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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 #:________________Signature12/21/2021Wd͗ϮϭϴϬϳϱϬ Ͳ^Ğƚ͗ϯϲϮϳϯJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1H-11950029235910000 KRU WLIPROFFINAL FIELD24-Jun-211H-11750029236020000 KRU WLIPROFFINAL FIELD16-Jun-213H-31A50103202050100 KRU WLCUTTERFINAL FIELD31-Jul-213S-61150103207740000 KRU WLCUTTERFINAL FIELD11-Oct-211R-10150029214040300 KRU WLSAMPLINGFINAL FIELD30-Jun-213H-3750103208220000 KRU WLGLSFINAL FIELD29-May-213F-0450029214490000 KRU WLIPROFFINAL FIELD23-Feb-211J-10150029232860000 KRU WLPPROFFINAL FIELD2-Mar-211D-0250029204290000 KRU WLIPROFFINAL FIELD17-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD18-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD20-Feb-21MP-150029205730000 KRU WLSCMTFINAL FIELD28-Mar-211G-0250029208130000 KRU WLIPROFFINAL FIELD1-Apr-211C-19050029231360000 KRU WLIPROFFINAL FIELD30-Oct-212L-31850103206810000 KRU WLIPROFFINAL FIELD24-Jul-21 ! " # " $ %& ' ()! * '$ +, !- ."! ! /, +, 01 021*- 1 3 + - " ' $ % $ 4 5 + 677 - 8 5+ '7 - 0 96 ' ) + - : 9 2" 8 $ ' " %& ' $ , ' (" 8 ; "$, % $ ; ;)!< = ,=; '! !3 %& ! 6 " 8 % % !" #$! % !" #$! % $ '" ' > +/1*-0(2#(2: 6! $ '" 6 &$ !"'() *! ? &11:(1 7@//21 #? ")!<"; " #? !" # $% #"& #%'( %#) * *+ , " &+ "'() *! $ ' ) A $ " 87) , , %,@ ,@),!$; !% 5)! 44))! -./0-01'2 -3&.0/.- *0 ' 2 $ ! 0 ! ! B" ? " 8 B +9 01 021*17021*7C020.:- ; #4 < 8 ' 4 5-26 *)' ' '8 " , , 8 !7 ( : 5) )8- 91 % 5) )8- 90 / " : " !7 ;)" % % : " 1#B1B :30101 " :1' By Meredith Guhl at 9:14 am, Sep 27, 2021 RBDMS HEW 9/28/2021 VTL 01/24/2022 DSR-9/27/21 SFD 9/28/2021 -00 SFD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD 12,287.0 1/28/2019 3H-31A pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Post Rig GLD install 8/31/2021 3H-31A fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 43.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.8 Set Depth (ftKB) 5,023.1 Set Depth (TVD) … 3,262.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 10,711.8 Set Depth (TVD) … 6,064.6 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-MOD Casing Description LINER A LATERAL OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 12,248.1 Set Depth (ftKB) 14,304.0 Set Depth (TVD) … 6,097.2 Wt/Len (l… 4.60 Grade L-80 Top Thread ST-L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,948.4 6,090.1 88.72 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.900 13,672.7 6,092.3 87.50 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.900 Tubing Strings Tubing Description Tubing – Completion Upper String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.6 Set Depth (ft… 10,290.8 Set Depth (TVD) (… 5,905.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.6 37.6 0.00 Hanger 3.5" Tubing Hanger 3.500 514.1 513.2 7.98 X Nipple 3.5" x 2.813" X nipple 2.813 3,137.0 2,409.1 64.62 GLM 3.5" x 1" KBMG 2.818 5,474.0 3,482.0 61.63 GLM 3.5" x 1" KBMG 2.818 7,162.8 4,247.4 61.62 GLM 3.5" x 1" KBMG SOV 2.818 8,630.3 4,957.7 59.53 GLM 3.5" x 1" KBMG 2.818 9,462.4 5,389.8 58.74 GLM 3.5" x 1" KBMG 2.818 10,159.3 5,809.5 45.03 GLM 3.5" x 1" KBMG 2.818 10,214.7 5,849.3 43.29 Seal Assembly, 80-40 Seal Locator and Seal Assembly, 80-40 2.940 10,217.1 5,851.0 43.24 PBR PBR, 80-40 2.990 10,246.8 5,872.7 42.64 Packer 3.5" x 7" HS Retrieveable Packer, 60k release 3.625 10,265.9 5,886.9 42.08 XN -Nipple 2.813", XN-Nipple 2.750 10,284.1 5,900.5 41.39 Overshot 3.5" Overshot 2.992 Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 10,288.1 Set Depth (ft… 10,336.6 Set Depth (TVD) (… 5,940.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,309.7 5,919.8 40.63 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.000 10,310.7 5,920.5 40.60 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 10,326.6 5,932.6 40.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 10,335.7 5,939.6 40.28 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 10,288. 0 5,903.4 41.26 2.78" AVA CATCHER SET 2.78" AVA CATCHER (34" OAL). 7/26/2021 0.000 10,288. 0 5,903.4 41.26 CUT MECHANICAL CUT TUBING @10,288' 7/31/2021 2.992 10,308. 0 5,918.5 40.68 PACKER Set Northern Solutions Liner Top Packer. (2.72" OD, 1.781" ID, OAL 8.08' 8/19/2018 1.781 10,309. 0 5,919.3 40.65 2.72" RBP 2.72" RBP w/ Fill extention (8.88' OAL) 7/26/2021 0.000 CPP35300 / CPEQ35042 10,316. 0 5,924.6 40.45 2 3/8" LINER 2 3/8" AL1 top thats in the mother bore. From whip stock @ 10,434' to 10,316'. 8/17/2018 1.992 10,434. 0 6,014.6 40.23 NS HEW WHIPSTOCK Whipstock 7/31/2018 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,137.0 2,409.1 64.62 SLB KBMG 1 GAS LIFT GLV BK 0.188 1,301.0 8/31/2021 2 5,474.0 3,482.0 61.63 SLB KBMG 1 GAS LIFT GLV BK 0.188 1,286.0 8/31/2021 3 7,162.8 4,247.4 61.62 SLB KBMG 1 GAS LIFT OV BK 0.188 0.0 8/30/2021 4 8,630.3 4,957.7 59.53 SLB KBMG 1 GAS LIFT DMY BK 0.000 8/27/2021 5 9,462.4 5,389.8 58.74 SLB KBMG 1 GAS LIFT DMY BK 0.000 8/27/2021 6 10,159.3 5,809.5 45.03 SLB KBMG 1 GAS LIFT DMY BK 0.000 8/27/2021 Notes: General & Safety End Date Annotation 8/17/2018 Note: CDR3-AC (CTD) Sidetrack 3H-31A, 9/23/2021 2:53:19 PM Vertical schematic (actual) LINER A LATERAL; 12,248.1- 14,304.0 LINER, AL1 LATERAL; 10,316.6 -14,648.0 PRODUCTION; 34.7-10,711.8 NS HEW WHIPSTOCK; 10,434.0 RPERF; 10,426.0-10,444.0 SLOTS; 10,316.0-14,648.0 2 3/8" LINER; 10,316.0 SOS; 10,335.7 NIPPLE; 10,326.6 CMT SQZ; 10,322.0-10,324.0 Cement Plug; 10,315.0 ftKB PACKER; 10,310.7 2.72" RBP; 10,309.0 PACKER; 10,308.0 SEAL ASSY; 10,309.7 2.78" AVA CATCHER; 10,288.0 CUT; 10,288.0 Overshot; 10,284.1 XN -Nipple ; 10,265.9 Cross Over Thread; 10,251.4 Packer; 10,246.8 Cross Over Thread; 10,243.0 PBR; 10,217.1 Seal Assembly, 80-40; 10,214.7 GLM; 10,159.3 GLM; 9,462.4 GLM; 8,630.3 GLM; 7,162.8 Tubing Punch; 5,884.0-5,884.1 GLM; 5,474.0 SURFACE; 41.8-5,023.1 Tubing Punch; 3,359.0-3,359.1 GLM; 3,137.0 X Nipple ; 514.1 CONDUCTOR; 43.0-121.0 Hanger; 37.6 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31A ... TD Act Btm (ftKB) 14,304.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020501 Wellbore Status PROD Max Angle & MD Incl (°) 95.35 MD (ftKB) 12,725.23 WELLNAME WELLBORE3H-31A Annotation End DateH2S (ppm) 450 Date 7/24/2019 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 44' of RatHole) 10,538.0 5/13/2018 3H-31 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install POGLMs 11/19/2018 3H-31 famaj Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 3,359.0 3,359.1 2,506.0 2,506.1 11/19/2018 1.0 Tubing Punch 5,884.0 5,884.1 3,668.3 3,668.4 11/16/2018 1.0 Tubing Punch 10,316.0 14,648.0 5,924.6 A-1, 3H-31 8/17/2018 SLOTS Prod #2, Slotted Liner 13,346'-14,646.6' (Slots) 10,322.0 10,324.0 5,929.1 5,930.7 7/4/2018 3.0 CMT SQZ 2" Powerflow, 3 SPF 120 deg phasing. 10,426.0 10,444.0 6,008.5 6,022.1 C-4, 3H-31 3/12/2000 4.0 RPERF 2 1/8" EJ III DP, 0 deg ph, +/ - 90 deg orient 10,452.0 10,482.0 6,027.9 6,046.8 A-2, A-1, 3H-31 5/14/1994 4.0 IPERF 4 1/2" HSD; 180 deg ph 10,482.0 10,494.0 6,046.8 6,052.8 A-1, 3H-31 1/28/2011 6.0 APERF Millenium Deep Penetrating charges, 60 degree phasing 12,243.0 14,304.0 6,083.8 6,097.2 A-1, 3H-31 8/8/2018 SLOTS Prod #1, Slotted Liner 12,257'-13,673' (Slots) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,315.0 10,550.0 5,923.8 6,066.7 Cement Plug Layed in 16.5 PPG class G cement 7/8/2018 10,458.0 10,550.0 6,032.0 6,066.7 Cement Plug Layed in 16.5 PPG Class G Cement- Milled out from 10,315' + 24' Rat Hole 7/8/2018 Notes: General & Safety End Date Annotation 8/17/2018 Note: CDR3-AC (CTD) Sidetrack 7/11/2018 Note: Tag TOC at 10,118 3H-31, 9/23/2021 3:28:41 PM Vertical schematic (actual) SLOTS; 12,243.0-14,304.0 SLOTS; 10,316.0-14,648.0 APERF; 10,482.0-10,494.0 IPERF; 10,452.0-10,482.0 RPERF; 10,426.0-10,444.0 LINER, AL1 LATERAL; 10,316.6 -14,648.0 PRODUCTION; 34.7-10,711.8 NS HEW WHIPSTOCK; 10,434.0 2 3/8" LINER; 10,316.0 SOS; 10,335.7 NIPPLE; 10,326.6 CMT SQZ; 10,322.0-10,324.0 Cement Plug; 10,315.0 ftKB PACKER; 10,310.7 2.72" RBP; 10,309.0 PACKER; 10,308.0 SEAL ASSY; 10,309.7 2.78" AVA CATCHER; 10,288.0 CUT; 10,288.0 Overshot; 10,284.1 XN -Nipple ; 10,265.9 Cross Over Thread; 10,251.4 Packer; 10,246.8 Cross Over Thread; 10,243.0 PBR; 10,217.1 Seal Assembly, 80-40; 10,214.7 GLM; 10,159.3 GLM; 9,462.4 GLM; 8,630.3 GLM; 7,162.8 Tubing Punch; 5,884.0-5,884.1 GLM; 5,474.0 SURFACE; 41.8-5,023.1 Tubing Punch; 3,359.0-3,359.1 GLM; 3,137.0 X Nipple ; 514.1 CONDUCTOR; 43.0-121.0 Hanger; 37.6 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31 ... TD Act Btm (ftKB) 10,730.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020500 Wellbore Status PROD Max Angle & MD Incl (°) 95.35 MD (ftKB) 12,725.23 WELLNAME WELLBORE3H-31A Annotation Last WO: End Date 3/9/1997 H2S (ppm) 450 Date 7/24/2019 Comment Casing Strings Casing Description LINER, AL1 LATERAL OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 10,316.6 Set Depth (ftKB) 14,648.0 Set Depth (TVD) … Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,316.6 5,925.1 40.43 SBR Seal Bore Receptical 2.250 12,293.7 6,083.8 92.39 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 13,324.4 6,092.6 90.03 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 14,014.6 6,097.7 89.72 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 3H-31AL1, 9/23/2021 3:28:42 PM Vertical schematic (actual) LINER, AL1 LATERAL; 10,316.6 -14,648.0 PRODUCTION; 34.7-10,711.8 NS HEW WHIPSTOCK; 10,434.0 RPERF; 10,426.0-10,444.0 SLOTS; 10,316.0-14,648.0 2 3/8" LINER; 10,316.0 SOS; 10,335.7 NIPPLE; 10,326.6 CMT SQZ; 10,322.0-10,324.0 Cement Plug; 10,315.0 ftKB PACKER; 10,310.7 2.72" RBP; 10,309.0 PACKER; 10,308.0 SEAL ASSY; 10,309.7 2.78" AVA CATCHER; 10,288.0 CUT; 10,288.0 Overshot; 10,284.1 XN -Nipple ; 10,265.9 Cross Over Thread; 10,251.4 Packer; 10,246.8 Cross Over Thread; 10,243.0 PBR; 10,217.1 Seal Assembly, 80-40; 10,214.7 GLM; 10,159.3 GLM; 9,462.4 GLM; 8,630.3 GLM; 7,162.8 Tubing Punch; 5,884.0-5,884.1 GLM; 5,474.0 SURFACE; 41.8-5,023.1 Tubing Punch; 3,359.0-3,359.1 GLM; 3,137.0 X Nipple ; 514.1 CONDUCTOR; 43.0-121.0 Hanger; 37.6 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31AL1 ... TD Act Btm (ftKB) 14,648.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020560 Wellbore Status PROD Max Angle & MD Incl (°) 93.69 MD (ftKB) 11,413.25 WELLNAME WELLBORE3H-31A Annotation End DateH2S (ppm) 450 Date 7/24/2019 Comment Page 1/3 3H-31 Report Printed: 9/22/2021 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/22/2021 20:00 8/23/2021 00:00 4.00 MIRU, MOVE MOB P PJSM, RAISE SUB, REMOVE RIG MATTING, MOVE SUB OFF 3H-26 MOVE RIG MATS & PIT LINER FROM AROUND WELL 3H-26, MOVE SUB COMPLEX & POSITION AT 3H-31A, HANGE NEW TREE IN CELLAR. RIG RELEASED AT 2000HRS 8-22-21 8/23/2021 00:00 8/23/2021 05:00 5.00 MIRU, MOVE MOB P CONT. TO REMOVE RIG MATTING FROM 3H-26, PLACE MATTING & PIT LINER AROUND 3H-31A, PLACE DSA IN CELLAR, SPOT SUB OVER WELL 3H-31A 8/23/2021 05:00 8/23/2021 07:30 2.50 MIRU, MOVE MOB P MOVE PIT COMPLEX, & SPOT SAME 8/23/2021 07:30 8/23/2021 11:00 3.50 MIRU, WELCTL RURD P INSTALL CUTTINGS TANK, HOOK UP INTERCONNECT, STEAM AND WATER TO PITS, INSTALL BURMING AROUND RIG AND PITS AND CUTTINGS TANK, TAKE ON 9.7 BRINE. ***** RIG ACCPETED @ 10:00 *****, IA=0 PSI, OPEN UP SSV- 0 PSI ON GAUGE 8/23/2021 11:00 8/23/2021 11:30 0.50 MIRU, WELCTL SFTY P PRE SPUD MEETING FOR WELL 3H- 31A 8/23/2021 11:30 8/23/2021 12:00 0.50 MIRU, WELCTL MPSP P PULL/SET BPV RIG UP HOSES IN CELLAR, RIG UP LUBRICATOR 8/23/2021 12:00 8/23/2021 13:30 1.50 MIRU, WELCTL MPSP P PULL/SET BPV CON'T RIG UP LUBRICATOR, TEST 1000 PSI, PULL BPV, 0 PSI ON TBG, RIG DOWN LAY DOWN LUBRICATOR 8/23/2021 13:30 8/23/2021 17:30 4.00 MIRU, WELCTL CIRC P RIG UP LINES IN CELLAR, PUMP DOWN TBG OUT IA THROUGH CHOKE, TAKE 150 BBL DIESEL TO CUTTINGS TANK, GET GOOD 9.7 BACK, CIRC TOTAL OF 375 BBLS @ 3 BPM, 192 PSI MAX PRESSURE, FLOW CHECK- STATIC, RIG DOWN CIRC LINES 8/23/2021 17:30 8/23/2021 18:30 1.00 MIRU, WELCTL MPSP P INSTSALL BPV & TEST & PT 1000PSI - GOOD TEST 8/23/2021 18:30 8/23/2021 19:30 1.00 MIRU, WHDBOP NUND P NU/ND TREE REMOVE TREE & TREE ADAPTER FROM WELL HEAD, CLEAN & INSPECT HNGR., INSTALL BLANKING PLUG, BLANK PLUG 11 TURNS RIGHT, BLANK RT 8 1/2 TURN LEFT, 8/23/2021 19:30 8/24/2021 00:00 4.50 MIRU, WHDBOP NUND P N/U BOPE 8/24/2021 00:00 8/24/2021 03:30 3.50 MIRU, WHDBOP NUND P Nipple up BOPE 0.0 0.0 8/24/2021 03:30 8/24/2021 14:00 10.50 MIRU, WHDBOP SVRG P In between well Maintenance. 0.0 0.0 8/24/2021 14:00 8/24/2021 14:30 0.50 MIRU, WHDBOP SVRG P Service Rig 0.0 0.0 8/24/2021 14:30 8/24/2021 15:30 1.00 MIRU, WHDBOP RURD P PU/MU test tools 0.0 0.0 8/24/2021 15:30 8/24/2021 23:00 7.50 MIRU, WHDBOP BOPE P Test BOPE 250/3,500 psi. BOP test witness waived by Bob Noble, AOGCC. Test PVT and gas monitors and alarms. No failures 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/27/2021 Page 2/3 3H-31 Report Printed: 9/22/2021 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/24/2021 23:00 8/25/2021 00:00 1.00 MIRU, WHDBOP MPSP P L/D Test Jnt. and pull BPV 0.0 8/25/2021 00:00 8/25/2021 02:30 2.50 COMPZN, RPCOMP THGR P Several attempts makinge up landing jnt. to hanger with no success, (2 xo threads were bad) pumped out the BOP stack, picked up a joint. of tubing, made it up to the hanger (good)pull hanger 10’ free 120K continue pulling hanger to the floor. 0.0 0.0 8/25/2021 02:30 8/25/2021 04:00 1.50 COMPZN, RPCOMP CIRC P Circ. B/U @ 244 GPM 420 psi. wash down 5' above the stump. Pick up weight decreased 115k MW 9.7 in and out 10,288.0 10,257.0 8/25/2021 04:00 8/25/2021 04:15 0.25 COMPZN, RPCOMP OWFF P Monitor Well (Static) MW 9.7 in and out 10,257.0 10,257.0 8/25/2021 04:15 8/25/2021 04:45 0.50 COMPZN, RPCOMP THGR P L/D Hanger and Landing jnt. 10,257.0 10,257.0 8/25/2021 04:45 8/25/2021 05:15 0.50 COMPZN, RPCOMP RURD P Rig up 3 ½ completion equipment 10,257.0 10,257.0 8/25/2021 05:15 8/25/2021 23:30 18.25 COMPZN, RPCOMP PULD P L/D 3 ½ 9.3# L-80 Tubing Inspect and strap all tubing removed from the hole. Cut offf Jnt.= 16.25 OD = 3.5 10,257.0 0.0 8/25/2021 23:30 8/26/2021 00:00 0.50 COMPZN, RPCOMP CLEN P Clean floor & change equipment around to RIH with 3 ½ completion. 0.0 0.0 8/26/2021 00:00 8/26/2021 00:30 0.50 COMPZN, RPCOMP SVRG P Service Drawworks, Top Drive and Crown. 0.0 0.0 8/26/2021 00:30 8/26/2021 01:00 0.50 COMPZN, RPCOMP RCST P TIH with 3 ½ 9.3# L-80 EUE-M completion. Tq. Connection to 2,200 Ft lbs. 0.0 314.0 8/26/2021 01:00 8/26/2021 01:30 0.50 COMPZN, RPCOMP RCST P Tubing string took wt. @ 314’ . Pick up and turn ¼ to the right. S/O passed through with no problems. 314.0 314.0 8/26/2021 01:30 8/26/2021 07:30 6.00 COMPZN, RPCOMP RCST P TIH with 3 ½ 9.3# L-80 EUE-M completion. F/314' - 3,902' Tq. Connection to 2,240 Ft lbs. 314.0 3,902.0 8/26/2021 07:30 8/27/2021 00:00 16.50 COMPZN, RPCOMP PUTB P TIH with 3 ½ 9.3# L-80 EUE-M completion. F/3,902' - 10,231' Tq. Connection to 2,240 Ft lbs. 3,902.0 10,231.0 8/27/2021 00:00 8/27/2021 01:00 1.00 COMPZN, RPCOMP CIRC P /U Jnts. 323, 324, and wash down over the top of the cut off jnt. @1.5 bpm 120 psi. F/10,232' - 10,277' set 15k down & sheared pins, completion no-go @ 10,294.0 10,231.0 10,294.0 8/27/2021 01:00 8/27/2021 02:00 1.00 COMPZN, RPCOMP PACK P /U 100K, set packer 2500 psi. hold for 10 min. bled presure down to 1000psi. Tesrt paker 10 min. Packer set @ 10,235' 10,294.0 8/27/2021 02:00 8/27/2021 03:00 1.00 COMPZN, RPCOMP OTHR P ressure up tbg. 1650 psi. P/U 30k over string wt. (130K) shear out PBR. Top of the PBR 10,206 8/27/2021 03:00 8/27/2021 04:00 1.00 COMPZN, RPCOMP HOSO P space out completion. M/U hanger /landing jnt. 8/27/2021 04:00 8/27/2021 05:00 1.00 COMPZN, RPCOMP CIRC P Displace well with 125 bbl. Corrosion inhibited 9.7 ppg. Brine @ 140 gpm 335 psi. followed by 90bbl. of 9.7 ppg. Brine. Rig: NABORS 7ES RIG RELEASE DATE 8/27/2021 Page 3/3 3H-31 Report Printed: 9/22/2021 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/27/2021 05:00 8/27/2021 06:00 1.00 COMPZN, RPCOMP THGR P Land hanger, RILD 8/27/2021 06:00 8/27/2021 08:00 2.00 COMPZN, WHDBOP PRTS P Pressure Tbg. up to 3000 psi. hold for 30 min.(good test) Slowly bled pressure down to 1500 psi. and hold. Pressured up on the IA to 2500 psi. hold for 30 min. (good test). Dump the pressure on the tubing and sheer the SOV. Pump 3bbl through the tubing and pump 3bbl. Down the I/A (SOV open). 8/27/2021 08:00 8/27/2021 09:00 1.00 COMPZN, WHDBOP MPSP P Install BPV test from below 1000 psi. (Good Test) 8/27/2021 09:00 8/27/2021 12:00 3.00 COMPZN, WHDBOP NUND P N/D BOPE 8/27/2021 12:00 8/27/2021 15:00 3.00 COMPZN, WHDBOP NUND P M/U tree adaptor, fill void & PT 500psi (Good Test) N/U tree with diesel & test 250/5000 (Good Test) 8/27/2021 15:00 8/27/2021 16:00 1.00 COMPZN, WHDBOP MPSP P Pull BPV 8/27/2021 16:00 8/27/2021 17:00 1.00 COMPZN, WHDBOP FRZP P Freeze Protcet well 8/27/2021 17:00 8/27/2021 18:00 1.00 COMPZN, WHDBOP MPSP P Install BPV test from below 1000 psi. (good test) 8/27/2021 18:00 8/27/2021 19:00 1.00 DEMOB, MOVE CLEN P Pick up cellar and secure. *****Rig Released from 3H-31 @ 19:00Hrs**** Rig: NABORS 7ES RIG RELEASE DATE 8/27/2021 From:Ward, Dusty K To:Loepp, Victoria T (OGC) Cc:DOA AOGCC Prudhoe Bay; Regg, James B (OGC) Subject:RE: [EXTERNAL]KRU 3H-31A(PTD 218-075, Sundry 321-295) BOP test pressure change APPROVED Date:Tuesday, August 3, 2021 7:29:26 AM Victoria, Thank you. Will do. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, July 30, 2021 8:52 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL]KRU 3H-31A(PTD 218-075, Sundry 321-295) BOP test pressure change APPROVED CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Dusty, The changes below are approved: 1. MPSP changed to 3325 psig 2. BOP test pressure increased to 3500 psig 3. Step 8: Install BPV with plug 4. Step 9: Pressure test BPV and plug to 1000 psig for 10 minutes from above to confirm as barrier. Please include this approval with your approved copy of the sundry and insure that it is included with the approved sundry available on the job site for the AOGCC inspector to view. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Thursday, July 29, 2021 9:58 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3H-31A Sundry Update Victoria, Hope this finds you well. I left you a phone message on this too. There were two small changes to the plan in attached sundry. 1. We got a recent SBHP (7/21/2021) that rendered an MPSP of 3325 psig. Therefore, we’re increasing our BOP test to a 3500 psig test, instead of 3000 psig. 2. Step 8 of the Rig work on page 3 of attached should read “Install BPV with plug.”. And step 9, should read “Pressure test BPV and plug to 1000 psig for 10 minutes from above to confirm as barrier.” a. The Hydrostatic set packer we’re planning to run on this could initiate setting below 1000 psig, so we’d confirm our BPV with plug installed from above, instead of from below to avoid pre-mature setting of the packer. Please confirm you’ve received this and let me know if you have any questions. Thanks for your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 3F-14 50-029-21500-00 907249583 Kuparuk River Packer Setting Record Field- Final 7-Jul-21 0 12 3H-31A 50-103-20205-01 n/a Kuparuk River Plug Setting Record Field- Final 26-Jul-21 0 13 3K-22A 50-029-22759-01 n/a Kuparuk River Plug Setting Record Field- Final 9-Apr-21 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϮϭϴϬϳϱϬ Ͳ^Ğƚ͗ϯϱϰϴϳBy Abby Bell at 2:11 pm, Aug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ll perforations are cemented All perforations are cemented By Samantha Carlisle at 9:41 am, Jun 15, 2021 321-295 DSR-6/15/21 DLB DLB 06/15/2021 X X VTL 7/22/21 10-404 BOP test to 3000 psig Annular preventer test to 2500 psig ; ADL0025523 X dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date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f PT of IA or tubing fails, notify AOGCC with plan forward PT tubing to 3000 psig, 30 min & chart MIT-IA to 2500 psig, 30 min & chart 3H-31 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15.06 62.5 H-40 WELDED WELDED Surface 5023.1 3263 9.625 8.92 36 J-55 BTC BTC Production/Interm ediate 10711.8 6065 7 6.28 26 L-80 BTC-MOD BTC-MOD Liner 14304 6097.2 2.375 1.99 4.6 L-80 ST-L ST-L Tubing 10288 5904 3.5 2.992 9.3 L-80 EUE 8rd EUE 8rd All Perfs Cemented PERF INFO TOP PERF BOTTOM PERF C-4 INTERVAL 10316 14648 UPPER KALUBIK 10322 10324 C-4 INTERVAL 10426 10444 A-2 INTERVAL 10452 10482 A-1 INTERVAL 10482 10494 CTD A-Sand Liner 12243 14304 PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrels @ TBD 3.5" x 7" Packer @ xxxx' RKB (3" ID) 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE S3 Permanend Packer @ 10311' RKB (3.25" ID) 2-3/8" Liner Top Packer 2-3/8" Liner Surface Casing Production/Intermediate Casing Conductor A-sand CTD Cemented Perfs Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 44' of RatHole) 10,538.0 5/13/2018 3H-31 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install POGLMs 11/19/2018 3H-31 famaj Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 43.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.8 Set Depth (ftKB) 5,023.1 Set Depth (TVD) … 3,262.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 10,711.8 Set Depth (TVD) … 6,064.6 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-MOD Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 3,359.0 3,359.1 2,506.0 2,506.1 11/19/2018 1.0 Tubing Punch 5,884.0 5,884.1 3,668.3 3,668.4 11/16/2018 1.0 Tubing Punch 10,316.0 14,648.0 5,924.6 A-1, 3H-31 8/17/2018 SLOTS Prod #2, Slotted Liner 13,346'-14,646.6' (Slots) 10,322.0 10,324.0 5,929.1 5,930.7 7/4/2018 3.0 CMT SQZ 2" Powerflow, 3 SPF 120 deg phasing. 10,426.0 10,444.0 6,008.5 6,022.1 C-4, 3H-31 3/12/2000 4.0 RPERF 2 1/8" EJ III DP, 0 deg ph, +/ - 90 deg orient 10,452.0 10,482.0 6,027.9 6,046.8 A-2, A-1, 3H-31 5/14/1994 4.0 IPERF 4 1/2" HSD; 180 deg ph 10,482.0 10,494.0 6,046.8 6,052.8 A-1, 3H-31 1/28/2011 6.0 APERF Millenium Deep Penetrating charges, 60 degree phasing 12,243.0 14,304.0 6,083.8 6,097.2 A-1, 3H-31 8/8/2018 SLOTS Prod #1, Slotted Liner 12,257'-13,673' (Slots) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,315.0 10,550.0 5,923.8 6,066.7 Cement Plug Layed in 16.5 PPG class G cement 7/8/2018 10,458.0 10,550.0 6,032.0 6,066.7 Cement Plug Layed in 16.5 PPG Class G Cement- Milled out from 10,315' + 24' Rat Hole 7/8/2018 Notes: General & Safety End Date Annotation 8/17/2018 Note: CDR3-AC (CTD) Sidetrack 7/11/2018 Note: Tag TOC at 10,118 3H-31, 6/10/2021 10:57:42 AM Vertical schematic (actual) SLOTS; 12,243.0-14,304.0 SLOTS; 10,316.0-14,648.0 PRODUCTION; 34.7-10,711.8 APERF; 10,482.0-10,494.0 IPERF; 10,452.0-10,482.0 LINER, AL1 LATERAL; 10,316.6 -14,648.0 RPERF; 10,426.0-10,444.0 NS HEW WHIPSTOCK; 10,434.0 2 3/8" LINER; 10,316.0 CMT SQZ; 10,322.0-10,324.0 Cement Plug; 10,315.0 ftKB PACKER; 10,310.7 PACKER; 10,308.0 GAS LIFT; 10,223.2 Tubing Punch; 5,884.0-5,884.1 SURFACE; 41.8-5,023.1 Tubing Punch; 3,359.0-3,359.1 NIPPLE; 488.0 CONDUCTOR; 43.0-121.0 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31 ... TD Act Btm (ftKB) 10,730.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020500 Wellbore Status PROD Max Angle & MD Incl (°) 95.35 MD (ftKB) 12,725.23 WELLNAME WELLBORE3H-31A Annotation Last WO: End Date 3/9/1997 H2S (ppm) 450 Date 7/24/2019 Comment Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD 12,287.0 1/28/2019 3H-31A pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Patches 1/18/2021 3H-31A zembaej Casing Strings Casing Description LINER A LATERAL OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 12,248.1 Set Depth (ftKB) 14,304.0 Set Depth (TVD) … 6,097.2 Wt/Len (l… 4.60 Grade L-80 Top Thread ST-L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,948.4 6,090.1 88.72 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.900 13,672.7 6,092.3 87.50 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.900 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.6 Set Depth (ft… 10,336.6 Set Depth (TVD) (… 5,940.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.6 37.6 0.00 HANGER MCEVOY GEN 4 TUBING HANGER 3.500 488.0 487.4 7.14 NIPPLE CAMCO DS LANDING NIPPLE 2.812 10,270.2 5,890.1 41.92 NIPPLE CAMCO W-1 SELECTIVE NIPPLE NO GO 2.812 10,309.8 5,919.9 40.63 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.000 10,310.7 5,920.6 40.60 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 10,326.6 5,932.7 40.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 10,335.7 5,939.6 40.28 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 10,308. 0 5,918.5 40.68 PACKER Set Northern Solutions Liner Top Packer. (2.72" OD, 1.781" ID, OAL 8.08' 8/19/2018 1.781 10,316. 0 5,924.6 40.45 2 3/8" LINER 2 3/8" AL1 top thats in the mother bore. From whip stock @ 10,434' to 10,316'. 8/17/2018 1.992 10,434. 0 6,014.6 40.23 NS HEW WHIPSTOCK Whipstock 7/31/2018 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 10,223.2 5,855.5 43.11 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 10/17/1997 Notes: General & Safety End Date Annotation 8/17/2018 Note: CDR3-AC (CTD) Sidetrack 3H-31A, 6/10/2021 10:57:42 AM Vertical schematic (actual) LINER A LATERAL; 12,248.1- 14,304.0 LINER, AL1 LATERAL; 10,316.6 -14,648.0 NS HEW WHIPSTOCK; 10,434.0 PRODUCTION; 34.7-10,711.8 RPERF; 10,426.0-10,444.0 SLOTS; 10,316.0-14,648.0 2 3/8" LINER; 10,316.0 CMT SQZ; 10,322.0-10,324.0 Cement Plug; 10,315.0 ftKB PACKER; 10,310.7 PACKER; 10,308.0 GAS LIFT; 10,223.2 Tubing Punch; 5,884.0-5,884.1 SURFACE; 41.8-5,023.1 Tubing Punch; 3,359.0-3,359.1 NIPPLE; 488.0 CONDUCTOR; 43.0-121.0 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31A ... TD Act Btm (ftKB) 14,304.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020501 Wellbore Status PROD Max Angle & MD Incl (°) 95.35 MD (ftKB) 12,725.23 WELLNAME WELLBORE3H-31A Annotation End DateH2S (ppm) 450 Date 7/24/2019 Comment SSSV: NIPPLE Casing Strings Casing Description LINER, AL1 LATERAL OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 10,316.6 Set Depth (ftKB) 14,648.0 Set Depth (TVD) … Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,316.6 5,925.1 40.43 SBR Seal Bore Receptical 2.250 12,293.7 6,083.8 92.39 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 13,324.4 6,092.6 90.03 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 14,014.6 6,097.7 89.72 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 3H-31AL1, 6/10/2021 10:57:43 AM Vertical schematic (actual) LINER, AL1 LATERAL; 10,316.6 -14,648.0 NS HEW WHIPSTOCK; 10,434.0 PRODUCTION; 34.7-10,711.8 RPERF; 10,426.0-10,444.0 SLOTS; 10,316.0-14,648.0 2 3/8" LINER; 10,316.0 CMT SQZ; 10,322.0-10,324.0 Cement Plug; 10,315.0 ftKB PACKER; 10,310.7 PACKER; 10,308.0 GAS LIFT; 10,223.2 Tubing Punch; 5,884.0-5,884.1 SURFACE; 41.8-5,023.1 Tubing Punch; 3,359.0-3,359.1 NIPPLE; 488.0 CONDUCTOR; 43.0-121.0 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31AL1 ... TD Act Btm (ftKB) 14,648.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020560 Wellbore Status PROD Max Angle & MD Incl (°) 93.69 MD (ftKB) 11,413.25 WELLNAME WELLBORE3H-31A Annotation End DateH2S (ppm) 450 Date 7/24/2019 Comment ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,304'NONE Casing Collapse Conductor Surface Production Packers and SSSV Type: 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Dusty Ward Contact Name:Dusty Ward Sr. Wells Engineer Contact Email: Contact Phone: (907) 265-6531 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Name: Authorized Title:Dusty.Ward@cop.com Authorized Signature: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. N/A N/A 3.500''L-80 PACKER - SAB-3 PERM PKR PACKER - LINER TOP PACKER - LWR PATCH PKR PACKER - UPR PATCH PKR PACKER - LWR PATCH PKR PACKER - UPR PATCH PKR 10,311 MD and 5921 TVD 10,308 MD and 5919 TVD 5,891 MD and 3672 TVD 5,875 MD and 3664 TVD 3,365 MD and 2509 TVD 3,349 MD and 2502 TVD 7/1/2020 10,337' Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size:Tubing Grade:Tubing MD (ft): 10,677'7''10,712'5,855' 78'16''121'121' 4,981'9 5/8 5,023'2,889' Length Size MD TVD Burst NONE P. O. Box 100360, Anchorage, Alaska 99510 50-103-20205-01-00 KRU 3H-31A ADL 25524, ADL 25531 Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY 6,097'14,304' 6,097' 2601psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.218-075 Perforate Reppair Well Exploratory Stratigraphic Development Service BOP Test Mechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate Mar-27-2020 By Samantha Carlisle at 10:52 am, Mar 27, 2020 320-140 VTL 3/31/20 BOP test to 3000 psig Annular preventer test to 2500 psig 10-404 DSR-3/31/2020 X X SFD 3/27/2020 XC/O tubing/GLMs 4/1/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 23, 2020 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3H- 31A (PTD# 218-075-0). Well 3H-31 was drilled and completed in February 1994 by Parker 245 as a water injector into the A/C-sands. The well was moderate injector until it became a CTD producer candidate in 2018. The well was CTD sidetracked in 2018 and became an A-sand producer. Holes were punched in the tubing and POGLMs were attempted to be set to lift the well, but successful sets werenever achieved. In 2020 the well became a RWO candidate to pull the tubing and stack a packer with new tubing and full GLD. If you have any questions or require any further information, please contact me at 265-6531. The tubing will be cut pre-rig. The 3.5" tubing will be pulled, then a stacked packer and 3.5" tubing with GLD will be ran to re-complete the well. 3HͲ31ARWOProcedure KuparukProducer PTD#218Ͳ075Ͳ0 Page1of1 RemainingPreͲRigWork 1. TͲPPPOT,TͲPOT,ICͲPPPOT,andICͲPOT. 2. Pullanyplugs,POGLMs,orpatchestomakefulldriftavailablethrutubing. 3. SBHP. 4. ConfirmallGLMsareclosedexceptleaveGLM#1at10223’RKBopenforcirculation.(Note,circulationswillalso shortcircuitthruthetubingpunchesabovethisGLM). 5. Circulate/bullheadwelloverto9.6ppgcorrosioninhibitedNaClabovethepackerat10308’RKB.Shouldbe about~452bbls(1.25xTbg&IAvolumesurfacetotopoffirstpacker). a. 9.6ppgNaCl(Freezingpoint~1degF)isusedforitsFreezeProtectionproperties. 6. SetplugrightontopoftheNorthernSolutionsLinerToppackerat~10308’toisolateworkfromtheformation. 7. CMITͲTxIAto2500psigtoconfirmplugandcasingintegrity.Perform30minuteNFT. 8. Chemcutthetubingat~10288’RKBinthemiddleofthe31’jointAbovethelinertoppackerandproduction packer. 9. Install“H’BPVwithin48hrsofrigarrivalandprepwellforrig. RigWork MIRU 1. MIRUDoyon142on3HͲ31A.PullBPVifneedtocirculate. 2. RecordshutͲinpressuresontheT&IA.Ifthereispressure,bleedoffIAand/ortubingpressureandcomplete 30ͲminuteNFT.Verifywellisdead.CirculateKWFasneeded. 3. SetBPVandconfirmasbarrierifneeded,NDTree,NUBOPEandtestto250/3,000psi.Testannular250/3,000 psi. RetrieveTubingSection 4. PullBPV,MUlandingjointandBOLDS. 5. Pull3Ͳ1/2”tubingdowntopreͲrigcut(~10,288’RKB). Installin3Ͳ½”TubingwithStackedPacker 6. MU3½”completionwithovershot,packer,andGLMs.RIHandovershottubingstub.Spaceout. 7. Landtubing.RILDS. 8. InstallBPV. 9. Pressuretestinnerannulusto1000psifor10minutesoncharttoconfirmBPVasbarrier. NDBOP,NUTree 10. Confirmpressuretests. 11. NDBOPE.NUtree.PTtree. 12. RDMO. PostͲRigWork 13. PullBPV 14. RUslicklineandDHD. 15. RIHandsetstandingvalveorplugbelownewlyStackedPacker.PTtubingto3500psigforatleast20minutes tosetpacker. 16. Pullstandingvalveorplug.BleedoffIApressure.PTtubingandpackerfrombelowto3000psig. 17. CMITͲTxIAto2500psigtoconfirmcasingintegrity. 18. RIH.PulllowerplugsetpreͲrig.POOH 19. RDMO. Doyon 142 BOP & Choke Configuration 2-7/8” x 5” VBR BLIND 2-7/8” x 5” VBR ANNULAR 3H-31 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15.06 62.5 H-40 WELDED WELDED Surface 5023.1 3263 9.625 8.92 36 J-55 BTC BTC Production/Interm ediate 10711.8 6065 7 6.28 26 L-80 BTC-MOD BTC-MOD Liner 14304 6097.2 2.375 1.99 4.6 L-80 ST-L ST-L Tubing 10288 5904 3.5 2.992 9.3 L-80 EUE 8rd EUE 8rd All Perfs Cemented PERF INFO TOP PERF BOTTOM PERF C-4 INTERVAL 10316 14648 UPPER KALUBIK 10322 10324 C-4 INTERVAL 10426 10444 A-2 INTERVAL 10452 10482 A-1 INTERVAL 10482 10494 CTD A-Sand Liner 12243 14304 PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrels @ TBD 3.5" x 7" Packer @ xxxx' RKB (3" ID) 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE S3 Permanend Packer @ 10311' RKB (3.25" ID) 2-3/8" Liner Top Packer 2-3/8" Liner Surface Casing Production/Intermediate Casing Conductor A-sand CTD Cemented Perfs Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 44' of RatHole) 10,538.0 5/13/2018 3H-31 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL POGLM #2, INSTALL PATCH, CHANGE OV TO DV 12/5/2018 3H-31 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 43.0 Set Depth (ftKB) 121.0 Set Depth (TVD) (… 121.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.8 Set Depth (ftKB) 5,023.1 Set Depth (TVD) (… 2,889.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 10,711.8 Set Depth (TVD) (… 5,854.7 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-MOD Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,359.0 3,359.1 2,133.0 2,133.1 11/19/2018 1.0 Tubing Punch 5,884.0 5,884.1 3,295.3 3,295.4 11/16/2018 1.0 Tubing Punch 10,316.0 14,648.0 5,551.6 A-1, 3H-31 8/17/2018 SLOTS Prod #2, Slotted Liner 13,346'-14,646.6' (Slots) 10,322.0 10,324.0 5,556.2 5,557.7 7/4/2018 3.0 CMT SQZ 2" Powerflow, 3 SPF 120 deg phasing. 10,426.0 10,444.0 5,635.5 5,649.3 C-4, 3H-31 3/12/2000 4.0 RPERF 2 1/8" EJ III DP, 0 deg ph, +/- 90 deg orient 10,452.0 10,482.0 5,655.4 5,678.4 A-2, A-1, 3H-31 5/14/1994 4.0 IPERF 4 1/2" HSD; 180 deg ph 10,482.0 10,494.0 5,678.4 5,687.6 A-1, 3H-31 1/28/2011 6.0 APERF Millenium Deep Penetrating charges, 60 degree phasing 12,243.0 14,304.0 A-1, 3H-31 8/8/2018 SLOTS Prod #1, Slotted Liner 12,257'-13,673' (Slots) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 10,315.0 10,550.0 5,550.8 5,730.6 Cement Plug- Casing 7/8/2018 10,458.0 10,550.0 5,660.0 5,730.6 Cement Plug- Tubing 7/8/2018 Milled out from 10,315' + 24' Rat Hole Notes: General & Safety End Date Annotation 8/17/2018 Note: CDR3-AC (CTD) Sidetrack 7/11/2018 Note: Tag TOC at 10,118 11/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3H-31, 3/27/2020 9:47:59 AM M D (ft K B) -2,021.3 -2,017.1 -2,013.8 -1,997.7 -1,981.6 -1,979.3 -1,971.1 -1,048.6 0.0 37.7 43.0 121.1 488.2 495.1 3,349.1 3,358.9 3,365.2 4,945.2 5,021.3 5,023.3 5,878.9 5,884.2 5,895.0 10,217.2 10,232.3 10,270.3 10,303.8 10,309.7 10,315.0 10,315.9 10,321.9 10,324.1 10,327.8 10,335.6 10,346.8 10,410.1 10,434.1 10,443.9 10,452.1 10,461.0 10,482.0 10,501.0 10,537.1 10,550.9 10,624.3 10,711.9 11,245.1 14,304.1 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA…UNIT …UNIT …C-4 IN…C-4B … C-4A …C-3 IN…C-2 IN…C-1 IN…C-1B …C-1A …UNIT …B-8 IN…B-7 IN…B-6 IN…B-5 IN…B-4 IN…B-3 IN…B-2 IN…B-1 IN…UNIT …A-6 IN…A-5 IN…A-4 IN…A-3 IN…A-2 IN…A2-2 S… A2-1 S… A-1 IN…A1-2 S… A1-1 S… MILUV… SLOTS; 12,243.0-14,304.0; 8/8/2018 SLOTS; 10,316.0-14,648.0; 8/17/2018 FLOAT SHOE; 10,710.3- 10,711.8; 1.53; 3-6; 7.000; 6.151 CASING; 10,624.5-10,710.3; 85.82; 3-5; 7.000; 6.276 FLOAT COLLAR; 10,623.1- 10,624.5; 1.37; 3-4; 7.000; 6.151 CASING; 10,410.3-10,623.1; 212.85; 3-3; 7.000; 6.276 APERF; 10,482.0-10,494.0; 1/28/2011 IPERF; 10,452.0-10,482.0; 5/14/1994 RPERF; 10,426.0-10,444.0; 3/12/2000 Liner-Red; 10,346.8-11,245.1; 898.24; 5-3; 2.375; 1.992 MARKER JT; 10,366.9- 10,410.3; 43.38; 3-2; 7.000; 6.276 SOS; 10,335.7-10,336.6; 0.93; 1-20; 4.000; 2.992 Liner - Pup; 10,322.6- 10,346.8; 24.19; 5-2; 2.375; 1.992 TUBING PUP; 10,327.6- 10,335.7; 8.11; 1-19; 3.500; 2.992 NIPPLE; 10,326.6-10,327.6; 1.00; 1-18; 4.441; 2.750 CMT SQZ; 10,322.0-10,324.0; 7/4/2018 TUBING PUP; 10,316.6- 10,326.6; 10.05; 1-17; 3.500; 2.992 SBR; 10,316.6-10,322.6; 6.00; 5-1; 2.630; 2.250 XO THREAD; 10,315.6- 10,316.6; 0.94; 1-16; 3.500; 2.992 PACKER; 10,310.7-10,315.6; 4.90; 1-15; 6.150; 3.250 SEAL ASSY; 10,309.8- 10,310.7; 0.92; 1-14; 4.000; 3.000 TUBING PUP; 10,303.7- 10,309.8; 6.13; 1-13; 3.500; 2.992 TUBING; 10,272.1-10,303.7; 31.55; 1-12; 3.500; 2.992 NIPPLE; 10,270.2-10,272.1; 1.92; 1-11; 4.540; 2.812 TUBING; 10,238.6-10,270.2; 31.60; 1-10; 3.500; 2.992 TUBING PUP; 10,232.4- 10,238.6; 6.17; 1-9; 3.500; 2.992 GAS LIFT; 10,223.2-10,232.4; 9.19; 1-8; 5.960; 2.867 TUBING PUP; 10,217.1- 10,223.2; 6.18; 1-7; 3.500; 2.992 Tubing Punch; 5,884.0- 5,884.1; 11/16/2018 TUBING; 495.0-10,217.1; 9,722.10; 1-6; 3.500; 2.992 CASING; 34.7-10,366.9; 10,332.15; 3-1; 7.000; 6.276 FLOAT SHOE; 5,021.5- 5,023.1; 1.65; 2-6; 9.625; 8.921 CASING; 4,946.6-5,021.5; 74.88; 2-5; 9.625; 8.921 FLOAT COLLAR; 4,945.3- 4,946.6; 1.35; 2-4; 9.625; 8.921 CASING; 2,422.1-4,945.3; 2,523.14; 2-3; 9.625; 8.921 Tubing Punch; 3,359.0- 3,359.1; 11/19/2018 CASING; 45.8-2,422.1; 2,376.33; 2-2; 9.625; 8.535 TUBING FLOW COUPLING; 489.0-495.0; 5.94; 1-5; 4.500; 2.920 NIPPLE; 488.0-489.0; 0.98; 1- 4; 4.540; 2.812 TUBING PUP; 481.8-488.0; 6.21; 1-3; 3.500; 2.992 TUBING; 41.6-481.8; 440.19; 1-2; 3.500; 2.992 CONDUCTOR; 43.0-121.0; 78.00; 1-1; 16.000; 15.062 HANGER; 41.8-45.8; 4.00; 2- 1; 12.000; 8.535 HANGER; 37.6-41.6; 4.04; 1- 1; 8.000; 3.500 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31 ... TD Act Btm (ftKB) 10,730.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020500 Wellbore Status PROD Max Angle & MD Incl (°) 65.93 MD (ftKB) 3,676.61 WELLNAME WELLBORE3H-31A H2S (ppm) 500 Date 8/24/2018 Comment Annotation Last WO: End Date 3/9/1997 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD 12,287.0 1/28/2019 3H-31A pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CORRECT GLV TABLE(WellView issue), TAG & H2S 1/28/2019 3H-31A pproven Casing Strings Casing Description LINER A LATERAL OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 12,248.1 Set Depth (ftKB) 14,304.0 Set Depth (TVD) (… 6,097.2 Wt/Len (l… 4.60 Grade L-80 Top Thread ST-L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,948.4 6,090.1 88.72 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.900 13,672.7 6,092.3 87.50 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.900 Tubing Strings Tubing Description TUBING String Max … 3 1/2 ID (in) 2.99 Top (ftKB) 37.6 Set Depth (ft… 10,336.6 Set Depth (TVD) (ft… 5,940.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 37.6 37.6 0.00 HANGER MCEVOY GEN 4 TUBING HANGER 3.500 488.0 487.4 7.14 NIPPLE CAMCO DS LANDING NIPPLE 2.812 10,270.2 5,890.1 41.92 NIPPLE CAMCO W-1 SELECTIVE NIPPLE NO GO 2.812 10,309.8 5,919.9 40.63 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.000 10,310.7 5,920.6 40.60 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 10,326.6 5,932.7 40.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 10,335.7 5,939.6 40.28 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 3,349.0 2,501.6 63.64 PATCH - UPR PKR (ME) 2.72" P2P CPP35143 w/ Anchor Latch CPAL35105. OAL 17' Max OD 2.725" 1/22/2019 1.625 3,351.0 2,502.4 63.63 SPACER PIPE 2 1/16" P110 SPACER PIPE 12/28/2018 1.600 3,365.0 2,508.7 63.54 PATCH - LWR PKR (ME) 2.72" P2P CPP35144 12/29/2018 1.625 5,875.0 3,664.3 63.30 PATCH - UPR PKR (ME) 2.72" P2P CPP35198 w/ Anchor Latch CPAL35104. OAL 15' Max OD 2.725" 12/28/2018 1.625 5,879.0 3,666.1 63.34 SPACER PIPE 2 1/16" P110 SPACER PIPE 12/28/2018 0.000 5,891.0 3,671.5 63.45 PATCH - LWR PKR (ME) 2.72" P2P CPP35029. OAL 4' Max OD 2.72" 11/16/2018 1.625 10,308.0 5,918.5 40.68 PACKER Set Northern Solutions Liner Top Packer. (2.72" OD, 1.781" ID, OAL 8.08' 8/19/2018 1.781 10,316.0 5,924.6 40.45 2 3/8" LINER 2 3/8" AL1 top thats in the mother bore. From whip stock @ 10,434' to 10,316'. 8/17/2018 1.992 10,434.0 6,014.6 40.23 NS HEW WHIPSTOCK Whipstock 7/31/2018 0.000 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 10,223.2 5,855.5 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 10/17/1997 Notes: General & Safety End Date Annotation NOTE: View Schematic w/ Alaska Schematic9.0 8/17/2018 Note: CDR3-AC (CTD) Sidetrack 3H-31A, 3/27/2020 9:48:00 AM M D (ft K B) -2,021.3 -2,017.1 -2,013.8 -1,997.7 -1,981.6 -1,979.3 -1,971.1 -1,048.6 0.0 37.7 43.0 121.1 488.2 495.1 3,349.1 3,358.9 3,365.2 4,945.2 5,021.3 5,023.3 5,878.9 5,884.2 5,895.0 10,217.2 10,232.3 10,270.3 10,303.8 10,309.7 10,315.0 10,315.9 10,321.9 10,324.1 10,327.8 10,335.6 10,346.8 10,410.1 10,434.1 10,442.9 10,445.9 10,471.1 10,549.9 10,730.0 12,248.0 12,293.3 12,948.5 13,647.0 13,672.6 14,303.5 14,648.0 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA… KUPA… UNIT …UNIT … UNIT … C-4 IN… C-4 IN… C-4B … UNIT …A-2 IN… A-1 IN… SHOE; 14,303.6-14,304.0; 0.40; 4- 10; 2.390 Slotted Liner; 13,673.5-14,303.6; 630.09; 4-9; 2.375; 1.992 DEPLOYMENT SLEEVE; 13,672.7 -13,673.5; 0.83; 4-8; 2.630; 1.900 SHOE; 13,672.3-13,672.7; 0.40; 4- 7; 2.390 LINER PUP; 13,646.9-13,672.3; 25.33; 4-6; 2.375; 1.992 SLOTTED LINER; 12,949.2- 13,646.9; 697.77; 4-5; 2.375; 1.992 DEPLOYMENT SLEEVE; 12,948.4 -12,949.2; 0.83; 4-4; 2.630; 1.900 SHOE; 12,948.0-12,948.4; 0.40; 4- 3; 2.390 Slotted Liner; 12,257.1-12,948.0; 690.89; 4-2; 2.375; 1.992 Aluminum Liner Top Billet ; 12,248.1-12,257.1; 9.00; 4-1; 2.630; 1.000 Slotted Liner; 11,245.1-12,293.3; 1,048.20; 5-4; 2.375; 1.992 Liner-Red; 10,346.8-11,245.1; 898.24; 5-3; 2.375; 1.992 RPERF; 10,426.0-10,444.0; 3/12/2000 CASING; 10,410.3-10,623.1; 212.85; 3-3; 7.000; 6.276 MARKER JT; 10,366.9-10,410.3; 43.38; 3-2; 7.000; 6.276 SLOTS; 10,316.0-14,648.0; 8/17/2018 SOS; 10,335.7-10,336.6; 0.93; 1- 20; 4.000; 2.992 Liner - Pup; 10,322.6-10,346.8; 24.19; 5-2; 2.375; 1.992 TUBING PUP; 10,327.6-10,335.7; 8.11; 1-19; 3.500; 2.992 NIPPLE; 10,326.6-10,327.6; 1.00; 1-18; 4.441; 2.750 CMT SQZ; 10,322.0-10,324.0; 7/4/2018 TUBING PUP; 10,316.6-10,326.6; 10.05; 1-17; 3.500; 2.992 SBR; 10,316.6-10,322.6; 6.00; 5-1; 2.630; 2.250 XO THREAD; 10,315.6-10,316.6; 0.94; 1-16; 3.500; 2.992 PACKER; 10,310.7-10,315.6; 4.90; 1-15; 6.150; 3.250 SEAL ASSY; 10,309.8-10,310.7; 0.92; 1-14; 4.000; 3.000 TUBING PUP; 10,303.7-10,309.8; 6.13; 1-13; 3.500; 2.992 TUBING; 10,272.1-10,303.7; 31.55; 1-12; 3.500; 2.992 NIPPLE; 10,270.2-10,272.1; 1.92; 1-11; 4.540; 2.812 TUBING; 10,238.6-10,270.2; 31.60; 1-10; 3.500; 2.992 TUBING PUP; 10,232.4-10,238.6; 6.17; 1-9; 3.500; 2.992 GAS LIFT; 10,223.2-10,232.4; 9.19; 1-8; 5.960; 2.867 TUBING PUP; 10,217.1-10,223.2; 6.18; 1-7; 3.500; 2.992 Tubing Punch; 5,884.0-5,884.1; 11/16/2018 TUBING; 495.0-10,217.1; 9,722.10; 1-6; 3.500; 2.992 CASING; 34.7-10,366.9; 10,332.15; 3-1; 7.000; 6.276 FLOAT SHOE; 5,021.5-5,023.1; 1.65; 2-6; 9.625; 8.921 CASING; 4,946.6-5,021.5; 74.88; 2 -5; 9.625; 8.921 FLOAT COLLAR; 4,945.3-4,946.6; 1.35; 2-4; 9.625; 8.921 CASING; 2,422.1-4,945.3; 2,523.14; 2-3; 9.625; 8.921 Tubing Punch; 3,359.0-3,359.1; 11/19/2018 CASING; 45.8-2,422.1; 2,376.33; 2 -2; 9.625; 8.535 TUBING FLOW COUPLING; 489.0 -495.0; 5.94; 1-5; 4.500; 2.920 NIPPLE; 488.0-489.0; 0.98; 1-4; 4.540; 2.812 TUBING PUP; 481.8-488.0; 6.21; 1 -3; 3.500; 2.992 TUBING; 41.6-481.8; 440.19; 1-2; 3.500; 2.992 CONDUCTOR; 43.0-121.0; 78.00; 1-1; 16.000; 15.062 HANGER; 41.8-45.8; 4.00; 2-1; 12.000; 8.535 HANGER; 37.6-41.6; 4.04; 1-1; 8.000; 3.500 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31A ... TD Act Btm (ftKB) 14,304.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020501 Wellbore Status PROD Max Angle & MD Incl (°) 95.35 MD (ftKB) 12,725.23 WELLNAME WELLBORE3H-31A H2S (ppm) 500 Date 8/24/2018 Comment SSSV: NIPPLE Annotation End Date Casing Strings Casing Description LINER, AL1 LATERAL OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 10,316.6 Set Depth (ftKB) 14,648.0 Set Depth (TVD) (… Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,316.6 5,925.1 40.43 SBR Seal Bore Receptical 2.250 12,293.7 6,083.8 92.39 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 13,324.4 6,092.6 90.03 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 14,014.6 6,097.7 89.72 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.000 Notes: General & Safety End Date Annotation NOTE: View Schematic w/ Alaska Schematic9.0 3H-31AL1, 3/27/2020 9:48:01 AM M D (ft K B) -2,021.3 -2,017.1 -2,013.8 -1,997.7 -1,981.6 -1,979.3 -1,971.1 -1,048.6 0.0 37.7 43.0 121.1 488.2 495.1 3,349.1 3,358.9 3,365.2 4,945.2 5,021.3 5,023.3 5,878.9 5,884.2 5,895.0 10,217.2 10,232.3 10,270.3 10,303.8 10,309.7 10,315.0 10,315.9 10,321.9 10,324.1 10,327.8 10,335.6 10,346.8 10,410.1 10,434.1 10,442.9 10,445.9 10,471.1 10,549.9 10,730.0 12,243.1 12,293.6 13,324.1 13,325.1 14,014.4 14,304.1 14,648.0 Vertical schematic (actual) BASE …KALU…UPPE… K-1 M…LOWE… KUPA… KUPA… KUPA… UNIT …UNIT … UNIT … C-4 IN… C-4 IN… C-4B … UNIT … UNIT … A-2 IN… A-1 IN… A-1 IN… Shoe; 14,647.6-14,648.0; 0.40; 5- 14; 2.375; 1.992 Slotted Liner; 14,015.4-14,647.6; 632.20; 5-13; 2.375; 1.992 DEPLOYMENT SLEEVE; 14,014.6- 14,015.4; 0.83; 5-12; 2.375; 1.000 Shoe; 14,014.2-14,014.6; 0.40; 5- 11; 2.375; 1.992 Slotted Liner; 13,325.2-14,014.2; 688.95; 5-10; 2.375; 1.992 DEPLOYMENT SLEEVE; 13,324.4- 13,325.2; 0.83; 5-9; 2.375; 1.000 Shoe; 13,324.0-13,324.4; 0.40; 5-8; 2.375; 1.992 Slotted Liner; 12,294.5-13,324.0; 1,029.49; 5-7; 2.375; 1.992 DEPLOYMENT SLEEVE; 12,293.7- 12,294.5; 0.83; 5-6; 2.375; 1.000 Shoe; 12,293.3-12,293.7; 0.40; 5-5; 2.375; 1.992 Slotted Liner; 11,245.1-12,293.3; 1,048.20; 5-4; 2.375; 1.992 Liner-Red; 10,346.8-11,245.1; 898.24; 5-3; 2.375; 1.992 RPERF; 10,426.0-10,444.0; 3/12/2000 CASING; 10,410.3-10,623.1; 212.85; 3-3; 7.000; 6.276 MARKER JT; 10,366.9-10,410.3; 43.38; 3-2; 7.000; 6.276 SLOTS; 10,316.0-14,648.0; 8/17/2018 SOS; 10,335.7-10,336.6; 0.93; 1- 20; 4.000; 2.992 Liner - Pup; 10,322.6-10,346.8; 24.19; 5-2; 2.375; 1.992 TUBING PUP; 10,327.6-10,335.7; 8.11; 1-19; 3.500; 2.992 NIPPLE; 10,326.6-10,327.6; 1.00; 1 -18; 4.441; 2.750 CMT SQZ; 10,322.0-10,324.0; 7/4/2018 TUBING PUP; 10,316.6-10,326.6; 10.05; 1-17; 3.500; 2.992 SBR; 10,316.6-10,322.6; 6.00; 5-1; 2.630; 2.250 XO THREAD; 10,315.6-10,316.6; 0.94; 1-16; 3.500; 2.992 PACKER; 10,310.7-10,315.6; 4.90; 1-15; 6.150; 3.250 SEAL ASSY; 10,309.8-10,310.7; 0.92; 1-14; 4.000; 3.000 TUBING PUP; 10,303.7-10,309.8; 6.13; 1-13; 3.500; 2.992 TUBING; 10,272.1-10,303.7; 31.55; 1-12; 3.500; 2.992 NIPPLE; 10,270.2-10,272.1; 1.92; 1 -11; 4.540; 2.812 TUBING; 10,238.6-10,270.2; 31.60; 1-10; 3.500; 2.992 TUBING PUP; 10,232.4-10,238.6; 6.17; 1-9; 3.500; 2.992 GAS LIFT; 10,223.2-10,232.4; 9.19; 1-8; 5.960; 2.867 TUBING PUP; 10,217.1-10,223.2; 6.18; 1-7; 3.500; 2.992 Tubing Punch; 5,884.0-5,884.1; 11/16/2018 TUBING; 495.0-10,217.1; 9,722.10; 1-6; 3.500; 2.992 CASING; 34.7-10,366.9; 10,332.15; 3-1; 7.000; 6.276 FLOAT SHOE; 5,021.5-5,023.1; 1.65; 2-6; 9.625; 8.921 CASING; 4,946.6-5,021.5; 74.88; 2 -5; 9.625; 8.921 FLOAT COLLAR; 4,945.3-4,946.6; 1.35; 2-4; 9.625; 8.921 CASING; 2,422.1-4,945.3; 2,523.14; 2-3; 9.625; 8.921 Tubing Punch; 3,359.0-3,359.1; 11/19/2018 CASING; 45.8-2,422.1; 2,376.33; 2 -2; 9.625; 8.535 TUBING FLOW COUPLING; 489.0- 495.0; 5.94; 1-5; 4.500; 2.920 NIPPLE; 488.0-489.0; 0.98; 1-4; 4.540; 2.812 TUBING PUP; 481.8-488.0; 6.21; 1 -3; 3.500; 2.992 TUBING; 41.6-481.8; 440.19; 1-2; 3.500; 2.992 CONDUCTOR; 43.0-121.0; 78.00; 1-1; 16.000; 15.062 HANGER; 41.8-45.8; 4.00; 2-1; 12.000; 8.535 HANGER; 37.6-41.6; 4.04; 1-1; 8.000; 3.500 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 2/13/1994 3H-31AL1 ... TD Act Btm (ftKB) 14,648.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020560 Wellbore Status PROD Max Angle & MD Incl (°) 93.69 MD (ftKB) 11,413.25 WELLNAME WELLBORE3H-31A H2S (ppm) 500 Date 8/24/2018 Comment Annotation End Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS R luE FEB 15 2015 1. Operations Abandon 71 Plug Perforations U Fracture Stimulate LJ Pull Tubing L Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool El Repair Well Q Re-enter Susp Well ❑ Other: Tubing Patches ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory Ell Stratigraphic ❑ Service ❑ 218-075-0 3. Address: PO Box 100360 6. API Number: Anchorage, AK 99510 50-103-2020501-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025531 JADL0025524 KRU 3H -31A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,304' feet Plugs measured N/A feet true vertical 6097' feet Junk measured N/A feet Effective Depth measured 14,304' feet Packer measured 10,311' feet true vertical 6097' feet true vertical 5921' feet Casing Length Size MD TVD Burst Collapse Conductor 78 16" 121 121 Surface 4981 95/81, 5023 3263 Production 10677 7" 10,712 6065 Perforation depth Measured depth NA feet True Vertical depth NA feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 10337' 5940' Packers and SSSV (type, measured and true vertical depth) Packer Baker SAB -3 Permanent 10311' 5921' Liner Top Packer Northerm Solutions 10308' 5919' Lower Patch Packer Paragon II Packer 5891' 3672' Upper Patch Packer Paragon II Packer 5875' 3664' Lower Patch Packer Paragon If Packer 3365' 2509' Upper Patch Packer Paragon II Packer 3349' 2502' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: I N/A N/A N/A N/A N/A Subsequent to operation: I N/A N/A N/A N/A N/A 14. Attachments (required per20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and Correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Rachel Kautz Contact Name: Rachel Kautz/Sara Carlisle Authorized Title: Well Integrity Supervisor Contact Email: N2549(rDconocoohillios com 2 L7 Authorized Signature: Date: Z / �� / Contact Phone: 659-7126 Form 10-404 Revised 4/2017 RBDMS�- FEB 19 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2019 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7s' Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patches set across tubing punches in producer KRU 3H -31A (PTD 218-075). Please contact Sara Carlisle or myself at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska, Inc. Date Event Summary Executive Summary 11/16/18 11/17/18 11/18/18 11/19/18 Kuparuk well 31-1-31A was to have two POGLM assemblies installed. Tubing punches were made at -5884' and -3359'. After difficulty setting the POGLM assemblies across the tubing punches, typical blank pipe patches were set across the tubing punches instead to restore integrity. Tubing integrity was confirmed by a passing MITIA to 2500 psi. BRUSH & FLUSH TBG INTERVALs FROM 3300' TO 3400' RKB & 5800' TO 6000' RKB. DRIFTED 2.73" x 20' DMY PATCH TO 6040' RKB. SHOOT 2" x 2' TBG PUNCH, 1 spf, 0° PHASE @ 5884' ELMD. CORRELATE TO SLB CALIPER 3 -JULY -2018. SET 2.72" P2P (#CPP35029) MID-ELEM @ 5891.5' ELMD. IN PROGRESS. CMIT TO 2500 (PASS) W/ TEST TOOL IN P2P @ 5891.5' ELMD. PUMPED 5 BBLS @ 1 BPM TAKING RETURNS OFF IA. 1500 TBG / 1200 IA. SET 2.72" P2P (#CPP35194), SPACER PIPE, POGLM (1" BTM - DV (5884' ELMD)), SPACER PIPE, ANCHOR LATCH (#CPAL35099) MID-ELEM @ 5877.35' ELMD. ATTEMPT MITIA (FAIL). MITTTO 2500 (PASS) W/ TEST TOOL IN P2P @ 5877.35' ELMD. PULLED DV @ 5884' ELMD AND SET NEW. ATTEMPT MITIA (FAIL) IN PROGRESS. PULLED UPPER POGLM ASSY @ 5877.35' ELMD (ANCHOR LATCH SHEARED). ATTEMPTTO SET POGLM ASSY; UNABLE TO STING IN (ANCHOR LATCH SHEARED). SET 2.72" P2P (#CPP35092), SPACER PIPE, POGLM (1" BTM -DV (5884' ELMD)), SPACER PIPE, ANCHOR LATCH (#CPAL35079) MID- ELEM @ 5877.35' ELMD. MITIA TO 2500 (PASS). PULLED DV IN POGLM @ 5884' ELMD & SET OV. DDT ON IA PASSED. IN PROGRESS. SET 2.72" P2P (#CPP35189) MID-ELEM @ 3366.5' ELMD. CORRELATE TO SLB CALIPER 3 -JULY -2018. MITT TO 2500 (PASS) W/ TEST TOOL IN P2P. SHOT 2" x 2' TBG PUNCH, 1 spf, 0° PHASE @ 3359' ELMD. SET2.72" P2P (#CPP35195), SPACER PIPE, POGLM (3359' ELMD, 1" BTM -GLV), SPACER PIPE, ANCHOR LATCH (#CPAL35100) MID-ELEM @ 3352.35' ELMD. MITT TO 2500 ( PASS) W/ TEST TOOL IN P2P. DDT ON IA PASSED. JOB COMPLETE AND READY FOR DHD TO TIFL. 11/22/18 ITIFIL (FAILED DUE TO INFLOW & PRESSURE INCREASE). 12/04/18 12/05/18 12/09/18 12/27/18 BRUSH n' FLUSH TBG TO 3352' RKB, PULLED GLV FROM POGLM @ 3356' RKB VLV, (SLIGHT ERROSION ON VLV NOGG, SEALS LOOK NEW). PULLED UPPER 2.72" P213 W/ POGLM ASSEMBLY @ 3352' RKB ( NO VISIBLE EXTERNAL ERROSION TO POGLM), PULLED OV @ 5881' RKB (SLIGHT EROSION ON VLV, LOOKS GOOD NOTHING IN CHECKS, PKG LOOK NEW), SET 2.72" P213 10' BLANK & ANCHOR ASSEMBLY @ 3351.14' RKB. IN PROGRESS. RAN 1" EZ SIDE POCKET TEST TOOL IN POGLM @ 5881' RKB MITIA FAILED W/ LINEAR LEAK, SET 1" BTM LATCH DV @ 5881' RKB ATTEMPT TO BLEED IA FAILED. JOB POSTPONED FOR PLAN FORWARD. RAN TTS TEST TOOL TO P2P PACKER @ 3351'RKB, GOOD TBG TEST. PULL UPPER PACKER & SPACER PIPE. RAN TTS TEST TOOL TO LOWER PACKER@3366'RKB. PASSING CMIT. PULLED TTS TEST TOOL. DIAGNOSTICS COMPLETE, WAITING FOR PLAN FORWARD. PULLED 2.72 P2P PACKER @ 3366' RKB, PULLED 2.72" P2P PACKER POGLM ASSEMBLY @ 5877' RKB, SET 3 1/2 TTS TEST TOOL IN 2.72 P2P PACKER @ 5891' RKB, GOOD TBG x IA TEST TO 2500 PSI FOR 10 MIN'S. IN PROGRESS. 12/28/18 12/29/18 12/30/18 12/31/18 01/01/19 01/02/19 01/19/19 01/22/19 LOAD TBG & IA W/ 130 BBLS INHIBITED SEAWATER & 80 BBLS DIESEL U -TUBE FREEZE PROTECT, CMIT TBG x IA 2500 PASS ON LOWER 2.72 P2P PACKER @ 5891' RKB, PULLED 3 1/2 TTS TEST TOOL @ 5891' RKB, SET 2.72" P2P PACKER SPACER ANCHOR ASSEMBLY @ 5876' RKB (OAL 15.85' / SN: CPP35198). IN PROGRESS. CMITTBG x IA 2500 PSI UPPER 2.72 P2P PACKER / PATCH ASSEMBLY @ 5867' RKB PASS, SET LOWER 2.72" P2P PACKER @ 3365' RKB, CMITTBG x IA 2500 PASS, SET UPPER 2.72" P2P PACKER POGLM ( BTM DV) SPACER ANCHOR ASSEMBLY @ 3350' RKB, MIT IA FAILED, BLEED IA TO 375 PSI FOR DRAW DOWN OVER NIGHT. IN PROGRESS. DRAW DOWN TEST GOOD ON IA OVER NIGHT, MIT IA FAILED, PULLED DV FROM POGLM @ 3359' RKB, SET DV W/ FREUDENBERG PACKING, MIT IA FAILED, PULLED DV @ 3359' RKB PACKING DAMAGED, SET DV W/ HIGH SEALABILITY PACKING @ SAME, MIT IA FAILED, PULLED 2.72" P2P PACKER POGLM ASSEMBLY @ 3350' RKB. IN PROGRESS. RAN 3 1/2 TTS TEST TOOL TO 2.72 P2P PACKER @ 3365' RKB CMITTBG x IA PASS, SET 2.72" P2P PACKER POGLM ANCHOR ASSEMBLY @ 3350' RKB WITH DV, MIT IA FAILED, RAN 3 1/2 TTS TEST IN UPPER 2.72" P2P PACKER @ 3350' RKB MIT TBG 2500 PASS, PULLED 2.72" P2P POGLM ASSEMBLY ELEMENTS SNAP LATCH & DV LOOK GOOD. IN PROGRESS. RAN 3 1/2 TTS TESTTOOL TO LOWER P2P PACKER @ 3365' RKB CMITTBG x IA 2500 PASS, SET 2.72 P2P PACKER @ 3347' RKB, MIT IA FAILED W/ LLR OF .3 BPM @ 2450 PSI, PULLED 2.72" P2P PACKER POGLM ASSEMBLY @ SAME, SET TTS TESTTOOL IN P2P PACKER @ 3365' RKB, CMITTBG x IA 2500 PASS. IN PROGRESS. SET 2.72" P2P PATCH ASSEMBLY (OAL 20.86'/ SN: CPP35143 / CPAL351001.60" ID) @ 3344.98' ME RKB, MIT IA 2500 FAILED WITH LLR .52 BPM @ 2450 PSI, RAN 3 1/2 TTS TESTTOOL TO 2.72" P2P @ 3344.98' RKB PASS, RAN SPINNER TEMP LOG UP FROM 3337' RKB TO SURFACE UNABLE TO SEE FLOW OR TEMP SHIFT. IN PROGRESS. RIH W/ 1 3/8" LDL TOOLS. PERFORM UP/DOWN PASSES OVER INTERVAL 10200'- 10400' AND STOP COUNTS @ 10320'& 10310'. PERFORM MAIN DYNAMIC PASS FROM 104001- 301. TEMPERATURE ANOMALY @ TOP PATCH (3355' RKB). AFTER FURTHER ANALYSIS APPEARS THAT CHANGE IN SPINNER AT 10310' IS 2 3/8" LINER. ONLY LEAK APPEARS TO BE AT UPPER PATCH. PULLED UPPER 2.72 P2P PACKER PATCH ASSEMBLY @ 3345' RKB, RAN 3 1/2 TTS TESTTOOL TO LOWER 2.72 P2P PACKER @ 3365' RKB CMIT TBG x IA PASS, SET 2.72 P2P PACKER PATCH ASSEMBLY @ 3349' RKB. MIT IA 2500 PASS. COMPLETE. MITIA to 2500 psi Results Pre-MITIA T/1/0= 1525/1560/40 Pressure up IA. Initial T/1/0= 1525/2525/40, 15 MIN T/1/0= 1525/2450/40 (-75) 30 MIN T/1/0= 1525/2425/40 (-25) PASS Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: n -� *1 AOGCC s ATTN: Natural Resources Technician II Alaska oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -WAj Anchorage, AK 99501 218075 30307 • •I 30 -Jan -19 30Ja n19.1W 01 WELL NAME 18-102 API # 50.029-23167-00 ORDERSERVICE EOSH•00015 FIELD NAME rCRIPTION KUPAa-91 All :4 LIA ml -.4111 DELIVERABLE DESCRIPTIONr. Caliper Ver2 FINAL FIELD Color DATELOGGED Prints 1-Jan•19 CD's 1 1J-10 1H-119 3H -31A 3M-19 1 H•116 1C-117 50-029-23010.00 50-029-23591-00 50.103-20205-01 50-029-21737-00 50-029.23594.00 50-029-23027-00 EOSH-00017 EOSH-00018 EOSH-00019 EOSH-00020 EOSH-00021 EOSH-00022 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL1 WL Caliper IPROF1 LDL LDL (PROF RST-WFL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 17 -Jan -19 18 -Jan -19 19 -Jan -19 20 -Jan -19 21 -Jan -19 22 -Jan -19 1 1 1 1 7 Signature courier or sign/scan and email a copy 0 Date and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package hare been verified to match the media noted above. The specific cortent of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. DATA SUBMITTAL COMPLIANCE REPORT 1/912019 Permit to Drill 2180750 Well NamelNo. KUPARUK RIV UNIT 311-31A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20205.01.00 MD 14304 TVD 6097 REQUIRED INFORMATION Completion Date 8/17/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No Mud Log No J DATA INFORMATION List of Logs Obtained: GR/ Res Well Log Information: Log! Electr Data Digital Dataset Type Med/Frmt Number Name ED C 29658 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data 29658 Digital Data Samples No Z Log Log Run Scale Media No Directional Survey Yes (from Master Well Data/Logs) Interval OH/ Start Stop CH Received Comments 10320 14304 8/31/2018 Electronic Data Set, Filename: 3H -31A GAMMA RES.Ias 8/31/2018 Electronic File: 3H -31A 2MD Final Log.cgm 8/31/2018 Electronic File: 3H -31A 51VID Final Log.cgm 8/31/2018 Electronic File: 3H -31A 5TVDSS Final Log.cgm 8/31/2018 Electronic File: 3H -31A 21VID Final Log.pdf 8/31/2018 Electronic File: 3H -31A 5MD Final Log.pdf 8/31/2018 Electronic File: 3H -31A 5TVDSS Final Log.pdf 8/31/2018 Electronic File: 3H -31A EOW - NAD27.pdf 8/31/2018 Electronic File: 3H -31A EOW - NAD27.W 8/31/2018 Electronic File: 3H -31A Final Surveys TO 14304'.csv 8/31/2018 Electronic File: 3H -31A Final Surveys TO 14304'.xlsx 8/31/2018 Electronic File: 3H -31A Survey Listing.bd 8/31/2018 Electronic File: 3H -31A Surveys.txt 8/31/2018 Electronic File: 3H- 31 A_25_tapescan_BHI CTK.txt 8/31/2018 Electronic File: 3H -31A_5_ tapescan_13HI_CTK.txk 8/31/2018 Electronic File: 3H-31A_output.tap 8/31/2018 Electronic File: 3H -31A 2MD Final Log.tif 8/31/2018 Electronic File: 3H -31A 5MD Final Log.tif AOGCC Page 1 of 3 Wednesday, January 9, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/9/2019 Permit to Drill 2180750 Well Name/No. KUPARUK RIV UNIT 3H -31A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20205-01-00 MD 14304 TVD 6097 Completion Date 8/17/2018 Completion Status 1-011- Current Status 1 -OIL UIC No ED C 29658 Digital Data 8/31/2018 Electronic File: 3H -31A 5TVDSS Final Log.tif Log C 29658 Log Header Scans 0 0 2180750 KUPARUK RIV UNIT 31-1-31A LOG Release Date: 7/5/2018 HEADERS ED C 29783 Digital Data 10/12/2018 Electronic File: 31-1-31A EOW - NAD27.pdf ED C 29783 Digital Data 10/12/2018 Electronic File: 3H -31A EOW - NAD27.txt ED C 29783 Digital Data 10/12/2018 Electronic File: 3H -31A EOW - NAD83.pdf ED C 29783 Digital Data 10/12/2018 Electronic File: 3H -31A EOW - NAD83.txt Log C 29783 Log Header Scans 0 0 2180750 KUPARUK RIV UNIT 31-1-31A LOG HEADERS Well Cores/Samples Information: _-- Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Y� Directional I Inclination Data (� Mud Logs, Image Files, Digital Data Y / lA Core Chips Y / A Production Test Informatior� NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Y� Core Photographs Y / A Geologic Markers/Tops O Daily Operations Summary L/ Cuttings Samples Y / 11 Laboratory Analyses Y / A COMPLIANCE HISTORY Completion Date: 8/17/2018 Release Date: 7/5/2018 Description Date Comments Comments: AOGCC Page 2 of 3 Wednesday, January 9, 2019 DATA SUBMITTAL COMPLIANCE REPORT 119/2019 Permit to Drill 2180750 Well Name/No. KUPARUK RIV UNIT 3H -31A MD 14304 TVD 6097,Completion Date 8/17/2018 Compliance Reviewed By: Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20205-01-00 Completion Status 1-0I1- Current Status 1-0I1 ) UIC No Date: / l 9 I /I A0G('(Page3oP3 Wednesday, January 9- 20 19 To: hER CJHES a U company Date: October 11, 2018 Meredith Guhl AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: 21 807:) 29733 Letter of Transmittal Michael Soper/Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT GREATER MOOSES TOOTH UNIT 3H -31A 3H-31AL1 MT6-03PH MT6-03 E 1H -21A IH-21AL1 MT6-05PB1 MT6-05PB2 RECEly C� 1H-21AL2 1H-21AL2-01 MT6-05 MT6-05L1 P�GGG MT6-08PB1 MT6-O8 (14) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -31A 50-103-20205-01 Baker Hughes INTEQ Definitive Survey Report 20 August, 2018 BAT(ER UGHES a GE company 21 8075 29783 Baker Hughes INTEQ BA ER ConocoPhilli s i� Definitive Survey Report twNEs Company: . ConooPhilliPs (Alaska)IncKup2 Local Co-ordinate Reference: Well 31-1-31 Project: Kuparuk River Unit TVD Reference: 3H-31 @ 80.00usft (31-1-31) Site: Kuparuk 311 Pad MD Reference: 31-1-31 @ 80.00usft (3H-31) Well: 31-1-31 North Reference: True Wellbore: 31-1-31 Survey Calculation Method: Minimum Curvature Design: 31-1-31 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 3H-31 Well Position +NAS 0.00 usft Northing: 6,000,687.91 usft Latitude: 70° 24'47,208 N +EuW 0.00 usft Fasting: 498,655.24usft Longitude: 150° 0'39.425 W `. Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3H -31A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°1 0 (nT) BGGM2018 9/1/2018 16.92 80.91 57,441 Design 3H -31A-- - Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10.409 00 Vertical Section: Depth From (TVD) -NAS +E/ -W Direction (usft) (usft) (usft) (°) 80.00 0.00 0.00 330.00 I Program Survey Date From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 8820 10,409.00 311-31 (3H-31) GCT -MS Schlumberger GCT mulfishot 1/12/2001 10,435.00 10,520.11 3H-31AMWD-INC(311-31A) MWD -INC ONLY MWD -INC_ ONLY FILLER 7/31/2018 8/1/2018 g 10,550.81 14,271.84 3H-31AMWD(3H-31A) MWD MWD - Standard 8/1/2018 8O/2018 8202018 12:29:59PM Page 2 COMPASS 5000.14 Build 85 Baker Hughes INTEQ BT WHES 0 ConocoPhilli s p Definitive Survey Report Company: Con000Phillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kuparuk 311 Pad Well: 31-1-31 Wellbore: 3H-31 Design: 314-31 Survey Local Cc -ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-31 3H-31 @ 80.00usft (3H-31) 3H-31 @ 80.00usft (3H-31) True Minimum Curvature OAKEDMP2 Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 82012018 12:29:59PM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing Eating DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ollow Survey Tool Name 10,409.00 40.27 34207 5,995.54 5,915.54 7,756.65 -1,617.44 6,008,444.07 497,03936 0.20 7,526.17 MWD-INC_ONLY (2) 10,435.00 40.23 347.03 6,015.39 5,935.39 7,773.02 -1,621.20 6,008,460.45 497,035.60 0.18 7,542.23 MWD -INC ONLY(2) 10,460.32 47.70 345.00 6,033.60 5,953.60 7,790.06 -1,625.47 6,008,477.48 497,031.34 30.02 7,559.12 MWD -INC _ONLY (2) 10,490.14 61.00 344.00 6,050.94 5,97094 7,813.35 -1631.94 6,008,500.77 497,024.87 44.68 7,582.53 MWD -INC _ONLY (2) 10.520.11 74.56 34300 6062.25 S.982.25 7,839.89 -1,639.82 6,008,527.31 497,017.00 45.35 7,609.45 MWD -INC _ONLY (2) 10,550.81 88.50 341.63 6,066.76 5,986.76 7,868.74 -1,649.02 6,008,556.16 497,007.80 45.62 7,639.04 MWD(3) 10,585.35 90.61 342.22 6,067,03 5,9a7.03 7,901.58 -1,659.74 6,008,58899 496,99709 6.34 7,672.84 MWD (3) 10,614.39 92.00 344.55 6,065.37 5,986.37 7,929.39 -1,668.04 6,008,616.81 496,988.79 9.34 7,701.08 MWD (3) 10,645.05 91.35 346.98 6,065.47 5,98547 7,959.10 -1,675.58 6,006,646.51 496,981.26 8.20 7,730.57 MWD (3) 10,68044 91.07 34969 6,064.72 5,964.72 7,993.74 -1,682.73 6,008,681.16 496,974.12 7.70 7,764.15 MWD (3) 10,710.55 89.45 35190 6,064.59 5,964.59 8,023.46 -1,687.55 6,008,710.88 496,969.31 9.10 7,792.30 MWD (3) 10,741.32 89.94 353.98 6,064.75 5,984.75 8,054.0 -1,691.33 6,008,74141 496,965.53 6.94 7,820.63 MWD (3) 10,765.17 89.75 354.94 6,064.81 5,984.81 8,077,74 -1,693.63 6,008,765.14 496,963.23 4.10 7,842.34 MWD (3) 10,795.51 89.57 357.31 6,064.99 5,964.99 8,108.00 -1.695.68 6,008,795.41 496,961.19 7.83 7,869.58 MWD (3) 10,83037 8963 0.04 6,065.24 5,985.24 8,142.85 -1,696.49 6,008,83025 496,960.39 7.83 7,900.16 MWD(3) 10,860.74 88.65 0.94 6,065.69 5,985.69 8,173.22 -1,696.23 6,008,860.61 496,960.65 4.38 7,926.33 MWD (3) 10,892.63 89.54 4.65 6,066.20 5,986.20 8,205.06 -1,694.67 6,008,892.45 496,962.22 11.99 7,953.12 MWD(3) 10,925.85 88.22 5.87 6,066.85 5,986.85 8,238.13 -1,691.62 6,008,925.52 496,965.27 5.39 7,980.24 MWD (3) 10,957.15 86.37 7.14 6,068.32 5,988.32 8,269.19 -1,688.08 6,008,956.58 496,968.82 7.17 8,005.37 MWD (3) 10,986.98 84.65 7.40 6,070.66 5,990,66 8,298.69 -1,684.32 6,008,986.07 496,972.59 5.83 8,029.03 MWD (3) 11,016.63 85.05 10.30 6,073.32 5,993.32 8,327.87 -1,679.77 6,009,01525 496,977.13 9.83 8,052.03 MWD (3) 11,047.09 87.05 1063 6,07542 5,995.42 8,357.75 -1674.25 6,003,045.12 496,98266 665 8,075.15 MWD (3) 11,081.18 88.96 11.85 6,07661 5,996.61 8,391.16 -1.667,61 6,009,078.53 496,989.30 665 8,100.76 MWD (3) 11,111.42 89.75 13.23 6,076.95 5,996.95 8,420.68 -1,661.05 6,009,108.04 496,995.87 5.26 8,123.04 MWO(3) 11,142.86 90.61 14.41 6,076.85 5,996.85 8,451.20 -1,653.54 6,009,138.57 497,003.39 4.64 8,145.73 MWD(3) 11,17405 92.18 19.0 6,076.09 5,996.09 8,481.06 -1,644.58 6,009,168.42 497,012.35 15.55 8167.10 MWD (3) 11,201.38 91.11 19.73 6,075.30 5,995.30 8,506.83 -1635.52 6,009,194.19 497,021.41 4.74 8,184.89 MWO(3) 11,231.43 9006 21.36 6,075.00 5,995.00 8,534.97 -1,624.98 6,009,222.32 497,031.96 6.45 8,203.99 MWD(3) 11,262.01 89.35 20.70 6,075.15 5,995.15 8,563.51 -1,614.00 6,009,250.86 497,042.94 3.17 8,22322 MWD (3) 11,291.42 8606 20.67 6,075.82 5,995.82 8,591.02 -1,603.62 6,009,278.36 497,053.33 4.39 8,241.85 MWD (3) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 82012018 12:29:59PM Page 3 COMPASS 5000.14 Build 85 Baker Hughes INTEQ UER ConocoPhilli S Definitive Survey Report 5,2 ES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 311 Pad Well: 3H-31 Wellbore: 3H-31 Design: 3H-31 Survey Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-31 3H-31 @ 80.00usft(3H-31) 311-31 @ 80.00usft (3H-31) True Minimum Curvature OAKEDMP2 8/202018 12:29: 59PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 1 11,322.50 87.61 2059. 6,076.99 5,996.99 8,620.08 -1,592.67 6,009,30742 497,064.28 1.47 8,26155 MWD(3) I 11,351.86 89.57 2162 6,077.72 5,997.72 8,647.46 -1,582.11 6,009,33479 497,074.85 7.54 8,279.98 MWD (3) 11,382.34 92.06 2265 6,077.28 5,99]28 8,675.69 -157062 8,009,363.02 497,086.33 8.84 8,298.68 MWD (3) 11,41324 93.69 20.00 6,075.73 5,995.73 8,704.44 -1,55940 6.009,391.76 497,097.56 10.06 8,317.96 MN/D(3) 11,442.84 90.09 12.70 6,074.75 5,994.75 8,732.80 -1,551.08 6,009,420.12 497,105.88 27.48 8,338.37 MWD (3) 11,471.44 89.79 6.62 6,074.78 5,994.78 8,760.98 -1,546.29 6,009,448.29 497,110.69 21.28 8,360.38 MWD (3) p 11,500.33 92.37 5.25 6,074.24 5,994.24 8,789.71 -1,543.30 6,009,477.02 497,113.68 10.11 8,383.76 MWD(3) 11,531.24 92.73 1.90 6,072.86 5,992.86 8,820.52 -1,541.37 6,009,507.83 497,115.61 10.89 8,409.49 MWD (3) 11,560.56 9323 35984 6,071.34 5,991.34 8,849.80 -1,540.93 6,009,537.10 497,116.06 7.22 8,434.62 MWD(3) 11,589.70 92.40 35698 6,06991 5,989.91 8,878.89 -1,541.74 6,009,566.19 497,115.26 10.21 8,460.21 MWD (3) 11,62176 91.01 358.25 6,068.95 5,988.95 8,910.91 -1,543.07 6,009,598.20 497,113.93 5.87 8,488.61 MWD (3) 11,651.50 90.74 0.26 6,068.50 5,968.50 8,940.64 -1,543.46 6,009,627.93 497,113,55 6.82 8,514.55 MWD(3) 11,680.18 90.52 0.62 6,068.19 5,988.19 8,969.32 -1,543.24 6,009,656.61 497,113.77 1.47 8,539.27 MWD(3) 11,711.32 88.68 0.75 6,068.40 5,988.40 9,000.45 -1,542.86 6,009,687.74 497,114.15 5.92 8,556.05 MWD (3) 11,741.02 89.23 2.93 6,068.94 5,988.94 9,030.13 -1,541.91 6,009,717.41 497,115.11 7.57 8,591.28 MWD (3) 11,770.90 90.25 4.20 6,069.08 5,989.08 9,059.95 -1,64005 6,009,74723 497,116.97 5.45 8,616.17 MWD(3) n 11,801.16 89.97 5.81 6,069.02 5,989.02 9,090.09 -1,537.41 6,009,77737 497,119.62 540 8,640.96 MWD (3) 11,831.52 89.26 8.10 6,069.23 5,98923 9,120.23 -1,533.74 6,009,80750 497,123.30 7.90 8,665.22 MWD(3) - 11,860.66 89.97 1141 6,059.42 5,989,42 9,148.94 -1,52880 6,009,836.21 497,128.24 1162 8,687.62 MWD (3) • 11,890.35 89.18 12.13 6,069.56 5,989.56 9,178.01 -1,522.74 6,00986527 497,134.30 2.93 8)09]6 MWD (3) 11,921,38 88.37 1042 6,070.15 5,990.15 9,208.43 -1,516.68 6,009,89569 497,140.37 6.57 8,733.08 MWD (3) 11,951.28 SSW 793 6,07109 5,991.09 9,237.93 -1,511.91 6,009,925.19 497,145.14 8.42 8,756.24 MM (3) 11,980.46 88.89 5.56 6,071.89 5,991.89 9,266.90 -1,50649 6.(W,954 15 497,148.57 8.67 8,779.61 MWD(3) 12,011.06 87.97 3.70 6,072.72 5,992.72 9,29738 -1,506.02 6,009,98463 497,151.04 6.78 8,804.78 MWD(3) 12,045.74 85.54 0.75 6,074.69 5,994.69 9,331.98 -1,504.67 6,010,019.22 497,152.40 11.01 8,834.07 MM (3) 12,071.64 86.37 358.14 6,076.51 5,996.51 9,357.81 -1,504.93 6,010,045.05 497,152.15 10.55 8,856.56 MWD (3) 12,10138 88.09 356.39 6,077.95 5,997.95 9,387.48 -1,506.34 6,010,074.72 497,150.74 8.25 8,882.96 MWD (3) 12,131.47 88.22 355.84 6,078.92 5,998.92 9,417.48 -1,508.38 6,010,104]2 497,148.71 1,88 8,909.97 MM (3) 12,162.46 86.25 351.27 6,080.42 6,000.42 9,448.23 -1,511.85 6,010,135.47 497,145.24 16.04 8,938.33 MWD (3) 12,191 28 8785 349.35 6,08190 6,001,90 9,476.60 -1,516.70 6,010,163.83 497,140.40 8.67 8,965.32 MWD (3) 12,22168 88.19 34741 6,082.95 6,002.95 9,506.36 -1,522.82 6,010193.59 497,134.29 648 8,994.15 MWD(3) 8/202018 12:29: 59PM Page 4 COMPASS 5000.14 Build 85 Baker Hughes INTEQ 6A R ConocoPhilli $ Definitive Survey Report UGt ES r Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit i Site: Kupamk 3H Pad 3. Well: 311-31 Wellbore: 311-31 � Design: 3H-31 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-31 311-31 @ 80.00usft (31-1-31) 311-31 @ 80.00usft (3H-31) True Minimum Curvature OAKEDMP2 iSurvey ...�_e.,,.... MD (usft) 12,256.48 12,281.05 12,309]8 12,341.96 12,389.81 12;397.33 12,429.99 12,460 27 12,490.06 12,520.95 12,545.17 t 12,574.98 12,604.93 12,635.08 12,655 48 E 12,69547 i 12,725.23 12,755.47 12,784 95 i 12,815.87 12,895.20 12,875.01 12,905.44 12,935,58 12,969.09 13,000.52 13,03039 i 13,060.89 13,090.81 13,12075 13.145.58 Inc 86.80 87.54 89.32 87.73 86.68 86.96 84,49 86.12 85,61 87.23 88.19 90.18 91.69 92.28 93.60 94.70 95.35 93.94 92.18 90.40 90.03 88.93 88.43 88.19 89.57 89.69 91 41 91.20 88.99 90.74 9129 Annotation 8202018 12.29:59PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical Azi TVD TVDSS +N/ -S +EI -W Northing Eating DLS Section (I (usft) (usft) (usft) (usft) (0/100 Survey Tool Name 343.83 6.08447 6,004.47 9,540.03 -1,531.45 6,01022726 497.125.66 11.03 9,027.63 MWD(3) 340.91 6085.68 6,005.68 9,563.41 -1,538.88 6,010,250.64 497,118.23 12.25 9,051.60 MWD(3) 340.39 6,086.47 6006.47 9,590.51 -1,548.40 6,010,277.74 497,108.73 6.45 9,079.82 MWD(3) 337.86 6,087.30 6,007.30 9,620.56 -1,559.86 6,010,30779 497,097.27 9.28 9,111.58 MM (3) 334.69 6,088.66 6,008.66 9,646.03 -1,571.05 6,010,333.25 497,086.09 11.98 9,139.23 MWD(3) 336.15 6,090.19 6,010.19 9,671.01 -1,582.48 6,010,358.24 497,074.66 5.39 9,166.58 MWD(3) 333.62 6,092.62 6,012.62 9,700.50 -1,596.30 6,010,387.73 497,060.85 10.81 9,199.03 MM (3) 33470 6,095.10 6,015.10 9,727.66 -1,609.45 6,010,414.88 497,04770 6.45 9,229.12 MWD(3) 329.66 6,097.25 6,017.25 9,753.93 -1,623.31 6,010,441.15 497,033.85 16.96 9,258.80 MWD(3) 329.30 6,099.18 6,019.18 9,76].49 -1,638.97 6,010,467.71 497,018.20 5.37 9,28963 MWD(3) 32563 6,100.14 6,020.15 9,800.88 -1,651.98 6,010.488.11 497,005.19 15.65 9,313.80 MWD(3) 325.93 6,100.57 6,020.57 9,825.53 -1,668.74 6,010,512.76 496,988.43 6.75 9,343.53 MWD(3) 327.57 6,100.08 6,020.08 9,850.57 -1,685.16 6,010,537.80 496,972.02 7.44 9,373.43 MWD(3) 328.66 6,099.04 6019.04 9,876.16 -1,701.08 6,010,563.38 496956.11 4.11 9,403.54 MWD (3) 331.67 6,097.48 6,017.48 9,902.49 -1,716.18 6,010,589.72 496,941.02 10.B) 9,433.90 MWD (3) 334.32 6,035.31 6,015.31 9,929.14 -1,729.76 6,010,616.36 496,927.44 9.55 9,463.76 MWD(3) 336.65 6,092.70 6,012.70 9,956.11 -1,74206 6,010,643.33 496,915.15 8.10 9,493.27 MWD (3) 339.12 6,090.25 6,010.25 9,984.03 -1753.41 6,010,671.25 496,903.81 9.38 9,523.12 MWD(3) 341.40 6,088.68 6,008.68 10,011.73 -1,763.35 6,010,698.% 496,893.87 9.76 9,552.09 MWD (3) 340.60 6,087.98 6,007.98 10,040.96 -1,773.41 6,010,728.18 496883.81 6.31 9,582.43 MWD (3) 338.14 6,087.87 6,007.87 10,068.41 -1,783.74 6,010,755.63 496,873.49 8.48 9,611.37 MWD(3) 335.66 6,088.14 6,OOB.14 10,095.82 -1,795.44 6,010,783.05 496,861.80 9.10 9,640.96 MWD(3) 334.03 6,06684 6008.84 10,123.36 -1,808.37 6,010,810.58 496,848.88 5.60 9,671.27 MWD(3) 329.48 6,089.73 6,009.73 10,149.89 -1,822.62 6,010,837.11 496,839.63 15.11 9,701.37 MM (3) 326.96 6,090.39 6,010.39 10,178.37 -1,840.26 6,010,86559 496816.99 8.57 9,734.86 MWD (3) 325.57 6,090.59 6,010.59 10,204.50 -185772 6,010,891.73 496799.54 444 9,766.22 MWD (3) 325.19 6,090.29 6,01029 10,229.08 -1,874.69 6,010,916.31 496,782.58 6.00 9,795.99 MWD(3) 323.16 6,089.59 6,009.59 10,25381 -1,892.53 6,010,941.03 496,764.74 6.70 9,82632 MWD (3) 319.56 6,089.54 6,009.54 10,277.17 -1,911.21 6,010,964.40 496,746.07 14.12 9,85690 MWD 13) 319.39 6,089.61 6,00961 10,299.93 -193067 6,010,987.15 496,726.62 5.87 9,885.33 MWD(3) 318.36 6,089.17 6009.17 10,318.63 -1,946.99 6,011,005 86 496,710.30 4.70 9,909.69 MWD (3) Annotation 8202018 12.29:59PM Page 5 COMPASS 5000.14 Build 85 Baker Hughes INTEQ BA ER I�l1GH�S ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-31 . Wellbore: 31-1-31 Design: 3H-31 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-31 31-1-31 @ 80.00usft (3H-31) 3H-31 @ 80.00usft (3H-31) True Minimum Curvature OAKEDMP2 8/2012018 12:29: 59PM Page 6 Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 13,175.76 91.87 317.57 6,068.34 6,008.34 10,341.03 -1,967.19 6,011,028.26 496,690.10 3.25 9,939.20 MWD (3) 13,205.94 92.37 315.12 6,087.22 6,007.22 10,362.85 -1,988.01 6,011,050.09 496,669.29 8.28 9,968.50 MWD (3) 13,235.43 92.15 31358 6,08606 6,006.06 10,38345 -2,009.08 6,011,070.68 496,648.23 5.27 9,996.87 MM (3) 13,265.47 92.98 312.50 6,084.72 6,004.72 10,403.93 -2,031.02 6,011,091.17 496,626.30 4.53 10,025.58 MWD (3) 13,295.58 91.90 314.80 6,083.43 6,00343 10.424.70 -2,052.78 6,011,111.93 496,604.54 8.43 10,054.44 MWD (3) 13,328.58 90.52 317.36 6,082.74 6,002.74 10,448.46 -2,075.66 6,011,135.70 496,581.67 8.81 10,086.46 MWD (3) 13,355.51 8975 31805 6,082.67 600267 10,468.38 -2,093.79 6,011,155.62 496563.55 3.84 10,112.77 MWD (3) 13,385.91 88.68 319.72 6,083.09 6,003.09 10,491.28 -2,113.77 6,011178.52 496,543.57 6.52 10,142.60 MWD (3) 13,416.87 8853 323.13 6,083.84 6,003.64 10,515.47 -2,133.07 6,011,202.71 496,524.28 11.02 10,173.20 MWD (3) 13,446.51 8675 325.33 6,085.06 6,005.06 10,539.50 -2,150.38 6,011,226.74 496,506.97 9.54 10,20266 MWD (3) 13,47563 86.93 327.91 6,086.67 6,006.67 10,563.77 -2,166.37 6,011,251.02 496,490.98 8.87 10,231.68 MWD (3) 13,504.96 8776 327.67 6,088.03 6,006.03 10,588.56 -2,181.99 6,011,275.81 496,475.37 2.95 10,260.96 MWD (3) 13,534.51 87.94 326.25 6,089.14 6,009.14 10,613.32 -2198.09 6,011,300.56 496,459.28 4.84 10,29645 MWD(3) 13,568.01 88.13 325.22 6,090.29 6,010.29 10,640.99 -2,216.94 6,011,328.23 496,440.44 3.12 10,323.83 MWD (3) 13,596.15 91.54 327.38 6,090.37 6,010.37 10,664.39 -2,232.55 6,011,351.64 496,424.83 14.34 10,351.91 MWD (3) 13,626.15 88.43 324.51 6,090.38 6,010.38 10,689.24 -2,249.35 6,011,376.49 496,408.04 14.11 10,381.83 MWD (3) 13,658.43 87.20 322.16 6,091.61 6,011.61 10,715.11 -2,268.61 6,011,402.36 496,388.79 8.21 10,413.86 MM (3) 13,687.39 87.82 320.34 6,092.86 6,012.85 10,737.68 -2.286.71 6,011,424.93 496,370.69 6.63 10,442.46 MWD (3) 13,718.01 87.45 318.84 6,094.13 6,014.13 10,760.97 -2,306.55 6,011,448.22 496.350.86 5.04 10,472.55 MWD (3) 13,753.47 88.93 318.07 6,095.25 6,015.25 10,787.50 -2,330.05 6,011,47475 496,327.36 470 10,507.27 MWD(3) 13,789.41 90.40 318.58 6,09546 6,01546 10,814.34 -2,353.95 6,011,50159 496,303.48 4.33 10,542.47 MWD (3) 13,827.67 89.66 316.82 6,09544 6,015.44 10,842.64 -2,379.70 6,011,52989 496,277.73 4.99 10,579.85 MWD (3) 13,853.51 88.56 316.06 6,095.84 6,015.84 10,86136 -2,39.50 6,011,54861 496,259.94 5.17 10,604.96 MM (3) 13,886.69 87.29 313.90 6,09764 6,01704 10,88480 -2,420.95 6,011,572.05 496,236.49 7.55 10,636.99 MWD (3) 13,907.22 86.71 312.63 6,098.12 6,018.12 10,898.85 -2,43588 6,011,586.11 496221.56 6.79 10,656.62 MWD (3) 13,937.72 86.16 312.30 6,10601 6,020.01 10,919.40 -2,458.34 6,011,606.66 496199.12 2.10 10,685.65 MWD (3) 13,967.85 88.68 312.35 6,101.37 6,021.37 10,93966 -2,480.59 6,011,626.93 496,176.87 8.37 10,714.32 MWD (3) 14,000.74 88.90 310.86 6,102.06 6,022.06 10,961.50 -2,505.18 6,011,648.76 496,152.29 4.58 10,745.52 MWD (3) 14,030.53 90.68 310.94 6,102.17 6,022.17 10,981.00 -2,527.69 6,011,668.27 496,129.78 5.98 10,773.67 MWD (3) 14,060.71 90.89 30865 6,101.76 6,021.76 11,000.31 -2,550.88 6011,68758 496,106.60 7.62 10.801.99 MWD (3) 14,091.79 90.92 306.65 6.101.27 6,021.27 11,019.30 -2,57548 6,011,70657 496,082.00 643 10830.73 MWD (3) 8/2012018 12:29: 59PM Page 6 Annotation COMPASS 5000.14 Build 85 Baker Hughes INTEQ ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 314-31 Project: Kuparuk River Unit TVD Reference: 311-31 @ 80.00usft (31-1-31) Site: Kuparuk 31-1 Pad MD Reference: 31-1-31 @ 80.00usft (31-1-31) Well: 31-1-31 North Reference: True Wellbore: 31-1-31 Survey Calculation Method: Minimum Curvature Design: 3H-31 Database: OAKEOMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS -NI-S (usft) (1) (°) (usft) (usft) (usft) 14,120.51 90.64 30551 6,100.88 6,020.88 11,036.21 14,150.39 90.21 302.61 6,100.65 6,020.65 11052.94 14,18044 8997 301.02 6,100.61 6,020.61 11,068.78 14,218.31 9074 301.44 6,100.37 6,020.37 11,08842 14,245.33 91.11 301.76 6,099.94 6,019.94 11,102.57 14,271.84 93.16 302.30 6,098.95 6,018.95 11,116.62 14,30400 93.16 302.30 6,0)TA8 6,017.18 11,133.78 Annotation BAER F�UGHES 82012018 12:29:59PM Page 7 COMPASS 5000.14 Build 85 Map Map Vertical +El -W Northing Easting DLS Section Survey Tool Name (usft) (ft) (ft) (°1100') (ft) -2,598.69 6,011,723.48 496,058.80 4.09 10,856.98 MWD(3) -2,623.44 6,011,740.22 496,034.05 9.81 10,883.85 MWD(3) -2,648.97 6,011,75606 496,008.52 5.35 10,91033 MWD (3) -2,681.35 6,011,775.70 495,976.15 2.32 10,943.53 MWD(3) -2,704.37 6,011,78986 495,953.14 1.81 10,967.29 MWD (3) -2,726.82 6,011,803,91 495,930.69 8.00 10,990.69 MWD (3) -2,753.97 6,011,821.07 495,903.55 0.00 11 019.12 PROJECTED to TD Annotation BAER F�UGHES 82012018 12:29:59PM Page 7 COMPASS 5000.14 Build 85 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Orr1 1 �r1� WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil[D Gas[:] SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105�r 20AAC 25.110 WINJ❑ WAGE] WDSPL❑ No. of Completions:_'. 1b. Well Class: Development 0 Exploratory ElGINJ❑ Service C] Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 8/17/2018 14. Permit to Drill Number/ Sundry: 218-075 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 6/2/2018 15. API Number: 50-103-20205-01-00 4a. Location of Well (Governmental Section): Surface: 970' FNL, 282' FWL, Sec 12, T12N, R8E, UM Top of Productive Interval: 3756' FNL, 282' FEL, Sec 34, T1314, R8E, UM Total Depth: 396' FNL, 1411' FEL, Sec 34, T13N, R8E, UM 8. Date TD Reached: 8/7/2018 16. Well Name and Number: KRU 3H -31A 9. Ref Elevations: KB:80 GL: 39 BF: 17. Field / Pool(s): Kuparuk River FieldlKuparuk RiverOil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25524, ADL 25531 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498656 y- 6000687 Zone- 4 TPI: x- 497036 y- 6008460 Zone- 4 Total Depth: x- 495903 y- 6011821 Zone- 4 11. Total Depth MD/TVD: 14304/6097 19. DNR Approval Number: LONS 84-134, LONS 84-149 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1746/1638 5. Directional or Inclination Survey: Yes ❑+ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 1043516015 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 Surface 121 Surface 121 24 200 sx AS 1 9.625 36 J55 Surface 5023 Surface 3262 12.25 1100 sx AS III, 600 sx Class G 7 26 L-80 Surface 10712 Surface 6228 8.5 250 sx Class G 2318 4.6 L-80 12243 14304 6084 6097 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINERS 12257-14304 MD and 6084-6097 TVD ';OJOPLE f IOIv �A E VERIF ED 7� 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3112 10337 1 10311/5921 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No � Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 8/20/2018 Method of Operation (Flowing, gas lift, etc.): FLOWING Date of Test: 8/24/2018 Hours Tested: 24hrs Production for Test Period Oil -Bbl: 323 Gas -MCF: 159 Water -Bbl: 2146 Choke Size: 176 Gas -Oil Ratio: 0.49 MCF/bbl Flow Tubin4 Press. 208 Casino Press: 1,100 Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: 169 Water -Bbl: 1 2146 Oil Gravity - API (torr): 1 24 Form 10407 Revised 5/2017 RBDMS��SEP 14 NINTINUED ON PAGE 2 /` (/ /�/� .�. *.$.1a/fr lfe V7 -1-d /elle I�6 ! 6 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑Z 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 TVD Well tested? Yes ❑ No ❑+ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1746 1638 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10431 6015 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TO 14304 6097 Formation at total depth: Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloolcal report. production or well test results, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Keith Herring 1JW7 Authorized Title: Staff CTD In ineer Contact Email: Keith.E.Herring0dop.com AuthorizedS Contact Phone: 263-4321 Signature: Date: / /d 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 1a: 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 41b: 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 TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 31-1-31 Final CTD Schematic 16" 629 H40 shoe @ 121' MD 9-618" 36# J-55 shoe 0 5023' MD Liner Top Packer at 10316 MD KOP (dJ 10,435' MD A -sand perfs squeezed 10,452'-10,494' MD 7" 26# L-80 shoe 10,712' MD Upper Completion 3-112" 9.3# LA0 EUE 8M Tubing W surface 3-115' DS nipple @ 488' RK8 (2.812" min ID) 3-112" Comm gas lift maMms Q 10223' RKB 3-12" WA nipple @ 10270' RKB, 10266 POC (2.812' min ID) Lower Completion Baker KBH-22 An&.r Seal Baker SAB -3 Permanent Faker @ 10311' RKB, 10307' PDC 3-12" D nipple C 10327' RKB, 10323' PDC (2.80" ID) Baker Shear Out Sub @ 10338' RK8, 10332' PDC 31-1-31AL1 TD = 14648' MD 2-318" slotted/blank liner w/ 6'sealbore deployment sleeve TOL = 10316' MD, BOL = 14648' MD Blank liner 10316'- 11245' MO 1A TD= 14304' MD "slotted liner w/ aluminum billet = 12243' MD, BOL = 14304' MD Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job V VII�V VIYCIRMIil� Dur hr ( ) 2.50 Phase MIRU Op Code MOVE Activity Code MOB Time P -T -X Operation Stan Depth (fit®) End Depth(flKB) P Attach Jeeps, prep for departure. 0.0 0.0 !7/1512018 1.00 MIRU MOVE MOB P Crew change, PJSM w Peak and 0.0 0.0 incoming crew, start move 6.00 MIRU MOVE MOB P Move rig from 1C-24 to the entrance 0o 0.0 of 3H pad 15.5 miles, 6 him - 2.58 mph 7/15/2018 0.50 MIRU MOVE MOB P Drop jeeps, spot rig mat in front of 0.0 O,p 13:00 well, dbl check tree valves, close master. spot sills for backing in, meet with pad op. 7/15/2018 1.50 MIRU MOVE MOB P Spot sub over well. Very narrow pad, 0.0 0.0 14:30 trucks having a hard time pulling forward very far. D8 dozer assist, set _ mats, on jack, drop trucks. Tight vertical clearance in the cellar. 7/15/2018 1.50 MIRU MOB P Spot service module. - trucks returned 0.0 0.0 16:00 to 1C for shop and 1/2 way house. Tiger tank on location 7/15/2018 0.10 MIRU EMOVE MOB P Spot tiger -tank 0.0 0.0 16'06 "Note DTH crew called out, night crew, after 6:30 pm. x/15/2018 2.50 MIRU RURD P Work RU check list, safe out 0.0 0.0 18:36 walkways. Cellar spill containment '/16/2018 5.40 MIRU WHDBOP RURD P Nipple up ROPE, tighten flowcross 0.0 0.0 )0:00 flanges, M/U MP line. R/U tiger tank line and air test, rig up putz, R/U steam. Center stack. Install / prep reel iron for circulating, install well name sign on side of rig. "` Check tree bolts (2 loose bottom of master) /16/2018 5.00 MIRU WHDBOP RURD P Continue installing CTC, re -head BHI 0.0 0.0 5:00 upper quick, pull test 35 k, install lubricators w/new o -rings, connect wash pipe, reconfigure test joint. install mouse holes, retrieve RKB's x16/2018 2.50 MIRU WHDBOP NUND P Crew change, grease valves, prep to 0.0 0.0 7:30 flood up. "`Rig accept 05:00 16/2018 2.30 MIRU WHDBOP TOPE P Flood up and shell test to 250/4200 0.0 0.0 ):48 psi, low high Tests 1-7 - good 16/2018 1.00 MIRU WHDBOP BOPE P 09:50 - Test 8 - Pass fail - C7 leaking, 0.0 0.0 ).48 greased, rebuilt - 16/2018 4.70 MIRU WHDBOP BOPE P complete BOPS testing 0.0 0.0 i:30 Swap to highline k@ 14:18 16/2018 ':30 2.00 MIRU WHDBOP RURD P PT ODS PDL and Eiger tank line to 0.0 0.0 1600 psi - good. 16!2018 1.00 PROD1 RPEQPT OWFF P Check for pressure under master, 0.0 0.0 :30 1,330 psi. IA 0, OA 0 psi. Bleed wellhead to the tiger tank. Crew change, Pressure remained at zero with no flow, Open up to the stack, obsew for flow - none 6/2018 1.10 PROD- RPEQPT PULD P PJSM, PU BHA#1, straight motor withtRprt :36 ridge set D331. Skid cart,stab on 6/2018 18 0.70 PROD1 RPEQPT CTOP P Inspect and adjust goose neck post swap to 2" coil. 6/2018 30 1.20 PROD1 RPEQPT TRIP P RIH displacing well to seawater taking returns of the tiger tank. Page 1/29 80/221290918 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Tire EM'rme Dur(ho phase Op Code Activity Code Time PJ -X Operation (tKB) End Depth take) 7/16/2018 7/16/2018 1.50 PROD1 RPEQPT SVRG P Park, lock out reel, inspect injector 5,096.0 5,096.0 21:30 23:00 goose neck alignment, inspect reel hubs, saddle clamps, torqe and hammer up inner reel iron. 7/16/2018 7/17/2018 1.00 PROD1 RPEQPT TRIP P Continue to RIH 5,096.0 9,551.0 23:00 00:00 7/17/2018 7/17/2018 0.20 PROD1 RPEQPT DLOG P log formation correction (plus 12.7'), 9,551.0 9,568.0 00:00 00:12 1 1 1 PUW 47 k 7/17/2018 7/17/2018 1.00 PROD1 RPEQPT TRIP P Continue IH, tag possibly cement 9,568.0 10,207.0 00:12 01:12 Node @ 10,207' DHWOB=3 k, PUW 48 k (no -pump) 7/17/2018 7/17/2018 2.00 PRODi RPEQPT TRIP P Bring pump up to 1.77 bpm at 4,409 10,207.0 10,327.6 01:12 03:12 psi, continue IH slowly to 10,220', PUW 40 k, work down towards bottom 50' at a time, PUH circulating BU, RBIH and continue 50' at a time. 7/17/2018 7/17/2018 0.50 PROD1 RPEQPT TRIP P PUH, while pumping BU, log gamma 10,327.6 9,515.0 03:12 03:42 1for depth controt. 7/17/2018 7/17/2018 0.30 PROD1 RPEQPT DLOG P Log gamma correction of plus 2.0' 9,515.0 9,575.0 03:42 04:00 7/17/2018 7117/2018 0.30 PROD1 RPEQPT TRIP P RIH 9,575.0 10,000.0 04:00 04:18 7/17/2018 7/17/2018 0.30 PROD1 RPEQPT DLOG P Log CCL, upload data to s:drive 10,000.0 10,320.0 04:18 04:36 7/17/2018 7/17/2018 0.45 PROD1 RPEQPT TRIP P PUH to log HRZ 10,320.0 9,875.0 04:36 05:03 7/17/2018 7/17/2018 0.30 PROD1 RPEQPT DLOG P Log HRZ correction of minus 2.5' 9,875.0 10,053.0 05:03 05:21 7/17/2018 7/172018 0.50 PROD1 RPEQPT TRIP P PUH to log CCL 10,053.0 9,950.0 05:21 05:51 7/17/2018 7/17/2018 1.00 PROD1 RPEQPT DLOG P Log CCL, upload data to s:drive 9,950.0 10,320.0 05:51 06:51 7/17/2018 7/17/2018 0.25 PROD1 RPEQPT TRIP P PUH, adjust gooseneck, bring pump 10,320.0 10,300.0 06:51 07:06 up 1.8 bpm at 4428 psi 7/17/2018 7/17/2018 0.20 PROD1 RPEQPT TRIP P RBIH, tag at 10,327', DHWOB=7.2 k, 10,300.0 10,327.0 07:06 07:18 PUH tag second time DHWOB=3.2 k, PUH 7/17/2018 7/17/2018 0.30 PROD1 RPEQPT MILL P Mill ahead 1.8 bpm at 4,428 psi, 10,327.0 10,332.0 07:18 07:36 CTSW=15 k, DHWOB=0.7-1.3 k 7/17/2018 7/17/2018 1.00 PRODi RPEQPT TRIP P POOH 10,332.0 2,611.0 07:36 08:36 7/17/2018 7/1712018 0.58 PROD1 RPEQPT SVRG P Inspect reel, tighten hub bolts 2,611.0 2,611.0 08:36 09:10 71172018 7117/2018 0.30 PROD1 RPEQPT TRIP P POOH 2,611.0 1,014.0 09:10 09:28 7/17/2018 7/172018 0.80 PROD1 RPEQPT SVRG P Inspect reel again, tighten hub bolts 1,014.0 1,014.0 09:28 10:16 again 7/172018 7/172018 0.25 PROD1 RPEQPT TRIP P POOH 1,014.0 62.5 10:16 10:31 7/17/2018 7/172018 0.50 PROD1 RPEQPT SFTY P At surface, check well for flow (no- 62.5 62.4 10:31 11:01 flow) 7/17/2018 7/1712018 0.40 PROD1 RPEQPT PULD P LD motor and mill, millling BHA #1 62.4 0.0 11:01 11:25 7/17/2018 7/17/2018 0.50 PROD1 RPEQPT PULD P PU 0.9 ako motor and D331 slick 0.0 65.5 11:25 11:55 gauge mill, surface test Coiltrak tools (good -test) 7/17/2018 7/17/2018 2.00 PROD1 RPEQPT TRIP P Tag up reset counters, RIH w/Milling 65.5 9,550.0 11:55 13:55 1 1 BHA #2 7/17/2018 7/17/2018 0.30 PROD1 RPEQPT DLOG P Log the HRZ correction of plus 10' 9,550.0 9,996.0 13:55 14:13 Page 2129 ReportPrinted: 812 212 01 8 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tune End Tams Dur(hr) Phase Op Code Activity Code TM PJA Opeaation Must End Depth (AKS) 7/1712018 7/17/2018 0.25 PROD1 RPEQPT TRIP P Continue IH, dry tagging cement @ 9,996.0 10,332.0 14:13 14:28 10,332', PUW 42 k 7/17/2018 7/17/2018 0.50 PROD1 RPEQPT MILL P Bring pump up 1.77 bpm @ 4,375 psi, 10,332.0 10,365.0 14:28 14:58 mill ahead @ 82 fph, DHWOB=2.5 k 7/1712018 7/17/2018 1.00 PROD? RPEQPT WPRT P Perform 3 cleanup passes from TT 10,365.0 10,365.0 14:58 15:58 down to TD 10,365' 7/17/2018 7/17/2018 1.80 PROD1 RPEQPT TRIP T POOH, w/closed EDC 10,365.0 55- 15:58 17:46 7/1712018 7/1712018 1.50 PROD1 RPEQPT PULD T At surface, flow check well -Dead. 55.0 0.0 17:46 19:16 PJSM. Lay down BHA#2 pilot hole mill with .9° AKO mill. Reconfigure BHA 7/17/2018 7/17/2018 1.50 PROD1 RPEQPT PULD T PJSM, P/U BHA #3 with Reeves 2 3/8" 0.0 77.7 19:16 20:46 under reamer, 2 1/8" WFT Motor and pup joints. Make up to coil and surface test - Good. Adjust gooseneck. Tag up and set counters 7/17/2018 7/17/2018 1.80 PROD1 RPEQPT TRIP T Trip in hole BHA #3 77.7 9,515.0 20:46 22:34 7/17/2018 7/17/2018 0.30 PROD1 RPEQPT DLOG T Log gamma tie in for+6' correction 9,515.0 9,577.0 22:34 22:52 7/17/2018 7/17/2018 0.40 PROD1 RPEQPT TRIP T Continue in well, Close EDC @ 9,577.0 10,345.0 22:52 23:16 1 10000, PUW=41 K. Continue in hole 7/17/2018 7/18/2018 0.72 PROD1 RPEQPT UREM T Get to 10345. Bring on pumps 1.38 10,345.0 10,356.0 23:16 00:00 BPM @ 4035 PSI FS. Recip underreamer to open blades. Under ream up to below TT Ream down hole. No vibration on meter. few stalls 7/18/2018 7/18/2018 0.10 PROD1 RPEQPT UREM T Under reaming, 1.4 BPM @ 3985 PSI 10,356.0 10,367.0 00:00 00:06 1 FS, BHP=3615 7/18/2018 7/1812018 3.50 PRODt RPEQPT UREM T Stall and restart @ 10367, 10,371, 10,367.0 10,370.0 00:06 03:36 PUW=48K, Slow going after end of pilot hole with stalls, Try light WOB <700 LBS 7/18/2018 7118/2018 2.50 PR0D1 RPEQPT UREM T Able to work WOB up to 1.5K and 10,370.0 10,373.0 03:36 06:06 maintain, 1.4 BPM @ 3990 PSI FS, continue to stall at 10,373', PUH, tool rep recommended we pull to inspect BHA 7/18/2018 7/18/2018 2.00 PROD1 RPEQPT UREM T POOH, w/open EDC 10,373.0 98.0 06:06 08:06 7/18/2018 7/18/2018 0.50 PROD1 RPEQPT UREM T At surface, check well for flow (no- 98.8 0.0 08:06 08:36 1 flow) 7/18/2018 711812018 0.30 PROD1 RPEQPT UREM T LD BHA#3, upon Inspection found 0.0 0.0 08:36 08:54 blades to be 5.0" OD, considable amount of wear on the reamer body and reamers.upload pictures to the s:ddve. 7/18/2018 7/18/2018 5.80 PROD1 RPEQPT WAIT T WOO, PJSM, wrap service loop, 0.0 0.0 08:54 14:42 perform various rig maintenance operations 7/18/2018 7/18/2018 0.25 PROD1 RPEQPT SFTY T BOT on location, load equipment onto 0.0 0.0 14:42 14:57 ng, PJSM 7/18/2018 7/1812018 1.00 PROD1 RPEQPT PULD T PU/MU Under reaming BHA, stab 0.0 77.1 14:57 15:57 UDS, surface test BHI Coiltrak tools (good-test), check pac-offs (good- condition) 7/18/2018 7/18/2018 1.80 PROD1 RPEQPT TRIP T Tag up, reset coutners, RIH w/ under 77.1 9,515.0 15:57 17:45 1 1 1reaming BHA #2, 7/18/2018 7/18/2018 0.30 PROD1 RPEQPT DLOG T Gamma tie in for+7.5 9,515.0 9,580.0 17:45 18:03 Page 3129 ReportPrinted: 8/2212018 Operations Summary (with Timelog Depths) 11 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sted Depth Sled Time E d-nme Write) phase Op Cade Activity Coce 11me P -T-% Operation W13) End DepN (0K113) 7/18/2018 7/18/2018 0.50 PROD? RPEQPT TRIP T Continue in well, Wt check @ 10300 9,580.0 10,346.0 18:03 18:33 4K, Shut EDC 7/18/2018 7/18/2018 3.20 PROD1 RPEQPT UREM T Bring on pumps 1.8 BPM and stall, 10,346.0 10,337.0 18:33 21:45 PUH bring on pumps 1.5 BPM @ 4200 PSI FS. Start reciping 10345 to 10335 working reamer open. Unable to ream bck down past 10343. Shut down pump and pick up into tubing to close blades. Run dry to get into pilot hole stack out 10343. Make several attemps to ease into 10343 with rapid stalls 7/18/2018 j 7/18/2018 0.80 PROD1 RPEQPT UREM T Consult town, go to 10337 with pumps 10,337.0 10,343.0 21:45 22:33 on @ 1.7 BPM @ 4730 PSI free spin for 30 minutes. Ream down slowly. Stall @ 10343 7/18/2018 7/19/2018 1.45 PROD1 RPEQPT UREM T PUH to tubing. RBIH dry to 10374, 10,343.0 10,344.0 22:33 00:00 PUH to 10350. Start working reamer blades open 7/19/2018 7/19/2018 0.40 PROD1 RPEQPT UREM T Reaming, 1.77 BPM @ 4872 PSI FS, 10,344.0 10,346.0 00:00 00:24 1 BHP=3670 7/19/2016 7/19/2018 1.60 PROD1 RPEQPT UREM T Stall / Restart 1.77 BPM @ 4873. Still 10,346.0 10,347.0 00:24 02:00 having stalling problems @ 10343' 18 7/19/2018 1.80 PROD1 RPEQPT UREM T Recip 10339 to 10347 Stalls 10,347.0 10,347.0 03:48 18 7/19/2018 0.70 PROD1 RPEQPT UREM T 10347 Ream down 1.6 BPM @ 4260 10,347.0 10,360.0 04:30 PSI FS - not going. Run in pilot hole r711912018 and back ream up 7/19/2018 1.50 PROD1 RPEQPT UREM T Back ream up past bad spot, stalling 10,360.0 10,337.0 06:00 18 7/19/2018 0.25 PROD1 RPEQPT UREM T Ream down slowlly 1.8 bpmat 5,031 10,337.0 10,341.0 06:15 psi 7/19/2018 7/19/2018 1.80 PROD1 RPEQPT UREM T Notice high vibration on BHA, POOH 10,341.0 77.1 06:15 08:03 1 to inspect BHA, open EDC 7/19/2018 7/19/2018 1.00 PROD1 RPEQPT UREM T Check well for flow, LD reaming BHA# 77.1 0.0 08:03 09:03 1 4 7/19/2018 7/19/2018 0.25 PROD1 RPEQPT UREM T Upload photo's of lost blade and under 0.0 0.0 09:03 09:18 1 reamer to sArive 7/19/2018 7/19/2018 2.70 PRO01 RPEQPT UREM T Stand by for orders 0.0 0.0 09:18 12:00 7/19/2018 7/19/2018 0.50 PR0D1 RPEQPT UREM T Tools on location, load into pipeshed, 0.0 0.0 12:00 12:30 PJSM, check well for flow (no -flow) 7/19/2018 7/19/2018 0.50 PROD1 RPEQPT UREM T MU Venturi BHA# 5, stab INJH, 0.0 55.2 12:30 13:00 1 surface test BHI tools (good -test) 7/19/2018 7119/2018 1.50 PROD1 RPEQPT UREM T RIH, w/venturi and G -force up/down 55.2 9,550.0 13:00 14:30jars, BHA#5 7/19/2018 7/19/2018 0.20 PROD1 RPEQPT UREM T Log the formation for depth control 9,550.0 9,537.0 14:30 14:42 1 correction of plus 7.5' 7/19/2018 7/19/2018 0.30 PROD? RPEQPT UREM T Continue IH 9,537.0 10,335.0 14:42 15:00 7/19/2018 7/19/2018 0.50 PRODt RPEQPT UREM T Perform 4 passes (10,335'-10375') 10,335.0 10,375.0 15:00 15:30 7/19/2018 7/19/2018 1.70 PROD1 RPEQPT UREM T POOH, pumping 1.08 bpm at 2,720 10,370.0 55.2 15:30 17:12 psi 7/19/2018 7119/2018 0.30 PROD1 RPEQPT UREM T PJSM, check well for flow, Lay down 55.2 0.0 17:12 17:30 BHA#5. Venturi full of metal and some cement sheath. No under reamer pieces 7/19/2018 7/19/2016 1.00 PROD1 RPEQPT UREM T Reconig BHA, Crew change 0.0 0.0 17:30 18:30 Page 4129 Report Printed: 812 212 01 8 Operations Summary (with Timelog Depths) e 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stat Time End Time Curtin) Phase Op Code Activity Code Tune P -T -X Operation End Depth 0003) 7/19/2018 7119/2018 0.30 PROD1 RPEQPT UREM T PJSM. BHA#6 Re nun venturi. Make 0.0 55.2 18:30 18:48 up to coil and surface test. Tag up and set counters 7/19/2018 1711912018 1.70 PROD1 RPEQPT UREM T Trip in venturi BHA #6 with EDC open 55.2 9,500.0 18:48 20:30 7/19/2018 7/19/2018 0.30 PROD1 RPEQPT UREM T Log Gamma tie in for +7'correction, 9,500.0 9,555.0 20:30 20:48 Close EDC 7/19/2018 7/19/2018 0.30 PROD1 RPEQPT UREM T Continue in hole to bottom 9,555.0 10,374.0 20:48 21:06 7/19/2018 7/19/2018 0.50 PROD1 RPEQPT UREM T Tag bottom, Bring pumps online 2 10,374.0 10,374.0 21:06 21:36 1 BPM @ 4885 PSI, Recip-40' 4 times 7/19/2018 7/19/2018 1.80 PROD1 RPEQPT UREM T Trip out of well 10,374.0 55.0 21:36 23:24 7/19/2018 7/20/2018 0.60 PROD1 RPEQPT UREM T At surface, PJSM stand back BHA #6. 55.0 0.0 23:24 00:00 Have 2 keeper pins and finger hinge pin in full venturi 7/20/2018 7/20/2018 0.60 PROD1 PEQ -PT UREM T Continue clean and inspect venturi 0.0 55.0 00:00 00:36 basxet. Make up to coil trek. Make up to coil and surface test 7/20/2018 7/20/2018 1.60 PRODt RPEQPT UREM T Trip in well BHA#7 Venturi basket, 55.0 9,500.0 00:36 02:12 1 1 EDC open 7/20/2018 7/2012018 0.30 PRODt RPEQPT UREM T Log Gamma tie in for +7' correction 9,500.0 9,554.0 02:12 02:30 7/20/2018 7/20/2018 0.40 PROD1 RPEQPT UREM T Continue in hole, Stop @ 10059 and 9,554.0 10,375.0 02:30 02:54 close EDC, Weight check @ 10290 @ 44K 7/20/2018 7/20/2018 0.60 PROD1 RPEQPT UREM T Tag bottom, Bring pumps online 2 10,375.0 10,375.0 02:54 03:30 BPM @ 4890 PSI Recip 4 times up to 10330 7/20/2018 7/20/2018 1.60 PROD1 RPEQPT UREM T POOH 10,375.0 79.0 03:30 05:06 7120/2018 7/20/2018 0.75 PROD? RPEQPT UREM T At surface, PJSM, Lay down BHA#7, 79.0 0.0 05:06 05:51 Under reamer blade recovered in venturi along with much less debris 7/20/2018 7/20/2018 1.00 PROD1 RPEQPT UREM T Inspect tools, MU Ventrui run #5, 0.0 55.2 05:51 06:51 BHA# 8 7/20/2018 7/20/2018 1.75 PROD1 RPEQPT UREM T RIH 55.2 9,500.0 06:51 08:36 7/20/2018 7/20/2018 0.20 PROD1 RPEQPT UREM T Log formation correction of plus 6.0' 9,500.0 9,540.0 08:36 08:48 7/20/2018 7/20/2018 0.20 PROD1 RPEOPT UREM T Continue IH, PUW @ 10,300'(46 k) 9,540.0 10,375.0 08:48 09:00 7/20/2018 7/20/2018 0.50 PROD? RPEQPT UREM T Tag bottom, bring pumps online 2.0 10,375.0 10,330.0 09:00 09:30 bpm at 4,890 psi, Recip 4 times up to 10,330' 7/20/2018 7/20/2018 1.50 PROD1 RPEQPT UREM T POOH 10,330.0 55.2 09:30 11:00 7/20/2018 7/20/2018 0.30 PROD1 RPEQPT UREM T PJSM, check well for flow (no -flow) 55.2 55.2 11:00 11:18 7/20/2018 7/20/2018 0.50 PROD1 RPEQPT UREM T LD, and inspect Venturi basket, found 55.2 0.0 11:18 11:48 hand full of cement cuttings and trace of metal. 7/20/2018 7/20/2018 3.50 PROD1 RPEQPT UREM T Wait on Caliper from Deadhorse. 0.0 0.0 11:48 15:18 7/20/2018 7/20/2018 1.00 PROD1 RPEQPT UREM T PDS, tool hand arrived on location, put 0.0 0.0 15:18 16:18 hand thru CDR3 orientation, PJSM, program tools. 7/20/2018 7/20/2018 -0 70 PROD? RPEQPT UREM T PU/MU caliper BHA, BHA#9 0.0 57.1 16:18 17:00 7/20/2018 7/20/2018 1.80 PROD1 RPEQPT UREM T RIH, w/PDS Caliper 57.1 9,500.0 17:00 18:48 Page 5129 Report Printed: 8/22/2018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Steri Time End Time Dw fe) Phase Op Cafe Activity CMe Time P-T-X Operation (8103) 1 EM Depth IRKS) 7/20/2018 7/20/2018 0.30 PROD1 RPEQPT UREM T Log gamma tie in for =3' 9,500.0 9,559.0 18:48 19:06 7/20/2018 7/20/2018 1.30 PRODI RPEQPT UREM T Continue in well. Stop and wait on 9,559.0 10,371.0 19:06 20:24 caliper to open 7/20/2018 7120/2018 1.20 PRODI RPEQPT UREM T Log up hole with caliper 50 FPM to 10,371.0 9,830.0 20:24 21:36 9830, Stop and wait for caliper arms to retract 7/20/2018 7/20/2018 0.70 PROD1 RPEQPT UREM T POOH with caliper 9,830.0 50.0 21:36 22:18 7/20/2018 7/20/2018 0.20 PROD1 RPEQPT UREM T At surface flow check. PJSM lay down 50.0 0.0 22:18 22:30 j BHA on dead well 7/20/2018 7/21/2018 1.50 PROD1 RPEQPT UREM T Reconfigure BHA, BOT here with 0.0 82.2 22:30 00:00 Haily under reamer. Make up BOT motor, pup joint, and up down jars. Make up to coil track. Make up to coil and surface test 7121/2018 7121/2018 0.10 PRODI RPEQPT UREM T Make up BOT motor, pup joint, and up 82.2 82.2 00:00 00:06 down jars. Make up to coil track. Make up to coil and surface test 7121/2018 7/21/2018 1.70 PROD1 RPEQPT UREM T RIH, EDC open 82.2 9,525.0 00:06 01:48 7x2112018 7/21/2018 0.30 PROD1 RPEQPT UREM T Log gamma be in for+7.5' 9,525.0 9,584.0 01:48 02:06 7121/2018 7121/2018 0.30 PROD1 RPEQPT UREM T Continue in well, weight check @ 9,564.0 10,340.0 02:06 02:24 10,000' for 45K, Close EDC 7121/2018 7/21/2018 2.00 PRODI RPEQPT UREM T Get to 10340, Bring pumps on 1.8 10,340.0 10,358.0 02:24 04:24 BPM @ 6000 PSI FS, Stall out, PIU and restart, ream down 7/21/2018 7/21/2018 2.50 PROD1 RPEQPT UREM T Stall motor, PUH to restart PUW 50 k, 10,358.0 10,370.0 04:24 06:54 1.79 bpm @ 5,945 psi, 7121/2018 7/21/2018 5.00 PROW RPEQPT UREM T Reaming 1.77 bpm at 5,476 psi, IA 10,370.0 10,426.0 06:54 11:54 920, OA 491, stall motor PUW 48 k I**** Note: bled IA 921 psi /13 psi 7/21/2018 7/21/2018 3.00 PROD1 RPEQPT UREM T Re-start 1.78 bpm 5,500 psi, IA 921, 10,426.0 10,443.0 11:54 14:54 OA 491 7/21/2018 7/21/2018 0.70 PROD1 RPEQPT UREM T Stalling in the perfs PUW 48 k, 10,443.0 10,443.0 14:54 15:36 countinue reaming @ 1.72 bpm at 5,887 psi, IA 49, OA 439 7/21/2018 7/21/2018 2.90 PROD1 RPEQPT UREM T Unable to make progress. Multiple 10,443.0 89.0 15:36 18:30 stalls. Trip to inspect BHA 7/21/2018 7/21/2018 0.70 PROD1 RPEQPT UREM T At surface, PJSM, Flow check well. 89.0 0.0 18:30 19:12 Break off injector, Swap BHA. Haily under reamer out with all blades missing hinge pin cap plug. Consult town "- Note: Under Reamer 1/2" under gauge..... 7/21/2018 7121/2018 0.80 FROM RPEQPT UREM T PILI BHA#11 Venturi run. Makeup to 0.0 49.3 19:12 20:00 coil and surface test. Check packoffs. Tag up and set counters 7/21/2018 7/21/2018 1.70 PRODI RPEQPT UREM T Trip in hole BHA#11 @ 9400 49.3 9,500.0 2000 21:42 observed out density dropping - 8 PPG. BHP=3300 7/21/2018 7/21/2018 0.30 PR0D1 RPEQPT UREM T Gamma tie in for +6'correction, Close 9,500.0 9,548.0 21:42 22:00 EDC 7/21/2018 7/21/2018 0.80 PROD1 RPEQPT UREM T Continue in well. Clean down to 9,548.0 10,444.0 22:00 22:48 10444. Pumps on 1.8 BPM @ 6000 PSI. Recip 3 times bottom up to 10300 7/21/2018 7/2212018 1.20 PROD1 RPEQPT UREM T POOH, Stop at 10099 Bit, Sensor @ 10,444.0 5,583.0 22:48 00:00 10079' TVD=5673.29 SS, BHP=3400 and slowly rising, Continue out of well Page 6129 Report Printed: 8/22/2018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten oepm Stan Time EMTme Durrut Phase op code Activity Cafe Time P -T -X operation (flKB) End Deplh(8KB) 7/22/2018 7122/2018 1.10 PROD? RPEQPT UREM T Continue tripping out 5,583.0 56.9 00:00 01:06 7/22/2018 7/22/2018 1.40 PROD1 RPEQPT UREM T At surface, tag up and space out. 56.9 0.0 01:06 02:30 Bleed well down. Went to 220 PSI. PJSM to PUD BHA. Pull off venturi. No whole plug in basket. 7/22/2018 7/22/2018 1.20 PROD1 RPEQPT UREM T Make up under reamer and pressure 0.0 82.2 02:30 03:42 deploy BHA#12. Check packoffs, Make up to coil and surface test 7/2212018 7/22/2018 1.70 PROD1 RPEQPT UREM T RIH, with Hailey Under Reamer. 82.2 9,500.0 0342 05:24 7/22/2018 7/22/2018 0.20 PROD1 RPEQPT UREM T Log formation correction of plus 8.0', 9,500.0 9,540.0 05:24 05:36 PUW 39 k 722/2018 7/22/2018 0.50 PROD1 RPEQPT UREM T Continue IH 9,540.0 10,399.0 05:36 06:06 7/22/2018 7/22/2018 2.50 PROD1 RPEQPT UREM T Stall, PUH, restart, 1.8 bpm at 5,500 10,399.0 10,465.0 06:06 08:36 psi 7/22/2018 7/22/2018 0.50 PROD1 RPEQPT UREM T Stall, PUH, re -start, hard spot, Back 10,465.0 10,465.0 08:36 09:06 Ream up to 10,420' 7122/2018 722/2018 0.60 PRODt RPEQPT UREM T Ream back down hole, stall motor 10,465.0 10,465.0 09:06 09:42 again (9 stalls @ 10465'), try and work down. Discuss w/town team, called TD 110,465' 7/22/2018 712212018 0.30 PRODt RPEQPT UREM T Back ream up hole to 10,345', 10,465.0 10,345.0 09:42 10:00 Note: Lost 1,000 psi differential at 10,368' 7/22/2018 7/222018 0.20 PROD1 RPEQPT UREM Ream back down, to log the K1 10,345.0 10,368.0 10:00 10:12 7/2212018 7/222016 0.20 PROD1 RPEQPT UREM Log the K1 marker correction of minus 10,368.0 10,386.0 10:12 10:24 2.0' 7/22/2018 722/2018 0.60 PROD1 RPEQPT UREM rT Continue IH to tag bottom 10,386.0 10,461.9 10:24 11:00 7/22/2016 7/22/2018 1.50 PROD1 RPEQPT UREM POOH, w/Hailey Under Reamer 10,461.9 82.1 11:00 12:30 7/22/2018 7/22/2018 1.50 PROD1 RPEQPT UREM At surface, space out, PUD BHA#12 82.1 0.0 12:30 14:00 Norte: Under Reamer upper Blades gauged 5.5", (6.122") 7/22/2018 7222018 2.30 PROD1 RPEQPT UREM T Inspect BHI Coilrak tools, PT tools in 0.0 0.0 14:00 16:18 pipe shed (good -test), hook up test cable (good -test), sim-ops inspect and rebuild Under reamer (BOT). 7/222018 7/222018 0.70 PROD1 RPEQPT UREM T PJSM, MU tools in well, load upper 0.0 0.0 16:18 17:00 section into PDL. Pressure test CT, CTC, and upper quick connect 7/22/2018 7222018 2.10 PROD1 RPEQPT UREM T PD BHA# 13, Haily under reamer, 0.0 82.2 17:00 19:06 Make up to coil and surface test, Tag up and set counters 7/22/2018 7/222018 1.70 PRODi RPEQPT UREM T RIH with BHA #13 Under reamer 82.2 9,525.0 19:06 20:48 7/222018 7/222018 0.30 PROD1 RPEQPT UREM T Gamma tie in for +6.5'correction 9,525.0 9,584.0 20:48 21:06 7/222018 7/22/2018 0.80 PROD1 RPEQPT UREM T Continue in well, swap out milling 9,584.0 10,370.0 21:06 21:54 fluid, closed EDC 7/22/2018 7222018 0.10 PROD1 RPEQPT UREM T Log Kt for -2.5' 10,370.0 10,382.0 21:54 22:00 Page 7129 Report Printed: 812 212 01 8 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stmt Time End Time Dur(hr) Phase Op Code N Ity Code Time P-T-X Operation ((9(8) End Depth (111<11) 7/22/2018 7/23/2018 2.00 PROD1 RPEQPT UREM T PUH to 10341. Pumps on 1.8 BPM @ 10,382.0 10,460.0 22:00 00:00 5990 PSI FS, BHP=4045. Start reaming down. Stall @ 10,381. P/U restart and stall again then ream past down to 10460. Work area multiple times until no motor work observed 10,410 to 10,460 7/23/2018 7/23/2018 1.10 PRODt RPEQPT UREM T Continue work 10,410 to 10,460 until 10,460.0 10,460.0 00:00 01:06 no motor work observed. One spot @ 10430 unable to get cleared up 7/23/2018 7/23/2018 1.80 PROD1 RPEQPT UREM T POOH, stop at 10116 open EDC 10,460.0 85.0 01:06 02:54 7/23/2018 7/23/2018 1.70 PRODt RPEQPT UREM T Tag up and space out, PJSM to PUD 85.0 0.0 02:54 04:36 BHA# 13 - Note: Under Reamer upper blades 1/2" under gauge, Lower blades 1/8" under gauge, Mill gauged 2.73 no-go 7/23/2018 7/23/2018 1.50 PROD1 RPEQPT UREM T RU, Haliburton Caliper, MU BHA# 14 0.0 26.0 04:36 06:06 7/23/2018 7/23/2018 2.20 PRODt RPEQPT UREM T RIH, w/BHA#114 HES caliper 26.0 10,455.0 06:06 08:18 7/23/2018 7/23/2018 0.30 PRODt RPEQPT UREM T Log up hole at 50 fpm, PUW 42 k 10,455.0 9,970.0 08:18 08:36 7/23/2018 7/23/2018 0.40 PRODt RPEQPT UREM T Hestiate let fingers close, RBIH 9,970.0 10,459.0 08:36 09:00 7/23/2018 7/23/2018 0.30 PRODt RPEQPT UREM T Let fingers extend, Log up at 50 fpm 10,459.0 9,970.0 09:00 09:18 7/23/2018 723/2018 2.00 PROD1 RPEQPT UREM T Close fingers, POOH 9,970.0 20.0 09:18 11:18 7/2312018 7/232018 0.20 PROD1 RPEQPT UREM T At surface, Lay down BHA#14, 20.0 0.0 11:18 11:30 Caloiper 7/23/2018 7232018 3.50 PROD? WHDBOP CTOP P Install noule and jet stack. Flush rig, 0.0 0.0 11:30 15:00 Service valves in prerperation for BOPE test 7/23/2018 7/232018 6.50 PRODt WHDBOP BOPE P Complete full BOPE test, Test witness 0.0 0.0 15:00 21:30 waived by Jeff Jones, AOGCC. Test PVT and gas monitors and alarms. No failures 7/23/2018 7/23/2018 1.70 PROD1 RPEQPT UREM T PJSM, M/U and PD BHA#15. D-331 0.0 51.4 21:30 23:12 slick gauge mill, 2.80", and straight motor to mill more pilot hole. Make up to coil and surface test, Install checks in UQC, Check pack offs 7/23/2018 7/24/2018 0.80 PROD1 RPEQPT UREM T Trip in hole BHA#15 to mill more pilot 51.4 3,758.0 23:12 00:00 hole 7/242018 7/24/2018 1.10 PROD1 RPEQPT UREM T Continue tripping in hole BHA#15 to 3,758.0 10,103.0 00:00 01:06 mill more pilot hole 7/242018 7/24/2018 0.10 PROD1 RPEQPT UREM T Close EDC, Wt chk @ 40K, Continue 10,103.0 10,330.0 01:06 01:12 in hole 7/24/2018 7/2412018 0.20 PROD1 RPEQPT UREM T Log K1 for +5' correction 10,330.0 10,355.0 01:12 01:24 7/24/2018 724/2018 0.10 PROD1 RPEQPT UREM T Continue in well, Dry tag @ 10463' 10,355.0 10,463.0 01:24 01:30 7/24/2018 7/24/2018 1.20 PROD1 RPEQPT UREM T PUH pumps on 1.8 BPM @ 4765 PSI 10,463.0 10,490.0 01:30 02:42 FS, BHP=4090, AVG ROP=25FPH, Pump 5 X 5 Sweeps 7/24/2018 724/2018 2.30 PRODt RPEQPT UREM T POOH chasing sweeps, PUW=42K 10,490.0 55.3 02:42 05:00 7/24/2018 7/24/2018 2.50 PROD1 RPEQPT UREM T Atsurface, PJSM, PUD BHA#15 55.3 0.0 05:00 07:30 Page 8129 ReportPrinted: 8/2212018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Sten Time End Tnne Dw(ho Phase Op Code Activity Code Time P -T -X Operation (111(13) End Depth(I") 7/24/2018 7/24/2018 3.00 PROD1 RPEQPT UREM T Stand by to P/U WFT 2 118" motor and 0.0 0.0 07:30 10:30 Reeves 2 3/8" under reamer with 6" blades 7/24/2018 7/24/2018 1.20 PROD1 RPEQPT UREM T PJSM, PIU BHA#16 and pressure 0.0 77.8 10:30 11:42 deploy. Make up to coil and surface test. Check pack offs, Tag up and set counters 7/24/2018 7/2412018 1.80 PROD1 RPEQPT UREM T RIH BHA#16 with WFT 2 1/8 motor 77.8 9,525.0 11:42 13:30 and reeved under reamer with 6" blades 7/24/2018 7/24/2018 0.30 PROD1 RPEQPT UREM T Run gamma tie in for +7' correction 9,525.0 9,571.0 13:30 13:48 7/24/2018 7/2412018 0.40 PROD1 RPEQPT UREM T Continue in well, close EDC @ 9,571.0 10,340.0 13:48 14:12 10,100', PUW=44K 7/24/2018 7/24/2018 4.00 PROD1 RPEQPT UREM T 10340 bring pumps online 1.3 BPM @ 10,340.0 10,455.0 14:12 18:12 3685 PSI FS. Stall hard multiple times @ 10370.5. Go past spot pumps down down to 10,450. Reipt 10450 to 10440 to work reamer open. Under -ream interval from 10,440'- 10,455' until little to no motorwork observed, begin to work up 20' interval to connect (14,420-14,445'), come up above 10,371' (stalling area), clean up & no motorwork down through. Decision made to POOH to inspect BHA and under -reamer 7/24/2018 7/24/2018 1.60 PROD1 RPEQPT TRIP T POOH to inspect BHA & under -reamer 10,370.0 78.0 18:12 19:48 7/24/2018 7/24/2018 1.20 PRODt RPEQPT PULD T PJSM, PUD BHA #16 78.0 0.0 19:48 21:00 7/24/2018 7/25/2018 3.00 PROD1 RPEQPT WAIT T Reeves under -reamer not re-runable, 0.0 0.0 21:00 00:00 upper blades have -.5" slop in the open position, broke tool down, broken seal fell from tool. Confer w/ town, attempt to track down DB UR, BOT does not have any additonal DB under -reamers on the slope. Await the arrival of Hailey under - reamer to slope, pumping managed pressure at 11.9 ppg 7/25/2018 7/25/2018 6.00 PROD1 RPEQPT WAIT T Continue painting rig, await Hailey 0.0 0.0 00:00 06:00 under -reamer delivery to slope 7/25/2018 7/25/2018 0.50 PRODt RPEQPT UREM T Perform injectivity lest. Unable to 0.0 0.0 06:00 06:30 achieve steady rate injection @ 2200 PSI WHP 7/25/2018 7/25/2018 5.70 PROD1 RPEQPT WAIT T Continue painting projects and 0.0 0.0 06:30 12:12 maintenance 7/25/2018 7/25/2018 1.50 PROD1 RPEQPT UREM T PJSM, pressure test GE transducer 0.0 76.3 12:12 13:42 installed by reel swivel. Under reamer on location. Discuss blade size and type options with town. WU under reamer. M/U to BHA#17 and deploy. Make up to injector and surface test. Tag up and set counters 7/25/2018 7/25/2018 2.40 PROD1 RPEQPT UREM T Trip in hole BHA#17 (4.72" & 4.85" 76.3 10,350.0 13:42 16:06 blades), EDC open, Slop @ 10,100' close EDC. PUW=39K, Continue RIH 7/25/2018 7/25/2018 0.20 PRODt RPEQPT UREM T Log Kt for+5' correction 10,350.0 10,377.0 16:06 16:18 7/2512018 7/25/2018 0.10 PROD1 RPEQPT UREM T Continue in to 10,345' 10,377.0 10,345.0 16:18 16:24 Page 9129 Report Printed: 812212018 ,I , Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sun Depth Sort Time End Time Dur (hr) Phase Op code Activit Code Time P -T -x Operation (flKe) End Depth(ftKB) 7/25/2018 7/25/2018 1.60 PROW RPEQPT UREM T Bring on pumps, 1.78 BPM @ 5950 10,345.0 10,385.0 16:24 18:00 PSI FS, Stay staionary for 10 minutes. then slowly start reaming down, significant vibration 7/25/2018 7/25/2018 3.00 PR001 RPEQPT UREM T Continue under -reaming from 10,385', 10,385.0 10,434.0 18:00 21:00 1.78 bpm, vibrations up to 6, stall at 10,386', FS = 1750 psi, pump & bore pressure dropped beginning at -10,416' (down to -1500 psi differential from 1800 psi), vibrations reduced down to 2's 7/25/2018 7/25/2018 1.20 PROD1 RPEQPT UREM T Continue under -reaming from 10,434' 10,434.0 10,455.0 21:00 22:12 to 10,455', pumping 1.78 bmp, circ pressure = 5322 psi, dp = 1512 psi 7/25/2018 7/25/2018 0.60 PROD1 RPEQPT UREM T Back ream up -hole, PUW = 44K, gel 10,455.0 10,350.0 22:12 22:48 parameters at 10,355', circ pressure = 5250 psi, dp = 1460 psi, decision made to POOH to inspect tools due to pressure drops 7/25/2018 7/26/2018 1.20 PROD1 RPEQPT TRIP T POOH 10,350.0 4,200.0 22:48 00:00 7/26/2018 7/26/2018 0.80 PRODt RPEQPT TRIP T Continue POOH 4,200.0 76.0 00:00 00:48 712612016 7/26/2018 1.10 PROD1 RPEQPT PULD T PJSM, PUD BHA#17 76.0 0.0 00:48 01:54 Note: LD BHI tools due to hour out on vibration 7/26/2018 7/26/2018 0.80 PROD1 RPEQPT OTHR T Inspect under -reamer, blades look 0.0 0.0 01:54 02:42 good with minimal cutter chips, retainer pins for blades show a bit of wear/deformation (2nd run), pistons look decent & blades show wear as if they had engagement, set screws are intact & retaining screws for blades look good. BOT motor tested good wl air Intstall 5.93" & 6.125" blades, redressed 6.125" blades struggle to fit in body window, pull & install 6" blades, hook UR up to air & lest, leaking past seals. 7/26/2018 7/26/2018 3.60 PROD1 RPEQPT WAIT T Confer w/ town, decision made to run 0.0 0.0 02:42 06:18 HAL caliper, await HAL arrival to dg 7/2612018 7/2612018 0.50 PROD1 RPEQPT PULD T HES on location, Start assembling 0.0 0.0 06:18 06:48 caliper 7/26/2018 7/26/2018 2.00 PROD? RPEQPT WAIT T HES missing go pin conned. Hot Shot 0.0 0.0 06:48 08:48 from deadhome 7126/2018 7/26/2018 0.50 PROD1 RPEQPT PULD T Parts on location. M/U BHA#18 0.0 24.5 08:48 09:18 caliper. Make up to coil and surface test. Check packoffs 7/26/2018 7/26/2018 2.10 PROD1 RPEQPT TRIP T Trip in hole BHA# 18 Caliper, Tie into 24.5 10,455.0 09:18 11:24 1<1 for+6' 7/26/2018 7/26/2018 0.80 PROD1 RPEQPT DLOG T 10,455'. Caliper up to 9990 and repeat 10,455.0 9,990.0 11:24 12:12 pass 7/26/2018 7/26/2018 1.60 PROD1 RPEQPT TRIP T POOH with caliper 9,990.0 23.0 12:12 13:48 7/26/2018 7/26/2018 0.50 PROD1 RPEQPT PULD T At surface, PJSM lay down caliper 23.0 0.0 13:46 14:18 7/26/2018 7/26/2018 0.50 PROD1 RPEQPT SVRG T Service reel. Check hubs and saddle 0.0 0.0 14:18 14:48 clamps Page 10129 Report Printed: 812 212 01 8 AmOperations Summary (with Timelog Depths) 3H-31 do 0 ' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan 7M End Time Our (hr) Phase Op Code ActiWy Code Time P -T -X Operation QtlDe End Depth (IIKB) 7126/2018 7/26/2018 1.30 PROD1 RPEQPT PULD T PJSM, MIN BHA#19 with Hailey 0.0 76.3 14:48 16:06 under reamer fitted with 4.72" blades on bottom 4.85 blades on top. 2.80 mill on nose. PD BHA. WU to coil and surface test. Tag up and reset counters 7/26/2018 7/26/2018 2.20 PROD1 RPEQPT TRIP T RIH BHA#19, EDC open, log K1 for 76.3 10,355.0 16:06 18:18 +3' correction 7/26/2018 7/26/2018 0.10 PRODt RPEQPT UREM T Stop at 10,355', close EDC, begin 10,355.0 10,355.0 18:18 18:24 pumping & get parameters Depth = 10,355' Rate = 1.65 bpm Circ pressure = 5292 psi Bore = 5326 psi dp = 1628 psi (FS) WHP = 205 psi BHP = 3700 psi 7/26/2018 7/26/2018 3.90 PROM RPEQPT UREM T Begin under -reaming, pumping 1.65 10,355.0 10,455.0 18:24 22:18 bpm, FS = 1628 psi, 18 fph, seeing little to no motorwork down to 10,385', increase speed to 0.5 fpm looking for motorwork, clean down to 10,455', vibrations up to 4's 7/26/2018 7/26/2018 0.40 PROD1 RPEQPT UREM T Back ream up -hole @ 5 fpm, pumping 10,455.0 10,350.0 22:18 22:42 1.65 bpm, dip = 1527 psi, circ = 5137 psi 7/26/2018 7/26/2018 1.10 PROD1 RPEQPT UREM T Ream down -hole @ 2 fpm, pumping 10,350.0 10,455.0 22:42 23:48 1.65 bpm, dp = 1489 psi, circ = 5111 psi, saw a bit of motorwork @ 10,430', stalled at 10,455' 7/26/2018 7/27/2018 0.20 PROD1 RPEQPT UREM T Begin POOH, 5 fpm to TT 10,455.0 10,368.0 23:48 00:00 7/27/2018 7/27/2018 2.10 PROD1 RPEQPT TRIP T Continue back -ream to TT, open EDC 10,368.0 76.0 00:00 02:06 @ 10,107', POOH, tag up, PJSM 7/27/2018 7/27/2018 0.70 PROD1 RPEQPT PULD T PUD BHA#19, mill gauged 2.73", 76.0 0.0 02:06 02:48 blades gauged 4.72" ` 4.85", pies on s: drive 727/2018 7/27/2018 1.20 PRODt RPEQPT PULD T PD BHA#20 (Hailey UR redressed 0.0 76.0 02:48 04:00 from BHA#17, w/ 5.93" & 6.125" blades & 2.74" mill), slide in cart, MU to coil, tag up, set counters 7/27/2018 7/27/2018 2.00 PROM RPEQPT TRIP T RIH w/ BHA #20, EDC open. Weight 76.0 10,360.0 04:00 06:00 ohk @ 10078 40K. Shut EDC continue n 7272018 7/272018 0.10 PROM RPEQPT DLOG T Log K1 for+3' correction. PUH to 10,360.0 10,349.0 06:00 06:06 10349 727/2018 727/2018 2.00 PROM RPEQPT UREM T 10349, Pumps on 1.65 BPM @ 10,349.0 10,380.0 06:06 08:06 5090PSI FS, 1400 PSI Diff. Start reaming down 727/2018 7/27/2018 0.90 PROD1 RPEQPT UREM T 10380', Stall and restart, PUW=40K, 10,380.0 10,386.0 08:06 09:00 1 1 1.64 BPM @ 4990 PSI FS 7/27/2018 7/272018 4.20 PROD1 RPEQPT UREM T 10,386. Stall and restart. Stall a 10,386.0 10,415.0 09:00 13:12 couple of time here and work through, Stall and restart @ 10393, PUW=40K 7/27/2018 7127/2018 1.90 PROM RPEQPT UREM T 10415, Stall and restart, PUW=36K, 10,415.0 10,433.0 13:12 15:06 1.72 BPM @ 5310 PSI. 7/27/2018 7/27/2018 1.80 PRODt RPEQPT UREM T 10,433 stall and restart, PUW=36K. 10,433.0 10,455.0 15:06 16:54 1.69 BPM @ 5155. 7/27/2018 7/27/2018 3.00 PROD1 RPEQPT UREM T Back ream up, a lot of motorwork @ 10,455.0 76.0 16:54 19:54 10,431',10,425- & 10,422', POOH, tag up, PJSM Page 11129 Report Printed: 8122120181 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stant oepm SbrtTens EM Tana Our (hq Phase Op Coda Amvity Cotle Time P-T-X Operatlon (flXB) End Dept (fll(a) 7/27/2018 7/27/2018 1.30 PROD1 RPEQPT PULD T PUD BRA #20, top blades gauged 76.0 0.0 19:54 21:12 5.81" & bottom blades gauged 5.84" (pics on s: drive) 7/27/2018 7/27/2018 0.90 PRODi RPEQPT OTHR T Make up blades to UR body, run coil 0.0 0.0 21:12 22:06 into pipe-shed, check for flat spots, none, UT coil at 12' up from CTC (lowest value .198"), replace return line in cellar & hammered up 7/27/2018 7/27/2018 1.30 PROD1 RPEQPT PULD T Confer w/town on blades to run, crew 0.0 76.0 22:06 23:24 change, PJSM, PD BHA#21 (Hailey UR, 2.74" mill, 5.93"& 6.1" blades), pics on s: drive, slid in cart, MU to coil, tag up, set counters 7/27/2018 7/28/2018 0.60 PROD1 RPEQPT TRIP T Begin RIH w/ BHA #21, EDC open 76.0 2,500.0 23:24 00:00 7/28/2018 7/28/2018 1.30 PROD? RPEQPT TRIP T Continue RIH w/ BHA#21, PUW @ 2,500.0 10,102.0 00:00 01:18 10,100'= 40K 7/28/2018 7/28/2018 0.30 PRODi RPEQPT DLOG T Obtain SBHP, close in choke, shut 10,102.0 10,102.0 01:18 01:36 down pumps: MD bit=10,102' TVD sensor= 5738' Annular= 3688 psi EMW = 12.4 ppg 7/28/2018 7/28/2018 0.70 PROD1 RPEQPT UREM T Continue RIH, log K1 for+3' 10,102.0 10,396.0 01:36 02:18 correction, under-ream down beginning at 10,365' Park @ 10,360', close EDC, & grab parameters: rate= 1.6 bpm, circ = 5497psi, bore = 5453 psi, dp = 1556 psi 7/28/2018 7/28/2018 2.30 PROD1 RPEQPT UREM T Reaming, multiple stalls from 10,396'- 10,396.0 10,408.0 02:18 04:36 10,408' 7/28/2018 7/28/2018 0.10 PROW RPEQPT UREM T Drop pump, RIH to 10,455'to back 10,408.0 10,455.0 04:36 04:42 ream up 7/28/2018 7/28/2018 3.00 PROD1 RPEQPT UREM T Back ream up hole to begin cleaning 10,455.0 10,455.0 04:42 07:42 up WS setting interval, stall bringing on pumps at 10,454', gel blades cutting at 10,452', work down to 10,455' Recip this area multiple stalls 7/28/2018 7/28/2018 0.10 PROD1 RPEQPT UREM T PUH to 10409 to ream interval down, 10,455.0 10,409.0 07:42 07:48 PUW=40K 7128/2018 7/28/2018 1.10 PROD1 RPEQPT UREM T 10409, ream down 1.57 BPM @ 5180 10,409.0 10,455.0 07:48 08:54 1 PSI FS stall at 10411 7128/2018 7/28/2018 0.10 PROD1 RPEQPT UREM T 10455, Back ream clean up to 10400, 10,455.0 10,400.0 08:54 09:00 Pump 5 X 5 Sweeps 7/28/2018 7/28/2018 1.90 PROD1 RPEQPT TRIP T Open EDC. Trip out 10,400.0 65.0 09:00 10:54 7/28/2018 7/28/2018 1.10 PR0D1 RPEQPT PULD T Tag up and space out, PJSM PUD 65.0 0.0 10:54 12:00 BHA# 21. Hailey under reamer out with blades at 5.91 lioer, 5.95 upper with small pinhole in body of tool 7/28/2018 7/2812018 1.00 PROD1 RPEQPT CTOP T Jet stack and flush rig with citric pill to 0.0 0.0 12:00 13:00 tiger tank 7/28/2018 7/2812018 0.60 PROD1 RPEQPT PULD T PJSM, P/U HES caliper, M/U to coil 0.0 24.5 13:00 13:36 land surface test 7/28/2018 7/28/2018 2.10 PROD1 RPEQPT TRIP T Trip in well BHA # 22 HES Caliper 24.5 10,222.0 13:36 15:42 7/28/2018 7/28/2018 0.10 PROD1 RPEQPT DLOG T Start logging gamma tie in for+27 10,222.0 10,350.0 15:42 15:48 7/28/2018 7/28/2018 0.20 PROD1 RPEQPT TRIP T Continue in well 10,350.0 10,460.0 15:48 16:00 Page 12129 Report Printed: 812212018 Operations Summary (with Timelog Depths) 3H-31 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stat Imre 6M Time Dur (hl) Phase Op Cone Activity Code Time P.T.X Operation dtl(B) End DepM(M) 7/28/2018 7/28/2018 0.50 PROD1 RPEQPT DLOG T 10460', start calipering casing up to 10,460.0 9,990.0 16:00 16:30 9995'. RBIH and repeat logging pass 7/28/2018 7/28/2018 1.70 PROD1 RPEQPT TRIP T POOH with caliper 9,990.0 25.0 16:30 18:12 7/28/2018 7/28/2018 0.90 PROW RPEQPT PULD T PJSM, LD BHA#22 HES Caliper, 25.0 0.0 18:12 19:06 Gear floor 7/28/2018 7/28/2018 1.70 PRODi RPEQPT WAIT T Await arrival of Hailey UR, pre -load 0.0 0.0 19:06 20:48 PDL, 6" & 6.1" blades 7/28/2018 7/2812018 1.60 PROD1 RPEQPT PULD T PJSM, PD BHA#23 Hailey UR (2.74" 0.0 76.0 20:48 22:24 mill, 6" & 6.1"), slide in cart, check pack -offs, good, MU to coil, tag up, set counters 7/28/2018 7/2912018 1.60 PROD1 RPEOPT TRIP T Begin RIH w/ BHA#23 76.0 9,000.0 22:24 00:00 7/29/2018 7/29/2018 0.50 PRODi RPEQPT TRIP T Continue RIH w/ BHA#23, PUW = 9,000.0 10,405.0 00:00 00:30 40K @ 10,100', close EDC, log K1 for +4' correction 7/29/2018 7/29/2018 0.90 PROD1 RPEQPT REAM T Under -ream from 10,405', Rate = 1.5 10,405.0 10,405.0 00:30 01:24 bpm, Circ = 5640 psi, Bore = 5486 psi, FS =1611 psi 0.2 fpm, vibrations @ 6, lose annular & bore on baker screen Have a drop in circ from 5600 psi to 5300 psi & vibrations dropped at same time (00:40:40) 7/29/2018 7/29/2018 2.20 PROD1 RPEQPT TRIP T POOH to TOC, allow MWD to trouble- 10,405.0 76.0 01:24 03:36 shoot baker tools, lost DPS, RBIH to 10,355', bring up rate to 1.5 bpm, circ = 5600 psi (pressure drop mysteriously gone), Confer with town, POOH to replace BHI tools, unable to open EDC w/ no dp from BHI tool, pump down MP line, plan to bench test UR w/ air 7/29/2018 7/29/2018 1.00 PRODt RPEQPT PULD T PJSM, PUD BHA #23 w/ EDC closed 76.0 0.0 03:36 04:36 7/29/2018 7/29/2018 3.40 PROD1 RPEQPT OTHR T LD tools, PU new BHI tools, bench 0.0 0.0 04:36 08:00 test UR, bottom piston seals are shot, contact Weatherford & they have a Reeves UR on the slope, confer wl town, get the UR coming to rig " Wait on Reeves UR w/ 6.125" blades 7/29/2018 7/29/2018 1.30 PROD1 RPEQPT PULD T WFT on location, Load tools into shed, 0.0 77.7 08:00 09:18 PJSM PD BHA#24 with 2 1/8 WFT motor, Reeves 2 3/8" under reamer with 6.125 blades. Make up to coil and surface test. Tag up and space out 7129/2018 7/29/2018F3.30 PROD1 RPEQPT TRIP T Trip in hole, BHA #24, EDC open, 77.7 10,360.0 09:18 11:18 Close EDC at 10,000', PUW=38K 7/29/2018 7/29/2018 PROD1 RPEQPT DLOG T Log K1 for +6' correction 10,360.0 10,376.0 11:18 11:24 7129/2018 7/29/2018 PROD1 RPEQPT TRIP T Continue in hole 10,376.0 10,405.0 11:24 11:30 7/29/2018 7/29/2018 PROD1 RPEQPT UREM T 10405 bring pumps on 1.49 BPM, 10,405.0 10,416.0 11:30 14:48 CTC=4743, Diff --872. Start reaming downStall @ 10413 3 times, stall @ 10416 multiple times. Page 13/29 Report Printed: 8122/2018 11 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stell Depth Stat Tsne End7me Dur(hr) Phase Op Code Acdvity Code Time P -T-% Operdinn (N(B) End Depth (WB) 7/29/2018 7/29/2018 3.20 PROD1 RPEQPT UREM T Hard to gel past 10416. Check caliper 10,423.0 10,441.0 14:48 18:00 log. go to 10423 at min rate. Bring pumps online 1.50 BPM and start working whipstock setting zone, stalls at 10,441' 7129/2018 7/29/2018 3.70 PROD1 RPEQPT UREM T Continue under -reaming from 10,441', 10,441.0 10,443.8 18:00 21:42 pumping 1.5 bpm, FS = 860 psi, stall at 10,442', go into auto driller @ tfph, vibrations in green with occasional red's, though push on it and stall, stall @ 10,442.6',10,443.2- 0,442.6',10,443.2'7/29/2018 7/29/2018 7/30/2018 2.30 PRODt RPEQPT UREM T Continue under -reaming from 10,443.8 10,445.7 21:42 00:00 10,443.8', pumping 1.5 bpm, FS = 860 psi, stall @ 110,4441'& 10,445.7', clean RBIH after stalls at faster speeds, virbrations in the greens, yellow, & reds 7/30/2018 7/30/2018 3.00 PRODt RPEQPT UREM T Continue under -reaming from 10,445.7 10.449.7 00:00 03:00 10,445.7', FS = 850 psi, vibrations between 2 - 4, stall again @ 10,447.7', stall @ 10,448.5- 7/30/2018 7/30/2018 1.00 PROD1 RPEQPT UREM T Continue under -reaming from 10,449.7 10,452.0 03:00 04:00 10,4497, stall @ 10,451.3', ream to 10,452' (depth discussed if reaming is difficult) '• Sunday Saftey Meeting held in OPS Cab 7/30/2018 7/30/2018 0.20 PROD1 RPEQPT UREM T Back ream @ 5 fpm, PUW =45K, 10,452.0 10,420.0 04:00 04:12 clean 7/30/2018 7/30/2018 0.20 PROD1 RPEQPT UREM T Under -ream back in-hole, 3 fpm, dp = 10,420.0 10,452.0 04:12 04:24 768 psi, clean 7/30/2018 7/30/2018 1.90 PROD1 RPEQPT UREM T Continue under -reaming from 10,452', 10,452.0 10,454.0 04:24 06:18 stall @ 10,452.5' 7130/2018 7130/2018 0.30 PROD1 RPEQPT UREM T Back ream up to 10,410 @ 5 FPM 10,454.0 10,410.0 06:18 06:36 7/30/2018 7/30/2018 0.20 PROD1 RPEQPT UREM T Ream down, Clear trip to bottom. 10,410.0 10,454.0 06:36 06:48 7/30/2018 7/30/2018 0.20 PROW RPEQPT UREM T Back ream up hole to 10360 10,454.0 10,360.0 06:48 07:00 1 7/30/2018 7130/2018 1.70 PRODt RPEQPT TRIP T Trip out of hole, Stop @ 10095 and 10,360.0 77.0 07:00 08:42 oipen EDC 7/3012018 7/30/2018 1.00 PROD1 RPEQPT PULD T Tag up and space out. PJSM PUD 77.0 0.0 08:42 09:42 BHA# 24 Reeves under reamer 7/30/2018 7/30/2018 0.80 PROW RPEQPT PULD T Reconfigure BHA for caliper run. HES 0.0 0.0 09:42 10:30 here rigging up caliper and computers 7/30/2018 7/30/2018 0.40 PROD1 RPEQPT PULD T PJSM, M/U caliper and surface test 0.0 24.0 10:30 10:54 7/30/2018 7/30/2018 2.00 PROD1 RPEQPT TRIP T RIH BHA # 25 Caliper, Tie in for -2' 24.0 10,458.0 10:54 12:54 7/30/2018 7130/2618 0.70 PROD1 RPEQPT DLOG T 10458', Log up with caliper to 9957, 10,458.0 9,940.0. 12:54 13:36 1 RBIH and repeat logging pass 7/30/2018 7/30/2018 2.40 PRODt RPEQPT TRIP T POOH after completing caliper interval 9,940.0 23.8 13:36 16:00 7/30/2018 7/30/2018 1.50 PROD1 RPEQPT PULD T PJSM, Lay down caliper, Load out 23.8 0.0 16:00 17:30 7/30/2018 7/30/2018 1.00 PROD? RPEQPT CTOP T Pull checks out of UQC, Stab on and 0.0 0.0 17:30 18:30 jet stack / Flush rig 7/30/2018 7/30/2018 2.00 PROD1 RPEQPT OTHR T Prep for BOPE test 0.0 0.0 18:30 2030 Page 14129 ReportPrinted: 812 212 01 8 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan beplh Start Time End Tmw our (tn) Pease Op Code Activity Code Tnne P -T -X Operation (fll(B) End DepN (ftKB) 7/30/2018 7/31/2018 3.50 PRODI RPEQPT BOPE P Start full BOPE test, Test witnessed by 0.0 0.0 20:30 00:00 Matt Herrera, AOGCC, Swab 2 Fail / Pass, On test 7 Tango 1 fail / fail. Move on to test 8 7/31/2018 7/31/2018 0.70 PROD1 RPEQPT BOPE P Continue wl BOPE test 0.0 0.0 00:00 00:42 7131/2018 7/31/2018 2.80 PRODI RPEQPT BOPE T Fail past Bravo 3 & 7, trouble -shoot, 0.0 0.0 00:42 03:30 flush stack, re -grease Tango 1, Bravo 3 & 7, cycle valves, re -test, good 7/31/2018 7/31/2018 3.00 PRODI RPEQPT BOPE P Continue w/ BOP test, draw down, 0.0 0.0 03:30 06:30 inner reel iron & stripper 7/31/2018 7/31/2018 1.70 PROD1 RPEQPT DISP P Clear floor, MU nozzle, displace coil to 0.0 0.0 06:30 08:12 viscosified seawater, load tools, pop off & break off nozzle, Gear floor, install checks 7/31/2018 7/3112018 0.70 PROD1 RPEQPT PULD P Bring WS to floor and assemble, put in 0.0 0.0 08:12 08:54 hole 7/31/2018 7/31/2018 1.60 PRODI RPEQPT PULD P PJSM, PD BHA#26 Northern 0.0 74.0 08:54 10:30 Solutions HEW WS NS rep confers w/ town, shear stud adjustment bar on WS not threaded on setting rod sufficiently, LD WS, re- adjust, continue on with PD, slide in cart, MU to coil, tag up, set counters 7/31/2018 7/31/2018 2.10 PROD1 RPEQPT TRIP P RIH w/ BHA#26, EDC open, stop at 74.0 10,360.0 10:30 12:36 10,100', close EDC, PUW = 39K, continue RIH pumps off 7/31/2018 7131/2018 0.10 PRODI RPEQPT DLOG P Log K1 for+4' correction 10,360.0 10,375.0 12:36 12:42 7/31/2018 7/31/2018 0.20 PROD1 RPEQPT TRIP P Continue RIH, arrive at setting depth, 10,375.0 10,442.8 12:42 12:54 pickup slack, bring up pumps, shear -- off WS at 4500 psi, TOWS -10,434', oriented HS, PUW = 39K 7/31/2018 7/31/2018 1.70 PROW RPEQPT TRIP P POOH, EDC open 10,442.8 76.0 12:54 14:36 7/31/2018 7/31/2018 1.10 PROD1 RPEQPT PULD P PJSM, PUD BHA#26 76.0 0.0 14:36 15:42 7/31/2018 7/31/2018 0.90 PROD1 WHPST PULD P PD BHA#27 Window Milling Assembly 0.0 75.0 15:42 16:36 (1.0 AKO X-treme motor, 2.80" string reamer, 2.80" window mill), slide in cart, MU to coil, tag up, set counters 7/31/2018 7/31/2018 1.90 PROD1 WHPST TRIP P RIH w/ BHA #27 75.0 10,355.0 16:36 18:30 7/31/2018 7/31/2018 0.20 PROD1 WHPST DLOG P Log the Kt correction of Plus 3.0' 10,355.0 10,390.0 16:30 18:42 7/31/2018 7/31/2018 0.40 PRODI WHPST DISP P Displace well to milling fluid (8.48 ppg) 10,390.0 10,390.0 18:42 19:06 7/31/2018 7131/2018 0.20 PROW WHPST TRIP P Continue IH, dry lag TOWS 10,438.5' 10,390.0 10,438.0 19:06 19:18 7/31/2018 7/31/2018 2.20 PROD1 WHPST MILL P PUH, and bring pump on line get 10,438.0 10,440.7 19:18 21:30 parameters, begin milling window @ 1 fph, 1.81 bpm at 4,291 psi, BHP=3,889, WHP=419, IA=26, OA=364. 7/3112018 7/31/2018 1.75 PRODI WHPST MILL P Notice DHWOB loss from 2.0k -0.8k, 10,440.7 10,442.2 21:30 23:15 Continue milling ahead. Note: Bottom of window (10,441') Note: Sample - g lauconite/cement/metal 7/31/2018 8/1/2018 0.75 PRODI WHPST MILL P Increase to 2 fph as per rep RP 10,442.2 10,444.0 23:15 00:00 Page 15129 Report Printed: 8122/2018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Time Dur(tr) Phase Op Code Activity Code Tim P -T -x Operation (Wtt) End Depth(fl(e) 8/1/2018 8/1/2018 3.50 PRODt WHPST MILL P Continue milling window off of 10,444.0 10,459.0 00:00 03:30 Northern Solutions HEW WS, TD rat hole 24' down from TOWS. 8/1/2018 8/1/2018 1.80 PROD? WHPST REAM P Perfrom Reaming passes as per 10,459.0 10,434.0 03:30 05:18 procedure HS @ 1 fpm, & 15° left & right, dry drift window, clean 8/1/2018 8/1/2018 1.90 PROD1 WHPST TRIP P POOH 10,434.0 76.0 05:18 07:12 8/1/2018 8/1/2018 1.00 PROD1 WHPST PULD P PJSM, PUD BHA#27, pumping 76.0 0.0 07:12 08:12 managed pressure 8/1/2018 8/1/2018 3.30 PROD1 DRILL CTOP P Perfrom slack management 0.0 0.0 08:12 11:30 Cut off CTC, protect a -line, stab on, reverse circlale 5 times up to 2.5 bpm, cut 72' of coil to find wire, test a -line, good, cut additonal 8' for a total of 80', ream coil, install CTC, pull test to 35K, good 8M/2018 8/1/2018 1.80 PROD1 DRILL CTOP P Head up a -line, MWD getting bad test, 0.0 0.0 11:30 13:18 trouble -shoot, pump and manually pull e -line out coil, trouble -shoot & resolve, complete heading up, clear floor 8/1/2018 8/1/2018 1.10 PROD1 DRILL CIRC P MU nozzle, stab on well, circulate 0.0 0.0 13:18 14:24 forward 1 coil volume, load ODS PDL, pop off, break off nozzle, PJSM 8/1/2018 8/1/2018 1.00 PROD1 DRILL PULD P PD BHA#28 Build/Turn Assembly 0.0 72.0 14:24 15:24 (2.4°+AKO motor, Baker Dynamus bit), MU to coil, tag up 8/1/2018 8/1/2018 2.00 PROD1 DRILL PULD T Tools experiencing power issues, 72.0 72.0 15:24 17:24 trouble shoot, pop off to inspect tools, shorted a -line, cut & re -head a -line. BHA failed testing from surface, PUD tools, operating w/ single PDL 8/1/2018 8/1/2018 0.60 PROD1 DRILL PULD T Unable to move BHA with SL, line up 72.0 72.0 17:24 18:00 and pump thru both B valves and 3 Romeo valves, no success 8/1/2018 8/1/2018 0.25 PRODt DRILL PULD T Crew Change, PJSM for plan forward. 72.0 72.0 18:00 18:15 8/1/2018 8/1/2018 1.25 PRODt DRILL PULD T Switch to PD failed tools, MU INJH to 72.0 172.0 18:15 19:30 tools BHA# 28, RIH 100' non -issues, pumping 0.5 bpm with EDC open (no - comms) 8/1/2018 8/112018 1.00 PROD1 DRILL PULD T Re -head SL, pull test to 700 psi 172.0 172.0 19:30 20:30 hydraulic pressure (1,600 lbs) 8/1/2018 8/1/2018 1.00 PROD1 DRILL PULD T Tag up, spaceout, PUD BHA# 28, LD 172.0 0.0 20:30 21:30 tools, check bit condition (good) 8/1/2018 8/1/2018 1.00 PROD1 DRILL PULD T PU/MU second build BHA# 29 0.0 72.0 21:30 22:30 8/1/2018 8/1/2018 0.25 PROD1 DRILL PULD P MU INJH to tools, perform surface test 72.0 72.0 22:30 22:45 (good -test) 8/1/2018 8/2/2018 1.25 PROD1 DRILL TRIP P RIH, wlbuild BHA#29, 2.4+ako motor 72.0 5,849.0 22:45 00:00 8/2/2018 8/2/2018 0.80 PROD1 DRILL - TRIP P Continue IH, w/ Build BHA #29 5,849.0 10,345.0 00:00 00:48 8/2/2018 8/2/2018 0.20 PRODt DRILL DLOG P Log the K1 marker correction of plus 10,345.0 10,365.0 00:48 01:00 2.0' 8/22018 8/2/2018 0.50 PROD1 DRILL DIS P P Continue displacing well to drilling fluid 10,365.0 10,365.0 01:00 01:30 8/2/2018 8/2/2018 0.20 PROD1 DRILL TRIP P Close EDC, continue IH 10,365.0 10,459.0 01:30 01:42 Page 16/29 ReportPrinted: 8122/2018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log smn Depth Slan Time EndTime Dur(ha) Phase Op Code ActiNly Cotle Time P -T -x Operation (W) End Depth(nKB) 8/2/2018 8/2/2018 1.00 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4,413 psi FS, 10,459.0 10,555.0 01:42 02:42 BHP=3,930, WHP=514, IA=O, OA=133 8/2/2018 8/2/2018 0.20 PROW DRILL TRIP P TD Build Section 10,555', PUW 43 k 10,555.0 10,345.0 02:42 02:54 8/2/2018 8/2/2018 0.20 PROD1 DRILL DLOG P Log the K1 marker correction of plus 10,345.0 10,363.0 02:54 03:06 0.5' 6/2/2018 8/2/2018 0.20 PROD1 DRILL DLOG P Log RA marker offical window depths 10,450.0 10,467.0 03:06 03:18 TOWS=10,435' TOW =10,438' BOW & RA=10,442' 8/2/2018 8/2/2018 1.70 PROD1 DRILL TRIP P POOH, w/open EDC, pumping 1.77 10,467.0 72.0 03:18 05:00 1 bpm at 3,873 psi, following MP 8/2/2018 822018 2.10 PROD1 DRILL PULD P Tag up, space out, PUD BHA #29, 72.0 0.0 05:00 07:06 againhave difficulty sucking tools into PDL, close tools in rams, break off PDL, hook up tools to surface power, orient HOT additional 90° ROHS, successfully pull tools into PDL, bit came out a 1-1 8/2/2018 8/212018 1.00 PROD1 DRILL PULD P PJSM, PD BHA#30 (NOV agitator, 0.0 80.0 07:06 08:06 0.5° AKO fixed bend Iron Side motor, RB C1 3D bit) Slide in cart, check pack -offs, good, MU to coil, tag up, set counters 82/2018 8/2/2018 1.90 PROD1 DRILL TRIP P RIH w/ BHA#30, stop at 500'& test 80.0 10,360.0 08:06 10:00 tools, good 8/2/2018 8212018 0.10 PROD1 DRILL DLOG P Log Kt for+3 10,360.0 10,272.0 10:00 10:06 8/212018 82/2018 0.30 PROD1 DRILL TRIP P Continue RIH 10,372.0 10,555.0 10:06 10:24 8/2/2018 8/2/2018 1.60 PROD1 DRILL DRLG P OBD, pumping 1.5 bpm, FS = 1800 10,555.0 10,955.0 10:24 12:00 psi, circ = 5842 psi, rip = 2000 psi, BHP = 4236, PUW = 38K Bring up rate to 1.8 bpm, FS = 2060 psi, circ = 6783 psi, bore = 7019, CWT = 12K, pump 5x5 sweeps @ 10,856', drilling 1 for 1, 12.7 ppg ECD @ 10,880' 8212018 8/22018 2.00 PRODt DRILL WPRT P Wiper up -hole, PUW = 40K, begin 10,955.0 8,676.0 12:00 14:00 pressuring up on bore from 6000 psi to -8500 psi @ 10,902, have full returns, no indication of CWT or WOB drag, no increase in annular, time 5x5 sweep for EOB, Observe -800 psi dp increase off bottom, confer with town, POOH to inspect tools, pressure returned to normal once through the window in 7" casing 8/2/2018 8/2/2018 1.00 PROD1 DRILL WPRT P Confer with town again, decision 8,676.0 10,995.0 14:00 15:00 made to go back to drilling, RIW = 15.5K, perfrom MAD pass for resistivity Page 17129 Report Printed: 8122/2018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SM Depth Start Time End Time Dor(tr) Phase op Code Ac fty Code Time P -T -X Operation (MB) End Depth(fll(B) 8/2/2018 8/2/2018 0.70 PROM DRILL DRLG P BOBD, pumping 1.8 bpm, FS = 1800 10,995.0 11,013.0 15:00 15:42 psi, bore = 5978 psi, circ = 5740 psi, dp = 1978 psi, BHP = 3934 psi, PUW = 39K, FS = 1800 psi, pump sweeps ROP decreased to 0 fph, attempt to drill off for 5 min, if no progress, POOH 8/2/2018 8/2/2018 2.00 PROM DRILL TRIP T POOH to inspect tools 11,013.0 80.0 15:42 17:42 812/2018 8/2/2018 1.75 PROD1 DRILL PULD T PJSM, PUD BHA #30 80.0 0.0 17:42 19:27 8/2/2018 8/212018 0.50 PROD1 DRILL PULD T MU BHI X-treme motor 0.4+° ako 0.0 0.0 19:27 19:57 motor 8/212018 8/212018 1.00 PROD1 DRILL PULD T PD lateral drilling BHA #31 0.0 78.2 19:57 20:57 8/2/2018 8/2/2018 0.25 PROD1 DRILL PULD T MU INJH, surface test Coiltrak tools 78.2 78.2 20:57 21:12 (good -test), continue PD 8/212018 812/2018 1.75 PRODI DRILL PULD T RIH w/Lateral BHA#31 78.2 10,350.0 21:12 22:57 8/2/2018 8/2/2018 0.20 PROD1 DRILL DLOG T Log the K1 marker correction of plus 10,350.0 10,363.0 22:57 23:09 4.5', PUW 40 k 8/2/2018 8/2/2018 0.25 PRODi DRILL TRIP T Continue IH 10,363.0 11,013.0 23:09 23:24 8/212018 8/3/2018 0.60 PROD1 DRILL DRLG P OBD, 1.79 bpm @ 4,954 psi, 11,013.0 11,045.0 23:24 00:00 WHP=391, BHP=3,996, IA=O, OA=169, 8/3/2018 8/3/2018 1.93 PROD1 DRILL DRLG P OBD, 1.78 bpm @ 5,231 psi, 11,045.0 11,410.0 00:00 01:55 WHP=345, BHP=4,014, IA=13, OA=236 8/3/2018 613/2018 0.38 PROM DRILL WPRT P Wiper up hole to the EOB, PUW 41 k 11,410.0 10,555.0 01:55 02:18 8/3/2018 8/3/2018 0.38 PROD1 DRILL WPRT P Wiper back in hole, RIW 15 k 10,555.0 11,410.0 02:18 02:41 8/3/2018 8/3/2018 2.41 PROD1 DRILL DRLG P BOBD, 1.79 bpm at 4,806 psi, 11,410.0 11,810.0 02:41 05:06 WHP=316, BHP=3,950, IA=33, OA=293 8/3/2018 8/3/2018 1.10 PROD? DRILL WPRT P Wiper up -hole, PUW =41K 11,810.0 10,330.0 05:06 06:12 8/312018 8/3/2018 0.70 PROM DRILL WPRT P Wiper in-hole, RIW = 11.5K 10,330.0 11,810.0 06:12 06:54 6/3/2018 8/3/2018 3.50 PROD1 DRILL DRLG P BOBD, pumping 1.8 bpm, FS = 1070 11,810.0 12,222.0 06:54 10:24 psi, CWT = 3K, WOB = 2.3K, BHP = 3981 psi, circ pressure = 5311 psi, WHP = 400 psi, pump sweeps @ 12,000', PUW = 42K, pump sweeps @ 12,130', lower ROP beginning at 12,189' 8/3/2018 813/2018 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW =44K 12,222.0 11,389.0 10:24 10:42 8/3/2016 8/312018 0.30 PROD1 DRILL WPRT P Wiper in-hole, RIW = 11.5K 11,389.0 12,222.0 10:42 11:00 8/3/2018 8/3/2018 3.00 PRODt DRILL DRLG P BOBD, pumping 1.8 bpm, FS = 1075 12,222.0 12,348.0 1100 14:00 psi, CWT = 2K, WOB = 1.8K, circ = 5442 psi, BHP = 4086 psi, WHP = 350 psi, low ROP beginning at 12,277', -35%Ankerite in sample from 12,335 (down to 3 fph) 8/3/2018 8/3/2018 2.50 PROD1 DRILL DRLG P Drilling break at 12,348', short lived, 12,348.0 12,403.0 14:00 16:30 drilling with low ROP w/ Ankerite in samples, CWT = 9.5K (up to 300 fph), WOB = 1K, BHP = 4109 psi, WHP = 368 psi, PUW = 45K Page 18129 Report Printed: 8/012018 Operations Summary (with Timelog Depths) ft-- 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Stan Time Ertl Time Our (hr) phase Cp Cotle A vhy Code nme PJA Operedon MKB) End Depth(flNB) 8/3/2018 8/3/2018 3.25 PROD1 DRILL DRLG P Continue drilling wl low ROP, pointing 12,403.0 12,561.3 16:30 19:45 straight down working to break through, CWT = -5K, WOB = 3.7K, BHP = 4075 psi, drilling break at 12,406- 8/312018 8/3/2018 0.30 PROD1 DRILL WPRT P 500' wiper up hole, PUW 49 k 12,561.3 12,068.0 19:45 20:03 8/3/2018 8/3/2018 0.25 PROD1 DRILL WPRT P Wiper back IH, RIW 1 k 12,068.0 12,561.3 20:03 20:18 8/3/2018 8/3/2018 2.20 PROD1 DRILL DRLG P BOBD, 1.82 bpm at 4,703 psi, 12,561.3 12,663.0 20:18 22:30 WHP=301, BHP=4,087, IA=374, OA=638 *** Note: New Mud at the bit @ 12,663' 8/3/2018 8/4/2018 1.50 PROD1 DRILL DRLG P New mud at the bit, OBD 1.82 bpm @ 12,663.0 12,722.0 22:30 00:00 5,176 psi, WHP=355, BHP=4,137, IA=391, OA=648 8/4/2018 8/4/2018 3.00 PROD1 DRILL DRLG P OBD, 1.81 bpm @ 5,069 psi, 12,722.0 12,850.0 00:00 03:00 WHP=378, BHP=4,155, IA=343, OA=565 8/4/2018 8/4/2018 1.20 PROD1 DRILL WPRT P Wiper up hole, PUW 45 k,(jog the 7" 12,850.0 10,350.0 03:00 04:12 110338'- 10,410), jog 7" casing 8/4/2018 8/4/2018 0.20 PROD1 DRILL DLOG P Log the K1 marker correction of plus 10,350.0 10,363.0 04:12 04:24 1 4.5' 8/4/2018 8/4/2018 1.40 PROD1 DRILL WPRT P Continue wiper back in hole, RIW 14 10,363.0 12,850.0 04:24 05:48 k, had to work to bottom from -12,400', reducing rate to work through 8/4/2018 8/4/2018 3.20 PROD1 DRILL DRLG P BOBD, pumping 1.8 bpm, FS = 1080 12,850.0 12,974.0 05:48 09:00 psi, CWT=-5K, WOB=1K, dp=1178 psi, BHP = 4125 psi, WHP = 347 psi 8/4/2018 8/4/2018 0.60 PRODt DRILL DRLG P Confer w/ town, decison made to trip 12,974.0 12,994.0 09:00 09:36 for bit, pump sweeps, additional sweeps timed for EOB 8/4/2018 8/4/2018 3.50 PRODt DRILL WPRT P POOH, PUW = 45K, open EDC in 7" 12,994.0 78.0 09:36 13:06 casing & jog, jogs at 5000'& 1000', add 1 % LoTorq to mud system, tag up 8/4/2018 8/4/2018 1.50 PROD1 DRILL PULD P PJSM, PUD BHA #31, replace quick 78.0 0.0 13:06 14:36 test union o-rings, bit came out a 2-2 w/ 1 missing nose cutter & 1 reamer Cutter (2-2), motor missing fill port plug 8/4/2018 8/4/2018 2.00 PROD1 DRILL PULD P Swap lower section of coil track (new 0.0 78.0 14:36 16:36 resistivity tool per geology request) PD BHA #32 (new agitator, 0.4°+AKO motor, RB HYC B8 bit), slide in cart, check pack-offs, MU to coil, tag up, set counters 8/4/2016 8/4/2018 1.91 PROD1 DRILL TRIP P RIH w/ BHA#32, close EDC, test tools 78.0 10,350.0 16:36 18:30 @ 500', good, open EDC, FS = 1000 psi 8/4/2018 8/4/2018 0.20 PROD1 DRILL DLOG P Log the Kt marker correction of plus 10,350.0 10,363.0 18:30 18:42 4.0', PUW 38 k 8/4/2018 8/4/2018 0.20 PROD1 DRILL TRIP P Continue IH, RIW 14 k 10,363.0 11,160.0 18:42 18:54 8/4/2018 8/4/2018 0.20 PROD1 DRILL DLOG P Perfrom Mad Pass 11,160.0 11,026.0 18:54 19:06 8/4/2018 8/4/2018 0.74 PROD1 DRILL TRIP P Continue IH,. RIW 14 11,026.0 12,994.0 19:06 19:51 8/4/2018 8/4/2018 1.30 PROD1 DRILL DRLG P BOBD, 1.81 bpm at 5,328 psi, 12,994.0 13,014.0 19:51 21:09 diff-1,180 psi, WHP=298, BHP=4,125, IA =194, OA=487 Page 19129 Report Printed: 812212018 Operations Summary (with Timelog Depths) 3H-31 Conocol"hillips, Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Toe I End Time Dur(hr) Phase Op code Activity Code Time P-T-x Operation (MKS) End Depth(ftKB) 8/4/2018 8/5/2018 2.85 PROD1 DRILL DRLG P BOBD, 1.70 bpm at 4,925 psi, 13,014.0 13,026.0 21:09 00:00 diff-1,180 psi, WHP=298, BHP=4,125, IA=194, OA=487 8/5/2018 8/512018 PRODi 13,026.0 00:00 00:60 8/5/2018 8/5/2018 0.30 PROD1 DRILL DRLG P BOBD, 1.70 bpm at 4,925 psi, 13,026.0 13,039.0 00:00 00:18 diff-1,180 psi, WHP=298, BHP=4,125, IA=194, OA=487 8/5/2018 8/5/2018 1.50 PROD1 DRILL DRLG P OBD, 1.80 bpm at 5,306 psi, 13,039.0 13,110.0 00:18 01:48 diff-1,180, WHP=324, BHP=4,145, IA=451, OA=697 8/5/2018 8/5/2018 0.10 PROD1 DRILL DRLG P PUW 38 k, 13,110.0 13,110.0 01:48 01:54 8/5/2018 8/5/2018 2.20 PROD1 DRILL DRLG P BOBD, 1.81 bpm @ 5,359 psi, 13,110.0 13,232.0 01:54 04:06 diff-1,180 psi, WHP=323, BHP=4,145, IA=452, OA=698 8/5/2018 8/5/2018 2.90 PROD1 DRILL DRLG P OBD, 1.81 bpm at 5,424 psi, 13,232.0 13,349.0 04:06 07:00 diff--1,180 psi, WHP=324, BHP=4,146, IA=452, OA=699 8/5/2018 8/5/2018 0.90 PRODt DRILL DRLG P OBD, 1.82 bpm @ 5461 psi, BHP = 13,349.0 13,395.0 07:00 07:54 4140 psi, WHIP = 311 psi, dp = 1267, CWT= -3K, WOB=.75K 8/5/2018 8/5/2018 0.30 PROD1 DRILL WPRT P Wiper up-hole, PUW =48K 13,395.0 12,453.0 07:54 08:12 8/5/2018 8/5/2018 0.50 PROD1 DRILL WPRT P Wiper in-hole, RIW =6K, worked to 12,453.0 13,395.0 08:12 08:42 get to bottom from -12,750' 8/5/2018 8/5/2018 2.00 PROD1 DRILL DRLG P BOBD, FS = 1180 psi @ 1.8 bpm, 13,395.0 13,467.0 08:42 10:42 CWT = -51K, WOB = 1.3K, BHP = 4077 psi, WHIP = 161 psi, begin adding additional 0.5% LoTorq to system 8/5/2018 815/2018 2.00 PROD1 DRILL DRLG P Drilling, 1.8 bpm, circ pressure = 5427 13,467.0 13,524.0 10:42 12:42 psi, BHP = 4074 psi, CWT = OK, WOB = 0.81K, rip = 1261 psi, reduce rate to allow DD to capture survey, PUW = 49K @ 13,510', BHA wiper, grab survey, work to get to bottom, stuggling wl weight transfer Begin sending bead pills 815/2018 8/5/2018 2.00 PROD1 DRILL DRLG P Drilling, 1.8 bpm, CWT=-3, WOB = 13,524.0 13,621.0 12:42 14:42 1K, rip=1315, PUN =52K@ 13,539', experiencing vibrations up to 4's, marginal benefit in weight transfer 8/5/2018 8/5/2018 1.20 PROD1 DRILL DRLG P Drilling, 177 bpm, FS = 1139 psi, tlp = 13,621.0 13,660.0 14:42 15:54 1369 psi, CWT = 2.8K, WOB = 0.81K, BHP = 4096, continue struggling w/ weight transfer 8/5/2018 8/512018 0.40 PROD1 DRILL WPRT P Wiper up-hole, PUW =51K 13,660.0 12,293.0 15:54 16:18 815/2018 8/5/2018 0.60 PROD1 DRILL WPRT P Wiper in-hole, RIW=4K 12,293.0 13,660.0 16:18 16:54 8/5/2018 8/5/2018 3.25 PROD1 DRILL DRLG P BOBD, lubed/beaded pill exiting bit, 13,660.0 13,904.0 16:54 20:09 1.8 bpm, CWT =IK, WOB =0.5K, dp = 1475 psi 8/5/2018 8/5/2018 0.10 PRODt DRILL WPRT P PUH, BHA wiper up hole, PUW 37 k 13,904.0 13,904.0 20:09 20:15 8/5/2018 8/5/2018 1.25 PROD1 DRILL DRLG P BOBD, 1.81 bpm at 5,673 psi, 13,904.0 13,951.0 20:15 21:30 Dig-1,203, WHP=238, BHP=4,319, IA=576, OA=625 8/5/2018 8/5/2018 1.75 PRODII DRILL WPRT P Motor work fail off, pull heavy, PUW 54 13,951.0 10,350.0 21:30 23:15 k, Wiper up hole, for tie in , jet the 7", jog 7" w/sweep, pump bottoms up Page 20129 Report Printed: 812212018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sled Depth Start Time End Time our (hr) Phase Op Code Activity Corte Time P -T -X operation (flKB) End Depth MR) 8/5/2018 815/2018 0.20 PROD1 DRILL DLOG P Log K1 marker correction of plus 7.0', 10,350.0 10,367.0 23:15 23:27 PUW 35 k 8/5/2018 8/6/2018 0.55 PROD1 DRILL WPRT P Perform Static Pressure survey --12.61 10,367.0 10,781.0 23:27 00:00 ppg, continue wiper in hole Sesor Depth TVD=5931.94' Annular Press =3,889 psi Current MW=8.58 ppg 8/6/2018 816/2018 1.50 PROM DRILL WPRT P Continue wiper back in hole, RIW 15 k 10,781.0 13,730.0 00:00 01:30 8/6/2018 8/6/2018 0.10 PROD1 DRILL WPRT P Set down do to weight transfer, PUH, 13,730.0 13,730.0 01:30 01:36 wait for beads 8/6/2018 8/6/2018 0.50 PROM DRILL WPRT P Continue IH, 2-4 k positive CTSW with 13,730.0 13,951.0 01:36 02:06 1.0 Ib beaded pill 8/6/2018 8/6/2018 0.10 PROD1 DRILL DRLG P Set down 4 k DHWOB, PUH, restart 13,951.0 13,951.0 0206 02:12 3.8 k 8/6/2018 8/6/2018 1.40 PROD1 DRILL DRLG P OBD, 1.81 bpm at 5,580 psi FS, 13,951.0 13,955.0 02:12 03:36 Diff -1,205 psi, WHP=251, BHP=4,268, IA=521, OA=566 8/6/2018 8/6/2018 4.00 PROM DRILL DRLG P Drilling break, 45-50 fph, OBD, 1.81 13,955.0 14,132.0 03:36 07:36 bpm at 5,698 psi, Diff=1,205 psi, WHP=249, BHP=4,226, IA=532, OA=574 8/6/2018 8/6/2018 3.40 PROD1 DRILL DRLG P Drilling, 1.8 bpm, BHP = 4184 psi, 14,132.0 14,243.0 07:36 11:00 WHP = 125 psi, CWT = -3K, WOB = 2.35K, pumping beaded pills 8/6/2018 8/612018 1.00 PROD1 DRILL DRLG P Plan from town, point straight up and 14,243.0 14,254.0 11:00 12:00 squire top of C -Sands Drilling, 1.8 bpm, CWT = 7K, WOB _ .2K, BHP = 4096 psi 8/6/2018 8/6/2018 1.40 PRODt DRILL WPRT P 500' wiper, stacking weight RIH, 14,254.0 14,254.0 12:00 13:24 reduce rate, struggling to get to bottom 8/6/2018 8/6/2018 4.60 PROD1 DRILL DRLG P Drilling, 1.8 bpm, FS = 1264 psi @ 1.8 14,254.0 14,266.0 13:24 18:00 bpm, CWT = -6.5K, WOB = 3K, BHP = 4170 psi, low ROP (2-4 fph) 8/6/2018 8/6/2018 2.00 PROD1 DRILL DRLG P Continued drilling w/ low ROP, 1.8 14,266.0 14,284.0 18:00 20:00 bpm, CWT = 1.7K, WOB = 3.5K, BHP = 4300 psi, drilling break at -14,267', ROP again dropped at 14,281' 8/6/2018 8/6/2018 2.10 PROD1 DRILL DRLG P Drilling, low ROP, 1.8 bpm, CWT 14,284.0 14,289.0 20:00 22:06 =AK, WOB = 3.6K, BHP = 4269 psi, WHP = 243, dp = 1341 psi, decision made to wiper up to window & obtain SBHP, pump 5 x 10 ( Io -vis & hi -vis bead pills) 8/6/2018 8/6/2018 1.28 PROD1 DRILL WPRT P Wiper to window, PUW=42K 14,289.0 10,442.0 22:06 23:22 8/6/2018 8/7/2018 0.62 PROD1 DRILL WPRT P PU through window, jog the 7" clean, 10,442.0 10,343.0 23:22 00:00 pumping bottoms up x 2 81712018 8/7/2018 0.50 PROD1 DRILL WPRT P Continue jogging 7", circulating 10,343.0 10,350.0 00:00 00:30 1 bottoms up. 8/7/2018 817/2018 0.20 PROD1 DRILL DLOG P Log the K1 marker correction of plus 10,350.0 10,370.0 00:30 00:42 4.0' 8/7/2018 8/7/2018 0.90 PROM DRILL WPRT P Perform Static Pressure Survey, bleed 10,370.0 10,370.0 00:42 01:36 well down 12.08 ppg (3,726 psi), monitor well, BHP=3,874 psi/12.565 ppg 8/7/2018 81//2018 1.20 PROD1 DRILL WPRT P Wiper back IH, RIW 15 k 10,370.0 14,289.0 01:36 02:48 8/7/2018 8/7/2018 4.20 PROM DRILL DRLG P BOBD, 1.8 bpm at 5,825 psi, 14,289.0 14,302.0 02:48 07:00 Diff -1,260 psi, WHP=226, BHP=4,282, IA=395, OA=496 Page 21129 Report Printed: 812212018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Suri Depth Stall Time End Tire Der(hr) Phaco Op Code Activity Code opendim (ills)) End Depth (WB) 8/7/2018 8/7/2018 2.50 PROD1 DRILL WPRT Wiper up to 7" Jog window & 7" csg. 14,302.0 10,369.0 07:00 09:30 817/2018 8/7/2018 1.25 PROD1 DRILL DLOG Log K-1, Correct +3. RIH, stack at 10,369.0 10,369.0 09:30 10:45 rP window. Turn TF 30R, go by. RIH. Call from town, decided to log RA to ensure WS has not moved. Log RA for a +1. 877/2018 8/7/2018 1.90 PROD1 DRILL WPRT Trip to bottom in prep for swab wiper. 10,369.0 14,305.0 10:45 12:39 Time out 10 x 10 sweep to bit. Tag TD 14305' 8/7/2018 817/2018 3.30 PROD1 DRILL WPRT P Start wiper to swab, chasing out 10 x 14,305.0 78.2 12:39 15:57 10 sweep w/ beads. 42K off BTM, pumping @ 1.81 BPM CP 5829, WHIP 134 PSI. At 500', Jog back up to 1000', then pooh to surface. Tag up @ 78.19 (78.12 BHA) 8/7/2018 8/7/2018 1.75 PROD1 DRILL WPRT P RIH 78.2 10,350.0 15:57 17:42 8/7/2018 8/7/2018 0.20 PROD1 DRILL DLOG P Log K1 marker correction of plus 5.0' 10,350.0 10,368.0 17:42 17:54 8/7/2018 817/2018 0.10 PROD1 DRILL WPRT P Continue IH 10,368.0 10,445.0 17:54 18:00 817/2018 8/7/2018 0.25 PROD1 DRILL TRIP T Set down at the bottom of window @ 10,445.0 10,445.0 18:00 18:15 HS, PUH, attempt again @ 30R and 30L. unsuccessful, crew change 817/2018 8/7/2018 0.25 PROW DRILL TRIP T Attempt to pass through window @ 10,445.0 10,445.0 18:15 18:30 HS, unsuccessful, discussed with town on plan forward. decision was made to POOH to inspect BHA 8/7/2018 8/7/2018 2.00 PROD1 DRILL TRIP T POOH, opening the EDC at 5,420' 10,445.0 78.2 18:30 20:30 8/7/2018 877/2018 0.10 PROD1 DRILL PULD T PJSM, tag up, space out+ 1.0' 78.2 78.2 20:30 20:36 817/2018 8/7/2018 1.20 PRODt DRILL PULD T PUD, drilling BHA# 32 78.2 0.0 20:36 21:48 Note: Bit Gauge 54 8/7/2018 8/712018 0.20 PROD1 DRILL PULD T LD motor/agitator/FVS 0.0 0.0 21:48 22:00 8/7/2018 8/7/2018 0.25 PROD? DRILL PULD P Function test BOPE 0.0 0.0 22:00 22:15 8/7/2018 181712018 1.25 PROD1 DRILL PULD T PD Redress BHA #33 0.0 62.7 22:15 23:30 8/7/2018 181712018 0.25 PROD1 DRILL PULD T Stab UQC, surface test tools (good- 62.7 62.7 23:30 23:45 test) 8/7/2018 877/2018 0.10 PROD1 DRILL PULD T Stab INJH, tag up reset counters 62.7 62.7 23:45 23:51 8/7/2018 8/8/2018 0.15 PROD1 DRILL TRIP T RIH 62.7 62.7 23:51 00:00 8/8/2018 818/2018 1.80 PROD1 DRILL TRIP T RIH, w/Re-dress BHA# 33 with 62.7 10,350.0 00:00 01:48 crayola mill (2.79 OD no-go) 8/8/2018 8/8/2018 0.20 PRODi DRILL DLOG T Log the K1 marker correction of plus 10,350.0 10,368.0 01:48 02:00 5.0' 8/8/2018 8/8/2018 0.10 PROD1 DRILL TRIP T Continue IH 10,368.0 10,407.0 02:00 02:06 8/8/2018 8/812018 1.30 PROD1 DRILL REAM T Reaming 1.8 bpm @ 4,789 psi, 10,407.0 10,462.0 02:06 03:24 Diff --399 psi, WHP=192, BHP=3934, IA=84, OA=233, HS, 30 LOHS, HS, 30 ROHS, HS, dry drift clean to 10,462' 8/8/2018 8/8/20182.35 PROD1 DRILL TRIP T Open EDC, POOH 10,462.0 62.0 03:24 05:45 8/8/2018 8/8/2018 1.00 PROD1DRILL PULD T PJSM. PUD, Lay dawn BHA. 62.0 0.0 05:45 06:45 I Page 22129 Report Printed: 8122/2018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time EMTime Dur(hr) Phase op Code AdiNty Code Time RT -X Operation MKe) End Depth(fl(B) 8/6/2018 8/8/2018 1.75 PROD1 DRILL PULD T PJSM, PD BHA#34 68.0 68.0 06:45 08:30 8/8/2018 8/8/2018 PROD1 DRILL TRIP T RIH, stop @ pump to test agitator, 68.0 10,438.0 08:30 11:45 good. CRIH. Log K1 for a +2 correction. Drift thin window cleanly. Stop trouble lime. 8/8/2018 8/8/2018 PROD1 DRILL TRIP P Continue RIH, clean down to BTM & 10,438.0 14,304.0 11:45 12:15 confirm TD @ 14,304' 8/8/2018 8/8/2018 [3.75 PROD1 DRILL DISP P Get 12.8 KWF beaded liner pill lined 14,304.0 68.0 12:15 16:00 up to pump down coil. Move pipe slowly until liner pill gets to the bit. Lay in beaded pill in open hole. Pump 12.8 KWF to surface. 8/8/2018 8/8/2018 -PR-0-D1-DR-ILL OWFF P Tag up. Watch well for flow & perform 68.0 68.0 16:00 16:30 PJSM. 8/8/2018 181M018 1.75 PROD1 DRILL PULD P Inspect 12' of CT above connector.Lay 68.0 0.0 16:30 18:15 1 down BHA# 34. 8/8/2018 8/8/2018 0.50 COMPZ1 CASING PUTS P Prep Rig Floor for liner operations 0.0 18:15 18:45 1 8/8/2018 8/8/2018 2.00 COMPZ1 CASING PUTB P PJSM, PU/MU Lower A liner assembly 0.0 630.1 18:45 20:45 w/20 Its of slotted liner & shorty deployment sleeve 8/8/2018 8/812018 0.25 COMPZ1 CASING PULD P su PU/MU Coiltrak tools, perform rface 630.1 675.5 20:45 21:00 test (good -test) 8/8/2018 8/812018 1.60 COMPZ1 CASING RUNL P Tag up, reset counters, RIH, set down 675.5 10,376.0 21:00 22:36 @ TOW, PUW 41 k 8/8/2018 8/8/2018 0.20 COMPZ1 CASING RUNL P Correct to the EDP flag, minus 3.9' 10,376.0 10,376.0 22:36 22:48 8/812018 8/812018 0.20 COMPZ1 CASING RUNL P Continue IH through window clean 10,376.0 10,955.0 22:48 23:00 818/2018 8/812018 0.20 COMPZI CASING RUNL P Log the K1 marker correction of plus 10,955.0 10,982.0 23:00 23:12 4.5' 8/8/2018 8/9/2018 0.80 COMPZ1 CASING RUNL P Continue IH 10,982.0 13,496.0 23:12 00:00 8/9/2018 8/9/2018 0.25 COMPZ1 CASING RUNL P Continue RIH with lower liner 13,496.0 14,170.0 00:00 00:15 1 assembly w/20 jts of slotted liner 819/2018 8/9/2018 0.67 COMPZ1 CASING RUNL T Set tlown 14,170', PUH PUW 50 k, 14,170.0 14,304.0 00:15 00:55 work pipe towards bottom 8/9/2018 8/9/2018 0.20 COMPZt CASING RUNL P Liner on bottom, bring pump up to 14,304.0 13,646.0 00:55 01:07 1.44 bpm at 6,000 psi, PUW 38 k, stop and remove liner length from BHA, line up across the top 819/2018 8/912018 2.80 COMPZ1 CASING TRIP P POOH BHA# 35, pumping across the 13,646.0 45.0 01:07 03:55 top 8/9/2018 8/9/2018 0.50 COMPZ1 CASING PULD P PJSM, LD Liner Running Tools 45.0 0.0 03:55 04:25 8/9/2018 8192018 4.00 COMPZ1 P PU/MU Upper A Lateral Liner 0.0 1,467.0 04:25 08:25 Assembly 8/9/2018 8/9/2018 2.58 COMPZI RUNL P RIH w/ "A"Liner upper section. (44 jls) 1,467.0 13,283.0 08:25 11:00 w/ Liner top billet. Stack out @ 13,283' 9/2018 8/9/2018 2.75 COMPZI rASINGPUTB RUNL T Work pipe, get by 13,283'after2 13,283.0 13,283.0 11:00 13:45 cycles. Work it down stacking out in various depths. Get down to 13,595'. Cycled pipe & lost ground. 8/9/2018 8/9/2018 0.75 COMPZ1 RUNL T Decision made to PUH 1000'to 12,300.0 13,283.0 13:45 14:30 12,300'. RBIH, no issues until 13283'. Cylced pipe several times, no go. 8/9/2018 8/9/2018 2.25 C0MPZ1 CASING TRIP T Decsion made to POOH to surface. 13,283.0 1,467.0 14:30 16:45 8/9/2018 8/9/2018 2.09 COMPZ11 CASING PULD T Tag up. Flow check. PJSM. Lay down 1,467.0 724.3 16:45 18:50 BHA, Billet & 22 jts of liner. Page 23129 Report Printed: 812 212 01 8 Summary (with Timelog Depths) 3H-31 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stall Depth Sten Time End Tkm Dur(M) Phase Op Code Aotivlly Code Time P -T -X Operation (fll(B) End Depth (M) 8/9/2018 8/9/2018 0.42 COMPZI CASING PULD T PJSM, PU/MU Coiltrak tools, surface 724.3 768.6 18:50 19:15 test (good -test) 8/9/2018 8/9/2018 1.73 COMPZI CASING RUNL T RIH, wtih Middle A Liner Assembly 768.6 11,045.0 19:15 20:59 w/22 jls of slotted Liner, weight check above window 42 k 8/9/2018 8/9/2018 0.15 COMPZI CASING RUNL T Log K1 marker plus 1.0', did not 11,045.0 11,045.0 20:59 21:08 change depth. 8/9/2018 8/9/2018 0.70 COMPZI CASING RUNL T Continue IH w/liner 11,045.0 13,672.0 21:08 21:50 8/9/2018 8/9/2018 0.20 COMPZ1 CASING RUNL P PUW, 43 k, set back down, bring 13,672.0 12,948.4 21:50 22:02 pump online 1.4 bpm at @ 5,917 psi, 0.78 bpm returns, PUW 40 k '•' TOL= 12948.7' 8/9/2018 181912018 COMPZI CASING RUNL P Remove liner length from counters, 12,948.4 12,916.7 22:02 22:02 line up across the top 8/9/2018 8/10/2018 1.96 COMPZI CASING TRIP P POOH, BHA#37 12,916.7 4,291.0 22:02 00:00 8/10/2018 8/10/2018 0.75 COMPZI CASING TRIP P Continue POOH w/ BHA #35 4,291.0 44.5 00:00 00:45 8/10/2018 8/10/2018 0.50 COMPZ1 CASING OWFF P PJSM, check well for Flow 44.5 44.5 00:45 01:15 8/10/2018 8/10/2018 0.75 COMPZI CASING PULD P LD Setting tools BHA# 37 44.5 0.0 01:15 02:00 8/10/2018 8/1012018 1.75 COMPZI CASING P Pick-up liner run #3. 0.0 744.5 02:00 03:45 8/10/2018 8/10/2018 3.00 COMPZI CASING P RIH wl Liner run #3, tie in far+1'Corr. 744.5 12,947.0 03:45 06:45 Set@ 12,947'. Pump off. 8/1012018 8/10/2018 2.25 COMPZI CASING ERUNL P Tdp out. 12,947.0 44.5 06:45 09:00 8/10/2018 8/10/2018 0.80 COMPZI CASING P Tag up. Check well for flow. PJSM. 44.5 0.0 09:00 09:48 Break off & lay down tools. 8/10/2018 8/10/2018 1.00 PRGD2 STK P PJSM; Pick up drilling BHA. BHA # 39 0.0 78.2 09:48 10:48 8/10/2018 8/10/2018 2.75 PROD2 STK TRIP P RIH w/ BHA# 39, Drilling BHA. Test 78.2 12,244.0 10:48 13:33 Agitator @ 500', good. Continue RIH, tie in for+ 1. Dry tag Billet @ 12,244. Drilling mud @ the bit, 8110/2018 8/10/2018 1.50 PROD2 STK DISP P Swap hole over to 8.6 used drilling 12,244.0 12,244.0 13:33 15:03 mud, Catch formate sample from open hole. 8/10/2018 8110/2018 2.60 PROD2 STK KOST P Fluid swap Complete, Start kick off of 12,244.0 12,253.0 15:03 17:39 billet. 20L TF. WHP 145 psi, CP 5331, Rate 1.76 BPM, @ 1'/hr, 27hr, and 1o'mr, 8/10/2018 8/10/2018 0.20 PROD2 DRILL DRLG P Increase WOB, drill ahead, 1.77 bpm 12,253.0 12,282.0 17:39 17:51 @ 5,233 psi, WHP=139, BHP=4,157, IA=318, OA=343 8/10/2018 8/10/2018 0.20 PROD2 DRILL WPRT P PUH, PUW 38 k, dry drift kickoff point 12,282.0 12,213.0 17:51 18:03 (Billet) clean. 8/10/2018 8/10/2018 0.20 PROD2 DRILL WPRT P RBIH 12,213.0 12,282.0 18:03 18:15 8/10/2018 8110/2018 2.00 PROD2 DRILL DRLG P BOBD, 1.78 bpm @ 5,221 psi, 12,282.0 12,559.0 18:15 20:15 WHP=139, BHP=4,151, IA=319, OA=344 8/10/2018 8/10/2018 0.15 PROD2 DRILL WPRT P BHA wiper up hole, PUW 45 k 12,559.0 12,559.0 20:15 20:24 8/10/2018 8/1012018 0.75 PROD2 DRILL DRLG P BOBD, 1.78 bpm @ 1.78 bpm @ 12,559.0 12,650.0 20:24 21:09 5,221 psi, WHP=145, BHP=4,164, IA=319,OA=344 8/10/2018 8/10/12018 0.20 PROD2 DRILL WPRT P Wiper up hole PUW 40 k 12,650.0 12,265.0 21:09 21:21 Page 24129 Report Printed: 8122/2018 Operations Summary (with Timelog Depths) AMY 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slart Depth SlartTim End Time our (hr) Phase op Code Activity Code Time P -T -k Operation (al(B) End Depth (WS) 8/10/2018 8/10/2018 0.20 PROM WPRT P Wiper back in hole, RIW 7.5 k 12,265.0 12,650.0 21:21 21:33 8/1012018 8/10/2018 1.55 PROD2 DRLG P BOBD, 1.8 bpm @ 5,255 psi, 12,650.0 12,822.0 21:33 23:06 WHP=155, BHP=4,161, IA=320, rDRILL OA=345 8/10/2018 8/10/2018 0.20 PROD2 WPRT P Short BHA Wiper up hole, PUW 39 k 12,822.0 12,822.0 23:06 23:18 8/10/2018 8/11/2018 0.70 PROD2 DRLG P BOBD, 1.77 @ 5,224 psi, WHP=153, 12,822.0 12,920.0 23:18 00:00 BHP=4,176, IA=322, OA=348 8/1112018 8/11/2018 1.85 PROD2 DRILL DRLG P OBD, 1.77 @ 5,224 psi, WHP=153, 12,920.0 13,036.3 00:00 01:51 BHP=4,176, IA=322, OA=348 8/11/2018 8/11/2018 0.88 PROD2 DRILL WPRT P Wiper up hole to the window, PUW 48 13,036.3 10,340.0 01:51 02:43 k 8/1112018 8/11/2018 0.75 PROD2 DRILL WPRT P Jog the 7" clean w/sweep and bottoms 10,340.0 10,350.0 02:43 03:28 up. 8/11/2018 8/11/2018 0.20 PROM DRILL DLOG P Log the K1 marker correction of plus 10,350.0 10,368.0 03:28 03:40 4.5' 8/112018 8111/2018 0.80 PROD2 DRILL WPRT P Wiper back in hole, RIW 14 k 10,368.0 13,036.0 03:40 04:28 8/11/2018 8/11/2018 7.50 PROD2 DRILL DRLG P OBD, 1.81 bpm @ 4721 psi, 13,036.0 13,387.0 04:28 11:58 WHP=133, BHP=4,149, WA 276, OA=352. Pull several BHAwipers along the way. Pull early 800' wiper. 8/11/2018 8/11/2018 0.70 PROD2 DRILL WPRT P Pull 800'wiper. 13,387.0 12,587.0 11:58 12:40 8/11/2018 8/11/2018 0.33 PROD2 DRILL WPRT P Wiper, RBIH 12,587.0 13,387.0 12:40 13:00 8/11/2018 8/11/2018 6.50 PROD2 DRILL DRLG P OBD, 1.81 bpm @ 4863 psi, 13,387.0 13,580.0 13:00 19:30 WHP=197, BHP=4,145, IA=420, OA=440. 8/11/2018 8/1112018 1.25 PROD2 DRILL DRLG P OBD, 1.77 bpm @ 4,747 psi, 13,580.0 13,650.0 19:30 20:45 WHP=327, BHP=4,226, IA=475, OA=487 8/1112018 8/11/2018 1.20 PROD2 DRILL WPRT P PUH, PUW 55 k, Wiper up hole to the 13,650.0 10,350.0 20:45 21:57 window, 8111/2018 8/11/2018 0.50 PROM DRILL WPRT P Jog the 7" clean, w/sweep & bottoms 13,350.0 13,350.0 21:57 22:27 up. 8/11/2018 8/11/2018 0.20 PROD2 DRILL DLOG P Log the Kt marker (plus 4.5') 13,350.0 10,368.0 22:27 22:39 8/11/2018 8/11/2018 1.05 PROD2 DRILL WPRT P Wiper back in hole, RIW 15 k 10,368.0 13,650.0 22:39 23:42 8/11/2018 8/122018 0.29 PROD2 DRILL DRLG P BOBD, 1.8 bpm @ 4,673 psi FS, 13,650.0 13,677.0 23:42 00:00 WHP=335, BHP=4,234, IA=437, OA=487 8/122018 8/122018 2.34 PROD2 DRILL DRLG P OBD, 1.81 bpm @ 4,981 psi, 13,677.0 13,709.0 00:00 02:20 WHP=333, BHP=4,230, IA=476, OA=509 8112/2018 8/12/2018 1.50 PROD2 DRILL DRLG P OBD, 1.81 bpm @ 5,201 psi, 13,709.0 13,727.0 02:20 03:50 WHP=333, BHP=4,227, IA=476, OA=509 8/12/2018 8/1212018 6.75 PROM DRILL DRLG P OBD, 1.81 bpm @ 5,277 psi, 13,727.0 13,899.0 03:50 10:35 WHP=322, BHP=4,237, IA=500, OA=526 8/12/2018 8/12/2018 5.25 PROD2 DRILL DRLG P 10 bbls pill of beads (1 LB/bbl) @ the 13,899.0 14,015.0 10:35 15:50 bit. Continue drilling, 1.76 bpm @ 5,2712 psi, WHP=304, BHP=4,300, IA=533, OA=557 8/12/2018 8/1212018 1.00 PROD2 DRILL WPRT P PU 48k, Pull window wiper. 14,015.0 10,350.0 15:50 16:50 8/12/2018 8/12/2018 0.20 PROM DRILL CLOG P Log the K1 correction of plus 6.0' 10,350.0 10,350.0 16:50 17:02 Page 25129 Report Printed: 6/22/2018 Operations Summary (with Timelog Depths) Dill am 3H-31 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log slant Depth Start71me FEW Time Dur(N) Phase op Cade Actltity Code operation (fIKB) End Depth (flKa) 8/12/2018 8/12/2018 0.42 PROD2 WPRT Jog the 7" clean w/sweep 10,350.0 10,350.0 17:02 17:27 8/12/2018 8/12/2018 1.55 PROD2 WPRT Wiper back in hole, 10,388.0 14,015.0 17:27 19:00 rP 8/12/2018 8/12/2018 0.40 PROD2 rDRILL DRLG BOBD, 1.78 bpm @ 5,192 psi, 14,015.0 14,026.0 19:00 19:24 WHP=161, BHP=4,256, IA=569, OA=582 8/12/2018 8/1212018 0.40 PROD2 WPRT PU, heavy PUW 58 k, perform short 14,026.0 14,026.0 19:24 19:48 mini wiper up hole, work coil back to bottom. 8/12/2018 8/13/2018 4.19 PROM DRILL DRLG P BOBD, 1.79 bpm @ 5,062 psi, 14,026.0 14,154.0 19:48 00:00 WHP=158, BHP=4,326, IA=571, OA=582 8/13/2018 8/13/2018 2.75 PROD2 DRILL DRLG P OBD hard spot, 1.79 bpm at 5,599 psi, 14,154.0 14,207.0 00:00 02:45 WHP=167, BHP=4,343, IA=592, OA=594 8/13/2018 8/13/2018 1.50 PROD2 DRILL DRLG P Drilling Break, OBD hard spot, 1.79 14,207.0 14,223.0 02:45 04:15 bpm at 5,599 psi, WHP=167, BHP=4,343, IA=592, OA=594 8/13/2018 8/13/2018 10.40 PROD2 DRILL DRLG P OBD hard spot, 1.77 bpm at 5,521 psi, 14,223.0 14,415.0 04:15 14:39 WHP=175, BHP=4,314, IA=594,, OA=594 8/13/2018 8/13/2018 0.60 PROD2 DRILL WPRT P Pick-up 47k. Wiper up for 1000' 14,415.0 13,415.0 14:39 15:15 8/13/2018 8/13/2018 1.25 PROD2 DRILL WPRT P Wiper back down to depth. Had to 13,415.0 14,415.0 15:15 16:30 work back down with beads. 8/13/2018 8/1412018 7.50 PROD2 DRILL DRLG P OBD 1.76 bpm at 5446 psi, 14,415.0 14,580.0 16:30 00:00 WHP=203, BHP=4,318, IA=492, OA=523 8/14/2018 8/14/2018 0.30 PROD2 DRILL DRLG P OBD, 1.76 bpm at 5,634 psi, 14,580.0 14,588.0 00:00 00:18 Diff--1090 psi, WHP=169, BHP=4,368, IA=630, OA=627 8/14/2018 8/14/2018 0.20 PROD2 DRILL WPRT P Short BHA wiper up hole, PUW 56 k 14,588.0 14,588.0 00:18 00:30 work pipe back to bottom 8/14/2018 8/14/2018 2.20 PROD2 DRILL DRLG P BOBD, 1.76 bpm @ 5,378 off bottom, 14,588.0 14,623.0 00:30 02:42 Diff=1,100 psi, WHP=186, BHP=4,398, IA=661, OA=653 8/14/2018 8/14/2018 0.20 PROD2 DRILL WPRT P BHA Wiper uphole, PUW 55 k, work 14,623.0 14,623.0 02:42 02:54 pipe back to bottom 8/14/2018 8/14/2018 1.50 PROD2 DRILL DRLG P BOBD, 1.76 bpm @ 5,378 off bottom, 14,623.0 14,643.0 02:54 04:24 Diff-1,100 psi, WHP=186, BHP=4,398, IA=661, OA=653 8/14/2018 8/14/2018 0.20 PROD2 DRILL WPRT P PUH PUW 47 k, circulate beads down 14,643.0 14,643.0 04:24 04:36 hole 8/14/2018 8/14/2018 2.40 PROD2 DRILL DRLG P Beads turned comer, BOBD, 1.76 bpm 14,643.0 14,648.5 04:36 07:00 @ 5,378 off bottom, Diff-1,100 psi, WHP=186, BHP=4,398, IA=661, OA=653 8/14/2018 8/14/2018L2.40 PROD2 DRILL WPRT 15 TD AL1 lataeral, pump 1 0x1 0 sweep 14,648.5 14,648.5 07:00 07:18 followed by beaded pill 8/1412018 8/14/2018 PROD2 DRILL WPRT P POOH, laying in beaded pill up to 14,648.5 12,500.0 07:18 09:18 12,500' 8/W2018 8/14/2018 PROD2 DRILL WPRT P Continue POOH, pumping 1.8 bpm at 12,500.0 78.2 09:18 11:42 4,378 psi 8114/2018 8/14/2018 PROD2 DRILL WPRT P Taq up, reset counters, RBIH, 78.2 10,350.0 11:42 13:30 pumping 0.33 bpm @ 2,378 psi 8/14/2018 8/14/2018 . PROD2 DRILL DLOG P Log the K1 correction of plus 4.0' 10,350.0 10,365.0 13:30 13:42 8/14/2018 8/14/2018 0.40 PROD2 DRILL WPRT T Continue IH, set down bottom of 10,365.0 10,443.8 13:42 14:06 window HS TF, PUW 40 k, Attempt 30 ROHS, 30 LORIS, and 20 LOHS, Discuss with town plan forward. Page 26129 Report Printed: 812212018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time Er Time our (hr) Phase Op Cade Activity Code Time P -T -x Operation (fiKa) End Depih(M(B) 8/14/2018 1811412018 1.50 PROD2 DRILL TRIP T POOH, pumping 1.8 bpm at 4,858 psi 10,443.8 78.4 14:06. 15:36 8/14/2018 8/14/2018 2.30 PROD2 DRILL PULD T PUD, drilling BHA #39, Blow down and 78.4 0.0 15:36 17:54 lay down tools, Unload uper BHA section in PDL 8/14/2018 8/14/2018 2.10 PROD2 DRILL CIRC P Install nozzle and jet slack / flush rig. 0.0 0.0 17:54 20:00 Swap coil to water. Prep for BOPE test 8/14/2018 8/1512018 4.00 PROD2 DRILL BOPE P Perform full bi weekly BOPE test. test 0.0 0.0 20:00 00:00 witness waived by Adam Earl, AOGCC. On test 11. No failures 8/15/2018 8/15/2018 2.00 PROD2 DRILL BOPE P Continue Full BOPE test 0.0 0.0 00:00 02:00 8/15/2018 8/15/2018 2.20 PROD2 DRILL CTOP P Roll CT back to mud, UT coil min 0.0 0.0 02:00 04:12 reading @ .154. Inpect pack offs - Good. Retread UQC. 8/15/2018 8/15/2018 1.90 PROD2 DRILL PULD T PJSM PD BHA #40. FCO BHA with D- 0.0 68.4 04:12 06:06 331-6* AKO motor and agitator. Surface test too 8/15/2018 8/15/2018 1.80 PROD2 DRILL TRIP T RIH, w/cleanout BHA #40 68.4 10,350.0 06:06 07:54 8/15/2018 8/1512018 0.30 PROD2 DRILL DLOG T Log the K1 marker, discover counters 10,350.0 10,368.0 07:54 08:12 off by 30', reset counters to match CTES counter, PUW 45 k, re -log K1 marker, correction of minus 3.0' 8/15/2018 8/15/2018 0.25 PROD2 DRILL TRIP T Continue IH, dry drift window exit 10,368.0 10,472.0 08:12 08:27 dean down to 10,472', PUW 40 k 8115/2018 8/15/2018 0.20 PROD2 DRILL TRIP T PUH, clean through window @ 1 fpm 10,472.0 10,385.0 08:27 08:39 8/15/2018 8/15/2018 0.15 PROD2 DRILL TRIP T RBIH, @ 1 fph, seen little motor work 10,385.0 10,443.0 08:39 08:48 @ 10,439', continue @ 1 fpm, set down 3.0 k @ 10,443', PUW 40 k 6/15/2018 8/15/2018 0.15 PROD2 DRILL TRIP T PUH, PUW 40 k clean PU 10,443.0 10,385.0 08:48 08:57 8/15/2018 8/15/2018 0.15 PROD2 DRILL TRIP T RBIH, @ 1.4 bpm @ 3,748 psi, set 10,385.0 10,443.0 08:57 09:06 down 3.5 k DHWOB 8/15/2018 8/15/2018 0.15 PROD2 DRILL TRIP T PUH 42 k PUW, 10,443.0 10,385.0 09:06 09:15 8/15/2018 8/15/2018 0.15 PROD2 DRILL TRIP T RIH through window w/no pump (dry 10,385.0 10,480.0 09:15 09:24 drift) clean down to 10,480' 8/15/2018 8/15/2018 0.25 PROD2 DRILL TRIP T PUH, pumping 1.8 bpm at 4,837 psi @ 10,480.0 10,564.0 09:24 09:39 1 fpm up to 10,385', no motor work observed, repeat clean, dry drift window again down to 10,484', come on line with pump @ 0.48 bpm at 2,336 psi to the EOB 8/15/2018 8/15/2018 0.30 PROD2 DRILL TRIP T PUH, (PUW 40 k) through window HS 10,564.0 10,350.0 09:39 09:57 full rale 1.78 bpm at 4,652 psi, IA=O, OA=95 8/15/2018 8/15/2018 0.30 PROD2 DRILL TRIP T Jetted the 7" (10,408'-10,340') w/ 10,350.0 10,350.0 09:57 10:15 bottoms up, sample showing cuttings and some pipe scale. 8/15/2018 8/15/2018 0.25 PROD2 DRILL TRIP T Changeoul INJH counter 10,350.0 10,350.0 10:15 10:30 8/1512018 8/15/2018 0.20 PROD2 DRILL DLOG T Log the K1 marker w/ no correction 10,350.0 10,368.0 10:30 10:42 8/15/2018 8/15/2018 1.20 PROD2 DRILL TRIP P Continue through window clean, RIH 10,368.0 14,648.0 10:42 11:54 to confirm TD 8/15/2018 8/15/2018 2.00 PROD2 DRILL TRIP P Confirm TD, send liner running pill, 14,648.0 10,300.0 11:54 13:54 POOH laying in 12.8 ppg beaded liner pill Page 27/29 ReportPrinted: 812 212 01 8 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Ting Log sort Depth Stan Time End Tree Dur(m) Phase Do Code Activity Code Time P -T -X Operetlon (KKa) End Depth(flKe) 8/15/2018 8/15/2018 1.80 PROD2 DRILL TRIP P Beads am out, continue POOH 10,300.0 68.4 13:54 15:42 displacing well to 12.8 ppg completion fliuid while POOH 8/15/2018 8/15/2018 0.50 PROD2 DRILL TRIP P Tagged up, checked well for flow, 68.4 68.4 15:42 16:12 PJSM 8/15/2018 8/15/2018 0.70 PROD2 DRILL TRIP P LD tools on a dead well. 68.4 0.0 16:12 16:54 8/15/2018 8/15/2018 0.50 COMPZ2 CASING PUTB P Prep floor to fun Al liner lower 0.0 0.0 16:54 17:24 segment 8/15/2018 8/15/2018 1.90 COMPZ2 CASING PUTB P PJSM, M/U ALl lower segment with 0.0 677.7 17:24 19:18 non ported bullnose, 21 Jts slotted liner, and shorty deployment sleeve. Make up to coiltrak, Make up to Coil and surface test 8/15/2018 8/15/2018 2.00 COMPZ2 CASING RUNL P Trip in with BHA #41,1ie into window 677.7 10,950.0 19:18 21:18 flag for -3.91, PUW=42K, Clean pass through window 8/15/2018 8/1512018 0.10 COMPZ2 CASING CLOG P Tie into Kt for +5' 10,950.0 10,974.0 21:18 21:24 8/15/2018 8/15/2018 1.40 COMPZ2 CASING RUNL P Continue in hole, One set down @ 10,974.0 14,648.0 21:24 22:48 12883. PIU and ran past clean. Set down @ 14371. Pass through after second pick up 8/15/2018 8/1612018 1.20 COMPZ2 CASING TRIP P 14648. PUW=47, Set back down 14,648.0 10,600.0 22:48 00:00 Pump on 1.5 BPM PUW=38K. Trip out paint EOP flags @ 13319 & 9433, TOL=14014.73 8/16/2018 8/16/2018 2.20 COMPZ2 CASING TRIP P Continue out of well 10,600.0 55.0 00:00 02:12 8116/2018 8/16/2018 0.50 COMPZ2 CASING PULD P At surface, PJSM, Flow check well, 55.0 0.0 02:12 02:42 1 Lay down tools on dead well 8116/2018 8/16/2018 1.80 COMPZ2 CASING PUTB P PJSM, P/U AL1 second liner segment, 0.0 734.4 02:42 04:30 Ported bullnose, 23 As slotted liner, Shorty deployment sleeve. Pick up coil track and latch into liner. Make up to coil and surface test, Inspect packoffs 8/16/2018 8/16/2018 1.80 COMPZ2 CASING RUNL P RIH BHA #42 734.4 10,334.0 04:30 06:18 8/16/2018 8/16/2018 0.20 COMPZ2 CASING RUNL P Correct to the EOP flag minus 2.3' 10,334.0 10,334.0 06:18 06:30 8116/2018 8/16/2018 1.20 COMPZ2 CASING RUNL P Continue IH 10,334.0 14,014.0 06:30 07:42 8/16/2018 8/16/2018 0.20 C0MPZ2 CASING RUNL P Tag bottom w/3.0 k DHWOB, PUW 45 14,014.0 14,014.0 07:42 07:54 k 8/16/2018 8/16/2018 0.10 COMPZ2 CASING RUNL P Set back down 2-3.0 k, bring pump up 14,014.0 14,014.0 07:54 08:00 to 1.4 bpm @ 5,386 psi, 0.79 bpm returns, PUH PUW 37 k, line up across the top, remove liner length from counters 8/16/2018 8/16/2018 2.50 COMPZ2 CASING TRIP P POOH, painting EOP flags @ 14,014.0 44.2 08:00 10:30 12,137.6'& 9,300' 8/16/2018 8/16/2018 0.30 COMPZ2 CASING OWFF P Tag up, check well for flow, PJSM 44.2 44.2 10:30 10:48 8/16/2018 8/16/2018 0.30 COMPZ2 CASING PULD P LD tools on a dead well 44.2 0.0 10:48 11:06 8/16/2018 8/16/2018 0.20 COMPZ2 CASING PUTB P Prep RF for Liner ops, PJSM 0.0 0.0 11;06 11:18 8/16/2018 8/16/2018 1.30 COMPZ2 CASING PUTB P PU 33 jts, slotted liner 0.0 1,029.5 11:18 12:36 8/16/2018 8/1612018 0.20 COMPZ2 CASING PULD P PU/MU Coiltrak tools 1,029.5 1,075.0 12:36 12:48 Page 28/29 Report Printed: 8/22/2018 Operations Summary (with Timelog Depths) 3H-31 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SM Depth sten Time End Time Dur(hr) Phase Op Code I activity Coe Time P -T -X Operation WE) End Depth (W13) 8/16/2018 8116/2018 0.50 COMPZ2 CASING PULD P Stab INJH, perform surface test (good 1,075.0 1,075.0 12:48 13:18 1 -test) 8116/2018 8/16/2018 2.00 COMPZ2 CASING RUNL P RIH, AL1 liner segment #3 1,075.0 10,381.6 13:18 15:18 8/16/2018 8116/2018 0.20 COMPZ2CASING RUNL P Correct to the EOP flag, minus 6.6' 10,381.6 10,375.0 15:18 15:30 8/16/2018 8/16/2018 1.00 COMPZ2 CASING RUNL P Continue IH 10,375.0 13,324.0 15:30 16:30 8/16/2018 8/16/2018 0.20 COMPZ2 CASING RUNL P Set down 3.0 k on bottom, PUW 48, 13,324.0 13,324.0 16:30 16:42 set back down 3.0 k, bring pump online 1.4 bpm, 0.79 bpm returns, PUW 38' 8/16/2018 8/16/2018 2.70 COMPZ2 CASING TRIP P Liner up across the top, remove liner 13,324.0 50.0 16:42 19:24 length from countes, POOH 8/16/2018 8/16/2018 0.40 COMPZ2 CASING PULD P Tag up, check well for flow, PJSM, LD 50.0 0.0 19:24 19:48 tools on a dead well 8/1612018 8/1612018 0.50 COMPZ2 CASING PUTB P Prep floor for liner ops 0.0 0.0 19:48 20:18 8116/2018 81162018 3.60 COMPZ2 CASING PUTB P PJSM, PIU BHA #44, AL1 upper 0.0 2,021.7 20:18 23:54 completion segment #4 with ported bull nose, 34 As slotted, 29 its blank, 3 pups, and sealbore deployment sleeve. Make up to coiltrak. M/U to coil and surface test - Good 8/16/2018 8/17/2018 0.10 COMPZ2 CASING RUNL P Trip in well BHA # 44 2,021.7 2,500.0 23:54 00:00 8/17/2018 8/17/2018 1.60 COMPZ2 CASING RUNL P Continue in well, BHA #4 AL1 liner 2,500.0 10,323.4 00:00 01:36 1 1 segment #4 8/172018 8/17/2018 0.80 COMPZ2 CASING RUNL P Correct to flag -2', PUW=41 K, 10,323.4 10,321.4 01:36 02:24 1 Continue in hole 8/17/2018 8/17/2018 0.10 COMPZ2 CASING RUNL P Tag bottom @ 12293. Pumps on 1.4 10,321.4 12,278.0 02:24 02:30 BPM @ 4900 PSI, PUW=34K, PUH displace well to seawater. Remove liner length from counters -1977.46 8/17/2018 8/17/2018 1.50 COMPZ2 CASING DISP P Pump 15 BBIs spacer, Displace well to 12,276.0 10,315.0 02:30 04:00 seawater recovering KFormate 8/17/2018 8/17/2018 1.75 COMPZ2 CASING TRIP P POOH, Freeze protect from 2500" with 10,315.0 44.4 04:00 05:45 diesel 8/17/2018 8/17/2018 1.75 COMPZ2 CASING PULD P Tag up,space out, PUD setting tools 44.41 0.0 05:45 07:30 8117/2018 8/17/2018 4.50 DEMOB WHDBOP RURD P RDMO as per TP, start Rig Move 0.0 0.0 07:30 12:00 Checklist Note: RIG RELEASE 12:OOpm (noon) Page 29129 ReportPrinted: 812212018 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -31A 50-103-20205-01 Baker Hughes INTEQ Definitive Survey Report 20 August, 2018 BA ER t UGHES Econpany Wellbore Baker Hughes INTEQ Matin" Modal Nath Sample Date � Coni Definitive Survey Report 3H -31A To Survey suraly (daft) Company'. ConomPhilllps (Alaska) Inc. -Kup2 Local Coordinate Reference: Wall 3H-31 Description Steri Dau, Project Kupamk River Unit TVD Reference. 311-31@8000usfl(31431) 3Ha1(311-31) GCT -Ms Site: Kupamk 311 Pad MD Reference: 31-141($ 80.00uaX(31-41) 10435.00 10,520.11 Well: 31-1-31 North Reference: Tome 7d112010 811=10 Wellborn: 3H-31 Survey Calculation Method: Minimum Curvature MWD MWD - Standartl Design: 3H-31 Database OAKEDMP2 Page 2 COMPASS 5000 14 surd 05 __tel Project Kupamk 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 Y1bll Reference Point Map Zone. Alaska Zone 04 Us' "adds. scale factor well 3Hai Well Position sW5 0.00 usX NortBing: 8,000,887.91 oafl latitude: ]0'24'4].208N i .ERV OLD usX Edam, 498,655.24usN Longitude: 150-V39+425try Position Uncertainty O00 usX Wellhead Elevation: usfl Ground Level: am uri Wellbore 3H21A Matin" Modal Nath Sample Date (aag) BGGM2010 91112018 Design 3H -31A Audit Notes Version: 1.0 Phase: ACTUAL Vertical Section'. WM F..(TVD) (-am Mediation M 16.92 Me On Depth: 10,409.00 .103 vm (aag) (dm) 9.00 0.00 Dip Angle r) 00.91 FMW Sit) Nl) 5],441 Distract M 330.00 — Survey Program Mm From To Survey suraly (daft) (deft) Survey(Wellbork) Tool Na. Description Steri Dau, End gate 8820 10,409.00 3Ha1(311-31) GCT -Ms SrJtlumbaryer GCT muOishol IlIV2001 10435.00 10,520.11 3Hd1A MVI INC (3H -31A) MWD -INC ONLY MVilli ONLY FILLER 7d112010 811=10 10,550.01 14,271.84 3R-3IA MWO(314.31A) MWD MWD - Standartl /1112010 80¢010 84?Ovtii 12:29 59PM Page 2 COMPASS 5000 14 surd 05 Baker Hughes INTEO WIigS CMGCo illi (� Definitive Survey Report 'COMPaw. ConacoPhillips(Alaska) Inc,-Kup2 Local crdinaM Reference: A41I 3H-31 Prejech Kupamk River Unit Tilt) Refereace: 3HJl@ 00.00ush(311d1) SIM: Kupamk 3H Pad MO Reference: 311411 @ 80.00ush (3114 1) WMI: 311-31 Nodh Reference: Tme :Wa ore: 314-31 Survey Calculation Method: Minimum Curvature patient 34-31 Database: CAKEDMP2 Sidney Map Map Vertical _ MO has RE TVD TVDSS -W43 *67.00 Northing Eastin9 OLS Section Survey Tool Nerve Annotation (-am17 I7 1111 (-am (uahl (sen) (ft) Ihl 81100.1 Ittl 1.0400.00 4027 3207 5995.54 5,91554 7756.65 -1 WAS 6.000464.07 49],039.36 020 7,526.17 MWD -INC ONLY (2) TIP 10435.00 40.23 3203 6.015.39 593539 7.773.02 -1,621.20 6,0064W.4S 407,02560 0.18 7,5t223 MN41143 ONLY (2) KOP 1.4,400.32 4770 345.00 6.03500 5953.60 7,79005 -1625,47 6,000.47]40 49703134 3002 7.09.12 MN KONLY(2) MMryolated Aahmth 10,490.14 (100 34.00 5.450.94 5,970.94 7,01535 -1,631.94 6,008.503]] 497,@4.07 N69 7,58253 MJUThINCONLY(2) Intery018Md/'mulh 10,40.11 74.55 34300 6,06225 5,902.25 7039.89 -163902 6.008,527.31 497.01700 4535 7.609.45 MiisolK _ONLY(2) Intepolated Azimuth 10,5s0A1 Wes 34163 6,066.76 5,986.76 7,80874 -1649.02 6,008.555.16 497007.00 4562 7,639.04 KMCi(t) 10.585.35 90.61 U1= 6,W7.0 5.997.03 7,90150 AS59]4 6.008580.00 456.99700 B.N 7,67284 MfN(3) 10.614.4 9200 24.55 6051 5.90047 7,92939 -i'sa 4 6.00661681 496,988.79 9.34 7,701.08 Mini 10,645.06 91.35 346.98 6,065.47 5,9115.47 7,969.10 -1.675.50 6008 assist 456,98126 820 7,730.57 WARDS) 10.680.4 91.07 349.60 Sinai 5984.n 799574 -1.68273 6,OMS01.16 496,97412 7.70 7,784.15 MMDS) f 10,71055 89.45 35100 6064.55 5,961.59 %(1 -1.607,55 6000,710.60 496,96931 9.10 7,792.30 SAID (3) I 10,741.4 89.94 353.98 606415 5.964]5 8.05900 -1691.33 6.00,741.41 496,985.53 6.94 7.4063 MAIDS) j 10,7651.7 thei 35AM 0.051.81 5904.01 8,07774 -1,693.83 6,00,765.14 496.963.23 4.10 7,84234 MMA) (3) 10,79551 09.57 357.31 6,06989 59111.89 6,10890 -0.695.65 6,000 195.41 496.561.19 TIM 7,168.58 MM (3) 10,830.37 8983 004 6,065.24 5985.24 8,142.85 -1.698.49 600"103035 496960.39 Ted 7900.16 MAS) (3) ' 10,86074 08.85 0.94 6,005.69 5,985.69 8175Y2 -169623 0.008860.61 49695065 4.38 7,926.33 MWD(3) 1689283 89.4 4.63 6.066.20 5,98630 8.205W -1.694.67 6,009,89245 4%95222 11.99 7,95512 el (3) 10,92585 06.22 587 6.066.85 5,986.85 0,238.13 -0,891.4 60104.926,4 496965.27 5.39 7,80024 SAID (3) 10.957.15 86.37 7J4 6.058.32 5.98832 828919 -1.680.08 S"Ses.59 496,96882 717 8,005.37 MW0(3) 10.986.98 84.86 740 607065 5990.66 8,29899 4684.32 6,009.98607 49597259 5.03 0,49.03 MWD (3) 1101663 "1 10.30 6.073.32 5.993.32 0,327.87 -1.61 8,00001585 496977.13 9.83 0,05203 "D(3) 11,0470. .7.00 10.63 6.075.42 5,995.42 835775 -0674.25 6.096,045.12 496,982.66 665 0,075.15 MWO(3) ""S'.A8 88.96 11.85 6.076.61 8,895.618391A6 -0.657.61 5[8 ,0,070,53 496989.30 6.65 sI(o76 SAID (3) 11,111 At 89.75 1523 6.0485 Sinai, 0,420.68 -1.66105 6,060.10804 495.995.07 5.25 0,1Y394 WORD (3) 11.14286 90.61 1941 6,07685 5,916.85 8,45120 4.65354 6,009.13857 497003.39 4.64 8,145]3 MIND (3) 11174.05 to 18 1900 6,07688 5,996.09 0.40106 464.58 6000.168.42 497,01235 15.55 8,167.10 "D (3) 11,201.38 mAi 19.73 6.075.30 8,995.30 8,50683 -1,635.4 6000,194.19 497.021.41 974 0,10489 Who (3) TI.231.43 90.06 21.36 6075.00 8,99500 0,534.97 4.62998 600622232 497031.86 645 8,203.99 MWD (3) 1.1.28201 89.% 2070 6075.15 5,995.15 8,53.51 -1.614.00 6,0741.250.96 497,04294 17 SM.= BI SM.WD(3) 11.291Q BBW 2067 6.075.82 599582 659112 -1,8654 6060.27835 497053.33 4.39 0,24185 "D(3) 840!101912, n:59PM Pae 3 COMP4555000. 14 sucks W Baker Hughes INTEQ"" 0 ConocoPhillips Definitive Survey Report Company: ConocOPhillips(Alaska) Inc.-Kup2 Local Co-adinafa Reference: Mil 3H-31 I Pmfetl: Ku,iuk Riva, Unit TVD Rehnsnne: 31446 C 80.00us8(31121) SM: Kupamk 3H Pad MO Refinance: 31441@M.00usfi(914J1) Well: 344-31 Nunn Reference: True Walloons: 3H-31 Survey Calculation Method: Minimum Curvature Oeaipn: 3H-31 Database: OAKEDMP2 Survey 0al In 12'a 59PM Pape 4 COMPASS 5000. M audaf 85 MapMedica Man MD Inc AM TVD MISS -NIS 4El-W fti No(ft) Ee(tln9 DLS sastiOl Semen Survey Tool Wma Annotation (uulp PI (9 lural luanl luen) lusty) (ft) (ft) (-flow) Ie) 11322.50 07,61 2559 8.07fi 90 5,996.99 8.62006 -1$92.67 8009307,@ 409.096.26 147 0,26155 MMD (3) 1135186 89.57 21.62 Aon.n 5,99]]2 8,64)46 -0.58211 6,009,334]9 49],0]085 7.54 0,279.90 MMD(3) 11302.34 92.06 M65 6,0]]30 5,997,20 8,67569 -1.57062 6,008,363.02 497,096.33 864 8.290.66 MWD(3) 1141334 93.69 MCO 6.0]5.]3 599573 8]44.44 455940 6009,391.76 49209]55 10.06 8,31795 M (3) 11.442.84 90109 1270 6.07415 Saki 8.732.80 -1551.08 6009420.12 497,10580 2746 8,338.37 MWD(3) 1147144 8979 0.62 6.07470 5,89418 0.760.86 -1,546.29 61009448.29 497,110.69 21.28 8,360.30 MWD(3) 8550.33 9237 525 6,07424 5,994.24 8.70871 -0,54130 6,009477.02 497,113.0 1011 8,30376 "D (3) 853134 9273 1.93 60806 5,99286 0,820.52 -1,54137 6,009,507.83 492115.61 10.09 8.409.49 MD (3) 11.560.59 93.23 359.04 6871.34 589134 0.849.80 -1,54083 6,009.53710 497,116.06 222 8,43462 MD 11.58970 92.40 346.98 6069.91 Saudi 0,87669 -1,09.74 6,003.55819 497,115.25 10.21 8,46021 MID 11,621.75 91.01 35835 8.068.95 5,9!0.95 8,910.91 -1,543.07 6,0995992➢ 497.113.93 507 0.488.81 MWD (3) 1165150 9074 036 55,064.09 5,900.50 8,94064 -1543.46 5W9.5P B3 497,11155 6.02 8514.55 MND(3) 11600.18 90.52 Oo2 6,068.19 5980.19 8,968.32 -1543.24 6.M,6% 61 49211317 147 0.53927 MID (3) 1171132 58.65 0.75 6.068.40 5906.40 9809.45 4542.86 6839.687.74 497,114.15 5.92 655609 MID 1174102 8973 283 6,058.94 5,988.94 9,03013 -1,541.91 B.W9,71241 497.115.11 7.57 859128 MJJO(3) 11710.90 90.25 425 6099.00 5959.08 9.059.95 .1,540.05 6,009,]47.23 497.11697 545 0,016.17 MND(3) 1100116 09.97 5.01 6,069.02 5,989.02 9,620.09 -1,53TA1 6,0097P37 497.11962 5.40 0,040.96 MJUD(3) 11831.52 0936 610 6.06933 5,968.23 8,12023 -1.53174 6,009.807.50 497,1M30 7.09 8,66572 RAND (3) 11.860M 8997 1141 6,059.42 5,98942 9.10.94 -1,526.00 800903631 497,12824 1162 8,60].62 ~(3) 11.m.35 8948 12.13 6.059.55 5988.56 9.9601 -1,52274 6,,009665P 487,13430 293 o7W.76 MA 0) 11821.39 8637 10.42 60]0.15 5,990.15 9,20843 -1,516.60 6009065.69 492140.37 657 0,73308 MWD(3) 11,01.28 Sam 293 6,071.09 5,99109 9237.93 -1,511.91 60099M19 492145.14 842 8.75624 MWD(3) 11.980.46 8889 556 6,071.89 599109 94666.90 -1.509.49 6,009954.15 497448.57 0.67 8,77861 MWO(3) 12,011.05 07.97 3.70 66.Om8 5992.72 9.29238 -1,506.02 6,009.909.63 497,15184 876 o8D478 MWD (3) 12045.]4 05.54 075 6w7oS9 5,994.69 9.33188 -1,504.67 6010,019.23 49715240 11.01 8,83407 "D (3) 1207161 66.3] 358.14 50]6.5, 5996.51 9,352al -1,504.93 6.015.44505 497152.15 1055 685858 "D (3) 12101.30 88.09 356.39 6,OP95 599295 9,307.48 -1,505.34 6,060,0718 497,150.]4 925 0,08296 MND(3) 12,13147 68.22 35584 6,078.91 5990.02 9417.48 -1,50838 6,010.1Wh 49].148.]1 100 B,B0l MM (3) 12,16246 06.25 351.27 6,009.42 60000.42 9440.23 .1511.85 6,010,13547 497.145.24 1661 0,938.33 MWD(3) 12 19128 0285 34935 now.so 8001.90 9,47660 -1,516.70 6.010,163.83 497.140.40 867 8985.32 MA4D(3) 12221.60 68.19 34]41 6082.95 8092.95 9,50836 -0.522.02 6,01619159 497.134214 6.48 6,094.15 kAND(3) 0al In 12'a 59PM Pape 4 COMPASS 5000. M audaf 85 Baker Hughes INTEQ CpnOCoPhillip5 Definitive Survey Report Compa.y: Cono PFitlips(AWska) Inc. -K,2 Local Coordinate Reference: We1131141 P1n(etf'. Kupamk River Unit TVO Rcfnence: 3H-31@ 00.00ua3(31H41) site: Kupamk 311 Pad MO Reference: 3H-31 @ 80.00u53(3H41) Well: 311-31 North Reference: Tme Wellbore: 3H-31 Survey GIcuie6on Method: Minimum Cvrvaiura Desl9n: 3H-31 Database: OAKEDMP2 survey 9OW01812: 29: 59PM Pape 5 COMPASS 500014 Suits 05 Map Map NHleal Me 173 Ad T1t M33 N 4 hVV91.3 NOHNnp Eaa9np ' Section survey Tool Name Annotation (Bai) (°) PI (Bate Nam (Bath (aeM (a) (M ('np09 (M 12,256,4. 06.00 34583 6084.47 6,.A7 9,540.03 -1ssIAS 6,010327.26 497.125M lim 902763 MID (3) 1228iM 07.54 3W.91 &06568 6,00568 9.56341 -1,538.88 .,01026864 497.118.23 12,25 9,MI.60 aWn p) 72303.78 89.32 340.39 6,00647 6,006,47 9.5.4151 -0,548.40 6.010,2n.74 497108.]3 645 9,079.82 MW) (3) 12,341.96 8].]3 337.86 600730 6,557.40 8,62056 -1,559.86 6,010,30]79 49],0372] 928 9,111.58 MM➢(3) 12359.81 85.68 334.69 6MM 6,05555 8,646.03 -1.,51105 6,010,33125 497,055.. 11.90 9.139.23 MPo➢(3) 12.7.33 55.96 336.15 6,09019 6.01019 9,671.01 -150248 6,010,35624 497074.86 539 9,166.58 MWU(3) 12429.99 84.49 333.62 &.2.62 6,01262 9.70050 -1596.30 6.010,367'63 497.0.85 1061 9,199.03 MN30) 12450.27 85.12 334.70 6095.10 6,015.10 9,72766 -1,60.45 6.010.414.55 49],04).70 645 9,22912 MWD (3) 1 1249005 8561 Med 6.0735 6,017.25 9,753.93 -0.623.31 6,010.441.15 4970330 16.66 9.25080 "WO (3) 12,520.95 8723 32930 6,098.18 6,019.18 9,780.49 -0,630.97 6,010,46771 497Mr. 537 9.28963 MD (3) 12545.17 88.19 325.55 6.100.14 6020.15 9,80.86 -1.651.55 6,01ii'mam 497,05518 1565 9,313.80 MWD(3) 12.57490 90.10 32593 6,10057 6.020.57 9,8253 -1.668.74 6,010.512,76 49695543 &75 9,343.53 MWD (3) 12,655.93 8169 32151 6.10d08 6.070.08 9,65057 -1,685.16 .,010,537.80 456.980 ]44 9,37143 MD (3) 120509 92.28 328'En 60el 6,019.04 9,01,616 -1,701.0 6010.563.38 49695fi.11 4.11 9,40354 MID (3) 12.665.48 93.0 =V 609].40 6,017,48 9,662A9 -1716.16 6,010,588.72 496.94102 1080 9,433.50 MND(3) 12,05.47 04.]0 334.32 6.00,31 5,015.31 9.2.14 -1729M 6,010616,36 4.6.92).44 9.55 9,455.7 vwo(3) 12725.23 9535 338.65 6,Dom 6,01270 9.956,77 -174206 8,01064133 486,915.15 8,10 8,493.27 MMD(3) ' 1?]554] 93.94 339.12 6.3.25 6,00025 9,984.. -1,753.41 6.0106]125 486,903.81 11,311 9,52342 ~(3) 12,78495 92.16 341.40 6089.0 a,lsil 10011.73 -1,763.35 6,010,6919,55 49,8.3..7 976 9.552,09 MWi](31 12815.87 90.40 34060 6,07.98 6,007.90 10,040.96 -1,n341 6,00.88.18 496,.B300 6.31 9,582.43 MWD(3) 12.64520 9803 338.14 6.06].8] 6,00].8] 10,55!1.41 -1,]83]4 6,00.75561 466,873.49 6.48 9,611.37 MWD(3) 12,67501 88,93 3265 5.0&W 6,008.14 10,0562 -1,79544 6.010.]83.0 455,851.80 9.10 9,550.96 MWD(3) 1290544 88A3 33401 6,088,84 6,008.84 10,12535 J,aW.37 6010,81059 4%848.88 560 9.671,27 MWD(3) 1293550 88.19 3240 60.9.73 609.73 10,149.89 -182262 6010,.37.11 456,834.63 15.11 9701.37 MWO(3) 12,9690 6951 35.66 6,00.39 6,010.39 10,1]8.3] -1,.55.26 6,010.86559 496,81689 8.57 0.734.86 MWD (3) 1300052 69. 3257 6.090.59 sales. 10,204.50 -1,057.8 6.00.091.73 49636654 444 B,M632 VWD(3) 13,030,38 91.44 22519 6.0.039 6,010.29 10,@908 -1,074.0 8,010,916.31 496.78256 600 979599 MD (3) 13060.89 9130 =,is 6.089.59 6.959 10.03,81 -1.892.53 6,010.941.03 496.]64]4 &M 9,626,32 ME) 13.00.61 68.. 31956 600.54 6,55154 10,2]].17 -1,90021 6.010,964.40 496.746,0 14,12 9,assm MNo(3) IM.76 .74 319.39 606961 6,0961 10,26993 -1,955.67 6,010,90715 49672662 5.07 9,80533 mo (a) 13.145.5. 91. 318.35 600947 6000.17 10.31863 -1,946.99 6,011 Ms. 496,]70.30 470 990.0 .1)(3) 9OW01812: 29: 59PM Pape 5 COMPASS 500014 Suits 05 Survey Baker Hughes INTEQ COnOCOPllllllps Definitive Survey Report Company: ConecoPnillips(Alaska) Inc. -Kup2 Local DooNinale Reference: Well 311-91 Project: Kuparvk River Dnit T Reference: 3Hdl Q BOAOusft(3W31) Si.: Kuparvk 311 Pad MD Reference: 31121 Q 00.00usft(314d1) Well: 3H2l NONB Relerence: True Wellbore: 3H-31 Survey Calculakan 09.3106: Minimum Curvature Design: 3H-31 Database: OAKEDMP2 Survey Mnotation a� a 8ROR01812:29:59PM Pepe 6 COMPASS &M.. 14 euild 85 FLp Map Ventral Inc Av TV[I WDSS ML3 ew4V Namill" Ea)n0 DD"(usn) su..eY Tool Nance V) 11) Juan) lush) (oMl loaf Ifq (°1100.1 m)^ 13, 1]5]6 9187 317.57 60W. 680834 10,341.03 -1.96].19 6.011U2. 496690.10 3.25 9,93920 MND(3) 1320594 9237 31512 6.007.22 6,007M 10,02.5 -1,&4.01 6.011=00 49&88929 828 9,WB.50 MND(3) 1323543 9215 31350 6005.05 6,006.06 10,30345 -2,0.09.0 6.01101060 4%,023 5.27 9,9%.62 MND(3) 13 26547 9285 31250 6084.8 8,11018 10,40383 $031.68 6,011,WlA7 4%626.30 4.53 10,025.50 LIM(3) 13,29558 91.50 314.00 6083.43 6,001. 1042470 -2^52]6 6,011,111.0 4%60154 843 10054.44 M (3) 13,320.56 8052 31]36 &00224 600224 10,44&46 Q075.66 6,011.135.20 496.50167 0.81 100%.46 MWD(3) 13,35551 8825 31805 600267 6,002.67 10.48&30 -2083]9 6,011155.62 496.W&M 1114 10,112]] MWD(3) 13.38591 88.M 319.77 608309 6,003.9 10.49120 -211397 6.011.178M 495.'43.52 652 10,142611 MWD(3) 13,41607 WkW 323.13 608184 6.03." 10.51542 -2133.07 6.011302.71 456.52426 11.2 10,1]3.20 "D (3) 13.446.51 86.25 325.33 6005.W 6,005.14 10,539.50 -2,150.35 6,011,M.24 496.506a7 954 10,202M MD (3) 13,4250 Was 322.91 6.082 5OOSS7 10,03]2 -2166.32 6,011,251.02 496.493.98 8,02 10,231.68 MWD (3) 13,M4.M 62.26 32262 6.0.03 6014.03 lo.538.56 -2,181.99 6,011,225.61 496.42532 295 10,26096 MD (3) 13534.51 02.84 328.25 6.149.14 6,149.14 '0,61332 -2,19&09 6,Oil sW.56 4%.45926 as" 10,290.45 MND(3) 13568.01 0.13 Mm 6.0%.29 6,010.29 'D..a. -2,216,94 6,011 328M 496.440.44 3.12 10,323.0 MND(3) 13596.15 91.54 322.38 6,093.32 6.010.37 1066A.39 -2,232.55 6011.351.84 4%,424.83 14.M 10,35191 MND(3) 13626.15 0843 324.51 6.093.9 6.01030 11109.24 $249.35 6,011,32649 4%.408.4 1411 10'saim aim (3) 1365043 82.20 3MAG 6.09161 6,01161 10.21511 -2,264.51 6.01140236 495,30]9 &21 10.413.136 MND(3) 13682.38 8202 32134 6,082.05 6.01286 10,23268 .2.2M.71 6,011,424.93 4M Man 6.63 10.442.46 MND (3) 13218.01 82.45 31&04 6.094.13 6,01413 10,260.92 -2,34X,% 6,016448.22 4911,300 5.04 10.42255 MND(3) 13,25342 60.93 310.02 6,09535 6,015,25 10,282.50 -2.333.14 6.011424.25 4%,32236 4.70 1O.WTV MWD (3) 1320941 90.40 31&58 5095.46 6,01546 10,814.34 -2,353.0 6,011.W'S9 4%,303.40 433 10.542.42 MND (3) 13,822.62 60.0 31802 6,095.44 6,01544 10,84264 Z3M.M 15.011$29.89 4%2nn 489 10,529.85 M (3) 13,853.51 80.56 3160 6085.84 8,01584 10,861.36 -239214 6011518.61 496,25994 512 1 AN,% khAVO) 13,88&% 82.29 31390 6.092." 8,01204 10,084.80 -2420% 6,011522.05 196, .49 2.55 10,63699 MW➢(3) 13.907M 0621 312.0 6098.12 601812 10098.85 243588 6.0115m.11 406,MIM V. 10,65662 MW9(3) 13.9328 .13.16 312.30 6,10001 6,0211.01 10.91940 -2,4511 601160.% 4%.199.12 210 10,0565 "D (3) 13,%2.85 0.0 31235 6,101.32 6,02132 10%966 -248059 6011,626.93 496.126.82 0.32 10,21432 MID (3) 14,140.. 0.90 31014 SAMO8 6.22.05 10.9,E150 -250518 6011648.26 40.152.29 4M 10245.52 MD (3) 14,030.53 90.68 310.14 6,102.12 6,M..12 t0,981.00 -2522.68 6,011 GM27 496,129]0 598 10,223.62 MNO(3) 14,050.21 Man 30.65 6.10126 6,021.M 11.003.31 -2,550AS 6,01160258 4%106.60 20 10.14189 MND(3) 14.128 9092 314.65 6.101P 6.02122 110193^ -252548 6,011,214.52 4%.082.0 643 io,m.m MNO(3) Mnotation a� a 8ROR01812:29:59PM Pepe 6 COMPASS &M.. 14 euild 85 Annotation h? > a4?W01612:29:59PM Pagel COMPASS 500014 Ikeof 9 Baker Hughes INTEQ Cof1000Phillip5 Definitive Survey Report Company. ConocoPhillips (Alas") Inc. -Kup2 Local LM1OIdlnaie Reference: _--- 00011311-31 - Project: Kupamk River Unit TVD Reference: 311-01@ 00.00usfl(31131) Site: IWpamk 3H Pad MD Reference: 311.31 @ 00.00usR (311-31) Well: 311x1 Nenh Reference: True Wellbore: 3H-31 Survey Calculation Method: Minimum,curvature Design: 3H-31 Database OAKEDMP2 Survey , Map Martleal MO Inc Ad mTWSS +008 ♦EI -W Nortrthing Ealing DLS Seellon Survey Tool Name luem PI 11) (Ileal Idem Idea (.aft) (m (m (.11w) (g) 14,120.51 90.. 3..51 61[000 6,=.w 11,03621 -2,%.69 6,01" .40 4%050.00 409 1085698 MWD(31 14,150.39 90.21 30Q.61 6,1[065 6.020es 11,05294 -2.623.. 6,011.740Y2 496034.05 .,at 10.W3A6 MWD (3) 1418D. 09.97 301.02 6,100.61 6,.91 11.W670 -2,&6.97 6,01U!4.05 4W.008.52 5.35 10.910.33 MWD (3) 14210.31 90.74 30144 6.100.37 6.020.32 11,00842 -2.601.35 6.011.77570 495.97615 2.32 10,941n MWD pI 1424533 91.11 301.76 6.099.94 6,019.94 11,102.57 $704.37 6.011.70900 495.953.14 1.61 10,967.29 MWD (3) 14221.& 9316 302.30 Gole,95 6.01895 11,116.62 3726.02 6.011803.91 485,010.09 0.00 10,990.69 MWO(3) 14304.00 83.16 30230 6087.10 6,01710 11.13370 3753.97 6.011,021.07 485900.9 900 11.019.12 PROI CTED toTD Annotation h? > a4?W01612:29:59PM Pagel COMPASS 500014 Ikeof 9 BA I _HES PRINT DISTRIBUTION LIST IUG a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H -31A FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(a�bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V ) RP North Slope. EOA, PBOC. PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99508 2 ConocoPhillips Alaska Inc. .Atm: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** .Attn: Resource Evaluation 550 West 7th Avenue. Suite 1100 Anchorage, Alaska 99501 Stamp "cooRdential" on all material deliver to DNR 6 B Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 N.. 218075 29 65 8 ie sign and return one copy of this transmittal form to: xoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. )oraae. Alaska 99510 LOG TYPE GR - RES LOG DATE August 14, 2018 TODAYS DATE August 29, 2018 Revision Details: Rev. Requested by: --- FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES lu 4 4 4 4 4 0 1 0 1 0 1 0 10 RECEIVED 0 0V6 3 110 0 AOGCC 0 1 1 1 1 1 0 0 0 1 0 1 1 0 I 0 0 1 0 1 1 1 0 10 TOTALS FOR THIS PAGE: 0 1 3 0 0 STATE OF ALASKA Reviewed 1B�1'r/ 6 OIL AND GAS CONSERVATION COMMISSION P.I. Suprv_1 BOPE Test Report for: KUPARUK RIV UNIT 3H -31A ✓ Comm Contractor/Rig No.: Nabors CDR3AC PTD#: 2180750 - DATE: 7/31/2018 - Inspector Matt Herrera - Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Newell/Conelly Rig Rep: Madsen/Wheeler Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopMFH18080I082458 Rams: Annular: Valves: NIASP: Type Test: WKLY NA 250/4200 - 250/2500 - 250/4200 - 3455 - Related Insp No: FLOOR SAFTY VALVES Quantity TEST DATA Upper Kelly MISC. INSPECTIONS: NA MUD SYSTEM: 0 NA P/F 2 '_ Visual Alarm Inside BOP Location Gen.: P Trip Tank P ' P_ Housekeeping: P _' Pit Level Indicators P P PTD On Location P Flow Indicator P - NA Standing Order Posted P Meth Gas Detector P - P Well Sign P H2S Gas Detector P P Drl. Rig P MS Mise NA NA Hazard Sec. P " Mise NA FLOOR SAFTY VALVES BOP STACK: ACCUMULATOR SYSTEM: Time/Pressure P/F Quantity P/F Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 '_ P Inside BOP 0 NA FSV Misc 0 NA - +ii)2043 BOP STACK: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure _ 3060 ___P_ Annular Preventer Pressure After Closure 2350 #1 Rams 200 PSI Attained 25 P Full Pressure Attained 46 P Blind Switch Covers: Yes - P Nitgn. Bottles (avg): - +ii)2043 P ACC Mise 0 NA Quantity Size P/F Stripper I ` 2" - P - Annular Preventer 1 - 7 1/16"" P - #1 Rams 1- BlindShear - P - #2 Rams 1 - 2" Slip _ P #3 Rams 1 2 3/8" - P- #4 Rams 1 - 2 3/8" P . 45 Rams 1 - BlindShe_a_r - _ P •_ 46 Rams 1 - 2" Slip - P. Choke Ln. Valves 2 2 1/16" P HCR Valves 4 - 2 1/16" - P Kill Line Valves 7 2 1/16" - FP,Z Check Valve 0 NA BOP Misc 2 - 2 1/16" • FP,/! CHOKE MANIFOLD: Quantity P/F No. Valves 12 P Manual Chokes 1 P Hydraulic Chokes I P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves I ' P Number of Failures: 4 Test Results Test Time 10 Remarks: Valves tested and Failed intially and passed retest were 13-3,13-7,T-1 and Swab 2 All valves are integrated into the well control system. No Audible on Flow Indicator Visual only. PTO 219 — o?S Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, July 10, 2018 1:58 PM To: Herring, Keith E (Keith.E.Herring@conocophillips.com) Cc: Ohlinger, James J (James.J.Ohlinger@conocophillips.com) Subject: KRU 3H-31A(PTD 218-075) PTD Approval Modifications Keith, Please make the following modifications to the approved PTD 218-075: Annular preventer test pressure is 2500 psig Subsequent Form Required: 10-407 Include this approval with the original approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V ictoria. Loepp0 alas ka. g ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victorla.Loeoo@alaska.aov THE STATE °fALAS-KA GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Gil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1 433 Fax: 907.276.7542 v>ww.aogccalaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H -31A ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-075 Surface Location: 970' FNL, 281' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 5117' FNL, 2074' FEL, SEC. 27, TUN, R8E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced development 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 with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair k� DATED this 'S day of July, 2018. STATE OF ALASKA ALA, A OIL AND GAS CONSERVATION COMMILJN PERMIT TO DRILL 20 AAC 25.005 UED �!u 1 a. Type of Work: Drill ❑ Lateral ❑ Redrill 0 ' Reentry ❑ 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG Service - Disp ❑ Stratigraphic Test ❑ Development - Oil El • Service - Winj ❑ Single Zone Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well is proposedrfor: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket ❑✓ . Single Well ❑ Bond No. 5952180 , 11. Well Name and Number: KRU 3H -31A ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 15200' ' TVD: 6067" 12. Field/Pool(s): Kuparuk River Pool / Kuparuk River Oil Pool ' 4a. Location of Well (Governmental Section): Surface: 970' FNL, 281' FWL, Sec 12, T12N, R8E, UM . Top of Productive Horizon: 3755' FNL, 282' FEL, Sec 34, T13N, R8E, UM Total Depth: 5117' FNL, 2074' FEL, Sec 27, T1 3N, R8E, UM 7. Property Designation: !4DZ, 2_S'.3/ ADL 25524 .. O 8. DNR Approval Number: LONS 84-134 & LONS 84-149 13. Approximate Spud Date: 7/9/2018 ' 9. Acres in Property: 1920 14. Distance to Nearest Property: 6820' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 498655 - y- 6000688 ' Zone- 4 10. KB Elevation above MSL (ft): 80' . GL / BF Elevation above MSL (ft): 39' 15. Distance to Nearest Well Open to Same Pool: 154', 3M-28 16. Deviated wells: Kickoff depth: 10437' . feet Maximum Hole Angle: 92 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4056 ` Surface: 3455 ✓ 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2450' 12750' • 6070' 15200' . 6067' Slotted 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): 10730' 6241' N/A 10623' 6160' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 200 sx AS 121' 121' Surface 4981' 9-5/8" 1100 sx ASI 11, 600 sx G 5023' 3262' Production 10677' 7" 250 sx Class G 10712' 6228' Perforation Depth MD (ft): 10426' - 10444' Perforation Depth TVD (ft): 6008'- 6022' 10452'- 10494' 6028'- 6060' Hydraulic Fracture planned? Yes❑ No ❑Q B ketch 20. Attachments: Property Plat ❑ DivaOer Sketch 8 DSelabed ing Report Program B Dri I ngeFluid Prog ay. Depthtm ot a 20 AAC 25.050 requ iremlentsShallow 8 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. Herrin CO .COm Authorized Title: Staff CTD Engineer// Contact Phone: 907-263-4321 Authorized Signature: Date: 41.7ellp Commission Use Only Permit to Drill /LJ Number: �rCJw API Number: 50-�Q,�.--�z��©r—L� Permit Approval �I Dale: / (� See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: t�� T -T. c-� yZOO �c.1 Samples req'd: Yes E]No ✓❑/ Mud log req'd: Yes [o� IG P f HzS measures: Yes [✓/No❑ Directional svy req'd: Yes No❑ �/ Spacing exception req'd: Yes ❑ No� Inclination -only svy req'tl: Yes ❑ No L+' Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY "'7 C �t Approved by: fiTI I NER THE COMMISSION Date: T 7 Form 10-401 Revised 5/2017 This permit iu,,VtAzl t Submit Form and to of approval per 20 AAC 25.005tal ,., rm..r,.�e m.6.Rs-3-OLH re ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 28, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 we l Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 3H-31 (PTD# 194-019) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in early July 2018. The objective will be to drill two laterals KRU 3H -31A and 3H-31AL1 targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20_.!:E—:. AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 3H -31A and 3H-31AL1 - Detailed Summary of Operations - Directional Plans for 3H -31A and 3H-31AL1 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 3H -31A and 3H-31 AU Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6)).............................................................................................-...................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program ........................ (Requirements of 20 AAC 25.005(c)(13)) ........................... Summary of Operations ......................................... Liner Running......................................................... ........................................................................ 4 .................................................................................................... 4 ..........................................................................................4 ..........................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 31-1-31A and 31-1-31AL1 laterals...............................................................................6 Attachment 2: Current Well Schematic for 31-1-31............................................................................................................6 Attachment 3: Proposed Well Schematic for 31-1-31A and 3H-31AL1 laterals.................................................................6 Page 1 of 6 June 28, 2018 PTD Application: 3H -31A & 31-1-31 AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3H -31A and 31-1-31AL1. The laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3H -31A and 31-1-31AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,200 psi. Using the maximum formation pressure in the area of 4,056 psi in 31-1-24 (i.e. 13.0 ppg EMW), the maximum potential surface pressure in 31-1-31, assuming a gas gradient of 0.1 psi/ft, would be 3,455 psi. See the "Drilling Hazards Information and Reservoir Pressure' section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3H-31 was measured to be 3 8, 27 psi (12.1 ppg EMW) on 5/13/2018. The maximum downhole pressure in the 31-1-31 vicinity is the 31-1-24 at 4,056 psi (13.0 ppg EMW) measured on 5/18/2018. / Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 31-1-31 have injected gas, so there is a possibility of encountering free gas while drilling the 31-1-31 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 31-1-31 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) T 3M-23 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity tes not required. Page 2 of 6 June 28, 2018 PTD Application: 3H -31A & 3H-31AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Name Liner Top Liner Btm Top Liner Top Liner Btm Liner BtmLateral Liner Details Btm MD MD MD TVDSS TVDSS 3H -31A 12,750' 15,200' 5,990' 5,987' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 121' 670 Surface aluminum billet on to 3H-31AL1 10,318' 15,200' 5,846' 5,996' 2-3/8", 4.7#, L-80, ST -L slotted / blank JBurstj12020 Production 7" liner; with sealbore deployment on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD ollapse sConductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 670 Surface 9-5/8" 53.5 J-55 BTC 0' 5023' 0'3262' JBurstj12020 Production 7" 26.0 L-80 BTC MOD 0' 10712' 0' 6228' 5410 Tubin 3-1/2" 9.3 L-80 ABM ELIE 0'10336' 0' 5940' 0540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System Window milling operations: Chloride -based PowerVis mud (8.6 ppg) Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure,, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 12.2 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". X In the 3H-31 laterals we will target a constant BHP of 12.2 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 June 28, 2018 PTD Application: 3H -31A & 3H-31AL1 Pressure at the 3H-31 Window 10437' MD, 6017' TVD Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3H-31 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A sand to the northwest of the 3H-31 parent wellbore. The laterals will increase recovery and add additional resources. This project may trial using 2-3/8" coiled tubing inside 3-1/2" production tubing and drilling 3-1/4" hole. If weight transfer and circulating pressures deem to be problematic, then the project will utilize 2" coiled tubing and drill 3" hole. Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock and obtain SBHP. 2. RU E -line: Punch holes in the 3-1/2" tubing tail below production packer. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the A/C -sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC rig. Page 4 of 6 June 28, 2018 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 12.1 3785 psi 3785 psi Mud Hydrostatic 8.6 2690 psi 2690 psi Annular friction i.e. ECD, 0.08psi/ft) 834 psi 0 psi Mud + ECD Combined no chokepressure) 3524 psi Underbalanced -261psi) 2690 psi Underbalanced -1095psi) Target BHP at Window 12.2 3817 psi 3817 psi Choke Pressure Required to Maintain Target BHP 293 psi 1127 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3H-31 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A sand to the northwest of the 3H-31 parent wellbore. The laterals will increase recovery and add additional resources. This project may trial using 2-3/8" coiled tubing inside 3-1/2" production tubing and drilling 3-1/4" hole. If weight transfer and circulating pressures deem to be problematic, then the project will utilize 2" coiled tubing and drill 3" hole. Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock and obtain SBHP. 2. RU E -line: Punch holes in the 3-1/2" tubing tail below production packer. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the A/C -sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC rig. Page 4 of 6 June 28, 2018 PTD Application: 3H -31A & 3H-31AL1 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H -31A Sidetrack (A1 sand - northwest) a. Mill 2.80" high -side pilot hole through the cement to 10470' MD. b. Caliper pilot hole and set top of whipstock at 10437' MD. c. Mill 2.80" window at 10437' MD. d. Drill 3" bi-center lateral to TD of 15200' MD. e. Run 2-3/8" slotted liner with aluminum billet from TD up to 12750' MD. 3H-31AL1 Lateral (A1 sand - northwest) a. Kickoff of the aluminum billet at 12750' MD. b. Drill 3" bi-center lateral to TD of 15200' MD. c. Run 2-3/8" slotted/ blank liner with sealbore deployment sleeve from TD up to 10318' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Install liner top packer onto the 2-3/8" liner. 2. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running - The 3H-31 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. Page 5 of 6 June 28, 2018 PTD Application: 31-1-31A & 3H-31AL1 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name DZ6820- Distance 3H-31A 3H-31AL1 to Nearest Well within Pool Lateral Name Distance Well 3H -31A 154' 3M-28 3H-31AL1 115' 3M-28 16. Attachments Attachment 1: Directional Plans for 3H -31A and 3H-31AL1 laterals Attachment 2: Current Well Schematic for 3H-31 Attachment 3: Proposed Well Schematic for 3H -31A and 3H-31AL1 laterals Page 6 of 6 June 28, 2018 S ) J ) 7 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-31 3H -31A Plan: 3H-31A_wp02 Standard Planning Report 27 June, 2018 BER T% " GHES GE company ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-31 Wellbore: 31-1-31A Design: 3H-31A_wp02 ConocoPhillips Planning Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method Well 3H-31 Mean Sea Level 3HJ1 Q 80.00usft (3H-31)' True Minimum Curvature Project Kupawk 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 1 Using geodetic scale factor BAFUGHES a GEcompary Sitr Kuparuk 3H Pad 3H-31 Site Position: Northing: 6,000,110.73usft Latitude: 70° 24'41.531 N From: Map Easting: 498,655.44usft Longitude: 150° 0'39A16 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Wen 3H-31 Well Position +N/S 0.00 usft Northing: 6,000,687.91 usft • Latitude: 70° 24' 47.208 N Model Name +E1 -W 0.00 usft Easting: 498,655.24 usft - Longitude: 150.0. 39.425 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: .0.00 usft 6,1712018 1:55:11 PM Page 2 COMPASS 5000.14 Build 85 Wellbore 3H -31A Magnetics Model Name Sample DateDeclination Dip Angle Field Strength BGGM2018 9/1/2018 16.92 80.91 57441 Design 3H -31A wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10 409 00 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 330.00 6,1712018 1:55:11 PM Page 2 COMPASS 5000.14 Build 85 Plan Sections ConocoPhillips BAT ConocoPhillips Planning Report FGHES Measured a GE compzry Database: EDT Alaska Sandbox Local Coordinate Reference: Well 3H-31 Dogleg Company: ConocoPhillips (Alaska) Inc -Kup2 TVD Reference: Mean Sea Level Project Kupamk River Unit MD Reference: 31-1-31 @ 80.00usft (31-1-31) System Site: Kupamk 3H Pad North Reference: True Rate Well: 31-1-31 Survey Calculation Method: Minimum Curvature (usft) Wellbore: 3H -31A P) (usft) (usft) Design: 3H -31A Wp02 (°Aaoft) ("I100ft) (-it 00ft) Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +WS +Ef-W Rate Rate Rate TFO (usft) C) P) (usft) (usft) (usft) (°Aaoft) ("I100ft) (-it 00ft) O Target 10,409.00 40.27 347.07 5,915.54 7,756.65 -1,617.44 0.00 0.00 0.00 0.00 10,437.00 40.22 347,02 5,936.92 7,774.28 -1,621.49 0.21 -0.18 -0.18 -147.16 10,458.00 44.42 347.02 5,952.44 7,788.05 -1,624.67 20.00 20.00 0.00 0.00 10,559.29 90.00 347.02 5,990.65 7,876.67 -1,645.09 45.00 45.00 0.00 0.00 10,650.00 90.55 353.35 5,990.21 7,966.00 -1,660.55 7.00 0.61 6.97 85,00 11,050.00 91.43 21.34 5,983.16 8,358.73 -1,809.97 7.00 0.22 7.00 88.00 11,250.00 90.90 7.34 5,979.08 8,551.97 -1,560.57 7.00 -0.26 -7.00 268.00 11,450.00 92.08 21.30 5,973.85 8,745.21 -1,511.24 7.00 0.59 6.98 85.00 11,650.00 91.29 7.31 5,967.93 8,938.44 -1,461.97 7.00 -0.39 -6.99 267.00 12,050.00 88.80 339.42 5,967.59 9,331.83 -1,507.70 7.00 -0.62 -6.97 265.00 12,330.00 88.53 359.03 5,974.17 9,605.47 -1,559.78 7.00 -0.09 7.00 91.00 12,730.00 87.30 331.04 5,989.02 9,987.81 -1,661.96 7.00 -0.31 -7.00 267.00 13,110.00 88.93 304.47 6,001.78 10,266.39 -1,915.05 7.00 0.43 -6.99 273.00 13,385.00 89.64 323.71 6,005.24 10,456.82 -2,111.63 7.00 0.26 7.00 88.00 13,665.00 89.66 304.11 6,OO6.95 10,650,05 -2,312.37 7.00 0.01 -7.00 270.00 13,990.00 89.30 326.86 6,009.91 10,880.25 -2,538.74 7.00 -0.11 7.00 91.00 14,390.00 90.79 298.89 6,009.56 11,149.71 -2,828.97 7.00 0.37 -6.99 273.00 14,790.00 92.11 326.87 5,999.22 11,419.10 -3,119.07 7.00 0.33 6.99 87.00 15,200.00 91.37 298.17 5,986.51 11,693.17 -3,417.97 7.00 -0.18 -7.00 269,00 627)2018 1:55: 11PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhillips Planning Report BAT a Glicompany Database: EDT Alaska Sandbox Local Coordinate Reference: Well 31-1-31 Company: ConocoPhillips (Alaska) Inc, -Kup2 TVD Reference, Mean San Level Project: Kuparuk River Unit MD Reference: 31-1-31 @ 80.00usft (31-1-31) Site: Kuparuk 3H Pad North Reference: True Well: 311-31 Survey Calculation Method: Minimum Curvature Wellbors: 311-31A Design: 3H-31A_wp02 Vertical 8272018 1:55.11PM Page 4 COMPASS 5000.14 Build 85 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NI-S +EI -W Section Rate Azimuth Northing Easting (usft) ('1 (') (usft) (usft) (usft) (usft) (-Hold[) (°l (usft) (usft) 10,409.00 40.27 347.07 5,915.54 7,756.65 -1,617.44 7,526.17 0.00 0,00 6,008,444.07 497,039.36 TIP 10,437.00 - 40.22 347.02 5,936.92 7,774.28 -1,621.49 7,543.47 0.21 -147.16 6,008,461.70 497,035.31 KOP 10,458.00 44.42 347.02 5,952.44 7,788.05 -1,624.67 7,556.98 20.00 0.00 6,008,475.48 497,032.14 End 20 dls, Start 46 dls 10,500.00 63.32 347.02 5,977.09 7,820.96 -1,632.25 7,589.27 45.00 0.00 6,008,508.38 497,024.56 10,559.29 90.00 347.02 5,990.65 7,876.67 -1,645.09 7,643.94 45.00 0.00 6,008,584.09 497,011.73 End 45 dis, Start 7 dls 10,600.00 90.25 349.96 5,990.56 7,916.55 -1,653.25 7,682.56 7.00 85.00 6,008,603.96 497,003.58 10,650.00 90.55 353.35 5,990.21 7,966.00 -1,660.55 7,729.04 7.00 85.01 6,008,653.41 496,996.29 5 10,700.00 90.67 356.84 5,989.68 8,015.81 -1,664.83 7,774.31 7.00 88.00 6,008,703.22 496,992.02 10,800.00 90.91 3.84 5,988.29 8,115.74 -1,664.23 7,860.55 7.00 88.04 6,008,803.13 496,992.64 10,900.00 91.13 10.84 5,986.52 8,214.84 -1,651.46 7,939.99 7.00 88.13 6,008,902.22 497,005.42 11,000.00 91.33 17.84 5,984.37 8,311.64 -1,626.72 8,011.45 7.00 88.26 6,008,999.01 497,030.18 11,050.00 91.43 21.34 5,983.16 8,358.73 -1,609.97 8,043.85 7.00 88.41 6,009,046.09 497,046.94 6 11,100.00 91.30 17.84 5,981.97 8,405.81 -1,59121 8,076.25 7.00 -92.00 6,009,093.17 497,063.70 11,200.00 91.04 10.84 5,979.93 8,502.62 -1,568.47 8,147.72 7.00 -92,08 6,009,189.96 497,088.46 11,250.00 90.90 7.34 5,979.08 8,551.97 -1,560.57 8,186.51 7,00 -92.23 6,009,239.31 497,096.37 7 11,300.00 91.20 10.83 5,978.16 8,601.33 -1,552.67 8,225.31 7.00 85.00 6,009,288.66 497,104.27 11,400.00 91.80 17.81 5,975.54 8,698.13 -1,527.97 8,296.79 7.00 85.06 6,009,385.45 497,128.99 11,450.00 92.08 21.30 5,973.85 8,745.21 -1,511.24 8,329.20 7.00 85.25 6,009,432.52 497,145,72 8 11,500.00 91.90 17.80 5,972.12 8,792.29 -1,494.53 8,361.61 7.00 -93.00 6,009,479.59 497,162.45 11,600.00 91.50 10.81 5,969.15 8,889.09 -1,469.84 8,433.10 7.00 -93.12 6,009,576.38 497,187.14 11,650.00 91.29 7.31 5,967.93 8,938.44 -1,461.97 8,471.91 7.00 -93.33 6,009,625.72 497,195.02 9 11,700.00 90.99 3.83 5,966.93 8,988.19 -1,457.12 8,512.56 7.00 -95.00 6,009,675.46 497,199.88 11,800.00 90.36 356.85 5,965.75 9,088.12 -1,456.53 8,588.81 7.00 -95.07 6,009,775.38 497,200.50 11,900.00 89.73 349.88 5,965.67 9,187.39 -1,468.07 8,690.55 7,00 -95.15 6,009,874.64 497,188.98 12,000.00 89.11 342.91 5,966.68 9,284.52 -1,491.57 8,786.41 7.00 -95.16 6,009,971.77 497,165.49 12,050.00 88.80 339.42 5,967.59 9,331.83 -1,507.70 8,835.45 7.00 -95.09 6,010,019.07 497,149.37 10 12,100.00 88.74 342.92 5,968.67 9,379.13 -1,523.83 8,884.48 7.00 91.00 6,010,066.38 497,133.25 12,200.00 88.64 349.93 5,970.96 9,476.25 -1,547.28 8,980.32 7.00 90.92 6,010,163.49 497,109.82 12,300.00 88.55 356.93 5,973.41 9,575.50 -1,558.72 9,071.99 7.00 90.76 6,010,262.74 497,096.40 12,330.00 88.53 359.03 5,974.17 9,605.47 -1,559.78 9,098.47 7.00 90.59 6,010,292.70 497,097.34 11 12,400,00 88.28 354.13 5,976.12 9,675.30 -1563.95 9,161.03 7.00 -93.00 6,010,362.53 497,093.18 12,500.00 87.95 347.14 5,979.41 9,773.85 -1,580.21 9,254.51 7.00 -92.86 6,010,461.07 497,076.95 12,600.00 87.64 340.14 5,983.27 9,869.67 -1,608.34 9,351.56 7.00 -92.63 6,010,556.88 497,048.83 12,700.00 87.37 333.14 5,987.63 9,961.33 -1,647.94 9,450.73 7.00 -92.36 6,010,648.54 497,009.26 12,730.00 87.30 331.04 5,989.02 9,987.81 -1,661.96 9,480.68 7.00 -92.06 6,010,675.02 496,995.24 12 12,800.00 87.56 326.14 5,992.16 10,047.47 -1,698.40 9,550.56 7.00 -87.00 6,010,734.68 496,958.82 12,900.00 87.97 319.14 5,996.06 10,126.84 -1,759.00 9,649.60 7.00 -86.78 6,010,814.06 496,898.24 13,000.00 88.41 312.15 5,999.22 10,198.27 -1,828.83 9,746.37 7.00 -86.51 6,010,885.49 496,828.43 13,100.00 88.68 305.17 6,001.58 10,260.69 -1,906.84 9,839.44 7.00 -86.29 6,010,947.91 496,750.44 13,110.00 88.93 304.47 6,001.78 10266.39 -1,915.05 9,848.46 7.00 -86.12 6,010,953.62 496,742.23 8272018 1:55.11PM Page 4 COMPASS 5000.14 Build 85 r ( ConocoPhillips BA, ICER ConocoPhillips Planning Report �jUGHES a GEcompaW Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 311-31 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-31 @ 80.00usft (3H-31) Site: Kupamk 3H Pad North Reference: True Well: 3W31 Survey Calculation Method Minimum Curvature Wellbore: 31-1-31A Map Map Design: 311-31A_Wp02 Azimuth System Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NI-S +EI -W Section Rate Azimuth Northing Easting (usft) (°) (") (usft) (usft) (usft) (usft) (°MOOR) (°) (usft) (usft) 13 13,200.00 89.15 310.77 6,003.29 10,321.29 -1,986.29 9,931.65 7.00 88.00 6,011,008.53 496,671.00 13,300.00 89.41 317,76 6,004.54 10,391.04 -2,057.86 10,027.83 7.00 87.89 6,011,078.28 496,599.46 13,385.00 89.64 323.71 6,005.24 10,456.82 -2,111.63 10,111.68 7.00 87.81 6,011,144.06 496,545.71 14 13,400.00 89.64 322.66 6,005.33 10,468.83 -2,120.62 10,126.58 7.00 -90.00 6,011,156.07 496,536.72 13,500.00 89.65 315.66 6,005.95 10,544.43 -2,185.97 10,224.73 7.00 39.99 6,011,231.68 496,471.39 13,600.00 89.66 308.66 6,006.56 10,611.50 -2,260.05 10,319.86 7.00 -89.95 6,011,298.76 496,397.32 13,665.00 89.66 304.11 6,006.95 10,650.05 -2,312.37 10,379.40 7.00 -89.91 6,011,337.31 496,345.02 16 13,700.00 89.62 306.56 6,007.16 10,670.29 -2,340.92 10,411.20 7.00 91.00 6,011,357.55 496,316.47 13,800.00 89.51 313.56 6,007.93 10,734.60 -2,417.41 10,505.14 7.00 90.98 6,011,421.87 496,240.00 13,900.00 89.40 320.56 6,008.89 10,807.75 -2,485.49 10,602.54 7.00 90.93 6,011,495.03 496,171.94 13,990.00 89.30 326.86 6,009.91 10,880.25 -2,538.74 10,691.94 7.00 90.86 6,011,567.53 496,116.71 16 14,000.00 89.34 326.16 6,010.03 10,868.59 -2,544.26 10,701.92 7.00 -87.00 6,011,575.87 496,113.20 14,100.00 89.71 319.17 6,010.85 10,968.04 -2,604.87 10,801.04 7.00 -86.99 6,011,655.33 496,052.61 14,200.00 90.09 312.18 6,011.03 11,039.53 -2,674.70 10,897.87 7.00 -86.93 6,011,726.82 495,982.79 14,300.00 90.46 305.19 6,010.55 11,101.99 -2,752.72 10,990.97 7.00 -86.92 6,011,789.29 495,904.80 14,390.00 90.79 298.89 6,009.56 11,149.71 -2,828.97 11,070.42 7.00 -86.96 6,011,837.01 495,828.56 17 14,400.00 90.83 299.59 6,009.42 11,154.60 -2,837.69 11,079.01 7.00 87.00 6,011,841.90 495,819.84 14,500.00 91.19 306.59 6,007.65 11,209.15 -2,921.41 11,188.11 7.00 67.01 6,011,896.46 495,736.14 14,600.00 91.53 313.58 6,005.28 11,273.48 -2,997.85 11,262.04 7.00 87.13 6,011,960.80 495,659.72 14,700.00 91.85 320.57 6,002.33 11,346.63 -3,065.88 11,359.41 7.00 87.30 6,012,033.95 495,591.71 14,790.00 92.11 328.87 5,999.22 11,419.10 -3,119.07 11,448.77 7.00 87.51 6,012,106.43 495,538.53 18 14,800.00 92.10 326.17 5,998.86 11,427.44 -3,124.59 11,458.74 7.00 -91.00 6,012,114.77 495,533.02 14,900.00 91.96 319.17 5,995.32 11,506.86 -3,185.15 11,557.80 7.00 -91.03 6,012,194.19 495,472.48 15,000.00 91.79 312.17 5,992.05 11,578.30 -3,254.95 11,654.58 7.00 -91.27 6,012,265.64 495,402.70 15,100.00 91.59 305.17 5,989.10 11,640.72 -3,332.94 11,747.63 7.00 -91.50 6,012,328.06 495,324.72 15,200.00 91.37 298.17 5,986.51 11,693.17 -3,417.97 11,835.57 7.00 -91.71 6,012,380.52 ' 495,239.71 Planned TD at 16200.00 6272018 1:551IPM Page 5 COMPASS 5000.14 Build 85 Targets ConocoPhillips gp R COIIOCOPhillip5 Planning Report I�U HES Target Name 1,637,080.00 70° 12'15.058 N 140° 48' 11.642 W I a OEcampany Database: EDT Alaska Sandbox Local Coordinate Reference: Well 31-1-31 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Leval Project: Kuparuk River Unit MD Reference: 31-1-31 @ 80.00usft (31-1-31) Site: Kuparuk 3H Pad North Reference: True Well: 3H-31 Survey Calculation Method: Minimum Curvature Wellbore: 3H -31A 5,986.00 11,649.941,136,728.35 Design: 3H-31A_wp02 1,635,272.00 70° 12'35.412 N 140° 48'55.502 W Targets 1,635,598.00 70° 12'31.891 N 140'48'47.525W - plan misses target center by 1138513.19usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) - Point Target Name 1,637,080.00 70° 12'15.058 N 140° 48' 11.642 W - plan misses target center by 1140009.24usft at 11800.00usft MD (5965.75 TVD, 9088.12N,-1456.53 E) - Rectangle (sides W1.00 H1,000.00 DO.00) -hit/miss target Dip Angle Dip Dir. TVD -NIS -El-W Northing Easting -Shape (°} (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3H -31A T09 0.00 0.00 5,986.00 11,649.941,136,728.35 6,012,132.00 1,635,272.00 70° 12'35.412 N 140° 48'55.502 W - plan misses target center by 1138187.76usft at 11800.00usft MO (5965.75 TVD, 9088.12 N, -1456.53 E) - Point - Point 1,636,072.00 70° 12' 27.326 N 140' 48'36.679 W - plan misses target center by 1138986.59usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) - Point 31-1-31A Fauft3 0.00 0.00 5,983.00 9,829.081,138,536.86 6,010,311.00 1,637,080.00 70° 12'15.058 N 140° 48'11.642 W - plan misses target center by 1139993.63usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) -Polygon Point 1 5,983.00 0.00 0.00 6,010,311.00 1,637,080.00 Point 5,983.00 1.00 1.00 6,010,312.00 1,637,081.00 31-1-31A Fauft4 0.00 0.00 6,001.00 11,336.961,137,054.44 6,011,819.00 1,635,598.00 70° 12'31,891 N 140° 48' 47.525 W - plan misses target center by 1138513.19usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) - Polygon Point 1 6,001.00 0.00 0.00 6,011,819.00 1,635,598.00 Point 6,001.00 1.00 1.00 6,011,820.00 1,635,599.00 3H-31A_Fault4_M 0.00 0.00 0.00 11,336.961,137,054.44 6,011,619.00 1,635,598.00 70'12'31.891N 140'48'47.525W - plan misses target center by 1138528.82usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1458.53 E) - Rectangle (sides W1.00 1-11,000.00 DO.00) 31-1-31 CTD Polygon 0.00 0.00 0.00 7,625.881,138,626.27 6,008,108.00 1,637,169.00 70° 11'53.536 N 140° 48'18.705 W - plan misses target center by 1140099.34usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) -Polygon Point 0.00 0.00 0.00 6,008,108.00 1,637,169.00 Point 0.00 1,313.19 242.72 6,009,421.01 1,637,411.93 Point 0.00 2,445.25 6.43 6,010,553.00 1,637,175.87 Point 0.00 4,312.99 -1,924.19 6,012,420.91 1,635,245.78 Points 0.00 4,027.91 -2,126.15 6,012,135.89 1,635,043.79 Point 0.00 2,188.16 -250.53 6,010,295.99 1,636,918.89 Point 0.00 1,327.11 -118.32 6,009,435.00 1,637,050.93 Point 0.00 27.92 -354.04 6,008,135.98 1,636,815.00 point 0.00 0.00 0.00 6,008,108.00 1,637,169.00 31-1-31A T08 0.00 0.00 6,001.00 11,336.961,137,054.44 6,011,819.00 1,635,598.00 70° 12'31.891 N 140'48'47.525W - plan misses target center by 1138513.19usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) - Point 31-1-31A Fauft3 M 0.00 0.00 0.00 9,829.081,138,536.86 6,010,311.00 1,637,080.00 70° 12'15.058 N 140° 48' 11.642 W - plan misses target center by 1140009.24usft at 11800.00usft MD (5965.75 TVD, 9088.12N,-1456.53 E) - Rectangle (sides W1.00 H1,000.00 DO.00) 31-1-31A T03 0.00 0.00 5,980.00 8,460.951,138,578.11 6,008,943.00 1,637,121.00 70° 12'1.715 N 140° 48'16.437 W - plan misses target center by 1140034.81 usft at 11800.00usftMO (5965.75 TVD, 9088.12 N. -1456.53 E) - Point 31-1-31A Fauh1 0.00 0.00 5,960.00 7,752.871,138,519.23 6,008,235.00 1,637,062.00 70° 11'54.928 N 14W 48'21.215 W - plan misses target center by 1139976.54usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) - Polygon Point 1 5,960.00 0.00 0.00 6,008,235.00 1,637,062.00 Point 5,960.00 1.00 1.00 6,008,236.00 1,637,063.00 31-1-31A T04 0.00 0.00 5,966.00 9,059.031,138,689.01 6,009,541.00 1,637,232.00 70' 12'7.357 N 140' 48' 10.648 W - plan misses target center by 1140145.54usft at 11800.00usft MO (5965.75 TVD, 9088.12 N. -1456.53 E) - Point 3H -31A T07 0.00 0.00 6,011.00 10,939.011,137,528.56 6,011,421.00 1,636,072.00 70° 12' 27.326 N 140' 48'36.679 W - plan misses target center by 1138986.59usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) - Point 31-1-31A T06 0.00 0.00 6,005.00 10,411.051,138,036.71 6,010,893.00 1,636,580.00 70° 12' 21.449 N 140° 48'23.427 W - plan misses target center by 1139494.00usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) - Point 6/272018 1:55:11PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips BA ConocoPhillips Planning Report UGHES a OEcompany Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupawk 3H Pad Well: 31-1-31 Wellbore: 3H -31A Design: 31-1-31A wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-31 Mean Sea Level 3H-31 @ 80.00usft (3H-31) True Minimum Curvature - plan misses target center by 1139993.63usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) 1,637,062.00 - Point - plan misses target center by 1139976.54usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) 3H-31A_T02 0.00 0.00 5,990.00 7,826.871,138,502.22 6,008,309.00 1,637,045.00 70" 11'55.671 N 140° 48'21.379 W - plan misses target center by 1139959.44usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) Diameter - Point 3H-31A_Feuln M 0.00 0.00 0.00 7,752.871,138,519.23 6,008,235.00 3H-31A_Fault2 0.00 0.00 5,980.00 8,460.951,138,578.11 6,008,943.00 1,637,121.00 70° 12'1.715 N 140° 48'16.437W - plan misses target center by 1140034.81 usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) 5,986.51 23/8" -Polygon - Rectangle (sides W1.00 H1,000.00 D0.00) Points 5,980.00 0.00 0.00 6,008,943.00 1,637,121.00 Point 5,980.00 1.00 1.00 6,008,944.00 1,637,122.00 3H-31A_T01 0.00 0.00 5,960.00 7,752.871,138,519.23 6,008,235.00 1,637,062.00 70° 11'54.928 N 140' 48'21.215 W', - plan misses target center by 1139976.54usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) Depth Depth - Point Diameter (usft) 3H-31A_Feuln M 0.00 0.00 0.00 7,752.871,138,519.23 6,008,235.00 1,637,062.00 70° 11'54.928 N 140° 48'21.215 W - plan misses target center by 1139992.15usft at 11800.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) 5,986.51 23/8" 2.375 - Rectangle (sides W1.00 H1,000.00 D0.00) 7,756.65 -1,617.44 3H-31A_Fault2_M 0.00 0.00 0.00 8,460.95 1,138,578.11 6,008,943.00 1,637,121.00 70° 12' 1.715 N 140° 48' 16.437 W - plan misses target center by 1140050.42usft at 11600.00usft MD (5965.75 TVD, 9088.12 N, -1456.53 E) -1,621.49 KOP - Rectangle (sides W1.00 H1,000.00 D0.00) 5,952.44 7,788.05 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 15,200.00 5,986.51 23/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +E/ -W (usft) (usft) (usft) (usft) Comment 10,409.00 5,915.54 7,756.65 -1,617.44 TIP 10,437.00 5,936.92 7,774.28 -1,621.49 KOP 10,458.00 5,952.44 7,788.05 -1,624.67 End 20 dis, Start 45 dis 10,559.29 5,990.65 7,876.67 -1,645.09 End 45 dis, Start 7 dis 10,650.00 5,990.21 7,966.00 -1,660.55 5 11,050.00 5,983.16 8,358.73 -1,609.97 6 11,250.00 5,979.08 8,551.97 -1,560.57 7 11,450.00 5,973.85 8,745.21 -1,511.24 8 11,650.00 5,967.93 8,938.44 -1,461.97 9 12,050.00 5,967.59 9,331.83 -1,507.70 10 12,330.00 5,974.17 9,605.47 -1,559.78 11 12,730.00 5,989.02 9,987.81 -1,661.96 12 13,110.00 6,001.78 10,266.39 -1,915.05 13 13,385.00 6,005.24 10,456.82 -2,111.63 14 13,665.00 6,006.95 10,650.05 -2,312.37 15 13,990.00 6,009.91 10,880.25 -2,538.74 16 14,390.00 6,009.56 11,149.71 -2,828.97 17 14,790.00 5,999.22 11,419.10 3,119.07 18 15,200.00 5,986.51 11,693.17 -3,417.97 Planned TD at 15200.00 6/27/2018 155: 11PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error. 0.00 usft Reference Well: 3H-31 Well Error. 0.00 usft Reference Wellbore 314-31A Reference Design: 3H-31A_wPo2 ConocoPhillips BA Travelling Cylinder Report UG! a GEmmpany Local Coordinate Reference: Well 3H-31 TVD Reference: 3H-31 @ 80.00ugft (31-1-31) MD Reference: 3H-31 @ 80.00usft (31-1-31) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDT Alaska Prod Offset TVD Reference: Offset Datum Reference 3H-31A_wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 209+ 100/1000 of reference Interpolation Method: MD Interva125.01 Error Model: ISCWSA Depth Range: 10,409.00 to 15,200.00usft Scan Method: Trai Cylinder North Results Limited by: Maximum center -center distance of 1,712.00 usft Error Surface: Pedal Curve Sumay, Tool Program Date 6/2712018 From To (usft) (usft) Survey (Wellbore) Toof Name Description 88.20 10,409.00 3H-31 (3H-31) GCT -MS Schlumberger GCT multishot 10,409.00 15,200.00 3H-31 A_wp02(3H-31 A) MWD MWD - Standard Casing Points Measured Vertical Depth Depth (usft) (usft) Reference 121.00 121.00 16" 5,023.10 3,262.47 95/8" 15,200.00 6,066.51 23/8" Casing Hole Diameter Diameter Name 16 26 9-5/8 13-112 2-3/8 3 Summary Kupaluk 3H Pad -3H -24 -3H -24-3H-24 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore- Design (usft) (usft) (usft) vertical (usft) beau, Kupamk 3H Pad brservreEame Cman Lacing- Carrtrtb Noes Allakvela warning ospm DeW 3H-21 - 3H-21 - 3H-21 nalat, Aauau,h aHrS Out of range 3H-22 - 31-1-221.1-02 - 31-1-2211-02 Camva Dhssaw Dealaaon (ash) (ien) lues) Out of range 3H-22 - 31-1-221.7-03 - 31-1-2217-03 lash) (0) (usft) (usft) f9 Out of range 3H-22- 3H-22L7-03PB7 - 31-1-221-1-03PB1 luau) 10.667.84 6,070.03 10,67500 5,327.W 70.88 Out of range 3H-22 - 3H-22L7-03PB2 - 3H-221_1-03PB2 7.856.48 -292534 5 1,46997 575.48 Out of range 3H -24 -3H -24-3H-24 10,750.00 10,925.00 1,467.69 570.93 956.36 Pass - Major Risk 3H -31 -3H31 -3H-31 10,425.00 10,425.00 0.00 1.01 -0.93 FAIL - Major Risk 3H -31-3H-31 AL1-3H-31AL1_wp01 13,071.56 13,075.00 22.84 1.37 22.61 Pass - Minor 1/10 3H-32 - 3H-32 - 311-32 575.01 989.31 Pass -MajorRisk 10100.00 6069.68 10.75000 5,365.10 Out of range Kuparuk 3M Pad -81.47 7,917.53 -2947.57 5 1,466.33 573.56 3M -24 -3M -241.1-03-3M-241.1-03 15,075.63 12,895.00 1,608.33 404.74 1,206.83 Pass -Major Risk 3M -28 -3M -28.3M-28 13,440.92 13,100.00 154.00 7.77 150.68 Pass -Minor 1/10 3M -29 -3M -29A -3M -29A 11,842.68 13,314.00 414.62 5.66 414.37 Pass - Minor 1/10 3M-29-3M-29APB1-3M-29APB1 11,731.96 13,088.00 498.67 10.60 498.42 Pass - Minor 1/10 Offset Design Kupaluk 3H Pad -3H -24 -3H -24-3H-24 01hux5ReEmr. 0.00 usft surrey Program: 156 -MWD RUM AWaMB: Major Risk bhal Well E.I. 0.00 usft Relevance Offset semi ValorNb Measured wniul Maasom4 vertical Rerevance beau, Toaaace+ brservreEame Cman Lacing- Carrtrtb Noes Allakvela warning ospm DeW Dapth nalat, Aauau,h aHrS +V- Hole 81st Camva Dhssaw Dealaaon (ash) (ien) lues) luald haft) lash) (0) (usft) (usft) f9 (uclt) (aan) luau) 10.667.84 6,070.03 10,67500 5,327.W 70.88 125.52 A&12 7.856.48 -292534 5 1,46997 575.48 975.89 Paas - Major Ruk 10,676.12 6069.94 10.700.00 5,3/0,02 70.89 125.85 55.06 7,87892 -2.93268 5 1,468.42 575.27 972.42 Pass -Major Risk 10854.31 6089.85 10,72500 5,352.51 70.89 126.18 ,45.03 7,89727 -2,94040 5 1,46719 575.01 989.31 Pass -MajorRisk 10100.00 6069.68 10.75000 5,365.10 70.90 126.51 -81.47 7,917.53 -2947.57 5 1,466.33 573.56 966.18 Pass - Major Risk CC - Mu fPn1lP u,f,.n1P.r d151anCP nr LOVPnr.nt nnmt. SF - min SPnaratlnn factor. ES - min Ouse senaration 0/27/2018 9: 26: 54AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Protect: Kuparuk River Unit Site: Kuparuk JH Pad os,a,unm<r„n xren Naareua _a ra uearwe FSM WELLBORE DETAILS: 3H -31A REFERENCE INF flMAUM Parent WtOtrore: 311-31 Co lNhl aemrerc� NalM1 Well: 3H-31 se.,em nuo.na Tie on MD' 10409.00 Mea GaJ Law vaumi irvoi Reremu Nees sm Erx v..1 setiaa Nsl Reiaau>'. Sub IOWN.OwEl Wellbore: JH 31A o�ep w.m. Northing Neewea [apn Rearcrce. lH3i@N aaftl3wtn Plan: JWellb 02 JH•Jt13H•91A _wP I ) nmy. aGo�wr Longitude Celabmn Wmx. raareure ca -,a. c_ BA ER I U'HES West( -)/East(+) (400 usf /in) F` Mean Vertical Section at 330.00° (150 usftlin) WELL DETAILS: 3H-31 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000687.91 498655.24 70° 24'47.208 N 150° 0' 39.425 W See MD Inc Azi TVDSS +N - eg Waco VSecl Annotation 1 10409.00 40.27 347.07 5915.54 7756.65 -1617.44 0.00 0.00 7526.17 TIP 2 10437.00 40.22 347.02 5936.92 7774.28 -1621.49 0.21 -147.16 7543.47 KOP 3 10458.00 44.42 347.02 5952.44 7788.05 -1624.67 20.00 0.00 7556.98 End 20 cgs, Start 45 dls 4 10559.29 90.00 347.02 5990.65 7876.67 -1645.09 45.00 0.00 7643.94 End 45 d1s, Start 7 cgs 5 10650.00 90.55 353.35 5990.21 7966.00 -1660.55 7.00 85.00 7729.04 5 6 11050.00 91.43 21.34 5983.16 8358.73 -1609.97 7.00 88.00 8043.85 6 7 11250.00 90.90 7.34 5979.08 8551.97 -1560.57 7.00 268.00 8186.51 7 8 11450.00 92.08 21.30 5973.85 8745.21 -1511.24 7.00 85.00 8329.20 8 9 11650.00 91.29 7.31 5967.93 8938.44 -1461.97 7.00 267.00 8471.91 9 10 12050.00 88.80 339.42 5967.59 9331.83 -1507.70 7.00 265.00 8835.45 10 11 12330.00 88.53 359.03 5974.17 9605.47 A559.78 7.00 91.00 9098.47 11 12 12730.00 87.30 331.04 5989.02 9987.81 -1661.96 7.00 267.00 9480.68 12 13 13110.00 88.93 304.47 6001.78 10266.39 -1915.05 7.00 273.00 9848.48 13 14 13385.00 89.64 323.71 6005.24 10456.82 -2111.63 7.00 88.00 10111.68 14 15 13665.00 89.66 304.11 6006.95 10650.05 -2312.37 7.00 270.00 10379.40 15 16 13990.00 89.30 326.86 6009.91 10880.25 -2538.74 7.00 91.00 10691.94 16 17 14390.00 90.79 298.89 6009.56 11149.71 .2828.97 7.00 273.00 11070.42 17 18 14790.00 92.11 326.87 5999.22 11419.10 -3119.07 7.00 87.00 11448.77 18 19 15200.00 91.37 298.17 5986.51 11693.17 -3417.97 7.00 269.00 11835.57 Planned TD at 15200.0 c_ BA ER I U'HES West( -)/East(+) (400 usf /in) F` Mean Vertical Section at 330.00° (150 usftlin) KUP PROD 3H-31 �/����(L� t'�[ _ Well Attitiutes Max AngleBMD TD �V`O' •'I"'t�_ WNpnrogPllNN Fltll Xamv WeIIWreSlalus ntl l'1 MOIDKRI ARR Tb Alaska.Inc. 501032020500 KUPARUK RAVER UNIT PROO 65.9J 3,6]6.61 10,]30.0 o""'N' M151Ppm1 Ogle AnnNXion End MM —ran Relem OM SSSV.NIPPLE Lass Pro: 3191199] 40,991""V1311994 311el,WGIRSI Last Tag Ad, n CeW1110116) EM Oak Lnl May LaV Tag: RKS(Est, 44' of RelHCle) 10,5380 511322018 umbaej Last Rev Reason Mnauun EM 0.k tact M r Rev Reason: Updated Tag 511412018 umbaej IwNeER. r,B • Casing Strings TDNEwCCONDrl casing OeecnNbn oO0n101ml Top lalt4B3l Depu gel Deplb lllK12a1 i6 02 0 0 Wrap cazin90e"Naron OD (Int ID (In) Top(KKBI—L.Phltll{BI Bel OM1N IN0)... WIILm 11... OrNe Tap ThrW SURFACE 95/8 8.921 41.8 5,023.1 2.869.5 35.00 L55 BTC uten ll... ate iop Tnraf Cacing.....mn oD lin) nl TOP( 1 bet OranldK9) set Dretn l]vDl-- 2.t.'61 PRODUCTION 71"16 2]6 34.] 10]118 5650.] 26.00 L-80 BTC-MOO Tubing Strings CONDUCTOR 4S 0-121 e Tubing Rrcripllon 31Nng Ma... IDlin1 Top Ir01B1 BN Oepifi (M1. Set Ceplfi (TVOI I... Vil96l11) Grate Top ConnMion TUBING 3112 2.992 376 103366 5,50].3 9.J0 L-60 ABMCUE Completion Details T.F(I Top Incl Nwnlni TOP INK61 (Itee 1'1 Item DM tem Ie Un) NIPPLE. 8880 376 376 006 HANGER MCEVOY GEN4 TUBING HANGER 1500 4880 1144 ].id NIPPLE CAMCG DS LANCING NIPPLE 2,812 75,270.2 5.5171 4192 NIPPLE CAMCO MI SELECTNE NIPPLE NO GO 2812 10.30. --9,M-9 4063 SEAL ASSY BAKER KeR2 ANCHOR SEAL ASSEMBLY 3.M to, 10. 4060 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 103266 5.5597 40.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 103357 55656 4028 SOS BAKER SHEAR OUT SUB 2.992 X! Perforations 8 Slats Bbal ohne iop ITV% atm (TVOI Mo (le'fl Top(MB) &m IXKBI lnKBl (Ntal taw Dela 1 Type Com ILII` 10,428.0 10.146.0 5635.5 5,649.3 Gl, 3H31 311212000 4.0 RPERF 2 ire' EJ III OR, O deg ph. H SURFACE. 41 e50231— -9D deg otlem 10.4520 10A82.0 56554 56]84 A-2,A-0.3FL31 5/14/1991 40 (PERF 4112'-SIX 180 deg ph 10.402.0 10,494.0 56]84 568>.fi M,SH-St 1128/2011 60 APERF Millenium Deep Penetrating charges, 60 degree plasm, GP5LAT iLMl Mandrel inserts M Sell Ter, ME) valor LYcn pM slv „ TOenagel 16.61 Meq NMN OO9n) Fy Type TYM (ln) q1;.1 Cam102 2 d8 5 OTIS LEX 1t/ A Urr DMT RM 000019W NIPPLE, 102703 Notes: General B Safety Ena Oak AnrKKe[kn tt/12/2010 NOTE. View SCKemalicw/Plas.a Scbemaic9.0 6EK PSSV; tp}'19B PACKER: 103107 NIPPLE.10.326.6 W%10035] RPERF:l0.L38.0,10.040 HERE: 1045].0-10403.0 AFERF. 10 b2 6t➢.4a.1.0 PRODUCTION;34.]-11G11e \ r`� X)* r 0 O ro 10 o=m N l(j J O O m a CL CO O @ 16 (j) o own 1 OU p IIIIII 0 N O a E N N E M E 0 w O 00 O (V N 0 LO n 0 �p LOO N rnro �p mg Y v p CL ma pj 0 N Cl) o N (6 C N �- i co cD o E C (n V a wva=� @13y� 0m 0 E 0) �O 3 (n O W Co cu0 Na �� V _ d C0 CL 0 0�. N a m 0 J GU C N M CL Q (0 U0)O�U� (`YU) 0 W J - dNNC7N(V 3YYN Y 7AA dAA Jfdm M m \ r`� X)* r 0 O ro 10 o=m N l(j J O O m a CL CO O @ 16 (j) o own 1 OU IIIIII IIIIIIIIIIII 1 V N O a o 0 0 LOO N M V O p O L ik � C CL pj 0 N O M N J C� a` �- i co V a No 0) �O cu0 Na T O N (o - co N Remark: AOGCC PTD No. 218-076 Coordinate Check 28 June 2018 INPUT Geographic, NAD27 KRU 3H -31A Latitude: 70 24 47.20800 Longitude:150 00 39.42500 OUTPUT Stale Plane, NAD27 5004 -Alaska 4, U.S. Feel ill NorthingN-. 6000687.8 75 EastinglX: 498655.239 Convergence: -0 00 37.14364 Scale Factor: 0.999900002 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: / PTD: ✓ Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: ��pQ ra_t IiJ'�r� ®� 1 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(1), 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 ermit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field &Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPAR_UK RIV UNIT 3H -31A Program DEV Well bore seg LJ PTD#: 2180750 Company CONOCOPHILLIPS ALASKA INO_ Initial Classlrype _ DEV / PEND GeoArea 890 Unit 11160 ___ _ On/Off Shore On _ Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31,05.0300. 1.A).0.2.A-D) _ _ _ NA .. . Date: -�(s� lk 1 Permit fee attached.... - - _ _ _ _ NA 2 Lease number appropriate.. Yes Surface Location lies within ADL0025531; Top Prod Int & TD lie within ADL0025524. _ 3 Unique well name and number _ Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432D _ 4 Well located in. a. defined pool_ - _ Yes Conservation Order No. 432D has no intenvell. spacing_ restrictions. Wellbore. will be. more than 500' ,5 Well located proper distance from drilling unit boundary Yes from an external property line where ownership or landownership. changes. As proposed, well will 6 Well located proper distance from other wells _ _ _ _ _ Yes conform to spacing. requirements... 7 Sufficient acreage. available in drilling unit Yes _ _ ... ... 8 If deviated, is wellbore plat included _ _ _ _ _ Yes 9 Operator only affected party _ _ Yes 10 Operator has. appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order _ _ Yes 12 Permit can be issued without administrative. approval Yes SFD 6/29/2018 13 Can permit be approved before 15 day wait. ... _ _ Yes 14 Well located within area and strata authorized by Injection Order # (put 10# incomments)(For. NA. .. . 15 All wells within 1/4 mile _area -of review identified (For service well only).......... NA 16 18 Pre -produced injector. duration of pre production less than 3 months (For service well only) Conductor string provided .... - - - _ _ _ _ _ ..... . . . . . . . . . . . NA NA _ Coiled tubing drilling sidetrack through productiontubing Engineering 19 Surface casing protects all known USDWs .. _ _ _ _ _ _ _ _ _ NA 20 CMT vol adequate to circulate.on conductor & surf csg .. - - _ _ _ _ NA _ .................... 21 CMT vol adequate to tie-in long string to surf csg_ _ _ _ ...... NA CTD slotted liner w/ TOL into existing tubing tail_ 22 CMT. will cover. all known productive horizons. _ _ _ _ _ _ _ _ - _ NA... CTD slotted liner. 23 Casing designs adequate for C, T, B & permafrost _ _ _ _ - _ _ NA... 24 Adequatetankage or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 25 If_a_re-drill, has.a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ Yes 26 Adequate wellbore separation proposed _ _ _ Yes -------------- 27 Ifdiverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ CTD sidetrack from existing production hole. Appr Date 28 Drilling fluid program schematic & equip list adequate ......... . . . . . . Yes - - .... . MGR 7/5/2018 29 BOPEs,do they meet regulation _ _ _ _ _ _ _ _ - - - _ _ _ - _ _ _ Yes 30 BOPE_press rating appropriate; test to (put psig in comments)_ ... _ _ .. _ _ _ _ Yes 31 Choke manifold complies w/API. RP -53 (May 84)____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown_ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ ........... _ _ ...... . 33 Is presence of H2S gas. probable _ _ _ _ _ _ _ _ _ I ............ Yes 34 Mechanical condition of wells within AOR verified (For service well only) _ - _ - - _ _ _ _ _ _ NA . . . . . . . . . . . . . . . . . . . . . . . . ............................. 35 Permit can be issued w/o hydrogen sulfide measures . . . . .................. No... ... 3H -Pad wells are H2S-bearing.-H2S measures are required.. Geology 36 Data presented on potential overpressure zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Expected reservoir pressure is 12.1 ppg EMW (with a maximum of 13.0 ppg EMW).. Well will be Appr Date 37 Seismic analysis of shallow gas zones ....... . . . . . . . . . ......... NA .... drilled using 8.6 ppg mud,,a coiled -tubing. rig, and managed_ pressure drilling technique to SFD 6/29/2018 38 Seabed condition survely.(if off -shote) ....... . . . . . . . . . . . . . . . ......... NA _ .. control formation pressures and maintain shale stability... _ 39 Contact name/phone for weekly.progress reports. [exploratory only] . . .............. NA .......... Geologic Engineering Public Commissioner: Date: -�(s� lk Commissioner: Date � s/& Com ioner Date ��� -4151t� pzs
