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209-006
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Scale Inhibition Treatment ConocoPhillips Alaska, Inc. 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 19,564 feet None feet true vertical 6,854 feet None feet Effective Depth measured 19,564 feet 11,252, 11,375 feet true vertical 6,854 feet 6605, 6665 feet Perforation depth Measured depth Pre-drilled liner 12,268'-15,442'Perforation depth MD: 18330-18350', 18630-18650', 19280-19300 Perf Pups: 15,648'-19,433'(re-perf) True Vertical depth Pre-drilled liner 6,959'-6,914'TVD: 6887-6886', 6882-6882', 6870-6869 Perf Pups: 6,914'-6,861' Tubing (size, grade, measured and true vertical depth)4.5" L-80 11,947'MD 6,890'TVD Packers and SSSV (type, measured and true vertical depth)Packer:Baker Premier Production Packer 11,252'MD 6,605'TVD Packer:Baker S-3 Production Packer 11,375'MD 6,665'TVD SSSV- BP-6i for WRSV 2,195'MD 2,019' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Mark Shulman Contact Name:Mark Shulman Authorized Title:Sr. Production Engineer Contact Email:mark.shulman@cop.com Contact Phone:(907) 263-3782 Senior Engineer:Senior Res. Engineer: CollapseBurst 2959' 12037' 2461 6942 6854 Authorized Signature with date: Authorized Name: Casing Conductor 16" 9-5/8" 7" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 431 Size 7534' Surface Intermediate 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 2181 Gas-Mcf measuredPlugs Junk measured Please see attached Summary 7415 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 209-006 50-103-20593-00-00 N/A 5. Permit to Drill Number: Colville River Field/Fiord Nechelik Field 2. Operator Name ADL 372105, ADL 380092, ADL 384215, ADL 389725 12156-19564' MD 1195 1360 CRU CD3-115 Liner 4-1/2" Length 77' P.O. Box 100360, Anchorage, Alaska 995103. Address: 4. Well Class Before Work: 385 Representative Daily Average Production or Injection Data 3242482 Casing Pressure Tubing Pressure 114 3138 Oil-Bbl measured true vertical Packer 19564 WINJ WAG 4726 Water-Bbl MD 114 2995 12156 TVD t Fra O g g g l g 6. A G L G R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 2:21 pm, May 04, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.05.04 14:05:54 -08'00' Alpine Oil Pool SFD 5/4/2021 VTL 5/5/21 SFD 5/4/2021DSR-5/5/21 RBDMS HEW 5/5/2021 Scale Inhibitor Squeeze Job pumped from 1245 - 0700 hrs on 4/18/21. LRS = Little Red Services ACF = Alpine Central Facility x Initial pressure TBG/IA/OA – 50/1325/320 x LRS and ACF pumped 254 bbls WAW5206/Diesel pre-flush at 2 bpm x LRS pumped 290 bbls Seawater/SCW3001 scale inhibitor main treatment at 2.0 bpm, TBG/IA/OA x ACF pumped 3083 bbls Diesel over-flush at 1.4 bpm, TBG/IA/OA – 370/1540/460 Interval treated: 12,156’ – 19,564’ MD Tubing: 4.5”, L-80, 11373’ MD, 6664’ TVD Upper Packer: Baker Premier Packer, 11252' MD, 6605' TVD Lower Packer: Baker S-3 Packer, 11375’ MD, 6665’ TVD SSSV: DB-6i WRDP, 2195' MD, 2019' TVD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: CTMD 19,453.0 1/25/2021 CD3-115 claytg Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set WRDP Post CTU 4/20/2021 CD3-115 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.2 Set Depth (ftKB) 2,995.0 Set Depth (TVD)… 2,461.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 119.7 Set Depth (ftKB) 12,156.2 Set Depth (TVD)… 6,941.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,029.9 Set Depth (ftKB) 19,564.0 Set Depth (TVD)… 6,853.7 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 12,029.96,914.3 74.81 SLEEVE "HR" Liner Setting Sleeve 5.81" ID (10.13' Inner Profile) 5.250 12,042.96,917.6 75.31 NIPPLE "RS" Packoff Seal Nipple 5.63" OD X 4.26" ID 4.260 12,046.66,918.6 75.45 HANGER Baker Flex Lock Liner Hanger 5.91" OD X 4.43" ID)4.430 12,056.4 6,921.0 75.83 XO REDUCING XO Bushing - 5 1/2" TKC X 4 1/2" SLHT (3.93" ID)3.930 15,602.6 6,912.5 88.70 PERF XO 4 1/2" 12.6 # L-80 XO - 4 1/2" IBT(p) x 4 1/2" SLHT(B) - CHANGE FROM (6) 1/2" HOLES IN CENTER OF 40' JOINT XO TO PERF PUPS (6) 2 1/2" holes per 5' pup joint, alternating with 200' solid pipe sections 3.958 16,897.26,885.090.64 Swell PKR TAM Packer on 18.78' Pup - 5.78" OD, 3.937" ID, Element 10.46' 3.937 Tubing Strings Tubing Description TUBING OVERSHOT TO PACKER String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 0.0 Set Depth (ft… 11,308.0 Set Depth (TVD) (… 6,633.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 0.0 0.0 0.00 HANGER FMC Horizontal Gen ll Tubing Hanger 3.900 2,195.4 2,019.0 46.66 NIPPLE 4.5" 9CHROME BP6i Nipple, 3.812" DB profile 3.812 11,232.2 6,595.3 60.08 GAUGE 4 1/2" SGM-FS ASSY, XDPG Gauge, SN# C14GM-0045 3.864 11,252.16,605.260.16 PACKER Baker 7" X 4.5" Premier Production Packer, PN# H784-63-0121 3.870 11,276.7 6,617.5 60.25NIPPLE 4.5" X landing nipple, 3.813 X profile 3.813 11,297.7 6,627.960.32 OVERSHOTBaker Poor Boy Overshot with 6.32' of swallow Picked up 3'4.950 Tubing Description TUBING SLICKSTICK EXTENSION String Ma… 4 1/2 ID (in) 3.88 Top (ftKB) 13.5 Set Depth (ft… 11,372.9 Set Depth (TVD) (… 6,664.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 11,296.4 6,627.360.32 OEJ SLICK STICK Poorboy Shear Assy.4.500 11,369.96,662.861.77 OVERSHOT Overshot 4.500 Tubing Description TUBING 4.5" IBTM String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 11,355.8 Set Depth (ft… 11,947.0 Set Depth (TVD) (… 6,890.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 11,375.36,665.4 61.88 PACKER Baker S-3 Production Packer PN# H409-12-5706 4.500 11,442.16,696.4 62.80 NIPPLE 4.5" XN landing nipple, 3.813 XN profile 3.725 11,937.0 6,887.4 72.32 MULE SHOE 7" X 4.5" Shear Indicating WLEG 3.890 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,195.4 2,019.0 46.66 MOD. WRDP SET 4.5" DB-6i WRDP w/ MODIFIED 7" HYDRAULIC SUB & STANDARD PKG ON 3.812" NO-GO SUB. STD PKG ON TOP = <<<<O> 7" HYDRAULIC SUB STD PKG ON BTM = <O>>>> 4/20/2021 2.250 HABS-0346 11,368. 0 6,662.0 61.73 TUBING CUT CHEMICAL CUT ABOVE PACKER @ 11,368 3/22/20193.958 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 12,268.0 15,442.0 6,959.1 6,914.0 NECH-CRSUP, CD3-115 3/4/2009 6.0 PERFP TOP LINER SECTION: PRE -DRILLED LINER 14 joints of 40' lengths with (6) 1/2" HOLES @ center of EACH 40' joint, alternating with 200' solid pipe sections 15,648.019,433.06,914.26,861.3 NECH-CRSUP, CD3-115 3/4/2009 32.0 PERFP LOWER LINER SECTION: PERF PUPS: (6) 2 1/2" holes per 5' pup joint, alternating with 200' solid pipe sections 18,330.0 18,350.0 6,886.7 6,886.3 NECH-CRSUP, CD3-115 1/26/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole HORIZONTAL, CD3-115, 4/20/2021 5:23:41 PM Vertical schematic (actual) XN LINER; 12,029.9-19,564.0 APERF; 19,280.0-19,300.0 APERF; 18,630.0-18,650.0 APERF; 18,630.0-18,650.0 APERF; 18,330.0-18,350.0 APERF; 18,330.0-18,350.0 PERFP; 15,648.0-19,433.0 PERFP; 12,268.0-15,442.0 INTERMEDIATE; 119.7- 12,156.2 MULE SHOE; 11,937.0 NIPPLE; 11,442.1 PACKER; 11,375.3 OVERSHOT; 11,369.9 OVERSHOT; 11,297.7 OEJ SLICK STICK; 11,301.0 NIPPLE; 11,276.7 PACKER; 11,252.1 GAUGE; 11,232.1 GAS LIFT; 11,205.7 GAS LIFT; 9,322.7 Annular Fluid - 10.9 ppg NaCl/NaBr Brine; 31.0-11,369.3; 4/4/2019 Annular Fluid - 10.9 ppg Brine NaCl/NaBr; 31.0-11,369.3; 4/4/2019 GAS LIFT; 4,887.4 SURFACE; 36.2-2,995.0 MOD. WRDP; 2,195.4 WR-SSSV; 2,195.4 NIPPLE; 2,195.4 CONDUCTOR; 37.0-114.0 HANGER; 30.9 WNS PROD KB-Grd (ft) 42.70 Rig Release Date 3/7/2009 CD3-115 ... TD Act Btm (ftKB) 19,564.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032059300 Wellbore Status PROD Max Angle & MD Incl (°) 93.81 MD (ftKB) 12,506.79 WELLNAME WELLBORE Annotation Last WO: End Date 3/20/2019 H2S (ppm)DateComment SSSV: BP-6i NIPPLE / WRDP Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 18,330.0 18,350.0 6,886.7 6,886.3 NECH-CRSUP, CD3-115 1/26/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole 18,630.0 18,650.0 6,882.3 6,882.2 NECH-CRSUP, CD3-115 1/26/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole 18,630.018,650.06,882.36,882.2 NECH-CRSUP, CD3-115 1/26/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole 19,280.019,300.06,869.96,868.8 NECH-CRSUP, CD3-115 1/25/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole 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 4,887.4 3,394.8 59.73 Camco KBG-2 1 GAS LIFT DMY 4/4/2019 2 9,322.7 5,578.3 60.38 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1,857.0 4/6/2019 3 11,205.7 6,582.1 59.99 Camco KBG-2 1 GAS LIFT OV BK 0.250 4/6/2019 Notes: General & Safety End Date Annotation 5/3/2019 NOTE: VIEW SCHEMATIC w/Alaska Schematic10.0 HORIZONTAL, CD3-115, 4/20/2021 5:23:44 PM Vertical schematic (actual) XN LINER; 12,029.9-19,564.0 APERF; 19,280.0-19,300.0 APERF; 18,630.0-18,650.0 APERF; 18,630.0-18,650.0 APERF; 18,330.0-18,350.0 APERF; 18,330.0-18,350.0 PERFP; 15,648.0-19,433.0 PERFP; 12,268.0-15,442.0 INTERMEDIATE; 119.7- 12,156.2 MULE SHOE; 11,937.0 NIPPLE; 11,442.1 PACKER; 11,375.3 OVERSHOT; 11,369.9 OVERSHOT; 11,297.7 OEJ SLICK STICK; 11,301.0 NIPPLE; 11,276.7 PACKER; 11,252.1 GAUGE; 11,232.1 GAS LIFT; 11,205.7 GAS LIFT; 9,322.7 Annular Fluid - 10.9 ppg NaCl/NaBr Brine; 31.0-11,369.3; 4/4/2019 Annular Fluid - 10.9 ppg Brine NaCl/NaBr; 31.0-11,369.3; 4/4/2019 GAS LIFT; 4,887.4 SURFACE; 36.2-2,995.0 MOD. WRDP; 2,195.4 WR-SSSV; 2,195.4 NIPPLE; 2,195.4 CONDUCTOR; 37.0-114.0 HANGER; 30.9 WNS PROD CD3-115 ... WELLNAME WELLBORE ! " # " $ % &' ( )$! * (% +, !- ."! ! /, +, 01 021*- 1 3 + - " ( % /42)5 ! )4.25 ! & % /42)5 4020446*2 )4.25 ))124)))2 7 7 8 8 + 944 - 52: ,#.1 4/5*;7% )4./1;8% < 8+ (4 - < =< < 4020;7% )4)12;8% < =<#6 < 46*2;7% )4))2;8% 8#=#) " 8 04/2;7% 041/;8% 0 >9 ( $ + - 6 > 2" < % ( " &' ( % , ( )" < ? "%, & % ? ?$!@ A ,A? (! !3 &' 7< ! 7< 9 & & < B +/1*-0)6#6*.0 "$!@"? 5111 " #= 5 0//2 02) 0*2/ #= < /2)5 )..*#)..);4)..0#)..0;4).*1#).)/; !""#$" % &&'!"6 5" = " < 010 % ( $ C % 0*0.65 5 .661#.621;4.)61#.)21;4/0.1#/611;4 %,6*0124%,6.11/04%,6.5024%,6./*02 !(($) !&*'(+ 6*2 62* A %6#2 , 5#30: ,% **; &,D ,D$,!%? !& 8$! 77$$! -. - / 012-3 4.,, .- 20 ("& ""$ (" !"# ("'&# "" "" !3 2 % ! 3 ! < 0 ! ! 5 +> 01 021*14021*4E020.6- )5* ? #7 @ < 0566 7 6211 *$( ( (< 662 08 *265; $ 9 9! % ): /#23.: *: 0/2/; 016*; 05) )/50 ).25 5 & & 1#515 630101 " 61( By Samantha Carlisle at 9:38 pm, Feb 24, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.02.24 14:50:05 -09'00' SFD 2/26/2021 Alpine Oil DSR-2/25/21VTL 3/3/21 RBDMS HEW 2/25/2021 SFD 2/26/2021 !"#$%& ' ())*+,-.*( /& !"!0# (123* 3)45 2' 6 &3155* '3 2'!778#.'(2*95(5*393+:93+ # # 7 *:93+ # "7;4 % 8 43-/39 ,(.1 "7;#<.*(= #5*392 )' '*) "0 #>"; # ! * % 5*392 *39#/"0 #>"; # 5*392 ?:#0!; #>0!7 #4 ?:@ ;4 ?:#0;; 4!#>0;7 4!#4 $ @? 8 (-*/', 3)A **B*53*>9 )'(/ 3*( +* 93+ "7# !0#4: #/(/5*393+*/.3 /* /)5(.*+* & '&'* %<)** 93 /)5(.*+* /* ()=4 8 $! C?: %4 ? 0 ? $ $@ D?C?4 0" ? ?4 % E %D ?$ ?? ;>7 ++(3-95*3( ) *393( ).(* $', Scale Inhibitor Squeeze Job pumped from 0500 - 0930 hrs on 1/27/21. LRS = Little Red Services ACF = Alpine Central Facility x Initial pressure TBG/IA/OA – 40/1510/374 x LRS and ACF pumped 60 bbls WAW5206/Diesel pre-flush at 2.1 – 2.5 bpm x LRS and ACF pumped 268 bbls WAW5206/Diesel pre-flush at 2.1 bpm x LRS pumped 274 bbls Seawater/SCW3001 scale inhibitor main treatment at 2.0 bpm, TBG/IA/OA x ACF pumped 60 bbls Diesel over-flush at 1.4 bpm, TBG/IA/OA – 450/1600/300 Interval treated: 12268’ – 19452’ MD Tubing: 4.5”, L-80, 11373’ MD, 6664’ TVD Upper Packer: Baker Premier Packer, 11252' MD, 6605' TVD Lower Packer: Baker S-3 Packer, 11375’ MD, 6665’ TVD SSSV: DB-6i WRDP, 2195' MD, 2019' TVD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: CTMD 19,453.0 1/25/2021 CD3-115 claytg Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Scale Removal / Perf / Sqz 1/31/2021 CD3-115 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.2 Set Depth (ftKB) 2,995.0 Set Depth (TVD)… 2,461.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 119.7 Set Depth (ftKB) 12,156.2 Set Depth (TVD)… 6,941.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,029.9 Set Depth (ftKB) 19,564.0 Set Depth (TVD)… 6,853.7 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 12,029.96,914.3 74.81 SLEEVE "HR" Liner Setting Sleeve 5.81" ID (10.13' Inner Profile) 5.250 12,042.96,917.6 75.31 NIPPLE "RS" Packoff Seal Nipple 5.63" OD X 4.26" ID 4.260 12,046.66,918.6 75.45 HANGER Baker Flex Lock Liner Hanger 5.91" OD X 4.43" ID)4.430 12,056.4 6,921.0 75.83 XO REDUCING XO Bushing - 5 1/2" TKC X 4 1/2" SLHT (3.93" ID)3.930 15,602.6 6,912.5 88.70 PERF XO 4 1/2" 12.6 # L-80 XO - 4 1/2" IBT(p) x 4 1/2" SLHT(B) - CHANGE FROM (6) 1/2" HOLES IN CENTER OF 40' JOINT XO TO PERF PUPS (6) 2 1/2" holes per 5' pup joint, alternating with 200' solid pipe sections 3.958 16,897.26,885.090.64 Swell PKR TAM Packer on 18.78' Pup - 5.78" OD, 3.937" ID, Element 10.46' 3.937 Tubing Strings Tubing Description TUBING OVERSHOT TO PACKER String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 0.0 Set Depth (ft… 11,308.0 Set Depth (TVD) (… 6,633.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 0.0 0.0 0.00 HANGER FMC Horizontal Gen ll Tubing Hanger 3.900 2,195.4 2,019.0 46.66 NIPPLE 4.5" 9CHROME BP6i Nipple, 3.812" DB profile 3.812 11,232.2 6,595.3 60.08 GAUGE 4 1/2" SGM-FS ASSY, XDPG Gauge, SN# C14GM-0045 3.864 11,252.16,605.260.16 PACKER Baker 7" X 4.5" Premier Production Packer, PN# H784-63-0121 3.870 11,276.7 6,617.5 60.25NIPPLE 4.5" X landing nipple, 3.813 X profile 3.813 11,297.7 6,627.960.32 OVERSHOTBaker Poor Boy Overshot with 6.32' of swallow Picked up 3'4.950 Tubing Description TUBING SLICKSTICK EXTENSION String Ma… 4 1/2 ID (in) 3.88 Top (ftKB) 13.5 Set Depth (ft… 11,372.9 Set Depth (TVD) (… 6,664.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 11,296.4 6,627.360.32 OEJ SLICK STICK Poorboy Shear Assy.4.500 11,369.96,662.861.77 OVERSHOT Overshot 4.500 Tubing Description TUBING 4.5" IBTM String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 11,355.8 Set Depth (ft… 11,947.0 Set Depth (TVD) (… 6,890.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 11,375.36,665.4 61.88 PACKER Baker S-3 Production Packer PN# H409-12-5706 4.500 11,442.16,696.4 62.80 NIPPLE 4.5" XN landing nipple, 3.813 XN profile 3.725 11,937.0 6,887.4 72.32 MULE SHOE 7" X 4.5" Shear Indicating WLEG 3.890 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,195.4 2,019.0 46.66 MOD. WRDP SET 4.5" DB-6i WRDP w/ MODIFIED 7" HYDRAULIC SUB & STANDARD PKG (SN: HPS-456) ON 3.812" NO-GO SUB. STD PKG ON TOP = <<<<O> 7" HYDRAULIC SUB STD PKG ON BTM = <O>>>> 1/31/2021 2.250 HAS-251 11,368. 0 6,662.0 61.73 TUBING CUT CHEMICAL CUT ABOVE PACKER @ 11,368 3/22/20193.958 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 12,268.0 15,442.0 6,959.1 6,914.0 NECH-CRSUP, CD3-115 3/4/2009 6.0 PERFP TOP LINER SECTION: PRE -DRILLED LINER 14 joints of 40' lengths with (6) 1/2" HOLES @ center of EACH 40' joint, alternating with 200' solid pipe sections 15,648.019,433.06,914.26,861.3 NECH-CRSUP, CD3-115 3/4/2009 32.0 PERFP LOWER LINER SECTION: PERF PUPS: (6) 2 1/2" holes per 5' pup joint, alternating with 200' solid pipe sections 18,330.0 18,350.0 6,886.7 6,886.3 NECH-CRSUP, CD3-115 1/26/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole HORIZONTAL, CD3-115, 2/1/2021 5:44:42 AM Vertical schematic (actual) XN LINER; 12,029.9-19,564.0 APERF; 19,280.0-19,300.0 APERF; 18,630.0-18,650.0 APERF; 18,330.0-18,350.0 PERFP; 15,648.0-19,433.0 PERFP; 12,268.0-15,442.0 INTERMEDIATE; 119.7- 12,156.2 MULE SHOE; 11,937.0 NIPPLE; 11,442.1 PACKER; 11,375.3 OVERSHOT; 11,369.9 OVERSHOT; 11,297.7 OEJ SLICK STICK; 11,301.0 NIPPLE; 11,276.7 PACKER; 11,252.1 GAUGE; 11,232.1 GAS LIFT; 11,205.7 GAS LIFT; 9,322.7 Annular Fluid - 10.9 ppg NaCl/NaBr Brine; 31.0-11,369.3; 4/4/2019 Annular Fluid - 10.9 ppg Brine NaCl/NaBr; 31.0-11,369.3; 4/4/2019 GAS LIFT; 4,887.4 SURFACE; 36.2-2,995.0 WR-SSSV; 2,195.4 MOD. WRDP; 2,195.4 NIPPLE; 2,195.4 CONDUCTOR; 37.0-114.0 HANGER; 30.9 WNS PROD KB-Grd (ft) 42.70 Rig Release Date 3/7/2009 CD3-115 ... TD Act Btm (ftKB) 19,564.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032059300 Wellbore Status PROD Max Angle & MD Incl (°) 93.81 MD (ftKB) 12,506.79 WELLNAME WELLBORE Annotation Last WO: End Date 3/20/2019 H2S (ppm)DateComment SSSV: BP-6i NIPPLE / WRDP Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 18,630.0 18,650.0 6,882.3 6,882.2 NECH-CRSUP, CD3-115 1/26/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole 19,280.0 19,300.0 6,869.9 6,868.8 NECH-CRSUP, CD3-115 1/25/2021 6.0 APERF 2.88" Guns - 6 SPF - 60 deg - 2,906 PJ Nova HMX - 16.9gm - 0.38" Ent Hole Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 4,887.4 3,394.8 Camco KBG-2 1 GAS LIFT DMY 4/4/2019 2 9,322.7 5,578.3 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1,857.0 4/6/2019 3 11,205.7 6,582.1 Camco KBG-2 1 GAS LIFT OVBK 0.250 4/6/2019 Notes: General & Safety End Date Annotation 5/3/2019 NOTE: VIEW SCHEMATIC w/Alaska Schematic10.0 HORIZONTAL, CD3-115, 2/1/2021 5:44:44 AM Vertical schematic (actual) XN LINER; 12,029.9-19,564.0 APERF; 19,280.0-19,300.0 APERF; 18,630.0-18,650.0 APERF; 18,330.0-18,350.0 PERFP; 15,648.0-19,433.0 PERFP; 12,268.0-15,442.0 INTERMEDIATE; 119.7- 12,156.2 MULE SHOE; 11,937.0 NIPPLE; 11,442.1 PACKER; 11,375.3 OVERSHOT; 11,369.9 OVERSHOT; 11,297.7 OEJ SLICK STICK; 11,301.0 NIPPLE; 11,276.7 PACKER; 11,252.1 GAUGE; 11,232.1 GAS LIFT; 11,205.7 GAS LIFT; 9,322.7 Annular Fluid - 10.9 ppg NaCl/NaBr Brine; 31.0-11,369.3; 4/4/2019 Annular Fluid - 10.9 ppg Brine NaCl/NaBr; 31.0-11,369.3; 4/4/2019 GAS LIFT; 4,887.4 SURFACE; 36.2-2,995.0 WR-SSSV; 2,195.4 MOD. WRDP; 2,195.4 NIPPLE; 2,195.4 CONDUCTOR; 37.0-114.0 HANGER; 30.9 WNS PROD CD3-115 ... WELLNAME WELLBORE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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 W DSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15.Well Class after work: Exploratory Development ServiceStratigraphic 16.Well Status after work:Oil Gas WDSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) WINJ W AG tion: tion: Gas-Mcf Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl W ater-Bbl summary: olumes used and final pressure: epth feet epth feet true vertical depth) d and true vertical depth) Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: mber):8.Well Name and Number: onic data per 20AAC25.071):10.Field/Pool(s): ry: ured feet feet tical feet feet ured feet feet tical feet feet CollapseBurstTVD 5.Permit to Drill Number: Size measuredPlugs Junkmeasured 4. W ell Class Before W ork: measured true vertical Packer MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:34 pm, Nov 09, 2020 ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 209-006 50-103-20593-00-00 ADL 380092, 372105, 389725, 384215 CD3-115 None Colville River Field/Fiord Oil Pool 19564 6854 None None 19564 6854 11375 6665 Conductor 77' 16" 114 114 Surface 2959' 9.625" 2995 2461 Intermediate 12122' 7" 12156 6942 Liner 7534' 4.5" 19564 6854 12268 - 19433 6959 - 6861 see attached see attached see attached 12156' - 19564' MD Please see attached summary 240 2748 1966 1203 321 467 3809 2842 1391 297 N/AKaylie Plunkett Senior Production Engineer Kaylie Plunkett Kaylie.B.Plunkett@conocophillips.com 265-6450 Scale Inhibition ✔ ✔ ✔✔ ✔ Kaylie Plunkett Digitally signed by Kaylie Plunkett Date: 2020.11.09 09:28:59 -09'00' VTL 2/24/21 SFD 11/9/2020RBDMS HEW 11/9/2020 DSR-11/10/2020 CD3-115 Scale Inhibition Treatment 10/8/20 Hybrid Scale Inhibitor Squeeze Job pumped from 0930 - 1730 hrs on 10/8/20. LRS = Little Red Services ACF = Alpine Central Facility x Initial pressure TBG/IA/OA – 587/1085/586 x LRS and ACF pumped 90 bbls WAW5206/Diesel pre-flush at 0.3 – 1.4 bpm, TBG/IA/OA – 138/1046/486 x LRS pumped 90 bbls Seawater/SCW3001 scale inhibitor main treatment at 0.3 – 1.6 bpm, TBG/IA/OA – 0/1033/449 x ACF pumped 500 bbls Diesel over-flush at 1.4 bpm, TBG/IA/OA – 2/1014/420 Interval treated: 12156’ – 19564’ MD Tubing: 4.5”, L-80, 11373’ MD, 6664’ TVD Upper Packer: Baker Premier Packer, 11252' MD, 6605' TVD Lower Packer: Baker S-3 Packer, 11375’ MD, 6665’ TVD SSSV: DB-6i WRDP, 2195' MD, 2019' TVD 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15.Well Class after work: Exploratory Development ServiceStratigraphic 16.Well Status after work:Oil Gas WDSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) WINJ W AG tion: tion: Gas-Mcf Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl W ater-Bbl summary: olumes used and final pressure: epth feet epth feet true vertical depth) d and true vertical depth) Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: mber):8.Well Name and Number: onic data per 20AAC25.071):10.Field/Pool(s): ry: ured feet feet tical feet feet ured feet feet tical feet feet CollapseBurstTVD 5.Permit to Drill Number: Size measuredPlugs Junkmeasured 4. W ell Class Before W ork: measured true vertical Packer MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 4:35 pm, May 20, 2020 ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 209-006 50-103-20593-00-00 ADL 380092, 372105, 389725, 384215 CRU CD3-115 None Colville River Field/Fiord Oil Pool 19564 6854 None None 19564 6854 11375 6665 Conductor 77' 16" 114 114 Surface 2959' 9.625" 2995 2461 Intermediate 12122' 7" 12156 6942 Liner 7534' 4.5" 19564 6854 12268 - 19433 6959 - 6861 4.5" L-80 11937' 6887' see attached see attached 11937' 6887' 12268' - 18088' CTMD Please see attached summary 672 2593 3693 1659 331 630 3283 3542 1591 328 N/AKaylie Plunkett Senior Production Engineer Kaylie Plunkett Kaylie.B.Plunkett@conocophillips.com 265-6450 Scale Inhibition ✔ ✔ ✔✔ ✔ Kaylie Plunkett Digitally signed by Kaylie Plunkett Date: 2020.05.19 09:07:38 -08'00' DSR-5/20/2020 RBDMS HEW 5/22/2020 VTL 5/26/20 SFD 5/20/2020 CD3-115 Scale Inhibition Treatment 4/6/20 – 4/8/20 Hybrid Scale Inhibitor Squeeze Treatment pumped from 1758 hrs on 4/6/20 to 0400 hrs on 4/8/20. LRS = Little Red Services CT = Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA – 320/1647/529 - RIH with CT to 17000’ CTMD - Pumped 290 bbls Diesel/M209/WAW5206 pre-flush through CT while RIH to 18088’ CTMD - Pumped 290 bbls Seawater and SCW3001 scale inhibitor through CT while POOH from 18088’ – 12268’ CTMD - LRS pumped 3086 bbls dead crude/M209 over-flush at 1.3 – 3.0 bpm - Final pressure TBG/IA/OA – 0/1630/350 Interval treated: 12268’ – 18088’ CTMD Packers and SSSV (type, measured and true vertical depth) Packer - Baker S-3 Packer, 11375' MD, 6665' TVD SSSV - DB-6i WRDP, 2195' MD, 2019' TVD 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL aGSTOR GINJSUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp W ell Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 209-006 50-103-20593-00-00 ADL 380092, 372105, 389725, 384215 CRU CD3-115 None Colville River Field/Fiord Oil Pool 19564 6854 None None 19564 6854 11375 6665 Conductor 77' 16" 114 114 Surface 2959' 9.625" 2995 2461 Intermediate 12122' 7" 12156 6942 Liner 7534' 4.5" 19564 6854 12268 - 19433 6959 - 6861 4.5" L-80 11937' 6887' see attached see attached 11937' 6887' 12268' - 19456' CTMD Please see attached summary 207 1850 1817 1538 328 690 2164 3729 1595 318 N/AKaylie Plunkett Senior Production Engineer Kaylie Plunkett Kaylie.B.Plunkett@conocophillips.com 265-6450 Scale Inhibition ✔ ✔ ✔✔ ✔ By Samantha Carlisle at 3:30 pm, Mar 31, 2020 SFD 3/31/2020VTL 4/8/20 DSR-4/8/2020 RBDMS HEW 4/2/2020 CD3-115 Scale Inhibition Treatment 2/19/20 – 2/21/20 Hybrid Scale Inhibitor Squeeze Treatment pumped from 1645 hrs on 2/19/20 to 0200 hrs on 2/21/20. LRS = Little Red Services CT = Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA – 1468/1230/524 - RIH with CT to 19456’ CTMD - Pumped 290 bbls Diesel/M209/WAW5206 pre-flush through CT at 2.0 bpm while POOH to 12268’ CTMD - Pumped 290 bbls Seawater and SCW3001 scale inhibitor through CT at 1.8 bpm while RBIH to 19456’ CTMD - POOH with CT. TBG/IA/OA – 1501/1757/426 - LRS pumped 3173 bbls dead crude/M209 over-flush. Interval treated: 12268’ – 19456’ CTMD Packers and SSSV (type, measured and true vertical depth) Packer - Baker S-3 Packer, 11375' MD, 6665' TVD SSSV - DB-6i WRDP, 2195' MD, 2019' TVD p�/� boy—aDL Loepp, Victoria T (CED) From: Regg, James B (CED) Sent: Thursday, February 6, 2020 4:18 PM To: Loepp, Victoria T (CED) Subject: FW: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Attachments: SVS CRU CD3 10-10-19.xis; SVS CRU CD3 12-19-19 MISC.xls Follow Up Flag: Follow up Flag Status: Flagged Looks like an extension is really the only acceptable option. I want to see a new passing SVS test (pilot and SSV) before granting the extension. The last test was 10-17-19 (retest) following the SSSV failed test on 10-10-19. Jim Regg Supervisor, Inspections AOGCC 333 W.7�h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.ree¢@alaska.Qov. From: Long, Jason W <Jason.W.Long@conocophillips.com> Sent: Thursday, February 6, 2020 2:48 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Victoria, Thank you. I will email first on Saturday, 2/8/20, with the current status and best estimate on timing for the CT work. The weather forecasts currently do no show temperatures warming and allowing wellwork to start until Sunday 2/9. The coil unit is currently spotted on CD3 -113 and has —1 day of work left once the weather breaks. The hope was to finish that job and then move immediately over to CD3 -115 which would most likely be Monday. Thanks, Jason Long WNS Production Engineer ConocoPhillips Alaska, Inc. Alpine Office: 907-670-4934 Anchorage Office: 907-263-4409 Cell. 405-760-2277 Jason. WLonq@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, February 6, 20201:59 PM To: Long, Jason W <Jason.W.Long@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Jason, Contact me on day 14(2/8/20?) and if the CTU work has not begun, we will make a decision at that point whether to allow continued production. If CTU work has not begun, please have an updated best estimate of when this work may be started. You may contact me at this email address first or at (907)242-9156. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoo(& alas ka. a ov CONFIDENTIALrrY NOTICE This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria our)[pC°.'alaS c,gov From: Long, Jason W <Jason W Long@conocophillips.com> Sent: Thursday, February 6, 2020 11:26 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: ALP DS Lead and Simops Coord <aIp1450@conocophillips.corn>; Clayton, Greg <Greg Clayton@conocophillips.com>; Shulman, Mark <Mark Shulman@conocophillips.com>; Susen, Philip R. <Philip.R Susen@conocophillips.com>; Johnstone, Sam <Sam Johnstone@conocophillips.com> Subject: CD3 -115 Waiver for Continued Operation without SSSV Victoria, CD3 -115 is a Fiord Nechelik producer. The well was shut-in on 1/25/20 for slickline to pull the WRDP and drift the well prior to the upcoming service coil fill cleanout, scale milling, and scale squeeze operations which were anticipated to start early this month. The well was brought back online the same day. Due to extreme cold weather delays/shutdowns we have not been able to start this work. We would like to request a waiver allowing for CD3 -115 to continue to produce until the weather breaks and coil can and move over to CD3 -11S to start the scheduled work. For now, we will coordinate with Operations to continue producing the well until advised otherwise. Please let me know if you have any questions. Thanks, Jason Long WNS Production Engineer ConocoPhillips Alaska, Inc. Alpine Office: 907-670-4934 Anchorage Office: 907-263-4409 Cell: 405-760-2277 Jason.W.Lonq@conocophillips.com Loepp, Victoria T (CED) From: Long, Jason W <Jason.W.Long@conocophillips.com> Sent: Friday, February 7, 2020 2:51 PM To: Regg, James B (CED); Loepp, Victoria T (CED); AOGCC Cc: ALP DS Lead and Simops Coord Subject: RE: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Follow Up Flag: Follow up Flag Status: Flagged Thank you. Thanks, Jason Long WNS Production Engineer ConocoPhillips Alaska, Inc. Alpine Office: 907-670-4934 Anchorage Office: 907-263-4409 Cell: 405-760-2277 Jason. W Lona@conocophillips.com From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Friday, February 7, 2020 2:37 PM To: Long, Jason W <Jason.W.Long@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; AOGCC <'AOGCC.Inspectors@a laska.gov'> Cc: ALP DS Lead and Simops Coord <alp1450@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Importance: High Just submit the test notice AOGCC using web notice form and give as much notice as possible; I'm not worried about 48hr notice. You might find an Inspector in the vicinity with all the exploration work ongoing. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.reez@alaska.gov. From: Long, Jason W <Jason.W.Long@conocophillips.com> Sent: Friday, February 7, 2020 1:17 PM To: Regg, James B (CED) <jim.regg@alaska.aov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Cc: ALP DS Lead and Simops Coord <a1p1450@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Jim/Victoria, The 48hr notice for state witnessed SVS testing, if put in today will be past when the 14 day clock expires (2/8/20 at 18:25). Will the waiver for continued operation still be ok even though the clock has expired and the witnessed SVS test has not been completed yet? Thanks Thanks, Jason Long WNS Production Engineer ConocoPhillips Alaska, Inc. Alpine Office: 907-670-4934 Anchorage Office: 907-263-4409 Cell: 405-760-2277 Joson.WLonq@conocophilli,ps.com From: Regg, James B (CED) <jim.regg@alaska.sov> Sent: Friday, February 7, 2020 1:04 PM To: Long, Jason W <Jason.W.LonQ@conocophillips.com>; Loepp, Victoria T (CED) <yictoria.loeppC@alaska.gov> Subject: RE: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV State witnessed Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.reggPalaska.goc. From: Long, Jason W <Jason.W.LonR@conocophillips.com> Sent: Friday, February 7, 2020 11:42 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Cc: Regg, James B (CED) <iim.reggCa)alaska.eov> Subject: Re: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Victoria, Thank you. This SVS test does not need to be state witnessed correct? Passing tests witnessed by the DSO is adequate for this extension? Thanks, Jason From: Loepp, Victoria T (CED) <yictoria.loepp@alaska.aov> Sent: Friday, February 7, 2020 11:26 AM To: Long, Jason W Cc: Regg, James B (CED) Subject: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Jason, We will grant an extension with a new passing SVS test(pilot and SSV). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCa2alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loenp@alaska.aov From: Long, Jason W <Jason.W.Long@conocophillips.com> Sent: Thursday, February 6, 2020 2:48 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Victoria, Thank you. I will email first on Saturday, 2/8/20, with the current status and best estimate on timing for the CT work. The weather forecasts currently do no show temperatures warming and allowing wellwork to start until Sunday 2/9. The coil unit is currently spotted on CD3 -113 and has —1 day of work left once the weather breaks. The hope was to finish that job and then move immediately over to CD3 -115 which would most likely be Monday. Thanks, Jason Long WNS Production Engineer ConocoPhillips Alaska, Inc. Alpine Office: 907-670-4934 Anchorage Office: 907-263-4409 Cell: 405-760-2277 Jason. W. L ona@conocophillips. com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, February 6, 20201:59 PM To: Long, Jason W <Jason.W.Long@conocophillips.com> Cc: Regg, James B (CED) <lim.regg@alaska.gov> Subject: [EXTERNAL]CRU CD3-115(PTD 209-006) Operation without SSSV Jason, Contact me on day 14(2/8/20?) and if the CTU work has not begun, we will make a decision at that point whether to allow continued production. If CTU work has not begun, please have an updated best estimate of when this work may be started. You may contact me at this email address first or at (907)242-9156. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepo a(�.alaska.00v 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 on unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (90717937247 or Vick i a Luej2g , ata 4. From: Long, Jason W <Jason.W.Long@conocophillips.com> Sent: Thursday, February 6, 2020 11:26 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: ALP DS Lead and Simops Coord <a1p1450@conocophil1ips.com>; Clayton, Greg <Greg.Clayton@conocophillips.com>; Shulman, Mark <Mark.Shulman conocophillips.com>; Susen, Philip R. <Philip.R.Susen@conocophillips.com>; Johnstone, Sam <Sam.Johnstone@conocophillips.com> Subject: CD3 -115 Waiver for Continued Operation without SSSV Victoria, 03-115 is a Fiord Nechelik producer. The well was shut-in on 1/25/20 for slickline to pull the WRDP and drift the well prior to the upcoming service coil fill cleanout, scale milling, and scale squeeze operations which were anticipated to start early this month. The well was brought back online the same day. Due to extreme cold weather delays/shutdowns we have not been able to start this work. We would like to request a waiver allowing for CD3 -115 to continue to produce until the weather breaks and coil can and move over to CD3 -115 to start the scheduled work. For now, we will coordinate with Operations to continue producing the well until advised otherwise. Please let me know if you have any questions. Thanks, Jason Long WNS Production Engineer ConocoPhillips Alaska, Inc. Alpine Office: 907-670-4934 Anchorage Office: 907-263-4409 Cell: 405-760-2277 Jason. W. Long @conocophillips. com O 0 0 ui Q M Q V 0. z y o � Z } � Z V1 l� O M Vl n P M M Vl C � F d d� 0. ti L ri tu Z_N K Q V 0 3 0�000300003030 0 0���� rn roe o, o�o,rn O O O O O O O Ad o0 C W o0 S M O V1 o d A � G � O y U y F U v Eoaaa ao.ac. a a a a U a ._oo`�. oMo o.rnrnrn oM. rn rn o r O O O O O O O O O O O O O O O O O O O O O O d cn 1 A7.. L W W W � W 07 00 W W W W 4 � N N N N N N N N N N Q y L Q Q �7A M M M M zcacac 0000000caca00000cao U U U UU UU ,, U U U U U U U U U U U U U U U U U U U 0 0 0 e 55 a 3 r P� a E U 3 E a HLULIVU) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 13 2019 REPORT OF SUNDRY WELL OPERATIONS A n rr% f% 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate Ll Pull Tubing 0 Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑' 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: DevelopmentEx lorato ❑ P ry❑ Stratigraphic ❑ Service ❑ 209-006 3. Address: PO BOX 100360 6. -API Number: Anchorage, AK 99510 50-103-20593-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3 -115 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11252 feet true vertical 6854 feet true vertical 6605 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461' Intermediate 12122' 7" 12156' 6942' Production Liner 7534' 4.5" 19564' 6854' Perforation depth Measured depth Pre -Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' True Vertical depth Pre -Drilled Liner 6959'- 6914', Pert Pups 6914'- 6861' Tubing (size, grade, measured and true vertical depth) 4.5", L-80, 11947' MD, 6891' TVD Packers and SSSV (type, measured and true vertical depth) Packer - Baker Premier Packer, 11252' MD, 6605' TVD SSSV - Camco TRMAXX-5E, 2169' MD, 2001' TVD, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12156'- 19564' MD Treatment descriptions including volumes used and final pressure: Please See aftached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water-BbPressurel Casing Tubing Pressure Prior to well operation: 484 2952 1 3028 1357 1 307 Subsequent to operation: 737 4251 1 3403 1354 1 348 14. Attachments (required per 20 AAC 25.070, 25.071, a 25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senniiorl Production Engineer Contact Email: Kavlle.B.PlunkettAeoo.com Authorized Signature: �^^+-�-�.V v Date: IIIA— (I 1 Contact Phone: 265-6450 I/ 7-Z- ir�7 Form 10404 Revised 4/2017 A /y/(60 I -ABD1111L+_.Vv-,Nov 14 20t^ Submit Original Only CD3 -115 Scale Inhibition Treatment 10/10/19 Hybrid Scale Inhibitor Squeeze Job pumped from 1000 - 2223 hrs on 10/10/19. LRS = Little Red Services ACF = Alpine Central Facility Initial pressure TBG/IA/OA-1050/1181/528 LRS and ACF pumped 90 bbls diesel/WAW5206 preflush at 0.4 bpm, TBG/IA/OA - 163/1161/433 LRS pumped 90 bbls seawater and SCW3001 scale inhibitor treatment at 1.5 bpm, TBG/IA/OA - 0/1174/417 ACF pumped 500 bbls diesel overflush at 0.6 -1.3 bpm, TBG/IA/OA - 0/1226/390 Final pressure TBG/IA/OA — 77/1266/400 Interval treated: 12156'— 19564' MD ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 0 6 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ %eratior),8 shutdown ❑ Performed: Suspend ❑ Perforate I] Other Stimulate ❑ After Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well 71 Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ Stratigraphic❑ Service ❑ 209-006 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20593-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: CRU CD3 -115 ADL 372105, ADL 380092, ADL 384215, ADL 389725 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 19,564 feet Plugs measured None feet true vertical 6,854 feet Junk measured None feet Effective Depth measured 19,564 feet Packer measured 11252, 11375 feet true vertical 6,854 feet true vertical 6605, 6665 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 16 114' MD 114' TVD SURFACE 2,959 feet 9 5/8 " 2,995' MD 2461' TVD INTERMEDIATE 12,037 feet 7 12,156' MD 6942' TVD LINER 7,534 feet 4 1/2 " 19,564' MD 6854' TVD Perforation depth: Measured depth: 12268-15442. 15648-19433 feet True Vertical depth: 6959-6914. 6914-6861 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 11,947' MD 6,890' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PRODUCTION PACKER 11,252' MD 6,605' TVD PACKER - BAKER S3 PRODUCTION PACKER 11,375' MD 6,665' TVD SSSV - BP -6i For WRSV 2,195' MD 2,019' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 201 750 2050 1 1730 1 281 Subsequent to operation:1 985 1750 1 5300 1 1805 1 390 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319.011 Contact Name: Dusty Ward Authorized Name: DustyWard Contact Email: Dusty.Ward@cop.com Authorized Title: Sr. Wells Engineer Contact Phone: (907) 265-6531 Authorized Signature: Date: S' G- ( ct orm w-vuw nevisea w/euii 1,n— 5-11 It R ��/»/!n '�,����atL,, MAY 0 7 2019 �uomrt ungmaiumy WNS PROD WELLNAME CD3 -115 C/������� Well Attributes 011000P%1ill(p5 amt Wellb reAPVDW WeIIMre Alaska.Inc FIORD NECHELIK 501032059300 PROD NIPPLE / WRDP WELLBORE CD3 -115 RORRONT.- cd,I serzo+elomaxm Last Tag Vasal Wemak'son'up AnnoWon DeIbLu MES EMDN WeI1Mrs lS.Nksg ay .............. ...-___ .._......._......... Last Tag; CD3 -115 jupes, Last Rev Reason NANGEg. se. AnnolDP End pass WaIIMre LastMM By Rev Reason: POST dg Wellwodt, Set WRDP 4I26I2T'019 CD3115 bcehmbh Casing Strings CONDDCTOR;WO-1140 Casing Description OrTn)ID (in) TOplhl(fiI Set Depth purso Set Deple 1TVDI... Yvi (1.. Grade Top Thoort CONDUCTOR 16 1525 37.0 114.0 1140 62.50 H40 Welded WROP; 21�A NlpXe z,'4G.4 Casing Description Coin) ID (in) Top(Mrel SNpeptb(111(a) Set Card, ITADL-M (L..GrMe Tap Thud SURFACE 95/8 8.83 36.2 2,995.0 2,461.1 4000 LEO BTC Cast, Description CDlin) IDlin) Top (Sugar beea., OnM Inner sDepM ITV01-.1WLen 11... Grate Top In. INTERMEDIATE ] 628 1197 12,1562 6,941.9 26.00 U80 BTCM Casing Descnptron .0 (in) ID,Sr Top him" Sel Dept, rIXB) are Deperv01... Wrhen h...Grade Top In. LINER 4112 396 12029.9 19,564.0 6,853. 1260 L-80 IBTM I aIIRFACE: aS2a.fiWD� Liner Details GIS LIFTJ,as]< Nomlral to TeplaKB1 TapfriD11KKB) Top Incl P) Nem Des Com fn1 12,029.9 6,914.3 74.81 SLEEVE -HR" Liner Sexing Sleeve 5. 1" ID (10 13' Inner 5250 Profile) 12,0429 6,917.6 75.31 NIPPLE "RS" Packofl Seal Nipple 5. DX4.26"ID 4,260 SAS Dml9=1 120466 6,918.6 7545 HANGER Baker Flex Lock liner Hanger 591 "OD X 443"ID) 4430 12,0564 6,921.0 75.83 X XO Bushing -5112'TK X41/2"SLAT C 93 ID) 3,930 REDUCING GAS LIFT. 11.26) 15,602.6 6,912.5 88.0 PERFXO 4 - 'IBT(p1 x 4112"SLAT 3958 GAuoE.II.=I (B) - CHANGE FROM (6)112" HOLES IN CENTER OF 40 JOINT NO TO PERF PUPS (6) 2112" holes PACKER: 11=1 per 5' pup joint, alternating with 200 solid pipe e nuns NIPPLE, 11,)7 16,897.2 6,8850 90.64 Swell PKR TAM Packer on t .'P up -5.78' 7" 3. ] Element 10.46' OU SUCK STICI(11sD1D Tubing Strings.RSROi: 11.Zil.T Tubing Description al ring Ma...ID (in) Top IXNBf set O29 In.. IND1I... Grade Top ConnecYon TUBING 4112 3.88 135 11,38.9 6Set 642M 6,66d.2 12.60 12601 L-80 IBTM SLICKSTICK OVERSHOT; 11,3e0 EXTENSION PACKER: 113Ts.a Completion Details Top(TVD) Topincl Namlwl Tap lfll(B) We) P) I hm Des I Co. ID 12th NIPPLE: I'aa' 11,2964 6,627.3 60.32 OU SL CK Pooft, Shea, Assy. 4.800 1 STICK Mum SHOE;'',Se0 11,369.91 6,662.6 61.]] JOVERSI 500 Tubing Description S' ring Me... ID pn1 Top IRKS) SN DapM (r1.. SN DepP IND)L.. WIpbYU Go]e Top COnnecaen TUBING OVERSHOT 4112 3.96 309 113080 6,633.0 12.60 LEO IBTM TO PACKER Completion Details Top(TVD) Tbp hd Nominal Tortola) Yong P) ups. Des Co. Died) 309 30.9 000 HANGER FMC Horiaontl Gen 11 Tubing Hanger 3900 INTERMEDIATE; 119 n12.lsap� 2,1954 2,0190 46.66 NIPPLE 4.5" OCHROME BE& Nipple, 3,812" DS profile 3812 11,232.2 6.595.3 60.08 GAUGE 412"SGM-FS ASSY, XDPG Gauge, TN#C14GM-0045 3.864 11,252.1 6,6052 60.15 PACKER Baker ]"X45" Premier Production Packer. PN#H84E34121 3.870 11,2]6] 6.6175 60.25 NIPPLE 4.5" X landing nipple. 3,813 Xprole 3813 11,297] 6,6279 60.32 OVERSHOT Baker Poor Be, Overshot v#th - of swallow Picked up 3' 4950 Tudna Dewnp'on 54i,p Me... lD (in) Tapno,) SN Site pL. SN union PND)(... WI x4411 Gude Top Connectlon TUBING-$"IBTM 4112 396 11,355.8 119470 fi890.5 1260 LEO IBTM Completion Details Pali I TopIND) I Toolml Nominal ToplMee) I (NKa) I P)Item Des Co. 10 (N 11,3]53 BC.. 61.88 PACKER Baker SJ Production Packer PN#H409-125706 4.500 11442.1 6,6964 62.80 NIPPIE 45"XN landing nipple, 3.81 XN profile 3]25 11,9370 6,8874 72 32 MULE SHOE ]"X45"SM1ear Indicating WLEG 3.690 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TopIND) Top hd Top Doug I(Ka) PI Dm C. Run Dale IO Pip 2,1954 2,019.0 46.fi6 WRDP WRDP(HA85-r.tu N IATI 'DB LOCK 4I2fi12019 2250 11,368.0 6,662.0 61)3 TUBING CUT I CHEMICAL CUT ABOVE PACKER@11,366 3'22/2019 3.958 Perforations & Slots Shot Dens TopIND) BMD) (ebotaf TopmKB) B.MM fill MB) Linked ton. Data ) Type Co. 12,2680 154420 5 1 ,914.0cMCRS P, TUBB9 fib PERFP TTP LINI CD3 -115 PRE -DRILLED LINER 14 joints of 40 lengths with (6) 112" HOLES @ Cerner of EACH 40' joint, alternating with 200' Solid pipe seLlions 15, .0 1 ,433.0 8,914.2 6,861.3 NE H R UP, 342009 32.0 PERFP LTWTVLI CD3 -115 PERF PUPS: (6) 2112" holes per 5pup joint, alternating with 200' solid PERFP;+SMa9194310-1 pipe sections Mandrel Inserts an H TopIND) Veale IJth Pon.ve TRO Run Tap Sea) IgKa) MaM Model 013gail senr Type Type (in) )psi) Run... Co. 4,887,94 3,394.8 Cam. KBG-2 1 GAS LIFT DMY 414/2019 2 9,3227 5,5]83 Cam. KBG-2 1 GASLIFT GLV BK 0.188 18570 41612019 3 11,205. 6.582.1 Cam. KBG-2 1 GAS LIFT OV BK 0.250 41&2019LINER; f1.gA.619.afN,p�� WNS PROD WELLNAME CD3 -115 WELLBORE CD3 -115 ConocoPhillips ' ff Alaska. Inc: HORIZONTAL-CCE115. W12L1910i 33PM Notes: General & Safety . rtM+sEc(—I) --ale F Ann0Uli0n ........... _._._......_... _______. 5IN2019 NOTE'. VIEW SCHEMATIC wIAInn Schelnetic10.0 HANGER', SCS ....._....-_ ......................._..._... _............. ................ COND-CTOR;370.1110 WRDP: ZTVA NIPPLE; 21Tv.< SURFACE; b2 LES 0—L GM LIFT, K8813 GAS LIFT; %.7 WS LIFT; MA E,? P PER: 11.M1 NIPPLE: 11.9&7 OU SLICK STICK f1.iJ10 OVERSHOT.It.]8).] OVER.; 11,333.3 PPCKER: 113]5.3 NIPPLE: I I.MI1 MU LE SHOE: I f,W0 1HTERNEO.TE; 1191121562 PERFP, I$2S8O15M 0- - - — - — PERFP: 15 ESE 0-1 G,C3 O� INNER', 1ZESS-1956401 Operations Summary (with Timelog Depths) CD3 -115 Rig: NORDIC 7 Job: RECOMPLETION Time Log SWA Depth Start Time End Time our(hr) Phase Op Cade Activity Code Time P -T -X Operation (ftKB) End Depth(MKB) 3/10/2019 3/10/2019 0.50 MIRU MOVE RURD P PJSM, Jack rig up, pull dg off well, 0.0 0.0 09:30 10:00 park and rotate tires. 3/10/2019 3/10/2019 4.00 MIRU MOVE RURD P PJSM, remove mats/herclite from well 0.0 0.0 10:00 14:00 CD3 114, level pad, set herclits R mats on well CD3 -115 3/10/2019 3/1012019 1.00 MIRU MOVE RURD P Jack rig up and pull over well. 0.0 0.0 14:00 15:00 3/10/2019 3/10/2019 3.00 MIRU MOVE RURD P PJSM, Level rig, see/ up berming, set 0.0 0.0 15:00 18:00 liner and spot cuttings box. 3/10/2019 3/10/2019 1.50 MIRU WELCTL MPSP P Rig Acceptance @ 19:30 hrs 0.0 0.0 18:00 19:30 3/10/2019 - Rig up lubicator, Pull BPV ( 900 psi on tubing) Rig down Lubicator. 3/10/2019 3/10/2019 2.00 MIRU WELCTL RURD P Rig up circulating tree cap, rig up 0.0 70- 19:30 21:30 circulatung lines to tiger tanks. 3/10/2019 3/11/2019 2.50 MIRU WELCTL RURD P Wait on Doyon 142 rig move to spot 0.0 0.0 21:30 00:00 trucks. blow down lines to tiger tanks to verify lines open. Spot vac trucks and off load fluid. 3/1112019 3/11/2019 0.50 MIRU WELCTL SFTY P PJSM for killing well, 0.0 0.0 00:00 00:30 3/11/2019 3111/2019 5.00 MIRU WELCTL KLWL P Begin circulating well pumping down 00:30 05:30 IA up the tubing at 3 BPM shut down pump at 22000 STK's, shut in tubing and IA, final tubing pressure 510 psi, final IA pressure 260 psi. 3/11/2019 3/11/2019 1.00 MIRU WELCTL SIPS P Monitor well for pressure build up. 05:30 06:30 Calculate new kill weight brine at 10.5 ppg call engineer and confirm the new weight. Order 10.5 ppg NaCl/NaBr from MI mud plant. 3/11/2019 3/12/2019 17.50 MIRU WELCTL WAIT T Mud plant access blocked by Doyon 06:30 00:00 142, Waiting for vac trucks to have aoces to MI mud plant to load. Perform rig maintenance. CD# road closed to plu mats 3/12/2019 3/12/2019 0.50 MIRU WELCTL SFTY P PJSM, on killing well 00:00 00:30 3112/2019 3/1212019 3.00 MIRU WELCTL KLWL P Pump 425bbis 10.5ppg NaCl/NaBr kill 00:30 03:30 fluid, pump 23452 strokes, 486.5 bbls, return s coming back 9.5 3/12/2019 3/12/2019 2.50 MIRU WELCTL WAIT T Wait on NaCl/NaBrkill fluid, 03:30 06:00 3/12/2019 3/12/2019 2.50 MIRU WELCTL KLWL P Pump 80 Bbls 10.5ppg NaCVNaBf kill 06:00 08:30 fluid 3/12/2019 3/12/2019 0.50 MIRU WELCTL OWFF P Observe well for flow, No flow, well is 08:30 09:00 on a slight vac 3/12/2019 3112/2019 1.00 MIRU WHDBOP MPSP P Set BPV, Performed rolling test at 3 09:00 10:00 BPM 200 PSI. 3/12/2019 3/12/2019 8.00 MIRU WHDBOP NUND P ND tree. Inspect hanger threads, 10:00 18:00 corrosion and pitting observed, cleaned with wire wheel. Installed test dart and blanking plug 10.5 turns. NU BOP's, choke and kill lines, accumulator hoses, and flow nipple. air up riser boots. 3/12/2019 3/12/2019 1.50 MIRU WHDBOP BOPE P Make up test joints. 18:00 19:30 3/12/2019 3/12/2019 0.50 MIRU WHDBOP BOPE P Fuclion test BOP'S. 19:30 20:00 3/12/2019 3/12/2019 1.00 MIRU WHDBOP RURD P Rig up line to fill IA., pump 18 bbls into 20:00 21:00 IA. Page 1110 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) CD3-115 Rig: NORDIC 7 Job: RECOMPLETION Time Log Stan Depth Start Time End rime our (hr) phase Op Code Activit' Code Tme P-T-X Operatlon (111(8) End Depth (fln) 3/12/2019 3/12/2019 0.50 MIRU WHDBOP BOPE P Fill choke & stack with water 21:00 21:30 3/12/2019 3/13/2019 2.50 MIRU WHDBOP BOPE P Test BOP'S with 2 7/8 and 4 1/2 test 21:30 00:00 Joints, lower rams failed. on 2 7/8 test joint. Cycled rams and passed re-test 3/13/2019 3/13/2019 6.00 MIRU WHOBOP BOPS P Cont. lest BOP'S with 2 7/8 and 4 1/2 00:00 06:00 test Joints, blind rams failed. on initial test Cycled rams and passed re-test. Tested gas alarms, PVT. Witness waived by AOGCC rep Guy Cook. 3/13/2019 3/13/2019 2.00 MIRU WHDBOP RURD P Rig down testing equipment and test 06:00 08:00 joints. Blow down surface lines. 3/13/2019 3/13/2019 1.00 MIRU WHDBOP MPSP P Remove blanking plug, test dart and 06:00 09:00 BPV. 3/13/2019 3/13/2019 3.00 COMPZN RPCOMP PULL P Attempt to pull hanger to rig floor. 09:00 12:00 Hanger came off of seat at 60K. Pulled up 173K with block several times no success, Consult town pulled up to 193K with blocks again no success. Decided hanger was not successfully cut. With hanger off seat opened TIW valve well is out of balance flowing back through tubing. Establish static loss rale of 12 BHP. 3/13/2019 3/13/2019 2.00 COMPZN RPCOMP CIRC T RU to circ down tubing. Pump 1.5X 12:00 14:00 tubing volume at 3 BPM. Shut down pumps and observe well for flow. Well stilling flowing out of tubing. 3/13/2019 3/13/2019 2.00 COMPZN RPCOMP CIRC T Build 15 Bbls pill with KCL to 11.5 14:00 16:00 PPG. Circ pill into tubing. Observe well for flow. Well remains out of balance flowing through tubing. 3/13/2019 3/13/2019 6.00 COMPZN RPCOMP CIRC T Order out dry bromide product to build 16:00 22:00 pill capable of balancing the well. Pump 25 ME 12.2 ppg pill. 3/13/2019 3/13/2019 1.00 COMPZN RPCOMP RURD T Change out 3 1/2" IF TIW with 3 1/2" 22:00 23:00 FOSV on landing joint. RU Pollard E- line 3/13/2019 3/14/2019 1.00 COMPZN RPCOMP ELOG T RU Pollard, pull pipe intension 100K, 23:00 00:00 set Slaps, rig up upper sheave.. 3/14/2019 3/14/2019 00:00 00:00 3/14/2019 3/14/2019 00:00 00:00 3/14/2019 3/14/2019 1.00 COMPZN RPCOMP ELOG T Continue Rigging up wire line equip. 00:00 01:00 3/14/2019 3/14/2019 5.00 COMPZN RPCOMP ELOG T RIH with Halliburton 26 arm caliper log 01:00 06:00 T/11600. Log F/ 11600 To 11,450, POOH with logging tools, send logs to Town. 3/14/2019 3/14/2019 3.00 COMPZN RPCOMP ELOG T Interoperate logs. Decide plan 06:00 09:00 forward with town. Wait on tools.. 3/14/2019 3/14/2019 2.50 COMPZN RPCOMP ELOG T MU and RIH with junk catcher 2.80 09:00 11:30 OD X 5.05'. Set in XN Nipple @ 11575', POOH. 3/14/2019 3/14/2019 4.50 COMPZN RPCOMP ELOG T MU and RIH with chem cutter. Cut 11:30 16:00 premier packer at 11536.4', with 20K over string weight. Returns were identified from the IA after packer was cut. Shut in annular, the weighted pill kept tubing held back continue POOH with E-Line. Shut in FOSV. RD Pollard E-Line. Page 2/10 ReportPrinted: 5/3/2019 e Operations Summary (with Timelog Depths) CD3 -115 Rig: NORDIC 1 Job: RECOMPLETION Time Log sten Depth Sten Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (110) End Depth (MRS) 3/14/2019 3/14/2019 5.00 COMPZN RPCOMP KLWL T Circ out packer gas through poor boy 16:00 21:00 with 10.4 PPG NaCl/NaBr. Stage pump up to 3 BPM. 133 Losses to well during circulation. Shut well in and monitor pressures- no pressure. 3/14/2019 3/14/2019 0.50 COMPZN RPCOMP OWFF P Observe well for flow for 30 Min.- well 21:00 21:30 flowing. 3/14/2019 3/14/2019 1.50 COMPZN RPCOMP KLWL T Shut well in, Call Engineer 21:30 23:00 3/14/2019 3/15/2019 1.00 COMPZN RPCOMP CIRC T Circulate bottoms up @ 2 bbls/min, 23:00 00:00 404 spp fluid wt -10.4 in, 10.4 out. 3/15/2019 3/15/2019 2.50 COMPZN RPCOMP CIRC T Circulate bottoms @ 11536'. to insure 00:00 02:30 fluid was balanced. pumped 14000 silks, @ 85 slks/ min, spp 250, fluid wt. 10.4 in and out. Lost 113 bbls down hole while circ. 3/15/2019 3/15/2019 0.50 COMPZN RPCOMP WAIT T Check For flow, well flowing, shut well 02:30 03:00 in record PSI - annuls 20 PSI, Tubing 20 psi. verify gauge reading correctly gauges check OK 3/15/2019 3/15/2019 12.50 COMPZN RPCOMP WAIT T Discuss with engineer, Wait on 10.5 03:00 15:30 fluid F/ mud plant. Build wt. up with fluid in pits to 10.5 while waiting on trucks 3/15/2019 3/15/2019 4.50 COMPZN RPCOMP KLWL T Circulate 10.5 PPG brine around at 3 15:30 20:00 BPM 450 PSI. Use ECD for 20 PSI back pressure. Losses to the well 288 Bbls. 3/15/2019 3/15/2019 1.00 COMPZN RPCOMP KLWL T Chalk well F/ Flow, 0 on anulas, 20 psi 20:00 21:00 on tubing, open annular, fill anulas, observe fluid level, annulas dropping, getting returns out of tubing. 3/15/2019 3/15/2019 0.50 COMPZN RPCOMP KLWL T Discuss with Engineer, discission 21:00 21:30 made to attempt to u4ube tubingh and anulas. 3/15/2019 3/15/2019 1.50 COMPZN RPCOMP RURD T Rig up lines and u -tube anulas and 21:30 2300 tubing. 3/15/2019 3/16/2019 1.00 COMPZN RPCOMP CIRC T Rig up and circulate down tubing (03 2 23:00 00:00 bbl/min. pump 208 bbls, SPP 190, 87 bbls to formation. 3/16/2019 3/16/2019 1.50 COMPZN RPCOMP CIRC T Continue to circulate. 00:00 01:30 3/1612019 3/16/2019 0.50 COMPZN RPCOMP OWFF T Flow check well no flow from tubing, 01:30 02:00 annulus fluid falling. 3/16/2019 3/16/2019 1.00 COMPZN RPCOMP THGR P Pull hanger to floor and lay down. 11,532.0 11,532.0 02:00 03:00 3/16/2019 3/16/2019 3.00 COMPZN RPCOMP PULL P UD 2 jts 4.5 tubing and 4.5 X 3.5 xo, 11,532.0 11,452.0 03:00 06:00 change over to 3.5 running equip. rig up hose to fill tubing. 3/16/2019 3/17/2019 18.00 COMPZN RPCOMP PULL P Continue pooh UD 3 1/2" - 9.6#, L-80, 11,452.0 6,626.0 06:00 00:00 EUE mod. tubing. Over pull 52K at 11531', 75K at 11318', 125K at 10850'. Recovered all 72 stainless steel bands for SSSV control line. Continue UD tubing T/ 6626.' 3/17/2019 3/17/2019 14.00 COMPZN RPCOMP PULL P Continue UD 3 1/2" 9.6# EUE mod. 6,626.0 0.0 00:00 14:00 tubing F/ 6626' T/ 0'. Packer was intact and tail pipe was attached. 3/17/2019 3/17/2019 2.00 COMPZN RPEQPT PULD P Strap old completion and clean and 0.0 0.0 14:00 16:00 clear pipe shed and rig floor 3/17/2019 3/17/2019 0.50 COMPZN RPEQPT SVRG P Service draw works, blocks and 0.0 0.0 16:00 16:30 crown. Page 3110 Report Printed: 513/2019 Summary (with Timelog Depths) CD3 -115 lipOperations Rig: NORDIC 1 Job: RECOMPLETION Time Log start Depth Stan Time Fid Time Our (hr) Phase Op Ootle Activity Code Time P -T -X Operation (NKB) End Depth (ftKB) 3/17/2019 3/17/2019 3.50 COMPZN RPEQPT SLPC P Slip and cut 86' of drill line. 0.0 0.0 16:30 20:00 3117/2019 3/17/2019 2.00 COMPZN RPEQPT BOPE P R/U to drain bop's, make up test jt. 0.0 0.0 20:00 22:00 and set test plug. 3/17/2019 3/1712019 1.00 COMPZN RPEQPT BOPE P Test Anular, kill HCR, and floor safety 0.0 0.0 22:00 23:00 vale @ 250/ 3500 psi F/ 5 min. 3/17/2019 3/18/2019 1.00 COMPZN RPEQPT OTHR P PJSM, load spoolers, for completion 0.0 0.0 23:00 00:00 1 1 1 inpipe shed. 3/18/2019 3/18/2019 22.50 COMPZN RPEQPT PULD P Process 200 joints 4 1/2" 12.6#, L-80, 0.0 0.0 00:00 22:30 IBTM tubing in the pipe shed. Break protectors off, rabbit with 3.833" drift, strap and talley pipe. Get lamps F/tech lines on floor, Schlumberger have probles w/ control box. 3118/2019 3/19/2019 1.50 COMPZN RPCOMP RCST P P/u Wleg, RIH 11 jts 41/2" 12.6# L80 0.0 750.0 22:30 00:00 IBTM tubing, XN nipple, 1 jt tubing, Baker S-3 Packer, SGM-FS ASSY, XDPG gauge. continue RIH w/ completion tubing. 3/19/2019 3/19/2019 17.50 COMPZN RPCOMP RCST P Cont to run 4 1/2", 12.6#, L-80, IBTM 750.0 8,618.0 00:00 17:30 completion T/ 8616' 3/19/2019 3/20/2019 6.50 COMPZN RPCOMP PUTB P Load pipe in shed 85 its and process, 8,618.0 8,618.0 17:30 00:00 drift strap and tally 3/20/2019 3/20/2019 7.50 COMPZN RPCOMP RCST P Cont to run 4 1/2", 12.6#, L-80, IBTM 8,618.0 11,941.0 00:00 07:30 completion. Obtained parameters at 11935'. UWT 95K, DWT 46K. Al 11941'took weight on slack off to 20K. PU to 120K no pipe movement. 3/20/2019 3/20/2019 3.00 COMPZN RPCOMP CIRC T Consult town. Rig up head pin and 11.941.0 11941.0 07:30 10:30 circulating hose onto tubing. Establish circulation down tubing taking returns up IA. 1 BPM 96 PSI. 2 BPM 107 PSI. 3 BPM 207 PSI. 3/20/2019 3/20/2019 0.50 COMPZN RPCOMP OWFF T Observe well for flow. Flow seen at 11,941.0 11,941.0 10:30 11:00 bell nipple. 3/20/2019 3/20/2019 4.50 COMPZN RPCOMP CIRC T Pump down tubing at 1 BPM to 11,941.0 11,941.0 11:00 15:30 provide ECD to stabilize well. Build a 45 Bbls 11.7 PPG pill for mud cap in tubing. 3/20/2019 3/20/2019 2.00 COMPZN RPCOMP CIRC T Pump 45 Bbls 11.7 PPG pill down 11,941.0 11,941.0 15:30 17:30 tubing and chase with 5 Bbis of 10.5 PPG fluid. Close annular and use charge pumps to bullhead fluid down the annular. Remove circulating equipment. Drop ball and rod. Make up circulating equipment. Open annular. Pump down tubing confirm ball is on seat. 3/20/2019 3/20/2019 0.50 COMPZN RPCOMP PACK T Pressure up to 4000 PSI set packer 11,941.0 11,941.0 17:30 18:00 and hold pressure for 15 Min. 3/2012019 3/20/2019 2.00 COMPZN RPCOMP RURD T Drain stack, Pull riser remove clamp 11,941.0 11,491.0 18:00 20:00 blow table, install riser, set string in tension 15k over pull 3/20/2019 3/21/2019 4.00 COMPZN RPCOMP ELNE T R/U ELine equipment and tool string 11,491.0 11,491.0 20:00 00:00 #1 retrieve Lock out sleeve in BPi6 nipple, M/U stripping head and pump in sub. 3/21/2019 3/21/2019 1.00 COMPZN RPCOMP ELNE T Continue R/U ELine equipment and 11,491.0 11,491.0 00:00 01:00 tool string #1 retrieve Lock out sleeve in 31361 nipple, M/U stripping head and pump in sub. 3121/2019 3/21/2019 2.00 COMPZN RPCOMP ELNE T RIH with 4 1/2" PRS to pull sleeve 11,491.0 11,491.0 01.00 03 00 from BP6i nipple. Run unsuccessful. Page 4110 Report Printed: 513/2019 Operations Summary (with Timelog Depths) CD3 -115 Rig: NORDIC 1 Job: RECOMPLETION Time Log Stan Depth start Time End Tme Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (Wlt) End Depth (ftKB) 3/21/2019 3/21/2019 1.50 COMPZN RPCOMP ELNE T RIH #2 with 4 112" PRS to pull sleeve 11,491.0 11,491.0 03:00 04:30 from BP6i nipple. Run unsuccessful. 3/21/2019 3/21/2019 1.50 COMPZN RPCOMP ELNE T RIH #3 with GR retrieval tool to pull 11,491.0 11,491.0 04:30 06:00 sleeve from BP6i nipple. Successful run sleeve pulled. 3/21/2019 3/21/2019 4.00 COMPZN RPCOMP ELNE T RIH with RS and retrieve ball and rod. 11,491.0 11,491.0 06:00 10:00 Successful run ball and rod pulled. 3/21/2019 3/21/2019 4.00 COMPZN RPCOMP ELNE T RIH with GR and pull RHC plug from 11,491.0 11,491.0 10:00 14:00 XN nipple. Successful run RCH plug pulled. 3/21/2019 312112019 4.00 COMPZN RPCOMP ELNE T Wait on Quadco Paragon II packer to 11,491.0 11,491.0 14:00 18:00 be delivered from Deadhorse. Bullhead 54 Bbls 10.6 PPG NaCl/NaBr down the tubing. 3/21/2019 3/21/2019 5.00 COMPZN RPCOMP ELNE T Run and set Quadco Paragon II 11,491.0 11,491.0 18:00 2300 packer at 11430' 3/21/2019 3/22/2019 1.00 COMPZN RPCOMP ELNE T POOH w/ plug Running tools, Plug 11,491.0 11,491.0 23:00 0000 set, Pin keeper ring off GU adaptor was missing 3/22/2019 3/22/2019 6.50 COMPZN RPCOMP ELNE T MU and RIH with chemical cutter. 11,491.0 11,361.0 00:00 0630 Locate packer and cul pipe l' below collar on pup above packer 11361'. Good indications of cut. Pull cutter up hole to 10800'. Stop E -Line movement. Energize pack off. 3/22/2019 3/22/2019 7.50 COMPZN RPCOMP CIRC T Flow observed on tubing. Spotted 32 11,361.0 11,361.0 06:30 14:00 Bbls flow vis pill all 50 vis on bottom at the end of a surface to surface conditioning that conditioned the hole to 10.5+ PPG NaCl/NaBr. 3/22/2019 3/22/2019 4.00 COMPZN RPCOMP OWFF T Observe well for flow. Flow from 11,361.0 11,361.0 14:00 18:00 tubing and IA. Shut well in. 30 PSI on tubing 20 PSI on IA after 15 Min. Open up bleed 5 Bbls off of well in 12:15. Shut back in 30 PSI on tubing 20 PSI on IA after 15 Min. Open up bleed 5 Bbis off of the well in 26:50. Bleed of additional 5 Bois in 2 hrs. Build 40 Bbls 11.7 PPG spike pill in pill pit. Pump 10 Bbls 11.7 down tubing. Observe well for flow. No flow. 3/22/2019 3/23/2019 6.00 COMPZN RPCOMP WAIT T Phase III Wait on weather to clear 11,361.0 11,361.0 18:00 00:00 monitor well static, POOH w/Eline to surface stand bye for weather 3/23/2019 3/23/2019 9.00 COMPZN RPCOMP WAIT T Phase III Continue to wait on weather 11,361.0 11,361.0 00:00 09:00 to clear monitor well static, 3/23/2019 3/2312019 1.50 COMPZN RPCOMP ELNE T RD Pollard E -Line pressure control, 11,361.0 11,361.0 09:00 10:30 circulating, tools and sheaves. 3/23/2019 3123/2019 1.00 COMPZN RPCOMP PULL T Pull 1/2", 12.6#, L-80, IBTM 11,361.0 11,319.0 10:30 11:30 completion string from cut at 11361'. Work up to 145K six times. Pulled free 85K UWT, 50K DWT. Cont POOH laying down in the pipe shed, removing cannon clamps and spooling up Tec Wire and stainless steel control Pine. 3123/2019 3/2312019 1.00 COMPZN RPCOMP CIRC T Pump 10 Bbls 11.7 PPG pill down 11,319.0 11,319.0 11:30 12:30 tubing. 3/23/2019 3/23/2019 0.50 COMPZN RPCOMP OWFF T Observe well for flow. No flow 11,319.0 11,319.0 12:30 13:00 3/23/2o19 3/23/2019 2.00 COMPZN RPCOMP PULL T Cont. pull 1/2", 12.6#, L-80, IBTM 11,319.0 10,479.0 13:00 15:00 completion string. Pulled total of 20 joints. Swabbed 9 Bbls Page 5/10 Report Printed: 513/2019 -, Operations Summary (with Timelog Depths) CD3 -115 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start DepN sw Time End Time our (hr) Phase Op CMe Acdv' Code M Time P -LX Operation (ftK8) End Depth (ftKB) 3/23/2019 3/23/2019 0.50 COMPZN RPCOMP OWFF T Observe well for flow. Flow seen from 10,479.0 10,479.0 15:00 15:30 annulus. Shut in annular. 10 PSI on annular 0 PSI on tubing. 3/23/2019 3/2312019 0.50 COMPZN RPCOMP CIRC T Bullhead 20 Bbls 10.8 PPG 10,479.0 10,479.0 15:30 16:00 NaCl/Naar down annulus at 2 BPM 150 PSI. 3/23/2019 3/23/2019 0.50 COMPZN RPCOMP OWFF T Observe well for flow. No flow. 10,479.0 10,479.0 16:00 16:30 3/23/2019 3/24/2019 7.50 COMPZN RPCOMP PULL T Cont. pull 1/2", 12.6#, L-80, IBTM 10,479.0 8,079.0 16:30 00:00 completion string. Wells swabbing every it, Bull head 30 bbls in for every 30 stands pulled 3/24/2019 3/24/2019 3.00 COMPZN RPCOMP PULL T Cont. pull 1/2", 12.6#, L-80, IBTM 8,079.0 7,097.0 00:00 03:00 completion string. Percentage of swabbing increased by 100%. 3/24/2019 3/24/2019 1.00 COMPZN RPCOMP CIRC T Bullhead 60 Bois 10.8 PPG 7,097.0 7,097.0 03:00 04:00 NaCl/NaBr down annulus and 20 BDIs down tubing. 3/24/2019 3/24/2019 0.50 COMPZN RPCOMP OWFF T Observe well for flow. No flow. 7,097.0 7,097.0 04:00 04:30 3124/2019 3/2412019 3.00 COMPZN RPCOMP PULL T Cont. pull 1/2", 12.6#, L-80, IBTM 7,097.0 5,943.0 04:30 07:30 completion string. Fluid began to U- tube out tubbing. 3/24/2019 3/24/2019 0.50 COMPZN RPCOMP CIRC T Bullhead 10 Bbls 11.7 PPG NaCl/NaBr 5,943.0 5,943.0 07:30 08:00 down tubing. OWFF, no flow. 3/24/2019 3/24/2019 10.00 COMPZN RPCOMP PULL T Cont. pull 4112", 12.6#, L-80, IBTM 5,943.0 0.0 08:00 18:00 completion string. Filling hole for pipe displacement with 10.6 PPG NaCl/Naar. All clamps recovered out of the hole. 3/24/2019 3/25/2019 6.00 COMPZN RPCOMP CLEN T Clean and clear floor, Change out tech 0.0 0.0 18:00 00:00 wire spool w/ crane, P/U test joint from beaver slide 3/25/2019 3125/2019 3.00 COMPZN WHDBOP RURD T RU testing equipment and set test 0.0 0.0 00:00 03:00 plug. 3/25/2019 3/25/2019 6.00 COMPZN WHDBOP BOPE T Test BOP's W/ 4 112" test joint, 0.0 0.0 03:00 09:00 25013500 PSI for 5 Min each. Test witnessed by AOGCC rep Brian Bixby. Test PVF, and gas alarms. All tests pass. Fill backside with 10.8 PPG NaCl/NaBr while testing. 3/25/2019 3/25/2019 1.00 COMPZN WHDBOP RURD T RD testing equipment and pull test 0.0 0.0 09:00 10:00 plug. 3/25/2019 3/25/2019 1.00 COMPZN RPCOMP RURD T RU to run completion. String Tec wire 0.0 0.0 10:00 11:00 over sheave in derrick. Verify joint count in pipe shed. 3/25/2019 3125/2019 0.50 COMPZN RPCOMP SFTY T PJSM with dg crew, Baker, 0.0 0.0 11:00 11:30 Schlumberger on running completion. 3/25/2019 3/26/2019 12.50 COMPZN RPCOMP RCST T Pick up and RIH with 4 1/2", 12.6#, L- 0.0 5,600.0 11:30 00:00 80, IBTM completion string. Make up cable head for gauge and pressure test to 5000 PSI for 5 Min. Good test. RIH placing cannon clamp on every collar. 3/26/2019 3/26/2019 12.00 COMPZN RPCOMP RCST T Pick up and RIH with 41/2", 12.6#, L- 5,600.0 11,327.0 00:00 12:00 80, IBTM completion string t/ 11,327' MD. Make up cable head for gauge and pressure test to 5000 PSI for 5 Min. Good test. RIH placing cannon clamp on every collar. 3/26/2019 3/26/2019 1.00 COMPZN RPCOMP RCST T Became hung up at 11,327'. 11,327.0 11,327.0 12:00 13:00 Attempted to PU 10k over & SO 10k over Page 6110 Report Printed: 5/3/2019 .M16Operations Summary (with Timelog Depths) CD3 -115 Rig: NORDIC 1 Job: RECOMPLETION Time Log start Depth Start Time End Time our (hr) Phase Op Cade Activity Code Time P -T -X Operation (ftKB) End Depth (ft)(B) 3/26/2019 3/26/2019 0.50 COMPZN RPCOMP CIRC T Reverse Circ 50 bbls @ 2.5 bbls w/ 11,327.0 11,327.0 13:00 13:30 143 psi 3/26/2019 3/26/2019 1.00 COMPZN RPCOMP RCST T Became hung up at 11,327'. 11,327.0 11,327.0 13:30 14:30 Attempted to PU IOk over & SO 1 O over 3/26/2019 3/26/2019 0.50 COMPZN RPCOMP CIRC T Reverse Circ 50 bbls @ 2.5 bbls w/ 11,327.0 11,327.0 14:30 15:00 143 psi 3/26/2019 3/26/2019 1.00 COMPZN RPCOMP RCST T Became hung up at 11,327'. 11,327.0 11,327.0 15:00 16:00 Attempted to PU 20k over & freed up the packer. POOH & LD jt 267 & RU circ equipment 3/26/2019 3/26/2019 1.50 COMPZN RPCOMP CIRC T Reverse Circ 170 bbls @ 2.5 bbls w/ 11,327.0 11,327.0 16:00 17:30 150 psi to attempt to clean around the packer 3/26/2019 312612019 2.00 COMPZN RPCOMP OWFF T Observe well dicuss options with town 11,327.0 11,327.0 17:30 19:30 3/26/2019 3126/2019 1.00 COMPZN RPCOMP RCST T Attempt to slack off through bad spot 11,327.0 11,327.0 19:30 20:30 take 5k wt 6.5' higher than previously, P/U on string 6k break over pulling 4k drag S/O tag 2.5' lower than first attempt P/U took 10k to break free, Slack off Sk at first spot it set down set down 5k took 10 k to break free 3/26/2019 3/26/2019 2.00 COMPZN RPCOMP CIRC T Pump 30 bbls 10.8 ppg fluid down 11,327.0 11,327.0 20:30 22:30 back side and 20 bbls down tubing, while discuss options with town on plan forward. 3/26/2019 3/27/2019 1.50 COMPZN RPCOMP PULD T POOH UD 4.5" Completion spooling 11,327.0 11,064.0 22:30 00:00 control line back on spools and removing cannon clamps T/ 11,064' MD 3/27/2019 3/27/2019 12.00 COMPZN RPCOMP PULD T Continue POOH UD 4.5" Completion 11.327.0 4,881.0 00:00 12:00 spooling control line back on spools and removing cannon clamps T/ 4881 MD 3/27/2019 3/27/2019 11.00 COMPZN RPCOMP PULD T Comtinue POOH UD 4.5" Completion 4,881.0 0.0 12:00 23:00 spooling control line and removing cannon damps to surface 3/27/2019 3/28/2019 1.00 COMPZN WELLPR CLEN T Clean and clear dg floor, change 0.0 0.0 23:00 00:00 handling equipment, R/U to run clean out easy. 3/28/2019 3/28/2019 2.50 COMPZN WELLPR RURD T Set up rig tongs, bring up baker tools 0.0 0.0 00:00 02:30 to the rig floor & fill pits w/ fluid 3/28/2019 3/28/2019 3.50 COMPZN WELLPR SHAH T PJSM, MU BHA per BHI rep 0.0 75.0 02:30 06:00 3/28/2019 3/28/2019 5.00 COMPZN WELLPR RCST T RIH on 4-1/2" 12.6# L-80 tubing T/ 75.0 3,665.0 06:00 11:00 3,665' 3/28/2019 3/28/2019 1.00 COMPZN WELLPR WAIT T Circ across the hole & fill the pits w/ 3,665.0 3,665.0 11:00 12:00 fluid 3/28/2019 3/28/2019 9.50 COMPZN WELLPR RCST T RIH on 4-1/2" 12.6# L-80 tubing T/ 3,665.0 11,270.0 12:00 21:30 11270' 3/28/2019 3/29/2019 2.50 COMPZN WELLPR WASH T Wash down f/ 11270't/11324'set 11,270.0 11,334.0 21:30 00:00 down 1 O P/U overpulled 20k Work string down to 11334' max set down 25k max over pull 40k unable to get past tight spot pump high vis sweep around 3/29/2019 3/29/2019 1.00 COMPZN WELLPR WASH T Confine working pipe while11,334.0 11,334.0 00:00 01:00 I circulating. Unable to get past 11,334' MD Page 7110 Report Printed: 5/3/2019 e Operations Summary (with Timelog Depths) CD3 -115 Rig: NORDIC 1 Job: RECOMPLETION Time Log Stan Depth Stan Time End Time our (hr) phase Op Corse Am ity Cane Time P -T-% Operation (ftKB) End Depth (MB) 3/29/2019 3/29/2019 3.50 COMPZN WELLPR CIRC T Circ down tubing, pump 10 bbl Hi -Vis 11,334.0 11,334.0 01:00 04:30 sweep STS, nothing retumed to surface with sweep, & loaded pits with 10.7 ppg fluid. -200 bbis lost while pumping 3/29/2019 3129/2019 1.00 COMPZN WELLPR OWFF T Monitor and allow well to breath 11,334.0 11,334.0 04:30 05:30 3/29/2019 3/29/2019 4.50 COMPZN WELLPR PULD T POOH LD 4.5" 12.6# L-80 tubing T/ 11,334.0 9,500.0 05:30 10:00 1 9,500' MD 3/29/2019 3/29/2019 1.00 COMPZN WELLPR CIRC T Transfer out fluids from pits 9,500.0 9,500.0 10:00 11:00 3/2912019 3/29/2019 0.50 COMPZN WELLPR PULD T POOH LD 4.5" 12.6# L-80 tubing 9,500.0 8,890.0 11:00 11:30 T/8890 3/29/2019 3/29/2019 7.50 COMPZN WELCTL KLWL T Shut in well monitor pressures 170 psi 8,890.0 8,890.0 11:30 19:00 on IA40 psi on tubing 3/29/2019 329/2019 4.00 COMPZN WELCTL KLWL T Circulate 10.8 ppg Brine around @ 3 8,890.0 8,890.0 19:00 23:00 bpm 280 psi through choke holding 100 psi back psi. Observe about 25% losses while circulating 3/2912019 3/30/2019 1.00 COMPZN WELCTL KLWL T Monitor well tubing 20 IA 10 psi 8,890.0 8,890.0 23:00 00:00 3/30/2019 313012019 1.00 COMPZN WELCTL KLWL T Continue weight up and vis pit system 8,890.0 8,890.0 00:00 01:00 3/30/2019 3130/2019 2.00 COMPZN WELCTL KLWL T Circulate surface to surface 369 bbls 3 8,890.0 8,890.0 01:00 03:00 bpm 250 psi 3/30/2019 3/302019 1.50 COMPZN WELLPR OWFF T OWFF well static slight loss, static 8,890.0 8,890.0 03:00 04:30 loss rate of 10 bph, load pits with 10.9 ppg brine 3/30/2019 3/30/2019 6.50 COMPZN WELLPR PULD T POOH f/ 8890' U 5764' UD tubing in 8,890.0 5,764.0 04:30 11:00 shed 3/3012019 3/30/2019 1.00 COMPZN WELLPR CIRC T tubing coming wet, pump 85 bbls 5,764.0 5,764.0 11:00 12:00 down tubing 10.9 ppg 3/30/2019 3/30/2019 9.50 COMPZN WELLPR PULD T Continue POOH f/ 5764' U 75' 5,764.0 75.0 12:00 21:30 j 3/30/2019 3/31/2019 2.50 COMPZN WELLPR BHAH T UD BHA, no visible marks on mills, 75.0 0.0 21:30 00:00 nose of cutlip shoe bent and buckled, boot baskets empty, magnets had fine medal wickers 15 lbs, Clear floor 3/31/2019 3/31/2019 0.25 COMPZN RPCOMP SFTY T PJSM for testing BOPE 0.0 0.0 00:00 00:15 3/31/2019 3/31/2019 0.50 COMPZN RPCOMP RURD T RU to test BOPE 0.0 0.0 00:15 00:45 3/31/2019 3/31/2019 1.50 COMPZN RPCOMP BOPE T Test BOPE PTAnnular, FOSV,Kill 0.0 0.0 00:45 02:15 HCR, CM 1,6,12,19 to 250/3500 PSI. for 5 minutes each. 3/31/2019 3/31/2019 0.25 COMPZN RPCOMP RURD T RD after testing BOPE 0.0 0.0 02:15 02:30 3!31/2019 3/31/2019 1.50 COMPZN RPCOMP RURD T PJSM for RU E -Line With CPAI, SLB 0.0 0.0 02:30 04:00 and Nordic. RU E -line. 3/31/2019 3/31/2019 5.00 COMPZN RPCOMP ELOG T Run E -line caliper log. from 11364' KB 0.0 0.0 04:00 09:00 to 10,500' KB. Requested rapid processing and request was denied. 3/312019 3/31/2019 0.25 COMPZN RPCOMP SFTY T PJSM with SLB/Nordlc/CPAI for RD E- 0.0 0.0 09:00 09:15 Line. 3/31/2019 3/31/2019 0.75 COMPZN RPCOMP RURD T RD SLB E -line. 0.0 0.0 09:15 10:00 3/31/2019 3/31/2019 0.25 COMPZN RPCOMP SFTY T PJSM to Clear floor of BHA -1. 0.0 0.0 10:00 10:15 3/31/2019 3/31/2019 0.75 COMPZN RPCOMP RURD T Clear floor of BHA -1 0.0 0.0 10:15 1100 Page 8110 Report Printed: 51312019 Summary (with Timelog Depths) CD3 -115 lipOperations Rig: NORDIC 1 Job: RECOMPLETION Time Log ft Start Depth Start Time End Time Dx(hr) Phase Op Cotle Ad i Code ry Tme P -T -x O ration pe e) End Depth (ftKe) 3/31/2019 3/31/2019 0.25 COMPZN RPCOMP SFTY T PJSM to replace TEK wire spool on 0.0 0.0 11:00 11:15 floor 3/31/2019 3/31/2019 0.75 COMPZN RPCOMP RURD T Prep floor to crane TEK wire off floor 0.0 0.0 11:15 12:00 and replace with new spooler of TEK wire. 3/31/2019 3/31/2019 0.25 COMPZN RPCOMP SFTY T PJSM with CPAI/ASRC/Nordic for 0.0 0.0 12:00 12:15 hoisting SLB TEK wire spool off and on floor. 3/31/2019 3/31/2019 0.75 COMPZN RPCOMP RURD T Hoist SLB TEK wire spool off and on 0.0 0.0 12:15 13:00 floor. 3/31/2019 3/31/2019 4.00 COMPZN RPCOMP RURD T Attempt to shim dg, Jack up and shim 0.0 0.0 13:00 17:00 set back down. 3/3112019 3/31/2019 1.00 COMPZN WHDBOP BOPE P R/U to lest BOPS 0.0 0.0 17:00 18:00 3/3112019 4/1/2019 6.00 COMPZN WHDBOP BOPE P Test BOPS w/ 4.5" test jt 0.0 0.0 18:00 00:00 4/1/2019 4/1/2019 1.50 COMPZN RPCOMP BOPE P RID BOPE test equipment. 0.0 0.0 00:00 01:30 4/1/2019 4/1/2019 1.00 COMPZN RPCOMP RURD T PJSM for getting BOT lower 0.0 0.0 01:30 02:30 completion equipment to the floor, and move lower completion assembly to rig floor. 4/1/2019 4/1/2019 0.25 COMPZN RPCOMP SFTY T PJSM for running completion. 0.0 0.0 02:30 0245 4/1/2019 4/1/2019 15.25 COMPZN RPCOMP PUTS T Run lower completion on 4.5" 0.0 10,450.0 02:45 18:00 workslring t/ 10450' 4/1/2019 4/1/2019 1.00 COMPZN RPCOMP SFTY P Orient new crew with rig operation, 10,450.0 10,450.0 18:00 19:00 crew getting off tour stayed over and hour to mentor new crew in opperations and rig systems. 4/1/2019 4/1/2019 2.00 COMPZN RPCOMP PUTS T Continue RIH w/ Overshot Assy. f/ 10,450.0 11,320.0 19:00 21:00 10450'1/ 11320' 4/1/2019 4/1/2019 1.00 COMPZN RPCOMP WASH T Wash Down f/ 11320'11 11375' Locate 11,320.0 11,3T5-0- 21:00 22:00 w/ over shot observe pressure increase shut down pumps, Over pull 10k verify latched, over pull 20k set down 15k over pull 30k shear off top of tubing stub 11301', UD 2 jts 411/2019 42/2019 2.00 COMPZN RPCOMP SLPC P Slip and cut drilling line 85' 11,375.0 10,980.0 22:00 00:00 4/2/2019 4/22019 1.00 COMPZN RPCOMP SVRG T Slip & cut drilling line 11,307.0 00:00 01:00 42/2019 4/2/2019 15.50 COMPZN RPCOMP PULD T Start laying down work string from 11,307.0 11,357-0- 01:00 16:30 11307 PU WT=80K 4/2/2019 4/2/2019 4.50 COMPZN RPCOMP SVRG T Service rig while loading pits and 11,307.0 11,307.0 16:30 21:00 prepping to run completion. clear floor pull control line and TEK wire through sheaves. Get Tex wire clamps T/ rig floor 4/2/2019 4/2/2019 0.50 COMPZN RPCOMP SFTY T PJSM on picking up tubing and 21:00 21:30 running completion string per running order. 4/2/2019 4/3/2019 2.50 COMPZN RPCOMP RCST P Pick up 4 1/2" 12.6# L-80 IBTM tubing 21:30 00:00 and RIH per running order. 4/3/2019 4/3/2019 16.00 COMPZN RPCOMP PUTS P ,Continue RIH with 4 1/2" 12.6# L-80 0.0 6,553.0 00:00 16:00 IBTM tubing per running order. 4/312019 4/32019 5.50 COMPZN RPCOMP PUTS P Make up BP6-i nipple and pressure 6,553.0 11,301.0 16:00 21:30 test hydraulic fitting connection,Continue RIH with 4 1/2" 12.6# L-80 IBTM tubing per running order. Ran 265 jts. P/U 85K, S/O 58K Page 9110 Report Printed: 5/3/2019 . WIN Operations Summary (with Timelog Depths) CD3 -115 Rig: NORDIC 1 Job: RECOMPLETION Time Log S W De Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operebon (rt B) End Depth (nxe) 4/3/2019 4/4/2019 2.50 COMPZN RPCOMP HOSO P Locate tubing Stubb @ 11,301' Slack 11,301.0 11,301.0 21:30 00:00 off and shear pins, pins sheared @ 14K over, slack off to no go @ 11,304', UD jts 267 & 266, Make up space out pups, and jt 265, M/U hanger T1 landing joint, terminate gauge wire -3 and capilary line @ hanger and test. 4/4/2019 4/4/2019 00 COMPZN RPCOMP CIRC P rig up hoses and reverse circulate 245 11,301.0 00:00 03:00 bbls Corrosion inhiberter. 4/4/2019 4/4/2019 2.50 COMPZN RPCOMP THGR P Land tubing hanger, run in LDS, test 03:00 05:30 tubing hanger seal to 5000 psi for 10 minutes. Drain BOP stack 4/4/2019 4/4/2019 1.50 COMPZN RPCOMP RURD P Drop ball and rod and RU hoses to 05:30 07:00 test packer and IA 4/4/2019 4/4/2019 2.00 COMPZN RPCOMP PRTS P Test tubing to 3000 PSI for 15 07:00 09:00 minutes, bleed back to 1500 PSI, pressure up IA to 2500 PSI for 30 minutes, Attemtp to shear SOV for 1 hour unable to shear at 2000 psi differential SOV sheared at 2700 PSI after several attempts. 4/4/2019 4/4/2019 1.50 COMPZN RPCOMP RURD P Blow down stack and choe and kill 09:00 10:30 1 lines RD test hoses 4!4/2019 4/4/2019 0.50 COMPZN RPCOMP MPSP P Set BPV and test from below to 1000 10:30 11:00 PSI for 10 min. 4/4/2019 4/4/2019 0.50 COMPZN RPCOMP SFTY P PJSM for ND BOPE 11:00 11:30 4/4/2019 4/4/2019 5.50 COMPZN RPCOMP NUND P ND BOPE and clean pits, 11:30 17:00 4/4/2019 4/5/2019 7.00 COMPZN RPCOMP NUND P prep Wellhead to set adapter and tree. 17:00 00:00 test adapter @ 250/5000 psi F/ 10 min, change out SBMS seal, nipple up tree, dg up and test tree @ 250 16000 F/10 min Page 10110 ReportPrinted: 5/3/2019 WELL LOG TRANSMITTAL #905557931 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: CD3 -115 Run Date: 3/15/2019 209006 30 73 1 April 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3 -115 Digital Data, Digital Log Image file, 3D viewers, and Interpretation Report 1 CD Rom 50-103-20593-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: RECEIVED MAY 0 8 2019 AOGCC Signed: Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: a AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 .f i 710 TRANSMITTAL DATE TRANSMITTAL tt WELL NANi- - API N 1- JkRVICE ORDER '� iii.. FIELD NAME • SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's � � i � iii • ...• 00 COLVILLE RIVER Signature Please return via courier or sign/scan and email a copy ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the `GG package have been verified to match the media noted above. Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this and CPAI. point. ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 1 f TRANSMITTAL DATE: TRANSMITTAL #: engtwuyj FIELD 30 626 BP North Slope 0 0 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 300 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. rx L.1 W116.&-10 0 Attn: NSK-69 APR 19 700 G Street Anchorage, Alaska 99501 AOGCC AOGCC 1 0 1 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 �h Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: 2C>9096 ORIGINATED 4/11/2019 ALASKA E -LINE SERVICES 04112019 42260 Kenai Spur Hwy 5 0 9611 O: (907) 283-7374 'FAX: (90BOX 1481 - Kena, Alaska7) 283-7378RECEIVED Alpine PH APR 12 2019 AOGCC DELIVERABLE DESCRIPTION 12681 ICD3-115 120-103-20596-00 1 CCL -Final Field 12/28/2019 1 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. 0 0 1 4ttn: NSK-69 700 G Street 4nchorage, Alaska 99501 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 Garrett Brown -Geologist I Division of Oil & Gas West 7th Ave, Suite #1100 - Anchorage, AK 99501 0 1 0 1 1 Signature Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: Date Licit C� 3-11 S p7b 2eYamr,O Regg, James B (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, March 29, 2019 9:13 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Cc: Senden, R. Tyler; ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/29/2019 Attachments: Wei lControl_Close BOP_AOGCC_Report_3_29.doc Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 115. Please let me know if you have any questions. Thanks. Good day. Dusty Ward Senior Wells Engineer Off ice: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Date: March 29, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nordic #1 with a written report. Time of BOPE Use: 3/29/2019 at 11:45 hours Well Location: CD3 - 115 API Number: 50-103-20593-00 PTD Number: 209-006 Rig Name: Nordic 1 Operator Contact: Dusty Ward (o) 263-6531. (c) 503-476-2519. DustyWard @ConocoPhillips.com Operations Summary Began tripping out of the hole after clean out run. Observed improper hole fill, monitored well slight flow on IA. The Hydril nnular was closed at 11:45 on 3/29/2019 and pressures were checked. IA pressure leveedout at 170 psi while shut in, exhale test was performed indicating some gas may have gotten into the annulus. Kill weight fluid will be weighted up, circulate and bullheaded into the well. BOPE Used: 11" Hydril Annular, 3.5" TIW, Choke valve 12 Reason for BOPE Use: The Hydril Annular was closed to force fluid down the IA. ' Actions to Be Taken: The Hydril Annular, Kill HCR and super choke will be retested once out of hole with the ' tubing. If you have any questions or require any further information, please contact me at 907-265-6531 Sincerely, Dusty Ward CPA] Drilling and Wells ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Date: March 29, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: (2 TO a,oq —oO�- As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nordic #1 with a written report. Time of BOPE Use: 3/29/2019 at 11:45 hours Well Location: CD3 - 115 API Number: 50-103-20593-00 PTD Number: 209-006 Rig Name: Nordic 1 Operator Contact: Dusty Ward (o) 263-6531. (c) 503476-2519. DustyWard @ConocoPhillips.com Operations Summary_ Began tripping out of the hole after clean out run. Observed improper hole fill, monitored well slight flow on IA. The Hydril Annular was closed at 11:45 on 3/29/2019 and pressures were checked. IA pressure leveled out at 170 psi while shut in, exhale test was performed indicating some gas may have gotten into the annulus. Kill weight fluid will be weighted up, circulate and bullheaded into the well. BOPE Used: I P' Hydril Annular, 3.5" TIW, Choke valve 12 Reason for BOPE Use: The Hydril Annular was closed to force fluid down the IA. Actions to Be Taken: The Hydril Annular, Kill HCR and super choke will be retested once out of hole with the tubing. If you have any questions or require any further information, please contact me at 907-265-6531 Sincerely, Dusty Ward CPAI Drilling and Wells Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, March 29, 2019 9:13 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Cc: Senden, R. Tyler; ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/29/2019 Attachments: WellControl_CloseBOP_AOGCC_Report_3_29.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 115. Please let me know if you have any questions. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, March 22, 2019 9:34 AM To: 'Ward, Dusty K' Subject: CRU CD3-115(PTD 209-006, Sundry 319-011) Packer Set Depth and Completion Change Dusty, Approval is granted for the change of packer depth to `11322' MD as outlined in the message below. Please include this approval with your copy of the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoo(a)a laska.00v CONFIDENTIAUTY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loegn@alaska.aov From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, March 22, 2019 9:17 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: CD3 -115 Packer Set Depth and Completion Change Victoria, I got calculated top of Cement at 11,200' KB based off of "Cement Detail Report" page 148/198 of the AOGCC files here: htt aogweb.state.ak.us/WebLink/DocView.aspx?id=37537&searchid=d5898ac2-c9a7-4bc7-b544- ab4713dd6400&dbid=0 Let me know if you need anything else. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, March 22, 2019 8:52 AM To: Ward, Dusty K<Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]RE: CD3 -115 Packer Set Depth and Completion Change Hi Dusty, I'm just reviewing your message - do we know the Intermediate TOC? From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Thursday, March 21, 2019 3:06 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska. > Subject: CD3 -115 Packer Set Depth and Completion Change Victoria, Hope this finds you well. On CD3 -115 as we were almost to bottom with running the new completion; we got stuck. It appears the packer slips prematurely engaged; so we finished setting the packer about ^'160' above (11372' RKB) the last packer position (11532' RKB) we pulled out. Unfortunately, we can't land the 4.5" tubing that is in the hole due to our completion configuration and where we got stuck, so we plan to - Cut and pull the completion, leaving the packer and tubing stub in place. - Stack a packer with a non -sealing overshot to re -complete the well. This will result in our new packer being placed at -11,322" RKB as shown in the attached schematic. Please confirm you received this and approve. Let me know if you need anything else or have any questions. I left a message for you also. Thanks greatly for your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, March 29, 2019 10:21 AM To: Ward, Dusty K Subject: CD3-115(PTD 209-006, Sundry 319-011) Packer Set Depth and Completion Change_2 Follow Up Flag: Follow up Flag Status: Flagged Dusty, Approval is granted for the packer depth setting change outlined below; that is stack the packer at —11,242' RKB. Please include this approval with your copy of the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppa().alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loe aoLalaska,gov From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, March 29, 2019 10:08 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: CD3-115(PTD 209-006, Sundry 319-011) Packer Set Depth and Completion Change_2 Victoria, I hope this finds you well. We're continuing to have decent challenges with CD3 -115. Since the last approval we've: - Ran in hole with completion again to land out. o We tagged about 1 joint high above the tubing stub and could not get down further to re-engage, w/o risk of damaging our New Packer (which is slightly longer and larger OD than the first packer that prematurely set the first time). o To not repeat premature packer setting, we decided to come out of hole again and do a designated clean out run. We saw some scaring on the packer, and think we may have had some metal debris down there. - We then tried cleaning out with a cleanout BHA that had string mills (used as a broach) that had slightly large OD than our packer. Goal was: Get down to tubing stub, circulate out any debris that may be there, and confirm drift w/ larger OD that has some cutting structure to push debris. o On the cleanout run, we tagged high also and worked it most of last night and could Not reach the tubing stub. We're currently pulling out of hole with the cleanout BHA and plan to run an Eline Caliper to Confirm Drift of our Tubing and Overshot down to the stub. Once we confirm we can get our Overshot and Tubing tail to re -tie into the tubing stub in the hole, we're planning to run the completion again and: - Stack the packer at 11,242' RKB (2 its higher than previously approved 11,322'), because we've Confirmed our packer drifts that far before from our 2nd attempt at landing the completion. (attached schematic). Calculated TOC referenced below. Please confirm you received this and approve. Let me know if you need anything else or have any questions. Thanks greatly for your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, March 22, 2019 9:34 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]CRU CD3-115(PTD 209-006, Sundry 319-011) Packer Set Depth and Completion Change Dusty, Approval is granted for the change of packer depth to -11322' MD as outlined in the message below. Please include this approval with your copy of the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeopLcDalaska.00v CONFIDENTIALRY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loer)ip@aiaska.gov From: Ward, Dusty K <Dusty Ward@conocophillips.com> Sent: Friday, March 22, 2019 9:17 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: CD3 -115 Packer Set Depth and Completion Change Victoria, I got calculated top of Cement at 11,200' KB based off of "Cement Detail Report" page 148/198 of the AOGCC files here: http //aogweb state ak us/WebLink/DocView aspx?id=37537&searchid=d5898ac2-c9a7-4bc7-b544- ab4713dd6400&dbid=0 Let me know if you need anything else. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria loepp@alaska.Rov> Sent: Friday, March 22, 2019 8:52 AM To: Ward, Dusty K <Dusty Ward conocophillips.com> Subject: [EXTERNAL)RE: CD3 -115 Packer Set Depth and Completion Change Hi Dusty, I'm just reviewing your message — do we know the Intermediate TOC? From: Ward, Dusty K <Dusty Ward@conocophillips.com> Sent: Thursday, March 21, 2019 3:06 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Subject: CD3 -115 Packer Set Depth and Completion Change Victoria, Hope this finds you well. On CD3 -115 as we were almost to bottom with running the new completion; we got stuck. It appears the packer slips prematurely engaged; so we finished setting the packer about —160' above (11372' RKB) the last packer position (11532' RKB) we pulled out. Unfortunately, we can't land the 4.5" tubing that is in the hole due to our completion configuration and where we got stuck, so we plan to - Cut and pull the completion, leaving the packer and tubing stub in place. - Stack a packer with a non -sealing overshot to re -complete the well. This will result in our new packer being placed at —11,322" RKB as shown in the attached schematic. Please confirm you received this and approve. Let me know if you need anything else or have any questions. I left a message for you also. Thanks greatly for your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Date: March 20, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nordic #1 with a written report. Time of BOPE Use: 3/20/2019 at 15:30 hours Well Location: CD3 - 115 API Number: 50-103-20593-00 PTD Number: 209-006 Rig Name: Nordic 1 Operator Contact: Dusty Ward (o) 263-6531. (c) 503-476-2519. DustyWard @ConocoPhillips.com Operations Summary: While circulating and losing I bbl/hr, the decision was made to drop the ball and rod to confirm the packer was fully set. The Hydril Annular was closed at 15:30 on 3/20/2019 so that fluid could be pumped down the IA while the ball fell. BOPE Used: 11" Hydril Annular Reason for BOPE Use: The Hydril Annular was closed to force fluid down the IA while the ball and rod was dropped to set the packer. Actions to Be Taken: The Hydril Annular, Kill HCR and super choke will be retested per the next BOPE test when tubing is pulled out of hole. If you have any questions or require any further information, please contact me at 907-265-6531 Sincerely, Dusty Ward CPAI Drilling and Wells Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Thursday, March 21, 2019 2:36 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Cc: Senden, R. Tyler; ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/20/2019 Attachments: WelICOntroI_CloseB0P_AOGCC_Report_3_20.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 115. Please let me know if you have any questions. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 zID q - SOU) ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Date: March 20, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nordic #1 with a written report. Time of BOPE Use: 3/20/2019 at 15:30 hours Well Location: CD3 - 115 ' API Number: 50-103-20593-00 PTD Number: 209-006 � Rig Name: Nordic 1 Operator Contact: Dusty Ward (o) 263-6531. (c) 503-476-2519. DustyWard @ConocoPhillips.com Operations Summary: While circulating and losing 1 bbl/hr, the decision was made to drop the ball and rod to confirm the packer was fully set. The Hydril Annular was closed at 15:30 on 3/20/2019 so that fluid could be pumped down the IA while the ball fell. BOPE Used: 11" Hydril Annular , Reason for BOPE Use: The Hydril Annular was closed to force fluid down the IA while the ball and rod was dropped to set the packer. Actions to Be Taken: The Hydril Annular, Kill HCR and super choke will be retested per the next BOPE test when ✓ tubing is pulled out of hole. If you have any questions or require any further information, please contact me at 907-265-6531 Sincerely, Dusty Ward CPAI Drilling and Wells f'rn za�orJl�ta Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, March 20, 2019 11:12 AM �ec� 31w1(h To: Ward, Dusty K Cc: ALP RWO CoMan; Senden, R. Tyler; DOA AOGCC Prudhoe Bay Subject: RE: CD3 -115 BOP Test Extension Request for Nordic 1 Request to delay the BOPE test (due today, 3/20) is approved. Since the test date is uncertain at this time please provide periodic updates and give as much notice as possible for the BOPE test. Jim Regg Supervisor, Inspections AOGCC 333 W.7rh Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.aov. From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Wednesday, March 20, 2019 10:55 AM To: Regg, James B (DOA) <jim.regg@alaska.gov> Cc: ALP RWO CoMan <ALPRWOCoMan@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: CD3 -115 BOP Test Extension Request for Nordic 1 Jim, Attached is the original Sundry I meant to attach in the previous e-mail. Also, if you need to call, please call my cell as I'm at the airport and will be traveling to the slope around noon. Rig phone number is 907-670-4721 if you can't get a hold of me. Thanks. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Ward, Dusty K Sent: Wednesday, March 20, 2019 10:52 AM To: Regg, James B (DOA) <iim.regg@alaska.gov> Cc: ALP RWO CoMan<ALPRWOCoMan@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: CD3 -115 BOP Test Extension Request for Nordic 1 Jim and to whom it may concern, ,/ Hope this finds you well. On CD3 -115 (209-006) Rig workover, we were running the completion this morning and planning to land this AM before our next BOP test. About 2 joints off of bottom, we became stuck. We're still evaluating the scenarios as to why we may be stuck. We are evaluating paths forward to try and get unstuck and land the completion OR if packer has pre -maturely set on us, we may finish the setting process and move into contingency planning. (Our muleshoe to re -connected the completion to the 4.5" tie back liner is probably about -80' away at this point from no -going.) We're requesting a BOP extension on Nordic 1 until we can get to a point where we can perform a weekly BOP test, as we will not be completing this well as we had anticipated. Thanks for your time. Please call if you have any questions. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 PT0 ?09-00% Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, March 15, 2019 1:10 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Cc: Senden, R. Tyler, ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/14/2019 Attachments: WeliControl_CloseBOP_AOGCC_Report.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 115. Please let me know if you have any questions. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Date: March 13, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting DOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nordic #I with a written report. Time of BOPE Use: 3/14/2019 at 20:00 hours Well Location: CD3 - 115 API Number: 50-103-20593-00 PTD Number: 209-006 Rig Name: Nordic 1 Operator Contact: Dusty Ward (o) 263-6531. (c) 503-476-2519. DustyWard @ConocoPhillips.com Operations Summary: After having the tubing in tension and cutting the cut -to -release -packer, the tubing began to pull indicating packer had released. The Hydril element was then closed @ 16:00 on 3/14/19 to circulate out the packer gas per routine operation. On that same circulation, it was planned to drop the KWF 0.1 ppg to help decrease the large loss rate that had been seen thus far on the well. Upon gas being circulated out, the well was checked for flow and well was observed to be flowing. The Hydril Annular was closed @ 20:00 hrs. 3/14/19. Shut in pressures were recorded @ 20 psi on annulus and 20 psi on tubing. Circulation was resumed and a bottoms up was pumped; no additional gas or any visible oil was observed at surface returns. The KWF will be re -weighted up 0.1 ppg and circulated around. BOPE Used: 11" Hydril Annular Reason for BOPE Use: The Hydril Annular was closed after a KWF weight change was circulated. Actions to Be Taken: The Hydril Annular, Kill HCR and super choke will be retested when tubing is pulled out of hole. If you have any questions or require any further information, please contact me at 907-265-6531 Sincerely, Dusty Ward CPAI Drilling and Wells C,,8 c D 3-115' p b ze ooh c Regg, James B (DOA) From: Ward, Dusty K <Dusty.Ward@conocophiIli ps.com> Sent: Friday, March 15, 2019 1:10 PM To: DOA AOGCC Prudhoe Bay, Loepp, Victoria T (DOA) Cc: Senden, R. Tyler; ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/14/2019 Attachments: WellControl_CloseBOP_AOGCC_Report.doc Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 115. Please let me know if you have any questions. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Date: March 13, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nordic #I with a written report. Time of BOPE Use: 3/14/2019 at 20:00 hours Well Location: CD3 - 115 API Number: 50-103-20593-00 PTD Number: 209-006 ✓ Rip Name: Nordic I Operator Contact: Dusty Ward (o) 263-6531. (c) 503-476-2519. DustyWard @ConocoPhillips.com Operations Summark After having the tubing in tension and cutting the cut -to -release -packer, the tubing began to pull indicating packer had released. The Hydril element was then closed @ 16:00 on 3/14/19 to circulate out the packer gas per routine operation. On that same circulation it was planned to drop the KWF Q. I Rpg to help decreat the large loss rate that had been seen thus far on the well. Upon gas being circulated out, the well was checked for flow and well was observed tote flowing. The Hvdril Angular way @ c1use 70.00 his. 3/14/19. Shut in pressures were recorded @ 20 psi on annulus and 20 psi on tt no additional gas or any visible oil was observed at circulated around. BOPE Used: I P' Hydril Annular I d Circulation was resumed and a bottoms up was pumped; :e returns. The KWF will be re -weighted up 0.1 ppg and Reason for BOPE Use: The Hydril Annular was closed after a KWF weight change was circulated. Actions to Be Taken: The Hydril Annular, Kill HCR and super choke will be retested when tubing is pulled out of hole. If you have any questions or require any further information, please contact me at 907-265-6531 Sincerely, Dusty Ward CPA] Drilling and Wells STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR ti 61, 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Ll Operations shutdown Lj Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑ 209-006 3. Address: PO Box 100360 6. API Number: Anchorage, AK 99510 50-103-20593-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3 -115 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 19564 feel Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461' Intermediate 12122' 7" 12156' 6942' Production Liner 7534' 4.5" 19564' 6854' Perforation depth Measured depth Pre -Drilled Liner 12268'- 15442', Pert Pups 15648'- 19433' True vertical depth Pre -Drilled Liner 6959'- 6914', Pert Pups 6914'- 6861' Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 12051' MD, 6920' TVD Packers and SSSV (type, measured and true vertical depth) Packer - Baker Premier Packer, 11532' MD, 6737' TVD SSSV - Camco TRMAXX-5E, 2169' MD, 2001' TVD, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12268'- 19450' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 206 796 2022 1730 1 274 Subsequent to operation: 1970 1424 3604 1934 1 269 14. Attachments (required per 20AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ i6. Well Status after work: Oil U Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Engineer Contact Email: Kavlle.B.Plunkett(cDcop.00m jProduction Authorized Signature: (� �n�,�. Dates 3 - - I Contact Phone: 265-6450 Form 10404 Revised 412017 t/r, 3/15/19 "V,;,//''l' RBDMS_J�/MAR 0 6 2019 Submit Original Only CD3 -115 Scale Inhibition Treatment 2/2/19 —2/3/19 Hybrid Scale Inhibitor Squeeze Treatment pumped from 11:15 hrs on 2/2/19 to 11:00 hrs on 2/3/19. LRS = Little Red Services CT = Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA-931/1814/380 - RIH with CT to 19070' CTMD - Pumped 290 bbls Diesel/M209/WAW5206 pre -flush through CT at 1.2 bpm while POOH to 12268' CTMD RBIH with CT to 19450' CTMD Pumped 290 bbls Seawater and SCW3001 scale inhibitor through CT at 1.3 bpm while POOH to 12268' CTMD POOH with CT. TBG/IA/OA — 1309/1775/395 LRS pumped 2087 bbls dead crude/M209 over -flush at 4.1-4.4 bpm. TBG/IA/OA — 2070/1545/320 Interval treated: 12268'— 19450' CTMD 209006 ORIGINATED 3/14/2019 ALASKA E -LINE SERVICES 03142019 42260 Kenai Spur Hwy _ PO BOX 1481- Kenai, Alaska 99611 R ' .i -Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 3047 1 MAR 19 213119))1 .,&.OGCC DELIVERABLE DESCRIPTION 2702 ICD3-115 150-103-20593-00 1 CCL -Final Field BP North Slope 1 0 0 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. 1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 return via e-mail a copy to both Alaska E -Line Services andUnoco Phillips Alaska: PTP ao9 -ooc_ Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Wednesday, February 27, 2019 1:20 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]Re: CD3 -115 (209-006) Scope Change/Update Follow Up Flag: Follow up Flag Status: Flagged Thank you. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, February 27, 2019 1:01 PM To: Ward, Dusty K <Dusty.Ward@conocophiIlips. com> Subject: [EXTERNAL]Re: CD3 -115 (209-006) Scope Change/Update Dusty, The changes outlined below are approved. Please include this approval change with the approved sundry. Victoria Sent from my iPhone On Feb 27, 2019, at 11:14 AM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: Victoria, Hope this finds you well. For CD3 -115 (209-006) RWO approved Sundry, we had the following changes: - New SBHP came in and put MPSP at 2525 psig; so we're increasing our BOP tests to 2,600 psig from 2,500 psig for both annular and rams. o Update Summary attached. - We decided to make the whole completion 4.5" AND added a Single Gauge to the completion design. Update Schematic attached. Thanks. Please let me know you received this and if you have any questions. Make it a great day! Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 <CD3 -115 APPROVED 10-403 PULL TUBING, REPAIR WELL Sundry App.pdf> <CD3 -115 RWO Summary_Revl.pdf> <CD3 -115 RWO Prop Schematic_REV1.pdf> 62.5# H-40 e@114'RKB 9-5/8" 40# L-80 shoe @ 2995' RKB 7" 26# L-80 shoe @ 12156' RKB CD3 -115 Proposed RWO Completion 4-1/2" Liner @ 19564' RKB 4-1/2" 12.6# IBTM 4-9d' BP -6i Nipple Profile at -2169' RKB w/ (3.813" min ID) (Set up for SCSSSV) 4-1/2" 12.6# IBTM 4-1/2" Carrico gas lifl mandrels @ TBD 4-1/2" Dual Gauge Baker 4-1/2" x 7" Packer -11515' RKB (XXX" ID) 4-9;' X landing nipple at xxxx' RKB (2.813" min ID) Baker Wireline Entry Guide @ 12026' RKB PT0 ?09-00% Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Friday, March 15, 2019 1:10 PM To: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Cc: Senden, R. Tyler, ALP RWO CoMan; Ward, Dusty K Subject: Notification of BOP use on Nordic 1 on 3/14/2019 Attachments: WeliControl_CloseBOP_AOGCC_Report.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria and to whom it may concern, Please see attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on CD3 - 115. Please let me know if you have any questions. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Date: March 13, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting DOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nordic #I with a written report. Time of BOPE Use: 3/14/2019 at 20:00 hours Well Location: CD3 - 115 API Number: 50-103-20593-00 PTD Number: 209-006 Rig Name: Nordic 1 Operator Contact: Dusty Ward (o) 263-6531. (c) 503-476-2519. DustyWard @ConocoPhillips.com Operations Summary: After having the tubing in tension and cutting the cut -to -release -packer, the tubing began to pull indicating packer had released. The Hydril element was then closed @ 16:00 on 3/14/19 to circulate out the packer gas per routine operation. On that same circulation, it was planned to drop the KWF 0.1 ppg to help decrease the large loss rate that had been seen thus far on the well. Upon gas being circulated out, the well was checked for flow and well was observed to be flowing. The Hydril Annular was closed @ 20:00 hrs. 3/14/19. Shut in pressures were recorded @ 20 psi on annulus and 20 psi on tubing. Circulation was resumed and a bottoms up was pumped; no additional gas or any visible oil was observed at surface returns. The KWF will be re -weighted up 0.1 ppg and circulated around. BOPE Used: 11" Hydril Annular Reason for BOPE Use: The Hydril Annular was closed after a KWF weight change was circulated. Actions to Be Taken: The Hydril Annular, Kill HCR and super choke will be retested when tubing is pulled out of hole. If you have any questions or require any further information, please contact me at 907-265-6531 Sincerely, Dusty Ward CPAI Drilling and Wells GTp�709 —00(r Ward, Dusty K From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, February 27, 2019 1:01 PM To: Ward, Dusty K Subject: [EXTERNAL]Re: CD3 -115 (209-006) Scope Change/Update Dusty, The changes outlined below are approved. Please include this approval change with the approved sundry. Victoria Sent from my iPhone On Feb 27, 2019, at 11:14 AM, Ward, Dusty K <Dusty.Ward(a)conocophi!lips.com> wrote: Victoria, Hope this finds you well. For CD3 -115 (209-006) RWO approved Sundry, we had the following changes: - New SBHP came in and put MPSP at 2525 psig; so we're increasing our BOP tests to 2,600 psig from 2,500 psig for both annular and rams. o Update Summary attached. - We decided to make the whole completion 4.5" AND added a Single Gauge to the completion design. o Update Schematic attached. Thanks. Please let me know you received this and if you have any questions. Make it a great day! Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 <CD3 -115 APPROVED 10-403 PULL TUBING, REPAIR WELL Sundry App.pdf> <CD3 -115 RWO Summary_Revl.pdf> <CD3 -115 RWO Prop Schematic_REV1.pdf> THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3 -115 Permit to Drill Number: 209-006 Sundry Number: 319-011 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogc c.a I a ska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, zv� Daniel T. Seamount, Jr. Commissioner Q , O DATED this ! flay off February, 2019. SCANNED FEB 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 'EIVED !AN 14 2019 , ,.OGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ' Operations shutdown❑ Suspend ❑ Perforate I] Other Stimulate ❑ Pull Tubing I] Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllli s Alaska Inc. Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 209-006 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-103-20593-00 -00a 7. If perforating: 8. Well Name and Number. rJ it-, What Regulation or Conservation Order governs well spacing in this pool? N/A p Will planned erforationsr require spacing exce tion? P P eq p g p Yes ❑ No 0 CRU CD3 -115 9. Property Designation (Lease Number):II 10. Field/Pool(s): ADL 380092, ADL 372105, ADL 389725, ADL 3842Y5'IQ Colville River Field / Fiord 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): 19,564' 6,854' 19564 6854 1843 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 114' Surface 2,959' 95/8 2,995' 2,461' Intermediate 12,122' 7" 12,156' 6,942' Liner 7,534' 41/2 1 19,564' 6,854' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 12268-15442,15648.19433 6959-6914,6914-68( 3.500" L-80 12,051' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER PREMIER PACKER 5.98" OD X 2.87" ID MD= 11532 TVD= 6737 12. Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑J 14. Estimated Date for 3/8/2019 / 15. Well Status after proposed work: Commencing Operations: OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Ward Dusty Ward Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: Dusty.Ward@cop.com Authorized Signature: �" Contact Phone: (907) 265-6531 i" I1'(^ I (/v Date : COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,J1 1'VtI Plug Integrity ❑ D/11 Test LyD/11Mechannical Integrity Test [:1 Location Clearance El iBOP Other: a op �i'Y/ YJ " 2 5-72 \ �, n/-/Rr! t—e-vCvr�/7/r jz-f 1/` 7- 5-29 rS 15 Post Initial Injection MIT Req'd? Yes E] No LX' Spacing Exception Required? Yes ❑ No Subsequent Form Required: /e — 4 04 - APPROVED BY Approved by: COMMISSIONER ( THE COMMISSION Date: c ll Ct,r`k v '17 Form 10-403 Revi d!4/1017 vy4 Gey/i67 '}�1 D I I AI /A\ RBDMSPN" EB 05 2019 1 1 fl 1 1 � \I (.{ Submit Form and Approved application a iii000iii 1222�..illrfflllo111111t s 1100A11Tnnl YYYIII to of approval. Attachments in Duplicate t_ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 14 Jan, 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t^ Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. (CPAI) hereby applies for Sundry Approval to workover Producer CD3 -115 (PTD# 209-006). CD3 -115 was drilled and completed in March of 2009 as a Fjord Nechelik producing well. The tubing retrievable SSSV had issues right away and a Wireline Retrievable Safety Valve (WRSV) was set. The well produced most of its life, but continues to slowly build up with scale, which has been periodically cleaned out with coil. In 2018 the well became a workover candidate to replace the SSSV and perforate the well. The well will have the entire tubing completion pulled. Then the well will be perforated with —3,000' of TCP guns on rig from 16,000-19,000' RKB to help slow the scale up of the well. The well will then be recompleted with packer set near original location and tubing to surface replaced. A new surface controlled SSSV will be ran with the completion. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, �� Dusty Ward Senior Wells Engineer CPA] Drilling and Wells CD3 -115 RWO Procedure Alpine Producer PTD #209-006 Pre -Rig Work 1. Pull WRSV. 2. Get additional SBHP. 3. Cut Premier Packer at "'11532' RKB in correct location to make it tubing retrievable. 4. Confirm deepest GLM is open. 5. Confirm latest packoff tests passed. 6. Coil Cleanout to 19,000' RKB to prepare for TCP run on -rig. 7. Install BPV. Rig Work MIRU 1. MIRU Nordic 1. Pull BPV. Kill well by circulating KWF long way around. 2. Record shut-in pressures on the T & IA. Plug and packer should provide competent barrier. If there is pressure, bleed off IA and/or tubing pressure and pull BPV. Complete 30 -minute NFT. Verify well is dead. a. Primary barrier: KWF and competent casing. b. Secondary barrier: Packoffs and Tree OR BOP. (BPV in place and confirmed in direction of flow while swapping tree to BOP and vice versa.) 3. Set BPV, confirm BPV with rolling test if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. a. MPSP of 1843 PSIG calculated from SBHP of 2528 prig at 11835' RKB (6855' TVD) on 2/12/2014. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2" x 3-1/2" tubing with jewelry down to mule shoe WLEG at 12026' RKB. Retrieve Tubing Section 6. Make cleanout run to 19,000' RKB if needed in addition to pre -rig coil cleanout run. 7. Makeup 3,000 of TCP guns and RIH on DP to depth of 19,000'. 8. Correlate on depth. Fire guns. TOOH. Install in 4-1/2" x 3-1/2" Tubing Completion 9. MU 4-1/2" x 3-1/2" completion with non -sealing overshot, nipples, packer, GLMs, and SCSSSV. RIH and confirm overshot has engaged tubing stub. 30. Space out, land tubing hanger and install packoffs. 11. Drop ball and rod and set packer top @ approximately 10520' RKB (6211' TVD) w/ completion. a. TOC calculated at 11200 RKB (6579' TVD). 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. Confirm BPV. 16. ND BOPE. NU tree. 17. Freeze protect well. 18. RDMO. Page 1 of 1 Adpo+ WNS PROD CD3 -115 COI'10C6pf11llIp5 tbilbu Well Attributes - Ml TD MBSk6,111C Weell I') me&MD FIeIE Name Wellbort Mewe nd r) MD(XN91 Ae<BIm IXKB) 501032059300 FIOPp NE CHELIK PROD 93.84 12599)9 19,584.0 Commend N331ppm) Oafe Mnotelon Entl Odle KBLN(X) RI9ROICMDYe SSSV'. WHO Land WO'. 42.70 W7/2W9 NOg20HTALCp1,15. 4.4M1018a]a.Oa PM Last Tag e ae amxe MnOIAIOn DepIM1 (KKB1 EnE pAe LYIM009y x/:NGFR,9p9- ............ Lai Ta9'. Viplwf Last Rev Reason enmOdion EndGale LYI MM By Rev Reason: SETMOD. MOB d SLIP STOP 41302010 Cleytg Casing Strings CONDucmR:»0-1144� kOaeeua4@tfa0 cealneoeacngwn oo(ml mlml T:ep(M.) ...Wh INK91 Be DeNA Tern-ml*"11._GMe mR Tnmd CONDUCTOR 16 15.250 3TO LISA 1140 62.60 H`O Welded BLET"V,'FMP 31880 saFETr VLv. zi697 .a,ze 1681 D idol Top(M1K6) SN Oepun IXKe) SM MIn RV L. WNLen 1. 111. Pip ThYM CYInB DaeerlpM00 OD (n1 :5 SURFACE B&8 8.035 3ft.2 2,9950 2,461.1 40.00 L-80 BTCM CYep peGlpryon OD yell- IGf1n1 Top IXKD) ed OeOn lade) Se Depth ITVDI.. W�Lefli-G,afe Tuned IT., INTERMEDIATE 7 6.276 34.0 12)55,2 6941.9 26.00 L-80 BTCM Casino De¢tlpllOn OD (In1 10(Inl Top (M1Ka) SN OeptM1 (XKB) Sn OepN (TVp)._ WIILen B... Grade Top Th,eed LINER 4 P2 3.958 12,029.9 19,564.0 8,8533 1260 LW IBTM SJRFACS MX 299I Liner Details orIInaI ID GA9LIFT;48780 Top lfiNa) Top IiYDI1ryK31 TOp l,wl r) Mm OY COm IInl 12029.9 6,914.3 74.81 SLEEVE 1HR' Uner SeOing Siceve 5.81' 10(10.13Inne, 5.250 Pw le) 12,0429 681).6 )6.31 NIPPLE 'RS•PackWSeel Nipple 5.60'OU X426' ID 4.260 12,046.6 6,918.6 7545 HANGER Bake] Flex Leek Liner Hanger 5.91"00X48%'10) 4430 GASLI1T. INS. 12,056.4 6,921.0 75.83 XOReducing XO Bushing- 512'TKC X41/7 SLH7(393"ID) 3.930 15,602.6 6.912.5 Sill PERFXO 4112`12.64L-0 XO�410I8T(p)%412"SLHT(B) 3.958 CHANGE FROM (6)1/2" HOLES IN CENTER OF G09upT, t I.111r 40' JOINT XO TO PERE PUPS (6) 21YG hdY per 5' pup old, afternatlna wiq XO' e01id pipe MKS. M PMNER:11931.6 16,697,2 6,0850 90.64 Swel; PKR TPM Packer on 10 J8'Pup - 5 78' D0, 3,937' ID. 3.937 Eletnery 1046 WILE 11,,"S Tubing Strings sing DeseNpllon 9lring Ma.. lOtln) Top (XKS) atl Oepih (X, Sri gpil, (!W)(.. WI pLMj GMe iep COnnzdlon wslxotsn TUBING45'YJ.S• 312 2992 309 120510 6,919.) 9.30L80 EUE Completbn Details .IEC: fzoZ6z T. T pI-) Top l,rI Nominal TOPIXNBI r) mm Dp COm ID11n) 30.9 30.9 0.00 HANGER FMC410TbgrzegeW2.32Wp 4.500 114.0 114.0 0.21 XO Reducing XO- 4129BTMRa X3I0EUErP) 2.902 21692 2.0009 4595 SAPFTYVLV Cameo TR M=-5ESSSVw128f7X prO61e(LOCKFOOpT 2812 FLAPPER 8 HYDRAULIC SLEEVE 42 ICiVil XNIpple Lockllg Pldile Pce9iMy Damaged ORERMEDI.ATE. 340-12156.2� 11,631.6 5736.6 63.63 PACKER Bake, Premier Packer 5,98` OD x 2.BT' 10 2870 11.675.6 6.7M.1 VBut NIPPLE HES •XN- NIPPLE W 281• POLISH BORE, 275" NO GO 270 120150 6.910.3 74.24 W -87 -XO 3, 12' 9.3X EUE X IBT-Tag pup p. W/ Sheer Pin Fuld No Go 2990 12026.2 6,913.3 74.67 WIEG Pup 3129BTTubing W/Mule shoe MEG 2880 ;sit In Hob ryMretins retro M plugs, valves, pumps, /lstL, ii TOP 11) TOP Incl ILL(M1N91 r) One Com Run Ind.ID(In) 1 2,168.0 2990.0 4591 SMP STOP 3 dUPSTOP 4Lip/2018 1.500 PERFP:1z.23e.LL10.41z0- 2.1682 $0088 4595 WRDP 281•WRDP(SN: HVS-51410N 2.84•No-Go w12.31•G 41302018 1.500 FISHING NECK (FRUEDENBERG PKG TOP 8 BTM) Perforations & Slots aha DY Tap-) Bd(WIN (•na%41 T12.268) BIm41ZO za,. Dw 1 Trp• cnm 12260.0 15.4420 8,9581 6,95 6.91 6,9140 NECH-CRSUP. 3MfL:U9 6.0 PERFP TOP LINERS CION: PRE CD}115 DRILLEDUNER 141dIXed 417 hophis Mth (6)1.? HOLES@cenmrMEACH 40 pint, aftelna8ng with 200 9u0d pipe seLlan5 15,610.0 19,433.0 69142 68613 NECH-C_RS UP. 34/20-9 32.0 PERFP -LBRE RUN ER5ECT10N: CD3 -115 PERF PUPS: (8) 21? hO.W5' Wpldnt a6nna" gM01200'.1M pipe acel:me Mandrel Inserts M IS IS TO I-) Valve LnMh Pod Size TRO Run M Tep(ft") MKS) III a., Cop.) Suez, TM (in) (W) Run Doe CBm 1 4,878.0 3,3906 CAMCO KBMG 1 GAS LIFT DMY BKS 0.000 00 3/52009 2 $3469 5.5912 CAMCO KBMG 1 GASLIFT GLV BKS O1 2.176.0 8242015 3 11444] 6.69)6 CAMCO KBMG i GAS LIFT OV BK 0.250 CO 2718/2018 Notes: General & Safety Ena Dm. Annamion 4242009 NOTE, VIEW SCHEMATIC w1A1aka SchelnM1c9.0 PERFP, 15,e166te13J 0� LINER:1Z.H &195310- CD3 -115 Proposed RWO Completion PROPOSED COMPLETION 4-1/2" 12.6# IBTM 4-%' SSSV at -2169' RKB w/ X Nipple Profile (3.813" min ID) 4-1/2" 12.6# IBTM Crossover to 3-1/2" 9.3# EUE 3-1/2" Camco gas lift mandrels @ TBD Baker 3-1/2" x 7" Packer -11515' RKB (XXX" ID) 3-1/" X landing nipple at xxxx' RKB (2.813" min ID) Baker Wireline Entry Guide @ 12026' RKB I Nordic 1 PTE3 2 ol—OO4 • Loepp, Victoria T (DOA) From: Johnstone, Sam <Sam.Johnstone@conocophillips.com> Sent: Friday, May 25, 2018 11:09 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]RE:CD3-115 SSSV extension request(PTD#209-006) Follow Up Flag: Follow up sumoJUN vvoia Flag Status: Flagged Thanks for the quick reply Victoria. Have a great Memorial Day weekend. --Sam From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, May 25,2018 11:03 AM To:Johnstone,Sam<Sam.Johnstone@conocophillips.com> Subject: Re: [EXTERNAL]RE: CD3-115 SSSV extension request(PTD#209-006) Approval is granted for 14 day extension to acquire data for k valve design.This extension expires on June 8, 2018. Victoria Sent from my iPhone On May 25, 2018,at 10:47 AM,Johnstone,Sam<Sam.Johnstone@conocophillips.com>wrote: Hi Victoria, See the sequence of events since May 10th below: 5/10—the well passed a State witnessed SSSV test and then later that day the SSSV lost control line pressure and was shut-in. 5/11—Pulled the WRDP and opened the well. 5/17—Attempted to set WRDP w/extended packing. Unable to achieve control line integrity. Performed brush and flush. 5/18—Attempted to set WRDP w/extended Frudenberg packing. Unable to achieve control line integrity. 5/19—Brush and flush SSSV nipple. Set WRDP with extended packing(Frudenberg packing on top and Chevron packing on bottom). Obtained control line integrity. Operator to perform closure test on 5/20. Well SI 5/20—Well put on production. Lost control line integrity.SI well. 5/21—Pulled WRDP and brushed and flushed. Set lower quadco packer,WRDP,and upper quadco packer. Obtained good control line integrity. Left well SI until able to monitor. 5/24—Monitored control line pressure while flowing the well. Control line holding solid at 3500 psig. Well left online and plan to State test within five days. As noted,we currently have control line integrity and we will likely test the valve on Sunday 5/27. The approval request from Dana below is in case we have another failure and need to respond quickly to go to the K-valve option. As you know,CD3 is somewhat of a logistical challenge due to not having road • access and also due to weer flight restrictions,so if needed,this approval will allow us to progress getting the K-valve option designed and installed as soon as possible. --Sam From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, May 25,2018 8:20 AM To:Glessner, Dana<Dana.Glessner@conocophillips.com> Cc:Johnstone,Sam <Sam.Johnstone@conocophillips.com> Subject: [EXTERNAL]RE: CD3-115 SSSV extension request(PTD#209-006) What has transpired over the original 14 day period? From:Glessner, Dana<Dana.Glessner@conocophillips.com> Sent:Thursday, May 24,2018 4:35 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Johnstone,Sam<Sam.Johnstone@conocophillips.com> Subject: RE:CD3-115 SSSV extension request(PTD#209-006) Victoria: I will be out of the office tomorrow,would you also please respond to Sam Johnstone (263- 4617)about this well? thanks, Dana Glessner ConocoPhillips Alaska, Inc Petroleum Engineer office (907) 265-1308 Dana.GlessnerPconocophillips.com From:Glessner, Dana Sent:Thursday, May 24, 2018 3:49 PM To: 'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject:CD3-115 SSSV extension request(PTD#209-006) Hello Victoria—we pulled the wireline retrievable SSSV on CD3-115 to troubleshoot loss of hydraulic pressure with slickline and our 14 days without an operable SSSV expires tomorrow(5/25).Our next plan is to run a different type of SSSV called a K-valve that operates with a bellows system similar to a gas lift valve to open and close the valve.A bellows valve is sensitive to the downhole temperature and pressure flowing conditions however. In order for us to properly design the K-valve bellows set point for the SSSV I would like to request a 14 day extension without an operable SSSV to deploy downhole gauges in the tubing, bring the well online, and record tubing pressures and temperatures while varying gas lift rates and choke settings on the tubing.This would give us until 6/8/18 to gather downhole data and run a K-valve downhole. Please let me know if you need more information and if this plan is acceptable. Thank you, Dana Glessner ConocoPhillips Alaska, Inc Petroleum Engineer office (907) 265-1308 Dana.Glessner@conocophillips.com 2 STATE •KA OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATIONS MAY 0 9 2018 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ is (Down ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 209-006 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461' Intermediate 12122' 7" 12156' 6942' Production SCANNED JUN 1 1 2 018 Liner 7534' 4.5" 19564' 6854' Perforation depth Measured Depth: Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' True Vertical Depth: Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD, 6920'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532'MD,6737'TVD SSSV-Camco TRMAXX-5E,2169'MD,2001'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12250'- 19564' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1049 1477 3144 1968 276 Subsequent to operation: 1361 1726 3778 1992 308 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑., Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.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: None Contact Kaylie Plunkett Email Kaylie.B.Plunkett@cop.com Printed Name Kaylie Plunkett Title Production Engineer Signature Phone 265-6450 Date 5- - 261� VT` .o/to /is ° 0 ' RBDMS±MAY 2 4 2018 Form 10-404 Revised 5/2015 Submit Original Only J CD3-115 Scale Inhibition Treatment 4/8/18—4/9/18 Hybrid Scale Inhibitor Squeeze Treatment pumped from 10:48 hrs on 4/8/18 to 10:00 hrs on 4/9/18. LRS = Little Red Services CT= Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA—830/1639/240 - RIH with CT to 19564' RKB - Lay in 290 bbls Diesel/M209/WAW5206 pre-flush through CT at 1.5 bpm while pulling CT from 19564'—12260' RKB. TBG/IA/OA— 1196/1563/226 - RBIH with CT to 19564' RKB - Lay in 290 bbls Seawater and SCW3001 scale inhibitor through CT while pulling CT from 19564'— 12250' RKB. TBG/IA/OA— 1230/1546/246 - POOH with CT. LRS pumped 3080 bbls Dead Crude/M209 over-flush at 1.0—4.0 bpm. TBG/IA/OA— 1426/1581/320 Interval treated: 12250'— 19564' RKB I � RECEIVED STATE OF ALASKA •SKA OIL AND GAS CONSERVATION C ISSION REPORT OF SUNDRY WELL OPERATIONS MAR 2 8 2018 1.Operations Abandon ❑ Plug Perforations H Fracture Stimulate ❑ Pull Tubing ❑ iG idvn ❑ Performed: Suspend ❑ Perforate H Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Run modified WRDP-SSSV❑✓ 2.Operator ConocoPhillips Alaska, Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development Q Exploratory ❑ 209-006-0 3.Address: P.O.Box 100360 Anchorage,AK,99510-0360 Stratigraphic ❑ Service ❑ 6.API Number: 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092,372105,389725,384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461' Intermediate 12122' 7" 12156' 6942' SCANNEV Production Liner 7534' 4.5" 19564' 6854' Perforation depth Measured depth Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' feet True Vertical depth Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' feet Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD, 6920'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532'MD,6737'TVD SSSV-Camco TRMAXX-5E,2169'MD,2001'TVD,locked out(4/28/2009) modified WRDP with NoGo w/PBR installed @ 2169'MD/2001'TVD,with Quadco Packer on top @ 2168'MD/2000'TVD n 12.Stimulation or cement squeeze summary: 10Intervals treated(measured): •yf' Q 03018-Vp!, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1098 1689 3847 1992 321 Subsequent to operation: 1211 1866 4233 1992 279 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas H WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: None Authorized Name:Dana Glessner Contact Name:Dana Glessner Authorized Title:Petroleu Engineer Contact Email: glessd@conocophillips.com Authorized Signature: Date:3/26/2018 Contact Phone: 265-1308 Form 10-404 Revised 4/2017 "TL���G , Submit Original Only . • Date Event Summary SET WRDP (SN: CZS-318) ON MODIFIED NOGO © 2169' RKB, SET QUADCO PACKER ON TOP OF VALVE TO ESTABLISH CONTROL LINE INTEGRITY. DSO PERFORMED 3/2/2018 GOOD CLOSURE TEST. COMPLETE BRUSH & FLUSHED SSSV NIP @ 2169' RKB w/ FULL BORE BRUSH, 2.78" G-RING. PROVED INTEGRITY OF LOWER POLISH BORE IN SSSV NIP w/TEST TOOL. ATTEMPTED TO SET WRDP & K-3 PACKER @ SAME, UNABLE TO GET PACKER TO 3/1/2018 HOLD PRESSURE. IN PROGRESS ATTEMPTED TO SET WRDP ON K-3 PACKER @ 2169' RKB, UNABLE TO ACHIEVE 2/28/2018 CONTROL LINE INTEGRITY. IN PROGRESS SET CATCHER @ 11575' RKB. PULLED 1" OV @ 11444' RKB, VALVE APPEARED TO BE IN GOOD SHAPE AND WORKING, SMALL AMOUNT OF FINE SCALE IN VALVE. SET 2/22/2018 NEW 1" OV (1/4" PORT) @ SAME. PULLED CATCHER @ 11575' RKB. IN PROGRESS PULLED 2.81" WRDP @ 2169' RKB. **UPPER PACKING DAMAGED FROM PULLING & 2/20/2018 SETTING**. IN PROGRESS. SET 3"WRDP (X-LOCK,30.5" SPACER &VLV/2.845"V PACKING BTM (2 0-RINGS) & 2.87" FREUDENBERG PACKING TOP/OAL = 89.5"/S/N: HTS-617) @ 2169' RKB. **PASS FUNCTION TEST**. AFTER WELL BOL, PANEL DUMPED. UNABLE TO PRESSURE 2/19/2018 WRDP BACK UP AND PANEL NEEDS REPAIRS. FP & LEFT SHUT IN. IN PROGRESS. GAUGE TBG TO 2.77" TO 11576' RKB. BRUSH GLM @ 11445' RKB. SET AVA CATCHER @ 11576' RKB. PULLED OV @ 11445' RKB. **NOSE CONE PACKED WITH FINE SCALE***. (BLED IA DOWN 300#TO VERIFY SET). REPLACE WITH NEW 1/4" OV. 2/18/2018 PULLED CATCHER @ 11576' RKB. IN PROGRESS. TROUBLE SHOORTWRDP @ 2169' RKB. SET MULTIPLE CONFIGURATIONS OF PACKING ON WRDP @ 2169' RKB. UNABLE TO GAIN C/L PRESSURE. PULLED VLV. 2/17/2018 FLOW WELL OVERNIGHT. IN PROGRESS. BRUSH & FLUSH X-NIP @ 2169' RKB. SET 2.81"WRDP (LOCK,30.5" SPACER &VLV/ 2.84" PKG ON BTM &2.88" TOP/S/N: HTS-617/ OAL = 90"). WILL RETURN IN AM FOR 2/16/2018 FUNCTION TEST. WELL TO FLOW OVERNIGHT TO WARM UP. CD3-115 WNS PROD 'r- Weil Attributes Max Angle&MD TD Conor"'(�)• "'"i WeiMore APVUWI Field Name Wellb Status Ind(*) MD(11KB) Act 131m(ftKB) Alaska,Inc 501032059300 FIORD NECHELIK PROD 93.81 12,506.79 19,564.0 ennocoPMCtps Comment 62S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... SSSV:WRDP Last WO: 42.70 3/7/2009 HORIZONTAL-003-115 3920184'13:49 PM.. Last Tag vertical ochemasc(aqua) Annotation Depth(ftKB) End Date Last Mod By tripN pi ' Last Rev Reason Annotation End Date Last Mod By 1 1� f.. Rev Reason:PULLED WRDP's,SET WRDP's,PUL&SET OV 3/9/2018 pproven CONDUCTOR,Rc7-0 Reducing: 114.0 ', XO etlucing;114.0 - Casing Description OD(In) ID(In) Top(ftKB) Se!Depth(ftKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Calling Description OD(In) ID(In) .,Top(ftKB) Set Depth(HKB) Set Depth(TVD)...WttLen(I...Grade Top Thread SAFETY VLV:2,169.2 P SURFACE 95/8 8.835 36.2 2,995.0 2,461.1 40.00 L-80 BTCM WRDP:2,169.0 Casing Description OD(In) ID(In) Top(ORB) Set Depth(PRO) Set Depth(TVD)...We/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 34.0 12,156.2 6,941.9 26.00 L-80 BTCM CasIng Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/len(I...Grade Top Thread LINER 41/2 3.958 12,029.9 19564.0 6,853.7 12.60 L-80 IBTM SURFACE.36.2-2,995.0 Liner Details { Nominal ID GAS LIFT,4,879.0 Top(ftKB) Top(TVD)(ftKB) Top Inel(°) hem Des Com (In) 12,029.9 6,914.3 /4.81 SLEEVE "HR"Liner Setting Sleeve5.81"ID(10.13'Inner 5.250 Profile) a=„ 12,042.9 6,917.6 75.31 NIPPLE "RS"Packoff Seal Nipple 5.63"OD X4.26"ID 4,260 12,046.6 6,918.6 75.45 HANGER Baker Flex Lock Uner Hanger 5.91"OD X 4.43"ID) 4.430 GAS LIFT,9.348.9 12,056.4 6,921.0 75.83 XO Reducing XO Bushing-5 1/2"TKC X4 1/2"SLHT(3.93"10) 3.930 15,602.6 6,912.5 88.70 PERE XO 41/2"12.6#L-80X0-41/2"IBT(p)x41/2'SLHT(B) 3.958 -CHANGE FROM(6)1/2"HOLES IN CENTER OF 40'JOINT XO TO PERF PUPS(6)2 1/2"holes per 5' GAS LIFT.11 444.7 pup Joint,alternating with 200'solid pipe sections 16,897.2 6,885.0 90.64 Swell PKR TAM Packer on 18.78'Pup-5,78"OD,3.937"ID, 3.937 PACKER',11,531.6 :'- Element 10.46' ate NIPPLE;11,575.6 ,eiti Tubing Strings Tubing Description String Ma ID(In) Top(MS) Set Depth(ft_.Set Depth(TVD)(..-WI ph/ft) Grade Top Connection SOS 12,015.0TUBING 4.5"x3.5" 3112 2.992 30.9 12,051.0 6,919.7 9.30 L-80 PUP w j Completion Details Tep)TVD) Top incl Nominal WLEG'.120282 ": � Top(ftKB) (ftKB) (°) Bent Des Com ID(in) } 30.9 30.9 0.00 HANGER FMC 41/2"Tbg hanger w/2.32'pup 4.500 114.0 114.0 0.21 XO Reducing XO-41/2"IBTM(8)X31/2"EUE(P) 2.992 2,169.2 2,000.9 45.95 SAFETY VLV Camco TRMAXX-5E SSSV w/2.812"profile HXS-0081(LOCKED 2.812 OUT wNALVE 4/28/2009)FLAPPER LOCKED OUT 11,531.6 6,736.6 63.63 PACKER Baker Premier Packer 5.98"OD x2.87 )0 2.870 INTERMEDIATE:34.0.12156.2- 11,575.6 6,756.1 63.94 NIPPLE HES"XN"NIPPLE W 2.81"POLISH BORE,2.75"NO GO 2.750 12,015.0 6,910.3 74.24 SOS X031(2"9.3#EUE X IBT-nig pupil.W/Shear Pin Fitted No Go 2.990 12,026.2 6,913.3 74.67 WLEG Pup-31/2"IBT Tubing W,Mule shoe WLEG 2.980 Other In Hole(Wireline retrievable plugs,va fi pumpsa fish,etc.) Top(TVD) Top lee( Top(BBB) (ftKB) (') Des Com Run Date ID(Inl 2,168.6 2,000.5 45.93 PACKER QUADCO PACKER w/STINGER(OAL 5.19')TO NGGO 3/2/2018 ON WRDP PERFP;12,268.0-15,142.0 2,169.0 2,000.7 45.94 WRDP WRDP(SN:CZS-318)ON MODIFIED NOGG w/PBR 3/2/2018 1.500 (2.5"PKG,2.6"0-RING,OAL 91.5",G FN) Re"'tttttttt ,ta#ioa 3 ,•. 11111 Shot Dene Top(TVD) Btm(TVD) (shots#t Top(MG) atm(088) (ftKB) (ftKB) Zone Date ) Type Com 12,268.0 15,442.0 6,959.1 6,914.0 NECH-CRSUP, 3/4/2009 6.0 PERFP TOP LINER SECTION:PRE CD3-115 -DRILLED LINER 14 Joints of 40'lengths with(6)1/2" HOLES @ center of EACH 40'Joint,alternating with 200' solid pipe sections 15,648.0 19.433.0 6.914.2 6,861.3 NECH-CRSUP, 3/4/2009 32.0 PERFP LOWER LINER SECTION: CD3-115 PERF PUPS:(6)2 1/2" yg ... holes per 5'pup Joint, alternating with 200'solid pipe sections 114 Mandrel Inserts e se - atl on Top(TVD) Valve Latch Pod Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sem Type Type (in) (pall Run Date Com . � 1 4,879.0 3,390.6 CAMCO KBMG 1 GAS LIFT DMY BKS 0.000 0.0 3/5/2009 1111. 2 9,3.48.9 5,591.2 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.185 2,176.0 8/24/2015 3 11,444.7 6,697.6 CAMCO KBMG 1 GAS LIFT OV BK 0 250 0.0 2/18/2018 III Notes:General&Safety 'p'44 End Date Annotation 00 - 4/1/2009 NOTE:SSSV TRDP failed&Recovery Lock Out Valve set Inside TROP as WRDP lir 4/24/2009 NOTE:VIEW SCHEMATIC w/Alaska Schemaltc9.0 PERFP;15,648.019,133.0 411 M nomi LINER;12,029.9-19,564.0 • STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 2 Exploratory ❑ 209-006 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461 ��Mf� Intermediate 12122' 7" 12156' 6942' Production RECEIVED Liner 7534' 4.5" 19564' 6854' Perforation depth Measured Depth: Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' MAR 0 9 2018 True Vertical Depth: Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' C AO G C Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD, 6920'TVD V Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532'MD,6737'TVD SSSV-Camco TRMAXX-5E,2169'MD,2001'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12268'- 17208' CTMD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 518 949 2025 1571 280 Subsequent to operation: 1263 2245 3900 1991 333 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ DevelopmentL Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPLD Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP LI 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: None Contact Kaylie Plunkett / Ai' SD b7 Email Kaylie.B.Plunkettcop.com Printed Name Kaylie Plunkett Title Production Engineer Signature ��------,,. v VP Phone 265-6450 Date 311- 1 g V7--L 3/1(0 11g 4 770,,,•"" RBDMS t\, c 018 Form 10-404 Revised 5/2015 Submit Original Only CD3-115 Scale Inhibition Treatment 2/10/18—2/11/18 Hybrid Scale Inhibitor Squeeze Treatment pumped from 12:00 hrs on 2/10/18 to 16:30 hrs on 2/11/18. LRS= Little Red Services CT=Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA—253/1988/397 - RIH with CT to 17203' CTMD - Pumped 290 bbls Diesel/M209/WAW5206 pre-flush through CT at 1.3 bpm while pulling CT from 17203'—12268' CTMD. TBG/IA/OA—888/2003/386 - RBIH with CT to 17208' CTMD - Pumped 290 bbls Seawater and SCW3001 scale inhibitor through CT at 1.4 bpm while pulling CT from 17208'—12268'CTMD. TBG/IA/OA—1030/1996/286 - POOH with CT. LRS pumped 3080 bbls dead crude/M209 over-flush at 2.0-4.0 bpm. TBG/IA/OA—1880/2030/425 Interval treated: 12268'—17208' CTMD P7-0 207 - 004 • • Loepp, Victoria T (DOA) From: Mustafin,Ilnur <Ilnur.Mustafin@conocophillips.com> Sent: Wednesday, March 07,2018 3:11 PM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]RE:CD3-115(PTD 209-006) SSSV extension request Follow Up Flag: Follow up Flag Status: Flagged Thanks! We'll do! SCAM Regards, ILNUR From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, March 07, 2018 2:48 PM To: Mustafin, Ilnur<Ilnur.Mustafin@conocophillips.com> Subject: RE: [EXTERNAL]RE:CD3-115(PTD 209-006)SSSV extension request Ilnur, Glad you had success. Please submit a 10-404. Thanx, Victoria From: Mustafin, Ilnur[mailto:llnur.Mustafin@conocophillips.com] Sent:Tuesday, March 06,2018 10:50 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: CD3-115(PTD 209-006)SSSV extension request Hi Victoria, Good news!! CD3-115 modified SSSV was set and successfully function tested last Friday on March 2nd Do you want me to submit Form 10-404? Regards, ILNUR Ilnur Mustafin Production Optimization Engineer ConocoPhillips Alaska Phone: 907-263-4039 Email: ilnur.mustafin@conocophillips.com 1 • • From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent: Friday, March 02,2018 11:25 AM To: Mustafin, Ilnur<llnur.Mustafin@conocophillips.com> Subject: RE: [EXTERNAL]RE:CD3-115(PTD 209-006)SSSV extension request Ilnur, A 7 day extension is granted. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepoalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Mustafin, Ilnur [mailto:Ilnur.Mustafin@conocophillips.com] Sent: Friday, March 02,2018 11:23 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:FW: [EXTERNAL]RE: CD3-115(PTD 209-006)SSSV extension request Hello Victoria, Thank you for your time discussing producer CD3-115(PTD 209-006). I am asking for your permission to extend SSSV clock for additional 7 days due to complications we are having to set a wireline retrievable(WR)SSSV. We had some delays to rig up on the well with the slick line unit due to weather days last week on February 24th and 25th.We have successfully set and pressure tested lower anchor assembly.We had made 2 attempts to set upper packer assembly with no success,but it gave us an additional information how to reconfigure the packing sealing elements of the upper packer assembly. We have a plan to optimize the packing sealing element configuration and successfully set the upper packer assembly. Flowing periods between the attempts will increase our chances for success by keeping the well warm and avoiding debris and sediments to settle in the SSSV profiles. Also,the surface safety valve remains functional. I would like to request an additional 7 days on the SSSV clock to attempt to set the new SSSV configuration and troubleshoot if necessary. Please give me a call to discuss if you need more details. Regards, ILNUR 2 • • Ilnur Mustafin Production Optimization Engineer ConocoPhillips Alaska Phone: 907-263-4039 Email: ilnur.mustafin@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Friday, February 23,2018 10:41 AM. To:Glessner, Dana<Dana.Glessner@conocophillips.com> Subject: [EXTERNAL]RE: CD3-115(PTD 209-006)SSSV extension request Dana, A 7 day SSSV extension is approved to set the new SSSV configuration and troubleshoot as outlined below. Please provide a status update at the end of this extension. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCu�alaska.ciov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.qov From:Glessner, Dana [mailto:Dana.Glessner@conocophillips.com] Sent: Friday, February 23,2018 10:10 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:CD3-115 SSSV extension request Hello Victoria—thank you for your time today to discuss producer CD3-115 (PTD 209-006). I would like to request a 14 day extension to our SSSV clock due to the trouble we are having setting a wireline retrievable(WR)SSSV. The tubing retrievable(TR)SSSV was damaged upon original installation(3/2009)and has never functioned but we still do have control line integrity to surface. However, it also appears that the polished bore of the SSSV was damaged originally which makes setting the WR-SSSV challenging. We pulled the WR-SSSV on 2/9/2018 @ 17:39 in order to do a coil tubing clean out.This is a routine clean out and scale removal job we do each year on CD3-115 when we have ice road access.After the coil job we brought the well back online 2/9/2018 @ 20:39.We have tried to set the WR-SSSV three times with slickline(on 2/16, 2/17,2/19)without success because the damaged polish bore continues to damage the packing on the WR-SSSV when run in hole and we can't get a good seal to the control line.We have slickline on the well again today(2/23)trying again to set the WR-SSSV. 3 • We have developed a plan to have a packer machined specially for this well to set on top of the WR-SSSV,which would set the seals above the damaged polished bore but still give us isolation to the control line and a functioning WR-SSSV. The machined piece will likely be delivered to us by Sunday(2/25).Also,the surface safety valve remains functional. I would like to request an additional 14 days on the SSSV clock to attempt to set the new SSSV configuration and troubleshoot if necessary. Please give me a call to discuss if you need more details. thanks, Dana Glessner ConocoPhillips Alaska, Inc Petroleum Engineer office (907) 265-1308 Dana.Glessner@conocophilligs.com • 4 • • nrD �aq - ooh Loepp; Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, February 23, 2018 10:40 AM To: 'Glessner, Dana' Subject: RE:CD3-115(PTD 209-006) SSSV extension request Follow Up Flag: Follow up Flag Status: Completed Dana, A 7 day SSSV extension is approved to set the new SSSV configuration and troubleshoot as outlined below. Please provide a status update at the end of this extension. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer q� /L,6 State State of Alaska �.p�1�E } Oil&Gas Conservation Commission sb,�'o1® 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov From:Glessner, Dana [mailto:Dana.Glessner@conocophillips.com] Sent:Friday, February 23,2018 10:10 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:CD3-115 SSSV extension request Hello Victoria—thank you for your time today to discuss producer CD3-115 (PTD 209-006). I would like to request a 14 day extension to our SSSV clock due to the trouble we are having setting a wireline retrievable(WR)SSSV. The tubing retrievable(TR)SSSV was damaged upon original installation(3/2009)and has never functioned but we still do have control line integrity to surface. However, it also appears that the polished bore of the SSSV was damaged originally which makes setting the WR-SSSV challenging. We pulled the WR-SSSV on 2/9/2018 @ 17:39 in order to do a coil tubing clean out.This is a routine clean out and scale removal job we do each year on CD3-115 when we have ice road access.After the coil job we brought the well back online 2/9/2018 @ 20:39.We have tried to set the WR-SSSV three times with slickline(on 2/16, 2/17,2/19)without success because the damaged polish bore continues to damage the packing on the WR-SSSV when run in hole and we can't get a good seal to the control line.We have slickline on the well again today(2/23)trying again to set the WR-SSSV. 1 • We have developed a plan to have mocker machined speciallyfor this well to setn topof the WR-SSSV,which would o d set the Seals above the damaged polished bore but still give us isolation to the control line and a functioning WR-SSSV. The machined piece will likely be delivered to us by Sunday(2/25).Also,the surface safety valve remains functional. I would like to request an additional 14 days on the SSSV clock to attempt to set the new SSSV configuration and troubleshoot if necessary. Please give me a call to discuss if you need more details. thanks, Dana Glessner ConocoPhillips Alaska, Inc Petroleum Engineer office (907) 265-1308 Dana.Glessner@conocophillips.com 2 RECO STATE OF ALASKA ALL OIL AND GAS CONSERVATION COM ION /-i!`G 0 1 ?001/ REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 209-006 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461' Intermediate 12122' 7" 12156' 6942' Production 1 2017, Liner 7534' 4.5" 19564' 6854' , e►AlattED NOV�4 U Perforation depth Measured Depth: Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' True Vertical Depth: Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD, 6920'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532' MD,6737'TVD SSSV-Camco TRMAXX-5E, 2169' MD,2001'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12156'- 19564' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 463 1377 1580 1402 310 Subsequent to operation: 440 1244 1558 1407 317 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑] Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.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: None Contact Kaylie Plunkett Email Kaylie.B.Plunkett@cop.com Printed Name Kaylie Plunkett Title Production Engineer Signature / Phone 265-6450 Date '3?- I- 2017 v'Tri- /%/i- - 4'/0!447 RBDMS t_L ONGt - 3 2017 Form 10-404 Revised 5/2015 / Submit Original Only ► y • • CD3-115 Scale Inhibition Treatment 7/2/17 Hybrid Scale Inhibitor Squeeze Job pumped from 10:00 hrs to 20:41 hrs on 7/2/17. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA-1600/1430/360 - LRS pumped 90 bbls diesel/WAW5206 preflush at 1.0—2.0 bpm,TBG/IA/OA-1150/1360/280 - LRS pumped 90 bbls seawater/SCW3001 scale inhibitor treatment at 1.0—2.0 bpm,TBG/IA/OA- 0/1383/278 - ACF pumped 500 bbls diesel overflush at 1.1 bpm,TBG/IA/OA-286/1839/282 Interval treated: 12,156'—19,564' MD ~ STATE OF ALASKA ALO OIL AND GAS CONSERVATION COMMIlik)N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment❑ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory ❑ 209-006 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' ' n U`.. Surface 2959' 9.625" 2995' 2461' SCANNED M 2 5 Ct . Intermediate 12122' 7" 12156' 6942' Production Liner 7534' 4.5" 19564' 6854' RECEIVED C 'V Perforation depth Measured Depth: Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' MAY 16 2017 True Vertical Depth: Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' AOGCC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD, 6920'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532'MD,6737'TVD SSSV-Camco TRMAXX-5E,2169'MD,2001'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12100'- 18046'CTMD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1223 4060 2666 1669 347 Subsequent to operation: 1550 3538 2565 1782 344 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D ExploratoryD Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil D Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: None Contact Kaylie Plunkett Email Kaylie.B.Plunkettancop.com Printed Name Kaylie Plunkett Title Production Engineer Signature �� Phone 265-6450 Date S`- 1 r 17 1 T►- 57i q) i-7- Form 10-404 Revised 5/2015 00 '" 1�7 RBDIIAS \. ►r A"r 0 Submit Original Only • • CD3-115 Scale Inhibition Treatment LRS= Little Red Services CT=Schlumberger Coiled Tubing 4/15/17-4/16/17 Hybrid Scale Inhibitor Squeeze Treatment pumped from 07:00 hrs on 4/15/17 to 06:00 hrs on 4/16/17 - Initial pressure TBG/IA/OA-1100/1600/257 - RIH with CT to 18046' CTMD - Pumped 180 bbls Diesel/M209/WAW5206 pre-flush through CT at .9 bpm while pulling CT from 18046'—12268' CTMD. TBG/IA/OA—1551/1567/245 - RBIH with CT to 17600' CTMD - Pumped 180 bbls Seawater and SCW3001 scale inhibitor through CT at 1.0 bpm while pulling CT from 17600'—12100'CTMD. TBG/IA/OA—1648/1504/246 - POOH with CT. LRS pumped 1301 bbls dead crude/M209 over-flush at 1.0—3.25 bpm. TBG/IA/OA—1100/1490/280 Interval treated: 12100'—18046' CTMD STATE OF ALASKA RECEIVED ALO OIL AND GAS CONSERVATION COMMON MAR 13 2017 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I=1Plug Perforations ElFracture Stimulate ❑ Pull Pull AT ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor TreatmentL 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 209-006 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst "" ,Hapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461' Intermediate 12122' 7" 12156' 6942' Production Liner 7534' 4.5" 19564' 6854' SCANNED r:� ; I4 of Perforation depth Measured Depth: Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' True Vertical Depth: Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD, 6920'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532'MD,6737'TVD SSSV-Camco TRMAXX-5E,2169'MD,2001'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 15530'- 17271'CTMD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 551 4513 1636 1438 359 Subsequent to operation: 1603 5287 2654 1853 427 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil CI Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: None Contact Kaylie Plunkett Email Kaylie.B.PlunkettCcr�cop.com Printed Name Kaylie Plunkett Title Production Engineer Signaturek--gtettco265-6450 Date 3-9-2617 V77... 3/z8/j 7_' ,0370 7 S �; ,7 RSDIJI \,�/ E�,,,R k 2 to i/ Form 10-404 Revised 5/2015 Submit Original Only • • CD3-115 Scale Inhibition Treatment LRS= Little Red Services CT=Schlumberger Coiled Tubing 2/13/17—2/14/17 Hybrid Scale Inhibitor Squeeze Treatment pumped from 13:54 hrs on 2/13/17 to 09:30 hrs on 2/14/17 - Initial pressure TBG/IA/OA-1000/2038/372 - RIH with CT to 17271' CTMD - Pumped 180 bbls Diesel/M209/WAW5206 pre-flush through CT at 1.45 bpm while pulling CT from 17221'—12200' CTMD. TBG/IA/OA—912/1950/361 - RBIH with CT to 17000' CTMD - Pumped 90 bbls Seawater and SCW3001 scale inhibitor through CT at 1.5 bpm while pulling CT from 17000'—9430' CTMD. TBG/IA/OA—1267/1869/291 - POOH with CT. LRS pumped 1301 bbls dead crude/M209 over-flush at 2.61—3.08 bpm. TBG/IA/OA—1350/1663/266 Interval treated: 12156'—17221' CTMD STATE OF ALASKA AlkA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 209-006 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532-- e'f e{ --- true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' 4 2016 Surface 2959' 9.625" 2995' 2461' SCp�µE JUN 2 Intermediate 12122' 7" 12156' 6942' Production RECEIVED Liner 7534' 4.5" 19564' 6854' APR 14 2016 Perforation depth Measured Depth: Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' C True Vertical Depth: Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' ®GC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD, 6920'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532' MD, 6737'TVD SSSV-Camco TRMAXX-5E, 2169'MD, 2001'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12156'- 15530' CTMD and 15530'- 18578' CTMD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1880 4342 2726 1960 388 Subsequent to operation: 1879 5300 3221 1945 399 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: None Contact Kerry Freedman Email Kerry.C.Freedman@co•.com Printed Name Kerry Freedman n Title Principal Production Engineer Signature �nA..... t. Phone 265-6579 Date yI J y 1 Vit.-- 671//11 o Form 10-404 Revised 5/2015 0 5— (U RBDMS Li- APR 1 4 2016 Submit Original Only • • CD3-115 Scale Inhibition Treatment LRS = Little Red Services CT=Schlumberger Coiled Tubing 3/13/16—3/14/16 Non-Aqueous Scale Inhibitor Squeeze Treatment—Stage 1 pumped from 15:30 hrs on 3/13/16 to 15:30 hrs on 3/14/16 - Initial pressure TBG/IA/OA—1689/1926/241 - RIH with CT to 18122' CTMD - Pumped 145 bbls Diesel/M209/WAW5206 pre-flush through CT at 0.2- 1.5 bpm while pulling CT from 18122'—15530' CTMD. TBG/IA/OA—1593/1894/220 - RBIH with CT to 18578' CTMD - Pumped 145 bbls 70/30 EG/Water and SCW3001 scale inhibitor through CT at 1.5 bpm while pulling CT from 18578'—15530' CTMD. TBG/IA/OA—1583/1893/240 - POOH with CT. LRS pumped 1680 bbls dead crude/M209 over-flush at 1.5 bpm. TBG/IA/OA— 1123/1829/1231 Interval treated: 15530'—18578' CTMD 3/15/16—3/16/16 Non-Aqueous Scale Inhibitor Squeeze Treatment—Stage 2 pumped from 09:57 hrs on 3/15/16 to 01:30 hrs on 3/16/16 - Initial pressure TBG/IA/OA—956/1850/250 - RIH with CT to 15530' CTMD - Pumped 145 bbls Diesel/M209/WAW5206 pre-flush through CT at 1.5 bpm while pulling CT from 15530'—12156' CTMD. TBG/IA/OA—1102/1766/200 - RBIH with CT to 15530' CTMD - Pumped 145 bbls 70/30 EG/Water and SCW3001 scale inhibitor through CT at 1.5 bpm while pulling CT from 15530'—12156' CTMD. TBG/IA/OA—1148/1770/205 - POOH with CT. LRS pumped 1680 bbls dead crude/M209 over-flush at 1.5-4.2 bpm. TBG/IA/OA—1570/1800/290 Interval treated: 12156' - 15530' CTMD WNS PROD • CD3-115 ConocUr111lhips 1.n Well Attributes Max Angle&MD TD ,. t Wellbore API/UWI Field None Wellbore Statue ilnel(°) MD(ftKB) Act Elm(ftKB) Alaska.Inc. 3.' 501032059300 FIORD NECHELIK PROD 93.81 12,506.79 19,564.0 i tworeselelnc ... Comment 1125(ppm) Date Annotation End Date KB-Grd(N) Rig Release Date HORIZONTAL CD3-115,3/19201612:5957 PM SSSV:WRDP Last WO: 42.70 3/7/2009 Vertical schematic( 1 al) Annotation Depth(ItKB) End Date Annotation Last Mod By End Date HANGiELast Ta Rev Reason:RESETWRDP pproven 3/19/2016 Casing Strings i' Casing Description OD(In) ID(In) Top(ftKB) Set Depth(WE) Set Depth(TVD)...Wt/Len(I...Grade Top Thread N; "y+ ua4.CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKE) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 137.0-11,0 . SURFACE 95/8 8.835 36.2 2,995.0 2,461.1 40.00 L-80 BTCM XO Reducing 114.0 , di Caning Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...WI/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 34.0 12.156.2 6,941.9 26.00 L-80 BTCM SAFETY VLV;7,189,2 Carie DescriptionOD Ire ID(In To ftKB Set Depth ftKB Set Depth(TVD)...'WffLen I Grade TopThread WRDP:7.169.7 ' ,.. 9 ( ) ) P( ) P ( ) Pt (... LINER 4 1/2 3.958 12.029.9 19,564.0 6,853.7 12.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(IVO)(11KB) Top Incl(') hem Des Com (In) SURFACE;362-2,995D� ( 12,029.9 6.914.3 74.81 SLEEVE "HR"Liner Setting Sleeve 5.81"ID(10.13'Inner 5.250 Profile) GAS LIFT,4,879.0 12,042.9 6.917.6 75.31 NIPPLE "RS"Packoff Seal Nipple 5.63"OD X4.26"ID 4.260 12,046.6 6.918.6 75.45 HANGER Baker Flex Lock Liner Hanger 5.91"OD X 4.43"ID) 4.430 12,056.4 6,921.0 75.83 XO Reducing XO Bushing-5 1/7 TKC X 4 1/2'SLHT(3.93"ID) 3.930 GAS LIFT',9.348.9 15,602.6 6,912.5 88.70 PERF XO 4 1/2"12.6 k L-80 XO-4 1/2"181(p)x 4 1/2"SLHT(B) 3.958 -CHANGE FROM(6)1/7 HOLES IN CENTER OF 40'JOINT XO TO PERF PUPS(6)2 1/2'holes per 5' pup Joint,afernating with 200'solid pipe sections GAS LIFT:.11.444.7 PACKER11,531.6 III 16,897.2 6,885.0 90.64 Swell PKR TAM Packer on 18.78'Pup-5.78"OD;3.937"ID. 3.937 `•- Element 10.46' '. Tubing Strings NIPPLE;11,575.6milli-Pi Tubing Description String Ma...ID(In) Top(11KB) Set Depth(ft...Set Depth(TVD)(...WI(Ib/It) Grade Top Connection ral TUBING 4.5"x3.5" 3)12 2.992 30.9 12,051.0 6,919.7 9.30 L-80 EUE sos.12.915.9 Completion Details i.IF U: Nominal ID IFII , (ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (In) WLEG,12,028.2 .. 30.9 30.9 0.00 HANGER FMC 4 1l2"Tbg hanger w/2.32'pup 4.500 114.0 114.0 0.21 X0 Reducing XO-4 1/2"IBTM(B)X 3 1/2'EUE(P) 2.992 2,169.2 2,000.9 45.95 SAFETY VLV Cameo TRMAXX-SE SSSV w/2.812"profile HXS-0081 2.812 (LOCKED OUT w)VALVE 4/28/2009)FLAPPER LOCKED OUT 11,531.6 6,736.6 63.63 PACKER Baker Premier Packer 5.98"OD x 2.87"ID 2-870 INTERMEDIATE;34.0-12.158.2- 11,575.6 6,756.1 63.94 NIPPLE HES-XN"NIPPLE W 2.81"POLISH BORE,2.75"NO GO 2.750 12,015.0 6,910.3 74.24 SOS XO 3 1/7 9.36 EUE X IBT-Tbg pup jt W/Shear Pin 2.990 Feted No Go : [ 12,026.2 6,913.3 74.67 WLEG Pup-31/2"IBT Tubing W/Mule shoe WLEG 2.980 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top incl - Top(11KB) (ftKB) (') Des Corn Run Date ID(In) - Ei 2.169.2 2.000.9 45.95'WRDP WRDP(S/N=C148-1074.30.5'SPACER,2.84" 3/18/2016 1.500 UPPER PACKING,2.88"DBL 0-RING LOWER PERFP;12,268.0-15,442.0 PACKING)NO GO TO CENTER OF BOTTOM PACKING STACK Perforations&Slots F Shot Deni r Top(TVD) Btm(TVD) (snoterc Top(ftKB) Btm(11KB) (ftKB) (ftKB) Zone Date t) Type Corn r' 12.268.0 15.442.0 6,959.1 6,914.0 NECH- 3/4/2009 6.0 PERFP TOP LINER SECTION: CRSUP,CD3- PRE-DRILLED LINER 115 14 joints of 40'lengths 1 with(6)1/7 HOLES 6 center of EACH 40'joint, alternating with 200' solid pipe sections 15,648.0 19,433.0 6,914.2 6,861.3 NECH- 3/4/2009 32.0 PERFP LOWER LINER . CRSUP,CD3- SECTION;PERF PUPS: 115 (6)2 1/2"holes per 5' pup Joint,alternating with ME 200'solid pipe sections Ft' Mandrel Inserts i St all NM an Top(TVD) Valve Latch Pod Sloe TRO Run U N Top(ftKB) (11KB) 1 4,879.0 3,390.6 CAMCO Make KBMGModel 00(In) Sery Type Type (In) (psi) Run Date Com 1 GAS LIFT DMY BK-5 0.000 0.0 3/5/2009 m. 2 9,348.9 5,591.2 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.185 2,176.0 8/24/2015 ■ 3 11,444.7 6,697.6 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 8/23/2015 ri Notes:General&Safety MN €i, End Dale Annotation i 4/1/2009 NOTE:SSSV TRDP failed 8 Recovery Lock Out Valve set inside TROP as WRDP it PERFP;15,648.0-19,433.01 4/24/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 4 - I III. 44. • i - El 44 MI LINER;12,029.9-19.564.0 • • PTD a oq �oo� Loepp, Victoria T (DOA) From: Freedman, Kerry <C ker .c.freedman@conoco hilli s.com> ►Y P P Sent: Thursday, March 10, 2016 8:09 AM To: Loepp,Victoria T (DOA) Subject: RE: CD3-115 SSSV 14 day Extension Follow Up Flag: Follow up Flag Status: Flagged Thanks Victoria. We hope the weather will cooperate, but what is the best way to communicate_onSunday 3/13 if we need to? Regards, Kerry Freedman SCAB APR 2 1 2016 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, March 10, 2016 7:47 AM To: Freedman, Kerry C<kerry.c.freedman@conocophillips.com> Subject: [EXTERNAL]CD3-115 SSSV 14 day Extension Kerry, Approval is granted to continue to flow the well for 3 additional days without the ScSSV installed (until March 13`h) Please contact the Commission if further delays are experienced. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loenpaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Freedman, Kerry C [mailto:kerry.c.freedman@conocophillips.com] Sent: Wednesday, March 09, 2016 5:06 PM To: Loepp, Victoria T(DOA); Schwartz, Guy L (DOA) Cc: Johnstone, Sam Subject: RE: [EXTERNAL]RE: CD3-115 SSSV 14 day Extension Victoria/Guy, 1 • • We are still staged at the well ready to resume operations to set the SSSV when the weather permits, but are currently still unable to rig up due to continuing high winds. Can we get an extension to continue to flow the well while waiting on winds to die down? Thanks and regards, Kerry C. Freedman WNS Production Engineer ConocoPhillips Alaska, Inc. 700 G Street,ATO 1750 Anchorage,Alaska 99501 El Email: kerry.c.freedman@conocophillips.com W Phone: 907.265.6579 1E Fax: 918.662.6088 From: "Schwartz, Guy L (DOA)" <guy.schwartz@alaska.gov> Date: March 7, 2016 at 2:40:57 PM AKST To: "Johnstone, Sam" <Sam.Johnstone�c conocophillips.com> Cc: "Loepp, Victoria T (DOA)" <victoria.loepp(aialaska.gov> Subject: [EXTERNAL]RE: CD3-115 SSSV 14 day Extension Sam, Approval granted to continue to flow well for additional 3 days without ScSSV installed (until March 10`h). If weather continues to delay installation past this date contact the Commission. 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). From: Johnstone, Sam [mailto:Sam.Johnstone@@conocophillips.com] Sent: Monday, March 07, 2016 1:32 PM To: Schwartz, Guy L (DOA) Subject: FW: CD3-115 SSSV 14 day Extension From: Johnstone, Sam Sent: Monday, March 07, 2016 8:51 AM To: 'victoria.loepp@)alaska.gov' Subject: CD3-115 SSSV 14 day Extension Victoria, 2 • • This morning we are reaching the 14 day timeline for the CD3-115 and request an extension. As you can see below we pulled the SSSV on February 22 to perform a coiled tubing scale mill job,then flowed the well for a number of days with the intent to equalize pressures in the horizontal well prior to performing the scale squeeze. Since last Thursday we have been trying to rig up on CD3-115 to set the SSSV, but have been unable to rig up slickline on the well due to high winds. Can we get an extension to continue to flow the well while we are waiting on winds to die down. I will give you a call to discuss. Thanks, Sam CD3-115 Remedial Operations February—March 2016 2/22/16 Pull WRDP SSV in preparation for coiled tubing operations(2/22+ 14 days= March 7) 2/23/16 Rig up coiled tubing unit. Function test BOPs. Work on inner reel valve. 24/16 RIH with scale blasting BHA on coiled tubing. Wash down in liner, hit hard tag at 14,448'CTMD. POOH to get milling BHA. 25/16 RIH with mill/motor assembly. Mill through multiple locations from 14,400' CTMD to lockup at 18,907' CTMD. POOH. 26/16 RIH with CT,tag landing nipple at 11,576' RKB for depth reference. RIH with scale blasting BHA, clean out liner to 18,790' CTMD. POOH. 27-2/28/16 Flowback to clean up well prior to CT scale squeeze operations 29/15 Delay CT scale squeeze to allow pressures to equalize along the wellbore. 4/16 Plan to install safety valve on 3/5/16,weather permitting 5/16 Plan to install safety valve 3/5/16 afternoon,weather permitting 6/15 Travel to CD3-115 to install safety valve after finishing tag in WD-02 (2.5 hours). (Had been in position on hold for WD-02 tag). Winds 40+MPH. Return to office,waiting on weather. 7/15 Waiting on weather. Sam Johnstone Office (907) 263-4617 Mobile (907) 632-7034 Home (907) 746-5809 3 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMSION REPORT OF SUNDRY WELL OPERATIONS 0 q201 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ e • utdown ❑ Performed: Suspend ❑ Perforate Et Other Stimulate ❑ Alter Casing ❑ = • rogram ❑ Plug for Redrill El Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment El 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 209-006 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092, 372105, 389725, 384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs measured None feet true vertical 6854 feet Junk measured None feet Effective Depth measured 19564 feet Packer measured 11532 feet true vertical 6854 feet true vertical 6737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2959' 9.625" 2995' 2461' Intermediate 12122' 7" 12156' 6942' Production siCA NEVE—- r� Liner 7534' 4.5" 19564' 6854' L� !� �' d, Perforation depth Measured Depth: Pre-Drilled Liner 12268'- 15442', Perf Pups 15648'- 19433' True Vertical Depth: Pre-Drilled Liner 6959'-6914', Perf Pups 6914'-6861' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12051' MD and 6920'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 11532'MD and 6737'TVD SSSV-Camco TRMAXX-5E, 2169'MD and 2001'ND, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12156'- 19564' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 808 1675 1866 1580 300 Subsequent to operation: 798 2654 1779 1586 313 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: None Contact Kerry Freedman Email Ker,y.C.Freedman(a�cop.com Printed Name Ker Freedman Title Principal Production Engineer Signature Phone 265-6579 Date a/3pc" r VII- 12/Z3/ir ,4,2/2,? RBDMS'1 C 0 3 2015 Form 10-404 Revised 5/2015 Submit Original Only • • CD3-115 Scale Inhibition Treatment 11/8/2015 Non-Aqueous Scale Inhibitor Squeeze Job pumped 11/8/15 from 11:42—23:25 hrs. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—304/1572/403 - LRS pumped 90 bbls WAW5206/Diesel pre-flush at 1-2 bpm,TBG/IA/OA—1300/1641/245 - LRS pumped 90 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 1.8 bpm,TBG/IA/OA—1300/1520/204 - ACF pumped 500 bbls Diesel over-flush at 1.1 bpm,TBG/IA/OA—227/1950/337 Interval treated: 12,156'—19,564' - r WNS PROD11110 CD3-115 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,11100 • Wellbore APUUWI Field Nome Wellbore Status ncl(°) MD(OK I3) Act atm(WB) c y.oreplyHns 501032059300 FIORD NECHELIK PROD 93,81 12,506.79 19564.0 ••• Comment H25(ppm) Date Annotation End Date KB•Grd(ft) Rig Release Date HORIZONTAL-CD3-115.102920-15 10'40:37 AM SSSV:WRDP Last WO: 42.70 3/7/2009 vertical schematic(ecty i Annotation Depth(MOB) End Data Annotation Last Mod By End Date -_ HANGER 30,9 7 Last Tow Rev Reason:GLV C/O,RESET WRDP pproven 10,29/2015 Casing Strings W u Casing Description OD(In) ID(In) Top(NCB) Set Depth(CM) Set Depth(TVD)...Wt/Len(I...Grade Top Thread m 4 CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded 'I auu Casing Description OD(In) ID(in) lop(ftKB) Set Depth(ttK8) Set Depth(TVD)...WULen p...Grade Top Thread CONDUCTOR:37.0-114,0 SURFACE 95/8 8.835 36.2 2,995.0 2,461.1 40.00 L-80 BTCM XO Reducing;114.0 Casing Description OD(Int ID(In) Top(ftK8) Set Depth(MB) Set Depth(TVD)...WULen p...Grade Top Thread SAFETY VLV;2,ifi9a INTERMEDIATE 7 6.276 34.0 12,156.2 6,941.9 26.00 L-80 BTCM i 4+--:'i CasingDescription OD 1 IDTop(MB) Set Depth ftKB Set Depth(ND WULen(I...Grade TopThread WRDP;2,169.2, ce, Pon (n) (in) 12029.9) Pt ( ) Pt (TVD)... 12.60 LINER 4 112 3.958 19,564.0 6,853.7 L-80 IBTM Liner Details Nominal ID {j Top(11103) Top(ND)(1100) Top Incl(°) Sem Das Com (in) SURFACE;36.2-2,985.0 ` 12,029.9 6,914.3 74.81 SLEEVE "HR"Liner Setting Sleeve 5.81"ID(10.13'Inner 5.250 Profile) GAS LIFT;4,679.0 12,042.9 6,917.6 75.31 NIPPLE "RS"Packoft Seal Nipple 5.63"OD X4.26"ID 4.260 12,046.6 6,918.6 75.45 HANGER Baker Flex Lock Liner Hanger 5.91"OD X 4.43"ID) 4.430 1 12,056.4 6.921.0 75.83 XO Reducing XO Bushing-5 1/7 TKC X4 1/7 SLIT(3.93"ID) 3.930 GAS LIFT:93ae.e 15,602.6 6,912,5 88.70 PERF XO 4 1/2"12.6 it L-80 XO-4 1/2"IBT(p)x4 1/2"SLHT(B) 3.958 -CHANGE FROM(6)1/2'HOLES IN CENTER OF 40'JOINT XO TO PERF PUPS(6)2 1(7 holes per 5' pup Joint,alternating with 200'solid pipe sections GAS LIFT:11.444.7 16,897,2 6,885.0 90.64 Swell PKR TAM Packer an 18.78'Pup-5,78"OD,3.937"ID. 3.937 Element 10.46' PACKER:11,531.6 III Tubing Strings NIPPLE;11,575.8 Tubing Description String Ma...ID(in) Top(WE) Set Depth(ft..-Set Depth(TVD)(...WI(Ib/It) Grade Top Connection TUBING 4.5"x3.5" 31/2 2.992 30.9 12.051.0 6.919.7 9.30 L-80 EUE sos:12,015.0 Completion Details -v.'_- -j Nominal ID Top(NKB) Top(TVD)(MB) Top Incl 1") Item Des Com (in) WLEG:12.026.2 30.9 30.9 0.00 HANGER FMC 41l2"Tbg hanger w/2.32'pup 4.500 i • 114.0 114.0 0.21 XO Reducing XO-41/2'IBTM(B)X 31/7 EUE(P) 2.992 I 2,169.2 2,000.9 45.95 SAFETY VLV Camco TRMAXX-5E SSSV w/2.812"profile HXS-0081 2.812 (LOCKED OUT wNALVE 4/28/2009)FLAPPER LOCKED OUT 11,531.6 6,736.6 63.63 PACKER Baker Premier Packer 5.98"OD x 2.87"ID 2.870 INTERMEDIATE;34.0-12,158.2-- 11,575.6 6,756.1 63.94 NIPPLE HES"XN"NIPPLE W 2.81"POLISH BORE,2.75"NO GO 2750 I- 12,015.0 6,910.3 74.24 SOS X031/79.36 EUE X IBT-Tbg pup jt W/Shear Pin 2.990' r}. Futed No Go T 12,026.2 6,913.3 74.67 WLEG Pup-31/2'IBT Tubing W/Mule shoe WLEG 2.980 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top mel Top UM El) (NKB) (°) Des Com Run Date ID(In) • 2.169.2- 2,000.9 45.95 WRDP 2.81"WRDP-1 (SN C145-1074)2.82'PACKING 10/16/2015 • 1.500 OAL=89,5":36.5"NO GO TO CENTER OF BOTTOM PERFP;12,268.0-15.442.0 PACKING STACK 1 Perforations&Slots 1 Shot Dens TopBt(f(TVD) (shotsd Top(RNB) etm(ftKB) (NKE)KB) {ftKB1)) Zone Date i) Type Com 1 [ 12,268,0 15,442.0 6,959.1 6,914.0 NECH- 3/4/2009 6.0 PERFP TOP LINER SECTION: CRSUP,CD3- PRE-DRILLED LINER - F 115 14 joints of 40'lengths with(6)1/7 HOLES C center of EACH 40'joint, --r alternating with 200' solid pipe sections 15,648.0 19,433.0' 6,914,2 6,861.3 NECH- 3/4/2009 32.0 PERFP LOWER LINER CRSUP,CD3- SECTION:PERF PUPS: �,., - 115 pup Joint,afe holes with 2 P1 9 200'solid pipe sections 44 if Mandrel Inserts si Ill at! 11 - onN Top(TVD) Valve Latch Pod Size TRO Run Top(MB) (ftKB) Make Model OD(in) Sery Type Type (In) (pal) Run Date Com ri - 1 4,879.0 3,390.6 CAMCO KBMG 1 GAS LIFT DMY BKS 0.000 0,0 3/5/2009 - s 2 9,348.9 5,591.2 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.185 2,176.0 8/24/2015 3 11,4447 6,697.6 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 8/23@015 IIINotes:General&Safety 11111 End Date Annotation .44 4/1/2009 NOTE:SSSV TRDP failed 8 Recovery Lock Out Valve set inside TRDP as WRDP i 4/24/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PERFP;15,648.0-19,433.0 Mil 37' - On ME tit IIIM . IN 11 NM IIMI 111: - LINER:12.029,919.564.0 STATE OF ALASKA AL,,,.,KA OIL AND GAS CONSERVATION CON. JSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther Scale Inhibitor Alter Casing r Pull Tubing r Stimulate-Frac Waiverr, Treatment � r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development Exploratory r 209-006 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20593-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380092,372105,389725,384215 CRU CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11 Present Well Condition Summary. Total Depth measured 19564 feet Plugs(measured) none true vertical 6854 feet Junk(measured) none Effective Depth measured 19564 feet Packer(measured) 11532 true vertical 6854 feet (true vertical) 6737 Casing Length Size MD TVD Burst Collapse Conductor 77 16" 114 114 Surface 2959 9 625" 2995 2461 Intermediate 12122 7" 12156 6942 Liner 7534 4 5" 19564 6854 RE C F...WED Perforation depth: Measured depth. pre-drilled liner 12268'-15442', perf pups 15648'-19433' MAY 0 7 2015 True Vertical Depth: 6959'-6914',6914'-6861' .A0GCC Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 12051 MD,6920 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 11532 MD and 6737 TVD SSSV-CAMCO TRMAXX-5E @ 2169 MD and 2001 TVD ' 12 Stimulation or cement squeeze summary Intervals treated(measured): 12156-13980, and 13980-16667.5 Treatment descriptions including volumes used and final pressure. see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1721 1293 2854 1957 329 Subsequent to operation 1837 1558 2716 1957 334 14.Attachments 15.Well Class after work. Copies of Logs and Surveys run Exploratory r- Development r Service r Stratigraphic r 16 Well Status after work Oil Jd Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ JJ SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt. none Contact Kerry Freedman Cad 265-6579 Email Kerry.C.Freedmantcr conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature I Phone: 265-6579 Date 5- // I J A.A v rL 5/,z//5 ��aY 4 015 RBDMS MAY 1 1 2015 IA i'97 Sca►g° Form 10-404 Revised 10/2012 Submit Original Only CD3-115 Scale Inhibition Treatment 4/8/15—4/9/15 Non-Aqueous Scale Inhibitor Squeeze Treatment-Stage 1 pumped 4/8/15,02:30—4/9/15 10:00 hrs - Initial pressure TBG/IA/OA—700/1886/539 - RIH with coiled tubing to 16,667.5' CTMD. - Pumped 135 bbls of Diesel/M209/WAW5206 pre-flush through CT at 1.2 bpm while pulling CT from 16,667.5'— 13,980'CTMD.TBG/IA/OA—545/1976/216 - Run back in with coiled tubing to 16,667.5' CTMD. - Pumped 135 bbls of 70/30 EG/Water and SCW3001WC scale inhibitor through CT at 1.5 BPM while pulling from 16,667.5'—13,980' CTMD.TBG/IA/OA—683/1953/195 - POOH with CT. LRS pumped 1424 bbls dead crude/M209 overflush at 3-4.25 BPM.TBG/IA/OA— 1520/1981/191 Interval Treated: 13,980'—16,667.5' CTMD 4/10/15 Non-Aqueous Scale Inhibitor Squeeze Treatment-Stage 2 pumped 4/10/15,04:15—4/11/15 01:00 hrs - Initial pressure TBG/IA/OA—740/587/94 - RIH with coiled tubing to 13,980' CTMD. - Pumped 135 bbls of Diesel/M209/WAW5206 pre-flush through CT at 1.3—1.5 bpm while pulling CT from 13,980'—12,156'CTMD.TBG/IA/OA—915/1733/193 - Run back in with coiled tubing to 12,156' CTMD. - Pumped 135 bbls of 70/30 EG/Water and SCW3001WC scale inhibitor through CT at 0.8- 1.3 BPM while pulling from 13,980'—12,156' CTMD.TBG/IA/OA—894/1733/208 - POOH with CT. LRS pumped 1424 bbls dead crude/M209 overflush at 2-2.5 BPM.TBG/IA/OA— 1500/1710/240 Interval Treated: 12,156' - 13,980' CTMD LRS—Little Red Services CT—Schlumberger Coiled Tubing E WNS PROD CD3-115 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl('1 MD(ftKB) Act Btm(ftKB( czerocvnr,,,, 501032059300 FIORD NECHELIK PROD 93.81 12,506.79 19,564.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-CD3-115,4/22/20153:13.40 PM SSSV:WRDP Last WO: 42.70 3/7/2009 Vertical schematic(actual) -Annotation Depth(ftKB( End Date Annotation Last Mod By End Date HANGER,30.9- 41" Last Tag: Rev Reason:RESET WRDP lehallf 4/22/2015 som Casing Strings ill :r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB( Set Depth(TVD)...Wt/Len(I...Grade Top Thread • CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...'Grade Top Thread CONDUCTOR;37.4-114.0 SURFACE 95/8 8.835 36.2 2,995.0 2,461.1 40.00 L-80 BTCM XO Reducing;114.0 7 CasingDescription OD(in) ID(in) To ftKB Set Depth ftKB Set Depth)T/D)...Wt/Len(I...Grade Top Thread P< PI ) p (ftKB) SAFETY VLV;2.169.2s, .. . INTERMEDIATE 7 6.276 34.0 12,156.2 6,941.9 26.00 L-80 BTCM WRDP;2,159.2 _- Casing Description OD(in) 'ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 12,029.9 19,564.0 6,853.7 12.60 L-80 IBTM Liner Details Nominal ID Top(MB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) SURFACE;36.2-2,995.0-ss 12,029.9 6,914.3 74.81 SLEEVE "HR"Liner Setting Sleeve 5.81"ID(10.13'Inner 5.250 Profile) GAS LIFT;4.879.0 12,042.9 6,917.6 75.31 NIPPLE "RS"Packoff Seal Nipple 5.63"OD X 4.26"ID 4.260 12,046.6 6,918.6 75.45 HANGER Baker Flex Lock Liner Hanger 5.91"OD X 4.43"ID) 4.430 12,056.4 6,921.0 75.83 X0 Reducing X0 Bushing-5 1/2"TKC X 4 1/2"SLHT(3.93"ID) 3.930 GAS LIFT;9.348.8 : 15,602.6 6,912.5 88.70'PERF X0 41/2"12.68L-80X0-41/2"IBT(p)x41/2"SLHT(B) 3.958 -CHANGE FROM(6)12"HOLES IN CENTER OF 40'JOINT XO TO PERF PUPS(6)2 1/2"holes per 5' pup joint,alternating with 200'solid pipe sections GAS LIFT;11,444.7 16,897.2 6,885.0 90.64 Swell PKR TAM Packer on 18.78'Pup-5.78"OD,3.937"ID, 3.937 Element 10.46' PACKER;11,531.6 :. _ Tubing Strings NIPPLE;11,575.6 Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft..Set Depth(ND)C..Wt(Ib/(I) Grade Top Connection TUBING 4.5"x3.5" 31/2 2.992 30.9 12,051.0 6.919.7 9.30 L.80 EUE SOS;12,015.0 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl El Item Des Com (in) WLEG;120262 • - 30.9 30.9 0.00 HANGER FMC 4 1/2"Tbg hanger w/2.32'pup 4.500 114.0 114.0 021 XO Reducing XO-4 1/2"IBTM(B)X 3 1/2"EUE(P) 2.992 2,169.2 2,000.9 45.95 SAFETY VLV Camco TRMAXX-5E SSSV w/2.812"profile HXS-0081 2.812 (LOCKED OUT wNALVE 428/2009)FLAPPER LOCKED OUT 11,531.6 6,736.6 63.63 PACKER Baker Premier Packer 5.98"OD x2.87"ID 2.870 INTERMEDIATE;34.0.12.756.2 11,575.6 6,756.1 63.94 NIPPLE HES"XN"NIPPLE W 2.81"POLISH BORE,2.75"NO GO 2.750 12015.0 6,910.3 74.24 SOS XO 3 12"9.38 EUE X IBT-Tbg pup jt.W/Shear Pin 2.990 Fated No Go 12,026.2 6.913.3 74.67 WLEG Pup-3 1/2"IBT Tubing W/Mule shoe WLEG 2.980 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc-) Top(ND( Top Incl Top(ftKB) (ftKB) ("I Des Com Run Date ID(in) 2,169.2 2,000.9 45.95 WRDP 2.81"WRDP-1 (SN HTS-611)2.82 PACKING 4/11/2015 1.500 OAL=89.5";36.5"NO GO TO CENTER OF BOTTOM PERFP;12268.0.15,442.0 j, PACKING STACK ILPerforations&Slots LI- Shot Dens Top(ftKB) Wm(ftKB) Top ftKB) B(flKB�) Zone Date (shtt) Type Com 12,268.0 15,442.0 6,959.1 6,914.0 NECH- 3/4/2009 6.0 PERFP TOP LINER SECTION: CRSUP,CD3- PRE-DRILLED LINER 115 14 joints of 40'lengths with(6)1/2"HOLES @ center of EACH 40'joint, alternating with 200' solid pipe sections 15.648.0 19.433.0 6.914.2 6,861.3 NECH- 3/4/2009 32.0 PERFP LOWER LINER CRSUP,CD3- SECTION:PERF PUPS: 115 (6)2 12"holes per 5' pup joint,alternating with MN200'solid pipe sections Mandrel Inserts Br St ctrl I I on Top(TVD) Valve Latch Port Size TRO Run I 8 N Top(ftKB)KB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Co . 1 4,879.0 3,390.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/5/2009 2 9,348.9 5,591.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/5/2009 ll Notes: 11 444.7 6,697.6 CAMCO KBMG 1 GAS LIFT OV BK 0250 0.0 3/11/2009 Notes:General&Safety Jr End Date Annotation 4/1/2009 NOTE:SSSV TRDP failed&Recovery Lock Out Valve set inside TRDP as WRDP 4/24/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PERFP;15,648.0-19.433.0 _ 11 II rNMIr rt 1r MI rt t MI rr 11 LINER;12,029.419,564.0 STATE OF ALASKA N • ALA—.A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate rOther p Scale Inhibitor Alter Casing r Pull Tubing r Stimulate-Frac Waiver r Treatment I— r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J 7 Exploratory r • 209-006 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service Ir • 50-103-20593-00 7.Property Designation(Lease Number 8.Well Name and Number: ADL 380092,372105,389725,384215 • CD3-115 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): o none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19564 feet Plugs(measured) none true vertical • 6854 feet Junk(measured) none Effective Depth measured 19564 feet Packer(measured) 11532 true vertical 6854 feet (true vertical) 6737 Casing Length Size MD TVD Burst Collapse Conductor 77 16" 114 114 Surface 2959 9.625" 2995 2461 Intermediate 12122 7" 12156 6942 Liner 7534 4.5" 19564 6854 ,; C'7,--,' SCOW AUGI �kZ01 n t Perforation depth: Measured depth: pre-drilled liner 12268'-15442', perf pups 15648'-19433' f .�~_,� True Vertical Depth: 6959'-6914',6914'-6861' �^''t'M� RBDMAI MAY 1 3 2014 Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 12051 MD,6920 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 11532 MD and 6737 ND SSSV-CAMCO TRMAXX-5E @ 2169 MD and 2001 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12156'-19564' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1946 1865 2020 1632 317 Subsequent to operation 1970 2047 2041 1821 302 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r • Service r Stratigraphic r 16.Well Status after work: Oil1-4.7Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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: none Contact Kerry Freedman (a,265-6579 Email Kerry.C.Freedman a(�,conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature 1/ A Phone: 265-6579 Date !w ,iw+ �14e•e t a, 2o I y V F jii1 t Form 10-404 Revised 10/2012 4j��y Submit Original Only WNS PROD CD3-115 ` ConocoPhdIips wend Well Attributes Max Angle&MD TD NaSI a.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(^) MD(kKB) Act Btm(ftKB) 501032059300 FIORD NECHELIK PROD 93.81 12,506.79 19,564.0 ".- Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date HORIZONTAL-0O3-115,3/4/20147.46.06 PM SSSV:WRDP - Last WO'. 42.701 3/7/2009 Vertical schematic(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date HANGER,30.9 1� f Last Tag: Rev Reason:SET WRDP lehallf 3/4/2014 ,,,,,,,,, Casing Strings q It Casing Description OD(in) ID(in) Top(ftKB) Set Depth(5613) Set Depth(ND)...Wt/Len(I...Grade Top Thread :� CONDUCTOR 16 15250 37.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(NG)... WbLen(I...Grade Top Thread CONDUCTOR;37.0.14.0 I SURFACE 95/8 8.835 36.2 2,995.0 2.461.1 40.00 L-80 BTCM XO Reducing;174.0 L Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)... WVLen(I...Grade Top Thread SAFETY VLV:2.169.21 f INTERMEDIATE 7 6.276 34.0 12,156.2 6,941.9 26.00 L-80 BTCM WROP:2169 2 -• -041 Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 12,029.9 19,564.0 6,853.7 12.60 L-80 IBTM LinToer p o Details Nominal T on p(ND)(1tKB) Top Ind(') Item Des Com (in) SURFACE;362-29950 A 12,029.9B) 6,914.3 74.81 SLEEVE "HR"Liner Setting Sleeve 5.81"ID(10.13'Inner 5.250lD 4.260 • Profile) GAS LIFT;4,879.0 12,042.9 6,917.6 75.31 NIPPLE "RS"Packoff Seal Nipple 5.63"OD X 426"ID 12,046.6 6,918.6 75.45 HANGER Baker Flex Lock Liner Hanger 5.91"OD X 4.43"ID) 4.430 12,056.4 6,921.0 75.83 XO Reducing X0 Bushing-5 1/2"TKC X 4 1/2"SLHT(3.93"ID) 3.930 GAS LIFT;9,348.9 15,602.6 6,912.5 88.70 PERF XO 4 12"12.6#L-80 XO-4 1/2"IBT(p)x 4 1/2"SLHT(B) 3.958 -CHANGE FROM(6)1/2"HOLES IN CENTER OF 40'JOINT XO TO PERF PUPS(6)2 12"holes per 5' pup joint,alternating with 200'solid pipe sections GAS LIFT;11,444.7 : 11 10897.2 6,885.0 90.64 Swell PKR TAM Packer on 18.78'Pup-5.78"OD,3.937"ID, 3.937 Element 10.46' PACKER;11,531.6 MI Tubing Strings NIPPLE;11575.8 ® Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4.5"x3.5" 31/2 2.992 30.9 12051.0 6,919.7 9.30 L-80 EUE SOS;12,015.0 Completion Details _) _ Nominal ID Top(RKB) Top(TVD)(tKB) Top Incl(°) Item Des Corn (in) • WLEG;12.026.2 30.9 30.9 0.00 HANGER FMC 4 1/2"Tbg hanger w/2.32'pup 4.500 114.0 114.0 0.21 XO Reducing XO-4 1/2"IBTM(B)X 3 12"EUE(P) 2.992 2,169.2 2,000.9 45.95 SAFETY VLV Camco TRMAXX-5E SSSV w/2.812'profile HXS-0081 2.812 (LOCKED OUT wNALVE 4/28/2009)FLAPPER LOCKED OUT 11,531.6 6,736.6 63.63 PACKER Baker Premier Packer 5.98"OD x 2.87"ID 2.870 INTERMEDIATE;31.012.156.2- 4, 11,575.6 6,756.1 63.94 NIPPLE HES"XN"NIPPLE 2.75"NoGo 2.813 12,015.0 6,910.3 74.24 SOS XO 3 12"9.3#EUE X IBT-Tbg pup jt.W/Shear Pin 2.990 Futed No Go 12.026.2 6,913.3 74.67 WLEG Pup-31/2"IBT Tubing VV/Mule shoe WLEG 2.980 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top MKS) (#613) 11 Des Com Run Date ID(in) 2.169.2 2,000.9 45.95 WRDP 2.81"WRDP-1 (SN HYS-141)2.84'PACKING 2/24/2014 1.500 OAL=89.5";36.5"NO GO TO CENTER OF BOTTOM PACKING STACK PERFP;12,268.0-15,442.0- Perforations 2.268.P15,4420 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotsk Top(kKB) Btm(kKB) (kKB) (kKB) Zone Date t) Type Corn 12,268.0 15,442.0 6,959.1 6,914.0 NECH- 3/4/2009 6.0 PERFP TOP LINER SECTION: CRSUP,CD3- PRE-DRILLED LINER 115 14 joints of 40'lengths with(6)1/2"HOLES @ center of EACH 40'joint, alternating with 200' solid pipe sections 15,648.0 19,433.0 6,914.2 6,861.3 NECH- 3/4/2009 32.0 PERFP LOWER LINER CRSUP,CD3- SECTION:PERF PUPS: 115 (6)212"holes per 5' $t pup joint,alternating with 200'solid pipe sections 11111M iB Mandrel Inserts in st 1 ati _ on Top(ND) Valve Latch Port Size TRO Run 41' N Top(RKB) (kKB) Make Model OD(in) Sen./ Type Type (in) (psi) Run Date Com • IC 4,879.0 3,390.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/5/2009 2 9,348.9 5,591.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 00 3/5/2009 3 11,444.7 6,697.6 CAMCO KBMG 1 GAS LIFT OV BK 0.250 00 3/11/2009 U Notes:General&Safety End Date Annotation ! 4/1/2009 NOTE:SSSV TRDP tailed&Recovery Lock Out Valve set inside TRDP as WRDP 11 18 4/24/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 18 PERFP,15.648.419.433.0 _ 84 IIS ' It I 1 M. MINI 11 M 1 t1, i 1 4:8l M r8 RR ' LINER;12,029.9-19,564.0 r CD3-115 Scale Inhibition Treatment 2/26/2014: Job Pumped 16:59 2/26 to 13:32 2/27 Non-Aqueous Scale Inhibitor Squeeze: Initial pressure TBG/IA/OA-925/1703/559; LRS pumped 270 bbls Preflush (216 bbls of LEPD plus 2,269 gal WAW5206 and 11 gal M209) at 2.5 bpm,450/1530/169; LRS pumped 270 bbl Scale Inhibitor(230 bbls 70/30 MEG plus 1,702 gal SCW3001WC scale inhibitor)at 2.5 bpm,0/1471/168; LRS pumped 2,567 bbls crude overflush at 2.5 bpm,840/1378/147. Intervals treated: 12,156'—19,564' STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMOSION . REPORT OF SUNDRY WELL OPERATIONS / 1. Operations Performed: Abandon ( Repair w ell E Plug Perforations is Perforate E Other Y 569- P ull Tubing E S timulate - Frac ( Waiver , nhl b r �1 wt Alter Casing jy' 9 E Ti me Extension j" C Change Approved Program r Operat. Shutdow n E Stimulate - Other Re -enter Suspended Well i — V t'1 1 O 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development j i Exploratory (`°" 209 -006 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ( Service , ^ 50 103 20593 - 00 '' Og 7. Property Designation (Lease Number): 8. Well Name and Number: , ADL 380092, 372105, 389725, 384215 r CD3 - 115 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 19564 feet Plugs (measured) none true vertical 6854 feet Junk (measured) none Effective Depth measured 19564 feet Packer (measured) 11532 true vertical 6854 feet (true vertical) 6736 Casing Length Size MD TVD Burst Collapse Conductor 77 16" 114 114 Surface 2959 9.625" 2995 2461 Intermediate 12122 7" 121 SCANNED APR 1. 6 Liner 7534 4.5" 19564 6854 ei K,> ..* :. ,,. Perforation depth: Measured depth: slots 12268' 15422', pert pups 15648' 19433' True Vertical Depth: 6958' 6914', 6914' - 6861' e (' f sw r"1"‘ Tubing (size, grade, MD, and TVD) 4.5 x 3.5, L -80, 12051 MD, 6920 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 11532 MD and 6736 TVD SSSV - CAMCO TRMAXX -5E @ 2169 MD and 2001 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12156' 19564' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 2403 4186 1054 -- 370 Subsequent to operation 2633 3811 1170 -- 315 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development l� ~ Service E Stratigraphic i 16. Well Status after work: 10i1 ry Gas (`-" WDSPL r Daily Report of Well Operations - XXX GSTOR E WINJ r WAG E GINJ E SUSP 1 SPLUG la 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: none Contact Tim Nelson @ 265 - 6859 Email Timothv .J.Nelson @conocoohillios.com Printed Name Tim Nelson Title Staff Production Engineer Signature ,_ / 4_ Phone: 265 -6859 Date Z aft to/3 Flaws APR 0 3 2013 4M 3 `' Form 10 -404 Revised 10/2012 ,. // Submit Original Only • • CD3 -115 3/24/2013 Scale Inhibition Treatment Initial pressure TBG /IA /OA- 910/1640/580; LRS pumped 21 bbl arctic low endpoint diesel containing 168 gal WAW5206 at 2.5 bpm, 840/1640/550; 149 bbl of 70:30 MEG containing 990 gal SCW3001WC was then pumped at 3.5 bpm, 325/1620/110; and 1842 bbl of crude overflush at 4 bpm. Final pressures 400/2000/300. Interval treated for this well was 12156' — 19564' WNS • CD3 -115 „ ConocloPhi lips 1061, ---e Well Attributes M ax Angle & MD TD Alaska, Inc 4':- Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) _... , hocoA dItm. 501032059300 FIORD NECHELIK PROD 93.81 12,506.79 19,564.0 Comment H2S (ppm) Date Annotation End Date KB (5) Rig Release Date SSSV: WRDP Last WO: 42.70 3/7/2009 Well Confab HORIZONTAL - CD3 -115, 3/2112013 992.34 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date _. Last Tag: Rev Reason: SET WRDP, ADD PERF ZONES osborl 3/21/2013 HANGER, 31 Casing Strings �' Casing Description String 0... String ID ... Top kKB Set De f... Set Depth De TVD String Wt.. String String Top Thrd 9 P 9 9 PI ) Depth P( P( )��� 9 9��� 9 P - CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H - 40 Welded i Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONUUCIOR, � _ SURFACE 95/8 8.835 36.2 2,995.0 2,461.1 40.00 L - 80 BTCM 37 - 114 Casin Description 'String 0... String ID... Top ftKB Set De Set Depth (TVD) String Wt... Strip String Top Thrd MEI XO Reducing, 9 P 9 9 P( I Depth Pt ( ) ••• g 9 - • 9 P 114 INTERMEDIATE 7 6.276 34.0 12,156.2 6,941.9 26.00 L - 80 BTCM VRDP,2,1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SAFETYVL V,� 2,169 f 1 LINER 41/2 3.958 12,029.9 19,564.0 6,853.7 12.60 L -80 IBTM Liner Details Top Depth (TVD) Top Inc! Nomi... SURFACE. Top (ftKB) (ftKB) 1 ") Item Description Comment ID (in) 36 - 2695 12,029.9 6,913.9 74.81 SLEEVE "HR" Liner Setting Sleeve 5.81" ID (10.13' Inner Profile) 5.250 GAS LIFT, I 4,879 • 12,042.9 6,917.5 75.31 NIPPLE "RS" Packoff Seal Nipple 5.63" OD X 4.26" ID 4.260 12,046.6 6,918.5 75.45 HANGER Baker Flex Lock Liner Hanger 5.91" OD X 4.43" ID) 4.430 12,056.4 6,921.0 75.83 XO Reducing X0 Bushing - 5 1/2" TKC X 4 1/2" SLHT (3.93" ID) 3.930 15,602.6 6,913.2 88.70 PERF X0 4 1/2" 12.6 # L-80 XO - 4 1/2' IBT(p) x 4 12" SLHT(B) - CHANGE FROM 3.958 (6) 1/7 HOLES IN CENTER OF 40' JOINT X0 TO PERF PUPS (6) 2 1/2" GAS LIFT. E holes per 5' pup joint, alternating with 200' solid pipe sections III 16,897.2 6,886.3 91.91 Swell PKR - TAM Packer on 18.78' Pup - 5.78" OD, 3.937" ID, Element 10.46' 3.937 GAS LIFT, Tubing Strings 11,445 Tubing Description String 0... String ID... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd TUBING4.5 "x3.5" I 31/2 I 2.992 I 30.9 I 12,051.0 I 6,919.6 9.30 I L -80 EUE PACKER, 4® Completion Details 11,532 `a Top Depth (ND) Top Incl Nomi... NIPPLE. 11,576 `.� Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 30.9 30.9 - 0.03 HANGER FMC 4 1/2" Tbg hanger w/ 2.32' pup 4.500 SOS. 12.015 ._....__._ 114.0 114.0 0.15 X0 Reducing X0 - 4 1/7' IBTM (B) X 3 12" EUE (P) 2.992 2,1692 2,0008 4695 SAFETY VLV Camco TRMAXX -5E SSSV w/ 2.812' profile HXS -0081 (LOCKED OUT 2812 WLEG. 12.026 M wNALVE 4/28/2009) FLAPPER LOCKED OUT • • 11,531.6 6,735.5 62.47 PACKER Baker Premier Packer 5.98" OD x 2.87' ID 2.870 11,575.6 6,756.0 63.72 NIPPLE HES "XN" NIPPLE 2.75" NoGo 2.813 12,015.0 6,909.6 74.24 SOS X0 31/2 9.3# EUE X IBT -Tbg pup jt. W/ Shear Pin Futed No Go 2.990 12,026.2 6,912.8 74.67 WLEG Pup -31/2" IBT Tubing W /Mule shoe WLEG 2.980 NTERMEDIATE, • r Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 3412'156 Top Depth (TVD) Top Incl Top (ftKB) (ftKB) 1') Description Comment Run Date ID (!n) 2,169.2 2,000.8 45.95 WRDP 2.81" WRDPw/EXTENSION (SN C28 -0301) 2.84' PACKING 3/15/2013 1.500 OAL= 89.5 "; 35.25" NO GO TO CENTER OF BOTTOM PACKING STACK Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment PERFP, 12,268.0 15,442.0 6,958.4 6,914.0 NECH - CRSUP, 3/4/2009 6.0 PERFP TOP LINER SECTION: 12,268 - 15.442 CD3 -115 PRE- DRILLED LINER 14 joints of 40' lengths with (6) 1/2" HOLES @ center of EACH 40' joint, alternating with 200' solid pipe sections 15,648.0 19,433.0 6,914.2 6,861.3 NECH - CRSUP, 3/4 /2009 32.0 PERFP LOWER LINER SECTION: PERF CD3 -115 PUPS: (6) 2 1/2" holes per 5' pup joint, alternating with 200' solid pipe sections Notes: General & Safety End Date Annotation 4/1/2009 NOTE: SSSV TRDP failed 8 Recovery Lock Out Valve set inside TRDP as WRDP 4/24/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 ME ME Mil MI NMI MI ■ MI Mandrel Details PERFP, Top Depth Top Port 15,648- 19.433 ME S... (ND) Inc! OD Valve Latch Size TRO Run _ N... Top(ftKB) /kKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 4,879.0 3,390.5 59.59 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/5/2009 ElEll 2 9,348.9 5,591.4 60.19 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/5/2009 ME 3 11,444.7 6,697.4 62.83 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 3/11/2009 ME li r MEM NEE LINER, 12.030- 10,564N TD, 19,564 • • OF Ty wi) *8 I cs. THE STATE Alaska Oil and Gas ofA AsKA. Conservation Commission Witt GOVERNOR SEAN PARNELL . 333 West Seventh Avenue OF Anchorage, Alaska 99501 -3572 ALAS"' Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney SCANt4E® MAR Z 13 Completion Engineer � / ConocoPhillips Alaska, Inc. a0 7 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3 -115 Sundry Number: 313-109 Dear Mr. Blakney: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, / / Cathy P. oerster �y Chair DATED this 1/ ay of March, 2013. Encl. STATE OF ALASKA 4A., 41s 1 ALA KKA OIL AND GAS CONSERVATION COMIOION r\ (/ APPLICATION FOR SUNDRY APPROVALS e 20 AAC 25.280 1. Type of Request: Abandon E Aug for Redrill I°...." Perforate New Pool I_,_. Repair w ell I Change Approved Program I..__- Suspend r Rug Perforations j"` Perforate (;►. Pull Tubing I` Time Extension E Operational Shutdown (`°` Re -enter Susp. Well r Stimulate Alter casing E Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fj. . Exploratory E 209 - 006 3. Address: Stratigraphic E Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20593 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes I No I✓ CD3 -115 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 380092, 372105, 389725, 384215 Colville River Field / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): • 19564 6854 - 19564' 6854' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16" 114' 114' SURFACE 2959' 9.625" 2995' 2461' RECEIVED d E D INTERMEDIATE 12122' 7" 12156' 6942' 1 V G LINER 7534 4.5" 19564' 6854' MAR ( 4 2013 AOGCC Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slots 12268' - 15422', pert pups 15648' - 19433' 6958' 6914', 6914 3.5 L - 80 12051 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER PREMIER PACKER • MD =11532 TVD =6736 SSSV - CAMCO TRMAXX -5E - MD =2169 TVD =2001 12. Attachments: Description Summary of Proposal • Fi 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ( Exploratory E Stratigraphic r Development Iii , Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/15/2013 Oil P ' Gas ra WDSPL E Suspended I- 16. Verbal Approval: Date: WAG I — Abandoned r PP WINJ lµ' GIN I� Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265 -6417 Email: Robert.G.Blaknev(a?conocoohillips.com Printed Name obe BJ j ne Title: Completion Engineer 2 Signature / �� .,� Phone: 265 -6417 Date 3 /i* 7_ 3 Commission Use Only -� Sundry Number: 3 1 3 - Conditions of approval: Notify Commission so that a representative may witness Plug Integrity is BOP Test E Mechanical Integrity Test I Location Clearance fl Other. RBDMS MAR 12 2013 Spacing Exception Required? Yes ❑ No [r Subsequent Form Required: (] APPROVED BY Approved by: iti / J� �� NNro � cd application is vakf& r r the from thT��R2V Date: 3 " f 1 - /3 Q r R-TG y, Vt/t'� Submit Form and Attachments in Duplicate 6;') WNS • CD3 -115 - Conoc Well Attributes Max Angle & MD TD Alaska, Itu , Wel!bore API/MI Field Name Well Status Ind(*) MD (ftKB) Act Finn (ftKB) 501032059300 FIORD NECHELIK PROD 9381 12,506.79 19,564.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date '° _ SSSV: WRDP Last WO: 42.70 3/7/2009 Well Confer HORIZONTAL - CD3 -115, 1/9/2013 10:16'.36 AM - Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag Rev Reason: WELL REVIEW, RESET WRDP osborl 1/9/2013 __ HANGER, 31 _ - Casing Strings ,,.. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H Welded Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WNUUL100, a , SURFACE 9 SS 8.835 36.2 2,995.0 2,461.1 40.00 L - 80 BTCM 37 -714 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd X0 Reducing, 114 INTERMEDIATE 7 6.276 34.0 12,156.2 6,941.9 26.00 L - 80 BTCM WRDP, 2,169 1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd SAFETYVLV. \ I I LINER 41/2 3.958 12,029.9 19,564.0 6,853.7 12.60 L - 80 IBTM 2,169 Liner Details Top Depth i (TVD) Top Inc! Nomi... SURFACE Top(ftKB) (ftKB) ( °) Item Description Comment ID (in) 36 12,029.9 6,913.9 74.81 SLEEVE "HR" Liner Setting Sleeve 5.81" ID (10.13' Inner Profile) 5.250 GAS 4 LIFT, - 12,042.9 6,917.5 75.31 NIPPLE "RS" Packoff Seal Nipple 5.63" OD X 4.26 ID 4.260 12,046.6 6,918.5 75.45 HANGER Baker Flex Lock Liner Hanger 5.91" OD X 4.43" ID) 4.430 12,056.4 6,921.0 75.83 XO Reducing XO Bushing - 5 1/2' TKC X 4 1/2' SLHT (3.93" ID) 3.930 1 16,897.2 6,886.3 91.91 Swell PKR TAM Packer on 18.78' Pup - 5.78" OD, 3.937" ID, Element 10.46' 3.937 GAS LIFT, I Tubing Strings _ 9.349 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4.5 "x3.5" 31/2 2.992 30.9 12,051.0 6,919.6 9,30 L -80 EUE _ GAS LIFT, Completion Details 11,445 i - - Top Depth (TVD) Top Inc! Nom'... Top (ftKB) MKS) (°) Item Description Comment ID (in) PACKER, . 30.9 30.9 - 0.03 HANGER FMC 4 1/2" Tbg hanger w/ 2.32 pup 4.500 11,532 I It 114.0 114.0 0.15 XO Reducing XO - 4 1/2" IBTM (B) X 31/2' EUE (P) 2.992 NIPPLE, 11576 aa; 2,169.2 2,000.8 45.95 SAFETY VLV Camco TRMAXX -5E SSSV w/ 2.812" profile HXS -0081 (LOCKED OUT 2.812 wNALVE 4/28/2009) FLAPPER LOCKED OUT SOS, 12,015 eliM 11,531.6 6,735.5 62.47 PACKER Baker Premier Packer 5.98" OD x 2.87' ID 2.870 11,575.6 6,756.0 63.72 NIPPLE HES "XN" NIPPLE 2.75" NoGo 2.813 WLEG, 12.026 12,015.0 6,909.6 74.24 SOS XO 3 1/2" 9.3# EUE X IBT -Tbg pup jt. W/ Shear Pin Futed No Go 2.990 12,026.2 6,912.8 74.67 WLEG Pup - 3 1/2" IBT Tubing W /Mule shoe WLEG 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top(ftKB) (ftKB) ( ") Description Comment Run Date ID (in) NTERMEOIATE, A 3412,156 2,1692 2,000.8 45.95 WRDP 2.81" WRDP w/EXTENSION (SN HTS -619) ON 2.18" XX 12/21/2012 1.500 • LOCK Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top(ftKB) Btrn(ftKB) (RKB) (ftKB) Zone Date (sh -. Type Comment 12,268.0 15,442.0 6,958.4 6,914.0 3/4/2009 32.0 SLOTS SLOTTED LINER: (6) 1/2' slots @ center of 40' joint, altemating with 200' solid pipe sections 15,648.0 19,433.0 6,914.2 6,861.3 3/4/2009 32.0 PERFP PERF PUPS: (6)2 1/2" holes per 5' SLOTS, pup joint, alternating with 200' solid 12,266 - 15.442 pipe sections Notes: General & Safety End Date Annotation 4/1/2009 NOTE: SSSV TRDP failed 8 Recovery Lock Out Valve set inside TRDP as WRDP 4/24/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 P MI Ell I li. MI MN II E. Mandrel Details PERFP, Top Depth Top Port 15,648-19633 MI (TVD) Inc' OD Valve Latch Size TRO Run lin Stn Top (ftKB) (ftKB) ( ") Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 4,879.0 3,390.5 59.59 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/5/2009 MN 2 9,348.9 5,591.4 60.19 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/5/2009 MB 3 11,444.7 6,697.4 62.83 CAMCO KBMG 1 GAS LIFT OV BK 0250 0.0 3/11/2009 I= MI ■ EM LINER, 12,030 - 19.584 60, 19.564 • • CD3 —115 Sundry Application CD3 -115 was completed in 2009 as horizontal producer in the Nechelik formation. The well was completed with 3.5" tubing and a 4.5" liner in the horizontal. This well is currently waiting on fill cleanout. Depending on the down -hole condition that is encountered during the fill cleanout we will decide if we need to perforate the liner. The well will be stimulated with a 3 stage job with bioballs used to achieve diversion. We expect the increased production to be 200 bpd in 2013 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Nechelik Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 7 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 2800 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 7,500 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 240 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 5000 psi. Stage 1 • 400 bbls YF130FX -D Pad • 184 bbls YF130FX -D w/ 2 ppa 16/20 Carbolite • 340 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 170 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 320 bbls YF130FX -D w/ 7 ppa 16/20 Carbolite • Bioball diversion Stage 2 • 240 bbls YF130FX -D Pad • 92 bbls YF130FX -D w/ 2 ppa 16/20 Carbolite • 255 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 85 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 154 bbls YF130FX -D w/ 7 ppa 16/20 Carbolite RB • • • Bioball diversion Stage 3 • 400 bbls YF130FX -D Pad • 184 bbls YF130FX -D w/ 2 ppa 16/20 Carbolite • 340 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 170 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 320 bbls YF130FX -D w/ 7 ppa 16/20 Carbolite • Flush with 147 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 500,000 Ibs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1 -01 disposal well until they are clean enough for production.) Production Casing Cement Report: CD3 -115: 7" casing cement pump report on 2/19/2009 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.2 ppg mud. Reciprocated pipe and had full returns throughout job. CD3 -128: 7" Casing two stage cement job was pumped on 2/23/2010 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 11.3 ppg mud. The plugs were bumped on both stages to 530 psi and 320 psi respectively, floats held. Full returns were observed during the job. CD3 -127: 7 -5/8" Casing two stage cement job was pumped on 2/21/2013 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, and was displaced with 10 ppg mud. The plugs were bumped at 950 psi and 200 psi respectively, floats held. Full returns were observed throughout the job. CD3 -125: 7" Casing two stage cement job was pumped on 3/28/2011 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg class G cement and was displaced with 11.5 ppg mud. The plugs were bumped at 1050 psi and 450 psi respectively, floats held. Full returns were observed throughout the job. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a1/4 mile radius or any other nearby well. RB • • Stimulation Surface Rig -Up c 0 Bleed / Tattle e 4t• Ri Tale Tank mr M kg 1:! 5� ak 775 B S ` • Minimum pressure rating on all surface treating lines 10,000 psi 0 " • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi Tr, 5 *_- t= • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 .1 psi. vigt Kx �l dwnd U 1.,:p on Tank 11111 ^lt taAb 1N 3 Li- I J Frac Pur-1;.. I Frac Pump Frac Pump 4f i < 0 --I 1,,f Frac Pump F 1 I 'u "I{ f Al -{ I` ,I h r:i_. F'u, RB • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION ■ (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) „ } , FR�RC IRON /CONNECTION rza D.. 1 0 . ` ,.Y",1:,,... • ,REMOTE OPERATED I MASTER VALVE O ti s 1 0.1111111111111111111111111. } MANLML OPERATED *5 • MASTER VALVE (i Felt ill • Stinger MANDREL I ■� s — �i : aP tI.011 -V/LLVE i �. OPEN !) ' 7 Ir i frIII \.• o f pi .�� It FLOW TEE AND '� F* A iii �/i�r VENT VALVE WELLHEAD �' . tile+. 3B VALVES / '/ , I 4 4 ' t at .- 1 i. ; owl A ' ' WELLHEAD r s VALVES .. --- W+'.' : CLOSED r s r'/. .4 i - QUAD PACKOEF " *% �. AU ASSEMBLY IN 'if .w r PLA CE IN TUBING ' 0I 3I•2 M TUBING .-,a • The universal tool is rated for 15,000 psi and has 84” of stroke. • Tool ID 2.25" down 4 1 /2 tubing and 1.75" down 3 1 /2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB CD3-1 15 Nechelik Frac Model • • Frac Design 1 stage Job Description Step Pump Fluid Name Step Gel Prop. Prop. Name Rate Fluid Conc. Type and Mesh Conc. (bbl /m Volume (lb /ma (PPA) in) (gal) 1) Pad 20.0 YF130FlexD 16800 30.0 0.00 2.0 PPA 20.0 YF130FlexD 7724 30.0 CarboLite 16/20 2.00 4.0 PPA 20.0 YF130FlexD 14297 30.0 CarboLite 16/20 4.00 4.0 PPA 20.0 YF130FlexD 7149 30.0 CarboLite 16/20 4.00 7.0 PPA 20.0 YF130FlexD 13503 30.0 CarboLite 16/20 7.00 Totals for all 3 stages • Fluid Totals 154,455 gal of YF130FX -D Proppant Totals 501,400 lb of CarboLite 16/20 Model Results Initial Fracture Top ND 6930.0 ft Initial Fracture Bottom ND 7030.0 ft • Propped Fracture Half- Length 280.0 ft EOJ Hyd Height at Well 212.0 ft Average Propped Width 0.607 in • Disclaimer Notice: — This model was generated using vendor supplied modeling • software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. LU:S- iU1Arti1 • • CD3 -114 CD -115 . CD3 = 02P63 CD3 -118 • CD3 -117 CD3 -124 Il • Q Lp3 -302PE • NIGLIQ 1A y.. • -•_, ` ,` � ' •. • 1.. . .,.; • I " ................ '4 ..." : .-: ............ '''..*,:, 4i. :. ,:v...'' ' ' •• ''''. F............, ::.r.......-* NIGLIQ 1 • . ....... 'r. — :::.::' . ..... ' ''.....1?...1. ....... .. .. ........................................ ::::::1:;.:::::.*-........ '''''''''''' K • Le Well Suspended P +A • Service .CD3- 127PB1 • Producer • CD3-125PB1 Observation • Injection: SW • Injection: SAPW • Injection: PW • In jec. A CTIVE, INJ, MWAG M A A CTIVE , INJ GAS G ACTIVE, INJ, GAS • ACTIVE, INJ, DG ACTIVE, INJ, <Null> CD3 -123 D isposal tion • CD3_115_Bufer • D3 -125 * Perforations O C onocoP h illips O perated Units aa, Nanuq Nanuq Participating Area p • NPR -A boundary CD3 -128 ConocoPhilhps NECHELIK 1 . 2013 CD3 -115 Fracture Locations N CONFIDENTIAL 0 0.25 0.5 A Miles FracProgram2013.mxtl CSR 1 -10 -2013
