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Home My WebLink About197-184Originated: Delivered to:9-Jul-24 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 # E SET# 1 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 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: T39146 T39147 T39148 T39149 T39150 T38151 T39152 T39153 T39153 T39154 181-173 181-065 201-248 223-038 197-184 214-138 210-181 196-096 182-161 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:03:51 -08'00' 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 197-184 T39150 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 1D-34 50-029-22975-00 200143_1D-34_CHC_02Aug2022 1D-36 50-029-22973-00 200130_1D-36_RBP_19Jul2023 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 _1E-12L1 50-029-20736-60 210004_1E-12_JetCutter_12Jun2022 210004_1E-12_MechCutter_06Jun2022 210004_1E-12_SBHPS-RBP-LDL_03Jun2022 2of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38317 T38318 T38321 T38322 T38323 T38324 T38325 T38326 T38327 T38328 2/29/2024 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:18:42 -09'00' Originated: Delivered to:20-Jun-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1D-135 50-029-22816-00 n/a Kuparuk River Packer Setting Record Field- Final 9-Jun-22 0 12 1F-03A 50-029-20853-60 907799903 Kuparuk River Multi Finger Caliper Field & Processed 9-Apr-22 0 13 1H-103 50-029-23593-00 n/a Kuparuk River Leak Detect Log Field- Final 3-Jun-22 0 14 1H-103 50-029-23593-00 n/a Kuparuk River Leak Detect Log Field- Final 4-Jun-22 0 15 1H-103 50-029-23593-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-22 0 16 1H-104 50-029-23610-00 n/a Kuparuk River Leak Detect Log Field- Final 6-Jun-22 0 17 1H-104 50-029-23610-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-22 0 18 2M-33 50-029-22816-00 n/a Kuparuk River Packer Setting Record Field- Final 15-May-22 0 19 3R-107 50-029-23660-00 n/a Kuparuk River Packer Setting Record Field- Final 20-May-22 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date: Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final 11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final 19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϭϵϳϭϴϰϬͲ^Ğƚ͗ϯϱϰϳϴBy Abby Bell at 2:10 pm, Aug 03, 2021 Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final 11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final 19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϭϵϳϭϴϰϬͲ^Ğƚ͗ϯϱϰϳϳBy Abby Bell at 2:10 pm, Aug 03, 2021 ! " # " $ %& ' ()! * '$ +, !- ."!! /, +, 01021*-1 3+ - " ' $ % $ 4 5 + 677 - 0 86 ' ) + - 9 8 2" : $ ' " %& ' $ , ' (" : ; "$, % $ ; ;)!< = ,=; '!!3 %& ! 6 ") ' % <>' ?'@ +/1*-(2/#*00A 6!<>' 6 ")!<"; " #> >&119(1 7B//21 !" #> #$ " $ ' )? $ #$ !" :7) %,B ,B),!$;!% 5)!44))! %"%&'(%)!"%*' 2 $ !0 ! ! A" >": A +8 01021*17021*7C020.9- " ; #4 <: '$+ ,%( *)' ' ': #$ : 9 ,-#./-0%$1/$2&$2!'.0$2"332 #$ 4.$56 567 -/ : 5+ '7 - !"#$%&''()*+, *+*-*(.)*+,-(.%/.(*%+ 0 %+ % % 4322.# 1#A1A 930101 " 91' By Samantha Carlisle at 1:18 pm, Aug 02, 2021 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳孻孱孳孵季孴孳孽孶孺孽孶孺孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶 Jan Byrne DSR-8/2/21 RBDMS HEW 8/3/2021 VTL 8/4/21 !""#" #! $ "!%& # '% ""'!%& ('!%& )) % ('!%&# ' #)#)"#"#"*(!$& ' ( " ('!%&#" (#+,#%#('!%& !#"* $ !$& ('!%& --- (#+,#%#( (!$&" -.% (#+#%#! $ * #"*#! #" "))# ' )! 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"#* ## ##"*"'!#"*! $ ##3#"*!$&(#( " .!.- -$.!%#" -.!-%1##%#! ! + '%456789:;< 4==9>?@ABC>9:6@7D Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 4,135.0 12/31/2004 1D-135 WV5.3 Conversion Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replace SOV & Replace Tbg Patches 7/21/2021 1D-135 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 40.6 Set Depth (ftKB) 5,000.0 Set Depth (TVD) … 4,366.3 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.0 Set Depth (ft… 4,167.9 Set Depth (TVD) (… 3,583.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.0 37.0 0.00 HANGER VETCO GRAY TUBING HANGER 2.992 2,110.3 2,004.3 38.33 PACKER ESP FEED-THRU PACKER, WEATHERFORD HYDROW II DUAL- STRING PACKER 3.250 4,078.2 3,500.2 21.74 DISCHARGE WELLLIFT DISCHARGE GUAGE UNIT (S/N: 12199200) 2.995 4,135.4 3,553.5 21.46 INTAKE TTC RECEIVING XO COUPLING w/ PERFORATED INTAKE (S/N: 1199081) 2.992 4,140.2 3,557.9 21.45 SEAL TANDEM SEAL SECTION (S/N: 12064503 / 12064727 ) 4,154.0 3,570.8 21.45 GEARBOX GEAR REDUCTION UNIT (S/N: 12177760) 11.42:1 4,155.8 3,572.5 21.45 MOTOR ESP MOTOR, 562MSP1, 60 hp/1240V/29 (S/N: 12059546) 4,164.1 3,580.2 21.45 GAUGE WELLLIFT GAUGE UNIT (S/N: 192-00827) 4,166.0 3,581.9 21.45 Centralizer MOTOR CENTRALIZER (P/N: C63569) Tubing Description GRAVEL PACK String Ma… 5.1 ID (in) 4.00 Top (ftKB) 4,219.4 Set Depth (ft… 4,629.7 Set Depth (TVD) (… 4,016.0 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 4,219.4 3,631.7 21.45 PACKER BAKER SC-1 GRAVEL PACK PACKER 4.000 4,223.3 3,635.3 21.45 MILLOUT MILLOUT EXTENSION 4.990 4,229.4 3,641.0 21.45 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,234.6 3,645.8 21.44 SLEEVE GRAVEL PACK SLIDING SLEEVE 3.480 4,236.3 3,647.4 21.43 SEAL BORE BAKER 3.25" SEAL BORE 3.250 4,278.1 3,686.4 21.16 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 4,338.3 3,742.5 20.80 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,340.5 3,744.6 20.79 PACKER BAKER SC-1L ISOLATION PACKER 3.875 4,343.8 3,747.7 20.78 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,349.0 3,752.5 20.76 SLEEVE GRAVEL PACK SLIDING SLEEVE 3.480 4,350.7 3,754.1 20.75 SEAL BORE BAKER 3.25" SEAL BORE 3.250 4,362.5 3,765.1 20.70 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 4,407.6 3,807.4 20.51 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,409.8 3,809.4 20.51 PACKER BAKER SC-1L ISOLATION PACKER 3.875 4,413.2 3,812.6 20.49 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,418.3 3,817.4 20.47 SLEEVE GRAVEL PACK SLIDING SLEEVE 3.480 4,420.0 3,819.0 20.46 SEAL BORE BAKER 3.25" SEAL BORE 3.250 4,451.6 3,848.6 20.33 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 4,511.6 3,904.9 20.09 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,513.8 3,907.0 20.08 PACKER BAKER SC-1L ISOLATION PACKER 3.875 4,517.2 3,910.1 20.06 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,522.3 3,915.0 20.04 SLEEVE GRAVEL PACK SLIDING SLEEVE 3.480 4,524.0 3,916.6 20.04 SEAL BORE BAKER 3.25" SEAL BORE 3.250 4,535.9 3,927.7 19.99 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 4,596.4 3,984.7 19.74 SEAL ASSY BANKER S-22 ANCHOR LATCH SEAL ASSEMBLY 82-40 3.281 4,597.6 3,985.7 19.73 PACKER BAKER FB-1 RETAINER PRODUCTION PACKER 4.000 4,600.0 3,988.0 19.72 NIPPLE BAKER CASING NIPPLE 4.410 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 1,978.5 1,898.3 34.51 PACKER-PATCH -UPPER 2.72" P2P (ME 1980.95' RKB) (UPPER PATCH PKR, SPACER PIPE, ANCHOR LATCH OAL 18.89') 7/21/2021 1.625 CPP35324 1,982.6 1,901.7 34.63 SPACER PIPE & ANCHOR LATCH 2-1/16" P-110 SPACER PIPE & ANCHOR LATCH 7/21/2021 1.620 CPAL35176 1,995.0 1,911.8 34.99 LEAK LDL FOUND LEAK AT 1995' 2/11/2019 2.992 1,996.5 1,913.1 35.04 PACKER-PATCH -LOWER 2.72" P2P (ME @1999' RKB) (4.01' OAL) 7/20/2021 1.625 CPP35323 2,203.5 2,076.0 41.07 PACKER-PATCH -UPPER 2.72" P2P (ME 2205.95' RKB) (UPPER PATCH PKR, SPACER PIPE, ANCHOR LATCH OAL 25.89') 7/19/2021 1.625 CPP35325 2,207.6 2,079.1 41.19 SPACER PIPE & ANCHOR LATCH 2-1/16" P-110 SPACER PIPE & ANCHOR LATCH 7/19/2021 1.620 CPAL35144 2,218.0 2,086.9 41.50 LEAK LEAK AT TOP OF STA.# 2 MANDREL. 6/16/2015 2,228.5 2,094.8 41.81 PACKER-PATCH -LOWER 2.72" P2P (ME 2231' RKB) (4.01' OAL) 7/19/2021 1.625 CPP35265 4,103.0 3,523.3 21.62 SLIP STOP 3-1/2" SLIP STOP (19" OAL) 7/11/2021 1D-135, 7/28/2021 11:44:16 AM Vertical schematic (actual) PRODUCTION; 40.7-5,000.0 PACKER; 4,597.6 IPERF; 4,542.0-4,598.0 SCREEN; 4,535.9 PACKER; 4,513.8 IPERF; 4,466.0-4,510.0 SCREEN; 4,451.6 PACKER; 4,409.8 IPERF; 4,370.0-4,408.0 SCREEN; 4,362.5 PACKER; 4,340.5 IPERF; 4,300.0-4,334.0 SCREEN; 4,278.1 PACKER; 4,219.4 GAUGE; 4,164.1 MOTOR; 4,155.8 INTAKE; 4,135.4 PCESP; 4,112.0 PACKOFF; 4,105.0 SLIP STOP; 4,103.0 DISCHARGE; 4,078.2 ESP MANDREL; 4,026.0 PACKER-PATCH-LOWER; 2,228.5 ESP MANDREL; 2,220.6 LEAK; 2,218.0 SPACER PIPE & ANCHOR LATCH; 2,207.6 PACKER-PATCH-UPPER; 2,203.5 PACKER; 2,110.3 PACKER-PATCH-LOWER; 1,996.5 LEAK; 1,995.0 ESP MANDREL; 1,986.1 SPACER PIPE & ANCHOR LATCH; 1,982.6 PACKER-PATCH-UPPER; 1,978.5 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) Rig Release Date 11/14/1997 1D-135 ... TD Act Btm (ftKB) 5,015.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292281600 Wellbore Status PROD Max Angle & MD Incl (°) 46.96 MD (ftKB) 2,809.65 WELLNAME WELLBORE1D-135 Annotation Last WO: End Date 5/7/2012 H2S (ppm) 10 Date 11/10/2014 Comment SSSV: NONE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 4,105.0 3,525.2 21.61 PACKOFF 3-1/2" D&D PACKOFF (92" OAL) 7/11/2021 4,112.0 3,531.7 21.58 PCESP 3-1/2" PCESP (OAL 23.14') 7/11/2021 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 4,300.0 4,334.0 3,706.8 3,738.5 WS D, 1D-135 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge 4,370.0 4,408.0 3,772.2 3,807.8 WS B, 1D-135 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge 4,466.0 4,510.0 3,862.1 3,903.4 WS A3, 1D-135 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge 4,542.0 4,598.0 3,933.5 3,986.2 WS A2, 1D-135 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge 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 1,986.1 1,904.5 34.73 CAMCO KBMG 1 ESP DMY BK-5 0.000 0.0 11/3/2019 Ext. PKG 2 2,220.6 2,088.8 41.57 CAMCO KBMG 1 ESP DMY BK- EXT PKG 0.000 0.0 5/11/2015 3 4,026.0 3,451.9 22.53 CAMCO KBMG 1 ESP SOV BK 0.000 0.0 7/19/2021 2000 # STS SOV Notes: General & Safety End Date Annotation 12/25/2007 NOTE: CENTRILIFT ESP CABLE TO 4160' - START HEAT TRACE @ -3000' 1D-135, 7/28/2021 11:44:17 AM Vertical schematic (actual) PRODUCTION; 40.7-5,000.0 PACKER; 4,597.6 IPERF; 4,542.0-4,598.0 SCREEN; 4,535.9 PACKER; 4,513.8 IPERF; 4,466.0-4,510.0 SCREEN; 4,451.6 PACKER; 4,409.8 IPERF; 4,370.0-4,408.0 SCREEN; 4,362.5 PACKER; 4,340.5 IPERF; 4,300.0-4,334.0 SCREEN; 4,278.1 PACKER; 4,219.4 GAUGE; 4,164.1 MOTOR; 4,155.8 INTAKE; 4,135.4 PCESP; 4,112.0 PACKOFF; 4,105.0 SLIP STOP; 4,103.0 DISCHARGE; 4,078.2 ESP MANDREL; 4,026.0 PACKER-PATCH-LOWER; 2,228.5 ESP MANDREL; 2,220.6 LEAK; 2,218.0 SPACER PIPE & ANCHOR LATCH; 2,207.6 PACKER-PATCH-UPPER; 2,203.5 PACKER; 2,110.3 PACKER-PATCH-LOWER; 1,996.5 LEAK; 1,995.0 ESP MANDREL; 1,986.1 SPACER PIPE & ANCHOR LATCH; 1,982.6 PACKER-PATCH-UPPER; 1,978.5 CONDUCTOR; 41.0-121.0 KUP PROD 1D-135 ... WELLNAME WELLBORE1D-135 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 22 3 2020 AOGCC 197184 32794 13 -Mar -20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Date: \J/ ,t "v Signed: WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 2M-07 50-103-20178-00 906173399 Kuparuk Plug Setting Record Final -Field 14 -Dec -19 0 1 2 1D-04 50-029-20429-00 906174414 Kuparuk Packer Setting Record Final -Field 16 -Dec -19 0 1 3 1A 01 50-029-20590-00 906236618 Kuparuk Packer Setting Record Final -Field 24 -Jan -20 0 1 4 1A 15 50-029-20711-00 906270889 Kuparuk Packer Setting Record Final -Field 26 -Jan -20 0 1 5 1A-17 50-029-22102-00 906333945 Kuparuk Packer Setting Record Final -Field 21 -Feb -20 0 1 6 1B-04 50-029-20595-00 906221237 Kuparuk Packer Setting Record Final -Field -2 4-Jan0 0 1 7 8-1a n-20 8 1D-130 50-029-22815-00 906340407 West Sak Packer Setting Record Final -Field 10 -Mar -20 0 1 9 1D-135 50-029-22816-00 906236619 West Sak Packer Setting Record Final -Field 14 -Jan -20 0 1 10 15-1a n-20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Date: \J/ ,t "v Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 2 1 2020 An(;rr 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ pera wns u own ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate E] V'fL Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ •erforate New Pool ❑ Repair Well F1{ Re-enter Susp Well ❑ Other: Tubing patch ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ Stratigraphic ❑ Servioe ❑ 197-184 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-22816-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1D-135 ADL0025650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10, Field/Pool(s): Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5,015 feet Plugs measured None feet true vertical 4,381 feet Junk measured None feet Effective Depth measured 4,135 feet Packer measured )84, 2000, 2207, 22: feel true vertical 3,554 feet true vertical )03, 1916, 2079, 20! feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 15 121' MD PRODUCTION 4,959 feet 9 5,000' MD Tubing (size, grade, measured and true vertical depth) 5.0 " 0 4,596' MD 3,985' TVD Packers and SSSV (type, measured and true vertical depth) PATCH - 2.725" P2P (CPP35193) W/ SI 1,984' MD 1,903' TVD PATCH - 2.725 P2P (CPP35224) DAL 4 2,000' MD 1,916' TVD PATCH - 2.725" P2P (CPP35032) W/ SI 2,207' MD 2,079' TVD PATCH - 2.725 P2P CPP35036) DAL 4 2,232' MD 2,097' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 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 Lij 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 Numb I' r I if C.O. Exempt: Contact Name: Jan Byrne / Dusty Freeborn Authorized Name: Jan Byrne Contact Email: N1617@conocophillips.com Authorized Title: Well Integrity & Compliance Specialist Contact Phone: 907-659-7224 Authorized Signature: —� � Date: 1/18/20 RBDMS 1'�JAN 2 3 2020 Form 10-404 Revised 4/2017 Submit Original Only 11/22/19 12/21/19 01/1 1D-135 DESCRIPTION OF WORK COMPLETED SUMMARY 1 D-135 Had been shut in since 12/13/18. The well failed a subsidence compliance MITIA on 2/9/19 and a downhole plug was set to secure the well for long term shut in. The DPE then determined in November 2019 that the well met metrics to be patched and an LDL located a tubing leak at 1995'. A 16' length, 3.5", P213 retrievable patch was set over the leak. During the AnnComm patch installation the existing C -sand patch was required to be pulled and reset to access the ESP. The pertinent well work is copied below. BASELINE PASS FROM SURFACE TO 2190' AND MAIN PASS FROM TOP OF PLUG @ 2190' TO SURFACE AT 120FPM WHILE LRS PUMPED 2BPM @ 900PSI. PERFORMED STATION SURVEYS @ 1970' AND 2050'. FOUND LEAK AT 1995' JUST BELOW GLM AT 1986'. LOGGED CALIPER FROM 2190' TO SURFACE @ 35FPM. PERFORMED REPEAT PASS FROM 300' TO SURFACE. PULLED DV @ 1966RKB; PULLED . 0 @ 2190' RKB; PULLED WFT WP PATCH ASSEMBLY (UPPER/LOWER) @ 2204' RKB; ATTEMPT TO LATCH SLIP STOP & ENCOUNTER FILL @ 4085' RKB' BAILED FILL @ SAME IN PROGRESS. SET UPPER 2.72" P2P & SPACER PIPE ANCHOR LATCH ASSEMBLY (CAL 25'11" / S#CPP35032 / S#CPAL35121) @ 2206' RKB; SET TEST TOOL @ SAME & OBTAIN PASSING CMIT TO 2500; SET LOWER 2.72" P2P (S#CPP35224) @ 2000' RKB; OBTAIN PASSING CMIT TO 2500 W/ TEST TOOL @ SAME; SET UPPER 2.72" P2P W/ SPACER PIPE ANCHOR LATCH ASSEMBLY (CAL 20'/ S#CPP35193 / S#CPAL35131) @ 1984' RKB; LRS PERFORM MIT -IA TO 2500 (PASS). JOB COMPLETE. INITIAL T/IA = 475/500, TAKES 3 BBLS TO PRESSURE UP, STARTING = 2525/2500, AFTER 15 MINS HAVE TO BUMP UP, STARTING = 255012550,15 MIN = 2500/2500, 30 MIN = 2475/2475 INITIAL T/IA = 700/700,TAKES 2 BBLS TO PRESSURE UP, HAVE TO BUMP UP, STARTING = 2550/2550 15 MIN = 2500/2500 30 MIN = 2475/2475 MITIA Pre T/1= 700/1075. Initial T/1= 750/2510.15 min T/1= 740/2400. 30 min T/1= 740/2375. ConocoPhillips KUP PROD WELLNAME 1D-135 WELLBORE 1D-135 Alaska, InG. mass, m..:DE SEPJ Perforations & Slots ven4al.emmMx pe1�n Top B1m ToplrvDl (IIK8 elmlrv0l 13,73 LD,I zone snot Den Ienasln 1 TVp� Com ---"-� HMN'ER; ]]0 4,300.0 300 334 4.3340 3,706.8 3,]38.5 9D, 1045 199 1/1111998 12 1PERF SOS 4.5"UldaPak; TCP M! CONq.CTOR: 41.6120 RDX Ch9l9a 4,370.0 4.4080 3,772.2 3,607.0. 5 ,1D-135 1/11/1998 1201PERF SOS 4.5" UItFaPak; TCP RDX Charge 4,466.0 4,510.0 3,062.1 3.903.4 7SA&1D-135 1111/1998 12.0 IPERF 5054.5'UlkaPak-,TCP RDX Ch.TO PATCH; I.SGO 4,542.0 4,590.0 3.933.5 ],906.2 WSA2. 11-135 iltt/1998 12.0 IPERF 5054.5"UIVaPak', TCP ESP MAR9REb.1.946.1 RDX Chdl9a SPACEIR PIPE: Less0 Mandrel inserts L�1.°�0 PATCH IN°0 &1 tl To Valve latch Po TRO Nun N Top(RIt91 ('R.) Mahe MO O°Ilnl $ery Tye p Type (Per,(Per,Ran Date Com 1 1.906.1 1.90d.5 T.W A MCO G MG 1 ESP DMY BWS Dun) O 0.000 0.0 11/3/2019 Ext PACKER: 31 ,1'1 PKG PATON: 2270 2 2,220.6 2080.8 CAMCO KBMG 1 ESP DMY BW D.000 0.0 51112015 EXT SPACE. PIPE 22110 PKG ESP WNDREL: E.S 3 4,0260 3,4519 CAMCO ROME 1 ESP SOV BK 000) 0.0 12/2412019 20004 PATCH: 22320 STS 50V Notes: General & Safety ESP IMNDiEI a.@fi.0 .1..1. 1 Rnnomuon 1025/2007 NOTE: CEWRILIFT ESP CABLE TO 41W- START HEAT TRACE @-3000' DISCHARGE: 4,075] SLIP STOP, 4.Z DBD PACKOFFASSEMBLY; 4.1aso PCESP: 4.11Z0 INrAKE<.13°.4 .M 4.14Dz GE44B 4.'E10 MOTOR; 4158 SI 4.181.1 Ce..; 9,108.0 I PACKER; 4.2184 MILLBT; Y S 4. SBO: I.T9. 4 sLEEVE;4,12Rb SEAL BORE: 4,953 SCREEN;9,P8,1 IPERF: 43D364,34.0- b°RAXNB PACKER: 4.311 a BR; 4.13. SLEEVE: 4,315. sE/,L BORE 4,TA.] SCREEN: 4.353. IPERF, 4,3M... SBR: 4.4079 PACKEF;4,4098 SSR:4A13.1 SLEEVE; 44183 ..LBORE', 4.421° SCREEN: 4,431. IPERF; MEEP4,510°- SBR; 4511. PACKER 4,5118 SBR; 4, S'2- 1]2 - SLEEVE: 4522.3 SEAL BORE 4.WaA SCREEN', 451`9 IPERF: 4.SIi.P4.599.0 SFPL ASSY; 4.596a PACKER: 4,597.6 NIPPLE. 4.600.0 - .600.0PRODUCTION: PRO D.,.R40.]4,01 0- ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 18, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7ch Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 1D-135 (PTD 197-184) for tubing patch repair. Please contact Dusty Freeborn or me at 659-7224 if you have any questions. Sincerely, < z 04—L-1 Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC K ATTN: Natural Resources Technician II Alaska oil & Gas Conservation Commision 333 W. 7th Ave, Suite loo -„y Anchorage, AK 99501 197184 TRANSMITTALDATE TRANSMITTAL# �r •� nt Please return via courier or sign/scan and email a copy Date lumberger and CPAL Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. 197184 30379 WELL LOG TRANSMITTAL #905483036 To: Alaska Oil and Gas Conservation Comm. February 13, 2019 Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Set Record: 1D-135 Run Date: 2/11/2019 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 ID -135 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22816-00 RECEIVED FEB 19 2019 AOGCC 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: VZO69 Signed: STATE OF ALASKA A OIL AND GAS CONSERVATION COMKSION REPORT OF SUNDRY WELL OPERATIONS QCT 6' 1 2`15 1. operations Abandon " Plug Perforations r Fracture Stimulate " Pull Tubing " c�4erii ow n I` Performed: Perforate Suspend p � r Other Stimulate IV j Alter Casing � Change Appro�e{i Program Rug for Redrill Repair Well ,`""`/ Other Set etch I✓ Perforate New Pool Re-enter Susp Well V-rito 2. Operator Name: 4. Well Class Before Work: 5. Permit to brill Number: ConocoPhillips Alaska, Inc. Development Exploratory j" Stratigraphic �"'" Service �"" 197-184 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22816-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 KRU 1D-135 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5015 feet Plugs (measured) none true vertical 4381 feet Junk (measured) none Effective Depth measured 4872 feet Packer (measured) 2110, 4219, 4341, 4410, 4514, 4598 true vertical 4245 feet (true vertical) 2004, 3632, 3745, 3809, 3907, 3986 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 4959 7.625 5000 4366 Perforation depth: Measured depth: 4300-4334, 4370-4408, 4466-4510, 4542-4598 'v True Vertical Depth: 3707-3739, 3772-3808, 3862-3903, 3934-3986' Tubing (size, grade, MD, and TVD) 3.5, L-80, 4168 MD, 3584 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED-THRU PACKER, WEATHERFORD HYDROW II DUAL -STRING PACKER @ 2110 MD and 2004 T PACKER - BAKER SCA GRAVEL PACK PACKER @ 4219 MD and 3632 TVD PACKER - BAKER SCA L ISOLATION PACKER @ 4341 MD and 3745 TVD PACKER - BAKER SCA L ISOLATION PACKER @ 4410 MD and 3809 TVD PACKER - BAKER SCA L ISOLATION PACKER @ 4514 MD and 3907 TVD PACKER - BAKER FBA RETAINER PRODUCTION PACKER @ 4598 MD and 3986 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): no stimulation or cement squeeze during this operation 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 32 1 34 -- 169 Subsequent to operation 150 3 104 -- 172 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Exploratory r- Development r Service r Stratigraphic Daily Report of Well Operations W' Copies of Logs and Surveys Run [ 16. Well Status after work: Oil r Gas WDSPL Printed and Electronic Fracture Stimulation Data "` GSTOR j- WINJ r WAG j` GINJ r— SUSP r— SPLUG r- 17. 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NSA if C.O. Exempt: none Contact John Peirce (a) 265-6471 Email John.W.Pierce(cy)conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone: 265-6471 Date � s lalz/�5 Form 10-404 Revised 5/2015 RBDMS)IUL I 0 1 201 Submit Original Only KUP PROD . 1D-135 ConocoPhillips Alaska.Inc. c..,�.ildlepa ID-135,9/7/2015 4.25.48 PM • Vertical schematic(actual) HANGER;37.0- t RR I t L # Mandrel Inserts CONDUCTOR;41.00.121.0OH`p, onTop(ND) Valve Latch Port Size TRO Run N Top(NAB) (NAB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 1,986.1 1,904.5 CAMCO KBMG 1 ESP DMY BK-5 0.000 0.0 5/6/2012 2 2,220.6 2,088.8 CAMCO KBMG 1 ESP DMY BK- 0.000 0.0 5/11/2015 ESP MANDREL;1,986.1 1 EXT PKG 3 4,026.0 3,451,9 CAMCO KBMG 1 ESP SOV BK 0.000 0,0 7/24/2015 20009 PACKER;2,110.3 ;;U.'f:.. TBG SHR Notes:General&Safety End Date Annotation PATCH;2,204.0., 12/25/2007 NOTE:CENTRILIFT ESP CABLE TO 4160'-START HEAT TRACE @-3000' ESP MANDREL;2,220.6 3 r. 12/27/2007 NOTE:WORKOVER 1/12/2011 NOTE:View Schematic w/Alaska Schematic9.0 ESP MANDREL;4,026.0 DISCHARGE;4,078.2 TBS STOP;4,085.0 LT PACKOFF;4,086.0 11E PCESP;4,094.0 INTAKE;4,135.4 Imo_ SEAL;4,140.2 GEARBOX;4,154.0 MOTOR,4,155.8 GAUGE,4,164.1 Centralizer,4,166.0 ' PACKER;4,219.4 MILLOUT;4,223.3 SBR;4.229.4 SLEEVE;4,234.6 ' SEAL BORE;4,236.3 .. 1111 SCREEN,4,278.1, 11111 IPERF;4,300.0-4,334.0- SBR;4,338,3 PACKER,4,340.5 SBR;4,343.8 SLEEVE;4,349.0 SEAL BORE,4,350.7 SCREEN,4,3625 - - IPERF;4,370.0-4,408.01 SBR,4,407.6 PACKER,4,409.8 ;IMF. ^ . SBE;4,413.1 ! � SLEEVE;4,418.3 SEAL BORE;4,420.0 SCREEN,4,451.6 IPERF;4,466.0.4,510.03 SBR;4,5110 PACKER;4,513.8 _• I: SBR;4,517.2 SLEEVE;4,522.3 - SEAL BORE,4,524.0 SCREEN,4.5359 IPERF;4,542.0-4,598.0• SEAL ASSY;4,596.4 rri PACKER;4597.6 NIPPLE;4,600.0 I PRODUCTION;40.7-5,000,0- 1 D-135 eL WORK SUMMARY 111 DATE SUMMARY 5/4/2015 (AC EVAL) MITIA PASSED TO 1510 PSI, IA DDT FOR BUR. 5/10/2015 DRIFTED TBG. W/2.5" BAILER &TAGGED SLIP STOP @ 4085' RKB. 5/11/2015 REPLACED DV @ 2200' RKB W/ EXTENDED PACKING DV; W/ HOLEFINDER APPEARS LEAK IS IN PUMP JOINT ABOVE GLM @ 2220' RKB. JOB SUSPENDED AWAITING NEW PROCEDURE. 6/16/2015 RAN LDL TO IDENTIFY LEAK @ 2,218.5' RKB LEAK APPEARS TO BE COLLAR AT TOP OF STA.#2 MANDREL. 7/24/2015 PULLED 3 1/2 SLIP STOP @ 4085' RKB; DEPLOY AVA CATCHER& REPLACE SOV IN KIND @ 4026' RKB; PULLED CATCHER & 3 1/2 D&D PACKOFF ASSEMBLY; FISH ELEMENT FROM TOP OF ESP @ 4094' RKB; PULLED 3 1/2 PCESP @ 4094' RKB (ESP LOADED W/SAND &W/SOME STATOR RUBBER IN DISCHARGE HEAD). IN PROGRESS. 7/25/2015 BRUSH n' FLUSH PATCH INTERVAL @ 2218' RKB; RAN 3 1/2 ROTATIONAL TEST TOOL CONFIRM MOTOR GOOD (ALL PINS SHEARED) . IN PROGRESS (READY TO SET NEW ESP ONCE PATCH IS READY) 7/29/2015 SET 41'4"x 3 1/2" PCESP @ 4094' RKB; SET 3 1/2" PACKOFF @ 4086' RKB & 3 1/2" SLIPSTOP @ 4085' RKB. (READY FOR PATCH). IN PROGRESS. 7/31/2015 SET 2.72"WEATHERFORD LOWER PACKER W/MIDDLE ELEMENT @ 2231' RKB.SET 2.72"WEATHERFORD UPPER PACKER W/MIDDLE ELEMENT @ 2214' RKB.SET 3.5" TEST TOOL.LRS PERFORMED MIT-T TO 2000 PSI,PASSED.WELL READY TO POP. 8/4/2015 PUMP 20 BBL DIESEL DOWN TBG FORA FREEZE PROTECT UNABLE TO PRESSURE UP ON TBG. TURN WELL OVER TO DSO. JOB IN PROGRESS 8/26/2015 MADE THREE ATTEMPTS W/ LDL,RECONFIGURED TOOL STRING EACH RUN.KEPT SETTING DOWN @ 2211' RKB...JOB IN PROGRESS. 8/27/2015 RAN 1.50" CENT DOWN TO 2300' SLM.SAW NO RESTRICTIONS.RAN 1.70" GAUGE RING,S/D @ 2175' SLM.UNABLE TO WORK THRU.RAN 3.5" BLB W/ 1.75" LIB.RECOVERED ON LOW SIDE, LIP ROLLED UP..JOB IN PROGRESS. 9/2/2015 RAN MEMORY LDL TO 4050' RKB. DATA SHOWED LOWER PATCH PACKER APPEARED TO BE LEAKING. JOB IN PROGRESS. 9/3/2015 PULLED WFT 2.72" UPPER PACKER W/SPACER PIPE & SNAP LATCH FROM 2211' RKB.PULLED WFT 2.72" LOWER PACKER FROM 2228' RKB. TAGGED SLIPSTOP W/ 2.75" CENT, 3 1/2" BRUSH, 2.5" GAUGE RING @ 4085' RKB. BRUSHED PATCH SET AREA FROM 2000'-2400' SLM FOR 20 MIN (NO RESTRICTIONS OBSERVED). *JOB IN PROGRESS 9/4/2015 LRS PUMPED 30 BBLS OF 130* DIESEL TO WARM UP TBG.SET 2.72"WFT LOWER WIDEPAK PACKER @ 2233' RKB.SET 2.72"WFT UPPER PACKER W/SPACER PIPE & SNAP LATCH @ 2208' RKB...JOB IN PROGRESS.. UPPER PKR SN: CP 3500159 SNAP LATCH SN: CPS 35007? LOWER PKR SN: CP 350050 9/5/2015 RAN 3.5"TEST TOOL TO TOP OF PACKER @ 2208' RKB.LRS PERFORMED MIT-T TO 2000 PSI.MADE SEVERAL ATTEMPTS,FAILED,APPEARS CAT VALVE LEAKING. POOH & LET LRS TIE INTO TREE CAP & PERFORM MIT-T TO 1000 PSI.PASSED.DSO BROUGHT WELL ON LINE TO VERIFY ESP SURFACING FLIID....WELL READY TO POP... XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. lq?-/77 File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Odginai- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type 'OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned by: ~ver~ MildredDaretha ~ Lowell Date: -~/~-~ Is/ TO RE-SCAN Notes: Re-Scanned by: ~ve~ Mildred Daretha Nathan Lowell Date: /si • STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMN0111)ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug FFrforations r Perforate E Other E Alter Casing r PuII Tubing r Stimulate - Frac J"" Waiver r Time Extension Change Approved Program E Operat. Shutdow n 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 p Exploratory r 197 -184 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r ' Service 50 029 - 22816 - 00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 ` -- 1 D -135 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5015 feet Plugs (measured) 2279 true vertical 4381 feet Junk (measured) None Effective Depth measured 4872 feet Packer (measured) see list below true vertical 4245 feet (true vertucal) see list below Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 4959 7.625 5000 4366 5{ANIVED O 3 2012 RECEIVED MAY 3 0 2012 Perforation depth: Measured depth: 4300 -4334, 4370 -4408, 4466 -4510, 4542 -4598 n/� True Vertical Depth: 3707 -3739, 3772 -3808, 3862 -3903, 3934 -3986 AOGCC Tubing (size, grade, MD, and TVD) 3.5, L -80, 4168 MD, 3584 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED -THRU PACKER, WEATHERFORD HYDROW II DUAL - STRING PACKER @ 2110 MD and 2004 PACKER - BAKER SC -1 GRAVEL PACK PACKER @ 4219 MD and 3632 TVD 3 BAKER SC-1L ISOLATION PACKERS @ 4340, 4410, 4514 MD and 3745, 3810, 3907 TVD PACKER - BAKER FB -1 RETAINER PRODUCTION PACKER @ 4598 MD and 3986 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 83 6 56 -- 168 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development fro - Service r Stratigraphic r 16. Well Status after work: Oil jai - Gas f VVDSPL r Daily Report of Well Operations XXX GSTOR VVINJ r WAG r GINJ r SUSP r 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: none Contact Ian Toomey Cad 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature Phone: 263 1 Date 2 Form 10 -404 Revised 11/2011 f MAY 3 0 201 C Submit Original Only 4 )•17,.._. 6.q In -1-- " € KUP 1D-135 Conoco Phillips illi Well Attributes Max Angle & MD TD Aldsha.I1V. Wellbore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292281600 WEST SAK PROD 46.96 2,809.65 5,015.0 "° Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date ' SSSV: NONE 10 9/26/2011 Last WO: 5/7/2012 11/14/1997 Well Confin - 1D-135 5/23/2012 7:58:29 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: 4,135.0 12/31/2004 Rev Reason: WELL REVIEW osborl 5/23/2012 HANGER, 37 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR ' CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H WELDED 41 - 121 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 5/8 6.875 40.6 5,000.0 4,366.3 29.70 L -80 BTC -MOD Tubing Strings Tubing Description String 0 String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ESP F ' TUBING WO 3 1/2 2.992 37.0 4,167.9 3,583.7 9.30 L -80 EUE8RDMOD MANDREL, Completion Details 1,986 11111111 Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (!n) PACKER. 2,110 37.0 37.0 -0.14 HANGER VETCO GRAY TUBING HANGER 2.992 NM 2,110.3 2,004.1 38.31 PACKER ESP FEED -THRU PACKER, WEATHERFORD HYDROW II 3.250 ESP DUAL-STRING PACKER MAN D, f - 4,078.2 3,500.2 21.45 DISCHARGE WELLLIFT DISCHARGE GUAGE UNIT (S/N: 12199200) 2.995 CATCHER, 4,135.4 3,553.5 21.45 INTAKE TTC RECEIVING XO COUPLING w/ PERFORATED INTAKE (S /N: 2.992 2,269 I A4<I 1199081) . . PLUG, 2,279 .•. 4,140.2 3,557.9 21.45 SEAL TANDEM SEAL SECTION (S/N: 12064503 / 12064727 ) ESP t 4,154.0 3,570.8 21.45 GEARBOX GEAR REDUCTION UNIT (S/N: 12177760) 11.42:1 MAN 4.026 _ 4,155.8 3,572.5 21.45 MOTOR ESP MOTOR, 562MSP1, 60 hp/1240V/29 (S/N: 12059546) 4,164.1 3,580.2 21.45 GAUGE WELLLIFT GAUGE UNIT (S/N: 192- 00827) MN DISCHARGE, 4.078 4,166.0 3,581.9 21.45 Centralizer MOTOR CENTRALIZER (P /N: C63569) _ Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK 5.1 4.000 4,219.4 4,629.7 4,016.1 INTAKE, 4,135 -F- -._ Completion Details SEAL, 4,140 Top Depth GEARBOX,_ r 4,154 (TVD) Top Inc! Nomi... MOTOR, 4,156 (C`� I Top (ftKB) (ftKB) (1 Item Description Comment ID (in) GAUGE, 4,164 ( °"='I 4,219.4 3,631.7 21.45 PACKER BAKER SC - 1 GRAVEL PACK PACKER 4.000 Centralizer, I I 4.166 4,223.3 3,635.3 21.45 MILLOUT MILLOUT EXTENSION 4.990 PACKER, 4,219 :,,,::1' 4,229.4 3,641.0 21.45 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,223 - - - - -- '�'� i 596. 4.229 - 7. 4234.6 3,645.8 21.23 SLEEVE GRAVEL PACK SLIDING SLEEVE 3.480 4,236.3 3,647.4 2122 SEAL BORE BAKER 3.25" SEAL BORE 3250 SLEEVE, 4,235 : ■ • SEAL BORE, ' - - 4,278.1 3,686.4 21.05 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 4,236 l 4,338.3 3,742.5 20.80 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,340.5 3,744.6 20.79 PACKER BAKER SC -1L ISOLATION PACKER 3.875 4,343.8 3,747.7 20.78 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,349.0 3,752.5 20.76 SLEEVE GRAVEL PACK SLIDING SLEEVE 3.480 4,350.7 3,754.1 20.75 SEAL BORE BAKER 3.25" SEAL BORE 3.250 . -� 4,362.5 3,7652 20.70 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 SCREEN, 4,278 a,3ooPa 3 P3ti 4,407.6 3,807.5 20.51 SBR BAKER SEAL BORE RECEPTACLE 3.250 �� 4,409.8 3,809.5 20.51 PACKER BAKER SC-1L ISOLATION PACKER 3.875 SBR, 4.338 PACKER, 4,340 ,..,,., 4,413.2 3,812.7 20.49 SBR BAKER SEAL BORE RECEPTACLE 3250 SBR. 4,344 ; 4,418.3 3,817.5 20.47 SLEEVE GRAVEL PACK SLIDING SLEEVE 3.480 SLEEVE. 4,349 ■?. 4,420.0 3819.1 20.46 SEAL BORE BAKER 3.25" SEAL BORE 3250 SEAL BORE, 4,451.6 3,848.7 20.33 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 4,511.6 3,904.9 20.09 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,513.8 3,907.0 20.08 PACKER BAKER SC -1L ISOLATION PACKER 3.875 4,5172 3,910.1 20.06 SBR BAKER SEAL BORE RECEPTACLE 3.250 SCREEN, 4,362 =�� 4,522.3 3,9152 19.61 SLEEVE GRAVEL PACK SLIDING SLEEVE 3480 4,370440ti - age M 4,524.0 3,916.8 19.60 SEAL BORE BAKER 3.25" SEAL BORE 3.250 SBR. 4.406 4,535.9 3,927.9 19.57 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 PACKER. 4.410 - - 4,596.4 3,984.8 19.42 SEAL ASSY ' BANKER S-22 ANCHOR LATCH SEAL ASSEMBLY 82 -40 3281 SBR, 4,413 . �x 4,597.6 3,985.9 19.41 PACKER BAKER FB RETAINER PRODUCTION PACKER 4.000 SLEEVE, 4,416 SEAL BORE, 4,600.0 3,988.2 19.41 NIPPLE BAKER CASING NIPPLE 4.410 T. 4,420 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Inc! Top (ftKB) (ftKB) (1 Description Comment Run Date ID (in) 2,269.0 2,124.6 42.73 CATCHER CATCHER SET ON TOP OF PLUG 5/6/2012 0.000 2,279.0 2,131.9 42.93 PLUG WRP 5/6/2012 0.000 SCREEN, 4,452 Perforations & Slots 4.4664,5 IPER F, ' =- Shot ♦-♦ Top (ND) Btm (TVD) Dens 888, 4,512 = Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date )eh-- Type Comment PACKER, 4,514 4,300.0 4,334.0 3,706.8 3,738.5 WS D, 1D 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge SBR, 4,517 Mk 4,370.0 4,408.0 3,772.2 3,807.8 WS B, 1D - 135 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge SLEEVE, R - SEAL BORE. 4,466.0 4,510.0 3,862.2 3,903.4 WS A3, 1D 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge E, 4,524 4,542.0 4,598.0 3,933.7 3,986.3 WS A2, 1D -135 1/11/1998 12.0 IPERF SOS 4.5" UltraPak; TCP RDX Charge Notes: General & Safety End Date Annotation 12/25/2007 NOTE: CENTRILIFT ESP CABLE TO 4160' - START HEAT TRACE @ -3000' SCREEN, 4,536 �� 12/27/2007 NOTE: WORKOVER IPERF, ��.1 1/1 2 / 2 0 11 NOTE Vi S w / Al as k a Schematic9.0 SEAL _ EAL 4596 , - � 4596 _ ` __` Mandrel Details PACKER, 4,598 Port ■ P Top Depth Top Size TRO Run (TVD) Intl OD Valve Latch NIPPLE, 4,600 • I Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 1,986.1 1,903.9 34.74 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/6/2012 PRODUCTION. 2 2,220.6 2,088.8 41.77 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/6/2012 415,000 TD. 5,015 •., A 3 4,026.0 3,451.9 22.53 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/6/2012 • • Conac ©Phillips Time Log & Summary WelNiew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/1/2012 8:00:00 AM Rig Release: 5/6/2012 11:00:00 PM Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 05/01/2012 24 hrSummary MIRU. Accept Rig. Load Plts w/3 %KCL -Sea Water. Pull BPV. Kill Well. Install BPV. ND Tree. Install Blanking Plug. NU BOP Stack. Start the initial BOPE Test. 05:00 06:00 1.00 MIRU MOVE MOB P Move from 1D-129 to 1D-135, pull over and set down. Found floor kit on 1 D-10 would not allow cuttings box to be place where needed. This was not captured on the pad prep for 1D Called Jim McPhetridge to have civil crew come and remove floor kit. 06:00 09:00 3.00 MIRU MOVE RURD P Continue to RU Nordic 3 on 1D-135, RU hard line to kill tank w/ KDTH, while rig crew tied into well for well kill purposes. Load lubricator and Centrilift Tote. 09:00 11:00 2.00 MIRU MOVE RURD T Civil crew arrived on location and removed floor kit. Loader attempted to set cuttings box, but was not able to get under cuttings chute. Dig out frozen gravel berm and was able to set cuttings box. Accept Nordic rig 3 at 08:00 hrs 11:00 12:00 1.00 COMPZ WELCTI MPSP P PJSM, Lubricate out BPV - IA @ 50 psi, TBG @ 40 psi. Begin loading pits w/ 230 bbls of 3% KCL sea water. 12:00 13:00 1.00 COMPZ WELCTL PRTS P PJSM, PT kill lines to kill tank at 250 / 3,000 psi - good test. Page 1 of 8 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:30 1.50 COMPZ WELCTL KLWL P Bleed gas from IA and TBG to kill tank. Begin pumping 165 °F 3% KCL Sea water down IA at 2 bpm at 130 psi w/ 50 psi back pressure at full open choke taking returns to kill tank. Had circulation after 9 bbls pumped thru TTC Intake at 4,139 -ft, increase to 2.5 bpm at 150 psi w/ 60 psi back pressure at full open choke. Increase to 3 bpm and returns began slugging, shut down rig pump and continue to fill hole w/ charge allow gas to break out at tank. Max back pressure seen was 160 psi, with 60 psi charge pump pressure. Bring pump back on line after back pressure began to decrease to 80 psi. Continue to reverse circulate for a total of 200 bbls with 190 bbls recovered. 95% of returns. 14:30 15:00 0.50 COMPZ WELCTL OWFF P Load Pits with remaining 165 °F 3% KCL Sea water while monitoriing well for flow - Slight vac on TBG and IA. 15:00 16:00 1.00 COMPZ WHDBO MPSP P Dry Rod BPV and Lay down dry rod. 16:00 17:00 1.00 COMPZ WHDBO NUND P PJSM, ND Vetco ESP Tree and hang in cellar. 17:00 18:00 1.00 COMPZ WHDBO NUND P PJSM, Install blanking plug and NU 11" 5M Class III stack with Weatherford Safety Tension Adapter. RU Kill and Choke lines, along with setting of riser. 18:00 23:00 5.00 COMPZ WHDBO BOPE T Attempt to shell test BOPE for the initial BOP test. However, have a high pressure leak. Trouble shoot surface equipment. Observe no surface leaks. Isolate Pump and Well Control Equipment. Found no problems. Call -out Vetco -Gray Service Hand. Pull Blanking Plug and found a bad Poppet Valve 0-Ring. Replace and install Blanking Plug. Repeat shell test. Good test. 23:00 00:00 1.00 COMPZ WHDBO BOPE P Begin the initial BOPE test per ConocoPhillips /AOGCC requirements at 250/3,000 psi. X5/02/2012 Continue with the Initial BOPE Test. Chase a high pressure leak during the Annular test. Replace the Upper and the Lower U -Seals on the Annular Piston. Prep to continue testing the Annular. 00:00 09:30 9.50 COMPZ WHDBO BOPE P Continue with the initial BOPE Test per ConocoPhillips /AOGCC requirements at 250/3,000 psi. (Note: Shoot Fluid Level at 300 -ft @ 01:00 hrs). 09:30 09:45 0.25 COMPZ WHDBO SFTY T Held PJSM on changing out Hydril 11" GKA 5M Element with rig crew. Page 2of8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 13:00 3.25 COMPZ WHDBO RGRP T ND Riser and Adapter. NU Annular cap removal tool and unscrew Annular cap. Remove element and prep for replacement. Replace Element and Nipple up Annular components, Nipple Up Riser. Rig not on downtime from (09:30 hrs to 13:00 hrs) as per Nordic, due to stripping through the element on 1 D -134 during clean out of liner. 13:00 18:00 5.00 COMPZ WHDBO BOPE T Continue with the initial BOPE Test per ConocoPhillips /AOGCC requirements at 250/3,000 psi. Still continue to chase a high pressure drop when testing the Annular with either the 3 1/2" or the 2 7/8" Test Joints. Close Blind Rams. Test the Blanking Plud against the Blind Rams. Solid test. Rig went on down time as of 13:00 hrs 18:00 00:00 6.00 COMPZ WHDBO BOPE T Continue to trouble shoot the Annular. Determined that pressure was leaking by the Piston Lower U -Seals and bleeding back into the Koomey hydraulic tank. Hold PJSM. Bleed pressure from the Koomey Unit and Lock - out/Tag -out. Nipple down Riser and nipple down Annular components. Pull the Piston. Replace both the Lower and the Upper U -Seals on the Piston. Re- install the Piston and nipple up the remaining Annular components. Nipple up the Riser. Prep to test Annular. 35/03/2012 T e s t Single down the 2 7/8" ESP /HT Completion. Trip in with the 2 7/8" x 3 1/2" Clean Out String. Reverse Well clean. Trip out with the Clean Out String._ 00:00 02:00 2.00 COMPZ WHDBO BOPE T Test the Annular with the 3 1/2" Test Joint at 250/3,000 psi. Good test. Test the Annular with the 2 7/8" Test Joint at 250/3,000 psi. Good test. Perform the Koomey Drawdown test. Good. All pressure test were recorded on a chart. The State's right to witness the test was waived by AOGCC Field Inspector, B. Noble. Nordic Rig 3 went off down time at 02:00 hrs. Page 3 of 8 Time Logs • • Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 02:00 03:00 1.00 COMPZ RIGMN1 PRTS P Pressure test the new installed Goose Neck with a Wireline Entry Guide on the Top Drive at 250 psi x 5 minutes and at 5,000 psi x 15 minutes. Good tests. Record on chart. Blow down Top Drive. 03:00 03:30 0.50 COMPZ WHDBO PLUG P Vetco -Gray Service Hand pull the Blanking Plug and the Back Pressure Valve. Install the Side Isolation Sleeve. 03:30 05:30 2.00 COMPZ RPCOM CIRC P Pump 23 bbls to catch returns (FL — 600 -ft). Circulate the Well with filtered 3% KCL Sea Water at 5.0 bpm/750 psi x 1 1/2 Volumes. 05:30 06:00 0.50 0 30 COMPZ RPCOM PULD P BOLDS. Pull Tubing Hanger to the Floor. Up Weight = 75K. 06:00 15:00 9.00 30 4,141 COMPZ RPCOM PULD P Remove Penetrator. Lay down Tubing Hanger and Landing Joint. Single down the 2 7/8" ESP /HT _ Completion. 15:00 18:00 3.00 4,141 0 COMPZ RPCOM PULD P Disassemble and lay down the ESP Assembly. (Note: Found sand in Pump section). Recovered 466 ea x 5 -ft Dual Channel Clamps, 1 ea x 4 -ft Dual Channel Clamp, 3 ea x 3 -ft Dual Channel Clamps, 2 ea x 2 -ft Dual Channel Clamps, 95 ea Dual Cross Channel Clamps, 22 ea Single Channel Clamps, 3 ea Flat Guards, 2 ea Protectolizers, 21 ea SS Bands. Note: Lost a piece of Metal, 4" L x 1 1/2" W x 1/2" T from one of the Protectolizers. 18:00 20:30 2.50 0 0 COMPZ RPCOM OTHR P Clear and clean Floor. Off load ESP equipment. 20:30 00:00 3.50 0 3,027 COMPZ WELLPF TRIP P PJSM. Install Wear Bushing. Single in with the 2 7/8" Hydril 511 Tubing. Make up XO, 7 5/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar. Continue to trip in the Clean -out BHA with 3 1/2" Drill Pipe from the Derrick. (Note: Worked the Casing Scraper across the targeted area were the Production Packer will be set four times). Up Weight = 80K. Down weight = 75K. 05/04/2012 Cont RIH with Clean Out String. Clean out the Screen Assy down to 4,641 -ft. Encounter no Fill. Rev Circ. TOOH with the Drill Pipe. LD the 2 7/8" Hydril 511 Tbg. PU Test Plug and Pkr. RIH. Test Csj TOOH with Test Pl jand Pkr. Prep to run Completion. 00:00 01:00 1.00 3,027 4,240 COMPZ WELLPF TRIP P Continue to trip in with the Clean -out String. Enter the top of the SC -1 Packer at 4,228 -ft with no problem. However, found the "Fish" from the ESP Protectolizers at 4,240 -ft. Page 4 of 8 • • Time Logs Date From To Dur S. Depth E. Death Phase Code - Subcode T Comment 01:00 03:00 2.00 4,240 4,641 COMPZ WELLPF FCO P Wash and work to move Fish. Set 7K down and Fish fell away. End Pump. Ease on down inside the Screen Assembly. Caught up with the Fish two more times at ID restrictions in the Screen Assembly but was able to set 5 - 7K weight on fish to move and it finally fell out the end of the Screen Assembly at 4,600 -ft. Continue down to 4,641 -ft (end of 2 7/8" Mule Shoe). Note: No Fill encountered. Blow down top Drive. 03:00 04:30 1.50 4,641 4,641 COMPZ WELLPF CIRC P Rig up Lines to Reverse Circulate. Reverse circulate at 4.0 bpm /700 psi. However, no fluid returns to surface. Fluff and Stuff the equivaliant of two Drill Pipe volumes behind Pipe. 04:30 08:00 3.50 4,641 0 COMPZ WELLPF TRIP P Trip out with the Clean -out String, standing back the 3 1/2" Drill Pipe in the Derrick. 08:00 08:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM on PU and RIH w/ Baker "G' RBP and Retrievamatic Test packer. 08:15 11:00 2.75 0 4,195 COMPZ WELLPF TRIP P PU, MU and RIH w/ Baker Test Packer assy to 4.195 -ft and set RBP. Release off RBP and POOH to 4,150 -ft w/ Test packer. 11:00 12:30 1.50 4,150 4,150 COMPZ WELLPF PRTS P PT 7 5/8, 29.7 #, L -80, BTC Mod CSG (8,160 psi Burst / 6,528 psi 80 %) to 1,560 psi for 30 minutes. Loss 50 psi in 15 minutes and 70 psi in the last 15 minutes. Bump up and retry to test at 1,570 psi and lost 70 psi in 15 minutes. Bleed off and and check test system for fluid pack. Retry at 1,570 psi for 30 minutes and lost 60 psi in 15 minutes and another 60 psi in the last 15 minutes. Bleed off pressure and open Upper pipe rams. 12:30 12:45 0.25 4,150 4,150 COMPZ WELLPF PACK P Set Baker Retrievamatic Packer at 4,150 -ft 90k up wt 80k do wt. 12:45 13:30 0.75 4,150 4,150 COMPZ WELLPF PRTS P Pressure test between test packer and RBP at 1,500 psi - loosing Qressure. Pressure up on Test packer set 4,150 -ft. on IA x 3 1/2 DP to 1,500 psi - Held solid - good test. Chart for 30 minutes. Bleed off pressure. 13:30 13:45 0.25 4,150 4,180 COMPZ WELLPF PACK P Release Test packer and RIH to 4,180 -ft and set. 13:45 14:15 0.50 4,180 4,180 COMPZ WELLPF PRTS P Pressure up to 1,500 psi between test packer and RBP - failed - Possible RBP leak. Bleed off. 14:15 15:00 0.75 4,180 4,200 COMPZ WELLPF PACK P Release Test packer and RIH to RBP at 4,195 -ft and lacth up. Release RBP and pull up hole 20 -ft and RIH to 4,200 -ft. Page 5 of 8 Time Logs • • Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 15:00 17:00 2.00 4,200 4,200 COMPZ WELLPF CIRC P Circulate 260 bbls of 3% KCL Seawater at 3 bpm at 220 psi ICP, 260 psi FCP to kill tank with 224 bbls recovered. (86% returns) 17:00 19:00 2.00 4,200 4,200 COMPZ WELLPF OTHR P Spot crane and off load spool of ESP cable pulled, along with Heat Trace pulled. Reload New ESP cable spool. Install guards. 19:00 22:30 3.50 4,200 36 COMPZ WELLPF TRIP P PJSM. Trip out with test PAcker and Retrievable Bridge Plug, standing back the 3 1/2" Drill Pipe in the Derrick. 22:30 23:00 0.50 36 0 COMPZ WELLPF PULD P Inspect test Packer and Retrievable Bridge Plug. Recovered same, complete. Lay down same. 23:00 23:30 0.50 0 0 COMPZ WELLPF OTHR P Pull and lay down the Wear Bushing. 23:30 00:00 0.50 0 0 COMPZ WELLPF CIRC P Begin to Bullhead in with Corrosion Inhibited Sea Water at 3.0 bpm /560 psi. 05/05/2012 Pick u• the ESP Ass and service same. Sin •le in the 3 1/2" ESP /Feedthru Pkr Completion as designed. Land Tbq Hanger. 00:00 03:00 3.00 0 25 COMPZ RPCOM PULD P Pick -up inspect and service ESP Assembly. (Note: continue to bullhead Corrosion Inhibited Sea Water while servicing the ESP Assembly. Total pumped 206 bbls. Shut down Pump and Monitor Well). Attach Motor Lead. Attach Welllift Discharge Tubing. 03:00 05:30 2.50 25 25 COMPZ RPCOM OTHR P Monitor Well. Slight flow back. Continue to monitor until Well turns around and goes on vacuum. 05:30 10:30 5.00 25 2,040 COMPZ RPCOM PUTB P Service ESP Motor and Tandem Seals. Single in with the 3 1/2" ESP W /Feedthru Packer Completion as designed. Packer at 2,040 -ft. Perform ESP Cable checks 10:30 13:30 3.00 2,040 2,040 COMPZ RPCOM OTHR P Space out for splice and conduct tie in splice on Bottom side of Packer. 13:30 17:00 3.50 2,040 2,040 COMPZ RPCOM OTHR T Waiting for Centrilift Ground spooling unit with Generator to be delivered or Crane to swap floor spools which ever comes first. Centrilift Ground spooling unit arrived at 14:26 hrs, lay out pit liner and set on on plywood. Load ESP spool. Still waiting for Gen set for power. Crane arrived on location at 15:30 hrs - load ESP spool 17:00 18:30 1.50 2,040 2,040 COMPZ RPCOM OTHR P Conducting Top Packer splice. Check Cable. Page 6 of 8 Time Logs • 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 21:00 2.50 2,040 4,125 COMPZ RPCOM PUTB P Continue to single in with the 3 1/2. ESP w /Feedthru Packer Completion as designed. Make ESP Cable checks. 21:00 21:30 0.50 4,125 4,125 COMPZ RPCOM THGR P Pick -up Landing Joint. Make -up Tubing Hanger (w /Side Port Isolation Sleeve installed). Install Penetrators. 21:30 23:30 2.00 4,125 4,125 COMPZ RPCOM OTHR P Make final ESP Tubing Hanger Connection Splice. Make ESP Cable checks as follows: Inlet pressure = 1,529 psi, discharge pressure =1,497 psi, tempeture = 78 degs F, motor tempeture = 79 degs F, phase to phase = 2.1 ohms, phase to ground = infinity, meger test = 4.16 gig ohms. 23:30 00:00 0.50 4,125 4,167 COMPZ WHDBO THGR P Up Weight = 80K. Down Weight = 72K. Land Tubing Hanger. Pump Intake at 4,135 -ft. RILDS. 05/06/2012 Test Tbg Hanger void. RU S -line. Set and test the WRP. Set the Feedthru Packer. Test the IA. De- pressurize the IA. S -Line pull Dummy Valve. Freeze Protect Well. Install Dummy Valve. Test Tbg. RD S -Line. Inst BPV. ND BOP. Check ESP Cable. NU Tree. Test Tree. Record final ESP checks. Secure Cellar. Release Rig. 00:00 01:00 1.00 4,167 4,167 COMPZ WHDBO PRTS P Test Tubing Hanger void at 5,000 psi x 15 minutes. Good. Lay down the Landing Joint. Pull the Side Port Isolation Sleeve. Pick -up the Landing Joint. 01:00 03:30 2.50 0 0 COMPZ RPCOM SLKL P PJSM. MIRU Slick -Line Unit. Bring Tool to the Floor. Pick -up Lubricator. Make -up Tool String. 03:30 07:45 4.25 COMPZ RPCOM SLKL P Pressure test Lubricator to 825 psi. Run in with a 2.780" WRP Drift to 2,404 -ft SLMD. POOH. Run in with a 3 1/2" OK -1 w/1.40 LIB. Locate GLM #2 at 2,209 -ft slmd. Flag Line. POOH. Pick -up Setting Tool and the WRP. Run to 2,279 -ft SLMD (Middle of 2nd Full joint below GLM #2) and set Weatherford 2.78" WRP w/ HES DPU. POOH. RIH w/ 10 -ft x 2.73" OD Catcher Sub to 2,279 -ft SLMD and release off w/ top at 2,269 -ft SLMD. POOH found F/L at 190 -ft. RIH w/ Knuckled kick over tool to GLM #1 at 1,974 -ft SLMD, locate and pull DV. POOH. 07:45 08:45 1.00 COMPZ RPCOM CIRC P Reverse Circulate 5 bbls of Neat Diesel followed by 60 bbls of Gelled Diesel thru open pocket at 1,986 -ft at 2 bpm at 550 psi FCP. 08:45 09:45 1.00 COMPZ RPCOM SLKL P RIH w/ DV and latch up in GLM #1, Pressure up tubing to 100 psi and release off DV. POOH. RIH w/ ko tool and locate DV at GLM #2 and pull DV at 2,229 -ft SLMD. POOH. Page 7 of 8 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:00 0.25 COMPZ RPCOM CIRC P Bullhead 40 bbls Neat diesel down TBG thru open pocket at 2,229 -ft at 2 bpm at 550 psi FCP. 10:00 10:30 0.50 COMPZ RPCOM SLKL P RIH w/ Knuckled kick over tool w/ DV to GLM #2 at 2,229 -ft and set DV. Pressure up on TBG from 200 psi to 300 psi. Release off DV. POOH> 10:30 11:00 0.50 COMPZ RPCOM PACK P Pressure up on TBG to 3,150 -ft psi and set WFT Hydro 11 packer at 2,110 -ft. 11:00 11:30 0.50 COMPZ RPCOM PRTS P Pressure test TBG at 3,000 psi and chart for 30 minutes. Good Test. Bleed off pressure to 1,000 psi. 11:30 12:30 1.00 COMPZ RPCOM SLKL P RD and offload slick line. 12:30 13:30 1.00 COMPZ RPCOM PRTS P Pressure p on IA to 1,500 psi, First 20 minutes lost 100 psi, bump back up to 1,500 psi and held steady for 30 minutes. Good Test 13:30 16:30 3.00 COMPZ RPCOM OTHR P Bleed IA as per Decompression schedule 16:30 17:00 0.50 COMPZ RPCOM MPSP P Install BPV w/ dry rod. 17:00 17:15 0.25 COMPZ RPCOM SFTY P Held PJSM with crew and Weatherford on ND Safety Tension Adapter and setting back on stump. 17:15 18:30 1.25 COMPZ WHDBO NUND P Nipple down BOP Stack and set back on Stump. Centrilift Service Rep make ESP Cable check as follows: Inlet Pressure = 1,511 psi, Discharge Pressure = 1,478 psi, Tempature = 79 degs f, Phase to Phase = 2.0 Ohms, Phase to Ground = Infinity, Meger 4.0 Gig Ohms. 18:30 21:00 2.50 COMPZ WHDBO NUND P Nipple up the Production Tree. Test Hanger void and Pack -offs at 5,000 psi x 15 minutes. Good. DSO verify Tree alignment (20:00 hrs). Fill Tree with Diesel and test at 250 psi x 5 minutes and at 5,000 psi x 15 minutes. good test. Record on Chart. 21:00 22:00 1.00 COMPZ WHDBO MPSP P Vetco -Gray Service Rep pull TWCV. Install BPV. 22:00 23:00 1.00 COMPZ RPCOM OTHR P Centrilift Service Rep record the final ESP readings as follows:lnlet Pressure = 1,501 psi, Discharge Pressure = 1,469 psi, Tempeture = 80 degs F, Phase to Phase = 2.0 Ohms, Phase to Ground = infinity, Meger = 3.67 Gig Ohms. Prep to move off of Well Slot. Released Rig at 23:00 hrs Page 8 of 8 ~~: PROf~Cf1YE DIA~'jNOSi1C SErtvicES~ ING_ ILL. ~ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 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 following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~; ~_j^~I+~~y << ~. -~ ~ F Suite C " `' ~~~~ Anchorage, AK 99518 Fax: (907j 245.8952 1) MTT Report 11.Jun-10 1 D-135 1 Report 50-029-22816-00 2) ig~ -1 ~`~ ~~~ x ~~ ,' -~, Signed : - _ Date ~ , ~ . Print Name: - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-NWIL : pdsaaaeh®rageC~memol-yi©g.l;om WEBSITE : w~x~n+.naemorvlog.com C:\Documents and Settings\Diane Williams\Desktop\Transmit Conoco.docx • Memory Magnetic Thickness Tool i Log Results. Summary Company: ConocoPhillips Alaska, Inc. Well: 1 D-135 Log Date: June 11, 2010 Field: West Sak Log No.: 10636 State: Alaska Run No.; 1 API No.: 50-029-22816-00 Pipet Desc.: 2.875" 6.5 Ib L-80 EUE 8RD MOD Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 214 Ft. (MD) Pipet Desc.: 7.625" 29.71b L-80 Top Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 214 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Top Log Intvl.: Surtace Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) ~ Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ' This MTT data is tied into fhe Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Toot (MTT). The MTT ' responds to the total metal thickness of the 2.875" tubing, 7.625" casing, and 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm before the ESP was shut down, and an additional 10Hz was made after the ESP was shut down. ~ INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surtace to 214'. Changes in metal volume are relative to the calibration points at 68' and 120', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 2.875" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by SHz, 8Hz and 10Hz passes (before ESP was shut down) is included in this report. This plot indicates significant metal volume loss features over the intervals (16' -22') and (45' - 56') in the 5Hz pass. The 8Hz and 10Hz passes showing a relative decrease in metal volume over these intervals from a higher metal volume base line that keeps them from indicating an actual metal volume loss relative to the calibration point of 68'. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss from the outer concentric string(s) in this interval. A log plot of the entire 5Hz pass and an expanded log plot of the top 30' of the 5Hz pass are included in this report. A maximum -14% circumferential metal loss is indicated in the interval between 45' and 56" in the 5Hz pass. A maximum -6°!° circumferential metal loss is indicated in the interval between 16' and 22' in the 5Hz pass. A maximum ^'7% circumferential metal loss is indicated in the interval between 74' and 77' in the 5Hz pass Log plots of 10Hz passes before and after the ESP was shut down are also included in this report. These plots also include the overlay of the average overall metal thickness from both 10Hz passes. Whether the ESP is energized or not appears to have no influence on the MTT tool response. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 2.875", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 2.875" tubing or 16" conductor. Field Engineer: G. Etherton Analyst: HY. Yang & J. Burton Witness: B. Boehme ProActive Diagnostic Services; Inc. ; P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (88$) 565-9©85 Fax: (281) 565-1369 E-mail: PDS;amemoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (9C~7) 659-2314 Q4O`£M~E~(s~n,' SHz, ~z and 10Hz Passes Delta M~I Thickness Overlay 1 D-135 June 11, 2010 PIIOACTIYF ~IATjNO5T1[ SERVICES Database File: d:lwarrior\datal1d-135\overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Tue Jun 15 11:05:39 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 0 Cross-over ~ i i Delta Metal Thickness (10Hz) - Delta Metal Thickness Delta Metal Thickness 20 Joint 40 60 I-Bottom of 16" Conductor 80 I ~ I I I I ~ Quo ~c~y ' `~~ ne[!sA R~rded Magnetic Thickness L~ Data - 5Hz Pass i` ' 1 D-135 June 11, 2010 PnoAcrivE DiayNOSric Scaviccs Database File: d:lwarriorldatal1d-13515hzpass.db Dataset Pathname: SHzDown.1 ' Presentation Format: 1.8 scale Dataset Creation: Tue Jun 15 12:47:40 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (%) 50 1.8 0 a Line Speed (ft/min) 200 -7 Line ~ 1 2.8 75" Coll ars ' ' 2. 875" Co llar ' 2. 875" Co llar ' 7.625" Gollar. - ' 2 875" Co llar . ' 7.625" Col lar Tree Cross-over Metal Thickness Tubing Jt. 1 Metal Loss 20 Pup 40 4% Metal Tubing Jt. 2 60 Metal Loss Bottom of 16" Conductor Tubing Jt. MTTP01 (rad) 11.8 MTTP12 (rad) 3 • 100 2.875" 625" Collar F I I 875" Gollar. 875" 7.625" Collar 2.875" Col l a rte- ng Jt. 4 120 140 Tubing Jt. 5 160 180 Tubing Jt. 200 Tubing Jt. Delta Metal Thickness ' Line Spee -50 Delta Metal Thickness (%) 50 ' 0 v Line Speed (ffJmin) 200 1.8 MTTP01 (rad) 11.8 -7 MTTP12 (rad) 3 A a`E`"~E"s E~anded 5Hz Pass Magnetic T~kness Log Data Q~ Fc~s +~, C; ~ ~ {Surface - 80') PR°aR~vE Dlnyn°STIC SERVICES 1 D-135 June 11, 2010 Database File: d:\warriorldatal1d-1351expanded 5hzpass.db Dataset Pathname: 5HzQown.1 Presentation Format: 1.8 scale Dataset Creation: Tue Jun 15 12:47:40 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min) 200 -7 MTTP12 (rad) 3 ____ _ ~ ~ "" Lin e S peed Tree -~ H _ _ _ _ - -~~ - =~ = anger ~ ~ _ i ~ ~ ~ Cross-over ' ~__ .:. i ~ - ; -- -I - 2.8 75" Coll ars ~ ~ ' ~°~` - ' - ' ~ _- ~ I .p M 9 ~n ~4 Delta Metal I I Thickness 1 Tubing Jt. 1 t' r ~ , ~ ~ i` ~ `, 6 % M eta l Lo ss 20 I 1 a i ii i, ~ '4 } ( ( t } -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min} 200 -7 MTTP12 (rad) 3 `~~wE"s~° ~Hz Magnetic Thickness Loc~ata {ESP On) ~ '~ 1D-135 June 11, 2Q10 Pf10/~CTIVE DIAfjIEOSTIC SER41CE5 ~o ~c,'~ Database File: d:lwarriorldatal1d-13511d-135 passes.db Dataset Pathname: 10HzDn Presentation Format: 29 Dataset Creation: Tue Jun 15 15:45:31 2010 Charted by: Depth in Feet scaled 1:150 0 Line Speed (ftlmin) 200 2.8 MTTP01 (rad) 12.8 -50 DMT (ESP OFF) (%) 50 -5.6 MTTP12 (rad) 4 -50 DMT (ESP ON) (%) 50 Line Spee Tree _Hanger_ 875" Collars Cross-over _ ~ Delta Metal Thickness Tubing Jt. 1 20 ~ Metal Thickness (ESP Pup -~ 40 7.625" Colla Tubing Jt. 2 60 875" Collar Metal Loss Bottom of 16" Conductor 80 7.625" Collar~_;~ ~ ~ ~ ~ ~ Tubing Jt. 3 .625" Collar a I .875" Collar_ 875" Collar Line Speed (ft/min) DMT (ESP OFF) (%) DMT (ESP ON) (%) 100 ng Jt. 4 120 140 Tubing Jt. 5 160 180 Tubing Jt. 6 Metal Thickness ~ 200 ~i Tubing Jt. al Thickness {ESP ON) 200 2.8 50 -5.6 MTTP01 {rad) 12.8 MTTP12 (rad} 4 ~ ~o ~~,'~ ~~M~'Eusp 10~ Magnetic Thickness Log D~ (ESP Shut Down} N ~ - une 11, 2010 Plt°ACTIVE ~IAE~IYOSTIC SERYIC45 Database File: d:\warrior\datal1d-13511d-135 passes.db Dataset Pathname: 10HzEx Presentation Format: 29 Dataset Creation: Tue Jun 15 15:46:29 2010 Charted by: Depth in Feet scaled 1:150 0 Line Speed (ft/min) -200 2.8 MTTP01 (rad) 12.8 -50 DMT (ESP ON) (%,l 50 -5.6 MTTP12 (rad) 4 -50 DMT (ESP OFF) (%) 50 Tree 875" Collars Cros~~ Delta Metal Thickness Tubing .Jt. 1 20 Collar `- ~rDelta Pup 40 .2.875" Collar ~~ n i i 7.625" COllar Tubing Jt. 2 60 6% Metal Loss I Bottom of 16" Conduct 80 =~-- _ _. Collar Tubing Jt. 875" Collar Tubing Jt. 4 120 t-7.625" Gallar 140 Tubing Jt. 5 160 Colla 625" Collar 180 Tubing Jt. 6 ~--Delta Metal Thickness (ESP OFF) 2.875" Collar ~ - -_: ~ 200 Tubing Jt. 7 Line Spee Delta Metal Thickness (ESP OP ~0 Line Speed (ft/min) -200 2.8 I'-50 DMT (ESP ON) (%) 50 -5.6 -50 DMT (ESP OFF) (%) 50 MTTP01 (rad) MTTP12 (rad) 12.81 ConocoPhillips Alaska, Inc. KRU 1 D-135 ~ 1 D-135 WIRE#2 API: 500292281600 WeIIT e: PROD An le TS: de (37-4165 SSSV T e: None Ori Com letion: 11/14/1997 An le TD: 19 de 5015 , OD:1.000) Annular Fluid: Last WJO: Rev Reason: Pull SOV TUBING Reference Lo Ref Lo Date: Last U date: 4/19/2007 (0-4135 - Last Ta : 4135 TD: 5015 ftK6 , 875 OD 2 Last Ta Date: 12/31/2004 Max Hole An le: 47 de 2810 : . , _ ID:2.438) Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.D00 0 121 121 62.58 H-40 PROD. CASING 7.625 0 5000 4366 29.70 L-80 ~ Tubin Strin -TUBING _ Size To Bottom TVD Wt Grade Thread GAUGE 2.875 0 4135 3553 6.50 L-80 EUE Srd Mod (floss-4os7, ~ Perf ati S OD:2 000) or ons umma . sAP Interval TVD Zone Status Ft SPF Date T e Comment (40964127 4300 - 4334 3707 - 3739 WS D 34 12 1/11/1998 IPERF SOS 4.5" UltraPak; TCP RDX OD 875 2 Char e : . ) 4370 - 4408 3772 - 3808 WS B 38 12 1 /11/1998 IPERF SOS 4.5" UltraPak; TCP RDX PUP ~ Char e (4127-4135 4466 - 4510 3862 - 3903 WS A3 44 12 1/11/1998 IPERF SOS 4.5" UltraPak; TCP RDX , ~ OD 875 Char e :2. ) 4542 - 4598 3934 - 3986 WS A2 56 12 1 /11/1998 IPERF SOS 4.5" UltraPak; TCP RDX i Char e Gas Lift MandrelsNalves - - St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt PUMP 1 4090 3511 Camco KBMM OPEN 1.0 BK 0 000 0 4/17/2007 (4135-4155, Other IU S e 1 t JEWELRY OD:4 000) 1 1 e C. - . De th TVD T e Descri tion ID 37 37 WIRE #1 Ra hem Heat Trace Run to 2257' 0.000 37 37 WIRE #2 ESP Electric W/I Wire Cable Run to 4165' 0.000 4096 3517 SAP Baker Dual Sensor Gau es attached to To Joint #1 2.441 4096 3517 GAUGE BAKER SENTRY GAUGE -PUMP DISCHARGE 0.000 g~ 4099 3520 GAUGE BAKER SENTRY GAUGE -PUMP INTAKE 0.000 (4155-4165 4127 3546 PUP EUE Srd Mod 2.441 , OD:5.125) 4135 3553 PUMP Centrilift Tandem Pum FPMTlAR & FPMTlAR w~ntake 0.000 4155 3572 SEAL Centrilift Seal Section GSFT DB HL PFS 0.000 4165 3581 MOTOR Centrilift PCESP MOTOR 57 HP 131526 KMH 0.000 4227 3639 GRAVEL BAKER GRAVEL PACK w/SCREEN 3 250 PROD. PACK . 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R ~~ H ~~~f~s (1~'£~S vii i+.~ ;. .f.~'{"~~. l;d ~'pr ~~' =~~~~N ~~t ~~ f~~~'a-. ~ 6 B y 3 _ - _ ,______ ____ ~ ....} __ _. ~ ~~_ __ ._ i _ __ a F g i _. ~ • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • RL..Vi~...i V~~ SEP 0 2 2008 August 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Alaska Qi! & Gas Cons. Commission Anchorage ~~97- iSy- 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 a 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 cement top jobs were performed between June 23, 2008 and August 24, 2008. The corrosion inhibitor/sealant was pumped on August 27, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. /,, Sincerely, i~~~~ M.J. oveland ~~~~ S~~ °~ ~ 20D8 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 '""'r+~ Date 8/27/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-23 191-Q09 12" na 12" na 6.80 8/27/2008 1 A-24 200-1'81 6" na 6" na 2.55 8127!2008 1A-28 191-002 8" na 8" na 1.70 8!27/2008 1 B-13 194-055 24" na 24" na 8.50 8/27/2008 1 B-15a 204-256 SF na SF na 8.50 8/27/2008 1 B-16 194-037 21' 8" 4.00 25" 8/24/2008 6.80 8/27/2008 1 B-17 194-045 6' S" 1.00 28" 8/24/2008 5.10 8!27/2008 1 D-134 198-111 SF na SF na 2.55 8!27/2008 1 D-135 197-184 SF na SF na 1.70 8/27/2008 1 D-141 a 208-016 16' 1.40 3' 6/23/2008 9.35 8/27/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~` Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing Q 'Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ~ ~ Exploratory ^ 197-184 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22816-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', pad 71' ~ 1 D-135 ' 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5015' ~ feet true vertical 4381' , feet Plugs (measured) Effective Depth measured 4135' feet Junk (measured) true vertical 3553' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' PROD. CASING 4959' 7-5/8" 5000' 436 6 ' ~~ yy r B ~y q, '~ ti 1 .~13 f ~C~ ~ ~ GQ~L' Perforation depth: Measured depth: 4300'-4334', 4370'-4408', 4466'-4510', 4542'-4598' true vertical depth: 3707'-3739', 3772'-3808', 3862'-3903', 3934'-3986' Tubing (size, grade, and measured depth) 2-7/8", L-80, 4141' MD . Packers &SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 125 3 54 -- 140 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development O Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NSA if C.o. Exempt: none Contact Brett .Packer @ 265-6845 Printed Name Brett Packer ~ ~^i~~ Title Ph Wells Group Engineer p. D t ~~~/8 Signature one e a tf Pre aced b Sha n Al1su Drake 263-4612 Form 10-404 Revised 04/2006 Submit Ori ~ ~( C~l~ • • Ct~nc~~t~P'hi~ps Time Log Summary LYeitvk~.. V/eb Reporting _-___ Well Name: 1 D-135 Job Type: RECOMPLETION ~ Time Lis _ ,' _- - - - _ Date From To ____ Dur S Depth E Depth. Phase C~dz__ Subcode T COM i 12/17/2007 17:00 23:00 6.00 5,015 5,015 MIRU MOVE MOB P Move f/ 2T pad to CPF-2. 23:00 00:00 1.00 5,015 5,015 MIRU MOVE WOOR P Move shut down per orders f/ SRT due to s ill clean-u riorities. 12/18/2007 00:00 12:00 12.00 0 0 MIRU MOVE OTHR P Standby with crews & Nordic Rig #3 CPF-2. Kee road clear for SRT. 12:00 17:00 5.00 0 0 MIRU MOVE MOB P PJSM-Move Nordic rig #3 from CPF-2 to 1 G 1 R Pad turn. 17:00 19:30 2.50 0 0 MIRU MOVE OTHR P Standby with crew.& Nordic Rig #3 Wait on lane & crew than e. 19:30 00:00 4.50 0 0 MIRU MOVE MOB P Move Nordic rig #3 from 1G 1 R Pad turn out to 1 D ad. 12/19/2007 00:00 03:00 3.00 0 0 MIRU MOVE RURD P PJSM, load tree to cellar. Move rig over well. center/ level sub over wellhead. Note: Nordic rig # accepted this date 0300 hrs. 03:00 07:00 4.00 0 0 COMPZ RPCOh RURD P Berm up perimeter. load lubricator. 07:00 09:00 2.00 0 0 COMPZ RPCOti RURD P PJSM RU lubricator, Pull BPV. Load ESP cable spooler to rig floor w/ crane. 09:00 15:30 6.50 0 0 COMPZ RPCOti OTHR P Spot remainder MI equipment/ chemicals/ lab. RU kill lines to production tree, while take on kill fluids. 15:30 18:00 2.50 0 0 COMPZ RPCO CIRC P PJSM, Test lines 2500 psi. 250 psi on tbg. 480 psi on annulus. Bleed annulus 480 to 0 psi. / 30 mins.. Commence circ kill fluids (8.7 ppg, 6% KCL filtered seawater. 130 deg) 3 bpm at 120 psi. Hold slight back press at annulus 40 si. Pum ed 270 bbls. 18:00 00:00 6.00 0 0 COMPZ RPCO OTHR P Shut in well. Tbg. pressure 40 psi csg. psi 60. Blow down kill lines & hoses. Wait on filtered seawater. Service top drive. 12/20/2007 00:00 02:30 2.50 0 0 COMPZ RPCOh OTHR P Filtering hot seawater to 2 microns. 02:30 03:30 1.00 0 0 COMPZ RPCO RURD P Hook up lines. Spot trucks. & prepare to circ. 03:30 06:00 2.50 0 0 COMPZ RPCOh CIRC P Circ. 8.7# hot seawater down annulus @ 3 bpm / 40 psi. Well stabilized. Tbg 40 si, ann 40 si. 06:00 10:00 4.00 0 0 COMPZ WELCT CIRC P PJSM, Load 10.1 ppg kill fluid to pits. Pump same do tbg with 100 psi held to choke. Coot circ to kill. No losses. Well killed with "0" psi tbg and annulus. Open well, no flow. ~m____---_~_--- • Time Logs Date From To Dur5 Depth E _Depth Phase Code Subcode T COM _ 12/20/2007 10:00 12:00 2.00 0 0 COMPZ WELCT OTHR P RU /set BPV. Secure well. 12:00 13:00 1.00 0 0 COMPZ RPCOh SFTY P Safety stand down as requested CPAI. All crews personnel to discuss world wide incident increase, how may we do art to miti ate. 13:00 14:00 1.00 0 0 COMPZ WELCT BOPE P Test tree adaptor /top tbg hgr. Insure safe to RD tree. 14:00 16:00 2.00 0 0 COMPZ RPCOh NUND P PJSM, ND prod tree, install test dart. 16:00 00:00 8.00 0 0 COMPZ RPCOh NUND P PJSM, NU BOPE, all related components. Change upper rams to 2 7/8". 12/21/2007 00:00 05:30 5.50 0 0 COMPZ WELC BOPE P Test all BOPE 250-2500 si. Test all related components. Perform time / volume /press test accumulator. All bottles press checked. Witness test waived b Chuck Scheve AOGCC. 05:30 09:30 4.00 0 0 COMPZ RPCOti PULD P PJSM, pull BPV, install isolation sleeve, MU Idg jt. Place ESP pull e ui to ri floor, RU same. 09:30 11:30 2.00 0 0 COMPZ RPCOh PULD P PuII tbg hgr to floor, 120K to break free, flow check, cont pull to floor with 55K pull. No swab. Remove penetrators, LD tbg hgr /pups / connectors. 11:30 13:00 1.50 0 0 COMPZ RPCOti CIRC P Circ fluids, slight imbalance after pull hgr. Note 8 - 10 bph losses. 3 bpm / 280 si. 13:00 13:30 0.50 0 0 COMPZ WELC OWFF P Flow check well, fluid column drop approx 6 - 8 bph static los_s~. Dynamic losses remain at 8 - 10 b h. 13:30 15:00 1.50 0 0 COMPZ RPCOti PULD P PJSM, commence_POH standing b~ 2-7/8 com tb .Spool up lines, strap tb , invento clam s accessories. 15:00 21:00 6.00 0 0 COMPZ RPCOh TRIP P POH w/ ESP & heat trace on 2 7/8" tbg. from 4026' to 1914' MD. End of heat trace. 21:00 23:00 2.00 0 0 COMPZ RPCOh TRIP P POH w/ ESP from 1914' to 101'. 23:00 00:00 1.00 0 0 COMPZ RPCOti PULD P Remove sensor gauges. 12/22/2007 00:00 03:00 3.00 0 0 COMPZ RPCOh PULD P Layed down ESP completion. Motor -Seal Section & Pum . 03:00 07:30 4.50 0 0 COMPZ RPCO OTHR P Clean floor. Monitor well & Count all Equipment layed down. Cable guards-steel bands & LaSalle clamps. (Recovered Everything) Well taking 7 BPH Fluid. 07:30 08:30 1.00 0 0 COMPZ RPCO PULD P Install wear bshg 08:30 10:00 1.50 0 0 COMPZ RPCOh PULD P PJSM, load pkr and rbp to pipe shed. MU BHA with same, flow check, RIH. 10:00 13:30 3.50 0 0 COMPZ RPCOti TRIP P Follow BHA with 2-7/8 tbg to 4110 ft. 13:30 15:30 2.00 0 0 COMPZ RPCOh OTHR P Set RBP, test 7-5l8 cs to 2500 si / 30 min. Test successful, no re-tests. _.~ m m _~. ___.__ _~~ ®m. _ ~~~:~ ~ ~f~~ i • • Time Logs ... Date From To Dur S. De ±h E. De th Phase Code Subcode T COM 12/22/2007 15:30 20:00 4.50 0 0 COMPZ WELCT EORP P PJSM, repair VR plug threads (IA outlet . Re lace valve IA outlet 20:00 00:00 4.00 0 0 COMPZ RPCOh RURD P Load out old ESP cable & spool from rig floor & heat trace cable & spool. Load new heat trace cable & spool on rig floor, load ESP pump & equipment in pipe shed. (NOTE) New ESP cable & Spool weigh 7k more than old cable & spool. Temp is -25 deg. Crane operator says for every 1 deg. below '0' deducts 1 % off capacity of crane. SO we need to wait on 90 ton crane or A rise in temperature. 90 ton crane wont be available till sometime late tomorrow. 12/23/2007 00:00 06:30 6.50 0 0 COMPZ RPCOh WOEQ NP Load completion equipment to rig floor, clamps-bands-heat trace & spool. Circ. well while waiting on crane to load ESP cable & spool to rig floor. (NOTE) 50 ton crane on location. Operator says for every degree below '0' you deduct 1 % off capacity pick up. Temp is -25 deg. 90 ton crane will be available sometime today. If Temperature rises to -15 to -10 we could ossibl load w/ 50 ton crane. 06:30 10:30 4.00 0 0 COMPZ RPCOh PULD P Flow check. Release RBP /Test PKR, POH from 4110, LD test PKR BHA. Flow check, static losses 10 BPH. 10:30 11:00 0.50 0 0 COMPZ RPCOh OTHR P Clear floor. Clean Oil residue from e ui . 11:00 12:00 1.00 0 0 COMPZ RPCOCV PULD P Pull wear bshg. 12:00 13:00 1.00 0 0 COMPZ RPCOti RURD P Arrival crane operator. PJSM, set ESP s ool to ri floor. 13:00 14:00 1.00 0 0 COMPZ RPCOh RURD P PJSM, RU ESP equip. Spool through sheaves, put pump / motor assy in lace. •14:00 00:00 10.00 0 0 COMPZ RPCOti RCST P Commence PU ESP ass ,follow with 2-7/8 comp tbg, mandrels, heat trace, control line clam s & bands.. 12/24/2007 00:00 00:00 24.00 0 0 COMPZ RPCOh PULD P Running 2 7/8" ESP completion w/ heat trace, clamps, bands & ESP cable from 601' to 4092' MD. Test Cable every 1000'. Up Wt. 68k Dn 62k. 12/25/2007 00:00 00:30 0.50 0 0 COMPZ RPCOh PULD P Continue running in hole w/ ESP com letion from 4092 to 4125' MD. 00:30 02:00 1.50 0 0 COMPZ RPCOti HOSO P Space out w/ 8' 2 7/8" pup & make up han er, install clam s & enetraters. 02:00 05:00 3.00 0 0 COMPZ RPCOh OTHR P Make final splice to heat trace, esp cable & TEC wire to enetraters. 05:00 06:00 1.00 0 0 COMPZ RPCOh DHEO P Megger testing heat trace, esp cable & enetraters. _~___m__~ - - j~~= 3 ~~ T • • Time Logs __ Date From To Dur S. Depth E. Deeth Phase Code Subcode. T- COM 12/25/2007 06:00 07:30 1.50 0 0 COMPZ RPCOh HOSO P Drain Stack. Land hanger, RILDS, test hanger seals, lower & upper 5k 10 mins.. Lay down landing jt. & set 2 way check. (Note: Up wt. 70k Dn 65k. 07:30 11:00 3.50 0 0 COMPZ RPCOh NUND P PJSM. Nipple down BOPE. 11:00 14:00 3.00 0 0 COMPZ RPCOh NUND P Clean wellhead & nipple up tree. 14:00 15:00 1.00 0 0 COMPZ RPCOh DHEO P Pressure test void & tree 15 mins. 5000 si OK. 15:00 16:00 1.00 0 0 COMPZ RPCOh RURD P Rig up lubricator & pull two way check valve. 16:00 16:30 0.50 0 0 COMPZ RPCO RURD P Rig up hot oil unit for freeze protecting. 16:30 19:30 3.00 0 0 COMPZ RPCOh FRZP P Freeze protect well w/ 20 bbls. diesel down 2 7/8" tbg. & 145 bbls. down 2 7/8" X 7 5/8" annulus. (Pumped down tbg. @ 1/2 bpm 1600 psi. pumped down annulus @ 1.2 bpm final pump ressure 1250 si. 19:30 21:00 1.50 0 0 COMPZ RPCOh RURD P Rig down hot oil unit. Clean cellar & re for ri move. 21:00 22:00 1.00 0 0 COMPZ RPCOh OTHR P Jack up rig & move off well # 1 D-135. (Rig released from 1 D-135 @ 2200 hrs. 12-25-2007.) ^. r~, ~f~ ~ ~'onocpPtl~~ps Alaska, inc. ~l 1 t3-13~ • KRU 1 D-135 lr wu. \....VllVl..vr JllJll}.J;:) Lh,-aVallVll u<.. .l'-'-}.IUB .l 'VJ"''''~J -~ .~ Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 lun 2006 07:00:24 -0800 fl'o:Eou Grimaldi <Iou _grimaldi@admin.state.ak.us>, John Spaulding 1<:.i9ht1_ spaulding@admin.state.ak.us>, John Crisp <john_ crisp@admin.stat~.ak.us>, Jeff Jones ;<jeff¿jones@admin.state.ak:.us>, Chuck Scheve·<chuc~scheve@admin.state.ak.us>, Jim Regg kjim__regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the IIbig digll project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom Subject: Date: From: To: CC: -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <NI878@conocophillips.com> tom maunder@admin.state.ak.us NS-K-~;:¡eiT--Integri ty proj dJl878@conocophillips. com> , aogcc prudhoe bay@admin.state.ak.us \\)-\~ç \~'\-''6-~ Tom: I don1t remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to IIpro-activelyll excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «IC and ID Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 SCANNED JUN 2 7 2006 1 C and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword 10f2 6/26/20067:51 AM ) PRIORITY 1 2 3 4 5 6 7 8 9 10 11 12 13 14 -----v 15 ~ 16 \<;~ - \<;;~ )) NAME 1 C-121 1 C-131 1 0-109 1 0-111 10-120 1 0-136 1D-137 10-138 1 D-139 1 C-119 -'::'.-:~~--:<-..:.~.-Iª~~i~§::"~:~.~.~.~<-j- 1D-135 : I ,.< .... ........< ..~n<. < .....~.<_.._.---"..._...<"-,... .............1 1D-141 I ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates TYPE PTD# LEAK DEPTH (ft) I COMMENTS I STATUS -- -,.. ---. -----'-... .. ----------~-- ·--l- INJ 201-080 4 I -...-.------.--.--.-- -- i INJ 201-185 7 I INJ 197 -235 5* I j INJ 198-166 5* I INJ 197-221 7 I Gas Lift 197-181 None Proactive dig Gas Lift 198-109 None Proactive dig INJ 198-121 5 INJ 200-046 None Proactive dig -. -~- . ,._-,-,-,-----_. ----.-- - -~._.- INJ 200-047 None Proactive dig -- -_._-_._-_.,_..._,,_.~. ..-- INJ 200-048 8 INJ 200-049 None Proactive dig INJ 201-139 16 Jet Pump 201-220 None Proactive dig ESP 197 -184 None Proactive dig, backup candidate (has 500' casing) Gas Lift 200-112 None Proactive dig backup candidate. Notes: 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 1 0-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 PI-I,LLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 April 23, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1D-135 (197-184) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the KRU well 1D- 135. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS :OperationS:perfOrmed: i OPerati0n shutdown_ stimulate _XX Plugging_ Perforate_ :: . iPull t~bing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 523' FNL, 602' FEL, Sec. 23, T11 N, R10F, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 560490, 5959141) 6. Datum elevation (DF or KB feet) RKB 112 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-135 At top of productive interval 847' FNL, 1177' FWL, Sec. 24, T11N, R10E, UM At effective depth At total depth 874' FNL, 3865' FEL, Sec. 24, T11 N, R10E, UM (asp's 562507, 5958806) 9. Permit number / approval number 197-184/ 10. APl number 50-029-22816 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical 5015 feet 4381 feet Effective depth: measured 4095 feet true vertical 3516 feet Plugs (measured) Casing Length CONDUCTOR 121' PROD. CASING 4888' Junk (measured) Size Cemented 16" 9 cu yds High Early 7-5/8" 488 sx AS III LW, 340 sx Class G, 60 sx AS 1 Measured Depth True vertical Depth 121' 121' 5000' 4366' Perforation depth: measured 4300' -4334', 4370' - 4408', 4466' - 4510', 4542' - 4598' true vertical 3707! - 3739', 3772' ' 3808', 3862' 3903', 3934' - 3986' Tubing (size, grade, and measured depth) 2-7/8",615#, L-80'Tbg @ 4135' MD. Packers & SSSV (type & measured depth) No packer No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) See attachment Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 87 Subsequent to operation 182 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 6 40 18 140 Casing Pressure Tubing Pressure 224 228 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended__ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedMichae/Mooney ~/'~~ Title: W ells Team Leader Form 10-404 Rev 06/15/88 · Questions? Call Mike Mooney 263-4574 Prepared b~/ Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 1 D-135 Event History 03/11/02 03/16/O2 03/17/O2 03/18/O2 ATTEMPTED TO LOAD IA W/DIESEL BY BULLHEADING DOWN IA INTO FORMATION. IA PRESSURE/RATE FLUCTUATING BETWEEN 0.5-0.9 BPM, 700-800 PSI-TIGHT (IA APPEARED FLUID PACKED). 24 BBLS AWAY; QUIT LOADING AND AND CONT. W/ACID FLUSH OF PUMP. INITIAL INJECTIVlTY THRU PUMP WAS 0.3 BPM @ 3300 PSI. AFTER 1ST 5 BBL ACID FLUSH, INJ INCREASED TO 1.0 BPM, 3000 PSI. 2ND 7 BBL ACID SHOWED LITTLE CHANGE; INJ. RATE 1.1 BPM @ 3500 PSI DISPL IA W/120 BBLS DIESEL, DISPL TBG W/40 BBLS DIESEL, PULLED 1" DV F/4090' RKB COMPLETE [GLV] PUMP 150 BBLS OF 12% HCL/3% ACETIC ACID WITH 20 BBLS OF 70% QUALITY FOAM DIVERTER. AVERAGE RATE = 1.5 BPM AND IA PRESS = 770 PSI. OVERFLUSH WITH 290 BBLS OF 2% KCL WATER AT AVG RATE OF 1.0 BPM AND IA PRESS OF 800 PSI. DISPLACE TUBING WITH 32 BBLS OF DIESEL. SET SOY @ 4090' RKB, PT TBG TO 1000# [GLV, PT TBG-CSG] Page I of 1 4/23/2002 ARY 03 2001 . W Well Report ~ 01 /~12 /1998 197-184-0 ARCO KUPARUK RIV U WSAK 1D-135 029-22816-00 Completion Status: 1-OIL Current Status ~'o/~- MD ~ TVD 04381 Name Interval Sent Received BO 8202 ~ SPERRY MPT/GR/EWR4 12/17/97 12/17/97 DGR/EWR4-MD ~2 132-5015 12/23/97 12/24/97 DGR/EWR4-TVD ~~.. 121-3702 12/23/97 12/24/97 Daily Well Ops II/~0,fi,> -- ]/~4 ~ Was the well cored? yes ._1~_~__ Are Dry Ditch Samples Required? yes ~ And R~ yes no Analysis Description Receiv °e. lt2~)~--m~--~- Samp~- Comments: Monday, January 10, 2000 Page 1 of I ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-135 (Permit No. 97-184) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-135. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Anchorage Kuparuk Development TWM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS E~] SUSPENDED [] ABANDONED~ SERVICE [---] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-184 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22816 4 Location of well atsudace i~ '!J.i~:{i'i ';~-~--:;.'{i:-ii-~! i~ 9 Unit or Lease Name 526' FNL, 601' FEL, Sec. 23, TllN, R10E, UM ;~ , Kuparuk River Unit At Top Producing Interval .~~/~.~r .,\ ~': ~ ...~ 10 Well Number 847' FNL, 1177' FWL, Sec. 24, T11 N, R10E, UM ~ ~. 2i~ West Sak 1 D-135 At Total Depth ~ 11 Field and Pool 876' FNL, 3864' FEL, Sec. 24, T11 N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date09.Nov.97Spudded 13 Date11-Nov-97T'D' Reached 14 Date12.Jan.98Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 5015' MD & 4381' TVD 4872' MD & 4245' TVD YES ~ NO U NA feet MD 1668 APPROX 22 Type Electric or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECOI~D 16" 62.58# H-40 SURF. 121' 24" 9 cu )/ds High Ead)/ 7.625" 29.7# L-80 SURF. 5000' 9.875" 488 sx AS III LW, 340 sx Class G, 60 ASI 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2.875" 4172' 4598', 4514', 4512', 4409', 4339', 4228' 4300-4334' M D 3707'-3738' TVD 12 spf 4370'-4406' MD 3772'-3806' TVD 12 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4466'-4510' MD 3862'-3903' TVD 12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4542'-4598' MD 3933'-3986' TVD 12 spf 4300'-4334' D: 83007# 16/20/proppant SWS 4.5" HSD TOP w/ultra-pack 24 GM I~DX chorges 4370'-4406' B: 119,588# 16/20 proppant 4466'-4510' A3: 8099# 16/20 proppant 4542'-4598' A2: 45355# 16/20 proppant 27 PRODUCTION TEST Date First Productionol/14/1998 Method of OperatiOnEsp(FIowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO Ol/22/1998 6 TEST PER ICI: 53 9 8 0I 187 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 152 -] 5 24-HOUR RATE: 2~ 2 40 34 21.4° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-t-80 CONTINUED ON REVEr~SE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 4299' 3706' Base West Sak Sand 4772' 4150' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 07, ,_ Prepared by Name/Number Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form10-407 Date: 2/6/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-135 RIG:NORDIC WELL_ID: AK9069 TYPE: AFC: AK9069 AFC EST/UL:$ 1810M/ 2172M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:il/09/97 START COMP:12/02/97 WI: 0% SECURITY:0 API NUMBER: 50-029-22816-00 FINAL:il/13/97 11/08/97 (D1) TD: 121' (121) SUPV:GRW MW: 9.1 VISC: 275 PV/YP: 32/36 APIWL: 4.8 WORKING ON BALL MILL Rig move from 1D-130 to 1D-135. Rig accepted at 14:30 hrs. 11/8/97. Function test diverter. 11/09/97 (D2) TD: 2111' (1990) SUPV:GRW MW: 9.4 VISC: 191 PV/YP: 23/29 APIWL: 7.8 DRILLING Function test diverter. Drill from 121' to 2111' 11/10/97 (D3) TD: 4200' (2089) SUPV:GRW 11/11/97 (D4) TD: 5015'(815) SUPV:DEB 11/12/97 (D5) TD: 5015'( SUPV:DEB 0) 11/13/97 (D6) TD: 5015'( SUPV:DEB 0) 11/14/97 (D7) TD: 5015'( SUPV:DEB 0) MW: 9.3 VISC: 204 PV/YP: 31/38 APIWL: 7.4 POOH FOR MWD Drill from 2111' to 2585' Had gas cut mud and slight oil show @ 2300' MD. Drill from 2585' to 4100' Pump hi-vis sweep. Circ hole clean. No problems. MW: 9.5 VISC: 118 PV/YP: 24/34 APIWL: 6.6 PREPARE TO POH FOR CASING Drill from 4200' to 4295'MD. MWD not working, try to get survey, no go. Change out LWD and MWD. Drill to 5015' MD. MW: 9.6 VISC: 48 PV/YP: 16/14 APIWL: 7.2 CIP ON 7-5/8" CASING RU to run 7-5/8" casing. Held pre-job safety meeting. Run 7-5/8" casing. Pump cement. MW: 9.0 VISC: 39 PV/YP: 5/22 APIWL: 18.8 WELL DISPLACED TO 9.3+ PPG BRI Continue let stage cement job. Pump 2nd stage cement job. NU BOPE, Test BOPE to 300/3000 psi. Wash and ream through cement stringers from 2030' to 2333' and 2525' to 2619' Tag cement. Drill out firm cement from 4500' to 4810' and continue to drill out cement. MW: 9.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Continue drilling cement from 4810' to plug/baffle at 4875' PBTD. Test 7-5/8" casing to 3000 psi for 30 minutes, OK. ND BOP. NU tubing head adapter. Test packoff~,to~5000:~psi~-~OK. Release rig @ 1430 hrs. 11/14/97. ill` [ii ~ ~ i.' 1%"" i'i. i~I Date: 2/6/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-135 RIG:NORDIC WELL_ID: AK9069 TYPE: AFC: AK9069 AFC EST/UL:$ 1810M/ 2172M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:il/09/97 START COMP:12/02/97 WI: 0% SECURITY:0 API NUMBER: 50-029-22816-00 FINAL:il/13/97 12/02/97 (C8) TD: 5000' PB: 4872' SUPV:DW 12/03/97 (C9) TD: 5000' PB: 4872' SUPV:DW 12/04/97 (Ci0) TD: 5015' PB: 4872' SUPV:DW 12/05/97 (Cll) TD: 5015' PB: 4872' SUPV:DW 12/06/97 (C12) TD: 5015' PB: 4872' SUPV:DW 12/07/97 (C13) TD: 5015' PB: 4872' SUPV:DW 12/08/97 (C14) TD: 5015' PB: 4872' SUPV:DW 12/09/97 (C15) TD: 5015' PB: 4872' CLEANING UNDER ROTARY TAB MW: 0.0 Turn key rig move from 2T-38A to lC pad. CLEANING RIG FLUID SYSTEM MW: 0.0 Continue turn key rig move from 2T pad to lC pad. Accept for rig cleaning operations 8 0400 hrs. 12/3/97. Clean pits. MW: 0.0 Continue to clean rigs fluid system. Make up 11" double gate BOP stack in cellar. MOVING RIG MW: 0.0 Continue cleaning, painting and working on 11" BOPE stack. MOVE RIG, MOVE OVER WELL MW: 0.0 Continue cleaning. Remodify cellar doors to clean instrument package on flowline. Move rig from lC pad to FCC. Dowell moving coil tubing unit on 1D-129 for quick tubing clean out. BOPE TEST. LEAK MW: 0.0 BRINE Continue move to iD pad. Move rig over 1D-135. N/D tree. N/U BOPE. Function test BOPE fill with water, test 250-3500 psi. P/U 3.5" WORKSTRING MW: 8.7 KCL Continue to test BOPE. Unable to get test leaking past plug. RIH w/3.5" mule shoe joint to 1881' Circulate w/warm seawater to remove diesel and to warm up hole. PREP TO SET BAKER SUMP PA MW: 8.7 Safety meeting. Pump Hogwash to clean out well. KCL Date: 2/6/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/10/97 (C16) TD: 5015' PB: 4872' SUPV:RWS 12/11/97 (C17) TD: 5015' PB: 4872' SUPV:RWS 12/12/97 (C18) TD: 5015' PB: 4872' SUPV:RWS 12/13/97 (C19) TD: 5015' PB: 4872' SUPV:RWS 12/14/97 (C20) TD: 5015' PB: 4872' SUPV:RWS 12/15/97 (C21) TD: 5015' PB: 4872' SUPV:RWS 12/16/97 (C22) TD: 5015' PB: 4872' SUPV:MC 12/17/97 (C23) TD: 5015' PB: 4872' SUPV:MC 12/18/97 (C24) TD: 5015' PB: 4872' SUPV:MC 01/03/98 (C25) TD: 5015' PB: 4872' SUPV:MC RIH W/BAKER BETA FRAC SCR MW: 8.7 KCL Safety meeting. RIH w/sump packer. Set packer e 4601' WLM. RIH w/perf guns. Guns fired. WOW E-LINE UNIT MW: 8.7 KCL Continue reversing circ and filtering fluid. Lay down perf guns. Ail guns fired. Safety meeting. RIH w/frac pac on tubing. PREP TO POH W/CLEANOUT AS MW: 8.7 KCL Continue RIH w/beta frac pac on 3.5" tubing. RIH w/GR-CCL to correlate depths. Confirm frac pac assy 12' high. Pull and lay down frac pac assy. Middle packer missing rubber and metal collets on both sides of element. MILLING SUMP PACKER MW: 8.7 KCL RIH w/cleanout BHA on 3.5" tubing. Worked pipe thru interval @ 4313-4343' where middle packer was stuck. No indication of any junk. R/D SCHLUMBERGER E-LINE MW: 8.7 KCL RIH with packer milling BHA. Mill sump packer @ 4594'. POH, 3 boot baskets contained - 3 gal metal cuttings. PREP TO FRAC BTM(A-2) SAN MW: 8.7 KCL Safety meeting. RIH w/sump packer and set @ 4598' WLM. Run isolation packeer. MW: 8.7 KCL Continue to try and set isolation packer. Pump frac 1st stage of 4 stage frac. Reverse out proppant. Flow flowing. Shut in. Monitor well. FREEZE PROTECT WELL. MOVI MW: 9.6 KCL Load brine into pits. Pump brine for well control. Fluid losses stabilized. RIG RELEASED MW: 0.0 Freeze protect w/diesel. Pump 10.3 ppg brine. Open tubing well flowing. Pump 10.3 ppg brine. Tubing dead. NU tree and test. Prepare to move rig. Release rig @ 1700 hrs. 12/18/97. TESTING BOPE Move rig. Accept rig @ 1900 hrs. MW: 8.7 KCL Date: 2/6/98 ARCO ALASKA INC. WELL SI/MMARY REPORT Page: 4 01/04/98 (C26) TD: 5015' PB: 4872' SUPV:MC RIH T/CUT 4.5" TUBING MW: 8.7 KCL NU BOPE. Function test. Test BOPE to 300/3000 psi. Pull tubing. Tag and latch into SC packer w/packer retrieving tool, attempt to release packer and POOH w/frac pac assembly. Unable to pull free. Attempt to rotate out of isolation packer w/o success. 01/05/98 (C27) TD: 5015' PB: 4872' SUPV:MC LOADING PIPE SHED W/3.5" MW: 8.7 KCL RIH w/3.5" DP. Cut 4.5" tubing below SCi packer @ 4261' Latch inn to SCi packer w/packer retrieving tool. Release packer. POOH w/packer. RIH to fish. Latch onto fish. Attempt to pull fish through perforations w/o success. Fish hung w/top isolation packer above 1st set of perforations and bottom isolation packer between 1st and 2nd set of perforations. 01/06/98 (C28) TD: 5015' PB: 4872' SUPV:DW POOH W/FISH MW: 8.7 KCL POOH w/fish. RIH w/fishing BHA #5. Work and drive down pull 250K fish came free. POOH slowly due to swabbing. POOH w/fish. 01/07/98 (C29) TD: 5015' PB: 4872' SUPV:DW SET PACKER MW: 8.7 KCL Tag fish @ 4450' Rotate and release latch f/isolation packer @ 4514' Continue to RIH with fishing BHA. 01/08/98 (C30) TD: 5015' PB: 4872' SUPV:DW SETTING ISOLATION PACKERS MW: 8.7 KCL Run packer to 4504' and set. RIH w/Baker frac pac assembly. 01/09/98 (C31) TD: 5015' PB: 4872' SUPV:DW COMPLETED B ZONE FRAC MW: 8.7 Set isolation packers. Pump frac of A3 sand perfs 4466-4510'. Set frac & pack B zone perforations @ 4370'-4406' Pump data frac. KCL 01/10/98 (C32) TD: 5015' PB: 4872' SUPV:DW RIH WITH 2-7/8" TBG MW: 9.2 KCL Continue frac & pack of zone B 4370'-4406' Pump frac of 'D' zone 4300'-4334' 01/11/98 (C33) TD: 5015' PB: 4872' SUPV:DW SPLICING ESP,'I' WIRE MW: 8.8 KCL RIN w/2-7/8" tubing. RIH with ESP & heat trace completion. 01/12/98 (C34) RIG RELEASED 1/12/98 @ 18 MW: 8.7 KCL TD: 5015' Finish running 2-7/8" tubing ESP completion. N/D BOPE, NU PB: 4872' tree and test to 5000 psi. Move off rig and clean up around SUPV:DW well. Release rig @ 1800 hrs. 1/12/98. i iii. ,?. End of WellSummary for Well-AK9069 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-135(W4-6)) JOB NUMBER 1210971614.3 DAY 1 WELL JOB SCOPE 1D-135 FRAC, FRAC SUPPORT DATE DALLY WORK UNIT NUMBER 12/16/97 PUMP "A-2" FRAC SUPERVISOR JOHNS KEY PERSON DS-YOAKUM Final Inner Ann I I 0 PSI OPERATION COMPLETE SUCCESSFUL NO NO Initial Tbg Press I Final Tbg Press Initial Inner Ann 0 PSII 0 PSI 0 PSI Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI DAILY SUMMARY PUMPED 45,355# OF 16/20 PROPPANT IN PERFS. SCREENED OUT MAX. 5600 PSI. 5.5 PPA. I TIME LOG ENTRY 04:54 PUMPED IMPULSE TEST AT 13 BPM, 20 BBLS AT 3000 PSI. 50# HEC GEL 04:58 SHUT DOWN FOR ISIP 905 PSI. 05:28 PUMP 180 BBLS BREAKDOWN AT 15 BPM AND 2982 PSI. 05:40 PUMP 51 BBLS FLUSH, 15 BPM AND 2215 PSI. 05:43 SHUTDOWN FOR ISIP AND PULSE TEST. 06:05 PUMP DISPLACMENT AND DATA FRAC, 5 TO 15 BPM, 141 BBLS AND 2228 PSI. 06:18 SHUT DOWN FOR ISIP, 919 PSI. 06:46 PUMP 65 BBLS PAD, 5 TO 15 BPM, 2233 PSI. 06:53 PUMP 2 PPA 16/20, 15 BPM 2187 PSI. 06:56 PUMP RAMP TO 5 PPA , 15 BPM AND 2054 PI. 07:20 WELL SCREENED OUT, 5600 PSI. 07:25 WENT TO REVERSE OUT WITH DRILL PIPE. TO CLEAN OUT. TOTAL OF 45355 # 16/20 IN PERFS. LEFT 6500# IN DRILL PIPE INITIALLY, THEN REVERSED IT OUT OF PIPE. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-135(W4-6)) WELL 1 D-135 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 1210971614.3 DATE DALLY WORK UNIT NUMBER 01/09/98 PUMP FRAC ON A-3 & B SANDS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 YES I YES DS-GALLEGOS JOHNS Final Inner Ann I I 0 PSI Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 0 PSII 0 PSI DAILY SUMMARY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI IPLACED 8099# 16/20 PROPPANT IN A-3 SANDS, FRAC SCREENED OUT EARLY. PLACED 119,558# 16/20 PROPPANT IN THE "B" SANDS. TIME LOG ENTRY 10:30 HELD PRE JOB SAFETY MEETING. 11:18 PRESSURE TEST TREATING LINE TO 4000 PSI. 12:26 START PUMPING BREAKDOWN WITH 50# HEC, 20 BPM AND 1000 PSI. HEC TANK SUCTION VALVES FROZEN , CALL HOT OIL PUMP TO THAW. 14:09 START BREAKDOWN PUMP100 BBLS HEC AT 15 BPM AND 3700 PSI. 14:17 PUMP FLUSH 15 BPM AND 2779 PSI. SHUT DOWN FOR ISIP 1168. 14:21 PUMP PULSE TEST AND SHUTDOWN. 15:25 START DATA FRAC AND FLUSH WITH 89 BBLS FLUIDS 5 TO 15 BPM AND 2839 PSI. SHUT DOWN FOR ISIP. 17:33 PUMP PAD AND DISPLACEMENT, 80 BBLS HEC. 17:43 PUMP 16/20 PROPPANT FROM 2 PPA TO 5 PPA, FRAC SCEENED OUT WITH 8099 # IN FORMATION. REVERSED SLURRY FROM TUBING AND POSITIONED FRAC PACK TOOL TO "B" SANDS. 19:48 START IMPULSE TEST ON "B" SANDS, 20 BBLS HEC GEL AND 3928 PSI. SHUT DOWN FOR ISIP 1012 PSI. 20:51 PUMP BREAKDOWN 15 BPM, 150 BBLS HEC AND 3260 PSI. 21:01 PUMP FLUSH WITH 39 BBLS DIESEL AT 15 BPM AND 2308 PSI. SHUT DOWN FOR ISIP AND PULSE TESTS. 22:20 START PUMPING DATA FRAC AND FLUSH WITH 37 BBLS HEC AND 38 BBLS DIESEL. 15 BPM AND 3246 PSI. SHUT DOWN FOR ISIP. 23:33 PUMP 95 BBLS PAD OF HEC AT 5 TO 15 BPM AND 2514 PSI. 23:45 PUMP 2 PPATO 9 PPA 16/20 PROPPANT, PLACED 119,558 PROP IN FORMATION. CUT RATE TO 3 BPM TO FORCE SCREENED OUT. REVERSED OUT TUBING SLURRY AND POSTIONED FRAC TOOL TO "D" SANDS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-135(W4-6)) WELL 1D-135 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 1210971614.3 DATE DALLY WORK UNIT NUMBER 01/10/98 PUMPED FRAC TO "D" SANDS DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 YES YES DS-GALLEGOS JOH NS Initial Tbg Press i Final Tbg Press i Initial Inner Ann 0 PSI1 0 PSII 0 PSI DAILY SUMMARY Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSI I P UMPED FRAC TO "D" SANDS, PLACED 83007 # 16/20 PROPPANT TO FORMATION, WELL SCEENED OUT SHORT OF PUMPING FULL DESIGN. TIME LOG ENTRY 02:02 PUMP IMPULSE WITH 20 BBLS DIESEL. 4116 PSI. 03:06 PUMP BREAKDOWN WITH 150 BBLS HEC, 15 BPM AND 3365 PSI. 03:16 PUMP FLUSH OF DIESEL, 15 BPM AND 3365 PSI. 04:41 PUMP DATA FRAC AND FLUSH, 37 BBLS HEC AND 38 BBLS DIESEL. 2363 PSI 5 TO 5 BPM. 05:48 PUMP PAD OF 24 BBLS HEC. 5 BPM AND 1841 PSI. 05:53 PUMP 83007# 16/20 PROPPANT, 2 PPA TO 5 PPA. SCREENED OUT FRAC, REVERSED OUT SLURRY FROM TUBING. SHUT DOWN. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, .iNC. KRU / WS 1D-135 500292281600 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/24/97 DATE OF SURVEY: 111297 MWD SURVEY JOB NUMBER: AKMM80003 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. · 00 .00 -111.50 121.00 121.00 9.50 380.00 380.00 268.50 560.35 560.33 448.83 649.96 649.93 538.43 0 0 0 0 0 25 1 6 0 3O N .00 E .00 .00N .00E .00 N .00 E .00 .00N .00E .00 S 86.99 E .16 .05S .95E .94 N 75.02 E .40 .36N 3.28E 3.17 N 78.00 W 1.74 .67N 3.73E 3.56 745.41 745.37 633.87 832.68 832.60 721.10 922.47 921.98' 810.48 1012.64 1010.96 899.46 1103.20 1099.44 987.94 0 19 3 0 7 38 10 55 13 36 S 50.01 E .84 .58N 3.53E 3.38 S 80.14 E 3.12 .02N 5.98E 5.88 S 81.29 E 5.17 1.28S 14.19E 14.20 S 78.62 E 3.68 3.88S 28.50E 28.74 S 75.39 E 3.04 8.26S 47.23E 47.94 1193.30 1186.51 1075.01 1290.19 1279.04 1167.54 1383.89 1367.71 1256.21 1479.29 1457.04 1345.54 1574.55 1544.95 1433.45 16 10 18 16 19 25 21 37 23 37 S 76.57 E 2.87 13.85S 69.68E 71.03 S 78.56 E 2.25 19.99S 97.69E 99.68 S 79.53 E 1.28 25.74S 127.41E 129.95 S 80.14 E 2.32 31.63S 160.34E 163.40 S 80.59 E 2.11 37.76S 196.47E 200.05 1670.15 1631.85 1520.35 1765.56 1716.83 1605.33 1860.28 1798.97 1687.47 1955.26 1879.01 1767.51 2049.38 1955.91 1844.41 25 36 28 27 31 16 33 50 36 34 S 79.93 E 2.08 44.50S 235.71E 239.86 S 79.03 E 3.02 52.43S 278.32E 283.20 S 79.60 E 3.00 61.17S 324.67E 330.36 S 79.11 E 2.71 70.62S 374.90E 381.47 S 79.53 E 2.91 80.66S 428.22E 435.72 2145.12 2031.39 1919.89 2240.83 2103.89 1992.39 2334.16 2172.03 2060.53 2521.48 2305.78 2194.28 2619.57 2374.67 2263.17 39 20 42 10 44 1 44 50 45 55 S 78.80 E 2.93 91.74S 486.04E 494.60 S 80.32 E 3.13 103.04S 547.48E 557.07 S 80.20 E 1.98 113.83S 610.32E 620.82 S 80.19 E .44 136.16S 739.54E 751.96 S 78.41 E 1.69 149.13S 808.14E 821.77 2809.65 2505.65 2394.15 3000.11 2636.79 2525.29 3189.40 2769.98 2658.48 3284.91 2838.04 2726.54 3381.02 2907.70 2796.20 46 57 46 0 44 32 44 34 42 29 S 79.68 E .73 175.29S 943.36E 959.48 S 79.59 E .50 200.14S 1079.22E 1097.59 S 79.40 E .78 224.66S 1211.45E 1232.07 S 82.64 E 2.38 235.11S 1277.62E 1299.04 S 83.65 E 2.29 243.02S 1343.33E 1365.13 3476.30 2979.82 2868.32 3572.01 3055.98 2944.48 3667.99 3135.34 3023.84 3761.28 3214.89 3103.39 3855.10 3297.12 3185.62 39 6 35 24 33 0 29 58 27 32 S 81.47 E 3.85 251.04S 1405.05E 1427.30 S 79.39 E 4.08 260.63S 1462.18E 1485.23 S 79.42 E 2.51 270.55S 1515.20E 1539.17 S 80.13 E 3.27 279.21S 1563.15E 1587.88 S 80.62 E 2.60 286.76S 1607.63E 1633.01 ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, .INC. KRU / WS 1D-135 500292281600 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/24/97 DATE OF SURVEY: 111297 MWD SURVEY JOB NUMBER: AKMM80003 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC. TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3949.34 3381.60 3270.10 25 2 S 79.88 E 2.68 4044.85 3469.19 3357.69 21 54 S 79.44 E 3.28 4137.42 3555.21 3443.71 21 27 S 79.06 E .52 4233.39 3644.53 3533.03 21 27 S 77.50 E .59 4328.49 3733.23 3621.73 20 50 S 80.70 E 1.37 293.82S 1648.76E 1674.74 300.63S 1686.19E 1712.78 307.01S 1719.78E 1746.97 314.14S 1754.14E 1782.05 320.64S 1787.81E 1816.34 4518.21 3910.99 3799.49 20 3 S 81.22 E .42 4801.55 4178.10 4066.60 18 53 S 82.85 E .46 4949.77 4318.50' 4207.00 18 30 S 84.69 E .47 5015.00 4380.35 4268.85 18 30 S 84.69 E .03 331.06S 1853.27E 1882.61 344.18S 1946.81E 1977.00 349.35S 1994.04E 2024.41 351.26S 2014.66E 2045.04 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2045.05 FEET AT SOUTH 80 DEG. 6 MIN. EAST AT MD = 5015 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 100.06 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,015.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, .INC. KRU / WS 1D-135 500292281600 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/24/97 DATE OF SURVEY: 111297 JOB NUMBER: AKMM80003 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.50 1000.00 998.54 887.04 2000.00 1915.89 1804.39 3000.00 2636.71 2525.21 4000.00 3427.80 3316.30 5000.00 4366.13' 4254.63 5015.00 4380.35 4268.85 .00 N .00 E 3.42 S 26.20 E 75.36 S 399.79 E 200.13 S 1079.15 E 297.50 S 1669.20 E 350.82 S 2009.92 E 351.26 S 2014.66 E .00 1.46 1.46 84.11 82.65 363.29 279.17 572.20 208.91 633.87 61.67 634.65 .78 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, .INC. KRU / WS !D-135 500292281600 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/24/97 DATE OF SURVEY: 111297 JOB NUMBER: AKMM80003 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.50 111.50 111.50 .00 211.50 211.50 100.00 311.50 311.50 200.00 411'.50 411.50 300.00 511.51 511.50 400.00 611.53 611.50 500.00 711.53 711.50 600.00 811.56 811.50 700.00 911.91 911.50 800.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .02 S .45 E .00 .00 .06 S 1.18 E .00 .00 .12 N 2.37 E .59 N 4.00 E .70 N 3.38 E .20 N 5.03 E · 08 S 12.90 E .01 .01 .03 .02 .03 .00 .06 .02 .41 .35 1013.20 1011.50 900.00 1115.62 1111.50 1000.00 1219.32 1211.50 1100.00 1324.37 1311.50 1200.00 1430.38 1411.50 1300.00 3.91 S 28.63 E 9.00 S 50.11 E 15.53 S 76.73 E 22.12 S 108.21 E 28.56 S 142.78 E 1.70 1.29 4.12 2.42 7.82 3.70 12.87 5.06 18.88 6.01 1538.05 1511.50 1400.00 1647.58 1611.50 1500.00 1759.50 1711.50 1600.00 1874.99 1811.50 1700.00 1994.65 1911.50 1800.00 35.37 S 182.06 E 42.80 S 226.11 E 51.89 S 275.50 E 62.56 S 332.24 E 74.79 S 396.78 E 26.55 7.67 36.08 9.54 48.00 11.92 63.49 15.49 83.15 19.67 2119.53 2011.50 1900.00 2251.10 2111.50 2000.00 2389.05 2211.50 2100.00 2529.54 2311.50 2200.00 2672.51 2411.50 2300.00 88.64 S 470.25 E 104.20 S 554.28 E 120.32 S 647.91 E 137.13 S 745.15 E 156.77 S 845.40 E 108.03 24.88 139.60 31.56 177.55 37.95 218.04 40.50 261.01 42.97 2818.22 2511.50 2400.00 2963.70 2611.50 2500.00 3107.35 2711.50 2600.00 3247.66 2811.50 2700.00 3386.14 2911.50 2800.00 176.41 S 949.52 E 195.41 S 1053.46 E 214.07 S 1154.88 E 231.76 S 1251.68 E 243.42 S 1346.74 E 306.72 45.71 352.20 45.48 395.85 43.65 436.16 40.31 474.64 38.49 3516.67 3011.50 2900.00 3639.56 3111.50 3000.00 3757.35 3211.50 3100.00 3871.31 3311.50 3200.00 254.94 S 1429.77 267.70 S 1499.98 278.87 S 1561.20 287.98 S 1615.03 E 505.17 30.53 E 528.06 22.89 E 545.85 17.80 E 559.81 13.96 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, .INC. KRU / WS 1D-135 500292281600 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/24/97 DATE OF SURVEY: 111297 JOB NUMBER: AKMM80003 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3982.20 3411.50 3300.00 4090.44 3511.50 3400.00 4197.90 3611.50 3500.00 4305.24 3711.50 3600.00 4412.24 3811.50 3700.00 296.23 S 1662.16 E 570.70 10.89 303.76 S 1702.87 E 578.94 8.24 311.34 S 1741.47 E 586.40 7.46 319.30 S 1779.65 E 593.74 7.34 325.45 S 1817.22 E 600.74 7.00 4518.75 3911.50' 3800.00 4625.21 4011.50 3900.00 4731.15 4111.50 4000.00 4836.85 4211.50 4100.00 4942.39 4311.50 4200.00 331.09 S 1853.46 E 607.25 6.52 336.66 S 1889.55 E 613.71 6.46 341.35 S 1924.19 E 619.65 5.94 345.61 S 1958.15 E 625.35 5.69 349.13 S 1991.71 E 630.89 5.54 5015.00 4380.35 4268.85 351.26 S 2014.66 E 634.65 3.76 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 I::! I I_1_ I ~ I~ S ~ !::1L~ I r' Ec~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 23, 1997 1D-135, AK-MM-80003 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-135: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22816-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22816-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F! I I--I-- I I~J I~ WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. \~-- Anchorage, Alaska 99501 ' MWD Formation Evaluation Logs 1D-135, AK-MM-80003 December 17, 1997 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' J'ma Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22816-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company MEMORANDUM TO: David joh~, '' Chairman,/'- State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 7, 1997 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor 1%(~¢' FROM: Lou Grimaldi,,~o.~ SUBJECT: Petroleum In§pector ACVJLGEE.DOC BOPE Test Nordic rig #2 Arco well #1 D-135 Kuparuk River Field PTD #97-184 Sunday, December 7, 1997: I witnessed the initial BOPE test on Nordic rig #2 which was preparing to complete Arco West Sak well #1D-135 in the Kuparuk River Field. The rig was ready to test when I arrived. The outside set of choke manifold valves along with the Blind rams and Mud manifold block valve tested "OK". We moved to the next set of valves on the choke manifold and had a slight bleed off on the high-pressure test. We attempted to isolate the leak but could not find the source. We moved to the next set of valves and found a leak there also. A thorough investigation revealed that the tubing hanger was the culprit. As the well was cemented with no perforations, I allowed for the hanger to be pulled and the test plug to be installed. This also leaked as verified by fluid coming out of the annulus valve. The test plug was pulled and reran three times with no success in obtaining a seal. A new test plug was obtained and run;h.h~is_seemed~rse. At this point I ha.'d been up 30 hours and i J eft location to get some rest. I received a call from Don Waster (Arc~'o-mp~that they had redressed the original tubing hanger and obtained a competent seal with it. ~had tested the remainder of the BOPE with all equipment passing. I passed the rig to pull the h'a~~nd complete the well. I noticed during the test a threaded connection on the'casing head that was not isolated from the well bore by a gate valve (see attachment). After speaking with the rig personnel I learned that this was going to be the producbon I~ne. I felt that th~s was not in line with prudent oil field practice and discussed it with the West Sak Production/engineers. I advised them that any threaded connections on wells 3K and above should/have a way to be isolated from the formation. I required at a minimum a VR plug was to.~b'e installed during the time the rig was on the well and that if the threaded connection was-f~ft where it was I would seek guidance from the Commission on whether to approve this, hi,~''/ The connection was moved one valve downstream and is now protected by a gate valve. SUMMARY: I witnessed part of the.. initial BOPE test on Nordic rig #2. There were three failures. ~ Nordic rig #2, Test time 4 hours. No (Partial test). L_o-. Attachments: AAVJLGEE.XLS Wellhead sketch CC: Mike 7anghi (Kuparuk Driilir)g Eng.) 7' ,'/~ .,.,,,,./'.,/~. ~,,.~,',,",.~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initia X 12/7/97 Workover: DATE: Nordic Rig No. 2 PTD # 97-184 Rig Ph.# ARCO Alaska Inc. Rep.: Don Wester 1D-135 (G7) Rig Rep.: Lance Johnson Set@ Location: Sec. 23 T. 11N R. IOE Meridian Umiat X Weekly Other 659-7115 Test MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 300/3000 P 300/3000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 250/3000 300/3000 P 300/3000 P 300/3000 P 300/3000 P 300/3000 P 300/3000 P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 16 300/3000 P 38 300/3000 P P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2,900 I 1,900 X minutes 20 sec. minutes 29 sec. Remote: X 1900 average Psig. Number of Failures: ,Test Time."-'/3.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Problems with tubing hanger/casing head assy made test time long. Pipe rams, Annular preventer, Mud cross valves tested after I left. Fax results to AOGCC offices. Be watful for threaded connections adjacent to wellbore. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) Aavjlgee.xls NON-CONFIDENTIAL KRU 1 D-135 Wellhead Sketch Spacer flange with 1" NPT cut-into it Direct to well bore Wing Valve Prod. Choke ISSV Casing Valve I Wellhead as Found Spacer flange with 1" NPT cut-into it Wing Valve Prod. Choke SSV J Casing Valve I Wellhead as Left IFIow Line TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 24. 1997 Michael Zanghi Drill Site Development Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: WEST SAK 1D-135 (G7) ARCO Alaska. Inc. Permit No. 97-184 Sur. Loc. 526'FNL. 601 'FEL. Sec. 23. T11N, R10E. UM Btmnhole Loc. 877'FNL, 1378'FWL, Sec. 24, T11N, R10E, UM Dear Mr. Zanghi' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for exceptions to 20 AAC 25.033(e) and 25.061 (a) is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surthce casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North David W.',Jo,.hnston Chairman BY ORDER OF THE COMMISSION dl f/enclosures Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. ARCO Alaska, Inc. Kuparuk Drill$ite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor October 16, 1997 ,..,':'.:i 'i .? ]',:)97 Alaska Oil and Gas Conservation Commission , 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill, Addendum Letter #1 West Sak 1D-135 (G7) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: Pursuant to the recent conversation with AOGCC staff regarding the above referenced APD, please note ARCO Alaska, Inc. is making some minor modifications to the original plan of operations for the well. With regard to annular pumping operations, please be advised that the incidental drilling fluids generated from the drilling of the above referenced well will not be hauled to WSI-01 and KRU 1C-12 as indicated in the original APD package dated September 22, 1997. Instead, the waste will be hauled to the nearest permitted disposal well, or it will be pumped down the surface / production casing annulus of an existing well on DS 1D. This plan should be in agreement with requirements set out by AOGCC staff. Please note that the anticipated spud date for this well is October 29, 1997. If you have any questions or require further information on this matter, please contact Tom McKay at (907) 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Attachments CC: West Sak 1D-135 (G7) Well File Tom Brockway ATO-1207 Mike Zanghi ATO-1276 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work' Drill' 'X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test E] Development Oil X Re-Entry E] Deepen [] Service [] UevelopmentGas [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RrB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 526' FNL, 601' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 846' FNL, 1205' FWL, Sec. 24, T11N, R10E, UM WEST SAr 1D-135 (G7) #U-630610 At total depth 9. Approximate spud date Amount 877' FNL, 1378' FWL, Sec. 24, T11N, R10E, UM 1 0/30/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-07 4952' MD 846' @ Target feet 30.8' @ 800' feet 2560 4322' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 800' feet Maximum hole angle 42.9° Maximumsudace 1447 psi• At total depth (TVD) 1 902 psi• 18'. C~sing program Setting Depth size Specifications Top Bottom Quantity of cement , Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 BTC-MO[ 491 1' 41' 41' 4952' 4322' 434 Sx Arcticset III & 406 Sx Class G ,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Intermediate Production Liner -'. Perforation depth: measured true vertical ,~,.,,,'u,~ 2'0. Attachments Filing fee X Property plat [] BOP Sketch X 'Eii'¢(~g~r~'~etch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the fo.r'e, going is true and correct to the best of my knowledge ' Stone ~' Title Drill Site Develop. Supv. Date Commission Use Only Permit Number -1 APl number I Approve, date ,._2¢ ~_.,~.~. I See cover letter for 77-/¢'¢I,o-o~y-- .,~..-,~.-~:~/~ /(/-~ ..- other requirements Conditions of approval Samples required j-'J Yes J~J No Mud log required J J Yes ~ No Hydrogen sulfidemeasures FJ Yes [] No girectionalsurvey required J~ Yes J--J No Required workingpressureforBOPE [] 2M E] 3M BI 5M [] 10M [] 15M Other: ,.~.~g~nat Signed 8~ W. Johnston by order of Approved by ;~/id Commissioner the commission Date //~-~ --,~ ~,/'~ ~'~ Form 10-401 Rev. 7-24-89 Submit in triplicate Drill and Case Plan for West Sak 1D-135 (G7) Frac-Packed Producer General Procedure: . Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . Run and cement 7-5/8" 29.7# L80 BTC-MOD casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. , Pick up 6-3/4" mill tooth bit, 4-3/4" drill collars, and 3-1/2" drill pipe. Trip in and drill out stage collar. Clean out to PBTD. . Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. , Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Nipple down BOP stack. Install production tree and pressure test same. Set back pressure valve. 11. Secure well and release rig. TWM, 9/23/97 Page 1 Completion Plan for West Sak 1 D-135 (G7) Four-Stage, Single-Trip Frac-Pack Job, Frac-Packed Producer General Procedure: Well Preparation 1. Move in / rig up completion rig. . , . . , . , o Pull back pressure valve, nipple down tree and install 11" 5M WP BOP stack and pressure test same. Trip in with 6-3/4" bit and scraper on 3-1/2" workstring, and RIH to to PBTD. Pressure test 7-5/8" 29.7# L80 BTC-MOD casing. Perform casing wash and displace well to filtered brine. Pickle workstring as required. Filter brine to desired level. Trip out. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. Make up Baker sump packer on E-line. RIH and set same below A2 sands (bottom pay sands). Space out and set sump packer to position TCP guns accurately on next trip in. POOH with E-line. Pick up TCP perforating gun string to perforate all West Sak intervals in one trip. Trip in with 3-1/2" workstring, and sting into sump packer seal bore. Locate TCP guns on depth. Set TCP packer above West Sak. Use diesel cap and/or void tubing to achieve desired underbalance. Drop bar and fire guns. Release packer and reverse out to clean brine. Kill well as required. TOH with TCP gun string. Pick up gravel pack assembly, including wire-wrapped screens, gravel pack and isolation packers, blank pipe, frac-pack crossover tool, and other jewelry and trip in hole on 3-1/2" workstring. Screens and packers should be spaced out to allow for isolated frac-packs on the following four West Sak intervals in one trip: Stage 1: A2 Stage 2: A3 Stage 3: A4 + B Stage 4: D Page 2 Stage 10. 11. 12. 13. 14. Stage 15. 16. 17. 18. 19. Stage 20. 21. 22. 23. 24. 1 Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set all isolation packers. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 1. Using 16-20 mesh carbolite proppant, proceed to frac Stage 1 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 1. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 2 Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 2. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 2. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 3 Re-position frac-pack tools to frac~pack Stage 3 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 3. Using 16-20 mesh carbolite proppant, proceed to frac Stage 3 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 3. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Page 3 Staae 4 25. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. 26. Position frac-pack crossover tool as required. Perform data frac for Stage 4. 27. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. 28. Shift crossover tool, and gravel pack Stage 4. 29. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 30. Release frac-pack running tools and trip out of well. At this point, the flow conduit inside the screens from the sump packer to the upper packer should be free of sand and any plugs. Rathole should be available below sump packer. 31. Circulate well to clean brine. TOH with workstring. Change rams to 2-7/8" and pressure test same unless VBR's are available. 32. Pick up Centrilift ESP on 2-7/8" production tubing. 33. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. 34. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 35. Position ESP at desired depth, and set tubing hanger and run electrical penetrators through same. 36. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 37. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 38. Release rig and turn well over to production. TWM, 9/22/97 Page 4 DRILLING FLUID PROGRAM, DRILLING West Sak PRESSURE CALCULATIONS AREA RISKS 1D-135 (G7) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 8-15 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.6-10.0 ppg 35 20-35 5-15 10-35 5-10 8.O-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 50-100 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure)' Since a string of surface casing is not planned for the West Sak 1D-135 (G7) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,684' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WSl-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base in the West Sak 1D- 135 (G7) well to surface, the following MASP can be computed' MASP = (4,134 ft)(0.46 - 0.11 psi/ft) = 1447 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# LB0 BTC casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Following the clean out operation with the completion rig, a frac-pack completion will be installed, after which the ESP pump, power cable, heat trace and production tubing would be installed. Page 2 Drillinq Area Risks: Drilling risks in the West Sak 1D-135 (G7) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-135 (GT). Well Proximity Risks: The nearest existing well to West Sak 1D-135 (GT) is KRU 1D-07. As designed, the minimum distance between the two wells would be 31' at 800' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS 1D, or another KRU drill site. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr)in pumping operations. The West Sak 1D-135 (G7) surface casing / production tubing annulus will be filled with diesel and/or non- freezing brine after setting the 2-7/8" production tubing and prior to the completion rig moving off of the well. Page 3 West Sak 1-01 Annulus Availability ARCO requests permission to utilize the West Sak 1-01 ("WS1-01") annulus for annt pumping of waste incidental fluids generated from the drilling of the West Sak 1 (GT) well. The WS1-01 well was drilled in 1989, and is located on a g ,I pad approximately 0.5 miles west of KRU 1D pad. The WS1-01 9-5/8" x 13-3/I annulus remains open, and a recent injectivity test confirmed its ability to receive fluid The WS1- 01 well records show that a total of 1,401 bbls of mud, water and diesel pumped into this annulus since the well was drilled. ARCO further requests a waiver on the limitation of 35,000 bbl~ annulus, hereby requesting that the WS1-01 annulus be permitted to receive a m mum of 50,000 bbls of fluid from the West Sak drilling operations proposed for e West Sak Phase lA development project on 1D pad. The WS1-01 annulus ha a high level of mechanical integrity as evidenced by the well records and cement bond information. As a side note, it is estimated that the West Sak Phase lA wells, of fourteen (14) wells will generate approximately 84,000 bbls of waste to be dis ',ed of. The WS1-01 well was a vertical well with 13-3/8" casing set through the permafrost to a depth of 2,699' MD/TVD. The 13-3/8" surf. af3e casing was successfully cemented to surface, and the 13-3/8" shoe was tested t¢ ¢~equivalenta of 12.0 ppg EMW after drill out. Later, the 9-5/8" production casing was seta/t~a, total depth of 4,230' MD/TVD. This casing was cemented back to a depth of 2,860',.MD/TVD, as confirmed by cement bond log. In addition, to ensure zonal isolation, @/'cement inflatable casing packer was run and cemented in the 9-5/8" casing at a de/p~ of 3,370' MD/TVD. / ./ Thus, the WS1-01 13-3/8" x 9-5/8*' annulus is fully capable of receiving waste fluids, and has demonstrable integrity bott~/~above and below the receiving zone for the fluids. The receiving zone would be inte~)als above the Ugnu formation which would be considered non-commercial, non-hydro/oarbon bearing zones in this area. ./ .,/ / /- / KRU 10-12 Annulus Availability The next available,-'~tnnulus in the KRU in the vicinity of KRU 1D pad is the 10-12 well drilled in the fall of 199'6. This annulus has not been used for annular pumping, but it remains open and has..-':~he required mechanical integrity to receive wastes. The 9-5/8" surface casing in th!.,s/well was set and cemented using a stage collar. Approximately 129 bbls of cement wff..re circulated to surface during the stage job. ?' The s.,u~sequent leakoff test was conducted to 14.1 ppg EMW, calculated using the standpipe pressure at the point of leakoff. Thus, the well's surface / production casing annulus has the required integrity to receive annular pumping wastes. ARCO further requests a waiver on the limitation of 35,000 bbls per annulus, hereby requesting that the /1'C-12 annulus be permitted to receive a maximum of 50,000 bbls of fluid from the West Sak /'~ drilling operations proposed for the West Sak Phase lA development project on 1D pad. TVVM, 9/22/97 Page 4 r Pad I1:G7 J Field : Kuparuk River Unit Location : North Slope, Alaska ~00 300 600 900 1200 ,.+- ~ 1500 1800 2100 2400 27O0 I 3000 3300 3600 3900 4200 Date plotted : Reference is ~S 10-135/G7 Ver81~ j3. ~o~Jnotes are in fe~ ~f~rence Vc~ic~I gep~s ore r~erence ~B (Parker East (feet) -> 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 EST. SURFACE LOCATION: 526' FNL, 601' FEL ~ SEC. 25, T11N, RIOE 400 RKB EL~ATION: 112' ¢/~ %~ O 600 100.06 AZIMUTH ~;~¢* ~ - ~ oo~ [~ ~aO~~ &o I TARGET LOCATION: lOOO ~IU IA~U~I/ J 846' FNL, 1205' FWL ' - [ SEC. 24, T11N, R]OE TARG ET ~D=5841 TMD=4440 KOP TVD=800 TMD=800 D~P=O DEP=1855 3.00 SOUTH 520 EAST 1806 6.00 ~ 9.00 ~ 12.00 k ~.oo I ¢~ ,OOAT,O,: ~ 8.00 DLS: 5.00 deg per 100 ft [ 877' FNL, 1378' k 212f~0 I SEC. 24. TllN. RIOE ~ ~'7 O0 B/ PERMAFROST ~D=1654 TMD=1663 DEP=192 k ~o.oo ~ 35.00 ~ ~6.00 ~ ;~.oo ~:~lOOTM~:~:;o ~,:~1~ MA ~Cx~Mu~~AN GLg ~ ~2.9 1 DgC ~ T/ UONU SN~S ~:;014 TM~:;4Za ~:~;60 42.0~/BEGIN ANGLE DROP ~D=3057 TMD=3509 DEP=1582 59.00 ~ 36.00 ~ DL~~eg p~ 1~ TARGET - W SAK A3 TVB=3g41 TMD=4440 DEP=lg35 ~B/ W SAK SNDS ~D:~34 TMD=4~52 DEP=1g41 TARGETGET ANGLEANGLE~ ;g0 DEG 4500 t ~ J ~ ~ ~ ~ ~ ~ ~ , ~ , , ~ , 300 0 300 600 900 1200 1500 1800 2100 Vertical Section (feet) -> Azimuth 100.06 with reference 0.00 N, 0.00 E from slot #135 Creo~e~ ~ fi.ch For: T McKAY Date plotted: 27-Aug-97 Plat Reference ts WIS 1D--135/G7 Version ~5. Coordinates ore [n feet reference sl~ ~135. T~e Ve~cal Dep~s are reference RKB (Pamer I^aco ___ Structure : Pad 1D Il : G7 Field : Kuparuk River Unit LoceHon : North Slope, Alesko 8O 4O 4o 8o 120 16O ~ 20o ,4-- 240 ..+- 0 280 I V 320 360 400 440 48O 520 560 600 East (feet) -> 120 80 40 0 40 80 120 160 200 240 280 320 .360 400 440 480 520 I I I I I t I I I I I I I I I I I I I I I I [ I I I I I I I I ,,~." /'"1200 .,.--'~ LC,' .'" ,"' '~ 1700 _ /"1300 70 C~,' A ! /800,00 ~O '~, 1800 //~oo ~ .q.°~ '%,o 9002/ ~ ........ ]_ .¢¢ _oo _ o ];'71000 ............. ~ at'soo ~ooo ,, ................. ~ ~o ~ ~oo ~-T~' ~4oo 1200 2100 ~ 3OO 2200 ~ 4OO 230O 1500 2400 2500 i t i I i 120 80 40 0 40 80 120 160 200 240 280 ;320 .360 400 440 480 520 East (feet) -> 120 160 200 0 240 280 _~. I 320 V 560 400 440 48O 520 560 600 ARCO Alaska, Inc. Pad 1D slot #135 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-135/H7 Version #3 Our ref : prop2187 License : Date printed : 27-Aug-97 Date created : 16-Apr-97 Last revised : 27-Aug-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 56.143,w149 30 36.428 Slot Grid coordinates are N 5959138.713, E 560490.237 Slot local coordinates are 526.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEAP~tNCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PGMS <O-8610'>,,6,Pad 1D 4-Aug-92 161.8 1525.0 1525.0 MSS <3311-8200'>,,7,Pad 1D 4-Aug-92 30.8 800.0 800.0 PGMS <O-8070'>,,3,Pad 1D 4-Aug-92 523.0 20.0 825.0 PG~MS <O-7502'>,,4,Pad 1D 4-Aug-92 402.1 720.0 720.0 PG~MS <O-8930'>,,5,Pad 1D 4-Aug-92 282.5 300.0 3689.3 TOTCO Survey,,WS-8,Pad 1D 16-0ct-96 70.2 1100.0 1100.0 PG94S <O-9783'>,,2,Pad 1D 4-Aug-92 642.8 420.0 420.0 PGMS <O-8365'>,,1,Pad 1D 4-Aug-92 762.6 600.0 600.0 WS 1D-121/G5 Version #2,,HS,Pad 1D 27-Aug-97 345.0 800.0 800.0 WS 1D-133/J5 Version #3,,J5,Pad 1D 26-Aug-97 51.1 825.0 825.0 WS 1D-130/H4 Version #3,,H4,Pad 1D 26-Aug-97 117.6 975.0 975.0 WS 1D-124/G3 Version #2,,G3,Pad 1D 26-Aug-97 255.0 800.0 800.0 WS 1D-129/J3 Version #2,,J3,Pad 1D 26-Aug-97 117.9 740.0 740.0 West Sak 1D-135 (G7) Completion Diagram Four (4) Stage Frac-Pack ~- 16" Conductor @ 80' 2-7/8" Production Tubing Heat Trace Through Permafrost Stage Tool Placed 200' +/- TVD Below Permafrost Power Cable for ESP Mandrel/Valve to circulate well for freeze protection purposes ESP Pump Section ESP Gearbox ESP Motor Section D Sand Frac-Pack Assembly with Screen B + A4 Sands Frac-Pack Assembly with Screen A3 Sand Frac-Pack Assembly with Screen A2 Sand Frac-Pack Assembly with Screen ARCO Alaska, Inc. 7-5/8" Combination Surface/ Production Casing, Cemented to Surface TWM, 9/22/97 KUPARUK RIVER UNIT - WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC 6 I HCR 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENAN(~E ¢ OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE, 4. 20"-2000 PSi DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15197 8 , 7 I J 6 5 4 3 13 5/8" 5000 PSI BOP STACK West Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16"- STARTING HEAD 2. 11" - 5000 PSI HORIZONTAL TUBING HEAD 3. 11" 5000 PSI X 13-5/8" 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" - 5000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 5. 13-5/8"- 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8"-5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8"-5000 PSI ANNULAR TWM, 9/22/97 1 : 9/02/97i AJR PC I AS-BUILT PER KSS~ K97082ACS 2 9/17/97 AJR PC S-BUILT PER K,SB~ Kg7082ACS '~o~ ~ ~ ~ ~ ' 2 ~ i !~ ~4.~3 0 I ~ ~ ,,~ '~ ~CINITY MAP ~ ~ 117 ' ~ SCALE: I~ = I MILE 119 ~ 120 121 , , LEGEND si[ SHE~ , 2 FOR NOTES ~O LO~TION INFORMATION o EX/S~O co~oucro~s ~ LOUNSBURT · NEW CONDUCTOR LOCA EON~z~~/j~ & ASSOCIATES, INC. ~EA' lO ~L[ XX ~NIT' 01 ~k DRILL SI~ 1-D ARCO Amaska, Inc. v ~sl SAK PHASE I- ~ CONDUCTORS AS-BUILT m m LK610410 9/02/97 CEA-D1DX-6104D10 1 ~ 2 2 SEA LEVEL. ALL DISTANCES SHOI~V ARE TRUE. PIT C ! 10 ", i d A 11 I~ MONUMENTS PER LHD AND ASSOCIATES. . `7. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 14 & 2.7, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. 4. DA TE OF SURVEYS: 8/25, 29 & 30/97, FIELD BK L97-24, pp. .72 - 45, 68 - 73. 5. DRILL SITE 1-D GRID NORTH IS ROTA TED 00' 01' 05" II/EST FROM A,S.P. ZONE 4 GRID NORTH. 6. SEE DRAWING NSK-`3,5-1 FOR AS-BUILT LOCATIONS OF CONDUCTORS /Ill THROUGH JtB. -" ~;" _A-/'"..~' ~"' 49th ~ f .... ~ ..... ....~..~..,~..~..~ ....... .,~...~... ..... , VICINITY MAP ~,~.~.~'N J. ROOKUS /,..~.0~.~~ SCALE: I " = I MILE ....... I A. ,.~. P. $ ~ SEC. SEC. PAD O.G. we// ' L A TI TUDE i L ONGI TUDE No. ~ ~ S,,c. 14., T. 11 N., R. IOE. F.S.L.F.E.L. 105 5,959,798.99 560,490.57 70' 18' 02.637' 149' `70' ,36.263' I I`74' 595'170.5' 62.0' 106 5,959,768.93 560,490.67 70' 18' 02.$41' 149' .70' .76.268' 104' 595'170.4' 62.3'! 109 5,959,72.7.89 560,490.60 70' 18' 01.898' 149' .70' .76.280" 59' 596' 70.4' 62.7' S~ c. 23, 7'.11 N., R. IOE. F.N.L.iF.E.L. i 115 5.959,603.9J ' 560,490.68 70' 18' .00.718' 149" JO' J6. J06' 61' 597' 70.4' 6J. 4' , 117 ' 5,959,57.7.95 ! 560,490.65 I 70' 18' 00.42.7' 149' .70' 36,`714" 9I' 597' 70.4' 16`7.4' 118 5,959,558.95 i 560,490.68 : 70' 18' 00.276' 149' 30' .76.$16" I06' 597' 70.4' 119 5,959,51`7.86 560,490.72 70' 17' 59.8`72' 149' 30' `76.326' I5I' 598'1 70.6° ! 66.0' 120 5,959,499.01 560,490.77 70' I7' 59.686' 149' 30' .76..727' 166' 598'i 70.6' i 66.0' 121 5.959,483.89 560,490.67 70' 17' 59.558' 149' 30' `76..735' 18I' 598'i 70.5' ; 66.0 124 5,959,39`7.96 560,490.70 70' 17' 58.65`7' 149' .70' .76.355' 271' 599' 70.,.," 65.0' I 129 5,959,27.7.92 560,490.79 70' 17' 57.472' 149' .70' `76.380' 391' 600' 70.$' 68.2' 1`70 5,959,259.09 ! 560,490.81 70' I7' 57.,:726' 149' .70' .76.383' 406' 600' 70.5' 68.2' 133. 5,959,21`7.89 i 560,490.68 ! 70' 17' 56.882' 149' `70' `76.397' 451' 600' 70.4' 69.0' 135 5,959,1,39.02 ! 560,490.80 70' 17' 56.146' 149' ,30' .76.412' 526' 601' 70.5' 69.4' SURVEYOR'S CERTIFICATE / HEREeW CER~r~ THAT ~ AM ~RO~ER. ~ REC~Sr~REO ANO .CENSEO TO ~RAC~CE ~ANO SURVE,N~ IN THE STATE OF ALASka ANO THAT THIS ~.Ar RE~RESENTS LOUNSBURY A SURVEY DONE BY ME OR UNOER Mr OIRECr SU~'ERWSION AND mar ALL DIMENSIONS AND OTHER ~/,[3~. & ASSOCIATES, INC. DETAILS ARE CORRECT AS OF AUGUST JO, 199Z ~,,~-'--~,,~,~,,,.ms Pu~,s,s su,v~,oRs AREA' 1D MODULE' XX UNIT' D1 ~ DRILL SITE 1-D ARCO Alaska, Inc. WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT I io i. v: LK6~0,,~0 9/02/97 CEA-D1DX-6104D10 2 DE 2 2 No. ,y, A.S.P.$ 'X' LA TITUDE LONGITUDE L~s L~s ELEV. ELEV. S,.c. 14, T. 11 N.,R. IOE. F.S.L.F.E.L. 105 5,959,798.99 560,490.57 70' 18' 02.6`37" 149' `70' 36.26`3' 134' 595' 70.5' 62.0' 106 5,959,768.9`3 560,490.67 70' 18' 02.,741" 149' JO' J6.268" 104' 595' 70.4' 62.,3'! 109 5,959,72`7.89 560,490.60 70' 18' 01.898" 149' `70' 36.280" 59' 596' 70.4' 62.7' S ,,c. 23, T. 11 N.,R. IOE. F.N.L.IF.E.L. 115 5.959,60,3.95 560,490.68 70' 18' .00.718' 149' JO' 36.306' 6I' 597' 70.4' 6`3.4' 117 5,959,573.95 560,490.65 70" 18' 00.42.7' 149' .70' 36,.714" 9I' 597' 70.4' 63.4' 118 5,959,558.95 560,490.68 70' 18' 00.276' 149' `30' .76.,316" I06' 597' 70.4' 119 5,959,51.7.86 560,490.72 70' 17' 59.8.72' 149' ,30' .76.,326' I5I' 598' 70.6' 66.0' 120 5,959,499.01 560,490.77 70' I7' 59.686' 149' ,30' .76..727' 166' 598' 70.6' 66.0' 121 5.959,48,3.89 560,490.67 70' 17' 59.538' 149' ,30' .76..7,35' 18I' 598' 70.5' 66.0 124 5,959,,39`7.96 560,490.70 70' 17' 58.65`3' 149® ,30' .76.355' 271' 599' 70.$' 65.0' 129 5,959,27J. 92 560,490.79 70' 17' 57.472' 149' JO' 36.380" 391' 600' 70.3' 68.2' 130 5,959,259.09 560,490.81 70' I7' 57.J26' 149' JO' 36.383' 406' 600' 70.5' 68.2' 1J3. 5,959,213.89 560,490.68 70' 17' 56.882' 149' JO' 36. J97' 451' 600' 70.4' 69.0' 135 5,959,1J9.02 560,490.80 70' 17' 56.146' 149' JO' 36.412" 526' 601' 70.5' 69.4' ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor September 22, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re- Application for Permit to Drill West Sak 1D-135 (G7) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs' ! ARCO Alaska, Inc. hereby g'pplies for a Permit to Drill an onshore development well to the West Sak in~/al from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed as a producer well using a frac-pack completion technique for reservoir stimulation and sand control purposes. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following' 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements detailed in ARCO's testimony for West Sak Pool Rules governing the West Sak development project. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · ' Anch0ra¢0 6) 7) 8) 9) 10) Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-135 (GT), such as shallow gas. There have been eight (8) Kuparuk wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. Please note that ARCO requests permission to use two (2) well annuli which are not located on KRU 1 D pad, and that ARCO requests that the 35,000 bbls disposal limitation be increased for these two annuli in order to accommodate the predicted volume of waste to be generated from the West Sak Phase lA development operation. The Phase lA development includes the drilling of fourteen (14) West Sak wells from the KRU 1 D pad. ARCO requests that the WS1-01 and 1C-12 wells be permitted to receive 50,000 bbls of waste each for the West Sak Phase lA project. Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is October 301 1997. If you have any questions or require further information, please contact Tom McKay at (907) 265-6890. Sincerely, Thomas W. c ay/P.E. Senior Drilling Engineer Attachments CC: West Sak 1D-135 (GT) Well Tom Brockway ATO-1207 Mike Zanghi AT©-1276 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 File · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ¢--7/¢(_,)/~'('~ INIT CLASS WELL NAME ¢~.,'P~'7/ ,~;,~,~ ./'~'/,'~,~' PROGRAM: exp [] dev~'redrll [] serv [] wellbore seg E} ann. disposal para req [] ./- ~::~/'/ GEOL AREA ~:~,~ O UNIT# //./'. ,~.:~ ~ ON/OFF SHORE ~,~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. ~ 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ ~---,N 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N ~"~ 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N ¢~R DATE/ ._ REMARKS 30. Permitcan be issued w/o hydrogen sulfide measures ..... '~, N~,.'/~ 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. /Y/' N 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for we,ekly,pro~lress reports / Y N lexplorarory only] ...... © GEOLOGY: ENGINEERING: COMMISSION: JUH ~ RNC ~~ CO Cz) HOW/lit - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Dec 16 11:06:39 1997 Reel Header Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80003 S. BURKHARDT G. WHITLOCK 1D-135 500292281600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 16-DEC-97 MWD RUN 2 AK-MM-80003 S. BURKHARDT G. WHITLOCK 23 liN 10E 526 601 .00 111.50 70.50 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 5015.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES AND MIKE WERNER OF ARCO ALASKA, INC. ON 12 DECEMBER, 1997. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5015'MD, 4380'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH 121.0 121.0 121.0 121.0 121.0 131.0 132.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 4970 0 4970 0 4970 0 4970 0 4977 5 4970 0 5015 0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 132.0 4295.0 2 4295.0 5015.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OH/~M 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 121 5015 2568 GR 8.1594 111.081 56.6314 RPX 0.4596 375.366 30.044 RPS 0.449 2000 38.5165 RPM 0.7552 2000 70.367 RPD 0.6302 2000 103.345 ROP 10.3955 987.027 267.914 FET 0.0734 13.0975 0.611233 Nsam 9789 9714 9699 9699 9699 9699 9766 9679 First Reading 121 121 121 121 121 121 132.5 131 Last Reading 5015 4977.5 4970 4970 4970 4970 5015 4970 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5015 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 121 . 0 4250 . 0 RPM 121 0 4250.0 RPS 121 0 4250.0 RPX 121 0 4250.0 GR 121 0 4258.0 FET 131 0 4250.0 ROP 132 5 4295.0 $ LOG HEADER DATA DATE LOGGED: 11-NOV- 97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 4295.0 TOP LOG INTERVAL (FT) : 132.0 BOTTOM LOG INTERVAL (FT): 4295.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 47.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : TOOL NUMBER P0866CRG6 P0866CRG6 9.880 9.9 SPUD MUD 180.80 191.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.5 450 7.8 3.400 2.630 4.500 4.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OH/~M 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 42.2 First Name Min Max Mean Nsam Reading DEPT 121 4295 2208 8349 121 GR 8.1594 104.898 53.9028 8275 121 RPX 0.4596 375.366 34.0372 8259 121 RPS 0.449 2000 43.9384 8259 121 RPM 0.7552 2000 81.3489 8259 121 RPD 0.6302 2000 119.992 8259 121 ROP 10.3955 987.027 287.871 8326 132.5 FET 0.0734 7.2578 0.496206 8239 131 Last Reading 4295 4258 4250 4250 4250 4250 4295 4250 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4295 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 ' Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4161 0 4161 0 4161 0 4161 0 4161 0 4170 5 4206 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIM13M ANGLE: MAXIMUM ANGLE: STOP DEPTH 4970.0 4970.0 4970.0 4970.0 4970.0 4977.5 5015.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA il-NOV-97 ISC 5.06 CIM 5.46 MEMORY 5015.0 4295.0 5015.0 18.5 20.8 TOOL NUMBER P0863CRG6 P0863CRG6 OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHFiM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.880 9.9 SPUD MUD 182.70 400.0 9.0 400 6.6' 4.000 2.990 4.600 4.200 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 44.5 Name Min Max Mean DEPT 4161 5015 4588 GR 37.3002 111.081 71.6284 RPX 1.2983 97.6399 7.02692 RPS 1.426 84.5193 7.31922 RPM 1.5937 87.3129 7.29185 RPD 1.6752 90.3249 7.7881 ROP 11.2617 652.585 158.094 FET 0.1987 19.0908 2.81939 Nsam 1709 1615 1619 1619 1619 1619 1618 1619 First Reading 4161 4170.5 4161 4161 4161 4161 4206.5 4161 Last Reading 5015 4977.5 4970 4970 4970 4970 5015 4970 First Reading For Entire File .......... 4161 Last Reading For Entire File ........... 5015 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File