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197-097
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By Samantha Carlisle at 4:01 pm, Jan 19, 2021 / 320-191 RBDMS HEW 1/25/2021 Abandon Date 12/19/2020 HEW xG DSR-2/25/21DLB 01/26/2021VTL 5/5/21 !"#"$ !"%&$ ' ( ) ! * +, ,, - - .' / +, / (0 '+ & ) + 1- - + + 22 + 1 ,- 3 2 , 4 ,3 5, 6 ,37 '+ ' , + 8 (+ 9: &#;%!! < ), ! ), !1 ), %1 ), 9 ), !" ), !9 ), & ), && ), & ), &% ), &: ), &= ), ), ! + 8 , > - + 8 )2 - ) 52 2 ' ) / , / ? , / ,, 8 + 2- ' / 2 1, ' '2 + + ,/ 1, ' / +' / '+2 '+ / 1 @ 1 - - ' & &":! 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Tyler Senden Digitally signed by R. Tyler Senden Date: 2021.01.19 10:15:00 -09'00' Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM 8,584.0 5/9/2014 3K-23 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Update fullbore cement P&A 9/9/2020 3K-23 cjkenne Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 45.2 Set Depth (ftKB) 121.0 Set Depth (TVD)… 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 45.2 Set Depth (ftKB) 4,969.5 Set Depth (TVD)… 4,094.2 Wt/Len (l… 29.70 Grade L-80 Top Thread ABM-BTC Casing Description PRODUCTION 5.5"x4.5" OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 45.2 Set Depth (ftKB) 10,439.2 Set Depth (TVD)… 6,679.4 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC-MOD Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 45.2 Set Depth (ft… 7,915.0 Set Depth (TVD) (… 6,206.7 Wt (lb/ft) 9.20 Grade L-80 Top Connection IBT-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 484.8 484.6 2.96 NIPPLE CAMCO DS NIPPLE 2.875 7,852.0 6,166.9 50.52 LOCATOR BAKER LOCATOR SUB 2.990 7,853.0 6,167.5 50.53 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 7,856.0 6,169.5 50.55 PBR BAKER 80-40 SPECIAL TRIM PBR 3.913 7,870.4 6,178.6 50.69 PACKER BAKER FA-1 PRODUCTION PACKER 2.930 7,887.0 6,189.1 50.85 NIPPLE CAMCO DS NIPPLE 2.812 7,908.6 6,202.7 51.21 OVERSHOT BAKER POOR BOY OVERSHOT 3.600 Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,895.2 Set Depth (ft… 8,756.4 Set Depth (TVD) (… 6,567.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,427.5 6,468.5 67.69 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,743.7 6,564.9 78.10 LOCATOR BAKER LOCATOR 3.000 8,744.7 6,565.1 78.14 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 6,828.0 5,441.6 42.53Cement Retainer 2.75 X 1.45 Cement retainer 8/28/2020 0.000 7,830.0 6,152.9 50.31 Cement Retainer 2.75" x 1.45' MILLABLE CEMENT RETAINER 2/11/20200.000 7,868.0 6,177.1 50.67 TUBING LEAK EL IDENTIFIED TBG LEAK @ 7868' WITH LDL 6/23/2019 2.990 7,872.0 6,179.6 50.71 CATCHER AVA CATCHER, 2.79" OD, OAL 34.5" 2/1/2020 0.000 7,875.0 6,181.5 50.74 CIBP 2.75" OD, BIG BOY CIBP, 10K PSI RATED, 12K TO SHEAR 1/21/20200.000 7,876.0 6,182.1 50.75 Peak spear Peak releasable spear planted in bowen non- releasable spear on top of CSV ( BAIT SUB 2.72" X 2.33') (XO 1.40" X .35') (PEAK SPEAR 2.19" X 1.63') TOL= 4.32' 7/8/20190.000 7,877.36,182.9 50.76 Bowen Spear Set Bown Non-releasable spear in CSV fish. 2.72" OD X 25.125" long. 2.348" Grapple. 4/17/2017 0.000 7,879.3 6,184.2 50.78 CSV CAT Standing Valve, with damaged fishing neck. 3/1/2017 0.000 10,423. 0 6,678.7 87.45 FISHFISH LOST 2 COLLETS IN WELL FROM T1 LATCH DURING 3/1/2007 GLV INSTALLATION 3/1/2007 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 3,047.5 3,052.5 2,684.8 2,688.4 9/7/2020 1.0 TBG PUNCH 2.0" TUBING PUNCH, 1 SPF, BIG HOLE RMX, 0° PHASE, DECNTRALIZED, HIGH SIDE ORIENTATION 6,846.0 6,850.0 5,454.8 5,457.8 8/10/2020 4.0 TBG PUNCH 2.0" TUBING PUNCH,4 SPF, 0° PHASE, DECENTRALIZED, LOW SIDE ORIENTATION, 7,845.0 7,850.0 6,162.5 6,165.6 2/3/2020 5.0 TBG PUNCH 1.56" OD TUBING PUNCH, 5SPF, 0° PHASE, DECENTRALIZED 8,807.0 10,432.0 6,577.3 6,679.1 A-5, A-4, A-3, A- 2, 3K-23 7/6/1997 24.0 IPERF 60 deg. phasing; Pre- perforated 4 1/2 CSG Frac Summary Start Date 1/6/2007 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 1/6/2007 Top Depth (ftKB) 8,807.0 Btm (ftKB) 10,432.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,895.0 7,850.0 5,491.1 6,165.6 Cement Squeeze 12.2 bbls into IA, 15.8 PPG Class G Cement. 2/11/2020 7,293.0 7,830.0 5,781.7 6,152.9 Cement Plug 4.4 bbls 15.8 ppg class G cement on top of cement retainer at 7830' 2/11/2020 3,102.0 6,828.0 2,724.2 5,441.6 Cement Plug 34 bbls 15.8 ppg class G cement on top of cement retainer at 6808' CTMD (6828' RKB) 8/28/2020 3,102.0 6,850.0 2,724.2 5,457.8 Cement Squeeze 42 bbls 15.8 ppg class G cement below cement retainer at 6808' CTMD (6828' RKB) to IA 8/28/2020 3K-23, 1/12/2021 2:31:09 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"; 45.2- 10,439.2 FISH; 10,423.0 IPERF; 8,807.0-10,432.0 A-SAND FRAC; 8,807.0 SEAL ASSY; 8,744.7 LOCATOR; 8,743.7 NIPPLE; 8,427.5 GAS LIFT; 8,374.7 OVERSHOT; 7,908.5 NIPPLE; 7,887.0 CSV; 7,879.3 Bowen Spear; 7,877.3 Peak spear; 7,876.0 CIBP; 7,875.0 PACKER; 7,870.4 CATCHER; 7,872.0 TUBING LEAK; 7,868.0 PBR; 7,856.0 SEAL ASSY; 7,853.0 LOCATOR; 7,852.0 TBG PUNCH; 7,845.0-7,850.0 Cement Retainer; 7,830.0 GAS LIFT; 7,800.2 Cement Squeeze; 6,895.0 ftKB Cement Plug; 7,293.0 ftKB GAS LIFT; 6,983.7 TBG PUNCH; 6,846.0-6,850.0 Cement Retainer; 6,828.0 GAS LIFT; 5,948.8 Cement Squeeze; 3,102.0 ftKB SURFACE; 45.3-4,969.5 GAS LIFT; 4,592.9 Cement Plug; 3,102.0 ftKB TBG PUNCH; 3,047.5-3,052.5 GAS LIFT; 2,892.3 NIPPLE; 484.8 CONDUCTOR; 45.2-121.0 Cement Plug; 45.2 ftKB Cement Plug; 45.2 ftKB Cement Plug; 45.2 ftKB KUP PROD KB-Grd (ft) 41.02 Rig Release Date 7/2/1997 3K-23 ... TD Act Btm (ftKB) 10,462.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292277100 Wellbore Status PROD Max Angle & MD Incl (°) 89.97 MD (ftKB) 9,152.52 WELLNAME WELLBORE Annotation Last WO: End Date 10/10/2013 H2S (ppm) 150 Date 12/24/2012 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 45.2 3,052.5 45.2 2,688.4 Cement Plug 15.6# Permafrost-C from tubing punches to surface 9/9/2020 45.2 3,052.5 45.2 2,688.4 Cement Plug 15.6# Permafrost-C from tubing punches to surface 9/9/2020 45.2 3,052.5 45.2 2,688.4 Cement Plug 15.6# Permafrost-C from tubing punches to surface 9/9/2020 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 2,892.3 2,573.6 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 2 4,592.9 3,816.5 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 3 5,948.8 4,805.2 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 4 6,983.7 5,556.4 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 5 7,800.2 6,133.8 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 6 8,374.7 6,447.5 BST ATX 1 GAS LIFT OPEN 4/18/2013 Notes: General & Safety End Date Annotation 10/10/2013 NOTE: 2013 Workover tubing cuts still downhole @ 8343', 8313', 8127', 8030' 9/23/2013 NOTE: Mandrel Orientation: 6) 11:30 3K-23, 1/12/2021 2:31:12 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"; 45.2- 10,439.2 FISH; 10,423.0 IPERF; 8,807.0-10,432.0 A-SAND FRAC; 8,807.0 SEAL ASSY; 8,744.7 LOCATOR; 8,743.7 NIPPLE; 8,427.5 GAS LIFT; 8,374.7 OVERSHOT; 7,908.5 NIPPLE; 7,887.0 CSV; 7,879.3 Bowen Spear; 7,877.3 Peak spear; 7,876.0 CIBP; 7,875.0 PACKER; 7,870.4 CATCHER; 7,872.0 TUBING LEAK; 7,868.0 PBR; 7,856.0 SEAL ASSY; 7,853.0 LOCATOR; 7,852.0 TBG PUNCH; 7,845.0-7,850.0 Cement Retainer; 7,830.0 GAS LIFT; 7,800.2 Cement Squeeze; 6,895.0 ftKB Cement Plug; 7,293.0 ftKB GAS LIFT; 6,983.7 TBG PUNCH; 6,846.0-6,850.0 Cement Retainer; 6,828.0 GAS LIFT; 5,948.8 Cement Squeeze; 3,102.0 ftKB SURFACE; 45.3-4,969.5 GAS LIFT; 4,592.9 Cement Plug; 3,102.0 ftKB TBG PUNCH; 3,047.5-3,052.5 GAS LIFT; 2,892.3 NIPPLE; 484.8 CONDUCTOR; 45.2-121.0 Cement Plug; 45.2 ftKB Cement Plug; 45.2 ftKB Cement Plug; 45.2 ftKB KUP PROD 3K-23 ... WELLNAME WELLBORE ! " # $ % &"#& " &' ( &)" (( " (" ( "* " $ + ,-.-/0121/3,134-/1, 135 ' ! ) ,-/6& 0121/31,78/9-/1 :2.# 97;198<,134-/1, /734;=,82,134-/1,94>-/?# 970121/34;8@1,134-/1, :993874=13>5 &08/342-/43138 &.:2.-/6A-1719 1,=8,2<11B9>=:99 3173 82.9131 317338?" ? $ $** ( 5?! " (? ! ' C ()" D5?# $? ! &%& " & &(*' ( &)" C " ( 5 E D " 5E D " $ + ( -,0:9431A?#;;97 F 1,24=,873$;91/A0121/3A8</3;64/A:.38 7:,=401"3G1/:.387:,=40143$;.2 -/490121/3,13:,/78/;83G4/A 70491A5 FH499101770121/3.:2.1A 831I1143340G1A3,143-/6,1.8,3-/ C ? ' D)' )' )' ) ? ' D)C"DC(C (( (( ' D) C (' ()* C' ) E .1/1A3G1""4/A3843287.G1,1=8,?2-/ 47,14A-/67-/3G1EE J" E..2"((EJ"&E..2 47 ,14A-/67-/3G1EE J" E..2"((EJ"&E..2 47 ,14A-/67-/3G1EE J" E..2"((EJ"&E..2 128@1<88A01994, 04@431A38K? :34/A,128@1A3G1734/A-/6.9431 8/3-/:1A38104@431381.8713G1?6,4A1;14274/A08,,:6431A01994, ' D) C E .1/D08/=-,2/8647,14A-/68/ 04@431381.8716,4A1;1427$L40BG4221,08,/1,7$0:34/A,128@1? M M6,4A1;1427 40BG4221,0121/34,8:/A<199 04@431381.87194,616,4A1;1424/AL40BG4221,08,/1,7D734,30:33-/6 8/3-/:10:33-/66,4A1;14274/A,128@18=<199 ' D) C( N((& E .1/D08/=-,2/8.7-8,647,14A-/6-/ 04@431381.871 %#%6,4A1;142$L40BG4221,08,/1,7$0:34/A,128@1 :34/A,128@1';198<6,4A1)8=<199G14A 04@43138$<431,711.-/6-/$738.=8,3G1/-6G3 # ' D)C* C* C * C#$(( * *% $ C '#?% ( " O38349<199,128@1A)(( ' D) (( ( ! ($ !(( DC ,1.<19973:;=8,24,B1,.9431$343124/<-3/1770121/34/A D24,B1,.9431$ <19A24,B1,.94318/<19973:; 40B=-99-/4/A4,8:/A %.-.1$ @-;,438,4/A@-;,431.-.18:3$.-91 13,46,4@198@1, D7-31 ' )C( ( ?!$? 9:64/A;4/A8/ :224,>8=.1,43-8/7 !"#$%"#& ' (" ")* + ! " #$ %&'% %&( ) %& & )* $ ' +,-$ . / 0 ' +,- )# $ 1#2 ' $ . /2 0#$ $ . 1 ' $ 1 $ 1$ . 1 $ $ # * 314 3 5 Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1970970 E-Set: 34347 12/08/2020 Abby Bell Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1970970 E-Set: 34346 12/08/2020 Abby Bell Originated:Delivered to:16-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/16/2020 PTD: 1970970 E-Set: 34122 10/20/2020 Abby Bell 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,462'10,423 Casing Collapse Conductor Surface Production Production Packers and SSSV Type: 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Jill Simek Contact Name:Jill Simek Staff Wells Engineer Contact Email: Contact Phone: (907) 263-4131 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.197-097 7,293 P. O. Box 100360, Anchorage, Alaska 99510 50-029-22771-00-00 KRU 3K-23 ADL 25519 Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY 6,680'10432 6679 0psi Length Size MD TVD Burst 4,928'7 5/8 4,966'4,094' 80'16''121'121' 10,400'5 1/2 10,434'6,679' 1,677'4 1/2 8,744'6,565' 8,756' Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size:Tubing Grade:Tubing MD (ft): 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7845-7850, 8807-10432 6162-6166, 6577-6679 3.500''L-80 PACKER - BAKER FA-1 PRODUCTION PACKER MD= 7870 TVD= 6179 5/15/2020 Authorized Name: Authorized Title:Jill.Simek@cop.com Authorized Signature: COMMISSION USE ONLY Perforate Reppair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Jill Simek Digitally signed by Jill Simek Date: 2020.05.05 07:23:39 -08'00' By Samantha Carlisle at 8:12 am, May 05, 2020 320-191 AOGCC inspection required after the cutoff and BEFORE any remedial cementing. VTL 06/05/20 X 10-407 X XSurface X DLB 05/05/2020 DSR-5/5/2020 Note: Reservoir abandonment plug successfully pumped previously: Sundry 320-064 VTL 06/05/20 dts 6/5/2020 6/5/2020Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.06.05 12:32:13 -08'00' RBDMS HEW 6/9/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska 28 April 2020 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: 3K-23 was drilled and completed in 1997 as an A sand horizontal producer. The well produced continuously until 2012 when it required a workover to replace tubing. In 2017, a CAT standing valve was installed to assist in diagnosing a failed tubing integrity test. The valve was left in hole after multiple failed attempts were made on slickline and coil tubing to retrieve it. Two spears were planted in the CAT standing valve during these attempts but have also been left in hole. The well produced through the stuck CAT standing valve until April 2019, when a second tubing leak was discovered above the valve. In January 2020, the well also began to exhibit inner annulus by outer annulus communication. To prevent the outer annulus pressure from building, a cast iron bridge plug was installed; however, this did not maintain integrity and did not prevent the outer annulus pressurization. In response, heavy brine was circulated to reduce formation pressure and later, in February 2020, a cement plug was pumped through a retainer as a mechanical barrier, isolating reservoir pressure from surface. The cement and fish in hole prevent any future economical utility of the well. The leftover resource of 3K-23 will either be picked up by the rotary horizontal well, 3K-24 to the north or accessed using coil tubing sidetrack out of 3K-03A or 3K-30. Thus, a Plug and Abandonment (P&A) of 3K-23 is recommended. P&A of 3K-23 will also allow for slot recovery for future WestSak development. The well is completed with 3 ½” tubing to 8,756ft KB and 5 ½” x 4 ½” production casing to 10,439ft KB. 7-5/8” surface casing is set at 4,970ft KB. A-sand perforations are at 8,807ft to 10,432ft KB. The well is currently suspended with cement from 7,845ft KB to 7,293ft KB (tubing) and 6,895ft KB (tubing x production casing annulus). Per this procedure, P&A operations will be performed by placing a cement plug in the tubing and tubing x production casing annulus (IA), from approximately 6,850ft KB to 3,000ft KB. Tubing and production casing will be perforated above top of cement and a second cement plug will be pumped fullbore, to bring cement to surface in the tubing, tubing x production casing annulus (IA), and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Please refer to the attached procedure for more details. If you have any questions or require any further information, please contact me at 263-4131. Sincerely, Jill Simek Staff Well Interventions Engineer p, y in February 2020, a cement plug was pumped through a retainer as a p,y,pgp mechanical barrier, isolating reservoir pressure from surface. gp The well is currently suspended with cement from 7,845ft KB to 7,293ft KB (tubing) yp and 6,895ft KB (tubing x production casing annulus). JS 3K-23 P&A Permit to Drill #197-097 P&A operations will be performed by placing a cement plug in the tubing and tubing x production casing annulus (IA), from approximately 6,850ft KB to 3,000ft KB. Tubing and production casing will be perforated above top of cement and a second cement plug will be pumped fullbore, to bring cement to surface in the tubing, tubing x production casing annulus (IA), and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Well Status: The well is currently suspended with cement plug from 7,845ft KB to 7,293ft KB (tubing) and 6,895ft KB (IA). Last known fluid: x 3-1/2” Tubing = diesel x 3-1/2” x 5-1/2” = diesel x 5-1/2” x 7-5/8” = formation water/diesel x Minimum ID = 2.875" at 484.8ft KB (Camco DS Nipple) x Diagnostics indicate TxIAxOA exists x Location of tubing and production casing leaks are unknown x Tubing LLR = 0.024 gpm at 2,000 psi x Production casing LLR = unknown Max Deviation = 45.7degrees at 2,682ft KB Procedure: Eline / Little Red: Objective: Drift for cement retainer, punch tubing, injectivity test 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU E-Line and PT Equipment as required. 3. RIH with 2.75” x 15’ dummy mechanical cement retainer tool string, down to 6,830ft KB. 4. RIH with 2” x 4’ tubing punch, 4 spf; reference 2/11/2020 schematic and tubing details for depth correlation. 5. Punch approximately 6,846ft – 6,850ft KB. JS 6. Rig up LRS and pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 7. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32’ above the previous holes. 8. RDMO. Coiled Tubing / Cementing: Objective: Plug #1 - Place a cement plug in tubing and IA Cement Volume Calculations: x 3 ½” tubing x 5 ½” production casing, tubing punch to 3,000ft KB: (0.01190 bbl/ft) * (6,850ft - 3,000ft) = 45.8 bbl x 3 ½” tubing, cement retainer to 3,000ft KB: (0.008696 bbl/ft) * (6,830 – 3,000) = 33.3 bbl x Total volume = 45.8 + 33.3 = 79.1 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design (Mark Dean 303 506-8462). The job is designed for 79.1 bbls of 15.8# Class “G” cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 2/11/2020 schematic and tubing details for depth correlation. Perform tie-in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with Weatherford 2.75” cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 6,830ft KB. 8. Close in the CT x Tubing annulus and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. RU HAL Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer. 12. Pump 45.8 bbls of Class “G” cement. 13. Shut down, un-sting from retainer 14. Lay in remaining 33.3 bbl cement above retainer (equates to ~ 3,830ft of cement above the retainer, leaving TOC ~3,000ft KB) 15. POOH above TOC 16. Circulate CTU clean. 17. RDMO Slickline / DHD Objective: Tag TOC, MIT-T, establish IAxOA LLR JS 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH and tag TOC @ approximately 3,000’ KB. Record Results. 4. Perform MIT-T to 1,500spi. 5. Perform MIT-TxIAxOA to 1,500psi. 6. Establish IAxOA LLR, if able. 7. Report issues and results to Well Interventions Engineer. 8. RDMO E-line / Little Red Objective: Perforate 3½” tubing and 5½” production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT equipment as required. 3. Log CBL to determine TOC in IA. 4. DISCUSS CBL RESULTS WITH WELL INTERVENTIONS ENGINEER TO CONFIRM REQUIRED PUNCH DEPTH 5. RIH with dual-string perforating gun, referencing 2/11/2020 schematic and tubing details for depth correlation. 6. Perforate above TOC ~3,000’ KB, as close to mid joint as possible. Orient perforating gun to shoot high side of tubing. 7. Rig up LRS and pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 8. If 2 bpm circ. rate is not achievable, RIH with a second perforating gun and perforate holes 32’ above the previous holes. 9. RDMO Cementing: Objective: Plug #2 - Fill the wellbore with cement from perforation depth (~3,000’ KB) to surface. We will be circulating cement down the 3 ½” tubing and up the 7 5/8” x 5 ½” annulus as well as up the 5 ½” x 3 ½” annulus. Cement Volume Calculations: x Volume in 3 ½” x 5 ½” annulus: (3,000’-0’) x 0.01190 bbl/ft = 35.7 bbl x Volume in 5 ½”x 7 5/8” annulus: (3,000’-0’) x 0.01653 bbl/ft = 49.6 bbl x Volume inside 3 ½’ tubing: (3,000’-0’) x 0.008696 bbl/ft = 26.1 bbl x Excess: 20 bbl x Total volume: 35.7 + 49.6 + 26.1 + 20.6 = 132 bbl JS 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design (Mark Dean 303 506-8462). The job is designed for 132 bbls of Permafrost cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU HAL Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 7 5/8” x 5 ½” (OA) and 3 ½” x 5 ½” (IA) annuli independently. Also ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up Permafrost cement. 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 132 bbl of Permafrost Cement (cement to surface in T/I/O, including 20 bbls excess) 9. After approximately 75.7 bbls of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good Permafrost cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. This step must be performed efficiently as Permafrost Cement is thixotropic and will develop gel strength quickly when static. 11. After approximately 35.7 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good Permafrost Cement to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 12. After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO DHD: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. JS Wellhead Excavation / Final P&A: 1. Determine top of cement in tubing and annuli; perform cement top up job. 2. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off T/I/O to ensure all pressure is bled off the system. 5. Remove the production tree, in preparation for the excavation and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness required. ConocoPhillips 3K-23 PTD #: 197-097 API #: 50-029-22771-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. **AOGCC inspection required after the cutoff and BEFORE any remedialcementing. VTL 06/05/20 ** JS Schematic: JS P&A Diagram: Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM 8,584.0 5/9/2014 3K-23 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: SET FH1 CEMENT RETAINER, PUMP 12.2 BBLS 15.8 PPG IN IA, PUMP 4.4 BBLS ABOVE RETAINER. 2/11/2020 3K-23 aappleh Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.2 Set Depth (ftKB) 121.0 Set Depth (TVD)… 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 41.2 Set Depth (ftKB) 4,969.5 Set Depth (TVD)… 4,094.2 Wt/Len (l… 29.70 Grade L-80 Top Thread ABM-BTC Casing Description PRODUCTION 5.5"x4.5" OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 38.8 Set Depth (ftKB) 10,439.2 Set Depth (TVD)… 6,679.4 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC-MOD Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 36.7 Set Depth (ft… 7,915.0 Set Depth (TVD) (… 6,206.7 Wt (lb/ft) 9.20 Grade L-80 Top Connection IBT-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 36.7 36.7 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 484.8 484.6 2.96 NIPPLE CAMCO DS NIPPLE 2.875 7,852.0 6,166.9 50.52 LOCATOR BAKER LOCATOR SUB 2.990 7,853.0 6,167.5 50.53 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 7,856.0 6,169.5 50.55 PBR BAKER 80-40 SPECIAL TRIM PBR 3.913 7,870.4 6,178.6 50.69 PACKER BAKER FA-1 PRODUCTION PACKER 2.930 7,887.0 6,189.1 50.85 NIPPLE CAMCO DS NIPPLE 2.812 7,908.6 6,202.7 51.21 OVERSHOT BAKER POOR BOY OVERSHOT 3.600 Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,895.2 Set Depth (ft… 8,756.4 Set Depth (TVD) (… 6,567.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,427.5 6,468.5 67.69 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,743.7 6,564.9 78.10 LOCATOR BAKER LOCATOR 3.000 8,744.7 6,565.1 78.14 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 7,830.0 6,152.9 50.31 Cement Retainer 2.75" x 1.45' MILLABLE CEMENT RETAINER 2/11/20200.000 7,868.0 6,177.1 50.67 TUBING LEAK EL IDENTIFIED TBG LEAK @ 7868' WITH LDL 6/23/2019 2.990 7,872.0 6,179.6 50.71 CATCHER AVA CATCHER, 2.79" OD, OAL 34.5" 2/1/2020 0.000 7,875.0 6,181.5 50.74 CIBP 2.75" OD, BIG BOY CIBP, 10K PSI RATED, 12K TO SHEAR 1/21/20200.000 7,876.0 6,182.1 50.75 Peak spear Peak releasable spear planted in bowen non-releasable spear on top of CSV ( BAIT SUB 2.72" X 2.33') (XO 1.40" X .35') (PEAK SPEAR 2.19" X 1.63') TOL= 4.32' 7/8/20190.000 7,877.3 6,182.9 50.76 Bowen Spear Set Bown Non-releasable spear in CSV fish. 2.72" OD X 25.125" long. 2.348" Grapple. 4/17/2017 0.000 7,879.3 6,184.2 50.78 CSV CAT Standing Valve, with damaged fishing neck. 3/1/2017 0.000 10,423.0 6,678.7 87.45 FISH FISH LOST 2 COLLETS IN WELL FROM T1 LATCH DURING 3/1/2007 GLV INSTALLATION 3/1/2007 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 7,845.0 7,850.0 6,162.5 6,165.6 2/3/2020 5.0 TBG PUNCH 1.56" OD TUBING PUNCH, 5SPF, 0° PHASE, DECENTRALIZED 8,807.0 10,432.0 6,577.3 6,679.1 A-5, A-4, A-3, A -2, 3K-23 7/6/199724.0 IPERF 60 deg. phasing; Pre- perforated 4 1/2 CSG Frac Summary Start Date 1/6/2007 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 1/6/2007 Top Depth (ftKB) 8,807.0 Btm (ftKB) 10,432.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Start Date Com 6,895.0 7,850.0 5,491.1 6,165.6 Cement Squeeze 2/11/2020 12.2 bbls into IA, 15.8 PPG Class G Cement. 7,293.0 7,830.0 5,781.7 6,152.9 Cement Plug 2/11/2020 4.4 bbls 15.8 ppg class G cement on top of cement retainer at 7830' Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,892.3 2,573.6 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 2 4,592.9 3,816.5 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 3 5,948.8 4,805.2 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 4 6,983.7 5,556.4 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 5 7,800.2 6,133.8 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 6 8,374.7 6,447.5 BST ATX 1 GAS LIFT OPEN 4/18/2013 3K-23, 4/29/2020 2:16:45 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"; 38.8- 10,439.2 FISH; 10,423.0 IPERF; 8,807.0-10,432.0 A-SAND FRAC; 8,807.0 SEAL ASSY; 8,744.7 LOCATOR; 8,743.7 NIPPLE; 8,427.5 GAS LIFT; 8,374.7 OVERSHOT; 7,908.5 NIPPLE; 7,887.0 CSV; 7,879.3 Bowen Spear; 7,877.3 Peak spear; 7,876.0 CIBP; 7,875.0 PACKER; 7,870.4 CATCHER; 7,872.0 TUBING LEAK; 7,868.0 PBR; 7,856.0 SEAL ASSY; 7,853.0 LOCATOR; 7,852.0 TBG PUNCH; 7,845.0-7,850.0 Cement Retainer; 7,830.0 GAS LIFT; 7,800.2 Cement Squeeze; 6,895.0 ftKB Cement Plug; 7,293.0 ftKB GAS LIFT; 6,983.7 GAS LIFT; 5,948.8 SURFACE; 41.2-4,969.5 GAS LIFT; 4,592.9 GAS LIFT; 2,892.3 NIPPLE; 484.8 CONDUCTOR; 41.2-121.0 HANGER; 36.7 KUP PROD KB-Grd (ft) 41.02 Rig Release Date 7/2/1997 3K-23 ... TD Act Btm (ftKB) 10,462.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292277100 Wellbore Status PROD Max Angle & MD Incl (°) 89.97 MD (ftKB) 9,152.52 WELLNAME WELLBORE Annotation Last WO: End Date 10/10/2013 H2S (ppm) 150 Date 12/24/2012 Comment SSSV: NIPPLE Notes: General & Safety End Date Annotation 10/10/2013 NOTE: 2013 Workover tubing cuts still downhole @ 8343', 8313', 8127', 8030' 9/23/2013 NOTE: Mandrel Orientation: 6) 11:30 3K-23, 4/29/2020 2:16:47 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"; 38.8- 10,439.2 FISH; 10,423.0 IPERF; 8,807.0-10,432.0 A-SAND FRAC; 8,807.0 SEAL ASSY; 8,744.7 LOCATOR; 8,743.7 NIPPLE; 8,427.5 GAS LIFT; 8,374.7 OVERSHOT; 7,908.5 NIPPLE; 7,887.0 CSV; 7,879.3 Bowen Spear; 7,877.3 Peak spear; 7,876.0 CIBP; 7,875.0 PACKER; 7,870.4 CATCHER; 7,872.0 TUBING LEAK; 7,868.0 PBR; 7,856.0 SEAL ASSY; 7,853.0 LOCATOR; 7,852.0 TBG PUNCH; 7,845.0-7,850.0 Cement Retainer; 7,830.0 GAS LIFT; 7,800.2 Cement Squeeze; 6,895.0 ftKB Cement Plug; 7,293.0 ftKB GAS LIFT; 6,983.7 GAS LIFT; 5,948.8 SURFACE; 41.2-4,969.5 GAS LIFT; 4,592.9 GAS LIFT; 2,892.3 NIPPLE; 484.8 CONDUCTOR; 41.2-121.0 HANGER; 36.7 KUP PROD 3K-23 ... WELLNAME WELLBORE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1`C�� 3i�1Zcw DATE: March 12, 2020 P.I. Supervisor 1`r SUBJECT: Well Bore Plug & Abandonment KRU 3K-23 FROM: Lou Laubenstein ConocoPhillips Alaska Petroleum Inspector PTD 1970970; Sundry 320-064 Section: 35 Drilling Rig: Operator Rep: Township: Rig Elevation: Bruce Richwine Casing/Tubing Data (depths are MD) Conductor: 16 - O.D. Shoe@ Surface: 7 5/8" 0. D. Shoe@ Intermediate: Csg 0. D. Shoe@ Production: 5.5" x 4.5" 0. D. Shoe@ Liner: Feet 0. D. Shoe@ Tubing: 3.5" 0. D. Tail@ Plugging Data (from 2/18/2020 Inspection Rpt): Test Data 13N Range: 9E Meridian: U 41.02 Total Depth: 10462 ft MD - Lease No.: ADL0025519 Suspend: X P&A: 121 - Feet 4970 Feet Feet 10439 Feet Feet 7915 Feet Type Plug Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing - Retainer 7830 ft MD 7293 ft MD- Wireline tag Annulus - Bottom - 7870 ft MD N/A 1730 1725 Initial 15 min 30 min 45 min Result Tubing 1800 1780 - 1770 - IA 1820 1790 1780 P OA 1800 1730 1725 Remarks: I arrived on location to witness a combo MIT-T/IA/OA on a suspension plug. Previous attempts to separately pressure test the tubing and combined IAxOA failed - refer to my 2/18/2020 report. Today's pressure test (combination TxIAxOA) was performed with passing results and without any issues. Attachments: none rev. 11-28-18 2020-0312_Plug_Verification_KRU_3K-23_11 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: RECEIVE, APR j 2 3 22020 AOGCC 197097 32804 23 -Apr -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:�- Signed: WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 2 3A-08 3K-23 3K-27 3N-09 3N-15 3M-17 50-029-21445-00 50-029-22771-00 50-029-22751-00 50-029-21541-00 50-029-21592-00 50-029-21729-00 906323212 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Multi Finger Caliper Radial Cement Bond Log Final -Field Final -Field Final -Field Final -Field Final -Field 15 -Feb -20 18 0 1 4 SBHP and Plug Setting Record String Shot -Feb -20 0 1 21 -Jan -20 906290370Final-Field 5 6 7 906290370 905268412 906251137 906236139 Record 2 -Feb -20 Tubing Punch Record Packer Set Record Packer Set Record Packer Set Record Packer Set Record 3 -Feb -20 30 -Dec -19 4 -Feb -20 0 1 8 9 10 0 1 10 -Feb -20 18 -Jan -20 19 -Feb -20 0 1 0 1 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:�- Signed: ! 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Tyler Senden Date: 2020.04.03 08:53:19 -08'00' Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM 8,584.0 5/9/2014 3K-23 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: SET FH1 CEMENT RETAINER, PUMP 12.2 BBLS 15.8 PPG IN IA, PUMP 4.4 BBLS ABOVE RETAINER. 2/11/2020 3K-23 aappleh Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.2 Set Depth (ftKB) 121.0 Set Depth (TVD)… 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 41.2 Set Depth (ftKB) 4,969.5 Set Depth (TVD)… 4,094.2 Wt/Len (l… 29.70 Grade L-80 Top Thread ABM-BTC Casing Description PRODUCTION 5.5"x4.5" OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 38.8 Set Depth (ftKB) 10,439.2 Set Depth (TVD)… 6,679.4 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC-MOD Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 36.7 Set Depth (ft… 7,915.0 Set Depth (TVD) (… 6,206.7 Wt (lb/ft) 9.20 Grade L-80 Top Connection IBT-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 36.7 36.7 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 484.8 484.6 2.96 NIPPLE CAMCO DS NIPPLE 2.875 7,852.0 6,166.9 50.52 LOCATOR BAKER LOCATOR SUB 2.990 7,853.0 6,167.5 50.53 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 7,856.0 6,169.5 50.55 PBR BAKER 80-40 SPECIAL TRIM PBR 3.913 7,870.4 6,178.6 50.69 PACKER BAKER FA-1 PRODUCTION PACKER 2.930 7,887.0 6,189.1 50.85 NIPPLE CAMCO DS NIPPLE 2.812 7,908.6 6,202.7 51.21 OVERSHOT BAKER POOR BOY OVERSHOT 3.600 Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,895.2 Set Depth (ft… 8,756.4 Set Depth (TVD) (… 6,567.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,427.5 6,468.5 67.69 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,743.7 6,564.9 78.10 LOCATOR BAKER LOCATOR 3.000 8,744.7 6,565.1 78.14 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 7,830.0 6,152.9 50.31 Cement Retainer 2.75" x 1.45' MILLABLE CEMENT RETAINER 2/11/20200.000 7,868.0 6,177.1 50.67 TUBING LEAK EL IDENTIFIED TBG LEAK @ 7868' WITH LDL 6/23/2019 2.990 7,872.0 6,179.6 50.71 CATCHER AVA CATCHER, 2.79" OD, OAL 34.5" 2/1/2020 0.000 7,875.0 6,181.5 50.74 CIBP 2.75" OD, BIG BOY CIBP, 10K PSI RATED, 12K TO SHEAR 1/21/20200.000 7,876.0 6,182.1 50.75 Peak spear Peak releasable spear planted in bowen non-releasable spear on top of CSV ( BAIT SUB 2.72" X 2.33') (XO 1.40" X .35') (PEAK SPEAR 2.19" X 1.63') TOL= 4.32' 7/8/20190.000 7,877.3 6,182.9 50.76 Bowen Spear Set Bown Non-releasable spear in CSV fish. 2.72" OD X 25.125" long. 2.348" Grapple. 4/17/2017 0.000 7,879.3 6,184.2 50.78 CSV CAT Standing Valve, with damaged fishing neck. 3/1/2017 0.000 10,423.0 6,678.7 87.45 FISH FISH LOST 2 COLLETS IN WELL FROM T1 LATCH DURING 3/1/2007 GLV INSTALLATION 3/1/2007 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 7,845.0 7,850.0 6,162.5 6,165.6 2/3/2020 5.0 TBG PUNCH 1.56" OD TUBING PUNCH, 5SPF, 0° PHASE, DECENTRALIZED 8,807.0 10,432.0 6,577.3 6,679.1 A-5, A-4, A-3, A -2, 3K-23 7/6/199724.0 IPERF 60 deg. phasing; Pre- perforated 4 1/2 CSG Frac Summary Start Date 1/6/2007 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 1/6/2007 Top Depth (ftKB) 8,807.0 Btm (ftKB) 10,432.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Start Date Com 6,895.0 7,850.0 5,491.1 6,165.6 Cement Squeeze 2/11/2020 12.2 bbls into IA, 15.8 PPG Class G Cement. 7,293.0 7,830.0 5,781.7 6,152.9 Cement Plug 2/11/2020 4.4 bbls 15.8 ppg class G cement on top of cement retainer at 7830' Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,892.3 2,573.6 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 2 4,592.9 3,816.5 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 3 5,948.8 4,805.2 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 4 6,983.7 5,556.4 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 5 7,800.2 6,133.8 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 2/1/2020 6 8,374.7 6,447.5 BST ATX 1 GAS LIFT OPEN 4/18/2013 3K-23, 4/2/2020 5:39:27 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"; 38.8- 10,439.2 FISH; 10,423.0 IPERF; 8,807.0-10,432.0 A-SAND FRAC; 8,807.0 SEAL ASSY; 8,744.7 LOCATOR; 8,743.7 NIPPLE; 8,427.5 GAS LIFT; 8,374.7 OVERSHOT; 7,908.5 NIPPLE; 7,887.0 CSV; 7,879.3 Bowen Spear; 7,877.3 Peak spear; 7,876.0 CIBP; 7,875.0 PACKER; 7,870.4 CATCHER; 7,872.0 TUBING LEAK; 7,868.0 PBR; 7,856.0 SEAL ASSY; 7,853.0 LOCATOR; 7,852.0 TBG PUNCH; 7,845.0-7,850.0 Cement Retainer; 7,830.0 GAS LIFT; 7,800.2 Cement Squeeze; 6,895.0 ftKB Cement Plug; 7,293.0 ftKB GAS LIFT; 6,983.7 GAS LIFT; 5,948.8 SURFACE; 41.2-4,969.5 GAS LIFT; 4,592.9 GAS LIFT; 2,892.3 NIPPLE; 484.8 CONDUCTOR; 41.2-121.0 HANGER; 36.7 KUP PROD KB-Grd (ft) 41.02 Rig Release Date 7/2/1997 3K-23 ... TD Act Btm (ftKB) 10,462.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292277100 Wellbore Status PROD Max Angle & MD Incl (°) 89.97 MD (ftKB) 9,152.52 WELLNAME WELLBORE Annotation Last WO: End Date 10/10/2013 H2S (ppm) 150 Date 12/24/2012 Comment SSSV: NIPPLE Notes: General & Safety End Date Annotation 10/10/2013 NOTE: 2013 Workover tubing cuts still downhole @ 8343', 8313', 8127', 8030' 9/23/2013 NOTE: Mandrel Orientation: 6) 11:30 3K-23, 4/2/2020 5:39:29 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"; 38.8- 10,439.2 FISH; 10,423.0 IPERF; 8,807.0-10,432.0 A-SAND FRAC; 8,807.0 SEAL ASSY; 8,744.7 LOCATOR; 8,743.7 NIPPLE; 8,427.5 GAS LIFT; 8,374.7 OVERSHOT; 7,908.5 NIPPLE; 7,887.0 CSV; 7,879.3 Bowen Spear; 7,877.3 Peak spear; 7,876.0 CIBP; 7,875.0 PACKER; 7,870.4 CATCHER; 7,872.0 TUBING LEAK; 7,868.0 PBR; 7,856.0 SEAL ASSY; 7,853.0 LOCATOR; 7,852.0 TBG PUNCH; 7,845.0-7,850.0 Cement Retainer; 7,830.0 GAS LIFT; 7,800.2 Cement Squeeze; 6,895.0 ftKB Cement Plug; 7,293.0 ftKB GAS LIFT; 6,983.7 GAS LIFT; 5,948.8 SURFACE; 41.2-4,969.5 GAS LIFT; 4,592.9 GAS LIFT; 2,892.3 NIPPLE; 484.8 CONDUCTOR; 41.2-121.0 HANGER; 36.7 KUP PROD 3K-23 ... WELLNAME WELLBORE SUNDRY NOTICE 10-407 ConocoPhillips Well 3K-23 Suspend (Sundry #320-064) March 30, 2020 ConocoPhillips Alaska, Inc. has performed Suspend operations on 3K-23, commencing operations on February 3, 2020 and completing the suspension on March 10, 2020. 16.6 bbls of 15.8 Class “G” cement was pumped to place a plug from 7,850ft, above the top of fish (stuck CAT-SV and slickline toolstrings), to 7,293ft KB in the tubing and 6,895ft KB in the tubing x production casing annulus (IA). A slickline tag and cement bond log were performed to confirm cement tops. Isolation has been verified with AOGCC State Witnessed Mechanical Integrity Test to 1,800psi. Well work summary is below: Daily Operations Start Date Last 24hr Sum 3/12/2020 3K-23 (SW) STATE WITNESSED (LOU LAUBENSTIEN) CMIT T X IA X OA PASSED TO 1800 PSI 3/10/2020 CMIT T X IA X OA TO 1800 PSI (PASSED) 2/28/2020 (PRE-SW) T X IA X OA CMIT INCONCLUSIVE TO 2000 PSI. 2/18/2020 STATE WITNESSED TAGGED @ 7293' RKB RECOVER SMALL CHUNKS OF CEMENT & SCALE, MIT TBG 2000 FAILED, DRAW DOWN ON TBG PASSED, CMIT IA x OA FAILED, DRAW DOWN ON IA & OA PASSED, RAN CBL LOG FROM 7293' RKB TO SURFACE. COMPLETE. 2/11/2020 RIH WITH STINGER, STING INTO RETAINER AT 7830' RKB STACK 10K WT DOWN, WHP 0, IA 368, OA 982, COIL PRESSURE CAME UP TO MATCH IA PRESSURE. WHP STAYED AT ZERO INDICATING WE ARE STUNG IN AND RETAINER HAS INTEGRITY. PJSM WITH HES, PUMPED 12.2 BBLS 15.8 PPG CMT INTO IA, 4.4 BBLS 15.8 PPG ON TOP OF RETAINER. CMT TOP +/- 7330' RKB. PUMP 60 BBLS POWERVIS PILL TO CONTAMINATE CEMENT DOWN TO 7330' RKB FOLLOWED WITH A DIESEL WASH TO SURFACE. ****READY FOR ELINE IN 24 HRS FOR STATE WITNESSED TAG.******* 2/10/2020 RIH WITH 2.75" FH1 CEMENT RETAINER, TAG CATCHER AT 7872' RKB, CORRECT TO ME AT 7870' RKB. PU TO 7830' RKB, DROP .5" BALL, SET RETAINER @7830' RKB. DID NOT GET GOOD INDICATION WE HAVE INTEGRITY WITH RETAINER. TRIED TO PUMP DOWN COIL UP IA AND OUR WHP WOULD INCREASE. JOB IN PROGRESS. 2/9/2020 TRAVEL TO 3K-23, MIRU, PERFORM WEEKLY BOP TEST. JOB IN PROGRESS. 2/3/2020 RAN 3 1/2 BRUSH & 2.80" GAUGE RING TO 7860' RKB, BRUSH TBG FROM 7860' TO 7750' RKB, SHOOT 1.56" X 5' TBG PUNCH, 0* PHASE, 5 SHOTS PER FT, TOP SHOT @ 7845' RKB, DRIFT TBG TO 7860' RKB W/ 2.75" x 15.25' CEMENT RETAINER DRIFT, LRS PREFORMED CIRCULATION TEST W/ 25 BBLS OF 12 PPG BRINE (-5 TCT) DOWN TBG UP IA, REPLACE IA FREEZE PROTECT W/ 6 BBLS DIESEL & U-TUBE. Page 1/1 3K-23 Report Printed: 4/2/2020 Cement Detail Report Cement Details Description Cement Squeeze Cementing Start Date 2/11/2020 07:00 Cementing End Date 2/11/2020 17:30 Wellbore Name 3K-23 Comment 12.2 bbls into IA, 15.8 PPG Class G Cement. Cement Stages Stage # <Stage Number?> Description Cement Squeeze Objective Top Depth (ftKB) 6,895.0 Bottom Depth (ftKB) 7,850.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 12.2 bbls into IA, 15.8 PPG Class G Cement. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Squeeze Job: Page 1/1 3K-23 Report Printed: 4/2/2020 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 2/11/2020 10:00 Cementing End Date 2/11/2020 17:30 Wellbore Name 3K-23 Comment 4.4 bbls 15.8 ppg class G cement on top of cement retainer at 7830' Cement Stages Stage # <Stage Number?> Description Cement Plug Objective Top Depth (ftKB) 7,293.0 Bottom Depth (ftKB) 7,830.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 4.4 bbls 15.8 ppg class G cement on top of cement retainer at 7830' Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Fm Supervisor `1�(�t � 3I�j2�w Regg DATE: February 18, 2020 SUBJECT: Well Bore Plug & Abandonment KRU 3K-23 FROM: Lou Laubenstein ConocoPhillips Alaska Petroleum Inspector PTD 1970970; Sundry 320-064 Section: 35 Township: 13N IRange: 9E Drilling Rig: NA Operator Rep: Rig Elevation: 41.02 ft WLM Jake Fama Casing/Tubing Data (depths are MD) Conductor: 16 O.D. Shoe@ Surface: 7 5/8" O.D. Shoe@ Intermediate: Csg O.D. Shoe@ Production: 5.5" x 4.5' • O.D. Shoe@ Liner: Feet O.D. Shoe@ Tubing: 3.5 O.D. Tail@ Plugging Data: Test Data: Total Depth: 10462 ft MD 121 Feet 4970 Feet Feet 10439 Feet Feet 7915 Feet Suspend: X Meridian: Umiat ' Lease No.: ADL 25519 - 19.*"--, T pe Pluq Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet T pe Pluq Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Retainer - 7830 ft MD- 7293 ft MD' Wireline tag Annulus Bottom 7870 ft MD 200 N/A 200 " 200 MIT -T Initial 15 min an min nC min P-1+ Tubing 2060 2030 1980 - 1950 ' IA 290 290 - 310 - 320 F OA 200 200 200 " 200 CMIT-IAxOA Initial 15 min 30 min 45 min RAS dt Tubing 560 640 690 - 760 IA 1880 1850 1840 - 1830 ' F OA 1820 1760 1800 1740 ' T Remarks: Pik ' tT fn.- !L°cA/u4- 1 arrived on location to witness the tag of TOC, MIT -T, MIT-IAxOA combo and a drawdown test. Wireline was rigged up with a 1.25' bailer and 2001b tool string, the tag showed TOC @ 7287 ft RKB. After retuning to surface the bailer only contained scale debris, it was decided to rig up a larger bailer and try to remove the remaining debris on top of the plug. The second run showed TOC to be @ 7293 ft RKB returning with more scale and small chunks of cement. The third and final run showed the TOC to be @ 7293 ft RKB and had a decent amount of cement chunks. The MITT test was deemed a FAIL after showing communication with the IA. The tubing was bled down to 200 psi and then a draw down test was completed with passing results. The combo MIT-IAxOA was represssured at 30 minutes with the same result as first 30 minutes (lost 60psi) - deemed a FAIL. Attachments: none i rev. 11-28-18 2020-0218_Plug Verification_KRU_3K-23 II Loepp, Victoria T (CED) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Good morning! PTL) /q3-og7-- Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Friday, March 13, 2020 10:18 AM Regg, James B (CED); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (CED); Wallace, Chris D (CED); Loepp, Victoria T (CED) NSK DHD Field Supervisor; Simek, Jill 10-426 for KRU 3K-23 (PTD 197-097) CMIT TxlAxOA MIT KRU 3K-23 03-12-20.xlsx Follow up Flagged Attached is the 10-426 for the 3K-23 CMIT TxIAxOA performed on 3/12/20 as part of the well suspension work (sundry #320-064). Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Friday, March 6, 2020 2:29 PM To: Loepp, Victoria T (CED) Subject: Re: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test Follow Up Flag: Follow up Flag Status: Flagged Victoria, We have pressures from 3/2/2020 (T/1/O=325/340/260psi) and today (T/I/O = 310/220/250psi). Note that we had pressured up tubing and annuli for "pre -SW" testing, since the 2/26 readings. We plan to repeat the drawdown test if CMIT is successful. Thanks, Jill From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, March 5, 2020 10:35 AM To: Simek, Jill <Jill.simek@conocophillips.com> Subject: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test Jill, Approval is granted for initial test pressure of 1800 psig for CMIT-TxlAXOA. Do you have the latest pressures T/1/0? Last pressures were 2/26/20. From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, March 5, 2020 9:28 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test Victoria, Well Integrity/DHD is scheduling the state witnessed CMIT-TxlAXOA and asking for clarification on the required 1,800psi test pressure. Typically we would start the test at 2,OOOpsi to allow for up to 10% pressure loss, per MIT pass criteria. Due to 3K-23 history of passing an MIT -OA with initial test pressure of 1,800psi, we would like to perform the state witnessed test to the same initial pressure (ie 1,800 not 2,OOOpsi). Please advise if this will be acceptable. Thanks, Jill From: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Sent: Thursday, February 27, 2020 2:10 PM To: Simek, Jill <1ill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test Approval granted. Thanx, Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, February 27, 2020 2:04 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Subject: RE: KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test Victoria, Last pressure readings on 3K-23 was yesterday, 2/26/2020: T/I/O = 250/250/190 psi As discussed, we would like to move onto the State Witnessed CMIT-TxlAxOA to 1800psi. If the CMIT passes, we will consider the well "Suspended". Thanks, Jill From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, February 24, 2020 8:03 PM To: Simek, Jill<Jill.Simek@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.sov> Cc: CPA Wells Supt <n1030@conocophillips.com>; NSK DHD Field Supervisor <NSKDHDFieldSupervisor(@conocophillips.com> Subject: RE: KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test Good Evening Jill and Victoria, We obtained updated pressures this evening. The current pressures are T/I/O = 250/250/180 psi (-17/-27/-30 change from 2/19). Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2S490cop.com Cell: 907-331-7514 ( sara.e.carlisle@cop.com From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Monday, February 24, 2020 3:56 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Cc: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test Victoria, We plan to get updated pressures tonight or tomorrow, which should give us an "extended drawdown" we can evaluate. In the meantime, DHD will arrange for State Witnessed CMIT-TxIAxOA to 1800psi. I'll be in touch when we have results to discuss. Thanks! Jill From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Sent: Friday, February 21, 2020 1:41 PM To: Simek, Jill <JiILSimek@conocophillips.com> Subject: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Reservoir Plug Pressure test On the drawdown test on the tubing, both the T and the IA build 70 psig and 40 psig respectively while the OA pressure remains constant. Where is that pressure coming from? Would like to repeat the drawdown tests for a longer period of time. Or what has happened to pressures over the last two days? Let's observe for a few days. Wednesday they were T/1/0 267/277/210 psig. Not State witnessed. Also, perform the CMIT-TxlAxOA to 1800psi, State witnessed. Thanx, Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, February 20, 2020 3:56 PM To: Loepp, Victoria T (CED) <yictoria.loepp@alaska.eov> Subject: RE: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Cementing Results Victoria, CBL log is attached, showing TOC in the IA at —6895ft KB (planned for 6,850ft KB). Based on the passing drawdown tests, ConocoPhillips believes the formation has been isolated from the wellbore. If the formation is isolated, the failing MIT -T and MIT-IAxOA is indicative of TXIA communication above the IA TOC. Recommended path forward is to perform CMIT-TxIAxOA to 1800psi to confirm isolation, after which we would submit an application for sundry approval to P&A. The CMIT-TxlAxOA could be state witnessed if required. Please advise. Thanks, Jill From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Sent: Thursday, February 20, 2020 1:27 PM To: Simek, Jill <1ill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Cementing Results STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim reao(dlalaska ow AOOCC.Inspectorsaalaska.gov: ohoebe.bmoks0alaske.aov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/3K Pad DATE: 03/12/20 OPERATOR REP: Beck / Van Camp AOGCC REP: Lou Laubenstein chris.tvalleceAalaska.0ov Well 3K-23 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. O= Other(describe in Notes) PTD 1970970 Type lnj N Tubing 330 1800 1780 1770 O - Clher (describe in notes) Type Test P Packer TVD 6179 BBL Pump 1.5 IA 330 1820 1790 1780 Interval O Test psi 1800 BBL Return 1.5 OA 280 1800 1730 1725 Result P Notes: CMIT T%IAx0A to a maximum of 1800 psi for suspension per Sundry* 320-064. Not to pressure over 1800 psi, approval from Victoria Loi email. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD I BBLPump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Cobea W = Water P = Pressure Test 1= Initisi Test P=P.. G=Gas O= Other(describe in Notes) 4=Four Year Cycle F=Fal S=slurry V= Required by Variance 1=lnconrAusrve I = InQueNel Wastewater O - Clher (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 3K-23 0312-20 pTv fa-3bg7- Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, February 19, 2020 10:57 AM To: Loepp, Victoria T (CED) Cc: Well Integrity Compliance Specialist WNS & CPF3 Subject: RE: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Cementing Results Follow Up Flag: Follow up Flag Status: Flagged Victoria, Yesterday, Slickline and Little Red were at 3K-23 to perform state witness tag and pressure tests, and to log the cement bond log. Results are below. As discussed, I will follow up with CBL results when the log has been delivered to me, then contact you to discuss plan forward. After yesterday's work, pressures were T/I/O = 300/450/400psi. Today's pressures are T/I/O = 267/277/210psi. 2/18/2020 Slickline/LRS: • STATE WITNESSED (Lou Laubenstein) TAGGED @ 7293' RKB RECOVER SMALL CHUNKS OF CEMENT & SCALE, MIT TBG 2000 FAILED, PLACE TEST GAUGES ON TREE. MIT -T 2000 PSI. o INITIAL T/I/O = 150/230/170, o LRS PT TBG TO 2000 PSI W/ 1. BBLS DSL. T/I/0= 2040/330/170 0 15 MIN T/I/0= 1920/280/200 ****FAILED**** o BUMP BACK UP (.1 BBLS) INITIAL T/I/0= 2060/290/200, 0 15 MIN T/I/0= 2030/290/200,(-30) 0 30 MIN T/I/0= 1980/310/200, (-50) 0 45 MIN T/I/0= 1950/320/200, (-30) 0 60 MIN T/I/0= 1900/340/200 (-50) TEST *****FAILED***** BLEED BACK TO 200 PSI • DRAW DOWN ON TBG PASSED, o DRAW DOWN TEST ON TBG T/I/0= 200/230/200, 0 15 MIN T/I/0= 260/260/200, 0 30 MIN T/I/0= 270/270/200 ***PASS*** • CMIT IA x OA FAILED, o LRS RIG DOWN FROM TBG & RIG UP TO IA PRE CMIT IA x OAT/1/0= 280/270/190, o PRESSURE UP (2.7 BBLS) T/1/0= 560/1880/1820, 0 15 MIN T/I/0= 640/1850/1760, o BUMP BACK UP T/I/0= 690/1840/1800(.1 BBLS) 0 15 MIN T/I/0= 760/1830/1740, STATE & CWG ***FAILED**** • BLEED IA & OA TO 200 PSI LRS RIG BACK UP TO TBG • DRAW DOWN ON IA & OA PASSED (bled down IA & OA then watched buildup while running CBL -interval pressures not recorded though), RAN CBL LOG FROM 7293' RK Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, February 13, 2020 3:07 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Cementing Results Yes, that will work, please include WBS with tag, CBL results Thanx, Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, February 12, 202011:05 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Subject: RE: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Status Update? Hi Victoria, Just yesterday we were able to get the cement plug set. Job details are below. When we get our next weather window, we will coordinating the witnessed tag and pressure tests with AOGCC inspector. Plan is to email you the CBL, tag, and pressure test results. Will that work? Thanks, Jill 2/11/2020 RIH WITH STINGER, STING INTO RETAINER AT 7830' RKB STACK 10K WT DOWN, WHP 0, IA 368, OA 982, COIL PRESSURE CAME UP TO MATCH IA PRESSURE. WHP STAYED AT ZERO INDICATING WE ARE STUNG IN AND RETAINER HAS INTEGRITY. PJSM WITH HES, PUMPED 12.2 BBLS 15.8 PPG CMT INTO IA, 4.4 BBLS 15.8 PPG ON TOP OF RETAINER. CMT TOP +/- 7330' RKB. PUMP 60 BBLS POWERVIS PILL TO CONTAMINATE CEMENT DOWN TO 7330' RKB FOLLOWED WITH A DIESEL WASH TO SURFACE. ****READY FOR ELINE IN 24 HRS FOR STATE WITNESSED TAG.******* 2/10/2020 RIH WITH 2.75" FH1 CEMENT RETAINER, TAG CATCHER AT 7872' RKB, CORRECTTO ME AT 7870' RKB. PU TO 7830' RKB, DROP .5" BALL, SET RETAINER @7830' RKB. DID NOT GET GOOD INDICATION WE HAVE INTEGRITY WITH RETAINER. TRIED TO PUMP DOWN COIL UP IA AND OUR WHP WOULD INCREASE. JOB IN PROGRESS. From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, February 12, 2020 9:29 AM To: Simek, Jill <JiILSimek a�conocophillipS.Com> Subject: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Status Update? From: Simek, Jill <JilLSirnekLa conocophillips-com> Sent: Thursday, February 6, 2020 4:24 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov> Cc: Well Integrity Compliance Specialist WINS & CPF3 <n2549@conocophillips.com>; NSK Coiled Tubing Field Supv <n 2541 @conocophillips.com> Subject: 3K-23 Update Victoria/Guy, This email is to update you on 3K-23. We continue to be delayed due to cold temps, so have yet to begin coil tubing operations (log/set cement retainer, pump cement). Last work performed was on 2/3/2020 when tubing was punched, injectivity confirmed, and cement retainer dummy drift performed. Today T/I/O is at 485/450/1160psi and all fluid levels are at surface. I'm off tomorrow and for the weekend. If you have questions please call me at 907 980-7503. Otherwise we will update you as work progresses. Thanks, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone. 907-263-41311 Cella 907-980-7503 PFD lR-7-oq� Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, February 6, 2020 4:24 PM To: Loepp, Victoria T (CED); Schwartz, Guy L (CED) Cc: Well Integrity Compliance Specialist WNS & CPF3; NSK Coiled Tubing Field Supv Subject: 3K-23 Update Follow Up Flag: Follow up Flag Status: Flagged Victoria/Guy, This email is to update you on 3K-23. We continue to be delayed due to cold temps, so have yet to begin coil tubing operations (log/set cement retainer, pump cement). Last work performed was on 2/3/2020 when tubing was punched, injectivity confirmed, and cement retainer dummy drift performed. Today T/I/O is at 485/450/1160psi and all fluid levels are at surface. I'm off tomorrow and for the weekend. If you have questions please call me at 907 980-7503. Otherwise we will update you as work progresses. Thanks, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cella 907-980-7503 Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, February 12, 2020 11:05 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Status Update? Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Just yesterday we were able to get the cement plug set. Job details are below. When we get our next weather window, we will coordinating the witnessed tag and pressure tests with AOGCC inspector. Plan is to email you the CBL, tag, and pressure test results. Will that work? Thanks, Jill 2/11/2020 RIH WITH STINGER, STING INTO RETAINER AT 7830' RKB STACK 10K WT DOWN, WHP 0, IA 368, OA 982, COIL PRESSURE CAME UP TO MATCH IA PRESSURE. WHP STAYED AT ZERO INDICATING WE ARE STUNG IN AND RETAINER HAS INTEGRITY. PJSM WITH HES, PUMPED 12.2 BBLS 15.8 PPG CMT INTO IA, 4.4 BBLS 15.8 PPG ON TOP OF RETAINER. CMT TOP +/- 7330' RKB. PUMP 60 BBLS POWERVIS PILL TO CONTAMINATE CEMENT DOWN TO 7330' RKB FOLLOWED WITH A DIESEL WASH TO SURFACE. ****READY FOR ELINE IN 24 HRS FOR STATE WITNESSED TAG.******* 2/10/2020 RIH WITH 2.75" FH1 CEMENT RETAINER, TAG CATCHER AT 7872' RKB, CORRECT TO ME AT 7870' RKB. PU TO 7830' RKB, DROP .5" BALL, SET RETAINER @7830' RKB. DID NOT GET GOOD INDICATION WE HAVE INTEGRITY WITH RETAINER. TRIED TO PUMP DOWN COIL UP IA AND OUR WHP WOULD INCREASE. JOB IN PROGRESS. From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, February 12, 2020 9:29 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3K-23(PTD 197-097, Sundry 320-064) Status Update? From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, February 6, 2020 4:24 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com>; NSK Coiled Tubing Field Supv <n2541@conocophillips.Corn> Subject: 3K-23 Update Victoria/Guy, This email is to update you on 3K-23. We continue to be delayed due to cold temps, so have yet to begin coil tubing operations (log/set cement retainer, pump cement). Last work performed was on 2/3/2020 when tubing was punched, injectivity confirmed, and cement retainer dummy drift performed. Today T/I/O is at 485/450/1160psi and all fluid levels are at surface. I'm off tomorrow and for the weekend. If you have questions please call me at 907 980-7503. Otherwise we will update you as work progresses. Thanks, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Freeborn Well Integrity Compliance Specialist ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-23 Permit to Drill Number: 197-097 Sundry Number: 320-064 Dear Mr. Freeborn: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r 4Price Chair DATED this S day of February, 2020. RBDMSI FEB 072020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 - C 25 280 RECEIVED FEB 0 5 2020 ,DAOGCC Z� 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑� • Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: EJPhillips Alaska, Inc. Exploratory Development ❑� 197-097 3. Address: 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50029227710000 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ KRU 3K-23 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025519 Kuparuk River/Ku aruk River Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 121' 121' Surface 4928' 7-5/8" 4970' 4094' Production 10400' 5-1/2"x4-1/2" 10439' 6680' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8807'-10423' 6577'-6678' 3-1/2" L-80 7915' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FA -1 Production Packer 7870' MD / 6178' TVD 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory p Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 2/1/2020 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 1/31/2020 Commission Representative: Victoria Loepp Z/S/20 GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Freeborn Jill Simek Contact Name: Authorized Title: Well Integrity Compliance Specialist Contact Email: jill.simek@conocophiliips.com Contact Phone: 907-263-4131 Authorized Signature: Date: F66 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: s D Plug Integrity L✓ BOP Test ❑ Mechanical Integrity Test n-,� Location Clearance ❑ Other: / F 77t� v /tr fo 'fvb CC 't ice' 7 q 5 �r� a va r !a Fe -L t, Post Initial Injection MIT Req'd? Yes ❑ No ®� 7 RBDMS L" � FEB 0 7 2020 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 — g 7' r APPROVEDBY Approved by: COMMISSIONER THE COMMISSION Date:51 i ,qVZ 2q 1512,0 Form 10-403 Revised 4/2017 Approved applicati s r f 2 n A L. date of approval. �mSubmit Form and AttachmKtts in Duplicate /ay L•5.7.,C� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 1", 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7"` Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3K-23 (PTD 197-097) to isolate the tubing and IA from formation with cement for suspension. Please contact Jill Simek at 980-7503, Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Z;�/' , Dusty Freeborn Well Integrity Compliance Specialist ConocoPhillips Alaska, Inc. KRU 3K-23 (PTD# 197-097) Description Summary of Proposal Well Work Justification & Objectives (and date required if appropriate): 3K-23 has TxlA through a leak in the PBR at 7868' RKB. It has started exhibiting high OA pressure due to TxlAxOA communication. The well remains in communication with formation pressure through either the CIBP or production packer. This procedure is to prepare the well for Suspend activities. FLUID WEIGHT CALCS: 1/21/20 SBHP = 4510 psi at 7876' MD/6182' TVD = 14.0 ppg 500' TVD/500' MD diesel FP = 500'x0.35 psi/ft = 175 psi Kill weight (without a safety factor): 175 psi FP + (6182'-500')*KWF = 4510 psi =__> KWF = 14.7 ppg (mud with a depressed freezing temperature so that only a 500' TVD diesel freeze protect is needed) 12.0 NaBr Circ Out (should have had TxIA at 614 psi WHP): 4150 psi BHP - 175 psi FP - ((6182'-500' TVD) * 12.0 ppg NaBr Brine * .052) = 614 psi WHP TxIA 4150 psi BHP - ((6182'- 4093' TVD SC) * 12.0 ppg NaBr Brine * .052) - ((4093' TVD SC) * 6.73 ppg Diesel .052) = 1414 psi Max OA Steps: DSL LRS Objective: Dummy GLD, drift for cement retainer, punch 3%" tubing to establish circulation for cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU DSL and PT Equipment as required. 3. Set catcher on top of CIBP at 7,875ft KB. 4. Dummy off the GLD as follows: • Install DV in open pocket at 7,800ft KB. • Pull OV at 6,983ft KB and set DV. • Pull GLV at 5,948ft KB and set DV. • Pull GLV at 2,892ft KB and set DV. 5. Retrieve catcher from top of CIBP at 7,875ft KB. 6. RIH with string shot to 7,830ft KB to remove scale on the cement retainer set area. 7. Brush cement retainer set area at 7,830ft KB. 8. Drift with dummy cement retainer to 7,830ft KB. 9. RIH and punch tubing at 7,845ft - 7,850ft KB as circulation point for cement. Correlate to CCL on LDL dated 6/23/2019 10. Rig up LRS and pump 10 bbls of 12 ppg brine through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,OOOpsi). Follow with 6 bbls diesel FP and jumper tubing to IA. 11. RDMO. Coiled Tubing / Cementing: Objective: Place a cement plug in tubing and IA Cement Volume Calculations: • 3 %" tubing x 5 %:" production casing, tubing punch to 6,850ft KB: (0.01190 bbl/ft) (7,850ft - 6,850ft) = 11.9 bbl • 3 %:" tubing, cement retainer to 7,330ft KB: (0.008696 bbl/ft) * (7,830-7,330) = 4.4 bbl • Total volume = 11.9 + 4.4 = 16.3 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Halliburton to coordinate services. The job is designed for 16.3 bbls of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 1/22/2019 schematic and tubing details for depth correlation. Perform tie- in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with Weatherford 2.75" cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 7,830ft KB (middle of full tubingjoint above seal assembly). 8. Close in the CT x Tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,OOOpsi). 10. RU HAL Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer. ` 12. Pump 11.9 bbls of Class "G" cement. c3 ^as J vo t�2�u r AS 13. Shut down, un -sting from retainer 14. Lay in remaining 4.4 bbl cement above retainer (equates to 500ft of cement above the retainer, leaving TOC-7,330ft KB) 15. POOH above TOC 16. Circulate CTU clean. 17. RDMO Eline LRS: Objective: State witnessed tag of TOC, CBL, MIT -T, DDT -T 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU eline and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,330ft KB. Record Results. TAG MUST BE AOGCC WITNESSED S. Log CBL to determine cement distribution and TOC in IA. 6. RU LRS and PT Surface Equipment as required. 7. Perform MIT -T to 1,500 psi. Record Results. PRESSURE TEST MUST BE AOGCC WITNESSED 8. Perform DDT -T. Record Results. 9. Report issues and results to Well Intery ntions Engineer. 10. RDMO Z✓" 7— !fl x o l �600 PsLS D T— l } x (5A AhvL1 Gas CAP• /(r Sit 0113 601 -lo- Dv T-- P�wed `' l 3o 664 vrc5� y a/rs`1. 01 -7sSb e z4 41f1�/ 9 /a 0 ,,,I— — q f7r, 'e5z )1-11 5 � '1'� KUP PROD WELLNAME 3K-23 WELLBORE 3K-23 ^e' Well Attributes Max An ConocoPhillips gIeBMD TD FIeIBNeme Wallbare APINWI W^ObereSte. e1 P) MBMKB) Ad Bon(WBI A'd$ka•Inn. KOPARI IK RIVFP nNIT ice• BVRFACEM.N,Ek9.E� . J". PACKER; CIBP; Peak epu� Bowen Bpex CBU NIPPLE; 1 red. Slots 9a nn an n no (TVD) Volvo LeNk Port W. TRO Run Teems) (RKB) Make Model Wild) bery Tyoe type Iln) (wl) Run oaM Cnm 1 2.892.3 CAM00 KBG-2- 1 V BTM 0.155 1,310.0 3/112017 9 2 4,592.9 MCO KBG2- 1 V BTM 015fi 1,298.0 &412017 9 3 5948.8 MCO NBG2- 1 BTM 0.188 1,333.03020V9 g 4 6,983.7 CO !!M KBG-2- 1 BTM 0.188 0.0CV1120199 5 7,800.2 MCO BG -2- 1 EN 12212020 98 6,374.7 qT% 1 EN 4_&2013 1 3 4 P �C z t, a bo�te PI✓�c ifs=ls QcAe 70 r, rlgsz' -Toe :/l �NG Lc,n�- �%S'Ee H M� CSe4,JG.S>.J� 'h .-Pr6b/ 6S6V'7'VD 791 Loepp, Victoria T (CED) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, February 5, 2020 8:45 AM To: Loepp, Victoria T (CED) Cc: Schwartz, Guy L (CED); NSK Coiled Tubing Field Supv; Well Integrity Compliance Specialist WINS & CPF3 Subject: RE: [EXTERNAL]KRU 3K-23 (PTD 197-097) Verbal Approval to proceed Thanks, Victoria. Per cementing record, there was a shoe pumped on 6/3/1997: 7-5/8" Surface casing cement history based on drilling rig report: Two-stage cement job pumped on -rig 6/3/1997 indicated good cement from surface casing shoe at to surface. 1't stage cement pumped 94 bbls 10.5ppg ASIIILW cement followed by 78 bbls 15.8 Class G cement. Plug was bumped and floats held. 2nd stage was pumped through HES cementer at 1880' MD. Cement/mud was noted from first stage, indicating good cement from shoe to 1880' MD. Pumped 311 bbis 10.5ppg ASIIILW cement followed by 10 bbls 15.8 ppg ASlcement with good returns to surface. From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, February 05, 2020 7:21 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; NSK Coiled Tubing Field Supv <n2541@conocophillips.com>; Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: [EXTERNAL]KRU 3K-23 (PTD 197-097) Verbal Approval to proceed Please add the CMIT IAx0A and DDT IAx0A to 1800 prig. Let us know the MIT, CBL results as soon as they are available. Also, the OA shoe is open, that is not cemented, is that correct? With these additions, verbal approval is granted to place cement plug in the tubing and IA and complete the work under this sundry which we expect to be delivered to our office this morning. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoo(a),alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeco@alaska aov From: Loepp, Victoria T (CED) Sent: Tuesday, February 4, 2020 6:41 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Schwartz, Guy L (CED) <guv.schwartzCTa alaska.gov> Subject: KRU 3K-23 (PTD 197-097) 10-403 submittal for suspension operations Hi Jill, We were expecting the 10-403 today. Verbal approval is granted for the log and setting the cement retainer. We will touch base tomorrow morning. I will be in by 7. Thanx, Victoria Sent from my iPhone On Feb 4, 2020, at 4:58 PM, Simek, Jill <Jill.Simek(a)conocophillips.com> wrote: Guy, I just received confirmation that we will move coil on to 3K-23 tomorrow (Wednesday 2/4/2020) to log and set the cement retainer. Cement plug will follow. Will the "verbal" sundry approval remain in place for this work? I am waiting for an update on status of the hardcopy 10-403, which came in the mailbag last night from Kuparuk. If it didn't go out today, it should be at AOGCC tomorrow. Thanks, Jill From: Schwartz, Guy L (CED) <guy.schwartzCTa alaska.gov> Sent: Monday, February 03, 2020 4:01 PM To: Simek, Jill<Jill.SimekCtconocophillips.com> Subject: RE: [EXTERNAL]RE: 3K-23 (PTD 197-097) 10-403 submittal for suspension operations Jill, I agree... I realized the PC leak was there. But if we can get a 1500 psi test on the IA that is good as we can get with the well condition as it sits now. The DTT will also be a good indicator of a successful job. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. if you ore an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793- 1226) or (Guv.schwartz@alasko.gov). From: Simek, Jill <1ill.Simek@conocophillips.com> Sent: Monday, February 3, 2020 2:44 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: NSK Coiled Tubing Field Supv <n2541@conocophillips.com>; Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: RE: [EXTERNAL]RE: 3K-23 (PTD 197-097) 10-403 submittal for suspension operations Guy, We wont be able to get a MIT -IA or DDT -IA due to the PC leak. I can add a combo MIT-IAxOA and DDT- IAxOA instead. The CMIT IA x OA would be to 1800 psi, and I would suggest that first. By doing the DDT second, it lets us leave it in progress overnight and see what it builds to if it does not want to bleed to 0 psi right away. Regarding timing, Thursday is now the earliest we could get to cementing. Tomorrow will likely be a weather day. Wednesday we could log/set cement retainer, then pump cement the next day. The hard copy of the 10-403 went on the 2pm flight from Kuparuk so it should get to your office Wednesday latest. Jill From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Monday, February 03, 2020 1:36 PM To: Simek, Jill <JiILSimek@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: NSK Coiled Tubing Field Supv <n2541@conocophillips.com>; Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips cor-> Subject: [EXTERNAL]RE: 3K-23 (PTD 197-097) 10-403 submittal for suspension operations Jill, Looks good ... if you guys are able to go tomorrow with cement a verbal is doable. Also, I saw there was no MIT -IA or DDT -IA after the cement plug is set. Was that an oversight? Does it make sense to do the DDT -IA first then the MIT -IA after WOC. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793- 1226) or (Guv.schwartz@alaska.gov). From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Monday, February 3, 2020 1:08 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: NSK Coiled Tubing Field Supv <n2541C@conocophillips.com>; Well Integrity Compliance Specialist WNS & CPF3 <n2549Cg@conocophillips.com> Subject: FW: 3K-23 (PTD 197-097) 10-403 submittal for suspension operations Guy, Per our discussion, we will be monitoring the cement job as follows to ensure adequate pressure is held on the IA to prevent formation fluid movement into the wellbore (through CAT SV/tubing leak): • Record starting T/I/O. (2/3/2020 pressures are 700/505/1300psi) • Establish circulation and monitor returns. 1:1 returns are required to ensure the well is not flowing during cementing. • Maintain back pressure with choke adjusting as necessary for 1:1 returns. • OA not to exceed 1800psi during job Depending on weather, we may be able to pump cement as early as tomorrow. Please let me know if you are able approve the sundry. Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, February 01, 2020 12:09 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Simek, Jill<Jill.Simek@conocophillips.com>; CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com>; Marti, Marty K <Srinagesh.K.Marti@conocophill ips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Valentine, Doug K<Doug.K.Valentine@conocophillips com>; CPF3 Prod Engrs <n1223 @conocophillips.com> Subject: 3K-23 (PTD 197-097) 10-403 submittal for suspension operations Victoria, A 10-403 for KRU 3K-23 (PTD 197-097) to suspend the well with cement as discussed yesterday has been sent via mail. Attached is an electronic copy for your review. CPAI requests either verbal or email approval to continue with the cementing operations. Please let me know if you have any questions or concerns. Thank you, Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 <image001.png> Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Friday, January 31, 2020 5:51 PM To: Simek, Jill Cc: Rixse, Melvin G (CED); Schwartz, Guy L (CED) Subject: KRU 3K-23 (PTD 197-097) Verbal Approval: Begin Suspend Operations Verbal approval is granted to begin these operations with the DSL/LRS work to dummy GLD, drift, punch and establish circulation(procedure steps 1 through 11). Please submit a sundry for approval for the full scope of this work for review and approval before proceeding further. You Thanx, Victoria Sent from my iPhone On Jan 31, 2020, at 5:15 PM, Simek, Jill <Jill.Simek@conocophillips.com> wrote: Victoria, As discussed, ConocoPhillips intends to suspend 3K-23 by placing a tubing and IA cement plug, to isolate the wellbore from Kuparuk perforations. As detailed below, the cement plug will be designed to leave top of cement in the IA at 6,850ft KB and top of cement in the tubing at 7,350ft KB. The cement plug will be pressure tested, tagged, and logged to confirm placement and isolation. Please review steps below and respond by email with authorization to perform this work. In addition to below, offset injector 3K-22 has been ordered shut-in for 3K-23 pressure management. Offset injector 3K-19 is already offline and will remain offline until suspend operations are complete and verified. With approval, suspend operations will begin tomorrow, 1/31/2020. We will continue to monitor 3K-23 pressures and let you know of any changes. MI has verified that 15ppg Zinc Bromide is minimum 4 weeks out, and Baroid has also confirmed long lead times for this fluid. We are extending our search to other operators on the Slope, in the case that one of them may have something we can use. Regarding subsidence, I don't see any history of subsidence on this well or others on 3K. I will consult early next week with our Subsidence Coordinator to confirm and let you know if I learn otherwise. Thanks again for your time. Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 Procedure: DSL/ LRS Objective: Dummy GLD, drift for cement retainer, punch 3'/2" tubing to establish circulation for cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU DSL and PT Equipment as required. 3. Set catcher on top of CIBP at 7,875ft KB. 4. Dummy off the GLD as follows: • Install DV in open pocket at 7,800ft KB. • Pull OV at 6,983ft KB and set DV. • Pull GLV at 5,948ft KB and set DV. • Pull GLV at 2,892ft KB and set DV. 5. Retrieve catcher from top of CIBP at 7,875ft KB. 6. RIH with string shot to 7,830ft KB to remove scale on the cement retainer set area. 7. Brush cement retainer set area at 7,830ft KB. 8. Drift with dummy cement retainer to 7,830ft KB. 9. RIH and punch tubing at 7,845ft - 7,850ft KB as circulation point for cement. • Correlate to CCL on LDL dated 6/23/2019 10. Rig up LRS and pump 10 bbis of 12 ppg brine through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). Follow with 6 bbls diesel FP and jumper tubing to IA. 11. RDMO. Coiled Tubing / Cementing: Objective: Place a cement plug in tubing and IA Cement Volume Calculations: 3'/2" tubing x 5'/" production casing, tubing punch to 6,850ft KB: (0.01190 bbl/ft) * (7,850ft - 6,850ft) = 11.9 bbl 3'/" tubing, cement retainer to 7,330ft KB: (0.008696 bbl/ft) * (7,830 — 7,330) = 4.4 bbl Total volume= 11.9 +4.4 = 16.3 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Halliburton to coordinate services. The job is designed for 16.3 bbis of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 1/22/2019 schematic and tubing details for depth correlation. Perform tie- in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with Weatherford 2.75" cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 7,830ft KB (middle of full tubing joint above seal assembly). 8. Close in the CT x Tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbis of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,OOOpsi). 10. RU HAL Cement Equipment and PT surface lines as required. 11. Pump 10 bbis fresh water spacer. 12. Pump 11.9 bbis of Class "G" cement. 13. Shut down, un -sting from retainer 14. Lay in remaining 4.4 bbl cement above retainer (equates to — 500ft of cement above the retainer, leaving TOC—7,330ft KB) 15. POOH above TOC 16. Circulate CTU clean. 17. RDMO Eline/ LRS: Objective: State witnessed tag of TOC, CBL, MIT -T, DDT -T 1. WOC per LICA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU eline and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,330ft KB. Record Results. TAG MUST BE AOGCC WITNESSED 5. Log CBL to determine cement distribution and TOC in IA. 6. RU LRS and PT Surface Equipment as required. 7. Perform MIT -T to 1,500 psi. Record Results. PRESSURE TEST MUST BE AOGCC WITNESSED 8. Perform DDT -T. Record Results. 9. Report issues and results to Well Interventions Engineer. 10. RDMO From: Simek, Jill Sent: Thursday, January 30, 2020 5:09 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com>; Helton, Sean C <Sea n.C. Helton@conocophillips.com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL]KRU 3K-23 (PTD 197-097) Brine availability/acquisition Victoria, Regarding availability of 15 ppg brine: Calcium Bromide and Zinc Bromide are the two brine options that are able to reach the weight needed. Calcium Bromide will not be compatible because the crystallization point at the weight required is not low enough, thus will risk freezing in our well. Zinc Bromide is thermally compatible, but is not presently available. Our vendor inquired about the availability to rush - ship. At minimum, it will be a 4— 6 week lead time for delivery to the slope. Regarding geology: I am attaching a table of formation tops and logs, showing an impermeable zone (HRZ) at 7750' MD -7840' MD. I've included this on the abandonment schematic below and in the attached "Status Report and Abandonment Proposal" (pg. 5). Given long lead time for the 15 ppg brine, we believe the abandonment cement plug option remains our best option. With approvals in place, cement can be pumped as early as Monday (2/3/2020). Please let me know if AOGCC agrees with this path forward. Thanks, Jill <image001.png> <image002.jpg> Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, January 30, 2020 2:59 PM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com>; Simek, Jill <JiILSimek@conocophillips.com>; Helton, Sean C <Sean.C.Helton@conocophillips.com> Cc: Rixse, Melvin G (CED) <r Avin.rixse@aIaska.gov> Subject: [EXTERNAL]KRU 3K-23 (PTD 197-097) Brine availability/acquisition 0 As the highest priority, please research acquiring a 15 ppg brine and the timing to kill the well. It appears that calcium or zinc brines may be available. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V ictoria. Loeon(a).a laska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907) 793- 1247 or Victoria.Loeipr)@alaska.gov From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Thursday, January 30, 2020 9:05 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Simek, Jill <Jill.Simek@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3K-23 (PTD 197-097) SCP: WO & Abd options AOGCC Hi Victoria, Thank for being willing to discuss! I'll plan to call in since I'm on the slope and Jill will meet you in person at 2pm. Sincerely, SAd"wC17.rUsl&(THelkVV)/Stephavt,G&Pack Well Integrity & Compliance Specialist, WNS & CP173 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25496bcop.com Cell: 907-331-7514 [ sara.e.carlisle@cop.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Sent: Thursday, January 30, 2020 8:53 AM To: Simek, Jill<Jill.Simek@conocophillips.com>; Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Subject: [EXTERNAL]KRU 3K-23 (PTD 197-097) SCP: WO & Abd options AOGCC Sara, Jill, I am available at 2 PM to discuss. Please confirm. Thanx, Victoria From: Helton, Sean C <Sean.C.Helton@conocophillips.com> Sent: Wednesday, January 29, 2020 9:21 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Subject: Re: [EXTERNAL]KRU 3K-23 (PTD 197-097) SCP; WO & Abd options AOGCC Sara, I will premise that Jill in town will follow-up with request on additional info and face-to-face discussions. Please continue options for APB mitigations premising a continual increase. Considerations may include additional KWF w/ or w/o bridging material and bleed -off. With CT Ops down for cold temps discuss with CT Sup thoughts on milling/fishing. Sean Sent from my iPhone On Jan 29, 2020, at 8:58 AM, Loepp, Victoria T (CED) <victoria.loepp@alaska. > wrote: Sara, At this point, it is not acceptable to abandon the reservoir in the proposed fashion. We will need to discuss this in more detail with schematics for abandonment options and workover options. Please plan to have an engineer come talk with the AOGCC about the status of this well and the path forward. Include schematics. Include cement records for the casings including TOC and whether this was determined by log or calculation. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeopOalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or V ictoria. Loe oo @a laska. a ov From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, January 28, 2020 5:41 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaskLggv> Cc: CPA Wells Supt <n1030@conocophillips.com>; Helton, Sean C <Sean.C.Helton@conocophillips.com>; Packer, J.Brett <J. Brett. Packer@conoco Phil Iips.com> Subject: RE: KRU 3K-23 (PTD# 197-097) Report of Sustained Casing Pressure Hi Victoria, Below is a summary of events since 3K-23 (PTD# 197-097) was reported for high pressure on the outer annulus 1/21/20. • 1/21/20: o A cast iron bridge plug was set at 7975' MD to secure the well. o DDT TxIA (PASS) against cast iron bridge plug and FA -1 production packer. o T/I/O = 900/900/200 psi. until 1/25/20. • 1/25/20: o Inner casing packoff test (PASS). o OA x IA leak rate of 0.24 gpm established. • 1/26/20: o CM ITTxIAxOAto 1800 psi (PASS). o CMIT TxIA to 2500 psi (FAIL) - 5.4 gpm leak rate established. o DDT TxIA (FAIL) - T/I/O = 1650/1650/1650 psi indicating that a barrier no longer has integrity. 0 12.0 ppg fluid circulated into the well. T/I/O = 250/290/980 psi. 1/27/20: o T/I/O = 255/300/1000 psi. 1/28/20: o T/I/O = 650/700/1375 psi. The well is being monitored for pressure stabilization to understand the constraints for a plan forward. Based on the stabilized outer annulus pressure, CPAI is considering further attempts to secure the well, including placing a cement plug in the tubing and the inner annulus. The size of a cement plug will affect rig workover scope and may lead to consideration of abandonment. If abandonment is progressed, we will need to request approval for variance to isolate the wellbore from the perforations (6577' TVD) with the base of the cement plug at 6181'TVD. This is due to a stuck standing valve, two stuck GS spears, and permanent cast iron bridge plug in the well. CPAI is requesting guidance on if abandoning the well in this fashion is acceptable in order to finalize a path forward and narrow the scope of a workover or abandonment. Please let me know if you have any questions or would like to discuss. Sincerely, SAN'LL CLLrUsl& (Hwo4rv) / Stepin avu6e� PaJv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop com Cell: 907-331-7514 1 sara.e.carlisle@cop com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Tuesday, January 21, 2020 6:03 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska,gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3K-23 (PTD# 197-097) Report of Sustained Casing Pressure Victoria, Kuparuk producer 3K-23 (PTD# 197-097) was reported on 5/4/19 for sustained casing pressure on the IA. Since then the well has remained shut in due to a standing valve stuck in the tubing tail and a tubing leak just above the production packer. While shut in the tubing and IA have equalized at 1950 psi. The well is currently awaiting a rig workover to remove the standing valve and repair the tubing leak. Three days ago, operations reported that the OA pressure reached 1450 psi and that the OA pressure would climb after it was bled. The OA pressure is currently being managed by bleed while CPAI is working to secure the well and then we will progress OA diagnostics. The 7-5/8", 29.7 Ib L-80 surface casing is rated to 6890 psi (45%= 3100 psi). A 90 day TIO trend and wellbore schematic are attached. Please let us know if you have any questions or disagree with this plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 ConocoPhillips 3K-23 Status Report/ Abandonment Proposal January 30, 2020 January 31, 2020 .. Y i. �• y1 f N.. Stuck CAT SV at 7879' MD, with 2 GS spears (installed 3/1/2017) SI April/2019 for TXIA 1/21/2020: Reported for high OAP 1/21/2020: Secured with CIBP @ MD 1/25/2020: Diagnostic IC POT (PASS); MIT -OA to 1800 (FAIL), OA x IA leak rate of 0.24 gpm established 1/26/2020: CMIT TxIAx0A to 1800 psi (PASS) * CMIT TxIA to 2500 psi (FAIL) - 5.4 gpm leak rate established DDT TxIA (FAIL) - T/I/0 = 1650/1650/1650 psi indicating that a barrier no longer has integrity 12.0 ppg fluid circulated into the well. T/I/0 = 250/290/980 psi. 1/27/2020: T/1/0 = 255/300/1000 psi. ConocoPhillips 1/28/2020: T/1/0 = 650/700/1375 psi. 16.6,.5#,H-40,121- MD 3K-23 2.8]5" DS profile 1/29/2020: T/1/0 = 675/710/1400 psi. 1/30/2020: T/1/0 = 705/725/1425 psi. Unknown PC leak depth tiatPPG 8rllle ]-518"529'7#, L-8, 4970 MD •,,,•^ es ®eN,oe1 :�Ftlrtaelien:H2O �: �: �: S rtace Casing Cement I Protluctlon Casing Cemen[, 5.5'X4.5" TOC, 7550' MD as per CBL 62911997 5-112" 15.5#, L-80,8756- MD HES Cementer, 8768' MD fxxx'TVD A -Sand Perforators, 8807 MD 16577' TVD 4.5" 11.60, L-80,10493' MD GLM, 6983' MD GLM, 7800' MD PBR, 7856' MD Tubing Leak, ]868' MD FAB Packer, 7870' MD wlfailetl CIBP, 7876' MO 2.75"'D' Nipple, 7087' MD ConocoPhillips Justification: Multiple failed barriers ® Uneconomical RWO Opportunity for resource recovery with KRU 3K-24 CTD Abandonment Steps: ® Dummy GLMs ® Tubing punch 7850' MD • Set cement retainer at 7830' M D • Pump 58bbls through retainer, up IA • Unsting and lay in 42bbis cement to 3000' MD • CBL and diagnose PC leak ® Cement T/IA/OA to surface 5kagn i L(05 SK.pie 10' B25p, Ni0, 131' MB 0. Lt, .1170 MD 5.5Y4S- 5-113' 15.6k, L-80,0)58' MM NES CI7nht, 0)M' MO W. ASanE pe1btag<na, M W MB /&5))' NO ConocoPhillips 3K-23 0)s os P"" Unknown PC IeA tl."h ys,d PPG:.t - i:'i:PB'wvYmmPi:::: snna=.�m.m PAap<a<n carne c.=.m GLM, W00'MU BalancM cement p to 5000MB GLM.)OOP MB X"g P�n<k-)as0 PBB, )A50' MB Taemg L-1, I..' MO FAB Pzk, )0)0' MB WIMiNE CIBP, )0)0' MO 3.1Fi 'O' MIPP6,)80)' MO s' Cono4hillips Abandonment Steps: ° Dummy GLMs n Tubing punch 7850' MD Set cement retainer at 7830' MD ® Pump 58bbls through retainer, up IA Unsting and lay in 42bbls cement to 3000' M D CBL and diagnose PC leak Cement T/IA/OA to surface Barriers to Formation: ° Tubing and IA plug 3000' MD to 7850' MD (2651' TVD o 6090' TVD) Production casing cement TOC = 7550' MD (5889' TVD) ® HRZ Shale 7750' M D to 7840' M D (6101' to 6159' TVD) III II -ina I. 16" MW H-40,121' MO ry 7-518" 29.71k L-8, 4970 MO I I I 5.5'X4.5"TOC, 7550' MD as per CBL 6/2 9119 97 --fly n 5.1/2" 15.59, L-80, 8756' MD .iw'vcu etie �ri'ii`a nv'ri HES Cementer, 8768' MO I xxa' TVD A -Sand Perforations, 8807 MO 16577' TVD I `✓ ConocoPhillips 3K-23 X2.875" DS profile — Unknown PC leak depth 12.D PPG Brine��- - �`cream -T FarmaN9R HZO PRACamepi Surface Casing Cement I Production Casing Camaro - — GLM, 6988' MD — Cement plug to 8000' MD - GLM. 7800- MO Tubing punch -7850 PSR, 7856' MD I Tubing Leak, 7868' MD FAB Packer, 7870' MO w/failed CIRP, 7876' MO i 2.75"'0' Nipple, 7087' MD ConocoPhillips 1/26/2020 PUMP 184 BBLS 12 PPG. BRINE DOWN IATAKING RETURNS UP TUBING DOWN THE FLOW LINE. PUMP 10 BBLS DSL FOR FREEZE PROTECT U TUBE TBG AND IA JOB COMPLETE 1/26/2020 (AC EVAL) CMIT-TX IA X OA TO 1800 PSI (PASSED). CMIT-TX IA TO 2500 PSI (FAILED), ESTABLISHED 5.36 GPM LLR TO OA/FORMATION. MON [TOR T, IA & OA FOR BUR POST CMIT. 1/25/2020 (AC EVAL) : MIT -OA TO 1800 PSI (FAIL), ESTABLISH OA LLR OF 0.24 GPM @ 1800 PSI (COMPLETE). IC POT (PASSED), CMIT-TX IA (IN PROGRESS), DDT -TX IA (IN PROGRESS). 1/22/2020 PULLED 1" DV @ 7800' RKB. IN PROGRESS. 1/21/2020 RAN 2.77" GAUGE RING & CCL, TIE INTO TBG TALLY 10/7/2013, TAG @ 7876' RKB BHP 4510 PSI, DRIFTTBG W/ DUMMY 2.78" WRP, RAN 21/2 PUMP BAILER W/ 2.75" BTM RECOVER 1/2 GAL. SCALE AFTER TWO RUNS TO TOP OF FISH @ 7876' RKB, SET 2.75" CAST IRON BRIDGE PLUG @ 7875.25' (ME), ATTEMPTTBGx IA DRAW DOWN. IN PROGRESS. 1/19/2020 (AC EVAL) T POT (PASSED) T PPPOT (PASSED) IC POT (PASSED) IC PPPOT (PASSED) 1/9/2020 PULLED DV @ 7800' RKB; CIRC'ED OUTTBG X IA 137 BBLS Cl SW FOLLOWED BY40 BBLS DIESEL (U - TUBE FP); SET DV @ 7800' RKB & PULLED CATCHER @ 7876' RKB. JOB COMPLETE. 1/8/2020 SET AVA CATCHER @ 7876' RKB & MADE SEVERAL ATTEMPTS TO PULL DV @ 7800' RKB. IN PROGRESS. 7/9/2019 PUMPED OFF FISH HAD NO MOVEMENT W /FISH. PULLED OOH FREEZE PROTECTED WELL TO 2500' W/21 BELS OF DIESEL RDMO 7/8/2019 RIH WITH DTI DOWN HAMMER, XRV, G -SPEAR, LATCH INTO FISH AT7845' CTMD, HAMMER DOWN, XRV UP/DOWN, GET 50 JAR LICKS WITH STRAIGHT PULLS TO 70K, NO MOVEMENT. POOH TO CUT COILANDTRYAGAIN. RBIH W/ UP DOWN JARS AND FOUR WT BARS JARRED UP & DOWN 50 TIMES WITH NO SUCCESS PUMP OFF FISH POOH FREEZE PROTECT WELL W 21 BBLS OF DIESEL ON THE WAY OOH 7/7/2019 RAN IN HOLE W / HAILY JARS & 3" G -SPEAR UNABLE TO LATCH CSV AND JARS WOULDN'T PUMP OPEN ONLY GOT 3JAR HITS DOWN POOH TO PICKUP A SLICK LINE INTERNAL SPEAR RAN BACK IN HOLE W /SUCK LINE BAITED INTERNAL SPEAR LATCHED UP TO CSV SPEAR JARRED UP 50TIMES AND DOWN 10 TRYING NOTTO SHEAR THE SPEAR UNABLE TO SHEAR THE SPEAR PUMPED OFF AND POOH TO CUT PIPE AND PICKUP THE DTI DOWN HAMMER 6/23/2019 LEAK DETECTION LOG. LEAK FOUND AT 7868'. LRS PUMPED 95 BELS OF DIESEL AT 0.75 BBLS/MIN WITH 2400PSI ON TUBING. LRS PUMPED 138 BBLS OF DIESEL AT 1.75 BBLS/MIN WITH 2000PSI ON TUBING. ConotoPhillips 6/9/2019 (AC EVA L) CMIT T X IA ( PASS TO 2500 PSI) LLR T X IA (7.3 GAL/MI N) 5/15/2019 TAG AT 7847' CTMD WITH VENTURI. PUMP SSW TO VENTURI 7800'- 7847, OOH WITH 4TBSP SCALE. RIH WITH FISHING BHA, MULTIPLE ATTEMPTS TO LATCH FISH, BOTH DRYTAGGING AND PUMPING TO HAMMER DOWN, ARE UNSUCCESSFUL. POOH WITHOUT FISH. FREEZE PROTECT TUBING AND COIL. JOB SUSPENDED. 5/14/2019 RIH TO 7838' CTMD TAG, PUMP SSW AND HAMMER DOWN TO 7843' RESISTANCE DEPTH. UNABLE TO LATCH FISH. MAKE CLEANOUT RUN WITH 1.75" DIN AND WASH TO 7853' WITH SSW AND GEL. RBIH WITH FISHING BHA TO 7852' TAG. HAMMER DOWN TO 7857' CTMD. PUH WITH 5K OVER PULL. RBIH HAMMERING DOWN, PUH ATSTRING WEIGHT. MULTIPLE ATTEMPTS TO LATCH UP AGAIN FAIL. RETURN TO SURFACE WITHOUT FISH. FREEZE PROTECT COIL AND WELL. SDFN. JOB IN PROGRESS. 5/13/2019 RIIH WITH HAMMER AND 3' G SPEAR. TAG & LATCH FISH AT 7851'. HAMMER DOWN PUMPING 776 SSW, MOVE FISH 1/2'- 1' DOWNHOLE. STARIGHT PULLS TO 38K. REPEAT HAMMER DOWN, LITTLE TO NO MOVEMENT. 2ND RUN WITH 2.80" MILL FOR SCALE REMOVAL 7850'- 7700'. FREEZE PROTECT WELL. AND COIL. JOB IN PROGRESS. 5/11/2019 TAGGED FILL W/ 2.5" PUMP BAILER @ 7880' RKB (BAILER FULL OF SCALE); AFTER SEVERAL ATTEMPTS REPLACED OV IN KIND @ 6984' RKB; ATTEMPT IA DDT (FAIL); JOB SUSPENDED FOR CTU. 4/30/2019 (AC EVAL) TIFL FAILED DUE TO PRESSURE INCREASE AND INFLOW 4/22/2019 BAILTHRU BRIDGE @ 7123' RKB TO 7152' RKB. PULL AVA CATCHER @ 7883' RKB. COMPLETE. 4/21/2019 BAILER APPROX 1.5 GALLONS OF SAND FROM 7120' RKB UNABLE TO RECOVER 31/2" AVA CATCHER ( DAL 39") IN PROGRESS 4/17/2019 BAILER - 2.5 GALLONS OF SCALE & SAND FROM 7100' RKB UNABLE TO RECOVER 31/2 AVA CATCHER (DAL 39"). IN PROGRESS. 4/16/2019 BAILED -3 GALLONS OF SCALE & FORMATION SAND FROM 7100' RKB ATTEMPTING TO RECOVER 3 1/2 AVA CATCHER, IN PROGRESS. 4/15/2019 TAGGED CSV WITH 2.5" BAILER @ 7879.25' RKB (NO RETURNS). ATTEMPT TO PUSH DOWN HOLE W/ 2.70" BLIND BOX. TAGGED @ 7873' RKB W/ 2.70" LIB (2.54" IMPRESSION). DEPLOYED CATCHER. PULLED OV (CHECK FOULED) @ 6984' RKB & REPLACED IN KIND. BLED IA TO CONFIRM SET. IN PROGRESS. Comc3hillips 0 7-5/8" Surface casing cement history based on drilling rig report: Two-stage cement job pumped on -rig 6/3/1997 indicated good cement from surface casing shoe at to surface. 1st stage cement pumped 94 bbls 10.5ppg ASIIILW cement followed by 78 bbls 15.8 Class G cement. Plug was bumped and floats held. 2nd stage was pumped through HES cementer at 1880' MD. Cement/mud was noted from first stage, indicating good cement from shoe to 1880' MD. Pumped 311 bbls 10.5ppg ASIIILW cement followed by 10 bbls 15.8 ppg ASlcement with good returns to surface. 5.5x4.5" Production casing cement history based on drilling rig report and verified by cement bond log: Single stage cement job pumped on -rig 6/15/1997 indicated good cement from HSE cementer at 8768' MD to 7550' MD. Pumped ^44 bbls of 15.8 Class G cement. Post rig CBL on 6/29/1997 indicated TOC at 7550'MD. ConocoPhillips CBL January 31, 2020 Annular Communication Surveillance Well Name: 3K- 23 Start Date: ; 3 . �n --C-, Days: 1 End Date: ' 7 ,n--'C2C Refresh ill(lFuiu 4-1x)1125 I t425 PCBSsurP Summary 7500 170 2000 150 1500 130 -o v a w 110 m 1000 n 90 r 50C 70 I�A 11 N 50 N i) "a ti M —WHP --AP —OAP Injection katp Summary 0.4 608 w 0 06 u. �? 0.5 z 0-4 C 0.3 u g 0.7 0: lJ r, —oG. MGI Annular Communication Surveillance Woll Name: 3K-23 Start Date; _' :C rC 1 [lays: 9C End Date: 3i -.an -~;2C Refresh I Injection Rate Summary �4 Q a.a 0.7 o 0.6 0 a Pressure Summary m 0.5 Y s 0.4 c 0-3 4 G 0.2 01 0 m 6 ;r YOGI MGI —PWI a ---•--SWI —SLP0 170 2000 lsc 1500 130 v Y W w 110 ro Y 1000 w a` a E 90 w x- 500 70 0 50 at .-1 � m a+ m m m V� O� m t� .m. m m mmi a� moi Q N O O N N eQi O O f7] O p z_ N N N N _ lL� a a s a � W W W W W W 1`D W W 5 C&l ySy LYl OY fh tb d, — WHP —IAP -.SOAP ---WNr Injection Rate Summary �4 Q a.a 0.7 o 0.6 0 a m 0.5 Y s 0.4 c 0-3 4 G 0.2 01 0 m 6 ;r YOGI MGI —PWI a ---•--SWI —SLP0 PTD r97 -09;� Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophil1ips.com> Sent: Tuesday, January 21, 2020 6:03 AM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt Subject: KRU 3K-23 (PTD# 197-097) Report of Sustained Casing Pressure Attachments: 3K-23.pdf, 3K-23 90 day TIO trend 1.21.20.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Kuparuk producer 3K-23 (PTD# 197-097) was reported on 5/4/19 for sustained casing pressure on the IA. Since then the well has remained shut in due to a standing valve stuck in the tubing tail and a tubing leak just above the production packer. While shut in the tubing and IA have equalized at 1950 psi. The well is currently awaiting a rig workover to remove the standing valve and repair the tubing leak. Three days ago, operations reported that the OA pressure reached 1450 psi and that the OA pressure would climb after it was bled. The OA pressure is currently being managed by bleed while CPA[ is working to secure the well and then we will progress OA diagnostics. The 7-5/8", 29.7 Ib L-80 surface casing is rated to 6890 psi (45%= 3100 psi). A 90 day TIO trend and wellbore schematic are attached. Please let us know if you have any questions or disagree with this plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 KUP PROD WELLNAME 3K-23 WELLBORE 3K-23 ConocoPhillips Well Attributes Max Angle & MD TD Aaska. Inc, Flala Name WellDnregPINWI WeIIDoreStays II'I Mupons) AR mm me) PAR K IV NIT 02 A R D 9.97 9,15252 10,462.0 CemmeM H2S 1ppml Dale grmotelMn Entl bah RG -GM In) Rig Rebase Na. SSSV:NIPPLE 150 1224/2012 La51 WO: 1MUS2013 41.02 ]/2199] 3K 31 ifiecooreSu:al qM LastTag Venial ¢Nemeuc ptluep pnmbllon pit, Mon Budgets I Wellbore I "Stmoaay UTT-9 SW 8,.0 592014.. NpshM w uaen Y 7 .. ... _.-. Last Rev Reason J. separate. I End one Wellbore I I.MMetl1y Rev Reason: Replace W 119/2020 3K-23 zembael Cdsing Strings casing DescnWbn GDpN 10 fin) ToPAI SNDSpithpi SR1301h (ND) WNLen(._Grade TIPTDreetl CONDUCTOR 16 15.06 412 1210 121.0 62.58 H40 WELDED "NMIOToe 41a4to GHng Oeanlgbn ODlln) toon) Top puts) Set DeponvsKB) .S.,11INDI...WNLen11... G2tle Top TDreetl SURFACE 759 6.87 41,2 4.96M 29.70 L-80 ABM -BTC - NIFREa8+.9 Case, Description OD (in. LOAM Top@RI SMiXener KB) gel OepM(NU)... WtlLen (._Getle Top TDrcatl PRODUCTION5.5'k45" 5112 4.95 38.8 10.439.2 15.50 L-80 LTC -MOO Tubing Strings - Tubing DncnpHon String Ma... to (M Tap lnKBl Set OepID IN.. S¢t Dep1M1 IND1 L.. WtpDM1 Gntle Top CanneMlon TUBING WO 3112 299 36.7 ],915.0 9.20 680 JT. _N Completion Details rep(NDI IDpmcl Nominee ToppointIn8e1 1'1 nem Dea Com ID pI) 3fi.] 36.7 0.00 HANGER FMCGENIVTUBINGHANGER 2.992 GASLIFT:30923 484.8 1 484.61 296 INIPPLE CAMCO DS NIPPLE 2875 7,852.0 1 50.52 LOCATOR BAKER LOCATOR SUB 2.990 7,853.0 50.53 REAL ASSY BAKER 8040 REAL ASSY 2.990 GAGuFT;+sez.e 7e56.o 50.55 MR BAKER 80-00 SPECIAL TRIM PER 3.913 7,870.4 --.9 PACKER BAKER FA -1 PRODUCTION PACKER 2.930 7,88].0 50.85 NIPPLE CAMC DB NIPPLE 2.812 ],908.6 51.21 OVERSHOT BAKER POOR BOY OVER HOT 3.600 TUDPop OeeniPNon S1Xno Ma... IDpnI Top InKBI .NDepl111R. get DeplD INOI L., W[IIbIhI Gntle Top ConneNlon TUBING Original 312 299 7,895.2 8756.4 9.30 L-80 ABM -EVE GURFACR412-+.aega- Completion Details GAG 111. g9U.0 To SQD) Top mel Nlmmae Top (blue SQ1°I neo" Des Com ID (in) 8,42)5 67.69 NIPPLE CAMCOONIPPLENOGO 2.750 Y_ Y 87437 78.10 L,.'1V I BARER LOCATOR 3.000 GAS LIFT; e,503T 8.747 ]8.14 SFAL gSSV BAKERLOCATORSEALABSEMBLV 3000 Other In Role (Wireline retrievable plugs, valves( pumps, fish, etc.) IND) TIP Incl _Top Top (MR)(flKe) 1'I Ges Com Run Gate In (in) Gas LIFT T.e0g.2 7,8680 5GER UBIN TGLEAK EL IDENTIFIED TBG LEAK@78WIITHLDL 623/2019 2.990 7,8760 5075 Paskspaer Peak releasable spear planned in baleen noes -releasable 71WO19 0.000 _ spear an top of CSV( BAIT SUB 2]2°X 2.33'1 IXO X.36) (PEAK SPEAR Z VP X 1.63) TOL= 4.32' LOGTGR; 1,85] b aFALgssv: AeSxg PRS;7,M "- NBING LE4K: T.080.a 1 7,8A.3 50.76 B .,R pear Set2Ying. 2.Mea GoapePearin SV BSM1.2J2°ODX 25.125' long. 2.348" GrzpPle. 411 A20t1 0,000 ].879.3 50.]8 CSV CAT Stantlin9 Valve, wKD Oama9etl fishing neck. 3I1I2017 0.000 PACKER)'e'S', - 10.423.0 BJ.45 FISH FISH LOST 2 COLLETS IN WELL FROMTILATCH 311/2007 O.WO pnk sF .,, 70780 DURING 3/12007 GLV INSTALLATION BP.lan spec. 7,an3 Perforations & Slots - CSV; IA GA gryM NIPPLE: 7.aeT.O Top pai BM raps) TIP (NaI 'RuSo BM IND) InNB) Unked Zona Dah IMotvT I Type Co. 8,807.0 10,432.0 AS,AA,A3,A- 1IW1997 24.0 (PERF 60 tlegPhha mTPM- 2, 3K23 I Perfo2letl 4 112 CSG 0VeRaHor;7.m55 Free Summery 81e 0 Won Sea Sort PNppaM CnlpnetlllD) PrappaM In Formanen lMl GAS LIFT; 0,]]7,] St'e l9srivate IT,p pepM MKB) BM IN(B) Llnhlo Fllltl SyMem Vol Clnnlbpp VW glumy lbbg 1 1W007 18, 10,432.0 Mandrel Inserts s< NIPPM,8,Q7S o0 N Top (flKB) Top (Nal IRKBI Make Verve Lamb PortSW TRORun Model OO (in) 9ery Type Type me (R1) Run asks Com 2.892.3 CAMCO KBG-2- 1 GASLIFT GLV BTM 0.156 1,310.0 3111201) 9 2 4,592.9 CAMCO KBG-2- 1 GASUFT GLV BTM 0.156 1,296.0 W42D17 9 35,918.8 CAMCO KR -2-1 GAR LIFT GLV BTM 0.188 1,338Z W12017 9 4 fi,983.7 CAMCO KB6-2- 1 GASMFr OV BTM 0.188 0.0 511112019 9 tOGrOR; a.7+17 6 7,800.2 CAMCO KBG-2- i GAB LIFT OMY BTM 0.003 0.0 19/2019 SE44 ASSY: V.7 - 9 6 6,3)67 BBT ATX 1 GAB LIFT OPEN 4/182013 - Notes: General & Safety Rntl Dme Annopi iW1W2013 NOT62013 WOBovar tubing cuts SAIR dGeinhole@83438313',8127,8030' 912312013 NOTE: Mantlrel Orienlation:6)11:30 11/312010 NOTE: UIaw Schem nEW/AaskaBMemalic9.0 AS ND Fa :80010 IPFAF: 9, W 10-+0.+32.0 rISH: MUSS FROWCPGN5.5'K.5^ 38 & ta.43ez 3K-23 1/20/20 3K-23 1/18/20 3K-23 1/18/20 Annular Communication Surveillance 90 -Day Bleed History 1000 200 800 OUTER GLO 1300 200 1100 OUTER GLO 1450 250 1200 OUTER GLO Annular Communication Surveillance Well Name: 3K-23 Start Date: 23 -Oct -2019 Days: 90 End Date: 21 -Jan -2020 Pressure Summary 2500 170 2000 150 LL 130 w a 1500 v v 3 N 110 v 1000 n a v 90 500 70 0 50 m m m m m rn m m m m m m m m m m m m m m m m m m o 0 0 0 0 0 0 rl rl N rl rl rl rl rl rl r -I rl c -I r1 ri ci N N ii N N .y 'y rl N N N N N N N V V >> O O > O > O > O > O > O > O > > w V V V V O O N N N N N N N d w N u u L C L L C C C O O O Z Z Z Z Z Z Z Z Z Z p O p p p p p p p O p m l0 6 .-y 4 ri o m to N T —WHP —IAP —OAP WHT Injection Rate Summary 1 0.9 0 0.8 0.7 O 0.6 0 S 0.5 v 0.4 0.3 V N c 0.2 0.1 0 N ci V m N —DGI MGI —PWI - SWI —BLPD RECEIVED STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMIltION OCT 2 2 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon fl Repair well 17. Rug Perforations r Perforate r Other rAOGGC Alter Casing fi Pull Tubing •Stimulate-Frac 1— Waiver r Time Extension Change Approved Program rOperat. Shutdown Stimulate-Other fi 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 _ 197-097 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22771-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25519 • 3K-23 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 10462 feet Plugs(measured) none true vertical 6680 feet Junk(measured) 10423 Effective Depth measured 10432 feet Packer(measured) 7870 true vertical 6679 feet (true vertical) 6179 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 4928 7.625 4970 4094 PRODUCTION 10400 5.5"x 4.5" 10439 6679' Perforation depth: Measured depth: 8807'-10432' SCANNED NOV L True Vertical Depth: 6577'-6679' !�A! Tubing(size,grade,MD,and TVD) 3.5, L-80, 7915 MD,6207 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FA-1 PRODUCTION PACKER @ 7870 MD and 6179 TVD NIPPLE-CAMCO DS NIPPLE @ 485 MD and 485 ND 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 shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory fl Development p's Service fi Stratigraphic fl 16.Well Status after work: Oil 17. Gas r WDSPL fi Daily Report of Well Operations )0 GSTOR WIND r WAG r GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Ian Toomey i7 263-4773 Email Ian.A.Toomey(p�conocophillips.com Printed Name Ian Toomey Title Wells Engineer Signature ......__----, Phone:263-4773 Date -1—� /t, ,2,./-/3 in- RBDMS OCT 2 5 2111.6 \-- id/z b 5 Form 10-404 Revised 10/2012 (S1(9 Submit Original Only r ; KUP PROD 3K-23 ConocoPhillips t r Well Attributes Max Angle&MD TD Alaska,Inc. Well bore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) t ,,,,,c 500292277100 KUPARUK RIVER UNIT PROD 89.97 9,152.52 10,462.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 1 Rig Release Date 3K-23.10/21/201311 0022 AM SSSV:NIPPLE I 150 12/24/2012 Last WO: 10/10/2013 41.021 72/1997 Vertical schem t c(actual) Annotation I Depth(ftKB) I End Date Annotation 1Last Mod By I End Date ... �11 _...Last Tag SLM 8,558.0 1/112011 Rev Reason:PULL PLUG Ihipshkf 10/19/2013 ........__...HANGER;36.7 teliffi' Casing Strmgs Casing Description OD(in) ID(in) Top(ftKBI Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread iii i T;, CONDUCTOR 16 15.062 41.2 121.0 121 0 62.58 H-40 WELDED , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 41.2 4,969.5 4,094.2 29.70 L-80 ABM-BTC IICasing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread II ° 'PRODUCTION 5.5"x4.5' 5 1/2 4.950 38.8 10,439.2 6,679.4 15.50 L-80 LTC-MOD !! ' Tubing Strings CONDUCTOR;41.2-121.0 ' Tubing Description String Ma...ID(in) Top(WW1 Set Depth(ft..I Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO 31/2 2.992 36.7 7,915.0 6,206.7 9.20 L-80 IBT-M NIPPLE;484.8 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(°) Item Des Com ON 36.7 36.7 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 484.8 484.6 2.96 NIPPLE CAMCO DS NIPPLE 2.875 --- 7,852.0 6,166.9 50.52 LOCATOR BAKER LOCATOR SUB 2.990 I I' 7,853.0 6,167.5 50.53 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 7,856.0 6,169.5 50.55 PBR BAKER 80-40 SPECIAL TRIM PBR 3.913 GAS LIFT;2,892.3 7,870.4 6,178.6 50.69 PACKER BAKER FA-1 PRODUCTION PACKER 2.930 s 7,887.0 6,189.1 50.85 NIPPLE CAMCO DS NIPPLE 2.812 ®I 7,908.6 6,202.7 51.21 OVERSHOT BAKER POOR BOY OVERSHOT 3.600 Tubing Description String Ma...I ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(11a/ft) Grade I Top Connection GAS LIFT,4.592.9 TUBING Original 3 1/2 2.992 7,895.2 8,756.4 6,567.5 9.30 L-80 ABM-EUE MI Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc'(°) Item Des Com (in) I 8,427.5 6,468.4 67.69 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,743.7 6,564.9 78.10 LOCATOR BAKER LOCATOR 3.000 I 8,744.7 6,565.1 78.14 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 i Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;41.2-4,9695- l Top(ND) Top Inc' Top(ftKB) (ftKB) El Des Com Run Date ID de) 10.423.0 6,678.7 87.45 FISH FISH LOST 2 COLLETS IN WELL FROM T1 LATCH 3/1/2007 0.000 GAS LIFT;5,948.8 _ DURING 3/1/2007 GLV INSTALLATION Perforations&Slots Shot Dens GAS LIFT;6,983.7 To (ftKB) Btm(ftKB) Top(ND) Btm(ND) IshtI Top ) ) (ftKB) m IN Zone Date O Type Com 8.807.0 10.432 0 6,577.3 6,679.1 A-5,A-4,A-3, 7/6/1997 24.0 IPERF 60 deg.phasing;Pre- A-2,3K-23 perforated 4 1/2 CSG Stimulations&Treatments GAS LIFT;7,800.2 • Min Top Mao Btm 11� Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 8,807.0 10,432.0 6,577.3 6,679.1 A-SAND FRAC 1/6/2007 A SAND FRAC-PLACED 323,000#16/20 CARBOLITE IN FORMATION,10 PPA ON THE PERFS.PLACED 100%OF DESIGN,FLUSHED TO LOCATOR;7,852.0 COMPLETION. SEAL ASSY,7,853.0 s" Mandrel Inserts PBR;7,856.0 St PACKER;7,870.4 '' o l C NO Valve Latch Port Size TRO Run o Top(ftKB) T(ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date NIPPLE;7,887.0 . 1 2,892.3 2,573.6 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,296.0 10/12/2013 m Tr 2 4,592.9 3,816.5 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,296.0 10/12/2013 la 3 5,948.8 4,805.2 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,293.0 10/12/2013 OVERSHOT;7,908.5 III I4 6,983.7 5,556.4 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.188 1,325.0 10/12/2013 GAS LIFT;8,374.7 1 5 7,800.2 6,133.8 CAMCO KBG-2-9 1 GAS LIFT OV BTM 0.250 0.0 10/11/2013 II 6 8,374.7 6,447.5 BST ATX 1 GAS LIFT OPEN 4/18/2013 NIPPLE;8,427.5 Notes:General&Safety End Date Annotation I 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 9232013 NOTE:Mandrel Orientation:6)11:30 10/10/2013 NOTE:2013 Workover tubing cuts still downhole @ 8343,8313',8127',8030' LOCATOR;8,743.7 SEAL ASSY;8,744.7 l 1 IPERF;8.807.0-10,4320 ,� II I A-SAND FRAC;8,807.01 FISH,10,423.0 ■ PRODUCTION 5.5''54.5';38.8- 10,439.2 3K-23 PRE AND POST WELL WORK • PRE-RIG WELL WORK • DATE SUMMARY 8/11/2013 PULLED PRONG &2.75 CA-2 PLUG @ 8428 RKB. READY FOR E/L. 8/14/2013 SET BAKER IBP MID ELEMENT AT 8776' IN MIDDLE OF 9' PUP JOINT. CCL TO MID-ELEMENT OFFSET IS 23.7'. CCL STOP DEPTH IS 8752.3'. CORRELATED TO PPROF DATED 27-NOV-1997. PUMPED SEAWATER AT RATE OF 3 BPM TO GET TO DEPTH. CMIT FAILED AFTER SETTING IBP. READY FOR SL. 8/16/2013 (PRE-RWO): T POT-PASSED; T PPPOT-PASSED; IC POT-PASSED; IC PPPOT-PASSED; ALL T LDS'S FUNCTIONED PROPERLY. 8/16/2013 ATTEMPT TO RETRIEVE IBP AT 8776'. RIH TO 8721"SLM DUE TO HIGH DEVIATION. RECONFIGURE TOOLS AND RESTART IN AM. IN PROGRESS 8/17/2013 ATTEMPT TO RETRIEVE IBP @ 8776'. ABLE TO EQUALIZE, BUT UNABLE TO LATCH. RECONFIGURE TOOLS & RESTART IN AM, IN PROGRESS. 8/18/2013 RETRIEVED IBP FROM 8738' SLM, JOB COMPLETE 8/22/2013 (PRE-RWO): MIT-OA PASSED TO 1800 PSI. 9/5/2013 PERFORMED FILL CLEAN OUT ACROSS IBP SETTING AREA 8700'-8830' CTMD USING DIESEUDIESEL GEL,VERY LIGHT SAND OBSERVED IN RETURNS, MAINTAINED 1:1 RETURNS THROUGHOUT FCO, RIH TO LOCATE NIPPLE AT 8427.5' RKB, FLAG PIPE, F/P TBG WHILE POOH, JOB IN PROGRESS. 9/6/2013 RIH TO FLAG @ 8427' RKB, CORRECT DEPTH (+19' CORRECTION), RIH TO SET DEPTH, WAIT 3 HOURS FOR FLUID TEMPERATURE STABALIZATION, DROP 1/2" BALL, SET INFLATABLE BRIDGE PLUG @ 8776' RKB MID ELEMENT, PRESSURE TEST IBP TO 1900 PSI, F/P TBG TO 3000' WITH S/D WHILE POOH, READY FOR SLICKLINE, JOB IN PROGRESS. 3K-23 WELL WORK DURING WORKOVER 9/7/2013 ATTEMPT CMIT TO 3000 PSI, FAIL, TAG IBP w/2.60 LIB @ 8734'SLM, RAN 2.77"GAUGE RING TO D-NIP @ 8427' RKB= 35' .IN PROGRESS 9/8/2013 ATTEMPT TO PLACE CaCO3 OVER IBP @ 8776' RKB PREMATURELY SHEARED 2.5" DUMP BAILER @ 8525'SLM RAN BLB AND GAUGE RING TO 8465'SLM ATTEMPT TO BAIL S/D HIGH 8528' SLM.IN PROGRESS 9/9/2013 BAILED THROUGH PREVIOUSLY DUMPED/BRIDGED CaCO3 WITH 10' BLR; WORKED 2.5" BLB TO 8730' SLM. RAN 10'x 2.5" DUMP BAILER W/2.125" BLIND BOX TO 8714' SLM. AT 78 DEG DEVIATION UNABLE TO SHEAR PIN. IN PROGRESS. 9/10/2013 WITH 2-1/2" BRUSH ATTEMPTED CLEAR TBG, UNABLE TO PASS 8714'SLM. WORKED 2.5" DD BAILER, 2.66" GAUGE RING TO 8714'. WORKED 2" DD BAILER TO 8714'. IN PROGRESS. 9/11/2013 RAN CATCHER TO 8427' RKB. PREP TO SET DV IN OPEN GLM @ 8375' RKB. CHANGE OF PLANS AS PER ENGINEER. PULLED CATCHER @ 8427' RKB. READY FOR CTU. 9/12/2013 Tag IBP lightly at 8,751-ft ctmd (8,769-ft RKB corrected) laid in 700#(130-ft)20/40 mesh from 8,745-ft to 8,358-ft ctmd, let sand settle 1.5 hrs, tag TOS at 8,590-ft ctmd, clean out sand to 8,700-ft ctmd, pushing sand down tag up at 8,744-ft ctmd (8,762-ft RKB)est. —7-ft sand on IBP. Job complete. 9/27/2013 PERFORM A FREE POINT LOG FROM 8230' UP. FOUND STUCK POINT AT 7956'. 10/7/2013 PULLED 2.81" RHC PLUG BODY @ 7887' RKB. SET 2.81"C- LOCK w/PRONG PLUG ASSEMBLY @ 7887' RKB. SET PRONG @7887' RKB. RIG TESTED PLUG, PASSED. COMPLETE. 3K-23 POST RIG WELL WORK 10/11/2013 GAUGED TBG TO 2.79"TO 7838' SLM. SET CATCHER @ 7838' SLM. PULLED SOV @ 7800' RKB. PUMPED 75 BBL DSL DOWN TBG, RETURNS OFF IA TO PRODUCTION. U-TUBE TO BALANCE FREEZE PROTECT ON TBG & IA. SET OV @ 7800', PULLED DV @ 6983' RKB. IN PROGRESS. 10/12/2013 PULLED DVs @ 5950', 4595'&2895' RKB. SET GLVs @ 6983', 5950', 4595'&2895' RKB. PULLED CATCHER @ 7880' RKB. PULLED PLUG @ 7887' RKB. TAGGED OBSTRUCTION @ 7915' SLM. IN PROGRESS. 10/13/2013 CLEARED DEBRIS WITH MAGNET& BAILER FROM 795T-8037' RKB. RECOVER PIECES OF METAL& BANDING. IN 1pGRESS. 10/14/2013 CLEARED DEBRIS WITH GNET& BAILER FROM 8052-8167' RP RECOVERED MANY PIECES OF METAL. WELL READY FOR CTU. 10/16/2013 VENTURI RUN#1 MADE IT TO 8758' MADE NO MORE HOLE POOH, HAD METAL CHUNKS WITH HARD CEMENT AND FRAC SAND FILTER FULL OF SAND AND MUD VENTURI RUIN#2 MADE IT TO 8774'RKB, HAD MINIMAL METAL SHAVINGS AND HAND FULL OF SAND RETURN IN THE MORNING TO RUN A NOZZLE AND FISH IBP ***JOB IN PROGRESS**** 10/17/2013 RAN IN HOLE WITH JSN TO CLEAN OUT ON TOP OF IBP, CAME BACK TO SURFACE PUT RETRIEVING TOOLS ON FOR IBP,RUN IN HOLE TO IBP THOUGHT THAT WE HAD IBP CAUSE THE WELL EQUALIZED, CAME TO SURFACE HAD NOTHING, PUT HYDRAULIC OVERSHOT ON, GO BACK IN THE HOLE TRY AND RETRIEVE IBP, LATCHED UP APPEAR TO HAVE IBP, PULLING OUT THE HOLE.AT SURFACE HAVE IBP, 3 STIFFENER RINGS LEFT IN HOLE. ***JOB COMPLETE**** Conoco Phillips Time Log & Summary Weliview Web Reporting Report hodl''oW t o v 1 Well Name: 3K-23 Rig Name: NORDIC 3 Job Type: ABANDONMENT Rig Accept: 9/23/2013 6:00:00 AM Rig Release: 10/10/2013 7:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 39/07/2013 24 hr Summary Pull off of 3M-22 well. Spot rig on 3M pad, remove BOP's, continue moving equipment to 3K-pad including camp. Rig up crane to windwalls on rig,too high of wind speeds.Wait on weather and rig move support equipment due to 141 rig move. Rig move support equipment available @ 21:00 hrs. 00:00 09:00 9.00 MIRU MOVE MOB P Pull off 3M-22 @ midnight. Place rig mats and stag rig in center of pad. Remove BOPE stack and skid stand behind the rig. Continue cleaning up location until the camp is ready to move. 09:00 12:00 3.00 MIRU MOVE MOB P Peak sow arrived on location, move rig camp to 3K-pad. 12:00 00:00 12.00 MIRU RIGMN1 RGRP T Start rigging up crane to install windwalls. High wind speeds, cannot lift wind walls.Wind speeds 25-30 MPH. Doyon 141 Rig move,fell through road. Remove rig support equipment from Nordic 3. 21:00 hrs,toolhouse continue to stage mats on Nordic 3 pad. 09/08/2013 Stage&set rig mats,wait on support equipment for rig move, continue moving rig equipment to 3K-pad. Start rig move 21:00 hrs. 00:00 06:00 6.00 MIRU MOVE MOB P Continue staging Mats,waiting on winds, 20 MPH.Winds too high for wind walls. Ready for rig move 04:00 hrs. 06:00 21:00 15.00 MIRU MOVE MOB P Wait on truck from Tool house to load out remaining rig equipment and set mats on the 3M access road. Loaders and mats spotted, equipment ready for rig move. 21:00 00:00 3.00 MIRU MOVE MOB P Rig starting to move from 3M-pad. 39/09/2013 Continue with rig move,double and triple mating lease road to 31 pad. 00:00 06:00 6.00 MIRU MOVE MOB P Continue mating and moving the rig. Painting mixing table, mud manifold and coke handles. 06:00 00:00 18.00 MIRU MOVE MOB P continue to shuffle mats and move rig toward 3 I pad. Required triple matting on most of the lease road dur to soft conditions. 09/10/2013 Continue with rig move, DROPS audit inspection performed on rig. of Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 MIRU MOVE MOB P Continue with rig move. Prep pipe shed for painting. DROPS Audit performed on rig 39/11/2013 Continue with rig move, DROPS audit inspection performed on rig. Arrive on 31 pad, install windwalls 00:00 16:00 16.00 MIRU MOVE MOB P Continue to move Nordic rig 3 from .2 miles of 31-Pad onto 31 Pad 16:00 23:00 7.00 MIRU RIGMNT RGRP P Move in rig and set down on mats. Rig up crane and installed windwalls. Release crane 23:00 hrs Start stacking and shuffling rig mats from 31 to CPF 3 access road 23:00 00:00 1.00 MIRU RIGMN1 RGRP P Secure& Pin windwalls 09/12/2013 Installed wind walls on 31 pad. Continue to shuffle mats from 31 to CPF 3 Access road. Continue moving rig. 00:00 08:30 8.50 MIRU MOVE MOB P Continue shuffling mats, secure _windwalls, paint pipe shed. 08:30 00:00 15.50 MIRU MOVE MOB P Continue moving rig&painting projects. 39/13/2013 Continue with rig move 00:00 19:00 19.00 MIRU MOVE MOB P Continue with Rig move to 31 access 19:00 00:00 5.00 MIRU MOVE MOB P Release 200-4"rig mats to KDTH, Shuffle remaining 200-6"rig mats ahead of rig and lay out same. 09/14/2013 Continue to shuffle mats from 31 access towards CPF 3. Begin moving Nordic rig 3 towards CPF3 00:00 05:00 5.00 MIRU MOVE MOB P Continue to shuffle and lay rig mats ahead of rig. 05:00 00:00 19.00 MIRU MOVE MOB P Begin moving Nordic rig 3 towards CPF 3 on rig mats 39/15/2013 Moving Nordic rig 3 towards B"Y" 00:00 00:00 24.00 MIRU MOVE MOB P Moving Nordic rig 3 towards 3B"Y" on rig mats, Shuffle mats and move to 3J access road. 09/16/2013 Continued moving Nordic rig 3 to 3B"Y"and shuffle mats around and lay towards CPF 3 00:00 00:00 24.00 MIRU MOVE MOB P Shuffle mats and move Nordic rig 3 to CPF3 and set down. 09/17/2013 Move rig to CPF 3 wait due to logistics. Continue to lay mats and move rig. 00:00 02:00 2.00 MIRU MOVE MOB P Coninue to move rig on mats to CPF-3 02:00 19:30 17.50 MIRU MOVE MOB P Wait at CPF-3 due to logistics. Lay mats towards 3C access 19:30 00:00 4.50 MIRU MOVE MOB P Move rig from CPF-3 toward 3C access on Oliktok road 39/18/2013 Move Rig towads 3K pad. Stop at 3C pad and move mats around and let traffic pass. 00:00 16:30 16.50 MIRU MOVE MOB P Conitnue to move rig towards 3K pad on mats to 3C access road. 16:30 20:00 3.50 MIRU MOVE MOB P Lay mats ahead of rig. 20:00 00:00 4.00 MIRU MOVE MOB P Move rig towards 3K pad access.At midnight 1.3 miles from 3K access 3.1 miles from 3K-23 .x Page 2 of 9 7 Time Logs 1111 1110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 39/19/2013 24 hr Summary Move Rig towards 3K pad access. 00:00 06:00 6.00 MIRU MOVE MOB P Continue to move rig on mats towards 3K access road. 1 mile from 3K access at 06:00hrs 06:00 00:00 18.00 MIRU MOVE MOB P Continue to move rig on mats towards 3K access road.At midnight .4 miles from 3K access road, 2.2 miles from 3K-23. 39/20/2013 Move rig towards 3K access road 00:00 16:30 16.50 MIRU MOVE MOB P Continue to move rig to 3K access road on Mats. 16:30 20:00 3.50 MIRU MOVE MOB P Allow traffic to pass and move mats in front of the rig at the 3K"Y" access. 20:00 22:30 2.50 MIRU MOVE SFTY P Stop moving mats due to extremely slick road conditions. Dispatch grader and scarify road. Hold meeting with ASRC operators and rig crew. Discuss Stopping the job and mitigating hazards. 22:30 00:00 1.50 MIRU MOVE MOB P Continue to move mats in front of the rig dow the 3K access road. 39/21/2013 Move rig on 3K access road 00:00 00:00 24.00 MIRU MOVE MOB P Move rig on mats on 3K access road. Double mat over the corrugated culvert sections. At midnight.8 miles away from the well. 39/22/2013 00:00 00:00 24.00 MIRU MOVE MOB P Move rig down 3K access road. Stop at E pit access and move all mats in front of the rig. Scarify road due to slick conditions. 09/23/2013 Move rig to 3K-23,Spot over well, accept rig, rig up to kill well. Pull BPV, Rig up circulating lines and lines to the Kill tank. Fill pits with 12.6ppg WBM and condition same.Test lines in cellar and to kill tank. Kill well with 224BBLs of 12.6pppg WBM. Monitor well. Set BPV. 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move Nordic 3 from 3K Pad entrance to 3K-Pad. Hang stack and tree in cellar while shuffling mats behind the rig. 05:00 06:00 1.00 MIRU MOVE MOB P PJSM, Notifiy DSO for spotting over well. Spot&level rig over well. *Accept Rig at 0600hrs 9/23/2013* 390 hour rig move 06:00 09:30 3.50 MIRU RPCOM MOB P Set cuttings tank. Berm up around rig and cuttings tank. Perform Rig acceptance check list. Spot kill tank and berm same. Rig up hard line and hoses 09:30 11:00 1.50 MIRU WHDBO PLUG P PJSM, Rig up lubricator and test to 2500 psi and pull bpv v * phi Time Logs II Date From To Dur S.Depth E. Depth_Phase Code Subcode T Comment 11:00 15:00 4.00 MIRU WELCTL KLWL P Fill pits with 12.6 WBM Conitnue to Rig up hard line and hoses. 15:00 17:00 2.00 MIRU WELCTL KLWL P PJSM, test cellar hoses and hard line. 250/3,000psi Good 17:00 18:30 1.50 MIRU WELCTL COND P Condition fluid back to 12.6 due to residual water in pits. 18:30 19:30 1.00 MIRU RIGMN1 RGRP T Change out#3 charge pump 19:30 22:00 2.50 MIRU WELCTL KLWL P JSA, Line up to kill well pumping down the tubing taking returns up the IA. Initial pressures;Tubing 90psi. IA 90psi, OA 220psi Pump 224 BBLs of 12.6ppg WBM 5 BPM ICP Tubing 550 psi IA 120 psi FCP Tubing 2010psi IA 100 psi 22:00 23:00 1.00 MIRU WELCTL OWFF P Monitor Well-Static 23:00 23:30 0.50 MIRU WELCTL KLWL P PJSM, Rig down hoses, BLow down 23:30 00:00 0.50 MIRU WHDBO PLUG P Set FMC ISA style BPV 39/24/2013 N/D tree and N/U BOPE.Test BOPE to 250/3500psi. Pull Blanking plug and BPV. BOLDS and unseat hanger.Attempt to pull seals free, No Go.Work pipe and circulate attempting to free seals while wating for Halliburton E-Line services. 00:00 02:00 2.00 MIRU WHDBO NUND P PJSM, Bleed voids, N/D Tree, inspect hanger threads, Good. Install Blanking plug for testing BOPE. 02:00 06:30 4.50 MIRU WHDBO NUND P N/U DSA and BOP's 06:30 08:00 1.50 MIRU WHDBO BOPE P Make up test joint and lines. Shell test and fix leaks on test stump for safety valve. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 13:30 5.50 MIRU WHDBO BOPE P PJSM test BOPE 250/3500 PSI (1)Blinds, Stand pipe kill, choke 4,11,12, 3.5 IF dart,TD Hyraulic UKV. Passed (2)BR, Kill HCR,Lower TD , 3.5 IF FOSV, Choke 3,7,9,10 Passed (3)BR, Man Kill, 3.5 FOSV 8rd, Choke 2,5,6. Passed (4) BR, Man Kill, 3.5 FOSV 8rd, Choke 8. Passed (5)LPR W/3 1/2"TJ Passed (6)Annular 3 1/2"TJ, Manual Kill, choke valves 2,5,6. Passed (7)Upper variable pipe rams 3 1/2" TJ, Choke HCR Passed (8)Manual choke Passed (9)Choke valve#1 Passed Accumulator test. Initial-3000psi Actuate all BOP(function upper pipe rams 2x's for blinds)1600 psi First 200psi-11sec Final 3000psi-93sec Ann. closing time 16sec Upper,Lower and Blind Ram closing time 4sec. each 4 N2 bottles @ 1925 psi 13:30 16:00 2.50 MIRU WHDBO MPSP P PJSM. Pulled Blanking plug and BPV. had trouble with BPV due to mud 16:00 17:30 1.50 8,745 8,745 COMPZ WELLPF PULL P PJSM BOLDS.Attempt to pull seal assembly.Working seals from 125K to 180 K. No real movement Tubing pressure built up to 170 Psi . 0 Psi on IA. 17:30 19:30 2.00 8,745 8,745 COMPZ WELLPF CIRC P Circulated well with 270BBLS of 12..6#mud @ 3 BPM @1500 psi. Through open choke through gas buster. No gains for losses during circulation. 19:30 20:00 0.50 8,745 8,745 COMPZ WELLPF OWFF P Monitor well for flow-Good 20:00 00:00 4.00 8,745 8,745 COMPZ WELLPF PULL P Attempt to pull seals while wait on E-line.Work pipe from 90K to190K. No movement. Break circulation every 15 minutes. 09/25/2013 Work pipe and circulate in an attempt to free seals. Circulate bottoms up and monitor well. Rig up Schlumberger Digital Slicklilne. Run in hole with 2.5"G/R to 8383' unable to pass. Run in hole with 2.5"G/R and knuckle assembly tag up at 8383'again. POOH and pick up Jet cutter and run in hole. 00:00 03:00 3.00 8,745 8,745 COMPZ WELLPF PULL P Work pipe and attempt to pull seals. 190k to 90k. Break circulation every 15 minutes. 03:00 04:00 1.00 8,745 8,745 COMPZ WELLPF CIRC P Circulate Surface to Surface 5 bpm 2450psi. r , qf Time Logs 410 4 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 8,745 8,745 COMPZ WELLPF PULL P Spaceout for e-line cut. 20k over at cut point of 8722'. Install FOSV w/ID of 2.992"head pin and circ hose. Blow down Top Drive. 05:00 12:30 7.50 8,745 8,745 COMPZ WELLPF OTHR T Waiting on Digital slick line unit for chemical cut. continue to circulate 12:30 16:30 4.00 8,745 8,745 COMPZ WELLPF SLKL P Spot Slumberger and up load tools to thre rig floor. PJSM made up 2.5 Gauge ring and lubicator. PT lubicator to 2000 psi. RIH with Gauge. 16:30 19:00 2.50 0 8,383 COMPZ WELLPF SLKL T Rih with 2.5 G/R to 8383'with pump assist. Unable to go any farther. 8'below last GLM with open pocket. POOH. Monitor hole on trip tank. 19:00 22:00 3.00 0 8,383 COMPZ WELLPF SLKL T Pick up knuckle joints and Rih with 2.5"G/R Pump assist at 2 BPM 1000psi. Coorelate at GLM#2. Unable to pass 8383'work 5x's. Pooh counting collars back to GLM#5. 22:00 00:00 2.00 0 8,343 COMPZ WELLPF SLKL T PJSM, Make up jet cutter assembly. RIH with pump assist 2 BPM 1000psi. 09/26/2013 Rih with jet cutter to 8343'. Fire. POOH and unable to work pipe free. Rig D. Slickline back up. Suspend operations due to Slickline crew being timed out and circulate. Resume Digital Slickline operations, PT lubricator, RIH with 2.75"Jet cutter and make cut at 8313'. Rig down D. Slickline. Indications that jet cutter fired, no indications of pipe movement. 00:00 01:30 1.50 8,343 8,343 COMPZ WELLPF SLKL T Tag up at 8360'. Log up and correlate. Shoot Jet cutter at 8343'middle of first full joint above GLM#1. POOH with jet cut run and confirm cutter fired. Well static 01:30 02:30 1.00 8,343 8,343 COMPZ WELLPF SLKL T PJSM, Rig down Digital Slick Line. 02:30 03:30 1.00 8,343 8,343 COMPZ WELLPF PULL T Attempt to pull free from jet cut at 8343'. Pick up and 150k out of slips. Work up to 190k with no movement. Reciprocate pipe from 85k to 190k no movement. Circulate at 2bpm 1000psi(No change) Consult with town engineer. 03:30 04:00 0.50 8,343 8,343 COMPZ WELLPF SVRG T Blow down lines and install 3 1/2" FOSV 04:00 05:00 1.00 8,343 8,343 COMPZ WELLPF SLKL T PJSM, Rig Schulmberger Digital Slickline back up for second Jet cut. 05:00 17:30 12.50 8,343 8,343 COMPZ WELLPF SLKL T Wireline crew timed out. Rig up to circulate during waiting period. Circulate at 2bpm 1000psi. No gains or losses. x t Page 6 of 1 r t 4� t Time Logs 410 11, Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 19:00 1.50 8,343 8,343 COMPZ WELLPF SLKL T PJSM, Install Schlumberger Digital Slickline BOPE equipment back on, stab lubricator and test to 2000psi. 19:00 21:00 2.00 8,343 8,343 COMPZ WELLPF SLKL T Make up 2.75"Jet cutter assembly. Pressure test connection at QC sub. 21:00 00:00 3.00 0 8,313 COMPZ WELLPF SLKL T Rih with 2.75"jet cutter with pump assist. Correlate and fire shot at 8313'. No movement at surface. Log out of hole 300'and no indication the pipe moved. Verifed on surface cutter fired. 09/27/2013 Rig down Digital Slickline. Pull on pipe and attempt to free. Circulate bottoms up and wait on Halliburton E-line. Rig up E-line with full pressure control. Perform free point operation 2 x's and establish stuck point @7956'. Rih with stringshot. 00:00 00:30 0.50 8,313 8,313 COMPZ WELLPF SLKL T Rig down digital slickline. 00:30 01:30 1.00 8,313 8,313 COMPZ WELLPF PULL T Attempt to pull pipe.Work up to 190K with no movement. Reciprocate pipe F/95K to 190K while pumping 2bpm 890psi. No movement. Call out Halliburton E-line for free point 01:30 02:30 1.00 8,313 8,313 COMPZ WELLPF CIRC T Circulate bottoms up 5bpm 1922psi 12.6ppg in and out 02:30 07:30 5.00 8,313 8,313 COMPZ WELLPF ELNE T Circulate 2bpm and workpipe while waiting for Hallburton E-line. 07:30 00:00 16.50 8,250 COMPZ WELLPF ELNE T Spot HES Eline. PJSM RU HES to run tbg.magnet recovery assembly in &out pass to 8250 ft,worked tubing from 100k to 150K. RBIH with Magnet recovery assembly. No chanage in magneric data. POOH with tool.work tubing from 100K to 190 K. Pick tools back up and RIH Locate free point @7955'2 full joints &pup below GLM#2. RIH with a 160 grain string shot. 09/28/2013 Rih and fire center of string shot @7910'. Make up RCT cutter and Rih correlate and cut @7910'Wireline depth. Rig down HES e-line. Circulate 270bbls and monitor well. POOH laying down completion assembly. Recover 246 joints. Top of fish at 7912'. 00:00 01:00 1.00 COMPZ WELLPF ELNE T Correlate&placed center of shot @7910'. Confirmed string shot fired. 01:00 03:00 2.00 7,905 7,915 COMPZ WELLPF ELNE T POOH with string shot, monitor hole on the trip tank. 03:00 09:00 6.00 7,910 7,910 COMPZ WELLPF ELNE T Add 20'more of lubricator. Make up RCT cutting assembly. RIH and correlate.Made cut @ 7910' with a solid jump on tubing. POOH with cutter and lay down equipment on rig. w=' Pacge7of17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:00 1.00 7,910 7,910 COMPZ WELLPF CIRC P Circulated with 270 BBLs of 12.6+ mud to condition mud. ICP=2460 psi , FCP=2000 psi @ 65BPM 10:00 11:00 1.00 7,910 7,910 COMPZ WELLPF ELNE P RD Eline while well on trip tank 11:00 12:30 1.50 7,910 7,880 COMPZ WELLPF OTHR P Cleaned and clear floor 12:30 17:00 4.50 7,880 4,455 COMPZ WELLPF PULD P POOH laying down production equipment. 17:00 18:00 1.00 4,455 4,450 COMPZ WELLPF CIRC T well was a little out of balance circulated bottoms up and hit with 5 BBL 12.9 dry job. 18:00 18:30 0.50 4,450 4,450 COMPZ WELLPF OWFF T monitor well for flow. 18:30 00:00 5.50 4,450 0 COMPZ WELLPF PULD P Continue to POOH with production string. Monitor hole on trip tank. 2"OD hole found below GLM#2 @7880.58' Lenght of cut joint 17.70' 246 joints laid down Top of fish @7912' 843'of fish left in hole including seal assembly lengrth. 09/29/2013 Rih with 4 11/16"overshot with 3 1/2"catch picking up 3 1/2"PH6 workstring. Circulate and condition mud while on bottom. Engage fish @ 7910'.Jar at 175k, 50k over up weight,straight pull to 280k. No movement. Attempt to establish circulation. Not possible. Get off fish and confirm workstring still free. Circulate hole clean, frac sand and formation sand over shakers. Re-engage fish and continue jarring and attempting circulation. 00:00 00:30 0.50 0 0 COMPZ WELLPF WWWH P Install Wear Bushing 6.375" ID 6 875"OD 8"Length Secure with 2 LDS 00:30 01:30 1.00 0 0 COMPZ WELLPF SEQP P Clear floor of extraneous materials. Bring remainder of fishing tools to the rig floor. Clear pipe shed of remainder of decompletion. 01:30 03:30 2.00 0 213 COMPZ WELLPF PULD T PJSM with Nordic and Baker fishing. Pick up#1 Fishing BHA w/4 11/16" overshot with 3 1/2"catch. Length of swallow 4.3' 03:30 06:00 2.50 213 2,770 COMPZ WELLPF PULD T PJSM Picking up 3 1/2" PH-6 workstring. Monitor hole on the trip tank while picking up pipe. Break Circulation every 2000'. 06:00 16:00 10.00 2,770 7,898 COMPZ WELLPF PULD T continue to Pick up 3.5 PH-6 hydril& RIH flushing tubular's every 2000 ft.. Tagged fill @ 7890 'reversed circulated 30 bbl's to complete final tubing flush. Time Logs •' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:00 2.00 7,898 7,910 COMPZ WELLPF CIRC T Broke circulation conventional @ 5 BPM @ 3500 psi circulated bottoms up and begin clean out. Up Wt. _ 125K Dn.Wt=90 K Dry wt./wet 90 K up, 72K dn. Perform pre-jarring derrick inspection. 18:00 20:00 2.00 7,910 7,910 COMPZ WELLPF FISH T Engage fish at 7910', confirm latch. Attempt to establish circulation. Pressure up to 1750 psi 1/4 BBL/min no circulation established. Jar at 175k and pull to 280, no movement. Continue to work and jar pipe,jar at 175k then straight pull to 280k re-cock jars at 75k.Alternate trying to establish circulation between jarring. No pipe movement and no circulation established. Rotate off of fish to verify work string still free at overshot. 20:00 21:00 1.00 7,910 7,910 COMPZ WELLPF CIRC T Circulate 6 bpm 3400psi. Frac sand and formation sand coming over shakers, Continue to circulate until shakers clean up. 1.5 bottoms up. 21:00 00:00 3.00 7,910 7,910 COMPZ WELLPF FISH T Re-engage fish at 7910',confirm latch. Attempt to establish circulation. Pressure up to 1950 psi 1/4 BBL/min no circulation established.Jar at 175k and pull to 280, no movement. Continue to work and jar pipe,jar at 175k then straight pull to 280k re-cock jars at 75k.Alternate trying to establish circulation between jarring. Still no pipe movement and no circulation established. Rotate off of fish to verify work string still free at overshot. 39/30/2013 Continue to jar and attempt to establish circulation. Still unable to free pipe or establish circulation. Release from fish. Circulate 2.5 bottoms up, recover formation sand and frac sand. Flow check well. Conduct post-jarring derrick inspection. Trip out of the hole racking back PH6 workstring. Lay down fishing assembly. Wash BOPE stack and well head. Pull wear ring. Set test plug.Test BOPE to 250/3,500psi witnessed by AOGCC representative Chuck Scheve. 00:00 02:00 2.00 7,910 7,900 COMPZ WELLPF FISH T Continue to jar and attempt circulation. No movement in pipe and no circulation established. Fish appears to be sanded off. Total of 73 Jar hits. Consult with town engineers and Baker fishing supervisor. Decision made to release from fish and proceed to operations to perform required weekly BOP test. �� , . Page 9 of 17 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:00 1.00 7,900 7,900 COMPZ WELLPF CIRC T Circulate 2.5 bottoms up. Rotate pipe 30rpm and reciprocate pipe. Pump 6 bpm @ 3500psi Frac sand and formation sand coming over shakers. 03:00 04:00 1.00 7,900 7,900 COMPZ WELLPF OWFF T Flow check well for 30min-Good Blow down the Top Drive. 04:00 05:00 1.00 7,900 COMPZ WELLPFSVRG T Perform rig post jarring inspection. 05:00 07:30 2.50 7,900 7,415 COMPZ WELLPF TRIP T Lay down top 2 joints to get on even stands. Then pull to 7415'. 07:30 11:00 3.50 7,415 7,415 COMPZ WELLPF RGRP T Slip&cut 84'drilling line. Inspect and adjust brakes. 11:00 13:30 2.50 7,415 5,200 COMPZ WELLPF TRIP T POOH with BHA#1 Monitoring hole fill on trip tank. 13:30 14:30 1.00 5,200 5,200 COMPZ WELLPF CIRC T codition mud 5 BPM @ 2100 psi 14:30 15:00 0.50 5,200 5,200 COMPZ WELLPF OWFF T Monitor well for flow. 15:00 18:00 3.00 5,200 213 COMPZ WELLPF TRIP T continue to POOH with BHA#1 Monitoring hole fill on trip tank. 18:00 19:30 1.50 213 0 COMPZ WELLPF TRIP T Rack back collars and lay down fishing tool assembly 19:30 20:30 1.00 0 0 COMPZ WHDBO WWWH T Swizel stick BOPE 20:30 21:30 1.00 0 0 COMPZ WHDBO WWSP T Pull Wear Ring, break down drill pipe joint with XO's on it. 21:30 22:00 0.50 0 0 COMPZ WHDBO BOPE T Set test plug, open IA, rig up BOP test equipment. Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:00 01:30 3.50 0 0 COMPZ WHDBO BOPE T Test BOPE to 250/3500psi witnessed by AOGCC representative Chuck Scheve. (1) Blinds, Stand pipe kill ,choke 4,11,12, 3.5 IF dart,TD Hyraulic UKV. Passed (2)BR,Manual Kill ,LKV TD, 3.5 IF FOSV, Choke 3,7,9,10 Passed (3)LPR,w/3 1/2"TJ 3.5 FOSV 8rd Passed (4)UPR,w/3 1/2"TJ HCR Kill, Choke 2,5,8. Passed (5) UPR w/3 1/2"TJ, HCR kill, Choke 1. Passed (6)UPR w/3 1/2"TJ, HCR Kill, Manual Choke. Passed (7)Upper variable pipe rams 3 1/2" TJ, Kill HCR, Choke HCR Passed Accumulator test. Initial-3000psi Actuate all BOP(function upper pipe rams 2x's for blinds)1925 psi First 200psi-18sec Final 3000psi-85sec Ann. closing time 14sec Upper Ram closing time 4sec. each Lower Ram closing time 3sec.each 4 N2 bottles @ 1800 psi Test Pit Gain loss and Flow show-Passed Tested Gas Alarm system: Rig Floor H2S Failed changed out sensor and retest Good 10/01/2013 Complete BOPE test,Pull Test plug, Rig up HES E-line. RIH and make cut @ 8127'. POOH, Lay down Eline equipment.Wait on BOT Hydra Pull Extenstion tool. P/U Hydra tool BHA, RIH 700'test. Good action @ 1.5 bpm/500psi. Continue to TIH with PH-6 workstring& fishing BHA 00:00 01:00 1.00 0 COMPZ WHDBO BOPE T Pull test plug and break down test joint. Set wear ring 6.375"ID 01:00 02:00 1.00 COMPZ WELLPF ELNE T Pick up dutch riser system and install for e-line 02:00 04:00 2.00 COMPZ WELLPF ELNE T Rig up HES e-line with full lubricator and pressure control. 04:00 12:00 8.00 8,127 COMPZ WELLPF ELNE T Run in hole with 160grain string shot. Made shot from 8124-8129' POOH. load&RIH with RTC cutter made cut @ 8127 ft. POOH with cutter RD HES 12:00 13:00 1.00 0 COMPZ WELLPF NUND T ND dutch Riser 13:00 15:00 2.00 COMPZ WELLPF OTHR T wait on Agitator from Baker __ pitgeltOt17 Time Logs a • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 19:30 4.50 0 285 COMPZ WELLPF TRIP T Upload tools into pipe shed. PJSM. Make up BHA#2 Baker 3 3/8" Hyda-tool Agitator with 2.25 spear assembly with 2.8 graple&RIH 19:30 00:00 4.50 285 5,600 COMPZ WELLPF TRIP T RIH 700'-test Hydra-tool,good action @ 1.5 bpm-560 psi.TIH with fishing BHA. 10/02/2013 TIH down to top of fish @ 7910'. P/U weight 125K, Circulate B/U with 12.6# @ 1.5 bpm, 2280 psi, 15#mud over shakers with B/U. Clean up well,engage fish, begin pumping with Temptress HydroPull Tool. Light vibration on pipe at surface, no luck recovering cut pipe. Max pull 250K. Stop pumping, continue to work string with 50K jarring hits. No luck, release spear,TOOH. RU Eline, RIH and cut tubing @ 8030'. POOH and RD Eline. 00:00 02:30 2.50 5,600 7,890 COMPZ WELLPF TRIP T TIH down to 7890' 02:30 03:30 1.00 7,890 7,890 COMPZ WELLPF CIRC T P/U two single joints,sit above fish and establish pump rates and pressures. P/U weight 125K, Dwn weight 90K. Start pumping 1 bpm, 1950 psi stable 1700 psi. 1.5 BPM, 2280 psi 2 BPM,2600 psi 14.2#coming back Pump until shakers clean up. 03:30 05:00 1.50 7,890 7,912 COMPZ WELLPF FISH T Set down into fish @ 7910'-Sit down 10K, P/U 150K, Fire jars. Set down to nuetral weight start pumping 2 BPM @ 1670 psi. Start working string with Agitator tool, light vibration on pipe at surface. Increase pump rate in stages 2.5 BPM, Max 3 BPM, 2200 psi. 05:00 06:00 1.00 7,912 7,912 COMPZ WELLPF FISH T Stop pumping,work jars 10 times. 175K, Fire-straight pull to 250K. No movement. Crew change. 06:00 09:30 3.50 7,912 7,912 COMPZ WELLPF FISH T Continue to work tubing jarring& agitatoring , pulling working from 110 K-225 K settting Jars @ 50 K over string wt. No movement in fish released spear 09:30 10:00 0.50 7,912 7,850 COMPZ WELLPF CIRC T condition mud/pump 47 bbls @ 3 bpm. 10:00 12:00 2.00 7,850 7,850 COMPZ WELLPF TRIP T Monitor well for no flow, derrick inspection 12:00 17:00 5.00 7,850 280 COMPZ WELLPF TRIP T TOOH with tubing string,function test Agitator tool 700'from surface. No movement-continue to TOOH. 17:00 19:00 2.00 280 0 COMPZ WELLPF PULD T Lay down BHA#2 19:00 00:00 5.00 0 0 COMPZ WELLPF ELNE T R/U dutch riser&Eline. RIH down to 8100'depth correction .5ft. P/U weight 2200#, Gamma stationed @ 8018'-tubing cutter 8030'. Good indication of cut, had to work string jars twice.-POOH with E-line. Inspect BHA @ surface,good firing indication, RD Eline. page,12.of 17 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/03/2013 24 hr Summary TIH with 3.5"Workstring, spear and jars. Circulate B/U, P/U weight 125K, Latch into fish @ 7910'.Try to break circulate through cut tubing, no luck. Begin jarring on string,jarring @ 175K, free pull to 275K. No luck recovering fish, release, condition well,flow check&derrick inspecxtion.TOOH&lay down BHA#3. Half of the swab cub torn on spear Graple also broken Missing 2"X 6 3/4"section. 00:00 01:00 1.00 0 0 COMPZ WELLPF RURD T Rig down Eline equipment, Dutch riser. 01:00 02:30 1.50 0 217 COMPZ WELLPF PULD T P/U Fishing BHA#3 with 2 15/16" ITCO spear, pack off and jarring assembly. 02:30 06:00 3.50 217 7,885 COMPZ WELLPF TRIP T TIH with BHA#3 06:00 07:30 1.50 7,885 COMPZ WELLPF CIRC T Establish SCr and circ B/U. 07:30 12:00 4.50 COMPZ WELLPF FISH T Engaged TOF @ 7910'working from 100K to 270 K straight pull. circulation @.25 BPM @ 1000 psi seal on spear appears to be cut. continue to work pipe with Jars and BS from 125K to 175 K&stright pull to 270K while circulating @.25 BPM /not circulating no movement in fish. released spear. 12:00 13:00 1.00 COMPZ WELLPF CIRC T circulate Bottoms up 13:00 13:30 0.50 COMPZ WELLPF OWFF T monitor well 13:30 15:00 1.50 7,910 7,950 COMPZ WELLPF OTHR T Laid down 2 jts complete derrick inspection(post jarring) 15:00 16:30 1.50 7,850 6,027 COMPZ WELLPF TRIP T POOH with BHA#3 16:30 18:30 2.00 6,027 6,027 COMPZ WELLPF CIRC T circulate hole volume due to well out of balance 18:30 21:30 3.00 6,027 287 COMPZ WELLPF TRIP T Continue TOOH. 21:30 23:00 1.50 287 0 COMPZ WELLPF PULD T PJSM-Lay down BHA-Swab cup torn. Half the cup missing the rubber. Graple is broken missing a 2"X 6 3/4"section 23:00 00:00 1.00 0 0 COMPZ WELLPF PULD T PJSM-P/I BHA#4 with 29 joints of 2 1/16"CS Hydrill pipe. 10/04/2013 TIH with 2-1/16"CS Hydrill clean out BHA.Tag fill @ 8030,8123,8313,8343'. Pump rate 5 bpm, 3600 psi. Work clean out BHA down to 8372', circulate B/U, returns of heavy mud and silica flour sand. TOOH with BHA#4. Inspect at surface, good. P/U BHA#5-4 3/4"shoe with 5.5"scraper assembly. 00:00 01:00 1.00 0 988 COMPZ WELLPF PULD T Complete P/U BHA#4. 01:00 06:00 5.00 988 7,920 COMPZ WELLPF TRIP T TIH with 3.5 PH-6 Workstring. Up weight 123K, Down 80K. Make Up working stand, break circulation, establish SCR. 1 bpm=710 psi/2 bpm= 1060 psi. Up weight pumping 97K, Down 75K. Slowly work string down into top of tubing stub pumping 4 bpm-2200 psi. 06:00 12:00 6.00 7,920 8,372 COMPZ WELLPF FCO T Tagged fill @ 8123'began clean out circulating convectional @ 5 BPM @ 3600 psi. Getting back heavy mud and silica flour sand . Clean out to 8372 Peg13c Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 8,372 COMPZ WELLPF CIRC T condition mud circulating well clean @ 8372 ft 13:00 13:30 0.50 COMPZ WELLPF OWFF T monitor well 13:30 17:30 4.00 8,372 1,000 COMPZ WELLPF TRIP T POOH with BHA#4(2 1/16"hydril) 17:30 19:30 2.00 1,000 0 COMPZ WELLPF PULD T Flow check and start laying down BHA. 19:30 22:30 3.00 0 210 COMPZ WELLPF PULD X Load and strap casing scraper/flush shoe run. PJSM-P/U BHA#5. 22:30 00:00 1.50 210 3,000 COMPZ WELLPF TRIP X TIH with 3.5" PH-6 Work string. 10/05/2013 TIH with 4 3/4"Burn over shoe and 5 1/2"Scraper assembly.Wash down from top of fish 7908'down to 7916'. Circulate B/U-wash over multiple times, TOOH with BHA#5. P/U packer assembly with 4 1/2"Poor boy overshot. 00:00 03:30 3.50 3,000 7,970 COMPZ WELLPF TRIP X TIH with BHA#5 03:30 06:00 2.50 7,970 7,915 COMPZ WELLPF WASH X P/U two single joints,establish SCR &free spin. P/U weight dry 130K. Slowly RIH down to top of fish pumping 3 bpm @ 1740psi.Tagged up 2ft early @ 7908.5'. Max. set down 5K. Cycle pipe and increase pump rate to try and get over fish, no luck. Slowly rotate over fish @ 30 rpm, 3 bpm @ 1450 psi. clean fill around fish down to 7915'.Work string up/down to ensure clean drift. 06:00 07:00 1.00 7,915 COMPZ WELLPF CIRC X Circulate 1.5X B/U pumping 5 BPM. 30 minute no-flow check. 07:00 12:00 5.00 7,915 0 COMPZ WELLPF TRIP X POOH with BHA#5 Scraper/wash over assembly. 12:00 15:00 3.00 0 COMPZ WELLPF PULD X Lay down D/C and BHA#5 Cleared tools 15:00 00:00 9.00 0 6,500 COMPZ RPCOM TRIP X Pick up Poor boy overshot, DS 2.812 Nipple, Baker 5.5 45-FA-36 packer, hydraulic setting tool.RIH on 3.5 PH -6 hydril tubing 10/06/2013 RIH with FA-1 Packer assembly with 4 1/2"Poor boy overshot. Lightly tag Top of 3.5"tubing stub @ 7908', turn pipe 1/4 to the left and slid over fishing neck. Set down @ 7915'P/U 1 ft and spot 10 bbls inhibited pill, drop ball followed by KWM. Set packer-good set, 50K over to release. Circulate out pill&slip and cut drill line.TOOH sideways with 3.5"workstring. Stop and condition mud @ 5000ft. Continue TOOH. 00:00 00:30 0.50 6,500 7,850 COMPZ RPCOM TRIP X TIH down to 7850'P/U weight 130K, down 85K. 00:30 03:00 2.50 7,850 7,914 COMPZ RPCOM PACK X Slowly RIH,tag top of fish @ 7908', continue in hole, shear @ 7911'5K down,go down to 7914'. P/U 1 ft and pump 10 bbls inhibited brine pill, Chase with KWF. Drop ball for J setting tool. Pump to bottom, pressure up to 2000 psi. Sit for 5 minutes,slowly P/U on string 10K over-then P/U 20K over to shear out 150K up weight. Bleed pressure zero. Top of packer @ 7870' POOH two joints. : y, ` � ��e14af17 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 7,870 7,820 COMPZ RPCOM CIRC X Circ B/U, sent out 25 bbls of commigled fluid to cutting tank. Once clean fluid around, stop pumping. Flow check,Well out of balance, pump 20 bbls dry job. 04:30 08:30 4.00 7,820 COMPZ RPCOM RGRP X Flow check, Slip and cut drill line. 08:30 10:00 1.50 7,820 7,000 COMPZ RPCOM PULD X POOH laying down 3.5 PH-6 work sring and setting tool. 10:00 11:30 1.50 7,000 COMPZ RPCOM CIRC X while pulling out of hole hole fill was not correct. stopped trip and circulated hole volume thru setting tools. ©4 BPM @ 2900 psi . 11:30 12:00 0.50 7,000 COMPZ RPCOM OWFF X monitor well 12:00 16:00 4.00 7,000 5,635 COMPZ RPCOM TRIP X Continue to lay down work string& setting tools filling tubing for pipe displacement do to fluid not falling past setting tools 16:00 19:00 3.00 5,635 5,600 COMPZ RPCOM CIRC X Condition mud do to hi Viis. issue 19:00 00:00 5.00 5,600 350 COMPZ RPCOM TRIP X Continue to TOOH, kicking out pipe every 1000'. 10/07/2013 Ran 3.5"completion with Baker PBR and KBH-anchor assembly down to 7863'. R/U Slick line, RIH to retrieve plug profile in DS nipple @ 7890'. Stacked out @ 7870'top of packer assembly. POOH to change SL BHA profile. 00:00 02:30 2.50 350 0 COMPZ RPCOM PULD X POOH and lay down Baker setting tool. BHA looked good. 02:30 16:30 14.00 0 7,863 COMPZ RPCOM PUTB P PJSM-P/U completion string as per tally/procedure. Sit 7ft off bottom. 16:30 23:00 6.50 7,863 7,863 COMPZ RPCOM SLKL XT PJSM Ru HES slick line to pull RH plug. Pressure test lubricator to 3000 psi at surface. RIH-cannot fall past 7780'. Start Pumping B/U down tubing to help clean up the hole. 2 bpm @ 1780psi. RIH tagging top of packer @ 7870', could not drift past, POOH, inspect tool. 23:00 00:00 1.00 7,863 7,863 COMPZ RPCOM SLKL XT RIH with second BHA-centrilzer's, & 10ft of stiff BHA. 10/08/2013 Unable to reach DS nipple with slick line BHA sue to tagging top of packer assembly @ 7870'. RD Slick Line, slowly move down 3.5"completion string to top of packer assembly. R/U SL-RIH reached DS nipples. Latch and pull profile, RIH with CA2 full body plug. Could not set, RIH with CA 2 plug and prong assembly. Latched, RD Slick Line,attempt to P/U 3.5"completion string. PBR anchor latched into packer. Complete setting PBR assembly. Sting out and test plug-failed @ 2850psi psi,sting back in and test packer. Passed. R/U SI. 00:00 02:00 2.00 7,863 7,863 COMPZ RPCOM SLKL XT Second SL BHA made it 3-4 ft further than first run 7873'. Could not P/U, wedged between upper and lower string.Worked BHA free, POOH. Lay down BHA&SL lubricator in pipe shed. e 4 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:00 03:30 1.50 7,863 7,870 COMPZ RPCOM PULD XT P/U weight 103K,down 70K, P/U 8ft pup, run 3.5"completion string down to top of PKR while rolling pumps 1/2 bpm. RIH 5 ft, saw pressure increase, stop movement. P/U 103K -RIH to mark. R/U slickline lubricator &test to 3K. 03:30 22:30 19.00 7,870 7,870 COMPZ RPCOM SLKL XT RIH with SL BHA#3, made it down to bottom. Latched into DS profile, worked free on fourth attempt. POOH. Fish @ surface. RIH with full body test plug, could not set in profile. POOH. P/U two pice setting tool, RIH Set in place, POOH,tattle tail showed to be set RIH w/prong, attempt to engage plug body,shear out setting tool. POOH. RIH w/ retrieving tool, recover prong. RIH w/prong on second set, good indications of tool setting.TOOH. Lay down lubricator 22:30 00:00 1.50 7,870 7,870 COMPZ RPCOM PACK XT P/U on pipe, 110K and did not break over.Work string to see if anchor has set, indication of set anchor. Pressure up to 2500 psi-P/U weight 125K,sheared. P/U additional 15 ft to sting out of PBR. Circ B/U. Close rams, P ressure up to 3000 psi. Plug not holding, broke over at 2850 psi. 10/09/2013 Continue to attempt to engage prong into plug body-Made multiple attempts, successfull test to 3000 psi with prong and seat. RD Slickline. Space out tubing, P/U and circ out mud with deep clean followed by Inhibited SW. Land tubing hanger, RILDS,Test tubing 3000 psi/30 minutes, IA 2500psi/30 minutes. Pressure up on SOV, partial shear @ 2250psi. No-flow test. Set BPV,test 1000 psi. NDBOPE. 00:00 01:00 1.00 7,870 7,870 COMPZ RPCOM CIRC XT Circulated B/U test packer 2000 psi on backside, 1500 psi on tubing. Good test.Test tubing to 2500 psi- leaked off.Test plug leaking by. Change out pup joint on rig floor. R/U Slickline. 01:00 14:00 13.00 7,870 7,870 COMPZ RPCOM SLKL P RIH with retrieving tool, pulled prong- indications look like it was not fully set. RIH with new setting tool. Engage prong and attempt to PT- failed. POOH w/prong, Drop prong and chase in hole with blind box. Engage prong into plug body, PU 40-ft and PT tbg to 3,000 psi for 5 minutes-good test. POOH and RD Slick Line. 14:00 16:00 2.00 7,870 0 COMPZ RPCOM PACK P MU Circ.equip and RIH, locate top of PBR, seen Pressure increase, bleed off and No-Go. PU 3-ft for space out, mark pipe and POOH. Add 6-ft pup jt and PU Hanger assy. RIH to Top of PBR. Page 16 Of 17 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:00 2.00 COMPZ RPCOM CIRC P PJSM, Pump 35 bbl sweep, chase with 50 bbl Deep Clean Pill,followed by 150 bbl SW, 100 Bbl CI SW and 16 bbl SW to clear lines. ICP= 2,280 @ 5 bpm, FCP=940 @ 5 bpm. 18:00 19:30 1.50 COMPZ WHDBO THGR P Lower TBG hanger to floor and Drain BOP stack. Land TBG hanger and RIH Lock down screws. 19:30 22:00 2.50 COMPZ WHDBO PRTS P Rig up floor iron to test tubing and IA. test 3.5"completion string to 3000psi/30 minutes. Bleed down to 1500 psi, pressure up IA,test packer 2500 psi/30 minutes. Bleed down string, pressure up on SOV broke over at 2250psi. Did not fully shear.Bleed off and make two more attempts, communication. 22:00 23:00 1.00 COMPZ WHDBO MPSP P Install BPV,test to 1000 psi. 23:00 00:00 1.00 COMPZ WHDBO CIRC P Wash and flush BOPE stack and lines. Prepare to NDBOPE 10/10/2013 NDBOPE, replace packing elements on hydril,top seals and rental rams. Install tree, pressure test and RDMO. ***Rig Release 07:00*** 00:00 04:00 4.00 COMPZ WHDBO NUND P Continue cleaning pits, Pull rams out of BOP companents, making breaks on BOPE stack to prepare for BOPE swap. ND BOPE. 04:00 06:00 2.00 COMPZ WHDBO PRTS P NU tree adapter,test 250/5000psi. Install Tree&test plug.test 250/5000 psi. Fluid pack with diesel. 06:00 07:00 1.00 COMPZ MOVE RURD P Empty pits, Held PJSM, Pull rig off well. Release Nordic Rig 3 @ 07:00 hrs. Fg+ 17f 9't • 214c D3 DATA LOGGED WELL LOG TRANSMITTAL vol-42013 M K BENDER To: Alaska Oil and Gas Conservation Comm. September 30, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIV OCT10 RE: Free Point Log, Tubing Cut Record, String Shot Record: 3K-23 AOGCC Run Date: 9/27/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook @halliburton.com 3K-23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22771-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. NEp DEC 1 li 201 Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: to Iv)b3 Signed: • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 1, 2010 • ~~~ ~ zoo Mr. Dan Seamount lr.~. ;4^ ~ ~ ~ : , ,_ ,~; _ ' ~ ~ r Alaska Oil & Gas Commission ._ 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we113K-23 (PTD 197-097). This report is for a tubing patch set in the tubing above the packer. Please call Martin Walters or myself at 659-7224 or M J Loveland / Perry Klein at 659- 7043 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~~~~ ~~.~ ~ ~ ~~1±! 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate ~ C~tt1~t" Alter Casing r Pull Tubing ~ Perforate New Fbol r Waiver ~ Time Extensiot5~?' ~i Change Approved Program r Operat. Shutdow n r Perforate ~ Re-enter Suspended Well ~° 2. Operator Name: 4. Current Well Status: 3ti Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory j-" 197-097 3. Address: Stratigraphic r Service ~ 6. API Number: ~ P. O. Box 100360, Anchorage, Alaska 99510 50-029-22771-00 7. Property Dgsignation: 8. Well Name and Number: ADL 25519, ALK 2555 ~ 3K-23 9. Field/Pool(s): '' Kuparuk River Field /Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 10462 feet Plugs (measured) None true vertical 6680 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8745 true vertical 0 feet (true vertucaq 6565 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 16 121 121' 0 0 SURFACE 4928 7.625 4970 4094' 0 0 PRODUCTION 10400 5.5 x 4.5 10434 6679' 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 8807-10432 True Vertical Depth: 6577-6679 Tubing (size, grade, MD, and TVD) 3.5, L-80, 8744 MD, 6565 TVD 3.5" Weathford tubing patch from 7865' - 7898' Packers & SSSV (type, MD, and TVD) SEAL ASSY @ 8745 MD and 6565 TVD NIPPLE - CAMCO 3 1/2" DS Nipple, 4.540" OD, 2.812" ID @ 506 MD and 506 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 13. Attachments 14. Well Class after proposed work: ~~ Copies of Logs and Surveys run Exploratory r Development r Service r 15. Well Status after work: Oi ~ GaS ~ WDSPL (- Daily Report of Well Operations GSTOR I- WAG (" GASINJ ~ WINJ ~ SPLUG ~ X 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. F~cempt: N/A contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone: 659-7224 Date 09/01/10 RBDMS SEP 0 7 2010 .' -~ Form 10-404 Revised 7/2009 ~ ~_/3~/G Submit Original Only 3K-23 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/15/10 SET WEATHERFORD ER PACKER IN 3.5" TUBING AT 7898'. 08/21/10 TEST WEATHERFORD ER PKR @ 7873' SLM TO 2500 PSI;PASS, SET WEATHERFORD 3! 1/2 SLICK STICK RECEPTACLE SPACER PIPE SNAP LATCH ASSEMBLE (24.17' OAL) @ 7873' SLM, TEST TO 2500 PSI;PASS, RAN WEATHERFORD ER PACKER SPACER PIPE SLICK STICK STINGER ASSEMBLE (8.42' OAL) ON WEATHERFORD SLICK PUMP, SET @ 7838' SLM TESTED TO 2500 PSI;PASS, COMPLETE. 08/21/10 CMIT TxIA- passed; Initial T/I/0= 1150/1150/80; Start T/1/0= 2560/2475/80; 15min. reading T/I/0= 2540/2450/80; 30min. reading T/I/0= 2530/2440/80 08/22/10 MITT passed; Initial T/I/0= 1150/325/70; Start T/I/0= 2550/350/80; 15min. reading T/I/0= 2475/370/80; 30min. reading T/I/0= 2460;370/80 08/31/10 RE-TIFL (passed ), T/I/0= 200/1240/580. SI well and X 2 lift gas, shot initial IA-FL @ 4834' station # 2. Stacked T, T/I/0= 1000/1040/340. Bled IA, T/I/0= 1000/360/250. Shot second IA-FL @ same location. 15 min post bleed T/I/0= 1000/360/250. 30 min post bleed T/I/0= 1000/360/250.45 min post bleed T/I/0= 1000/360/250. 60 min post bleed T/I/0= 1000/360/250. Summary Set 30' (mid element to mid element) 3.5" Weatherford ER patch assembly from 7865' - 7898'. TIFL passed following patch set. • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 20, 2010 .i= RE Packer Setting Record: 3K-23 Run Date: 8/15/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22771-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.w x Date: U ~ `. f , :~ar~ /g~~~~ dda~ Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3K-23 Run Date: 8/4/2010 August 5, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-23 Digital Data in LAS format, Digital Log Image file 50-029-22771-00 w, u~~,; f°`'~-~ ~y :~ tC}'~f 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 ' ~,~ r ~9 ~ ~~ 9 ~a Office: 907-273-3527 Fax: 907-273-3535 klinton.wood Date: AUG ~ ~ 2010 ~o . Signed: V ~~~ ~~ ~~- PrtoAcrive DiAyNOSric SeRVicES, INC. 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 Suite C •~ ~ :,,~~~ R I ~ ~:~ ~~ ~o ids' Anchorage, AK 99518 Fax: (907) 245-8952 1 J Caliper Report 26-Ju1-10 3K-23 1 Report / EDE 50-029-22771-00 2) 9~E~~~'~ Signed Print Name: - a~~ ~ ~o~o Date £~i1 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraae pn6saemorylog.corn WEesITE : ~nv~.snerrlor~log.com C:\Documen~ and Settings\Diane Williams\Desktop\Tiatismit_Conoco.docx Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3K-23 Log Date: July 26, 2010 Field: Kuparuk Log No.: 7433 State: Alaska Run No.: 1 API No.: 50-029-22771-00 Pipet Desc.: 3.5" 9.3 Ib. L-80ABM EUE Top Log Intuit.: Surface Pipet Use: Tubing Bot. Log Intuit.: 8,759 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage -nspection COMMENTS This caliper data is tied into the D-Nipple @ 8,428' (Driller's Depth). This tog was run to assess the condition of 3.5" tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing appears to be in fair to poor condition, with a maximum recorded wall penetration of 67% in joint 261 (8,342'). Wall penetrations ranging from 20% to 67% wall thickness are recorded in 42 of the 286 joints logged. Recorded damage appears as corrosion and isolated pitting acting on areas of apparent wear from 7,880' to _8,740'. No significant areas of cross- sectional wall loss or I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: Corrosion (67%) Jt. 261 @ 8,342 Ft. (MD) Apparent Wear /Isolated pitting (57%) Jt. 254 @ 8,117 Ft. (MD) Corrosion (54%) Jt. 260 @ 8,327 Ft. (MD) Isolated pitting { 50%) Jt. 259 @ 8,283 Ft. (MD) Isolated pitting (47%) Jt. 252 @ 8,067 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 13%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer: Wm. McCrossan Analyst: C. Lucasan Witness: C. Fitzpatrick RroFtctive Diagnostic Serv[ces, Inc. P.O. Box 135°, Seafford, TX 77497 Fhone: (281) yr {888j 555-9085 Fax: (281j 555-1359 E-rr~aii: PD9~cur~'ierrtorylog.c©r~t Prudhoe Bay Field Office Phane: (907; 559-2387 Fax: (907) 659-23].4 Correlation of Recorded Damag Pipe 1 3.5 in (21.8' - 8759.3') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 3 K-23 Kuparuk ConocoPhillips Alaska, Inc. USA July 26, 2010 ® A pprox. T ool De viation ^ A pprox. Borehol e Profil e 25 781 1567 2347 GLM 1 3161 3938 ~ ~ . GLM 2 4718 ~ a 5537 GLM 3 6351 GLM 4 7132 GLM 5 7986 GLM 6 272.3 8759 U 5 0 1 00 Da mage P rofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 272.3 I 25 50 `_ _, x L 75 100 125 v E ~ Z 150 'o 1i5 200 i i 25t) I • • PDS Report Overview ~.~. ~-~,,. Body Region Analysis Well: 3K-23 Survey Date: July 26, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 ABM EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (%wall) ® penetration body =- -< metal loss body 300 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 286 pene. 0 88 163 28 7 0 loss 25 260 1 0 0 0 Damage Configuration (body ) 150 100 5ci I 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 156 138 18 0 0 0 Damage Profile (% wall) p~ penetration body _ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 272.3 Analysis Overview page 2 • PDS REPORT JOINT TABI Pipe: 3.5 in 9.3 ppf L-80 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date • 1LATION SHEET 3K-23 Kuparuk ConocoPhillips Alaska, Inc USA July 26, 2010 Joint No. Jt. Depth (Ft.) I'~~n. U{~sE~( {Ins.) Pen. Body (Ins.) Pen. °o al~~t;il loss °~Q~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 22 a 0.01 E~ i 2.97 PUP 1 25 t1 0.04 14 4 2.94 Shallow ittin . 2 56 i) 0.03 1 1 _' 2.95 3 87 a 0.03 I ~) 2.95 4 119 i) 0.02 9 _' 2.94 5 150 U 0.01 :.' ? 2.95 6 182 a 0.03 L~ 2.94 Shallow ittin . 7 213 a 0.01 ~1 2.95 8 245 i) 0.02 ~~ 2.92 9 276 ~) 0.01 5 ~ 2.93 10 308 !~ 0.03 13 ~' 2.94 Shallow ittin . 11 339 t'~ 0.02 ~~ 2.94 12 371 i i 0.02 9 2.96 13 402 i - 0.01 4 I 2.94 14 434 ~ ~~ 0.02 ~) 2.93 15 465 ii 0.02 7 I 2.95 15.1 496 i) 0 U (1 2.81 Camco DS Ni le 16 499 U 0.01 5 I 2.94 17 529 r ~ 0.02 ~? 2.94 18 561 i ~ 0.01 4 i 2.95 19 592 t~ 0.02 ~) 2.92 ( 20 623 (~ 0.01 4 . 2.92 21 655 i? 0.03 1i; 2.95 22 686 t) 0.01 4 2.93 23 718 (~ 0.02 £i 2.95 24 749 i ~ 0.01 d _' 2.95 25 781 t t 0.03 1 it 2.95 26 813 O 0.03 I Z 2.93 Shallow _ ittin . 27 843 (! 0.01 2.93 28 875 0.02 ~~ 2.95 29 907 i ~ 0.01 ~ 2.95 ~~ 30 938 i) 0.01 t, 2.91 31 970 ;? 0.01 2.94 32 1001 i? 0.01 i ? 2.93 33 1033 O 0.01 - I 2.94 34 1064 n 0.03 11 2.93 35 1096 t) 0.02 6 2.93 36 1127 0 0.03 10 _' 2.94 37 1159 (~ 0.02 9 2.94 ~ 38 1 190 t ~ 0.02 £3 2.94 39 1222 ~.~ 0.02 ~> 2.95 40 1253 c? 0.02 9 ~ 2.93 41 1284 (' 0.02 9 1 2.95 ~ 42 1316 1 i 0.02 9 ? ~ 2.95 43 1346 i i 0.02 9 ? 2.94 44 1378 ~ i 0.01 4 I 2.95 45 1409 i? 0.02 ~i _' 2.93 ~ 46 1441 ( 0.02 ~) ? 2.94 47 1472 (~ 0.03 13 2.93 Shallow ittin . 48 1504 +> 0.02 9 2.94 ~ _ Penetration Body Metal Loss Body Page I I • PDS REPORT JOINT TABS Pipe: 3.5 in 9.3 ppf L-80 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date, • CATION SHEET 3 K-2 3 Kuparuk ConocoPhillips Alaska, Inc. USA July 26, 2010 Joint No. Jt. Depth (Ft) I'c~n. UI_isc~l (In~.l Pen. Body (Ins.) I'en. ",~ Mcl ~I I c~~ti °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1535 (? 0.03 11 ~ 2.95 50 1567 ~? 0.03 11 ? 2.93 51 1598 i? 0.01 6 ? 2.95 52 162 8 0.01 I 2.94 53 1660 i ` 0.03 I ~ 2.96 54 1691 ?? 0.02 ti ~' 2.93 ~ 55 1723 ~ ~ 0.04 1 7 2.95 Shallow ittin . 56 1754 U 0.03 12 2.94 57 1786 ~~ 0.03 11 _' 2.93 58 1816 i) 0.02 9 ,' 2.93 59 1847 i? 0.02 9 ? 2.93 60 1879 ~:? 0.03 1 ' 2.95 Shallow ittin . 61 1910 i? 0.03 1 _' 2.93 62 1941 ~ i 0.02 ~? 2.93 63 1972 i? 0.04 14 2.94 Shallow ittin . 64 2004 ~~ 0.03 11 ? 2.94 65 2035 t) 0.02 ~? I 2.95 66 2065 t? 0.03 11 ' 2.93 67 2097 ~) 0.02 ~) I 2.95 68 212 8 u 0.01 2 2.94 69 2160 I) 0.02 ~) ~ 2.93 70 2191 ~ ~ 0.02 '? 1 2.94 71 2222 i i 0.02 '? 2.94 72 2253 (~ 0.02 ~~ I 2.96 73 2285 i? 0.03 11 2.94 74 2316 ti 0.02 ~> 2.95 75 2347 t i 0.01 > ~ 2.94 76 2377 ~.? 0.03 1C~ _' 2.96 77 2409 0.03 I ~ ~' 2.93 Shallow corrosion. 78 2439 t ~ 0.02 9 ? 2.93 79 2470 i 1 0.02 ~? 1 2.94 80 2500 i~ 0.01 4 I 2.94 81 2531 ~? 0.02 ~? 2.94 82 2563 t) 0.03 I+) 2.96 83 2594 U 0.01 4 I 2.96 84 2626 !~ 0.02 2.95 85 2657 l? 0.04 1 t: 2.93 Shallow ittin . 86 2689 n 0.03 10 2.95 87 2 7 19 a 0.01 ~1 2.96 ~ 88 2750 ~? 0.02 ~i 2.94 89 278`2 ! ~ 0.03 13 2.95 Shallow ittin . 90 2813 U 0.02 9 ? 2.93 91 2844 l) 0.03 11 ' 2.94 92 2874 ti 0.02 9 _' 2.94 92.1 2905 ~.? 0.02 9 I 2.96 PUP 92.2 2920 U 0 U u N A CLM 1 Latch @ 11:00 92.3 2927 t? 0.01 4 _' 2.95 PUP ~ 93 2942 t? 0.03 13 ? 2.94 Shallow ittin . 94 2974 t ~ 0.03 1 t? ? 2.94 95 3005 !! 0.03 ! '• _' 2.92 Shallow ~iuin . __ Penetration Body Mctal Loss Body Page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LU.: 2.992 in Country: Survey Date: • 'CATION SHEET 3 K-2 3 Kuparuk ConocoPhillips /\laska, Inc USA July 26, 2010 Joint No. Jt. Depth (Ft.) i'c~n. lli~sc~f ii~~..l Pen. Body (Ins.) Pen. % Meal Ic~ss `;o Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 3035 0.05 ~'U ~' 2.95 Isolated ittin . 97 3066 t! 0.04 15 ~' 2.95 Shallow ittin 98 3098 i i 0.03 l U Z 2.95 99 312 9 ~) 0.03 I Z i 2.95 100 3161 U 0.03 13 _' 2.92 Shallow ittin ~ _ 101 3191 U 0.03 12 ' 2.94 102 3223 n 0.03 11 I 2.94 103 3254 t? 0.02 ~) -1 2.92 104 3286 U 0.03 1U 2.95 105 3317 i) 0.04 la 2 2.92 Shallow ittin . 106 3349 t! 0.02 ~> 2.93 107 3381 (1 0.03 1> :' 2.93 Shallow ittin . 108 3411 U 0.03 i t 2.93 Shallow ittin . 109 3443 i) 0.03 I 0 2.95 110 3474 ~! 0.04 15 2.92 Shallow corrosion. 111 3506 i) 0.04 17 2.95 Shallow ittin . 112 3537 U 0.02 ~~ ~~ 2.94 113 3569 U 0.03 1I 2.94 114 3600 U 0.03 11 2.94 115 3631 U 0.02 9 Z 2.93 116 3661 +! 0.04 13 3 2.93 Shallow ittin . 117 3692 (! 0.03 ! 3 2.92 Shallow ittin . 118 3723 t! 0.04 17 2.94 Shallow ittin . 119 3751 (~ 0.03 12 _' 2.93 120 3782 U 0.03 11 ' 2.93 121 3814 U 0.03 1 ~' 2.94 Shallow ittin . 122 3846 U 0.03 12 2.93 123 3877 t! 0.03 11 ~ 2.91 124 3906 t> 0.03 I3 2.94 Shallow ittin . 125 3938 i1 0.03 1::1 2.91 Shallow ittin . 126 3969 ~? 0.03 11 2.93 127 4001 (! 0.03 1 Z _' 2.93 128 4032 U 0.04 17 ~' 2.92 Shallow ittin . 129 4064 (! 0.04 I G ~' 2.93 Shallow ittin . 130 4095 (~ 0.03 11 2.93 131 4127 a 0.04 18 2.93 Shallow ittin . 132 4157 t) 0.04 1;; 2.92 Shallow ittin . 133 4186 l) 0.04 1( 2.92 Shallow ittin . 134 4218 (1 0.03 f 3 2.91 Shallow ittin ~ 135 4249 it 0.05 I ~~ 2.93 Shallow ittin . 136 4280 ~'! 0.03 12 2.94 137 4312 (! 0.04 1(; 2.92 Shallow ittin . 138 4343 !? 0.03 13 _ 2.93 Shallow ittin . 139 4375 (? 0.05 18 2.93 Shallow corrosion. 140 4406 ! ~ 0.04 1 2.92 Shallow ittin 141 4437 0.04 i=1 2.91 Shallow itlin . 142 4467 U 0.03 i _' 2.93 Shallow ittin . 143 4499 U 0.03 13 5 2.92 Shallow ittin . 144 4530 ~_! 0.03 l _' 2.93 Shallow ittin . 145 4561 (! 0.04 !!; 2.92 Shallow ittin . _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 ABM LUF Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: • ~ LATI O N SHEET 3 K-2 3 Kuparuk ConocoPhillips Alaska, Inc USA July 26, 2010 Joint No. Jt. Deplh (Ft.) 1'~~n. t llx<~t jlns.) Pen. Body (Ins.) Pc°n. "/~ Ntetal I c>ss `;~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 146 4592 t) 0.04 10 2.93 Shallow ittin . 147 4624 i) 0.04 14 2.94 Shallow ittin ' 148 4655 n 0.04 17 2.93 Shallow ittin - 149 4687 i! 0.03 12 2.93 Shallow ~ittin ' 150 4718 i? 0.03 13 2.94 Shallow ittin - 151 4750 t? 0.03 I.3 Z 2.92 Shallow ittin . 152 4781 i) 0.03 i 1 _' 2.95 152.1 4812 t7 0.01 `"i I 2.96 PUP 152.2 4828 U 0 i? t) N A GLM 2 Latch @ 4:30 152.3 4834 t! 0.07 Wit; ~ 2.92 PUP Isolated ittin . 153 48.50 i t 0.03 11 i 2.93 154 4Y,79 t? 0.04 15 "2.93 Shallow ittin . 155 4910 i) 0.04 16 ~ 2.92 Shallow ittin . 156 4941 t? 0.06 ~?_> 2.92 Isolated ittin . 157 4973 i! 0.04 . ` ~1 2.88 Shallow ittin . 158 5004 i? 0.04 1 ~' 2.92 Shallow ittin . 159 5036 i` 0.03 I S 2.93 Shallow ittin . 160 5067 U 0.04 I ~ 2.91 Shallow ittin . 161 5098 t? 0.04 i 4 2.91 Shallow ittin . 162 5129 0.03 , 3 l 2.91 Shallow ittin . 163 5159 i? 0.04 16 ? 2.92 Shallow ittin . 164 5191 .? 0.05 2C~ 2.90 Shallow ittin 165 5223 l? 0.03 1 ~i 2.90 Shallow ittin . 166 5254 (? 0.04 14 -1 2.93 Shallow ittin . 167 5286 tt 0.04 I S 2.91 Shallow ~ittin . 168 531 7 ~? 0.03 1 ' 2.91 Shallow ittin . 169 5348 i? 0.04 1 ~ 2.92 Shallow ittin . 170 5380 ~' 0.03 I ' 2.92 171 541 1 ~ ~ 0.04 i ; 2.92 Shallow ittin . 172 5443 i. 0.03 Li 2.91 Shallow ittin Lt. De osits. 173 5474 ~! 0.04 16 -1 2.92 Shallow ittin . 174 550b ~! 0.03 10 2.92 175 5537 t! 0.03 l:? 2.92 Shallow ittin . 176 5568 ~ 1 0.04 15 _' 2.93 Shallow ittin . 177 5598 U 0.03 13 2.91 Shallow ittin . 178 5630 t! 0.03 13 2.93 Shallow iitin . 179 5661 tl 0.04 16 2.92 Shallow ittin 180 5693 ~? 0.04 1~ 2.93 Shallow ittin . 181 5724 a 0.06 1 - 2.91 Corrosion. 182 5756 i! 0.03 1 C? 2.93 183 5787 n 0.03 I U 2.91 184 5817 ~ ? 0.03 1 1 2.92 185 5847 ~~ 0.03 I ' 2.93 Shallow ittin . 186 5879 !! 0.04 1-: 2.94 Shallow ittin . 187 5910 t i 0.03 1 1 2.92 188 5942 U 0.03 i t) 2.93 189 5972 U 0.05 2~? 2.92 Isolated ittin . 190 6005 t? 0.03 12 2.94 191 6035 0 0.03 1? 2 2.90 192 6066 +! 0.04 I ~~ ~ 2.93 Shallow ittin . _, Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • 'EATION SHEET 3 K-2 3 Kuparuk ConocoPhillips Alaska, Inc USA July 26, 2010 Joint No. Jt. Depth (Ft.) I'cn. i 11x~~! tln~.! Pen. Body (Ins.) Pen. `% Metal I ~~~~ ," Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 193 6097 t! 0.03 11 2.94 194 6128 t! 0.03 t 1 ? 2.94 195 6160 ~! 0.04 15 2.91 Shallow ittin . 195.1 6191 i) 0.01 i 2.96 PUP 195.2 6206 !! 0 t? t? N A GLM 3 Latch ~ 3:00 195.3 6211 (? 0.07 ?;' 2.93 PUP Isolated ittin . 196 6229 a 0.04 15 2.90 Shallow ittin . 197 6260 i) 0.03 l ? Z 2.92 198 6292 t! 0.05 18 _' 2.93 Shallow ittin . 199 6323 t? 0.03 I:i ~ 2.93 Shallow ittin . 200 6351 ~! 0.04 1 ~ 2.93 Shallow ittin - 201 6383 U 0.05 ~!('` _' 2.92 Isolated ittin . 202 6415 U 0.02 ~) 2.94 203 6446 t? 0.04 16 1 2.92 Shallow corrosion. 204 6477 i) 0.03 11 I 2.94 205 6507 t! 0.03 I:? 2.93 Shallow ittin 206 6539 U 0.03 11 _' 2.94 207 6569 U 0.03 1 'I ? 2.94 208 6601 t? 0.04 1 S _' 2.94 Shallow ittin 209 6633 t! 0.05 I fS ? 2.91 Shallow ittin . 210 6663 t! 0.04 15 s 2.93 Shallow ittin . 211 6693 t! 0.03 1 _? ? 2.94 Shallow ittin . 212 672_', (i 0.04 1 ~ ~ 2.89 Shallow corrosion. 213 6756 (~ 0.03 1:• ~ 2.93 Shallow ittin . 214 6786 i! 0.04 17 7 2.90 Shallow corrosion. 215 6818 !! 0.03 12 r, 2.94 216 6850 !! 0.04 I:i 2.91 Shallow ittin . 217 6881 !! 0.03 l ! 2.93 Shallow ittin . 218 6911 i! 0.03 11 2.94 219 6941 t! 0.04 1 > 2.90 Shallow ittin . 220 6974 U 0.03 i 3 _' 2.94 Shallow ittin . 221 7006 t? 0.04 1 ~; 2.95 Shallow ittin . 222 7037 Q03 1l) 2.94 223 7069 ? 0.03 11 2.92 224 7100 a 0.04 17 2.92 Shallow ittin . 225 7132 t! 0.03 II 2.94 225.1 7161 t~ 0.03 Ls i 2.97 PUP Shallow ittin . 225.2 7175 n 0 U tl N A CLM 4 Latch @ 6:00 225.3 7182 i? 0.08 rt! 3 2.95 FUP Isolated ittin . 226 7198 !! 0.11 41 1 2.91 Isolated ittin . 227 7229 ~' 0.05 1 t 2.95 Shallow ittin . 228 7258 i! 0.03 1 ', 2.94 Shallow ittin . 229 7290 U 0.03 I s _' 2.96 Shallow ittin . 230 7321 t! 0.05 2U ~4 2.92 Shallow ittin . 231 7353 (! 0.04 16 4 2.94 Shallow ittin . 232 7384 O 0.04 14 ? 2.90 Shallow -ittin Lt De osits. 233 7416 '.? 0.05 tt; 2.91 Shallow ittin . 234 7448 U 0.05 20 2.94 Isolated ittin . 235 7479 U 0.05 ~(~ 2.91 Shallow ittin . 236 7511 t1 0.05 1(1 2.92 Shallow corrosion. __ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI Pipe: 3.5 in 9.3 ppf L-80 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date, • 1LATION SHEET 3 K-2 3 Kuparuk ConocoPhillips Alaska, Inc. USA luly 26, 2010 Joint No. Jt. Depth (Ft.) !'~°n. tll;`t~t (Ir~c! Pen. Body (Ins.) Pen. `;% Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (%wall} 0 50 100 237 7543 i l 0.04 17 :' 2.93 Shallow ~ittin . 238 7574 U 0.04 14 ~' 2.93 Shallow ittin . 239 7604 it 0.04 1 ~; ~ 2.90 Shallow ittin - 240 7637 ~) 0.05 1~~ y 2.93 Shallow ittin - 241 7668 ! ~ 0.04 l i; ~ 2.93 Shallow ittin - 242 7699 i } 0.03 13 Z 2.91 Shallow ittin . 243 7730 i ~ 0.05 1 ~j I 2.91 Shallow ittin . 244 7763 t ~ 0.04 I i 9 2.92 Shallow ittin . 245 7792 t) 0.05 1~1 ~ 2.92 Shallow ittin LGDe osits. 246 7824 tr 0.05 1f~ i 2.92 Shallow ittin Lt. De osits. 246.1 7856 +~ 0.04 1 ~ _' 2.9.2 PUP Shallow ~ittin Lt. Deposits. 246.2 7871 U 0 O t1 N A GLM 5 Latch a. 12:00 246.3 7876 (1 0.10 3~) 2.96 PUPA agent Wear. Isolated ittin . 247 7893 t? 0.08 1 ~' -t 2.92 A agent Wear. Isolated ~ ittin . 248 7924 tr 0.05 ~'1 ~ 2.91 Isolated ~~ittin . 249 7956 t) 0.07 'ii - 2.93 Isolated ittin Lt. De osits. 250 7986 t) 0.05 -'~.~ 2.93 Shallow ittin . 251 8015 U 0.08 >~ -1 2.92 Isolated ittin . 252 8045 t1 0.12 4i` 3 2.93 Isolated ~ittin . 253 8076 U 0.06 ?1 2.93 Isolated ittin . 254 8109 t} 0.14 i; 5 2.93 A agent Wear. Isolated ittin . 255 8139 t? 0.09 ~ C. 2.93 Corrosion. 256 8170 U 0.09 ~` ? 2.93 Corrosion. Lt. De osits. 257 8203 t) 0.09 2.94 ,A agent Wear. Isolated ittin . 258 8234 ~ ~ 0.08 ~~(> 2.94 Isolated ittin . 259 8265 ti 0.13 S('~ 2.93 Isolated -ittin . 260 8296 +) 0.14 5=s (, 2.93 Corrosion. 261 8328 ~? 0.17 i,T i 2.93 Corrosion. 261.1 8360 i! 0.11 ~~. 2.96 PUPA agent Wear. Isolated ittin - 261.2 8374 t? 0 U ~ ~ N A GLM 6 Latch ~ 1 1:00 261.3 8382 t? 0.07 28 2.96 PUPA agent Wear. Isolated ittin - 262 8397 i) 0.09 34 -t 2.91 A agent Wear. Isolated ittin . 262.1 8428 t) 0 0 +~ 2.75 Camco D Ni le 263 8430 t) 0.08 31 =t 2.89 Corrosion. Lt. De osits. - 264 8461 t) 0.08 iCr 4 2.82 Isolated ittin Lt De osits. 265 8493 t) 0.10 4tr E~ 2.83 A agent Wear. Isolated ittin Lt. De osits. -- 266 8523 ~~ 0.09 i% 4 2.84 A arentWear. Isolated ittin Lt De osits. ~~ 267 8554 r) 0.09 35 ~) 2.84 Corrosion. Lt De osits. - 268 8586 U 0.08 31 C; 2.81 Corrosion. Lt. De osits. 269 8617 ti 0.07 Z1; t, 2.81 A agent Wear. Isolated ittin Lt. De osits. 270 8648 0.09 ;(~ ~) 2.79 Corrosion. Lt. De osits. 271 8678 i) 0.08 3:~ t, 2.80 Corrosion. Lt. De osits. 272 8709 U 0.09 ;a 2.80 A agent Wear. Isolated ittin Lt. De osits. 272.1 8742 t) 0 U U 3.00 Baker GBH-22 Locator with 10' Seals 272.2 8746 t? 0.07 26 ? 2.79 PUP Corrosion. Lt. De osits. 272.3 8759 !) 0 0 ~~~ N A l-FL Penetration Body Metal Loss Bodv Page 6 • s, PDS Report Cross Sections ~. Well: 3K-23 Survey Date: July 26, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 2~1 Tubin 3.5 ins 9.3 f L-80 ABM EUE Anal st: C. Lucasan Cross Section for Joint 261 at depth 8341.78 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 95 Tool deviation = 67 " Finger 5 Penetration = 0.169 ins Corrosion 0.17 ins = 67% Wall Penetration HIGH SIDE = UP Cross Sections page 1 • PDS Report Cross Sections ~. -- ~ ,, Wcll: 3K-23 Survey Date: July 26, 2010 Field: Kuparuk Tool Type: UW MEC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Dubin 3.5 ins 9.3 f L-80 ABM EUE Anal st: C. Lucasan Cross Section for Joint 254 at depth 8117.05 ft Tool speed = 43 Nominal ID = 2.992 - -- Nominal OD = 3.500 Rcrnaining wall area = 95 Tool deviation = 61 " Finger 9 Penetration = 0.144 ins Apparent Wear /Isolated pitting 0.14 ins = 57% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ~~ ~ KUP ~ 3K-23 ConoeoPhillip s ~ I At tributes An le & MD TD ,I ,., ! Wellbore APINWI 500292277100 FlNtl Name We115[a[us Intl l°) KUPARUK RIVER UNIT PROD 89.97 ND IRKS) 9,152.52 AQ e[m IRKS) 10,462.0 ••• Comnerx SSSV: NIPPLE K2S Ippm) 225 Date 12/11/2009 Arrwtabon Last WO: Entl Date K8-Grtl nt) 41.02 Rig Release Dale 7/2/1997 Well Confi '. - bK-23 7/18 /20IC ' . ~ qM schematic- Aauo, Amotation Last Tag' Depth pll®) 8,760.0 Fntl Die Arrrotatlon Last MOtl By 10/6/2008 Rev Reason: GLV C/O Imosbor F.ntl Dale 7/18/2010 ~ Casio Strin s Casiny D escription 5[dng W Ml S[dng ID M1 Top (RKB) Set Depm (RKB) Se[ Depm (ND) IM(e) Stdng Wt (lbslft) Stdn Gatl g e String Top Thrd 'r~ ' "{"' - CONDUCTOR 1 6 15.062 0.0 121.0 121.0 62.58 H-00 ceNCUCTeR. 111 SURFACE 7 51 8 6.750 0.0 4.970.0 4,094.5 29.70 L-80 PRODUCTION 51/ 2 4.653 0.0 8.756.0 6,567.4 15.50 L-80 PRODUC TION 4 1! 2 3.833 8.756.0 10,434.0 6,679.2 12.75 L-80 NIPPLE. soe Tubin Strin s Nbing Description Stdng OD llnl String ID Iln) Set Depm Top Im(BI (ftK8) Set Depth (ND) (ftK8) Strirg WI QbsM) Stnn Dratl g e String Top Thrtl TUBING 3 1/ 2 2.992 0.0 8.756.0 6,5674 9.30 L-80 ABM EUE Other I n Hole A ll Jewel :Tubin Run 8 Retrievabl Fish etc. r.AS uFr, _,_, ~ Top (RKB) Top Depm IND) del Top Intl (') Description Comment RrnDate IDpnl 506 505.8 2.95 N IPPLE Camm'DS' Nipple 7!6/1997 2.812 2,927 2,598.4 44.43 G AS LIFT BSTlAXT/1/GLV/T-1/.1 56/1 29 31 Commem: STA 1 3/1/2007 2.880 4.834 3,994.4 42b5 G AS LIFT BSTlAXT/1/OVR-1/.25/1 Comment: STA 2 7/17/2010 2.880 6,210 4.995.7 43.47 G AS LIFT BST/AXT/t/DMV(f-1 ///Comment STA3 3/1/2007 2.880 7,179 5,69R.5 43.22 G AS LIFT BST/AXTl1/DMVIT-1///Comment STA4 7/6/1997 2.880 7.873 6,180.2 50.72 G AS LIFT BST/AXT/1/DMVIT-1///Comment: STA5 4/19/2006 2.880 r.AS uFT 8,375 6.447.5 65.60 G AS LIFT BST/AXT/1/DMY/T-1///Comment: STAG 12x/2007 2.880 . n.asn - 8,428 6.468.5 67.71 N IPPLE Camco'D' Nipple NU GO 7/611997 2.750 8.744 6.564.9 78.11 L OCATOR Baker'GBH-22' w! 10' Seals 7!6!1997 3.000 8,769 6,569.9 78.75 C EMENTER Halliburton'ES' w/ BTC coon. 7/6!1997 4.600 euRFncE 8.780 6,572.1 78.79 P ACKER Baker External Csg PACKER 7/6/1997 4.600 4 az: 8,807 6,577.3 79.19 P C RE-PERF SG 60 deg. phasing 7/6/1997 7/6/1997 3.833 10,423 6,678.7 87.45 F ISH FISH LOST2COLLETS IN WELL FROM TI LATCH 3/1/2007 0.000 GAS uFT. s z1o DURING 3/1/2007 GLV INSTALLATION . Pertora tions & Slots lop lmtBl etm (RKB) ToD ITVD) 1~6) Btm IND) lie) Zone Date sna Dens (~~- 7ype Comment 8,807 10.432 6.577.3 6.679.1 A A -5, A-0, A-3, -2. 3K-23 716/1997 24.0 IPERF 60 deg. phasing; Pre-perforated 4 1/2 CSG Stimula tions & Treatments GAS LIFT 7.t7~ Mn7op lrgx etm lop Depth emttom Depth Depm (RKB) Depth (RKB) (ND) (RKB) (ND) IRKeI Type Date ComneM 8,807.0 10,432.0 6,577.3 6,679.1 A -SAND FRAC 1/6!2007 A SAND FRAC -PLACED 323,000# 16/20 CARBOLITE IN FORMATION, 10 PPA ON THE PERFS. PLACED 100 % OF DESIGN, FLUSHED TO COMPLETION. OM LIFT. 7.873 i,HS L IFT 8.375 N I~FLE,8428 LOCATOR. 8 ld4 PRODUCTION, ~.7sc CEMENTER. PACKEP.. 8.780 PRE-PEP,F CSG, 8 807 (PERF, 8,807-10,432 A-SAND FRAC, 8.807 FISH, 10.423 PROCUCTION, 10 A34 TD, 10,462 • • Page 1 of 1 Regg, James B (DOA) ~ ~q~~c ~~ From: NSK Problem Well Supv [n1617@conocophillips.com] o Sent: Monday, July 12, 2010 5:00 PM ~~~ ~ 1I~~'f To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 3K-23 (PTD 197-097) Report failed TIFL Attachments: 3K-23 schematic.pdf Tom, Jim, Guy t `1?-~ Kuparuk gas lifted producer 3K-23 (PTD ~9~99~}fiailed a diagnostic TIFL on 07/11/10. The TIO prior to the test was 150/1070/700. A leaking GLV is suspected. lickline will troubleshoot the leak and repair if possible. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 7/15/2010 KRU 3K-23 PTD 1970970 7/12/2010 TIO Pressures Plot TII/0 Plot - 3K-23 1400 1200 1000 _ 800 a 600 400 200 o ~ 12-Apr-10 25-Apr-10 08-May-10 21-May-10 03-Jun-10 Date 16-Jun-10 29-Jun-10 200 150 a E as 100 Y O t v 50 0 . ... KUP ~ 3K-23 A ~} / ` ~ Well Attnbutes °~a~~~~~~'~` ~ TD ? x An le 8 MD _ 1 I I VJ IIb re APl/UWI , 00292277100 _ _ _____ FI Id Name Well Statua Inc! (°) MD (RKB) Act Btm (RKB) KUPARUK RIVER UNIT PROD 89.97 9,152.52 10,462.0 ' Comment H25 (ppm) Date Annotation End Date KB-Grd (R) Rig Release Data I SSSV: NIPPLE 225 1211/2009 Last WO: 41.02 72/1997 :.:., ~, s nemanc a Iva! - - - -- - A t ,t -~-~~ Depth (RKB) End Date Annot hon Last Mod By End Date Last i 8 ,760 0 10/62008 Rev Reason: GLV C/0 Imosbor 4/182010 ---_- -- ~ Casing Strings, - " _ String OD St 'rag iD Set Depth Set Depth (TVD) eu,ng Wt Siring ' . ~.~aing Description lira! On) Top (ttKB) (RKB) (RKB) (Ibalft) Drode String Top Thrd ~ ~ CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 coruoucroR. ~ SURFACE 7 5/8 6.750 0.0 4,970.0 4,094.5 29.70 L-80 tzt _ f'. PRODUCTION 51/2 4.653 0.0 8,756.0 6,567.4 15.50 L-80 PRODUCTION ' ] ~ 4 1/2 3.833 8,756.0 10 434.0 6,679.2 12.75 L-80 NIPPLE, 506 '~ j] trln ng_ S ~ - --1 ~ t OD St In I 9 g D -"-_ _ -...__- - ' - _ Set D pth Set Depth (ND) Strang Wt St Ing S o Tubi 9 P (l I (In) Ic~~(RKD) (flKB) (ttKB) (Ibslh) G de St glop Thrd _- _ ~ TUBING i .. .. ABM EUE ~ 8 756 0 6,567-4 9.30 L 80 0.0 Other In Hole All Jewel : Tubin ( ry . -- Run 8 Retrievable, Fish, etc. 9 - ~ Top Depth - ---- ---- GAS LIFT, (ND) 2,927 - _ Top (RKB) (RKB) 506 505.8 - ~-' Top Intl (°) Description 2.95 NIPPLE Comment Run Date ID (in Camco'DS'Nipple 7/6/1997 2.81 ~ ~: 2,927 2,598.4 44.43 GAS LIFT BST/AXT/1/GW/f-1/.156/1293/ Comment: STA 1 3/12007 2.88 4,834 3,994.4 42.55 GAS LIFT BST/AXT/1/OV/i-1/25//Comment: STA2 4/10/2010 2.88 6,210 4,995.7 43.47 GAS LIFT BST/AXT/1/DMY/T-1/// Comment: STA 3 3/1/2007 2.88 7,179 5,698.5 43.22 GAS LIFT BST/AXT/1/DMY/T-1///Comment: STA 4 7/6/1997 2.88 7,873 6,180.2 50.72 GAS LIFT BST/AXT/1/DMYIf-1///Comment: STA 5 4/19/2006 2.88 8,375 6.447.5 65.60 GAS LIFT BST/AXT/1/DMY/T-1/// Comment: STA 6 12!7/2007 2.88 GAS LIFT, , _ a,e3a "- 8,428 6,468.5 67.71 NIPPLE Camco'D' Nipple NO GO 7/6/1997 2.75 8,744 6,564.9 78.11 LOCATOR Baker'GBH-22' w/ 10' Seals 7/6/1997 3.00 ~` 8,769 6,569.9 78.75 CEMENTER Halliburton'ES' w/ BTC coon. 7/6/1997 4.60 8,780 6,572.1 ~_ 78.79 PACKER Baker External Csg PACKER 7/6/1997 4.60 SURFACE, 4,970 k', ~ 8,807 6,577.3 79.19 PRE-PERF 60 deg. phasing 7/6/1997 7/6/1997 3.83 e CSG 10,423 6,678.7 87.45 FISH FISH LOST 2 COLLETS IN WELL FROM T1 LATCH 3/12007 0.00 Gras uFT, DURING 3/12007 GLV INSTALLATION s.zto _ I Perforations 8 Slots - _ _ _ -~-- shot Top (RKB) Btm (RKB) lop (ND) Btm (ND) (flKB) (ttKB) Dens Zone Date (ah^~ Type Comment 8,807 10,432 6,577.3 6,679.1 A-5, A-4, A-3, 7/6/1997 24.0 (PERF 60 deg. phasing; Pre-perforated 4 1/: A-2, 3K-23 CSG Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (RKB) (RKB( (RKB) (RKB) Tyne Date nr~ - ITE IN FORMATION, 10 PPA ON THE PLACED 100% OF DESIGN, FLUSHED TO GAS LIFT. ~ 7,573 i t i% GAS LIFT, 8.375 1 F NIPPLE, 8,428 ~ - I r LOCATOR, 8,744 PRODUCTION, 8,756 CEMENTER, 8,769 PACKER, 8,780 PRE-PERF ~ ~-~ ~ , u"a_a a~ C6G, 8,807 (PERF, 8.807-10,432 A-SAND FRAC. ~` _1 y - ( l:l~ a 8,807 I ( FI6H, 10,423 r f j PRODUCTION, i 10,434 ~ 1 TD, 10,462 . ~ ConocoPhillips Alaska . ,JUL 0 3 2007 () CI. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 IQ7-0Q7 sCANNED JUL 0 5 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4¡~ M.J. Loveland ConocoPhì11ips Well Integrity Supervisor e----/ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 1 C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1 C-127 201-114 18" none 18" na 12 7/1/2007 1C-133 201-077 16" none 16" na 8.5 7/1/2007 1 C-190 203-003 27" none 27" na II.i 10 6/24/2007 ~ ¡;'!iii_, }}i,¡;i,iiHii ~ 6" none 6" na 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 ~:' .¿-c2..p'-é)7 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION . RECEIVED , ~~ as ;nn<i f' D D Plug Perforations D Stim~late [] I 1. Operations Performed: Abandon Repair Well Other Afia¡,. .' "Jrage Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory D 197-097/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22771-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 34' 3K-23 8. Property Designation: 10. Field/Pool(s): ADL 25519,'ALK 2555 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 1 0462' , feet true vertical 6680' . feet Plugs (measured) Effective Depth measured 10424' feet Junk (measured) true vertical 6679' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' ." SUR. CASING 4939' 7-5/8" 4970' 4094' PROD. CASING 8716' 5-1/2" y.. 8756' 6567' PROD. CASING 1678' 4-1/2" 10434' 6679' Perforation depth: Measured depth: 8807'-10432' SCANNED FEB o 1 2007 true vertical depth: 6577'-6679' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8756' MD. Packers & SSSV (type & measured depth) pkr= BAKER EXTERNAL CSG PKR pkr= 8780' Cameo 'OS' nipple @ 506' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8807'-10432' MD Treatment descriptions including volumes used and final pressure: pumped 323000# of 16/20 carbolite 13. Representative Daily Average Production or Injection Data Oil·Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 264 1364 963 -- 179 Subsequent to operation 780 385 2161 -- 223 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development [] Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[] GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Guy Schwartz @ 265-6958 p~inted Name ./' Guy SC~. ; Title Wells Group Engineer Signature é.~.:S: h;:;{.... Phone Date /- (;{. 3 - (Y"1 Prenared bv Sharon AI/sun-Drake 263-4612 F"m /f Rev;~d 0412004 '-tJRIGINAL RBDMS 8F! ,IAN 3 ~~~ "dÞ I· Z-~·PJ ~ °1Ï~íbj JAN 2 <1 2007 REPORT OF SUNDRY WELL OPERA TIONSAlaska û;, & G c on . 3K-23 Well Events Summary . DATE Summary 12/23/06 BRUSH & FLUSH TOP 3 GLM'S, PULLED GLV @ 2927' RKB, IN PROGRESS 12/24/06 PULLED OV @ 6210' RKB, ATTEMPT TO PULL GLV @ 4834' RKB, IN PROGRESS 12/25/06 ATTEMPT TO PULL GLV @4834' RKB, IN PROGRESS 12/26/06 ATTEMPT TO PULL GLV @4834' RKB, IN PROGRESS 12/28/06 PULLED LGLV FROM STA # 2 @4834' RKB. SET DGLV'S IN STA # 1 @ 2927' RKB AND 4834' RKB. ATTEMPTED TO SET CAT STANDING VALVE BUT ENCOUNTERED SCALE @ 8250' SLM AND ABLE TO WORK DOWN TO 8350' SLM ( UNABLE TO GET BY). MADE ONE ATTEMPT TO POCKET BRUSH STA #3 @ 6210' RKB, BUT UNABLE TO GET TOOLS TO SIT DOWN. 12/29/06 BRUSH AND FLUSHED SCALE IN TBG. FROM 7949' SLM TO 8420' SLM (D-NIPPLE @ 8424' RKB / 8405' SLM). SET CAT STANDING VALVE @ 8424' RKB. MADE TWO ATTEMPTS TO RUN POCKET BRUSH IN STA # 3 (UNABLE TO LOCATE OR SIT DOWN) PUMPED 105 BBLS OF DIESEL DOWN TBG., UP lA, AND DOWN FLOWLINE @2.15 BBLS PER MIN. MADE TWO ATTEMPTS TO SET DGLV IN STA#3. 12/30/06 SET DGLV IN STA # 3 @ 6210' RKB ( USED KJ, DECENTRAILlZER, AND 31/2 OK-1 W/ ARM ORIENTATED TO 3 O'CLOCK). MIT TBG TO 3500 PSI ( PASSED). MIT IA TO 3500 PSI ( PASSED). PULLED CAT STANDING VALVE @ 8428' RKB (( JOB COMPLETE )). 12/31/06 Initial A sand Frac pumped. Placed 65380 Ibs of #16/20 prop in the formation w/6# PPA @ the perfs using 50# XL Gel. Frac was only partially completed due Schlumberger equipment failure. One of the driver engines on the PCM failed and was no longer able to transfer gel. Ended frac and flushed with 75 bbls of diesel down to 8700'. 1/5/07 Removed solids and gel to 10,423.7' CTMD using diesel & diesel gel. Well freeze protected to 3,500' RKB with diesel. Heavy solids to surface. Ready for re-frac. Injected 2 BPM @ 882 PSIIWHP. 1/6/07 PUMPED A SAND FRACTURE TREATMENT. PLACED 323,000# 16/20 CARBO LITE IN FORMATION, 10 PPA ON THE PERFS. PLACED 100% OF DESIGN, FLUSHED TO COMPLETION. 42 BBLS DIESEL IN WELL. 1/11/07 Performed FCO to bottom of liner @ 10,424' CTMD. 1: 1 or better returns through job, heavy frac sand in returns, washed GLM's while POOH. 1/13/07 TAGGED FRAC SAND IN TBG AT 8235' SLM. PULLED DVs FROM 6210' AND 4834' RKB. ATTEMPTED SET GLVs AT SAME. IN PROGRESS. 1/14/07 SET OV AT 6210' RKB. PULLED DV FROM 2927' RKB. ATTEMPTED SET GLV AT 2927' RKB. IN PROGRESS. 1/15/07 SET GLV AT 2927' RKB. BLEED PRESSURE FROM lA, CONFIRM VALVES SET. . . ConocoPhillips Alaska, Inc. KRU 3K-23 API: 500292277100 Well Tvpe: PROD AnQle @ TS: 68 deQ @ 8430 SSSV Type: Nipple OriQ Completion: 7/2/1997 Anole t1ìJ TD: 87 dea t1ìJ 10462 NIP (506-507. Annular Fluid: Last W/O: Rev Reason: FRAC. FCO. GLV C/O OD:3.5OO) Reference Loa: Ref Loa Date: Last UPdate: 1/20/2007 Last Taa: 10424' CTMD TD: 10462 ftKB Last Taa Date: 1/11/2007 Max Hole Anale_9153 Description Size Top Bottom TVO Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 121 121 62.58 H-40 MandrelNalve SUR. CASING 7.625 0 4970 4094 29.70 L-80 1 (2927-2928, PROD. CASING 5.500 0 8756 6567 15.50 L-80 PROD. CASING 4.500 8756 10434 6679 12.75 L-80 Size Top Bottom I TVD Wt Grade Thread Gas Lift 3.500 I 0 I 8756 65;: . 9.30 , L-80 I IÎÏÎ EUE MandrelNalve 2 (4834-4835. Interval TVO Zone Status Date rvoe 8807 " 10432 6577 - 6679 I, UNIT .I 11625124 I 7/6/1997 IPERF I?O "on nh~o;nn' Pre-perforated I^ r ^ '> 41/2C:SG Gas Lift I Interval Date Tvpe Comment MandrelNalve 8807 - 10432 1/612007 A-SAND FRAC A SAND FRACTURE TREATMENT. PLACED 323,000# 16/20 3 (6210-6211, CARBOLlTE IN -UKMA IIUN, 10 PPA ON THE PERFS. PLACED 100% OF I TO COMPLETION. St MO TVD Man Mfr Man Type VMfr V Type VOO Latch Port TRO Date Run Vlv Gas Lift Cmnt ¡ndrel/Dummy 1 2927 2599 BST AXT GLV 1.0 T-1 0.156 1320 1/15/2007 Valve 4 2 4834 3994 BST AXT GLV 1.0 T-1 0.188 1358 1/13/2007 (7179-7180, OD:4.750) 3 6210 4996 BST AXT OV 1.0 T-1 0.250 0 1/14/2007 4 7179 5699 BST AXT DMY 1.0 T-1 0.000 0 7/2/1997 5 7873 6180 BST AXT DMY 1.0 T-1 0.000 0 4/19/2006 Gas Lift 6 8375 6447 BST AXT DMY 1.0 T-1 0.000 0 12/7/2007 ¡ndrel/Dummy Valve 5 I Depth I TVD I Tvpe I Description 10 (7873-7874. 8807 6577 PRE-PERF 60 deg. phasing 7/6/1997 3.833 OD:4.750) CSG Gas Lift Depth TVD Type Description 10 ¡ndrel/Dummy 506 506 NIP Camco 'DS' Nipple 2.812 Valve 6 8428 6468 NIP Camco '0' Niople NO GO 2.750 (8375-8376. 8744 6565 LOCATOR Baker 'GBH-22' w/1 0' Seals 3.000 OD:4.750) 8769 6570 CEMENTER Halliburton 'ES' w/ BTC conn. 4.600 8780 6572 PKR Baker External Csa PKR 4.600 NIP (8428-8429, OD:3.5OO) LOCATOR (8744-8745, OD3.5OO) TUBING (0-8756. OD:3.5oo. ID:2.992) CEMENTER (8769-8770, OD:4.653) PKR I (8780-8781. OD:4.653) A-SAND ~ ~ FRAC '> <: (8807-10432) <;; <Ç " « e e Mike Mooney Wells Group Team Leader Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 April 13, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3K-23 (APD # 197-097) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3K-23. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ),1. t¡f~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells . . ,-' ¡"':1:--~\~~': ~~;,L#!¡:ftF'\:~''ê>·· M M/skad e RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONsAlaska e ¡lPR 1 8 2006 Cons. Commission .' 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate 0 Other 'tJ' ,'~ t1\Hv Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Opera!. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 197-097/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22771-00 7. KB Elevation (ft): 9. Well Name and Number: Rig RKB 41', Pad 34' 3K-23 8. Property Designation: 10. Field/Pool(s): ADL 25519, ALK 2555 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10462' feet true vertical 6680' feet Plugs (measured) Effective Depth measured 10413' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structu ral CONDUCTOR 80' 16" 121' 121' SUR. CASING 4029' 7-518" 4970' 4094' PROD. CASING 8715' 5-1/2" 8756' 6567' PROD. CASING 1678' 4-1/2" 1 0434' 6679' Perforation depth: Measured depth: 8807'-10432' true vertical depth: 6577'-6679' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8756' MD. RBDMS 8Ft APR 1. 8 2006 Packers & SSSV (type & measured depth) pkr= BAKER EXTERNAL CSG PKR 8780' Cameo 'OS' nipple @ 506' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8807'-10432' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 142 739 597 -- 170 Subsequent to operation 239 664 965 -- 175 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader d7)¿;~ Signature /I. ~I ~ Phone Date Prena""d bv Sharon AI/sun-Drake 263-4612 '- Form 10-404 Revised 04/2004 Submit Original Only e 3K-23 Well Events Summary e Dttmstart Summaryops 03/31/0608:00 AM Pumped 36 bbls of 12% HCI Acid for tubing wash, followed by 42 bbls of seawater to place Acid at top of perfs. 04/02/0608:00 AM RIH w/ 3.5" tbg scraper to top GLM, could not get past. RIH with 2.6" HEJW penetrator nozzel to 8756' CTMD. (Heavy scale from 8220' to 8756'). 04/03/0608:00 AM RIH with 2.0" Spiral jet, performed FCO to hard tag @ 10,413 CTMD. MEMORANDUM. TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser,-~.~~I~D~ Commissioner Tom Maunder, P. i. Supervisor DATE: May 18, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K -Pad May 18,2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The ^OGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc CC; NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Ol~rator: ,?h,!nips Alasl~, , Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: Date: Field/Unit/Pad: Kupamk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3K-01 1861010 65 70 50 P P ' OIL , 3K-03 1861030 65 70 55 P P OIL 3K-06' 1861240 65 70 50 P P OIL 3K-09A 1861740 65 60 54 P P OIL 3K-10 1861630 651 70 52 P P OIL 3K-11 1861640 65 70! 50 P p " 'OIL 3K-14 18613'70, 65 60 58 P ' P' ' ' OIL 3K-16 1861390 65 70 "70 P "p ' OIL , , 3K-i7 1861520 65 60 35 -P P OIL ~~;~:~?:~ 1970970 65 70 58 P P OIL 3K~24 1982490 65 70 50 P P 'Oil, 3K-27 1970460 65 70 52 P 4 OIL 3K-32 1970760 65 70 55 P P ' OIL 3K-35 1971090 65 70 50 P P _ O~_L- , , Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% ~ ~0 var Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 M PL A T E W E IA L UNDER T H IS M ARK ER PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 07/19/99 RUN RECVD 97-097 DIR SRVY S~~PERRY 0-10462 08/01/97 97-097 8075 ~PERRY MPT/GR/EWR4/ROP 2-4 08/20/97 97-o97 M~D SRvY ~:Sp~,R~y 0-~0462. 08/29/97 ~-0~ ~S~/~W~-T~ ~0~-~0 F~ 0~/~/~ ~-o~s~ ~ ~ss ~oo-~oo ~/~/~ ~ o~o~ ~-o~~ co~ c~ ~o-~o ~/~/~ ~ o~~ _ Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis & description received? yes no Are well tests required? ~ yes no Received? yes no Well is in compliance Initial COMMENTS T D BOX -- il. Type of Request: Abandon STATE OF ALASKA ALt-~._ A OIL AND GAS CONSERVATION COry, .~SION APPLICATION FOR SUNDRY APPROVALS Suspend _ Operation Shutdown Re-enter suspended well Alter'casing Repair well __ Change appFoved program__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1347' FSL, 318' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 301' FNL, 1662' FEL, Sec. 35, T13N, R9E, UM At effective depth At total depth 1512' FSL, 792' FEL, Sec. 26, T13N, R9E, UM Plugging __ Pull tubing __ 5. Type of Well: Development X Exploratory -- Stratigraphic __ Service Ti--me extension Stimulate Variance PErforate -- Other X -- -- 6. Datum elevation (DF or KB) 41' RKB Annular Injection feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-23 9. Permit number 97-97 10. APl number 50-029-22771 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: (approx) Effective depth: (approx) Casing Structural Conductor Surface measured true vertical measured true vertical Length 80' 4939' 10462' 6680' 10432' 6679' Size 16" 7.625" Intermediate Production Perforation depth: 8703' 1690' 5.5" X 4.5" measured 8807'-10432' true vertical 6577'-6679' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 8756' Packers and SSSV (type and measured depth) Baker External csg Pkr @ 8780', No SSSV feet feet feet feet Plugs (measured) None Junk (measured) ORIGINAL Cemented Measured depth True vertical depth 4.5 CY High Early 121' 515 sx AS III LW 4970' & 430 sx Class G & 60 sx AS I 210 sx Class G 8744' tapered string 10434' 121' 4095' 6565' 6680' 13. Attachments Description summary of proposal Detailed operation program BOP sketch __ Contact Brian Robertson at 265-6034 with any questions_ ---~OT test, surface cement details and casing--Eetail sheets __X 14. Estimated date for commencing operation December 10, 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed ~..~,._~'.~_ ~. ~/--'~_~_ Title Kuparuk Team Leader / FOR COMMISSION USE ONLY 15. Status of well classification as: Gas Suspended _ -- ! · Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance__ Mechanical Integrity Test Subsequent-form require 10- Approved by the order of the Commission ~Jet.~l[~ ~,~,l, .j0hTiS~.~,il Commissioner Form 10-403 Rev 06/15/88 IApprovd j~o_,~ ~.~ ~ I -,.,7_,,-;¢ / SUBMIT IN TRIPLICATE CASING / TUBING ! LINER DETAIL 7-5/8" Surface Casin~7 ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 3K-23 KRU DATE: 6/3/97 I OF I PAGES # ITEMS 42 Jts Joint 'B' Joint 'A ' 68 Jts I Jt 2 Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Landing Ring - Parker Rig #245 Fluted Mandrel Casing Hanger 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A - Baker Locked Halliburton ES Cementer 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A - Baker Locked 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing Halliburton Landing Collar 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing Gemoco Float Collar 41.20 1.75 1796.02 41.27 2.40 43.10 2911.64 1.34 42.54 1.33 85.43 1.50 Bottom of Shoe ==>> TD = 498O' MD (10' Rathole', 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing Gemoco Float Shoe BakerLock to top of Baffle Collar joint (LC). (Use 25 Centralizers: ' & 'B') Instafl a Bow Spring Centralizer on each of the first 23 joints, Install a Bow Spring Centralizer on each of Joints 'A' & 'B'. a Stop Ring & install Centralizers in the middle of Jts #1,2,3 & 'A Run 'ES' Cementer & BakerLock Jts 'A' & 'B' between Jts #71 & #72. Run Fluted Casing Hanger on Top of Jt #113 41.20 42.95 1838.97 1880.24 1882.64 1925.74 4837.38 4838.72 4881.26 4882.5g 4968.02 4969.52 Leave 17 Jts in the Shed (Jts #114 thru #130). Remarks: String Weights with Blocks: 225K# Up, 150K# Dn, 76K# Blocks. Ran 115 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections (National = BOL 2000). Made up connections to the base of the triangle stamp. Parker Ri~7 #245 Drillin9 Supervisor: Don E. Breeden ARCO Alaska, Inc. Well#: Casing Size 7-5/8" Centralizers Mud Spacer Lead Cement Tail Cement Displacement Cementing Details 3K-23 Field: Kuparuk River Unit Date: 6/3/9 7 Hole Diameter KOP&Anglo I ShoeDepth LCDepth I °/owashout 9-7/8" 700' - 44° 4970' 4837' State type used, intervals covered and spacing 25 Gemoco Bow Spring Centralizers: One on each of 1st 23 joints, 1st 3 on stop rings in middle of float joints; One on stop ring in middle of joint on each side of ES Cementer Weight 9.5 Ppg Gels before 4/5 stage collar. PV(prior cond) 19 Gels after 3/5 Type Water Type I Mix wtr temp AS III LWI +_75° F Additives: Class G + 3.5% D44 50% D124+ 1.5%S1 PV(after cond)IYP(prior cond) 16 I 21 Total Volume Circulated Stg 1:698 Bbls / Volume I 50 Bbls / 20 Bbls No. of sacks 120 sx / 395 sx} YP(after cond) 8 Stg 2:246 Bbls Weight 10.5 ppg Weight 8.34 ppg Yield 4.42 cfs + 0.6% D46 + 30% D53 + 1.5% D79 + ClassG&ASl +_75° F J430 sx/60 sx 15.8 / 15.7 1.15 / 0.93 Additives: Stage 1: Class G + 0.266% D29 + 0.2% D46 + 0.3% D65 + 1% S1 Stage 2: Arctic Set 1 Rate(before tail at shOe) 6.8 BPM Reciprocation length 12'- 15' Theoretical Displacement 222 Bbls / 86 Bbls Calculated top of cement 1880' & 4619" Rate(tail around shoe) 6.8 bpm Reciprocation speed _+3O FPM Remarks: Actual Displacement 226 Bbls / 93 Bbls Str. Wt. Up 225K# Str. Wt. Down 150K# Str. Wt. in mud 126K# I CtP Bumped plug I FIoats held 1145, 6/3 Yes Yes Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage 1:5 Bbls water, test lines 3500 psi, 50 Bbls water, Mix & Pump 94 Bbls Lead, drop bottom bypass plug, Mix & Pump 78 Bbls Class G Tail, drop top shut-off plug, pump 10 Bbls Tail on top of plug, pump 20 Bbls wash-up water, rig pump 196 Bbls mud & bumped plug to 1000 ps~, floats held, 1st Stage ClP @ 0925. Stage 2' Open ES Cementer at 1880' @ 3100 psi, circulate annulus clean, circulated out 34 Bbls cement & contaminated mud, circulated 246 Bbls. Pump 20 Bbls water, Mix & Pump 10.5 ppg Lead cement until getting good 10.5 ppg cement returns, pumped 311 Bbls Lead, switch to Tail pump 10 Bbls AS 1, drop top closing plugl pump 20 Bbls wash-up water, rig pump 73 Bbls mud & bumped plug, pressured up & closed ES Cementer @ 1400 psi, pressure up & hold 2000 psi, OK, check floats, floats held, 2nd Stage CIP @ 1145, 6/3/97. Full returns throughout. Reciprocated until _+80 Bbls Lead cement around shoe. Cement Company IRig Contractor Isignature Dowell Parker Rig #245 Don E. Breeden CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: 3K-23 KRU Date: 6/4/97 Don E. Breeden 7 5/8, 29.7#, L-80, ABM-BTC Casing Size and Description: Casing Setting Depth: Mud Weight: 8.4 4970' TMD 4094' ppg EMW = Leak-off Pressure (PLO) 0.052 x TVD EMW = 1700 psi/(0.052 x 4094 ft) + 8.4 ppg EMW = 16.39 ppg (F.I.T. - did not leak off) TVD + MW 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 3OO 20O 100 0 i ? ! "-.,-._._._,._._._...l 10' rAinule ~n I --m-- LEAK-OFF TEST ~ CASING TEST i --!-, 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 STROKES CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: 3K-23 KRU Date: 6/5/97 Don E. Breeden 7 5/8, 29.7#, L-80, ABM-BTC Casing Size and Description: Casing Setting Depth: Mud Weight: 10.5 4970' TMD 4094' TVD .PPg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD EMW = 750 psi/(0.052 x 4094 ft) + 10.5 ppg 6-3/4" Hole @ 7964' MD, 6238' TVD EMW -- 14.0 ppg at Shoe EMW = 12.8 ppg @ 6-3/4" Depth 1300 1200 1100 IOO0 9OO 800 LLI n- 700 /~ 600 5OO 400 300 2OO lO0 I\ [ t I.;;" ! i ! ! ,'~/! ! I ! i 10 Mil~ute Shu'-in · I .·· / " ~/ ! ~ { I ,." I/ I I I ; ~ I ." /~ ! I =-- LEAK-OFF TEST - - -o- -- REFERENCE LINE 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 STROKES 1 2/1 0/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11632 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 3F-5 ~ '~ - c~ ~ PRODUCTION PROFILE 971124 I 1 3F-10 ~'~ ~ c,~-~l PRODUCTION PROFILE 971119 I 1 , , 3F-15 ~.z~ ~3 L[,I~--.- INJECTION PROFILE 971014 I 1 3G-03 ~Lp- /~- PRODUCTION PROFILE 971016 I 1 3G-03 ',J.~ PRODUCTION PROFILE 971 026 I 1 3H-01 '~"~ - I~ O PRODUCTION PROFILEW/DEFT 971030 I 1 3 K-22 ~ ~7 - O ~ I ,l, ~ ~ PRODUCTION PROFILE 9711 2 6 I 1 3 K-23 ~ -7 - O~/~ PRODUCTION PROFILE 971 1 27 1 1 30-20 C~.'--/- ©c/~- GAS LIFTSURVEY 971026 I 1 13Q-08A ~--/~--~'"~ BRIDGE PLUG SE'i-riNG RECORD 971015 I 1 3R-18 ~;~.- (~l-~ GAS LIFT SURVEY 971025 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 9/22/97 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11366 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1B-8A ~"'/- /Io~. CEMENT BOND LOG 970811 1 1 1Q-08A ~'7 - O ~ '5 STATIC BOTTOM HOLE SURVEY 970729 I 1 1R-34 qz~_ /~-~. GAS LIFT SURVEY 970810 I 1 3F-12 ~- ,~ ~ [~,tC_._~ INJECTION PROFILE 970619 I 1 31-02 '~,~- ~>o % l~t (--- INJECTION PROFILE 970818 I 1 31-06 ~ c/._ O~'~ {)~ ¢.... INJECTION PROFILE 970708 1 1 3K-23 ~ ~ - Oc1~ CEMENT EVALUATION LOG W/GR 970629 I 1 3 K-23 ~ CEMENT BOND LOG W/GR 97 062 9 I 1 3K-26 ~f "1 - © ~"~ STATIC BHP LOG 970723 1 1 3M-17 <~"7 - O~c~ GAS LIFTSURVEY 970707 I 1 3 M-23 ~ '~ -' I ~-J GAS LIFT SURVEY 970704 I 1 3N-03 ~(o- O1(~ (.JL, I C.~. INJECTION PROFILE 970703 1 1 3N-7 '~ (~ - O~ PRODUCTION PROFILE 970702 I 1 3N-7 ,4/ DEFT LOG 970702 1 I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: RECEIVED SEP 2 9 '1997 Alaska Oil & Gas ¢8~s. Com~$sion /~chora§e 9/3/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11312 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1. A- 17 ............ Cil~.- ~ ~ t PRODUCTION PROFILE W/i')EFT 970625 1 1 3H-07 ~,~. ©'-'1 Cl INJECTION PROFILE 970621 I 1 3K-23 c~ --/_. ~) cj --j STATIC BOTTOM HOLE 970629 I 1 3N-13 ~ L~ - t~ INJECTION PROFILE 970624 I 1 3R-19 ~- (~H Lp GAS LIFT SURVEY 970624 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Gas Cons. Commiss{o~"- Anchorage WELl, LOG TRANSMITTAL To: State of Alaska August 27, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3K-23, AK-MM-70157 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3K-23: 2" x 5" MD Gamma Ray Logs: 50-029-22771-00 2" x 5" TVD Cranuna Ray Logs: 50-029-22771-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia AUG 2 ? 199F ~aska Oil & Gas Cons. C0mmi~ ~ch.c~age 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I~! I L_I_ I N 13 S$1:IVIC$S August 26, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re' MWD Survey 3K-23 Dear Sir/Madam, Enclosed is two hard copy of the above mentioned fie(s). Well 3K-23 Tie in point 0.00' and Projected depth at 10,462.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. AUG 29 1997 Oil & Gas Co~s. Comrnt~,c4~ ~cho~ge 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 3K-23 Dear Sir/Madam, Enclosed is two hard copy of the above mentioned file(s). Well 3K-23 Tie in point 0.00' and Projected depth at 10,462.00' Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. August 26, 1997 RECEIVED AUG 29 1997 Oil & Gas Cons. Oommissi~.~ Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 . (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 31, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-23 (Permi[ No. 97-97) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-23. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad ORIGINAL -- STATE OF ALASKA : ALASr,,,-, OIL AND GAS CONSERVATION ,..,,...,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-97 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-22771 4. Classification of Service Well 12. 17. 22. Location ofwell at surface ~-i~.?~_7:;::.;::~.~ ~ 9. Unit or Lease Name ~ ...... ..~,-,..~i ~,_.,~..., i Kuparuk River Unit 1347' FSL, 318' FWL, Sec.35, T13N, R9E, UM At top of productive interval I ~ 10. Well Number 301' FNL, 1662' FEL, Sec. 35, T13N, R9E, UM i ?/-/~"~,'7--~ 3K-23 At total depth 1512' FSL, 792' FEL, Sec. 26, T13N, R9E, UM ¢ -,'~-~.--.~7~ i 11. Field and Pool Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and SericJ,,.~.? Kuparuk River Rig RKB 41', Pad 34' I ADL 25519, ALK 2555 Date Spudded i13. Date T.D. Reached 114. Date Comp., Sump., or Aband.115. Water depth, if offshore ~'~6. No. of Completions 6/1/97 ~ 6/12/97 I 7,¢~ ?~/.¢,,/~7 N/A MSL/ One '=l-0tal D~)th (MD~'~v~')' ] i8. Plug Back Depth (MD+TVD)I19. Directional SurveyS20. Depth where SSSV set~l. Thickness of Permafrost 10462 6680 FTJ 10432 6679 F~ ~Yes [~No I N/A MD/ 1565' (Approx.) Type Electric or Other Logs Run GR/CCL/CBT/CET 23. CASING SIZE VVT. PER FT. GRADE 1 6" 151.5# X-65 7.625" 29.7# L-80 5.5" 15.5# L-80 4.5" 12.7# 8744' CASING, LINER AND CEMENTING RECORD SE-I-rING DEPTH I"' HOLE ToP BOTTOM 1 S!ZE Surf. 121' Surf. 4970' j__9__:__8_7__51'___ Surf. 8744' L-80 24. Perforations open to Producti'~J'n (MD+TVD of Top and Bottom and interval, size and number) CEMENTING RECORD AMOUNT PULLED 4.5 cubic yards High Early 515 sx AS III LW, 430 sx 'G', 60 sx ASI tapered string - 210 sx Class G MD TVD 88o7'-10432' 6577'-6679' 24 hpf 10434'I 6t7511, MD TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8756' 8780' 26. AC~D FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED _~ 7. PRODUCTION TEST Date First Production 7/15/97 Date of TestiHours Tested 7/19/97 i 24.0 Flow TubinglOasing Pressure iPress. 35~ 1340 28. iMethod of Operation (Flowing, gas lift, etc.) __L G_~as b i PRODUCTION FOR J OIL-EEL GAS-MCF TEST PERIOD ° I 1 832 81 2 ~'-AL(~ ~A-~ ~- -~ ...... 1-(~i~:E~-I_ ..... GAS-MCF 24-HOUR RATE J. 2008 1309 CORE DATA WATER-EEL i'CHOKE SIZE l GAS-OIL RATIO 19 l .......... -1---2--4- .... i 443 WATER-EEL lOlL GRAVITY-APl (CORR) 19 I 0 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Mi 30. Formation Tests Measured True Vertical Includ'e interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. · Top Kuparuk C 8430' 6469' Bottom Kuparuk C 8510' 6498' Top Kuparuk A 8844' 6584' Bottom Kuparuk A 10462' 6680' Annulus left open - freeze protected with diesel. ",~i. '1' ist ~f Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ....... _S!_g__~e~___ ~ ___ Title "~,.~t\,¥,.~o _~___-~¢O_'~_C_ .............. D_ate .... --'ll - Pret~red ~/-)Name/Number: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 7/23/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3K-23 RIG:PARKER 245 WELL ID: AK8741 TYPE: AFC:--AK8741 AFC EST/UL:$ 1430M/ 1720M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:06/01/97 START COMP: WI: 0% SECURITY:0 API NUMBER: 50-029-22771-00 FINAL:07/02/97 05/31/97 (D1) TD: 125' (125) SUPV: DEB DAILY:$ 06/01/97 (D2) TD: 3956' (3831) SUPV: DEB DAILY:$ 06/02/97 (D3) TD: 4980' (1024) SUPV: DEB DAILY :$ 06/03/97 (D4) TD: 4980' ( 0) SUPV: DEB DAILY:$ 06/04/97 (D5) TD' 6635' (1655) SUPV:DEB DAILY:$ 06/05/97 (D6) TD: 8331' (1696) SUPV:DEB DAILY' $ 06/06/97 (D7) TD: 8827' (496) SUPV: DEB DAILY:$ MW: 8.4 VISC: 80 PV/YP: 17/31 APIWL: 9.8 DRILLING @ +/- 900' Move rig from 3K-26 to 3K-23. Accept rig @ 1700 hrs. 5/31/97. NU diverter system. Function test diverter. OK. Drill gravel out of conductor from 42' to 125'. 72,807 CUM'$ 72,807 ETD'$ 51,237 EFC:$ 1,451,570 MW: 9.0 VISC: 62 PV/YP: 19/19 APIWL: 6.4 DRILLING @ 4370' MD Drill from 125' to 3956'. Pump lo/hi visc sweeps and circulate around. 73,992 CUM:$ 146,799 ETD:$ 278,446 EFC:$ 1,298,353 MW: 9.3 VISC: 49 PV/YP: 17/14 APIWL: 5.2 RUNNING 7-5/8" SURFACE CASING Drill from 3956' to 4980'. Circulate lo & hi visc sweeps around. 3 tries for survey, no go. Monitor well. Pump slug. POOH. Hole trying to swab from 2468' to 1470', pulled slow. RU to run 7-5/8" surface casing. 71,613 CUM:$ 218,412 ETD:$ 339,593 EFC:$ 1,308,819 MW: 9.5 VlSC: 45 PV/YP: 16/ 8 APIWL: 5.5 CLEAN OUT CEMENT IN 7-5/8" CSG Pre-job safety meeting on running casing. Run 7-5/8" surface casing. Pump first stage cement. Pump second stage cement. NU BOPE. Test BOPE to 300/3000 psi. OK. 206,785 CUM:$ 425,197 ETD:$ 339,593 EFC:$ 1,515,604 MW: 8.7 VISC: 45 PV/YP: 12/14 APIWL: 10.2 DRILLING @ +/- 7300' Clean out cement and drill out ES cementer @ 1880' Clean out cement and float equipment, clean out rathole to 4980' Drill 20' of new hole to 5000' MD. Test formation to 16.4 ppg EMW. Drill from 5000' to 6635' Drilling ahead. 71,318 CUM:$ 496,515 ETD:$ 667,170 EFC:$ 1,259,345 MW: 10.5 VISC: 45 PV/YP: 14/16 APIWL: 5.8 DRILLING @ +/- 8550' Drill from 6635' to 7964' Circulate lo/hi visc sweeps around. Test formation, leaked off 10.5 ppg mud - 14.0 ppg EMW at 7-5/8" shoe - 12.8 EMW @ 7964' MD. Drill to 8331' and drilling ahead. 87,792 CUM:$ 584,307 ETD:$ 1,002,863 EFC:$ 1,011,444 MW: 10.5 VISC' 47 PV/YP. 19/19 APIWL' 4.4 PRECAUTIONARY REAM OUT ~' ~=~ ?--: ~ ,,. -- Drill from 8331' to 8827' Circulate lo/hi around. Check for flow, no flow. Pump slug. POH. Flow check, OK. RIH with BHA #3.:~ e~']r' 6' ~6 82,192 CUM:$ 666,499 ETD:$ 1,101,037 EFC: ' 9 2 ,. Date: 7/23/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/07/97 (D8) TD: 8984' (157) SUPV: DEB DAILY:$ 06/08/97 (D9) TD: 9130' ( 146} SUPV: DEB DAILY:$ 06/09/97 (D10) TD: 9150' ( 20) SUPV: DEB DAILY:$ 06/10/97 (Dll) TD: 9150' ( 0) SUPV:DCL DAILY:$ 06/11/97 (D12) TD: 9577' (427) SUPV:DCL DAILY:$ 06/12/97 (D13) TD:10462' (885) SUPV:DCL DAILY:$ 06/13/97 (D14) TD:10462' ( 0) SUPV:DCL MW: 10.5 VISC: 50 PV/YP: 15/30 APIWL: 7.8 CIRCULATE HOLE CLEAN @ 9131' Change out mud to NDF (Sheardril-N) . Precautionary back-ream out of hole from 8827' to 7750' Log Sperry-Sun MWD from 8735' to 8827' Drill from 8827' to 8984' Hole getting sticky. Tight spot @ 8825'. Packing off from 8084' to 7827', ream out. POH to 7480'. Check flow, OK. Pump slug. Ream from 8825' to 8912' Mud gas cut to 10.0 ppg on bottoms up. 136,804 CUM:$ 803,303 ETD:$ 1,132,112 EFC:$ 1,101,191 MW: 10.7 VlSC: 55 PV/YP: 18/38 APIWL: 5.4 CIRCULATE HOLE CLEAN @ 9030' Wash from 8912' to bottom at 8984'. Drill from 8984' to 9130' Attempt to slide, would not slide. Back ream from 9130' to 8912' & 8735' to 8364'. POH. Pulled tight at 8227' Back ream from 8272' to 8120'. Hole acts like shale sloughing in and packing off. Ream from 7535' to 8066'. Hole tight and packing off. Weight up to 10.7 ppg and circulate. Ream from 7535' to 7648', packing off. Work and continue to ream. 84,239 CUM:$ 887,542 ETD:$ 1,161,010 EFC:$ 1,156,532 MW: 10.5 VISC: 53 PV/YP: 20/28 APIWL: 6.4 RIH W/6.75" HOLE OPENER Ream 8180' to 8297', packing off at times, work, ream and circulate. Ream from 9100' to 9130' Unable to slide. Drill 10' more to 9150' . Ream out to 9101'. Reduce mud weight to 10.5 ppg. Pipe jarred free. Ream out of hole, tight in spots. Pump slug. 77,900 CUM:$ 965,442 ETD:$ 1,164,969 EFC:$ 1,230,473 MW: 10.5 VISC: 51 PV/YP: 16/31 APIWL: 5.8 RIH BIT AND MOTOR Ream from 7500' to 9150' Tight spot at 7841' Circ lo/hi vis sweep. Tight spot at 8289' Ream from 8915' to 8949' Circ lo/hi vis sweep. 80,484 CUM:$ 1,045,926 ETD:$ 1,164,969 EFC:$ 1,310,957 MW: 10.5 VISC: 58 PV/YP: 21/36 APIWL: 3.8 WIPERTRIP AT 9730' CBU. No gas cut mud. Drilling from 9150' to 9215'. BHA attempting to wall stick. Circ and condition mud. Add Pac-L to system to lower water loss and improve filter cake. Drilling from 9215' to 9577' -- 84,014 CUM:$ 1,129,940 ETD:$ 1,249,486 EFC:$ 1,310,454 MW: 10.5 rISC: 58 PV/YP: 21/33 APIWL: 4.5 POH FOR HOLE OPENER Drilling from 9577' to 9736' Circ and pump lo/hi vis sweep. Pump out to 8820' CBU. No gas. Drilling from 9736' to 10462'. Circ lo/hi vis sweep. 77,967 CUM:$ 1,207,907 ETD:$ 1,424,655 EFC:$ 1,213,252 MW: 10.5 vise: 58 PV/YP: 22/37 APIWL: 3.6 POH TO RUN CSG Pump out 17 stands to top of sand Monitor P0H to 8000'. Hole tight from 8256 to 8000'. CB0-.~N~ Ream from 7500' to 8950' Circ. Ream from 9150' to 9223'. Date: 7/23/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 DAILY:$ 06/14/97 (D15) TD:10462' ( 0) SUPV:DCL DAILY:$ 06/15/97 (D16} TD:10462' ( 0) SUPV:DCL DAILY:$ 07/01/97 (D17) TD:10462' ( 0) SUPV:DEB DAILY:$ 07/02/97 (D18) TD:10462' ( 0) SUPV:DEB DAILY:$ 07/03/97 (D19) TD:10462' ( 0) SUPV:DEB DAILY:$ 80,222 CUM:$ 1,288,129 ETD:$ 1,424,655 EFC:$ 1,293,474 MW: 10.5 VISC: 57 PV/YP: 24/34 APIWL: 3.4 WOC Ream from 9738' to 9874'. RU to run casing. Held prejob safety meeting. RIH w/4.5" perf casing and 5.5" casing w/ECP. 122,968 CUM:$ 1,411,097 ETD:$ 1,424,655 EFC:$ 1,416,442 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Pump cement. ND BOPE. Install packoff and wellhead. Test. Freeze protect annulus. Secure well. Release rig @ 2000 hrs. 6/15/97. 144,845 CUM:$ 1,555,942 ETD'$ 1,424,655 EFC:$ 1,561,287 MW: 10.7 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RUNNING 3.5" TUBING Move rig from 3K-30 to 3K-23. Accept rig at 1330 hrs 7/1/97. Monitor well - dead. Test BOPE to 300/3000 psi. 217,629 CUM'$ 1,773,571 ETD'$ 1,424,655 EFC:$ 1,778,916 MW: 10 NU WKM TREE Hold pre-job safe tubing & GLMs. Ri machine. Continue 177,706 CUM:$ 1,9 .7 VlSC: 0 PV/YP: 0/ 0 APIWL: 0.0 ty meeting g repair - running 3. 51,277 ETD: MW: 10 RIG RELEASED Test tubing to 35 Released rig @ 21 63,343 CUM:$ 2,0 .7 VISC: 00 psi for 00 hrs. 7/3 14,620 ETD: on running tubing. Run 3.5" change out Power Track on pipe 5" completion assembly. $ 1,424,655 EFC:$ 1,956,622 0 PV/YP: 0/ 0 APIWL: 0.0 10 minutes, OK. Freeze protect. /97. $ 1,424, 655 EFC:$ 2,019,965 End of WellSummary for Well:AK8741 SPk .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-23 500292277100 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 061397 MWD SURVEY JOB NUMBER: AK-MM-70157 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -75.30 121.00 121.00 45.70 257.00 256.99 181.69 439.00 438.86 363.56 656.27 655.85 580.55 0 0 0 0 0 45 3 0 2 49 N .00 E .00 .00N .00E .00 N .00 E .00 .00N .00E .00 N 64.00 E .55 .39N .80E .82 N 72.00 E 1.24 2.38N 6.40E 5.98 N 73.55 E .09 5.66N 16.95E 15.34 746.76 746.15 670.85 838.75 837.61 762.31 930.31 927.98 852.68 1020.41 1016.39 941.09 1112.52 1106.73 1031.43 4 24 7 49 10 34 11 36 10 56 N 77.93 E 1.77 7.02N 22.50E 19.99 N 69.31 E 3.84 9.97N 31.82E 28.31 N 69.13 E 2.99 15.17N 45.50E 41.17 N 75.45 E 1.77 20.39N 61.99E 55.88 N 72.39 E .97 25.36N 79.29E 70.92 1204.64 1196.92 1121.62 1297.16 1286.72 1211.42 1391.34 1377.42 1302.12 1484.27 1466.30 1390.99 1573.93 1550.69 1475.39 12 35 15 15 16 0 17 53 21 31 N 60.68 E 3.14 32.92N 96.38E 87.80 N 54.43 E 3.30 44.94N 115.07E 109.10 N 52.84 E .93 59.99N 135.50E 133.83 N 50.30 E 2.18 76.86N 156.70E 160.44 N 47.64 E 4.16 96.74N 179.46E 190.36 1665.00 1634.41 1559.11 1756.11 1715.93 1640.63 1848.80 1795.98 1720.68 1941.75 1873.13 1797.83 2034.61 1947.20 1871.90 24 47 28 13 32 16 35 29 38 40 N 45.81 E 3.68 121.31N 205.50E 225.96 N 44.56 E 3.82 149.99N 234.32E 266.50 N 44.83 E 4.37 183.18N 267.17E 313.08 N 44.54 E 3.46 220.02N 303.60E 364.77 N 43.76 E 3.47 260.20N 342.59E 420.65 2220.60 2090.94 2015.64 2406.96 2229.62 2154.32 2681.72 2424.92 2349.62 2867.40 2555.75 2480.45 3052.71 2688.46 2613.16 40 5 43 43 45 39 44 45 43 46 N 43.93 E .76 345.31N 424.33E 538.48 N 43.29 E 1.96 435.43N 510.15E 662.77 N 41.36 E .86 578.29N 640.18E 855.87 N 41.56 E .50 677.04N 727.42E 987.61 N 41.71 E .53 773.69N 813.34E 1116.92 3239.07 2824.02 2748.72 3514.80 3023.58 2948.28 3880.67 3289.78 3214.48 4159.80 3496.31 3421.01 4529.09 3769.23 3693.93 42 52 44 24 42 12 42 20 42 20 N 41.23 E .51 869.50N 898.02E 1244.77 N 45.02 E 1.10 1008.28N 1028.12E 1434.83 N 45.75 E .62 1184.51N 1206.69E 1684.88 N 43.27 E .60 1318.39N 1338.29E 1872.19 N 41.69 E .29 1501.85N 1506.28E 2120.82 4903.16 4045.16 3969.86 5128.80 4211.00 4135.70 5407.76 4415.23 4339.93 5684.00 4614.14 4538.84 5958.51 4812.04 4736.75 42 35 42 47 43 4 44 49 42 53 N 44.92 E .59 1685.56N 1679.46E 2373.03 N 43.20 E .53 1795.51N 1785.84E 2525.75 N 43.73 E .16 1933.42N 1916.56E 2715.54 N 39.66 E 1.20 2076.58N 2043.94E 2907.14 N 40.81 E .76 2221.78N 2166.75E 3097.31 ORIGINAL_ RECEIVED AUG 29 1997 Oil & Gas Cons. OorrlmissJo.~,., A~cherage SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-23 500292277100 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 061397 MWD SURVEY JOB NUMBER: AK-MM-70157 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6239.03 5016.48 4941.18 6516.09 5215.57 5140.27 6699.43 5347.31 5272.01 6884.78 5483.26 5407.96 7069.37 5618.45 5543.15 43 32 44 34 43 32 42 4 43 43 N 44.39 E .90 2363.07N 2296.73E N 41.19 E .89 2504.44N 2427.52E N 39.54 E .84 2601.56N 2510.10E N 38.21 E .93 2699.61N 2589.17E N 38.54 E .90 2798.11N 2667.18E 3289.19 3481.65 3609.13 3735.02 3860.57 7252.48 5751.71 5676.41 7345.41 5819.89 5744.59 7439.54 5887.07 5811.77 7531.87 5951.30 5876.00 7621.47 6013.98 5938.68 42 42 46 45 45 52 N 41.46 E 1.19 2894.29N 2747.85E 44 N 40.67 E .59 2941.90N 2789.33E 10 N 41.52 E 3.71 2991.57N 2832.68E 39 N 40.98 E .71 3041.43N 2876.40E 34 N 40.86 E .12 3089.82N 2918.35E 3986.10 4049.24 4115.16 4181.48 4245.51 7713.27 6076.62 6001.32 48 20 7805.18 6136.67 6061.37 50 4 7898.50 6196.01 6120.71 50 57 7990.16 6252.31 6177.01 53 15 8083.27 6306.27 6230.97 55 54 N 40.50 E 3.02 3140.70N 2962.07E N 38.81 E 2.34 3194.26N 3006.46E N 37.44 E 1.48 3250.92N 3050.91E N 34.77 E 3.39 3309.36N 3093.51E N 33.89 E 2.96 3372.02N 3136.28E 4312.60 4382.15 4454.09 4526.18 4601.58 8175.33 6355.41 6280.11 59 32 8265.13 6398.98 6323.68 62 24 8356.07 6439.38 6364.08 64 50 8449.48 6476.31 6401.01 68 33 8543.23 6509.46 6434.16 70 1 N 32.07 E 4.29 3437.32N 3178.63E N 31.78 E 3.19 3503.95N 3220.14E N 30.19 E 3.12 3573.80N 3262.07E N 29.72 E 4.00 3648.12N 3304.90E N 29.19 E 1.64 3724.48N 3348.01E 4678.69 4756.29 4836.59 4920.87 5006.87 8636.67 6538.26 6462.96 74 4 8668.91 6546.98 6471.68 74 33 8698.78 6554.55 6479.25 76 5 8728.01 6561.23 6485.94 77 27 8758.76 6567.58 6492.28 78 42 N 28.73 E 4.36 3802.23N 3391.04E N 29.20 E 2.05 3829.39N 3406.07E N 28.40 E 5.77 3854.71N 3419.99E N 27.91 E 4.96 3879.79N 3433.42E N 27.99 E 4.07 3906.37N 3447.52E 5093.88 5124.27 5152.54 5180.32 5209.66 8785.58 6572.81 6497.51 78 48 8815.23 6578.47 6503.17 79 10 8845.12 6583.69 6508.39 80 41 8878.25 6588.62 6513.32 82 13 8906.69 6592.28 6516.98 82 59 N 27.42 E 2.12 3929.66N 3459.75E N 27.76 E 1.68 3955.46N 3473.23E N 27.82 E 5.06 3981.49N 3486.95E N 27.65 E 4.65 4010.48N 3502.19E N 27.17 E 3.18 4035.52N 3515.18E 5235.30 5263.64 5292.33 5324.25 5351.70 8938.67 6595.98 6520.68 83 42 8968.31 6599.13 6523.83 84 6 9000.19 6601.94 6526.64 85 46 9030.35 6603.62 6528.32 87 50 9062.02 6604.70 6529.40 88 15 N 27.35 E 2.32 4063.76N 3529.72E N 27.71 E 1.81 4089.89N 3543.35E N 26.58 E 6.29 4118.15N 3557.83E N 27.17 E 7.14 4145.00N 3571.44E N 27.58 E 1.83 4173.11N 3586.00E 5382.60 5411.29 5442.16 5471.40 5502.20 ~,Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-23 500292277100 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 061397 MWD SURVEY JOB NUMBER: AK-MM-70157 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9091.64 6605.52 6530.22 9126.82 6606.19 6530.89 9152.52 6606.37 6531.07 9184.34 6606.50 6531.21 9218.10 6607.00 6531.70 88 34 N 26.98 E 2.31 4199.42N 3599.57E 89 13 N 26.36 E 2.55 4230.85N 3615.35E 89 58 N 26.70 E 3.17 4253.85N 3626.83E 89 32 N 25.89 E 2.88 4282.37N 3640.93E 88 46 N 25.01 E 3.46 4312.85N 3655.43E 5531.00 5565.13 5590.04 5620.86 5653.43 9247.49 6607.96 6532.66 9276.66 6609.47 6534.17 9308.35 6611.31 6536.01 9339.59 6613.08 6537.78 9365.25 6614.65 6539.35 87 30 N 25.84 E 5.16 4339,38N 3668.04E 86 33 N 24.73 E 5.00 4365.72N 3680.49E 86 47 N 25.23 E 1.75 4394.39N 3693.85E 86 43 N 25.12 E .40 4422,62N 3707.11E 86 14 N 24.66 E 2.62 4445.85N 3717.89E 5681.77 5709.85 5740.30 5770.36 5795.00 9397.26 6617.12 6541.82 9429.24 6620.00 6544.70 9460.21 6622.87 6547.57 9492.13 6625.78 6550.48 9522.90 6628.35 6553.05 84 54 N 24.52 E 4.18 4474.87N 3731.17E 84 46 N 24.16 E 1.19 4503.89N 3744.30E 84 34 N 24.46 E 1.16 4531.99N 3756.99E 84 56 N 23.87 E 2.17 4560.99N 3770.01E 85 28 N 23.58 E 1.96 4589.07N 3782.34E 5825.66 5856.22 5885.81 5916.28 5945.61 9553.72 6630.67 6555.37 9587.12 6632.96 6557.66 9617.14 6634.74 6559.44 9647.53 6636.28 6560.98 9678.31 6637.67 6562.37 85 52 N 25.09 E 5.05 4617.06N 3795.01E 86 16 N 24.48 E 2.20 4647.32N 3808.97E 86 54 N 24.17 E 2.31 4674.62N 3821.32E 87 19 N 25.89 E 5.82 4702.12N 3834.16E 87 28 N 26.01 E .65 4729.77N 3847.61E 5975.09 6007.14 6035.89 6065.11 6094.85 9710.70 6639.13 6563.83 9739.86 6640.40 6565.10 9773.34 6641.75 6566.45 9803.28 6643.07 6567.77 9833.20 6644.81 6569.51 87 20 N 25.08 E 2.90 4758.96N 3861.57E 87 39 N 24.62 E 1.90 4785.40N 3873.81E 87 43 N 24.47 E .48 4815.83N 3887.70E 87 14 N 23.21 E 4.50 4843.18N 3899.79E 86 4 N 24.58 E 5.99 4870.49N 3911.89E 6126.08 6154.11 6186.24 6214.87 6243.46 9865.02 6647.09 6571.79 9892.51 6649.14 6573.84 9922.76 6651.35 6576.05 9954.32 6653.64 6578.34 9987.22 6656.02 6580.72 85 42 N 24.98 E 1.71 4899.30N 3925.19E 85 45 N 24.78 E .74 4924.17N 3936.73E 85 50 N 24.66 E .49 4951.58N 3949.34E 85 50 N 23.91 E 2.37 4980.27N 3962.29E 85 52 N 23.06 E 2.58 5010.36N 3975.36E 6273.98 6300.36 6329.36 6359.56 6390.90 10017.98 6658.19 6582.89 10047.15 6660.07 6584.77 10075.62 6661.70 6586.40 10106.56 6663.38 6588.08 10141.18 6665.20 6589.90 86 1 N 23.69 E 2.10 5038.53N 3987.54E 86 35 N 24.18 E 2.55 5065.13N 3999.35E 86 49 N 24.43 E 1.22 5091.04N 4011.05E 86 56 N 24.53 E .51 5119.15N 4023.85E 87 0 N 24.25 E .83 5150.64N 4038.12E 6420.19 6448.07 6475.33 6505.00 6538.18 SPi IY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-23 500292277100 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 061397 MWD SURVEY JOB NIIMBER: AK-MM-70157 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 10173.17 6666.90 6591.60 86 55 N 23.60 E 2.05 5179.84N 4051.08E 10201.49 6668.40 6593.10 86 59 N 23.72 E .49 5205.74N 4062.43E 10233.53 6670.02 6594.72 87 11 N 23.64 E .70 5235.05N 4075.28E 10264.36 6671.49 6596.19 87 21 N 22.77 E 2.87 5263.35N 4087.41E 10294.09 6672.84 6597.54 87 24 N 23.88 E 3.73 5290.62N 4099.17E 6568.77 6595.81 6626.41 6655.78 6684.13 10322.83 6674.11 6598.81 87 32 N 23.32 E 2.00 5316.93N 4110.67E 10354.31 6675.41 6600.11 87 43 N 21.78 E 4.92 5345.98N 4122.73E 10401.36 6677.39 6602.09 87 26 N 22.13 E .94 5389.58N 4140.30E 10462.00 6680.09 6604.79 87 26 N 22.13 E .00 5445.69N 4163.12E 6711.57 6741.46 6785.97 6843.40 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6854.72 FEET AT NORTH 37 DEG. 23 MIN. EAST AT MD = 10462 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 40.69 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,462.00' MD S~ %Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-23 500292277100 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 061397 JOB NUMBER: AK-MM-70157 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION .00 .00 -75.30 .00 N .00 E .00 1000.00 996.40 921.10 19.36 N 58.02 E 3.60 2000.00 1919.96 1844.66 244.82 N 327.78 E 80.04 3000.00 2650.39 2575.09 746.47 N 789.08 E 349.61 4000.00 3378.18 3302.88 1240.45 N 1264.11 E 621.82 3.60 76.44 269.57 272.21 5000.00 4116.45 4041.15 1731.97 N 1725.73 E 883.55 6000.00 4842.44 4767.14 2243.15 N 2185.21 E 1157.56 7000.00 5568.33 5493.03 2760.60 N 2637.30 E 1431.67 8000.00 6258.18 6182.88 3315.85 N 3098.00 E 1741.82 9000.00 6601.92 6526.62 4117.98 N 3557.75 E 2398.08 261.72 274.01 274.12 310.15 656.25 10000.00 6656.94 6581.64 5022.09 N 3980.36 E 3343.06 10462.00 6680.09 6604.79 5445.69 N 4163.12 E 3781.91 944.99 438.84 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~ ~,Y-SUN DRILLING SERVICES ANCHOR3%GE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-23 500292277100 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 061397 JOB NUMBER: AK-MM-70157 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75 75.30 75.30 175.30 175.30 100 275.31 275.30 200 375.35 375.30 300 .30 .00 .00 .00 .00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .50 N 1.02 E .01 .01 1.35 N 3.23 E .05 .04 475.49 475.30 400 575.62 575.30 500 675.74 675.30 600 776.02 775.30 700 876.86 875.30 800 .00 .00 .00 .00 .00 2.97 N 8.22 E .19 .14 4.53 N 13.13 E .32 .13 5.93 N 17.87 E .44 .12 7.65 N 24.96 E .72 .28 11.95 N 37.04 E 1.56 .84 978.46 975.30 1080.51 1075.30 1182.51 1175.30 1285.34 1275.30 1389.14 1375.30 900 1000 1100 1200 1300 .00 .00 .00 .00 .00 18.25 N 53.86 E 23.52 N 73.50 E 30.70 N 92.20 E 43.19 N 112.57 E 59.63 N 135.01 E 3.16 1.61 5.21 2.05 7.21 1.99 10.04 2.83 13.84 3.80 1493.75 1475.30 1600.47 1575.30 1710.37 1675.30 1824.50 1775.30 1944.43 1875.30 1400 1500 1600 1700 1800 .00 .00 .00 .00 .00 78.77 N 158.97 E 103.48 N 186.77 E 135.11 N 219.51 E 174.12 N 258.17 E 221.14 N 304.70 E 18.45 4.61 25.17 6.72 35.07 9.90 49.20 14.12 69.13 19.93 2070.60 1975.30 2200.15 2075.30 2332.70 2175.30 2470.17 2275.30 2610.72 2375.30 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 276.45 N 358.14 E 335.82 N 415.20 E 398.66 N 475.36 E 467.23 N 540.11 E 540.18 N 606.63 E 95.30 26.18 124.85 29.55 157.40 32.55 194.87 37.46 235.42 40.55 2753.80 2475.30 2894.94 2575.30 3034.49 2675.30 3172.58 2775.30 3309.26 2875.30 2400 2500 2600 2700 2800 .00 .00 .00 .00 .00 616.98 N 674.25 E 691.54 N 740.28 E 764.29 N 804.95 E 835.47 N 868.20 E 905.27 N 929.93 E 278.50 43.08 319.64 41.14 359.19 39.56 397.28 38.09 433.96 36.69 3447.44 2975.30 3587.20 3075.30 3726.14 3175.30 3861.13 3275.30 3996.11 3375.30 2900.00 3000.00 3100.00 3200.00 3300.00 974.81 N 995.17 1044.10 N 1063.96 1112.08 N 1132.34 1175.35 N 1197.29 1238.63 N 1262.24 E 472.14 38.18 E 511.90 39.76 E 550.84 38.94 E 585.83 34.99 E 620.81 34.99 SP~ .Y-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE A~RCO ALASKA, INC. KUPARUK RIVER UNIT / 3K-23 500292277100 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 061397 JOB NUMBER: AK-MM-70157 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASKA INC FT. 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 4131.37 3475.30 3400.00 1304.44 N 1325.16 E 656.07 35.25 4266.68 3575.30 3500.00 1370.81 N 1387.64 E 691.38 35.31 4401.99 3675.30 3600.00 1437.91 N 1449.33 E 726.69 35.31 4537.30 3775.30 3700.00 1505.98 N 1509.96 E 762.00 35.31 4672.61 3875.30 3800.00 1574.05 N 1570.58 E 797.31 35.31 4808.27 3975.30 3900.00 1640.09 N 1634.11 E 832.97 35.66 4944.10 4075.30 4000.00 1705.18 N 1699.02 E 868.80 35.83 5080.15 4175.30 4100.00 1771.41 N 1763.22 E 904.85 36.05 5216.44 4275.30 4200.00 1838.91 N 1826.61 E 941.14 36.29 5353.10 4375.30 4300.00 1906.44 N 1890.76 E 977.80 36.66 5490.34 4475.30 4400.00 1974.79 N 1955.27 E 1015.04 37.24 5629.41 4575.30 4500.00 2047.22 N 2019.25 E 1054.11 39.07 5770.23 4675.30 4600.00 2123.38 N 2082.75 E 1094.93 40.83 5908.36 4775.30 4700.00 2195.94 N 2144.45 E 1133.06 38.12 6044.85 4875.30 4800.00 2266.25 N 2205.16 E 1169.55 36.49 6182.22 4975.30 4900.00 2335.11 N 2269.36 E 1206.92 37.37 6320.17 5075.30 5000.00 2403.01 N 2335.83 E 1244.87 37.95 6459.55 5175.30 5100.00 2474.57 N 2401.39 E 1284.25 39.38 6599.95 5275.30 5200.00 2548.73 N 2466.28 E 1324.65 40.40 6738.05 5375.30 5300.00 2622.09 N 2527.05 E 1362.76 38.11 6874.06 5475.30 5400.00 2693.96 N 2584.73 E 1398.76 36.00 7009.65 5575.30 5500.00 2765.82 N 2641.46 E 1434.35 35.59 7148.04 5675.30 5600.00 2840.65 N 2701.06 E 1472.74 38.39 7284.66 5775.30 5700.00 2910.70 N 2762.35 E 1509.36 36.63 7422.65 5875.30 5800.00 2982.49 N 2824.66 E 1547.35 37.99 7566.20 5975.30 5900.00 3059.96 N 2892.50 E 1590.90 43.54 7711.30 6075.30 6000.00 3139.59 N 2961.12 E 1636.00 45.10 7865.63 6175.30 6100.00 3230.65 N 3035.39 E 1690.33 54.33 8029.13 6275.30 6200.00 3335.27 N 3111.36 E 1753.83 63.50 8215.36 6375.30 6300.00 3466.78 N 3197.04 E 1840.06 86.23 8446.77 6475.30 6400.00 3645.94 N 3303.65 E 1971.47 131.40 8798.40 6575.30 6500.00 3940.83 N 3465.54 E 2223.10 251.64 10351.51 6675.30 6600.00 5343.38 N 4121.69 E 3676.21 1453.10 10380.00 6676.44 6601.14 5369.81 N 4132.26 E 3703.56 27.35 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES KUPARUK RIVER UNIT / 3K-23 (E) 50-029-22771-00 MEASURED ANGLE DIRECTION VERTICAL DEPTH DEG DEG DEPTH LATITUDE FEET 0.00 0.00 0.00 121.00 0.00 0.00 257.00 0.75 64.00 439.00 3.00 72.00 656.27 2.83 73.55 0.00 121.00 257.00 438.89 655.88 0.00 0.00 0.39 N 2.38 N 5.66 N 746.76 4.41 77.93 838.75 7.83 69.31 930.31 10.57 69.13 1020.41 11.60 75.45 1112.52 10.94 72.39 746.18 837.64 928.01 1016.43 1106.77 7.02 N 9.97 N 15.17 N 20.39 N 25.36 N 1204.64 12.59 60.68 1297.16 15.25 54.43 1391.34 16.01 52.84 1484.27 17.90 50.30 1573.93 21.52 47.64 1196.96 1286.76 1377.46 1466.35 1550.74 32 44 59 76 96 .92 N .94 N .99 N .86 N .75 N 1665.00 24.79 45.81 1756.11 28.23 44.56 1848.80 32.28 44.83 1941.75 35.49 44.54 2034.61 38.68 43.76 1634.46 1715.98 1796.03 1873.18 1947.25 121.32 N 149.99 N 183.18 N 220.02 N 260.20 N 2220.60 40.09 43.93 2406.96 43°72 43.29 2681.72 45.66 41.36 2867.40 44.75 41.56 3052.71 43.77 41.71 2091.00 2229.68 2425.01 2555.83 2688.55 345 435 578 677 773 .32 N .44 N .32 N .07 N .73 N 3239.07 42'.88 41.23 3514.80 44~41 45.02 3880.67 42.20 45.75 4159.80 42.35 43.27 4529.09 42.35 41.69 2824.12 3023.67 3289.91 3496.46 3769.39 869 1008 1184 1318 1501 .53 N .31 N .57 N .46 N .92 N 4903.16 42.59 44.92 5128.80 42.80 43.20 5407.76 43.07 43.73 5684.00 44.83 39.66 5958.51 42.89 40.81 4045.34 4211.19 4415.42 4614.33 4812.26 1685 1795 1933 2076 2221 .66 N .60 N .52 N .68 N .89 N 6239.03 43.54 44.39 6516.09 44.58 41.19 6699.43 43.55 39.54 6884.78 42..08 38.21 7069.37 43.73 38.54 5016.73 5215.85 5347.59 5483.56 5618.76 2363 2504 2601 2699 2798 .21 N .60 N .73 N .78 N .29 N. Page 1 JUNE 13, 1997 NORTH SLOPE BOROUGH DEPARTURE VERTICAL DOG FEET SECTION LEG 0.00 0.00 0.00 0.00 0.00 0.00 0.80 E 0.82 0.55 6.40 E 5.98 1.24 16.95 E 15.34 0.09 22.50 E 19.99 1.77 31.82 E 28.31 3.84 45.50 E 41.17 2.99 62.00 E 55.88 1.77 79.29 E 70.92 0.97 96.38 E 87.80 3.14 115.07 E 109.10 3.30 135.50 E 133.83 0.93 156.70 E 160.44 2.18 179.46 E 190.36 4.16 205.50 E 225.97 3.68 234.33 E 266.50 3.82 267.17 E 313.08 4.37 303.60 E 364.77 3.46 342.59 E 420.66 3.47 424.34 E 538.49 0.76 510.16 E 662.78 1.96 640.21 E 855.90 0.86 727.45 E 987.66 0.50 813.37 E 1116.97 0.53 898.05 E 1244.82 0.51 1028.15 E 1434.87 1.10 1206.75 E 1684.96 0.62 1338.36 E 1872.28 0.60 1506.35 E 2120.92 0.29 1679.55 E 2373.16 0.59 1785.94 E 2525.89 0.53 1916.66 E 2715.68 0.16 2044.04 E 2907.28 1.20 2166.87 E 3097.47 0.76 2296.86 E 3289.38 0.90 2427.67 E 3481.87 0.89 2510.26 E 3609.36 0.84 2589.33 E 3735.26 0.93 2667.35 E 3860.82 0.90 O 161NAL SPERRY-SUN DRILLING SERVICES Page 2 KUPARUK RIVER UNIT / 3K-23 (E) 50-029-22771-00 JUNE 13, 1997 NORTH SLOPE BOROUGH MEASURED ANGLE DIRECTION DEPTH DEG DEG VERTICAL DEPTH LATITI/DE FEET DEPARTURE VERTICAL DOG FEET SECTION LEG 7252.48 42.87 41.46 5752.04 2894.48 7345.41 42.74 40.67 5820.22 2942.09 7439.54 46.18 41.52 5887.39 2991.76 7531.87 45.65 40.98 5951.63 3041.62 7621.47 45.58 40.86 6014.30 3090.01 N N N N N 2748.03 E 3986.36 1.19 2789.51 E 4049.51 0.59 2832.85 E 4115.42 3.71 2876.58 E 4181.74 0.71 2918.53 E 4245.77 0.12 7713.27 48.34 40.50 6076.95 3140.89 7805.18 50.07 38.81 6137.00 3194.46 7898.50 50.96 37.44 6196.34 3251.12 7990.16 53.25 34.77 6252.64 3309.56 8083.27 55.91 33.89 6306.60 3372.22 N N N N N 2962.25 E 4312.86 3.02 3006.64 E 4382.42 2.34 3051.10 E 4454.37 1.48 3093.69 E 4526.45 3.39 3136.47 E 4601.85 2.96 8175.33 59.55 32.07 6355.75 3437 8265.13 62.40 31.78 6399.31 3504 8356.07 64.85 30.19 6439.71 3574 8449.48 68.56 29.72 6476.64 3648 8543.23 70.02 29.19 6509.80 3724 .52 .16 .00 .33 .68 N N N N N 3178.81 E 4678.97 4.29 3220~33 E 4756.57 3.19 3262.26 E 4836.86 3.12 3305.08 E 4921.14 4.00 3348.20 E 5007.15 1.64 8636.67 74.07 28.73 6538.60 3802 8668.91 74.55 29.20 6547.32 3829 8698.78 76.09 28°40 6554.89 3854 8728.01 77.46 27.91 6561.57 3880 8758.76 78.71 27.99 6567.92 3906 .44 .60 .92 .00 .58 N N N N N 3391.23 E 5094.16 4.36 3406.26 E 5124.55 2.05 3420.18 E 5152.83 5.77 3433.61 E 5180.60 4.96 3447.71 E 5209.95 4.07 8785.58 78.81 27.42 6573.15 3929 8815.23 79.18 27.76 6578.81 3955 8845.12 80.69 27.82 6584.03 3981 8878.25 82.22 27.65 6588.95 4010 8906.69 82.99 27.17 6592.61 4035 .87 .67 .70 .70 .74 N N N N N 3459.94 E 5235.58 2.12 3473.42 E 5263.93 1.68 3487.14 E 5292.61 5.06 3502.39 E 5324.54 4.65 3515.37 E 5351.99 3.18 8938.67 83.71 27.35 6596.32 4063.97 8968.31 84.11 27.71 6599.46 4090.11 9000o19 85.77 26.58 6602.27 4118.36 9030.35 87.84 27.17 6603.96 4145.22 9062.02 88.25 27.58 6605.04 4173.33 N N N N N 3529.92 E 5382.89 2.32 3543.54 E 5411.59 1.81 3558.03 E 5442.46 6.29 3571.64 E 5471.70 7.14 3586.19 E 5502.50 1.83 9091.64 88.58 26.98 6605.86 4199 9126.82 89.23 26.36 6606.53 4231 9152.52 89.97 26.70 6606.71 4254 9184.34 89.54 25.89 6606.84 4282 9218.10 88.77 25.01 6607.34 4313 .65 .08 .07 .60 .08 N N N N N 3599.76 E 5531.30 2.31 3615.55 E 5565.42 2.55 3627.03 E 5590.34 3.17 3641.13 E 5621.16 2.88 3655.63 E 5653.73 3.46 9247.49 87.50 25.84 6608.30 4339 9276.66 86.55 24.73 6609.81 4365 9308.35 86.79 25.23 6611.65 4394 9339.59 86..73 25.12 6613.42 4422 9365.25 86.24 24.66 6614.99 4446 .61 .94 .62 .85 .08 N N N N N- 3668.24 E 5682.07 5.16 3680.69 ~"~}1~i~.~:10.15 5.00 o. o SPERRY-SUN DRILLING SERVICES Page 3 KUPARUK RIVER UNIT / 3K-23 (E) 50-029-22771-00 JTJNE 13, 1997 NORTH SLOPE BOROUGH MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPTH DEG DEG DEPTH FEET DEPARTURE VERTICAL DOG FEET SECTION LEG 9397.26 84.91 24.52 6617.46 4475.10 N 9429.24 84.78 24.16 6620.33 4504.12 N 9460.21 84.58 24.46 6623.21 4532.22 N 9492.13 84.95 23.87 6626.12 4561.22 N 9522.90 85.48 23.58 6628.68 4589.30 N 3731.37 E 5825.97 4.18 3744.50 E 5856.53 1.19 3757.19 E 5886.11 1.16 3770.21 E 5916.59 2.18 3782.54 E 5945.92 1.96 9553.72 85.87 25.09 6631.01 4617.30 N 9587.12 86.28 24.48 6633.30 4647.55 N 9617.14 86.90 24.17 6635.08 4674.85 N 9647.53 87.32 25.89 6636.61 4702.35 N 9678.31 87.48 26.01 6638.01 4730.00 N 3795.21 E 5975.40 5.05 3809.18 E 6007.45 2.20 3821.52 E 6036.20 2.31 3834.36 E 6065.42 5.82 3847.82 E 6095.16 ' 0.65 9710o70 87.35 25.08 6639.47 4759.20 N 9739.86 87.66 24.62 6640.74 4785.63 N 9773.34 87.72 24.47 6642.09 4816.06 N 9803.28 87.24 23.21 6643.41 4843.42 N 9833.20 86.08 24.58 6645.15 4870.73 N 3861.77 E 6126.39 2.90 3874.01 E 6154.42 1.90 3887.91 E 6186.55 0.48 3900.00 E 6215.18 4.50 3912.10 E 6243.77 5.99 9865.02 85.71 24.98 6647.43 4899.54 N 9892.51 85.75 24.78 6649.47 4924.41 N 9922.76 85.84 24.66 6651.69 4951.82 N 9954.32 85.84 23.91 6653.98 4980.51 N 9987.22 85.88 23.06 6656.36 5010.60 N 3925.40 E 6274.30 1.71 3936.93 E 6300.67 0.74 3949.55 E 6329.68 0.50 3962.49 E 6359.87 2.37 3975.57 E 6391.22 2.58 10017.98 86.03 23.69 6658.53 5038.77 N 10047.15 86.59 24.18 6660.40 5065.38 N 10075.62 86.83 24.43 6662.04 5091.28 N 10106.56 86.95 24.53 6663.72 5119.40 N 10141.18 87o01 24.25 6665.54 5150.88 N 3987.74 E 6420.51 2.10 3999.55 E 6448.38 2.55 4011.25 E 6475.65 1.22 4024.05 E 6505.32 0.50 4038.33 E 6538.50 0.83 10173.17 86.92 23.60 6667.23 5180.08 N 10201.49 86.99 23.72 6668.74 5205.99 N 10233.53 87.20 23.64 6670.36 5235.29 N 10264.36 87.36 22.77 6671.82 5263.59 N 10294.09 87.41 23.88 6673.18 5290.87 N 4051.28 E 6569.09 2.05 4062.63 E 6596.13 0.49 4075.49 E 6626.72 0.70 4087.62 E 6656.10 2.87 4099.38 E 6684.45 3.73 10322.83 87.54 23.32 6674.45 5317.18 N 10354.31 87.72 21.78 6675.75 5346.22 N 10401.36 87.45 22.13 6677.73 5389.82 N 10462.00 87.45 22.13 6680.43 5445.94 N 4110.87 E 6711.89 2.00 4122.93 E 6741.78 4.92 4140.51 E 6786.30 0.94 4163.33 E 6843.72 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET THE VERTICAL SECTION WAS COMPUTED ALONG 40.69° (TRUE) BASED UPON. MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 6855.04 FEET, IN THE DIRECTION-OF 37.40° (TRUE) TONY KNOWLES, GOVERNOR -, ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 30. 1997 Michael Zanghi. Drill Site Develop. Supv. ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3K-23 ARCO Alaska. Inc. Permit No 9%97 Sur. Loc.' 1347'FSL, 318'FWL, Sec. 35. T13N. R9E. UM Btmhole Loc' 1494'FSL'. 773'FEL. Sec. 26, T13N. R9E, 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. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity, Test (FIT) - cementing records. FIT data. and any CQLs are to be submit-ted to the Commission prior to the start of disposal operations. 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 surface 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 Slope pager at 659-3607. _C~.aifman~ ; BY ORDER OF COMMISSION dlt?enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALAb,,A OIL AND GAS CONSERVATION COMMIS$,...4 PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill n J lb Type of Well Exploratory r-~ Stratigraphic Test D Development Oil X Re-Entry D D~epen [~I Service 1~ Development Gas [~ Single Zone X Multiple Zone n 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. Ri~l RKB 41', Pad 34' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25519, ALK 2555 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2O AAC 25.025) 1347' FSL, 318' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 263' FSL, 1354' FEL, Sec. 26, T13N, R9E, UM 3K-23 #U-630610 At total depth 9. Approximate spud date Amount 1494' FSL, 773' FEL, Sec. 26, T13N, R9E, UM 5/29/97 $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 3K-04 10489' MD 263 @ Target feet 12' @ 20' feet 2560 6722' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 43.4° Maximum surface 2422 ~ psig At total depth (TVD) 3500 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Length MD TVD MD TVD linclude stage data/ 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 4936' 41' 41' 4977' 4091' 1410 Sx Arcticset III & HF-ERW 330 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 8911' 41' 41' 8952' 6614' 300SxClassG HF-ERW 6.75" 4.5" 11.6# K-55 IBTCMo¢ 1537' 8952' 661 4' 10489' 6722' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: ,rmueeaS,~;ret~cal ;;eel Plugs(measured) 0 R I GI NA L Effective depth: measured feet Junk (measured)~~-" ~-~ V true vertical feet . Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor I;~/~ ,Y 2 0 ],9,70 7 Surface Intermediate ~-~-~,~ ,~ GaS (~0IIS, [;Di'J~li-rjliSDh. Production Liner ......... Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat E] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements X 2 t. I hereby certify theft the foregoing is true and correct to the best of my knowledge Signed ~&~[~] Title Dr i Site Develop. Supv. Date ,~//~/¢~ I ~ f~ ~ ~'-" ~L For questions, please call Denise Petrash -'~ [/'"' Commission Use Only Perm_it Number I APFf[umber _ . ~ Approval date P,~-- ~'7 JE0-~.~E.-~-- .-~-- -~. ~,/ I[ See cover letter for other requirements Conditions of approval Samples required E] Yes .J~ No Mud Icg required E] Yes ,,~ No Hydrogen sulfide measures J~ Yes r"] No Directional survey required '~ Yes [~ No Required working pressure forBOPE E] 2M ~ 3M r'l 5M [-1 1OM [~ 15M Other: by order of Approved by Commissioner the commission Date Form lC)-4¢)1 R~v Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3K-23 , , . , , . . . . / 11. 16. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,977')according to directional plan. Run and cement 7-5/8" casing, using stage collar placed at least 200' below the base of the permafrost, and light weight lead cement. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to total depth (10,489) according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 4-1/2" Bonzai tapered casing string with 4-1/2" pre- perforated production section. Please see schematic of Bonzai completion for placement details. The production casing will consist of an integral PBR, a stage cementing tool and an external casing packer set above the 4-1/2" pre-perf section. Once the ECP is hydraulically set, the casing string will be cemented through the stage cementing tools. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. ND BOPE. NU tubinghead & master valve. RDMO Parker #245. MIRU CTU. Install and test BOPE to 3500 psi. Pressure test 5-1/2" x 4-1/2" casing to 3500 psi above ECP. Drill out plugs and cement in 5-1/2 and 4-1/2" casing. Clean out pre-perf section. ND BOPE. RDMO CTU. Note: Alternatively, Parker #245 may do the cleanout if a CTU is not available. MIRU Parker #245. NU and test BOPE to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU upper tree assembly. Note: As a dedicated producer, a CBL will not be run unless there are problems with cement job. Shut in and secure well. Clean location and release rig. 3K-23 Proposed Bonzai Completion Top of cement 500' min above top possible pay Evaluate best placement of bottom GLM based on angle 3-1/8" 5M FMC tubing hanger with 3-1/2" L-80 EUE 8rd pin down. N. 3-1/2", 9.3#, L-80 EUE 8rd Mod tbg to surface M. 3-1/2" CAMCO 'DS' landing nipple with 2.812" ID No-Go profile set at +/- 500' MD. L. 3-1/2", 9.3#, L-80 EUE 8rd Mod tubing to 'DS' landing nipple w/3-1/2" x 1" BST 'AXT' mandrels with DV's and T-1 latch; BTC Mod SPCL conx on mandrels require XO L-80 handling pups. Space out as follows: GLM# MD-RKB TVD-RKB 2 3 4 5 6 K. 3-1/2" x 1" BST 'AXT' mandrel w/DV and T-1 BST latch. L-80 crossover handling pups (BTC pin x Special Clearance EUE 8rd) installed on GLM. J. 1 jt 3-1/2" L-80 EUE Srd MOD tbg (may require more to keep GLM below 65° angle) I. 3-1/2" CAMCO 'D' landing nipple with 2.750" ID and NoGo profile H. GBH-22 seal assembly w/10' stroke and Iocator; 6'x 3-1/2" L-80 pup made up on top of the seal assembly. G. 12' PBR, 4" x 5" LTC pin x pin with XOs to 5-1/2" L-80 15.5# LTC-M on top and 4-1/2" L-80 12.75, EUE-M on btm Possible 4-1/2" L-80 12.75# EUE-M to allow future access to C or B Sand. F. One 6' x 4-1/2" L-80 pup, EUE 8rd box to BTC pin Base of cement Horizontal or near-horiz E. Halliburton 4-1/2" Type H ES Cementer with BTC connections D. Baker External Casing Packer, 4-1/2" x 20', with 8' pup on top and 2' pup on btm to reach BTCM box x pin Approx. top of A Sand pay C. Halliburton4-1/2" baffle adaptor; includes two-stage free-fall plug set; shutoff & closing plugs are combo 5.5" x 4.5", each must be less than 24" in length. BTC. Straight-bladed rigid centralizers to ___65°, bowspring or turbulators above. B. 4-1/2" K-55 11.6# BTC-M (? possible change) pre-perforated casing: 24 hpf, 0.5" holes, 60° phasing, DE-BURRED some blank joints possible A. Baker 4-1/2" V-Set Shoe, BTCM DKP 4/11/97 DRILLING FLUID PROGRAM Well KRU 3K-23 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9,5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2422 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3K-23 is 3K-04. As designed, the minimum distance between the two wells would be 12' @ 20'. Drillin~l Area Risks: Risks in the 3K-23 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3K-23 Incidental fluids developed 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. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3K-23 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3K-23 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3K surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4053 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range, Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wai~tes'~-~-~ec!ated w~th drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, Inc. Pad 3K 23 slot #23 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 23 Version Our ref : prop1796 License : Date printed : 9-May-97 Date created : 27-Aug-96 Last revised : 9-May-97 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 25 48.667, w149 45 49.2 Slot location is n70 26 1.914,w149 45 39.869 Slot Grid coordinates are N 6008340.698, E 529308.610 Slot local coordinates are 1347.00 N 318.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <466 - ????>,,27, Pad 3K 26 Version #2,,26,Pad 3K PGMS <O-9150'>,,1,Pad 3K 3K-35IE Version #1,,IE,Pad 3K PGMS <O-9960'>,o2,Pad 3K PGMS <0-8900'>,,3,Pad 3K PGMS <0-8980'>,,4,Pad 3K PGMS <0-8140'>,,5,Pad 3K PGMS <0-8100'>~,6,Pad 3K PGMS <0-8500'>,,7~Pad 3K PGMS <O-8500'>,,8,Pad 3K PGMS <0-7580'>,,9A,Pad 3K PMSS <5275 - 7443'>,,9,Pad 3K PGMS <0-7300'>,~10,Pad 3K PGMS <0-7853'>,,11,Pad 3K PGMS <0-7770'>~12,Pad 3K PGMS <0-8580'>,~13,Pad 3K PGMS <0-8960'>,~14,Pad 3K PGMS <0-9275'>,,15,Pad 3K PGMS <0-9843'>,,18,Pad 3K 30 Version #2,,30,Pad 3K PGMS <0-9584'>~17,Pad 3K PGMS <0-9038'>,,16,Pad 3K H Version #2,,H,Pad 3K 32 Version #2,,32,Pad 3K Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 6-May-97 99.8 280.0 540.0 7-Apr-97 75.0 700.0 700.0 10-0ct-96 87.0 20.0 20.0 25-Feb-97 325.0 280.0 280.0 10-0ct-96 62.0 20.0 20.0 10-0ct-96 37.0 20.0 20.0 10-0ct-96 12.0 20.0 20.0 10-0ct-96 12.9 140.0 140.0 10-0ct-96 33.1 800.0 800.0 10-0ct-96 61.0 600.0 825.0 10-0ct-96 85.1 850.0 850.0 10-0ct-96 106.9 825.0 825.0 10-0ct-96 106.9 825.0 825.0 10-0ct-96 187.0 20.0 20.0 10-0ct-96 208.6 850.0 850.0 10-0ct-96 237.2 520.0 520.0 10-0ct-96 263.0 20.0 20.0 10-0ct-96 287.0 20.0 340.0 10-0ct-96 313.0 20.0 20.0 10-0ct-96 388.0 20.0 20.0 18-Mar-97 200.0 380.0 9260.0 10-0ct-96 362.0 20.0 20.0 10-0ct-96 338.0 20.0 20.0 8-0ct-96 48.1 520.0 520.0 21-Apr-97 250.0 480.0 480.0 PMSS (SS) <648-11180'>,,22,P~'3K 7-May-97 22.8 380.0 .... 380.0 A I v Structure : Pad 5K Well : Field : Kuparuk River Unit Location : North Slope, AlaskaI East (feet) -> 500 1000 1500 2000 2500 5000 I I I [ I I I I I I I 3500 4000 45OO I I I TD LOCATION: I 3K-23E (B/A2 #3) Rvsd 6-May-97~ 1494' FSL, 773' FELI / I SEC. 28,T13N, RgE I / TARGET ¢2 - A2 Interval (EOB)/ TARGET #2 LOCATION: Begin Final Build/ 1011' FSL, 1001' FEL n End.Angle~Brop~' I SEC. 26, T13N, R9E I ueg~n ~ngle UFO/ 40.69 AZIMUTH ' ' TARGET #1 - Top A3 Interval (EOB),/- 534' (TO TARGET #1) F ~-I TARGET #1 /Top A Unit ! 26.3' FSL, 1.354' FEL J ~Ty, D~= 6..6. 3_2. ./Top B Unit / SEC. 26, T1;N, RgE I b~H--~A~ /'Top C Unit NORTH 4196 )/'Top D Unit EAST 3608 ./K-1 Marker //Bose HRZ Begin Angle Build & Final Tur/,~Companian T Sands RKB ELEVATION: 75' 5OO KOP ?¥D=?O0 TMD:?O0 DEP:O / . .3.00 ./' 7 5/8 Casing Pt IN R T T 1 Base West Sok Sands 8.61 BEG TUN 0 AROET TVD=966 TMD=967 DEP= 2 /Base West Sok Sands 1000 / 15.51 /Top West Sak Sands 18.75 DLS: .%00 deg per 100 ft 1500 24.45 B/ PERMAFROST TVD=1640 TMD=1674 DEP=203 .30.26 /Top Ugnu Sands .36.15 2000 42.03 EOC TVD=2108 TMD=2247 DEP=529 .'/EOC , , /Base Permafrost J 1547' FSL, 518' FWL I 2500 Begin Turn to Target J SEC..35, T15N, RgE J T/ UGNU SNDS TVD=2692 TMD=3051 DEP=1082 T/ W SAK SNDS TVD=3407 TMD=4036 DEP=1758 30OO 3500 4OO0 4500 5000 5500 6000 6500 7000 TANGENT ANGLE 43.42 DEG TD B/ W SAK SNDS TVD=5891 TMD=4702 DEP=2216 7 5/8" CSG PT TVD=4(~91 TMD='4977 DEP=2405 5500 CAMP T SNDS TVD=Sg21 TMD=7497 DEP=4156 BEGIN ANGLE BUILD & FINAL TURN TVD=6001 TMD=7606 DEP=4211 B/ HRZ TVO=6192 TMD=?S89 OEP=441g K-1 MARKER TVO=6283 TMD=8041 DEP=4541 T/ L)NIT D TVD=6400 TMD=8267 DEP=4752 T/ UNiT C TVD=6496 TM0=849~ OEP=4958 T/ QNIT B TVD=6535 TMD=8604 DEP=5058 ~f/7. '~ Z~['~ ~ T/ UNIT A TVD=6614 TMD=B952 0EP=5368 TARGET #1 T/ A3 INT(EOB) 46.00 '~' TVD=6632 TMI3-Ol~4 DE?=5534 Sl.S~ BEGIN ANGLE DROP TVD=6665 TMD=9624 DEP=6015 57.19 END ANGLE DROP TVD=6664 TMD=g651 DEP=6041 65.71 BEGIN FINAL BUILD TVD=6686 TMD=9935 DEP=6314 77.17 TARGET #2 T/ A2 INT(EOB) TVD=6687 TMD=9954 DEP=6332 TI) TVD=6722 TMD=10489 DEP=6846 TARGET #1 ANGLE 86.5 DEG 5000 4500 4OO0 3500 Z 5000 0 2500 ~ --i- 2000 ~ 1500 1000 5OO TARGET //2 ANGLE 86.25 DEG DLS: 5.00 deg per 100 ft I I I I I I I I I II I I II I I I I I I I I 500 1000 1500 2000 2500 5000 3500 4000 4500 5000 5500 6000 Vertical Section (feet) -> Azimuth 40.{50 with reference 0.00 Iq, 0.00 E from slot #23 I i i i I 6500 7000 o,o~eo ~.~, For: D PETRASH Bets pl~tted: 12-May-g7 P~ot Reterence ~s 23 Ve~on ~4. C~r~notes ore in feet r~erence ~ot rme Ved~el Depths ore ref~ence ~g (Park~ ~245). ARCO ALASKA, Inc. Structure : Pod 5K Well: 25 Field : Kuporuk River Unit Locofion : North Slope, Alosko 28O 260 240 220 200 180 160 A 140 I · 4-- 120 (D "-I-- lO0 O Z 8o 2O 20 4o 60 Eost (feet) -> 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 i i i B i i i i i i i J i i i ~ i i ~ i ~ i ~ i t i i 1200 1300 O0 1100 1200 1000 900 3300 8OO 700 80~ 70O 31 3000 1000 28OO 2700, 70O 1100 1000 3100 1100 1000 29OO .-""~300 ~800 ...../ ...... %00 1100 2600 900 2300 700 800 .......... '-- 3600 700..- .... 5500 (~f ........ 3400 3500 700 1300 .-"1 600 · 1200 ../'/ .- / //'"i 500 / / /'#1'400 / 280 1100 . ............ 4000 1000 ........... 3900 ...... 3800 3700 1800 260 41 I 210 I I I I I i I I I I I i I I I 0 0 20 40 60 80 100 120 Eosf (feet) -> 1900 24O 22O 2OO 180 .~ 160 / ../-" -140 A 700../'"' I Z ...-// 120 0 400 1 O0 '--'F" 80 1200 20OO I I I I I I I t I I I 140 160 180 200 220 240 6O 4O 2O 4O 6O ~UPARUK RIVER UNh~ 20" DIVERTER SCHEMATIC 6 I4 I , 3 . DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION U PON IN ITIAL 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. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 ,6 , 13 5/8" 5000 PSrBOP STACK 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. 5 BOP STACK TEST 4 I 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13.5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 1. FILL BOP STACKAND 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 KILLAND 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 RAMSAND 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 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. WELL PERMIT CHECKLISTco. .Y PROGRAM: expr] dev~ redrlO servO wellbore segr] ann disp para req~ ~ UN~T# ///~ 0 ON~O~ sHoRE ADMINISTRATION ENGINEERING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. ~ Y~ Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. I 'Y/ Well located proper distance from drlg unit boundary. '1 'Y/ Well located proper distance from other wells ..... l' YI, Sufficientacreageavailable indrillingunit ..... t.I Y/ If deviated, is wellbore plat included ........ Ii ~Y Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. . Can permit be approved before 15-day wait ....... REMARKS 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.~.~ 17. CMT vol adequate to tie-in long string to surf csg . . .~ 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~--N~~ 22. Adequate wellbore separation proposed .......... .~~N 23. If diverter required, is it adequate .......... N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate .................... N 26. BOPE press rating adequate; test to ~O~[w; psig~ 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N~/' N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY APPR ~ATE . 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~ 31. Data presented on potential overpressure zones ..... Y/N .~/ / 32. Seismic analysis of shallow gas zones .......... / N /~~- ~ ~ 33. Seabed condition survey (if off-shore) ........ / Y N ~ 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 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 Mon Aug 18 10:38:40 1997 Reel Header Service na~ne ............. LISTPE Date ..................... 97/08/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services 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: MWD RUN 2 AK-MM-70157 P. SMITH D. BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3K-23 500292277100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 18-AUG-97 MWD RUN 3 AK-MM-70157 R. GEHRES D. BREEDEN MWD RUN 4 AK-MM-7 0157 S. BURKHARDT D. LUTRICK 35 13N 09E 1347 318 .00 75.80 34.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 4969.0 6.750 10462.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 THROUGH 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE REMARK ON THE SCHLUMBERGER CBT LOG RUN ON 29 JUNE 1997. THE CBT DATA WAS TIED INTO SPERRY-SUN'S (DGR) GAMMA RAY LOG DATA RUN ON 13 JUNE 1997. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10462'MD, 6680'TVI3. 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 ....... 97/08/18 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. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 4928.0 FET 4960.0 RPD 4960.0 RPM 4960.0 RPS 4960.0 STOP DEPTH 10420.0 10427.0 10427.0 10427.0 10427.0 RPX 4960.0 ROP 4980.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MtgD $ REMARKS: 10427.0 10462.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 4980.0 8826.0 3 8826.0 9149.0 4 9149.0 10462.0 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 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHNIM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHlVIM 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 Nsam DEPT 4928 10462 7695 11069 ROP 4.3143 961.523 190.203 10965 GR 23.3676 461.466 97.4017 10985 RPX 0.5596 2000 12.0932 10935 RPS 0.05 2000 15.6947 10935 RPM 0.05 2000 27.976 10935 RPD 0.05 2000 33.3017 10935 FET 0.1136 78.6589 1.77353 10935 First Reading 4928 4980 4928 4960 4960 4960 4960 4960 Last Reading 10462 10462 10420 10427 10427 10427 10427 10427 First Reading For Entire File .......... 4928 Last Reading For Entire File ........... 10462 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/18 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 ........... 1o0.0 Date of Generation ....... 97/08/18 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 NIIMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4928.0 4960 0 4960 0 4960 0 4960 0 4960 0 4980 0 2.17f 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 MINIMUM ANGLE: IfhAXIMUMANGLE: STOP DEPTH 8774 0 8781 0 8781 0 8781 0 8781 0 8781 8825 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 06-JUN-97 ISC 4.88/5.06 CIM 5.46/SP4 5.03/DEPII MEMORY 8826.0 4980.0 8826.0 42.8 78.7 TOOL NUMBER P0715SP4 P0715SP4 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) : 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 6.750 6.8 LSND 200.00 46.0 9.0 6OO 8.4 2.400 1.580 3.100 2.700 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 RPX MWD 2 OHF/M 4 1 68 8 3 RPS ~4D 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 51.7 First Name Min Max Mean Nsam Reading DEPT 4928 8825.5 6876.75 7796 4928 GR 40.8129 461.466 111.378 7693 4928 RPX 0.5596 2000 3.72127 7643 4960 RPS 0.05 2000 3.98244 7643 4960 Last Reading 8825.5 8774 8781 8781 RPM 0.05 2000 7.90285 7643 RPD 0.05 2000 6.88656 7643 ROP 11.0655 821.388 210.544 7692 FET 0.1136 49.4831 0.816671 7643 4960 4960 4980 4960 8781 8781 8825.5 8781 First Reading For Entire File .......... 4928 Last Reading For Entire File ........... 8825.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/18 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 ....... 97/08/18 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8770 0 8775 0 8775 0 8775 0 8775 0 8775 0 8820 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.17f DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH 9096 5 9104 0 9103 0 9103 0 9103 0 9104 0 9148 5 09-JUN-97 ISC 4.88/5.06 CIM 5.46/SP4 5.03/DEPII MEMORY 9149.0 8826.0 BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE iNCLINATION (DEG MINIMVJMANGLE: MAXIMUM ANGLE: 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) : 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 9149.0 78.8 88.2 TOOL NLH~BER P0715SP4 P0715SP4 6.750 6.8 SHEARDRIL 205.80 55.0 9.0 16000 5.4 .420 .190 .330 .670 75.0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHI41~ 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 Na/ne DEPT GR RPX RPS RPM RPD ROP FET Min 8770 25 4755 3 2317 3 6146 4 0386 4 1134 17 5105 0 5122 Max Mean Nsam 9148.5 8959.25 758 126.702 67.2026 654 110.4 28.0485 659 124.971 34.7579 657 317.41 55.2381 657 422.179 57.7415 657 961.523 164.249 658 32.3492 7.56695 659 First Reading 8770 8770 8775 8775 8775 8775 8820 8775 Last Reading 9148.5 9096.5 9104 9103 9103 9103 9148.5 9104 First Reading For Entire File .......... 8770 Last Reading For Entire File ........... 9148.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/18 Maximum Physical Record..65535 File Type - LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 4 .5000 START DEPTH 9090 0 9100 0 9100 0 9100 0 9100 0 9100 0 9140 0 STOP DEPTH 10420.0 10427 0 10427 0 10427 0 10427 0 10427 0 10462 0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.17f DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: I~zAXIMUM ANGLE: 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) : 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 ....................... 12-JUN-97 ISC 4.88/5.06 CIM 5.46/SP4 5.03/DEPII MEMORY 10462.0 9149.0 10462.0 84.6 90.0 TOOL NI/MBER P0694SP4 P0694SP4 6.750 6.8 SHEARDR I L 201.90 58.0 9.5 14500 4.5 .410 .225 .240 .780 58.3 .0 Datum Specification Block sub-type...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 4 AAPI 4 1 68 MWD 4 OHMM 4 1 68 MWD 4 OHMM 4 1 68 MWD 4 OHl~4 4 1 68 MWD 4 OHUIM 4 1 68 MWD 4 FT/H 4 1 68 MWD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Nalne DEPT GR RPX RPS RPM RPD ROP FET Min 9090 23 3676 5 5464 8 9375 10 8343 12 6608 4 3143 0.311 Max Mean Nsam 10462 9776 2745 102.73 64.1282 2661 148.054 32.208 2655 441.702 44.6929 2655 2000 79. 0852 2655 2000 103.537 2655 935.156 137.344 2645 78.6589 3.44972 2655 First Reading 9090 9090 9100 9100 9100 9100 9140 9100 Last Reading 10462 10420 10427 10427 10427 10427 10462 10427 First Reading-For Entire File .......... 9090 Last Reading For Entire File ........... 10462 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/18 Origin ................... STS Reel Name ................ IZNK_NOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Scientific Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
