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218-112
DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 1 1 2 1 - 6 0 - 0 0 We l l N a m e / N o . KU P A R U K R I V U N I T 2 G - 0 6 L 1 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 10 / 2 3 / 2 0 1 8 Pe r m i t t o D r i l l 21 8 1 1 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 81 3 4 TV D 59 7 0 Cu r r e n t S t a t u s P& A 8/ 2 1 / 2 0 2 3 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : GR / R e s No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e C 11 / 1 3 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 E O W - N A D 2 7 . p d f 29 9 9 3 ED Di g i t a l D a t a C 11 / 1 3 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 E O W - N A D 2 7 . t x t 29 9 9 3 ED Di g i t a l D a t a C 11 / 1 3 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 E O W - N A D 8 3 . p d f 29 9 9 3 ED Di g i t a l D a t a C 11 / 1 3 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 E O W - N A D 8 3 . t x t 29 9 9 3 ED Di g i t a l D a t a C 0 0 2 1 8 1 1 2 0 K U P A R U K R I V U N I T 2 G - 0 6 L 1 L O G HE A D E R S 29 9 9 3 Lo g Lo g H e a d e r S c a n s C 11 / 1 5 / 2 0 1 8 79 9 0 8 3 3 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : 2 G - 0 6 L 1 P B 1 GA M M A R E S . l a s 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 2 M D F i n a l L o g . c g m 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 5 M D F i n a l L o g . c g m 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 5 T V D S S F i n a l Lo g . c g m 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 2 M D F i n a l L o g . p d f 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 5 M D F i n a l L o g . p d f 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 5 T V D S S F i n a l Lo g . p d f 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 E O W - N A D 2 7 . p d f 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 E O W - N A D 2 7 . t x t 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 F i n a l S u r v e y s . c s v 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 F i n a l S u r v e y s . x l s x 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 S u r v e y L i s t i n g . t x t 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 S u r v e y s . t x t 30 0 1 4 ED Di g i t a l D a t a Mo n d a y , A u g u s t 2 1 , 2 0 2 3 AO G C C P a g e 1 o f 3 PB 1 2G - 0 6 L 1 P B 1 GAM M A R E S.l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 1 1 2 1 - 6 0 - 0 0 We l l N a m e / N o . KU P A R U K R I V U N I T 2 G - 0 6 L 1 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 10 / 2 3 / 2 0 1 8 Pe r m i t t o D r i l l 21 8 1 1 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 81 3 4 TV D 59 7 0 Cu r r e n t S t a t u s P& A 8/ 2 1 / 2 0 2 3 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 10 / 2 3 / 2 0 1 8 Re l e a s e D a t e : 10 / 9 / 2 0 1 8 C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 06 L 1 P B 1 _ 2 5 _ t a p e s c a n _ B H I _ C T K . t x t 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 06 L 1 P B 1 _ 5 _ t a p e s c a n _ B H I _ C T K . t x t 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 _ o u t p u t . t a p 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 2 M D F i n a l L o g . . t i f 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 5 M D F i n a l L o g . t i f 30 0 1 4 ED Di g i t a l D a t a C 11 / 1 5 / 2 0 1 8 E l e c t r o n i c F i l e : 2 G - 0 6 L 1 P B 1 5 T V D S S F i n a l Lo g . t i f 30 0 1 4 ED Di g i t a l D a t a C 0 0 2 1 8 1 1 2 0 K U P A R U K R I V U N I T 2 G - 0 6 L 1 L O G HE A D E R S 30 0 1 4 Lo g Lo g H e a d e r S c a n s Mo n d a y , A u g u s t 2 1 , 2 0 2 3 AO G C C P a g e 2 o f 3 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 0 2 9 - 2 1 1 2 1 - 6 0 - 0 0 We l l N a m e / N o . KU P A R U K R I V U N I T 2 G - 0 6 L 1 Co m p l e t i o n S t a t u s P& A Co m p l e t i o n D a t e 10 / 2 3 / 2 0 1 8 Pe r m i t t o D r i l l 21 8 1 1 2 0 Op e r a t o r Co n o c o P h i l l i p s A l a s k a , I n c . MD 81 3 4 TV D 59 7 0 Cu r r e n t S t a t u s P& A 8/ 2 1 / 2 0 2 3 UI C No Co m p l i a n c e R e v i e w e d B y : Da t e : Mo n d a y , A u g u s t 2 1 , 2 0 2 3 AO G C C P a g e 3 o f 3 M. G u h l 8/ 2 1 / 2 0 2 3 By Meredith Guhl at 11:41 am, Sep 10, 2021 GSFD 9/10/2021RBDMS HEW 9/10/2021 WCB - 2023-07-13 L1: 8134' MD / 5970' TVD L1 PB1: 8330' MD / 6063' TVD SFD 8/9/2022 SFD 8/9/2022 DSR-9/10/21 SFD 9/10/2021 10/22/2021 SFD Abandonment Date 10/23/2018 HEW ! " # $ ! % " & ' # ( # ) * + ! " , * - . / ! " ! / 0 & 1 ! 2 3 4 1 - 5 " / ! , 1 / 6 6 6 6 7 8 9 7 : 0 & 2 3 7 8 ; ' - 8 0 & 2 3 . / ! " ! / 0 & 1 ! 2 3 , * + ! " , ! / & 0 9 4 3 5 ' 9 7 ) 6 % * , 6 4 < ! " 6 9 - 8 = ' > 9 - 8 1 ? / 4 1 / , ! ; ! / ! " # $ ! % " ' , ) " 9 , ! / % ! > Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,031.0 2/6/2019 2G-06 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Rockscreen & Updated Tag Depth 2/6/2019 2G-06 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.58 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 9.21 Top (ftKB) 37.2 Set Depth (ftKB) 3,133.9 Set Depth (TVD) … 2,773.7 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.9 Set Depth (ftKB) 8,449.1 Set Depth (TVD) … 6,223.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 30.1 Set Depth (ft… 7,969.3 Set Depth (TVD) (… 5,841.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.1 30.1 0.09 HANGER Vetco/Gray Gen II TUBING HANGER 2.938 524.7 524.6 1.18 NIPPLE 3.5" Camco "DS" Nipple w/ 2.875 profile 2.875 7,956.6 5,831.6 39.63 PBR PBR Seal Assembly (sheared) w/ 2' space out STABBED INTO PACKER ASSEMBLY 2.980 Tubing Description TUBING PACKER ASSY String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,968.3 Set Depth (ft… 8,043.6 Set Depth (TVD) (… 5,899.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8RD EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,968.3 5,840.7 39.50 PACKER FHL Packer 3.030 8,011.2 5,873.8 39.03 NIPPLE 2.813" DS Nipple 2.813 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,097.5 5,941.4 37.98 Window in 7" casing HEW WS failed & fell down hole, leaving window exposed in 7" casing 10/21/201 8 2.800 8,132.0 5,968.7 37.54 NS High Expansion Wedge WS NS High Expansion Wedge WS Note: WS slid down-hole. Likely top at 8136' MD (10/23/18) 10/21/201 8 0.000 8,136.0 5,971.8 37.49 NS High Expansion Wedge WS NS High Expansion Wedge WS 10/16/201 8 0.000 8,158.0 5,989.3 37.21 FISH LOWER PACKER FROM OLD COMPLETION, PXX PLUG, & REST OF TUBING DOWN TO WIRELINE RE- ENTRY GUIDE IS IN FILL. TAGGED HARD MUD @ 8158 SLM. 1/6/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,188.0 8,198.0 6,013.3 6,021.3 A-5, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Schlumberger Casi 8,216.0 8,246.0 6,035.7 6,059.9 A-4, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4" Schlumberger Casi Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,951.5 2,655.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,240.0 2/8/2018 9:30 2 4,945.5 3,851.9 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,220.0 2/8/2018 10:30 3 6,250.3 4,646.2 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,217.0 2/8/2018 1:00 4 7,246.0 5,310.6 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,232.0 2/8/2018 9:30 5 7,898.2 5,786.8 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 2/7/2018 10:30 Notes: General & Safety End Date Annotation 1/2/2000 NOTE: WORKOVER 12/10/2007 NOTE: ** MIT TESTING WILL HAVE TO USE DS NIPPLE @ 8008' *** 12/10/2007 NOTE: WORKOVER 7/2/2009 NOTE: 5005' = TIGHT SPOT, UNABLE TO WORK 2.6" GAUGE RING PAST 6/27/2009 7/2/2009 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE 2G-06, 2/7/2019 8:25:37 AM Vertical schematic (actual) PRODUCTION; 35.9-8,449.1 IPERF; 8,216.0-8,246.0 IPERF; 8,188.0-8,198.0 FISH; 8,158.0 NS High Expansion Wedge WS; 8,136.0 NS High Expansion Wedge WS; 8,132.0 NIPPLE; 8,011.2 PACKER; 7,968.3 PBR; 7,956.6 GAS LIFT; 7,898.2 GAS LIFT; 7,246.0 GAS LIFT; 6,250.3 GAS LIFT; 4,945.4 SURFACE; 37.2-3,133.9 GAS LIFT; 2,951.5 NIPPLE; 524.7 CONDUCTOR; 38.0-110.0 HANGER; 30.1 KUP PROD KB-Grd (ft) 36.00 Rig Release Date 6/18/1984 Annotation Last WO: End Date 7/14/2010 2G-06 H2S (ppm) 110 Date 12/19/2017... TD Act Btm (ftKB) 8,485.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292112100 Wellbore Status PROD Max Angle & MD Incl (°) 54.60 MD (ftKB) 4,000.00 WELLNAME WELLBORE2G-06 &R Q R F R 3 K L O O L S V $ O D V N D , Q F . X S # " $ % # " $ & " ' & ( ) * + , ( - ( ( . / " / * " ( ' " / 01 / / % & ' 2 / 2 / " " 3 ' / - "# ( ) * . , / ) 0 ) ) & 1 " # ( ) * 2 4 / &R Q R F R 3 K L O O L S V $ O D V N D , Q F . X S ! " # $ "# ( ) * "# ( ) * + , 3% "# ( ) * + , 3% " " " / % , / 7 $ 3 / "# ( ) * . , / ) 0 ) ) & 1 " # ( ) * 2 / 8 " # ( ) * 3" / & " / . 3" 5 / " / !' ' , 9 " : 1 2 7 % , 9 " : 1 7 % 6 6 ! ' 2 ! ; ' 7 ; ! $ ' 7 < ) / - ' + ! 8 & ! $ & 2 2 * 4 ' / *" ' / " 4 / 4 / & 6 7 ( 2 6 7 ( % " & & & & ' * / "# ( ) * & & )0 ) ) )0 ) ) 4; 9 / / ; , = 4 0 " , 4) > ; 9 " 9 0 9 ) )0 ) ) 2 " ' " / & )0 ) ) :) ? , 4 @ = ) 0 9 , , ,/ 9 ? 4 4 @ / ) 0 , * 4 8 2 " 89 : ; ' 4 8 0 : " " < 4 89 : 3 ' " 3" 4 "# ( ) * + , , # # - " ) , > , " A , A " ) , > , * 0 : 4 > ) 0 > , 4 : ; / " / " / 1 / < ' / 4 "# ( ) * + , , ,0 ) 7 ! 7 + 1 " / ; 8 0 1 : 8 : 6 7 ( 8 : 89 : 6 7 ( 2 8 : 0 = / >; , ) ) 0 ) ) )0 ) ) )0 ) ) )0 ) ) ,/ ) 0 ) ) ; 8 : 4 " 0 " 8 2 : 0 8 : " " " ' " ' - ' ' ") ) 0 ) ) >; , ) ) 0 ) ) " # ( ) * 1 " # ( ) * 2 ,A , " A " ) ) , -8 % ( 6 + B - 8 % ( 6 + B C + + >; , = / 0 ) ) >; " " , 0 / " " # ( ) * + , , - 8 % ( 1 " # ( ) * + , , 2 ,) A , 4 A " ) , > , ) A , 4 A " ) , > -8 % - 8 % ( ' $ $ >; " 4 , 0 , > >; " > , 0 4 : " # ( ) * + , , - 8 % 1 " # ( ) * + , , 2 ,) A , 4 A " ) , > , ) A " ) A " ) , > . / " / * " ( ' " / 01 / / % & ' 2 / 2 / " " 3 ' / - "# ( ) * . , / ) 0 ) ) & 1 " # ( ) * 2 4 / &R Q R F R 3 K L O O L S V $ O D V N D , Q F . X S ! " # $ "# ( ) * "# ( ) * + , 3% "# ( ) * + , 3% " " " / % , / 7 $ 3 / "# ( ) * . , / ) 0 ) ) & 1 " # ( ) * 2 / 8 " # ( ) * 3 8 : > 89 : <? 89 : 6 7 ( 2 8 : 6 7 ( 8 : 01 8 : 01 8 : 3" 4 8 : 3" " 4 8 : 1 " 8 : * 89 7 @ : 0 " 7 >; , ) ) 0 ) ) = : 0 9 4 / 9 0 ) : 4 ; 9 / = 0 = * = ; = , : 0 : " = ; * : ) 0 / = 4; > ) = 0 = * 4 ; 9 / : ; / 4 * 0 9 / 4 , " ; 4 9 * 0 ) " , 0 " " = ; = , : 0 : " - 8 % ( 6 + B 1 " 2 >; , = / 0 ) ) = : 0 4 , / 9 0 ) : 4 ; 9 : ) 0 " 4 = ; = = , 0 = 4 = ; * > * 0 , / 4; > = ) 0 " 4 4 ; 9 / : ; / : ) 0 4 9 4 , " ; * , , 0 : " , 0 " 9 = ; = = , 0 = 4 - 8 % ( 6 + B 1 " 2 6 >; , * = 0 4 , / = 0 4 = / : 0 : / 4 ; 9 9 " 0 * : = ; = / / 0 ) > = ; : ) ) 0 / : 4; > 4 " 0 * : 4 ; 9 / : ; / > = 0 = / 4 , " ; * " * 0 ) = " ) 0 * , = ; = / / 0 ) > - 8 % ( 6 + B 1 " 2 $ 7 D >; , 9 ) 0 / * / 9 0 9 " / * 0 : 9 * ; ) , , 0 , / = ; = 4 : 0 = 9 = ; : , / 0 > : 4; > : , 0 , / 4 ; 9 / : ; / 9 * 0 * : 4 , " ; * / ) 0 / , " = 0 > 4 = ; = 4 : 0 = 9 - 8 % ( 6 + B 1 " 2 $ 7 D >; " " , 0 / " 4 > 0 " ) / 4 0 9 ) * ; ) " 9 0 " 9 = ; = : / 0 * 9 = ; : = " 0 9 > 4; > > 9 0 " 9 4 ; 9 / : ; 4 , = 0 9 > 4 , " ; * 4 > 0 4 ) " * 0 > / = ; = : / 0 * 9 - 8 % ( 6 + B 1 " 2 $ 7 D >; " 4 , 0 , > * * 0 / 9 / 4 0 , : * ; ) / = 0 ) 9 = ; = 9 = 0 , / = ; : 4 , 0 : : 4; 9 ) = 0 ) 9 4 ; 9 / : ; 4 = " 0 / * 4 , " ; * : : 0 " : " : 0 9 / = ; = 9 = 0 , / - 8 % 1 = 2 >; " > , 0 4 : : * 0 * * / = 0 : , * ; ) 4 " 0 * 9 = ; / , = 0 : , = ; : : , 0 9 " 4; 9 , " 0 * 9 4 ; 9 / : ; 4 4 = 0 ) / 4 , " ; * 9 : 0 / ) = = 0 : : = ; / , = 0 : , - 8 % 1 = 2 >; = = ) 0 ) ) : * 0 * * / = 0 : , * ; ) * = 0 > * = ; / / : 0 : : = ; > ) / 0 / > 4; 9 " = 0 > * 4 ; 9 / : ; 4 > : 0 , / 4 , " ; : " 9 0 9 , ) 0 ) ) = ; / / : 0 : : 6 5 % % 1 Guhl, Meredith D (CED) From:Guhl, Meredith D (CED) Sent:Friday, September 10, 2021 11:40 AM To:Ohlinger, James J Cc:Loepp, Victoria T (CED); Carlisle, Samantha J (CED) Subject:RE: [EXTERNAL]RE: KRU 2G-06 et al That will work perfectly, and no need to send it to the processing email, we’ll log it in and get it out to senior staff for review from here. This closes out the PTD 218‐112 file. Thank you James! Meredith From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Friday, September 10, 2021 11:38 AM To: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 2G‐06 et al I was able to find all the pieces and put together a new file. Let me know if this will work. From: Guhl, Meredith D (CED) meredith.guhl@alaska.gov Sent: Friday, September 10, 2021 10:04 AM To: Ohlinger, James J James.J.Ohlinger@conocophillips.com Cc: Loepp, Victoria T (CED) victoria.loepp@alaska.gov; Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 2G‐06 et al Hi James, I’ve looked in the places where the 10‐407 might be but have had no luck. If the only copy ConocoPhillips has is the scanned 10‐407 you forwarded yesterday, we will accept that scan, submitted via the aogcc.permitting@alaska.gov email. The scan text is mostly legible, except for the schematics. Would it be possible to attach new digital schematics to the scanned 10‐407 for clarity please? Thanks for your assistance and understanding with this issue. Regards, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov 2 Direct: (907) 793‐1235 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 Meredith Guhl at 907‐793‐1235 or meredith.guhl@alaska.gov. From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Thursday, September 9, 2021 8:01 AM To: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 2G‐06 et al Ok, I can have another copy printed and sent over if needed. Thanks From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Thursday, September 09, 2021 7:59 AM To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 2G‐06 et al Hi James, I can see that we logged the 10‐407 in as received on 11/21/2018, this was when we were still fully paper. I don’t see the 10‐407 in the well history file, I am going to do what checking I can in our digital files and will look more thoroughly through the paper files when I am at the office tomorrow. Given as it’s been almost 3 years since submittal, it’s pretty likely that I won’t be able to find it. I will update you tomorrow. Thanks, Meredith From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Thursday, September 9, 2021 7:52 AM To: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2G‐06 et al Form Tracker has the following. 3 From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Wednesday, September 08, 2021 2:44 PM To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2G‐06 et al Hi James, Thank you for the thorough update. The AOGCC will need a 10‐407 to close out 2G‐06L1, PTD 218‐112, please. Even though the well lateral was not completed, there was work done under that permit to drill number. It was an error at the AOGCC to mark the permit expired. The full downhole data suite was submitted to the AOGCC and also the directional survey, so the only outstanding material needed is the 10‐407 packet. I will include your email and slides as a note to the well history file, along with a note that the PB1 data is the only data available for 2G‐06L1. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793‐1235 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 Meredith Guhl at 907‐793‐1235 or meredith.guhl@alaska.gov. From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Tuesday, September 7, 2021 3:00 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 2G‐06 et al Forgot a piece: CTD Operations 10/16/18 Set HEW (whipstock) at 8134’ MD Drill L1, plugback 10/21/18 Set 2nd HEW ~8093’ MD, fell downhole Leave 2G‐06 2/25/19 Set 3rd HEW @ 8095’ MD on eline 3/1/19 Cement motherbore 3/8/19 Drill A and AL2 sidetracks 4 From: Ohlinger, James J Sent: Tuesday, September 07, 2021 2:32 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: KRU 2G‐06 et al I put some slides together to sort this out, I had to remember what we did first. Here’s a summary below. Let me know if I missed something, or if more information is needed. Thanks Sundry 12/4/17 317‐529 Cement mother‐bore. Didn’t use, changed to a HEW (whipstock) exit from the original cement pilot hole exit 9/26/18 318‐407 Set 1st HEW ~8134’ MD 12/6/18 318‐530 Ops Shut‐Down 2/14/19 319‐065 Cement mother‐bore and set 3rd HEW (whipstock) Permits 2G‐06L1 218‐112 Plugback, turned into L1PB1 2G‐06L1‐01 218‐113 Not Used 2G‐06L1‐02 218‐114 Not Used 2G‐06AL2‐01 218‐115 Not Used 2G‐06A 219‐019 Completed 2G‐06AL1 219‐020 Not Used 2G‐06AL2 219‐021 Completed 2G‐06AL2‐01 219‐022 Not Used From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, September 01, 2021 11:20 AM To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Cc: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Subject: [EXTERNAL]KRU 2G‐06 et al 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. Hi James, We need to straighten out where we are on 2G‐06, 2G‐06L1(and L1‐01,02,03)etc. This is some history: 10/9/20 KRU 2G‐06L1(PTD 218‐112) Permit 218‐112 expired? 2/25/19 KRU 2G‐06A(PTD 219‐019) 2G‐06AL1, AL2, AL2‐01(219‐020 thru ‐022)PTDs 2/14/19 KRU 2G‐06 (PTD 184‐082, Sundry 319‐065) Plug for CTD redrill 12/6/18 KRU 2G‐06L1(PTD 218‐112, Sundry 318‐530) Op SD 11/29/18 2G‐06 Email from Ohlinger: we’re planning to put a rock screen in TT and produce? 10/9/18 KRU 2G‐06L1 thru L1‐01 to 03(PTD 218‐112 thru 115) PTDs approved 12/4/17 KRU 2G‐06(PTD 184‐082, Sundry 317‐529) Plug for CTD redrill 5 This is what I am thinking needs to be done. Is this the way you see it? 1. What is the status of 2G‐06? Is it producing? 2. Expire permits 2G‐06L1, L1‐01, L1‐02, L1‐03 3. Expire 2G‐06L1(PTD 218‐112, Sundry 318‐530) Op SD. Op SD is good for 1 year 4. Expire 2/14/19 KRU 2G‐06 (PTD 184‐082, Sundry 319‐065) Plug for CTD redrill 5. Expire 2/25/19 KRU 2G‐06A(PTD 219‐019) 2G‐06AL1, AL2, AL2‐01(219‐020 thru ‐022) 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 Sundry12/4/17 317‐529 Cement mother‐bore (Didn’t use)9/26/18 318‐407 Set 1stHEW ~8134’ MD12/6/18 318‐530 Ops Shut‐Down2/14/19 319‐065 Cement and set HEW (whipstock)Permits2G‐06L1 218‐112 Plugback, turned into L1PB12G‐06L1‐01 218‐113 Not Used2G‐06L1‐02 218‐114 Not Used2G‐06AL2‐01 218‐115 Not Used2G‐06A 219‐019 Completed2G‐06AL1 219‐020 Not Used2G‐06AL2 219‐021 Completed2G‐06AL2‐01 219‐022 Not Used12/4/17 KRU 2G‐06(PTD 184‐082, Sundry 317‐529) Plug for CTD redrillDidn’t use 317‐‐529, changed from our Cement Pilot Hole exit to the High Expansion WedgeMother‐bore was still open10/9/18 KRU 2G‐06L1 thru L1‐01 to 03(PTD 218‐112 thru 115) PTDs approved 11/29/18 2G‐06 Email from Ohlinger: we’re planning to put a rock screen in TT and produce?Lateral fell apart and caved inLeft 2G‐06L1PB1Didn’t use L1‐01, L1‐02 and L1‐0312/6/18 KRU 2G‐06L1(PTD 218‐112, Sundry 318‐530) Op SD2/14/19 KRU 2G‐06 (PTD 184‐082, Sundry 319‐065) Plug for CTD redrillCemented the mother‐bore2/25/19 KRU 2G‐06A(PTD 219‐019) 2G‐06AL1, AL2, AL2‐01(219‐020 thru ‐022)PTDsDrilled the A sidetrack to the northAL1 – didn’t drillDrilled the AL2 lateral to the southAL2‐01 – didn’t drill10/9/20 KRU 2G‐06L1(PTD 218‐112) Permit 218‐112 expired?1. What is the status of 2G‐06? Is it producing?1. The A and AL2 are producing2. Expire permits 2G‐06L1, L1‐01, L1‐02, L1‐03 1. Yes3. Expire 2G‐06L1(PTD 218‐112, Sundry 318‐530) Op SD. Op SD is good for 1 year1. Yes4. Expire 2/14/19 KRU 2G‐06 (PTD 184‐082, Sundry 319‐065) Plug for CTD redrill1. We completed 319‐0655. Expire 2/25/19 KRU 2G‐06A(PTD 219‐019) 2G‐06AL1, AL2, AL2‐01(219‐020 thru ‐022)1. Used A and AL2 permits 1stRig Up: Oct. 2018 2ndRig Up: Mar. 2019 Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Tuesday, December 22, 2020 2:51 PM To: william.r.long@cop.com Cc: Loepp, Victoria T (CED) Subject: KRU 2G-061-1 Permit Expired Hi William, The permit to drill for well 2G-061-1 which was issued to CPAI on October 9t" 2018 has expired under regulation 20 AAC 25.005tgj. The permit has been marked expired in the well history file and in the AOGCC database. Please let me know if you have any questions. Thanks HueV Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.Rov 907-793-1241 I THE STATE "'ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-06L 1 Permit to Drill Number: 218-112 Sundry Number: 318-530 Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French { l Chair DATED this v day of December, 2018. RBDMQ�-PtL 0 71018 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ����$ 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 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: ConocoPhillips Alaska Inc Exploratory ❑ Development El Stratigraphic Service ❑ ❑ 218-112 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-21121-60-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2G-061_1 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25656 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8485' 6253' 8368' 6158' 4420 N/A 8158' Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 16" 110, 110, Surface 3097' 9-5/8" 3134' 2774' Intermediate Production 8413' 7" 8449' 6224' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8188' - 8198', 8216' - 8246' 6013' - 6021', 6035' - 6060' 3-1/2" L-80 8044' Packers and SSSV Type: Baker FHL Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): 7968' MD / 5841' TVD 12. Attachments: Proposal Summary F,-/] Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: N/A (Operations Shutdown) Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ElSPLUG ElCommission 16. Verbal Approval: Date: Representative: GINJ ElOp Shutdown El Abandoned El 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: William Long Authorized Title: Staff CTD Engineer Contact Email: William. R.Lon COP.com Contact Phone: 263-4372 Authorized Signature: • Date: // JO COMMISS ON U E ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I / Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Location Clearance ❑ ❑� /Test Other: / 5 Post Initial Injection MIT Req'd? Yes ❑ No ZDi� Spacing Exception Required? Yes ❑ No v❑r Subsequent Form Required: EC 7 T%w APPROVED BY Approved by: - COMMISSIONER THE COMMISSION Date: 1p L Late ubmit Forma d Form 10-403 Revised 412017 Approved application is a 1nAeof approval. Attachments in Duplicate KRU 2G-06L1 (PTD #218-112) CTD Summary for Sundry (Operations Shutdown) A high expansion wedge, whipstock, was set in KRU well 2G-06 (184-082) at 8134' MD and a window cut in the 7" casing. KRU lateral well 2G-061-1 PB1 (218-112) was drilled to 8330' MD. Multiple attempts to drill the build section of the hole were attempted and multiple fill cleanouts conducted. Drilling conditions included excess cuttings returns, hole problems, and pack offs. Due to poor hole conditions the wellbore was deemed to be a plug back and the decision was made to utilize a backup kick off point. A backup high expansion wedge was set up hole at 8095' MD and a backup window was attempted to be cut in the 7" casing. When tripping in hole with the drilling BHA to make another attempt at drilling KRU 2G-06L1 (218-112) the high expansion wedge was found to have slid downhole. CDR3-AC rigged down and moved off. KRU 2G-06 (184-082) is planned to be returned to production. ConocoPhillips Alaska currently anticipates developing a plan to make another attempt to cut a window and drill the 2G-06L1 (218-112) lateral. A subsequent Application for Sundry Approvals will be submitted once plans are finalized. Page 1 of 1 11/29/2018 Long, William R From: Long, William R Sent: Thursday, November 22, 2018 7:32 AM To: 'Loepp, Victoria T (DOA)' Cc: Herring, Keith E; McLaughlin, Ryan; Ohlinger, James J; Starck, Kai Subject: RE: KRU 2G-06L1(PTD 218-112) CTD Backup Window Unsuccessful; Operations Shutdown Victoria, We do plan to come back to the well and make another attempt to cut a window and drill the L1 lateral. It is currently 5- 6 months out on the rig schedule. We hope the wellbore will produce pre-CTD rates in the meantime and plan to return the well to production. We will submit a 10-403 for Operations Shutdown per your request when the office reopens next week. We will submit a subsequent 10-403 prior to rigging up again in a few months. Happy Thanksgiving. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, November 21, 2018 1:18 PM To: Long, William R <William.R.Long@conocophillips.com> Subject: [EXTERNALIRE: KRU 2G-06L1(PTD 218-112) CTD Backup Window Unsuccessful; Operations Shutdown William, What are the future plans for this well? Will you be returning with a rig within 1 year? Would you attempt to drill 2G- 061-1? Will you produce from 2G-06 in the mean time? I think a 10-403 for an Operations Shutdown would be the correct form to file for this lateral. I know a 10-407 has been submitted. Please resubmit as a 10-403 Operations Shutdown. To resume drilling would require another 10-403 submission. 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 Victoria. Loepp(cDaIaska.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: Long, William R <William.R.Long@conocophillips.com> Sent: Tuesday, October 23, 2018 8:49 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: KRU 2G-06 CTD Backup Window Unsuccessful Victoria, Unfortunately CDR3 was unsuccessful in milling the backup window. Data indicates that the backup high expansion wedge, whipstock, slid downhole. CDR3 plans to rig down and move off this well. We will plan to submit a Sundry Report (10-404) for KRU 2G-06 (184-082) and a Completion Report (10-407) for the L1 (218-112) plug back lateral within 30 days. Included will be an operations summary report and a updated schematic. If further analysis indicates that it will be possible to come back to this well and successfully mill a window, we will submit an Application for Sundry Approvals prior to doing so in the future. Please let me know if you would like any further information, or us to use any different forms to document these operations. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com From: Long, William R Sent: Saturday, October 20, 2018 5:41 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>; Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Subject: KRU 2G-06 CTD Backup Window Victoria, CDR3 is currently rigged up on KRU 2u-06 (184-082) and has been attempting to drill the L1 lateral (218-112). We have made multiple attempts to drill the build section of the hole and conducted multiple fill cleanouts. We continue to experience excess cuttings returns, hole problems, and pack offs. We plan to move up hole approximately 40' and set another high expansion wedge, a type of whipstock, cut a backup window, and make another attempt to drill the L1 lateral. The window exit style, lateral targets, and overall drilling program plan and objectives remain unchanged. Please let us know if any approval or further documentation is required. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com { , Operations Summary (with Timelog Depths) x 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/14/2018 10/14/2018 3.00 MIRU MOVE MOB P Trucks on location, Load shop on 0.0 0.0 06:00 09:00 flatbed, PJSM with Peak for rig move. Move pits & sub off well 31-01, Jeep up, R/D cellar berm and herculite 10/14/2018 10/14/2018 5.00 MIRU MOVE MOB P Move rig 31 to 2G pad 0.0 0.0 09:00 14:00 10/14/2018 10/14/2018 1.00 MIRU MOVE MOB P On 2 G pad, De jeep rig, Rig up 0.0 0.0 14:00 15:00 herculite in cellar, Scaffolding crew here. 10/14/2018 10/14/2018 2.00 MIRU MOVE MOB P Spot sub and pits 0.0 0.0 15:00 17:00 10/14/2018 10/14/2018 1.00 MIRU MOVE MOB P Start pre spud check list, Safe out rig, 0.0 0.0 17:00 18:00 stairs down. Ensure egress routes clear. 10/14/2018 10/14/2018 3.00 MIRU WHDBOP RGRP P Swap out swab #2 on stack, Work rig 0.0 0.0 18:00 21:00 up check lists 10/14/2018 10/14/2018 2.00 MIRU WHDBOP NUND P Nipple up stack, change out riser, 0.0 0.0 21:00 23:00 Obtain RKB's, RIG ACCEPT 21:00 10/14/2018 10/15/2018 1.00 MIRU WHDBOP SVRG P Grease stack, R valves, and drilling 0.0 0.0 23:00 00:00 choke 10/15/2018 10/15/2018 0.50 MIRU WHDBOP SFTY P PJSM to perform full BOPE test, Test 0.0 0.0 00:00 00:30 witness waived by Adam Earl, AOGCC 10/15/2018 10/15/2018 8.00 MIRU WHDBOP BOPE P Start full BOPE test, Test pressure 5K, 0.0 0.0 00:30 08:30 stab INJH, test inner reel iron, inner reel valve, and pac-off. 10/15/2018 10/15/2018 0.50 MIRU WHDBOP CTOP P Valve crew on location load lubricator 0.0 0.0 08:30 09:00 into pipeshed, Unstab INJH, changeout UQV floats. 10/15/2018 10/15/2018 1.50 MIRU WHDBOP PRTS P Perform valve check -list, test PDL's 0.0 0.0 09:00 10:30 and tiger tank line. 10/15/2018 10/15/2018 1.20 MIRU WHDBOP PRTS P PJSM, P/T Lube, pull BPV 0.0 0.0 10:30 11:42 10/15/2018 10/15/2018 0.30 MIRU WHDBOP CTOP P Load out Valve crew eqiupment 0.0 0.0 11:42 12:00 10/15/2018 10/15/2018 0.30 SLOT WELLPR CTOP P Move INJH forward remove UQC, 0.0 0.0 12:00 12:18 boot a -line, stab INJH 10/15/2018 10/15/2018 0.60 SLOT WELLPR CTOP P Line up and pump slack 0.0 0.0 12:18 12:54 manangement. 10/15/2018 10/15/2018 0.30 SLOT WELLPR CTOP P Unstab INJH, rig up hydraulic CT 0.0 0.0 12:54 13:12 cutter 10/15/2018 10/15/2018 3.80 SLOT WELLPR CTOP P PJSM, start trimming coil, found wire, 0.0 0.0 13:12 17:00 continue trimming coil, RD cutter and dress CT for CTC. "' Note: Found wire @ 28' 10/15/2018 10/15/2018 1.50 SLOT WELLPR CTOP P PJSM, install CTC, pull test to 35 k 0.0 0.0 17:00 18:30 10/15/2018 10/15/2018 0.60 SLOT WELLPR CTOP P Re -head BHI upper quick connect, 0.0 0.0 18:30 19:06 test e-line (good -test), install floats 10/15/2018 10/15/2018 0.40 SLOT WELLPR CTOP P PT connections and re -head 4,500 psi 0.0 0.0 19:06 19:30 (good test) 10/15/2018 10/15/2018 1.00 SLOT WELLPR PULD P PJSM, slide cart back, load both 0.0 0.0 19:30 20:30 PDL's 10/15/2018 10/15/2018 1.30 SLOT WELLPR PULD P PD cleanout BHA#1, perform surface 0.0 51.3 20:30 21:48 test (good test) 10/15/2018 10/15/2018 1.90 SLOT WELLPR TRIP P Tag up, reset counters, RIH with 51.3 7,990.0 21:48 23:42 Cleanout BHA, PUW @ 4,0007 24 k 10/15/2018 10/15/2018 0.10 SLOT WELLPR DLOG P Log the K1 marker correction of+2', 7,990.0 8,019.0 23:42 23.48 PUW=38K 10/15/2018 10/16/2018 0.20 SLOT WELLPR PRTS P Start static BHP, TVD 5872, 8,019.0 8,030.0 23:48 00:00 Ann=3778, EMW=12.38 Page 1/10 Report Printed: 11/29/2018 Operations Summary (with Timelog Depths) = 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/16/2018 10/16/2018 0.20 SLOT WELLPR PRTS P Static BHP, TVD 5872, Ann=3778, 8,030.0 8,030.0 00:00 00:12 EMW=12.38 10/16/2018 10/16/2018 0.30 SLOT WELLPR TRIP P Trip in to 8158 dry. PUH to 8000 for 8,030.0 8,000.0 00:12 00:30 CCL pass 10/16/2018 10/16/2018 0.20 SLOT WELLPR DLOG P Log CCL down to 8158, Bit to CCL 8,000.0 8,158.0 00:30 00:42 39.5 10/16/2018 10/16/2018 0.40 SLOT WELLPR CIRC P recip CT waiting on sweeps 8,158.0 8,158.0 00:42 01:06 10/16/2018 10/16/2018 1.60 SLOT WELLPR TRIP P Sweeps out trip out displacing well to 8,158.0 56.8 01:06 02:42 used PwrPro 10/16/2018 10/16/2018 1.10 SLOT WELLPR PULD P At surface, PJSM PUD BHA #1 56.8 0.0 02:42 03:48 10/16/2018 10/16/2018 1.90 PROD1 RPEQPT PULD P Assemble Northern High Expansion 0.0 73.5 03:48 05:42 Wedge whipstock, M/U to Coil track and deploy. M/U to coil and surface test. Check pack offs. 10/16/2018 10/16/2018 1.60 PROD1 RPEQPT TRIP P RIH BHA #2 NS HEW whip stock 73.5 8,020.0 05:42 07:18 10/16/2018 10/16/2018 0.20 PROD1 RPEQPT DLOG P Tie into K1 marker for -1', PUW=37K 8,020.0 8,043.0 07:18 07:30 10/16/2018 10/16/2018 0.10 PROD1 RPEQPT TRIP P Continue in hole to setting depth 8,043.0 8,142.8 07:30 07:36 10/16/2018 10/16/2018 0.10 PROD1 RPEQPT TRIP P 8142, at set depth oriented to HS. 8,142.8 8,142.8 07:36 07:42 Close EDC pull slack from CT. Pumps on .5 BPM see tool shift 4200 PSI Set down lightly on whipstock 10/16/2018 10/16/2018 1.50 PROD1 RPEQPT TRIP P POOH after setting whip stock 8,142.8 61.0 07:42 09:12 10/16/2018 10/16/2018 0.90 PROD1 RPEQPT PULD P Tag up at surface. Space out. PJSM 61.0 0.0 09:12 10:06 PUD BHA#2 10/16/2018 10/16/2018 1.10 PROD1 WHPST PULD P M/U and PD BHA#3 to mill window. 0.0 76.8 10:06 11:12 WFT 1° fixed bend motor, 2.80 window mill, and 2.79 string reamer. M/U to coil and surface test 10/16/2018 10/16/2018 4.20 PROD1 WHPST TRIP P RIH BHA#3 to mill window, close EDC 76.8 8,025.0 11:12 15:24 @ 500' Pumps on @ 1.80 BPM @ 4111 PSI. Take screen shots. Continue in well, Stacked out hard @ 4790'. Nothing in the area. PUH Inspect pipe and injector. Good. Trip in. Stack out. Roll pump @ ,7 BPM and roll TF to HS. Taking weight every -30 feet. Continue in well pumping at reduced speed 10/16/2018 10/16/2018 0.20 PROD1 WHPST DLOG P Log K1 for-3', PUW=34K 8,025.0 8,049.0 15:24 15:36 10/16/2018 10/16/2018 0.50 PROD1 WHPST TRIP P Continue in well, Dry tag pinch point 8,049.0 8,137.0 15:36 16:06 @ 8137.8', PUH 10/16/2018 10/16/2018 2.70 PROD1 WHPST MILL P Bring pumps on 1.8 BPM @ 3803 PSI 8,137.4 8,140.0 16:06 18:48 FS, Start milling @ 8137.4 10/16/2018 10/16/2018 1.50 PROD1 WHPST MILL P Continue milling window per 8,140.0 8,142.0 18:48 20:18 procedure, 1.8 bpm, BHP = 3986 psi, WHP = 394 psi, BOW called at 8140.2' (WOB & dp fall off), string reamer through window 10/16/2018 10/16/2018 3.20 PROD1 WHPST MILL P Begin pushing, milling rat -hole, CWT = 8,142.0 8,163.0 20:18 23:30 11.8K, WOB = 0.7K - 3K, BHP = 3846 psi, WHP = 406 psi, -5.5 bph losses, pump 5 x 5 sweeps 10/16/2018 10/17/2018 0.50 PROD1 WHPST REAM P Begin reaming passes per procedure 8,163.0 8,163.0 23:30 00:00 1 (HS, 30L, & 30R) Page 2110 Report Printed: 11/29/2018 Operations Summary (with Timelog Depths) room'.. 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/17/2018 10/17/2018 0.80 PROD1 WHPST REAM P Complete reaming passes per 8,163.0 8,163.0 00:00 00:48 procedure (HS, 30L & 30R), dry drift window, clean up & down, PUW = 35K 10/17/2018 10/17/2018 2.10 PROD1 WHPST TRIP P POOH, slight overpull at 4781', 8,163.0 76.0 00:48 02:54 slowed , close EDC, PJSM 10/17/2018 10/17/2018 1.10 PROD1 WHPST PULD P PUD BHA#3 (1.8° AKO motor, RB 76.0 0.0 02:54 04:00 Hughes bit), mill & string reamer came out 2.79" no-go 10/17/2018 10/17/2018 1.10 PROD1 DRILL PULD P PD BHA#3 Build/Turn Assembly (1.8° 0.0 72.0 04:00 05:06 AKO motor, RB Hughes bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 10/17/2018 10/17/2018 1.70 PROD1 DRILL TRIP P RIH w/ BHA #4, Set down @ 5077 72.0 8,031.0 05:06 06:48 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P Log K1 for -1.5', PUW=35K 8,031.0 8,031.0 06:48 06:54 10/17/2018 10/17/2018 0.10 PROD1 DRILL TRIP P Continue in well, clean pass through 8,031.0 8,165.0 06:54 07:00 window, Tag up and drill from 8165 10/17/2018 10/17/2018 0.50 PROD1 DRILL DRLG P 8165', Drill 1.77 BPM @ 3790 PSI FS, 8,165.0 8,180.0 07:00 07:30 BHP=3810 10/17/2018 10/17/2018 1.20 PROD1 DRILL DRLG P 8180 stall, Pick up, PUW=40K loosing 8,180.0 8,010.0 07:30 08:42 returns,pulling heavy, DHWOB=-14K, Pull up into casing. Orion shut down. WITTS running very slowly. Restart BHI and orion computers - Gas in returns at surface. Divert to tiger tank. Pump bottoms up. PUH 10/17/2018 10/17/2018 0.40 PROD1 DRILL WPRT P PUH to log K1 for+1', trip in and log 8,010.0 8,029.0 08:42 09:06 RA@ 8141, TOWS=8134, TOW=8137, BOW=8140 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P RBIH to drill, returns fall off - 8178'. 8,029.0 8,181.0 09:06 09:18 Work to bottom 10/17/2018 10/17/2018 0.20 PROD1 DRILL DRLG P 8181', Drill 1.78 BPM @ 4010 PSI FS, 8,181.0 8,195.0 09:18 09:30 BHP=4130, RIW=12.8K 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P 8195 Pick up stacking, Overpulling, 8,195.0 8,175.0 09:30 09:42 DHWOB=-10K, Initial PUW=55K with - 20K DHWOB 10/17/2018 10/17/2018 1.70 PROD1 DRILL WPRT T 8175 Stuck, work pipe, Try to orient 8,175.0 8,175.0 09:42 11:24 looks bit stuck. Diminshed / no returns. Reduce well head. Shut down pump to relax. Circulate 8 BBIs LVT down CT. Spot 2 BBIs out, let soak. Work pipe. Spot 3 more bbls out. Let soak. Work pipe and pop free 10/17/2018 10/17/2018 0.10 PROD1 DRILL WPRT P Continue wiper to cased hole 8,175.0 8,122.0 11:24 11:30 10/17/2018 10/17/2018 1.80 PROD1 DRILL CIRC P Pump 10 X 10 sweeps and circulate 8,122.0 8,013.0 11:30 13:18 bottoms up. Little material coming overshaker 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P 8013 tie into K1 for 1.5' correction 8,013.0 8,030.0 13:18 13:24 10/17/2018 10/17/2018 0.50 PROD1 DRILL WPRT P RBIH, stop @ 8127 and perfor static 8,030.0 8,127.0 13:24 13.54 pressure test, TVD 5931.4, Annular pressure 3935, EMW=12.7. Holding 12.8 PPG at window 10/17/2018 10/17/2018 0.10 PROD1 DRILL WPRT P RBIH to drill, stack and loose returns 8,127.0 8,195.0 13:54 14:00 @ 8178 work through 10/17/2018 10/17/2018 0.30 PROD1 DRILL DRLG P 8195', Drill, 1.77 BPM @ 3860 PSI 8,195.0 8,205.0 14:00 14:18 FS, BHP=3850 10/17/2018 10/17/2018 0.90 PROD1 DRILL WPRT P 8205, PUH into casing. Pressures all 8,205.0 8,111.0 14:18 15:12 over. Circ bootoms up. Sample to geo. Calls it B shale. Blow down micro motion Page 3/10 Report Printed: 11/2912018 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P RBIH to drill 8,111.0 8,207.0 15:12 15:24 10/17/2018 10/17/2018 0.70 PROD1 DRILL DRLG P 8207', Drill, 1.76 BPM @ 3860 PSI 8,207.0 8,210.0 15:24 16:06 FS, BHP=4250, frequent pick ups. On pick up from 8210 became stuck @ 8190. Work pipe up to 50K, DHWOB=- 16K. Down to zero. DHWOB=6K 10/17/2018 10/17/2018 0.60 PROD1 DRILL DRLG T Pipe stuck, Pump 8 BBIs LVT down 8,210.0 8,210.0 16:06 16:42 CT 10/17/2018 10/17/2018 1.60 PROD1 DRILL WPRT P Get two bbls out CT let soak. Work 8,210.0 8,075.0 16:42 18:18 pipe. Pump 3 more bbls out let soak. Pull free. Trip to cased hole. Pump 10 X 10 sweeps, circulate multiple bottoms up, pump additioal sweep 10/17/2018 10/17/2018 1.80 PROD1 DRILL TRIP T Decision mae to POOH for cleanout 8,075.0 72.0 18:18 20:06 assembly, silt/shale over shakers, not sticky, low clay content, fairly benign 10/17/2018 10/17/2018 0.80 PROD1 DRILL PULD T PJSM, PUD BHA #4 72.0 0.0 20:06 20:54 10/17/2018 10/17/2018 1.90 PROD1 DRILL PULD T PJSM, make up new tools, PD BHA 0.0 63.0 20:54 22:48 #5 (1.0° AKO motor, string reamer, D331 w/ridge-set, no Res tool), slide in cart, check pack -offs, MU to coil, tag up, set counters, blow down choke & micro -motion 10/17/2018 10/18/2018 1.20 PROD1 DRILL TRIP T RIH wl BHA#5 63.0 5,500.0 22:48 00:00 10/18/2018 10/18/2018 0.50 PROD1 DRILL TRIP T RIH w/ BHA #5 5,500.0 8,005.0 00:00 00:30 10/18/2018 10/18/2018 0.10 PROD1 DRILL DLOG T Log K1 for-1' correction 8,005.0 8,037.0 00:30 00:36 10/18/2018 10/18/2018 0.50 PROD1 DRILL DLOG T Continue RIH to 8100, close EDC, 8,037.0 8,137.0 00:36 01:06 PUW = 35K Stop, obtain SBHP (15 min): MD = 8120.6', TVD_senor = 5932.9', BHP = 4050 psi, WHP = 1367 psi, EMW = 13.13 ppg, pressure climbed during test 10/18/2018 10/18/2018 2.30 PROD1 DRILL REAM T Work to end of rat -hole in 10' bites, 8,137.0 8,137.0 01:06 03:24 PUW's = 35K, FS = 394 psi @ 1.8 bpm, BHP = 4071 psi Perfrom reaming passes of window & rat -hole (8137' to 8166'): HS down - hole. 30L, 30R, HS, & 2 passes LS all up -hole (1 fpm through window, 5 fpm in rat -hole), pump multiple sweeps 10/18/2018 10/18/2018 1.90 PROD1 DRILL TRIP T POOH, open EDC, pre -loaded IDS 8,137.0 59.0 03:24 05:18 PDL 10/18/2018 10/18/2018 1.00 PROD1 DRILL PULD T At surface, Tag up and space out. 59.0 0.0 05:18 06:18 PUD BHA#5 10/18/2018 10/18/2018 0.40 PROD1 DRILL PULD T Reconfigure pre loaded tool to remove 0.0 0.0 06:18 06:42 UltraSlim Resistivity tool from BHA 10/18/2018 10/18/2018 1.10 PROD1 DRILL PULD T Pressure deploy BHA#6 with 1.8° 0.0 62.6 06:42 07:48 AKO motor, RR HCC bi center. No agitator or USR. Make up to coil and surface test. Check pack offs 10/18/2018 10/18/2018 1.70 PROD1 DRILL TRIP T Trip in hole, BHA#6, Test HOT on 62.6 8,010.0 07:48 09:30 stop 10/18/2018 10/18/2018 0.10 PROD1 DRILL DLOG T Log K1 for -1/2', Close EDC, 8,010.0 8,030.0 09:30 09:36 PUW=34K Page 4/10 Report Printed: 11/29/2018 k i Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (WB) End Depth (ftKB) 10/18/2018 10/18/2018 0.40 PROD1 DRILL TRIP T Trip in well, initial tag up @ 8176 work 8,030.0 8,210.0 09:36 10:00 down to next tag up @ 8195. Work down to 8209. recip up to 8160. Clear on way up. No overpulls on DHWOB. RBIH stack at 8179. work pipe down to 8210 10/18/2018 10/18/2018 0.40 PROD1 DRILL DRLG 8210', Drill, 1.79 BPM @ 3850 PSI 8,210.0 8,216.0 10:00 10:24 FS, BHP=4075, Hard to maintain differential pressure. Able to get all DHWOB. Tool is hanging up above bit. Multiple pick ups to get back to bottom with Diff pressure 10/18/2018 10/18/2018 0.60 PROD1 DRILL WPRT 8216, stacking out. PUH, PUW=50K. 8,216.0 8,216.0 10:24 11:00 Stuck @ 8190. Work pipe within limits of HOT. Seeing negative weight. Unable to orient. Work free. PUH to 8150. RIH to drill. Have to work 8178 down 10/18/2018 10/18/2018 1.40 PROD1 DRILL DRLG 8216', Drill, 1.8 BPM 3995 PSI FS. 8,216.0 8,236.0 11:00 12:24 Returns coming and going. Start get gas in returns. Ship returns to tiger tank, Frequent pickups to get differential pressure. Unable to maintain steady state drilling 10/18/2018 10/18/2018 0.20 PROD1 DRILL WPRT One of many pickups over pull and 8,236.0 8,236.0 12:24 12:36 stuck, Not showing any WOB. Able to orient freely. Work pipe. Little returns. Not showing any pull on HOT. Work free @ 70K 10/18/2018 10/18/2018 1.40 PROD1 DRILL WPRT T After pulled free BHA shorted out. 8,236.0 8,075.0 12:36 14:00 PUH to cased hole. Pump 10 X 10 sweeps. Circulate gas out of well Trouble shoot surface electrical componets. Shorted down hole 10/18/2018 10/18/2018 2.30 PROD1 DRILL TRIP T Trip out maintain 1 to 1. At 500' well 8,075.0 63.0 14:00 16:18 unloaded heavy shales. Jog back in hole. Pull to surface, Tag up and space out. Swap chokes and lost all WHP. Open up tangos. MP line showed zero. Open up whitey valve on riser. No pressure 10/18/2018 10/18/2018 1.00 PROD1 DRILL TRIP T Trip in hole to find pack off / bridge 63.0 63.0 16:18 17:18 holding 1100 PSI WHP. RIH to 750'.Saw nothing. Blleed off WHP to 650 PSI. Bridge must be down much lower. POOH 10/18/2018 10/18/2018 1.30 PROD1 DRILL PULD T PUD BHA#6, DBV bent (pictures on 63.0 0.0 17:18 18:36 S: drive), bit came out a 1-3 (7 broken reamer cutters & 1 plugged nozzle) 10/18/2018 10/18/2018 1.00 PROD1 DRILL PULD T Decision made to PU build assembly, 0.0 63.0 18:36 19:36 PD BHA #7 Build Assembly #3 (1.8° AKO motor, RR Dynamus bit, no RES tool), slide in cart, check pack -offs, MU to coil, tag up, set coutners 10/18/2018 10/18/2018 2.00 PROD1 DRILL TRIP T RIH w/ BHA#7, EDC closed, RIH 63.0 8,005.0 19:36 21:36 pumping anticipating bridge -off at unknown depth 10/18/2018 10/18/2018 0.20 PROD1 DRILL DLOG T Log K1 for -0.5' correction, PUW = 8,005.0 8,030.0 21:36 21:48 34K 10/18/2018 10/18/2018 0.50 PROD1 DRILL TRIP T Continue RIH, clean down to 8120', 8,030.0 8,100.0 21:48 22:18 pump 5x5 sweeps 10/18/2018 10/18/2018 0.40 PROD1 DRILL TRIP P Begin working through window, stack 8,100.0 8,133.0 22:18 22:42 8K WOB at 8133' (believe found bridge -off at window stopping flow to surface), allow sweeps to exit bit Page 5110 Report Printed: 11/29/2018 Operations Summary (with Timelog Depths) r ? f 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/18/2018 10/19/2018 1.30 PROD1 DRILL TRIP T EDC open, POOH for FCO assembly 8,133.0 600.0 22:42 00:00 10/19/2018 10/19/2018 0.50 PROD1 DRILL TRIP T EDC open, POOH for FCO assembly, 600.0 63.0 00:00 00:30 tag up, PJSM 10/19/2018 10/19/2018 0.80 PROD1 DRILL PULD T PUD BHA#7, bit came out balled up 63.0 0.0 00:30 01:18 with clay from setdown at TOWS, 2 plugged nozzles 10/19/2018 10/19/2018 1.20 PROD1 DRILL PULD T PD BHA#8 FCO Assembly (1.0°AKO 0.0 63.0 01:18 02:30 motor, D331 w/ ridge -set), slide in cart, check pack -offs, MU to coil, tag up, set counters 10/19/2018 10/19/2018 1.80 PROD1 DRILL TRIP T RIH w/ BHA#8, corrupt data on Baker 63.0 8,005.0 02:30 04:18 screen, trouble -shoot & resolve issue 10/19/2018 10/19/2018 0.10 PROD1 DRILL DLOG T Log K1 for+4.5' correction, close EDC 8,005.0 8,027.0 04:18 04:24 10/19/2018 10/19/2018 0.20 PROD1 DRILL TRIP T RIH to TOWS, PUW = 35K 8,027.0 8,130.0 04:24 04:36 10/19/2018 10/19/2018 0.70 PROD1 DRILL TRIP T FCO from TOWS, 1.8 bpm, FS = 360 8,130.0 8,163.0 04:36 05:18 psi, circ = 3792, BHP = 4080 psi, WHP = 780 psi, 390 lb motorwork beginning at 8146', PUW = 37K from 8147', pull up through window. Continue in -hole to end of rat -hole (8163'), PUH to BOW, PUW = 37K 10/19/2018 10/19/2018 1.00 PROD1 DRILL TRIP T Continue FCO, 1.77 BPM. Set down 8,163.0 8,150.0 05:18 06:18 @ 8186, Pull heavy 52K, -6K DHWOB. PUH pack off RBIH to 8173. PUH to window. 10/19/2018 10/19/2018 0.10 PROD1 DRILL DLOG T Log RA for+1' correction 8,150.0 8,173.0 06:18 06:24 10/19/2018 10/19/2018 2.80 PROD1 DRILL WPRT T RBIH, stckout @ 8175 recip up hole to 8,173.0 7,960.0 06:24 09:12 8098. RBIH to 8216. Packoff with overpull, 70K. PUH to 8150. RBIH to bottom @ 8234, Pumping multiple sweeps. Getting medium amount of shales on shaker. Pull up through window at full rate. PUH through 7" to 7960, 10/19/2018 10/19/2018 0.20 PROD1 DRILL WPRT T RBIH, clean pass through window 7,960.0 8,139.0 09:12 09:24 stack at 8175. PUH stuck at window 8139. 10/19/2018 10/19/2018 1.10 PROD1 DRILL WPRT T Work pipe out of window, PUH to 8,139.0 7,960.0 09:24 10:30 8070. RBIH clean through window. Stack out at 8175. Pick up sticky 65K with -17K DHWOB. PUH to TT at full rate with more sweeps 10/19/2018 10/19/2018 2.00 PROD1 DRILL WPRT T 7960 RBIH clean through window. run 7,960.0 8,063.0 10:30 12:30 past 8275 @ 4 FPM with 90% returns. Full returns back @ 8285. Continue to bottom @ 8126. Recipt twice to 8143. Pumping sweeps. Maintaining full returns. Hole looks clean. Not stacking or over pulls. Pump 10 X 10 sweeps 10/19/2018 10/19/2018 1.80 PROD1 DRILL WPRT T Sweeps out, Chase to swab. Jog @ 8,063.0 60.0 12:30 14:18 729' Hole unloading. Same shales as yesterday 10/19/2018 10/19/2018 1.50 PROD1 DRILL WPRT T Tag up at surface, Set counters, RBIH 60.0 8,010.0 14:18 15:48 10/19/2018 10/19/2018 0.10 PROD1 DRILL DLOG T Log K1 for+1', PUW=32K 8,010.0 8,030.0 15:48 15:54 10/19/2018 10/19/2018 0.10 PROD1 DRILL WPRT T Continue in well. Clean through 8,030.0 8,234.0 15:54 16:00 window and past 8175 to 8185 area with returns Page 6/10 Report Printed: 11/29/2018 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/19/2018 10/19/2018 0.40 PROD1 DRILL WPRT T PUH to 7". Clean trip through build 8,234.0 8,130.0 16:00 16:24 with no overpulls no packoff events. Start sweeps down CT 10/19/2018 10/19/2018 0.10 PROD1 DRILL WPRT T Sweeps close to bit. RBIH to 8200. 8,130.0 8,200.0 16:24 16:30 Clean trip to 8200 10/19/2018 10/19/2018 1.70 PROM DRILL WPRT T Sweeps at bit, POOH pumping 1.8 8,200.0 63.0 16:30 18:12 BPM, PUW=33K, open EDC, PJSM 10/19/2018 10/19/2018 0.90 PROM DRILL PULD T PUD BHA#8, mill came out 2.80" no- 63.0 0.0 18:12 19:06 go 10/19/2018 10/19/2018 1.00 PROM DRILL PULD T PD BHA #9 (Build Assembly, 1.8° AKO 0.0 63.0 19:06 20:06 motor, RR P104 bit, & no res tool), slide in cart MU to coil, change out pack -offs, tag up, set counters 10/19/2018 10/19/2018 1.60 PROD1 DRILL TRIP T RIH w/ BHA#9, lost COMMS to BHA 63.0 7,975.0 20:06 21:42 at 4146', stop trouble -shoot, resolved 10/19/2018 10/19/2018 0.60 PROM DRILL DLOG T Did not see K1 on first pass, PUH to 7,975.0 8,025.0 21:42 22:18 7975 to re -log, +34.5' correction 10/19/2018 10/19/2018 0.40 PROM DRILL TRIP T Continue RIH, PUW = 38K, log RA for 8,025.0 8,236.0 22:18 22:42 +1' correction, bring up rate 10/19/2018 10/19/2018 0.80 PROM DRILL DRLG P OBD, 1.88 bpm, FS = 525 psi, circ = 8,236.0 8,330.0 22:42 23:30 4313 psi, CWT = 13K, WOB = 1.8K, BHP = 4120 psi, WHP = 710 psi, pump sweeps, Begin packing off at 8330', losing returns 10/19/2018 10/20/2018 0.50 PROM DRILL WPRT P Wiper, PUW = 45K, continue to pull 8,330.0 8,050.0 23:30 00:00 heavy, working up & down to release pack -off, pulling up to 68K, density out drops, clear packoff, pull up through window, begin taking returns to TT, begin circulating bottoms up 10/20/2018 10/20/2018 0.50 PROD1 DRILL WPRT P Continue circulating bottoms up in 7" 8,050.0 8,050.0 00:00 00:30 casing, sweeps coming to surface, density out climbs to 8.94 ppg, bring returns back inside after 42 bbls Sample to geo: —50% cavings, remaining 50% mixutre of cuttings (shale & sand) 10/20/2018 10/20/2018 0.40 PROM DRILL WPRT P RBIH, stack weight at 8164', PUW = 8,050.0 8,175.0 00:30 00:54 38K, stack again at 8169', again at 8170', begin packing off, begin losing returns, pull -1 OK WOB, wiper to bottom of window, turn around 10/20/2018 10/20/2018 0.90 PROM DRILL WPRT P RBIH at 7 fpm, taking bites & PUH, 8,175.0 7,835.0 00:54 01:48 begin packing off at 8205', erratic returns, reciprcate pipe to clear pack - off, PUW = 45K, pulling heavy up to 66K Pull up to tubing tail & circulate, 8.9 ppg slug over shakers, rate out drops while in 7", circulate bottoms up, pull 500' into tubing tail 10/20/2018 10/20/2018 1.40 PROM DRILL WPRT T Circulating, pins/ retaining -stops on 6 7,835.0 7,835.0 01:48 03:12 gripper block plates sheared pff, elastomers worn, circulate awaiting mechanic, 10/20/2018 10/20/2018 4.70 PROD1 DRILL TRIP T POOH @ 50 fpm, EDC open 7,835.0 63.0 03:12 07:54 Decision made to POOH, replace failed gripper block plates & elastomers on Nabors rig repair time Page 7110 Report Printed: 11/29/2018 operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/20/2018 10/20/2018 1.60 PROD1 DRILL PULD T PJSM, PUD BHA #9, Lay down BHA 63.0 0.0 07:54 09:30 10/20/2018 10/20/2018 3.00 PROD1 DRILL RGRP T Continue with repairs to chains, 0.0 0.0 09:30 12:30 Change out all elastomers Confer with town asset, drilling, & rig. Decision made to cleanout down to 7" & set backup ** 8 hrs agreed upon for Nabors rig repair time (SIMOPS w/ replanning of second WS) 10/20/2018 10/20/2018 1.20 PROD1 DRILL PULD T Repairs complete, Start making up 0.0 0.0 12:30 13:42 build section BHA. Plan change going to run whipstock 10/20/2018 10/20/2018 0.90 PROD1 DRILL PULD T M/U BHA#10. FCO BHA with 1° motor 0.0 62.3 13:42 14:36 and D-331. Pressure deploy. Make up to coil and surface test 10/20/2018 10/20/2018 1.80 PROD1 DRILL TRIP T Trip in hole to clean 7" casing for 62.3 7,995.0 14:36 16:24 whipstock set 10/20/2018 10/20/2018 0.10 PROD1 DRILL DLOG T 7995', Log K1 for- 1/2', PUW=39K, 7,995.0 8,031.0 16:24 16:30 Pumping sweeps 10/20/2018 10/20/2018 1.80 PROD1 DRILL CIRC T PUH circulating sweeps DH 8,031.0 8,128.0 16:30 18:18 10/20/2018 10/20/2018 1.60 PROD1 DRILL TRIP T POOH, open EDC 8,128.0 62.0 18:18 19.54 10/20/2018 10/20/2018 1.00 PROD1 DRILL PULD T PUD BHA#10 62.0 0.0 19:54 20:54 10/20/2018 10/20/2018 1.90 PROD1 RPEQPT PULD T MU & PU HEW, PD BHA#11 (HEW 0.0 74.0 20:54 22:48 Whipstock #2), slide in cart, MU to coil, tag up, set counters 10/20/2018 10/21/2018 1.20 PROD1 RPEQPT TRIP T RIH w/ BHA #11 74.0 5,400.0 22:48 00:00 10/21/2018 10/21/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH w/ BHA#11, EDC open 5,400.0 8,015.0 00:00 00:24 10/21/2018 10/21/2018 0.10 PROD1 RPEQPT DLOG T Log K1 for -1' correction 8,015.0 8,043.0 00:24 00:30 10/21/2018 10/21/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH, arrive at setting depth 8,043.0 8,103.8 00:30 00:54 (8103.78'), PUW = 38K, RBIH, close EDC, bring up pump, shear off @ 5100 psi, set down 2K on WS, PUW = 37K, TOWS-8095', oriented HS 10/21/2018 10/21/2018 1.40 PROD1 RPEQPT TRIP T POOH, EDC open, PJSM 8,103.8 65.0 00:54 02:18 10/21/2018 10/21/2018 1.10 PROD1 RPEQPT PULD T PUD BHA#11 65.0 0.0 02:18 03:24 10/21/2018 10/21/2018 1.50 PROD1 WHPST PULD T PD BHA#12 Window Assembly (1.0° 0.0 77.0 03:24 04:54 AKO motor, string reamer, window mill), slide in cart, check pack -offs, clean up metal built around brass & pressure wash, MU to coil, tag up, set counters 10/21/2018 10/21/2018 1.80 PROD1 WHPST TRIP T RIH w/ BHA#12, Tagged up on collar 77.0 8,025.0 04:54 06:42 @ 4965', Work through, Coninue in 10/21/2018 10/21/2018 0.20 PROD1 WHPST DLOG T Log K1 for -1.5'corretion, PUW=36K, 8,025.0 8,046.0 06:42 06:54 close EDC 10/21/2018 10/21/2018 0.10 PROD1 WHPST TRIP T Continue in well, Dry tag pinch point 8,046.0 8,099.0 06:54 07:00 @ 8099, PUH 10/21/2018 10/21/27 2.60 PROD1 WHPST MILL T Pumps on 1.8 BPM @ 4530 PSI FS, 8,099.0 8,100.4 07:00 09:36 BHP=4095. Call pinch point 8097.5. Start milling window per procedure Page 8/10 Report Printed: 11/29/2018 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/21/2018 10/21/2018 2.40 PROD1 WHPST MILL T Call BOW 8100.4 Time Milling 8,100.4 8,100.3 09:36 12:00 formation 10/21/2018 10/21/2018 1.50 PROD1 WHPST MILL T Milling rathole, Stall @ 8103.19 8,100.3 8,103.3 12:00 13:30 Restart and stall here again 10/21/2018 10/21/2018 4.40 PROD1 WHPST MILL T Continue milling rathole, 1.81 BPM @ 8,103.3 8,122.0 13:30 17:54 4620 PSI FS, BHP=4050 10/21/2018 10/21/2018 2.10 PROD1 WHPST REAM T Perform reaming passes 1 fpm 8,122.0 8,122.0 17:54 20:00 through window, 5fpm in rat -hole (HS, 30L, 30R, LS), dry drift up & down, clean 10/21/2018 10/21/2018 1.70 PROD1 WHPST TRIP T POOH, EDC open, lost WITS data, 8,122.0 77.0 20:00 21:42 trouble -shoot, reboot Canrig server, up & running. 10/21/2018 10/21/2018 1.20 PROD1 WHPST PULD T PUD & LID BHA#12, mill came out 77.0 0.0 21:42 22:54 2.79" no-go, string reamer came out 2.80" no-go 10/21/2018 10/22/2018 1.10 PROD1 DRILL CTOP T Clear floor, MU nozzle, stab on & jet 0.0 0.0 22:54 00:00 stacK Sunday Safety Meeting in dog -house (SIMOPS) 10/22/2018 10/22/2018 0.50 PROD1 DRILL CTOP T Break off nozzle, clear floor, break 0.0 0.0 00:00 00:30 down & snake MM 10/22/2018 10/22/2018 1.30 PROD1 DRILL PULD T PJSM, PD BHA#13 Build Assembly 0.0 62.0 00:30 01:48 (2.4° AKO motor, RR Hughes bit), MU to coil, check pack -offs, tag up, set counters 10/22/2018 10/22/2018 1.60 PROD1 DRILL TRIP T RIH w/ BHA #13 62.0 8,010.0 01:48 03:24 10/22/2018 10/22/2018 0.20 PROD1 DRILL DLOG T Log K1 for -1' correction, close EDC, 8,010.0 8,030.0 03:24 03:36 PUW = 38K 10/22/2018 10/22/2018 0.40 PROD1 DRILL TRIP T Continue RIH, did not find bottom at 8,030.0 8,136.0 03:36 04:00 8122', found it at 8136', stalled, PUW = 38K 10/22/2018 10/22/2018 0.80 PROD1 DRILL TRIP T PUH to log RA, did not see it & tag at 8,136.0 8,136.0 04:00 04:48 8134', PUW = 38, RIH to find bottom, stall 10/22/2018 10/22/2018 0.30 PROD1 DRILL TRIP T PUH to log K1 & find RA. Log K1 for 0' 8,136.0 8,136.0 04:48 05:06 correction, do not see RA tag, PUW = 38K, PUH 10/22/2018 10/22/2018 0.20 PROD1 DRILL TRIP T Confer with town, attempt to find RA 8,136.0 8,136.0 05:06 05:18 an additional time, 10/22/2018 10/22/2018 1.60 PROD1 DRILL TRIP T No sign of RA marker, POOH. Open 8,136.0 65.0 05:18 06:54 EDC @ 8024 10/22/2018 10/22/2018 1.20 PROD1 DRILL PULD T Tag up / space out, PJSM. PUD BHA 65.0 0.0 06:54 08:06 #13 10/22/2018 10/22/2018 0.30 PROD1 DRILL BOPE P Perform Bi Weeekly BOPE function 0.0 0.0 08:06 08:24 test 10/22/2018 10/22/2018 3.10 PROD1 DRILL WAIT T Stand by for Caliper, Inspect CT .195 0.0 0.0 08:24 11:30 min wall thickness found. Pull all gripper blocks and check elastomers - AII good 10/22/2018 10/22/2018 1.00 PROD1 DRILL PULD T HES on location, M/U caliper and put 0.0 25.7 11:30 12:30 in well. Rig up HES computer 10/22/2018 10/22/2018 2.10 PROD1 DRILL TRIP T Trip in with BHA #14 HES caliper 25.7 8,029.0 12:30 14:36 10/22/2018 10/22/2018 0.10 PROD1 DRILL DLOG T Log K1 for+20, Continue in 8,029.0 8,050.0 14:36 14:42 10/22/2018 10/22/2018 0.10 PROD1 DRILL TRIP T Continue in well 8,050.0 8,126.0 14:42 14:48 10/22/2018 10/22/2018 0.30 PROD1 DRILL DLOG T 8126. run 2 logging passes up to 8,126.0 8,000.0 14:48 15:06 8000' Page 9/10 Report Printed: 11/29/2018 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/22/2018 10/22/2618 1.30 PROM DRILL TRIP T POOH with HES caliperr 8,000.0 25.0 15:06 16:24 10/22/2018 10/22/2018 1.50 PROD1 DRILL PULD T At surface, Lay down BHA#14 HES 25.0 0.0 16:24 17:54 caliper 10/22/2018 10/22/2018 0.20 PROM DRILL SFTY P Crew change, PJSM o service rig 0.0 0.0 17:54 18:06 valves 10/22/2018 10/22/2018 0.90 PROM DRILL SVRG P Service rig valves 0.0 0.0 18:06 19:00 10/22/2018 10/22/2018 0.60 PROD1 DRILL PULD P PJSM, M/U nozzle and stinger. Put in 0.0 16.8 19:00 19:36 well and hook up coil. M/U injector to well. Tag up 10/22/2018 10/22/2018 1.90 DEMOB WHDBOP DISP P Trip in hole. Seawater here load into 16.8 8,050.0 19:36 21:30 suction pit. Start pumping sewater time to get to nozzle @ 8050 10/22/2018 10/22/2018 1.60 PROD1 WHDBOP FRZP P !0 BBIs seawater out of CT. Trip out. 8,050.0 17.0 21:30 23:06 Freeze protect from 2500' with diesel 10/22/2018 10/23/2018 0.90 PROD1 WHDBOP PULD P At surface, Tag up and shut swabs. 17.0 0.0 23:06 00:00 Lay down BHA#15 '* 1400 psi WHP 10/23/2018 10/23/2018 1.00 DEMOB WHDBOP CTOP P Complete jetting stack & surface lines 0.0 0.0 00:00 01:00 10/23/2018 10/23/2018 2.30 DEMOB WHDBOP CTOP P Await valve crew, crews prepping to 0.0 0.0 01:00 03:18 move rig, boro-scope stack 10/23/2018 10/23/2018 1.00 DEMOB WHDBOP RURD P Set BPV 0.0 0.0 03:18 04:18 10/23/2018 10/23/2018 2.70 DEMOB WHDBOP RURD P Clear floor, prep for move, await plan 0.0 0.0 04:18 07:00 forward 10/23/2018 10/23/2018 2.50 DEMOB WHDBOP RURD P Freeze protect tree, work RD 0.0 0.0 07:00 09:30 checklist, ND BOPE `* Rig Released: 10/23/18 @ 9:30 AM Page 10/10 ReportPrinted: 11/29/2018 0 N t9 Q Q � C_ NLO M U U r— 0p O N O Q oq p d N to O Q v @ Zo co to O p 2 VM 0 a .M. � �c` V CO 72 00 a) CArnrn @ Ci v a c @ � p r @ Ud a .2- o oo uJ OP � -0 � bo a`� m cmo � W N k N J N N N (O @ @ N (V r cr Y Y Cl) Cl) Cl) I- @ @ CO Co co M @ O) a op p C Q cu M X r O0 W(M�) C tb a1 O) aF- cu (6 O @ C en @ @ a_V LL J m Q � c oOMU _a M _ -1 00 O o @ a Q VVVVVV VVVVVV @ a o� -C (A 0 0- p LO `;gyp p V) cu @v `C 00 N Mtn a)L' M a- - M Y C m @ O r N O N N V' - OD L to *k M W .0 0 @ a� 0 C i Q. 00 ti� �p Cl) 2� 3 E No ,n0 O O JU Qq0 �N Q0o (p r tT CD CO �, Loepp, Victoria T (DOA) From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Thursday, November 29, 2018 2:13 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2G-06L1(PTD 218-112) CTD Backup Window Unsuccessful; Operations Shutdown Follow Up Flag: Follow up Flag Status: Flagged Thanks, I got your message. William will submit a 10-403 shortly. From: Ohlinger, James J Sent: Thursday, November 29, 201812:17 PM To: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) <victoria.loepp@alaska.gov> Subject: FW: KRU 2G-06L1(PTD 218-112) CTD Backup Window Unsuccessful; Operations Shutdown We're planning to put a rock screen back in the tubing tail, and bring the well back on line to produce. Does the 10-403 Operations Shutdown affect that operation? Physically we're not shutting down operations, we're planning to set another whipstock and pump cement (service coil and eline work) to prepare the well again for a CTD sidetrack. We should be submitting a sundry for the 3rd whipstock and cementing the mother -bore the first part of the new year; i.e. Q1—'19. From: Long, William R Sent: Thursday, November 22, 2018 7:32 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Rvan.McLaughlin@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com> Subject: RE: KRU 2G-06L1(PTD 218-112) CTD Backup Window Unsuccessful; Operations Shutdown Victoria, We do plan to come back to the well and make another attempt to cut a window and drill the L1 lateral. It is currently 5- 6 months out on the rig schedule. We hope the wellbore will produce pre-CTD rates in the meantime and plan to return the well to production. We will submit a 10-403 for Operations Shutdown per your request when the office reopens next week. We will submit a subsequent 10-403 prior to rigging up again in a few months. Happy Thanksgiving. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, November 21, 2018 1:18 PM To: Long, William R <William.R.Long@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2G-06L1(PTD 218-112) CTD Backup Window Unsuccessful; Operations Shutdown William, What are the future plans for this well? Will you be returning with a rig within 1 year? Would you attempt to drill 2G- 06L1? Will you produce from 2G-06 in the mean time? I think a 10-403 for an Operations Shutdown would be the correct form to file for this lateral. I know a 10-407 has been submitted. Please resubmit as a 10-403 Operations Shutdown. To resume drilling would require another 10-403 submission. 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 Victoria. Loepp@alaska.gov CONFIDENTIAL17Y 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.aov From:_Long, William R <William.R.Long@conocophillips.com> Sent: Tuesday, October 23, 2018 8:49 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Starck, Kai <Kai.Starck@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: KRU 213-06 CTD Backup Window Unsuccessful Victoria, Unfortunately CDR3 was unsuccessful in milling the backup window. Data indicates that the backup high expansion wedge, whipstock, slid downhole. CDR3 plans to rig down and move off this well. We will plan to submit a Sundry Report (10-404) for KRU 2G-06 (184-082) and a Completion Report (10-407) for the L1 (218-112) plug back lateral within 30 days. Included will be an operations summary report and a updated schematic. If further analysis indicates that it will L, possible to come back to this well and successfully mill a window, we will submit an Application for Sundry Approvals prior to doing so in the future. Please let me know if you would like any further information, or us to use any different forms to document these operations. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Long@ConocoPhillips.com From: Long, William R Sent: Saturday, October 20, 2018 5:41 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Ohlinger, James 1 <James.J.Ohlinger@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com>; Herring, Keith E <Keith.E.Herring@conocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin @conocophillips.com>; Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Subject: KRU 2G-06 CTD Backup Window Victoria, CDR3 is currently rigged up on KRU 2G-06 (184-082) and has been attempting to drill the L1 lateral (218-112). We have made multiple attempts to drill the build section of the hole and conducted multiple fill cleanouts. We continue to experience excess cuttings returns, hole problems, and pack offs. We plan to move up hole approximately 40' and set another high expansion wedge, a type of whipstock, cut a backup window, and make another attempt to drill the L1 lateral. The window exit style, lateral targets, and overall drilling program plan and objectives remain unchanged. Please let us know if any approval or further documentation is required. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) 281-723-6000 (cell) William.R.Lone@ConocoPhillips.com BA UGHES ER I WOWPRINTDISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2G-06L1PB1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP 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. Attn: 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 21 81 12 30014 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 20, 2018 TODAYS DATE November 14, 2018 Revision No Details: Rev. Requested by: FIELD / FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES 1# OF COPIES 4 4 4 4 4 IG 0 0 0 0 0 0 0 0 0 lot 5 DNR - Division fOil & Gas *** 0 0 0 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6, BP Exploration (Alaska) Inc. 0 0 0 0 Petrotechnical Data Center, IIt2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 II81 12 29993 FEE, IP-- 2 BAKER HUGNES To Date: November 12, 2018 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Letter of Transmittal Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2G-06L1PB1 F R CFi �olli3 I/FO 01 -9pGCce (6) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. 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'c � a n > a t N a a �^ O Y Y J J Yi U C Q (O Q O O O (O O O 7 7 N N N U Y Y n` O � c m O a d v o°° d sz d m 3 (.) a 0, o rn w E E E Q Q Q c a o a o m v m m m m m o 0 0 0 a a a a Q p .Y c c c O h M (r0. N V O � g p "m rn rn rn rn rn rn rn Z rp 0 m u! V ri c� ri ci M ci M ci n M O M (Op I� r M M M M M V ' Z= co co co m M M M M + (p r v rn rn (o M N (O N q (O W � ^ m m m m m m m m FS 3 vS �ri �ri �n vS ui (n uS M (p N rN O q M AM O N O M N M m rn rn o 0 0 0 ([d .�_... N N 0 (O (O tp tp tp D o ti pry m tn n a v v v v (o v v v v M � M ONJ N V (gyp tp Cl � :.. ro M v vj tt0o td tr6 0 0 (n v v °0 o 00 m N N N M N R co 0 N C THE STATE 'ALASKA GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-06L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-112 Surface Location: 547' FSL, 236' FWL, SEC. 32, T11N, R9E, UM Bottomhole Location: 5206' FNL, 1356' FEL, SEC. 29, T11N, R9E, UM 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 184-082, API No. 50-029-21121-00- 00. Production should continue to be reported as a function of the original API number stated above. 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 DATED this day of October, 2018. STATE OF ALASKA ALr,_KA OIL AND GAS CONSERVATION COMMI__. ON PERMIT TO DRILL I SEA' 18 20118 20 AAC 25.005 1 a. Type of Work: Drill ❑ Lateral ❑✓ Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑✓ ' Service - Winj ❑ Single Zone ❑✓ - Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is proposed for: 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 2G-06L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9750' • TVD: 5882' 12. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 547' FSL, 236' FWL, Sec 32, T11 N, R9E, UM ° Top of Productive Horizon: 1402' FNL, 1347' FEL, Sec 32, T11N, R9E, UM Total Depth: 5206' FNL, 1356' FEL, Sec 29, T11 N, R9E, UM 7. Property Designation: ADL 25656 8. DNR Approval Number: LONS 82-180 13. Approximate Spud Date: 10/1/2018 9. Acres in Property: 2491 14. Distance to Nearest Property: 23075' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 508930 y- 5944135 - Zone- 4 10. KB Elevation above MSL (ft): 140' GL / BF Elevation above MSL (ft): 104' 15. Distance to Nearest Well Open Ito Same Pool: 525', 2F-20 16. Deviated wells: Kickoff depth: 8134' . feet Maximum Hole Angle: 99 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4,908 . Surface: 4,320 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 1350' 8400' 5912' 9750' 5882' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 8485' Total Depth TVD (ft): 6253' Plugs (measured): N/A Effect. Depth MD (ft): 8368' Effect. Depth TVD (ft): 6158' Junk (measured): 8158' Casing Length Size Cement Volume MD TVD Conductor/Structural 72' 16" 202 sx Cold Set II 110, 110' Surface 3097' 9-5/8" 1035 sx PF E, 250 sx PF C 3134' 2774' Production 8413' 7" 575 sx Class G, 250 sx PF C 8449' 6224' Perforation Depth MD (ft): 8188' - 8198' 8216' - 8246' Perforation Depth TVD (ft): 6013' - 6021' 6035' - 6060' Hydraulic Fracture planned? Yes❑ No ❑✓ 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program B Seabed Report B Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 8 20 AAC 25.050 requirements 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 G Contact Phone: 907-263-4321 Authorized Signature: Date: 9��v Commission Use Only Permit to Drill Number: 150- API Number: —2 .— 6000 Permit Approval Date: 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: 19-11 Other: Qr�7 fC� f 0 5DOD�� Samples req'd: Yes ❑ No[j�' Mud log req'd: Yes❑ No[�r q f%/� r v/cZr %JI �l�fn tr S 7` 16v 2 SDO p 5 15112S measures: Yes [il' No El ✓ Directional svy req'd: Yes & No❑ / Spacing exception req'd: Yes ❑ No [v Inclination -only svy req'd: Yes ❑ No ©' Post initial injection MIT req'd: Yes ❑ No APPROVED BY Approved by: _q _ / COMMISSIONER THE COMMISSION Date: i Form 10-401 Revised 5/2017 his permit iy vplio for GRIfiGN-A-1pr n� Submit Form and oval per 20A ��3� 5(g) Attachments in Duplicate AP- IV —If-d-lillw ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 10, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 2G-06 (PTD# 184-082) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in October 2018. The objective will be to drill four laterals, KRU 2G- 06L1, 2G-061_1-01, 2G-061_1-02, and 2G-061_1-03, targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 2G-06L1, 2G-061_1-01, 2G-061_1-02, and 2G-061_1-03 — Detailed Summary of Operations — Directional Plans for 2G-06L1, 2G-061_1-01, 2G-061_1-02, and 2G-061_1-03 — 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 2G-061-1, 2G-06L1-01, 2G-0611-1-02, and 2G-061-1-03 qW Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13)).........................................................................................-..................................................... 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plans for 2G-061-1, 2G-061-1-01, 2G-061-1-02, and 2G-06L1-03 laterals................................7 Attachment 2: Current Well Schematic for 2G-06...........................................................................................................7 Attachment 3: Proposed Well Schematic for 2G-06L1, 2G-061-1-01, 2G-06L1-02, and 2G-06L1-03 laterals.................7 Page 1 of 7 September 10, 2018 PTD Application: 2G-06L1, 2G-06L1-01, 2G-0611-1-02, and 2G-06L1-03 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 2G-061-1, 2G-061-1-01, 2G-061-1-02, and 2G-06L1-03. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 5,000 psi. Using the maximum formation pressure in the area of 4,908'psi in 213-05 (i.e. 5 ppg EMW), the maximum potential surface pressure in 2G-06, assuming a gas gradient of 0.1 psi/ft, would be 4,320 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 2G-06 was measured to be 3,897 psi (12.6 ppg EMW) on 7/15/2018. The maximum downhole pressure in the 2G-06 vicinity is the 213-05 at 4,908 psi or 15.5 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 2G-06 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2G-06 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)) The 2G-06 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 September 10, 2018 PTD Application: 2G-06L1, 2G-061_1-01, 2G-061_1-02, and 2G-061_1-03 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details MD MD TVDSS TVDSS 2G-06L1 8,400' 9,750' 5,912' 5,882' %", 4.7#, L-80, ST-L slotted liner 2; aluminum billet on to 2G-06L1-01 8,300' 9,750' 5,913' 5,859' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 2G-061_1-02 8,400' 9,900, 5,914' 5,898' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 2G-061_1-03 8,006' 9,900, 57730' 5,873' 23/", 4.7#, L-80, ST-L slotted liner; deployment sleeve on to Existing Casing/Liner Information Category OD Weigh t f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 110, Surface 110, 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 3134' Surface 2774' 3520 2020 Production 7" 26 J-55 BTC Surface 8449' Surface 6224' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 8rd MOD Surface 8044' Surface 5899' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System . A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power-Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling 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: BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.8 ppg potassium formate completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with potassium formate. Page 3 of 7 September 10, 2018 PTD Application: 2G-06L1, 2G-06L1-01, 2G-0611-1-02, and 2G-06L1-03 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000-psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2G-06 laterals we will target a constant BHP of 12.6 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed . for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 2G-06 Window (8,134' MD, 5,970' TVD) Using MPD ✓ Pumps On 1.8 b m Pumps Off Formation Pressure 12.6 • 3897 psi 3897 psi Mud Hydrostatic 8.6 2669 psi 2669psi' Annular friction i.e. ECD, 0.080 si/ft 650 psi 0 psi Mud + ECD Combined no chokepressure) 3319 psi underbalanced —578psi) 2669 psi underbalanced —1228psi) Target BHP at Window 12.6 3911 psi 3911 psi Choke Pressure Required to Maintain Target BHP 592 psi 1242 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 KRU well 2G-06 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize laterals to target the Kuparuk A -sands to the north and south of the existing 2G-06 wellbore. The laterals will reclaim resource from the long term shut in rock producer 2G-06 and provide additional offtake in a high-pressure area. • Page 4 of 7 September 10, 2018 PTD Application: 2G-06L1, 2G-06L1-01, 2G-06L1-02, and 2G-06L1-03 CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 8,134' MD. The 2G-06L1 lateral will exit through the 7" at 8,134'MD and TD at 9,750' ✓ MD, targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8,400' MD with an aluminum billet for kicking off the 2G-06L1-01 lateral. The 2G-06L1-01 lateral will drill to a TD of 9,750' MD targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8,300' MD with an aluminum billet for kicking off the 2G-06L 1-02 lateral. The 2G-06L1-02 lateral will drill to TD of 9,900' MD targeting the A sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 8,400' MD with an aluminum billet for kicking off the 2G-06L 1-03 lateral. The 2G-06L1-03 lateral will drill to TD of 9,900' MD targeting the A sand to the south. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 8,006' MD with a deployment sleeve. Pre-CTD Work 1. RU Service Coil: Conduct fill cleanout. 2. RU Slickline: Obtain SBHP and conduct dummy whipstock drift. 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2G-06L1 Lateral (A4 sand - North) a. Set top of high expansion wedge at 8,134' MD. b. Mill 2.80" window at 8,134' MD. c. Drill 3" bi-center lateral to TD of 9,750' MD. " d. Run 2%" slotted liner with an aluminum billet from TD up to 8,400' MD. 3. 2G-06L 1-01 Lateral (A4 sand -North) a. Kick off of the aluminum billet at 8,400' MD. b. Drill 3" bi-center lateral to TD of 9,750' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,300' MD. 4. 2G-06L1-02 Lateral (A4 sand -South) a. Kickoff of the aluminum billet at 8,300' MD. b. Drill 3" bi-center lateral to TD of 9,900' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD. 2G-06L1-03 Lateral (A4 sand - South) a. Kick off of the aluminum billet at 8,400' MD. b. Drill 3" bi-center lateral to TD of 9,900' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 8,006' MD. 6. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 September 10, 2018 PTD Application: 2G-06L1, 2G-06L1-01, 2G-06L1-02, and 2G-06L1-03 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — 2G-06 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 23/" liner. 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). Page 6 of 7 September 10, 2018 PTD Application: 2G-06L1, 2G-0611-1-01, 2G-06L1-02, and 2G-0611-1-03 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 Distance 2G-06L1 23,075' 2G-06L1-01 23,075' 2G-06L1-02 22,200' 2G-061-1-03 22,200' — Distance to Nearest Well within Pool Lateral Name Distance Well 2G-06L1 525' 2F-20 2G-06L1-01 525' 2F-20 2G-06L1-02 1285' 2G-08 2G-06L1-03 1285' 2G-08 16. Attachments Attachment 1: Directional Plans for 2G-06L1, 2G-06L1-01, 2G-06L1-02, and 2G-06L1-03laterals. Attachment 2: Current Well Schematic for 2G-06. Attachment 3: Proposed Well Schematic for 2G-06L1, 2G-06L1-01, 2G-06L1-02, and 2G-06L1-03 laterals. Page 7 of 7 September 10, 2018 ConocoPhilli s p _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 2G Pad 2G-06 2G-06L1 Plan: 2G-06L1 wp03 Standard Planning Report 21 August, 2018 BA ER 0 UGHES a GE company ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 2G Pad Well: 2G-06 Wellbore: 2G-061-1 Design: 2G-06L1_wp03 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: gAl- IGHES a GE company Well 2G-06 Mean Sea Level 2G-06 @ 140.00usft (2G-06) " True Minimum Curvature 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 1 Using geodetic scale factor Site Kuparuk 2G Pad Site Position: Northing: 5,944,015.12 usft Latitude: 70° 15' 29.734 N From: Map Easting: 508,649.96 usft Longitude: 149° 55' 48,314 W Position Uncertainty: - 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.07 ° Well 2G-06 Well Position +N/-S 0.00 usft Northing: 5,944,135.21 usft y Latitude: 70° 15' 30.911 N +E/-W 0.00 usft Easting: 508,929.90 usft Longitude: 149° 55' 40.165 W ! Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft i Wellbore 2G-061-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0 (1) K) BGGM2018 12/1 /2018 16.75 80.81 57,424 Design 2G-06L1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 8.100.00 Vertical Section: Depth From (TVD) +N/S +E/-W Direction (usft) (usft) (usft) (`) 0.00 0.00 0.00 0.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) V) (1) (usft) (usft) (usft) ('/100usft) (°/100usft) (°/100usft) Target 8,100.00 37.95 49.07 5,803.36 3,317.72 3,670.43 0.00 0.00 0.00 0.00 8,134.00 37.51 49.07 5,830.25 3,331.35 3,686.14 1.29 -1.29 0.00 180.00 8,155.00 41.71 49.07 5,846.42 3,340.12 3,696.26 20.00 20.00 0.00 0.00 8,327.46 90.00 49.07 5,914.90 3,440.19 3,811.67 28.00 28.00 0.00 0.00 8,475.00 97.89 8.39 5,904.31 3,566.33 3.881.09 28.00 5.35 -27.58 282.00 8,545.00 96.60 3.62 5,895.48 3,635.37 3,888.35 7.00 -1.85 -6.81 255.00 8,645.00 90.52 0.13 5,889.28 3,735.06 3,891.60 7.00 -6.07 -3.49 210.00 8,845.00 86.92 346.59 5,893.76 3,933.17 3,868.56 7.00 -1.80 -6.77 255.00 8,950.00 88.22 339.35 5,898.22 4,033.41 3,837.86 7.00 1.24 -6.90 280.00 9,050.00 89.44 346.25 5,900.26 4,128.86 3,808.31 7.00 1.23 6.89 80.00 9,200.00 98.95 350.72 5,889.29 4,275.23 3,778.45 7.00 6.34 2.98 25.00 9,300.00 97.67 357.67 5,874.81 4,373.61 3,768.46 7.00 -1.28 6.96 100.00 9,400.00 90.78 356.46 5,867.45 4,473.15 3,763.36 7.00 -6.89 -1.21 190.00 9,750.00 84.55 332.73 5,881.91 4,807.76 3,671.34 7.00 -1.78 -6.78 255.00 812112018 1:30:46PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhillips Planning Report F IGHES BAT GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 2G-06 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-06 @ 140.00usft (2G-06) Site: Kuparuk 2G Pad North Reference: True Well: 2G-06 Survey Calculation Method: Minimum Curvature Wellbore: 2G-061-1 Design: 2G-06L1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/S +E/_W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) j°) (usft) (usft) 8,100.00 37.95 49.07 5,803.36 3,317.72 3,670.43 3,317.72 0.00 0.00 5,947,456.94 512,596.021 TIP 8,134.00 37.51 49.07 5,830.25 3,331.35 3,686.14 3,331.35 1.29 180.00 5,947,470.59 512,611.72 KOP 8,155.00 41.71 49.07 5,846.42 3,340.12 3,696.26 3,340.12 20.00 0.00 5,947,479.37 512,621.83 End 20 dis, Start 28 dis 8,200.00 54.31 49.07 5,876.47 3,361.98 3,721.48 3,361.98 28.00 0.00 5,947,501.27 512,647.021 8,300.00 82.31 49.07 5,913.06 3,422.25 3,790.98 3,422.25 28.00 0.00 5,947,561.61 512,716.44 8,327.46 90.00 49.07 5,914.90 3,440.19 3,811.67 3,440.19 28.00 0.00 5,947,579.58 512,737.11 4 1 8,400.00 94.14 29.17 5,912.25 3,496.13 3,857.18 3,496.13 28.00 -78.00 5,947,635.56 512,782.54 8,475.00 97.89 8.39 5,904.31 3,566.33 3,881.09 3,566.33 28.00 -78.73 5,947,705.78 512,806.37 End 28 dls, Start 7 dis 8,500.00 97.43 6.68 5,900.98 3,590.88 3,884.34 3,590.88 7.00 -105.00 5,947,730.34 512,809.59 8,545.00 96.60 3.62 5,895.48 3,635.37 3,888.35 3,635.37 7.00 -105.23 5,947,774.82 512,813.55 6 8,600.00 93.26 1.69 5,890.76 3,690.09 3,890.89 3,690.09 7.00 -150.00 5,947,829.54 512,816.02 8,645.00 90.52 0.13 5,889.28 3,735.06 3,891.60 3,735.06 7.00 -150.17 5,947,874.50 512,816.68 7 8,700.00 89.53 356.41 5,889.25 3,790.02 3,889.94 3,790.02 7.00 -105.00 5,947,929.46 512,814.96 8,800.00 87.72 349.64 5,891.65 3,889.19 3,877.81 3,889.19 7.00 -105.00 5,948,028.60 512,802.71 8,845.00 86.92 346.59 5,893.76 3,933.17 3,868.56 3,933.17 7.00 -104.84 5,948,072.57 512,793.41 8 8,900.00 87.59 342.80 5,896.39 3,986.15 3,854.06 3,986.15 7.00 -80.00 5,948,125.53 512,778.85 I8,950.00 88.22 339.35 5,898.22 4,033.41 3,837.86 4,033.41 7.00 -79.82 5,948,172.77 512,762.59 i 9 i 9,000.00 88.83 342.80 5,899.50 4,080.68 3,821.65 4,080.68 7.00 80.00 5,948,220.01 512746.33 9,050.00 89.44 346.25 5,900.26 4,128.86 3,808.31 4,128.86 7.00 79.91 5,948,268.17 512:732.94 10 9,100.00 92.61 347.73 5,899.36 4,177.56 3,797.06 4,177,56 7.00 25.00 5,948,316.85 512,721.62 i 9,200.00 98.95 350.72 5,889.29 4,275.23 3,778.45 4,275.23 7.00 25.03 5,948,414.49 512,702.90 11 i 9,300.00 97.67 357.67 5,874.81 4,373.61 3,768.46 4,373.61 7.00 100.00 5,948,512.85 512,692.80 12 9,400.00 90.78 356.46 5,867.45 4,473.15 3,763.36 4,473.15 7.00 -170.00 5,948,612.37 512,687.57 13 j 9,500.00 88.97 349.70 5,867.67 4,572.35 3,751.32 4,572.35 7.00 -105.00 5,948,711.55 512,675.42 11 1 9,600.00 87.17 342.93 5,871.05 4,669.40 3,727.69 4,669.40 7.00 -104,98 5,948,808.56 512,651.68 9,700.00 85.41 336.14 5,877.53 4,762.83 3,692.83 4,762.83 7.00 -104.76 5,948,901.94 512,616.71 9,750.00 a 84.55 332.73 5,881.91 4,807.76 3,671.34 4,807.76 7.00 -104.32 5,948,946.84 512,595.17 Planned TD at 9750.00 rasing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,750.00 5,881.91 2 3/8" 2.375 3.000 812112018 1:30:46PM Page 3 COMPASS 5000.14 Build 85 �. ConocoPhillips ConocoPhillips Planning Report BAT BA ER a GE company Database: EDT 14 Alaska Production Local Coordinate Reference: Well 2G-06 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-06 @ 140.00usft (2G-06) Site: Kuparuk 2G Pad North Reference: True Well: 2G-06 Survey Calculation Method: Minimum Curvature Wellbore: 2G-061-1 Design: 2G-06L1_wp03 Pnal nal Annotations Measured Vertical Local Coordinates Depth Depth +N/S +E/-W (usft) (usft) (usft) (usft) Comment 8,100.00 5,803.36 3.317.72 3,670.43 TIP 8,134.00 5,830.25 3,331.35 3,686.14 KOP 8,155.00 5,846.42 3,340.12 3,696.26 End 20 dls, Start 28 dls 8,327.46 5,914.90 3,440.19 3,811.67 4 8,475.00 5,904.31 3,566.33 3,881.09 End 28 cis, Start 7 dls 8,545.00 5,895.48 3,635.37 3,888.35 6 8,645.00 5,889.28 3,735.06 3,891.60 7 8,845.00 5,893.76 3,933.17 3,868.56 8 8,950.00 5,898.22 4,033.41 3,837.86 9 9,050.00 5,900.26 4,128.86 3,808.31 10 9,200.00 5,889.29 4,275.23 3,778.45 11 9,300.00 5,874.81 4,373.61 3,768.46 12 9,400.00 5,867.45 4,473.15 3,763.36 13 9,750.00 5,881.91 4,807.76 3,671.34 Planned TD at 9750.00 812112018 1:30:46PM Page 4 COMPASS 5000.14 Build 85 - ConocoPhillips BA_ ER ConocoPhillips Travelling Cylinder Report BAT a GE company Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2G Pad Site Error. 0.00 usft Reference Well: 2G-06 Well Error: 0.00 usft Reference Wellbore 2G-061-1 Reference Design: 2G-06L1_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2G-06 2G-06 @ 140.00usft (2G-06) 2G-06 @ 140.00usft (2G-06) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 2G-06L1_wp03 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,100.00 to 9,750.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,161.00 usft Error Surface: Pedal Curve Survey Tool Program Date 8/21/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 8,100.00 2G-06 (2G-06) SEEKER MS BHI Seeker multishot 8,100.00 9,750.00 2G-06L1_wp03 (2G-06L1) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,750.00 6,021.91 2 3/8" 2.375 3.000 Summary Site Name Offset Well - Wellbore - Design 2L Pad 2L-328 - 2L-328 (Sierra) - 2L-328 Planned Kuparuk 2F Pad 2F-20 - 2F-20 - 2F-20 Kuparuk 2G Pad 2G-06 - 2G-06 - 2G-06 2G-06 - 2G-061-1-01 - 2G-06L1-01_wp05 2G-06 - 2G-061-1-02 - 2G-06L1-02_wp03 2G-06 - 2G-06L1-03 - 2G-06L1-03_wp03 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 9,750.00 7,075.00 981.99 243.57 9,282.00 9,300.00 23.82 1.64 Out of range 741.07 Pass - Major Risk Out of range 23.34 Pass- Minor 1/10 Out of range Out of range Offset Design Kuparuk 2F Pad - 2F-20 - 2F-20 - 2F-20 Offset Site Error. 0.00 usft Survey Program: 282-MWD Rude Assigned: Major Risk Onset Well Error. 0.00 usft Reference onset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Tootface + Offset Wellbore Centre Casing - Centre to No Go Allowable wanting Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (usft) lush) (usft) (usft) (usft) (usft) (') (usft) (usft) (in) (usft) (usft) (usft) 9,721.12 6.019.29 6,900.00 5.422.47 64.88 59.22 33.02 5,242.66 4,537.91 6.312 1,138.53 237.54 904.86 Pass -Major Risk 9,724.85 6,019.61 6,925.00 5,440.51 64.88 59.48 33.12 6,242.28 4.520.59 6.312 1,116.00 238.33 881.32 Pass - Major Risk 9,728.64 6,019.95 6,950.00 5458.52 64,88 59.74 33.23 5,241.86 4,503.26 6,312 1,093.52 239.13 85TS2 Pass - Major Risk 9,732.49 6,020.29 6,975.00 5,476.52 64.89 60.00 33.34 5,241.38 4,485.92 6.312 1,071.09 239,95 834.35 Pass - Major Risk 9,736.40 6,020.64 7,000.00 5,494.50 64.89 60.26 33.47 5,240.84 4468.56 6.312 1,048.72 240.78 810.92 Pass - Major Risk 9,750.00 6,021.91 7,025.00 5,512.46 64.90 60.52 33.02 5,240.25 4,451.18 6.312 1,026.51 242.85 788.56 Pass - Major Risk 9.750,00 6,021.91 7,050.00 5,530.41 64.90 60.79 33.42 5139.61 4,433.79 6.312 1.004.20 243.21 764.79 Pass - Major Risk 9,750.00 6,021.91 7,075.00 5,548.34 64.90 61.05 33.84 5,238.92 4,416.38 6.312 981.99 243.57 741.07 Pass - Major Risk, CC, ES, SF CC - Min Centre to center distance or covergent point, SF - min separation factor. ES - min ellipse separation 812112018 2:07.18PM Page 2 COMPASS 5000.14 Build 85 n a Lo 07 � 0o Jr 'O � t!7 O N o a y o a m m rn U3 U Q O h N 76 O W N c a� c C a C C Qh-YWVWcotiWrn��.-.-d � UN � !Js'2C2 MI�tO N 1� MMMO � ct GDN cp e- f- o o co ui ui c+i ri ao ui ri <'�i n co (Q O W O OOOOO O 000 0000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O J p N O O O O O O O O O O O O O w O N 0 0 0 0 0 0 O O O O O O O O- O N m 1 n ti ti ti r n I ` N N N M <o I-- V' V' N to O M (D W M V M M 00 O c�Co �e-m�m 1�mm W M� c6� W<n co W mmmmmmmmmm N O M M M M M M M J W N itJ� OMf-COS �tD M.--NCO Q 00 oZr-�ooco �n ui ri c•i co Sri ai �'i t� w Q M J NN oW m<ON W rn� �r '= W CO M N ,I:' O� M Ct N t� Cl! O M O (O �r O M m O O cf f� O M V O O W 01 m O m� c O W C N> r W W W 6) p� W W W W O m W W W �M u'i cn cn u'>�� O N 1+ n ti O) N M O f J N 1 W M z Q O O O O M Iq M N I W V f O LO 01 O O Q 1 W M O C O O c D O 1 W N V R V' C M M M M M M M M C Q>Cl O: W r- 10 QM M 6) O O O W W m O] O O W Lilo + 000W0000000000 o 0 o v o 0 0 0 0 0 0 0 0 0 o--*-Lnf-��LO�000000 O�2 �N� V' V' V' �'OOO� M V W W W Q� O N M V 1� 0 �_ z O W 0 c a y 3 (ui/8sn OS) 41doQ jcoiuon anus KUP PROD 2G-06 C011000I�It1II1PS t' Alaska, nc. '" Well Attributes Max Angle & MD TD Field Name KUPARUK Rp/ER UNIT We@,ore APIMM7 Wellbore 500292112100 PROD Status ncl (°J MD 4.60 4,000.00 (ftKBj Ad 8,485.0 Btm (ftKBJ Commend iUS SSSV: NIPPLE 110 (ppm) Date 12119QO17 Annotation Las( WO: End Date 7fi4/2010 KB.Grd (M Rig 36.00 6/1811994 Release Date 2G06, 71,7aJ189Q3.32AM Last Tag Vertical schematic (ackal) Annotation Last Tag: RKB End Date 711512018 Depth (RKBj Last $168.0 fergusp Mod By HANGER 30A CONDUCTOR, 38.0110.0 NIPPLE: 524,7 GAS LIFT, 2951.5 j V ((I SURFACE; a?.z-3,, 3a.9- 1 GAS LIFT', 4.945.1 GAS LIFT; 6,250.3 GAS LIFT: 7,246.0 GAS LIFT, 7 898.2 PBR; 7,956,E PACKER ; 7,96e.3 NIPPLE' 8,011.2 FISH: 8.158.0 IPERF: 8,, 88.0$,196.0- IPERF, 8,216.0-8.246.0- PRODUCTION: 35.9 .4 el DORN Last Rev Reason Annotation End Date Last Mod By Rev Reason: Set new Rocksaeen. 7/1612018 fergusp Casing Strings Casing Description CONDUCTOR DID(in) 16 ID (in) Top 15.06 38.0 VMS) Set Depth(RKBI Set 110.0 110.0 Depth(TVD)... WHLen(L.. 62.58 Grade H40 Top Thread Welded Casing Description SURFACE OD (n) 9518 ID C.) Top 9.21 3Z2 (RKBj Set Depth (ftKB) Set 3133.9 2.773.7 Depth (TVD)... Will- 36.00 (1... Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) I Top 6.28 35.9 VI BJ Set 8,449.1 Depth (RKB) Set 6,223.8 Depth (ND)... WIA-- 26.00 (L.. Grade 3-55 Top Thread BTC Tubing Strings Tubing Description String Ma.. 1D (n) lop (RKB) Se[ Depth (R.. Set Depth (TVD) (... Wt (Ibi t) Grade Top Connection TUBING WO 31!2 299 30.1 7,969.3 5,841.4 9.30 L-80 EUEBrdABMOD Completion Details Top(ftKS) TOp(TVD) (mcBj 1 Topind (1 Item Des Corn Nominal ID (in) 30.1 30.1 0.09 HANGER Vetco/Gray Gen It TUBING HANGER 2938 524.7 524.6 1.18 NIPPLE 3.5' Camco'OS" Nipple w/ 2.875 profile 2.875 7,956-6 5,931.6 39.63 PBR PBR Seal Assembly (sheared) w/ 2 space out STABBED INTO PACKER ASSEMBLY 2.980 Tubing Description String Ma... ID (in) Top(ftKB) Set Depth (ft.. Set Depm O VD) (... bit ObM) Grade Top Connecuon TUBING Packer Assy 3 112 2.99 7,968.3 8,043.E 5,899.1 9.30 L-80 SRD EUE Completion Details Top(ftK8) Top fTVDI Top (RKB) Ind CI hem Des Com Nomi„al ID(in) 7,968.3 5,840.7 39.50 PACKER FHLPacker 3.030 8,011.2 5,873.8 39.03 1 NIPPLE 2.813' DS Nipple 2.813 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc,) Top ((tKB) 7opD) To (TVp (RKB) lnd r) Des Corn Run Date ID (in) 8,011.0 5,873.7 39.04 CS-LOCKfFHEA ROCKSCREEN 2.81' CS -LOCK W/ tapppered Rockscreen, 2.79 x 2.40" THEA Rockscreen (OAL 80") 7116/2018 0.000 8,158.0 5,989.3 37.21 FISH LOWER PACKER FROM OLD COMPLETION, PXX PLUG, 8 REST OF TUBING DOWN TO WIRELINE RE - ENTRY GUIDE IS IN FILL. TAGGED HARD MUD @ 8158 SLM. 1/6/2008 0.000 Perforations & Slots Top (RKB) Top(TVD) Son (RKB) (RKB) Bun (TVD) (RKB) Linked Zone Date Shot Dens (shotslft I Type Com 8,188.0 8,198.0 6,013.3 6,021.3 A-5, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4' Schlumberger Casi 8,216.0 8,246.0 6,035.7 6,059.9 A4, 2G-06 9/24/1988 4.0 IPERF 90 deg. Phasing; 4' Schlumberger Cast Mandrel Inserts St ad on N Top (ftKB) I Top f m) (RKBJ Make Model OD (in) Se Val. Type Latch Type Port Size (in) TRO Run (P-0 Run Date Corn 2,951.5 2.655.4 Cameo MMG 1 1R GAS LIFT GLV RK 0.188 1,240.0 2/8/2018 9.30 2 4,945.51 3,851.9 Cameo MMG 1112 GAS LIFT GLV RK 0.188 1,220.0 2/8/2018 10:30 3 6,250.31 4,646.2 Cameo MMG 1 112 GAS LIFT GLV RK 0.188 1,217.0 2/8/2018 1:00 q 7,246.0 5,310.E Cameo MMG 1 1,2 GAS LIFT GLV RK 0.188 1,232.0 2/8Y2018 9:30 5 7,898.2 5,786.8 Carrico MMG 1 112 GAS LIFT OV RK 0.250 0.0 2f712018 10:30 Notes: General & Safety End Date Annotation 1l2/2000 NOTE: WORKOVER 12/10/2007 NOTE: "MIT TESTING WILL HAVE TO USE DS NIPPLE @ 8008"" 12/10/2007 NOTE: WORKOVER 712/2009 NOTE: 5005' = TIGHT SPOT, UNABLE TO WORK 2.6" GAUGE RING PAST 6/27/2009 7/2/2009 NOTE: View Schematic w/ Alaska Schematic9.0 V r l4 E d t V cn 0 H V .a d N O CL O a` w 'o V N O Lo N co O m E V _C E U r c rn M U aD v 3 O /�cli` V d Q) O m CD CD�� � co E co ` cD co N a N m kn CO O -, r, N n M v LU c 0 co LU N c @) v C) °o O C _ co Q) 2 m Y (L U O) C 'O .�. 0 E^ CL NJ cm M Cn m C r- = CA m O U m r) LL O N N N Coca Y Y N N cn Cl) A n co M M C%) cn �2aI Q Q � p O M Op Q O N Jmon 98. �� Q <p�� m 'cv F-J Yam (,gyp c 90. v MScm O V N a Q N Q LO lu o � v nr m v - v a co n F- m C � co y tD Q 00 Q co From: Herring, Keith E To: der, David L (DOA) Cc: Davies, Stephen F (DOA); Long, William R Subject: RE: [EXTERNAL]Survey Digital Files for KRU 2G-06L1, L1-01, L1-02 and L1-03 Date: Friday, September 21, 2018 9:15:50 AM Attachments: image001.pno 2G-061_1 wp03 MD - NAD27.txt 2G-061-1-01 wo05 MD - NAD27.txt 2G-06L1-02 wo03 MD - NAD27.txt 2G-061-1-03 wp03 MD - NAD27.txt Dave, Please see attached. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.11errine!a conoconhillins.com From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Friday, September 21, 2018 8:46 AM To: Herring, Keith E <Keith.E.Herring@conocophillips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: [EXTERNAL]Survey Digital Files for KRU 2G-06L1, 1-1-01, L1-02 and L1-03 Hi Keith, Permit to Drill Applications for the 4 KRU 2G-06 laterals on 09/18. Steve and I are reviewing them and see that the first lateral is scheduled for 10/01/18. If you can e-mail me digital surveys (Excel or ASCII text files) for the 4 laterals, it really speeds up the data entry into our Geographics database. We only load the MD, inclination, and azimuth columns but if it is easier to send the Baker Hughes files, we can extract what we need to plot the well on our maps. Thank you, Dave Boyer Senior Geologist AOGCC TRANSMITTAL LETTER CHECKLIST WELL NAME: K R % J� G - 0 6 1- PTD: v/ Development Service _ Exploratory Stratigraphic Test Non -Conventional FIELD: L( Q r R ► veV- POOL: Kaparu r 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. J 5!4: --0$ati API No. 50- 0M -_2.J J g J - o-_do v/ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by ✓ (CompM 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 - 490000 _ Well Name: KUPARUK RIV UNIT 2G-061_1 _ Program DEV Well bore seg d❑ PTD#:2181120 Company CONOCOPHILLIPS ALASKA, INC. __ __ Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 — On/Off Shore On _ Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included No Directional p_lanview os four laterals is included. 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 DLB 9/20/2018 13 Can permit be approved before 15-day wait Yes 114 Well located within area and strata authorized by Injection Order # (put I0# in comments) (For NA 15 All wellswithin1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Conductor set in KRU 2G-06 - Engineering 19 Surface casing protects all known_ USDWs NA Surface casing set in KRU 2G-06 20 CMT vol adequate to circulate -on conductor & surf csg NA Surface casing set and fully cemented 121 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No Productive interval will be completed with uncemented slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete: no major risk failures 27 If diverter required, does it meet regulations NA - Appr Date 28 Drilling fluid program schematic -& equip list adequate Yes Max formation pressure is 4908 psig(15.5 ppg EMW), will drill -w/ 8.6 ppg EMW and maintain overbal w/ MPD VTL 10/5/2018 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to -(put psig in comments) Yes MPSP is 4320 psig, will test BOPs to 5000 psig 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 - Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures - - - - No Wells -on-2G-Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Appr Date �37 Seismic analysis of shallow gas zones NA DLB 9/20/2018 ,38 Seabed condition survey (if off -shore) NA '39 Contact name/phone for weekly progress reports [exploratory only] - - - NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Co is ' ner Date �y
