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208-192
1 Gluyas, Gavin R (OGC) From:Wallace, Chris D (OGC) Sent:Monday, January 27, 2025 12:07 PM To:AOGCC Records (CED sponsored) Subject:FW: KRU 2L-301 (PTD 208-192) Suspected IA Integrity Attachments:2L-301 Bleed Log 1-24-25.csv; AnnComm Surveillance TIO for 2L-301.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, January 24, 2025 10:24 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2L-301 (PTD 208-192) Suspected IA Integrity Hi Chris, CPAI has concluded our monitoring and diagnostics of KRU 2L-301 (PTD 208-192). The well exhibits IAxOA communication in both directions while on produced water injection. The well passed an MIT-IA to 3000 psi and IC packoƯ tests on 1/10/25. Our diagnostics indicate a slow thread leak in the production casing within the surface casing shoe. The Outer Annulus can be maintained below its Operating Pressure Limit of 1000 psi but the IA and OA pressure are equalizing. CPAI intends to prepare a water only injection AA application for the well and requests to keep the well online on water injection only while preparing and awaiting the AA. The TIO plots, bleed reports, and schematic are attached. Please let me know if you have any questions or disagree with the plan. Thanks, Jaime From: Well Integrity Specialist CPF2 Sent: Thursday, January 9, 2025 8:03 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-301 (PTD 208-192) Suspected IA Integrity Hi Chris, KRU 2L-301 is a WAG injector currently on water injection. On review of the IA and OA pressure trends, IA pressure fall is indicating a possible IA integrity issue. CPAI intends to conduct diagnostics at this time. The TIOs, bleed logs, and schematic is attached. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Cell: 907-229-8282 24-JAN-25 10:14 Well Annulus Test Report DS WL TIME DURATION STR-PRES END-PRES DIF-PRES CASING SERVICE MATERIAL 2L 301 ########+002:00 135 250 -115 OUTER PWI FLUID 2L 301 ########+002:00 205 217 -12 INNER PWI FLUID 2L 301 ########+000:05 154 92 62 OUTER PWI 2L 301 ########+000:10 262 100 162 OUTER PWI 2L 301 ########+000:07 285 600 -315 INNER PWI NITROGEN 2L 301 ########+000:10 1567 886 681 INNER PWI GAS DIES 2L 301 SI ########+000:07 230 530 -300 INNER PWI GAS 2L 301 ########+000:02 610 1050 -440 INNER PWI GAS 2L 301 ########+000:09 1680 100 1580 INNER PWI DIESEL 2L 301 ########+000:10 1450 1150 300 INNER PWI DIESEL 2L 301 ########+000:05 310 500 -190 INNER PWI DIESEL 2L 301 ########+000:08 1800 850 950 INNER PWI DIESEL 2L 301 ########+000:08 708 275 433 OUTER PWI DIESEL 2L 301 SI ########+001:30 1 1 0 INNER PWI FLUID 2L 301 ########+000:15 1880 1150 730 INNER PWI DSL 2L 301 ########+000:50 1184 496 688 OUTER MIS GAS 2L 301 ########+003:00 582 987 -405 OUTER MIS NITROGEN 2L 301 ########+000:26 1985 1000 985 INNER MIS FLUID 2L 301 SI ########+003:00 761 875 -114 OUTER MIS GAS 2L 301 ########+004:00 78 880 -802 OUTER MIS N2 2L 301 ########+000:23 300 104 196 OUTER MIS FLUID 2L 301 ########+000:23 256 182 74 INNER MIS FLUID 2L 301 ########+000:18 1500 500 1000 INNER PWI DIESEL 2L 301 SI ########+000:03 180 100 80 INNER PWI DIESEL 2L 301 SI ########+000:03 307 425 -118 INNER PWI DIESEL 2L 301 SI ########+000:25 1800 500 1300 INNER PWI FLUID 2L 301 ########+000:10 1990 1000 990 INNER PWI LIQUIDS 2L 301 ########+000:20 1360 765 595 INNER PWI LIQUID 2L 301 ########+000:25 1960 730 1230 INNER PWI LIQUID 2L 301 ########+000:10 2200 1400 800 INNER PWI GAS/DIES 2L 301 SI ########+000:10 2304 1318 986 INNER PWI GAS/DIES 2L 301 ########+000:25 2320 935 1385 INNER MIS GAS/LIQU 2L 301 ########+000:05 1200 850 350 INNER PWI GAS/DIES 2L 301 ########+000:05 329 645 -316 INNER PWI GAS 2L 301 ########+000:12 1100 500 600 INNER PWI DIESEL 2L 301 ########+000:35 2436 402 2034 INNER GIN FLUID/GA 2L 301 ########+000:10 150 750 -600 INNER GIN GAS 2L 301 ########+000:09 1170 485 685 INNER PWI FLUID 2L 301 ########+000:04 1160 962 198 INNER PWI FLUID 2L 301 ########+000:10 1157 977 180 INNER PWI FLUID 2L 301 ########+000:20 2050 800 1250 INNER PWI DSL 2L 301 ########+000:35 2753 1950 803 INNER PWI DIESEL 2L 301 ########+000:12 1788 1239 549 INNER OIL LIQUID 2L 301 ########+000:10 1834 1237 597 INNER MIS DIESEL 2L 301 ########+000:10 2955 2700 255 INNER GIN DIESEL 2L 301 ########+000:05 354 200 154 INNER PWI GAS 2L 301 ########+000:25 1635 550 1085 INNER PWI GAS/DIES 2L 301 ########+000:00 1325 950 375 INNER PWI DIESEL 2L 301 ########+000:00 100 150 -50 INNER PWI FLUID 2L 301 ########+000:00 1198 915 283 INNER PWI FLUID 2L 301 ########+000:30 1500 750 750 INNER PWI DIESEL COMMENTS DHD pressured OA for D DHD pressured OA for D Bled OA to maintain >1 Bled OA to maintain a Bled to get 500 differ <100dp <100dp. Fluid packed. Was SI. WAG to PWI ye <500 with TBG DHD left IA high post Thermal- Inj Rate doub Thermal- Inj Rate doub DHD bled IA pre/post p WAG to pwi DHD Bled post SCLD DHD charged OA for SCL DHD bled IA post Passi DHD is doing an SCLD ( DHD pressured up the O DHD bled and loaded OA DHD bled and loaded OA <100dp <100dp DHD bled for DDT bled for compliance bled for DSPE/DHD bled for compliance bled to comply with DN bled to comply with DN bled for state complia Maintain 500 psi Dp Charged to maintain 10 Added PSI for Ia/OA dP DHD bled for BUR DHD bled post SW MITIA post wag to PWI Wagged to PWI For DSE/town assume l What ever....? bled to maintian prope POST PASSING STATE WIT POST PASSING MIT-IA BY 2L-301 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2L-301 2025-01-10 262.0 100 -162.0 OA 2L-301 2025-01-10 154.0 92 -62.0 OA 2L-301 2025-01-10 205.0 217 12.0 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 14,787.0 11/5/2020 2L-301 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag & updated composite plug to milled out & pushed to BTM. 11/5/2020 2L-301 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 28.5 Set Depth (ftKB) 3,315.0 Set Depth (TVD) … 2,272.8 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 39.3 Set Depth (ftKB) 15,049.9 Set Depth (TVD) … 5,841.1 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 22.0 Set Depth (ft… 14,344.4 Set Depth (TVD) (… 5,377.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.0 22.0 0.00 HANGER Tubing Hanger w/ 2.32' Pup 2.992 511.3 510.2 7.32 NIPPLE Camco 3 1/2" x 2.875" "DS" Nipple 2.875 14,226.1 5,321.6 64.68 SLEEVE-C 3 1/2" Baker CMU Sliding Sleeve w 2.813" DS profile (CLOSED 11/2/18) 2.813 14,272.1 5,342.0 62.50 PBR Seal Assembly locator "PBR" 5.87" OD x 3.00" ID 3.000 14,285.8 5,348.4 61.85 PACKER Baker FHL Packer,29.7# 7.625" OD X 2.94" ID 2.940 14,305.7 5,357.9 60.89 NIPPLE Camco 3 1/2" D Nipple w/ 2.75" profile 2.750 14,343.9 5,377.2 58.64 WLEG 3 1/2" Wireline Entry Guide OD 4.54" ID 3.00" 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 14,787. 0 5,652.6 46.45 Milled up composite bridge plug 2.73" Mill E-Z Composite Bridge Plug. Milled out and pushed to 14,338' CTM 10/03/20 (OAL 1.5') Tagged bottom 11/05/20 @ 14787' RKB. 10/3/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 14,257.0 14,259.0 5,335.1 5,336.0 8/25/2020 4.0 CMT SQZ 2" Tubing Punch 4spf 0 deg ph 14,670.0 14,690.0 5,573.7 5,587.0 T2, 2L-301 1/29/2009 6.0 IPERF 2.5" HJ 2506, 60 deg phase Frac Summary Start Date 1/31/2009 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/31/2009 Top Depth (ftKB) 14,670.0 Btm (ftKB) 14,690.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,787.8 2,437.6 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 3/27/2009 2 7,585.6 3,492.5 CAMCO KBMG- LTS 1 Chemical DMY BK5 0.000 0.0 9/25/2010 Notes: General & Safety End Date Annotation 9/13/2010 NOTE: CONVERTED FROM PRODUCTION TO INJECTOR HORIZONTAL, 2L-301, 11/8/2020 7:50:02 AM Vertical schematic (actual) PRODUCTION; 39.3-15,049.9 IPERF; 14,670.0-14,690.0 FRAC; 14,670.0 WLEG; 14,343.9 NIPPLE; 14,305.7 PACKER; 14,285.8 PBR; 14,272.1 CMT SQZ; 14,257.0-14,259.0 SLEEVE-C; 14,226.1 CHEMICAL; 7,585.6 GAS LIFT; 3,787.8 SURFACE; 28.5-3,315.0 NIPPLE; 511.3 CONDUCTOR; 28.0-116.0 HANGER; 22.0 KUP INJ KB-Grd (ft) 28.00 Rig Release Date 1/16/2009 2L-301 ... TD Act Btm (ftKB) 15,064.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032058800 Wellbore Status INJ Max Angle & MD Incl (°) 76.02 MD (ftKB) 7,596.85 WELLNAME WELLBORE2L-301 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2L-301 (PTD 208-192) Suspected IA Integrity Date:Thursday, January 9, 2025 11:05:07 AM Attachments:AnnComm Surveillance TIO for 2L-301.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, January 9, 2025 8:03 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-301 (PTD 208-192) Suspected IA Integrity Hi Chris, KRU 2L-301 is a WAG injector currently on water injection. On review of the IA and OA pressure trends, IA pressure fall is indicating a possible IA integrity issue. CPAI intends to conduct diagnostics at this time. The TIOs, bleed logs, and schematic is attached. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2L-301 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2L-301 2024-10-21 285 600 315 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 14,787.0 11/5/2020 2L-301 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag & updated composite plug to milled out & pushed to BTM. 11/5/2020 2L-301 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 28.5 Set Depth (ftKB) 3,315.0 Set Depth (TVD) … 2,272.8 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 39.3 Set Depth (ftKB) 15,049.9 Set Depth (TVD) … 5,841.1 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 22.0 Set Depth (ft… 14,344.4 Set Depth (TVD) (… 5,377.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.0 22.0 0.00 HANGER Tubing Hanger w/ 2.32' Pup 2.992 511.3 510.2 7.32 NIPPLE Camco 3 1/2" x 2.875" "DS" Nipple 2.875 14,226.1 5,321.6 64.68 SLEEVE-C 3 1/2" Baker CMU Sliding Sleeve w 2.813" DS profile (CLOSED 11/2/18) 2.813 14,272.1 5,342.0 62.50 PBR Seal Assembly locator "PBR" 5.87" OD x 3.00" ID 3.000 14,285.8 5,348.4 61.85 PACKER Baker FHL Packer,29.7# 7.625" OD X 2.94" ID 2.940 14,305.7 5,357.9 60.89 NIPPLE Camco 3 1/2" D Nipple w/ 2.75" profile 2.750 14,343.9 5,377.2 58.64 WLEG 3 1/2" Wireline Entry Guide OD 4.54" ID 3.00" 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 14,787. 0 5,652.6 46.45 Milled up composite bridge plug 2.73" Mill E-Z Composite Bridge Plug. Milled out and pushed to 14,338' CTM 10/03/20 (OAL 1.5') Tagged bottom 11/05/20 @ 14787' RKB. 10/3/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 14,257.0 14,259.0 5,335.1 5,336.0 8/25/2020 4.0 CMT SQZ 2" Tubing Punch 4spf 0 deg ph 14,670.0 14,690.0 5,573.7 5,587.0 T2, 2L-301 1/29/2009 6.0 IPERF 2.5" HJ 2506, 60 deg phase Frac Summary Start Date 1/31/2009 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/31/2009 Top Depth (ftKB) 14,670.0 Btm (ftKB) 14,690.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,787.8 2,437.6 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 3/27/2009 2 7,585.6 3,492.5 CAMCO KBMG- LTS 1 Chemical DMY BK5 0.000 0.0 9/25/2010 Notes: General & Safety End Date Annotation 9/13/2010 NOTE: CONVERTED FROM PRODUCTION TO INJECTOR HORIZONTAL, 2L-301, 11/8/2020 7:50:02 AM Vertical schematic (actual) PRODUCTION; 39.3-15,049.9 IPERF; 14,670.0-14,690.0 FRAC; 14,670.0 WLEG; 14,343.9 NIPPLE; 14,305.7 PACKER; 14,285.8 PBR; 14,272.1 CMT SQZ; 14,257.0-14,259.0 SLEEVE-C; 14,226.1 CHEMICAL; 7,585.6 GAS LIFT; 3,787.8 SURFACE; 28.5-3,315.0 NIPPLE; 511.3 CONDUCTOR; 28.0-116.0 HANGER; 22.0 KUP INJ KB-Grd (ft) 28.00 Rig Release Date 1/16/2009 2L-301 ... TD Act Btm (ftKB) 15,064.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032058800 Wellbore Status INJ Max Angle & MD Incl (°) 76.02 MD (ftKB) 7,596.85 WELLNAME WELLBORE2L-301 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-301 KUPARUK RIV U TARN 2L-301 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2L-301 50-103-20588-00-00 208-192-0 G SPT 5349 2081920 1500 3560 3560 3560 3560 221 221 227 227 4YRTST P Austin McLeod 8/3/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2L-301 Inspection Date: Tubing OA Packer Depth 1390 2190 2160 2160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220804183537 BBL Pumped:1.5 BBL Returned:1.4 Friday, September 2, 2022 Page 1 of 1 ! " # " $ % &' ( )*! + (% ,- !. /"! ! 0- ,- 12 132+. 2 4 , . " ( % & % 5 6 , 788 . $ 6, (8 . : 9 3" $ % ( " &' ( % - ( )" $ ; "%- & % ; ;*!< = -=; (! !4 &' ! 7 & " & & & !!"# $% #& '&( )* 7 #) ' : ,%" % +)- .) !/ 0)!! * ,+1 +*( ( ($ $ 3 % ! 1 ! ! >" ? " $ 2 &$ /' > ,9 12 132+28132+8@131/:. 3 4 & ; #5 < $ % ( * A % $8* 5 5 5 &-B -B*-!%; !& 6*! 55**! +60+0. 1+78606+530 "*!<"; " #? 3 4 & %$ ;%$C ,02+.1):#>2)1 7! %$ ? '22:)2 8B0032 #? 2#>2> :41212 " :2( 1 97 ( * , . ' ()1>3- $ * Steven G. Drake Digitally signed by Steven G. Drake Date: 2020.12.07 15:12:22 -09'00' By Samantha Carlisle at 3:26 pm, Dec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tate of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, November 23, 2020 P.I. Supervisor � . 1' I el ZZTu SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2L-301 FROM: Lou Laubenstein KUPARUK RIV U TARN 2L-301 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2L-301 API Well Number 50-103-20588-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL201116094559 Permit Number: 208-192-0 Inspection Date: 11/14/2020 Rel Insp Num: Well 2L-301 PTD 2081920 Packer Type Inj W ' TVD Type Test SPT Test psi Depth Ssa9 Tubing 1500 IA BBL Pumped: - Interval a BBL Returned: ----- OTHER - P/Fi' 4 - OA P Notes: MIT -IA post cement packer repair per Sundry # 320-271 Pretest Initial 15 Min 30 Min 45 Min 60 Min 1795 1795 1795 1795 . 310 2500 2450 2440 240 297 298 297 Monday, November 23, 2020 Page 1 of I Originated:Delivered to:9-Nov-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-24 50-029-22984-00 906642121 Kuparuk River Plug Setting Record Field- Final 5-Aug-20 0 1 2 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 25-Aug-20 0 1 3 1F-19 50-029-22660-00 906642776 Kuparuk River Packer Setting Record Field- Final 6-Aug-20 0 1 4 1Y-27 50-029-22379-00 n/a Kuparuk River Production Profile Field- Final 29-Aug-20 0 1 5 2B-02A 50-029-21154-01 906679203 Kuparuk River Multi Finger Caliper Field- Processed 29-Aug-20 0 1 6 2C-15 50-029-21219-00 n/a Kuparuk River Packer Setting Record Field- Final 30-Aug-20 0 1 7 2G-08 50-029-21125-00 906659316 Kuparuk River Packer Setting Record Field- Final 16-Aug-20 0 1 8 2L-301 50-103-20588-00 906671629 Kuparuk River Plug Setting Record Field- Final 24-Aug-20 9 2L-301 50-103-20588-00 906671629 Kuparuk River Tubing Punch Record Field- Final 25-Aug-20 10 2M-33 50-103-20240-00 906598622 Kuparuk River Leak Detect Log Field- Final 13-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 2081920 E-Set: 34229 Originated:Delivered to:9-Nov-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-24 50-029-22984-00 906642121 Kuparuk River Plug Setting Record Field- Final 5-Aug-20 0 1 2 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 25-Aug-20 0 1 3 1F-19 50-029-22660-00 906642776 Kuparuk River Packer Setting Record Field- Final 6-Aug-20 0 1 4 1Y-27 50-029-22379-00 n/a Kuparuk River Production Profile Field- Final 29-Aug-20 0 1 5 2B-02A 50-029-21154-01 906679203 Kuparuk River Multi Finger Caliper Field- Processed 29-Aug-20 0 1 6 2C-15 50-029-21219-00 n/a Kuparuk River Packer Setting Record Field- Final 30-Aug-20 0 1 7 2G-08 50-029-21125-00 906659316 Kuparuk River Packer Setting Record Field- Final 16-Aug-20 0 1 8 2L-301 50-103-20588-00 906671629 Kuparuk River Plug Setting Record Field- Final 24-Aug-20 9 2L-301 50-103-20588-00 906671629 Kuparuk River Tubing Punch Record Field- Final 25-Aug-20 10 2M-33 50-103-20240-00 906598622 Kuparuk River Leak Detect Log Field- Final 13-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 2081920 E-Set: 34228 ORIGINATED TRANSMITTAL DATE:11/3/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3196 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3196 2L-301 50-103-20588-00 CBL/CCL 10/24/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 tom.osterkamp@conocophillips.com (ShareConnect transfer) Received By: Print Name Signature Date AOGCC 1 0 0 ATTN: Natural Resources Technician II abby.bell@alaska.gov (e-mail link to OneDrive file) Received By: Print Name Signature Date DNR 1 0 0 Natural Resource Tech II DOG.Redata@alaska.gov (e-mail link to OneDrive file) Recevied By: Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com PTD: 2081920 E-Set: 34172 Received by the AOGCC 11/03/2020 Abby Bell Abby Bell 11/03/2020 Operations shutdownPlug Perforations Fracture Stimulate Repair WellAbandon1. Type of Request: Change Approved ProgramPerforate Other Stimulate Pull TubingSuspend Perforate New Pool Re-enter Susp Well Alter CasingPlug for Redrill Other: CEMENT PACKER REPAIR 5.Permit to Drill Number:4.Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. W ell Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool?N/A NoWill planned perforations require a spacing exception? Yes 10. Field/Pool(s):9. Property Designation (Lease Number): 11. Junk (MD):Plugs (MD):MPSP (psi):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): 15,064'NONE CollapseCasing Conductor Surface Production Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratoryStratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLWINJOILCommencing Operations:Suspended WAGGASDate:16. Verbal Approval:SPLUGGSTOR Commission Representative: GINJ AbandonedOp Shutdown Steve Drake Contact Name:Steve Drake Sr. Wells Engineer Contact Email: Contact Phone:(907) 263-4062 Date: Sundry Number:Conditions of approval: Notify Commission so that a representative may witness BOP Test Mechanical Integrity Test Location ClearancePlug Integrity Other: Post Initial Injection MIT Req'd? NoYes Spacing Exception Required? Subsequent Form Required:NoYes APPROVED BY Date:ONCOMMISSIONERApproved by:THE COMMISSI Sr Res EngSr Pet GeoSr Pet EngComm.Comm. Authorized Name: Authorized Title:Steve.G.Drake@cop.com Authorized Signature: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. L-803.500''5574-558714670-14690 MD= 14286 TVD= 5348PACKER - BAKER FHL PACKER,29.7# 7.625" OD X 2.94" ID 14,344' Packers and SSSV MD (ft) and TVD (ft): Tubing MD (ft):Tubing Grade:Tubing Size:Perforation Depth TVD (ft):Perforation Depth MD (ft): 5,841'15,050'7 5/815,011' 116'116'16''88' 2,273'3,315'10 3/43,287' BurstTVDMDSizeLength NONE P. O. Box 100360, Anchorage, Alaska 99510 50-103-20588-00-00 KRU 2L-301 ADL 25603, ADL 380051, ADL 380052 Kuparuk River Field / Tarn Oil Pool PRESENT WELL CONDITION SUMMARY 5,852'2500psi577414958 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.208-192 Perforate Reppair Well ServiceDevelopmentExploratoryStratigraphic BOP Test Mechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 7/10/2020 Steven G. Drake Digitally signed by Steven G. Drake Date: 2020.07.06 14:19:46 -08'00' By Samantha Carlisle at 10:39 am, Jul 14, 2020 320-271 DSR-7/14/2020 X DLB 07/14/2020 X 10-404 VTL 7/15/20 X Cement evaluation log required to determine cement placement and TOC in the IA Comm. 7/15/2020 JLC 7/15/2020 RBDMS HEW 7/16/2020 General Well Work Request Form GWWRv4.0b 4/17/20 klm 2 GWWR FORM OUT OF DATE--GET NEW GWWR FORM Well: 2L-301 Date of Request:5/19/2020 Request SPOC:CPF2 PE David/Adam x7519, pgr 252 Well Type:Injector Req. Written by:Steve Drake, 263-4062 Job Scope: Shut-In Reason Code:270 Tubing / Casing / Packer Leaks Well Shut in Date (if SI): 10/3/2019 Prioritization Category:Compliance Budget Category: Network: Network Description:Wells Group use Well Work is not justified via increased production Preventive Maintenance Program Request Injection Well Data Surrounding Producer Data Current Injection Rate (RVBPD) 0 Total Offset (AOF) Oil Rate (BOPD) 555 Expected Post Job Rate (RVBPD) 500 Total Offset (AOF) Gas Rate (MSCFD) 100 Offset WC 1.8%Total Offset (AOF) Water Rate (BWPD) 10 IGOR for CPF (SCF/STB) 30100 Rate Prediction Engr./Source Well monthly production data Gross Oil Benefit (BOPD) 98 NOB (BOPD) 98 Success Probability 80%If job fails, expected rate Zero Est. Duration of Job (SI Days) 4 Risked NOB (BOPD) 78 Est. Job Cost 118,000$ Est. Cost $/rNOBD 1,511$ Est. Number of Equipment Days 4 Risked NOB/Equip. Day 20 Last SBHP 12/11/1910 psi Last Tag 14,801'md H2S (PPM): SBHP Date 6/2/2019 Tag Date 3/1/2017 Any Fluid Restriction on Well?No SBHP Datum (TVD/SS?)5200 SS Max Inclin.76°Max Dogleg 7° Min. I.D (at/above work)2.813''Max Incl. Depth 7,597'md Max Dogleg Depth 1,149'md Ann Comm Kuparuk Base Expense Well Work Justification & Objectives (and date required if appropriate): 2L-301 has developed a packer leak which needs to be fixed before it can be put back into service. The leak is a one way leak with a low leak rate; passes MIT-IA, but fails a DDT test. The injector supports a number of very low water cut producers in an area lacking pressure support. This procedure will outline the steps necessary to place cement on the packer between the tubing and IA to fix the leak. Risk/Job Concerns: - Leaking packer - TxIA communication on gas. - 3.5" Baker CMU sliding sleeve DS profile closed 11/2/18 Steps: Halliburton Relay/LRS (set CA2, dump sand, tubing punch, injectivity test) 1. MIRU HAL Relay unit and associated equipment. 2. Utilizing CI SW, perform brush and flush of RBP setting area with braided line brush the nipple profile @ 14305' RKB. 3. Perform dummy CA2 drift run down to nipple @ 14305' RKB. (may include GR in brush run as dummy drift) 4. RIH and set CA2 in nipple @ 14305' RKB. MITT plug to 2500 psi. Troubleshoot any failing pressure test. 5. RIH and shake off 5' catcher on CA2 @ 14305' RKB. 6. Dump bail ~35' of sand on top of plug and confirm sand top is at 14265' RKB. (With a 2 1/2" bailer should take ~8 runs.) 7. MU and RIH with 2' tubing punch @ 4 spf and punch holes from 14260-14262' MD. (just above PBR) 8. Utilizing LRS and corrosion inhibited SW with 1% CRW-132, perform step rate injectivity test in half barrel increments pumping down the tubing and taking returns off the IA. 9. Once injectivity rates are recorded, pump 250 bbls of diesel. 10. Pump 160 bbls of corrosion inhibited sea water with 1% CRW 11. Pump 75 bbls of surfactant. 12. Pump 100 bbls or CI SW. 13. Pump 24 bbls of diesel for FP. 14. This pump schedule will place a diesel FP in the IA on top of SW with surfactant over the cement zone as well as SW in the tubing with diesel FP on top. 15. RDMO. Well is ready for coil to pump LockCem cement resin job 2" CTU - (Pump cement resin packer repair) Planned cement blend: 15.8 ppg LockCem cement with 20% resin and 6 hour working time. Need to confer with HAL on the cement design. 1. Prior to pumping cement job, contact Halliburton cement (town: Karl Molvig/Julia Nichols 435-219-2014/303-710-3932 slope: Mark Dean 303- 506-8462) to ensure cement product and crews are available and ready. 2. Contact Northern Solutions (Carl Diller/Jon Milne 307-258-6679/xxx-xxx-xxxx) to check on availability of a 3.5" WFD millabl e cement retainer. ********************** PROCEDURE CONTINUED ON NEXT PAGE ******************** 2L-301 Packer Repair 06-02-2020 SGD.xlsm Printed 6/17/2020 Page 2 Well: 2L-301 Date of Request:5/19/2020 Request SPOC:CPF2 PE David/Adam x7519, pgr 252 Steps Continued (list service type): 2" CTU (Pump cement resin packer repair) continued 3. MIRU CTU and associated equipment. (fluid pack coil with CI SW prior to RIH) 4. MU and RIH with 3.5" Weatherford millable cement retainer on an open choke to tanks. 5. Tag top of sand for depth correction. See previous WSR. Sand top should be @ 14265' RKB. Tubing punch is at 14260-14262 'RKB. 6. Set WFD millable cement retainer @ 14250' RKB (in the middle of the first full joint below the sliding sleeve). Perform a tubing integrity test and ensure tubing/coil annulus is isolated. 7. Come online with seawater to establish circulation between tubing and IA through tubing punches at 14260-14262' RKB, taking returns off the IA to tanks. DO NOT EXCEED PUMPING 100 BARRELS OF SEAWATER INTO IA PRIOR TO PUMPING CEMENT JOB. 8. Once circulation is established follow sea water with 5 barrel fresh water spacer. 11. Pump 65 barrels of 15.8 ppg WellLock cement resin blend. This should place cement over ~ 1900' of length in the production casing/tubing annulus. 14260-12348' RKB. 12. Follow WellLock cement blend with 5 barrels fresh water spacer. 13. Follow fresh water spacer with diesel. 14. With 1-2 barrels of cement remaining in the coil, unsting from retainer placing remaining cement on top of the retainer. Continue pumping out fresh water spacer followed by diesel. Pump diesel displacement while POOH. Maintain WHP while pulling out of hole as a ba ckup measure in case the retainer is leaking. 15. POOH. RDMO. Allow cement 72 hours to cure before milling out. DHD- (Pressure test) 1. Perform a MITIA to 2,500 psi and DDT to 0 psi on the IA to confirm that the cement repair is holding in both directions. CTU- (Mill cement/retainer) 1. RIH with milling assembly and mill up cement, taking returns off tubing to tanks. Mill through cement retainer at 14250' RKB. 2. Clean out sand as deep as possible to safe distance above the RBP plug at 14290' RKB. (RBP @ 14290' with 5' catcher on top puts top of assembly at 14285' RKB) 3. POOH. RDMO. Well ready for SL. Slickline (Pull catcher/RBP) 1. MIRU SL and associated equipment. 2. Pull catcher. (May need to bail sand off of top of catcher) 3. Utilize hydrostatic bailer to clean up fishing neck of CA2. 4. Pull CA2. 5. RDMO. Turn well over to Ops to BOL DHD - (Pressure Test) 1. Perform a State Witnessed MITIA to 2500 psi after the well has been brought online and operating. 2L-301 Packer Repair 06-02-2020 SGD.xlsm Printed 6/17/2020 From:Drake, Steve G To:Loepp, Victoria T (CED) Cc:Senden, R. Tyler Subject:RE: [EXTERNAL]KRU 2L-301(PTD 208-192, Sundry 320-271) Cement Packer Repair Date:Wednesday, July 8, 2020 9:00:44 AM Victoria, My experience has indicted that more cement on top of a packer in the IA is more effective at preventing the formation of a micro annulus. There are other wells in the past where I haven’t had the luxury of the extra space on top of the packer because of other jewelry in the tubing string that I did not want to compromise with placing cement on the backside (sliding sleeves, gas lift mandrels, etc.). Those wells with small or smaller amounts of cement have proven difficult and have sometimes required additional cement squeezes. I feel that this amount of cement will provide us with a very good chance at success on the first attempt. With regards to the leak diagnostics, yes, an acoustic log was run on 10/2/2019 that showed a leak signature at the packer. Regards, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, July 8, 2020 7:55 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]KRU 2L-301(PTD 208-192, Sundry 320-271) Cement Packer Repair Steve, Steve, Why do you need 1874’ of cement to fix a packer leak? Are there any diagnostics that show the location of the leak(s) Victoria From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Monday, July 6, 2020 1:27 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 2L-301(PTD 208-192, Sundry 320-271) Cement Packer Repair Victoria, The latest MIT-IA was performed on 8/12/2019 and passed to 4070 psi. Cement height above packer is 1874’. TOC is 12438’ RKB. Packer depth is 14285’ RKB. Post job schematic is attached. I will have the 10-403 submission date changed to 7/6/2020 with an anticipated start date of 7/10/2020. Would you like me to submit the packet to you when completed? Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, June 29, 2020 1:02 PM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]KRU 2L-301(PTD 208-192, Sundry 320-271) Cement Packer Repair Steve, Would like to see latest results of MIT-IA. Also, what height of cement above packer, TOC, packer depth, post job schematic. Also, work comencing date was the same as the submission date to the AOGCC; please send me revised date. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 104' of Rathole) 14,794.0 6/1/2019 2L-301 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull Plug & Updated Tag 6/1/2019 2L-301 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 28.5 Set Depth (ftKB) 3,315.0 Set Depth (TVD) … 2,272.8 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 39.3 Set Depth (ftKB) 15,049.9 Set Depth (TVD) … 5,841.1 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 22.0 Set Depth (ft… 14,344.4 Set Depth (TVD) (… 5,377.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.0 22.0 0.00 HANGER Tubing Hanger w/ 2.32' Pup 2.992 511.3 510.2 7.32 NIPPLE Camco 3 1/2" x 2.875" "DS" Nipple 2.875 14,226.1 5,321.6 64.68 SLEEVE-C 3 1/2" Baker CMU Sliding Sleeve w 2.813" DS profile (CLOSED 11/2/18) 2.813 14,272.1 5,342.0 62.50 PBR Seal Assembly locator "PBR" 5.87" OD x 3.00" ID 3.000 14,285.8 5,348.4 61.85 PACKER Baker FHL Packer,29.7# 7.625" OD X 2.94" ID 2.940 14,305.7 5,357.9 60.89 NIPPLE Camco 3 1/2" D Nipple w/ 2.75" profile 2.750 14,343.9 5,377.2 58.64 WLEG 3 1/2" Wireline Entry Guide OD 4.54" ID 3.00" 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 14,670.0 14,690.0 5,573.7 5,587.0 T2, 2L-301 1/29/2009 6.0 IPERF 2.5" HJ 2506, 60 deg phase Frac Summary Start Date 1/31/2009 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/31/2009 Top Depth (ftKB) 14,670.0 Btm (ftKB) 14,690.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,787.8 2,437.6 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 3/27/2009 2 7,585.6 3,492.5 CAMCO KBMG- LTS 1 Chemical DMY BK5 0.000 0.0 9/25/2010 Notes: General & Safety End Date Annotation 2/8/2016 NOTE: TAG ICE @1,980' SLM 9/13/2010 NOTE: CONVERTED FROM PRODUCTION TO INJECTOR 1/24/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 HORIZONTAL, 2L-301, 6/17/2020 10:43:21 AM Vertical schematic (actual) PRODUCTION; 39.3-15,049.9 IPERF; 14,670.0-14,690.0 FRAC; 14,670.0 WLEG; 14,343.9 NIPPLE; 14,305.7 PACKER; 14,285.8 PBR; 14,272.1 SLEEVE-C; 14,226.1 CHEMICAL; 7,585.6 GAS LIFT; 3,787.8 SURFACE; 28.5-3,315.0 NIPPLE; 511.3 CONDUCTOR; 28.0-116.0 HANGER; 22.0 KUP INJ KB-Grd (ft) 28.00 Rig Release Date 1/16/2009 2L-301 ... TD Act Btm (ftKB) 15,064.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032058800 Wellbore Status INJ Max Angle & MD Incl (°) 76.02 MD (ftKB) 7,596.85 WELLNAME WELLBORE2L-301 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log with ACX: 2L-301 Run Date: 10/1/2019 208192 3 160 6 November 21, 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 FRS_ANC@halliburton.com 2L-301 Digital Data in LAS format, Digital Log file, and Interpretation Report 1 CD Rom 50-103-20588-00 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: L��Rop RECEIVED DEC 0 9 2019 Signed: AOGCC Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Monday, July 29, 2019 5:19 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 2L-301 (PTD 208-192) Update with new plan forward Attachments: 2L-301 90 day TIO trend 7.29.19.pdf Chris, KRU Tarn WAG injector (PTD 208-192) is nearing the end of the monitor period on water injection and has exhibited no signs of annular communication. Recently the CPAI reservoir engineers have evaluated 2L -301's pattern and have determined that injecting MI into 2L-301 will yield an estimated 50 BOPD incremental benefit. CPAI now intends to pursue an AA to allow continued miscible injection with known TxIA communication. The plan is to WAG the well back to MI within 14 days. The well will be placed on a 60 day monitor period while on Ml. During this period the IA will be monitored to determine if the IA pressure will maintain below the MAOP of 2400 psi with two bleeds or less per month (non -thermal). In addition an MITIA to MAIP and an acoustic log will be performed to prove barriers and satisfy due diligence investigating for the communication source. At the conclusion of the monitor period the required paperwork will be submitted for continued injection or corrective action. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 �WEL.LS TEAM CWWC31PhtlYps Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, June 30, 2019 8:44 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 2L-301 (PTD 208-192) Suspect IA Behavior during MI Injection update 6.30.19 Attachments: 2L-301 30 day TIO trend 6.30.19.png Chris, WAG injector 2L-301 (PTD 208-192) is coming to the end of a 30 day monitor on water injection. The IA pressure built initially after being BOI, but after being bled on 6.21.19 has appeared to trend with injection rate and temp. Due to the short period of stable IA pressure CPAI intends to extend the monitor period another 30 days to ensure the IA pressure remains stable while on water injection. The proper paperwork for corrective action or continued injection will be submitted at the conclusion of the monitor period. A 30 day TIO trend is attached. Please let us know if you disagree or have any issues with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM JvlCows From: NSK Well Integrity Supv CPF1 and 2 Sent: Sunday, April 14, 2019 5:52 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: KRU 2L-301 (PTD 208-192) Suspect IA Behavior during MI Injection update 4-14-19 Chris, 2L-301 was shut in on October 31st and has remained shut-in since then. The well was circ'ed out with fresh fluid on November 1st but continued to fail the MITIAs on November 2 -3rd with a very small liquid leak rate ("'0.6 gallons per minute at 3000psi). Once the well was shut in, the IA pressure never showed any buildup (see the attached 180 -day TIO plot). But based on the failing tests, an acoustic LDL was run on February 18" which never saw anything definitive (there was a non -repeatable signature at the packer). Based on the relatively high reservoir pressure, we would have expected a rise in IA pressure if the packer was actually compromised. An MITIA passed on March 16th. At this point, it is suspected that the circ out was not an efficient one and we were battling residual gas entrainment initially. CPAI intends to return the well to water injection for a 30 -day monitor to ensure that the suspected leak is a gas -only one. An update will be provided at the conclusion of the monitor with path forward. Please let us know if you disagree with the plan. Kelly Lyons/ Jan Byrne Well Integrity Supervisor Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, April 14, 2019 5:52 PM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: KRU 2L-301 (PTD 208-192) Suspect IA Behavior during MI Injection update 4-14-19 Attachments: 2L-301 180 day TIO 4-14-19.PNG; MIT KRU 2L-301 diagnostic MIT 03-16-19.xlsx Chris, 2L-301 was shut in on October 31st and has remained shut-in since then. The well was cireed out with fresh fluid on November 1st but continued to fail the MITIAs on November 2 -3rd with a very small liquid leak rate (-0.6 gallons per minute at 3000psi). Once the well was shut in, the IA pressure never showed any buildup (see the attached 180 -day TIO plot). But based on the failing tests, an acoustic LDL was run on February 18th which never saw anything definitive (there was a non -repeatable signature at the packer). Based on the relatively high reservoir pressure, we would have expected a rise in IA pressure if the packer was actually compromised. An MITIA passed on March 16th. At this point, it is suspected that the circ out was not an efficient one and we were battling residual gas entrainment initially. CPAI intends to return the well to water injection for a 30 -day monitor to ensure that the suspected leak is a gas -only one. An update will be provided at the conclusion of the monitor with path forward. Please let us know if you disagree with the plan. Kelly Lyons/ Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 From: NSK Well Integrity Supv CPF1 and 2 Sent: Tuesday, October 30, 2018 9:35 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 2L-301 (PTD 208-192) Suspect IA Behavior during MI Injection Chris, Tarn injector 2L-301 is still showing signs of IA pressurization after the WAG to water injection. At this time, we believe the IA fluids are gas entrained and gas breakout from the fluids is causing the pressurization. CPAI plan to circ -out the IA as soon as reasonably possible with clean fluids, then restart the 30 -day monitor on water injection. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From-NSK Wea tegrity Supv CPFl and 2 Sent: Thursday, Octobe 2018 3:02 PM To: Wallace, Chris D (DOA) <chn . ace alaska. ov> Cc: Senden, R. Tyler <R.T Ier.Senden co E hilli s.com> Subject: KRU 2L-301 (PTD 208-192) Suspect IA Be ha ' Kc ring MI Injection iRS-11. PROACTIVE DIAgNOSTIC SERVICES, INC. WELL LO TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: 3048? RECEIVED ProActive Diagnostic Services, Inc. MAR 2 2 2019 Attn: Diane Williams 130 West International Airport Road A�GCC Suite C Anchorage, AK 99518 Ddsanchoraae(cDmemorvloo.com 18 -Feb -19 2L-301 CD 50-029-20588-00 Date : zdq PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SIIITEC, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEaMEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM D:Ucldve MmtuTemplatcFiles\Templa[ iDutribudon\Trvnsmi Shcets',Conowplu2iq Tivumitdoc Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, January 21, 2015 12:46 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; CPF2 Prod Engrs; Senden, R.Tyler Subject: RE: Report of IA pressure anomaly Tarn injector 2L-301 (PTD 208-192) 12-23-14 Attachments: Picture (Device Independent Bitmap) 1 jpg; 2L-301 90 day TIO 12-23-14.JPG; 2L-301 schematic.pdf; 2L-301 90 day TIO plot.JPG Chris, The end of the 30 day monitor period on gas injection is ending. The IA pressure has appeared to have stabilized with a good differential pressure between the tubing and the IA. There are a couple of IA pressure climbs that could be attributed to thermal and rate reasons. It is ConocoPhillips intention to return the well to normal WAG injection status and continue to operate under AIO 16. As per rule 7, if any further indications of communication are identified,the well will be reported and further diagnostics performed at that time. Please let me know if you disagree with this plan. Attached is a 90 day TIO plot for reference. SCANNED ‘'AN 2 6 2 ; • • Well Name 2L-301 Notes: Start Date 10/23/2014 Days 90 End Date 1/2112015 Annular Communication Surveillance •o0o — let WHP 300 OAP 1 14C WHT 3000 12C 2500 10( •uo 2000 SO 1500 — 50 1000 40 500 20 o 0 Oct-14 Oct-14 Nov-14 Nov-14 N ov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-1S Jan-15 tIuJ • WIVV11\4444\ Oct-14 Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Date Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager (907) 659-7000 pgr. 909 WELLS TEAM ConOooPFaps 2 e KUP INJ 2L-301 -' A ConocoPhillips . Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(7 MD(ftKB) Act Btm(ftKB) r rinivratell,p, 501032058800 TARN PARTICIPATING AREA INJ 76.02 7,596.85 15,064.0 ••• Comment H2S(ppm) Date Annotation End Dale KB-Grd(tt) `Rig Release Date HORIZONTAL-2L-301,10/12/20142'.20'.38 PM SSSV:NIPPLE Last WO. 28.00 1/16/2009 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 14,716.0 10/6/2014 Rev Reason:TAG,SET CHOKE lehallf 10/12/2014 HANGER 22 0=----I ---j""". Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread , CONDUCTOR 16 15.062 28.0 116.0 116.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(L..Grade Top Thread ' ' '' "' "'""""''"" SURFACE 10 3/4 9.950 28.5 3,315.0_ 2,272.8 45.50 L-80 ETC Casing Description "0D(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread 7`, or PRODUCTION 7 5/8 6.875 39.3 15,049.9 5,841.1 29.70 L-80 BTCM [�` yY� Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(tt..Set Depth(ND)(...Wt(Ibdt) Grade Top Connection TUBING 31/2 2.992 22.0 14,344.4 5,377.4 9.30 L-80 EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl("I Item Des Com (in) 22.0 22.0 0.00 HANGER Tubing Hanger w/2.32'Pup 2.992 511.3 510.2 7.32 NIPPLE Camco 3 1/2"x 2.875""DS"Nipple 2.875 ,a-seta-CONDUCTOR;za.o-ne.o,eA.A,.,.." -,^;,„�� 14.226.1 5,321.6 64.68 SLEEVE-C 3 1/2"Baker CMU Sliding Sleeve w 2.813"DS profile 2.813 (CLOSED 9/9/2010) 14272.1 5,342.0 62.50 PBR Seal Assembly locator"PBR"5.87'OD x 3.00"ID 3.000 14285.8 5,348.4 61.85 PACKER Baker FHL Packer,29.7#7.625"OD X 2.94"ID 2.940 14,305.7 5,357.9 60.89 NIPPLE Camco 3 1/2"D Nipple w/2.75"profile 2.750 NIPPLE''511 3 14,343.9 5.377.2 58.64-WLEG 3 1/2"Wireline Entry Guide OD 4.54"ID 3.00" 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) --I Top(TVD) Top Incl Top(1KB) (ftKB) (°I Des Com Run Date ID(in) 14.305.7 5.357.9. 60.89 VALVE SET CHOKE(.813")ON 2.75"C-LOCK '10/11/2014 0.813 Perforations&Slots I Shot Dena Top(ND) Btm(ND) (ahotnIf Top(ftKB) Btm(ftKB) (11KB) (ftKB) Zone Date tI Type Com 14.670.0' 14.690.0 5,573.7 5,587.0 T2,2L-301 •1/29/2009 6.0 IPERF 2.5"HJ 2506,60 deg SURFACE;28.6-3,315.0- - phase Stimulations&Treatments Min Top Max Btm Depth Depth Top(TAD) Blm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Dab Com GAS LIFT;3,787.8 14.670.0 14.690.0 5.573.7 5,587.0 FRAC 1131/2009 FRAC T2 SAND-PLACED 1802098 16)20 CARBOLITE INTO FORMATION w/9ppa ON PERFS Mandrel Inserts Sl au I on Top(ND) N Top( Valve Latch Port Sloe TRO Run kKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Corn f 3,787.8 2,437.6 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 3/27/2009 CHEMICAL 7 585 6 2 7,585.6 3,492.5 CAMCO KBMG- 1 Chemical DMY BK5 0.000 0.0 9/25/2010 ' LTS Notes:General&Safety End Date Annotation 1/24/2009 NOTE: ""PRE-PRODUCED INJECTOR""" 1/24/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 9/13/2010 NOTE:CONVERTED FROM PRODUCTION TO INJECTOR SLEEVE-C;14,228.1 PBR;14,272.1 --`- PACKER;14,285.844 VALVE; ,30. NIPPLE;1414,3055.771 MEG;14.343 9II-=1.161 FRAC;14,870.0 (PERF;14670.0-14,190 0 = =I PRODUCTION,393.15.0499 - 410 • Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 Commissioner Dan Seamount ‘10V ,, D Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 Mika Oil & p � $ � � � Anchorage, AK 99501 ieC! °F3�s� kn aos 1 Commissioner Dan Seamount: a L _ ' 0 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped 10/18, 10/19 and, 10/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, `/V 0/1& Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • , ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 2L, 3K, 3M & 3Q PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # _ cement pumped cement date inhibitor sealant date ft bbls ft _ gal 2L -301 50103205880000 2081920 10" N/A 10" N/A 1.7 10/18/2011 3K -20 50029230190000 2010880 SF N/A 14" N/A 1.7 10/19/2011 3K -24 50029229350000 1982490 SF N/A 24" N/A 3.5 10/19/2011 3M -01 50029216600000 1870120 SF N/A 12" N/A 5.95 10/21/2011 3M -03A _ 50029216960100 2081790 SF N/A 18" N/A 5.1 10/21/2011 3M -08 50029217090000 1870280 SF N/A 17" N/A 2.85 10/21/2011 3M -11 50029217180000 1870380 SF _ N/A 26" N/A 4.25 10/21/2011 3M -21 50029217390000 1870660 SF N/A 15" N/A 3.4 10/21/2011 30-03 50029222210000 1911260 SF N/A 18" N/A 3.45 10/19/2011 . 30-07 50029216820000 1861940 SF N/A 17" _ N/A 4.68 10/21/2011 3Q -08A 50029216810100 1971930 SF N/A 15" N/A 3.55 10/21/2011 _ 30-09 50029216740000 1861860 SF N/A 13" N/A 4.4 10/21/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation gr Commission DATE: Thursday, January 20, 2011 TO: Jim Regg 1(7-'61 i f P.I. Supervisor SUBJECT: Mechanical Inteity Tests (L CONOCOPHILLIPS ALASKA INC 2L -301 FROM: John Crisp KUPARUK RIV U TARN 2L -301 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry r, NON CONFIDENTIAL Comm Well Name: KUPARUK RIV U TARN 2L - 301 API Well Number: 50 103 - 20588 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110112112431 Permit Number: 208 - 192 - Inspection Date: 1/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2L -301 - Type Inj. w TVD 1 5349 ' IA 100 2000 ' 1940 1930 ' P.T.D 2081920' TypeTest SPT 1 Test psi 1500 - OA 311 320 323 323 Interval mum- p/F P ' Tubing I 1100 1120 1120 1120 Notes: 5.61 bbls pumped for test. Well is injecting water. No problems witnessed. FED la 1. ` ZWi ti Thursday, January 20, 2011 Page 1 of 1 ' • STATE OF ALASKA • r' ALASKA OIL AND GAS CONSERVATION COMMISSION �rr REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Ierforations r Stimulate r Other 0 Prod to Inj Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development pl Exploratory r — 208 -192 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service ❑ '' 50 7. Property Designation: 8. Well Name and Number: ADL 380052,380051,025603 r 2L -301 9. Field /Pool(s): Kuparuk River Field / Tam Oil Pool 10. Present Well Condition Summary: Total Depth measured 15064 feet Plugs (measured) none true vertical 5852 feet Junk (measured) none Effective Depth measured 14958 feet Packer (measured) 14226, 14272, 14286, 14306 true vertical 5774 feet (true vertucal) 5322, 5342, 5348, 5358 Casing Length Size MD TVD Burst Collapse CONDUCTOR 88 16 116 120 0 0 SURFACE 3286 10.75 3315 2273 0 0 PRODUCTION 15009 7.625 15052 5842 0 0 0 0 0 51.4}NED JAN 1 2 20)) o oesa�duauv o uoissll loon se9 It ViSON Perforation depth: Measured depth: 5574 True Vertical Depth: 5587 s 4 g 0 N V Tubing (size, grade, MD, and TVD) 3.5, L -80, 14344 MD, 5377 TVD FI 333 Packers & SSSV (type, MD, and TVD) SLEEVE-0 - 3 1/2" BAKER CMU SLIDING SLEEVE W 2.813" DS PROFILE (OPEN 3/26/09) © 14226 MD and 5322 TVD PBR - SEAL ASSEMBLY LOCATOR "PBR" 5.87" OD X 3.00" ID @ 14272 MD and 5342 TVD PACKER - BAKER FHL PACKER,29.7# 7.625" OD X 2.94" ID @ 14286 MD and 5348 TVD NIPPLE - CAMCO 3 1/2" D NIPPLE W/ 2.75" PROFILE © 14306 MD and 5358 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 2387 1040 1479 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Serv V 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WA W GASINJ r VVINJ r SPLUG r 16. 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 310 -312 Contact Bob Christensen /Darrell Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature a - _ } Phone: 659 -7535 Date /� ‘ii / / "- 7/2009 y $ JAN U , 6 ZQ11 " � 2 y � f 7 j ,submit Original Onl1j1/ ( // Form 10-404 Revised 7/2009 �""' ` • 2L-301 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/26110IWeIII brought up on produced water injection 10/30/10 GAUGE TBG TO 2.78" TO 14305' RKB. SET 2.75" MACCO INJ VALVE w/ .813" CHOKE © 14305' RKB. JOB COMPLETE. 09/25/10 COMFIRM OPEN POCKET AT STA 2 © 7586' RKB, SET DMY VLV @ 7586' RKB, PRESSURE TEST TBG TO 3000 #, PULL CAT SV FROM D- NIPPLE @ 14306' RKB, JOB COMPLETE. I I I I I I I. • KUP 2L -301 ConocoPhillips Well Attributes ax Angle & MD TD i ,, Wei!bore APIIUWI Field Name Well Status Intl ( °) MD (RK8) Act Btm (RKB) 1:alom•twkpa 501032058800 TARN PARTICIPATING AREA PROD 76.02 7,596.86 15,064.0 Comment H2S (ppm) Dam Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 28.00 1/16/2009 Well Conlin: HORIZONTAL - 2L -301, 11/12010 S55.11 AM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 14,780.0 9/23/2010 Rev Reason: SET INJ VLV Imosbor 11/1/2010 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 28.0 116.0 116.0 62.50 -(40 WELDED HANGER, 22 'Raft . ': Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 103/4 9.950 28.5 3,315.0 2,272.5 45.50 L BTC Cuing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 75/8 6.875 42.7 15,052.0 5,842.7 29.70 L-80 BTCM tzttbktag to "awitl■ Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd 7 TUBING 31/2 2.992 22.0 14,344.4 5,378.2 9.30 L -80 EUE8rdABMOD Completion Details Top Depth (TVD) Top Incl Noml... Top (ftl(8) IRKS) (°) Rem Description Comment ID (In) 22.0 22.0 0.14 HANGER Tubing Hanger w/ 2.32' Pup 2.992 511.3 510.2 7.32 NIPPLE Camco 3 1/2" x 2.875" "DS" Nipple 2.875 14,226.1 5,324.9 65.57 SLEEVE -C 3 1/2" Baker CMU Sliding Sleeve w 2.813" DS profile (CLOSED 2.813 9/9/2010) CONDUCTOR, 28 - 14,272.1 5,342.6 62.86 PBR Seal Assembly locator "PBR" 5.87" OD x 3.00" ID 3.000 14,285.8 5,348.6 62.06 PACKER Baker FHL Packer,29.7# 7.625" OD X 2.94" ID 2.940 14,305.7 5,358.0 60.89 NIPPLE Camco 3 1/2" D Nipple w/ 2.75" profile 2.750 14,343.9 5,377.9 58.64 WLEG 3 1/2" W reline Entry Guide OD 4.54" ID 3.00" 3.000 NIPPLE,511 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TM Top loci Top(f1KB) (RKB) (°) Description Comment Run Date ID (In) 14,305.7 5,358.0 60.89 VALVE 2.75" C-LOCK w/MACO INJECTION VLV 10/30/2010 0.813 Perforations & Slots Shot I Top (TVO) Btm (TVD) Dens Top MKS) Btm IRKS) (RKB) IRKS) Zone Date (sh... Type Comment 14,670.0 14,690.0 5,573.8 5,587.0 T2, 2L - 301 1/29/2009 6.0 IPERF 2.5" HJ 2506, 60 deg phase SURFACE , _ 29 -3,315 Stimulations & Treatments Bottom Min Top Max 8110 Top Depth Depth Depth Depth (TVD) (TVD) (RKB) (RKB) (RKB) (RKB) Type Dab Comment GAS LIFT, 1 14,670.0 14,690.0 5,573.8 5,587.0 FRAC 1/31/2009 FRAC T2 SAND - PLACED 180209# 16/20 3.788 CARBOLITE INTO FORMATION w/9ppa ON PERFS Notes: General & Safety End Date Annotation 1/24/2009 NOTE: " "PRE- PRODUCED INJECTOR "' f l 1/24/2009 NOTE: VIEW SCHEMATIC w /Alaska Sernatic9.0 9/13/2010 NOTE: CONVERTED FROM PRODUCTION TO INJECTOR CHEMICAL. I 7,586 7 SLEEVE -C, I I 14,225 1 H .. P98, 14.272 ` PACKER, 14,286 VALVE.14,306 NIPPLE, 14,306 WLEG. 14.344 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (RKB) (RKB) (°) Make Model (In) Sem Type Type On) (psi) Run Dab Com... 1 3,787.8 2,437.6 70.88 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 3/27/2009 IPERF, 2 7,585.6 3,492.6 76.12 CAMCO KBMG-LTS 1 Chemical DMY BK5 0.000 0.0 9/25/2010 14 67014690 FRAC, 14,670 PRODUCTION, 4 }[5,052 ikx TD, 15,OW
