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Home My WebLink About186-027Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 25-Jun-24 0 1 2 3J-14 50-029-21496-00 909382822 Kuparuk River Patch Setting Record Field- Final 29-Jun-24 0 1 3 3N-06 50-029-21538-00 n/a Kuparuk River Plug Setting Record Field- Final 1-May-24 0 1 4 3S-610 50-103-20875-00 909539033 Kuparuk River Plug Setting Record Field- Final 31-May-24 0 1 5 3S-626 50-103-20878-00 909417481 Kuparuk River Cement Evaluation with CASTField & Processed 19-Jun-24 0 1 6 3T-621 50-103-20882-00 909382821 Kuparuk River Correlation Record Field- Final 20-Jun-24 0 1 7 3T-621 50-103-20882-00 909394238 Kuparuk River Sigma and Gadolinium AnalysField & Processed 22-Jun-24 0 1 8 9 10 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: T39140 T39141 T39142 T39143 T39144 T39145 T39145 209-103 185-288 186-027 223-126 224-007 224-022 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 11:36:20 -08'00' 3N-06 50-029-21538-00 n/a Kuparuk River Plug Setting Record Field- Final 1-May-24 0 1 T39142 186-027 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7750'feet None feet true vertical 6691' feet None feet Effective Depth measured 7447'feet 6970', 7046'feet true vertical 6448' feet 6081', 6139' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 6999' MD 6103' TVD Packers and SSSV (type, measured and true vertical depth) 6970' MD 7046' MD N/A 6081' TVD 6139' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Authorized Title: 3707' 3596' Burst Collapse Production Liner 7693' 4087' Casing 6677' 5-1/2" 7731' 7119' 6194' 3669' 115'Conductor Surface Intermediate 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-027 50-029-21538-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025521 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3N-06 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1 Gas-Mcf MD 1226 Size 115' 1637 1309703 207 168679 182 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 914 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer SSSV: None Well Integrity Specialist 7306-7324', 7407-7432', 7434-7460' 6336-6351', 6416-6436', 6437-6458' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Contact Name:Jan Byrne Contact Email:jan.byrne@conocophillips.com Contact Phone: (907) 265-6471 By Grace Christianson at 1:33 pm, May 21, 2024 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.05.21 05:53:11-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DSR-5/22/24 RBDMS JSB 052824 DTTMSTART JOBTYP SUMMARYOPS 3/4/2024 ACQUIRE DATA (AC-EVAL) OBTAINED OA-LLR OF 1.0 BPM @ 30 PSI (COMPLETE) 4/5/2024 REPAIR WELL ATTEMPT TO PERFORM RST WATERFLOW LEAK DETECTION LOG TO LOCATE POTENTIAL LEAK IN PRODUCTION CASING. BASELINE PASS DOWN, LIGHTLY TAG PRONG AT 7053'. LRS ONLINE W/ CISW DOWN THE OA, TUBING PRESSURE TRACKING (9.4 BBLS CISW PUMPED BEFORE REACHING MAX ALLOWABLE OA PRESSURE). POOH AND ATTEMPT MIT-T, OA TRACKING. PERFORM PASSING CMIT T X OA TO 1725 PSI. UNABLE TO U-TUBE OR TAKE RETURNS DUE TO PAD BEING OFFLINE, LRS WILL RETURN TO DETERMINE TxOA LLR AND FP OA. ***JOB IN PROGRESS*** 4/5/2024 REPAIR WELL PUMP 48 BBLS DSL DWN TBG, TAKING RETURNS UP OA, U-TUBE TO FREEZE PROTECT TBG X OA FOR 45 MINUTES (UNABLE TO VERIFY THAT TBG X OA ACTUALLY U-TUBE THROUGH SOUND OR NOTICABLE FLOW TBG LEAK INTO OA @ 2300 PSI= 0.72 BPM READY FOR E-LINE 4/6/2024 REPAIR WELL PERFORM LEAK DETECTION LOG TO DETERMINE LOCATION OF T X OA COMMUNICATION. LOG BASELINE PASS DOWN FROM SURFACE TO 7055' AT 120 FPM. LRS ONLINE PUMPING DIESEL DOWN THE TUBING TAKING RETURNS UP THE OA TO NEIGHBORING FLOWLINE. ESTABLISH LLR OF .5 BPM AT 1400 PSI. LOG UP AND LOCATE LEAK AT 7020'. LOG STATION STOPS TO CONFIRM. NO OTHER LEAKS IDENTIFIED. LRS U-TUBE T X OA FOR FP. JOB COMPLETE, READY FOR PLAN FORWARD 4/7/2024 PUMPING TRACKING ONLY FREEZE PROTECT PUMPED 10 BBLS MeOH DWN FLOWLINE JOB COMPLETE 4/22/2024 ACQUIRE DATA DRIFT & TAG 2.31" PXX PLUG W/ 10'X2" BAILER @ 7060' RKB, RUN 24 ARM CALIPER FROM 7060' RKB TO SURFACE, GOOD DATA .JOB COMPLETE 4/30/2024 REPAIR WELL BAILED ~ 8' OF SCALE FROM 2 7/8 EQ PRONG @ 7053' RKB, PULLED 2 7/8 EQ PRONG @ 7053' RKB, PULLED 2.31 XX PLUG @ 7060' RKB. IN PROGRESS. 5/1/2024 REPAIR WELL BRUSH n' FLUSH TBG TO 7100' RKB, CLEAN DRIFT W/ 31.5' DUMMY 2.29" PATCH TO 7100' RKB, SET LOWER 2.29" P2P @ 7048' RKB (CE) (3.55' / SN: CPP287055), MIT TBG 2400 (PASS) WITH NO COMMUNICATION TO OA @ THIS TIME. SET 2.224" PBR SPACER ANCHOR LATCH (OAL 28.98' / SN: CPBR7013 / CPAL287057) IN LOWER 2.29" P2P @ 7048' RKB. IN PROGRESS. 5/2/2024 REPAIR WELL GOOD TBG TEST TO 2400 PSI W/ 2 7/8 TTS TEST TOOL IN 2.224" PBR @ 7017.67' RKB, SET 2.224" PBR SPACER ANCHOR LATCH @ 6994.44' RKB (OAL 24.03' / SN:CPBR287010 / CPAL287041), CMIT TBG x OA (FAILED) TROUBLE SHOOT FAILURE, PULLED 2.224" PBR ASSEMBLY @ 6994' RKB, RAN 2 7/8 TTS TEST TOOL TO 2.224" PBR @ 7017' RKB CMIT TBG x OA TO 2400 PSI (PASS). IN PROGRESS. 5/3/2024 REPAIR WELL SET MIDDLE 2.224" PBR SPACER ANCHOR LATCH (OAL 24.01' / SN: CPBR287010 / CPAL287047) IN LOWER 2.224" PBR @ 7017' RKB TOP @ 6994' RKB, CMIT TBG x OA TO 2400 PSI WITH 2 7/8 TTS TEST TOOL IN PBR @ 6994' RKB (PASS), ATTEMPT TO SET UPPER 2.29" P2P W/ EXPANSION JOINT @ 6973' RKB UNABLE TO STAB INTO PBR @ 6994' RKB. IN PROGRESS. 5/4/2024 REPAIR WELL PULLED 2.224" PBR ASSEMBLY @ 6994' RKB (PBR DAMAGED), CMIT TBG x OA 2400 PSI (PASS) WITH 2 7/8 TTS TEST TOOL IN PBR @ 7017.67' RKB, SET 2.24" PBR W/ BOW SPRING SPACER ANCHOR LATCH @ 6991' 56' RKB (OAL 26.9' / SN: CPBR287009 / CPBSC150005 / CPAL287050), CMIT TBG x OA 2400 PSI (PASS) WITH 2 7/8 TTS TEST TOOL IN PBR @ 6991.56', SET 2.29" P2P BOW SPRING EXPANSION JOINT ANCHOR LATCH (OAL 19.33' / SN: CPP287086 / CPTJ228007 / CPBSC150006 / CPAL287033) @ 6970.42 (CE) TOP @ 6972.57' RKB, MIT TBG 2500 PSI WITH 2 7/8 TTS TEST TOOL IN UPPER 2.29" P2P @ 6972' RKB (PASS), MIT OA TO 2400 PSI (PASS). JOB COMPLETE. 3N-06 Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,447.0 3N-06 10/27/2021 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug, Set tubing patch 3N-06 5/4/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 (2 pages/print double sided) 2/25/2010 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 38.2 88.2 88.2 62.58 H-40 Welded SURFACE 9 5/8 8.83 38.2 3,707.0 3,595.6 36.00 J-55 BT&C PRODUCTION 7 6.28 38.2 7,731.1 6,676.8 26.00 J-55 BT&C LINER - 2015 TIEBACK - 5 1/2" x 4 1/2" x 2 7/8" 5 1/2 4.94 32.5 7,119.4 6,193.8 15.50 L-80 5.5 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.5 Set Depth … 6,998.8 Set Depth … 6,103.1 String Max No… 2 7/8 Tubing Description Tubing – Completion Upper Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE 8rd ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.5 32.5 0.02 HANGER 11.000 FMC TUBING HANGER FMC TC-1A- EMS 2.922 35.8 35.8 0.02 XO - Reducing 3.500 3 1/2" 8rd box x 2 7/8" 8rd pin Crossover XO 2.922 2,515.6 2,514.8 8.32 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.366 4,119.9 3,914.0 41.08 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.366 5,409.6 4,908.0 40.40 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.366 6,447.3 5,685.9 41.17 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.366 6,917.8 6,041.7 40.59 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.366 6,976.8 6,086.5 40.79 LOCATOR 3.450 BAKER LOCATOR Baker Locator 2.441 6,977.9 6,087.3 40.79 Stick Up 2.875 7-ft Stick-Up. Tubing 2.441 6,984.9 6,092.6 40.82 SEAL ASSY 3.230 BAKER 80-32 PBR Baker 80-32 PBR 2.410 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 120.0 120.0 0.06 LEAK - CASING Surface casing leak at 120' 1/1/1984 8.500 6,969.9 6,081.3 40.77 PACKER - PATCH - UPR 2.29" PIIP Upper patch packer set mid-element @ 6972.05' RKB (Upper patch section consists of Upper Packer, spacer pipe, splined expansion joint stroked open 5', Bow Spring Centraliser, Anchor Latch) (OAL = 25.53') TTS PIIP CPP2 87086 5/4/2024 1.375 6,973.1 6,083.7 40.78 ANCHOR LATCH ON SPACER PIPE Part of upper patch section TTS CPTJ 22800 7/CPB SC15 0006/ CPAL 28703 3 5/4/2024 1.370 6,991.6 6,097.6 40.84 ANCHOR LATCH ON SPACER PIPE Middle section of patch (PBR, Bow Spring Centraliser, Spacer Pipe, Anchor Latch) (OAL = 26.1') TTS CPBR 28700 9/CPB SC15 0005/ CPAL 28705 0 5/4/2024 1.379 7,017.7 6,117.4 40.98 ANCHOR LATCH ON SPACER PIPE Lower section of patch (PBR, Spacer Pipe, Anchor Latch) (OAL = 28.18') TTS CPBR 28701 3/CPA L2870 57 5/1/2024 1.379 7,020.0 6,119.1 40.99 LEAK TBG LEAK IDENTIFIED BY LDL AT 7020' RKB 4/6/2024 2.441 7,045.9 6,138.6 41.15 PACKER - PATCH - LWR 2.29" PIIP Lower Patch Packer set mid-element @ 7048' RKB. (OAL = 3.55') TTS PIIP CPP2 87065 5/1/2024 1.375 7,115.0 6,190.6 41.31 TUBING CUT TUBING CUT W/ CHEM CUTTER @ 7115' RKB 8/25/2015 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,515.6 2,514.8 8.32 1 GAS LIFT GLV BK 1 1,330.0 4/8/2018 CAMCO KBMG 0.188 4,119.9 3,914.0 41.08 2 GAS LIFT GLV BK 1 1,318.0 4/8/2018 CAMCO KBMG 0.188 5,409.6 4,908.0 40.40 3 GAS LIFT GLV BK 1 1,313.0 4/8/2018 CAMCO KBMG 0.188 6,447.3 5,685.9 41.17 4 GAS LIFT GLV BK 1 1,310.0 4/7/2018 CAMCO KBMG 0.188 6,917.8 6,041.7 40.59 5 GAS LIFT OV BK 1 0.0 12/21/2023 CAMCO KBMG 0.188 3N-06, 5/14/2024 11:40:52 AM Vertical schematic (actual) PRODUCTION; 38.2-7,731.1 IPERF; 7,446.0-7,460.0 RPERF; 7,434.0-7,459.0 RPERF; 7,435.0-7,447.0 IPERF; 7,440.0-7,441.0 RPERF; 7,407.0-7,432.0 IPERF; 7,416.0-7,417.0 RPERF; 7,410.0-7,419.0 IPERF; 7,414.0-7,415.0 IPERF; 7,306.0-7,324.0 LINER - 2015 TIEBACK - 5 1/2" x 4 1/2" x 2 7/8"; 32.5-7,119.4 TUBING CUT; 7,115.0 PACKER - PATCH - LWR; 7,045.9 ANCHOR LATCH ON SPACER PIPE; 7,017.7 LEAK; 7,020.0 ANCHOR LATCH ON SPACER PIPE; 6,991.6 ANCHOR LATCH ON SPACER PIPE; 6,973.1 PACKER - PATCH - UPR; 6,969.9 GAS LIFT; 6,917.8 GAS LIFT; 6,447.3 GAS LIFT; 5,409.6 GAS LIFT; 4,119.9 SURFACE; 38.2-3,707.0 GAS LIFT; 2,515.6 LEAK - CASING; 120.0 CONDUCTOR; 38.2-88.2 HANGER; 32.5 KUP PROD KB-Grd (ft) 38.49 RR Date 3/1/1986 Other Elev… 3N-06 ... TD Act Btm (ftKB) 7,750.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292153800 Wellbore Status PROD Max Angle & MD Incl (°) 42.47 MD (ftKB) 5,800.00 WELLNAME WELLBORE3N-06 Annotation Last WO: End Date 9/28/2015 H2S (ppm) 110 Date 3/12/2014 Comment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,987.1 6,094.3 40.83 XO - Reducing 5.500 4 1/2" IBT pin x 5 1/2" BTC box Crossover XO 3.370 7,011.3 6,112.6 40.94 XO - Reducing 4.270 4 1/2" IBT box x 2 7/8" pin Crossover. XO 2.440 7,026.4 6,124.0 41.03 PBR 4.270 BAKER 80-32 PBR Baker PBR 3.250 7,039.8 6,134.1 41.11 PACKER 5.500 BAKER FH PACKER Baker FH packer 2.400 7,060.7 6,149.8 41.24 NIPPLE 5.500 X NIPPLE Camco X Nipple 2.313 7,110.0 6,186.8 41.37 OVERSHOT 2.870 2 FT STICK UP Baker Pup Jt 2.430 7,112.0 6,188.3 41.35 OVERSHOT 3.510 BAKER POORBOY OVERSHOT Baker Overshot 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,306.0 7,324.0 6,336.5 6,350.6 C-2, 3N-06 4/21/1986 12.0 IPERF 120° ph; 5" HJ II Csg Gun 7,407.0 7,432.0 6,415.8 6,435.6 A-3, 3N-06 7/21/2018 6.0 RPERF 2" Powerjet; HMX HSD 60° Phasing 7,410.0 7,419.0 6,418.2 6,425.3 A-3, 3N-06 1/2/1989 8.0 RPERF 60° ph;2 1/8" EnerJet 7,414.0 7,415.0 6,421.4 6,422.2 A-3, 3N-06 4/21/1986 1.0 IPERF 4" Csg Gun 7,416.0 7,417.0 6,423.0 6,423.7 A-3, 3N-06 4/21/1986 1.0 IPERF 4" Csg Gun 7,434.0 7,459.0 6,437.2 6,457.1 A-2, 3N-06 7/21/2018 6.0 RPERF 2" Powerjet; HMX HSD, 60 deg Phasing 7,435.0 7,447.0 6,438.0 6,447.5 A-3, 3N-06 1/1/1989 8.0 RPERF 60° ph;2 1/8" EnerJet 7,440.0 7,441.0 6,442.0 6,442.8 A-3, 3N-06 4/21/1986 1.0 IPERF 4" Csg Gun 7,446.0 7,460.0 6,446.8 6,457.9 A-2, 3N-06 4/21/1986 4.0 IPERF 90° ph; 4" HJ II Csg Gun 3N-06, 5/14/2024 11:40:52 AM Vertical schematic (actual) PRODUCTION; 38.2-7,731.1 IPERF; 7,446.0-7,460.0 RPERF; 7,434.0-7,459.0 RPERF; 7,435.0-7,447.0 IPERF; 7,440.0-7,441.0 RPERF; 7,407.0-7,432.0 IPERF; 7,416.0-7,417.0 RPERF; 7,410.0-7,419.0 IPERF; 7,414.0-7,415.0 IPERF; 7,306.0-7,324.0 LINER - 2015 TIEBACK - 5 1/2" x 4 1/2" x 2 7/8"; 32.5-7,119.4 TUBING CUT; 7,115.0 PACKER - PATCH - LWR; 7,045.9 ANCHOR LATCH ON SPACER PIPE; 7,017.7 LEAK; 7,020.0 ANCHOR LATCH ON SPACER PIPE; 6,991.6 ANCHOR LATCH ON SPACER PIPE; 6,973.1 PACKER - PATCH - UPR; 6,969.9 GAS LIFT; 6,917.8 GAS LIFT; 6,447.3 GAS LIFT; 5,409.6 GAS LIFT; 4,119.9 SURFACE; 38.2-3,707.0 GAS LIFT; 2,515.6 LEAK - CASING; 120.0 CONDUCTOR; 38.2-88.2 HANGER; 32.5 KUP PROD 3N-06 ... WELLNAME WELLBORE3N-06 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-04-22_23023_KRU_3N-06_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23023 KRU 3N-06 50-029-21538-00 Caliper Survey w/ Log Data 22-Apr-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 186-027 T38756 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 10:00:19 -08'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϲϬϮϳϬͲ^Ğƚ͗ϯϲϭϰϳJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS . 1.Operations Abandon [ Plug Perforations 3.._.. Fracture Stimulate ....... Pull ""w Operations Shutdown 7 Performed: Suspend 1 Perforate I- Other Stimulate j...._ Alter Casing r.% Change Approved Program 1- Plug for Redrill 7 Perforate New Pool E Repair Well F.07 Re-enter Susp Well I— Other r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen " Exploratory 1...... 186-027 3.Address: 6.API Number: Stratigraphi [7 Service 1 P. O. Box 100360,Anchorage,Alaska 99510 50-029-21538-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 255521 KRU 3N-06 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 7750 feet Plugs(measured) none true vertical 6692 feet Junk(measured) none Effective Depth measured 7646 feet Packer(measured) 7040, 7151,7355 true vertical 6607 feet (true vertical) 6134, 6218,6375 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80 0 0 SURFACE 3670 11 3707 3596 0 0 PRODUCTION 7696 7.656 7731 6391' 0 0 LINER 7087 5.5 7119 6194 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7306-7324, 7410-7419, 7435-7460 True Vertical Depth: 6337-6351,6418-6425,6438-6458 RECEIVE: Tubing(size,grade,MD,and TVD) 2.875, L-80, 7376 MD,6391 TVD NOV 0 6 22015 Packers&SSSV(type,MD,and TVD) PACKER-BAKER FH PAKER @ 7040 MD and 6134 TVD OGCC PACKER-AVA'RHS' RETRIEVABLE PACKER @ 7151 MD and 6218 TVD PACKER-BROWN'1 B'PERMANENT PACKER @ 7355 MD and 6375 TVD SAFETY VLV-none 12.Stimulation or cement squeeze summary: C Intervals treated(measured): NE' APR 0 8 2016 Treatment descriptions including volumes used and final pressure: )C�" 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Daily Report of Well Operations P 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Copies of Logs and Surveys Run [W_ Exploratory 17 Development I✓ Service 17 Stratigraphic P none 16.Well Status after work: Oil 3v., Gas I...... WDSPL r .. Printed and Electronic Fracture Stimulation Data F...... GSTOR ...... WINJ 17 WAG r GINJ r SUSP p 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: 315-467 Contact Theresa Lee 263-4837 Email Theresa.M.Lee(a�conocophillips.com Printed Name ,Theresa Lee Title Wells Engineer Signature III,�JiJ�1�V ` Phone:263-4837 Date \ ' J 'J / Form 10-404 Revised 5/2015 Y�I L 3//rl/b L Submit Original Only "0 X177% RBDMS'� NOV 1 0 2015 • • Daily Operations Summary ting W+ 3N-06 ConocoPhi lips Rig: NABORS 7ES Job: RECOMPLETION Daily Operations Start Date Last 24hr Sum 9/28/2015 Completed 1E-33 Program. Begin to Move Nabors Rig 7es to 3N-Pad. 9/29/2015 Move to Oliktok"Y". Park Rig for Kuparuk Field change out. Move Rig mats as needed.Continue moving to 3N-06 pad. 9/30/2015 Complete Rig move to 3N-Pad. Rig up Nabors 7es at 3N-06 Well slot. Kill well, N/D tree and N/U BOPE. 10/1/2015 N/U BOPE,function test NCR's and body test BOP's.Test BOPE witnessed by AOGCC Rep. Matt Herrera, Annular preventer failure, replace element and test. 10/2/2015 Pressure test Annular element#2.,element failed pressure test. Replaced and N/U Annular preventer. Ready preventer for pressure test. 10/3/2015 Repair and test BOPE. Pull tubing hanger free, Circulate and condition well. Pull and single down 2 7/8"tubing. Repair Koomey unit. Pull and single down tubing to 3,130'. Set Storm packer and N/D BOP's and tubing head. Spear 7"casing and re-energize casing slips. Cut 1.29'of excess 7"casing and set pack-off. N/U FMC Gen 5 casing head. 10/4/2015 N/U 11"3M X11"5M 5 1/2"casing head. N/U BOP's. Test casing head and BOP's. Pull remaining 2 7/8"tubing. Change to 5 1/2"rams and test. RIH with 5 1/2"liner and 2 7/8"lower completion. 10/5/2015 Run 5 1/2"liner and lower 2 7/8"completion to 7,119'. Pump corrosion inhibitor and diesel freeze protect. Shear seal assembly from PBR. Set slips,cut and dress 5 1/2"liner. Pressure test pack-off. N/U BOP's and pressure test VBR's. RIH with 2 7/8"gas lift completion. 10/6/2015 Run 2 7/8"gas lift completion. Space out. Pump corrosion inhibitor. Land hanger. Pressure test tubing and casing. Shear out of SOV. Between well maintenance. N/D BOPE and N/U Tree.Test Tree and pack-off. 10/7/2015 Freeze protect,equalize fluids, Install BPV and RD LRS. Release rig at 09:00 10/7/2015 Page 1/1 Report Printed: 11/4/2015 4 4 KUP PROD • 3N-06 • ConocoPhillipisWell Attributes Max Angle&MD TD Alaska inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r,a,,,,rvalps 500292153800 KUPARUK RIVER UNIT PROD 42.47 5,800.00 7,750.0 .." Comment H2S(ppm) Date Annotation End Date KB-GM(ft) Rig Release Date 35-00,11/5201511:00,48.AM SSSV NONE 110 3/12/2014 Last WO: 9/28/2015 38.49 3/1/1986 VertcalschematcJaealag Annotation Depth(ftKB) End Date Annotation Last Mod By End Date , p Last Tag:SLM 7,469.0 10/24/2015 Rev Reason:GLV C/O,PULLED CATCHER, pproven 10/29/2015 HANGER;32.5- WRP and TAG Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.,,Grade Top Thread ' ��.. 'Ir CONDUCTOR 16 15.062 38.2 88.2 88.2 62.58 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread ✓�SURFACE 9 5/8 8,835 38.2 3,707.0 3,595.6 36.00 J-55 BT&C Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.2 7,731.1 6,676.8 26.00 J-55 BT&C Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.,,Grade Top Thread CONDUCTOR;382-8e.2-45 1 . LINER-2015 TIEBACK- 51/2 4.940 32.5 7,119.4 6,193.8 15.50 L-80 5.5BTC 51/2"x4112"x2718" iiii Liner Details GAS LIFT',2,515.6 ' Nominal ID IR Top(ftKB) Top(ND)(ftKB) Top Incl 71 Item Des Com (in) 6,987,1 6,094.3 40.83 XO-Reducing 4 1/2"IBT pin x 5 1/2"BTC box Crossover 3.370 t 6,989.8 6,096.3 40.84 SBE BAKER SEAL BORE EXTENSION 3.250 7,011.3 6,112.6 40.94 XO-Reducing 4 1/2"IBT box x 2 7/8"pin Crossover. 2.440 SURFACE;38.2-3,707,0 7,024.4 6,122.5 41.02 SEAL ASSY Seal Assembly 2-ft Stick-Up...11.3 t remains stung in 2.440 a PBR GAS LIFT:4,119.9 7,026.4 6,124.0 41.03 PBR BAKER 80-32 PBR 3.250 7,039.8 6,134.1 41.11 PACKER BAKER FH PACKER 2.400 I i 7,060.7 6,149.8 41.24 NIPPLE CAMCO X NIPPLE 2.400 GAS LIFT;5,409.6 ;- 7,110.0 6,186.8 41.37 OVERSHOT 2 FT STICK UP 2.430 11 t 7,112.0 6,188.3 41.35 OVERSHOT BAKER POORBOY OVERSHOT 3.000 Tubing Strings GAS LIFT,6447.3 Iff i Tubing Description Strang Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection �. I TUBING-WO 2015- 2 7/8 2.441 32.5 6,998.8 6,103.1 6.50 1-80 EUE 8rd II 3 1/2"x 2 7/8"@35.83 Completion Details GAS LIFT;6,917.8 l Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) II 32.5 32.5 0.02 HANGER FMC TUBING HANGER 2.922 1. 35.8 35.8 0.02 XO-Reducing 3 1/2"8rd box x 2 7/8"8rd pin Crossover 2.922 LOCATOR;6,9788 6,976.8 6,086,5 40.79 LOCATOR BAKER LOCATOR 2.441 6,977.9 6,087.3 40.79 Stick Up 7-ft Stick-Up. 2.441 SEAL ASSY,6E84.9 _ 6,984.9 6,092.6 40.82 SEAL ASSY BAKER 80-32 PBR 2.410 N._ Tubing Description Stang Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING-ORIGINAL 27/8 2.441 7,115.0 7,375.7 6,391.1 6.50 L-80 EUE8r4ABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 1°) Item Des Com (in) . 7,136.5 6,206.7 41.08 PBR AVA'LSU'PBR 2.374 7,151.1 6,217.8 40.91 PACKER AVA'RHS'RETRIEVABLE PACKER 2.374 7,352.3' 6,372.7 38.31 SEAL ASSY BAKER GB-22 80/32 LOCATOR/SEAL ASSEMBLY 2.406 w/one half MULESHOE BOTTOM 7,355.4 6,375.1 38.28 PACKER BROWN'1 B'PERMANENT PACKER 3.250 7,367.6 6,384.7 38.13'NIPPLE CAMCO'D'NIPPLE 2.250 7,375.0 6,390.6 38.04 SOS CAMCO SHEAROUT SUB 2.875 TUBING CUT;7,115.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LINER-2015 TIEBACK-5112' Top(ND) Top Incl 0 41/2-z 27/8.32.5-7,119.4 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,115.0 6,190.6 41.31 TUBING CUT TUBING CUT W/CHEM CUTTER @ 7115'RKB 8/25/2015 PBR;7,138.5 PACKER;7,151 1 = - Perforations&Slots , Shot PRODUCTION;7,186.2 Dens j Top(TVD) Ben(ND) (shots/f PRODUCTION;7,2577 Top(ftKB) Ben(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,306.0 7,324.0 6,336.5 6,350.6 A-3,3N-06 4/21/1986 12.0 IPERF 120 deg ph;5"HJ II Csg Gun IPERF;7,308.0-7,324.0- 7,410.0 7,419.0 6,418.2 6,425.3 A-3,3N-06 1/2/1989 8.0 RPERF 60 deg ph;2 1/8"EnerJet IF PRODUCTION;7,333.8 7,414.0 7,415.0 6,421.4 6,422.2 A-3,3N-06 4/21/1986 1.0 IPERF 4"Csg Gun SEAL ASSY;7,352.3 7,416.0 7,417.0 6,423.0 6,423.7 A-3,3N-06 4/21/1986 1.0 (PERF 4"Csg Gun 7,435.0 7,447.0 6,438.0 6,447.5 A-3,3N-06 1/1/1989 8.0 RPERF 60 deg ph;2 1/8"EnerJet PACKER;7,355 3 7,440.0 7,441.0 6,442.0 6,442.8 A-3,3N-06 4/21/1986 1.0 IPERF 4"Csg Gun NIPPLE;7,367 6 a 7,446.0- 7,460.0 6,446.8 6,457.9 A-2,3N-06 4/21/1986 4.0 IPERF 90 deg ph;4"HJ II Csg ill Gun SOS;7,375.0 Mandrel Inserts sr I - ae IPERF;7,414.0-7,415.0 -- on Top(ND) Valve Latch Port Size TRO Run RPERF;7,410.0-],419.0 N Top(ftKB) (ftKB) Make Model OD in Sam Type Type (in)) ( ) y (psi) Run Date Com 2,515.6 2,514.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 10/24/2015 IPERF;7,416.0-7,417.0 c 2 4,119.9 3,914.0 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 10/24/2015 3 5,409.6 4,908.0 CAMCO KBMG 1 GAS LIFT DMY BK-5 0,000 0.0 10/24/2015 IPERF;7,440.0-7,441.0 Lam. RPERF;7,435.0-7,447.0- 4 6,447.3 5,685.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/4/2015 5 6,917.8 6,041.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/4/2015 IPERF;7,446.0-7,460.0- 6 7,186.2 6,244.3 MACCO SPM-2A 11/2 PROD DMY RK- 0.000 0.0 1/18/1993 Closed 7 7,257.7 6,299.1 MACCO SPM-2A 11/2 PROD DMY RK- 0.000 0.0 2/18/1993 Closed PRODUCTION;38.2-7,731.1 l ..1 KUP PROD • 3N-06 ConocoPhillips 4 Alaska Inc. . file 11 3N-06,11/5/2015 11:00:50 AM Vertical ac50rnatic(actual) HANGER,32.5—..1..,. t Mandrel Inserts at L !' Top(ND) Valve Latch Port Size TRO Run f`N Top(ftKB) (11KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com g 7,333.8 6,358.2 MACCO SPM-2A 11/2 PROD DMY RK- 0.000 0.0 2/18/1993 Closed • Notes:General&Safety CONDUCTOR;38.2-88.2 - - End Date Annotation 2/25/2010 NOTE VIEW SCHEMATIC w/Alaska Schematic9 0(2 pages/print double sided) GAS LIFT;2,515.6 •• SURFACE;38.2-3,707.0 GAS LIFT;4,119.9 GAS LIFT;5,409.6 GAS LIFT;6,447.3 P: GAS LIFT;6,917.8 LOCATOR',6,976 8 i SEAL ASSY,6,984.9 let iffA TUBING CUT;7,115.0 LINER-2015 TIEBACK-5 1/2' 04112'x 2718';32.5-7,119.4 PBR;7,136.5 PACKER;7,151.1 PRODUCTION;7,186.2 PRODUCTION;7,257.7lir IPERF;7,306.0-7,324.0----. i _ 11 PRODUCTION;7,333.8 SEAL ASSY',7,352.3 PACKER;7,355.3 444 NIPPLE;],36].6 SOS;7,375.0 li IPERF;7,414.0-7,415.0 _ RPERF;7,410.0-7,419.01_, IPERF;7,416.0-7,417.0 IPERF;7,440.0-7,441.0L_::::: -. RPERF;7,435.0-7,447.0-- -. IPERF;7,446.0-7,460.0— I I PRODUCTION;38.2-7,731.1 J l • i =, Milling- Operations Summary (with Timelog Depths) ={ &Wells 3N-06 ConocoPhiili Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/28/2015 9/29/2015 10.00 MIRU MOVE MOB P Prep to move Rig. Rig down Pits, 14:00 00:00 Shop,and Camp. BAck Rig off of 1E- 33 Well Slot. Lower Derrick. Begin to move off of 1 E-Pad towards Oliktok 9/29/2015 9/29/2015 12.00 MIRU MOVE MOB P Continue to move Rig to Oliktok"Y". 00:00 12:00 Park Rig th re for Kuparuk Field change out. Move rig mats as needed. 9/29/2015 9/29/2015 3.50 MIRU MOVE MOB P Continue to move Rig to 3N-Pad. 12:00 15:30 Park Rig at the CPF-3 turn-off for Kuparuk Field crew change out. Move rig mats as needed. 9/29/2015 9/30/2015 8.50 MIRU MOVE MOB P Continue to move Rig to 3N-Pad. 15:30 00:00 9/30/2015 9/30/2015 2.75 MIRU MOVE MOB P Stage rig on 3N pad and install BOP 00:00 02:45 stack and tree in the rig sub base. 9/30/2015 9/30/2015 1.75 MIRU MOVE MOB P Spot rig over 3N-06, 02:45 04:30 9/30/2015 9/30/2015 3.00 MIRU MOVE MOB P Move and connect pit module to rig. 04:30 07:30 9/30/2015 9/30/2015 1.00 MIRU MOVE RURD P Berm up Rig and Modules. Install 07:30 08:30 handrails. Set Cutting Box and berm same. Spot Kill Tank,Choke House, lay hardline. 9/30/2015 9/30/2015 2.50 MIRU MOVE RURD P Raise Derrick. Bridle down. Accept 08:30 11:00 Rig at 11:00 hrs 9/30/2015 9/30/2015 1.50 MIRU WELCTL RURD P Rig up Floor. Taking on 8.6 lb/gal Sea 11:00 12:30 Water in Pits. Insulate Cellar. Install secondary annular valve. Rig up circulating manifold. 9/30/2015 9/30/2015 1.50 MIRU WELCTL MPSP P Pick-up Lubricator. Pressure test at 12:30 14:00 2,000 psi. Good. Pull BPV. Lay down BPV and Lubricator. Well head pressures as follows: Tbg= 100 psi, IA="0"psi,OA=60 psi. 9/30/2015 9/30/2015 2.00 MIRU WELCTL RURD P Finish rigging up Cellar. Finish rigging 14:00 16:00 up Circulating Manifold. 9/30/2015 9/30/2015 0.25 MIRU WELCTL SFTY P PJSM. Discuss pressure testing and 16:00 16:15 the Well Kill operations. 9/30/2015 9/30/2015 0.25 MIRU WELCTL SEQP P Pressure test Kill Line at 3,000 psi. 16:15 16:30 Good. 9/30/2015 9/30/2015 2.50 MIRU WELCTL KLWL P Begin to kill/circulate the well with 8.6 16:30 19:00 lb/gal sea water at 3.0 bpm/660 psi. Increase rate to 5.0 bpm/1,570 psi, pump 272 bbls. 9/30/2015 9/30/2015 0.50 MIRU WELCTL OWFF P Monitor well for 30 minutes,well static. 19:00 19:30 9/30/2015 9/30/2015 0.50 MIRU WHDBOP MPSP P Set BPV and test to 1000 psi. 19:30 20:00 9/30/2015 9/30/2015 3.00 MIRU WHDBOP NUND P R/U load cell, N/D tree and adaptor 20:00 23:00 flange. Tree pulled free at 6,635 lbs, hanging weight 1,750 lbs. Inspect hanger threads and install blanking plug. 9/30/2015 10/1/2015 1.00 MIRU WHDBOP NUND P N/U DSA and BOP's. Install Koomey 23:00 00:00 fittings and lines. Page 1/6 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) &Wells 3N-06 Conocciftd1ups ALS.. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/1/2015 10/1/2015 6.50 MIRU WHDBOP NUND P N/U BOP's,function test HCR's and 00:00 06:30 change out HCR line. Body test BOP's prior to AOGCC witnessed BOP test....(AOGCC Field Inspection on the way...requested that we wait until he arrived on location before beginning the test). 10/1/2015 10/1/2015 7.00 MIRU WHDBOP BOPE P Perform the initial BOPE test as per 06:30 13:30 ConocoPhillips/AOGCC requirements at 250/3,800 psi. Using a 2 7/8"and a 3 1/2"Test Joints. Test all Gas alarms. Perform the Koomey drawdown test. Record all pressure test on chart. The test was witnessed by AOGCC Field Inspector...M. Herrera. (Note: Annular element failed to pass both the low and the high pressure with the 2 7/8"Test Joint. All other tests,good). 10/1/2015 10/2/2015 10.50 MIRU WHDBOP BOPE T Re-place the Hydril"GK"Annular 13:30 00:00 element. Unable to pass a pressure test during the initial BOPE test. 10/2/2015 10/2/2015 6.00 MIRU WHDBOP RGRP T Annular Preventer replacement 00:00 06:00 element would not hold test pressure on 2 7/8"or 3 1/2"pipe. Filled stack with water and could observe pressure leaking by seal area of element. Installing another new replacement element#2. 10/2/2015 10/2/2015 13.50 MIRU WHDBOP RGRP T Fill BOP Stack. Prep to test 06:00 19:30 replacement element#2. Annular failed both the low and the high test. Discuss the next best option and plan forward. Nabors management has elected to swap out the Annular Unit. Peak Crane Supervisor performed and on-site visit and filled out a Critical LIR Permit. Received the required signatures. Crane in route to location. 10/2/2015 10/2/2015 0.50 MIRU WHDBOP SFTY T Crane and replacement Annular 19:30 20:00 preventer arrived on location. Perform Critical Lift PJSM with rig crew,crane crew and pad operator. 10/2/2015 10/3/2015 4.00 MIRU WHDBOP RGRP T Perform critical lift. Lift and place 20:00 00:00 replacement Annular preventer in the sub base. Pick up the preventer with the BOP bridge cranes and N/U. 10/3/2015 10/3/2015 2.50 MIRU WHDBOP NUND T N/U Annular Preventer and riser. 00:00 02:30 Function Preventer and ready BOPE for test. 10/3/2015 10/3/2015 0.50 MIRU WHDBOP BOPE T Test Annular Preventer 250/2500 psi 02:30 03:00 on 2 7/8"pipe. Pressure test charted low/high. (Test good). Witness waived by AOGCC Field Inspector M. Herrera. ay down Test JOint. 10/3/2015 10/3/2015 1.00 MIRU WHDBOP RURD P Rig down test equipment. Blow down 03:00 04:00 lines. Ready Cellar. 10/3/2015 10/3/2015 0.75 MIRU WHDBOP MPSP P Pull Blanking Plug and BPV. Lay 04:00 04:45 down same. Page 2/6 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) &Wells 3N-06 ton coPhiilips ,n Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/3/2015 10/3/2015 1.00 COMPZN RPCOMP PULL P Make-up Landing Joint. BOLDS. Pull 0.0 7,087.0 04:45 05:45 Tubing Hanger off seat a 75K. Pulled Tubing Hanger to the Floor at 70K with no problems. 10/3/2015 10/3/2015 0.25 COMPZN RPCOMP CIRC P Circulate and condition Well. Monitor, 7,087.0 7,087.0 05:45 06:00 static. 10/3/2015 10/3/2015 2.00 COMPZN RPCOMP RURD P Rig up floor to pull the 2 7/8" 7,087.0 7,087.0 06:00 08:00 Completion. Rig up GBR tubing equipment. Rig up Schlumberger Spooling Unit. Change Elevators. Lay down 10/3/2015 10/3/2015 0.50 COMPZN RPCOMP PULL P Single down 1 Joint of the 2 7/8" 7,087.0 7,087.0 08:00 08:30 Completion while spooling Control Line....(stop to investigate why the Koomey Pump is still running) 10/3/2015 10/3/2015 0.50 COMPZN RPCOMP SVRG P Secure Well. Service Rig. Inspect 7,087.0 7,087.0 08:30 09:00 Top drive,grease blackjack,grease dyno-brake,inspect drawworks. 10/3/2015 10/3/2015 3.50 COMPZN RPCOMP RGRP T It was determined that the pressure 7,087.0 7,087.0 09:00 12:30 switch was faulty. De-pressure the Koomey system. Replace the pressure. Also it was discovered that the starter motor for the electric pump has shorted out. Continue with repairs. 10/3/2015 10/3/2015 2.00 COMPZN RPCOMP PULL P Continue to single down the 2 7/8" 7,087.0 5,265.0 12:30 14:30 Completion while spooling Control Line to the SSSV, Lay down SSSV. Recovered 32 SS Bands as expected. 10/3/2015 10/3/2015 0.50 COMPZN RPCOMP RURD P Rig Down Spooling Unit and remove 5,265.0 5,265.0 14:30 15:00 from the Floor. 10/3/2015 10/3/2015 2.00 COMPZN RPCOMP PULL P Continue to single down the 2 7/8 in 5,265.0 3,130.0 15:00 17:00 Completion from 5,265-ft. 10/3/2015 10/3/2015 1.00 COMPZN WELLPR MPSP P RIH with Storm Packer 100'below well 3,130.0 3,130.0 17:00 18:00 head. Test Packer to 1000 psi for 5 minutes. (Test Good). 10/3/2015 10/3/2015 1.50 COMPZN WELLPR NUND P N/D BOP's. 3,130.0 3,130.0 18:00 19:30 10/3/2015 10/3/2015 1.50 COMPZN WELLPR CUTP P N/D Tubing Head Use Hadratight to 3,130.0 3,130.0 19:30 21:00 control 7"Casing growth. Starting gap 0 inches,total growth of 7"Casing=9 1/2 inches. 10/3/2015 10/3/2015 1.00 COMPZN WELLPR CUTP P Spear 7"casing and pick up 20K over 3,130.0 3,130.0 21:00 22:00 neutral weight(52K)to free slips. Slack off weight to re-energize slips (10K). Cut off 1.29'of excess 7" casing with the Wachs cutter. Install 7"casing pack-off. 10/3/2015 10/4/2015 2.00 COMPZN WELLPR NUND P N/U new FMC Gen 5, 11"3M X 11" 3,130.0 3,130.0 22:00 00:00 5M 5 1/2"casing head. Pressure test casing head 250/3000 psi. (Test Good) 10/4/2015 10/4/2015 2.50 COMPZN WELLPR NUND P N/U new FMC Gen 5, 11"3M X 11" 3,130.0 3,130.0 00:00 02:30 5M 5 1/2"casing head. Pressure test pack-off to 250/3000 psi. 10/4/2015 10/4/2015 2.00 COMPZN WELLPR NUND P N/U BOP's with 11"adaptor flange. 3,130.0 3,130.0 02:30 04:30 Install secondary Valve. Page 3/6 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) &Wells 3N-06 ConocoPhill ps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/4/2015 10/4/2015 1.50 COMPZN WELLPR BOPE P Rig up test equipment. Install 11"Test 3,130.0 3,130.0 04:30 06:00 Plug. Fill Stack. Test Wellhead and BOP breaks at 250/3,000 psi x 5 minutes. Record on chart. Good. Pull test plug. Rig down test equipment. 10/4/2015 10/4/2015 1.00 COMPZN WELLPR MPSP P Run in with Retrieving Tool. Latch 3,130.0 3,130.0 06:00 07:00 and release Baker Storm Packer. 10/4/2015 10/4/2015 1.00 COMPZN WELLPR CIRC P Circulate Well at 4.0 bpm/455 psi. 3,130.0 3,130.0 07:00 08:00 Monitor Well(SIMOPS:blow down Top Drive). 10/4/2015 10/4/2015 0.50 COMPZN WELLPR MPSP P Pull and recover Storm Packer, 3,030.0 3,030.0 08:00 08:30 complete. Lay down Storm Packer and Retrieving Tool. 10/4/2015 10/4/2015 0.25 COMPZN RPCOMP SFTY P PJSM. Review the hazards of laying 3,030.0 3,030.0 08:30 08:45 down tubing and Skate operation. 10/4/2015 10/4/2015 3.50 COMPZN RPCOMP PULL P Continue to single down the remaining 3,030.0 0.0 08:45 12:15 2 7/8"Completion. Recovered a total of 221 Jts and a 12.71-ft Chemical Cut Stub. OD=2.91". Good cut. Also recovered 1 SSSV and 8 ea GLMs. Most of the Tubing Couplings from Joint 203 to Joint 221 were "pitted"...with Joint being the worst one. No holes in the Tubing were noted. 10/4/2015 10/4/2015 2.50 COMPZN RPCOMP BOPE P Pull the 2 7/8"x 5"VBRs from the 0.0 0.0 12:15 14:45 lower gate and install 5 1/2"solid rams. 10/4/2015 10/4/2015 2.50 COMPZN RPCOMP BOPE P Test annular preventer to 250/2500 0.0 0.0 14:45 17:15 psi. Test 5 1/2"upper rams to 250/3000 psi. (Tests Good) 10/4/2015 10/4/2015 1.75 COMPZN RPCOMP RURD P R/U to run 5 1/2"casing. Load 2 7/8" 0.0 0.0 17:15 19:00 lower completion in the pipe shed and verify running order and measurements. 10/4/2015 10/5/2015 5.00 COMPZN RPCOMP PUTB P RIH with 5 1/2"15.50#L-80 BTCM 0.0 3,994.0 19:00 00:00 liner and lower 2 7/8"completion to 7,119' 10/5/2015 10/5/2015 4.00 COMPZN RPCOMP PUTB P RIH with 5 1/2"liner and 2 7/8"lower 3,994.0 7,117.0 00:00 04:00 completion. 10/5/2015 10/5/2015 1.00 COMPZN RPCOMP HOSO P Tag tubing stick up at 7,113',sheared 7,117.0 7,117.0 04:00 05:00 pins 7,115 and at No Go 7,117'. Tag 20'up on joint 164. Original RKB of 32'and 2'swallow=7,114'at tubing stick up. 10/5/2015 10/5/2015 1.00 COMPZN RPCOMP CRIH P R/U to pump corrosion inhibitor and 7,117.0 7,117.0 05:00 06:00 diesel freeze protect. 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP SFTY P PJSM with Rig Crew,Lil'Red, FMC, 7,117.0 7,117.0 06:00 06:30 and MI. Discuss Hazards and responsibilities for pumping the corrosion inhibitor and diesel freeze protect. Page 4/6 Report Printed: 3/15/2016 • • lUr�il1!" Operations Summary (with Timelog Depths) sWen 3N-06 ConocoPhillip Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP CRIH P Lil'Red pressure test their line at 7,117.0 7,117.0 06:30 07:00 100/2,500 psi....stand-by with diesel freeze protect. Bring Rig Pump on line down the 7"x 5 1/2"Annulus at 1.5 bpm/72 psi with corrosion inhibited sea water(Congor 303A with the recommended additives as per design). Increase rate 2.4 bpm/620 psi. Shut down Rig Pump with 53 bbls pumped. 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP FRZP P Bring Lil'Red on line with diesel 7,117.0 7,117.0 07:00 07:30 freeze protect down the 7"x 5 1/2" Annulus at 1.0 bpm/120 psi. Pumped a total of 22 bbls. Isolate Lil'Red line and stand-by. Record on chart. 10/5/2015 10/5/2015 0.25 COMPZN RPCOMP HOSO P Slack off and swallow the 2 7/8" 7,117.0 7,117.0 07:30 07:45 chemical cut stump down to the 2-ft space-out mark. 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP PACK P Drop the packer setting ball/rod. Wait 7,117.0 7,117.0 07:45 08:15 on same to fall on seat. Bring Rig Pump on line and walk pressure up to 2,300 psi. Hold pressure x 5 minutes. Good set. Record on chart. 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP PRTS P Lil'Red on line with diesel down the 7" 7,117.0 0.0 08:15 08:45 x 5 1/2"Annulus with diesel and pressure test the Packer at 1,500 psi x 10 minutes. Record on chart. Good. Release Lil'Red. 10/5/2015 10/5/2015 0.25 COMPZN RPCOMP PACK P Pressure up on the 5 1/2"to 2,000 psi. 0.0 0.0 08:45 09:00 Shear the Seal Assembly free from the PBR at 15K. Leave Seal Assembly stabbed into the PBR with 2 -ft stick-up from No-Go. Bleed pressure. Final String weigh (including 30K Blocks). Up weight= 120. Down weight= 102K. 10/5/2015 10/5/2015 4.00 COMPZN RPCOMP CUTP P Suck out the cut off joint. Break out 09:00 13:00 landing pup joints. Lift Stack. Set Slips as per FMC with 70K string weight. Cut-off/dress the 5 1/2"Liner with the Wachs Cutter. Lay down cut- off joint(8.47-ft...note the next 5 1/2" Coupling is 34-ft below the wellhead). Set BOP Stack back on the stump. 10/5/2015 10/5/2015 2.00 COMPZN RPCOMP WWSP P Install 5 1/2"Pack-Offs. Nipple up 13:00 15:00 new 5 1/2"Tubing Spool. 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP WWSP P Pressure test 5 1/2"Pack-Offs at 250 15:00 15:30 psi x 5 minutes and 5,000 psi x 10 minutes. 10/5/2015 10/5/2015 4.50 COMPZN RPCOMP BOPE P Nipple up BOP Stack. Pull the 5 1/2" 15:30 20:00 solid ram blocks and install the 2 7/8" x 5"VBR in the lower cavity. 10/5/2015 10/5/2015 1.00 COMPZN RPCOMP BOPE P Test 2 7/8"X 5"VBR's the lowercavity. 20:00 21:00 10/5/2015 10/5/2015 1.00 COMPZN RPCOMP RURD P R/U to run 2 7/8"gas lift completion. 21:00 22:00 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP SVRG P Service Rig. 22:00 22:30 Page 5/6 Report Printed: 3/15/2016 0 i Drilling Operations Summary (with Timelog Depths) ={ E71 &Wells 3N-06 Conor 15hiINiips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth ' Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2015 10/5/2015 0.50 COMPZN RPCOMP SFTY P PJSM: Running 2 7/8"tubing 22:30 23:00 completion. 10/5/2015 10/6/2015 1.00 COMPZN RPCOMP PUTB P Veryify tubing tally and completion 0.0 92.0 23:00 00:00 running order.Run 2 7/8"gas lift completion. 10/6/2015 10/6/2015 9.00 COMPZN RPCOMP PUTB P RIH with 2 7/8"gas lift completion. 92.0 5,696.0 00:00 09:00 10/6/2015 10/6/2015 1.00 COMPZN RPCOMP HOSO P Tag top of SBE at 6,981'. PUW 67K/ 5,696.0 7,005.0 09:00 10:00 SOW 60K. Sting seal assembly into SBE until fully located at 7,005.87'. Space out 7.57'to 6,998.37'with 1 full joint below the hanger. 10/6/2015 10/6/2015 1.00 COMPZN RPCOMP CRIH P Reverse circulate 145 bbls of 7,005.0 7,005.0 10:00 11:00 corrosion inhibited seawater. 10/6/2015 10/6/2015 0.50 COMPZN RPCOMP THGR P Land 11"Tubing hanger and RILDS. 7,005.0 7,005.0 11:00 11:30 10/6/2015 10/6/2015 1.25 COMPZN RPCOMP PRTS P Pressure test tubing to 3000 psi for 15 7,005.0 7,005.0 11:30 12:45 minutes. Pressure test casing to 2500 psi for 30 minutes. 10/6/2015 10/6/2015 0.25 COMPZN RPCOMP CIRC P Shear SOV and pump down the IA at 7,005.0 7,005.0 12:45 13:00 3 bpm,and down tubing at 2 bpm. 10/6/2015 10/6/2015 0.50 COMPZN WHDBOP MPSP P Set BPV and test to 1000 psi in the 7,005.0 7,005.0 13:00 13:30 direction of flow. 10/6/2015 10/6/2015 7.50 COMPZN WHDBOP SVRG P Between Well Maintenance: Open 7,005.0 7,005.0 13:30 21:00 doors on BOP stack and inspect blind rams and lower pipe rams. 10/6/2015 10/6/2015 1.50 COMPZN WHDBOP NUND P N/D BOPE and DSA. 7,005.0 7,005.0 21:00 22:30 10/6/2015 10/6/2015 1.25 COMPZN WHDBOP NUND P N/U Tree,verify orientation per DSO. 7,005.0 7,005.0 22:30 23:45 10/6/2015 10/7/2015 0.25 COMPZN WHDBOP PRTS P Pressure test 11"Tubing head pack- 7,005.0 7,005.0 23:45 00:00 off and Tree to 250/5000 psi. 10/7/2015 10/7/2015 3.00 COMPZN WHDBOP PRTS P Pressure test Tree 250/5000 psi. 00:00 03:00 (Test Good) 10/7/2015 10/7/2015 3.50 COMPZN WHDBOP FRZP P Freeze protect well. Reverse circulate 03:00 06:30 43 bbls of diesel. ICP=1 bpm at 1000 psi. FCP=2 bpm at 1200 psi. U-tube well and monitor. (Static) 10/7/2015 10/7/2015 2.50 DEMOB MOVE RURD P Install BPV and remove secondary 06:30 09:00 annulus valve,install Tree cap and valve gauges. TBG 0 psi, IA 0 psi, OA 5 psi,OOA 5 psi. All fluids evacuated from pits. Rig released 09:00 hrs. Page 6/6 Report Printed: 3/15/2016 LOF ''y�. �A,w\�- THE STATE Alaska Oil and Gas ' ofA KA Conservation Commission 'It'•i.t `- __ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF P Main. 907.279 1433 ALASV. Fax 907.276 7542 www aogcc alaska gov Theresa Lee � D �� Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 3 ;Af N D? Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3N-06 Sundry Number: 315-467 Dear Ms. Lee: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working 1 day if the 23rd day falls on a holiday or weekend. Sincerely, °%--4-4 Cathy /c___\ P. o erster Chair DATED this c.-day of August, 2015 Encl. STATE OF ALASKA AL,- .SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Fill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing ` Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well , Re-enter Susp Well r Other: I- 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inca Exploratory r Development r, 186-027 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21538-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r KRU 3N-06 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 255521 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured). Junk(measured): 7750 • 6692 ` 7646' • 6607' ' 7170' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80' 80' SURFACE 3670 9.625 3707 3596' E : if E u PRODUCTION 7696 7 7376' 6391' JUL 3 i 201 Dr 8'I Si) S AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft). 7306-7324,7410-7419,7435-7460 - 6337-6351,6418-6425,6438-6458 2.875 L-80 7376 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-AVA'RHS'RETRIEVABLE PACKER MD=7151 TVD=6218 - PACKER-BROWN'16'PERMANENT PACKER MD=7355 TVD=6375 t SAFETY VLV-OTIS FMX SERIES 10 SSSV MD=1828 TVD=1827 , 12.Attachments: Description Surrmary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F7- Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 9/1/2015 OIL P. WINJ r WDSPL r Suspended r 16 Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Theresa Lee @ 263-4837 Email: Theresa.M.Leeaconocophillips.com Printed Name eresa LeeTitle: Wells Engineer Signature . /fin Phone:263-4837 Date " )�t • ��[ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 316- li cal Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearancelr Other: Z I'P /- —f fo �g a a p_5"/ (it,1 /7 f' /5 3G 33 p5 f J Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /0— d4 .4 APPROVED BY _ _ Approved by: COMMISSIONER THE COMMISSION Date: O - �—1 ,) U.1-L 4- `5P- pp�ap fication Is valid for 12 months from the date of approval. Submit Form and Form 10-403 Revised 5/2015GINAL �' I IS Rgp ntsi�'Qµplat�e0R � F4(JU 4 2015 Nov ConocoPhillips EA � D Alaska JUL 3 1 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOCC July 29, 2015 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover the Kuparuk Producer Well 3N-06 (PTD# 186-027). 3N-06 was drilled in 1986 and completed in the A3, A4, and Cl sands and the A sand was initially frac'ed. The A sands were re-perfed in January 1989. In 1992 there was a rig workover to replace the tubing and packer, re-frac the A3 sand, and close the C sand. The well was shut-in in May of 2007 due to a surface casing leak. Diagnostics found the leak in the surface casing at 120'. 3N-06 remained shut-in until January of 2009 when a Brinker platelet surface casing repair was attempted, but was unsuccessful. The well was waivered to free flow without gas lift and brought online in March of 2014. It produced for one month and was shut-in due to a failed inner annulus mechanical integrity test. A leak detect log was run in August of 2014 and found a leak in the tubing at 7,092'. 3N-06 is currently shut-in due to a tubing leak, inner annulus by outer annulus communication (thread leaks to gas only), and a surface casing leak. The proposed workover will reinstate gas lifted production service. The workover scope includes pulling the 2 7/8" production tubing and installing new 2 7/8"tubing after running a 5 1/2"tie-back casing to surface. This Sundry application is intended to document the proposed work on the producing well 3N-06 and to request approval to workover the well. If you have any questions or require any further information, please contact me at 263-4837. Regar. Theresa Lee Workover Engineer CPAI Drilling and Wells Theresa.M.Lee@conocoph illips.com 3N-06 Kuparuk Producer Rig Workover (PTD #: 186-027) Current Status 3N-06 was shut-in April, 2014 for diagnostic well work and is waiting on rig workover repairs. Scope of Work The proposed workover will reinstate gas lifted production service. The workover scope includes pulling the 2 7/8" production tubing and installing new 2 7/8"tubing after running 5 1/2"tie-back casing to surface, General Well info , /(64- 35; ) 34.33 p5 , MP5/� MPSP: 1,600ps(using shut in tubing pressure prior to setting plug (SI 2 months) Reservoir pressure/TVD: 4,271 psi at 7,435' MD (6,438' TVD) SBHP taken on August 26, 2013 Wellhead type/pressure rating: FMC Gen IV 5K BOP configuration: Annular/ Pipe Rams/ Blind Rams/Mud Cross/ Pipe Rams MIT Results: MIT-OA failed due to SC leak @ 120' June 2007 MIT-T failed August 9, 2014 with a leak at 7,092' MIT-TxIA passed to 2,600 psi on October 24, 2014 Well Type: Producer Estimated Start Date: September 1, 2015 Production Engineer: Jason Long 265-6039/Jason.W.Long@conocophillips.com Workover Engineer: Theresa Lee 263-4837/Theresa.M.Lee@conocophillips.com Pre-Rig Work 1. SL: Pull valve from GLM#8 and leave open. 2. Ops: Set BPV within 24 hours of rig arrival. Proposed Procedure - 1. MIRU. Pull BPV. Reverse circulate kill weight fluid. Verify well is dead. i 2. Set BPV PT to 1,000 psi from below if possible, ND tree, NU BOPE & PT to 2,500 psi. 3. Pull BPV, screw in landing joint, BOLDS's, unland tubing hanger. 4. RU to pull tubing, MU landing joint, BOLDS's, POOH laying down tubing. a. If seals will not pull free, RU E-line: Cut the tubing in the middle of the first full joint above the PBR. RDMO E-line. b. RIH w/overshot&grapple on drillpipe, latch onto tubing stub and jar seals free. POOH laying down drillpipe. 5. While POOH with 2,500 ft left to go PU and land a storm packer at—100 ft. Pressure test storm packer. ND BOP and remove tubing head. Grow 7"with hydratight and re-land with additional 5-1/2" casing hanger attached .Pull storm packer and POOH laying down remaining tubing. fJ F 0{' 6. RIH w/inner casing string to just above the PBR/SBE. Reverse circulate corrosion inhibited KWF into the new annulus. Drop ball and rod and set FH packer. 7. Lower casing until seals engage the PBR/SBE, space out. PT new annulus to 500 psi to confirm seals are engaged. Land the inner casing in the air slips. 8. RU Wachs cutter and cut excess casing. Install packoff& new tubing head. PT packoffs. NU BOP to the tubing head & shell test breaks. 9. RIH w/new tubing and seal assembly to just above the SBE. 10. Slowly cycle the charge pump and look for pressure increase as the seals engage the SBE. Shut down charge pump. Space out, mark the pipe, and pull out of SBE. 11. Circulate corrosion inhibited brine around the Tbg and IA. 12. Install space out pups below the hanger, MU hanger. Land the hanger, RILDS. 13. PT the tubing for 10 minutes. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 14. Pull the landing joint, install ISA BPV. PT BPV to 1,000 psi from below. 15. NU tree. Pull BPV& install tree test plug. Test tree. Pull test plug. 16. Freeze protect well w/diesel. Set BPV. RDMO. Post-Rig Work: 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. Pull Ball and Rod. 3. Pull and Replace SOV with Gas Lift Design. Pull catcher and WRP. 4. Turn well over to operations. • 3N-06 ConocoPhillips i - P&R 2-7/8" Tubing with 5'/2" Liner to Surface Casing—9-5/8" 36#, J-55 BTC to 3,707' NIP Casing—7"26#, J-55 BTC to 7,731' MOW 4 Camco 2 7/8"x 1" KBMG GLM's Casing—5-'/2' 15.5#, L-80 BTCM to 7,043' —MP- — Baker 80-31 PBR @ 7,147' V4I ' .L FHL Packer @ 7,062' 1 0 f 2.313"X-Nipple @ 7,084' 41-illAva LSU PBR @ 7,136' 4 4 Ava RHS Packer @ 7,151' 2 7/8"x 1 1/2" SPM-2A @ 7,186' 4 2 7/8"x 1 1/2" SPM-2A @ 7,257' A-3 Perfs 7,306'to 7,324' ' I 1 i=- 1.1 2 7/8"x 1 '/2' SPM-2A @ 7,334' ,,_, 4, Brown B-1 Packer @ 7,355' 41j.- Tubing—2 7/8"6.5#, J-55, 8rd Mod EUE to 7,375' --► 2.250" D-Nipple @ 7,367' I I Camco SOS @ 7,375' A-3 Perfs 7,410'to 7,441' —► A-2 Perfs 7,446'to 7,460' --IN. _I G _� Date: July 29,2015 I Drawn By: Theresa Lee iKUP PROD 3N-06 0, \ ConocoPhillips I Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) [momiFvl6p7 - 500292153800 KUPARUK RIVER UNIT PROD 42.47 5,800.00 7,750.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3N-06.8123/20144.42:10 PM SSSV:TRDP 150 1/16/2007 Last WO: 10/8/1992 38.49 3/1/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _.._._...._.._............._............__Last Tag:SLM 7,457.0 8/26/2013 Rev Reason:SET CATCHER,GLV C/O hipshkf 8/23/2014 HANGER,32.5 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 80.0 80.0 62.58 H-40 Welded Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread ''' n I I I "-• "„l.SURFACE 9 5/8 8.835 37.1 3,707.0 3,595.6 36.00 J-55 BT&C Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread f PRODUCTION 7 6.276 35.0 7,731.1 6,676.8 26.00 J-55 BT&C I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;30.0-80.0-S ' TUBING 27/8 2.441 32.5 7,375.7 6,391.1 6.50 L-80 EUEBrdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Teel(") Item Des Com (in) SAFETY vLv;1,827.5 )"T 32.5 32.5 0.02 HANGER FMC GEN IV TUBING HANGER 2.875 1,827.5 1,827.5 0.67 SAFETY VLV 'OTIS FMX SERIES 10 SSSV 2.313 7,136.5' 6206.7 41.08 PBR AVA'LSU'PBR 2.374 GAS LIFT;2,2544III 7,151.1 6,217.8 40.91 PACKER AVA'RHS'RETRIEVABLE PACKER 2.374 7,352.3 6,372.7 38.31 SEAL ASSY BAKER GB-22 80/32 LOCATOR/SEAL ASSEMBLY 2.406 w/one half MULESHOE BOTTOM 7,355.4 6,375.1 38.28 PACKER BROWN'1B'PERMANENT PACKER 3.250 l 7,367.6 6,384.7 38.13 NIPPLE CAMCO D'NIPPLE 2.250 SURFACE:37.1-3,707.0 7,375.0 6.390.6 38.04 SOS CAMCO SHEAROUT SUB 2.875 GAS LIFT;3,804.8 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl GAS LIFT;4,883.5 ETop(ftKB) (1108) C) Des Com Run Date ID(in) 7,163.0' 6,226.8 40.78,CATCHER 2.5"CATCHER ON WRP(2.28 NOGO/84"OAL) 8/21/2014 • 7,170.0 6,232.1 40.70 PLUG SET 2.25"WRP 6/12/2014 GAS LIFT;5,457.9 Perforations&Slots GAS LIFT;5,842.8- E Shot i Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 0 Type Com GAS LIFT;6.259.2 7,306.0' 7,324.0' 6,336.5 6,350.6 A-3,3N-06 4/21/1986 12.0'IPERF 120 deg ph;5"HJ II Csg Gun GAS LIFT;6,675.8 7,410.0 7,419.0 6,418.2 6,425.3 A-3,3N-06 1/2/1989 8.0 RPERF 60 deg ph;2 1/8" II EnerJet GAS LIFT;7,092.4III 7,414.0 7,415.0 6,421.4 6,422.2 A-3,3N-06 4/21/1986 1.0 IPERF 4"Csg Gun 7,416.0 7,417.0 6,423.0 6,423.7 A-3,3N-06 4/21/1986 1.0 IPERF 4"Csg Gun II 7,435.0 7,447.0 6,438.0 6,447.5 A-3,3N-06 1/1/1989 8.0 RPERF 60 deg ph;2 1/8" PER;7.1365 �_ EnerJet mom PACKER;7,151.1 7,440.0 7,441.0 6,442.0 6,442.8 A-3,3N-06 4/21/1986 1.0 IPERF 4"Csg Gun 7,446.0 7,460.0 6,446.8 6,457.9 A-2,3N-06 4/21/1986 4.0 IPERF 90 deg ph;4"HJ II Csg ' Gun CATCHER;7,163.0 PLUG;7,170.0 ::: Mandrel Inserts St ati C PRODUCTION;7,186.2 No Top(ND) Valve Latch Port Size TRO Run m ® Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type (in) (psi) Run Date 1• 2,254.4 2,254.3 McMurry FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 9/11/2013 PRODUCTION;7,257.7 2' 3,804.8 3,673.9 McMurry FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 9/11/2013 3' 4,883.5 4,502.1 McMurry FMHO 1 GAS LIFT OMY BK-2 0.000 0.0 9/4/2003 IPERF;7.306.0.7,324.0- I 4 5,457.9 4,944.8 McMurry FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 9/13/2013 ' 5 5,842.8 5,235.5 McMurry FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 10/8/1992 ® 6 6,259.2 5,5447 McMurry FMHO 1 GAS LIFT DMY BK-2 • 0.000 0.0 9/12/2013 7 6,675.8 5,858.4 McMurry FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 10/8/1992 PRODUCTION;7.333.8L-al 8 7,092.4 6,173.6 MACCO SPM-2A 11/2 GAS LIFT DMY RK- 0.000 0.0 8/21/2014 EXT SEAL ASSY;7.352.3 _ PKG 1 9 7,186.2 6,244.3 MACCO SPM-2A 11/2 PROD DMY RK 0.000 0.0 1/18/1993 Closed PACKER;7,355.3 1 7,257.7 6,299.1 MACCO SPM-2A 1 1Q PROD DMY RK 0.000 0.0 2/18/1993 II0 Closed NIPPLE:7,367.6 1 7,333.8 6,358.2 MACCO SPM-2A 11/2 PROD DMY RK 0.000 0.0 2/18/1993 1 Closed ■ Notes:General&Safety SOS;7.375.0 171End Date Annotation 2/25/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0(2 pages/print double sided) IPERF;7,414.0.7,415.0 - RPERF;7,410.0.7,419.01 IPERF;7,416.0.7,417.0- IPERF;7,440.0-7,441.0` RPERF;7,435.0.7.447.0 .... IPERF;7.446.0-7460.0 6 I PRODUCTION;35.0-7.731.1-J . FMC Corporatio _ Wellhead Equipment Division 700 West International Airport Road /2 . O Box 4-2089 Anchorage, Alaska 99509 r 907 0 563-3990 cC-3 Pur /6t . ,,62'5- \[- _L___, _ __ /0. 0- _ --/\., ...1- -i 93, y3$ C 7'0 r ---0. zz_,/Z5- SI:•CSo f-=-_____\t. [_, d ( I ' -D 730 -v I _7-----\.. :(i ": LI [ 1 ..--..4"C.o /'vn,�,Cu,r *.Eit! 7// ) 1,/,;/CS W/aTC, "r k//2 5: ‘.- S/'/ r6--6- , 'FMC Technologies Well Workover Details Well Number Customer Date 3N-06 ConocoPhillips 6/1/2015 T. Lee Current Configuration FMC KRU Gen III/IV Item Description MPN Customer ID Tubing Head Head, tbg, TCM-ET, 9 83-600-630 N/A Blk, 11-3000 X 7-1/16 5000 W/Two 2-1/16- 5000 outlets Tubing Hanger Hgr, Tbg, TC-IA-EMS 6 82-747-039 3253848 X 2-7/8 UP Top & Btm W/ ISA BPVG Adapter Flange Adapter, A-4-M, 7-1/16 02-047-622 3253295 5000 X 2-9/16 5000 W/ prep for SBMS Primary PACKOFF ASSY, UH-ET, W/ 12-140-212 100609372 Packoff COMP SEAL, F/ 10.880 BOWL X 7 CSG, 5K, NBR, L- U, PSL 3, EE-NL, SPCL F/C- 29 BOWL Secondary REDUCER BUSHING 83-160-328 10609278 Packoff ASSEMBLY, 4-S, 9 X 7 TRIM B 1 f MCTechnologies New Configuration FMC KRU Hybrid Item Description MPN Customer ID Tubing Head TUBING HEAD SECTION P155792 10972535 ASSY, COMPLETE W/ OUTLET VALVES AND COMPONENT, C-29-ET, 9 BG BTM PREP, 11-3K STDD BTM X 11-5K FLG TOP, EE, K-U, PSL 2, MONOGRAMMED Reducer REDUCER BUSHING 83-160-328 10609278 Bushing ASSEMBLY, 4-S, 9 X 7 TRIM B Tubing Head TUBING HEAD SECTION P120190-0002 10619209 ASSY, COMPLETE W/OUTLET VALVES AND COMPONENTS, 10.380 THRU-BORE, 11-5K STDD BTM X 11-5K TOP, EE, K-U, PSL 2, MONOGRAMMED Casing Hanger SLIP BOWL ASSEMBLY,C- 12-093-115 10614878 21,11 X 5 1/2 CSG W/BLAST SKIRT Packoff SEAL BUSHING ASSY, W/ P172806 10698797 FS/S SEALS, SPCL F/ 10.880 X 10.380 BOWLS, 10.853 OD X 4.91 ID X 10.74 LG, 5K, EE, LOW TEMP NBR, L-U PSL 2, F/5 1/2 CASING, W/LDS GROOVE Adapter Flange ADAPTER ASSY, A-4-M, 11- P183875 113115422 5K STDD BTM X 3 1/8-5K STDD TOP BORED F/7.115 OD EN, W/1 CONTINUOUS SCSSV PORT, DD, K-U, PSL 2, MONOGRAMMED TUBING HANGER ASSY, TC-1A-EMS, 11 FLG, 3 1/2 UPTBG BTM X 3 1/2 UPTBG TOP, CIWHBPVT, 7.115 EN, W/1 CONT SCSSV PORT,COMP PACKOFF Tubing Hanger BTM DD-1,5, K-U, PSL P190191-0002 10619939 'FMC Technologies 2,COMPLETE W/3 FT PUP JOINT, W/SPECIAL DRIFT REQUIREMENTS This completion will require a 3-1/2 X 2-7/8 crossover below the Notes: tubing hanger. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization {done) .~~wo-Sided RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: D Poor Quality Originals Other~ TOTAL PAGES: ~)' ~ NOTES: Other, No/Type ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si Scanned (don.) IIl[lllllllllllllll PAGES: ~ ~ (at the time of scanning) SCANNED BY' BEVERLY BREN VINCE~ARIA LOWELL F~ESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ GeneralNotesorCommentsaboutthisfile: /'O//~7'/~) Quality Checked {done) RevlNOTScanned.wpd ~~~/~~ !1 ~® STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS APR 1 3 2~PORT OF SUNDRY WELL OPERATIONS Re air well SC Palelet repair ~. operations Pertormed: Abandon p r Rug Pt'rforations r Stimulate [" Other r •~~ ~~~' ~ Pull Tubing r" F~rforate New Fool r Waiver r Time Extension ~ Change Approve ogram ~ Operat. Shutdow n r Perforate r Re-enter Suspended Well r 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory r 186-027 3. Address: Stratigraphic r Service 1- .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21538-00 7. Property Designatio ~ 8. Well Name and Nu~ber: ADL 0025521 3N-06 9. Field/Pool(s): Kuparuk River Field /Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 7750 feet Plugs (measured) None true vertical 6692 feet Junk (measured) None Effective Depth measured 7646 feet Packer (measured) .7151, 7355 true vertical 6607 feet (true vertucal) 6218, 6375 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 80 80 0 0 SURFACE 3670 11 3707 3592 3580 4320 PRODUCTION 7696 7.656 7731 6677 4980 5410 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7306-7324, 7410-7419, 7435-7447, 7446-7460 True Vertical Depth: 6336-6350, 6419-6425, 6438-6447, 6447-6458 APB ~ ~~~ ~a~o Tubing (size, grade, MD, and TVD) 2.875, L-80, 7375 MD, 6391 TVD Packers &SSSV (type, MD, and TVD) PACKER - AVA'RHS' RETRIEVABLE PACKER @ 7151 MD and 6218 TVD PACKER -BROWN '1 B' PERMANENT PACKER @ 7355 MD and 6375 TVD SAFETY VLV - OTIS FMX SERIES 10 SSSV @ 1828 MD and 1828 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 Subsequent to operation 0 500 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development ~ Service . Well Status after work: Oil r Gas r" WDSPL r Daily Report of Well Operations X GSTOR r' WAG r GASINJ r WINJ r SPLUG 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: NA Contact MJ Loveland/ Perry Klein Printed Name MJ Loveland Title Well Integrity Proj Supervisors Signature 1 ~ ,~ Pone: 659-7043 Date ) Form 10-404 Re ised 7/2009 ~~p$ APR 13 ~ ~~''~~ yi3•/osubmit Original Only °~ , ,,~~~.~® 3N-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/10/10 SC Leak Repair -Successful (Brinker Platelet), Initial T/I/0= SI/720/50. FL in the conductor was unknown. Rigged up to Hot Oil and established 1st LLR - 0.1 bbls @ 1290 psi. - 1290 psi. - 1290 psi. estimated hole size 1.93 mm, 2nd LLR - 0.15 bbls @ 1720 psi -1720 psi - 1720 psi.with estimated hole size 2.23 mm, 3rd LLR - 0.1 bbls @ 940 psi. - 940 psi. 940 psi. estimated hole size 2.11 mm, 4th LLR - 0.15 bbls @ 1200 psi. -1200 psi. -1200 psi. estimated hole size 2.44 mm, 5th LLR - 0.1 bbls @ 900 psi. - 900 psi. - 900 psi. estimated hole size 2.14 Deployed platelets in deisel Gel, 20 - 10 mm spheres pumped for 5 minutes. Then rigged up to a triplex to injection manifold with diesel gel. Deployed 2nd batch of platelets 30 -10 mm pumped for a total of 50 - 10 mm spheres pumped. LLR gallons of diesel gel is about 9 gallons minute with an estimate of 1 bbls pumped for MITOA. Initial T/I/O = SI/720/40. On the fourth try pressuring up the OA the pressure held. Start MITOA @ 1800 psi, 15 min T/I/O = SI/720/1800, 30 min T/I/O = SI/720/1800, 45 min T/I/O = SI/720/1800, 60 min T/I/O = SI/720/1800. Final T/I/0= SI/720/1800. • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 3, 2009 .,: Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 9 ~~~ f~~~? f~ ~ 2~0~ ~,. r. ommiss+or~ rnclt®rag~ Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3N-06 PTD 186-027 Brinker Platelet job. Please call MJ Loveland or myself with any questions. Sincerely, Perry Klein Well Integrity Projects ~r~ 1rf • •fl STATE OF ALASKA ~~AR ` ~ ~da~ ALASKA OIL AND GAS CONSERVATION CQ~SS ! N REPORT OF SUNDRY WELL OPEF~',i~,ls• commission ~. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other Q Platelet sc repair Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhilllps Alaska, InC. Development ~ Exploratory ^ 186-027 3. Address: Stratigraphic ^ Service ^ 6. APt Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21538-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 67' 3N-06 8. Property Designation: 10. Field/Pool(s): ADL0025521 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7750' ~ feet true vertical 6692' feet Plugs (measured) Effective Depth measured 7646' feet Junk (measured) true vertical 6607' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCCTOR 80' 16" 80' 80' SURFACE 3636' 9-5/8" 3703' 3592' 3580 4320 PRODUCTION 7664' 7" 7731' 6677' 4980 10490 Pertoration depth: Measured depth: 7306-7324, 7410-7419, 7414-7417, 7435-7447, 7440-7441, 7446-7460 true vertical depth: 6336-6350, 6419-6425, 6422-6424, 6438-6447, 6442-6443, 6447-6458 Tubing (size, grade, and measured depth) 2 7/g", L-80, 7376' and Packers &SSSV (type & measured depth) AVA RHS Packer 7151' , Browm 1 B packer 7355, SSSV TRDP 18; 12. Stimulation or cement squeeze summary: ~~~~ ~ ~ ~' ~ ~~ Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation S/I S/I S/1 1000 1800 Subsequent to operation S/I S/I S/I 1020 1800 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ • Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: NA conta MJ Lovel d/ Pe lein Printed Name Title WI Project Supervisor Signature + Phone 659-7043 Date Form 10-404 Revised 04/2004 ': .j s ~~ ~ ~ (1- ~ ~~T~~ f Submit Original Only 3N-06 • DESCRIPTION OF WORK COMPLETED E;'3~r~~i~~~ri7 Date Event Summary 01/26/09 Brinker Platelets SC Repair -unsuccessful. Initial T/I/O = SI/1000/0. Rigged up pump to the platelet skid and started pumping diesel down the OA and established a LLR of .3 bpm @ 1300 psi. Loaded batch # 1 of 50 - 8 mm lite platelets and injected them at .3 bpm @ 1750 psi. dropping the rate to .1 bpm @ 1430 psi. shutting down with the OA dropping to 0 psi. Loaded batch # 2 of 50 - 8 mm lite platelets and injected them at .125 bpm @ 1860 psi. increasing the rate to .75 bpm @ 2000 psi. shutting down with the OA dropping to 0 psi. Without injecting more platelets established a 2nd LLR of .3 bpm @ 1800. Loaded batch # 3 of 250 - 5 mm heavy platelets and injected them at .3 bpm @ 1800 psi. shutting down with the OA dropping to 0 psi. Without injecting more platelets established a and LLR of .3 bpm @ 1500. Shutting down the pump with the OA dropping to 0 psi. Rigged down pump and platelet skid. Final T/I/O = SI/1020/0 Brinker Platelets SC Repair -unsuccessful. " ~~~ KUP ~ 3N-06 COfIOCOPhI~~IpS ( Well Attributes ~1!,r,«,~, I. ~ Wellhere API/UWI field Name Well Status Maximum Inclination (°) Total Depth (RKB) 500292153800 KUPARUK RIVER UNIT PROD 42.47 7,750.0 "' Con 102008 9 05 02 AM Comment HYS (ppm) Date TRDP 150 7/1/2008 Annotation End Date Last WO: 10/811992 KB-0rd (fl) Rig Release Date 38.49 3/1/1986 _ aUC- c1ueT - ~ ~ Annotation DepM (f[KB) End Oate Annotation End Date Last Tag: 7,455.0 7/31/2008 Rev Reason: DRIFT 8 TAG 8/10/2008 Casin Strin a ONDUCCTOR, a0 Casing Descdpllon OD (In) ID (In) Top (RK8) Sat Depth (fIKB) Set Depth (TVD) (ftKe) WI (IbsM) Greer Top Thread CONDUCCTOR 16 15.062 0.0 80.0 80.0 62.58 H-40 sssv,l.e2e o SURFACE 95/8 8.765 0.0 3,703.0 3,592.4 36.00 J-55 PRODUCTION 7 6.151 0.0 7,731.0 6,676.7 26.00 J-55 Tubin Strin a OAS LIFT, 2,251 I 77 Tubing Dee<dptbn OD (In) 10 (In) Top (RKB) $at OePth (nKB) Sel Depth (TVD) (fU(B) Wt (Iba/N) Grade Top Thread suRFACE, TUBING 2 7/8 2.441 0.0 7,376.0 6,391.4 6.50 L-80 EUE SRD AB MOD 3'703 Other In Hole All Jewel :Tubin Run 8a Retrievable Fish etc. OAS LIFT Top (fll(B) Deacdption Comment Run Dete ID (In) , 3,sos 1,828.0 SSSV TRDP OSS'FMX' 10 4/22/1986 2.313 2,254.0 GAS LIFT MCMURRAY/FMHO/1/GLVIBK-2!.125/1304/ Comment: STA 1 9/4/2003 2.347 ons ~ 3,805.0 GAS LIFT MCMURRAY/FMHOl1/GLVIBK-2/.156/1335/ Comment: STA 2 9/412003 2.347 e~e ei 4,883.O GASLIFf MCMURRAY/FMHO/1/DMYIBK-2///Comment: STA3 9!4!2003 2.347 5,458.0 GAS LIFT MCMURRAY/FMHO/1/GLVIBK-2/.188/136C>/Commem: STA4 9/4/2003 2.347 ons uFT, sse s 5,843.0 GAS LIFT MCMURRAYIFMHO/1/DMY/BK-2l// Comment: STA 5 10/8/1992 2.347 , 6,259.O GASLIFT MCMURRAY/FMHO/1/GLV/BK-2/.188/1354/Comment: STAG 9!4/2003 2.347 6,676.0 GAS LIFT MCMURRAY/FMHO/1/DMY/BK-2/// Comment: STA 7 10/811992 2.347 onsuFT, 5,813 7,pg3.O GASLIFT MACCO/SPM-2AI1.S/OVIRKI.1881/Comment: STAB 91212003 2.347 7,136.0 PBR AVA'LSU' PBR 4Y22I1986 2.374 OAS LIFT 7,151.0 PACKER AVA'RHS'PACKER 4122/1986 2.374 , s.zs9 7,186.0 PRODUCTION MACCO/SPM-2Al1.5/DMVlRK/I/Comment: CLOSED STA9 2/18/1993 2.347 7,258.0 PRODUCTION MACCO/SPM-2Al1.5/DMY/RK/// ComrtlenC CLOSED STA 10 2/18/1993 2.347 oAS uFr, 7,334.0 PRODUCTION MACCO/SPM-2A/1.5/DMVIRK/l/Comment CLOSED STA 11 2/18/1993 2.347 e,e7e 7,352.0 SEAL Baker'GBH-22 seal assembty 4/2211986 2.406 7,355.0 PACKER Brown'18' PACKER 4Y22/1986 3.250 oAS LI ~ 7,368.0 NIPPLE Camco'D' Nipple NO GO 412211986 2.250 7,375.0 SOS Camco 4/22/1986 2.441 PBR, 7,138 7,376.0 TTL 4/2211986 2.441 Perforat ions PACKER, 7,151 Top (ftKB) Bbn RKB) Top (ND) (RKB) Btm (TVD) (hK8) T Zone snot Dana (shot... pap Comnynt 7,306.0 7,324.0 6,336.5 6,350.6 IPRF A-3, 3N-06 12.0 4121/1986 120 deg ph; 5" HJ II Csg Gun PRODUC 10 N 7,410.0 7,419.0 6,418.9 8,425.9 RPERF A3, 3N-O6 8.0 1/2!1989 60 deg ph; 2 1/8" EnerJet ' 8 a, 7,414.0 7,415.0 6,422.0 6,422.8 IPERF A-3, 3td-O6 1.0 4121/1986 4" Cs9 Gun 7,416.0 7,417.0 6,423.5 6,424.3 IPERF A-3, 3N-06 1.0 4/21/1986 4" Cs9 Gun PROOUCnoN. 7,435.0 7,447.0 6,438.4 6,447.8 RPERF A-3, 3N-06 8.0 1/1/1989 60 deg ph; 21/8' EnerJet T15e 7,440.0 7,441.0 6,442.3 6,443.1 IPERF A-3, 3N-06 1.0 4/21/1986 4" Csg Gun 7,446.0 7,460.0 6,447.0 6,458.0 IPERF A-2, 3N-06 4.0 4/21/1986 90 deg ph; 4" HJ II Csg Gun IPRF, 7.3067.32. Notes: General 8 Sa End Date Annotation 9/16/1999 NOTE: WAIVERED WELL: IAxOA COMMUNICATION PRODUCTION, 7,331 SEAL, 7,352 PACKER, 7,355 NIPPLE, 7,388 SOS, 7,375 TTL, 7,378 IPERF, 7,111-7,115 -- RPERF, 7,110-7,119 IPERF, 7,41&7,117 IPERF, 7,4407,441 RPERF, ],/36],N] IPERF, 7,44&7,480 PRODUCTION, 7,731 TD, 7,750 ~ MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ·/ STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~ON REPORT OF SUNDRY WELL OPERATIONS ORIGINAL 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1562' FSL, 329' FEL, SEC 29, T13N, R9E, UM At top of productive interval 1210' FNL, 678' FEL, SEC 32, T13N, R9E, UM At effective depth 1446' FNL, 710' FEL, SEC 32, T13N, R9E, UM At total depth 1506' FNL~ 718' FELt SEC 32~ T13N~ RgE, UM 12. Present well condition summary Total Depth: measured 7 7 5 0' true vertical 6691 ' feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 67' 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-06 9. Permit number/approval number 86-P7 10. APl number 50-029-2153800 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 6 4 6' feet true vertical 6607' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 1 6" 3670' 9-5/8" 7696' 7" measured 7306'-7324', true vertical 6336'-6349', Cemented 234 SX CS II 1060 SX PF E, 290 SX CLASS G 300 SX CLASS G, 175 SX PFC 7410'-7419', 7435'-7460' 6417'-6424', 6437'-6457' Measured depth 115' 3707' 7731' True vertical depth 115' 3595' Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80 @ 7376' Packers and SSSV (type and measured depth) AVA 'RHS' RET ~ 7151~ BAKER 'lB' @ 7355', OTIS FMX SERIES 10 @ 1827' 13. Stimulation or cement squeeze summary A SAND FRACTURE TREATMENT Intervals treated (measured) 7410'-7419', 7435'-7460' Treatment description including volumes used and final pressure SEE ATTACHED WELL SERVICE REPORT SUMMARY 6676' RE( EIVED DEC 1 6 1992 Alaska 0il & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 448 336 286 1400 1266~ 891 1036 50 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service Tubing Pressure 156 122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Petroleum Engineer Date SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 11/14/92 TO 11/14/92 CPF-3 DS-3N 3N-06 11/14/92 PUMPED GELLED SEAWATER REFRAC WITH DS YF140D. PUMPED 150 BBL DATAFRAC + 45 BBL FLUSH @ 20 BPM. LAST WHTP=5593 PSI, ISIP=1917 PSI, FG=.74 PSI/FT, EXCESS FRIC=1316 PSI. PUMPED 75 BBL DATAFRAC + 45 BBL FLUSH @ 20 BPM. LAST WHTP=5561 PSI, ISIP=1963 PSI, FG=.75 PSI/FT, EXCESS FRIC=1238 PSI. DATAFRAC RESULTS WERE AS FOLLOWS: STAGE CLOSURE PRESSURE CLOSURE TIME FLUID EFFICIENCY DF %1 4400 PSI 14.0 MINUTES 50%-55% DF ~2 4425 PSI 17.5 MINUTES 65%-70% PUMPED 100 BBL PAD @ 20 BPM. PUMPED 2.2 MLBS 16/20 CARBOLITE IN 2 PPA STAGE & 113.2 MLBS OF 12/18 CARBOLITE IN 4 TO 12 PPA STAGES. WENT 24 BBLS LONG IN 12 PPA STAGE & FLUSHED JOB TO COMPLETION 2 BBLS SHORT OF TOP PERF. TOT PROP: DESIGN=109.6 MLBS, IN FORM=Il2.5 MLBS W/12.0 PPA @ PERFS. TOT FLUIDS: WATER=714 BBL, DIESEL(FLA+FLUSH)=52 BBLS, LIQUID ADDITIVES=14 BBLS. FLUIDS LOOKED GREAT. SMART COMPUTER WORKED WITHOUT ANY PROBLEMS. (HARVEY/CORBELL/BOTELLO). DEC 1 6 1992 Alaska Oil & Gas Cons. Comrnissior', Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '1. Operations performed: Operation Shutdown __ Pull tubing X Alter casing Stimulate __ Plugging Repair well __ Other Perforate 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1562' FSL,329' FEL, SEC 29, T13N, R9E, UM At top of productive interval 1210' FNL, 678' FEL, SEC 32, T13N, R9E, UM At effective depth 1446' FNL, 710' FEL, SEC 32, T13N, R9E, UM At total depth 1506' FNL, 718' FEL, SEC 32, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7750' 6691 ' 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet feet 6. Datum elevation (DF or KB) RKB 67'. PAD 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-06 9. Permit number/approval number 86-27(Conserv Order No. lO. APl number 50-029-21538 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) 261)_ Effective depth: measured 7646' true vertical 6607' feet feet Junk (measured) 7506'( Top of Fill )tagged 5/29/92 Casing Length Size Structural 8 0' 1 6" Conductor Surface 3670' 9-5/8" Intermediate Production 7696' 7" Liner Perforation depth: measured 7306'-7324, 7410'-7460' M D true vertical 6635'-6349', 6417'-6457' TVD Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80 @ 7376' Packers and SSSV (type and measured depth) Cemented 234 SX CS II Measured depth True vertical depth 115' 115' ' 1060 SX PF E 3707' 3 5 9 5" & 290 SX CLASS G 300 SX CLASS G 7731 ' 6676' 175 SX PFC R CEIVED NOV 1 9 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage AVA RHS RETR PKR @ 7151',BAKER lB PERM PKR @ 7355', OTIS FMX SSSV @ 1827' MD i 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector m Oil X Gas Suspended Service Tubing Pressure 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10:404 Rev 155/17T89 Title Area Drillin~l En~]ineer Date ///~/-//~Z- SUBMIT IN DUPLICATE AR'CO ALA.~KA INC DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3N-06 NORTH S'~ OPE KUPARUK RIVER KUPARUK RIVER 50-029-fi1538 86-27 ACCEPT: 10/02/92 02:10 SPUD: RELEASE: 10/08/92 07:10 OPERATION: WORK0VER DRLG RIG: NONE WO/C RIG: NORDIC 1 10/02/92 TD: 7750 PB: 0 10/03/92 ( 2) TD: 7750 PB: 7596 WAITING ON NEW ANN VALVE MW: 8.6 FSW MVE RIG F/3H-O4 TO 3N-06. SPOT RIG OVER 3N-06. RIG ACCEPTED @ 02:30 HRS 10/02/92. RU HARD LINE UP TO ANN VALVE. ATTEMPT TO PULL VR PLUG. WRENCH SOCKET BROKE ON PLUG & VR PLUG IS LEAKING GAS. WAITING ON NEW ANN VALVE TO PUT ON OTHER SIDE OF TREE FOR KILLING WELLL. RECEIVED 351 BBL SW FOR WELL KILL. PMP KILL WT. ELUID MW:10.2 NaC1/Br WAIT ON FMC ANN VALVE. REPLACE COMPANION FLANGE/BULL PLUG ON TBG HEAD. PULL VR PLUG & BPV. RU SWS ELINE. MU JET CUTTER. TEST LUB TO 2500 PSI. TOOL PUSHED UP AGAINST GREASE HEAD & WIRE CRIMPED. REHEAD TOOL. RIH W/CUTTER. WORK DN TO 1798' & STOP. PMP SSSV LINE TO 5000 PSI. PMP 6 BBL DN TBG-SSSV OPEN. POOH W/CUTTER. MU 2-1/8" WT BAR. RIH & STOP @ 1052' POOH. POSS ICE PLUG FORMING. BULLHEAD 15 BBL 80 DEGREE SW DN TBG-SSSV OPEN. RIH W/WT BAR THROUGH TBG TAIL TO 7395' POOH & MU JET CUTTER. RIH & TIE IN. CUT TBG @ 7286'. POOH. BOTH CUTS LOOKED GOOD. RD SWS. TEST CHOKE LINE TO ANN VALVE @ 3000 PSI-OK. BLOW AIR THROUGH LINE TO FLOWBACK TANK TO ENSURE CLEAR. TEST HARD LINE TO FLOWLINE . BLEED OFF ANN TO 920 PSI. BLEED TBG TO 500 PSI & BEGAN GETTING FLUID BACK. BLEED OFF ANN A LITTLE MORE, THAN START PMP SW DN ANN. SOME GAS AT FIRST, THEN RETURNS ALL FLUID. PMP 46 BBL & SI. BULLHEAD 20 BBL SW DN TBG @ 3.2 BPM-TAKING FLUID EASILY. BLEED DN. LOOKED LIKE SW GOING INTO C' SAND. PMP SW DN TBG TAKING RETURNS THROUGH CHOKE. PMP 305 BBL, SI & CK RETURNS-GETTING SW BACK. SI 45 MIN. CALC REQUIRED BRINE WT TO 10.2 PPG. FREEZE PROTECT HARD LINE & FLOWLINE TO MANIFOLD BLDG. TRANS 11.2 VISC BRINE F/STORAGE TANK TO RIG & WATER BACK TO 10.2. BEGIN PMP 10.2 BRINE DN TBG TAKING RETURNS. WELL : 3N-06 OPERATION: RIG : NORDIC PAGE: 2 10/04/92 ( 3) TD: 7750 PB: 7596 10/05/92 ( 4) TD: 7750 PB: 7596 POOH W/2-7/8" TBG & LD MW:10.7 NaCl/Br TBG LOADED W/10.2 PPG BRINE. BULLHEAD 21 BBL TO PERFS @ 3 BPM 1300 PSI-SI & MONITOR. CIRC 10.2 BRINE AROUND ANN, RETURNS THROUGH CHOKE TO FLOWLINE. PMP 265 BBL GETTING 10.2 PPG RETURNS. SI & MONITOR WELL. APPEARS WELL KILLED & STABLE. NO GAIN OR LOSS OF FLUID. FREEZE PROTECT FLOWLINE W/20 BBLS DIESEL. SET BPV-NO 7" CSG VALVES. SWITCH VR PLUG TO ORIG COMPANION FLANGE SIDE. REPLACE FLANGE/BULL PLUG. MU ORIG 7" CSG VALVE. ND TREE. NU BOPE. TEST ALL TO 3000 PSI-OK. ACCUM TEST-OK. PULL BPV. MU LANDING JT. PULL TBG HGR TO FLOOR. CIRC.-SOME OIL IN BRINE. MIX & PMP DRY JOB. LD LANDING JT & HGR. POOH & LD 2-7/8" TBG. HOLE NOT TAKING RIGHT AMT OF BRINE @ 57 JTS OUT. BULLHEAD 3 BBL DN TBG. CONT POOH. MONITOR AND CHECK FILL EVERY 15 JTS. @ 95 JTS OUT, REVERSE CIRC OUT DRY JOB & MONITOR HOLE FILL. CIRC DN TBG. SI & MONITOR. WELL FLOWING ON BOTH TBG & ANN SLOWLY. RIH W/2-7/8" TBG TO 7132' LOAD TBG W/10.2 PPG BRINE. SI & MONITOR WELL. BLEED OFF. SI & MONITOR AGAIN F/2 HRS WHILE WEIGHTING UP BRINE-FINAL BRINE @ 10.7 PPG. PMP TBG VOL OF 46 BBLS. BULLHEAD 20 BBLS 10.7 TO PERFS. SI & MONITOR WELL. CIRC AROUND TO ANN TAKING RETURNS THROUGH CHOKE. SI & MONITOR WHILE WEIGHT UP PITS TO 10.7 BRINE. VACUUM ON TBG, ANN FLOWING SLIGHTLY, STOPPING AS FLUID COLUMN BALANCES OUT. POOH W/2-7/8" TBG & LD. POOH SLOW, CK HOLE FILL MW:10.7 NaCl/Br CONT POOH & LD 2-7/8" TGB. MIX PMP 25 BBL 11.0 PPG DRY JOB. CONT POOH & LD 2-7/8" TBG & JEWELRY. ALL TBG & JEWELRY NORM TESTED-ALL OK. LOAD PIPE SHED W/3-1/2" DP & TALLY. SET WEAR RING. MU FTA #1 & RIH DN 3-1/2" DP. STDP 212 JTS INTO HOLE. PU KELLY & RIH TO 7131' CIRC 100 BBLS. RIH & TAG PBR @ 7135'. RAN SPEAR IN 3' WORK FISH, PULLING 160K-230K-PKR RELEASED @ 238K, 130K OVERPULL. PU TO 7095' & CIRC 260 BBL. FL DURING CIRC 21 BBL. BLOW DN, STD BACK KELLY. POOH 8 STDS, MONITOR-HOLE FILL 2 BBL-1 BBL GAIN. CONT POOH, MONITORING HOLE FILL EVERY 8 STDS. POOH SLOWLY. WELL : 3N-06 OPERATION: RIG : NORDIC PAGE: 3 10/06/92 ( 5) TD: 7750 PB: 7596 10/07/92 ( 6) TD: 7750 PB: 7596 10/08/92 ( 7) TD: 7750 PB: 7596 RIH W/BIT CSG SCRAPER F C/O MW:10.7 NaCl/Br SERV RIG. POOH SLOWLY W/3-1/2" DP & FTA #1. LD PBR, PKR, 3 JTS TBG, 2 GLMS, & 9' STUB. CHANGE PIPE RA34S TO 3-1/2" & TEST TO 3000 PSI. SET WEAR RING. MU FTA #2 & RIH ON 3-1/2" DP. STOP @ 7108' & PU KELLY. WASH DN 7108'-7269'. TAG FISH(CUT TBG STUB). DRESS DN TBG STUB & LATCH ONTO FISH. PU 20' & CIRC BU 4 BPM & 800 PSI. MIX & PMP 20 BBL 11.1 PPG DRY JOB. BLOW DN & STAND BACK KELLY. FISH PULLED EASY. SLIP & CUT DRLG LINE. POOH SLOWLY W/3-1/2" DP. CALC HOLE FILL @ 44 BBL. POOH W/12 4-3/4" DCS. CHIP SCALE FROM BLAST RING JT SO CBRS COULD BE REMOVED. FIRST CUT MADE ABOVE 2-7/8" X 1" GLM DID NOT TAKE. POOH W/STUB, CBR JT, PUP, GLM, PUP, & SEAL ASSEMBLY. LD SAME. BREAK OFF OVERSHOT. MU BIT & CSG SCRAPER ON 3-1/2" DP & RIH. POOH, LD 3-1/2" DP'S MW:ll.1 NaCl/Br SERV RIG. FUNCTION TEST BOPE. CONT RIH W/BIT & CASG SCRAPER. PU KELLY. CLEAN OUT F/7130'-7341' CBU. PMP SLUG. POOH W/BIT & SCRAPER. LD 4 3/4" DC'S AND BHA. PU 1 JT HYDRIL PIPE RIH ON 3-1/2" DP. TAG PKR @ 7341' WELL UNSTABLE. CLOSE ANN PREVENTER. CBU THROUGH CHOKE. LITTLE AMT OF GAS BUBBLE TO SURF. PU KELLY. CIRC & ROTATE/WORK HYDRIL PIPE INTO THE PKR BORE DN TO EOT. CIRC TO CLEAN UP PKR/TBG TAIL ASSY. OBSERVE WELL-FLOWING+/-I" STREAM IN FLOWLINE. BLOW DN & STAND BACK KELLY. SI WELL. WT UP BRINE TO 11.1 PPG. CIRC 11.1 PPG BRINE AROUND THROUGH CHOKE @ 3.6 PBM. HOLD 100 PSI BACK PRESSURE. OBSERVE WELL-FLUID DROP 5' IN ANN AFTER 15 MIN. WEIGHT UP REMAINING BRINE IN PIT TO 11.1 PPG. SLUG PIPE. POOH. LD 3-1/2" DP'S. MONITOR WELL CLOSELY. FUNCTION TEST SSSV MW:ll.1NaC1/Br FIN POH W/i-i/4" HYDRILL TBG. LD 3-1/2" DP'S. RD DP EQUIP. RU 2-7/8". TEST SAME TO 3000 PSI. MU 2-7/8" SS COMPL ASSY. SURF TEST SSSV TO 4700 PSI. CONT RIH W/COMPL ASSY. WORK TBG STRING TO STING INTO PKR BORE. PRESS UP TBG TO 200 PSI AGAINST A SAND. SEALS IN PLACE. SPACE OUT. MU TBG HGR AND CONTROL LINE FITTING. PRESS UP CONTROL LINE TO 4700 PSI. WORK TBG STRING TO STING IN SEAL ASSY. LAND TBG HGR. PRESS UP TBG TO 200 PSI AGAINST A SAND. SEALS IN PLACE. RU CAMCO SL LUB. SET STD VALVE IN D-NIPPLE. PRESS UP TBG TO 3000 PSI. AVA RETRV PKR SET @ 2200 PSI. HOLD PRESS @ 3000 PSI-GOOD. POH W/CAMCO SETTING TOOL. RD LUB. PRESS UP ANN TO 2000 PSI TO RELEASE AVA PBR. BOLDS. PULL TBG STRING 4 FT. PBR RELEASED. RILDS. FUNCTION TEST SSSV. PRESS TBG TO 1000 PSI. BLEED OFF CONTROL LINE PRESS TO CLOSE SSSV. BLEED OFF TBG PRESS TO 500 PSI, TEST SSSV FOR 15 MIN. WELL : 3N-06 OPERATIOt.i: RIG · NORDIC PAGE: 4 10/09/92 ( 8) TD: 7750 PB: 7596 RELEASE RIG MW:ll.1NaCl/Br FIN FUNCTION TEST SSSV. PRESS TEST ANN TO 2500 PSI. KEEP ANN PRESS, PRESS TBG TO 3500 PSI TO TEST PBR SEALS. BLEED OFF PRESS. CLOSE SSSV. INSTALL BPV. ND BOPS. NU X-TREE. PULL BPV, INSTALL TEST PLUG. TEST TREE TO 250 PSI & 5000 PSI. TEST PACKOFF TO 5000 PSI. PULL TEST PLUG. RU CAMCO LUB. TEST SAME TO 1500 PSI. PULL DUMMY VALVE F/I-i/2" GLM ABOVE PBR(MISS FIRST RUN, HAVE TO MAKE 2ND RUN). PMP/REVERSE CIRC 122 BBLS SEA WATER, 255 BBLS 11.2+ BRINE & 17 BBLS DIESEL. RU CAMCO LUB. SET DUMMY VALVE IN 1-1/2" GLM. TEST TBG TO 3500 PSI. POH. ?U PULLING TOOL. PULL STANDING VALVE F/D NIPPLE. RD CAMCO EQUIPMENT. BULLHEAD 4 BBLS DIESEL DN TBG. SHUT WELL IN. SECURE WELL. RELEASE RIG @ 19:00 HRS 10/08/92. S I GNATUR?_'.: (drilling ~n~ DATE: ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 5 Kupaurk Fluid Level Report 1 2 - 0 3 - 8 7 3 N- 1 8 Kupaurk Fluid Level Report 1 2 - 1 8 - 8 7 3 F- 01 Kupaurk Fluid Level Report 8-29-87 3 F- 0 2 Kupaurk Fluid Level Report 8-29-87 3 F- 0 9 Kupaurk Fluid Level Report 8-29-87 3 F- 0 6 Kupaurk Fluid Level Report 8-29-87 3 F- 1 0 Kupaurk Fluid Level Report 8-29-87 3 F-1 1 Kupaurk Fluid Level Report 8-29-87 3 F- 1 5 Kupaurk Fluid Level Report 8-29-87 3 F- 1 4 Kupaurk Fluid Level Report 8-29-87 3 N - 1 0 Kupaurk Fluid Level Report 5-18-87 3 N- 0 6 Kupaurk Fluid Level Report 5-22-87 3N-09 Kupaurk Fluid Level Report 5-21-87 31 - 0 1 Kupaurk Fluid Level Report 4-24-87 3 N- 1 1 Kupaurk Fluid Level Report 4-15-87 3 N- 1 4 Kupaurk Fluid Level Report 4-13-87 3 F- 0 8 Kupaurk Fluid Level Report 4-14-87 3 N- 01 Kupaurk Fluid Level Report 4-20-87 3 N - 1 4 Kupaur. k Fluid Level Report 1 2 - 0 4 - 8 7 3 F- 1 5 Kupaurk Fluid Level Report 2-02-89 3 F.- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B- 0 5 Kuapruk Well Pressure Report 2-20-89 1 E- 2 5 Kuparuk Fluid Level Report 2-19-89 3 B- 1 1 Kupaurk Fluid Level Report 2-20-89 3A-03 Kupaurk Fluid Level Report 2-21-89 3 H-01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31-1 2 Kupaurk Fluid Level Report 2-20-89 1 E-08 Kupaurk Fluid Level Report 2-19-89 3 M - 1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin~"~ Casinc~ 3 H- 01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 E-29 Kupaurk Fluid Level Report - 2-15-89 Casing 1C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3 M - 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged' - .......................... Date: ............ DISTRIBUTION: D&M State of Alaska · SAPC Unocal Mobil Chevron . . . . . 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3No10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 -. Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk FlUid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku2aruk Fluid Ku:~aruk Fluid Ku~aruk Fluid Acknowledged: Level Report Level Report Level Report Level Report Level Report Level Report Level Report Leyel Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Re3ort Level Re2ort Level Reaort Level Re aort Level Re2ort Level Re 2ort Level Re 2ort Level Re 2ort Level Re 2ort Level Re 2ort Level Re 2ort Level Re 2ort Level Re 2ort Level Re ~ort Level Re 2ort Level Re 2ort LeVel Re 2ort Level Re 2ort Level Re 2ort Level Re 2ort Level Re 2ort 9-11-87 12-06-86 9-11-87 10-1 I -87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 I -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 .. 6-1 7-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & Gas Con;. Ccrnmlssjor, DISTRIBUTION; D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 11 Sub. Surface Pressure Survey 1 0 - 0 6 - 88 3 H - 1 2 Kuparuk Well Pressure Report 8 - 29 - 88 30-07 Kuparuk Well Pressure Report 1 2-20-88 3 F o 1 0 Kuparuk Well Pressure Report 8 - 29 - 87 3 F- 0 6 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F o 0 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 9 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 3 F - 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 3 F - 1 1 Kuparuk well Pressure Report 8 - 2 9 - 8 7 3 F- 0 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 3 F - 0 5 Kuparuk Well Pressure Report 1 2 - 1 2 - 8 8 3 F - 13 Kuparuk Wel~ Pressure Report 1 2 - 31 - 88 3 N- 1 0 KuparUk Well Pressure Report 6 - 11 - 87 3 N- 1 0 Kuparuk Well Pressure' Report 6 - 11 - 87 3 N - 04 Kuparuk Well Pressure Report 9 - 01 - 87 3 N - 09 Kuapruk Fluid Level Report 5 - 04 - 87 30-1 4 Kuparuk Fluid Level Report 2 - 1 3 - 8 9 30-1 4 Kuparuk Fluid Level Report "2 - 1 0 - 8 9 3 M - 1 8 Kuparuk Fluid Level Report 2- 1 0 - 8 9 3 F- 1 6 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 9 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 8 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 6 - 8 7 3 F - 1 3 Kuparuk Fluid Level Report 6 - 21 - 8 7 3 F - 0 8 Kuparuk Fluid Level' Report 5 - 0 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 o 1 8 - 87 3 F- 1 6 Kuparuk Fluid Level Report 8 o 24 - 87 3 F - 13 Kuparuk Fluid Level Report 6 - 05 - 87 3 F - 1 6 Kuparuk Fluid Level ' Report 6- 2 / 3 - 8 7 3 F - 1 6 Kuparuk Fluid Level Report 8 - 5 - 8 7 3 F- 16 Kuparuk Fluid Level Report 6 - 5 - 8 7 3 F - 1 4 Kuparuk Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Tubing Casing Casing ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April Transmittal # 5966 Return to= Transmitted receipt and ARCO Alaska, Inc. Attn: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 995lO-O360 herewith are the following items. Please acknowledge return one signed copy of this transmittal. 3N-7 C£T 4-1-86 6202-7597 3N-6 CET 4-1-86 6061-7583 3N-11 CET 4-22-86 7600-8675 3N-12 CET 4-29-86 6396-7965 3N-10 CET 4-14-86 7462-9130 3J-16 CET 3-29-86 7704-8727 35-15 CET 3-29-86 7400-8398 iA-8 CET 1-5-86 5755-6154 2Z-7 C£T 4-14-87 8250-8491 2Z-7 C£T 4-12-87 8246-8595 2Z-7 Squeeze &. Retainer Record 4-i5-87 8250-8491 2Z-7 Squeeze, BP & Retainer Record 4-~2-87 8290-8588 ~ Alask~ 0il & Gas Cons. A~ch0ra~ Receipt Acknowledged: DISTRIBUTION: NSK Drilling Chevron Mobil Date: ~'State of Alaska (~ sepia) SAPC Unocal Vault BPAE (film) ARCO Alaska. Inc. is a SuDsl~liary of AtlanticRichfieldCompany ARCO Alaska. ir Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 07-30-86 TRANSMITTAL # 5 72 6 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints' Schl' Open Hole' One * of each / 2A-9/5" DIL/SFL-GR 02-17-86 Run #1 7939-84C2 12" DIL/SFL-GR 02-17-86 Run #1 7939-8462 1~[-----5" Den/Neu-GR (poro) 02-17-86 Run #1 7939-8437 k~~~ii Den/Neu-GR (poro) 02-17-86 Run #1 7939-8437 Den/Neu-GR (raw) 02-17-86 Run #1 7939-8437 Den/Neu-GR (raw) 02-17-86 Run #1 7939-8437 Cyberlook 02-17-86 Run #1 7939-8437 3I-7 5" DIL/SFL-GR 02-19-86 Run #2 0200-7506 ; 2" DIL/SFL-GR 02-19-86 Run #2 0200-7506 5" Den/Neu (poro) 02-19-$6 Run #2 5500-7480 2" Den/Neu (poro) 02-19-86 Run #2 5500-7480 5" Den/Neu (raw) 02-19-86 Run #2 5500-7480 2" Den/Neu (raw) 02-19-86 Run #2 5500-7480 Cyberlook 02-19-86 Run #2 6650-7457 5" LSS-GR 02-20-86 Run #2 3287-7502 2" LSS-GR 02-20-86 Run #2 3287-7502 3N-6 f5" DIL/SFL-GR 02-28-86 Run #1 1700-7736 / 2" DIL/SFL-GR 02-28-86 Run #1 1700-7736 ~ 5" Den/Neu (poro) 02-28-86 Run #1 6950-7710 ~ 2" Den/Neu (poro) 02-28-86 Run #1 6950-7710 , 5" Den/Neu (raw) 02-28-86 Run #1 6950-7710 ~2" Den/Neu (raw) 02-28-86 Run #1 6950-7710 Cyberlook 02-28-86 Run #1 6950-7680 6as Cons. ~mmi~i0n Receipt Acknowledged: Date: State Of 'Ai~Ska*bl/se Rathmell*b! NSK Clerk*bi Drilling*bi D & M*bl ARCO Alllka. Inc. il · SuDt~cl,lry of Atiattt~cRIcl~t*el~lComDln¥ Vault*films ! STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION ~ WELL COMPLETION OR REcoMPLETION REPORT AND LOG ' 1. Status of Well Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-27 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21538 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 329' FEL, Sec.29, T13N, R9E, UN Kuparuk River Unit f~lT0OP Producing Interval 10. Well Number FNL, 678' FEL, Sec.32, T13N, R9E, UM 3N-6 At Total Depth 11. Field and Pool 1506' FNL, 718' FEL, Sec.32, T13N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 67' RKB ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Dare'comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 02/22/86 02/27/86 06/09/86*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7750'MD,6691 'TVD 7646'MD,6607'TVD YESX[~] NO []I 1808 feetMD 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GCT, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6;~ eZ.b¢~ H-~O Surf 115' 24" 234 sx CS II 9-5/8" 36.0# J-55 Surf 3707' 12-1/4" 1060 sx PF "E" & 290 sx Class G 7" 26.0# J-55 Surf 7731' 8-1/2" 300 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7306'-7324'MD 6335'-6349'TVD 2-7/8" 7381' 7165' & 7361' 7446 ' -7460 'MD 6446 ' -6457 'TVD 7414 'MD 6420'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7416'MD 6422'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7440'MD 6441'TVD See attached addemum, dated 6/11/86, for fracture data 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ILIL 1 0 Absk~ 0il & Gas ConS. Form 10-407 * NOTE: Drilled RR 3/1/86. Well perf'd & tubing run 4/22/86. WC1/078 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. " ' 30. ~' -' GEOLOGIC:MARKERS .' FORMATION-TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7253' 6294' N/A Base Kuparuk C 7316' 6343' Top Kuparuk A 7394' 6404' · Base Kuparuk A 7533' 6515' · . 31. LIST OF ATTACHMENTS Addendum (dated 6/11/86) __ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3N-6 3/10/86 6/09/86 Arctic Pak w/175 sx PF "C", followed by 56 bbls Arctic Pak. Frac'd Kuparuk "A" sand perfs 7414', 7416', 7440' & 7446'-74460' in 8 stages per 5/22/86 procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd ann to 1700 psi w/diesel. Tst lns to 8000 psi; OK. Stage #1: Pmp'd 20 bbls 140° diesel w/5% Musol @ 1BPM w/760-2650 psi Stage #2: 25 bbls gel/diesel spacer @ 1BPM w/2650-2740 psi Stage #3: 30 bbls gel/diesel spacer @ 20 BPM w/2740-5570 psi Stage #4: 14 bbls gel/diesel w/1 ppg 100 mesh @ 1B?M w/200-2800 psi ("batch") Stage #5: 10 bbls gel/diesel pad @ 1BPM w/2800 psi Stage #6: 16 bbls gel/diesel pad @ 10 BPM w/2800-5280 psi Stage #7: 19 bbls gel/diesel w/8 ppg 20/40 @ 19-20 BPM w/5280-6100 psi Stage #8: 43 bbls gel/diesel flush @ 20 BPM w/6100-4900 psi. Pmp'd 600# 100 mesh & 6115# 20/40 in formation leaving 270# 20/40 sand in csg. Load to recover 177 bbls of diesel. Job complete @ 1630 hrs, 6/9/86. Turn well over to Production. Drilling Supervisor Date : STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COIvlMISSlON F-- ....... / WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED)~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ~ 86-27 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21538 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 329' FEL, Sec.29, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3N-6 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 67' RKBI ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 02/22/86 02/27/86 03/01/86I N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth whereSSSV set 21. Thickness of Permafrost 7750 'MD 7646 'ND YES [] NO ~ N/A feet MD 1 700 ' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report not available. 9-5/8" 36.0¢ J-55 Surf 3707' 12-1/4" 1060 sx PF "E" & 290 sx Class G 7" 26.0¢ J-55 Surf 7731' 8-1/2" 300 sx Class G & 175 sx PF "C" 24. Perforations open to Production (M D+TVD of Top and Bottom and 25. TUBING R ECOR D interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~GAS-OILRATIO I TEST PERIOD ~ . Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL iOILGRAVlTY-API (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 DAH2/WC10 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate¢ 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__._ ~~ ~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 SUB. SURFACE DIRECTIONAL ~URVEY ~UIDANCE [~ONTINUOUS [-~OOL q,/Ll/oo Company A~CO ALASKA, INCORPORATED Well Name WELL 3N-6 (1562'FSL, 329'FEL, S29, T13N, R9E) I il I iii ii ii i! Field/Location KWARUK, NORTH SLOPE, ALASKA Jqb Reference No; Date 71411 15-APR-1986 Lg(~ed By; Computed By; WEST HALSTEAD ~,'-'r, '~:~.:rT[3, . ,-.'~L SU;'V:Y S~jmV:y,. b"T~:. _a-S~.- ,.! F-. T H 0 .-,S ~. T]CL L ~C~T[]~.]· 3~-6 KUPARUK N3RTH SLOP~,AL~SKa TRUE ME~SURE] DEPTH C~PTM 0.00 O.O0 -S7.00 100.00 iO0.OO 33.00 ZO0.O0 £O0.OO 133.00 300.00 300.00 Z3~.O0 400,00 400,33 3~3,03 500.OO 500.00 433,0j 600,03 600,JO 533.00 700,00 7OO,OJ 53~.00 ~00.00 739.99 732.)? ~OO.O0 899.)9 832.99 i000,00 999,~9 llDO,O0 109~,99 i032,~9 1200.00 1199.)9 i132.9~) 1300.00 .1299,)9 1232.)9 1400.00 1399.~9 i332.~9 1600.00 1599.99 153Z.9~ 1700.00 1693.~2 1532.~3 1800.00 17~9.~B i732.S$ 1~00.00 1899.97 i8~2.97 2000,03 1999,96 1932,~6 2100,OO 2099,~5 2032,95 2200,00 2129,95 2131.~5 2300,0J 12~9,$4 22~2,94 2400,00 2399,57 23j2,37 2500.00 2499.37 2432.37 2500.00 2597.B3 2700.0~ 2695.27 262~.£7 2300.00 Z791.59 2724.59 2~00.00 28S5.96 ~1~.~$ 3000,00 2951.23 2914.23 3100,00 3073,B0 3005,80 3200.00 3164.29 3097.29 3300,00 3253,22 3135.22 3430.00 3340.~4 3273.4~ 3500.00 3425.50 3333.50 3600.00 3508.91 3441.)! 3700,00 35~9,65 3522.56 380~,O0 ~66~. 77 360~..77 3900.00 374,5.12 353!.12 V f? l' l C a L ,3 ] ' L ~ G SECTiPN SEV-~ITY OaTE 3: SURV--Y: 3-31-~5 K=LLY ?!jSHiNG EL~V6Ti3N: ,.=. "q :,g ! ;q J =R: w{ST 24 3 $ lO 35 . S2 i5 S .I.~ ~') 35 29 i Ii 11 37 Zl S 1~ 45 40 Z S ~ 45 ~.I3~Tm./S 3UTH 2~'$T/W: ST ~IST. .=' =_T ~-" 5 E T F'~ET O,O0 ~; 0.00 0.:~I f: 0.41 0 · 5 ~ '- "~ 54 0.5~ ~ 0.56 0.57 ~_ 0.57 we .. C ~e ~ l. OO F 1.14 i ~ * = 1 . '53 I .~ ,~ I .55 S 2.01 1.35 ~ 1.~2 I .~.9 ~ !. 35 1.ii ~ 1.~1 0.~1 e 1.75 0.5? W 3.90 3.70 W 5.13 J. ~ ~ W 7.57 3.43 W .~..~ ~ 0 ~7 W 1n ~.~3 W 13.32 1.3~ W ~0.3~ 0..~4 W 62.7~ O.S3 5 ~'~.17 6,I6 W 152,~4 i2.54 W l~O.13 ZO.~7 :,~ ~32.35 3Z.lB W 277.5! 44.ZZ W 3Z3.i3 57.45 ~ 373.33 70.i7 :.4 ~33.35 81.5~ ~ 93.13 w 552.14 13).71 231. '75.7~ 323.11 37 _--., )'~ ~+27,53 ~5.53 605.35 67.00 FT DEPARTURE &ZIM!JTH 3~'S MIN ~RCO ~L.~S<,A, IqC. 3 ~i - $ N]RTH SL3m~,ALASK4 ~'NT~R°OL~T=3 V,~L.U':3 ;Oq :V~i InO FZ-T T~UE ~JF-S:A ~EASURED YE2TICAL VZRTiC~L DEPTq DEPTfl DSPTd 4000.00 3323.4~ 3755.49 ~100.00 3~9~.5~ 3831.54 ~200.00 397~.90 3907.00 ~300.00 4050.06 3993.05 4500.00 4203.62 ~135.~£ 4500.00 ~280.92 ¢213.92 4700.00 4355.51 4291.51 4~00.00 4~36.33 4359.33 4~00.00 4514,47 4447,47 5000,00 45~2,7~ 4525,73 5100,03 ~571,i5 ~604,15 5200.00 4748,36 46~1,36 5300,00 4824,91 ~757,01 5~00.00 48~9.~i 483Z.~1 5500.00 a9~6.15 ~0).16 5500.00 5052.7~ ~9~5.7~ 5790,00 5129,11 5062,11 5800.00 5203,32 5135,02 5900.00 5276.93 520~f93 6000,00 5350,~2 5293.92 bl30,O0 5~25,!3 535~,!5 6200.00 5499.51 5432.51 6300.00 557~.30 3507.30 0400,OJ 3649,3~ 55~2.39 6500.00 5724.66 ~657.65 6500.09 5800.0~ 573~.04 6700.00 51~75.71 580~.71 6800,00 5951,27 5~34.27 6~00.00 5027.16 ~6~.16 7000,00 5103,17 5035.17 7100,00 6178,20 6111.2J 7230.00 5253,59 51~6.5~ 7300,30 5330,66 6263.05 7400,00 6409,15 $3~2,i5 7500.00 6488,56 54£1.36 7690,00 6569,~3 6522,43 7700,03 5550,58 55~3.5~ 7ZSO.OO 56~1.!5 ~.62~.15 C 0 J C S ~: V ~Z R T I C -1L 2 ]~q- ~ D=ViATI3'~ ~1Z i ~<!u T q S::STICN S~Vi2 3':G ql~ 3£3 MIW F~T DtG/1 C = ,qiaSUq"9 ITY "~]RTq/S 57,00 ,It~R C2"JR:IiF4AT~S HDR Z. D~Oa, RTURE odrq EAST/W':ST DIST. IIZ I qIJTH F~ET FF:~T O':G MIN 114,36 W 679,97 125,00 W 745,04 13~,33 W Bl!,55 144.33 'W 57.5.55 162,'33 W i00~,65 170,20 W 106{,06 i.{.J.O0 W 1193.{~ !94.~0 W lZ56.27 202,19 N 1313,:~0 ~'~9 ~0 W IA'~0,53 217.53 W 225.57 W 1509.49 233.3~ ~ i574,~ 241,12 :~ 153S.15 248,~,..~ W ~703,44 256,31 W ! /67.)5 25{.60 W I~35.25 27~.7~ W 1902.56 277.')6 W 1--)6)~.30 295.35 W 2035.74 29!.74 ;~ 2103.47 29{.10 W 2169. 36~.Z2 W 2235. 3!0.']~ W 230!,5~ $15,5~ W 2367.27 320.68 W 2432. 325,35 W ]4')7, ~3 32),71 W 25~1,~2 333.:19 ~ 2627.77 333.55 W 2593.77 344.9~ 'N 2759.44 353.30 W 2223.14 36.1,~3 ,4 2'5.%'5.11 36~. ~ ~ 2"~5.74 377,53 W 3~04.70 3~5,05 W 3J,53.1~ 35 J.'~2 w 3Jq2. 35 S 9 43 N S 9 35 W S 9 33 ~ S 9 23 w S ~ 16 W S 9 10 S 9 3 S 3 57 S ;3 5 3 w S 7 17 N S 7 S 7 10 S 7 11 ',,~ S 7 12 ,~ S 7 1Z ;~ .~ 7 13 S 7 13 $ 7 13 N FT PaGE 3 ~CO ALASKA, INC. 3N-6 KUP&RUK NgRTH SLOPE,&L&SK~ V':RTIC~L VERTICAL ]:'S qZi,i DES 100 200 400 500 600 70O 775 O.OO 0.00 -67.00 0.00 9:)9.99 932.99 0.00 1999.96 1952.95 0.00 2921.£3 2~I~.23 O.O3 3~23.~9 3755.4:~ O.O0 ~5~2.73 ~525.73 0.00 5350. ~2 52~3.92 0.00 5103.~? 5035,17 0.00 5691,15 552~.15 1333 VEqTI"&L gS:}LEG SECTZDN S;'V~RiTY ~..j~DPT~/ 'E O.O0 J 0.~$ 0.17 _i 5.37 W 1~!.5~ 2.53 W 67~.95 ,,~ .~5g,4~) W :6o6 4' 1.4q W 30~0.53 ~TE 3= SJ~VEY: 3-31-~5 ELLY 5USHING ~L~VaTiON: =NS I'.,~E = R: W=ST S 0 ,J T H f 57. ']0 ,SOSqJiN&TES '-!,]~IZ. DEPARTURE E.~ST/WiST D"ST. '~ZI~UTH ,=~=T F-- :~ T DES S 54 5O E S 6 5 W S 2 15 W S 9 43 W 5 7 17 7 13 W FT 3N-6 NJRTH SLJPE,'AL~SKA T~Uf MSASURE3 VERTICAL V~RTi'AL 3EPTH DSPFq OE;TH O.OO 0.00 -57.00 57.00 57.00 0.00 157.00 157.00 103.00 267.00 257.00 357.00 357.00 300.00 ~57.00 ~57.00 557.00 ~57.J0 ~O0.OO 567.00 557.00 500.00 767.01 757.00 700.30 367.01 857.30 800.00 967,01 967,00 900,00 1067,01 1057.00 lOOO,O0 1157,01 1157.00 110~.~ 1267.01 1267.00 1357,01 1367,00 i300.00 1457,01 1467,00 I~JD.90 1567,01 1567,00 150J.]O 1557,01 1667.00 1600.00 1767.02 1767.00 1700.00 1857,02 18.57,00 15OO.O0 1957.03 1967.00 1900.00 2057.0~ 2057.00 2003.30 2157.05 2157,30 2100,00 2257.06 2257,30 2202.00 2357,0~ 23.57.00 £30~.00 2457,39 2467.00 256~.5~ 2567.J0 2570.92 2657.00 26C0.00 2774.27 2767,00 2?OO.OO 2984.~ 2967.00 2903.00 3092.55 3057.00 3009.03 3203.03 3167.00 3315.57 3267.33 3ZO0.OO 3431.15 3357.00 3303.00 354~,30 3467,00 3~03.3J 3571,3~ 3567.00 3500.00 3796.52 3667.00 3503.00 392~.$3 3757.00 3703.00 ~05~.06 3~57.J0 3~09.0J C~JRSE -'=VIATI]N AZI~OT 0 3 0 2 0 0 11 0 15 0 17 0 7 0 0 0 25 J ~2 0 0 0 ,j Z 10 13 15 g5 :I ~2 24 57 2S 3i 33 37 47 -- I) Lq = V- OAT~ '3: SJRVEY: 3-3!-86 K~:LLY '~USHiNG E' "V&T£ON: I 0= S!J--S=.A 3EmTH ~G RECT.:N-tJLaR RiTY ',iC'qT~/S',']bTm 100 !.~t 147.34 S 3.2! 1{S.7~ S £. ~5 :Z32.73 .S 1.45 2~£.75 S .,.:~ 33~.:~ S 3.~,~ 3~.79 S J.":, ~5~.!0 S 1.17 5"2.17 S £.3J 521.20 S ..... :,.17 S 2RD IN~ TES 'S T/;,,~ :- S T :_ ET =E~T 0,00 0,38 0.38 0,51 0,55 O- 55 3,57 1.O0 I 1.~5 !,6~ 1,50 1,50 i.'~3 !.23 <3. 36 0.39 0.12 0.53 2 · O1 1.96 !. 97 1.36 1.74 1. ~ 3 2.57 3.53 4.6 9 0 · 70 3.53 0.49 1.75 2 · 19 0.72 0.39 1. OZ 5.39 11.)9 21.29 33.98 45.28 63.99 75.34 92.73 105.35 1£0.~0 147.~4 1~7.13 !33.70 29~,70 342.31 404.q7 475.60 550.04 539.32 71~.40 67.00 ~T AZIMUTH CSM~LITa. TZ]N D.~T:: 15-~PR-,qS P~SE 5 lNT~RPDLaTED VaLUiq FnR _=V'=,N 10,J . ,~ T~U5 SJ~-S~a ~E&SURED VE~TIC&L VHRTiC&L DEPTH DEPTq DEPTH 4190,7% 3967.00 3903,00 4322.18 4067,00 ~OOO.O0 ~452.44 4157.00 4100,00 45~2.01 4267.00 4710.~ 4367.00 ~30O.O0 4967.12 4567.00 5094.72 4667.~0 4600.00 5224.5~ ~767.00 5356.72 4~57.JJ 5518.55 5057°00 5009.0? 5751.09 5151.00 5100.00 5886.57 5257.~0 5200.00 6021.57 5367.S0 5156.25 5~67,$0 5400,00 6290.25 5567.00 550~.00 6423.46 5667.00 5600.00 6556.1~ 5767.00 5700.00 55~.~9 5857,00 580~.00 6~20,75 5967.00 5952.39 5057.00 5003,00 7085.02 6167.00 7217.50 6267.00 7346.53 6367.~0 6303.00 7~72.91 6457.0~ 6403.~0 7597.01 6567.00 7720.24 6667.00 6600.00 7750.0~ 5691.15 56£~.!5 D~Vi~TZJN ~ZiMUTq 40 ~7 S 3 3*= W ~0 .3 S 8 13 .39 ~0 S 7 44 W 39 15 S 7 15 w 5'~ 3'~ S 7 3,B ~;3 S 7 17 33 Z5 S 7 1 W 40 ~7 , q7 ~ ~ W ~0 .36 D,~'T'Y ~F SjtV~Y: 3-31-~5 K=LLY :? U S W l ~.] G SU~-S:~ D'-~TH V~RTIC6L DJSLZS ~TY S~CTiON 'SEV~ . ~-, 97a, 31 C .~ 1056.6'~ t135.30 0.33 i21,~.4~ 0.33 12'93.01 ,~, 1~53.00 3.7~ i~'~..=. 01 1'q73.2.~ 0,15 Zn7 ~ ,~ n Z152.9~ b.5~ 2250.7{ 2424.1j 251'],37 2.i~ 2575,60 1582.37 0.7~ 276q.2° 2.51 2927.74 1.{3 57.00 794.3S S ~ 7 ;5.76 961.42 S 1.'343.11 S !12~. ?,~, S 1 Z ':? 3 · $ 6 !351.25 S 1443.4~ S 1529 . i ~ S Cn,S~Jiq~IT2~.~ _. H]qI'~. 3=P~RTUR:,_ ~ E,~STIW:qT_ ~iST,., .AZi~IUTH. F ".-i £ T CE~T OEG 1'~_; 3. ':~2. ',~ 305,59 145,39 '.'.4 ~90.$7 !57.9B W 974.32 ~7~. ? '=, W 11 '~..S'.o~, IS).2J W 121S.44 129.62 ~ !293.03 20':~.41 W 137F.26 > IS.54 W !i50.05 22m.'~5 W 1546.3~ 2492..15 P57= S7 2652,~9 =749.!1 £329.74 2?05,31 ~7S 15 3350.55 7367.~1 240.19 W 153!,44 2f.O,Z~ W 17!5, ~0 260.03 W 1~J2.20 26~.'~2 w t~3,53 279,51 W 198~,32 l~ ~9 W ~074 3~ 297..$9 W 2t63.4~ 305.~2 W 2,!51,36 313._?I W ~'~33:~.52 323.11 W 2~25.03 325.2B W 2511.44 331.90 .J 25'~6.87 337.:!~ W '2553.84 345.35 W 2770,~ 357,32 W 2~2.21 3~7.75 i,! 2~2q.49 377.31 W 3002.95 3~5.5~ ~ 5074,96 3~8.~2 W 3J~2.35 g 27 W 8 17 w '.~ 5 W S O ~ 7 54 W 7 41 W 7 35 W 7 27 W 7 ZO .~ 7 I.~ W 7 10 w 711 N 7 1 Z .4 7 13 W 7 !3 ~, 7 13 ARCO ~L~SKA, INC. 3'/-6 KUPAR'JK NJRTH 5LJnE,ZlLdSKA TOP a~SE TOP 5~SE PBTD TD ;,1 d R K E ~, KUP~qUK C K!.Ja ~ RUK C KUoaRUK ,q CO~'!PUT~TIDN DATE: iS-APR-BY "NT"'q~SL&T=~_,. v&Ldci) Fnq.. CH'mS£N_~ ~£~ZZ]N~. TV7 1552' S 'J-2,- S -' ~ Car": ~= U- = . .-: u S .<V Y: 3-31-8~ K~LLY :}dSqlq.3 ELEVATION: £NSIW-E~': W:ST 57.00 329' $=L, qECTaNGU 2771.5 ~,lC.~ g~58.7 2 ~ ~ !. 9 3007.5 .?,',] 5 7.3 L]CdT!ON aT S~C 29, T13~, l~q CgORDIN.~T~S ]!JTq ~AST/WEST 349.27 w 354.5.3 W 351.B3 W 37v~. a4 W 380. ~9 W FT K~P~RUK NgRTH SLOP~,~L~S~ 57,00 TOP BaSE TOP BASE PBTO TD M~RK~R KUo~UK C ORi:S=W= 1552' q!&q:JR=~. ..~ D=OTN,; TV~,R 7253.00 5294.25 5227. !5 739~.00 o~Oa.3:~ 533 l, 39 7533.00 8515.!2 5~3. 12 7546,00 5806. 75 05'3 ~. 75 7750.00 553i.!5 ~.$2~.15 $ 3 2 9 ' ; RE'CT 27 2'~ ,.. ~T ~L, SEC 29, T13W, R9E, &NG'JL2~ CCOROIN~TfS TH/S]UTM ~&ST/i~EST 71,50 S 3~9.27 I0.~1 S _; . ~]~.?~ S 3~1.~3 W ~!.~~ 37,~5 .~ 38J,~9 W ~7.~i S 385.32 W ;INAL ME~SJREO DEPTH WELL LJ-~TTT]U TRj= V=RTTC~L~ ~ fiT T~' V~TI-&L 3~PTH 5 ,z s T ~N C.=_ a l !',IUT~ ~T 7750.00 65~1 15 S52~* ] 5 ~S ~2 ~ ......... ~ 7 ! 3 ,,w SCHLUMBEROER O I RECT TONAL SURVEY COMPANY ~ ARCO ALASKA INC WELL 3N-8 F I ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOEO 31 - MAR - 88 REFERENCE O000?14~l ~WELL 3N-6 (1562'FSL, 329'FEL, S29, T13N , R9E) HORIZONTAL PROJECTION NO~TH 3000 2000 REF OOOO'71411 SCALE = 1/1000 IN/FT ! ooo - l ooo -2000 -3000 -4000 SOUTH -SO00 WEST -4000 -3000 - 2000 -; 000 0 1000 2000 :3000 4000 EAST WELL 3N-6 (1562'FSL, 329'FEL, S29, T13N, R9E) VERTICAL PROJECTION -2000 - 1000 0 0 ! 000 2000 3000 4000 gO00 6000 189. ::::::::::::::::::::::::::::::::: "'f'?"i'"'!"'i'-'i'"'f" ;....; ........... : ................. ~i" ~ . EXACT RAO!US OF CURVATURE METHOD TIE-IN LOCATION MEASURED DEPTH TRUE VERTICAL OEPTH DISTANCE NORTH DISTANCE EAST BOTTOM HOLE COURSE LENOTH LOCATION COURSE AZIMUTH MEASURED OEPTH TRUE VERTICAL DEPTH DISTANCE SOUTH DISTANCE WEST 0.0 FT 0.0 FT 0.0 FT O ,0 FT 3092.! FT 189.2 OEO 7750.0 FT 8691.4 FT 9067.6 FT 988.8 FT REF 00007~4~1 Form to be inserted in each "A~ive" well folder to check for timely compliance with our regUlations. OPERATOR,' WEEL NAME 'AND NUMBER Reports and Materials to be .received by..~ Required Date Received Remarks Completion Report ! Samples Mud Log Core Ch~ps ~Core Description ~ , Inclination Survey ,,, Directional , st Reports Production Test Reports Log Run ,D~g~t~zed Data STATE OF ALASKA ALASK, .~IL AND GAS CONSERVATION COMM, .iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Alter Casing ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P ri_ Re× 100350 Anchorage, .~.K 99510 4. Location of well at surface 1562'FSL, 329'FEL, Sec.29, T13N, R9E, UM At top of productive interval 1210' FNL, 678'FEL, Sec.32, T13N, RgE, UM At effective depth 1446'FNL, 710'FEL, Sec.32, T13N, R9E, UM At total depth 1506'FNL, 718'FEL, Sec.32, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 67 ' 6. Unit or Property name 7."¢¢eii 'n"u 6¥r' v., t 8. Approval number Permit #86-27 9. APl number 50-- 029 -21 538 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3670' Production 7696' 7750 6691 7646 6607 feet feet feet feet Size 16" 9 -5/8" 7" Perforation depth: measured true vertical 7306'-7324'MD 7446'-7460'MD 6335'-6349'TVD Plugs (measured) N o ne Junk (measured) Cemented None Conductor report not avail able. 1060 sx PF "E" & 290 sx Class C 300 sx Class G & 175 sx PF "C" 7414'MD 7416'MD 6420'TVD Measured depth 115'MD 3707 'MD 7731'MD 6446 ' -6457 'TVD 6422 'TVD Tubing (size, grade and measured depth) 2-7/8"~ J-55, tbg w/tail ~ 7381' Packers and SSSV (type and measured depth) HB-1 pkr @ 7165', lB WL pkr ~ 7361 ', FVL SSSV ~ 1808' 7440'MD 6441'TVD True Vertical depth 115'TVD 3595'TVD 6676'TVD 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Wel 1 History with Addendum) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] ~uK~) 1,5. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Enqineer (DAM) SWO/O04 Date Submit in Duplicate ARCO Oil and Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided, The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AKl134 Nordic #1 Operator ARCO Alaska, Inc. Spudded or W,O. begun Complete 4/22/86 Date and depth as of 8:00 a.m. 4/23/86 ICounty or Parish ILease or Unit -ITM North Slope Borough ADL 25521 Accounting cost center code State Alaska Completion API 50-029-21538 IWell no. 3N-6 I A.R.Co. W.I. 56.24% Date 4/21/86 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our ~Prior status If a W,O, 1800 hrs. I 7" @ 7731' 7651' PBTD, RIH w/2-7/8" compl string 10.1 ppg NaC1/NaBr Accept ri~ @ 1800 hrs, 4/21/86. ND tree. NU & tst BOPE to 3500 psi. Perf f/7446'-7460', 7306'-7324' w/4" guns, 4 spf, 90° phasing & 7414', 7416' & 7440' w/4" guns, 1 spf. Rn 6.092" gage ring/JB. Set WL pkr @ 7354' WLM. RIH w/2-7/8" compl string. 7" @ 7731' 7651' PBTD, RR Diesel in tbg & ann Fin rn'g 2-7/8" single selective compl w/lB pkr @ 7361' pkr @ 7165', "D" nipple @ 7373', SSSV @ 1808' TT @ 7381'. BOPE, NU & tst tree. Displ well w/diesel. RR @ 1400 hrs, 4/22/86. ND Old TD New TD 7651' PBTD Released rig Date 1400 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth 4/22/86 K nd of rig IType completion (single, dual, etc.) single Official reservoir name(s) Kuparuk Sands Rotary Well no. !Date Reservoir Producing Interval Oil or gas Test time Production Oil on {est Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 3N-6 3/10/86 Arctic Pak w/175 sx PF "C", followed by 56 bbls Arctic Pak. Drilling Supervisor Date AtlanticRichfieldCompany ~ Daily Well History-Final Report Inal~uetk~t~= Prepare and submit the "Final I:lel~rt" on the first Wednesday after allowable has Oeen assigned or well la Plugged, Abandoned, or 8old. 'Fibril Rll~rt" should be submitted al~o when operations ar~ suN)ended for an indefinite or appreciable length of time. On workovar~ whansn officlM test Is not required upon completion, report completion and representative test data in blocks provided. The "Flflel R~rt" form may be used for reporting the entire operation If space is available. District ICounty or Parish Alaska Field ILease or Unit Kuparuk River { ADL 25521 Auth. or W.O. no. ]Title AFE AK1134 I Drill Doyon 9 AP1 50-029-21538 O~erator [ A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun IDate Spudded [ 2/22/86 Date and del=th Complete rlcor(t for each day reported Accounting cost center code State North Slope Borough Alaska IWell no. 3N-6 Iotat number of wells (active or inactive) on this, est canter prior to plugging and / bandonment of this well our I Prior status If · W.O. 1500 hrs. aa of 8:00 a.m, 2/28/86 3/01/86 thru 3/03/86 9-5/8" @ 3707' 7750', (463'), Logging w/Schl Wt. 9.8+, PV 13, YP 5, PR 9.5, WL 5.6, Sol 9 Drl 8½" hole f/7287'-7750', 42 std short trip, C&C, TOH. & begin rn'g OHL. RU SOS. 7" @ 7731' 7750' TD, 7646' PBTD, RR 10.0 ppg brine Rn DIL/GR/SP/SFL f/7744'-3707', cont w/GR to 1700'. Rn FDC/CNL f/7744'-6950', CAL f/7744'-3707', RD SOS. TIH, C&C, TOH, LD DP. Chg rams to 7" &tst. RU & rn 184 jts, 7", 26#, J-55 BTC csg w/FS @ 7731', FC @ 7647'. Cmt w/ 100 sx Poz C1 "G" w/.85% CFR-2, .7% Halad-9, & 5% salt, followed by 200 sx C1 "G" w/.6% FDP C-344 w/.25% HR-5. Displ w/lO.O ppg brine, did not bump plug. Instl lower wellhead &tst pack-off to 3000 psi. RR @ 1315 hfs, 3/l/86. Old TD Released rig New TD Date 1315 hrs. Clal~lflcatlons (oil, gal, otc.) Oil Producing method Potential test data Flowing PB Depth 7750' TD 7646' PBTD I KInd of rig 3/1/86 Rotary IType completion (single, dual, otc,) Single Official reservoir name(N Kuparuk Sands Well no. Date Reservoir Producing interval OII or gas Test time Production OII on toot Gal per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date co rrected Signature For form preparation and d~illrlbutlon, see Procldurel Mlnull. Section Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Well History- Initial Report - Daily Inetrueflens: Prepare attd~lubmit the "Initial Rel~ert" on the first Wednesday after a well is spudded or workover operations ars started. Daily wo~ I~l~r to spudding should be SummarJzed on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFEAKl134 Doyon 9 ICounty. parish or borough North Slope Borough L,,se ADL 25521 or Unit Title Drill IStste Alaska JWell no. 3N-6 AP1 50-029-21538 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date end dep~, as of 8:00 a.m. 2/22/86 thru 2/24/86 2/25/86 2/26/86 2/27/86 IARCO W.I. [Hour 1500 hrs. IPrl°r st'tu' Complete record for each day regorted if · W.O. 16" @ 115' 3727', (3612'), LD Wt. 9.2, PV 13, YP 10, PH 8.5, WL 12.2, Sol 6 Accept ri~ @ 1200 hfs, 2/22/86. NU diverter sys. 1500-hfs, 2/22/86. Drl & surv 12¼" hole to 3727' C&C, POOH, LD BHA. 2300', Assumed vertical 2406', 2911', 3446', 3667', Spud well @ , short trip, 4.0°, S12.25W, 2405.9 TVD, 3.7 VS, 3.6S, 0.8W 19.1°, S 9.25W,. 2897.3 TVD, 112.7 VS, 113.4S, 4.4W 31.6°, S15.25W, 3379.0 TVD, 342.6 VS, 338.3S, 54.2W 36.3°, Sll.25W, 3562.3 TVD, 465.6 VS, 458.4S, 82.5W 9-5/8" @ 3707' 4520', (793'), Drlg 8½" hole Wt. 8.7, PV 3, YP 2, PH 10.0, WL 16.2, Sol 3 RU & rn 93 jts, 36#, J-55 BTC csg w/FC @ 3625', FS @ 3707'. M&P 1060 sx PF "E" w/5#/sx Gilsonite, followed by 290 sx C1 "G" w/2% CaCi~. Displ using rig pmp, bump plug. CIP @ 1400 hfs, 2/24/86. ~ND diverter. Nil &tst BOPE. PU BHA~ ~I~, tst csg to 2000 psi. DO flt equip & cmt + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole f/3737'-4520'. 9-5/8" @ 3707' 7030', (2510'), Circ lost circ pills Wt. 9.8, PV 12, YP 5, PH 9.0, WL 8.8, Sol 9 Drl & surv 8½" hole f/4520'-7030', lost 50 bbls mud, circ lost circ pills & observe well. 4332', 40.3°, S8.25W, 4071.7 TVD, 892.8 VS, 879.8S, 152.1W 4772', 39.0°, S7.25W, 4410.4 TVD, 1173.5 VS, 1158.0S, 190.0W 5244', 40.9°, S8.25W, 4772.3 TVD, 1476.5 VS, 1458.3S, 230.8W 5776', 42.8°, S7.25W, 5168.5 TVD, 1831.3 VS, 1810.0S, 278.7W 6150', 42.0°, S6.25W, 5444.7 TVD, 2083.2 VS, 2060.4S, 308.3W 6530', 41.0°, S6.25W, 5729.1 TVD, 2335 VS, 2311.0S, 335.8W 9-5/8" @ 3707' 7287', (257'), Drlg Wt. 9.8, PV 11, YP 5, PH 9.0, WL 6.2, Sol 9 Circ& observe well. Drl 8½" hole f/7030'-7130', lost circ, cut mud wt to 9.7 & spot LCM pill, TOH. Chg BHA, stage into hole, no fluid loss. Drl 7130'-7287'. 6844', 40.8°, S4.25W, 5966 TVD, 2540 VS, 2516S, 354W 7067', 41.5°, S3.25W, 6134 TVD, 2686 VS, 2662S, 364W 56.24% The above is correct Signature For form' preparation and dietrtbul~'ofl, see Procedures Manual, Section 1~, Drilling, Pages 86 and 87. Title Drilling Superintendent ARCO Alaska. ;' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 03-19-86 TRANSMITTAL #5604 . Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes plus Listings/ Schl/ One of each 3~-2A 01-31-86 Run #1 4540.0-8904.5"~' -- 3N-6 02-28-86 Run #1 1698.0-7759.0 Receipt Acknowledged: ~tate i'of Alaska' Alaska 011 & Gas Cons. Commission Anchorage ARCO Alllka. Inc. is · Subsidiary of AtlanticRichlieldComl)lny ~ STATE OF ALASKA -' ¢c~ ' ALASKA 0,~ AND GAS CONSERVATION CO~ ,MISSION ~- MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-27 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21538 4. Location of Well at surface 1562' FSL, 329' FEL, Sec.29, T13N, R9E, UM 6. Lease Designation and Serial No. ADL 25521 ALK 2557 For the Month of. February , 19 86 5. Elevation in feet (indicate KB, DF, etc.) 67 ' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3N-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1500 hrs, 2/22/86. Drld 12-1/4" hole to 3727'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7750'TD (2/27/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7646' Secured well & RR ~ 1315 hrs, 311/86. 13. Casing or liner run and quantities of cement, results of pressure tests · 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3707'. Cmtd w/lO60 sx PF "E" & 290 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 7731'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/7744' - 3707'; GR to 1700' FDC/CNL f/7744' - 6950' Cal f/7744' - 3707' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None Alaska 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED &~}~J ~ TITLE Associate Engineer DATE ~"/~"'~ NOTE -Report on els form is required for each calendar month, regardless af the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR28 Submit in duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 'telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3N Pad (Wells 1- 18) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you nave any questions, please call. me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L45 Enclosure If ARCO -' aska. Inc. is e Subsidiary of AtlanticRichfie.: Company ~.OCATED IN PROTRACTED SEe's 28 & 29, T13 N, R 9E,U.M. LOCATED IN PROTRACTED LOCATED ~N PROTRACTED SEC. 29, TI3N, R9E, U.M. SEC. 29, TI3N~RgE, U.M. 1 - Y = 6,013,799.67 LAT. 70°26'55.9615" l0 - y = 5,013,799.37 LAT. 70°26'55.9519'' X = 517,946.19 LONG. 149°Sl'i2.938" X = 518,~1.07 LONG. I49°51'04.865" 454' FEL, I562' FSL OG = 28.2 PAD = 33.7 179' FEL, i56~' FSL OG 2 - Y = 6,013,799.65 LAT. 70026'55.9606" ll - Y = 6,013,799.3Z LAT. 70026'55.9508" X = 517,971.Z~ LONG. 149°51'12.203" X = 518,246.03 LONG. 149°5i'04.13Z" 429' FEL, 1562' FSL 0G = 28.2 PAD = 33.8 155' FEL, [561' FSL OG = 28.5 PAD = 33.8 3 - Y = 6,013,799.54 LAT. 70025'55.9590" 12 - Y = 6,013,799.45 LAT. 70°26'55.9515'' X = 517,996.25 LONG.149°Sl'll.468'' X = 5~8,270.89 LONG.I49°5I'03.403" 404' FEL, 156Z' FSL OG = 28.4 PAD = 33.9 130' FEL, 1561' FSL 0G = 28.5 PAD ~ 34.0 4 - Y = 6,0~3,799.50 LAT. 70026'55.9580" 13 - Y = 6,013,799.41 LAT. 70°26'55.9505" X = 5~8,02~.~6 LONG.149°51'I0.736" X = 518,295.97 LONG. i49°Sl'02.666" 379' FEL, 156Z' FSL OG = 28.4 PAD = 33.7 ~ 105' FEL, 1561' FSL 0G = Z8.5 PAD = 34.1 5 Y = 6,013,799 ~ LAT. 70026'55.9572" m . - · .~ 14- Y = 6,013,799.33 LAT 70°26'55.9491" X = 518,046.18 LONG. 149°51' 10.002" ~ X = 518,320.91 L~G. 149°51'01.934" 354' FEL, 1562' FSL 0G = 28.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL OG = 2B.5 PAD ' 34.0 o x- s~,o~z.~ ~0,~.~'0~.~'' ~ x= s~,3~s.77 LO,~.]~os~'oz.~o~'' · ~ ~ 55 FEL, 1561 FSL 0G = 28.5 PAD = 34.0 7 - Y = 6,013,799.44 LAT. 70026'55.9556" ~ ~ ~ ~ 16 - Y = 6,013.799.25 LAT. 70°26'55.9471" X = 518,096.21 LONG' 149°51'08'533" ~ O ~ ~ x = 518,370.74 LONG. 149~51'00.470" 304' FEL, 1561' FSL 0G = 28.5 PAD = 33.9 ~ ~ ~ ~ 30' FEL, 1561' FSL 0G = 28.5 PAD = 34.1 8 - y = 6,013,799.45 LAT. 70°26'55.9551" ~ ~ ~ 17 - y = 6,013,799.26 LAT. 70026'55.9466.' X = 518,121.15 LONG. 149°51'07.800" ~ X = 515,395.63 L0~G. 149°50' 59.739" 279' FEL, !561' FSL 0G = 28.6 PAD = 33.9 ~ ~ ~ 5' FEL, 1561' FSL 0G = 28.5 PAD 9 - y = 6,013,799.42 LAT. 70026'55.9542" X = 518,146.15 LONG.149°51'07.066'' ~'~ SEC. 28,TI)N, RgE, U.M. 254' FEL, 1561' FSL 0G = 28.6 PAD = 34.0 ~ 18 - Y = 6,013,799.15 LAT. 70°26'55.9449'' X = 518,420.80 LONG. 149°50' 59.000'' NOTES ~0' FWL, 1561' FSL 0G = Z8.5 PAD = 34.0 I. ALL COORDINATES ARE A.S.P.,ZONE4. 2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD ~ ASSOC. 4. VERTICAL POSITIONS BASED ON MODULE PILES 3JOI -8 ~ 3J01-4. , , CERTIFICATE OF SURVEYOR; ~ ~E~EBY CERTIFY THAT I AM .... ~-.' ' / ;~E C~RRECT AS OF 14 JAN 86. -. ~- ~ ,~, ~n ~,qn ~ A~U AIOSKO, inc. ' 3~tE i4 JAN ~6 J~ :~ ~ ~ w~ DRILL SITE ~N CONDUCTOE .,, [l"Oe ,~ ....... January 30, 1986 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 TELECOPY NO. 276-7542 Re: Kuparuk River Unit 3N-6 ARCO Alaska, Inc. Permit No. 86-27. Sur. Loc. 1562'FSL, 329'FEL, Sec.29, T13N, R9E, UM. Btmhole Loc. I519'FNL, 824'FEL, Sec.32, T13N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. VBrsq truly yours, C. V. Ch~rtte~ton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO}-~MISSION dlf Enclosure ce: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 22, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3N-6 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill 3N-6, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on February 15, 1986. any questions, please call me at 263-4970. Sincerely, JRegional Drilling Engineer JBK/LWK/tw PD/L210 Enclosures If you have RECEIVED JAN 2 Oil & Gas Cons. Cornmissior} ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALASKA oIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~x DEVELOPMENT GAS [] SERVICE [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 9. Unitorleasename Kuparuk River Unit 10. Well number 3N -6 4. Location of well at surface 1562' FSL, 329' FEL, Sec.29, T13N, RgE, UM At top of proposed producing interval 1249' FNL, 781' FEL, Sec.32, T13N, RgE, UM At total depth 1519' FNL, 824' FEL, Sec.32, T13N, RgE, UH 11. Field and pool Kuparuk River Fi eld Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 67', PAD 33' ] ADL 25521 ALK 2557 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 329 feet 3N-5 well.:.:~ surface feet 17. Number of acres in lease 2560 16. Proposed depth (MD & TVD) 7730' MD, 6623' TVD 18. Approximate spud date 02/15/86 2902 psig@ 80"F Surface 3332 ..psig@ 6472 ft. TD (TVD) feet 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2327 feet. MAXIMUM HOLE ANGLE 41 oI (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 80' SETTING DEPTH MD TOP TVD 35' I 35' 35' I 35' MD BOTTOM TVD 115~ 115' 36961 3582' QUANTITY OF CEMENT (include stage data) + 200 cf 1060 sx PF "E" & 3661 ' SIZE CASING AND LINER Hole Casing Weight Grade Coupling Length 2~" 16" 62.5# iH-40 / Weld 12-1/4" 9-5/8" 36.0# 1-55/HF-E W BTC 22. Describe proposed program: i I 290 sx PF Class "G" 7696' 34 I 34' 77301 6623' 300 sx Class "G" neat I t ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7730'MD(6623' TVD). , Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2902 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annul i through the permafrost interval. 3N-6.._w__~i_].]_.?.~_.25._~?~y~_~rom_~.N~5 .at the sur~face. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) · 23. I hereby c.~fy that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Regional Drilling Engineer DATE Th e spac~'ow ¢ (~/oyissi~n us' e '-~' CONDITIONS OF APPROVAL Samples required Mud log required [~]YES ~NO []YES ~'NO Permit numbero~/~'- ~ ,t Approva~l da~)e~]. / 30 / 86 Form 10401 ~WK) PDt2 Rev. 7-1-80 Directional Survey required J~YES []NO APl number 50- ~,~q SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission January 30, 1986 Submit in triplicate PERMIT TO DRILL 3N-6 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED ARCO ALASKA, INC. PAD 3N. WELL NO, 6 P. JPOSED KUFARUK FIELD. NORTH SLOPE. ALASKA . EAST~IAN WHIPSTOCK. INO. SURFACE · 1000 BASE PERI1AFROST TVD=1717 2000 KOP TVD=2327 TI'ID=2327 DEP=O TOP-U~NU SNDS TVD=2457 TI'ID=2457 DEP=4 .3000 4000 .. 5OO0 60O0 I I I 0 1000 2000 3000 .............. VERTICAL SECTION - -- 7000 TOP W SAK SNDs' '1'VD=3152 TI'ID=3180 DEP=187 K-1 2 TVD=3382 TI'ID=3445 DEP=31 8 ~39" EOC (9 5/8' CSO PT) ~~ TVD=3582 TMD=3696 DEP=470 ~ AVERAGE ANGLE ............. .........: % T~ ZONE D TVD=6262 THO=Z252 DEP=2807 ~ T/ ZONE C TVD=6309 THD=7314 DEP=2847 ', ~', T/ ZONE A TVD=6362 THD=7384 DEP=2894 ~ TARGET CNTR TVD=6391 THD=T423 DEP=2919 B/ KUP SNDS TVD=6472 THD=7530 DEP=2990 TD (LOG PT) TVD=6623 THD=7730 DEP=3121 1 4000 JAN 2 0;! A HORIZONTAL PROJECTION SCALF~ IN. = 1000 FEET ARCO ALASKA;-~ 'i'NO;'- : ........... ' PAD 3N. WELL NOt 6 PROPOSED /11~ KUPARUK FIELD, NORTH SLOPE, ALASKA EASTMAN WHIPSTOCK. INC. 2000 .... 1000 ,,, . _ 1000 _ . 2000 _ ;3000 _ WEST-EAST .... 1000 0 I I 4000 _ TD LOCAT !ON' 1519' FNL, 824' FEL SEC. 32, T13N, RGE: 1000 ,. SURFACE LOCAT I ON ~ 1562' FSL, 329' FEL SEC. 29, T15N. RgE TARGET CENTER TVD=6391 THD=?423 DEP=2919 SOUTH 2882 WEST 463 TARGET LOCATION, 1320' FNL. 7*92' FEL SEC. 32. T13N. RGE ''S 9 DEC 8 MI N W 2919' (TO TARGET) J,A:N 2 4 ,,Oo= -' 8O0 ,I 800 _ 7'00 _ 600 _ 400 _ 300 _ 200 _ 6OO ; I ",2.000 \ · 500 I \ "~ 8-500.......%,,1500 400 ,3OO 200 I , 3OOO 800 ?5000 I ,, 7'OO / 1500 i 600 ~ Soo I1 I I I I I I I I' I I 200 500 400 300 ,1 O0 I , I 100 .1 O0 - _ i i KUPARUK R I VEtR UNIT 20" DI VF_J~TER SCHEMATIC J 5 DE S CR I PT I ON L_ i. IG' COhOUCTOR. 2. TANi<O STARTER MEAD. 3. TANKO SAVER SUB. 4. TAI~<O LO~R OUICK-CONINECT ASSY. 5. TAt~<O UPPER OUICK-CCt,,t~CT ASSY. 20' 2000 PSI DRILLING SPOOL W/I O' OUTLETS. ?. I0' HCR BALL V~LVF_~ W/I.O' DI VERTER L I KEno VALVEJ[ OPEN AUTOMATICALLY UPON CLOSURE CF ANN.A_AR PREVENTER. 8. 20" 2000 PSI Ah, rdJLAR PREVENTER. MAINTENANCE & OPERAT. ION , ~m I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES ' HAVE OPENED PROPERLY. 2. CLOSE ANINULAR PREVENTER AND BLOW AIR THROUGN DIVERTER LINES EVERY 12 HOURS, CLOSE ANINULAR PREVENTER IN THE EVENT 'THAT AN INFLUX OF ~LLBOR1E FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANtJALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE DONNWIND DIVERSION. DO NOT SHUT IN ~LL u~R ANY: ~ ~=~CJJ~_~TA~ES. JAN 2 4 ]~S $1~ R4 6 DIA~AM #1 I ~-.5/' ~:,OC)O PSI RSR.RA BOP STACK I. 16' - 2000 PS! TAN(CO STARTINS FF..AD 2. I1' - 3000 PSI CASINg FE. AD 3. I1' - 3000 PSI X 13-5/8' - ,5ODD PSI SPACE~ SPOCL 4. ID'-5/8' - 5000 PSI PIPE RA~ 5. 13-5/8' - 5000 PSI DRILLING SPCEI. W/Q-K3~ AND KILL LIhF_S 6. 15--5/8' - 5000 PSI DOUBLE ~ W/PIPE RAb~ CIN TC~o '7, 13--5/8' - 50C0 PSI ANN.I_AR ACO, MJLATOR CAPACITY TEST I. C~ECX AND FILL A(~TOR R~OIR TO 'PRC~ LEVEl. WITN ~~IC ~UID. 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ I~ ~i ~T~ ~ ~ ~~T~. 3. ~~ TI~, ~ ~ ~ ~ITS SIXThlY ALL ~ITS ~ ~~ MI~ ~I~ ~ ~. 4. ~~ ~ ~ ~T, ~ A~T~ L~ LIMIT P~~. 5 4 13-5/8" BOP STAO< TEST I. FILL BOP STACK AND CHO<E MANIFCLD WITN ARCTIC DIESEL. 2, C~CX THAT ALL LO~ D~ S~ IN ~E2_LJ-F~ A~ FI~..LY F~C-TRACTED. SF_AT TEST PLUG IN WITH Rt~ING JT AAD RglN IN LO~ SCREW. 3. CLOSE ~ P~ AND MANJ~ K,ILL LI~ VALVES ADJA~ TO B~P STAO<. ALL VALVES AND O-O<ES S~ BE CF~N. 4. PRE~ UP TO 250 PSI Ahf) HOLD FOR I0 MIN. IN- CREASE PRE~ TO 3000 PSI AND HOLD FOR I0 MIN. BL.~Fo RRESSURE TO 0 PSI. 5. CPEN ~ PR~EVENTER Aha) ~JAL KILL AND CHOKE LI~E VALVES. Q_OSE TCP PIRE ~ AND HC~ VALVES ON K~LL AND CHO<E Li~S. 6. TEST TO 250 RSi AND 3000 RSI AS IN STEP 4. ?. COVTIh~JE TESTING ALL VALVES, LI~ES, AND WITH A 2_50 PSI LC~ AND 3000 PSI HIGM. TEST AS IN STEP 4. DO NOT PR~SSL~ TE~T ANY Cy~KE THAT IS NOT A FULL CLOSING POSITIVE SF_ALC~ ONLY FlJNCIIC~ lES1 C~K]K~$ THAI DO NDI FlJ_LY CLOSE:. 8. ~ TOP PIPE PoNV~ AND CLOSE ~OT'[C~ PIP~ TEST BOTTC~ PIPE RAN~ TO ~ RSI AND 3000 PSI. 9. OPEN BOTTC~ PIPF~ RAN~, BACK OLfT RUN~ING JT AND .~0. CLOSE BLIND RAV~ AND TEST TO 250 PSI AND .3000 PSI. I1. ~ BLIND RA~S Ahf) RETRI~E TEST PLUG. N~<E SURE MAJNIFO_D Ah~ LIh~S ARE FULL. CF NON-FREEZING. FLUID. SET ALL VALVES IN DRILLING POSITIC~t TEST STAh~PIPE VALVES, K~ l:Y, KE].LY COCKS, DRILL' PIPE SAFETY VALVE, AhO INSIDE BOP TO 2_50 PSI AgO 3000 PSI. 13. RE~ TEST I~FO:~ATION C~ BLC~K~JT PR~ TEST FOG~, SIGN, Ahf) SF_hO TO DRILI. ING SUPERVISDR. 14. RF_R~O;~ ~ETE BO:~ TEST AF-FER NIPPLING UP AND ~EY_KLY T~_REAFTER FUNCTI~LY OPERA~ BGPE DAILY. RECEIVED JAN 2 4 IS$ Alaska Oil & Gas Cons. 510084001 REV. 2 APPROVE' DATE 3. 4. 8. (2 thru 8) '(8) ~ ' (3> ..Admin ~04~ /-ZT'.-:~'~ 9. 5 d~//Z9 thru 1/~ 10. (10 and f2) / 12. (13 thru 21) (22 thru 26). 13. -14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. ompany LeaSe & Well No. K~ YES NO · , - Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. /7~0ff . Is well located proper distance from property line .................. f/~d~ Is well located proper distance from other wells .................... f~0~ Is sufficient undedicated acreage available in this pool ............ /~ Is well to be deviated and is wellbore plat included ................ ~ IS operator the only affected party ................................. /~ , , Can permit'be approved before ten-day wait .................... ' ....... ~d~ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ..................... Is the lease number Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will'cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ...... ......... Will all casing give adequate safety in collapse]~si~n';nd ~urst Is this well to be kicked off from an existing wellbore ..~ .......... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ,~ _ / Does BOPE have sufficient pressure rating - Test to ~,_~)~ psig ,, Does tho choke manifold comply w/APE RP-53 (Feb.78) .................. A/o~r Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ . o Geology: JAL rev: 03/13/85 6,011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS g. aREA NO. SHORE 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. · LIS T~E FE~!;ICATI3~ LISTIN~ O!O.MOZ VERiFiC~TiS~ LISTINZ ~AGE I SfR~ICE Na~E :fDiT :35/03/10 3RI3IN : ~E~LN~ :149388 ~D~TIN~TIDN ~ :01 PR~V'!Dg$ R~EL : COqMENTS :~IBR~RY TAPE H:~DER ~, SEq~ICE NA~E :EDIT ]&TE :85/03/10 DRI3ZN :0000 TAD5 N~ME :1317 SO~TZNg~TIDN ~ :01 ~RE~IOJS T~PE : CQMMENTS :LIBRarY T~PE =ZL~ N~M~ :Eg!T .001 5~RVICE NAME : DArE : MAXIMUM L~METH : i02~ FIL= Typ= : ::-~; iNFDRM.aTi3N qEC~,RDS ~- ...... qN'_'~ C2~TENTS NN : 3N-5 :N : KJ~ARU< TSNN: SEST: 29 ST~T: ALASKA CT~Y: JNIT TY~5 000 OOO OOO 033 O03 003 003 003 039 TY~{ OJO 300 O00 900 JO0 3O0 300 30O JO0 O00 '" ~T E 300 SIZE 019 00~ 008 OOZ 004 002 005 0O3 SIZE '2DE 065 065 055 065 065 065 065 065 065 -- 055 J85 NU~5ER ,6T. &CC: 71~17 ~U~ ~1' DATE LDSG'E~: 2~-FES-86 LD~: L. B. CgDNEY SASiNS = ~.62'5" TY~E FLUID = USND DEqSITY = ~.8 L~/S ~ZS5OS!TY = ~8.0 S :LJID L3SS = 5.2 ~3 ~ 3707' ~IT SIZE R M ~T 7750" : 3. 510 : 3.1TO : 2.550 : 1.937 73.0 OF 68.0 OF 72.0 OF 138. Dm M6TRIX SaNDSTgNE S'-HLU~ER3ER L3GS INCLUDED W~TH T~IS M~SN~TZS TAP;: · ,- DJAL tNOO3TI]~ SP~ERISALLY FD'~JSED :',: 2ATA AVaiLABLE: 370~' T~ 7735' ~'.,- :3R'~ATISN DENSITY :;= 2AT~ AVAILABLE: ~:~ SAMMA RAY IN 'ASI~G =~ DAT~ AV~iLAB: E: 3733' 'T:~ iTOO' - OlO.H02 VSRI=IC~TIDq LISTiN3 P6SE 4 ENTRY 5' OCKS~ R~DB NP~i 3=_DT SP R-~35 ~P~I SP 3=~T SD 775'~. 5003 S.=~J -135.0525 GR 2. ~+70~ 3R-~3 35.5~3~. NCN, 7700.3000 SFLJ -lg.3232 2.533~ DRtD 35.9529 NCN' 7500.0000 S;,J -35.1133 SR 2.3752 D~t] 7500.0000 SF~J -2Z.1)~2 SR 2.4084 DRHD 37.3117 7400.0000 SF~J -21.3701 SR 2.4152 O.q~] 66 55 73. 55 65 AP1 APl ~Pl ~ILE TYP6 CLASS ~D 000 gO 0 O 220 O1 9 0 120 ~5 O O 1ZO 44 9 0 010 O1 0 0 310 O1 O 0 310 O1 O 0 280 O1 0 0 350 02 0 0 356 O1 0 0 420 Ol 0 0 000 O0 3 8~0 O0 O 0 33D 31 O O 330 30 0 0 310 01 O 0 ~!.7148 0.201! 2131.5000 3.4338 39.0273 0.2~1 2.7249 71.9548 0.3342 1~58.5575 B.2353 74.7148 0.3239 2255.5000 ill FC~L iLD 3R NRAT FC~' ILD NRaT FC~' ILl G~ NR~T FC~L ILO N~AT .5.4929 3.~5~8 0.0293 ~NTRY 1 . lin 1 0 SIZE SPL 1 1 1 I ¢ ~ 1 4 I 1 2.9299 ~!.7148 3.0920 550.3123 2.9327 39.0273 5~3.3125 2.3555 3.5~97 503.3906 7.0242 74.714~ 3.1B19 517.3125 5.5554 ~3.954~ 3.0393 REPR PROCESS C~DE (OCTAL) 5B 00000000090000 5~ 00000000000000 5~ OOO00000000000 iL4 CALl RNR& SR IL~ RNR6 iLM S~LI RNR~ IL~ CALi RNR~ ILM CALI RNRA 00000000000000 OOOO0000000000 00000000000000 00000000000000 58 00300030000000 53 00000000000000 OOO00000000000 99000000000000 00000000000000 OOO00000000000 58 00000000000000 OOOO00OO000000 53 00000000000000 2.519~ 8.5020 3.2756 -999.2500 3.1505 3.3056 3.2522 -9~9.2500 2.3276 8.70!0 3.8~09 -909.2590 7.1960 5.7207 3.5526 -999.2500 5.7390 8.3145 3.1174 OIO.HOI V.ERi~IC~TI3~ Li3TiN3 P~JE SP SP SP qPqI ]EPT S P RH35 NPqI SP SP ~ , SP SP qPqI 3E~T SP ~HDB ~P~I SP S~ 34.2773 NC~L 7300.0000 SFLJ -16.198Z SR 2.6760 OR~3 34.~727 NC~~ 7!00.0000 S~LJ -8.4199 GR 2.¢~65 DRH3 7100.0000 SFLJ -38.9579 GR 2.3225 DRq3 49.2575 NCNL ?000.0000 SFLJ -38.925~ JR 2.3323 DRH] ¢7.7051 NCN. 6900.0000 S~kJ -$0.4883 gR -9'99.2500 DRS] -~99.2500 ~C~U 6800.0000 SF~J -35.~570 3R -999.Z500 3RH] -999.2500 NCN. 5700.0000 SF=J -59.9853 ~R -999.2500 3Rq3 -999.2500 ~CN~ 6500.0000 SF~.J -58.4383 JR -999.2300 ORt3 -999.2500 NCW~ 650.3.9000 SFLJ -56.7383 3R -~9~.2500 DR93 -999.2500 NCN~ 6~00.003D SFLJ -43.5738 -~99.2300 DRH] -9~9.Z500 NC~_ 6300.0000 SFLj -37.9258 2273.5000 r-C~L 4.3835 78.5273 O. 130'~ NR~T 23P7 5000 2-6858 115.0273 0.0220 1.6250 ILl 109.3398 &R 0.0127 NR~T 1737.5875 FC~=. 2.17~1 ILD 110.3398 GR 0.0145 NR~T 1730.5875 FCIC- 2.8555 iLD 12~.2773 GR -999.2300 NR~T -9~9.2500 FCqL 5.8562 IL3 132.3125 -9~9.2500 -9')9.2500 3.8535 IL2 137.5525 GR -9~9.2300 NR~T -999.2500 FC~L 3.~515 ILl ~4.9223 GR -9~9.2500 NR~T -9~9.2500 FC~L 2.3948 ILO 134.8123 GR -999.2500 NR2T -9~9.2300 ;CNL 2.~358 -999.2500 ~.!921 IL3 B3.$395 gq 728.8125 4.5593 78.5!73 C~LI 3.0~91 801.8125 2.9397 ILM 115. 0~73. 3.1370 RNR~ 558.8125 1.5782 ILM 109.3398 CALI 4.0085 RNRa ~!6.8906 3R 2.1~97 IL4 110.3398 C~Li 3.9512 RN~ 427.5~06 2.5315 -999.2500 CALI -999.2500 -999.2500 2.9788 ILM -999.25:00 CALI -9'~9.2~00 RNRd -999.2300 JR 3.2345 iLM -999.2500 CALl -999.2500 RNR~ -999.2500 3.7554 IL4 -999.2500 CALI -999.2500 RNR& -999.2300 GR 2.5100 iLM -999.2500 CALl -999.2300 RNRA -999.2500 gR 2.6}56 ILM -9~9.250J C4LI -999.2500 RNR~ -999.2500 GR 3.9924 iL4 -9~9.2500 C~i i~ -999.2500 4.3328 2,9006 -999.2500 3.1135 9.9395 3.27.37 1.5837 10.5426 4.1548 -999.2500 2. 2775 11.9963 4.1509 -9~99,2500 2.5555 -999.2500 -999.2300 -9~9.Z500 3.~202 -999.2500 -999.2590 -999.2500 3.~299 -9~9.2500 -999.2500 -999.2500 3.9590 -999.2500 -999.2500 -999.2500 2.7561 -999.2500 -999.2500 -999.2500 2.8323 -g99.2500 -9~9.2500 -999.Z300 ~.2975 -g~g. ZSO0 · ~ Olg. H02 VERIFIC,~TI3~ LISTIN3 PAGE ~Pqi -999.250D NC~ -939,2500 NRAT -9~9.2500 FC~ 3E=T 6200,0000 SFLO RH35 -999,2300 ~R53 NPHI -999,2500 NC~_ 2,0530 IL3 109,1523 GR -999,2500 NR~T -999,2500 FC~ 3E~T 5100,0000 SFLj SP -4:5,1445 ~PqI -999.2~00 2 · 95 ? 3 I L ] 12'7,5898 -999,2500 NR~T -999,2500 DE=T 6000,0000 SFLJ SP -~2,t758 GR RH]5 -999,2500 ORq3 MPHI -999.2500 NC~_~ 2'1956 IL2 105,2773 GR -999,2500 N'RAT -999,2500 FCNL DEPT 5900,0000 SFLj SP -50.22T0 SR RH35 -999,2500 ~PqI -999,2500 NCq~ 3,4Z2t iLD 130,3!25 -999..2500 NR~T -999,2509 FCic 2E~T 5800.0000 SFLJ RH]5 -999.2500 9RH3 ~PHI -99~.2500 !,516B 1~2,0~9B GR -999,2500 NR~T -999,2500 FCNL 9E~T 5700,0000 SF~j SP -51,9883 GR ~H33 -999.2500 gRq3 ~Pqi -999.2500 NCNL 2,7327 iL3 94,5523 GR -9~9,Z500 NRAT -939.2500 FC~L 35~T 5500.0000 SFLJ SP -52.2070 ~R ~H33 -999.2500 OqqD WP~I -999.2500 NCN~ 2.8967 ILD 132.3Z73 GR -999,2500 -9~9.2500 :CML ]~DT 5500.0000 SFLJ SP -50.4258 RH3~ -999,2500 NP~I -9~9.Z503 2.5~92 ILl 39.$398 gR -999.2509 NRAT -9~9.2590 FC~L DEDT 5~00.0000 SF-J SP -57.7227 SR ~H]B -999.2500 DRflD ~D~I -999.2500 NCR: 7.$804 ILl 34,4548 SR -939,2500 NR~T 3E~T 5300.3300 SF J SP -57.7383 3R ~P~I -39~,2500 NCN_ 3.552~ -9~9.2500 ;CqL -999.2500 -999,2500 SR 2,5100 ILM -999,2500 CALi -939,2500 RNR~ -999,2500 ~R 2,9827 !LM -999,2500 CALI -999,2~00 RNR~ -999.2500 ~R 1,6172 IL~ -99'9,2500 CALl -999,2500 RNRA -999,2500 GR 3.3901 ILM -999,2500 2ALi -999,2500 RNRA -999,2500 GR 1.6~26 ILM -999,2500 CALl -~99,2500 RNa& -999.2500 ~R 2,7542 ILM -999,2500 CALl -999,2500 RNR& -999.2500 GR 2,9592 ILM -999,2500 CALI -999.2500 RNR~ -999,2500 SR 2.5022 ILM -999.2500 ZAcl -999,2500 RNq~ -999,2500 GR 5,a30~ IL~ -999.2500 CALl -999,2500 RNR& -999,2500 SR 3.7393 ILM -999.2500 CALI -9~9.2500 -999.2500 -999.2500 2.5705 -999,2500 -999,2500 -999,2500 3.0Z76 -999.2500 -999.2500 -999.2500 1,8165 -999,2500 -999,2500 -999,2500 -999.2500 -999.Z500 -999.2500 1,7276 -999,2500 -999,2500 -999,2500 2,8499 -999,2500 -999.2500 -999.2500 3.0569 -999.2500 -999.2500 -999.2500 2.5~23 -999.2500 -999.2500 -999.2500 7.5950 -999.2500 -999.2500 -999.2500 3.8284 -999.2500 -999.2500 ]E~T 5ZO0.O000 S=-j 2.972~ ill 3.3555 ILM ~.¢~17 SP ~,H35 -55.7383 SR 5100,0000 S~LJ -53,95?2 -999,2500 -999,2500 NC~.: 5000,0000 SFLJ -59,737'3 -999.2500 -999,2500 NC~ -68,2227 -99'9,2500 -999.2500 NCN~ %BO0,OOOO SFLJ -63,972? -999.2500 -999,2500 NCq. 4700,0000 STLO -63,2~70 -999.2500 4500,0000 S~LJ -53.7370 -999.2500 -999.2500 ~50O.O000 SFLJ -68.9102 -999.2500 -999,2500 -70,9727 SR -999,2500 -~99,2500 ~300,O00J SF~ J -~99.2500 -~99.2~0.3 NC~. ¢Z00,3003 S=~J -69.2227 -999.2500 -~99,2503 NC~_ 36.,2773 -999.2500 -9)9.Z500 Z,2~4~ ~1,~548 SR -9~9.2500 NR&T -999,Z~00 ~C.~ 3,'2170 -999.2500 NR~T ~9,0273 -999.2500 NRAT 2.3~8¢ 98.5~98 -9~9.2500 MR~T 2.3088 ~4,5895 GR -9~9,2500 NR~T' -999.2500 2,1504 -999.2500 NRAT -9~9.2500 FCNL 2.7993 iL~ 98.0898 -9~9,2500 NR6T -999.~500 ~C~L Z.5519 ZLg -:999.2500 NR~T -999,2500 FC~_ 2,9983 33.~$~5 -9~9.£5~0 NR&T -999,2300 ~.1524 7~.2773 -9~9.23~0 NR&T -99'9.2500 CALI -99"9.2500 SR 3.0~32 -999,2500 CALl -999,2500 -999,2500 3.7463 IL~I -999,2509 CALZ -999,2500 RNR~ -999,2500 GR 3.3Z45 iL~ -999,2500 CaLZ -9'99,2:500 RNqA -999,2500 2,~768 -999,2500 CALl -999.2500 RNR~ -9~9,2500 2.~t2~ IL~4 -999,2500 CALI -999.2500 RNR~ -9~9.2500 SR 2.3579 IL~ -!999.2500 CALl -999.2500 RNR.~ -999.2500 GR 2.8792 -999.2500 CALI -999,2500 -999.2500 2.93~5 -999,2500 CA' i- -999,2500 RNR~ -999.2500 3.2307 ZL~ -999,2500 CALI -999.2500 RNR.~ -~9,2500 3R 3.0959 iLV~ -9~9.2530 'ALI -999.2300 RNa6 -999,2500 -g99,2500 -999,2500 -999,2500 2,9~36 -999,2500 -999.2500 -999.2500 3,8167 -999,2500 -999,2500 -999,2500 3.3284 -999,2500 -999,2500 -999,2500 2.~866 -999,2500 -999.2500 -999,2500 2,4590 -999.2500 -999,2500 -999.2300 2.3557 -999.2500 -999,2500 -999,2500 2.~772 -999.2500 -999.25~0 -999.2500 2,8516 -9~9,2500 -999.2500 3.203~ -9~9,2500 -999,2500 -999,2500 3.1377 -999.2500 -999,2500 -999.2500 ~ OlO.H02 VERIFIC~TID~ SP '~PqZ SP SP NPHI ]EPT SP RH3~ NP~i 3EDT SP ~H33 WPHI DE~T S P Rrt3B "~P -I I SEPT SP WPSi SP WPHI DEbT SP WP't! SP SP 100.0000 SFLJ -78.2221 GR 999.2500 DRH] '99'9.2500 NCNL 300.0303 S~LJ -72.2227 SR 999.2503 DRH] 999,2500 NCqL 900.0000 SFLJ -80,7227 999.25,00 999.2500 NCNL B03.0000 SFLJ -80.7227 GR 999.2503 DRY3 999.2500 NCN, 700,0000 SFLJ -41,2383 ~R 999.2500 999.2500 NCN_ 500.9003 SFLJ 999,2500 $R 999,2500 DRH3 999,2500 NCN. 500.0000 SFLJ 999.2500 5R 999.2500 DRq] 999.2500 NCN~ 3~00,0000 SFLj -999,2503 GR -999,2500 ORW3 -999.2~00 NCN. 3300,0000 S~LJ -999,2509 GR -99'9,2503 DqqD -99'9.2500 NCW. 3203,0000 S:LJ -999,2503 S~ -999.2500 NCN. lO0.DO30 SF_J 999.2500 GR 999.2503 3Rq] 999.2500 NCN~ LISTING 2,799i 35,3398 -999,2500 -9~9,2500 FCNL 2,517~ iLD 84.71~8 GR -999,2500 ~CWL 2,5858 -999,2500 NR&T -999,2500 FS'~L 3.1370 ILD 71.4,5~8 GR -999. 2500 NRaT -999.2~00 FCWL !3.9395 ZLD 55.~180 -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 SR -9~9.2500 NR~T -999.2500 FCML -999.2500 ILD -999.2500 GR -9~9.2500 NR~T -929.2500 FCNL -999.2500 iL3 -999.2500 GR -999.2500 NR~T -999,2500 FCN~ -9~9.2~00 ILD -999.2500 -999.2500 NR~T -9~'~.2500 -999.2500 iLD -999,2500 GR -999,2500 N~&T -999,2500 FCNL -999.2500 ltd -999,2500 -9)9.2500 NRIT 3,1252 -999.2500 CALI -999.2500 RNRA -999.2~00 2,80~9 ILM -999,2500 C~LI -999,2500 RNR~ -999,2~00 2,912~ ILM -999.2500 CALl -999.2500 RNR~ -999.2500 3.~241 -999,2500 CALl -999.2500 RNR~ -999.2500 SR 7.0!03 IL~ -999.2500 C~Li -999.2500 RNR~ -999.2500 3R -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALZ -999,2500 RNRA -999.2500 SR -999.2500 ILM -999.2500 CALI -999.2500 RN~ -999.2500 GR -999,2500 IL~4 -999.250..9 CALl -999,2500 RNR~ - 9~9. 2503 GR -999.2500 ILM -999.2500 CAsI -999,2500 -999,2500 -999,2500 CALZ -9~9,25j0 -999.2500 3.1819 -999.2500 -999.2500 -999.2500 2.5120 -999,2500 -999.2500 -999,2500 2,8088 -999,2500 -999,2500 -999,2500 3.3616 -999.2500 -999.2500 -999.2500 2900.$875 -999,Z500 -999.2500 55.3555 -999.2500 -999.2500 -999.2500 $1.~580 -999.2500 -999.2500 -999.2500 ~5.9~92 -999.2500 -999.2500 -999.2500 54.3555 -999.Z500 -999.2500 -999.2500 ~1.5117 -999.2500 -999.2500 -999.2500 &0.8~67 -999.2590 -999.2500 -999.2500 55.~150 .~? 0!0.~02 VSqIFIC~T!D~ LISTIN3 P~35 9 DEPT 3300.0000 SFLJ SP -999.2500 qH35 -99'9.2500 DEOT 2900.'3309 SFLJ SP -999.2503 SR qH35 -999.2503 NP~I -399.250~ gEOl' 2300.0000 SFLJ SP -999.Z500 SR RH]5 -399.Z500 DR-J] NPgl -999.2500 NCNL QEmT !700.0000 SFa3 SP -999.2503 39 ~H]5 -~99.2500 ORq3 NPfll -999.2500 NC~. SP -999.2500 ~R qH35 -999.2500 DRH3 ~Pql -999.2500 NC~, ]EPT 2500.0000 SFL3 SP -999.2500 G2 ~HDB -999.2500 DRq] WP~i -999.2500 NCNL DE~T 2~O0.O00O S~L3 ~Pqi -999.2502 NCN~ ]EPT 2300.0000 SFLJ SP -)99.2500 SR qH]5 -399.2500 D2q] ~I -~99.2~00 NC~. 3EPT 2Z00.3000 S~J SP -999.Z500 SR RH]5 -999.2500 Dqq] NPqi -999.2500 NCW_ D~PT 2100.0000 S~LJ SP -999.2500 39 q?~I -399.£500 NCN~ 3EPT 2000.0000 SFLJ SP -999.2509 -9~9.2500 ILD -9~9.2S00 GR -999.2500 NR&T -~9.2500 FC~L -939.Z500 -999.2500 -999.2500 -939.2500 ~CNL -999.2500 ILD -999.2500 $~ -9~9.2500 NR~T -9~9.2500 FC4L -939.2500 ILD -9~9.2500 GR -9~9.2500 NR&l. -939.2500 FCNL -999.2500 ILD -9~9.2500 GR -9)9.2500 NR~T -9~9.2500 F~ -9~9.2500 ILD -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 -9~9.2500 -9~9.2500 NRdT -939.~500 FC~L -'9)9.2500 ILO -999.2500 GR -999.2500 NR~T -9~3.2500 MC~L -999.2500 -939.2500 -939.2500 NRaT -939.2500 -939.2300 iL3 -9~9.2500 -9)9.2500 NRdT -9)9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 CALZ -999.2500 RNR& -999.2500 -999.2500 -999.2500 C6LI -999.2500 RNa& -999.2300 -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2300 GR -99'9.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNR~ -999.2500 GR -999.2300 ILM -999.2300 CALI -999.2500 RNR& -999.2500 GR -999.2500 ILM -999.~500 ~L~ -999.2300 RNR~ -9'99.2500 SR -999.2500 ZL~ -999.2300 CALl -999.2500 RNR~ -999.2500 SR -999.2500 ILM -999.2500 CakI -999.2500 RNR& -999.2500 SR -9~9.2500 -999.2500 CALI -999.2500 RNRd -9~9.2500 -'9'99.2300 ILM -999.2500 C~LI -399.2300 RNR~ -399.2500 -999.2500 -999.2500 ~3.5367 -999.2500 -999.2500 -999.2500 ~8.32~2 -999.2500 -999.2500 -999.2300 21.6924 -999.2500 -999.2500 -999.2500 ~3.5367 -999.2500 -999.2300 -999.2500 34.2930 -999.2500 -999.2500 -999.2500 32.8~$7 -999.2500 -999.2500 -999.2500 ~8.5742 -999.2500 -999.2500 -999.2500 29.7705 -999.2500 -999.2500 -999.2500 ~4.3555 -999.2500 -999.2500 -9'39.2500 -999.2500 -999.Z500 -999.2500 .¢5 O!O.H02 VERIFIC~TIJ~ LiSTINi P~$E 10 ~P~I -999.2500 -999.2500 FC~L DEPT 1900.0000 SFLJ SP -999. 2500 '~H]5 -999.2500 ~Pql -999.2500 -999.2200 ILO -999.2500 GR -999.2500 NR~T '-9~9.2500 PC~L 2EPT 1800'0000 SFLJ SP -999.2500 ~R RH3~ -999.2500 DR4~ ~Pqi -999.2502 NC~L -999.2500 IL9 -999.2500 GR -999.2~00 NR~T -999.2500 FCgL DE~T i700.0000 SP -999.!503 RHDB -999.2503 ~PWI -999.2500 NCNL -979.2500 ILD -999.2500 NR~T -999.2500 FCNL DE~T 1598.0000 SP -999.Z500 RHO~ -999.2500 MPqi -999.1500 -999.2500 -999.2500 -999.2500 -999.2500 FC~L ~ FILE TR&ILER Fi~E N&ME ::EDIT SERVICE N,AME : VE~SIO~ ~ : 9~TE : q~XIMUM L~NGTH : miLE TYPE : .001 102~ :::=i-~ T~PE TR~iLER .o,:~: SERVICE N&'qE :EDIT DATE :85/03/10 ORi3IN :0030 TA~5 N~'q~ :1317 C~NTIN]~TI]N ~ :01 ~2~ENTS : LiERaqY T~PE S~RVIC: N ~ ',1 E :EDIT 3aT-- : ~5/03/I0 ]RI3iN : RE-=~ N~E :149388 '3'~TINJ~TIDN ~ :01 '~EXY REEL ~aME : -999.2500 -999.2500 ILM -999.2500 C&LI -999.2500 RNR~ -999.2500 SR -999.2500 -999.2500 CALi -999.2500 RNR~ -999.2500 GR -999.2500 -999.2500 C4LI -999.2500 RNR~ -999. Z 500 GR -999.2500 ILM -999.2500 CALi -999.2500 RNR~ -999.2500 ~9.8867 -999.2500 -999.2500 -999.2500 44.%~92 -999.2500 -999.2500 -999.2500 38.3242 -999.2500 -999.2500 -999.2500 27.1143 -999.2500 -999.2500 -999.2500 23.7393 ,v~ OI~.HOZ VER~iC~TI~M LZSTIN~ PAGE 11