77 1,867.95 5,980,916.68 1,691,453.60 1.03 1,611.18 MWD+IFR-AK-CAZ-SC(4) 3,806.13 70.04 72.26 2,751.30 2,658.36 218.70 1,952.50 5,980,945.16 1,691,537.95 1.07 1,695.64 MWD+IFR-AK-CAZ-SC(4) 3,900.72 69.91 73.26 2,783.69 2,690.75 245.04 2,037.37 5,980,972.06 1,691,622.65 1.00 1,779.42 MWD+IFR-AK-CAZ-SC(4) 3,995.36 69.53 72.61 2,816.49 2,723.55 271.09 2,122.24 5,980,998.66 1,691,707.33 0.76 1,863.02 MWD+IFR-AK-CAZ-SC(4) 4,090.05 69.78 72.06 2,849.42 2,756.48 298.03 2,206.83 5,981,026.15 1,691,791.74 0.61 1,946.93 MWD+IFR-AK-CAZ-SC(4) 4,184.60 70.13 71.13 2,881.82 2,788.88 326.07 2,291.11 5,981,054.75 1,691,875.82 1.00 2,031.25 MWD+IFR-AK-CAZ-SC(4) 4,279.49 69.96 69.52 2,914.21 2,821.27 356.10 2,375.09 5,981,085.32 1,691,959.60 1.60 2,116.51 MWD+IFR-AK-CAZ-SC(4) 11/20/2017 1:13:11PM Page 3 COMPASS 5000.14 Build 85 • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 H-114 Project: Kuparuk River Unit TVD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-114 actual @ 92.94usft(Doyon 142) Well: 1H-114 North Reference: True Wellbore: 1H-114 Survey Calculation Method: Minimum Curvature Design: 1H-114 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,374.75 70.19 65.84 2,946.68 2,853.74 390.11 2.457 92 5,981,119.87 1,692,042.19 3.64 2,203.24 MWD+IFR-AK-CAZ-SC(4) 4,468.89 69.71 62.05 2,978.97 2,886.03 428.94 2,537.35 5,981,159.22 1,692,121.36 3.82 2,290.12 MWD+IFR-AK-CAZ-SC(4) 4,563.31 68.49 59.48 3,012.66 2,919.72 472.01 2,614.32 5,981,202.78 1,692,198.03 2.85 2,377.56 MWD+IFR-AK-CAZ-SC(4) 4,658.90 67.70 57.00 3,048.32 2,955.38 518.68 2,689.72 5,981,249.95 1,692,273.12 2.54 2,465.91 MWD+IFR-AK-CAZ-SC(4) 4,752.53 67.13 54.27 3,084.29 2,991.35 567.47 2,761.08 5,981,299.20 1,692,344.15 2.76 2,552.27 MWD+IFR-AK-CAZ-SC(4) 4,846.72 65.85 50.58 3,121.87 3,028.93 620.11 2,829.52 5,981,352.29 1592,412.24 3.84 2,638.61 MWD+IFR-AK-CAZ-SC(4) 4,941.55 63.98 47.27 3,162.08 3,069.14 676.52 2,894.27 5,981,409.11 1,692,476.60 3.73 2,724.23 MWD+IFR-AK-CAZ-SC(4) 5,035.90 62.94 44.96 3,204.24 3,111.30 735.02 2,955.10 5,981,468.00 1,692,537.05 2.45 2,807.97 MWD+IFR-AK-CAZ-SC(4) 5,130.83 62.14 42.01 3,248.03 3,155.09 796.12 3,013.06 5,981,529.47 1,692,594.60 2.88 2,890.97 MWD+IFR-AK-CAZ-SC(4) 5,224.94 61.93 37.58 3,292.17 3,199.23 859.96 3,066.25 5,981,593.66 1,692,647.36 4.16 2,971.78 MWD+IFR-AK-CAZ-SC(4) 5,319.30 61.24 33.54 3,337.09 3,244.15 927.45 3,114.50 5,981,661.45 1,692,695.17 3.84 3,050.81 MWD+IFR-AK-CAZ-SC(4) 5,414.84 61.82 32.36 3,382.63 3,289.69 997.92 3,160.18 5,981,732.22 1,692,740.38 1.24 3,129.57 MWD+IFR-AK-CAZ-SC(4) 5,509.84 63.65 28.41 3,426.17 3,333.23 1,070.76 3,202.86 5,981,805.33 1,692,782.57 4.17 3,207.33 MWD+IFR-AK-CAZ-SC(4) 5,604.44 62.90 24.03 3,468.73 3,375.79 1,146.53 3,240.19 5,981,881.33 1,692,819.40 4.21 3,282.56 MWD+IFR-AK-CAZ-SC(4) 5,627.65 62.74 23.72 3,479.33 3,386.39 1,165.41 3,248.55 5,981,900.27 1,692,827.63 1.37 3,300.55 MWD+IFR-AK-CAZ-SC(4) 5,699.33 66.03 22.86 3,510.31 3,417.37 1,224.77 3,274.09 5,981,959.79 1,692,852.78 4.72 3,356.53 MWD+IFR-AK-CAZ-SC(4) 5,721.59 66.99 22.30 3,519.19 3,426.25 1,243.62 3,281.93 5,981,978.69 1,692,860.50 4.89 3,374.08 MWD+IFR-AK-CAZ-SC(4) 5,793.80 64.56 20.17 3,548.81 3,455.87 1,304.98 3,305.79 5,982,040.20 1,692,883.95 4.31 3,429.90 MWD+IFR-AK-CAZ-SC(4) 5,888.74 62.34 15.07 3,591.27 3,498.33 1,385.87 3,331.52 5,982,121.25 1,692,909.15 5.34 3,498.90 MWD+IFR-AK-CAZ-SC(4) 5,983.39 61.88 9.17 3,635.58 3,542.64 1,467.61 3,349.08 5,982,203.10 1,692,926.17 5.53 3,561.86 MWD+IFR-AK-CAZ-SC(4) 6,051.96 61.78 5.07 3,667.96 3,575.02 1,527.58 3,356.57 5,982,263.10 1,692,933.27 5.27 3,603.72 MWD+IFR-AK-CAZ-SC(4) 6,078.33 61.79 3.73 3,680.43 3,587.49 1,550.74 3,358.35 5,982,286.28 1,692,934.90 4.48 3,619.01 MWD+IFR-AK-CAZ-SC(4) 6,173.22 64.02 0.92 3,723.65 3,630.71 1,635.13 3,361.76 5,982,370.68 1,692,937.75 3.53 3,672.21 MWD+IFR-AK-CAZ-SC(4) 6,268.53 65.38 0.27 3,764.38 3,671.44 1,721.29 3,362.65 5,982,456.84 1,692,938.07 1.55 3,724.45 MWD+IFR-AK-CAZ-SC(4) 6,362.99 64.52 359.60 3,804.38 3,711.44 1,806.87 3,362.56 5,982,542.40 1,692,937.42 1.11 3,775.55 MWD+IFR-AK-CAZ-SC(4) 6,456.87 64.65 359.22 3,844.67 3,751.73 1,891.66 3,361.68 5,982,627.17 1,692,935.99 0.39 3,825.56 MWD+IFR-AK-CAZ-SC(4) 6,551.61 64.70 359.28 3,885.19 3,792.25 1,977.28 3,360.56 5,982,712.78 1,692,934.30 0.08 3,875.87 MWD+IFR-AK-CAZ-SC(4) 6,645.12 64.74 358.31 3,925.12 3,832.18 2,061.82 3,358.78 5,982,797.30 1,692,931.97 0.94 3,925.00 MWD+IFR-AK-CAZ-SC(4) 6,741.28 64.67 358.11 3,966.21 3,873.27 2,148.72 3,356.07 5,982,884.17 1,692,928.69 0.20 3,974.79 MWD+IFR-AK-CAZ-SC(4) 6,835.04 64.77 359.11 4,006.25 3,913.31 2,233.47 3,354.01 5,982,968.90 1,692,926.07 0.97 4,023.83 MWD+IFR-AK-CAZ-SC(4) 6,930.30 64.53 1.00 4,047.04 3,954.10 2,319.55 3,354.09 5,983,054.97 1,692,925.59 1.81 4,075.38 MWD+IFR-AK-CAZ-SC(4) 7,023.44 64.96 1.47 4,086.78 3,993.84 2,403.77 3,355.91 5,983,139.19 1,692,926.85 0.65 4,127.20 MWD+IFR-AK-CAZ-SC(4) 7,053.77 64.82 1.21 4,099.65 4,006.71 2,431.23 3,356.55 5,983,166.64 1,692,927.31 0.90 4,144.13 MWD+IFR-AK-CAZ-SC(4) 7,110.60 64.82 1.21 4,123.83 4,030.89 2,482.65 3.357.64 5,983,218.06 1,692,928.06 0.00 4,175.75 NOT an Actual Survey _. 7"&111/4 .___ 7.121 00 64.82 1.21 4,128.25 4,035.31 2,492.05 3,357.84 5,983,227.47 1,692.928.20 0.00 4,181.54 PROJECTED to TD 11/20/2017 1:13:11PM Page 4 COMPASS 5000.14 Build 85 w • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. 17. Yes J No I have checked to the best of my ability that the following data is correct: Surface Coordinates Declination & Convergence C GRS Survey Corrections Vincent Digitally signed by Vincent Osara DN:cn=Vincent Osara. Survey Tool Codes o:5chwmberger, ou=5chlumberger, Osara email-vosara*slb.com c=US SLB DE: Date 2017.1120143131-W00' Jamal m a I C h err Digitally signed by Jamal Cherry Client Representative. Y Date:2017.11.21 11:56:47-09'00' Date: 20-Nov-2017 N • • M ,,— _i!`1" v•- �r•'`1 r- -o o z ca CO o _° c z o a_ — a, o L ,� 3 e-- N W�w N O +, Y� N O ? 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Loepp, Victoria T (DOA) From: Klem,Adam <Adam.Klem@conocophillips.com> Sent: Thursday, November 16, 2017 3:02 PM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]Re: KRU 1H-114 PTD 217-136 CBL Follow Up Flag: Follow up Flag Status: Flagged Thanks for the quick review and approval! From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, November 16,2017 2:35 PM To: Klem,Adam<Adam.Klem@conocophillips.com> Subject: [EXTERNAL]Re: KRU 1H-114 PTD 217-136 CBL Adam, Looks good.Approval is granted to proceed with perforating. Thanx, Victoria Sent from my iPhone On Nov 16,2017, at 1:22 PM, Klem,Adam<Adam.Klem@conocophillips.com>wrote: Victoria, Attached are the CBL,cement report and our analysis for the 7"casing cement job for 1H-114.Can you review and let us know if we have approval to proceed with our on rig perforating operation? Please let me know ASAP if you need anything else as any delays will result in rig delays. Thanks, Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1586 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com <1H-114 Cement Review.pptx> 1 • . 6. of Cement Detail Report it 1H-114 Cortoot]4ilritilhps htacln String: Production casing cement Job: DRILLING ORIGINAL, 11/5/2017 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production casing cement 11/15/2017 10:00 11/15/2017 12:21 1H-114 Comment Blow down top drive and rig up cement hose 1 line I T's etc.etc.Stage pumps up to 8 BPM, initial circulating pressure=584 PSI with a final circ pressure of 500 PSI. UP WT=173K and DWN WT=96K. Pumped 7,589 stks. Pump 40 BBL nut plug gauge pill at same rate surf/surf 4990 stks, Actual volume pumped= 518.6 bbls. Perform prejob safety meeting while continuing to circulate at slower rate of 5 BPM 304 PSI. 16% Ff0. UP wT= 188K, DWN WT=98K. 1108 stks pumped while waiting for SLB to stage up. Total volume pumped before cement job was 1565 bbls. Flush lines and PT SLB to 4K. (GOOD). Pump 30.8 BBLS mud push at 1-4 BPM due to weight challenges 50-235 PSI DPP. 6-15%F/O. Load btm plug and pump 116.2 BBLS 15.8 PPG cement @ 4.5 BPM ICP=216 FCP=89. Flush lines to the floor w/8 bbls of water. Load top plug and KO with 10 BBLS of fresh water displace with 9.0 PPG brine at 8 BPM. ICP=132 PSI FCP=1270 PSI. 24%F/O. reduce rate at 2,400 STKS to 3 BPM ICP 780 PSI, FCP 900 psi. 12%F/O. Bump plug at 2560 STKS. Full returns through out job. Pressure up to 1,400 PSI for 5 min. CIP= 12:21. Pressure test casing to 3,500 PSI chart same for 30 MIN. PT good. 39 STKS pressure up with 3.9 BBLS bled back. RD/BD TD. and all circ lines. RD Volant tool and bale extensions/elevators etc. LD landing joint. kick out GBR equipment. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Production casing cement 3,790.0 7,121.0 Yes 0.0 Yes Yes 0 Pump Inst(bbilm...Q Pump Final(bbil...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 5 4 900.0 1,400.0 Yes 10.00 No Tagged Depth(fBKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,983.0 Wireline Comment Blow down top drive and rig up cement hose 1 line I Ts etc.etc.Stage pumps up to 8 BPM, initial circulating pressure=584 PSI with a final circ pressure of 500 PSI. UP WT=173K and DWN WT=96K. Pumped 7,589 stks. Pump 40 BBL nut plug gauge pill at same rate surf/surf 4990 stks, Actual volume pumped= 518.6 bbls. Perform prejob safety meeting while continuing to circulate at slower rate of 5 BPM 304 PSI. 16% F/O. UP wT= 188K, DWN WT=98K. 1108 stks pumped while waiting for SLB to stage up. Total volume pumped before cement job was 1565 bbls. Flush lines and PT SLB to 4K. (GOOD). Pump 30.8 BBLS mud push at 1-4 BPM due to weight challenges 50-235 PSI DPP. 6-15% F/O. Load btm plug and pump 116.2 BBLS 15.8 PPG cement©4.5 BPM ICP=216 FCP=89. Flush lines to the floor w/8 bbls of water. Load top plug and KO with 10 BBLS of fresh water displace with 9.0 PPG brine at 8 BPM. ICP=132 PSI FCP=1270 PSI. 24%F/O. reduce rate at 2,400 STKS to 3 BPM ICP 780 PSI, FCP 900 psi. 12%F/O. Bump plug at 2560 STKS. Full returns through out job. Pressure up to 1,400 PSI for 5 min. CIP=12:21. Pressure test casing to 3,500 PSI chart same for 30 MIN. PT good. 39 STKS pressure up with 3.9 BBLS bled back. RD/BD TD. and all circ lines. RD Volant tool and bale extensions/elevators etc. LD landing joint. kick out GBR equipment. TOC confirmed by ELINE LOG on 11/16/2017.TOC 3786'. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 3,790.0 7,121.0 G 116.2 Yield(ft'Isack) Mix H2O Ratio(gal/sa... Free Water(%) Density(113/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.12 15.80 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.05 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.05 gal/sx Additive Type Concentration Conc Unit label Fluid Loss Control D255 0.5 %BWOC Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud push 2,949.0 3,790.0 MP 30.8 Yield(ft!sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lblga) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) lbs/bbl Additive Type Concentration Conc Unit label D031 • • 1n a E a U O 0 0 0 0 00 , > > > > > C i- F- 1- r- 0 03- in ;;-- i- b V o In c CO CO 1,- CO CO .- M M oi C7 M a000000 Cio -,...) cm_ 0 Co pCO CA r-- N CO et Is .- et CO CO CO CO O O LL E▪ o m Q N o F CO /) (0 C 4 m to Vi U O m S' Z O Q. F,W .y U CD C 0 �Q O 1 in LU to Z 0 O 10 v i., oo io 1`r° 0) 1n f0 A . b (z.") O elt GI i4 1 •1 10 61 14. r •1 CO 10 CO Na a a 4 P O $ a ° d a>, a !1. r 0 u Q Q Q 'i, \' \ 1\ as i o m r .r F o rn X d F I:4 ki e•'• s‘1411111111H114jgglli.' / - E ers a) _ ( { Vq o w Vrt00I ,, , C)a M M W N cO o I c-1 A 1 v U = ConocoPhillips 114114 Water Injector I (Wetted by Chary CDCD rl 1I/1.47 7• III I . i E. OC r 1 L $ V I 4 N o v 0., = 1 Col a. Z I O. a1 I - 0 o v_ .-i �. M rl b N N el ill N .t E ..e- _E ID a O I- �1__,,I T N>- O C a h co CU -o N ._ N E to O_ U x E 0 U o v E o 00 i-+Y OZD eL +-+ a`: O _ N t ++ O v U pA Q OL _Q a 4J 00 Z Q N .E CL cn Q. v' Q E a "a (0 O N E > � Q 7:5 '-' cL O i i 00 +a "a L O V `�= Q 0 s) Q M 0 cu L • v v o g co o o —'' 0 N c -o Q. C 4- 'N 0 �' _ O `° o awn 41 N r..i VO Ln U C7 CC cn a NO n Q) Q v Q -i (1) ONLn EO1U m vT vI N • 0 • Loepp, Victoria T (DOA) From: Klem,Adam <Adam.Klem@conocophillips.com> Sent: Thursday, November 16,2017 1:19 PM To: Loepp,Victoria T(DOA) Cc: Cherry,Jamal M Subject: KRU 1H-114 PTD 217-136 CBL Attachments: 1H-114 Cement Review.pptx;CPAI_1H-114_SCMT 500psi_16Nov17_FieldPrint.Pdf; Wellview Cement Report.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached are the CBL,cement report and our analysis for the 7"casing cement job for 1H-114.Can you review and let us know if we have approval to proceed with our on rig perforating operation? Please let me know ASAP if you need anything else as any delays will result in rig delays. Thanks, Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1586 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com 1 • OF T 4,i)I//j%s THE STATE Alaska Oil and Gas Conservation C® issl®n 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *h Main: 907.279.1433 o�ALASFax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-114 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-136 Surface Location: 259' FSL, 784' FEL, SEC. 28, T12N, R10E, UM Bottomhole Location: 2798' FSL, 2653' FEL, SEC. 27, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. 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. 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 4ith 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, al32F.C\„- Hollis S. French Chair DATED this 1 day of October, 2017. RECEIVED • STATE OF ALASKA • OCT 0 2 ?017 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL , , G 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG [T Service-Disp ❑ lc.Specify if well is proposed for: Drill ❑ Lateral 0 Stratigraphic Test ❑ Development-Oil 0 Service- Winj 0 Single Zone MI tY Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone t 1 Geothermal CI Shale Gas El2.Operator Name: 5. Bond: Blanket l Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 a KRU 1H-114 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 7,243' ' TVD: 4,182' . Kuparak River Field 4a. Location of Well(Governmental Section): 7. Property Designation: West Sak Oil Pool • Surface: 259'FSL&784'FEL,Sec 28,T12N,R10E, UM ADL25639 . Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: 1894'FSL&2655'FEL,Sec 27,T12N,R10E, UM 80-261 11/9/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2798'FSL&2653'FEL,Sec 27,T12N,R10E, UM 2560 acres • 2,481'to ADL025638 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 93.1' ` 15.Distance to Nearest Well Open Surface:x- 549,555.50' y- 5,980,961.86' Zone- 4 . GL/BF Elevation above MSL(ft): 54'.1 • to Same Pool: 5,855'to 1 B-102 16.Deviated wells: Kickoff depth: 460 feet - 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 70.02 degrees 1 Downhole: 1,790 psi • Surface: 1,391 psi • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 80' Surf Surf 119' 119' Existing 13-1/2" 10-3/4" 45.5# L-80 HYD563 1718' Surf Surf 1757' 1700' 627 sx 11.0 ppg,272 sx 15.8 ppg 8-3/4" 7" 26# L-80 -IYD563/TXF 7204' Surf Surf 7243' 4182' 358 sx 15.8 ppg Class G 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Hydraulic Fracture planned? Yes❑ No El 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program 7 Time v.Depth Plot Shallow Hazard Analysis - Diverter Sketch Seabed Report Drilling Fluid Program V 20 AAC 25.050 requirements � 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Jamal Cherry 3'G. Authorized Name: Chip Alvord Contact Email: jamal.m.cherrvRcop.com Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6028 Authorized Signature: �,.�� aot Date: 10(L (Lo 1'7 Commission Use Only Permit to Drill ,.„,, API Number: _ Permit Approval See cover letter for other Number: a,( - l34, 50- `Qa9- a3b$',/--00 -Oo Date: lo/illi requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan ,gas hydrates,or gas contained in shales: [+ Other: Q D p 1.e.6l f p o 3 5-o O p$I Sam les req'd: Yes No[l] Mud log req'd:Yes❑ No[' /}y}/-1 via✓ prC✓Cv1 1C r 1-2- 14°t v 25- 0� 2easures: Yes J No[, Directional svy req'd:Yes E 'No Spacing exception req'd: Yes❑ Nog Inclination-only svy req'd:Yes Ci No Post initial injection MIT req'd:Yes Q'No❑ agetif • APPROVED BY ', Approved by: /// COMMISSIONER THE COMMISSION Date: t O b It q lcIa/t` � Submit Form and /� Form to aot evised 5/2r 1 p rmit is va'd f r months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate 4/qIi/ RI • • Application for Permit to Drill,Well 1H-114 Saved:21-Sep-17 Sept 18,2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 FiLCEIVED Anchorage,Alaska 99501 OCT 0 2 Re: Application for Permit to Drill Well 1H-114,a West Sak Sand Injector � 17 Dear Commissioner: AO/ GCo( »' ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots injector well from the 1H pad. The expected spud date for this well is November 9th,2017. It is planned to use rig Doyon 142. / 1H-114 is planned to be a slant thru the West Sak sands.The surface section will be drilled with 13-1/2"bit and run 10- 3/4"casing to±1,757'MD/ 1,700'TVD. The production section will be drilled with 8-3/4"bit and run 7" casing to+/- +7,243'MD/4,182' TVD. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment,diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a) and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jamal Cherry at 265-6028 (jamal.m.cherry@cop.com) or Chip Alvord at 265-6120. Sincerely, A_ 6, a, Chip Alvord Drilling Manager • • Application for Permit to Drill Document Kuparuk Well 11-1-114anocciP, iMps Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as KRU 1H-114 Location Summary Requirements of 20 AAC 25.005(c2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 259'FSL&784'FEL,Sec 28,T12N,R10E,UM NGS Coordinates RKB Elevation 93.1'AMSL Northings: 5,980,961.86' Eastings: 549,555.50' Pad Elevation 54.1'AMSL Location at Top of 1894'FSL&2655'FEL,Sec 27,T12N,R10E,UM Productive Interval (West Sak D Sand) NGS Coordinates Measured Depth,RKB: 6,249' Northings: 5,982,620.08' Eastings:552,949.34' Total Vertical Depth,RKB: 3,762' Total Vertical Depth,SS: 3,669' Location at Total Depth 2798'FSL&2653'FEL,Sec 27,T12N,R10E,UM NGS Coordinates Measured Depth,RKB: 7,243' Northings: 5,983,524.31' Eastings:552,943.40' Total Vertical Depth,RKB: 4,182' Total Vertical Depth,SS: 4,089' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(0(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142 and attachment. • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP)while drilling 1H-114 is calculated using an estimated maximum reservoir pressure of 1,590 psi(based on 1H-105 MDT pressure of 1749 psi, 8.6 ppg I equivalent, and corrected to depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A2 sand at 3,995' TVD: A Sand Estimated. BHP = 1,790 psi A Sand estimated depth =3,994' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 399 psi (3,994' TVD * 0.10 psi/ft) MPSP=BHP—gas column = 1,391 psi (1,790 psi—399 psi) (B)data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 1H-114 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(); A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) • An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg OD Hole Weight Length Top MD/TVD Btm MD/TVD (in) Size (Ib/ft) Grade Conn. A (/t) ()t) Cement Program (in) 20 42 94 H-40 Welded 80 Surf 119/119 Existing Cement to Surface with 10-3/4 13-1/2 45.5 L-80 HYD563 1,718 Surf 1,757/1,700 627 sx LiteCRETE Lead 11.0 ppg, 272 sx UniSLURRY Tail 15.8 ppg 7 8-3/4 26 L-80 HYD563/ 7 204 Surf 7,243/4,182 358 sx Class G at 15.8ppg TXP w/TOC at 5,352'MD 10-3/4"Surface casing run to 1,757'MID/1,700'TVD Cement from 1,757'MD to 1,257'(500'of tail)with 15.8 ppg UniSLURRY,and from 1,257'to surface with 11 ppg LiteCRETE. Assume 150%excess annular volume for lead and 50%excess for tail,and 0%excess in 20"conductor. • • Lead slurry from 1,257'MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119'—0')x 1.364 ft3/ft x 1.0(0%excess)=162 ft3 Bottom of Lead to Conductor (1,257'—119')x 0.3637 ft3/ft x 2.50(150%excess)=1,035 ft3 Total Volume=162+1,035=1,197 ft3=>627 sx of 11 ppg LiteCRETE @ 1.91 ft3/sk Tail slurry from 1,757'MD to 1,257'MD with 15.8 ppg UniSLURRY Shoe to Top of Tail (1,757'—1,257')x 0.3637 ft3/ft x 1.50(50%excess) =273 ft3 Shoe Joint (80')x 0.5400 ft3/ft x 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=>272 sx of 15.8 ppg UniSLURRY @ 1.16 ft3/sk 7"Production casing run to 7,243'MD 14,182'TVD Single stage slurry is designed to be placed from TD to 5,352'MD,which is 250'TVD above top of West Sak Pool (base of Ugnu);40%excess annular volume. Slurry from 7,243'MD to 5,352'MD with 15.8ppg Class G+additives Shoe to Top of Cement (7,243'—5,352')X 0.1503 ft3/ft X 1.40(40%excess) =398 ft3 Shoe Joint (80')X 0.2148 ft3/ft X 1.0(0%excess) =17 ft3 Total Volume=398+ 17=415 ft3=>358 sx of 15.8 ppg Class G @ 1.16 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic attached. f Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; • • Mud Program Summary Surface Production 13-1/2"Hole 8-3/4"Hole 10-3/4"Casing 7"Casing Mud System Spud LSND (WBM) (WBM) Density 8.8-9.5 9.0-10.0 PV ALAP ALAP YP 30-80 20-30 250—300 Funnel Viscosity Permafrost Base 100-150 to TD N/A Initial Gel 30-50 9- 11 10-minute Gel 30-50 <20 API Filtrate NC <6 HTHP Fluid Loss at 160°F N/A < 10 pH 10.8-11.2 9.5- 10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A -Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: i • The proposed drilling program is included below. Please refer to attachment for proposed well schematic. 1. Move in/rig up Doyon Rig 142. Install Annular with 16"diverter line and function test. Notify AOGCC 24 hrs before test. 2. Spud and directionally drill 13.5"hole to surface TD at+/- 1,757'MD/1,700'TVD as per directional plan. Run MWD tools and required for directional monitoring(gamma ray,resistivity)./ 3. Run and cement 10.75",45.5#,L80,HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug.Notify AOGCC if top job is required. 4. Remove diverter system and install wellhead. Install and test 13-5/8"x 5,000 psi BOP's to 250 psi low and 3,500 psi high(annular preventer to 3,500 psi). Notify AOGCC 24 hrs before test. 5. PU 8.75"bit and 6.75"drilling assembly,with MWD/LWD(gamma ray and resistivity).RIH,clean out cement to top of float equipment and test casing to 3,000 psi for 30 min. 6. Drill out cement and between 20' of new hole.Perform leak off test to a minimum of 11.5ppg EMW LOT/FIT, -► recording results. 7. Displace to 9.2 ppg LSND water-based drilling fluid. 8. Directionally drill to production TD at 7,243'MD/4,182'TVD. 9. Circulate hole clean. POOH. 10. Run 7",26#,L80,HYD563/TXP casing to surface.(Top of cement to be 5,352'MD/3,356'TVD which corresponds to 250'TVD above top of the West Sak Pool.) 11. Install 7"packoff and test to 3,500 psi. 12. Flush 10.75"x 7"annulus with water,followed by isotherm. 13. Pressure test production casing to 3,500 psi for 30 mm . h G j rc S v/f5 14. Run CBL on wireline. Atof7{f 40 CG of GQL rz$vlf5 15. RIH with TCPs and perforate zones. 16. Close annular and reverse circulate perforations(circulate out gas from perf guns any potential hydrocarbons). 17. Make clean out run if needed. 18. Run 3.5"upper completions with packers and gauges. 19. Land hanger,run in lock screws,and test seals to 5,000 psi. 20. Set BPV and test in the direction of flow. 21. Nipple down BOPE,nipple up tree and test.Pull BPV. 22. Freeze protect 3.5"x 7"annulus(if the schedule and equipment availability allows,the Wells Group will freeze protect the well post rig). 23. Set BPV,test in the direction of flow and move off rig. • • Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during tile drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DS 1B CRI)or Prudhoe DS-4.((All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Diverter Layout Diagram Attachment 6 BOP Configuration • • Attachment 1 AOR An Area of Review plot is shown below of the 1H-114 planned wellpath and offset wells. The included table identifies any of the offset wellbores within the'/4-mile review. ,a .September 22p,7 1 H-114wp22.1r' ZIA Quarter Mile View 8000— - 1 H-102 6000—____ in.JO_w 1H-418 114_101 1K-102_�Z8 --ill-1021A i � L00 ` S CJ ,� 0 0 N f . jy°s I000__ i x ry 407v -2000—.--- N -4000 -2000 0 2000 4000 6000 8000 10000 12000 Wet(-)'Fast(+) (2000 usft/in) Top of West TOC Well TOC Reservoir Cement Operations Status Sak D Sand Determined Zonal Isolation Name (MD/TVD) (MD/TVD) By Status Summary 1 H-114 Proposed 6,249'/3,762' 5,352'/3,356' CBL Not Yet Drilled Column of cement to be 250' Well does not exist yet Injector TVD above pool top. 1H-101 Proposed Not Yet Drilled N/A Not Yet Drilled Column of cement to be 250' Well does not exist yet Producer TVD above pool top. 1H-102 Proposed Not Yet Drilled N/A Not Yet Drilled Column of cement to be 250' Well does not exist yet Producer TVD above pool top. Intersects West Column of cement is 1H-118 Proposed 7 244'/3,674' 3,160'/2,502' CBL Sak sands:A,B, 1,172'TVD(4,084'MD) Lead:215 sxs @ 14 ppg Injector C and D above West Sak D sand. Tail:330 sxs @ 15.8 ppg • • 1H-105 Proposed Not Yet Drilled CBL Not Yet Drilled Column of cement to be 250' Well does not exist yet Injector TVD above pool top. Kuparuk and Cement plugs placed in OH: Cement plugs as follows: West Sak •Plug#1:9,825'-10,890' •Plug#1:225 sxs,"G"@ P&A'd. (Kuparuk) 15.8 ppg Original •Plug#2:5,100'MD-5,700' •Plug#2:290 sxs,"G"@ wellbore was MD(West Sak D-A2) 15.8 ppg sidetracked •Plug#3:3,979'-4,590' •Plug#3:260 sxs,"G"@ outside surface (Ugnu C) 15.8 ppg(tagged) casing(1H- •Plug#4:2,550'-2,715' •Plug#4:240 sxs,"Artic 1H-05 P&A'd 5,242'/3,715' OH through OH through 105). Cement (below surf shoe&K- Set II"@ 15.7 ppg(tagged) reservoir. reservoir. plugs in OH markers) •Plug#5:250 sxs,"Artic abandoned •Plug#5:2,200-2,545(into Set I"@ 15.7 ppg(tagged) wellbore surface casing,but drilled out isolating with sidetrack operations). hydrocarbon zones(both Kuparuk and West Sak formations). 8:32,August 11 2017 • cul 1 H-114wp22. 1 6.154 Plan Summary `T-;K-15 • 5- , , UG_(UCUGNa WS D� 0 0 12 1 } o o m 000S1 co - i1 �° PFROST S rho "'_ SOS p' 11 N W Vv BASE 20"x 42' 10-3/4"x 13-1/2' 3000 4500 6000 . 7"x 8-3/49C'' ' Measured Depth �'��,„,,,v,......,.......ir o �logPlan:54.1+39 @ 93.10usft(Doyon 142) • L � 0 U ' a) 2 3 I . `:0 ^O O gy _ ir 1 1 1 1 1 1 1 n\ l 1 1 1 1 l 1 1 1 1 l I.I1 1 1 1 1 1 I I I, I 0 1 0 700 1400 2100 2800 3500 4200 cc'49001 t Oso- 650 20"x 42' 10-3/4"x 13-1/2' 11 ti 30 650- 840 Horizontal Departure 7"x 8-3/4' Err" ��tom.. T1s 840- 1030 017 1 ll II 1 11' I Ill, 11 �,`\ 1220- 1420 1- IIIIlliili II IiIII IP�I�"� Mil l 1 °OIL.I II��I��1111111 lul Pv p' 300 �lr1420- 1610 i:: Nlll nIII IIIU,, NIIuI I,IIII II I" I' 1800,1rI, c��'!7 11u III 111! �� 11 2030 III 2250p IIIdIII •iq��l :dI111��1��11 �I�'�nlll��ll 1 ft v�... ,t, yt, 2250'f1 ' e, '' I! V 2480- 2700 .9.. �(I� IIII 11III�I;IIII��IU 270�„ :90 2700- 2930 d 1111111 Ilp III 111 !' ! o 02I ilii,•-$( 2930- 3150 !lIlllI!!! III1 ,„:„.,41,. L,, I. 1�,111 3150'�"'- 3380 ci 20 Equivalent Magnetic Distance i ;� ' 1 11r 3360- 3600 y..1��d4,,e "'�R�1� /„ ,\,i \\ 1, 3000- 3000 0 1000 2000 3000 4000 5000 6000 700011'111��11�;1�A#,'� Milli 1iII"`ItJh '.00xwp21 4060 4510 �ieiq�ti4.. * 14 ;� Ir }'.' •_4..► �1 /J 4510- 3070 Measured Depth X11 irl�y�',r 3070- 5320 SURVEY PROGRAM Surface Location !�\' } /7, 5420- 5880 North/Y: Depth From Depth To Survey/Ran Tool 210 `41, 150 5880 6330 39.00 800.00 1H-114wp22.1 (Plan: GYD-GC-SS East/ ,' -',4t 2 6330 """"' 6790 800.00 1756.87 1H-114) 1H-114wp22.1 MWD Pad Elevation: 54.10 6790- 7243 800.00 1756.87 (Plan: 1H-114) MWD+IFR-AK-CAZ-SC TVD MD Name 180 1756.87 3256.87 1H-114wp22.1 (Plan: MWD 118.10 118.10 20"x 42" 1756.87 7243.00 1H-114) 1H-114wp22.1 MWD,IFR-AK-CAZ-SC 1700.00 1756.87 10-3/4"x 13-1/2" (Plan: la114wp22.1 1(Plan) 1161 .91 7243.00 7"x 6-3/4" Magnetic Model&Date: BGGM2017 15-Dec-17 1H-114) Magnetic North is 17.35°East of True North(Magnetic Declination) Magnetic Dip&Field Strength: 80.94° 57481.96nT OCL,I IL/IV UC IAIIO Lithology Column Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 460.00 0.00 0.00 460.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.51100'DLS,110°TF,for 140.03' 3 600.03 2.10 110.00 600.00 -0.88 2.41 1.50 110.00 -0.88 Start 2.51100'DLS,-5°TF,for 301.8' 1626.5 4 901.83 9.64 106.08 900.00 -9.78 31.93 2.50 -5.00 -9.78 Adjust TF to-11°,for 703.95' PFROST 5 1605.78 27.12 98.81 1565.52 -51.01 248.83 2.50 -11.00 -51.01 Hold for 151.09' 1793.3 6 1756.87 27.12 98.81 1700.00 -61.56 316.90 0.00 0.00 -61.56 Adjust TF to 0°,for 20' T-3 7 1776.87 27.12 98.81 1717.80 -62.96 325.91 0.00 0.00 -62.96 Start 4"/100'DLS,-20°TF,for 974.18' 8 2751.05 65.00 85.08 2383.02 -58.97 1011.81 4.00 -20.00 -58.97 Adjust TF to-69.36°,for 318.76' 2622.5 9 3069.81 70.02 72.39 2505.35 -1.02 1299.68 4.00 -69.36 -1.02 Hold for 1281A' 10 4351.21 70.02 72.39 2943.19 363.38 2447.50 0.00 0.00 363.38 Start 3.51100'DLS,-109.36°TF,for 1893.94' 1 1 6245.16 65.00 0.00 3760.20 1636.17 3405.02 3.50 -109.36 1636.17 1H-116 01.D 052115 RW Hold for 547.85' 12 6793.00 65.00 0.00 3991.73 2132.69 3405.02 0.00 0.00 2132.69 Adjust TF to 0°,for 450' 13 7243.00 65.00 0.00 4181.91 2540.52 3405.02 0.00 0.00 2540.52 TD:7243'MD,4181.91'TVD K-15 3089.3 UG_C 3320.1 UG B 9002.6 - UG A 3606.6 - Na :11,k_11 ]8 390 S A2 ao 1 n] I By signing this I acknowledge that I have been informed of all risks,checked that the I )"' ; I , `I data is correct,ensured it's completeness,and all surrounding wells are assigned to 2the proper position,and I approve the scan and collision avoidance plan as set out in Orientation the audit pack.)approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that unless notified otherwise all targets have a 100 feet lateral 'repared by Chd@I&n69: 4ccepted by Approved by: S. DeLapp Huy Bui Anh Erik Sterk J. Cherry • • 0 5 43 70 a • • 111111111111111111 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I LIM al) _ I) 01111 -IV- -Q _3 —;:l -0 O -3 ON V ■ M 3 a CON NMC. 7- 0 4- ti } O -T Ze- U F\,-- z cv,_i --,qr0 —a N ON N = CD O LO -3O- . CCS rix + a W —.0 N� ° N 3 rT«_ r O. T 3 — O \o VIII _ N - r ®Ili ki‘ 111‘ 1 1 v- _ .\.,.4k1 ifilii Plil': I - _ AI1t4co 90 ± e .. . '‘111W al"11111. ,- r rt COJ 7 - , , , , ,1 1 1 1 1 , 1 1 I I I ni N (ul�l}sn 00g I.) 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Plan: 1H-114 (formerly 30B, 116) 50103xxxxx00 Plan: 1H-114 Plan: 1 H-114wp22.1 Standard Proposal Report 11 August, 2017 u a. Aja I. z ConocoPhillips 9 • ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:1H-114(formerly 30B,116) Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan:1H-114(formerly 30B,116) Survey Calculation Method: Minimum Curvature Wellbore: Plan:1H-114 Design: 1H-114wp22.1 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37° Well Plan:1H-114(formerly 30B,116) Well Position +N/-S 990.79 usft Northing: Latitude: +E/-W 364.84 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan:1H-114 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2017 12/15/2017 17.35 80.94 57,481.96 Design 1 H-114wp22.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 0.00 Plan Survey Tool Program Date 8/11/2017 Depth From Depth To (usft) (usft) Survey(Wellbore) Tool Name Remarks 1 39.00 800.00 1H-114wp22.1 (Plan:1H-114) GYD-GC-SS Gyrodata gyro single shots 2 800.00 1,756.87 1H-114wp22.1 (Plan:1H-114) MWD MWD-Standard 3 800.00 1,756.87 1H-114wp22.1 (Plan:1H-114) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,756.87 3,256.87 1H-114wp22.1 (Plan:1H-114) MWD MWD-Standard 5 1,756.87 7,243.00 1H-114wp22.1 (Plan:1H-114) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/11/2017 8:39:21AM Page 2 COMPASS 5000.14 Build 85 • • ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:1H-114(formerly 308,116) Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan:1H-114(formerly 30B,116) Survey Calculation Method: Minimum Curvature Wellbore: Plan:1H-114 Design: 1 H-114wp22.1 Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (0) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 460.00 0.00 0.00 460.00 0.00 0.00 0.00 0.00 0.00 0.00 600.03 2.10 110.00 600.00 -0.88 2.41 1.50 1.50 0.00 110.00 901.83 9.64 106.08 900.00 -9.78 31.93 2.50 2.50 -1.30 -5.00 1,605.78 27.12 98.81 1,565.52 -51.01 248.83 2.50 2.48 -1.03 -11.00 1,756.87 27.12 98.81 1,700.00 -61.56 316.90 0.00 0.00 0.00 0.00 1,776.87 27.12 98.81 1,717.80 -62.96 325.91 0.00 0.00 0.00 0.00 2,751.05 65.00 85.08 2,383.02 -58.97 1,011.81 4.00 3.89 -1.41 -20.00 3,069.81 70.02 72.39 2,505.35 -1.02 1,299.68 4.00 1.57 -3.98 -69.36 4,351.21 70.02 72.39 2,943.19 363.38 2,447.50 0.00 0.00 0.00 0.00 6,245.16 65.00 0.00 3,760.20 1,636.17 3,405.02 3.50 -0.27 -3.82 -109.36 1H-116 01.D 052115 I 6,793.00 65.00 0.00 3,991.73 2,132.69 3,405.02 0.00 0.00 0.00 0.00 7,243.00 65.00 0.00 4,181.91 2,540.52 3,405.02 0.00 0.00 0.00 0.00 8/11/2017 8:39:21AM Page 3 COMPASS 5000.14 Build 85 >r- 0 • ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:1H-114(formerly 30B,116) Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan:1H-114(formerly 30B,116) Survey Calculation Method: Minimum Curvature Wellbore: Plan:1H-114 Design: 1H-114wp22.1 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 118.10 0.00 0.00 118.10 0.00 0.00 0.00 0.00 0.00 0.00 20"x 42" 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 460.00 0.00 0.00 460.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.60 110.00 500.00 -0.07 0.20 -0.07 1.50 1.50 0.00 600.00 2.10 110.00 599.97 -0.88 2.41 -0.88 1.50 1.50 0.00 600.03 2.10 110.00 600.00 -0.88 2.41 -0.88 1.50 1.50 0.00 700.00 4.60 107.28 699.79 -2.69 7.96 -2.69 2.50 2.50 -2.72 800.00 7.09 106.47 799.26 -5.64 17.71 -5.64 2.50 2.50 -0.81 900.00 9.59 106.09 898.20 -9.70 31.64 -9.70 2.50 2.50 -0.39 901.83 9.64 106.08 900.00 -9.78 31.93 -9.78 2.50 2.50 -0.29 1,000.00 12.06 103.84 996.41 -14.51 49.79 -14.51 2.50 2.46 -2.28 1,100.00 14.53 102.32 1,093.72 -19.69 72.19 -19.69 2.50 2.48 -1.52 1,200.00 17.02 101.23 1,189.95 -25.21 98.80 -25.21 2.50 2.48 -1.09 1,300.00 19.50 100.41 1,284.91 -31.08 129.58 -31.08 2.50 2.49 -0.82 1,400.00 21.99 99.77 1,378.41 -37.27 164.45 -37.27 2.50 2.49 -0.64 1,500.00 24.48 99.26 1,470.29 -43.79 203.36 -43.79 2.50 2.49 -0.51 1,600.00 26.98 98.83 1,560.37 -50.61 246.23 -50.61 2.50 2.49 -0.42 1,605.78 27.12 98.81 1,565.52 -51.01 248.83 -51.01 2.50 2.49 -0.39 1,700.00 27.12 98.81 1,649.38 -57.59 291.28 -57.59 0.00 0.00 0.00 1,756.87 27.12 98.81 1,700.00 -61.56 316.90 -61.56 0.00 0.00 0.00 10-3/4"x 13-1/2" 1,776.87 27.12 98.81 1,717.80 -62.96 325.91 -62.96 0.00 0.00 0.00 1,800.00 27.99 98.14 1,738.30 -64.53 336.49 -64.53 4.00 3.77 -2.91 1,900.00 31.79 95.62 1,824.99 -70.43 385.96 -70.43 4.00 3.80 -2.52 2,000.00 35.63 93.58 1,908.16 -74.83 441.26 -74.83 4.00 3.84 -2.03 2,100.00 39.50 91.90 1,987.42 -77.71 502.14 -77.71 4.00 3.87 -1.68 2,200.00 43.38 90.48 2,062.37 -79.05 568.29 -79.05 4.00 3.89 -1.43 2,300.00 47.29 89.24 2,132.66 -78.85 639.40 -78.85 4.00 3.90 -1.23 2,400.00 51.20 88.15 2,197.93 -77.11 715.11 -77.11 4.00 3.91 -1.09 2,500.00 55.12 87.18 2,257.88 -73.83 795.06 -73.83 4.00 3.92 -0.97 2,600.00 59.05 86.29 2,312.20 -69.03 878.85 -69.03 4.00 3.93 -0.89 2,700.00 62.99 85.48 2,360.64 -62.75 966.09 -62.75 4.00 3.94 -0.82 2,751.05 65.00 85.08 2,383.02 -58.97 1,011.81 -58.97 4.00 3.94 -0.77 2,800.00 65.70 83.07 2,403.44 -54.38 1,056.06 -54.38 4.00 1.44 -4.11 2,900.00 67.22 79.03 2,443.39 -40.10 1,146.59 -40.10 4.00 1.52 -4.04 3,000.00 68.84 75.09 2,480.81 -19.33 1,236.95 -19.33 4.00 1.62 -3.95 3,069.81 70.02 72.39 2,505.35 -1.02 1,299.68 -1.02 4.00 1.69 -3.87 3,100.00 70.02 72.39 2,515.66 7.56 1,326.72 7.56 0.00 0.00 0.00 3,200.00 70.02 72.39 2,549.83 36.00 1,416.30 36.00 0.00 0.00 0.00 3,300.00 70.02 72.39 2,584.00 64.44 1,505.87 64.44 0.00 0.00 0.00 3,400.00 70.02 72.39 2,618.17 92.88 1,595.45 92.88 0.00 0.00 0.00 3,500.00 70.02 72.39 2,652.34 121.31 1,685.02 121.31 0.00 0.00 0.00 3,600.00 70.02 72.39 2,686.51 149.75 1,774.60 149.75 0.00 0.00 0.00 3,700.00 70.02 72.39 2,720.67 178.19 1,864.18 178.19 0.00 0.00 0.00 3,800.00 70.02 72.39 2,754.84 206.63 1,953.75 206.63 0.00 0.00 0.00 3,900.00 70.02 72.39 2,789.01 235.07 2,043.33 235.07 0.00 0.00 0.00 4,000.00 70.02 72.39 2,823.18 263.50 2,132.90 263.50 0.00 0.00 0.00 4,100.00 70.02 72.39 2,857.35 291.94 2,222.48 291.94 0.00 0.00 0.00 4,200.00 70.02 72.39 2,891.52 320.38 2,312.05 320.38 0.00 0.00 0.00 8/11/2017 8:39:21AM Page 4 COMPASS 5000.14 Build 85 • • ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:1H-114(formerly 30B,116) Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan:1H-114(formerly 30B,116) Survey Calculation Method: Minimum Curvature Wellbore: Plan:1H-114 Design: 1 H-114wp22.1 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 4,300.00 70.02 72.39 2,925.69 348.82 2,401.63 348.82 0.00 0.00 0.00 4,351.21 70.02 72.39 2,943.19 363.38 2,447.50 363.38 0.00 0.00 0.00 4,400.00 69.46 70.67 2,960.08 377.88 2,490.91 377.88 3.50 -1.14 -3.53 4,500.00 68.37 67.10 2,996.06 411.48 2,577.94 411.48 3.50 -1.09 -3.57 4,600.00 67.36 63.48 3,033.75 450.18 2,662.07 450.18 3.50 -1.01 -3.62 4,700.00 66.43 59.82 3,073.00 493.84 2,743.01 493.84 3.50 -0.93 -3.67 4,800.00 65.59 56.10 3,113.67 542.29 2,820.44 542.29 3.50 -0.84 -3.72 4,900.00 64.84 52.33 3,155.60 595.36 2,894.07 595.36 3.50 -0.75 -3.77 5,000.00 64.19 48.52 3,198.64 652.85 2,963.64 652.85 3.50 -0.65 -3.81 5,100.00 63.63 44.67 3,242.64 714.53 3,028.88 714.53 3.50 -0.55 -3.85 5,200.00 63.18 40.79 3,287.41 780.19 3,089.55 780.19 3.50 -0.45 -3.88 5,300.00 62.84 36.88 3,332.81 849.58 3,145.41 849.58 3.50 -0.34 -3.91 5,400.00 62.60 32.95 3,378.66 922.44 3,196.28 922.44 3.50 -0.23 -3.93 5,500.00 62.48 29.01 3,424.78 998.49 3,241.95 998.49 3.50 -0.12 -3.94 5,600.00 62.47 25.06 3,471.01 1,077.45 3,282.25 1,077.45 3.50 -0.01 -3.95 5,700.00 62.57 21.12 3,517.17 1,159.04 3,317.03 1,159.04 3.50 0.10 -3.94 5,800.00 62.78 17.19 3,563.10 1,242.94 3,346.17 1,242.94 3.50 0.21 -3.93 5,900.00 63.09 13.27 3,608.61 1,328.83 3,369.56 1,328.83 3.50 0.32 -3.91 6,000.00 63.52 9.39 3,653.54 1,416.41 3,387.10 1,416.41 3.50 0.43 -3.89 6,100.00 64.05 5.53 3,697.73 1,505.35 3,398.73 1,505.35 3.50 0.53 -3.86 6,200.00 64.68 1.71 3,741.00 1,595.30 3,404.41 1,595.30 3.50 0.63 -3.82 6,245.16 65.00 0.00 3,760.20 1,636.17 3,405.02 1,636.17 3.50 0.70 -3.79 6,300.00 65.00 0.00 3,783.38 1,685.87 3,405.02 1,685.87 0.00 0.00 0.00 6,400.00 65.00 0.00 3,825.64 1,776.51 3,405.02 1,776.51 0.00 0.00 0.00 6,500.00 65.00 0.00 3,867.90 1,867.14 3,405.02 1,867.14 0.00 0.00 0.00 6,600.00 65.00 0.00 3,910.16 1,957.77 3,405.02 1,957.77 0.00 0.00 0.00 6,700.00 65.00 0.00 3,952.43 2,048.40 3,405.02 2,048.40 0.00 0.00 0.00 6,793.00 65.00 0.00 3,991.73 2,132.69 3,405.02 2,132.69 0.00 0.00 0.00 6,800.00 65.00 0.00 3,994.69 2,139.03 3,405.02 2,139.03 0.00 0.00 0.00 6,900.00 65.00 0.00 4,036.95 2,229.66 3,405.02 2,229.66 0.00 0.00 0.00 7,000.00 65.00 0.00 4,079.21 2,320.29 3,405.02 2,320.29 0.00 0.00 0.00 7,100.00 65.00 0.00 4,121.47 2,410.92 3,405.02 2,410.92 0.00 0.00 0.00 7,200.00 65.00 0.00 4,163.73 2,501.55 3,405.02 2,501.55 0.00 0.00 0.00 7,243.00 65.00 0.00 4,181.91 2,540.52 3,405.02 2,540.52 0.00 0.00 0.00 7"x 8-3/4" Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape C) r) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1H-116 01.0 052115 RN 0.00 0.00 3,760.20 1,636.17 3,405.02 -plan hits target center -Circle(radius 1,320.00) 8/11/2017 8:39:21AM Page 5 COMPASS 5000.14 Build 85 • • ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan.1H-114(formerly 30B,116) Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan:1H-114(formerly 30B,116) Survey Calculation Method: Minimum Curvature Wellbore: Plan:1H-114 Design: 1H-114wp22.1 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name I") (") 118.10 118.10 20"x 42" 20 42 1,756.87 1,700.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 7,243.00 4,181.91 7"x 8-3/4" 7 8-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,674.33 1,626.53 PFROST 1,863.05 1,793.34 T-3 2,146.02 2,022.46 K-15 4,725.77 3,083.35 UG_C 5,272.19 3,320.13 UG_B 5,538.58 3,442.61 UG_A 5,895.46 3,606.55 Na 6,249.14 3,761.89 WS_D 6,370.41 3,813.13 WS_C 6,416.76 3,832.72 WS_B 6,496.13 3,866.27 WS_A4 6,600.77 3,910.49 WS_A3 6,797.27 3,993.54 WS_A2 7,036.50 4,094.64 WS_A1 7,224.46 4,174.07 BASE Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 460.00 460.00 0.00 0.00 KOP:Start 1.5°/100'DLS,110°TF,for 140.03' 600.03 600.00 -0.88 2.41 Start 2.5°/100'DLS,-5°TF,for 301.8' 901.83 900.00 -9.78 31.93 Adjust TF to-11°,for 703.95' 1,605.78 1,565.52 -51.01 248.83 Hold for 151.09' 1,756.87 1,700.00 -61.56 316.90 Adjust TF to 0°,for 20' 1,776.87 1,717.80 -62.96 325.91 Start 4°/100'DLS,-20°TF,for 974.18' 2,751.05 2,383.02 -58.97 1,011.81 Adjust TF to-69.36°,for 318.76' 3,069.81 2,505.35 -1.02 1,299.68 Hold for 1281.4' 4,351.21 2,943.19 363.38 2,447.50 Start 3.5°/100'DLS,-109.36°TF,for 1893.94' 6,245.16 3,760.20 1,636.17 3,405.02 Hold for 547.85' 6,793.00 3,991.73 2,132.69 3,405.02 Adjust TF to 0°,for 450' 7,243.00 4,181.91 2,540.52 3,405.02 TD:7243'MD,4181.91'TVD 8/11/2017 8:39:21AM Page 6 COMPASS 5000.14 Build 85 AC Summary 0 I a. 1111111111111111111 IIIIIIIIIIIII •MC 0 0 C V if. a N ss, E c 1 N C • r O U C 7N f6 N co N w O U C N O ^ ` d _a O CIS W d m o s + O co • O d N w 0 0 £ I 3 a A . 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O. CL N = 33 3 3 3 2 W v v v '4' v r UN . L \I O V s LL N 77) C 3 r oN- N- N O y 3 aa) m r O m m co 0 , c Z I _ o co co co ri -p a d 2 O M N- � N 0 LO LO LO N a m r. CL F r M I� O a) U j ti) ^ Yl a3 E v, i.. _ N U N C [/IIS) ^ O a c E i O O 0 O. Q N w 0 0 0 I- r O N — a • O O O W 00 N — a1 mmil TD L \ O O (O (O W .0 C Num 0 4— O O N oo °� w 11 t d " L IL �. O` U D7 C a a d aS N _ a Om 0 OS 0 a ° C .� m To Q) ar at VN. o 2- a a) m m o ^O C N OU j G fA N C ,Ow y N N N C 3 O .,w O. �, O a bo f V/� .-=°- U O Q U -03 .`L' a, N LL OU a O ° a o m a +U O U O Y Q Q Q N a N W 0 W D 5 Q Ladder View 8;44,August 11 2017 • I, 1 H-114wp22.1 L dder View 0 O O O J N Z 3 a U m Z ' O o III+ I I i,I�I I' litr r I' r _ InatlpQpil6 �I17 �� ' III( 11 ,"11' I' I' �� ( I I L. 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ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1H-114(formerly 308, 116) Project: Kuparuk River Unit TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Well: Plan:1H-114(formerly 30B,116) North Reference: True Wellbore: Plan:1H-114 Survey Calculation Method: Minimum Curvature Design: 1 H-114wp22.1 Output errors are at 1.00 sigma Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37° Well Plan:1H-114(formerly 30B,116) Well Position +N/-S Northing: Latitude: +E/-W Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan:1H-114 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2017 12/15/2017 17.35 80.94 57,481.96 Design 1 H-114wp22.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (0) 39.00 0.00 0.00 0.00 Survey Tool Program Date 8/11/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 800.00 1 H-114wp22.1 (Plan: 1H-114) GYD-GC-SS Gyrodata gyro single shots 800.00 1,756.87 1 H-114wp22.1 (Plan: 1H-114) MWD MWD-Standard 800.00 1,756.87 1 H-114wp22.1 (Plan: 1H-114) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,756.87 3,256.87 1H-114wp22.1 (Plan: 1H-114) MWD MWD-Standard 1,756.87 7,243.00 1H-114wp22.1 (Plan:1H-114) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/11/2017 8:38:57AM Page 2 COMPASS 5000.14 Build 85 • ConocoPhillips • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1H-114(formerly 30B,116) Project: Kuparuk River Unit TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Well: Plan:1H-114(formerly 30B,116) North Reference: True Wellbore: Plan:1H-114 Survey Calculation Method: Minimum Curvature Design: 1 H-114wp22.1 Output errors are at 1.00 sigma Database: OAKEDMP2 Plan Survey Tool Program Date 8/11/2017 Depth From Depth To (usft) (usft) Survey(Wellbore) Tool Name Remarks 1 39.00 800.00 1H-114wp22.1 (Plan:1H-114) GYD-GC-SS Gyrodata gyro single shots 2 800.00 1,756.87 1H-114wp22.1(Plan:1H-114) MWD MWD-Standard 3 800.00 1,756.87 1H-114wp22.1 (Plan:1H-114) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,756.87 3,256.87 1H-114wp22.1 (Plan:1H-114) MWD MWD-Standard 5 1,756.87 7,243.00 1H-114wp22.1 (Plan:1H-114) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 100.00 0.00 0.00 100.00 0.04 0.00 0.04 0.00 1.15 0.00 0.00 0.04 0.04 0.00 GYD-GC-SS(1,1) 118.10 0.00 0.00 118.10 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD-GC-55(1,1) 200.00 0.00 0.00 200.00 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD-GC-S5(1,1) 300.00 0.00 0.00 300.00 0.33 0.00 0.33 0.00 1.15 0,01 0.01 0.33 0.33 0.00 GYD-GC-S5(1,1) 400.00 0.00 0.00 400.00 0.48 0.00 0.48 0.00 1.15 0.01 0.01 0.48 0.48 0.00 GYD-GC-5S(1,1) 460.00 0.00 0.00 460.00 0.57 0.00 0.57 0.00 1.15 0.02 0.02 0.57 0.57 0.00 GYD-GC-SS(1,1) 500.00 0.60 110.00 500.00 0.61 0.00 061 0.00 1.15 0.02 0.02 0.61 061 45.00 GYD-GC-S5(1,1) 600.00 2.10 110.00 599.97 0.68 0.00 0.68 0.00 1.15 0.03 0.03 0.68 0.68 45.00 GYD-GC-S5(1,1) 600.03 2.10 110.00 600.00 0.68 0.00 0.68 0.00 1.15 0.03 0.03 0.68 0.68 45.00 GYD-GC-S5(1,1) 700.00 4.60 107.28 699.79 0.77 0.00 0.77 0.00 1.16 0.05 0.05 0.77 0.77 18.81 GYD-GC-SS(1,1) 800.00 7.09 106.47 799.26 0.88 -0.01 0.89 0.00 1.15 0.07 0.07 0.89 0.89 17.56 GYD-GC-55(1,1) 900.00 9.59 106.09 898.20 0.94 -0.01 0.96 0.01 1.15 0.09 0.09 0.96 0.96 179.72 MWD(1,2) 901.83 9.64 106.08 900.00 0.94 -0.01 0.96 0.01 1.15 0.09 0.09 0.96 0.96 179.48 MWD(1,2) 1,000.00 12.06 103.84 996.41 0.95 -0.01 1.05 0.03 1.15 0.11 0.11 1.05 0.99 107.74 MWD(1,2) 1,100.00 14.53 102.32 1,093.72 0.98 -0.02 1.24 0.06 1.15 0.13 0.15 1.25 1.04 106.17 MWD(1,2) 1,200.00 17.02 101.23 1,189.95 1.04 -0.03 1.56 0.10 1.14 0.16 0.19 1.56 1.10 104.97 MWD(1,2) 1,300.00 19.50 100.41 1,284.91 1.11 -0.04 1.97 0.16 1.14 0.19 0.25 1.97 1.19 104.02 MWD(1,2) 1,400.00 21.99 99.77 1,378.41 1.20 -0.05 2.48 0.23 1.14 0.22 0.32 2.48 1.29 103.23 MWD(1,2) 1,500.00 24.48 99.26 1,470.29 1.32 -0.06 3.07 0.32 1.14 0.25 0.41 3.08 1.41 102.56 MWD(1,2) 1,600.00 26.98 98.83 1,560.37 1.45 -0.07 3.75 0.43 1.15 0.28 0.52 3.76 1.54 101.98 MWD(1,2) 1,605.78 27.12 98.81 1,565.52 1.45 -0.07 3.79 0.44 1.15 0.29 0.52 3.80 1.54 101.96 MWD(1,2) 1,700.00 27.12 98.81 1,649.38 1.60 -0.07 4.47 0.55 1.18 0.32 0.64 4.48 1.67 101.54 MWD(1,2) 1,756.87 27.12 98.81 1,700.00 1.38 -0.06 2.31 0.04 1.14 0.34 0.36 2.32 1.49 106.20 MWD(2,3) 1,776.87 27.12 98.81 1,717.80 1.38 -0.06 2.37 0.06 1.14 0.35 0.37 2.39 1.49 105.67 MWD(2,3) 1,800.00 27.99 98.14 1,738.30 1.38 -0.07 2.45 0.09 1.14 0.36 0.38 2.47 1.50 105.08 MWD(2,3) 1,900.00 31.79 95.62 1,824.99 1.41 -0.10 2.94 0.24 1.14 0.39 0.47 2.95 1.54 102.46 MWD(2,3) 2,000.00 35.63 93.58 1,908.16 1.47 -0.14 3.63 0.41 1.14 0.43 0.61 3.65 1.63 100.15 MWD(2,3) 2,100.00 39.50 91.90 1,987.42 1.56 -0.18 4.49 0.62 1.16 0.47 0.79 4.52 1.73 98.22 • MWD(2,3) 2,200.00 43.38 90.48 2,062.37 1.69 -0.23 5.50 0.87 1.20 0.50 1.02 5.53 1.85 96.62 MWD(2,3) 2,300.00 47.29 89.24 2,132.66 1.85 -0.27 6.63 1.15 1.29 0.53 1.28 6.67 1.97 95.28 MWD(2,3) 8/11/2017 8:38:57AM Page 3 COMPASS 5000.14 Build 85 • ConocoPhillips • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1H-114(formerly 30B,116) Project: Kuparuk River Unit TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Well: Plan:1H-114(formerly 30B,116) North Reference: True Wellbore: Plan:1H-114 Survey Calculation Method: Minimum Curvature Design: 1 H-114wp22.1 Output errors are at 1.00 sigma Database: OAKE DM P2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Seed-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 2,400.00 51.20 88.15 2,197.93 2.03 -0.32 7.87 1.47 1.41 0.56 1.58 7.91 2.11 94.11 MWD(2,3) 2,500.00 55.12 87.18 2,257.88 2.23 -0.37 9.19 1.82 1.57 0.59 1.92 9.24 225 93.09 MWD(2,3) 2,600.00 59.05 86.29 2,312.20 2.45 -0.43 10.59 2.20 1.77 0.62 2.30 10.65 2.38 92.19 MWD(2,3) 2,700.00 62.99 85.48 2,360.64 2.68 -0.48 12.05 2.61 2.00 0.64 2.70 12.11 2.51 91.37 MWD(2,3) 2,751.05 65.00 85.08 2,383.02 2.79 -0.50 12.82 2.84 2.13 0.65 2.92 12.88 2.58 90.98 MWD(2,3) 2,800.00 65.70 83.07 2,403.44 2.97 -0.55 13.48 3.06 2.26 0.66 3.13 13.60 2.64 90.60 MWD(2,3) 2,900.00 67.22 79.03 2,443.39 3.34 -0.65 14.75 3.49 2.55 0.68 3.56 15.00 2.75 89.65 MWD(2,3) 3,000.00 68.84 75.09 2,480.81 3.72 -0.75 15.98 3.91 2.85 0.70 3.98 16.41 2.86 88.49 MWD(2,3) 3,069.81 70.02 72.39 2,505.35 3.97 -0.81 16.81 4.19 3.06 0.71 4.27 17.40 2.95 87.59 MWD(2,3) 3,100.00 70.02 72.39 2,515.66 4.07 -0.81 17.26 4.31 3.16 0.71 4.39 17.84 2.98 87.19 MWD(2,3) 3,200.00 70.02 72.39 2,549.83 4.38 -0.81 18.82 4.73 3.47 0.73 4.80 19.35 3.08 85.98 MWD(2,3) 3,300.00 70.02 72.39 2,584.00 2.60 -0.48 8.11 0.16 2.10 0.75 0.99 8.38 2.34 87.66 MWD+IFR-AK-CAZ-SC(3,3) 3,400.00 70.02 72.39 2,618.17 2.76 -0.48 8.68 0.16 225 0.76 1.03 8.93 2.38 86.62 MWD+IFR-AK-CAZ-5C(3,3) 3,500.00 70.02 72.39 2,652.34 2.92 -0.48 9.25 0.16 2.40 0.78 1.08 9.49 2.43 85.70 MWD+IFR-AK-CAZ-5C(3,3) 3,600.00 70.02 72.39 2,686.51 3.07 -0.48 9.82 0.16 2.58 0.80 1.12 10.04 2.48 84.90 MWD+IFR-AK-CAZ-SC(3,3) 3,700.00 70.02 72.39 2,720.67 3.23 -0.48 10.39 0.16 2.71 0.81 1.17 10.60 2.52 84.19 MWD+IFR-AK-CAZ-SC(3,3) 3,800.00 70.02 72.39 2,754.84 3.40 -0.48 10.97 0.16 2.87 0.83 1.21 11.17 2.57 83.55 MWD+IFR-AK-CAZ-SC(3,3) 3,900.00 70.02 72.39 2,789.01 3.56 -0.48 11.55 0.16 3.03 0.85 1.26 11.74 2.61 82.99 MWD+IFR-AK-CAZ-SC(3,3) 4,000.00 70.02 72.39 2,823.18 3.72 -0.48 12.13 0.16 3.19 0.87 1.31 12.31 2.66 82.47 MWD+IFR-AK-CAZ-5C(3,3) 4,100.00 70.02 72.39 2,857.35 3.89 -0.48 12.71 0.16 3.34 0.89 1.36 12.88 2.71 82.01 MWD+IFR-AK-CAZ-5C(3,3) 4,200.00 70.02 72.39 2,891.52 4.05 -0.48 13.29 0.16 3.50 0.91 1.41 13.45 2.76 81.59 MWD+IFR-AK-CAZ-5C(3,3) 4,300.00 70.02 72.39 2,925.69 4.22 -0.48 13.87 0.18 3.66 0.93 1.47 14.03 2.80 81.20 MWD+IFR-AK-CAZ-5C(3,3) 4,351.21 70.02 72.39 2,943.19 430 -0.48 14.17 0.16 3.75 0.94 1.50 14.32 2.83 81.02 MWD+IFR-AK-CAZ-SC(3,3) 4,400.00 69.46 70.67 2,960.08 4.43 -0.47 14.34 0.19 3.82 0.95 1.52 14.56 2.85 80.86 MWD+IFR-AK-CAZ-SC(3,3) 4,500.00 68.37 67.10 2,996.06 4.71 -0.45 14.58 0.27 3.98 0.97 1.58 14.98 2.90 80.52 MWD+IFR-AK-CAZ-SC(3,3) 4,600.00 67.36 63.48 3,033.75 5.03 -0.43 14.76 0.35 4.14 0.99 1.64 15.38 2.95 80.11 MWD+IFR-AK-CAZ-SC(3,3) 4,700.00 66.43 59.82 3,073.00 5.37 -0.41 14.87 0.43 4.29 1.01 1.70 15.77 3.02 79.62 MWD+IFR-AK-CAZ-SC(3,3) 4,800.00 65.59 56.10 3,113.67 5.73 -0.40 14.91 0.51 4.45 1.04 1.76 16.14 3.09 79.08 MWD+IFR-AK-CAZ-SC(3,3) 4,900.00 64.84 52.33 3,155.60 6.12 -0.40 14.88 0.60 4.60 1.07 1.82 16.50 3.18 78.47 MWD+IFR-AK-CAZ-SC(3,3) 5,000.00 64.19 48.52 3,198.64 6.54 -0.40 14.77 0.69 4.75 1.10 1.88 16.83 3.28 77.83 MWD+IFR-AK-CAZ-SC(3,3) 5,100.00 63.63 44.67 3,242.64 6.96 -0.40 14.58 0.78 4.90 1.13 1.95 17.15 3.39 77.14 MWD+IFR-AK-CAZ-SC(3,3) 5,200.00 63.18 40.79 3,287.41 7.39 -041 14.32 0.88 5.05 1.16 2.01 17.44 3.52 76.43 MWD+IFR-AK-CAZ-SC(3,3) 5,300.00 62.84 36.88 3,332.81 7.82 -0.43 14.00 0.97 5.20 1.20 2.08 17.72 3.68 75.69 MWD+IFR-AK-CAZ-SC(3,3) 5,400.00 62.60 32.95 3,378.66 8.24 -0.46 13.60 1.07 5.34 1.23 2.14 17.96 3.85 74.94 MWD+IFR-AK-CAZ-SC(3,3) 5,500.00 62.48 29.01 3,424.78 8.64 -0.49 13.14 1.16 549 1.27 2.21 18.19 4.04 74.18 MWD+IFR-AK-CAZ-SC(3,3) 5,600.00 62.47 25.06 3,471.01 9.01 -0.52 12.63 1.26 5.63 1.30 2.27 18.40 4.26 73.41 MWD+IFR-AK-CAZ-5C(3,3) 5,700.00 62.57 21.12 3,517.17 9.35 -0.57 12.08 1.35 5.78 1.34 2.33 18.58 4.49 72.64 MWD+1FR-AK-CAZ-5C(3,3) 5,800.00 62.78 17.19 3,563.10 9.66 -0.62 11.51 1.44 5.92 1.38 2.39 18.74 4.76 71.89 MWD+IFR-AK-CAZ-5C(3,3) 5,900.00 63.09 13.27 3,808.81 9.91 -068 10.92 1.53 6.07 1.42 2.46 18.89 5.04 71.14 MWD+IFR-AK-CAZ-SC(3,3) 6,000.00 63.52 9.39 3,653.54 10.12 -0.74 10.33 1.62 621 1.45 2.52 19.01 5.35 70.40 MWD+IFR-AK-CAZ-SC(3,3) 6,100.00 64.05 5.53 3,697.73 10.28 -0.80 9.78 1.70 6.36 1.49 2.57 19.12 5.69 69.69 MWD+IFR-AK-CAZ-SC(3,3) 6,200.00 64.68 1.71 3,741.00 10.39 -0.87 9.28 1.78 6.50 1.53 2.63 19.21 6.04 68.99 MWD+IFR-AK-CAZ-SC(3,3) 6,245.16 65.00 0.00 3,760.20 10.42 -0.90 9.08 1.82 6.57 1.54 2.65 19.24 6.21 68.69 MWD+IFR-AK-CAZ-SC(3,3) 6,300.00 65.00 0.00 3,783.38 10.49 -0.90 9.26 1.82 6.65 1.56 2.68 19.29 6.35 68.29 MWD+IFR-AK-CAZ-5C(3,3) 6,400.00 65.00 0.00 3,825.64 10.60 -0.90 9.54 1.82 6.80 1.60 2.74 19.39 6.49 67.52 MWD+IFR-AK-CAZ-5C(3,3) 6,500.00 65.00 0.00 3,867.90 10.72 -0.90 9.84 1.82 6.95 1.63 2.80 19.50 6.66 66.73 MWD+IFR-AK-CAZ-5C(3,3) 6,600.00 65.00 0.00 3,910.16 10.84 -0.90 10.16 1.82 7.10 1.67 2.86 19.61 6.85 65.91 MWD+IFR-AK-CAZ-5C(3,3) 6,700.00 65.00 0.00 3,952.43 10.96 -0.90 10.49 1.82 7.25 1.71 2.92 19.73 7.05 65.06 MWD+IFR-AK-CAZ-SC(3,3) 6,793.00 65.00 0.00 3,991.73 11.08 -0.90 10.82 1.82 7.39 1.74 2.98 19.84 7.26 64.25 MWD+IFR-AK-CAZ-SC(3,3) 6,800.00 65.00 0.00 3,994.69 11.09 -0.90 10.84 1.82 7.40 1.75 2.99 19.85 7.28 64.19 MWD+IFR-AK-CAZ-SC(3,3) 6,900.00 65.00 0.00 4,036.95 11.21 -0.90 11.21 1.82 7.55 1.79 3.06 19.98 7.51 63.29 MWD+IFR-AK-CAZ-5C(3,3) 7,000.00 65.00 0.00 4,079.21 11.34 -0.90 11.59 1.82 7.70 1.82 3.13 20.12 7.76 62.36 MWD+IFR-AK-CAZ-SC(3,3) 7,100.00 65.00 0.00 4,121.47 11.46 -0.90 11.98 1.82 7.85 1.86 3.20 20.26 8.01 61.41 MWD+IFR-AK-CAZ-SC(3,3) 7,200.00 65.00 0.00 4,163.73 11.59 -0.90 12.38 1.82 8.00 1.90 3.27 20.41 828 60.42 MWD+IFR-AK-CAZ-5C(3,3) 8/11/2017 8:38:57AM Page 4 COMPASS 5000.14 Build 85 • • ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1H-114(formerly 30B, 116) Project: Kuparuk River Unit TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Well: Plan:1H-114(formerly 30B,116) North Reference: True Wellbore: Plan:1H-114 Survey Calculation Method: Minimum Curvature Design: 1 H-114wp22.1 Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) P1 (uon) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (') 7,243.00 65.00 0.00 4,181 91 11.65 -0.90 12.56 1.82 8.06 1.92 3.30 20.48 8.39 59.99 MWD+IFR-AK-CAZ-SC(3,3) Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1H-116 01.D 052115 RVI 0.00 0.00 3,760.20 1,636.17 3,405.02 5,982,372.00 1,692,981,00 70°21'46.613 N 149°34'22.646 W -plan hits target center -Circle(radius 1,320.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (•') (•') 118.10 118.10 20"x 42" 20 42 1,756.87 1,700.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 7,243.00 4,181.91 7"x 8-3/4" 7 8-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,674.33 1,626.53 PFROST 1,863.05 1,793.34 T-3 2,146.02 2,022.46 K-15 4,725.77 3,083.35 UG_C 5,272.19 3,320.13 UG_B 5,538.58 3,442.61 UG_A 5,895.46 3,606.55 Na 6,249.14 3,761.89 WS_D 6,370.41 3,813.13 WS_C 6,416.76 3,832.72 WS_B 6,496.13 3,866.27 WS_A4 6,600.77 3,910.49 WS_A3 6,797.27 3,993.54 WS_A2 7,036.50 4,094.64 WS_A1 7,224.46 4,174.07 BASE 8/11/2017 8:38:57AM Page 5 COMPASS 5000.14 Build 85 • • ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1H-114(formerly 308,116) Project: Kuparuk River Unit TVD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan:54.1+39 @ 93.10usft(Doyon 142) Well: Plan:1H-114(formerly 30B,116) North Reference: True Wellbore: Plan:1H-114 Survey Calculation Method: Minimum Curvature Design: 1 H-114wp22.1 Output errors are at 1.00 sigma Database: OAKEDMP2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 460.00 460.00 0.00 0.00 KOP:Start 1.5°/100'DLS,110°TF,for 140.03' 600.03 600.00 -0.88 2.41 Start 2.5°/100'DLS,-5°TF,for 301.8' 901.83 900.00 -9.78 31.93 Adjust TF to-11°,for 703.95' 1,605.78 1,565.52 -51.01 248.83 Hold for 151.09' 1,756.87 1,700.00 -61.56 316.90 Adjust TF to 0°,for 20' 1,776.87 1,717.80 -62.96 325.91 Start 4°/100'DLS,-20°TF,for 974.18' 2,751.05 2,383.02 -58.97 1,011.81 Adjust TF to-69.36°,for 318.76' 3,069.81 2,505.35 -1.02 1,299.68 Hold for 1281.4' 4,351.21 2,943.19 363.38 2,447.50 Start 3.5°/100'DLS,-109.36°TF,for 1893.94' 6,245.16 3,760.20 1,636.17 3,405.02 Hold for 547.85' 6,793.00 3,991.73 2,132.69 3,405.02 Adjust TF to 0°,for 450' 7,243.00 4,181.91 2,540.52 3,405.02 TD:7243'MD,4181.91'TVD Checked By: Approved By: Date: 8/11/2017 8'38:57AM Page 6 COMPASS 5000.14 Build 85 Pool Report u • o • u LLo CO ... I • O N 2 O 0 co 0 c W a t N (V co_ Ln co r' . • = r ■� _ r O O co Le A 0Y N I CO C7 uiD4 ' O o '• r i N LnN Pfd 1 O c 17) O LO Cr) (k 111\iii 11 N coco ( . O N co r N \ : 1 Ailkill& \ X f , .N‘ \ ,, 7. IT 41 r•-• SD- • N N .h' 1 NI 1\ / N i1) ON .r-- r* Akl co co . Fi1H\tit � Ii / Mil0 o I coI cv rnI I I 1 I I I I I I I I I I I I 1 I I I _lJ 1 I I I I a� 0 O O co O `— co O coo 10 co O co 0 N-- co I r N N (ul/� }sn 098) (+)4UoN/(-)43noS 0 7 R f ,, im CIi COI \\\\\ i . 1 F i , i , .., / •� '� ' X'. N N V"' N N ° ,d, /, 0 T''' “-z c N V ff J33 J Tim '\\ /////...\: Sf NX . O Ck O / r '_ Y • i . ., .\ 001) a ' ilk : CI I. •. \ , N c • . i 11111111 1 \ P- NQ. ■ 3 N \ N N ND O N \ , i . 141111' 1 r , I _ N O_ N O� i. i i 0 COI N :-.1 Q N N O O . i .— fii .,,,,.,. • c N \,.....''''.",.„,..,,.... O J 0 Uz Z Tilill ,. S • tV N .Fr- i i N 0 I d' T' r r • • 1 H-114-wp22.1 Surface Location r Efj, CPA:Coordinate Converter . L ,. 1 G l r,a,m y From: To: Datum: INAD83 Region: lalaska j Datum: 1NAD27 Region: lalaska t` Latitude/Longitude Decimal Degrees r Latitude/Longitude IDecimal Degrees . - " UTM Zone: E South r UTM Zone: ETrue._ f— South +'zState Plane Zone:"4 , Units: lus-ft J C� State Plane Zone: q Units: us-ft Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: — Ending Coordinates: j X: 11689587.12 X: 1549555.497847551 Y: 15980713.67 Y: 15980961.85688692 Transform I Quit Help i 1 H-114-wp22.1 Surface Location CPA.'Coordinate Converter 1 "-= I Q' l ,E3 From: To: Datum: INAD83 i Region: lalaska I Datum: INAD27 .l Region: Ialaska .1 C Latitude/Longitude 'Decimal Degrees .l C Latitude/Longitude 'Decimal Degrees . C UTM Zone:I E South C UTM Zone:'True F- South t: State Plane Zone:j4 Units: 1us ft . C State Plane Zone: ; Units: us-ft . C Legal Ca<-'..rii,Au,,(NAD27 only) ( Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11689587.12 Township: Ran e: 1012 N 9 1010 E Y: X5980713.67 Meridian. I Section:128 [P61—. 1258.95113 FEL 1783.96634 Transform ii Quit Help 1 4 ,: - — • 0 1H-114-wp22.1 Surface Casing , ,„,, , n CPA:Coo-Pinate Converter [ From: To: Datum: 1NAD83 , Region: ralaska zj Datum: NAD27 Region: jalaska , ( Latitude/Longitude Decimal Degrees ...7j: C Latitude/Longitude !Decimal Degrees • r UTM Zone: 1 I— South C UTM Zone: !True r South a State Plane Zone:14 v1 Units: rt;711---, trZ. State Plane Zone: r4 , Units: i .......J C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11689904.39 X: I 549872.762651477 Y: 15980654.20 Y: 1 5980902.38228549 II I Transform I Quit I Help 1 lei 1H-114-wp22.1 Surface Casing In CPA!Coordinate Converter I=3 E !v.-a,tril i 1 From: To: Datum: 1NAD83 ••• Region: jalaska . Datum: I INAD27 ......j Region: 1---- =7 alaska --.I 1 C Latitude/Longitude IDecimal Degrees . r LatitudelLongitude 'Decimal Degrees -. r UTM Zone:1 - r South r UTM Zone: True 1- South tr State Plane Zone: 71-----.1 Units: 1.----- us . -ft C State Plane Zone:14 .,i Units: 16;i1-7,-1 i C Legal Description[NAD27 ot;;,,,i 0" Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11689904 39 Township: 1012 IN:71 Range: 1 010 IE H Y: 15980654.20 Meridian: ILT-11--- . Section:W--1-- IFSL ...mi 1197.37493 ITEE ;j 1467.20479 Transform Quit I Help I 1 i , • • 1H-114-wp22.1 Production Horizon F t j. CPA:Coordinate Converter �_ Lir From: I To: Datum: Region: I Datum: Region:NAD83 g alaska NAD27 g alaska C Latitude/Longitude 'Decimal Degrees =7 C Latitude/Longitude Decimal Degrees -.1 r UTM Zone:r r South C UTM Zone:1True r South Ce State Plane Zone: ,F-71 Units: lus•ft _II Com` State Plane Zone:1q Units: lus-ft . r Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: — X: 11692981.0 Ending Coordinates: X: 1 55294a 338026557 Y: 5982372.0 Y: 15982620.0833798 Transform '1 Quit ; Help i 1 H-114-wp22.1 Production Horizon r3CPA:Coordinate Converter CJ From: _ To: Datum: NAD83 Region: alaska—J Datum: 1NAD27 . Region: alaska . C Latitude/Longitude 'Decimal Degrees . C Latitude/Longitude Decimal Degrees .I C' UTM Zone: — - r South C UTM Zone: [True f South r. State Plane Zone: q Units: us-ft . C State Plane Zone: q Units: us-ft . I r Leal C f:riptior'i trw,AD27 only) C+ Legal Description(NAD27 only) Starting Coordinates: Legal Description — X: 11692981.0 Township: 12 FE Range: 1010 FE Y: 15982372.0 Meridian: ICF--" , Sectiorr127 a E1 1 FSL 11894.0741 FEL 2655.2659 Transform Quit I Help • • 1 H-114-wp22.1 TD CPA;Coordinate Converter 1`=' Ii itt, - From: To: _.... Datum: INAD83 q71 Region: lalaska Datum: 1NAD27 I Region: lalaska .w Latitude/Longitude (Decimal Degrees . .1 C Latitude/Longitude !Decimal Degrees C- UTM Zone: r—.W.__, r South C UTM Zone: True r South ( State Plane Zone: 14 ..1 Units: 1-1.7;41,i. i;- State Plane Zone:14 i Units: 1 �lus-flus ft C' Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: — Ending Coordinates: X: 11692975.06 i X: 1552943.404383343 Y: 15983276.25 Y: 15983524.31208106 L ...., , ... , , Transform Quit Help II 1 H-114-wp22.1 TD in CPA!Coordinate Converters r= I"p ,.-From: To: Datum: 1NAD83 .j Region: lalaska .r l . Datum: 1NAD27 jj Region: lalaska . -( C Latitude/Longitude Decimal Degrees C Latitude/Longitude Decimal Degrees C UTM Zone:1 E South C UTM Zone: True r- South C• State Plane Zone:1-4----;1 Units: lus-ft .1 C State Plane Zone: VI i Units: ius-ft l " f C' Lr:gni LEs _i,:oa3 U .L '.7 only) 0' Legal Description(NAD27 only) �-Starting Coordinates: — — r Legal Description X: 11692975.06 Township: 012 1N J Range: 1010 lis Y: 15983276.25 Meridian: 10-7i,j Section: ] F972 12798.4002 FEL .1 [2653.2116 Transform 11 Quit Help l As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY 0 APP DESCRIPTION 1 2/05/05 MRT CC Rev. Per K05014ACS 2 02/01/17 JAH LGM Rev. Per K170005ACS 25 33 \I 29 28 ` 27 2 125 N ,10 I I - , VIP 1H sink: 31 32 33 34 35 36 -TA eT12N.,10E j 7115110E A.4 5 2 otaidi 1 6 • 0120 lA' ASP GRID NORTH 0'119 -VEZEI �4 • 0118 7 8 - ai 1, 11 12 0117 �% 0116 0115 18 7 16 15 14 13 0114 lE i .� LEGEND 0113 1F . _ _ 1>t 0112 24 19 E 20 21 2: r 23 O AS—BUILT CONDUCTOR 0111 0110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 0108 0103 28 27 *10733 34 0102 0106 0101 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. •UGNU 01 4. ALL CONDUCTORS ARE LOCATED WITHIN •14 PROTRACTED SECTIONS 28 AND 33, •5 TOWNSHIP 12 NORTH, RANGE 10 EAST, .20 .12 UMIAT MERIDIAN, ALASKA. •19 •11 5. DATES OF SURVEY: 12-26-16 THRU 022 010 1-31-17 FIELD BOOKS L16-35, L16-40, .17 •6 L17-02 & L17-03. •16 •21 •1 5 •13 6. ALL DISTANCES SHOWN ARE GROUND. •1 •9 .2 •7 •3 •18 GRAPHIC SCALE 0 100 200 400 111111 .q •g 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSOCIATES, INC. ,,,* SURVEYORS ENGINEERS PLANNERS lb AREA:1H MODULE: XXXX UNIT: D1 ConocoPhilIi ps DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CA LK6108d31 2/05/05 DRAWING NO. CEA—D1 HX-6108D31 I PART: 1 OF 3 I REV: 2 REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 1 2/05/05 MRT CC Rev. Per K05014ACS 2 02/01/17 JAH LGM Rev. Per K170005ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 33, T. 12 N., R. 10 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.N.L F.E.L. O.G. PAD 1 5,979,969.32' 549,197.55' N 70' 21' 21.836" W 149' 36' 01.664" 732' 1151' 49.9' 54.4' 2 5,979,939.43' 549,199.75' N 70' 21' 21.542" W 149' 36' 01.605" 762' 1149' 49.8' 54.2' 3 5,979,909.70' 549,201.04' N 70' 21' 21.249" W 149' 36' 01.573" 791' 1148' N/A N/A 4 5,979,789.20' 549,210.20' N 70' 21' 20.064" W 149' 36' 01.328" 911' 1140' N/A N/A 5 5,980,174.54' 549,543.27' N 70' 21' 23.832" W 149' 35' 51.517" 528' 803' N/A N/A 6 5,980,054.85' 549,551.90' N 70' 21' 22.654" W 149' 35' 51.288" 648' 796' N/A N/A 7 5,979,935.13' 549,560.55' N 70' 21' 21.476" W 149' 35' 51.058" 768' 788' N/A N/A 8 5,979,815.46' 549,569.18' N 70' 21' 20.299" W 149' 35' 50.829" 888' 781' N/A N/A 9 5,979,964.85' 549,559.64' N 70' 21' 21.769" W 149' 35' 51.079" 738' 789' 50.2' 54.6' 10 5,980,084.49' 549,550.97' N 70' 21' 22.946" W 149' 35' 51.309" 619' 796' 50.3' 54.4' 11 5,980,114.39' 549,548.80' N 70' 21' 23.240" W 149' 35' 51.367" 589' 798' 50.4' 54.3' 12 5,980,144.15' 549,546.49' N 70' 21' 23.533" W 149' 35' 51.428" 559' 800' 50.3' 54.3' 13 5,979,993.93' 549,557.42' N 70' 21' 22.055" W 149' 35' 51.138" 709' 791' 50.3' 54.4' 14 5,980,204.14' 549,542.05' N 70' 21' 24.123" W 149' 35' 51.547" 499' 804' 50.1' 54.2' 15 5,979,999.18' 549,195.34' N 70' 21' 22.130" W 149' 36' 01.722" 702' 1153' 50.0' 54.5' 16 5,980,029.08' 549,192.10' N 70' 21' 22.424" W 149' 36' 01.811" 671' 1156' N/A N/A 17 5,980,058.86' 549,191.00' N 70' 21' 22.717" W 149' 36' 01.838" 642' 1156' 49.7' 54.4' 18 5,979,904.84' 549,564.14' N 70' 21' 21.178" W 149' 35' 50.959" 799' 785' 50.4' 54.5' 19 5,980,118.88' 549,186.59' N 70' 21' 23.308" W 149' 36' 01.955" 582' 1160' 49.5' 54.6' 20 5,980,148.10' 549,183.14' N 70' 21' 23.595" W 149' 36' 02.050" 552' 1164' N/A N/A 21 5,980,024.57' 549,555.22' N 70' 21' 22.356" W 149' 35' 51.196" 679' 793' 50.2' 54.4' 22 5,980,089.04' 549,188.93' N 70' 21' 23.014" W 149' 36' 01.893" 612' 1158' 49.6' 54.7' UGNU 5,980,234.12' 549,542.20' N 70' 21' 24.418" W 149' 35' 51.536" 469' 804' 50.0' 54.1' 01 ' *101 5,980,602.66' 549,581.92' N 70' 21' 28.040" W 149' 35' 50.304" 101' 761' 48.0' 54.0' *102 5,980,662.56' 549,577.46' N 70' 21' 28.630" W 149' 35' 50.423" 41' 765' 48.0' 54.0' *106 5,980,632.86' 549,579.90' N 70' 21' 28.337" W 149' 35' 50.357" 70' 762' 48.0' 54.0' *107 5,980,692.31' 549,575.52' N 70' 21' 28.922" W 149' 35' 50.474" 11' 766' 48.0' 54.0' * CONDUCTOR ASBUILT THIS SURVEY LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA:1H MODULE: XXXX UNIT: 01 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CA LK6108d31 2/05/05 DRAWING NO. CEA-D1 HX-6108D31 PART: REV: 2 OF 3 2 -4110 REVDATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 02/01/17 JAH LGM Create Per K1 70005ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N., R. 10 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. O.G. PAD *103 5,980,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY �•�� OF MN. �P:••'' "''4) SURVEYOR'S CERTIFICATE AV v 49thI HEREBY CERTIFY TREGISTERED AND •', �I LICENSED TO PRACTICE LAND SURVEYING IN THE STATEOF II ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND $�, ;JEREMIAH F. CORNELL E• THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION t♦s� LS 12663 •••�;'�: ARE CORRECT AS OF JANUARY 31, 2017. LOUNSBURY � ,,•14' FESSIONAL ♦ & ASSOCIATES, INC. SURVEYORS ENGINEERS YI,dNNERS AREA:1H MODULE: XXXX UNIT: 01 ConocoPhiIIi s DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CA LK6108d31 12/27/16 DRAWNG NO. CEA-D1 HX-6108D31 PART: 3 OF 3 REV: 1 • • 1H-114 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of conductor Low Monitor the cellar continuously during interval. Gas hydrates Moderate Control drill,reduce pump rates, reduce drilling fluid temperatures and add ScreenClean. _ Running sands and gravels Low Maintain planned mud parameters, increase mud weight and use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling(use of trip sheets)and pumping or back reaming out of hole. Washouts/hole sloughing Low Cool mud temperatures and minimize circulating times when possible. 8-3/4" Open Hole / 7" Casing Interval Hazard Risk Level Mitigation Strategy Running sands and gravels Low Maintain planned mud parameters, increase mud weight and use weighted sweeps. Stuck pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA and decrease mud weight. Abnormal reservoir pressure Low BOP training and drills and increase mud weight. Lost circulation Moderate Reduce pump rates, mud rheology and add LCM. Differential sticking Moderate Follow the mud program and keep pipe moving when possible. Anti-collision Moderate Closely follow real-time surveys. Hole swabbing on trips Moderate Trip speeds, proper hole filling(use of trip sheets) and pumping or back reaming out of hole. Getting casing to bottom Moderate Use proper drilling and hole cleaning practices and follow the mud program. Fault crossings and concretions Moderate Use developed best practices for concretion drilling. 1H-114 Drilling Hazards.doc 9/19/20172:19.30 PM •C •g / % % k \ R $ 2 0 c § -0' \/ / 2 = Eo 2 ° ) \/ # .. \ bj ƒ R3 to co 6 0 to / k � iii� � a { CD CL N a � < .0- g IM ) J \ k \ _ ) ) eu \ �� t / f ] \ �� I \ \§ \ ) �� — & _ ! ~ �� \ / ) \ , en �� en — = 05 ii! -�� \ \}\ ) I\ } \ _ © \ t , � � _ }j\ ° b - \ ) �� * o. r i \ 0.\0 Fn � k 0 a 2 ® . ) m \ �/3 ki 0 ri \ \ Ea > ƒ E-, o.,« £ )) / la O. \R \ } ?wd«G4§ \ , �IawG%«« ~~ A • 0 z a / o 1- N / Dm 0 0 O El 1 a r. Q r �I = 1 / D L - . re' ,_ H F- W (11 [z][..7.1 J LII„op ifiI1 5., 1j:f/ '.Ia14NNNNEII!1NNN-NN ENNI i _ 1 ,_ E II 3,,,) _s____... : ___ , y is .� �o . U 101-111I tie— — V 1 1 1 p 001-111 TEN ///// 901-141 TM / / !01-141 TEM J IN1 TBI 011111. 901,1 TIM • n1 TM 1 1 ,EF. • 901-141 TIM 1 t 411-141 TM 111 I llt-141 TINA r-,___„, :A.1%..\ _____,.., 111,.1„,,‘N. 0 I141 1 [. Ell-14l `` r CD •l L11-l1 TSN •sm X11-144 101NNNY6 %YIIM I- --� SIA-01lI.Nitl W is ell-NI TM 1 9 J III Mil 01-11 TEN g g n Q y S 9 / m N - < 11 1 • • Attachment 6 BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. (: T. Ann a Y:As :4 Fixed '111111111M111- 4_1 I Blind . 1 :' 4 sjo,, ... a C.. mQ.o� VBR �., III) • Well: KRU 1K-114 <==Data Input Name: CPAI <==Data Input MEW ' 11110, Mud Weight(ppg) 8.60 <==Data Input Weak point or LOT-Measured depth(ft) SII <==Data Input Weak point or LOT True vertical depth(ft) 1,700' <==Data Input ., Weak point or LOT-Hole angle(deg) 27.0° <==Data Input Weak point or LOT-Hole size(in) 13.500" <==Data input Weak point pressure or LOT-EMW(ppg) 11.50 <==Data Input Zone of interest-Measured depth(ft) 6,300' <==Data Input Zone of interest-True vertical depth (ft) 3,783' <==Data Input Zone of interest-Hole angle(deg) 65.0° <==Data Input Zone of interest-Hole size(in) 8.750" <==Data Input k Zone of interest-Pore pressure EMW(ppg) 8.60 <==Data Input Gas gradient(psi/ft) 0.10 <==Data Input Bottom hole assembly OD(in) 8.0" <==Data Input Bottom hole assembly length(ft) 151' <==Data Input Drill pipe OD(in) 5.000" <==Data Input I BHA annular vol.@ zone of interest(bbl/ft) 0.0122 DP annular vol.@ zone of interest (bbl/ft) 0.0501 DP annular vol. r, weak •oint bbl/ft 0.1528 Additional safety margin(psi) 0.00 <==Data Input Weak point pressure(psi): Pio 1,017 psi Weak point pressure-Safety margin: Pmax 1,017 psi Pmax EMW 11.50 ppg Max anticipated formation pressure(psi): Pf 1,692 psi Weak Pt to Zone of Interest distance(ND ft): OH {TVD} 2,083' Weak Pt to Zone of Interest distance(MD ft): OH {MD} 4,543' Maximum influx height at the bit (ND ft): H TVD} 738' Maximum influx height at the bit (MD ft): H {MD} 1,747' Calc.volume of{H}around BHA: V1bha 1.8 bbl Calc.volume of(H)around drill pipe: V 1 dp 79.9 bbl Calc.volume that H equals @ initial shut in: V1 81.8 bbl Calc.vol.that H equals®weak point(MD ft): VWp 126.6 bbl Calc.volume of Vwp @ initial shut in: V2 76.1 bbl Kick Tolerance: V2 76.1 bbl NOTE: V Loep• 10/17/17 • • TRANSMITTAL LETTER CHECKLIST WELL NAME: n(A �!•/ iI PTD: z/ Development /Service _Exploratory Stratigraphic Test Non-Conventional FIELD: `�� POOL: ktAtc,AIK W�S , C7� I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: / Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. 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