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Home My WebLink About216-1471. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Convert to Inj Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11984'feet None feet true vertical 6201' feet None feet Effective Depth measured 11984'feet 9578'feet true vertical 6201' feet 5979' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 4-1/2" L-80 9736' MD 6075' TVD Packers and SSSV (type, measured and true vertical depth)9578' MD N/A 5979' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4348' 3127' Burst Collapse Production Liner 10017' Casing 6268'10052' 4313' 115'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-147-0 50-103-20097-62-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025523, ADL0025531 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3H-22L1-02 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) INJECTOR Gas-Mcf MD ~ Size 115' ~ ~~ ~ ~~ ~ 322-685 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker 587-400 Model F Prod Packer SSSV: None Lynn Aleshire lynn.aleshire@conocophillips.com (907) 265-6525Surveillance Reservoir Engineer Slotted Liner: 10050-11984' Slotted Liner: 6124-6201' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 1:46 pm, Feb 21, 2023 3H-22 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/20/23 Choke inspected; removed and sent to valve shop for repair. 01/22/23 DSM installed choke and well BOL. 01/30/23 State witnessed MITIA. PASS Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,803.0 3H-22 5/26/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: H2S Update & Correct ICON 3H-22 4/19/2022 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: Bad spot in 7"CSG 8257'-8281'; Max ID=6.45"; Tested to 2600psi w/10 ppg Brine. 4/28/1988 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,347.6 3,126.8 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 10,052.2 6,267.8 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.0 Set Depth 9,586.8 Set Depth 5,984.6 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.09 HANGER 6.930 McEvoy Gen III Tubing Hanger, MSDP-1-6.5-MS-3, 7-1/16" x 3-1/2" EUE 8rd Box x Box, 3" H BPVG McEvoy Gen III MSDP-1 -6.5-MS- 3 2.950 3,246.3 2,509.1 56.20 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 267AG07 Camco MMG 2.915 5,598.9 3,802.4 58.62 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 263AG07 Camco MMG 2.915 7,260.2 4,693.3 58.20 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with SOV, RKP Latch, SN: 165AG07 Camco MMG 2.915 8,576.8 5,395.5 56.11 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 283AG07 Camco MMG 2.915 9,517.3 5,942.4 52.77 GAS LIFT 5.968 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 266AG07 Camco MMG 2.915 9,574.2 5,976.9 52.65 LOCATOR 5.240 Locator Sub, GBH-22 (bottom of the locator spaced out 3.83') Baker GBH-22 2.990 9,575.3 5,977.6 52.65 SEAL ASSY 3.730 Seal Assembly, 80-40 Baker 80-40 3.020 Top (ftKB) 9,578.3 Set Depth 9,736.0 Set Depth 6,075.3 String Ma 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection STC ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,578.3 5,979.4 52.65 PACKER 5.870 587-400 Model 'F' Production Packer Baker 587-400 Model 'F' 4.000 9,581.6 5,981.4 52.64 SBE 5.030 80-40 Seal Bore Extension (SBE) Baker 80-40 SBE 4.000 9,591.0 5,987.1 52.62 XO Reducing 5.670 Crossover, 4-3/4" Stub Acme Box x 3-1/2" EUE 8rd Pin Baker 2.970 9,639.7 6,016.7 52.57 NIPPLE 3.930 Nipple, HES, 2.813" X, SN: C- 3562596 Halliburt on X' Profile 2.812 9,651.6 6,023.9 52.56 PORTED CROSSOVER 4.500 Ported Crossover, 3-1/2" EUE 8rd Mod Box x 4-1/2" STC Pin Baker 2.992 9,653.4 6,025.0 52.56 PORTED WEARSOX 4.500 Ported Wearsox Joint, 4-1/2", 12.6#, L-80, STC Box x Mule Shoe Baker 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5" WHIPSTOCK(GENII DELTA). TOWS = 9715, WHIPSTOCK ORIENTATION = 330DEG, CCL TO TOP OF WHIPSTOCK = 14.9', RA TAG @7.35 FROM TOP, WHIPSTOP OAL=12.97 10/6/2016 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,246.3 2,509.1 56.20 1 GAS LIFT DMY RK 1 1/2 0.0 5/26/2017 0.000 5,598.9 3,802.4 58.62 2 GAS LIFT DMY RK 1 1/2 0.0 5/26/2017 0.000 7,260.2 4,693.3 58.20 3 GAS LIFT DMY RK 1 1/2 0.0 3/15/2017 0.000 8,576.8 5,395.5 56.11 4 GAS LIFT DMY RK 1 1/2 0.0 3/19/2016 0.000 9,517.3 5,942.4 52.77 5 GAS LIFT DMY RK 1 1/2 0.0 5/27/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,690.0 9,710.0 6,047.3 6,059.4 A-3, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,716.0 9,736.0 6,063.1 6,075.3 A-2, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,754.0 9,774.0 6,086.2 6,098.4 A-1, 3H-22 4/25/1988 4.0 IPERF SOS 4.5" Ultra P; 120° ph 3H-22, 2/20/2023 4:42:37 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22 ... TD Act Btm (ftKB) 10,234.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009700 Wellbore Status PROD Max Angle & MD Incl (°) 60.15 MD (ftKB) 5,100.00 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS & GLV C/O 3H-22L1 2/9/2017 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner (Slotted) 2 3/8 1.99 9,812.2 11,751.0 4.70 L-80 ST L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,812.2 6,104.3 79.00 Aluminum Billet 2.700 Aluminum Billet BOT Billet 0.000 3H-22L1, 2/20/2023 4:42:38 PM Vertical schematic (actual) L1 Liner (Slotted); 9,812.2- 11,751.0 PRODUCTION; 35.0-10,052.2 L1-03 Liner; 9,714.0-12,000.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22L1 ... TD Act Btm (ftKB) 11,751.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009760 Wellbore Status PROD Max Angle & MD Incl (°) 99.31 MD (ftKB) 10,800.66 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS & GLV C/O 3H-22L1- 02 2/9/2017 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 10,049.7 11,984.0 4.70 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,049.7 6,124.4 90.38 Aluminum Billet & Anchor 2.630 OH Anchor & Aluminum Billet BOT Billet 1.920 10,632.2 6,113.5 91.14 Deployment Sleeve Shorty Deployment Sleeve 3H-22L1-02, 2/20/2023 4:42:38 PM Vertical schematic (actual) L1-02 Liner; 10,049.7-11,984.0 L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22L1-02 ... TD Act Btm (ftKB) 11,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009762 Wellbore Status PROD Max Angle & MD Incl (°) 100.26 MD (ftKB) 10,940.98 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS & GLV C/O 3H-22L1- 03 2/9/2017 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-03 Liner 2 3/8 1.99 9,714.0 12,000.0 6,138.7 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,714.0 6,061.9 52.52 Deployment Sleeve 2.625 Shorty Deployment Sleeve Baker Shorty 1.000 3H-22L1-03, 2/20/2023 4:42:39 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22L1-03 ... TD Act Btm (ftKB) 12,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009763 Wellbore Status PROD Max Angle & MD Incl (°) 101.16 MD (ftKB) 10,170.57 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None 4hEbK2Ej{Evx=:`Cb`1Z{R1Erk:xVb`v $k:?x{nE3xV]{Z:xE2Eh:Vk7EZZ0hEk:xVb`vvT{xCg` 3{vhE`C1Erk:xE0xTEk3xV]{Z:xE1{ZZ4{=V`R !T:`REhhkc}EC1kbRm:] 1Z{RLbk2ECkVZZ1Erk:xE/J1bbZ2E E`xEk3{vh7EZZZxEk!:vV`R0xTEk!b`~Etxb7'/* 0hEk:xbk/:]E !{kp`x7EZZ!Z:vv 1Ek]Vxxb"kVZZ/{]=Ek !b`b?b1TVZZVhvZ:vY: '`?#hZbk:xbk"H}EZbh]E`x > CCnEvv3xk:xVRk:hTV?3Ek}V?E 1'/{]=Ek 10 b `?Tbk:RE + 'KhErk:xV`R7EZZ/:]E:`C/{]=Ek 7T:x2ER{Z:xVb`bk!b`vEk}:xVb`0kCEkRb}Ek`vEZZvh:?V`RV`xTVvhbbZ> 7VZZhZ:``EChErk<Vb`vkEj{VkE:vh:?V`RE?EhxVb`9Ev /b 1kbhEkz"EvVR`<Vb`-E:vE/{]=Ek $VEZC!{kp`x1bbZv1kbhbvEC1bbZv >;4%5;->,<)5>,).(> ;4%5;->,<)5>,.>22.> ;4%5;->,<)5>,.>22.> >#> >!$> 4bx:Z"EhxT."4bx:Z"EhxT46"#N?xV~E"EhxT." #N?xV~E"EhxT46".131hvV1Z{Rv."*{`Y." /b`E/b`E %8,1*> )1*9+>,=)>> ">;789> 2..%48)> 3xk{?x{oZ !b`C{?xbk 3{q?E '`xEk]ECV:xE 1kbC{?xVb` -V`Ek 1Erk<Vb`"EhxT."1Erk<Vb`"EhxT46" 4{=V`R3VE 4{=V`R%k:CE 4{=V`R." 3ZbxxEC-V`Ek 3ZbxxEC-V`Ek 8 - 1:?YEkv:`C33364hE1:?YEk :YEk .bCEZ$1kbC1:?YEk1:?YEkv:`C3336.":`C46".":`C46" 3336/b`E/ xx:?T]E`xv1kbhbv:Z3{]]:k7EZZ=bkEv?TE]:xV?7EZZ!Z:vv:OEkhnbhbvECbkY "I:VZEC0hEk<Vb`v1kbRm:] 013YEx?T#hZbk<bk3xk<VRk:hTV?"H}EZbh]E`x #vxV]:xEC"<EKbk 7EZZ3x:x{v:OEkhnbhbvECbkY !b]]E`?V`R0hEk<Vb`v>0'-7'/*7"31- 6Ek=:Zhhkf}:Z"<E%37%%3402 0%!!2EhpvE`x:xV}E%'/*0h3T{xCg` (UFlF>@FuWPyU;yyUFMdlFSdWaSWwyl|F;aDyUFild@FD|lF;iildFDUFlFWaW[[ady>FDFW;yFDMld^WyUd|yilWdllWyyFa;iild;[ {xTbkVEC/:]E:`C !b`x:?x/:]E -``ZEvTVnE 3Ek}V?E 3{vhE`CEC 31-5% =:`Cb`EC "VRVx:Z3VR`<{kEVxT"<E!b`x:?x#]:VZZ``:ZEvTVnE\?b`b?beTVZZVev?b] !b`x:?x1Tb`E {xTbkVEC4VxZE3{k}EVZZ:`?E2EvEk}bVk#`RV`EEk >!>$> !b`CVxVb`vbK:hhkf}:Z/bxVQ0%!!vbxT:x:kEhnEvE`x:xV}E]:Vx`Evv3{`Ck/{]=Ek 1Z{R'`xERkVx 014Evx .E?T:`V?:Z'`xERkVx4Evx-b?:xVb`!ZE:k:`?E 0xTEk 1bvx'`VxV:Z'`XE?xVb`.'42EjC9Ev /b 3h:?V`R#BEhxVb`2Ej{VkEC9Ev/b 3{=vEj{E`x$bk]2Ej{VkGC 11206#" 9 hhs}EC=!0..'33'0/#24&# 0%!!"<E !b]])Ab]]3k1Ex#`R 3k1Ex%Eb3k2Ev#`R 4452<)&>%44/,'%9,21><%,&>:25>>0219+8>6520>&%9)>26>%4453<%/>3{=]Vx1"$xb:bR??hEk]xx_R::v,:Rb} 20097 SFD 12/2/22 X VTL 12/16/2022 10-404 DSR-12/1/22SFD 12/2/2022 X GCW 12/16/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.16 09:36:50 -09'00' RBDMS JSB 122222 $%&'( # " " ! *+ () 2"!!. () /0 !1 ' 6/ 130 /0 4'45'.1 " ( ) * ) 7 8 352.;7) / 9:: 1 3.&,;7) 5325;8) ,'.5;8) 35.2;7)$ 8/ (: 1 !6 53.3;8) !6 4 <9 ( - / 1 !6 & < 5" $ ) ) ( " *+ ( ")0= ," $ 0 ( = 0?=?=-!>* ) (!!6 *+ ! * 9 !6 * = * 9! ) ) "-!>"= @ " #A #A .-( ( ($ @ 4& 0( ( B /3'.14,5#,545 * &#64C0#2' 0 D#64C0#2' $52.#D''7CC$ 8! $ ) ( -E ) 5'4.24432 @ #- D /< 4'45'.':45'.:F4542&1 ' = #7 @ *0G 0G-0!)=!* 8-!77--! " 4 ! ! D" A"$ # $%&'(%)*+ (* ,-"$%&'(%)*+ (*,, $:- A+''&,' :G335' & $.!! >$ !6 /01 *2 3 3 3 0#'40 4'5*/ B''5.#32D; B,4D#,4'; 4,,'&5 6%(50 7 3 " &'( '#D'D '64'4 ,-! !!! 5 ) ! !! Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2021.11.16 17:10:23 -09'00' SFD 11/18/2021 DSR-11/17/21 RBDMS HEW 11/18/2021 -00 VTL 01/24/2022 SFD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,803.0 5/26/2016 3H-22 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: H2S, GLV C/O 5/28/2017 3H-22 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,347.6 Set Depth (TVD) … 3,126.8 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 10,052.2 Set Depth (TVD) … 6,267.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.0 Set Depth (ft… 9,586.8 Set Depth (TVD) (… 5,984.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.09 HANGER McEvoy Gen III Tubing Hanger, MSDP-1-6.5-MS-3, 7-1/16" x 3- 1/2" EUE 8rd Box x Box, 3" H BPVG 2.950 9,574.2 5,976.9 52.65 LOCATOR Locator Sub, GBH-22 (bottom of the locator spaced out 3.83') 2.990 9,575.3 5,977.6 52.65 SEAL ASSY Seal Assembly, 80-40 3.020 Tubing Description Tubing – Completion Lower String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 9,578.3 Set Depth (ft… 9,736.0 Set Depth (TVD) (… 6,075.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection STC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,578.3 5,979.4 52.65 PACKER 587-400 Model 'F' Production Packer 4.000 9,581.6 5,981.4 52.64 SBE 80-40 Seal Bore Extension (SBE) 4.000 9,591.0 5,987.1 52.62 XO Reducing Crossover, 4-3/4" Stub Acme Box x 3-1/2" EUE 8rd Pin 2.970 9,639.7 6,016.7 52.57 NIPPLE Nipple, HES, 2.813" X, SN: C-3562596 2.812 9,651.6 6,023.9 52.56 PORTED CROSSOVER Ported Crossover, 3-1/2" EUE 8rd Mod Box x 4-1/2" STC Pin 2.992 9,653.4 6,025.0 52.56 PORTED WEARSOX Ported Wearsox Joint, 4-1/2", 12.6#, L-80, STC Box x Mule Shoe 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,697.0 6,051.5 52.52 Junk Catcher AVA CATCHER (2.73" x 35") 3/14/2017 0.000 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5" WHIPSTOCK(GENII DELTA). TOWS = 9715, WHIPSTOCK ORIENTATION = 330DEG, CCL TO TOP OF WHIPSTOCK = 14.9', RA TAG @7.35 FROM TOP, WHIPSTOP OAL=12.97 10/6/2016 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,690.0 9,710.0 6,047.3 6,059.4 A-3, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,716.0 9,736.0 6,063.1 6,075.3 A-2, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,754.0 9,774.0 6,086.2 6,098.4 A-1, 3H-22 4/25/1988 4.0 IPERF SOS 4.5" Ultra P; 120° ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,246.3 2,509.1 56.20 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 2 5,598.9 3,802.4 58.62 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 3 7,260.2 4,693.3 58.20 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/15/2017 4 8,576.8 5,395.5 56.11 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 5 9,517.3 5,942.4 52.77 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/27/2017 Notes: General & Safety End Date Annotation 11/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/28/1988 NOTE: Bad spot in 7"CSG 8257'-8281'; Max ID=6.45"; Tested to 2600psi w/10 ppg Brine. 3H-22, 10/20/2021 3:39:04 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22 ... TD Act Btm (ftKB) 10,234.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009700 Wellbore Status INJ Max Angle & MD Incl (°) 60.15 MD (ftKB) 5,100.00 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: ADD LATERALS & GLV C/O 2/9/2017 3H-22L1 pproven Casing Strings Casing Description L1 Liner OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 9,812.2 Set Depth (ftKB) 11,751.0 Set Depth (TVD) … Wt/Len (l… 4.70 Grade L-80 Top Thread ST L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,812.2 6,104.3 79.00 Aluminum Billet Aluminum Billet 0.000 3H-22L1, 10/20/2021 3:39:05 PM Vertical schematic (actual) L1 Liner; 9,812.2-11,751.0 L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22L1 ... TD Act Btm (ftKB) 11,751.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009760 Wellbore Status INJ Max Angle & MD Incl (°) 99.31 MD (ftKB) 10,800.66 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: ADD LATERALS & GLV C/O 2/9/2017 3H-22L1-02 pproven Casing Strings Casing Description L1-02 Liner OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 10,049.7 Set Depth (ftKB) 11,984.0 Set Depth (TVD) … Wt/Len (l… 4.70 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,049.7 6,124.4 90.38 Aluminum Billet & Anchor OH Anchor & Aluminum Billet 1.920 10,632.2 6,113.5 91.14 Deployment Sleeve Shorty Deployment Sleeve 3H-22L1-02, 10/20/2021 3:39:06 PM Vertical schematic (actual) L1-02 Liner; 10,049.7-11,984.0 PRODUCTION; 35.0-10,052.2 L1-03 Liner; 9,714.0-12,000.0 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22L1-02 ... TD Act Btm (ftKB) 11,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009762 Wellbore Status INJ Max Angle & MD Incl (°) 100.26 MD (ftKB) 10,940.98 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: ADD LATERALS & GLV C/O 2/9/2017 3H-22L1-03 pproven Casing Strings Casing Description L1-03 Liner OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 9,714.0 Set Depth (ftKB) 12,000.0 Set Depth (TVD) … 6,138.7 Wt/Len (l… 4.60 Grade L-80 Top Thread ST-L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,714.0 6,061.9 52.52 Deployment Sleeve Shorty Deployment Sleeve 1.000 3H-22L1-03, 10/20/2021 3:39:06 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22L1-03 ... TD Act Btm (ftKB) 12,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009763 Wellbore Status INJ Max Angle & MD Incl (°) 101.16 MD (ftKB) 10,170.57 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None !" #$% &' (! )*)+*%( ,- +*( STATE OF ALASKA • ALA"OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate LJ Pull Tubing LJ Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ ,erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ PROD TO WAG 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhlllips Alaska, Inc. Development El Exploratory ❑ 216-147-0 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-103-20097-62 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25523,25531 KRU 3H-22L1-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,984 feet Plugs measured None feet true vertical 6,201 feet Junk measured None feet Effective Depth measured 11,984 feet Packer measured 9578 feet true vertical 6,201 feet true vertical 5979 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79 16 115 115 Surface 4,313 12 4,348 3127 Intermediate Production 9,777 7 9,812 6104 RECEIVED Slotted liner 1,934 2.375 11,984 6201 Perforation depth Measured depth 10057-11984 feet JUN 1 4 2017 True Vertical depth 6127-6201 feet AOGCC Tubing(size,grade,measured and true vertical depth) 3.5 L-80 -,-9,52,_,,,,,r,.. 6024 Packers and SSSV(type,measured and true vertical depth) Model F Prod.Pkr 9578 5979 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7n17, Treatment descriptions including volumes used and final pressure: CAM*" NOV 1 3 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 170 490 1180 1300 200 Subsequent to operation: 1900 1150 2865 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-161 Authorized Name: Lynn Aleshire Contact Name: Lynn Aleshire Petroleum Engineer Contact Email: Lynn.Aleshire©conocophillips.com Authorized Title: 9 Authorized Signature: 1/11" Date: &I iy{1 v Contact Phone: (907)265-6525 v-1-2- [ ` ! p /i�Jki p Form 10-404 Revised 4/2017 ` CO�=/ y RBD1 1 MS 1 (� ��i 1 4 [017 Submit Original Only ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 RECEIVED June 8, 2017 JUN 14 2011 AOGCC Commissioner AOGCC State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3H-22L1-02 (PTD# 216-1470). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed 1 • • 3H-22L1-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 6/6/17: OPEN WELL. RETURN TO SERVICE 5/27/17: LOAD IA W/225 BBL'S INHIBITED SW&65 BBL'S DIESEL FREEZE PROTECT. SET DV @ 9517' RKB. MIT IA TO 3000 PSI, PASS. 5/26/17: MEASURED BHP @ 9717' RKB (2763 psi) PULLED OV @ 5598' RKB. SET DV @ SAME. PULLED GLV @ 3246' RKB. SET DV @ SAME, DRAW DOWN TEST GOOD. PULLED DV @ 9517' RKB. READY TO LOAD IA, SBHP OF 2,763 PSI MEASURED. 5/22/17: FREEZE PROTECT TUBING W/25 BBLS OF DIESEL. FREEZE PROTECT 3H-34 FLOWLINE W/ 11 BBLS OF DIESEL • KUP I0 • 3H-22 41, ConocoPh)llips Pz, i ;-, Well Attributes Max Angle&MD TD Alaska,Inc: ?°.,`-? Wellbore APW WI Field Name Wellbore Status ncl(°) MD(ttKB) Act Btm(tt(B) corwcoPhiohps- 501032009700 501032009700 KUPARUK RIVER UNIT INJ 60.15 5,100.00 10,234.0 ... Comment H2S(ppm) Date Annotation End Date K8-Grd(ft) Rig Release Date 3H-22,6/13/2017 9,31:25AM SSSV: None 240 4/30/2017 _Last WO: 3/20/2016 42.01 2/28/1988 Vertical schematic(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By End Date ." Last Tag:SLM 9,803.0 5/26/2016 Rev Reason:H2S,GLV C/O pproven 5/28/2017 HANGER;350 Casing Strings Casing Description OD(in) ID(in) Top(ttKB) Set Depth(BOB) Set Depth(ND)...WtlLen(I...Grade Top Thread J CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(BOB) Set Depth(BOB) Set Depth(TVD)... WtlLen(L..Grade Top Thread uw SURFACE 9 5/8 8.921 35.0 4,347.6 3,126.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(BOB) Set Depth(flKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread �,,`/--, n.r PRODUCTION 7 6.276 35.0 10,052.2 6,267.8 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(flKB) Set Depth(ft..Set Depth(TVD)(...Wt)IbKt) Grade Top Connection CONDUCTOR;36.0.115.0-4 TUBING RWO 2016 1 31/21 2.9921 35.01 9,586.81 5,984.61 9.301 L-80 'Top 8rd Mod Completion Details Nominal ID GAS LIFT;3,246.3 Top(flKB) Top(ND)(ftK0) Top Incl(°) Item Des Com (in) 35.0 35.0 0.09 HANGER McEvoy Gen III Tubing Hanger,MSDP-1-6.5-MS-3,7- 2.950 1/16"x 3-1/2"EUE 8rd Box x Box,3"H BPVG 9,574.2 5,976.9 52.65 LOCATOR Locator Sub,GBH-22(bottom of the locator spaced out 2.990 3.83') • 9,575.3 5,977.6 52.65 SEAL ASSY Seal Assembly,80-40 3.020 Tubing Description String Ma...ID(in) Top(BOB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) GradeITop Connection LOWER COMP RWO 41/2 3.958 9,578.3 9,736.0 6,075.3 12.60 L-80 STC SURFACE;SURFACE;35.04,347.6-. 2016 1 I 11 Completion Details Nominal ID GAS LIFT;5,596.911. Top(BOB) Top(ND)(BOB) Top Incl 0 Item Des Com (in) 9,578.3 5,979.4 52.65 PACKER 587-400 Model'F'Production Packer 4.000 9,581.6 5,981.4' 52.64 SBE 80-40 Seal Bore Extension(SBE) 4.000 9,591.0 5,987.1 52.62 XO Reducing Crossover,4-3/4"Stub Acme Box x 3-1/2"EUE 8rd Pin 2.970 9,639.7 6,016.7 52.57 NIPPLE Nipple,HES,2.813"X,SN:C-3562596 2.812 GAS LIFT;7,260.2ii a 9,651.6 6,023.9 52.56 PORTED Ported Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"STC 2.992 CROSSOVER Pin • 9,653.4 6,025.0 52.56 PORTED Ported Wearsox Joint,4-1/2",12.68,L-80,STC Box x 3.958 WEARSOX Mule Shoe GAS LIFT;8,576.8 II Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(flKB) (BOB) (°) Des Com Run Date ID lin) 9,697.0 6,051.5 52.52 Junk Catcher AVA CATCHER(2.73"x 35") 3/14/2017 0.000 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5"WHIPSTOCK(GENII DELTA). 10/6/2016 ' TOWS=9715,WHIPSTOCK ORIENTATION= GAS LIFT;9,517.214 330DEG,CCL TO TOP OF WHIPSTOCK=14.9', RA TAG @7.35 FROM TOP,WHIPSTOP OAL=12.97 • • Perforations&Slots Shot • LOCATOR;9,574.2 Top(ND) ' Btm(TVD) • Dens (shots/ Top(ttKB) Btm(flKB) (ttKB) (ttKB) Zone Date ft) Type Com 9,690.0 9,710.0 6,047.3 6,059.4 A-3,3H-22 8/11/1988 8.0 APERF 21/8 EnerJet;60 deg ph PACKER;9,5763` SEAL ASSY;9,575.3 9,716.0 9,736.0 6,063.1 6,075.3 A-2,3H-22 8/11/1988 8.0'APERF 21/8 EnerJet;60 deg ph SBE;9,581.6 9,754.0 9,774.0 6,086.2 6,098.4 A-1,3H-22 4/25/1988 4.0 IPERF SOS 4.5"Ultra P;120 X0 Reducing;9,591.0 - deg ph • Mandrel Inserts • St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ttKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 1- 3,246.3 2,509.1 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 NIPPLE;9,639.6 2 5,598.9 3,802.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 3 7,260.2 4,693.3 Camco .MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/15/2017 4 8,576.8 5,395.5 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 5 9,517.3 5,942.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/27/2017 PORTED CROSSOVER; 9,651.6 Notes:General&Safety End Date Annotation 4/28/1988 NOTE:Bad spot in 7"CSG 8257'-8281';Max 10=6.45';Tested to 2600psi w/10 ppg Brine. PORTED WEARSOX;9,653.4 yyyppp��e,At,�r 11/2/2010 NOTE:View Schematic w/Alaska Schemabc9.0 Junk Catcher;9,697.0- APERF;9,690.0-9,710.0 ItI WHIPSTOC;9,715.0� • APERF;9,716.0-9,736.0-,. I L • !PERF;9,754.0-9,774.0- . II PRODUCTION;35.0-10,052.2 L1-03 Liner;9,714.0-12,000.0 • L KUP I • 3H-22L1 f ConocoPhillips 4 Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ttKB) Act Btm(ftKB) ,c,,,, Ptlmips 501032009760 KUPARUK RIVER UNIT INJ 99.31 10,800.66 11,751.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 3H-22L1,6/13/2017 9:32:14 AM SSSV: None 240 4/30/2017 Last WO: 3/20/2016 42.01 2/28/1988 ........ Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Rev Reason:ADD LATERALS 8 GLV C/O pproven 2/9/2017 HANGER;35.0 11 ' Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread [• • • L1 Liner 2 3/8 1.992 9,8)2.2 11,751.0 4.70 L-80 ST L • Liner Details .......... ..p.. ...,..,....,....,..�.......... Nominal ID .... _.IIIII Top(ttKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) ,� 9,812.2 6,104.3 79.00 Aluminum Aluminum Billet 0.000 Billet CONDUCTOR;36.0-115.o GAS LIFT;3,2463 II SURFACE;35.04,347.6— It GAS LIFT;5,596.9- • GAS LIFT;7,260.2 GAS LIFT;8,576.8 GAS LIFT;9.517.2 — LOCATOR;9,574.2 PACKER;9,578.3 SEAL ASSY;9,575.3 - SSE;9,561.6 telleirr ,11391 XO Reducing;9,591.0 *6 it NIPPLE;9,639.6 .72 PORTED CROSSOVER; 9,651.6 PORTED WEARSOX;9,653.4 _, Junk Catcher;9,697.0 I,illi I APERF;9,690.0-9,710.0—.--,I WHIPSTOC;9,715.0 iiL1-03 Liner;9,714.0-12,000.0 I! PRODUCTION;35.0-10,052.2` FJ I- II II L1 Liner;9,812.2-11,751.0 i KUP I0 -22L1-02 • Conoc©1 hit ips z Well Attributes Max Angle&MD TD Alaska.Inc, Wellbore APYUWI Field Name Wellbore Status ncl Cl MD(ftKB) Act Btm(ftKB) Cenci'tlitlips 501032009762 KUPARUK RIVER UNIT INJ 100.26 10,940.98 11,984.0 A y� Comment 112S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date • 3H-22L1-02,6/13/20179'.32:39 AM SSSV:None 240 4/30/2017 Last WO: 3/20/2016 42.01 2/28/1988 VeOcal schamabc(actual) ' Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Rev Reason:ADD LATERALS 8 GLV C/O pproven 2/9/2017 HANGER;35.0 6 7 II).: .l 1 Casing Strings L i Casing Description 00(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread J L1-02 Liner 2 3/8 1.992 10,049.7 11,984.0 4.70 L-80 STL Liner Details Nominal ID 1 Top(CAB) Top(TVD)(ftKB) Top Inc!C) Item Des Corn (in) 10,049.7 6,124.4 90.38 Aluminum OH Anchor 8 Aluminum Billet 1.920 Billet 8 Anchor CONDUCTOR;36.0-115.0 10,632.2 6,113.5 91.14 Deployment Shorty Deployment Sleeve Sleeve GAS LIFT;3,246.3---41 f SURFACE;359-4,347.6—., GAS LIFT;5,598.9 GAS LIFT;7,260.2-1 „i GAS LIFT;8,576.0 1 GAS LIFT;9,517.2 <_ LOCATOR;9,574,2 -S PACKER;9,578.3 SEAL ASSY;9,575.3 _ --�'P �SBE;9,581.8 X0 Reducing;9,5919 e: ) NIPPLE;9,639.6 4r 1 — ll PORTED CROSSOVER; 9,651.6 PORTED WEARSOX;9,653.4 Junk Catcher;9,897.0 '`,IIj/Ip APERF;9,6900-9,710.0—. ISI WHIPSTOC;9,715.0 1, APERF;9,716.0-9,736.0---., I I= IPERF;9,754.0-9,7740 . : ! -- I I L1-03 Liner;9,714.0-12,000.0 ' • PRODUCTION;35.0-10,052.2 {n` I I L1-02 Liner;10,049.7-11,984.0 re KUP I. -22L1-03 . ConocoPhillips 03 Well Attributes Max Angle&MD TD Alaska.Inc, WellboreAPI/UWI Field Name Wellbore Status ncl 01 MD(ftKB) Act Btm(ftKB) ConocoPhilgps 501032009763 KUPARUK RIVER UNIT INJ 101.16 10,170.57 12,000.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-22Lt-03,6/13/20179:33:08 AM SSSV: None 240 4/30/2017 Last WO: 3/20/2016 42.01 2/28/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ Rev Reason:ADD LATERALS 8 GLV C/O pproven 2/9/2017 , HANGER;35.0 �1;.'. 1 11ss -Casing Strings Casing Description OD(in) ID(in) Top(1108) Set Depth MOB) Set Depth(TVD)... WULen(I...Grade Top Thread 01-03 Liner 23/8 1.992 9,714.0 12,000.0 6,138.7 4.60 L-80 ST-L Liner Details au Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 01 Item Des Com (in) 9,714.0 6,061.9 52.52 Deployment Shorty Deployment Sleeve 1.000 Sleeve CONDUCTOR;36.0-1150 b. GAS LIFT;3,246.3 • SURFACE;35.0-4,347.6 GAS LIFT;5,598.9 GAS LIFT;7,260.2 GAS LIFT;8,576.8 GAS LIFT;9,517.2 LOCATOR;9,574.2 td PACKER;9,578.3 SEAL ASSY;9,575.3. t—WI• 581.6 I..1=f SBE ;e, li XO Reducing;9,591.0 �i t (I NIPPLE;9,639.6 I PORTED CROSSOVER; Y{ 9,651.8 PORTED WEARSOX;9,653.4 Junk Catcher;9,697.0 APERF;9,690.0-9,710.0r C_ WHIPSTOC;9,715.0 APERF;9,716.0-9,7360 I ` I IPERF;9,754.0-9,774.0--. II II PRODUCTION;35.0-10,052.2 • • L1-03 Liner;9,714.0-12,000.0 • ®F 74.1, 0 • 4i\'\1yy��s,, THE STATE Alaska Oil and Gas F .4 ofA T /\, SKA Conservation Commission .1E2 !�L. 333 West Seventh Avenue ' o- ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®1e. \ ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov Lynn Aleshire %OWED N 0 V 0 12017, Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-22L1-02 Permit to Drill Number: 216-147 Sundry Number: 317-161 Dear Ms. Aleshire: Enclosed is the approved application for 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, Ofa- -7 Daniel T. Seamount,Jr. Commissioner DATED this 1. day of April,2017. RBDMS tv✓ Psi - 3 2017 • • RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 0 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon H Plug Perforations LL Fracture Stimulate L1 Repair Well Li Operations shutdown LL Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ PROD to WAG H 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development H • 216-147-0 3.Address: 6.AP b r: 43 Stratigraphic ❑ Service ❑ 8 m_g £ i x_ ..� P.O.Box 100360,Anchorage,Alaska 99510 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No Q i KRU 3H-22L1-02 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25523, 25531 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): 11,984' 6,201' )j 'i t G32.01 ' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 4,313' 12" 4,348' 3,127' Intermediate Production 9,777' 7" 9,812' 6,104' Slotted Liner 1,934' 2.375" 11,984' 6,201' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted liner 10057-11984'MD. Slotted Liner 6127-6201'TVD 3.500" L-80 9,652' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No SSSV PACKER-587-400 MODEL'F'PRODUCTION PACKER , MD=9578 TVD=5979 12.Attachments: Proposal Summary ❑✓ Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/1/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Lynn Aleshire Contact Name: Lynn Aleshire Authorized Title: Petroleum Engineer Contact Email: Lynn.Aleshire@conocophillips.com r Contact Phone: (907)265-6525 Authorized Signature: Date: 4(�(II_/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31-7-t cQ t Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ t k'F. "4 (24 I1'x'1 Other: f t Post Initial Injection MIT Req'd? Yes krNo ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / r -÷C4. (/ f q RBDMS (, MA? - 3 2017 • pp APPROVED BY 4. (2, `f /7 Approved by. COMMISSIONER THE COMMISSION Date: 4 41/21//7' a6kVrI- ivz61 i _ �Form0 RAII 'I 10-403 Revised 4/2017 @ IC is valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. RECEIVED Anchorage, AK 99501-3448 APR 2 0 2017 April 21, 2017 AOGCC AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3H-22 and its associated laterals from Oil Production to Water Alternating Gas Injection service. This request for conversion will conclude the post-CTD pre-production period. Enclosed you will find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3H-22, 3H-22L1, 3H-22L1-02 and 3H-22L1-03 (PTD# 188-0110, 216-1450, 216-1470, 216-1480). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, 6/1 . Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary AOR Detail Area Map Well Schematic 1 • • 3H-22L1-02 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk River Unit Well 3H-22 and its associated laterals L1, L1-02 and L1-03 (PTD# 188-0110, 216-1450, 216-1470, 216-1480) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk River Unit Well 3H-22 and its associated laterals was completed as an injector on 1/20/17 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 3H-19, 3H-20 and associated laterals and 3H-21. The top of the A sand was found at 9690' MD/6047'TVD. Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset injector 3H-31 and producers 3M-29 and 3M- 29A, there are no additional production/injection wells located within a 1/4 mile radius of the 3H-22, 3H-22L1, 3H-22L1-02, 3H-22L1-03 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3H-22 is and its associated laterals is good and is classified as a "CTD horizontal triple-lateral"well. The injection tubing/casing annulus is isolated via a Baker F packer located at 9578' and (5979'tvd). A State-witnessed MIT-IA will be performed once well 3H-22 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: See attached AOR Detail The 16" Conductor was cemented with 250 Sx AS I. The 9-5/8" Surface casing was cemented with 1500 Sx AS III & 500 Sx Class G. The 7" Production casing was cemented with 1280 Sx Class G & 175 Sx AS I • 0 • • rcl 2 § k F{ k5 } \\ E E < . \ \\\ \,u \=\ k \ ) \/ �) / ®© ''.2— \s y/ ) \ / { {j { \;/ \� \\SI\ Lk1 \ \ \ W2,_ { _ _ L §Wo / e! , Ce q u_ £! ` (14 p Cr §_ Et /\ \ § ƒ � k , \{ \ } ( \ \ \O `:°1-' L. } , 2 : ADL355032 ADL025522 Aon 025 ADL025523 3r C 36'501 til ADL025524 4P Ant 025 J ON f ^ N. N N I2� zz 3 • Well Pad Top A Form Picks(ATDB) w N Producer:Oil CV INJ:MWAG A INJ:PW P+A Well Trajectory 3H-22 Open Interval ADL025631 3H-22L1 Open Interval ADL025531 -3H-22L1-02 Open Interval 3H -3H-22L1-03 Open Interval Q 3H-22 01 Quarter Mile Radius 3H-22L1 01 Quarter Mile Radius N ConocoPhillips 3H-22L1-02 01 Quarter Mile Radius Alaska,Inc. 3H-22L1-03 01 Quarter Mile Radius Other Active Well 3H_22 et al --- Other Inactive Well 0 0.2 0.4 0.6 0.8 Injection Sundry Miles CPAI Leases 4/1 3/201 7 • 0 3H-22 EOW CTD Schematic Modified by RLP 1/20/17 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-112"Camco MMG gas lift mandrels at 3246',5599', —.mil �'y'I I 7260',8577',9517'MD 16"62.5#H-40 Locator&80-40 seal assembly at 9574'MD shoe @ 115'MD Baker F packer at 9578'MD Baker 80-40 sealbore extension at 9582'MD J (2 3-112.813"HES"min landingID) nipple at 9640'MD 9-5f8"366J-55 4-1/2"BigTail Pipe 9653'-9736'MD shoe @ 4348'MD 4 3H-22L1-03WP07 TO©12.000'MD 9714'TOWS \ Liner top at 9714'MD 330°toolface b = .....- A-sand perfs3H-22L1-03P82 A3:9690'-9710' TD 11,090'MD A2:9716'-9736' Billet(Q 10,350'MD L. 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I fa. m cn OE 5� r N 1 1 Ilk GM N N C > a3 Y CO • m A c d v� Q CO N m c p ,� O. ° 43 a 0 Y CO •Ts - a Qci • E - N I o 2 0 I Z II 1 as as as n co 0 f0 f0 RI 0 D C Z N N N Co Co To0 - O LO O 10 0 0 E O O 7- rn co rn lE W E . 0 m N N N N ',.' m W O H N m r C. a) re p0. c = a) m CoFE I E ea 0 a� 4) W mCL O z L) 0 w c °� H Q o o � Q o 0 0 ii I C U U U U c �, Ci 5) a a) N .a 0 Co E 0 O 0 •'o 0 Q- a10i 0 E a o d 0 0 0 0 — LL o 2 o 0E oE E d a 2 w w w 3 i 0 a. 0 0 0 c ° 0 0 RECEIV D 21 6 1 4 PatO FEB 15 2017 2 7 9 8 1 BAKER PRINT DISTRIBUTION LIST HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. Tom Osterkamp DATA LOGGED /0"/201, WELL NAME 3H-22L1-02 700 G Street. M.K.sENDEr Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE January 19,2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(c�bakerhughes.com TODAYS DATE February 13,2017 Revision STATUS Final Replacement: No Details: Requested by: --- COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO)I LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF I'NIN I S #OF COPIES #OF COPIES #OF COPIES V 4 4 4 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 I 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 jAnchorage,AK 99503 4State of Alaska -AOGCC 1 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 I 1 I Attn:Resource Evaluation 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 6 BP Exploration(Alaska)Inc. I 1 I 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 I TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 r • co N N ■ M big; m Ct W o V N NV 0- 0 LL, O I W u- < d CC _ co O Y 0. co 0 w — W II a H ,, Q Z O .- ci. — s — . '_ cill A+ 0 7 N w Uc in cl- O _ O v R M O O L _ N C 0 r N O 2 7 N 1 4 _ V O a aN p CO 0 YYMi mCi M 0 0 • • 1®ct= `- .- ro w9 t Ihstuu io M O cr, LoC Lo N N r- oo OLo N O ti) C N N N N .O N C 0, cn u. 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O V M UM M O) CO Cr r O o D) Cr r W 0 N C CO N V UN.Q N r UN 0 0 N UN N pQV M M M N M co M M co co M N M oaay N N in L a' M O O Q a Y YO ` ` J J C N N N O r W M M m * O 0 ar0 co a 4 •� O 7 7C '-" O O co co N O) (0 7 N (0 (0 O ( (i �L U Y Y al I coi C °..• co m m m m r r r N- (o (o co COo CO EL a Q M O O U CO N O 0 M M M O 0 N 4 M N 0) 7 (O O) U) O O U) Oos o 0 0 0 Oi o 06 0 0 o O NO) N U) 0) 00 N 0 NOON 0 CO C c7A ` • cg. U) co N (O 1- r r (O (O CO (O 0) 0 0 c c mUgo. m = N oO _ ` c. d d d 7 n U a ( a Cn 03 0 • ',RECEIVED 21 61 4 7 27971 FEB 15 2017 Letter of Transmittal Eau AOGCC BAKER Date: DATA LOGGED February10 2017 z it6i2ot-T HUGHES ' K BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1H-16A 1H-16AL1PB1 1H-16AL1 3H-22L1 CD in 1 H-16A 216-159 27967 3H-22L1-02 3H-22L1-03PB1 CD in 3H-22L1 216-145 27970 3H-22L1-03PB2 CD in 2T-41L1 216-167 27975 3H-22L1-03 2T-41L1 2T-41L1-01 (10) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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N N c(;', (o 0 O C) O OD O) N C) W (0 n C) a S I 2 -C] O IU Ln CO Oi (O N CO ai co V co co • o Y Y i CO O O m m m N N N O O O O m Z pOp� k£ V ° G nitifiL 44,, 0 41 R7� CO'" n O 0 CO CO N0 0 0 InV ? i ' CO CO CO O V O O O O O o Ov NjQ 0 CO0 0 oOo0N0 0 O mNVO d nco (o (o N- N- N- co_ cow to m 0 oO a 0 .. s ° ` it; U a 'o d,- d d = Q 0 a 6 o h • • • • 3H-22 EOW CTD Schematic Modified by RLP 1/20/17 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Camco MMG gas lift mandrels at 3246',5599', 7260',857T,9517'MD � tttt� 16"62.5#H<0 Locator&80-40 seal assembly at 9574'MD shoe @ 115'MD Baker F packer at 9578'MD Baker 80-40 sealbore extension at 9582'MD 3-1/2"HES landing nipple at 9640'MD t (2.813"min ID) 9-5/8'36#J-55 shoe @ 4348'MD 4-1/2"Big Tail Pipe 9653'-9736'MD > 3H-22L1-03WP07 TD @ 12,000'MD 9714'TOWS - '\ Liner top at 9714'MD 330°toottace =_ - A-sand parts - •-- f 3H-22L1-03PB2 TD @ 11,090'MD A3'9690'-9710' 4 vim' Billet @ 10,350'MD A2:9716'-9738' _---- .._� Al:9754.-9774' E):; — 3H-222L1-03PB1 TD 11,072'MD Billet @ 10,195' 810,175'MD 3H-22L1-02 north TD @ 11,984'MD Billet @ 10,057'MD T 266 J-55 shoe @ 10,052'MD = _ - 3H-22L1 west - - TD @ 11,751'MD Billet @ 9,812'MD •0 erations Summary (with TimelogDepths) 3H-22 Corxx Pt imps �kxka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 1/2/2017 1/2/2017 2.50 MIRU MOVE MOB P PJSM w/Nabors crew,COP,and 00:00 02:30 PEAK, Move Pits and Sub off well, install jeeps,environmental walkdwon with DSO,called NSK security prior to departing 1H Pad 1/2/2017 1/2/2017 2.50 MIRU MOVE MOB P Move to 3H Pad 02:30 05:00 1/2/2017 1/2/2017 1.50 MIRU MOVE MOB P Hold at 1Q pad for C/O 05:00 06:30 1/2/2017 1/2/2017 3.00 MIRU MOVE MOB P Move from 1Q turnout to 3H pad 06:30 09:30 1/2/2017 1/2/2017 1.50 MIRU MOVE MOB P Spot drilling module 09:30 11:00 1/2/2017 1/2/2017 1.00 MIRU MOVE MOB P Spot Service module,trucks round trip 11:00 12:00 for shop and halfway house. 1/2/2017 1/2/2017 4.00 MIRU MOVE MOB P Lunch break,Rig up interconnect, 12:00 16:00 electrical,air and fluids. Take on fluid to the pits. 1/2/2017 1/2/2017 2.75 MIRU WHDBOP NUND P Nipple up BOP stack and double 16:00 18:45 check tree flange bolts,Change out, rig move checklist. 1/2/2017 1/2/2017 2.00 MIRU WHDBOP BOPE P PJSM,flood stack,shell test(pass) 18:45 20:45 ***Rig Accepted at 18:45'"" 1/2/2017 1/3/2017 3.25 MIRU WHDBOP BOPE P Initial BOP test(witnessed by AOGCC 20:45 00:00 Guy Cook),started 18:45 1/3/2017 1/3/2017 3.00 MIRU WHDBOP BOPE P Continue BOP test 00:00 03:00 1/3/2017 1/3/2017 4.00 MIRU WHDBOP BOPE P Filling coil with SW at min rate, 03:00 07:00 generator went down,brought a 2nd generator online,and both went down, back online,continue filling coil. Test IRV,failing due to air in the system, AOGCC witness left at 06:45,purge reel,retest IRV w/out AOGCC Witness. 1/3/2017 1/3/2017 4.50 MIRU WHDBOP OTHR T Waiting on Partner Approval to 07:00 11:30 continue operations Crews working on rig repair and maintenance projects. 1. Replaced 1/4"hydraulic injector brake manifold fitings w/1/2"fittings 2. Isolated and repaired accumulator system hydraulic leak;disassembled, retaped and tightend fittings, reassembled 3.Dissassembled O.D.S.BOP Stack, 2-3/8"external bonnet and replaced leaking rod seal,reassembled bonnet 1/3/2017 1/3/2017 4.00 MIRU WHDBOP OTHR T 4.Repair damaged square tubing on 11:30 15:30 level wind 5.Replaced J-Boxes on injector head transducers 6.Pressure test PDL's 1/3/2017 1/4/2017 8.50 MIRU WHDBOP OTHR T Prep traveling blocks for counter 15:30 00:00 weights,bring 5 weights up to rig floor. Updates to rig move checklists&rig move procedures.House keeping on rig&in shop Page 1/17 Report Printed: 1/24/2017 • Operations Summary (with Timelog Depths) 3H-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB):, End Depth(ftKB) 1/4/2017 1/4/2017 1.00 MIRU WHDBOP OTHR T Continue top-drive counter weight 00:00 01:00 installation project 1/4/2017 1/4/2017 5.00 MIRU WHDBOP OTHR T Continue housekeeping.Build well in 01:00 06:00 Cerberus. 1/4/2017 1/5/2017 18.00 MIRU WHDBOP OTHR T 1.Install counter weights on traveling 06:00 00:00 blocks-GBH welder fabricated and installed hardware and brackets for counter weights,installed 1 x 1200 lb weight,Nabors engineering looking at the remaining 5 weights. 2.Rig Electrician repaired damaged wires and broken J-Box on injector head 3.Central Shops Insulators came out to take measurments to fabricate insulation blankets for the interconnect in the PUTZ utility module. 4.Fabricate and install improved safety rail on 3rd floor bridge between Pits and sub. 5.Remove remaining counter weights from rig floor back to shop. 6.Continue with general housekeeping 1/5/2017 1/5/2017 5.50 MIRU WHDBOP OTHR T Perform rig maintenance projects and 00:00 05:30 general housekeeping. 1/5/2017 1/6/2017 18.50 MIRU WHDBOP WAIT T Phase III weather conditions. 05:30 00:00 1/6/2017 1/6/2017 5.50 MIRU WHDBOP WAIT T Phase Ill weather conditions lifted at 00:00 05:30 05:30, Currently Phase I on 3H-Pad and main roads. 1/6/2017 1/6/2017 3.50 MIRU WHDBOP WAIT T Discuss with town pulling BPV with no 05:30 09:00 KWF at rig. Decision to get valve crew to pull BPV and move forward with operations while waiting for KWF. Finish install of weights&brackets on travelling block while waiting for valve crew. 1/6/2017 1/6/2017 0.50 MIRU WHDBOP SFTY P Hold pre spud meeting with Nabors 09:00 09:30 Crew,Baker Inteq,MI Swaco,and COP 1/6/2017 1/6/2017 2.00 MIRU WHDBOP MPSP P Valve crew arrived @ 9:30,load 09:30 11:30 lubricator into pipe shed,PJSM,pull lubricator to the rig floor,RU,PT to 2500 psi,pull two-way check,RD lubricator,lower to the pipe shed. Clean&clear rig floor,prep for MU BHA. 1/6/2017 1/6/2017 2.80 PROD1 WHPST PULD P PJSM,MU BHA#1,Weatherford 1° 0.0 76.9 11:30 14:18 fixed bend motor,2.80"diamond mill and diamond string reamer,Pressure deploy,Tag up at surface and set depth 1/6/2017 1/6/2017 0.20 PROD1 WHPST TRIP P Start tripping in w/EDC open,line to 76.9 572.0 14:18 14:30 pump SW,taking returns to tiger tank, sat down at 88',saw WOB,closed EDC,feel like pushing something, possible ice in tbg,Eline tools stopped working,stop at 572 ft to troubleshoot CoilTrak, No power to tool,good electrical test to the collector at the reel. Page 2/17 Report Printed: 1/24/2017 • a Operations Summary (with Timelog Depths) r 3H-22 ConocoPhilliiss Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/6/2017 1/6/2017 0.80 PROD1 WHPST TRIP T Pull out to troubleshoot Eline,bump 572.0 76.9 14:30 15:18 up,space out 1/6/2017 1/6/2017 1.20 PROD1 WHPST PULD T PJSM, PUD,BHA#1,insulation test is 76.9 76.9 15:18 16:30 low, 1 mega ohm,continuity measures 80 ohms,powered up DH tool with test cable,tested good,inspect flow sub,looks normal,insulation and continuity re-tested the same 1/6/2017 1/6/2017 2.78 PROD1 WHPST PULD T LOTO reel,inspect pressure 76.9 76.9 16:30 19:16 bulkhead.After troubleshooting and re -packing the grease at the pressure bulkhead and the latest readings were 600 meg ohms with the continuity test at 72 ohms. 1/6/2017 1/6/2017 0.69 PROD1 WHPST PULD T Re-install BHA#1 and stab injector 76.9 76.9 19:16 19:58 after installing pull plate and passing pressure test. 1/6/2017 1/6/2017 0.35 PROD1 WHPST SFTY T Hold Pre-Spud meeting with Night 76.9 76.9 19:58 20:19 Shift Nabors crew,DD, MWD and Mud Engineer.After,hold PJSM for Pressure Deploying BHA#1. 1/6/2017 1/6/2017 0.70 PROD1 WHPST PULD T Pressure Deploy BHA#1 after holding 76.9 76.8 20:19 21:01 PJSM for Pressure Deploying BHA#1. Tag up and correct depth 1/6/2017 1/6/2017 0.58 PROD1 WHPST TRIP T RIH with open EDC. WOB rising 76.8 572.0 21:01 21:36 around 91' PUH....PUW=6.5k Stop at 86'. Shut down pump,close EDC. Bring pump online at.97 bpm RBIH. Make it past 91'with bit spinning and no WOB increases. 1/6/2017 1/6/2017 1.74 PROD1 WHPST TRIP P Continue RIH after opening up EDC 572.0 9,565.0 21:36 23:20 1/6/2017 1/6/2017 0.37 PROD1 WHPST DLOG P Log for K1 Marker and make 9,565.0 9,610.0 23:20 23:42 correction of+5 ft 1/6/2017 1/6/2017 0.20 PROD1 WHPST TRIP P Continue RIH 9,615.0 9,680.0 23:42 23:54 1/6/2017 1/7/2017 0.09 PROD1 WHPST DISP P Stop at 9,680.0 and complete the 9,680.0 23:54 00:00 tubing displacemenmt to drilling fluid. 1/7/2017 1/7/2017 0.60 PROD1 WHPST DISP P Stop at 9,680.0 and complete the 9,680.0 9,680.0 00:00 00:36 tubing displacemenmt to drilling fluid. Close EDC. 1/7/2017 1/7/2017 4.40 PROD1 WHPST WPST P RIH and tag TOWS©9,716.3 ft. 9,680.0 9,720.1 00:36 05:00 PUH and bring pump online at 1.5 bpm.Free spin established at 4,400 psi.RBIH and see motor work beginning at 9,716.69 ft. Time milling off of 3 1/2"x 4 1/2"TT WhipStock through 4 1/2"BTP TT and 7"casing. WOB= 1.30 klb, 1.5 bpm, Circ Press =4,528, Diff=635 Note:No fluid losses 1/7/2017 1/7/2017 5.20 PROD1 WHPST WPST P Time mill window at 1.49 bpm,4460 9,720.1 9,722.9 05:00 10:12 psi CT,390 psi WHP,640 to 740 psi on-bottom diff, 1.5 to 2.5k WOB Page 3/17 Report Printed: 1/24/2017 0 - Operations Summary (with Timelog Depths) P 3H-22 Conoco Phillips 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) 1/7/2017 1/7/2017 2.50 PROD1 WHPST WPST P After 15 min with no progress,pick-up 9,722.9 9,724.2 10:12 12:42 and increase pump rate to 1.75 bpm, 33K CT Wt,4462 psi CT,396 psi WHP,568 psi off bottom diff. OB milling parameters @ 1.75 bpm,4903 psi CT,377 psi WH,755 psi on- bottom diff,2.5 to 2.8k WOB. Saw WOB drop at 9724.2'at 12:41 pm,see formation in samples 1/7/2017 1/7/2017 3.30 PROD1 WHPST WPST P Continue to mill at 1 fph for 2 more 9,724.2 9,741.0 12:42 16:00 feet,increase ROP at 9726'to drill rat hole. 1/7/2017 1/7/2017 2.54 PROD1 WHPST REAM P Ream up/down at 1 fpm,3x at 330° 9,741.0 9,680.0 16:00 18:32 (as-drilled orientation). Back ream up only at 300°&360°ROHS. Dry drift with no weight bobbles. 1/7/2017 1/7/2017 2.44 PROD1 WHPST TRIP P After pumping a 10 x 10 sweep and it 9,680.0 109.8 18:32 20:58 is above the bit a bit,chase to surface. 1/7/2017 1/7/2017 1.08 PROD1 WHPST PULD P At surface. Hold PJSM.Pressure 109.8 109.8 20:58 22:03 Undeploy BHA#1. 1/7/2017 1/7/2017 0.62 PROD1 WHPST PULD P L/DBHA#1 109.8 0.0 22:03 22:40 Note:Both String Mill and Mill gauged at 2.79" 1/7/2017 1/7/2017 0.57 PROD1 DRILL PULD P P/U BHA#2,Drill Build Section 0.0 0.0 22:40 23:15 Assembly w/2.1°AKO 2 3/8"X-Treme Motor(10343026) and RB Hughes Christensen 2.74"x 3.0"Bi-Center Bit (7041614). 1/7/2017 1/8/2017 0.75 PROD1 DRILL PULD P Hold PJSM and Pressure Deploy BHA 0.0 110.7 23:15 00:00 #2 1/8/2017 1/8/2017 0.60 PROD1 DRILL PULD P Finish Pressure Deploying BHA#2 w/ 110.8 72.2 00:00 00:36 2.1°AKO 2 3/8"X-Treme Motor (10343026) and RB Hughes Christensen 2.74"x 3.0"Bi-Center Bit (7041614). Packoffs good.Tools tested good at surface.Tag up and make correction. 1/8/2017 1/8/2017 1.97 PROD1 DRILL TRIP P RIH with open EDC. 72.2 9,543.0 00:36 02:34 1/8/2017 1/8/2017 0.21 PROD1 DRILL DLOG P Log for K1 Marker and make 9,543.0 9,583.0 02:34 02:46 correction of+1 ft 1/8/2017 1/8/2017 0.19 PROD1 DRILL TRIP P Continue RIH,but with a closed EDC 9,583.0 9,741.0 02:46 02:58 now (closed EDC at 9,688 ft) 1/8/2017 1/8/2017 0.40 PROD1 DRILL DRLG P BOBD. 1.76 bpm, Circ Press-4,907, 9,741.0 9,795.0 02:58 03:22 WHP-448, Diff-654, WOB-1.66 klb, ROP-169 fph 1/8/2017 1/8/2017 0.58 PROD1 DRILL DLOG P PUH and log for the K1 Marker and 9,795.0 9,688.0 03:22 03:57 made a correction of+.5 ft and logged the RA at 9,721.3 ft which puts the TOWS at 9,714 ft. 1/8/2017 1/8/2017 1.74 PROD1 DRILL DRLG P BOBD. 1.76 bpm, Circ Press-4,889, 9,795.0 10,000.0 03:57 05:41 WHP-413, Diff-754, WOB-2.36 klb, ROP-162 to 188 fph Note: 10 x10 Sweep was pumped and timed to be out of bit when at TD Page 4/17 Report Printed: 1/24/2017 Operations Summary (with Timelo ttPths) 0-4 0 3H-22 ConocoPhitiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time e End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/8/2017 1/8/2017 0.40 PROD1 DRILL WPRT P Sweep pill out and above bit; start to 10,000.0 9,673.0 05:41 06:05 POOH. Stop at window to take pressure survey. Pumps off,close choke trap 1062 psi WHP,bleed CT pressure below WHP,monitor for 5 min,3862 psi BHP, 12.3 ppg EMW. 1/8/2017 1/8/2017 2.02 PROD1 DRILL TRIP P Open EDC,trip out of hole,perform 9,673.0 72.2 06:05 08:06 jog near surface,bump-up,space out to 68.25' 1/8/2017 1/8/2017 1.40 PROD1 DRILL PULD P PJSM,PUD BHA#2, 72.2 0.0 08:06 09:30 1/8/2017 1/8/2017 1.50 PROD1 DRILL PULD P Pick-up Weaterford 0.5°AKO motor, 0.0 74.8 09:30 11:00 RR HCC bi-center bit, MU BHA#3 and pressure deploy. Inspect pack- offs,pack-offs good. 1/8/2017 1/8/2017 1.70 PROD1 DRILL TRIP P Trip in with EDC open,pump 12.8 ppg 74.8 9,575.0 11:00 12:42 MP schedule 1/8/2017 1/8/2017 0.30 PROD1 DRILL DLOG P Log K1 marker,-4.5 ft correction 9,575.0 9,608.0 12:42 13:00 1/8/2017 1/8/2017 0.30 PROD1 DRILL TRIP P Close EDC,trip in to drill,weight 9,608.0 10,000.0 13:00 13:18 check above window,36K CW,clean ttrip thru window, 10.5k RIW. Tag EOB at 10002',PU and bring pumps to drilling rate 1.8 bpm,5260 psi CT, 452 psi WH,897 psi off-bottom. 1/8/2017 1/8/2017 0.60 PROD1 DRILL DRLG P Drilling, 1.80 bpm,5360psi CT,393 10,000.0 10,125.0 13:18 13:54 psi WH, 1053 psi diff,target 2.5k WOB,ROP 180 to 250 FPH ROP. 1/8/2017 1/8/2017 0.20 PROD1 DRILL WPRT P DD wiper trip,getting less than 10,125.0 10,125.0 13:54 14:06 expected DL,recalc survey,lower rate to 1.5 bpm,4450 psi CT,350 psi WH, 652 psi off-btm diff 1/8/2017 1/8/2017 0.70 PROD1 DRILL DRLG P Drilling at 1.5 bpm,4861 psi CT,427 10,125.0 10,315.0 14:06 14:48 psi WH, 1297 psi on-btm diff, 1.2k WOB,ROP 330. PU W 34k,increase rate 1.7 bpm,crossed 1st fault early at 10310',stalled motor, PUW 44K 1/8/2017 1/8/2017 0.20 PROD1 DRILL WPRT P BHA wiper,start 5x5 sweep. 10,315.0 10,315.0 14:48 15:00 1/8/2017 1/8/2017 1.20 PROD1 DRILL DRLG P Drilling at 1.7 bpm,5460 psi CT,457 10,315.0 10,450.0 15:00 16:12 psi WH, 1209 psi on-btm diff,2.2k WOB,ROP 250 1/8/2017 1/8/2017 0.60 PROD1 DRILL WPRT P Wiper trip#1,PUW 34k,start 5x5 10,450.0 10,450.0 16:12 16:48 sweep. 1/8/2017 1/8/2017 3.10 PROD1 DRILL DRLG P Drilling at 1.80 bpm,5470 psi CT,378 10,450.0 10,900.0 16:48 19:54 psi WH, 1140 psi on-btm, 1.75K WOB, ROP 120 to 160 fph Performed several BHA wiper trips 1/8/2017 1/8/2017 0.86 PROD1 DRILL WPRT P Wiper trip#2,PUW 35k,start 5x5 10,900.0 10,900.0 19:54 20:46 sweep. Turn around at 9,800 ft.RBIH at reduced pump rate until out of build section. 1/8/2017 1/8/2017 2.90 PROD1 DRILL DRLG P BOBD at 1.8 bpm,5650 psi CT,380 10,900.0 11,350.0 20:46 23:40 psi WH, 1224 psi on-btm diff, 1.8k WOB,ROP 160 to 220 fph 1/8/2017 1/9/2017 0.33 PROD1 DRILL WPRT P Wiper trip#3 to the window PUW 37k, 11,350.0 10,080.0 23:40 00:00 start 5x5 sweep. Page 5/17 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) -.' 3H-22 h3.y. Co RJB ■ifilps 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(ftKS) 1/9/2017 1/9/2017 0.85 PROD1 DRILL WPRT P Continue performing wiper/tie-in trip 10,080.0 11,350.0 00:00 00:51 to window/RA. Tie-In at RA was+4 ft. 1/9/2017 1/9/2017 3.76 PROD1 DRILL DRLG P BOBD at 1.8 bpm,5640 psi CT,396 11,350.0 11,750.0 00:51 04:36 psi WH,990 psi on-btm diff, 1.8k WOB,ROP 80 to 160 fph Performed several BHA wiper trips 1/9/2017 1/9/2017 2.00 PROD1 DRILL TRIP P After 10 x 10 Hi/Lo Vis pill above bit, 11,750.0 9,703.0 04:36 06:36 chase out of hole to swab valve. Perform several jogs at 4 1/2"TT, circulate 1X BU. Stop at window, 9703'to get pressure survey,pumps off,closed choke,bled 50 psi off 3x and BHI annular pressure built to 4038 psi in 5 min each time,***13.0 ppg EMW*** 1/9/2017 1/9/2017 1.80 PROD1 DRILL TRIP P Continue trip out to swab 9,703.0 74.8 06:36 08:24 1/9/2017 1/9/2017 1.70 PROD1 DRILL TRIP P Trip in hole 74.8 9,575.0 08:24 10:06 1/9/2017 1/9/2017 0.20 PROD1 DRILL DLOG P Tie-in to K1,-7'correction, 9,575.0 9,600.0 10:06 10:18 1/9/2017 1/9/2017 0.50 PROD1 DRILL SRVY P Trip inand stop with DPS sub at 9,600.0 9,760.0 10:18 10:48 window. Stop for repeat pressure survey,per town. Bring pump rate up to get BHP to 4050 psi,pumps off, closed choke and monitored for 15 min, BHP stable at 4062 psi***12.9 ppg EMW*** 1/9/2017 1/9/2017 1.10 PROD1 DRILL TRIP P Close EDC,trip in clean. Tag TD at 9,760.0 11,751.0 10:48 11:54 11751' 1/9/2017 1/9/2017 2.00 PROD1 DRILL DISP P POOH laying in liner running pill, 13.1 11,751.0 5,294.0 11:54 13:54 ppg w/2%Lo-Torq,2%776 lubes, and 2 ppb beads,swap to 13.1 ppg K- Formate KWF w/0.6%Safe Lube. Paint yellow EOP flag at 9760',paint white EOP flag at 7600' 1/9/2017 1/9/2017 1.00 PROD1 DRILL CIRC P Stop at 5294',inlet MM density 5,294.0 5,294.0 13:54 14:54 dropped to 12.91 ppg,check MW,add ssacks to bring MW up to13.1 ppg, circulate a coil volume before pulling up hole. 1/9/2017 1/9/2017 1.30 PROD1 DRILL TRIP P Continue POOH,micro motion 5,294.0 74.8 14:54 16:12 IN/OUT density dropped when started moving coil,checking MW at pits getting 1.3 ppg,possible restricted suction screen causing inlet density to drop,appears to track pump rate. 1/9/2017 1/9/2017 0.60 PROD1 DRILL OWFF P At surface,begin 30 min flow check at 86.1 0.0 16:12 16:48 16:16 PM,good test. 1/9/2017 1/9/2017 1.00 PROD1 DRILL PULD P LD BHA#3 0.0 0.0 16:48 17:48 1/9/2017 1/9/2017 1.20 COMPZ1 CASING PUTB P Clean&clear rig floor,prep liner 0.0 0.0 17:48 19:00 running equipment,crew handover, PJSM, 1/9/2017 1/9/2017 3.50 COMPZ1 CASING PUTB P MU solid bullnose,63 joints of 2-3/8", 0.0 1,938.9 19:00 22:30 slotted liner. Well Control drill,kick while running liner,PU safety joint and RIH Page 6/17 Report Printed: 1/24/2017 40 •1,0 ., , erations Summary (with Timelog Depths) 3H-22 C ► niti'ps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/9/2017 1/10/2017 1.49 COMPZ1 CASING PULD P PJSM,LD safety joint, MU BHA#4; 1,938.9 1,983.9 22:30 00:00 liner top billet,GS,knuckle and Baker Inteq.Surface test good,tag up at surface,set depth. 1/10/2017 1/10/2017 1.50 COMPZ1 CASING RUNL P Deploy liner in hole 1,983.9 9,584.0 00:00 01:30 1/10/2017 1/10/2017 0.25 COMPZ1 CASING RUNL P Correct to the EOP flag minus 12.0', 9,584.0 9,584.0 01:30 01:45 PUW 43 k,RIW 1/10/2017 1/10/2017 0.75 COMPZ1 CASING RUNL P Continue RIH,set down 11297", -10 9,584.0 11,751.0 01:45 02:30 k, PUW 47 k 1/10/2017 1/10/2017 0.25 COMPZ1 CASING RUNL P Bring pump up to 1.5 bpm,5,500 psi, 11,751.0 11,751.0 02:30 02:45 1.0 bpm returns,PUH,PUW 37 k, stop and remove liner length from counter 1/10/2017 1/10/2017 2.00 COMPZ1 CASING TRIP P POOH,pumping 1.0 bpm,3,590 psi 11,751.0 45.0 02:45 04:45 1/10/2017 1/10/2017 0.50 COMPZ1 CASING OWFF P Check well for flow,PJSM 45.0 45.0 04:45 05:15 1/10/2017 1/10/2017 0.75 COMPZ1 CASING PULD P LDBHA#4 45.0 0.0 05:15 06:00 1/10/2017 1/10/2017 1.00 PROD2 STK BOPE P Crew change,perform bi weekly 0.0 0.0 06:00 07:00 BOPE function test-Check reel saddle clamps 1/10/2017 1/10/2017 1.50 PROD2 STK PULD P PJSM, P/U BHA#5,L1-02 Kick off 0.0 74.7 07:00 08:30 and drill with RR HYC bi center and .43°WFT Motor,Service checks and packoffs,Make up to coil and surface test 1/10/2017 1/10/2017 2.00 PROD2 STK TRIP P RIH,EDC open 74.7 9,575.0 08:30 10:30 1/10/2017 1/10/2017 0.20 PROD2 STK DLOG P Log K1 for-7.5'correction 9,575.0 9,597.0 10:30 10:42 1/10/2017 1/10/2017 0.10 PROD2 STK TRIP P Continue in well to 9710 9,597.0 9,710.0 10:42 10:48 1/10/2017 1/10/2017 1.00 PROD2 STK CIRC P Displace well to 8.8PPG flow Pro 9,710.0 9,710.0 10:48 11:48 1/10/2017 1/10/2017 0.20 PROD2 STK TRIP P Closed EDC and trip in,Dry tag TOB 9,710.0 9,812.0 11:48 12:00 @ 9812 1/10/2017 1/10/2017 2.10 PROD2 STK KOST P PUH bring pumps online @ 1.6 BPM 9,812.0 9,814.0 12:00 14:06 @ 4465 PSI FS,BHP=4088,TF=30R. Get right on billet with one stall 1/10/2017 1/10/2017 0.30 PROD2 DRILL DRLG P Go to 1K DHWOB,Drill ahead,1.6 9,814.0 9,850.0 14:06 14:24 BPM @ 4465 PSI FS,BHP=4105 1/10/2017 1/10/2017 0.10 PROD2 DRILL WPRT P PUH past billet,clean up and down, 9,850.0 9,850.0 14:24 14:30 PUW=35K 1/10/2017 1/10/2017 3.00 PROD2 DRILL DRLG P 9850',Drill ahead. 1.85 BPM @ 4950 9,850.0 10,300.0 14:30 17:30 PSI FS,BHP=4170 1/10/2017 1/10/2017 1.00 PROD2 DRILL WPRT P 10300',wiper to window with static 10,300.0 10,300.0 17:30 18:30 pressure survey(13 ppg at window), PUW=36K 1/10/2017 1/10/2017 3.25 PROD2 DRILL DRLG P Drilling at 1.78 bpm(circ.pressure at 10,300.0 10,750.0 18:30 21:45 5540 psi),CWT=3.7k, DHWOB=2K, BHP=4253 psi,differential=1266 psi,MW in=8.85 ppg,MW out=8.93 PP9. **Encountered high gamma interval beginning at 10,706'MD Page 7/17 Report Printed: 1/24/2017 ,' !erations Summary (with Timelog tpths) Af- 3H-22 ConocoPhillips 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(ftKE) 1/10/2017 1/10/2017 0.25 PROD2 DRILL WPRT P Wiper-trip uphole,PUW=35K 10,750.0 9,839.0 21:45 22:00 1/10/2017 1/10/2017 0.50 PROD2 DRILL WPRT P Wiper-trip downhole,RIW=7K 9,839.0 10,750.0 22:00 22:30 1/10/2017 1/11/2017 1.50 PROD2 DRILL DRLG P Drilling at 1.78 bpm(circ pressure at 10,750.0 10,875.0 22:30 00:00 5475 psi),CWT=3K,DHWOB= 1.6K,BHP=4215 psi,differential= 1125 psi,MW in=8.89 ppg,MW out= 8.95 ppg. **Began increasing inclination at -10,750'MD to determine location within gelology(currently 95 degrees). "PU at 10,800'MD,PUW 36.5K **High gamma interval believed to be Miluveach 1/11/2017 1/11/2017 1.50 PROD2 DRILL DRLG P Drilling at 1.75 bpm(circ pressure at 10,875.0 11,000.0 00:00 01:30 5462 psi),CWT=3.2K,DHWOB= 1.4K, BHP=4253 psi,differential= 1151 psi,MW in=8.87 ppg,MW out= 8.95 ppg,inclination=99 degrees 1/11/2017 1/11/2017 0.50 PROD2 DRILL WPRT P Wiper-trip uphole,PUW=37.8K off 11,000.0 9,737.0 01:30 02:00 bottom,no heavy pulls observed through high gamma interval(10,706'- 10,760'MD) 1/11/2017 1/11/2017 0.50 PROD2 DRILL WPRT P Wiper-trip downhole,RIW=7k,little 9,737.0 11,000.0 02:00 02:30 issue RBIH. 1/11/2017 1/11/2017 2.25 PROD2 DRILL DRLG P Drilling at 1.8 bpm(circ pressure of 11,000.0 11,250.0 02:30 04:45 5641 psi),CWT=2.8K,DHWOB= 2K,BHP=4203 psi,differential= 1290 psi,MW in=8.9 ppg, MW out= 8.98 ppg. 1/11/2017 1/11/2017 0.70 PROD2 DRILL WPRT P Wiper to 10250',PUW=39K,Clean trip 11,250.0 11,250.0 04:45 05:27 up and down 1/11/2017 1/11/2017 2.60 PROD2 DRILL DRLG P 11250', Drill, 1.8 BPM @ @ 5291 PSI 11,250.0 11,511.0 05:27 08:03 FS,BHP=4262 1/11/2017 1/11/2017 0.70 PROD2 DRILL WPRT P 11511', Wiper to 10,600, PUW=39K, 11,511.0 11,511.0 08:03 08:45 Slight bobble RIH in high gamma area,No set down 1/11/2017 1/11/2017 1.70 PROD2 DRILL DRLG P 11511',Drill ahead, 1.7 BPM @ 5210 11,511.0 11,641.0 08:45 10:27 PSI FS,BHP=4235 1/11/2017 1/11/2017 4.90 PROD2 DRILL DRLG P BHA Wiper,PUW=42K,Definate 11,641.0 11,734.0 10:27 15:21 drilling break,Ratty drilling 11640 through 11,700'. Poor weight transfer. Multiple pick ups,BHA wiper.Pump sweeps-try different pump rates. High gamma areas 1/11/2017 1/11/2017 0.80 PROD2 DRILL DRLG P Swap mud new mud at bit @ 11734. 11,734.0 11,761.0 15:21 16:09 System 1 out with 1922'drilled..9% DS 1/11/2017 1/11/2017 0.85 PROD2 DRILL WPRT P 11761',Wiper to 10650,Clean trip up, 11,761.0 11,761.0 16:09 17:00 set down @ 10734 @ 1.8 BPM. reduced rate to 1.4 and cleaned up area.Bobble @ 10750-no set down 1/11/2017 1/11/2017 3.00 PROD2 DRILL DRLG P Drilling ahead at 1.58 bpm(circ 11,761.0 11,980.0 17:00 20:00 pressure=4852 psi),CWT=-2K, DHWOB=2.5K, BHP=4333 psi.TD called at 11,980'MD Page 8/17 Report Printed: 1/24/2017 • • Operations Summary (with Timelog Depths) ;2 3H-22 Cc nocoPhiiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start TameEnd Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/11/2017 1/11/2017 3.00 PROD2 DRILL TRIP P Pump 10 x10 sweep and chase to 11,980.0 74.7 20:00 23:00 swab,jog 4-12"BTP. 1/11/2017 1/12/2017 1.00 PROD2 DRILL TRIP P Begin RBIH from swab valve to 74.7 4,750.0 23:00 00:00 confirm TD. 1/12/2017 1/12/2017 0.80 PROD2 DRILL TRIP P Continue RIH to confirm TD. 4,750.0 9,555.0 00:00 00:48 1/12/2017 1/12/2017 0.20 PROD2 DRILL DLOG P Tie into K1 marker for-4.5'correction 9,555.0 9,603.0 00:48 01:00 1/12/2017 1/12/2017 1.50 PROD2 DRILL TRIP P Closed EDC,continue to RIH to 9,603.0 11,984.0 01:00 02:30 confirmed TD of 11984'MD. Stacked weight while RIH: 2.4K at 10762'MD 2.8K at 11720'MD 3.6K at 11727'MD 4.7K at 11743'MD(reduce rate to.5 bpm to get by) 1/12/2017 1/12/2017 0.25 PROD2 DRILL TRIP P POOH,laying in liner running pill 11,984.0 11,909.0 02:30 02:45 1/12/2017 1/12/2017 0.25 PROD2 DRILL TRIP T Bore and WH pressure begin to spike 11,909.0 11,908.0 02:45 03:00 at-11908'MD.Suspect choke A packed off,line-up to choke B. Pressures return to normal levels. 1/12/2017 1/12/2017 3.00 PROD2 DRILL TRIP P Continue POOH laying in liner running 11,908.0 70.0 03:00 06:00 pill and KWF to surface. Paint EOP flags at 10655'& 8275'MD 1/12/2017 1/12/2017 0.50 PROD2 DRILL OWFF P Tag up at surface,perform 30 Min No 70.0 70.0 06:00 06:30 flow test-Good test 1/12/2017 1/12/2017 1.00 PROD2 DRILL PULD P PJSM,lay down BHA#5 on dead well 70.0 0.0 06:30 07:30 1/12/2017 1/12/2017 0.40 COMPZ2 CASING PULD P Prep floor to run liner 0.0 0.0 07:30 07:54 1/12/2017 1/12/2017 2.50 COMPZ2 CASING PUTB P M/U L1-02 lower liner segment,Non 0.0 1,351.3 07:54 10:24 ported bull nose,44 Jts slotted liner, and shorty deployment sleeve 1/12/2017 1/12/2017 1.00 COMPZ2 CASING PULD P M/U BHA#6 liner running tools to top 1,351.3 1,396.0 10:24 11:24 of liner,surface test tools,Tag up and set depth 1/12/2017 1/12/2017 1.90 COMPZ2 CASING TRIP P Trip in hole,BHA#6,EDC closed 1,396.0 9,606.0 11:24 13:18 1/12/2017 1/12/2017 0.10 COMPZ2 CASING DLOG P Tie into 8200'EOP flag for-10', 9,606.0 9,596.0 13:18 13:24 PUW=40K,DHWOB=-5K 1/12/2017 1/12/2017 1.60 COMPZ2 CASING RUNL P Continue in well,Clean pass through 9,596.0 11,983.0 13:24 15:00 window,Had to work liner 10730 area and 11650 area.PUW=49K 1/12/2017 1/12/2017 0.50 COMPZ2 CASING TRIP P Bring pumps online, 1.45 BPM, 11,983.0 9,540.0 15:00 15:30 PUW=35K,Remove liner length left in hole from counters,Trip out 1/12/2017 1/12/2017 0.20 COMPZ2 CASING DLOG P 9540 log K1 for+5'correction.Started 9,540.0 9,567.0 15:30 15:42 taking weight @ 11980.5. BOL=10984.5,TOL=10632 1/12/2017 1/12/2017 2.30 COMPZ2 CASING TRIP P Continue out of well,Paint 9000'EOP 9,567.0 41.0 15:42 18:00 flag 1/12/2017 1/12/2017 0.50 COMPZ2 CASING OWFF P Tag up at surface,perform 30 Min No 41.0 41.0 18:00 18:30 flow test-Good test.PJSM 1/12/2017 1/12/2017 0.50 COMPZ2 CASING PULD P LD L1-02 Lower Liner Running 41.0 41.0 18:30 19:00 Assembly,BHA#6 Page 9/17 Report Printed: 1/24/2017 a 0 Operations Summary (with TimelogDepths) Int 3H-22 Conocormiril Rk€kap 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) 1/12/2017 1/12/2017 1.75 COMPZ2 CASING PUTB P MU L1-02 Upper Liner Running 41.0 643.0 19:00 20:45 Assembly, BHA#7.Ported bull-nose, 18 joints slotted liner,two 6'pup joints, OH anchor&aluminum billet 1/12/2017 1/12/2017 2.25 COMPZ2 CASING RUNL P RIH with Upper Liner Assembly 643.0 9,650.0 20:45 23:00 1/12/2017 1/12/2017 0.10 COMPZ2 CASING DLOG P Tie into EOP pipe flag,minus 7' 9,650.0 9,650.0 23:00 23:06 1/12/2017 1/12/2017 0.55 COMPZ2 CASING RUNL P Continue RIH with liner assembly, 9,650.0 10,145.0 23:06 23:39 close EDC 1/12/2017 1/12/2017 0.10 COMPZ2 CASING DLOG P Tie into K1 Marker for+2'correction. 10,145.0 10,164.0 23:39 23:45 1/12/2017 1/13/2017 0.25 COMPZ2 CASING RUNL P Continue RIH with liner assembly. 10,164.0 10,635.0 23:45 00:00 Stacking 7K WOB at window,orient TF and work past. 1/13/2017 1/13/2017 0.25 COMPZ2 CASING RUNL P Check PUW=35K,pressure up to 10,635.0 10,635.0 00:00 00:15 5200 psi&set anchors at 30 degrees ROHS.TOB at 10,050'MD 1/13/2017 1/13/2017 0.25 COMPZ2 CASING TRIP P POOH to LD BHA#7 10,635.0 9,697.0 00:15 00:30 1/13/2017 1/13/2017 0.50 COMPZ2 CASING RGRP T Pack-offs not holding pressure. 9,697.0 9,697.0 00:30 01:00 Decision made to stop in cased hole and replace as per Nabors procedure. PJSM,monitor well for flow,shut in annular,replaced pack-offs.New pack -offs holding pressure. 1/13/2017 1/13/2017 2.25 COMPZ2 CASING TRIP P Continue POOH,tag up at surface. 9,697.0 55.0 01:00 03:15 1/13/2017 1/13/2017 0.50 COMPZ2 CASING OWFF P Perform 30 minute flow check,PJSM 55.0 55.0 03:15 03:45 1/13/2017 1/13/2017 0.70 COMPZ2 CASING PULD P LD BHA#7. 55.0 0.0 03:45 04:27 1/13/2017 1/13/2017 0.55 PROD3 STK SVRG P Check chokes and micor motion blow 0.0 0.0 04:27 05:00 down 1/13/2017 1/13/2017 1.00 PROD3 STK PULD P PJSM,P/U Drilling BHA#8 with.5° 0.0 75.0 05:00 06:00 WFT Motor and new Hughes bi center bit.Make up to coil and surface test 1/13/2017 1/13/2017 1.90 PROD3 STK TRIP P Trip in well,EDC open 75.0 9,576.0 06:00 07:54 1/13/2017 1/13/2017 0.10 PROD3 STK DLOG P Log K1 for+4'correction 9,576.0 9,603.0 07:54 08:00 1/13/2017 1/13/2017 0.10 PROD3 STK TRIP P Continue in well 9,603.0 9,690.0 08:00 08:06 1/13/2017 1/13/2017 2.40 PROD3 STK CIRC P Stop above window displace to 9,690.0 9,690.0 08:06 10:30 8.8PPG Flo Pro 1/13/2017 1/13/2017 0.30 PROD3 STK TRIP P Close EDC,Trip in.Clean pass 9,690.0 10,057.0 10:30 10:48 through window,Dry tag TOB @ 10057 1/13/2017 1/13/2017 0.60 PROD3 STK KOST P Bring pumps online, 1.6 BPM @ 4570 10,057.0 10,057.0 10:48 11:24 PSI FS,BHP=4195 1/13/2017 1/13/2017 0.50 PROD3 STK RGRP T Trouble shoot MWD computer,Wipe 10,057.0 10,057.0 11:24 11:54 uphole to 9017 1/13/2017 1/13/2017 1.80 PROD3 STK KOST P Mill off Billet, 1.7 BPM @ 4596 PSI 10,057.0 10,070.0 11:54 13:42 FS,BHP=4166,Stall 6 times to get on billet.time mill from 10056.4 to 10070' Page 10/17 Report Printed: 1/24/2017 • ," �erations Summary (with Timelog Depths) t Operations tR .. 3H-22 ConocoPhititps 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) 1/13/2017 1/13/2017 0.30 PROD3 DRILL DRLG P 10070'Drill ahead, 1.68 BPM @ 4596 10,070.0 10,090.0 13:42 14:00 PSI FS,BHP=4198,ROP=80FPH 1/13/2017 1/13/2017 0.20 PROD3 DRILL WPRT P 10090',PUH dry drift billet area, 10,090.0 10,090.0 14:00 14:12 PUW=38K 1/13/2017 1/13/2017 4.30 PROD3 DRILL DRLG P 10090',drill ahead, 1.8 BPM @ 4720 10,090.0 10,510.0 14:12 18:30 PSI FS,BHP=4116,RIW=5.32 K, DHWOB=1.6K 1/13/2017 1/13/2017 0.50 PROD3 DRILL WPRT P Wiper-trip uphole, PUW=34.5K 10,510.0 9,850.0 18:30 19:00 1/13/2017 1/13/2017 0.50 PROD3 DRILL WPRT P Wiper-trip inhole,RIW=6.5K 9,850.0 10,510.0 19:00 19:30 1/13/2017 1/13/2017 1.75 PROD3 DRILL DRLG P Drill ahead at 1.78 bpm and 5525 psi 10,510.0 10,695.0 19:30 21:15 circ pressure,CWT=4.9K,WOB= 2.4K,BHP=4210 psi,dp=1072 psi, WHP=371. 1/13/2017 1/13/2017 1.25 PROD3 DRILL DRLG P Drilling ahead.Encountered high API 10,695.0 10,756.0 21:15 22:30 gamma iterval from-10695'-10756' MD(150-190 API) 1/13/2017 1/14/2017 1.50 PROD3 DRILL DRLG P Continue drilling ahead at 1.75 bpm at 10,756.0 10,910.0 22:30 00:00 5575 psi circ pressure.CWT=1.7K, WOB=2.7K,BHP=4212 psi,WHP= 319 psi,dp=1221 psi. 1/14/2017 1/14/2017 0.75 PROD3 DRILL DRLG P Drill ahead at 1.76 bpm and circ 10,910.0 10,959.0 00:00 00:45 pressure of 5735 psi,CWT=2.2K, WOB= 1.5K,BHP=4272 psi,dp= 1111 psi. 1/14/2017 1/14/2017 0.50 PROD3 DRILL WPRT P Wiper-trip uphole,heavy pull at 10894' 10,959.0 10,104.0 00:45 01:15 MD of 47.5K,then clean pull back to 34.5K 1/14/2017 1/14/2017 0.50 PROD3 DRILL WPRT P Wiper-trip inhole,RIW=7K off bottom. 10,104.0 10,959.0 01:15 01:45 1/14/2017 1/14/2017 3.00 PROD3 DRILL DRLG P BOBD at 1.78 bpm and circ pressure 10,959.0 11,025.0 01:45 04:45 of 5528 psi,CWT=4K,WOB=2K, BHP=4253 psi,dp=1012 psi. Shortly after BOBD,begin having difficulty maintaining WOB, requiring frequent PU's.CWT-4.8K,WOB =.3K,dp=730 psi, Inclination=99.7 degrees 1/14/2017 1/14/2017 1.50 PROD3 DRILL WPRT T Encountered high gamma area+210 11,025.0 9,690.0 04:45 06:15 perform geo wiper,PUW=39K 1/14/2017 1/14/2017 0.10 PROD3 DRILL DLOG T Log RA for-1'correction 9,690.0 9,745.0 06:15 06:21 1/14/2017 1/14/2017 0.90 PROD3 DRILL WPRT T RBIH to drill,Had to work down from 9,745.0 11,025.0 06:21 07:15 11,000'to TD @ 11,025 1/14/2017 1/14/2017 2.50 PROD3 DRILL DRLG T 11025',Drill, 1.8 BPM @ 5530PSI FS, 11,025.0 11,072.0 07:15 09:45 BHP=4350 1/14/2017 1/14/2017 2.50 PROD3 DRILL TRIP T 11,072',Trip out for OH Anchor billet, 11,072.0 65.0 09:45 12:15 PUW=40K,Jog tail pipe,Open EDC @9700' 1/14/2017 1/14/2017 3.00 PROD3 DRILL PULD T 65',Tag up and space out,PJSM PUD 65.0 0.0 12:15 15:15 BHA#8,During PDL pre load ops both PDL shieves frozen.Suspended pre load until injector could be parked out of way.Treat W/L shieves with methonal.Complete PUD Page 11/17 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) Pk`L .0 3H-22 CococoPhiiiaps 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) 1/14/2017 1/14/2017 1.70 PROD3 STK PULD T PJSM, PD BHA#9 OH anchored 0.0 72.8 15:15 16:57 billet, Inspect packoffs.M/U to BHA and surface test.Good test.Strip on well 1/14/2017 1/14/2017 2.55 PROD3 STK TRIP T Trip in hole EDC open,pump min rate, 72.8 9,606.0 16:57 19:30 tie in to K1 for a-7.5'correction,PUW =37K,close EDC in open-hole.Tie into K1 for-7.5'correction. 1/14/2017 1/14/2017 0.75 PROD3 STK TRIP T Continue RIH with OH anchor billet, 9,606.0 10,195.0 19:30 20:15 weight check PUW=39K.Bit depth of 10,206.75'puts TOB at 10,195'MD, anchor 180 degrees ROHS.Bring pumps up to 5000 psi and shear off anchor,setdown 3K on billet,begin POOH, PUW=36K. 1/14/2017 1/14/2017 2.00 PROD3 STK TRIP T POOH to LD BHA#9 10,195.0 63.0 20:15 22:15 1/14/2017 1/15/2017 1.75 PROD3 STK PULD T 63',tag up and space out,PJSM,PUD 63.0 0.0 22:15 00:00 BHA#9.Begin to LD BHA#9 1/15/2017 1/15/2017 0.25 PROD3 STK PULD T LDBHA#9 0.0 0.0 00:00 00:15 1/15/2017 1/15/2017 2.25 PROD3 STK PULD T PJSM,PU&PD BHA#10(.46 degree 0.0 75.0 00:15 02:30 Weatherford,HYC B8 bit).Check Pack offs,C/O UQC,strip on WH 1/15/2017 1/15/2017 1.75 PROD3 STK TRIP T RIH with BHA#10 to KO billet at 75.0 9,555.0 02:30 04:15 10,195'MD 1/15/2017 1/15/2017 0.25 PROD3 STK DLOG T Tie into K1 Marker for-8'correction 9,555.0 9,591.0 04:15 04:30 1/15/2017 1/15/2017 0.50 PROD3 STK TRIP T Conitnue RIH to KO billet.Dry tag 9,591.0 10,195.0 04:30 05:00 billet at 10195'MD 1/15/2017 1/15/2017 0.80 PROD3 STK KOST T PUH, Pumps on, 1.8 BPM @ 5250 10,195.0 10,199.0 05:00 05:48 PSI FS,2 stalls getting on 1/15/2017 1/15/2017 0.50 PROD3 STK KOST T 10199,Control drill 1K DHWOB, 1.77 10,199.0 10,208.0 05:48 06:18 BPM @ 5265 PSI FS, BHP=4105 1/15/2017 1/15/2017 0.30 PROD3 STK DRLG T Drill, 1.8 BPM @ 5390 PSI FS, 10,208.0 10,230.0 06:18 06:36 BHP=4190,ROP=78, DHWOB=1.8K, 2 stalls @ 10207 1/15/2017 1/15/2017 0.50 PROD3 STK WPRT T PUH to Drift billet area,Clean up and 10,230.0 10,347.0 06:36 07:06 down.RIH to 10238 with no motor work or WOB,PUH to discuss. RBIH to 10347 with no WOB or motorwork. Near bit at as drilled PB lateral. Observed res tool indicate passing billet @ 10199.Didn't appear to be pushing anything down hole. 1/15/2017 1/15/2017 2.30 PROD3 STK TRIP T Confer with town,Trip out for anchor 10,347.0 65.0 07:06 09:24 billet,Open EDC @ 9691 1/15/2017 1/15/2017 2.00 PROD3 STK PULD T Tag up space out,PJSM. PUD BHA 65.0 0.0 09:24 11:24 #10,Scribe tool string.All good 1/15/2017 1/15/2017 1.80 PROD3 STK PULD T PJSM,PD BHA#11,OH Anchor 0.0 72.0 11:24 13:12 billet,M/U to coil track and surface test tool 1/15/2017 1/15/2017 2.20 PROD3 STK TRIP T Trip in hole BHA#11 72.0 9,570.0 13:12 15:24 1/15/2017 1/15/2017 0.20 PROD3 STK DLOG T Log K1 for-6' 9,570.0 9,601.0 15:24 15:36 Page 12/17 Report Printed: 1/24/2017 Operations Summary (with Timelog ftths) 0 • 3H-22 ConocoPhilihps 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) 1/15/2017 1/15/2017 0.90 PROD3 STK TRIP T RIH to 9680,Shut EDC, PUW=38K, 9,601.0 10,186.9 15:36 16:30 Stack out twice @ 9750 PUH orient to 40 right.Increase tripping speed to 30 FPM and get through,Stop at set depth 11186.75,TOB=10175, Oriented to 180°,see tool shift at 5700 psi,Set down 5.5K.Lift off billet 1/15/2017 1/15/2017 2.00 PROD3 STK TRIP T Trip out,open EDC in cased hole. 10,186.9 65.0 16:30 18:30 1/15/2017 1/15/2017 1.50 PROD3 STK PULD T Tag up,space out. PJSM,PUD BHA 65.0 0.0 18:30 20:00 #11, 1/15/2017 1/15/2017 2.50 PROD3 STK PULD T PJSM,PU&PD BHA#12(.5 degree 0.0 75.0 20:00 22:30 Weatherford motor&RB HYC B8 Edge bit).C/O packoffs&UQC floats, MU QC,test MWD,strip on WH. 1/15/2017 1/16/2017 1.50 PROD3 STK TRIP T RIH with BHA#12 to KO billet at 75.0 7,895.0 22:30 00:00 10,175'MD 1/16/2017 1/16/2017 0.25 PROD3 STK TRIP T Continue to RIH to KO billet at 10,175' 7,895.0 9,555.0 00:00 00:15 MD. 1/16/2017 1/16/2017 0.25 PROD3 STK DLOG T Tie into K1 marker for-3'correction. 9,555.0 9,597.0 00:15 00:30 1/16/2017 1/16/2017 0.50 PROD3 STK TRIP T Continue to RIH to KO billet at 10,175' 9,597.0 10,175.0 00:30 01:00 MD,clean through window. 1/16/2017 1/16/2017 5.30 PROD3 STK KOST T Tag TOB at 10,175"MD. PUH to 10,175.0 10,193.0 01:00 06:18 10,165',bring up pumps to 1.35 bpm and begin KO billet 150 degrees ROHS.Continual stalls getting re- started on billet at 10,177'MD. 1/16/2017 1/16/2017 0.80 PROD3 DRILL WPRT T 10193',Dry drift billet area,Tag up @ 10,193.0 10,193.0 06:18 07:06 10178 with stall twice.S/D pumps and go right through, PUW=40K 1/16/2017 1/16/2017 3.20 PROD3 DRILL DRLG T 10193',Drill 1.8 BPM @ 5390 PSi FS, 10,193.0 10,630.0 07:06 10:18 BHP=4165,RIW=9K,WOB=1.7K 1/16/2017 1/16/2017 0.40 PROD3 DRILL WPRT T 10630 wiper to 10,100',PUW=38K, 10,630.0 10,630.0 10:18 10:42 Clean past billet up and down, 1/16/2017 1/16/2017 3.00 PROD3 DRILL DRLG T 10630',Drill, 1.8 BPM @ 5525 PSI 10,630.0 11,063.0 10:42 13:42 FS,BHP=4185,RIW=2.5K, WOB=1.8K,Run into high gamma zone @ 10,990,pull mini wiper 1/16/2017 1/16/2017 1.10 PROD3 DRILL WPRT P 11063'Wiper to 10250,Off T time @ 11,063.0 10,250.0 13:42 14:48 11,025 1/16/2017 1/16/2017 1.70 PROD3 DRILL DRLG P 11063 Drill ahead, 1.7 BPM @ 5250 11,063.0 11,090.0 14:48 16:30 PSi FS,BHP=4211,Low ROP,good weight transfer, RIW=2.5K, WOB=2.8K,Good differential-900 PSI 1/16/2017 1/16/2017 2.90 PROD3 DRILL TRIP T 11090',Out of zone,Pump 5 X 5 11,090.0 66.2 16:30 19:24 Sweeps.Trip out for billet 1/16/2017 1/16/2017 1.50 PROD3 DRILL PULD T At surface,PJSM,PUD BHA#12 66.2 0.0 19:24 20:54 1/16/2017 1/16/2017 2.00 PROD3 STK PULD T PJSM,PD BHA#13 Anchor billet, 0.0 72.0 20:54 22:54 Make up to coil and surface test tools, Strip on and tag up 1/16/2017 1/17/2017 1.10 PROD3 STK TRIP T Trip in hole,EDC open,Pumping min 72.0 4,142.0 22:54 00:00 rate 1/17/2017 1/17/2017 1.00 PROD3 STK TRIP T Continue RIH to set anchored billet at 4,142.0 9,555.0 00:00 01:00 10,350'MD Page 13/17 Report Printed: 1/24/2017 ,. • •erations Summary (with Timelog Depths) 3H-22 ConocoPhillips 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) 1/17/2017 1/17/2017 0.25 PROD3 STK DLOG T Tie into K1 marker for-6'correction. 9,555.0 9,778.0 01:00 01:15 1/17/2017 1/17/2017 0.25 PROD3 STK TRIP T Continue RIH with BHA#13 to set 9,788.0 9,788.0 01:15 01:30 anchored billet at 10,350'MD 1/17/2017 1/17/2017 0.75 PROD3 STK TRIP T Difficulty getting anchored billet past 9,788.0 10,350.0 01:30 02:15 9,788'MD in build-section,with multiple set-downs up to 8K WOB. Attempt various TF's to get by.Get by at 180 degree TF with continual 5.3K WOB to 9810'MD. PUH with negative 2K WOB to to 9788',RBIH with up to 9K WOB at-9812'MD.PUH to 9805', change TF to 270 degrees,RBIH, take weight to 8.8K WOB at 9817'MD. Cleaned up past 9838'MD. 1/17/2017 1/17/2017 0.25 PROD3 STK WPST T Arrive at set depth.PUW=35K. 10,350.0 10,350.0 02:15 02:30 Orient to 30 degrees ROHS,bring pumps up to 4800 psi, .4 bpm,shear off anchor with TOB at 10,350'MD. Set down 5K on billet,good. 1/17/2017 1/17/2017 2.00 PROD3 STK TRIP T Trip to surface to LD BHA#13 10,350.0 64.0 02:30 04:30 1/17/2017 1/17/2017 1.50 PROD3 STK PULD T Tag up and space out,PJSM,PUD 64.0 0.0 04:30 06:00 BHA#13.LD BHA#9 1/17/2017 1/17/2017 3.50 PROD3 STK CTOP T Blow down stack.Grease stack and 0.0 0.0 06:00 09:30 tree,grease well control choke,pull UQC checks for reverse circulating (testing inner reel valve),Prep for BOPE test. 1/17/2017 1/17/2017 7.00 PROD3 STK BOPE T 'Perform bi-weekly BOPE test(witness 0.0 0.0 09:30 16:30 waived by Brian Bixby).Test rams and valves to 250 psi low,4500 psi high. Annular 250 psi low,2500 psi high. Rig down test equipment. R3 failed, greased,retested-good. 1/17/2017 1/17/2017 1.00 PROD3 STK CTOP T Install checks in UQC&displace coil 0.0 0.0 16:30 17:30 1/17/2017 1/17/2017 0.50 PROD3 STK PULD T PJSM,PU BHA#14,crew change 0.0 0.0 17:30 18:00 1/17/2017 1/17/2017 2.00 PROD3 STK PULD T PJSM,check pack offs,PD BHA#14, 0.0 74.8 18:00 20:00 L1-03 drilling BHA,bump up. 1/17/2017 1/17/2017 1.60 PROD3 STK TRIP T RIH w/BHA#14. 74.8 9,575.0 20:00 21:36 1/17/2017 1/17/2017 0.30 PROD3 STK DLOG T Tie into K1 for correction-4.5'close 9,575.0 9,592.0 21:36 21:54 EDC,Wt CK,38k lbs. 1/17/2017 1/17/2017 0.60 PROD3 STK TRIP T Continue to RIH, 9,592.0 10,350.0 21:54 22:30 SD at the window,stacking weight @ 9723',PU 38 k lbs,fan pump to roll bit, RBIH,drift clean,continue to RIH, SD @ 9775',PU,38 k lbs,orient left of highside,RBIH,pumping min rate. Slide through clean, tag TOB @ 10350,PU Wt 38 k lbs Page 14/17 Report Printed: 1/24/2017 c Operations Summary (with Timelog Depths) 3H-22 ConocoPhii ips ` 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(ftKS) 1/17/2017 1/18/2017 1.50 PROD3 STK KOST T Stacked out,saw diff increase—100 10,350.0 10,352.0 22:30 00:00 psi,assuming bit blockage,tried to clear with rate to 1.9 bpm,no success. Set rate to 1.35 bpm,off bottom,CT 3900 psi,535 psi dif,7 k lbs RIHWt 08 Time drill off billet, 1 ft/hr for 1 ft 2ft/hr for 1ft 1/18/2017 1/18/2017 0.70 PROD3 STK KOST T OB Time drill off billet, 10,352.0 10,353.0 00:00 00:42 2 ft/hr for 1 ft 3 ft/hr for 1 ft 1/18/2017 1/18/2017 0.60 PROD3 DRILL DRLG T targetting 1k lbs WOB 10,353.0 10,388.0 00:42 01:18 1/18/2017 1/18/2017 0.20 PROD3 DRILL WPRT T Dry drift clean up and down 10,388.0 10,388.0 01:18 01:30 1/18/2017 1/18/2017 4.00 PROD3 DRILL DRLG T BOBD L1-03 Lat. 1.80 bpm 10,388.0 10,860.0 01:30 05:30 Off bottom,Ct 5118 psi,Diff 797 psi OBD,CT 5417 psi,CT Wt 3 k lbs, WOB 1.54 k lbs,ROP 94-130ft/hr **New mud at the bit,system#3,@ 10,565' 1/18/2017 1/18/2017 0.35 PROD3 DRILL WPRT T Wiper trip,PU Wt 36k lbs 10,860.0 10,100.0 05:30 05:51 1/18/2017 1/18/2017 0.40 PROD3 DRILL WPRT T Wiper trip in-hole.RIW=6.5K lb 10,100.0 10,860.0 05:51 06:15 1/18/2017 1/18/2017 1.75 PROD3 DRILL DRLG T Drilling ahead at 1.78 bpm and 5196 10,860.0 11,090.0 06:15 08:00 psi circulating pressure.CWT=5.4K, WOB=2K,dp=991,BHP=4222, WHP=600 psi. 1/18/2017 1/18/2017 1.50 PROD3 DRILL DRLG P Off TT at 11,090'MD. 11,090.0 11,310.0 08:00 09:30 Drilling ahead at 1.78 bpm and 5418 psi circulating pressure.CWT=2.9K, WOB=2.6K,dp=1059 psi,BHP= 4291 psi,WHP=558 psi. 1/18/2017 1/18/2017 0.25 PROD3 DRILL WPRT P Wiper-trip uphole.PUW=34K 11,310.0 10,412.0 09:30 09:45 1/18/2017 1/18/2017 0.25 PROD3 DRILL WPRT P Wiper-trip back in hole.RIW=6K 10,412.0 11,310.0 09:45 10:00 1/18/2017 1/18/2017 3.25 PROD3 DRILL DRLG P Drilling ahead at 1.76 bpm and 5366 11,310.0 11,760.0 10:00 13:15 psi circulating pressure.CWT=12K, WOB=3K,dp= 1168 psi, BHP= 4230 psi,WHP=541 psi. 1/18/2017 1/18/2017 0.75 PROD3 DRILL WPRT P Wiper-trip uphole. PUW=34K lb.Tied 11,760.0 9,744.0 13:15 14:00 into the RA tag for a+6'correction. 1/18/2017 1/18/2017 1.00 PROD3 DRILL WPRT P Wiper-trip inhole.RIW=7.5K 9,744.0 11,760.0 14:00 15:00 1/18/2017 1/18/2017 2.10 PROD3 DRILL DRLG P Drilling ahead at 1.8 bpm and 5076 psi 11,760.0 12,000.0 15:00 17:06 circulating pressure.CWT=6.9K, WOB.2K,dp=785 psi,BHP=4234 psi,WHP=462 psi. 1/18/2017 1/18/2017 1.20 PROD3 DRILL WPRT P TD,pull wiper to window. 12,000.0 9,600.0 17:06 18:18 1/18/2017 1/18/2017 0.40 PROD3 DRILL WPRT P wipe back in hole,pump 10x10 9,600.0 10,000.0 18:18 18:42 sweeps Page 15/17 Report Printed: 1/24/2017 : Operations Summary (with Timelog Depths) 3H-22 Conoco!tulips 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) 1/18/2017 1/18/2017 1.00 PROD3 DRILL WPRT P Sweeps at surface,very few aluminum 10,000.0 9,699.0 18:42 19:42 cuttings and small amount of silt/sand returned to the shaker,open EDC, trap 4076 and 4089 psi respectively on the annular and bore, pressures declined to 4022&4021 psi respectively for 12.97 ppg formation pressure. 1/18/2017 1/18/2017 1.80 PROD3 DRILL WPRT P POOH,wiping to swab,pumping 2 9,669.0 63.0 19:42 21:30 bpm,Choke packed off with aluminum billet at 980'. Cleared choke continue to POOH,bump up,small slug of aluminum at the shaker 1/18/2017 1/18/2017 1.60 PROD3 DRILL TRIP P RBIH 63.0 9,577.0 21:30 23:06 1/18/2017 1/18/2017 0.40 PROD3 DRILL DLOG P Tie into theK1 for correction-6' 9,577.0 9,595.0 23:06 23:30 correction.Complete building Liner running pill. By pass pump screens, close EDC. 1/18/2017 1/19/2017 0.50 PROD3 DRILL TRIP P continue to RIH 9,595.0 10,429.0 23:30 00:00 1/19/2017 1/19/2017 0.60 PROD3 DRILL TRIP P RIH,tag bottom to confirm depth of 10,429.0 12,000.0 00:00 00:36 12,000' 1/19/2017 1/19/2017 1.50 PROD3 DRILL DISP P Lay in 50 bbl beaded liner running pill, 12,000.0 7,374.0 00:36 02:06 POOH painting window and TD flags respectively,7374.76'white,9744.76 yellow 1/19/2017 1/19/2017 1.60 PROD3 DRILL DISP P Continue to POOH laying in 13.1 ppg 7,374.0 74.0 02:06 03:42 KW fluid,Potassium Format brine, estimate-5 bbl losses while laying in KW. 1/19/2017 1/19/2017 0.50 PROD3 DRILL OWFF P PJSM,Observe well for flow-good 74.0 74.0 03:42 04:12 1/19/2017 1/19/2017 2.00 PROD3 DRILL PULD P Lay down BHA#14 over a dead well 74.0 0.0 04:12 06:12 while keeping hole full.estimate-3 bbls lost while picking up liner. 1/19/2017 1/19/2017 1.50 COMPZ3 CASING PUTB P PJSM,clear rig floor,prep for running 74.0 0.0 06:12 07:42 liner 1/19/2017 1/19/2017 4.30 COMPZ3 CASING PULD P Clear floor,MU BHA#15 L1-03 liner 0.0 2,330.0 07:42 12:00 running assembly. Non-ported bullnose,61 joints slotted liner,and shorty deployment sleeve.Performed BOP Drill"Kick While Running Liner". PJSM,estiomate-6 bbls lost while running liner. 1/19/2017 1/19/2017 3.50 COMPZ3 CASING RUNL P RIH with L1-03 Liner assembly. 2,330.0 12,000.0 12:00 15:30 Weight check at window PUW=39K. Stacking weight at 11,789 MD, multiple runs at it to get through. Release liner. BOL at 12,000'MD puts TOL at 9714'MD(TOWS) 1/19/2017 1/19/2017 2.20 COMPZ3 CASING DISP P pump 10 bbls spacer and displace coil 9,714.0 9,714.0 15:30 17:42 and well to seawater. Estimate-5 bbl loss of 13.1 ppg potassium formate. 1/19/2017 1/19/2017 1.20 COMPZ3 CASING DISP P POOH displacing well to seawater 9,714.0 2,500.0 17:42 18:54 Page 16/17 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) : w 3H-22 conocathimps 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) 1/19/2017 1/19/2017 2.40 COMPZ3 CASING DISP P Park at 2500',still lots of beads 2,500.0 2,500.0 18:54 21:18 coming back across the shaker,LRS PJSM,Rig up. ECD open,LRS crew change.PT to 4k psi,good,@ 5 bbls away discovered a weep,bleed and suck back,change out plug valve,re PT to 4000k psi-good,heat the ambient diesel on the fly to-90 F, pump 28 bbls total diesel. 1/19/2017 1/19/2017 0.60 COMPZ3 CASING TRIP P POOH 2,500.0 36.6 21:18 21:54 1/19/2017 1/19/2017 1.90 COMPZ3 CASING PULD P Bump up,Space out,PJSM,PUD 36.6 0.0 21:54 23:48 BHA#15,wash water line froze, steam to thaw. Lay down BHA#15. 1/19/2017 1/20/2017 0.20 DEMOB WHDBOP SFTY P Crew change 0.0 0.0 23:48 00:00 1/20/2017 1/20/2017 2.00 DEMOB WHDBOP CIRC P Make up nozzle,stab on,jet stack, 0.0 0.0 00:00 02:00 pop off. 1/20/2017 1/20/2017 1.50 DEMOB WHDBOP MPSP P Set BPV 0.0 0.0 02:00 03:30 1/20/2017 1/20/2017 3.00 DEMOB WHDBOP RURD P Flush,Blow down,Clean and de 0.0 0.0 03:30 06:30 inventory pits 1/20/2017 1/20/2017 2.50 DEMOB WHDBOP NUND P Vac out stack,Nipple down BOP,vac 0.0 0.0 06:30 09:00 out tree,confirm/test all tree bolts- good,freeze protect tree with 5 gal neat MetOH. ***Rig Release @ ND of BOP at 9:00 AM 1/20/2017"` Page 17/17 Report Printed: 1/24/2017 • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-22L1-02 50-103-20097-62 Baker Hughes INTEQ Definitive Survey Report HUGHES 31 January,2017 • • • ConocoPhillips Mall ConocoPhillips Definitive Survey Report IMBIES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-22 Project: Kuparuk River Unit TVD Reference: 3H-22 @ 76.00usft(31-1-22) Site: Kuparuk 3H Pad MD Reference: 3H-22 @ 76.00usft(3H-22) Well: 3H-22 North Reference: True Welitmre: 3H-22L1-02 Survey Calculation Method: Minimum Curvature Design: 3H-22L1-02 Database: EDM Alaska NSK Sandbox 1.peejeritl.rt, Kuparuk River Unit,North Slope Alaska,United States IMap System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor '. Well 3H-22 Well Position +N/-S 0.00 usft Northing: 6,000,700 42 usft Latitude: 70°24'47.331 N +E/-W 0.00 usft Easting: 498,655.73usft Longitude: 150°0'39.411 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Weilbore 31.. 3H-22L1-02 `. Magrletiosl Model Name' Sample Date Declination Dip Angle Field Strength 1°) (°) (nT) BGGM2016 12/1/2016 17.83 80.98 57,545 Design 3H-22L1-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,810.25 Vertical Section: Depth From(TVD) ! ON/-S +El-W Direction (usft) (usft) 76.00 0.00 0.00 0.00 Survey Program Date 1/31/2017 From To Survey Survey (usft) (usft) Survey(Wellbore) Teel Neots Desedpden Start Date End Date 100.00 9,700 00 3H-22(3H-22) GCT-MS Schlumberger GCT muitishat 1/12/2001 9,714.00 9,810.25 31-1-22L1(3H-22L1) MWD MWD-Standard 1/6/2017 1/9/2017 9,812.00 11,940.01 3H-22L1-02(3H-22L1-02) MWD MWD-Standard 1/10/2017 1/12/2017 1/3172017 2:54:38PM Page 2 COMPASS 5000.1 Build 74 • • ConocoPhillips 1ii�111 ConocoPhillips Definitive Survey Report HKER UG ES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-22 '.. Project: Kuparuk River Unit TVD Reference: 3H-22 Cot 76.00usft(3H-22) Site: Kuparuk 3H Pad MD Reference: 3H-22 @ 76.O0usft(3H-22) Well: 3H-22 North Reference: True Wellbore: 3H-22L1-02 Survey Calculation Method: Minimum Curvature Design: ':3H-22L1-02 Database: EDM Alaska NSK Sandbox "eE Survey Ma inc At NO 1VOSB ,MN1-S 4Et-W Notthlno Easttop OLS Sectio " tem' (1 (o) IV" (u�) (L ) (�) t t (,N0 !n) Survey Tool Name Annotation 9,81025 78.65 342.57 6,103.95 6,027.95 7,149.85 1,019.39 6,007,849.37 499,676.30 38.39 7,149 85 MWD(2) TIP 9,812.00 78.96 34222 6,104.29 6,028.29 7,151.49 1,018.87 6,007,85101 499,675.78 26.43 7,151.49 MWD(3) KOP I 9,840.95 79.03 345.36 6,109.82 6,033.82 7,178.77 1,010.93 6,007,878.29 499,667.86 10.65 7,178.77 MWD(3) 9,870.97 81.28 348.43 6,114.95 6,038.95 7,207.57 1,004.23 6,007,907.09 499,661.16 1256 7,207.57 MWD(3) 9,899.83 82.98 348.76 6,118.90 6,042.90 7,23500 998.58 6,007,935.11 499,655.51 600 7,235.60 MWD(3) I 9,931.67 85.09 350.19 6,122.21 004621 7,266.73 992.80 6,007,966.24 499,649.73 7.99 7,266.73 MWD(3) 9,960.53 87.08 350.51 6,124.18 6,048.18 7,295.11 987.97 6,007,994.63 499,644.91 6.98 7,295.11 MWD(3) 2 9,99125 90.15 351.80 6,12492 6,048.92 7,325.45 983.25 6,008,02496 499,640.20 10.84 7,325.45 MWD(3) 10,021.41 90.74 354.04 6,124.69 6,048.69 7,355.38 979.53 6,008,054.89 499,636.49 7.68 7,355.38 MWD(3) 10,053.18 90.34 356.74 6,12439 6,048.39 7,387.04 976.98 6,008,086.55 499,633.94 8.59 7,387.04 MWD(3) 10,079.89 89.85 358.38 6,124.34 6,048.34 7,413.73 975.84 6,000113.23 499,632.81 6.41 7,413.73 MWD(3) 10,110.37 91.66 201 6,123.94 6,047.94 7,444.20 975.94 6,008,143.70 499,632.92 13.31 7,444.20 MWD(3) 10,139.82 90.06 1.90 6,123.50 6,04750 7,473.63 976.95 6,008,173.13 499,633.93 5.45 7,473.63 MWD(3) 10,170.53 9209 6.87 6,122.92 6,046.92 7,504.23 979.30 6,008,203.73 499,636.28 17.48 7,504.23 MWD(3) 10,199.81 9212 8.49 6,121.85 6,045.85 7,533.23 983.21 6,008,232.72 499,640.19 5.53 7,533.23 MWD(3) il 10,231.09 9200 8.87 6,120.72 6,044.72 7,564.13 987.92 6,008,263.62 499,644.92 1.27 7,564.13 MWD(3) 5 10,260.01 89.79 8.54 6,120.27 6,044.27 7,59271 992.30 6,008,292.19 499,649.30 7.73 7,592.71 MWD(3) 10,286.26 90.61 9.89 6,120.18 6,044.18 7,618 62 996.50 6,008,318.10 499,653.50 6.02 7,618.62 MWD(3) g 10,315.71 8948 10.30 6,120.16 0044.16 7,647.62 1,001.67 6,008,347.09 499,658.67 4.08 7,647.62 MWD(3) I, 10,346.08 88.68 4.24 6,120.65 0044.65 7,677.72 1,005.51 6,008,377.19 499,662.52 20.12 7,677.72 MWD(3) 10,375.78 90.95 2.93 6,120.74 6,04474 7,707.36 1,007.36 6,008,406.83 499,664.38 8.82 7,707.36 MWD(3) 10,411.46 91.17 0.29 6,120.08 6,044.08 7,743.02 1,008.37 6,008,44248 499,665.39 7.42 7,743.02 MWD(3) s 10,436.62 91.94 2.78 6,119.40 6,04340 7,768.16 1,009.04 6,008,467.62 499,666.07 10.36 7,768.16 MWD(3) 10,465.85 92.61 6.48 6,118.24 6,042.24 7,797.27 1,011.40 6,008,496.72 499,668.43 12.85 7,797.27 MWD(3) 10,496.25 92.06 8.21 6,117.00 6,041.00 7,827.39 1,015.28 6,008,526.84 499,672.32 5.97 7,82739 MWD(3) 10,526.11 92.76 11.23 6,115.74 6,039.74 7,856.79 1,020.31 6,008,556.24 499,677.36 10.37 7,856.79 MWD(3) 10,556.24 90.31 10.79 6,114.94 6,038.94 7,886.35 1,026.07 6,008,585.80 499,683.11 8.26 7,886.35 MWD(3) 10,586.05 91.23 14.03 6,114.54 6,038.54 7,915.46 1,032.47 6,008,614.90 499,689.52 11.30 7,915.46 MWD(3) q 10,616.17 91.50 16.56 6,113.82 6,037.82 7,944.50 1,040.41 6,008,643.94 499,697.47 8.45 7,944.50 MWD(3) 10,645.81 90.83 18.67 6,113 22 6037 22 7,972 75 1,049.38 6,008,672 18 499 70644 7.47 7R72.75 MWD(3) 1/312017 2:54:38PM Page 3 COMPASS 5000.1 Build 74 • ail ConocoPhillips ///111 ConocoPhillips Definitive Survey Report BAKEHUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-22 Project: Kuparuk River Unit TVD Reference: 3H-22©76.00usft(311-22) Site: Kuparuk 3H Pad MD Reference: 3H-22 @ 76.00usft(3H-22) `Well: 311-22 North Reference: True Wellbore: 3H-22L1-02 Survey Calculation Method: Minimum Curvature Design: 3H-22L1-02 Database: EDM Alaska NSK Sandbox Survey I Map Map Vertical MD Inc - Azi TVD TVDSS +N/-S +EI-W Northing Easim DLS Section (usft) (°) (°l ( ). ( ) ( ) (usft) .{111 (ftlg ' (, ) (ft) Survey Tool Name Annotation usft usft usft usft /100 10,675.46 91.57 21.46 6,112.59 6,036.59 8,000.59 1,059.55 6,008,700.02 499,716.61 9.73 8,000.59 MWD(3) 10,705.52 91.90 21.58 6,111.68 6,035.68 8,028.54 1,070.57 6,008,727.96 499,727.64 1.17 8,028.54 MWD(3) 1 10,735.57 89.82 20.17 6,111.23 6,035.23 8,056.61 1,081.28 6,008,756.03 499,738.35 8.36 8,056.61 MWD(3) I 10,765.96 90.06 18.96 6,111.27 6,035.27 8,085.25 1,091.45 6,008,784.66 499,748.53 4.06 8,085.25 MWD(3) 10,796.16 92.02 18.47 6,110.72 6,034.72 8,113.84 1,101.14 6,008,813.25 499,758.22 6.69 8,113.84 MWD(3) 10,825.58 93.69 19.14 6,109.25 6,033.25 8,141.66 1,110.61 6,008,841.06 499,767.70 6.12 8,141.66 MWD(3) 10,855.60 95.87 19.29 6,106.75 6,030.75 8,169.90 1,120.46 6,008,869.30 499,777.55 7.28 8,169.90 MWD(3) ) 10,880.48 97.79 19.66 6,103.79 6,027.79 8,193.19 1,128.69 6,008,892.59 499,785.79 7.86 8,193.19 MWD(3) I 10,910.61 100.05 19.18 6,099.12 6,023.12 8,221.26 1,138.59 6,008,920.66 499,795.69 7.66 8,221.26 MWD(3) 10,940.97 100.26 18.36 6,093.77 6,017.77 8,249.56 1,148.21 6,008,948.95 499,805.31 2.75 8,249.56 MWD(3) 10,970.71 97.82 16.78 6,089.09 6,013.09 8,277.56 1,157.07 6,008,976.84 499,814.17 9,74 8,277.56 MWD(3) 10,995.81 96.39 16.85 6,085.99 6,009.99 8,301.40 1,164.27 6,009,000.78 499,821.38 5.70 8,301.40 MWD(3) 11,020.89 95.31 17.29 6,083.43 6,007.43 8,325.25 1,171.60 6,009,024.62 489,828.71 4.65 8,325.25 MWD(3) 11,056,09 94.24 19.16 6,080.50 6,004.50 8,358.56 1,182.57 6,009,057.93 499,839.69 6.10 8,358.56 MWD(3) l 11,081.25 92.98 20.55 6,078.92 6,002.92 8,382.18 1,191.10 6,009,081.55 499,848.22 7.45 8,382.18 MWD(3) 11,106.20 91.47 21.15 6,077.95 6,001.95 8,405.48 1,199.97 6,009,104.84 499,857.09 6.51 8,405.48 MWD(3) 11,133.83 88.99 22.87 6,077.84 6,001.84 8,431.09 1,210.32 6,009,130.45 499,867.45 10.92 8,431.09 MWD(3) a 11,165.01 88.40 24.50 6,078.55 6,002.55 8,459.64 1,222.85 6,009,158.99 499,879.98 5.56 8,459.64 MWD(3) 3 11,195.50 86.93 26.75 6,079,79 6,003.79 8,487.10 1,236.02 6,009,186.45 499,893.15 8.81 8,487.10 MWD(3) E 11,225.41 85.97 28.07 6,081,64 6,005.64 8,513.60 1,249.76 6,009,212.95 499,906.90 5.45 8,513.60 MWD(3) 11,255.77 84.43 29.91 6,084.18 6,008.18 8,540.06 1,264.42 6,009,239.40 499,921.56 7.89 8,540.06 MWD(3) (( 1 11,285.69 83.38 27.58 6,087.36 6,011.36 8,566.15 1,278.73 6,009,265.48 499,935.87 8.50 8,566.15 MWD(3) j 11,315.86 82.15 24.35 6,091.16 6,015,16 8,593.05 1,291.83 6,009,292.38 499,948.98 11.38 8,593,05 MWD(3) 1 11,345.32 82.86 22.88 6,095.01 6,019.01 - 8,619.81 1,303.53 6,009,319.13 499,960.68 5.50 8,619.81 MWD(3) q) 11,375.63 84.22 21,73 6,098.42 6,022.42 8,647.67 1,314.96 6,009,346.99 499,972.12 5.86 8,647.67 MWD(3) ) 11,405.89 84.53 24.29 6,101.38 6,025.38 8,675.39 1,326.73 6,009,374.70 499,983.89 8.48 8,675.39 MWD(3) 11,435.81 85.20 26.77 6,104.06 6,028.06 8,702.28 1,339.58 6,009,401.59 499,996.74 8.55 8,702.28 MWD(3) 11,470.53 87.20 28.92 6,106.36 6,030.36 8,732.91 1,355.76 6,009,432.21 500,012.92 8.45 8,732.81 MWD(3) 1 11,500.84 88.22 30.40 6,107.57 6,031.57 8,759.22 1,370.74 6,009,458.52 500,027.91 5.93 8,759.22 MWD(3) 11,530.79 89.48 31.90 6,108.17 6,032.17 8,784.85 1,386.23 6,009,484.14 500,043.40 654 8,784.85 MWD(3) , 11.560.87 8169 3131 6,108.39 603239 8,810.19 1,402.44 6,009,509.47 500 059 61 4.74 8,810.19 MWD(3) 1/31/2017 2:54:38PM Page 4 COMPASS 5000.1 Build 74 0 • ConocoPhillips ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-22 Project: Kuparuk River Unit ND Reference: 3H-22 @ 76.00usft(3H-22) Site: Kuparuk 3H Pad MD Reference: -. 311-22 r@ 76.00usft(3H-22) Well: , 3H-22 North Reference: <' True Wellbore: ': 3H-22L1-02 Survey Calculation Method: Minimum Curvature Design: 3H-22L1-02 Database: EDM Alaska NSK Sandbox Survey Map Map Vgrtieal MD Inc Azi ND NDSS +NI.S +EI-W Northing Fasting DUS Sactibn survey Tool Name Annotation(use) (°t (°t (usft) (uom) (usft) (usft) inl... (n) (*MOO') (1t) ; 11,590 23 90.61 35.19 6,108.31 6,032.31 8,834 45 1,418.96 6,009,533.73 500,076.14 7.13 8,834.45 MWD(3) 11,620.35 90.77 37.14 6,107.95 6,031.95 8,858.77 1,436.73 6,009,558.04 500,093.91 6.50 8,858.77 MWD(3) 11,650.17 87.88 36.99 6,108.30 6,032.30 8,88256 1,454.70 6,009,581.83 500,111.89 9.70 8,882.56 MWD(3) 11,680.21 85.30 37.45 6,110.09 6,034.09 8,906.43 1,472.84 6,009,605.70 500,130.03 8.72 8,906.43 MWD(3) 11,709.91 82.89 37.73 6,113.15 6,037.15 8,929.84 1,490.86 6,009,62a 10 500,148.05 8.17 8,929.84 MWD(3) 11,740.49 79.81 3693 6,117.74 6,041.74 8,953.88 1,509.19 6,009,65a 13 500,166.38 10.40 8,953.88 MWD(3) 11,770.60 76.96 36.99 6,123.81 6,047.81 8,977.44 1,526.92 6,009,676.69 500,184.12 9.47 8,977.44 MWD(3) t 11,800.53 74.20 36.51 6,131.26 6,055.26 9,000.67 1,544.26 6,009,699.91 500,201.46 9.35 9,000.67 MWD(3) q 11,830.53 72.36 36.46 6,138.88 6,063.88 9,023.77 1,561.35 6,009,723.00 500,218.55 6.07 9,023.77 MWD(3) 5 11,861.01 69.81 35.81 6,149.76 6,073.76 9,047.05 1,578.35 6,009,746.28 500,235.55 8.67 9,047.05 MWD(3) 11,891.09 66.78 34.24 6,160.88 6,084.88 9,069.93 1,594,39 6,009,769.16 500,251.60 11.18 9,069.93 MWD(3) 11,920.59 64.71 32.47 6,173.00 6,097.00 9,092.39 1,609.18 6,009,791.61 500,266.39 8.90 9,092.39 MWD(3) { 11,940.01 63.13 31.56 6,181.54 6,105.54 9,107.18 1,618.43 6,009,806.40 500,27564 9.16 9,107.18 MWD(3) 11,984.00 63.13 31.56 6,201.42 6,125.42 9,140.62 1,638.97 6,009,839.83 500,29618 0.00 9,140.62 PROJECTED to TD 1X5172017 2:54:38P0.4 Page 5 COMPASS 5000.1 Build 74 • S pi-17 2JG ` fLP-- Loepp, Victoria T (DOA) From: Aleshire, Lynn <Lynn.Aleshire@conocophillips.com> Sent: Wednesday, February 08, 2017 4:14 PM To: Loepp,Victoria T(DOA) Subject: 3H-22L1 PTD 216-145;3H-22L1-02 PTD 216-147;3H-22L1-03 PTD 216-148 Follow Up Flag: Follow up Flag Status: Flagged Victoria, Our CTD group was just finalizing the Completion Report and will now submit it as a producer so your email confirmation for 60-day pre-production will not be needed. We will submit the 10-403 before putting on injection. Thanks, Lynn From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, February 08,2017 3:27 PM To:Aleshire, Lynn<Lynn.Aleshire@conocophillips.com> Subject: [EXTERNAL]RE: 3H-22 Please include all lateral names and PTD numbers in subject line. Thanx, Victoria From:Aleshire, Lynn [mailto:Lynn.Aleshire@conocophillips.com] Sent:Wednesday, February 08, 2017 3:07 PM To: Loepp,Victoria T(DOA)<victoria.loeppPalaska.gov> Subject:3H-22 Hi Victoria, As discussed this afternoon,we are pre-producing the long-time injector 3H-22 after completing three CTD laterals.The well is currently flowing to the plant for a planned 60 days. I am writing to confirm that a 10-403 will not be required for the pre-production period greater than 30 days. A 10-403 will be submitted with the required description and Area of Review before the well is returned to injection. Regards, Lynn Aleshire Lynn Aleshire I Petroleum Engr 3HGS&Subsidence I ConocoPhillips Alaska 1700 G St.ATO 1348,Anchorage,AK 99501 Office: (907)265-6525 I Mobile:(907)240-2583 1 vOF ? • • 0'1,��✓�1/7 4„ THE STATE Alaska Oil and Gas _ o f e T KA Conservation Commission tit 333 West Seventh Avenue ►-. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ` +' Main: 907.279.1433 FAiAs�'� Fax: 907.276.7542 www.aogcc.alaska.gov G. Eller CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-22L1-02 ConocoPhillips Alaska,Inc. Permit to Drill Number: 216-147 Surface Location: 957' FNL, 282' FWL, Sec. 12, T12N,R8E,UM Bottomhole Location: 2557' FNL, 2884' FWL, Sec. 35, T13N, R8E,UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 188-110, API No. 50-103- 20097-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 4/r/4/ Daniel T. Seamount,Jr. Commissioner DATED this 15day of November, 2016. RECEIVED STATE OF ALASKA A OIL AND GAS CONSERVATION COMM )N NOV 0 3 2016 PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG Q. Service-Disp ❑ 1 c.Specify if well is proposed for: Drill ❑ , Lateral CI Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone 0 • Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 ' KRU 3H-22L1-02 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11,750' ' TVD: 6178'' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): r'9 Kuparuk River Field/Kuparuk Oil Pool w Surface: 957'FNL,282'FWL,Sec. 12,T12N,R8E, UM ' ADL 25523' $3' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4280'FNL,2341;FWL,Sec.35,T13N,R8E,UM ALK 2559 12/5/2016 Total Depth: 9.Acres in Property: N 14.Distance to Nearest Property: 2557'FNL,2884'FWL,Sec.35,T13N,R8E,UM 25110 372,. 11075' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 76 - 15.Distance to Nearest Well Open Surface:x- 498656 y- 6000700 Zone-4 ° GL Elevation above MSL(ft): 39 , to Same Pool: 1322'to 3M-29 16.Deviated wells: Kickoff depth: 9815' feet . j 17. Maximum Potential Pressures in psig(see 20 AAC 25.035) DIvZ Maximum Hole Angle:9� degrees Downhole:'j n 9<r4 psig Surface: L/ Q5- 3 11 psig 1�J 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 9900 6113 11750 6178 Slotted 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 10234' 6379' None 9818' 6125' None Casing Length Size Cement Volume MD TVD Conductor/Structural 115' 16" 250 sx AS I 115' 115' Surface 4348' 9-5/8" 1500 sx AS III&500 sx Class G 4348' 3127' Intermediate Production 10052' 7" 1280 sx Class G&175 sx AS I 10052' 6268' Liner Perforation Depth MD(ft): 9690'-9710',9716'-9736',9754'-9774' Perforation Depth TVD(ft): 6047'-6059',6063'-6075',6086'-6098' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard AnalysisL Diverter Sketch Li Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date /0/7.40% 22. I hereby certify that the foregoing is true and the procedure approved herein will not Jeff Connelly @ 263-4112 be deviated from without prior written approval. Contact Email jeff.s.conneIIv cop.com Printed Name `\ G. Eller Title CTD Team Lead Signature ilkCI.14-\ Phone 263-4172 Date \\ f7.)\c Commission Use Only Permit to Drill API Number: Permit Approval 1See cover letter for other Number: a f — `y 0- 50-10-,4200 CI t�1—U0 Date: 1 1 I ` i l y requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [( Other: 7t`II 5"a (s,. 00 f' / S f--" Samples req'd: Yes Nod Mud log req'd:Yes❑ No L ' AL 2 e)r_.' les 4 ,An" j.;c-t— H25 measures: Yes[ No❑ Directional svy req'd:Yes[Zr No dv T Spacing exception req'd:qYes❑ No Inclination-only svy req'd:Yes❑ No k' a/1-1"4,----1-- Or----'_T c--,-, .t c-c.e vizi,itc;�- / /1JO 2C- injectionreq'd: ❑ No❑ �/' L✓ Post initial MIT Yes -x' V e�'',�i ti.1ti�� 'i 2 o ARC 2 S .C)/S(b,) 0 Yrt�,f, Q i ,//oc:J !�4. ,4, X66 f)c��i v,k / c'- w 1....._.4_, h v„c f-14ca^ lie.^e , t APPROVED BY / / Approved by: COMMISSIONER THE COMMISSION Date: (1 ( I L ( 1hp i"a ii `G 1I OsRrfi6viliNrAnf20 /1 i//! (( YMI/' Submit Form and Form 10-401(Revised 11/2015) from the date of ap royal(20 AAC 25.005(g)) Attachments in Duplicate • S ConocoPhilli s p Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 NOV 0 3 2016 October 27, 2016 AOGCO Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a hexa-lateral out of the Kuparuk Well 3H-22 (PTD# 188-011) using the coiled tubing drilling rig, Nabors CDR2-AC or CDR3-AC (Note: The 3H-22 CTD project is planned for CDR2-AC drilling at the time of PTD submittal, please be aware that for scheduling purposes, CDR3 may be utilized for drilling activities should the need arise). The work is scheduled to begin December 5, 2016. The CTD objective will be to drill six laterals (3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1- 03, 3H-22L1-04, and 3H-22L1-05), targeting the Kuparuk A-sand intervals. A 4-1/2" big tail pipe was installed during RWO prior to CTD operation. 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 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H- 22L1-04, and 3H-22L1-05 — Detailed Summary of Operations — Directional Plans for 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H-22L1-04, and 3H-22L1-05 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, /./(/' Jeff Connelly Coiled Tubing Drilling Engineer ! • Ku pa ru k CTD Laterals NABOAS ALASKA 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, o„ Ps 3H-22L1-04, and 3H-22L1-05 Application for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 8 Attachment 1: Directional Plans for 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H-22L1-04, and 3H-22L1-05...8 Attachment 2: Current Well Schematic for 3H-22 8 Page 1 of 8 October 27,2016 • Attachment 3: Proposed Well Schematic for 3H-22L1, 3H-22L1-01,3H-22L1-02, 3H-22L1-03, 3H-22L1-04, and 3H- 22L1-05 8 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H- 22L1-04, and 3H-22L1-05. All laterals will be classified as"Service—WAG"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H-22L1-04, and 3H-22L1- 05. 3. Blowout Prevention Equipment Information (Requirements of 20 AA C 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4700 psi. Using the maximum formation pressure in the area of 3H-31 (i.e. 15 ppg EMW), the maximum potential surface pressure in 3H-22, assuming a gas gradient of 0.1 psi/ft, would be 4205 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 3H-22 was measured to be 4107 psi (13.01 ppg EMW) on 9/25/2016. The maximum downhole pressure in the 3H-22 vicinity is 3H-31 at 4825 psi (15 ppg EMW) measured 10/8/2016. The lowest downhole pressure in the 3H-22 vicinity is to the east in the 3H-21 producer at 3290 psi (10.22 ppg EMW) measured 6/24/2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) MI gas injection has occurred in the area, there is the potential of encountering free gas while drilling the 3H-22 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 3H-22 laterals will be shale instability at large fault crossings. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3H-22 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 8 October 27,2016 PTD Application: 3H-22L1, L1-01, pp L1-02, L1-03, L1-04, and L1-05. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3H-22L1 10,070' 11,750' 6,036' 6,725' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3H-22L1-01 9,815' 11,150' 6,028' 6,008' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3H-22L1-02 9,900' 11,750' 6,037' 6,102' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3H-22L1-03 9,765' 11,825' 6,013' 6,071' 23/ 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3H-22L1-04 9815 11,750' 6028' 5,950' 2%", 4,7#, L 80, ST-L slotted liner; aluminum billet on top 3H-22L1-05 9,715' 11,750' 5,987' 6111 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 115' 0' 115' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 0' 4,348' 0' 3,126' 3520 2020 Production 7" 26.0 J-55 BTC 0' 10,052' 0' 6269' 4980 4330 Tubing 3-1/2" 9.3 L-80 EUE 0' 9664' 0' 6457' 10180 10540 Tubing Tail 4-1/2" 12.6 L-80 STC 9664' 9748' 6402' 6457' NA NA 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based FloVis mud (8.6 ppg) - Drilling operations: Chloride-based FloVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. - Completion operations: The well will be loaded with NaBr or K-Formate completion fluid in order to provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing Page 3 of 8 October 27,2016 • • PTD Application: 3H-22L1, L1-01, L1-02, L1-03, L1-04, and L1-05. pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3"Blowout Prevention Equipment Information". In the 3H-22 laterals we will target a constant BHP of 13.1 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Reservoir pressure at 3H-22 is expected to continue to come down, as it has in the past two months through pressure management in the area. Target pressure at the window will likely be modified to reflect this decrease in pressure at time of CTD drilling, though for purposes of planning 13.1 ppg at the window will be used for the calculations below. Pressure at the 3H-22 Window(9715' MD, 6435' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (13.1 ppg) 4107 psi 4107 psi Mud Hydrostatic (8.6 ppg) 2778 psi 2778 psi Annular friction (i.e. ECD, 0.080 psi/ft) 777 psi 0 psi Mud + ECD Combined 3555 psi 2778 psi (no choke pressure) (underbalanced —552 (underbalanced psi) —1329 psi) Target BHP at Window(13.1 ppg) 4383 psi 4383 psi Choke Pressure Required to Maintain Target 828 psi 1605 psi BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3H-22 is a Kuparuk A-sand injection(service)well that has been recently worked over to install new 3'/2"tubing with a 4-1/2" Big Tail Pipe(BTP). Six CTD laterals will be drilled from the 3H-22,three to the north and three to the west, with the laterals targeting the Kuparuk Al,A2, and A3 sands. Page 4 of 8 October 27, 2016 • fTD Application: 3H-22L1, L1-01, L1-02, L1-03, L1-04, and L1-05. The 3H-22L1 lateral will exit through the 4'/2"BTP and 7"casing at 9715' MD and TD at 11,750' MD, targeting the Al,A2 and A3 sands. It will be completed with 23/8" slotted liner from TD up to 10,070' MD with aluminum billet for kicking off the 3H-22L1-01 lateral. The 3H-22L1-01 lateral will drill west to a TD of 11,150' MD targeting the Al and A2 sands. It will be completed with 2%" slotted liner from TD up to 9,815' MD with an aluminum billet for kicking off the 3H- 22L1-02 lateral. / The 3H-22L1-02 lateral will drill north to a TD of 11,750' MD targeting the Al sand. It will be completed with 2%" slotted liner from TD up to 9,900' MD with an aluminum billet for kicking off the 3H-22L1-03 lateral. The 3H-22L1-03 lateral will drill south to a TD of 11,825' MD targeting the Al,A2, and A3 sands. It will be completed with 2%"slotted liner from TD up to 9765' MD with an aluminum billet for kicking off the 3H-22L1-04 lateral. The 3H-22L1-04 lateral will drill west to a TD of 11,750' MD targeting the A sands. It will be completed with 2%"slotted liner from TD up to 9815' MD with an aluminum billet for kicking off the 3H-22L1-05 lateral. The 3H-22L1-05 lateral will drill north to a TD of 11,750' MD targeting the A3 sands. It will be completed with 2%" slotted liner from TD up to TOWS with a deployment sleeve. Pre-CTD Work 1. RU Slickline: Pull sheared SOV, injection test, obtain an A-sand SBHP, drift a dummy whip-stock. 2. RU E-line: Perform a jewelry log 3. RU E-line: Set Baker Hughes whipstock at 9715' 4. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16"BOPE,test. 2. 3H-22L1 Lateral(A sand-west) a. Mill 2.80"window at 9715' MD. b. Drill 3"bi-center lateral to TD of 11,750' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 10,070' MD. 3. 3H-22L1-01 Lateral(A sand-west) a. Kick off of aluminum billet at 10,070' MD. b. Drill 3"bi-center lateral to TD of 11,150' MD. c. Run 2%" slotted liner from TD up to 9,815' MD. 4. 3H-22L1-02 Lateral(A sand-north) a. Kick off of aluminum billet at 9,815' MD. b. Drill 3"bi-center lateral to TD of 11,750' MD. c. Run 2%" slotted liner from TD up to 9,900' MD. 5. 3H-22L1-03 Lateral(A sand-north) a. Kick off of aluminum billet at 9,900' MD. b. Drill 3"bi-center lateral to TD of 11,825' MD. Page 5 of 8 October 27,2016 PTD Application: 3H-22L1, - pp L1-01, L1 02, L1 03, L1-04, and L1-05. c. Run 2%" slotted liner from TD up to 9765' MD. 6. 3H-22L1-04 Lateral(A sand-west) a. Kick off of aluminum billet at 9,765 MD. b. Drill 3"bi-center lateral to TD of 11,750' MD. c. Run 23/8" slotted liner from TD up to 9,815' MD. 7. 3H-22L1-05 Lateral(A sand-north) a. Kick off of aluminum billet at 9,815' MD. b. Drill 3"bi-center lateral to TD of 11,750' MD. c. Run 2%" slotted liner from TD up to TOWS at 9715' MD. 8. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. / 2. Pre-produce for less than 30 days J 3. Return to injection. 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, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse Liner Running — The 3H-22 laterals will be displaced to an overbalanced fluid (K-Formate or NaBr depending on pressures encountered at time of drilling) prior to running liner. See"Drilling Fluids" section for more details. Page 6 of 8 October 27,2016 • filD Application: 3H-22L1, L1-01, L1-02, L1-03, L1-04, and L1-05. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14))� • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 f or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lat eaI Nairn r star . 3H-22L1 9820' 3H-22L1-01 10060' 3H-22L1-02 11075' 3H-22L1-03 _ 11075' 3H-22L1-04 9820' 3H-22L1-05 11,075' — Distance to Nearest Well within Pool Lateral'Name, Distance... 3H-22L1 1551' 3H-19L1 3H-22L1-01 1551' 3H-19L1 3H-22L1-02 1322' 3M-29 3H-22L1-03 1322' 3M-29 3H-22L1-04 1551' 3H-19L1 3H-22L1-05 1322' 3M-29 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There are no wells within %4-mile of the 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H-22L1-04, and 3H- 22L1-05 laterals Page 7 of 8 October 27,2016 • • PTD Application: 3H-22L1, L1-01, L1-02, L1-03, L1-04, and L1-05. 3H-22 (mother bore) Injector • Classified as a "Normal Well" • Original PTD is 188-011 &API Number is 50-103-20097-00 • The well was completed in RWO with 3.5" 9.3# L-80 tubing, 4.5" 12.6# L-80 Big Tail Pipe, and 7" 26#J- 55 production casing. • A-sand perforations: • Measure Depth: 9690' —9710' MD, 9716'-9736' MD, and 9754'-9774' MD • TVD: 6047'-6059' TVD, 6060'-6075' TVD, and 6086'-6098' TVD • Production packer at 9578' MD—5979' TVD, which is less than 200' from A-sand perforations • Well is currently off-line • 7" production casing was cemented with 200 sx class G (minimum) • TOC 500' above top of Kuparuk • 3H-22L1-02, 3H-22L1-03, & 3H-22L1-05 are planned at 1322' from 3M-29, 3M-29A, & 3M-29APB1, which is 2' outside of 1/4 mile radius. 17. Attachments Attachment 1: Directional Plans for 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H-22L1-04, and 3H-22L1-05 Attachment 2: Current Well Schematic for 3H-22 Attachment 3: Proposed Well Schematic for 3H-22L1, 3H-22L1-01, 3H-22L1-02, 3H-22L1-03, 3H-22L1-04, and 3H-22L1-05 Page 8 of 8 October 27, 2016 • r ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-22 3H-22L1-02 Plan: 3H-22L1-02_wp02 Standard Planning Report 27 September, 2016 r' ® BAKER HUGHES ConocoPhillips 1 Fa', ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3H-22 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-22©76.00usft(3H-22) Site: Kuparuk 3H Pad North Reference: True Well: 3H-22 Survey Calculation Method: Minimum Curvature Wellbore: 3H-22L1-02 Design: 3H-22L1-02_wp02 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3H Pad Site Position: Northing: 6,000,110.73 usft Latitude: 70°24'41.531 N From: Map Easting: 498,655.44 usft Longitude: 150°0'39.416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 3H-22 Well Position +N/-S 0.00 usft Northing: 6,000,700.42 usft Latitude: 70°24'47.331 N +E/-W 0.00 usft Easting: 498,655.73 usft Longitude: 150°0'39.411 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3H-22L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2016 12/1/2016 17.83 80.98 57,545 Design 3H-22L1-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,815.00 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) (°) (°) (usft) (usft) (usft) (°/100ft) (0/100ft) (°/100ft) (°) Target 9,815.00 82.19 344.22 6,027.98 7,154.93 1,020.97 0.00 0.00 0.00 0.00 9,915.00 85.73 350.29 6,038.51 7,251.87 999.06 7.00 3.54 6.08 60.00 10,015.00 89.25 356.35 6,042.89 7,351.03 987.46 7.00 3.52 6.06 60.00 10,420.00 89.34 24.70 6,048.01 7,745.13 1,060.69 7.00 0.02 7.00 90.00 10,600.00 88.26 12.15 6,051.79 7,915.52 1,117.46 7.00 -0.60 -6.98 265.00 10,750.00 91.86 2.28 6,051.63 8,064.13 1,136.27 7.00 2.40 -6.58 290.00 11,075.00 89.40 24.90 6,048.00 8,377.93 1,212.15 7.00 -0.76 6.96 96.00 11,225.00 84.18 34.03 6,056.40 8,508.16 1,285.68 7.00 -3.48 6.09 120.00 11,425.00 84.36 19.96 6,076.48 8,685.03 1,375.77 7.00 0.09 -7.03 270.00 11,725.00 86.52 40.92 6,100.61 8,941.35 1,526.48 7.00 0.72 6.99 85.00 11,750.00 86.52 39.16 6,102.13 8,960.46 1,542.53 7.00 0.01 -7.01 270.00 9/27/2016 4:32:35PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips PIS. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3H-22 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-22 @ 76.00usft(3H-22) Site: Kuparuk 3H Pad North Reference: True Well: 3H-22 Survey Calculation Method: Minimum Curvature Wellbore: 3H-22L1-02 Design: 3 H-22 L 1-02_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (0) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 9,815.00 82.19 344.22 6,027.98 7,154.93 1,020.97 7,154.93 0.00 0.00 6,007,854.45 499,677.89 TIP/KOP 9,900.00 85.19 349.39 6,037.32 7,237.15 1,001.70 7,237.15 7.00 60.00 6,007,936.66 499,658.63 9,915.00 85.73 350.29 6,038.51 7,251.87 999.06 7,251.87 7.00 59.43 6,007,951.38 499,656.00 Start 7 dls 10,000.00 88.72 355.44 6,042.63 7,336.07 988.53 7,336.07 7.00 60.00 6,008,035.58 499,645.48 10,015.00 89.25 356.35 6,042.89 7,351.03 987.46 7,351.03 7.00 59.75 6,008,050.54 499,644.41 3 10,100.00 89.25 2.30 6,044.01 7,435.98 986.46 7,435.98 7.00 90.00 6,008,135.48 499,643.43 10,200.00 89.27 9.30 6,045.31 7,535.40 996.56 7,535.40 7.00 89.92 6,008,234.88 499,653.55 10,300.00 89.29 16.30 6,046.57 7,632.84 1,018.70 7,632.84 7.00 89.83 6,008,332.32 499,675.71 10,400.00 89.33 23.30 6,047.77 7,726.86 1,052.56 7,726.86 7.00 89.74 6,008,426.32 499,709.57 10,420.00 89.34 24.70 6,048.01 7,745.13 1,060.69 7,745.13 7.00 89.66 6,008,444.59 499,717.71 4 10,500.00 88.85 19.12 6,049.27 7,819.31 1,090.54 7,819.31 7.00 -95.00 6,008,518.76 499,747.56 10,600.00 88.26 12.15 6,051.79 7,915.52 1,117.46 7,915.52 7.00 -94.91 6,008,614.95 499,774.50 5 10,700.00 90.66 5.57 6,052.73 8,014.27 1,132.85 8,014.27 7.00 -70.00 6,008,713.68 499,789.91 10,750.00 91.86 2.28 6,051.63 8,064.13 1,136.27 8,064.13 7.00 -69.94 6,008,763.54 499,793.34 6 10,800.00 91.49 5.76 6,050.16 8,113.98 1,139.77 8,113.98 7.00 96.00 6,008,813.38 499,796.85 10,900.00 90.74 12.72 6,048.21 8,212.60 1,155.82 8,212.60 7.00 96.10 6,008,911.99 499,812.92 11,000.00 89.98 19.68 6,047.59 8,308.56 1,183.71 8,308.56 7.00 96.24 6,009,007.94 499,840.82 11,075.00 89.40 24.90 6,048.00 8,377.93 1,212.15 8,377.93 7.00 96.28 6,009,077.30 499,869.26 7 11,100.00 88.53 26.42 6,048.45 8,400.46 1,222.97 8,400.46 7.00 120.00 6,009,099.82 499,880.09 11,200.00 85.05 32.50 6,054.06 8,487.35 1,272.03 8,487.35 7.00 119.97 6,009,186.69 499,929.16 11,225.00 84.18 34.03 6,056.40 8,508.16 1,285.68 8,508.16 7.00 119.63 6,009,207.50 499,942.82 8 11,300.00 84.21 28.75 6,064.00 8,571.83 1,324.53 8,571.83 7.00 -90.00 6,009,271.16 499,981.67 11,400.00 84.31 21.72 6,074.01 8,661.78 1,366.92 8,661.78 7.00 -89.47 6,009,361.09 500,024.08 11,425.00 84.36 19.96 6,076.48 8,685.03 1,375.77 8,685.03 7.00 -88.76 6,009,384.33 500,032.93 9 11,500.00 84.84 25.21 6,083.55 8,753.94 1,404.44 8,753.94 7.00 85.00 6,009,453.24 500,061.60 11,600.00 85.54 32.20 6,091.94 8,841.29 1,452.27 8,841.29 7.00 84.51 6,009,540.56 500,109.45 11,700.00 86.32 39.17 6,099.05 8,922.25 1,510.42 8,922.25 7.00 83.92 6,009,621.51 500,167.61 11,725.00 86.52 40.92 6,100.61 8,941.35 1,526.48 8,941.35 7.00 83.42 6,009,640.60 500,183.66 10 11,750.00 86.52 39.16 6,102.13 8,960.46 1,542.53 8,960.46 7.00 -90.00 6,009,659.70 500,199.72 Planned TD at 11750.00 9/27/2016 4:32:35PM Page 3 COMPASS 5000.1 Build 74 • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-22 3H-22L1-02 3H-22L1-02_wp02 Travelling Cylinder Report 14 September, 2016 BAKER HUGHES • Baker Hughes INTEQ rug ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-22 Project: Kuparuk River Unit TVD Reference: 3H-22 @ 76.00usft(3H-22) Reference Site: Kuparuk 3H Pad MD Reference: 3H-22 @ 76.00usft(3H-22) Site Error: 0.00 usft North Reference: True Reference Well: 3H-22 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3H-22L1-02 Database: OAKEDMP2 Reference Design: 3H-22L1-02_wp02 Offset TVD Reference: Offset Datum Reference 3H-22L1-02_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,815.00 to 11,750.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,367.40 usft Error Surface: Elliptical Conic Survey Tool Program Date 9/14/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 9,700.00 3H-22(3H-22) GCT-MS Schlumberger GCT multishot 9,700.00 9,815.00 3H-22L1_wp04(3H-22L1) MWD MWD-Standard 9,815.00 11,750.00 3H-22L1-02_wp02(3H-22L1-02) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 115.00 115.00 16" 16 26 4,348.00 3,127.05 9 5/8" 9-5/8 13-1/2 11,750.00 6,178.13 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) 4 (usft) (usft) (usft) Kuparuk 3H Pad 3H-20-3H-20L1-3H-20L1 Out of range 3H-20-3H-20L1-02-3H-20L1-02 Out of range 3H-20-3H-20L1-06-3H-20L1-06 Out of range 3H-21-3H-21-3H-21 Out of range 3H-22-3H-22-3H-22 9,834.66 9,850.00 42.12 8.13 34.02 Pass-Major Risk 3H-22-3H-22L1-3H-22L1_wp04 9,824.99 9,825.00 0.35 0.30 0.11 Pass-Minor 1/10 3H-22-3H-22L1-01-3H-22L1-01_wp01 9,824.99 9,825.00 0.35 0.30 0.11 Pass-Minor 1/10 3H-22-3H-22L1-03-3H-22L1-03_wp02 9,900.00 9,900.00 0.00 0.28 -0.22 FAIL-Minor 1/10 3H-22-3H-22L1-04-3H-22L1-04_wp02 9,824.99 9,825.00 0.35 0.30 0.10 Pass-Minor 1/10 3H-22-3H-22L1-05-3H-22L1-05_wp02 9,825.00 9,825.00 0.00 0.58 -0.53 FAIL-Minor 1/10 3H-24-3H-24-3H-24 Out of range 3H-28-3H-28-3H-28 Out of range 3H-28-3H-28A-3H-28A Out of range 3H-31-3H-31-3H-31 Out of range 3H-32-3H-32-3H-32 Out of range 3H-32-3H-32PB1-3H-32PB1 Out of range Kuparuk 3M Pad 3M-29-3M-29-3M-29 11,621.11 11,400.00 1,322.89 533.69 792.61 Pass-Major Risk 3M-29-3M-29A-3M-29A 11,621.11 11,400.00 1,322.89 537.61 788.76 Pass-Major Risk 3M-29-3M-29APB1-3M-29APB1 11,621.11 11,400.00 1,322.89 537.61 788.76 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/14/2016 3:51:15PM Page 2 COMPASS 5000.1 Build 74 en N O Q N N1 • .O O Q III x ad x p N 7:1i - O `W; N�\ N N N N en M •y Nhilig '+ , a WC , o 4Illtj"'-1 N N. 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UOM COR CO CD O COLO NN m M _b C. -I-N MCV COR MCA CO O N CO CT CT a0<2 a)R R CO CD O CO m oO O W Oo0 a0 CO x000 sc'b S O \ ^ W Q O O O o 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 N 0 0 .0. a 0 o r 0•cr o O CO CO CA C70 O CA NJ Cn Cr)CS '0 m NOCt)�NNN CO 0 0 H 0 0 NO b �O b O OO U 0 0 0 0 0 0 0 N R ti C O O CO 0 U NMR COCO�O 0 0 c- = (U 0O Z o (u!/$sn c9)piaci!eo!11an anu V KUP INJ • 3H-22 ConocoPhillips ii Well Attributes Max Angle&MD TD • • Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status net(°) MD(ftKB) Act Blm(ftKB) CvacoPwe,� 501032009700 KUPARUK RIVER UNIT INJ 60.15 5,100.00 10,234.0 ••• Comment H2S(ppm) Date Annotation End Date KBSxd(ft) 'Rig Release Data 3H-22,10/7/2016342'55 PM SSSV:None Last WO: 3/20/2016 42.01 2/28/1988 Vertical schematic(actual) iI Annotation Depth(ftKB) End Date Annotation Last Mod By End Date 1 q Last Tag:SLM 9,803.0 5/26/2016 Rev Reason:SET WHIPSTOCK pproven 10/7/2016 '. HANGER:35.0 illll'j� "1..__ 1d Yl Casing Strings ° , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED • i- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...W1/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 4,347.6 3,126.8 36.00 J-55 BTC •4 4 ^ • 4• 4 - •4 • •„ mommaw Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 10,052.2 6,267.8 26.00 J-55 BTC ^A'""'Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection i TUBING RWO 2016 3 1/2 2.992 35.0 9,586.8 5,984.6 9.30 L-80 EUE 8rd Mod CONDUCTOR;36.0-115.0 ' i Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 35.0 35.0 0.09 HANGER McEvoy Gen III Tubing Hanger,MSDP-1-6.5-MS-3,7- 2.950 GAS LIFT;3,248.3 1/16"x 3-1/2"EUE 8rd Box x Box,3"H BPVG 1 9,574.2 5,976.9 52.65 LOCATOR Locator Sub,GBH-22(bottom of the locator spaced out 2.990 3.83') 9,575.3 5,977.6 52.65 SEAL ASSY Seal Assembly,80-40 3.020 Tubing Description String Ma...ID(in) Top(ftKB) Sat Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection LOWER COMP RWO 4 1/2 3.958 9,578.3 9,736.0 6,075.3 12.60 L-80 STC 2016 Completion Details SURFACE;35.04,3476 + A Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 9,578.3 5,979.4 52.65 PACKER 587-400 Model'F'Production Packer 4.000 9,581.6 5,981.4 52.64 SBE 80-40 Seal Bore Extension(SBE) 4.000 GAS LIFT;5,598 9 INF 9,591.0 5,987.1 52.62 XO Reducing Crossover,4-3/4"Stub Acme Box x 3-1/2"EUE 8rd Pin 2.970 ff 9,639.7 6,016.7 52.57 NIPPLE Nipple,HES,2.813"X,SN:C-3562596 2.812 9,651.6 6,023.9 52.56 PORTED Ported Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"STC 2.992 CROSSOVER Pin I GAS LIFT;7,260.2It 9,653.4 6,025.0 52.56 PORTED Ported Wearsox Joint,4-1/2",12.6#,L-80,STC Box x 3.958 WEARSOX Mule Shoe Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) - Top(TVD) Top Incl Top(ftKB) (ftKB) (°) • Des Com Run Date ID(in) 9,715.0 6,062.5 52.52'WHIPSTOC BAKER 3.5"X4.5"WHIPSTOCK(GENII DELTA). 10/6/2016 GAS LIFT-3.078 n TOWS=9715,WHIPSTOCK ORIENTATION= 330DEG,CCL TO TOP OF WHIPSTOCK=14.9',RA TAG @7.35 FROM TOP,WHIPSTOP OAL=12.97 Perforations&Slots ( Shot GAS LIFT;9,517.2 Dens Top(ND) Btm(TVD) • (shotstf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone _ Date t) Type Com 9,690.0 9,710.0 6,047.3 6,059.4 A-3,3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet;60 deg ph 9,716.0 9,736.0 6,063.1 6,075.3 A-2,3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet;60 deg ph LOCATOR;9,574.2 9,754.0 9,774.0 6,086.2 6,098.4 A-1,3H-22 '4/25/1988 4.0 (PERF SOS 4.5"Ultra P;120 4u. deg ph PACKER;9,578.3, - Mandrel Inserts SEAL ASSY;9,575.3 _ St if ati SBE;9,581.6 rir on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 3,246.3 2,509.1 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 XO Reducing;9,591.0 i I 2 5,598.9 3,802.4 Comm MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 3 7,260.2 4,693.3 Camco MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 5/27/2016 4 8,576.8 5,395.5 Camcc MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 5 9,517.3 5,942.4 Cameo MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 • Notes:General&Safety End Date _ Annotation NIPPLE;9,639.6 4/28/1988 NOTE:Bad spot in 7"CSG 8257'-8281';Max ID=6.45";Tested to 2600psi w/10 ppg Brine. 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 PORTED CROSSOVER; 9,651.6 PORTED WEARSOX;9,653.4, APERF;9,690.0-9,710.0--6-* WHIPSTOC;9,715.0, APERF;9,718.0-9,738.0 - IPERF;9,754.0-9,774.0- PRODUCTION;35.0-10,052.2 • S N N p O O 0 2 3 2 3 o .c O 0 L p o a O Q2 co p 2 m a0 O Cu)o coV 32p� co N N @ O N O N O a .-N N u]Ql J•- O J,-c0 3J�mN V N NG •- ro� 2pc N©O JM F .J ' U = p c M H Q o n 2 0 3 p<- a �2' 3m rpN Som rm(�) Yg -4-L° a Lo o .0 Lo rn aII m o�a J"a ii N Lo N p` M o N©� ''{' II I _0 c �p`` 2 p c u 'i co F--1 CO p o N@ co f-J 1 Nc O () - N MI-J PIP V = V 5 >" O N 0) O „ ii H Eo c (6 �_ i � co X N M N ii W o co � co � (6 Co c C) C o ii D CD- m0) 0 CT)c ,i W N m a) o-0 ''; O 00 o , Y co N,c cc''77 N t j KS n-p W N o CO 0) 0 m o U.co 2 m ao N Nb U-Y N v ,_ o co M� JCC] (mm Y) V I VI r 1 _ / n CO i i i i i pM 11_ ,.. N v ... l 1 O O N y U a ) aN w2- O a Lo 2 a 0 N L 0 2 a� o 0 a T p in 0oiov `�2 (V = 0 m rnOM m rn0) Ln N v 0 0 N 0 mBo co a o 10 - o (D L W G 0 c00 r N•-- M w m rn m rn i. N M N Q Q Q Q - le • • all e SMO m MB 9y N L J - _rte iP'lV / O^ M IC OO r 0 o Fn N 4o r S' «. CS o . � os zooyU I a . ,sI n 2000 c l�, - .n 6 _ U c c c vNN g-,' O'— _/W a Lomm N te . ` so oU _ m v .!-^"� r ' — G E,v`w , a o5 is"' _ 66 � x- � ,� r g d � h yz..-°,:;, in X0 ,J--,---!- o s 40� . ` a= o rxn . J 1 ,. % -i h5W I o o :7 ., ktik,_ m z ' = '' , _ -Q , i � .� _hA c '\, y - omNNE Ja © ▪C E 1001 „ 5 I �_z▪v m000 } - E:6 N 4 . 31- 111111 z Lii.:11\*P �� . s 1 : ',:,- _ ) ____„,,,,,,4 re -- „--., -_,•:,,, , c.: MOS - : i__ 1 _ _ „., _, N 1_ N it 0- 'C r I \ N J Pit ill:, 7 N o AC M M 3� Pill /i. I O Y Y r t� rirm -.14„,:: Y YMMa ,■ _ _ - , ii:,•y6. - ao, I ., ! _ o a` dN 1 / v ./ rn III ii i N __.__--- -_... - ( ... r - O / I- 00 C 00 _ a 0 I!” '' A rif o 0 VI Illi i 0 O CL , NENNINNI jr os 0,, ,_ , a's-I 8 _ _ • '� O u p o o o , 0 0, 0 0 0 0 0, 0 0 0 0 0 0 0 0 0 0 0 V V m m N N -, O . . co W , r 8 8 O V V M OM r--. N - O N V (ui/gsn OSS) (+)quol�U(-)q;nos M ■ W • • AllZ �W0 0 V 111 Iii_ 1 00 i =± . Millih: 1 . b ■■ IIIIIII — �% .....:„ r__ W t 111\ 1:;II N II _ �—?Sw M \ ,. IH1U � i IL .-.ONS�m• J 1 Nill o 0 '. : ! o 0 oy, 0 r _ r i ' I LI 11o I !! ,C ,-. 1, : O Ldj a O \`\\\ �- —may ' 111 _-_ O 111 P.C O \lk $ - ___... ` _ _ ... _ - A -.. P "We ....., ..... a dm o "Sa v1 1 # '1111111it VF =AI "-§t g.° ; iz , Illk �, I O ,;:,1 111114 iia„.„iii1111110k(1....._ . nO _ V O ® ,__ Nal , „..,, , , ,., •. , 1 , s, d 6 N1 ■ lip 09 ■ i,,,,, I O rii J N liN O. ■ IXC-. . I. , I� ,O YYr=ino j � c' o __ _..._ i _ _ o I 1 _ui3a J - ! I .I M , : i. _ O A 11 I i p I 0-78.o o '211 111111 i III oO VI MNIPIP MP." 2,7 N _ uOno 1 I pw.---gi <:, 8 11 1 O Oa ,- I ' t c Cf cirU1 II' I OO O O O O O O OO O O O O O O O O O O O O e O O O O O O OOOO OOO O OO O O O O O O O WO O o O V N OCOO V N O W NO N ,0 R N O 0 .O V N O N N O O O O , 0, 0, a N o W 07 N N N N b b b b h N N0 V - _ - - (ui/8sn OOZ) (+)gIoN/(-)u�nos • • Schwartz, Guy L (DOA) From: Connelly,Jeff <Jeff.S.Connelty@conocophillips.com> Sent Monday, November 14, 2016 10:50 AM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA);Connelly,Jeff Subject: RE: KRU 3H-22L1 (PTD 216-145) Guy, I checked with our directional team at Baker Hughes and you are indeed correct. Below is the pertinent information regarding 3H-31, including cementing information. 3H-31 (Injector),—1000'away from 3H-22L1 at 11,750' MD • Classified as a"Normal Well" • The well is an injector • The well is completed with 3.5" 9.3# L-80 tubing and 7"26#L-80 production casing. • Packer located at 10,311' MD which is located less than 200'from the top of the perforations. • A/C-sand perforations: C4: 10,426'—10,444 MD, A2/A1: 10,452—10,482' MD, and Al: 10,482'— 10,494' MD • Well is currently SI for Pre-CTD well work(shut-in since 10/6/2016). • Production casing was cemented with 250 sx Class'G' • Surface casing was cement with 1100 sx AS III &600 G • Conductor casing was cemented with 200 sx AS I Please let me know if you have additional questions. Regards, -Jeff From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, November 14,2016 8:58 AM To:Connelly,Jeff<Jeff.S.Connelly@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]KRU 3H-22L1 (PTD 216-145) Jeff, It appears that 3H-31 transects the'A mile AOR. Can you verify that the wellbore is cemented or that the A sand is not present. I can't tell looking at a mapview. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 • • Bettis, Patricia K (DOA) -2m 2j(o _ iY 7 - From: Connelly,Jeff <Jeff.S.Connelly@conocophillips.com> Sent: Wednesday, November 09, 201.6 5:47 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3H-22L1 (PTD 216-145): Permit to Drill Application Patricia, The maximum down-hole pressure and potential surface pressure should be based on 3H-31 as follows: Maximum down-hole pressure:4825 psi Maximum potential surface pressure:4205 psi (assuming a gas gradient of 0.1 psi/ft) I apologize for the inconsistency between the two documents. Regards, Jeff Connelly From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Tuesday, November 08, 2016 4:32 PM To: Connelly,Jeff<Jeff.S.Connelly@conocophillips.com> Subject: [EXTERNAL]KRU 3H-22L1 (PTD 216-145): Permit to Drill Application Good afternoon Jeff, On Form 10-401, Box 17,the maximum downhole pressure is shown as 4384 psig; whereas the maximum potential surface pressure is stated as 3741 psig. On page 2 of the "Application for Permit to Drill Document", it is stated that the maximum downhole pressure in the 3H- 22 vicinity is 3H-31 at 4825 psi; whereas the maximum potential surface pressure in 3H-22, assuming a gas gradient of 0.1 psi/ft would be 4205 psi. Please clarify what ConocoPhillips anticipates to be the maximum downhole pressure in the 3H-22 vicinity and the maximum potential surface pressure for 3H-22. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: -az 1.1 -.0 9, PTD: 02110 -f-( Development Xervice Exploratory Stratigraphic Test Non-Conventional FIELD: Kura.4 V POOL: g ?.Air r `d< R,v4 r o t 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. / l/13 , API No. 50- /0 3- a 00? -QO - 00. ✓ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 • 11 171 6 N a)• a � � a) N N C' • Tu c N d' a s a, el L E o, W: (Q ° c. N f4 O a). 7, c a). y N m a ° as. a 3, o of ii II c , , , , o; , 3, , , , —, y 3, 2 ds, y, = o = co .� , L Z. >. a c a , , v c:, P. 2' o a) o m o. y. — o. co w, E N a v. > o o; a) CV � V y' '` �� co pa WOM� c, E� -o �� J O C' N' �, a). o � f/ D In ' N H N O. a, � E' , � � � , 4 N. c ac). 3 a) o' �� 4 � =, N -la ' 0 zU 0 � CO O' �, ma oof a a' O: N' , t , , c N. y' -2' o 5, � N. 7. W' d. a) N' N N. Z , d a . 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