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Home My WebLink About195-0591. 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: Pull /Replace 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 6791'feet None feet true vertical 6383' feet 6476', 6480' feet Effective Depth measured 6791'feet 5847', 6329', 6387'feet true vertical 6383' feet 5496', 5943', 5997' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 5963' MD 5603' TVD Packers and SSSV (type, measured and true vertical depth) 5847' MD 6329' MD 6387' MD N/A 5496' TVD 5943' TVD 5997' 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 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: Contact Name: Contact Email: Authorized Title:Contact Phone: 3003' 2879' Burst Collapse Production Liner 6166' 830' Casing 5827' 3-1/2" 6205' 6789' 6381' 2964' 121'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-059 50-103-2022-00-00 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: ADL0025570 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2A-18 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) 50 Gas-Mcf MD 1100 Size 121' 1500 1250650 50 1951250 200 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 300 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: FHL Packer Packer: P2P Patch Packer Packer: P2P Patch Packer SSSV: None Jill Simek Jill.Simek@conocophillips.com (907) 263-4131Staff Well Interventions Engineer 6345-6385', 6450-6470', 6474-6494' 5958-5996', 6057-6076', 6080-6099' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:58 pm, Jul 14, 2025 Jill Simek Digitally signed by Jill Simek Date: 2025.07.14 14:26:16 -08'00' JJL 7/21/25 RBDMS JSB 071725 DSR-7/21/25 DTTMSTART JOBTYP SUMMARYOPS 3/19/2025 DATA ACQUISITION DRIFT FOR 2.72" DUMMY RBP TO 5,847' RKB (NO ISSUES), JOB COMPLETE 5/23/2025 REPAIR WELL DRIFT w/ 2.80'' GAUGE TAG TUBING CUT @ 5927' RKB, PULL UPPER PACKER & SPACER PIPE @ 6387' RKB, MADE ONE ATTEMPT FOR SPACER PIPE @ 6354' RKB, JOB IN PROGRESS 5/24/2025 REPAIR WELL MADE 4 ATTEMPTS TO PULL SPACER PIPE SECTION @ 6354' RKB WITH 0.125 WIRE WITH NO SUCCESS, PREP FOR ATTEMPTING WITH 0.160 WIRE. JOB IN PROGRESS 5/25/2025 REPAIR WELL MADE 5 ATTEMPTS TO PULL SPACER PIPE SECTION @ 6354' RKB WITH 0.160 WIRE WITH NO SUCCESS, 3-1/2 TTS P/T w/ G-FN (20'' OAL) LATCHED TO SPACER PIPE SECTION LIH. READY FOR COIL TO PULL PATCH. 6/6/2025 REPAIR WELL MIRU CTU 11. PULLED BAITED TTS PULLING TOOL w/ LOWER PBR, SPACER PIPE & SNAP LATCH @ 6352' RKB. RBIH FOR LOWER PACKER MIDNIGHT DEPTH 2100'. JOB IN PROGRESS 6/7/2025 REPAIR WELL MIDNIGHT DEPTH 2100' PIN HOLE IN PIPE AT 288'. RECOVERED LOWER PIIP PACKER f/ 6388' RKB. CHANGE PACKOFFS, MECHANICS REPAIRED GENERATOR, CUT 500' OF COIL. RIH WITH QUADCO PACKER MILLING BHA, ENGAGE ECLIPSE PACKER @ 6366' CTMD, MILL FOR 7.25 HRS STARTED MOVING DOWN AND STOPPED MOVING IN THE MIDDLE OF THE PERF'S @ TRIP OOH AND CK MILL 6/8/2025 REPAIR WELL SWAP MILLS RBIH W/ PARABOLIC BURN SHOE, CONTINUE MILLING f/ 6449' TO 6459' CTMD (4.25 HOURS). RIH WITH JUNK MILL AND AGITATOR CONTINUE MILLING TO 6460' CTMD / ~6480' RKB. MILL HAD SOME ROCKS & MUD IN THE WATER COURSES. SHOWED SOME WEAR ON THE OUTSIDE AND ON THE BACK REAM CUTTERS. READY FOR ELINE. 6/10/2025 REPAIR WELL DRIFT W/ 10' X 2.125" DUMMY GUN TO 6481.5' - SHOT 2.125" STRIP GUNS LOADED W/6 SPF, 60 DEG PHASING W/ OWENS 12.5 GRAM SHOGUN CHARGES FROM 6450'-6470' - WELL LEFT S/I & READY FOR PATCH 6/24/2025 REPAIR WELL BRUSH AND FLUSHED PATCH SETTING AREA 6329' RKB TO 6389' RKB. ** RECOVERED PIECES OF RAGS IN BRUSH **, RE RAN BRUSH TO SAME (CLEAN). RAN 20' x 2.72" PATCH DRIFT, TOOLS DRIFT FREELY TO 6435' RKB. SET 2.72" LOWER P2P PATCH PACKER (SN = CPP35134 / OAL = 4.01') MID-ELEMENT AT 6389' RKB. JOB IN PROGRESS 6/25/2025 REPAIR WELL SET 2.72" PBR, SPACER PIPE & ANCHOR LATCH (SN: CPPBR3508 / OAL= 28.8') IN LOWER PACKER @ 6386' RKB. ATTEMPT TO SET 2.72" UPPER PATCH PACKER ASSEMBLY AND UNABLE TO PASS 2.75" D- NIPPLE @ 5954' RKB . PULL UP HOLE TO 5047' RKB. LET DPU SET PACKER, PULL UPPER PACKER @ 5047' RKB. DURING INSPECTION FOUND JAM NUT ON P2P PACKER WAS 2.78" OD (TOO LARGE TO PASS THROUGH NIPPLE). REDRESS PACKER WITH CORRECT JAM NUT SIZE. SET 2.72" UPPER PACKER, SPACER PIPE & ANCHOR LATCH (SN: CPP35377 / OAL= 30.88') IN PBR @ 6358' RKB. JOB COMPLETE. *** C-SAND INJECTIVITY TEST: BEFORE PATCH SET ABLE TO PUMP 1 BPM @ 525 PSI / AFTER PATCH SET 1 BPM @ 900 PSI *** 2A-18 Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,480.0 2A-18 6/6/2024 spilch Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch 2A-18 6/25/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: MANDRELS off by 4' (#1 WV=2,431' ACTUAL=2,427.5') 4/5/2017 pproven NOTE: 5.6' difference from original tubing pulled 1/8/2008 triplwj 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 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 38.8 3,002.7 2,878.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.8 6,204.5 5,827.0 26.00 L-80 BTC-MOD LINER 3 1/2 2.99 5,958.9 6,789.0 6,381.1 9.30 L-80 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.7 Set Depth … 5,933.7 Set Depth … 5,576.7 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 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) 38.7 HANGER 7.000 GEN IV TUBING HANGER FMC 2.992 510.3 510.3 0.19 NIPPLE 4.520 DS NIPPLE w/ 2.875" Profile (SEE NOTE RE 2.85 RESTRICTION) Camco 2.850 2,427.3 2,349.4 22.74 GAS LIFT 5.968 Camco MMG 2.920 3,774.2 3,589.5 23.23 GAS LIFT 5.968 Camco MMG 2.920 4,745.2 4,483.0 23.18 GAS LIFT 5.968 Camco MMG 2.920 5,524.4 5,199.7 22.80 GAS LIFT 5.968 Camco MMG 2.920 5,773.0 5,428.7 22.85 GAS LIFT 5.968 Camco MMG 2.920 5,831.4 5,482.5 22.70 LOCATOR 4.510 LOCATOR Baker 2.992 5,833.1 5,484.0 22.71 PBR 5.010 PBR Baker 3.000 5,846.5 5,496.4 22.85 PACKER 5.970 FHL PACKER Baker 3.000 5,888.8 5,535.3 22.95 NIPPLE 4.520 DS NIPPLE Camco 2.812 5,927.2 5,570.7 22.87 OVERSHOT 4.520 POOR BOY OVERSHOT Baker 3.625 Top (ftKB) 5,932.6 Set Depth … 5,962.7 Set Depth … 5,603.4 String Max No… 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade L-80 Top Connection ABMEUE ID (in) 2.99 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) 5,954.6 5,596.0 22.82 NIPPLE 4.500 'D' NIPPLE Camco 2.750 5,961.6 5,602.4 22.81 SEAL ASSY 4.500 GBH-22 LOCATOR SEAL ASSY Baker 3.000 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) 510.0 510.0 0.19 OBSTRUCTI ON CALIPER SURVEY-SHOWS 2.85 RESTRICTION @ 510' 3/17/2015 0.000 6,222.5 5,843.6 21.89 LEAK - TUBING LDL, LEAK DETECTED @ 6,222.5' RKB 8/23/2016 6,328.6 5,942.5 20.49 PACKER - PATCH - UPR 3-1/2" UPR P2P PKR MID- ELEMENT AT 6331' RKB WITH ANCHOR LATCH AND SPACER PIPE, OAL 30' TTS P2P CPP3 5377 / CPAL 35144 6/25/2025 1.630 6,332.2 5,945.9 20.44 SPACER PIPE SPACER PIPE WITH ANCHOR LATCH 6/25/2025 1.600 6,358.6 5,970.7 20.10 PBR PBR AT 6359.59' RKB CPPB R3500 8 6/25/2025 1.620 6,359.6 5,971.6 20.08 SPACER PIPE SPACER PIPE WITH PBR AND ANCHOR LATCH, OAL 28' CPAL 35121 6/25/2025 1.600 6,386.6 5,997.0 19.73 PACKER - PATCH - LWR 3-1/2" LWR P2P PKR MID- ELEMENT AT 6389' RKB, OAL 4.01' TTS P2P CPP3 5134 6/24/2025 1.630 6,476.0 6,081.5 18.55 FISH 4' x 2" of strip gun left in hole on top of milled packer 6/10/2025 0.000 6,480.0 6,085.3 18.50 FISH MILLED ECLIPSE PACKER 6/7 & 6/8/25. PUSHED DOWN HOLE 4/17/2005 0.000 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) 2,427.3 2,349.4 22.74 1 GAS LIFT GLV RK 1 1/2 1,198.0 3/12/2020 0.188 3,774.2 3,589.5 23.23 2 GAS LIFT GLV RK 1 1/2 1,207.0 3/12/2020 0.188 4,745.2 4,483.0 23.18 3 GAS LIFT GLV RK 1 1/2 1,209.0 3/12/2020 0.188 5,524.4 5,199.7 22.80 4 GAS LIFT GLV RK 1 1/2 1,211.0 3/12/2020 0.188 5,773.0 5,428.7 22.85 5 GAS LIFT OV RK 1 1/2 0.0 3/12/2020 0.250 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) 5,958.9 5,599.9 22.81 SLEEVE 5.750 BAKER TIE BACK SLEEVE BAKER 5.250 5,966.4 5,606.8 22.80 PACKER 5.875 BAKER H LINER TOP PACKER BAKER H 4.313 5,977.0 5,616.6 22.77 PBR 5.000 BAKER PBR BAKER 4.000 2A-18, 7/7/2025 11:28:38 AM Vertical schematic (actual) LINER; 5,958.9-6,789.0 FRAC; 6,474.0 IPERF; 6,474.0-6,494.0 FISH; 6,476.0 APERF; 6,450.0-6,470.0 PACKER - PATCH - LWR; 6,386.6 SPACER PIPE; 6,359.6 APERF; 6,345.0-6,385.0 PBR; 6,358.6 SPACER PIPE; 6,332.2 PACKER - PATCH - UPR; 6,328.5 LEAK - TUBING; 6,222.5 PRODUCTION; 38.8-6,204.5 Primary – Full Bore; 5,980.0 ftKB PACKER; 5,846.5 GAS LIFT; 5,773.0 GAS LIFT; 5,524.4 GAS LIFT; 4,745.2 GAS LIFT; 3,774.2 SURFACE; 38.8-3,002.7 GAS LIFT; 2,427.3 Primary – Full Bore; 45.9 ftKB OBSTRUCTION; 510.0 Squeeze – Behind Casing Squeeze; 45.9 ftKB CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 45.90 RR Date 5/19/1995 Other Elev… 2A-18 ... TD Act Btm (ftKB) 6,791.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032022000 Wellbore Status PROD Max Angle & MD Incl (°) 24.89 MD (ftKB) 2,825.00 WELLNAME WELLBORE2A-18 Annotation Last WO: End Date 1/8/2008 H2S (ppm) 114 Date 12/1/2023 Comment SSSV: NIIPPLE 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) 5,987.1 5,625.9 22.73 XO THREAD 5.688 3.000 6,700.4 6,295.9 16.00 LANDING COLLAR 3.500 BAKER LANDING COLLAR BAKER 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,345.0 6,385.0 5,957.9 5,995.5 C-4, 2A-18 3/1/1999 6.0 APERF 60° phasing; SWS 2½" HSD- DP 6,450.0 6,470.0 6,056.9 6,075.8 A-4, 2A-18 6/10/2025 6.0 APERF 60° phasing; Owens 12.5 gram Shogun 6,474.0 6,494.0 6,079.6 6,098.6 A-3, 2A-18 10/15/1995 4.0 IPERF 180° phasing' SWS 2½" BH Titan Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,474.0 6,494.0 1 FRAC 1/15/1998 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 45.9 3,004.0 45.9 2,879.7 Primary – Full Bore Lead 710 sx 12.1 ppg Arctic Set III + Tail 400 sx 15.8 ppg Class G... Plug bumped. No pres noted. ^^Csg OD=9.625 45.9 309.0 45.9 309.0 Squeeze – Behind Casing Squeeze Top Job 24 bbl 16 ppg Arctic Set I + Tail 17 bbl 12.1 ppg Arctic Set III **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 5,980.0 6,193.0 5,619.4 5,816.3 Primary – Full Bore Single Stage 27 bbl 15.8 ppg Class G ... Calc TOC 5690. Plug bumped. No pres noted. ^^Csg OD=7 2A-18, 7/7/2025 11:28:38 AM Vertical schematic (actual) LINER; 5,958.9-6,789.0 FRAC; 6,474.0 IPERF; 6,474.0-6,494.0 FISH; 6,476.0 APERF; 6,450.0-6,470.0 PACKER - PATCH - LWR; 6,386.6 SPACER PIPE; 6,359.6 APERF; 6,345.0-6,385.0 PBR; 6,358.6 SPACER PIPE; 6,332.2 PACKER - PATCH - UPR; 6,328.5 LEAK - TUBING; 6,222.5 PRODUCTION; 38.8-6,204.5 Primary – Full Bore; 5,980.0 ftKB PACKER; 5,846.5 GAS LIFT; 5,773.0 GAS LIFT; 5,524.4 GAS LIFT; 4,745.2 GAS LIFT; 3,774.2 SURFACE; 38.8-3,002.7 GAS LIFT; 2,427.3 Primary – Full Bore; 45.9 ftKB OBSTRUCTION; 510.0 Squeeze – Behind Casing Squeeze; 45.9 ftKB CONDUCTOR; 42.0-121.0 KUP PROD 2A-18 ... WELLNAME WELLBORE2A-18 Originated: Delivered to:8-Jul-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2A-18 50-103-20220-00 910149874 Kuparuk River Packer Setting Record Field- Final 24-Jun-25 0 12 2K-29 50-103-20867-00 910153613 Kuparuk River Multi Finger Caliper Field & Processed 5-Jul-25 0 13 3S-624 50-103-20868-00 910133399 Kuparuk River Multi Finger Caliper Field & Processed 18-Jun-25 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:195-059214-025223-104T40650T40651T406527/9/202512A-1850-103-20220-00910149874Kuparuk RiverPacker Setting RecordField- Final24-Jun-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:32:58 -08'00' ORIGINATED TRANSMITTAL DATE: 6/25/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5498 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5498 2A-18 50103202200000 Perf Record 10-Jun-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 195-059 T40611 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.25 08:14:14 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 8/8/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4952 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4952 2A-18 50103202200000 Production Profile (PPROF) 24-Jul-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 195-059 T39383 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.08 13:22:26 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com cq5-oSel 26Coi� WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 23, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 i2o� � i. K.BEND R Anchorage, Alaska 99501 RECEIVED APR 0 3 2015 RE: Multi Finger Caliper(MFC) : 2A-18 Run Date: 3/17/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-18 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20220-00 SCANNED MO 0 6 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: o_eoteeit X95-oSc) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2A-18 Run Date: 8/30/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20220-00 Bottom Hole Pressure Survey Log 1 Color Log 50-103-20220-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 same VIA 2 1. 2015 Office: 907-273-3527 ` Fax: 907-273-3535 klinton.wood@halliburton.com Date: 2V\9/1r; Signed: }14.411at 6piy,‘ XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by: Beverly ~Vincent Nathan Lowell Date: ("~. "" 1 Isl~.~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ • ~~~~~~D STATE OF ALASKA FE~ ~ g ~p~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT1011L~4A nli R ~Aa Cnna. Catnmissinl~ 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other Anch~lgs Alter Casing ^ Pull Tubing ^~ . Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 195-059 / - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20220-00 - -,7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 94' ~ 2A-18 ' 8. Property Designation: 10. Field/Pool(s): ~~ ADL 25570, ALK 2668 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6791' ' feet true vertical 6382' feet Plugs (measured) 6004' Effective Depth measured 6661' feet Junk (measured) true vertical 6257' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 2963' 9-5/8" 3004' 2878' PROD. CASING 6152' 7" 6193' 5815' LINER 830' 3-1/2" 6789' 6380' Perforation depth: Measured depth: 6345'-6385', 6474'-6494' p~gg p~ ~y D 6~ ~y{~~}g~ ~~+t~OC 1Y1h1tZ ,Er ~ LU!!t4 true vertical depth: 5959'-5997', 6081'-6099' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5962' MD. Packers 8~ SSSV (type & measured depth) pkr= BAKER'FHL' PACKER , BAKER'H' LINER TOP PACKER pkr- 5850', 5966' Camco'DS' nipple @ 514' ._..r....,....,,,,. 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI - -- Subsequent to operation 387 523 2054 - 223 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil - Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NrA if C.O. Exempt: none Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title / Wells Group Engineer ~ Signature Phone ~ ~~ Date ` Pre ar Sha n All u -Drake 263-4612 Form 10-404 Revised 04/2006 ~ ~~ Submit Ori i I O y ~~~ • • _~~--_.. ~- ~~onc~ct~~t^Iillips A~a~ska, Inc. s2A-18 - - APi: 501032022000 Well T e: PROD TUBING (05932, OD:3.500, tD:2.992) KRU 2A-18 i ~nnia Gi TR• i 9fl rion rnl F,3d9 i SSSV Type: Nipple Orig Com letion: 5119/1995 Angle @ TD: 16 deg @ 6791 Annular Fluid: Last W/O: 1/8/2008 Rev Reason: WORKOVER Reference Lo Ref Lo Date: Last U date: 1/26/2007 Last Ta : 6661' TD: 6791 ftK6 Last Tag Date_14/16/2(D5 I Max Hole Angle:_I 25 deg fa) 2788 I I I .Casing String -ALL STRINGS Descri ion Size To Bottom TVD Wt Gratle Threatl CONDUCTOR 16.000 0 121 121 62.58 H-40 SUR. CASING 9.625 0 3004 2878 40.00 L-80 PROD. CASING 7.000 0 6193 5815 26.00 L-80 LINER 3.500 5959 6789 6380 9.30 L-80 ;Tubing String -TUBING TUBING (59325962, OD:3.500, ID:2.992) PBR (59775978, OD:5.000) PATCH (6331~i392, OD:2.992) Size Top Bottom TVD Wl Grade Thread 3-500 0 5932 5574 9.30 L-80 ABM EUE 3.500 5932 5962 5602 9-30 L-80 ABM EUE ~, 'Perforations Summary - - -- Interval ND Zone Status Ft SPF Date T Comment 6345- 6385 5959 - 5997 C-4 40 6 3/1/1999 APERF 60 deg phasing; SWS 2 1/2" HSD-DP 6474 - 6494 6081- 6099 A-3 20 4 10/15/1995 IPERF 180 deg. phasing' SWS 2 1/2" BH Titan _ Stimulations & Treatments _ _ Interval Date T e Commenf 6474- 6494 11/24/1995 Srale Inhibitor Pumped_37.6 BBI SW/SS-5206 Then Purnp - -- ---- Gas Lift MandrelsNalves ~ __ , St MD TVD - Man Mfr - _ _ Man Type V Mfr V Type V OD Latch Port 7R0 Date Run Vlv Cmnt 1 2431 2353 CAMCO MMG DMY 1.5 RK 0.000 0 1/8/2008 2 3778 3592 CAMCO MMG DMY 1.5 RK 0.000 0 1/8/2008 ~ 4 5528 5202 CAMCO MMG DMY 1.5 RK 0.000 0 1/8/2008 '~" ~ ~ ; i 5 5777 5431 CAMCO ~ - Other lugs, equip., etc De th TVD T e MMG SOV 1.5 RK 0.000 0 1/8/2008 - -- .) -COMPLETION _ ____ Descri ion D 42 42 HANGER TUBING HANGER 2.992 514 514 NIP CAMCO'DS' NIPPLE 2.875 ~ 5837 5487 PBR BAKER S.O. 1.36" 80/40 POLISHED BORE RECEPTACLE 2.980 5850 5499 PACKER FHL BAKER PACKER 3.000 "~. 5892 5537 NIP CAMCO'DS' NIPPLE 2.812 5931 5573 Overshot BAKER POOR BOY OVERSHOT 3.750 5955 5595 NIP Camco'D' Ni le; NO GO 2.750 5959 5599 SLEEVE-TB BAKER tie back sleeve 5.250 5962 5602 TTL 2.992 5962 5602 SEAL Baker'GBH-22' Seal Assembl 3.000 5966 5605 PKR Saker'H' Liner To Packer 4.313 5977 5616 PBR Baker 4.000 6004 5640 PLUG WRP set 1/8/2008 w/1' of CAC03 DUMPED ON TOP 0.000 6331 5946 PATCH SET TBG PATCH @ 6366' SLM(LOWERASSEMBLY-OAL--33.07', UPPER ASSEMBLYOAL--28.59'), STABBED INTO ECLIPSE PACKER @ 6392. TEST TO 2000 PSI. PASSED. SET 3.5" SLIPSTOP ON TOP OF K3 PACKOFF 6302' SLM; set 4/21/2005 1.750 , 6392 6003 PATCH ECLIPSE PACKER SET FOR 3' OAL PATCH. set 4/17/2005 1.750 _- -- General. Notes . - - Date Note 9/9/2006 NOTE: TBG Leaks detected 5766' & 5881' ~ 1/8/2008 3 4749 4486 CAMCO MMG DMY 1.5 RK 0.000 0 1/8!2008 NOTE: WORKOVER w/CHEMICAL CUT ~ 5932' Scats Inhibitor (6474-6494) • • KRU_2A-18_TxIA_2006-0909.txt subject 2A-18 (PTD 1950590) report of sCP From: NSK Problem Well supv <n1617@conocophillips.com> Date: sat, 09 sep 2006 19:49:43 -0800 TO: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim_regg@admin.state.ak.us> Tom & Tim, 2A-18 gas lifted producer has been added to the SCP report due to a suspected tbg leak found during slickline gas lift work on 9/7/06. After a new gas lift design was installed on 9/6/06, the tbg would not pressure test. Preliminary slickline leak detection work indicates a possible tbg leak between 5848 and 5519 SLM. Additional diagnostics will be performed to verify the leak and exact location to evaluate repair options. On 9/5/06 while the well was on line, the T/I/o was 180/1250/350. Attached is a well schematic and a 90 day T/I/o trend. Please let me know if there are any questions. Marie McConnell Problem well Supervisor 659-7224 «2A-18 90 day TIO plot 9-09-06. gif» «2A-18.pdf» 2A-18 90 day TIO plot 9-09-06.gif Content-Description: 2A-18 90 day TIO plot 9-09-06.gif Content-Type: image/gif Content-Encoding: base64 2A-18.pdf Content-Description: 2A-18.pdf Content-Type: application/octet-stream Content-Encoding: base64 Page 1 ~~ Conc~coPhllips Time Log Summary We1lriew Web RePOrtrng Well Name: 2A-18 - 4 Job Type: RECOMPLETION __ _- - 'Time Logs - -- -- ---- - T --- _ __ _ . - Date From To Dur S~De th E De th Phase Code Subcode T COM 01/03/2008 06:00 00:00 18.00 MIRU MOVE MOB P Moving Nordic 3 Rig from 3M-24 to 2A-18. 01/04/2008 00:00 03:00 3.00 MIRU MOVE MOB P Move rig to 2A pad. 03:00 05:00 2.00 MIRU MOVE PSIT P Set up liner and T-mats. Move rig over well, spot and level rig, set down. Start prep for well work operations. Ri acce ted this date 0500 hrs. 05:00 08:00 3.00 MIRU MOVE RURD P Berm cellar, drop tarps and spot su ort a ui ment. 08:00 09:00 1.00 COMPZ RPCO NUND P Pull BPV w/ lubricator. 09:00 15:00 6.00 COMPZ RPCO RURD P R/U to circulate, spot rockwasher & equipment. R/U line to kill tank, finiksh berm around kill tank. Bring on 9.6 ppg brin, PT kill line t/ 3000 psi. BD same. 15:00 18:00 3.00 COMPZ RPCOI~ CIRC P PJSM, .ill well w/ 9.6 ppg brine and circulate around @ 4 bpm & 390 psi. B/D lines, RD hoses and manifold. 18:00 20:30 2.50 COMPZ RPCOti NUND P Set BPV, bleed void in tree, N/D tree, set outside cellar, PU new tree, hang in cellar. Install blankin lu . 20:30 00:00 3.50 COMPZ RPCOh NUND P PJSM, NU BOP. 01/05/2008 00:00 03:00 3.00 COMPZ RPCOh NUND P Finish nipple up of 11" 5M BOP stack. 03:00 08:00 5.00 COMPZ WELCT BOPE P Testin BOPE. Testing annular t/ 250/2500 psi. Test remainder @ 250 / 3000 psi. Test time 5 hrs, no failures. Witness of testing waived by J. Cris w/ AOGCC. 08:00 09:30 1.50 COMPZ RPCOh NUND P Pull blanking plug, pull BPV, BOLDS. Pre are to ull tb . 09:30 15:30 6.00 COMPZ RPCOh OTHR P Attempt to pull hanger, Work up to 205 klbs w/ circulating, unable to free. Order out wireline w/ string shot and tbg cutter while continue to work pipe in attem t to free. 15:30 17:30 2.00 COMPZ FISH RURD P PJSM, RU SWS. Install Pump in sub, set sli s w/ i e tension at 160 klbs. 17:30 20:30 3.00 COMPZ FISH ELNE P RIH w/double string shot t/ seals from 5978' - 5989' ORKB . Fire shot, no progress. POOH w/wireline f/ 2nd shot. RD Pack-off, Pre f/ 2nd shot. F~~g~ 1 0# ~ • • Time Logs _ Date From To Dur S. De th E. De th t'hase Code Subcode T COM ' I 01/05/2008 20:30 23:30 3.00 COMPZ FISH ELNE P RU 2nd strin shot on SWS eline. RU packoff, RIH w/shot #2. Shot #2 set off from 5925' - 5937' ORKB. RD SWS floor equipment and lower sheeve. RU pump-in sub, attempt to work/pull pipe to determine effectiveness of string shot before loading chem cutter. Work wt up to 200 klbs re eat no ro r 23:30 00:00 0.50 COMPZ FISH ELNE P Re-install SWS PI-Sub, Hose & sheave. PU & set slips w/ 137 klbs tension 50 klbs OP f/ cut rocedure. 01/06/2008 00:00 01:00 1.00 COMPZ FISH ELNE P RIH w/ eline & chemical cutter, cu, t tb9 5935' eline de th SORKB Correlate De th . 01:00 04:30 3.50 COMPZ FISH ELNE P POOH with eline. Having problems with tool han in u in mandrels, 04:30 05:00 0.50 COMPZ FISH ELNE P Inspect chem cutting tool @ floor, LD and. RD SWS a ui ment. 05:00 05:30 0.50 COMPZ FISH CIRC P Pull on tbg to verify cut, finish clearing ri of eline a ui ment, LD same. 05:30 06:00 0.50 COMPZ RPCOf~ CIRC P Reverse (2) tubing volumes to clear @ 4 bpm/ 420 psi. Prepare to POOH w/ la in down tubin . 06:00 13:00 7.00 COMPZ RPCOh PULD P POOH w/ la do 3 1/2" tb , stra and tall same. 13:00 16:30 3.50 COMPZ RPCOti PULD T Rig Down Time: Shut down f/ repairs to i e skate. Broke chain. 16:30 17:00 0.50 COMPZ RPCO PULD P Finish POOH w/ LD tubing to 5935'. Noticed holes in tubin 5767' & 5881' (Jts 178 & 182) ORKB. Partial 't 183 tb cut had obvi us s lit. 17:00 19:30 2.50 COMPZ RPCOh OTHR P Finish strap, tally & removal of remaining pulled tbg. Culled /marked corroded tb 'ts for further i n. Remove old completion equipment, clean floor and pipe-shed in re aration of runnin new strin . 19:30 00:00 4.50 COMPZ RPCO RCST P Make u,p new completion string w! Poor-Bo overshot and new Baker , FHL acker w/ PBR/seal ass .RIH w/ installing jewelry as indicated in program. Running on new 3 1!2" 9.3# L-80 8rd EUEMod tb . 01/07/2008 00:00 02:00 2.00 COMPZ RPCOh RCST P Continue running new completion f/ 3954' - 5929' w/ picking up 3 1/2" tbg from pipe shed. Tbg appeared to stack out at 5929' ORKB ,set 15k, did not attem t to shear. 02:00 03:00 1.00 COMPZ RPCOh WOSP NP Wait on late truck w/ corrosion inhibitor. 03:00 04:00 1.00 COMPZ RPCOh CIRC P Mix and displace 10 bbls 9.6 ppg inhibited brine, displace w/untreated 9.6 brine Page 2 cif d n Time Logs ~ Die __ From To __ Dur S. De th E_ Depth Phase Code Subcode T COM 01/07/2008 04:00 06:00 2.00 COMPZ RPCOh HOSO T Set back down on stub and attempt to shear, no obvious shear action noted, exact position of Poor Boy overshot inconclusive, not sure if stacked on top of stub or fully located. RU, reverse circulate, while work pipe, no further progress. Noted sudden pressure increase at previous stack depth, still inconclusive as to status of overshot location w/ respect to tubing stub. Decision made to POOH and ins ect status of shear b I ~n overs .PJSM, Pre are to TOH. 06:00 11:00 5.00 COMPZ RPCOf~ TRIP T PJSM, Blow down choke and kill lines. POOH stand back tbg f/ 5929' - Surf. UD overshot & inspect, bolts not sheared. 11:00 15:00 4.00 COMPZ RPCOti WOEQ T Wait on wash over tools from fishing sho . 15:00 16:00 1.00 COMPZ RPCO PULD T Bring in fishing tools, strap same and make up clean-out BHA consisting of washover shoe, washover extension i e and inner mill. 16:00 22:00 6.00 COMPZ RPCOh TRIP T RIH w/washover pipe assy while laying out GLM's on way into hole. Using 3 1/2" tubing string for work-strin on clean-out. RIH U 5717'. 22:00 23:00 1.00 COMPZ RPCO CIRC T Rig down time: Attempt to circulate, top drive frozen, Hook up steam lines & thaw same. 23:00 00:00 1.00 COMPZ RPCO FCO T Cont. RIH f/ 5717' - 5906'. 01/08/2008 00:00 03:00 3.00 COMPZ RPCO FCO T Wash /circulate w/ rotating 3 1/2" tbg. Initial to @ 5927' ORKB,_Able to wash over tbg stub with positive locate on to of stub @ 5932' ORKB. Washover pipe shoe final depth 5944' ORKB. Circulate, pump hi-vis pill to clean out any remaining debris, noted black gritty material on bottoms up. Circulate to clean brine. 03:00 06:00 3.00 COMPZ RPCOh TRIP T PJSM, TOH w/wash-over shoe, CO ass . 06:00 12:00 6.00 COMPZ RPCOh TRIP T RIH wlcompletion (tubing from derrick). Stabbed over tubing stub 5933' ORKB, sheared ins to confirm. PU and spot corrosion inhibitor. Lowered PB Overshot back over stub. 12:00 12:30 0.50 COMPZ RPCOI~ WOP T Wait on Slickline. 12:30 21:00 8.50 COMPZ RPCOh SLKL T RU Slickline, RIH and retrieved RHC body. RIH with 2.730" guage ring and confirmed tubing stub /overshot open. Perform alignment check ,tag up at 5944' (Sticky), Work through to 5953' ORKB. Alignment OK. POOH, RIH and set CA2 lu RD slickline. Pa~~ 3 of 4 • Time Logs Date _ From To __ _Dur S. Depth E. D~th Phase C__ode Subcode T COM ___ 01/08/2008 21:00 21:30 0.50 COMPZ RPCOI~ PACK P Set packer ,top of Baker Ret FHL, acker 5845.64' MD ORKB, Top PBR @ 5832.28' MD ORKB. On Final set, bottom Poor-boy overshot Mule shoe @ 5937.4', spaced 1 ft frommo go on tbg stub located at 5933' ORKB. Stub swallowed 5' 21:30 23:30 2.00 COMPZ RPCO SLKL P RU slickline, RIH and pull CA2 plug f/ packer eval. Pressure down tbg 1500 si, no bleed off, OK. 23:30 00:00 0.50 COMPZ RPCOti HOSO P Space, PU and MU new FMC tbg hn r. 01/09/2008 00:00 01:00 1.00 COMPZ RPCOh HOSO P Land tubing hanger, RILDS. 01:00 02:30 1.50 COMPZ RPCOti DHEO P Test tbg to 2500 psi f/ 15 min, OK bleed back to 1500 psi, pressure test IA to 2500 psi f/ 30 min, OK. record on chart. Bleed off tbg pressure, shear SOV. 02:30 05:30 3.00 COMPZ RPCOb NUND P Install BPV, ND BOP's. 05:30 09:00 3.50 COMPZ RPCOh NUND P Pull BPV and set tree test plug. Nipple up tree and pressure test to 250/5000 psi. Test packoff to 250/5000 si. Pull tree test lu . 09:00 11:30 2.50 COMPZ RPCOh FRZP P Freeze protect the well by pumping 90 bbls diesel into IA, connect tubing and IA on the wellhead with jumper hose and let diesel fluid U-tube between tubin & IA. ND hoses. 11:30 12:00 0.50 COMPZ RPCOh NUND P Set BPV. 12:00 16:00 4.00 COMPZ RPCO RURD P PJSM -Clean pits, offload brine. RD move off well. Release rig @ 1600 hrs 1-9-2007 ~~-. a P~g~ ~ of 4 • 2A-18 Summary • DATE Summary 1/26/08 TAGGED @ 5930' SLM, NO SAMPLE, RAN 2.5" BAILER, HAD CARBOLITE AND SCHMOO, SET CATCHER @ 5892' RKB, PULLED SOV @ 5777' RKB, LDFN, READY FOR CIRC OUT, IN PROGRESS. 1/27/08 CIRCULATE IA TO DIESEL. SET DV @ 5777' RKB. MITxIA TO 2500 PSI- PASS. PULLED DV @ 5528' RKB, ATTEMPT TO PULL DV @ 4749' RKB, IN PROGRESS. 1/28/08 PULLED DVs @ 4749' RKB, 3778' RKB, 2431' RKB, SET OV @ 5528' RKB, SET GLVs @ 4749' RKB, 3778' RKB, 2431' RKB, PULLED CATCHER @ 5892' RKB, BAILED FRAC SAND & SCHMOO TO 5947' SLM, IN PROGRESS. 1/29/08 BAILED FILL FROM 5947' TO 5972' SLM. RAN 2.62" LIB, SET DOWN @ 5966' SLM, FILL. IN PROGRESS. 1/30/08 BAILED FILL FROM 5969' TO 5970' SLM. IN PROGRESS. 1/31/08 BAILED FILL & PULLED WRP @ 6004' RKB. IN PROGRESS. 2/1/08 ATTEMPTED PULL 3-1/2" SLIPSTOP FROM PATCH @ 6331' RKB. SHUCKED SLIP RETAINING RING, RECOVERING UPPER MANDREL ONLY. FISHED EACH OF 3 SLIPS WITH MAGNET. SPEARED & RECOVERED LOWER MANDREL (100% RECOVERY). IN PROGRESS. 2/2/08 TAGGED @ 6498' RKB, EST. 4' RATHOLE. SET SLIPSTOP ON C SAND PATCH @ 6315' SLM. COMPLETE. r-~ Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission : 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~ ~ ~ ~ ~ ~ ~~~~ Dear Mr. Maunder: • ~~ `\ /~'- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductar. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant fop-off Report of Sundry Operations (10-404) Kuparuk Field Date ~~wKi'nm Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12/14/2007 2A-02 184-050 SF na SF na 3.5 12/14!2007 2A-03 184-051 44" na 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.2 10" 9!24!2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 1215/2007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14/2007 2A-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.75 12/14/2007 ZA-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 12!5/2007 ?A-18 195-059 NA na 8' na 35 12/14JZ~7 2A-21 193-133 5' 0.7 18" 9/24/2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 ZA-23 193-142 SF na SF na 2 12/5/2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MlT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax; (907) 245-8951 1 BL / EDE Disk 2A - 18 Caliper Report 20-Sep-06 1) 2) 3) 4) 5) 6} 7} ('; ~r Print Name: C/.J t- f.J. (~t;..J.;.IA...r¿ rì1.öJA.IA, L( ~'1 RECEIVED SEP 2 9 2006 Date: .I\Iaska 011 & Gas Cons. Commission Anchorage Signed : I CJ "5- ~ 0 f)} :¡t: / "/1 ?.! <-I PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: POSANCHORAGE(WMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM 0:100 ]DSANC-2006\Z _ WordlDistributionITransmitta'-_SheetsITransmit_ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. September 20,2006 8047 1 3.5" 9.3 lb. ABM EUE Tubing Well: 2A-18 Field: Kuparuk state: Alaska API No.: 50-103-20220-00 Top Log Intvl1.: Surface Bot. Log IntvI1.: 6,294 Ft. (MD) Inspection Type: Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the "0" Nipple @ 5,955' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good to poor condition with respect to corrosive damage. Holes, probable holes, and possible holes are recorded in 11 of the 212 joints logged. Penetrations in excess of 20% are recorded in 28 of the 212 joints analyzed. The damage appears in the forms of isolated pitting, general corrosion, and lines of corrosion. The more serious damage is recorded in the interval between 5,550' (GLM 5) and 6,294' of the tubing interval logged, as illustrated in the Body Region Analysis Page of this report. No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the 3.5" tubing interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. The caliper hung up in GLM 6 during the logging operations, resulting in a loss of coverage for the pup joint located directly above this GLM. The pup joint is labeled as "No Data" in the tabulation sheets. MAXIMUM RECORDED WALL PENETRATIONS: Hole Hole Hole Probable Hole Probable Hole ( 100%) ( 100%) ( 100%) ( 98%) ( 98%) Jt. Jt. Jt. Jt. Jt. 182 @ 185 @ 187 @ 194 @ 191 @ 5,877 Ft. (MD) 6,014 Ft. (MD) 6,060 Ft. (MD) 6,234 Ft. (MD) 6,177 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 15%) are recorded throughout the tubing interval logged. MAXIMUM RECORDED ID RESTRICTIONS: RECEIVED No significant 1.0. restrictions are recorded throughout the tubing interval logged. SEP 2 9 2006 Field Engineer: R. Richey ission \9t>-D5'1 ~ ILl ¡L(Lt I I I Well: Field: Company: Country: 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread 1-80 I I Penetration and Metal loss (% wall) penetration body metal 1055 body I 200 150 100 50 0 o to 1% 10 to 20 to 40 to over 20% 40% 85% 85% I 1 to 10'10 I 11 o I pene. loss I Damage Configuration ( body ) 40 I 30 20 I 10 o I isolated general line ring hole / poss pìttíng corrosion corrosion corrosÎon ible hole I 11 I I PDS Report Overview ody Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Ana sf: Nom.lD 2.992 ins September 20, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) penetration body o o GLM6 GLM 5 GLM4 GLM 3 GLM2 GLM 1 Bottom of Survey = 196 Analysis Overview page 2 I I rnetalloss body 50 100 I I Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (13.4' - 6289.0') Well: field: Company: Country: Survey Date: 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 20, 2006 I I I Approx. Tool Deviation Approx. Borehole Profile I 1614 GLM 1 2430 Õ ~ 3211 .,.; GLM2 ll.. .£: ..;:: ...... Q.. (j) 4013 0 GLM3 GLM4 4827 18 I I 825 I I I I GLM5 5650 I I GLM6 I 196 o 50 6289 100 I Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 196 I I I I I I I I I I I I I I I I I I I I I ! l_______ PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf 1-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 20, 2006 Joint Jt. Depth F'("II Pen. F'en \I"eial Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) (11 (Ins.) (Ins.) 0 50 100 .1 13 (I 0.03 II J 2.93 PUP 1 18 (I 0.03 11 ±B' 93 It. Deoosi ts. 1.1 51 (I 0.01 5 2.93 PUP 1.2 61 () 0.02 9 I 2.92 PUP 1.3 69 iJ 0.01 3 ;; 2.92 PUP 1.4 76 0 0.01 2 -¡ 2.96 PUP 2 80 I 0.02 (I '5 2~g1- 3 111 0.04 14 ) 2.92 Shallow nittin<I. Lt. Denosits. 4 143 0.02 J 2.92 5 174 i 0.02 2.93 6 205 I 0.02 2.93 Lt. De"osi ts. 7 236 ( 0.01 2.93 Lt. De..osi ts. 8 266 U 0.02 (I 2.93 Lt. Deoosits. 9 296 0 0.02 U 2.93 It. Denosits. 10 332 (I 0.03 13 '\ 2.93 Shallow nittin<I. 11 I 167 (I 0.CJ3 ì i, 2.93 12 404 0 0.02 F 2.94 13 439 0 0.02 " 2.92 Lt. Deoosi ts. ) 14 475 0 0.02 ) 2.93 14.1 509 (I 0 0 n 2.81 DS Landinv Ni....le 15 511 0 0.02 B ) 2.92 It. Denosits. 16 544 0.02 ) 2.92 Lt. Denosits. 17 576 0.02 2.91 Lt. Deoosits. 18 607 0.02 2.94 It. Deoosits. 19 638 0.02 2.92 Lt. Denosi ts. 20 668 ( 0.ü2 2.93 )1 699 0 0.03 II 2.93 22 730 0.02 7 ;; 2.93 23 762 0 0.03 I ) 2.93 Shallow nittinQ. Lt. Denosits. 24 793 0 0.02 II ) 2.94 25 825 0 0.02 11 ) 2.92 r Lt. Denosits. 26 856 0 0.03 P 2.92 27 888 (I 0.03 10 2.94 28 919 I) 0.03 12 2.93 29 951 0 0.02 (I 2.94 30 983 0 0.ü2 (I ) 2.94 31 1015 0 0.03 I '5 2.94 32 1048 (I 0.03 I I 2.94 It. Denosits. 33 1081 0 0.03 1 2.93 34 1112 U 0.03 I 2.93 35 1145 0 0.02 (I 2.93 36 1178 I) 0.03 I 2.92 Shallow corrosion. 37 1211 U 0.03 13 2.93 Shallow corrosion. Lt. Denosits. 38 1244 U 0.02 B ) 2.93 39 1274 (I 0.02 9 2.93 40 1305 0 0.03 11 2.94 Lt. DeDosits. 41 1336 0 0.04 I 2.93 Shallow Dittin\!. 42 1367 (I 0.02 2.93 L t. De..osi ts. 43 1398 0 0.03 10 2.93 Lt. Denosits. 44 1428 0 0.02 ( ) 2.93 Lt. DeDosits. Body Metal Loss Body Page 1 - I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 20, 2006 I Joint Jt. Depth Pc: Pen. PerL I Me:al Min. Damag e Profile No. (Ft.) Jpsc': Body 1.0. Comments (% wall) (Ins.) (Ins.) 0 50 100 45 1458 () 0.03 11 2.93 Shallow corrosion. Lt. Deoosits. 46 1489 () 0.03 11 2.93 47 1520 () 0.02 (, 2.94 48 1550 0 0.03 11 2.9>1 Shallow corrosion. 49 1582 () 0.03 13 2 2.93 Shallow oittim!. 50 1614 0 0.02 7 2 2.95 51 1646 0 0.03 I ) 2.93 Shallow corrosion. 52 1679 0 0.03 1 2.94 53 1711 () 0.02 Ci 2.92 54 1740 () 0.03 I 2.92 Shallow corrosion. 55 1773 () 0.01 ;, 2.93 56 1804 0 0.03 10 -j 2.94 57 1834 0 002 9 ] 2.94 58 1866 0 0.02 7 2 2.92 Lt. DeDosits. 59 1896 0 0.02 (, 2 2.93 60 1928 0 0.03 1 3 2.94 Shallow nittim~. 61 1959 () 0.04 I 2 2.93 Shallow corrosion. 62 1991 0.03 1 ) 2.93 63 2022 0.03 !] ] 2.93 Shallow corrosion. 63.1 2054 0.03 1 ] 2.94 PUP 63.2 2059 : 0 0 0 N/A GLM 1 {Latch @ 11 :00\ 63.3 2069 0 0.03 1 2.94 PUP Shallow Dittìm;¡. Lt. Denosits. 64 2074 0 0.03 I 2.94 Shallow nittinQ. 65 2106 0 0.02 f1 2.94 66 2137 () 0.03 II 2.91 Lt. Deoosits. 67 2169 0 0.03 12 2.92 Shallow Dinin2. Lt. DeDosits. 68 2202 0 0.02 7 2.93 69 2234 11 0.05 Iß 2 2.92 Shallow corrosion. 70 2266 C 0.02 2.92 71 2299 (1 0.01 2.93 72 2331 0 0.03 I 2.92 73 2364 0 0.02 2.95 74 2397 : 0.03 1 2.92 Lt. Deoosits. 75 2430 ( 0.03 10 2.92 76 2464 I 0.02 9 2.93 77 2496 0.03 12 ] 2.93 78 2527 0 0.03 Iì 2.94 79 2558 ( 0.03 13 2.93 Shallow corrosion. 80 2590 0 0.03 11 2.93 Shallow nittìn2. 81 2622 0 0.02 7 2.95 82 2653 () 0.03 ¡¡ 2.94 Shallow oittim!. 83 2686 () 0.ü2 9 2.93 Lt. DeDosits. 84 2717 0 0.02 () 2.93 85 2750 () 0.03 L 3 2.92 86 2784 0 0.03 13 2 2.91 87 2815 U 0.02 I) 7 2.92 88 2848 0 0.02 I) .2 2.93 89 2878 0 0.03 10 2 2.92 90 2910 0 0.03 1] 2 2.91 Shallow Dinin2. Lt. Deoosits. 91 2942 () 0.03 1, 2 2.92 Shallow corrosion. I I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf 1.-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 2A-18 Kuparuk ConocoPhillíps Alaska, Inc. USA September 20, 2006 I Joint Jt. Depth F'e: Pen. Pen FJletal Min. Damag e Profile No. (Ft.) Body 1.0. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 92 2975 n 0.02 9 ) 2.93 93 3007 n 0.03 2.93 94 3037 n 0.02 2.94 Lt. Deoosi ts. 95 3066 n 0.03 2.93 Shallow corrosion. 96 3096 n 0.02 2.93 97 3124 n 0.04 ! 2.92 Shallow corrosion. 98 3153 0 0.04 ! 2.92 Shallow nittino. 99 111>2 0 0.03 !D 2.95 100 3211 0.03 + ) 2.94 101 3240 0.03 2.94 Shallow oittinQ. 102 3271 I 0.03 W 2.94 103 3302 0.02 C1 2.92 104 3333 0 0.02 C! 2.94 104.1 3364 0 0.03 11 2.93 PUP 104.2 3371 n 0 0 n N/A GLM 2 (Latch @ 11 :301 1 04.3 3379 n 0.02 9 .C\. 2.95 PUP 105 3384 n 0.04 16 ) 2.93 Shallow oittinQ. 106 3415 n 0.02 9 2.94 107 3445 n 0.03 II 2.93 108 3476 n 0.02 9 2.93 Lt. Deoosits. lOQ 3507 n 0.02 9 2.92 110 I 3536 I) 0.06 n 2.93 Corrosion. 111 3568 n 0.03 13 2.92 Shallow corrosion. 112 3599 0 0.02 ß 1 2.93 113 3630 11 0.02 9 2.94 114 3662 0 0.03 11 2.93 115 3693 0 0.04 14 2.92 Shallow corrosion. 116 3725 0.02 9 2.95 117 3758 0 0.03 10 2.92 118 3790 I) 0.02 ß j 2.93 119 3823 n 0.01 3 ) 2.93 Lt. Deoosits. 120 3854 I 0.03 I ) 2.93 Shallow corrosion. II 121 3886 0.04 1 2.93 Shallow corrosion. 122 3918 ) 0.03 I 2.92 123 3950 ) 0.03 1 2.93 Lt. Deoosits. 124 3980 I) 0.03 1 2.91 125 4013 () 0.03 1 2.92 Shallow corrosion. 126 4046 0 0.02 7 ) 2.93 127 4077 11 0.03 ) 2.92 128 4110 11 0.02 2.93 129 4141 11 0.02 2.93 130 4173 0 0.02 2.92 130.1 4205 0 0.02 2.92 PUP 130.2 4209 () 0 0 n N/A GLM 3 (Latch @ 3:00\ 130.3 4222 () 0.03 13 ) 2.95 PUP Shallow corrosion. 131 4225 I) 0.04 15 1 2.92 Shallow corrosion. 132 4256 () 0.02 I ) 2.92 133 4289 () 0.02 ) 2.92 134 4320 () 0.02 2.93 135 4351 I) 0.04 15 2.92 Shallow oittinQ. II I I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 20, 2006 Joint ]t. Depth 1\'11 Pen. PeLL \i\eliJl Min. Damage Profile No. (Ft.) 1::::"1 Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 136 4384 I 0.03 II 4 2.92 137 4416 0.03 13 2 2.92 Shallow corrosion. 138 4450 0.03 12 ) 2.91 Shallowaittin\!. 139 4482 0.03 II 2.93 140 4515 0 0.04 16 2.92 Shallowaittim:<. Lt. Deoosits. r 141 4548 I! 0.03 13 2.93 Shallow corrosion. /"' 142 4580 0 0.04 15 2.92 Shallow corrosion. fill 143 4611 0 0.03 -I 2.91 Shallow oittin\!. 144 4641 0 0.02 9 1 2.91 145 4671 0 0.03 I: I 2.93 146 4703 0 0.03 I 1 2.94 Shallow oittir12l. 147 4734 C 0.03 13 2 2.93 Shallow oittin\!. 148 4765 0 0.03 10 2.92 ¡ 149 4796 0 0.03 12 2.93 150 4827 0 0.02 9 2.93 Lt. Deoosits. 151 4858 I 0.04 I 2.92 Shallow corrosion. ¡ 152 4890 0.04 I 4 2.92 Shallow corrosion. 152.1 4920 0.03 I 4 2.95 PUP Shallow nittim!. 152.2 4925 ) 0 0 0 N/A GLM 4 (Latch @ 6:00) 152.3 4939 0 0.01 5 1 2.95 PUP 153 4942 0 0.04 1 r ¡ 2.93 Shallow corrosion. II 154 4973 I) 0.03 1. 2 2.91 Shallow oittin\!. I 155 5005 0.04 It 2.93 Shallow corrosion. 156 5036 0.03 I 2.94 157 5067 0.03 1 2.92 Shallow pittin\!. 158 5099 0.03 11 2.93 159 5129 0 0.02 ß 2.92 160 5159 0 0.04 1 r. 2 2.93 Shallow oitlin\!. 161 5191 0 0.04 It 2.92 Shallow pittim!!. Lt. Deposits. 162 5221 0 0.ü3 I 2.92 Shallow pitting. 163 5252 () 0.05 I 2.92 Shallow pitting. 164 5284 0 0.03 1 2.92 Shallow pittin\!. 165 5315 II 0.03 1 2.92 166 5347 0 0.03 10 2.92 167 5378 II 0.03 11 2.92 168 5410 II 0.04 1 2 2.91 Shallow pittim?;. 169 5441 0 0.03 I 3 2.92 Lt. Deposits. 170 5472 0 0.03 1 2.93 171 5504 I) 0.03 I 2.91 171.1 5537 I) 0.02 ) 2.95 PUP 171.2 5542 I) 0 I N/A GLM 5 (Latch @ 9:00) 171.3 5552 0 0.06 2.92 PUP Isolated oittim?;. 172 5556 0 0.10 1 2.91 Line corrosion. Lt. Deposits. 173 5588 0 0.08 " 2.90 Isolated pitting. 174 5619 () 0: 0.13 4 2.92 Line corrosion. 175 5650 OJ)¡ 0.14 0 2.91 Line corrosion. 176 5682 00 0.14 6 2.91 Line mrrosion. Lt. Deoosits. 177 5714 0.6 0.16 61 6 2.94 Line corrosion. I 178 5745 010 0.24 94 12 2.92 HOLE! 179 5772 0.04 0.17 65 9 2.93 Line corrosion. Lt. Deposits. Body Metal Loss Body Page 4 I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA September 20, 2006 I Joint Jt. Depth Pen Pen. Pen. ,SAe !:J Min. Damage Profile No. (Ft.) (::)\(;1 Body !.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 180 5803 0' j 0.11 44 7 2.93 Line corrosion. , , 181 5836 0 ~/gi) 's 2.93 Line corrosion. 1& . 182 5867 o H, IS 2.91 I HOLE! 182.1 5898 0 0 il NIA PUP (No Datal 182.2 5899 I) 0 0 N/A GLM 6 {Latch @ 6:001 182.3 5915 011 0.18 I , 2.84 PUP Corrosion. Lt. Deoosits. , 183 5921 IID7 0.23 ( 1 2.94 Possible HOLE! 183.1 5955 I) 0 I 2.75 D Ninnle 183.2 5961 I) i=* ¡ 5.25 Tie Back 184 5962 0 2.94 line corrosion. 184.1 5986 D 0 ii 3.00 Packer 185 I 5987 0 0.32 100 11( 2.94 Multinle HOLES! 186 I f)016 1)1 ( 0.24 91 10 2.94 Possible HOLE! 187 6043 I)JP 0.26 H I) 11 2.94 Multiole HOLES! 188 6070 1)1( 0.24 f) II 2.93 Possible HOLE! 189 6097 001 0.23 f) 11 2.95 Possible HOLE! 190 6124 11.10 0.22 as II 2.96 Possible HOLE! Lt. Denosits. 191 6151 0.11 0.25 9fJ Î 1 2.96 Probable HOLE! 192 6179 0 0.19 73 It) 2.96 Corrosion. Lt. Deoosits. 193 6206 o 17 0.24 n 1'; 2.96 Possible HOLE! 194 6234 I) 21 0.25 qfJ ;2 2.94 Probable HOLE! 195 6261 I) OfJ 0.14 ;4 II 2.96 Corrosion. Lt. Deoosits. 196 6289 D.13 0.14 ,4 n 2.94 Corrosion. Lt Deoosits. End of Log. I I I I I I I Penetration Body Metal Loss Body I I I I I I Page 5 I I ------ ------- - - -- - - PDS Report Cross Sections Well: Field: Company: Country: Tubin : 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L·BO Survey Date: Tool Type: Tool Size: ,'-.Jo. of Fingers: Anal st: September 20, 2006 MFC 24 ,r-..Jo. 40665 1.69 24 M. Tahtouh Cross Section for Joint 182 at depth 5877.05 ft Tool speed = 50 NominallD = 2.992 Nominal 00 = 3.500 Remaining wall area = 85 % Tool deviation = 38 0 Finger 4 Penetration = 0.432 ins Hole 0.43 ins 100% Penetration HIGH SIDE = UP Cross Sections page 1 ------ --------- PDS Report Cross Sections Well: field: Company: Country: Tubin : 2A-18 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L·80 Survey Date: Tool Type: Tool Size: ,'\Jo. of Fingers: Anal sf: September 20, 2006 MfC 24 No. 40665 1.69 L4 M. Tahtouh Cross Section for Joint 185 at depth 6014.04 ft Tool speed 42 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 88 % Tool deviation = 58 0 finger 3 Penetration = 0.318 ins Hole 0.32 ins = 100% Penetration HIGH SIDE = UP Cross Sections page 2 - - .. .. I KRU 2A-18 I 128S'ª API: 501032022000 Well Type: PROD Angle @ TS: 20 deg @ 6342 W SSSV Type: Nipple Orig 5/19/1995 Angle @ TO: 16 deg @ 6791 NIP (509-510, Completion: 00:3.500) Annular Fluid: LastW/O: Rev Reason: GL V design, Set TUBING PATCH (0-5962, Reference Log: Ref Log Date: Last Update: 4/28/2005 00:3500, 10:2.992) Last Tag: 6661 TO: 6791 ftKB ~ 4/16/2005 Max Hole Angle: 25 deg @ 2788 Gas lift f....A.I..l MandrelNalve Description Size Top Bottom TVD Wt Grade Thread 1 CONDUCTOR 16.000 0 121 121 62.58 H-40 (2059-2060, SUR. CASING 9.625 0 3004 2878 40.00 L-80 PROD. CASING 7.000 0 6193 5815 26.00 L-BO LINER 3.500 5959 6789 6380 9.30 L-80 ....,i......i!!;:t..;....,... II,IDII\l1,,:3 Gas lift Size I Top I Bottom I ND I Wt I Grade Thread MandrelNalve 2 3.500 I 0 I 5962 I 5602 I 9.30 I L-80 ABM EUE (3370-3371, Interval NO lone Status Ft SPF Date Type Comment 6345 - 6385 5959 - 5997 C-4 40 6 3/1/1999 APERF 60 deg phasing; SWS 21/2" HSO-OP Gas Lift: 6474 - 6494 6081 - 6099 A-3 20 4 10/15/1995 IPERF 180. d~g, phasing' SWS 2 MandrelNalve 1/2" BH Titan 3 (4209-4210, ~T'~ Comment 4 - 6494 Sæle Inhibitor I Pumped 37.6 BBI Then Pump <Lift Gas Lift St MO NO Man Man Type V Mfr V Type VOO Latch Port TRO Date VI" MandrelNalve Mfr Run Cmnt 4 1 2059 2010 Camco MMM GLV 1.5 RK 0.188 1269 4/25/2005 (4923-4924, 2 3370 3216 Cameo MMM GLV 1.5 RK 0.188 1268 4/25/2005 3 4209 3989 Cameo MMM GLV 1.5 RK 0.188 1261 4/25/2005 4 4923 4645 Cameo MMM GLV 1.5 RK 0.250 1290 4/26/2005 Gas Lift 5 5542 5215 Cameo MMM OV 1.5 RK 0.250 0 4/26/2005 Mandre!Nalve ~5553 ca.MMM DMY 1.5 RK 0.000 0 10/8/1995 5 :¡¡;;I1\l~ .RY (5542-5543, Depth ND TYPe Description ID 509 509 NIP Cameo 'OS' Landing 2.813 5955 5595 NIP Cameo 'D' Nipple· NO GO 2.750 5959 5599 SLEEVE- TB BAKER tie back sleeve 5.250 Gas Lift 5962 5602 HL 2.992 I ndrel/Dummy Valve 6 5962 5602 SEAL Baker 'GBH-22' See I Assembly 3.000 (5909-5910, 5966 5605 PKR Baker 'H' liner Too Packer 4.313 00:6.016) 5977 5616 PBR Baker 4.000 6331 5946 PATCH SET TBG PATCH @ 6366' SLM(LOWER ASSEMBL Y-OAL--33.0T, UPPER 1.750 ASSEMBLYOAL--28.59'), STABBED INTO ECLIPSE PACKER @ 6392. TEST TO 2000 PSI. PASSED. SET 3.5" SLlPSTOP ON TOP OF K3 PACKOFF @ 6302' SLM; set 4/21/2005 6392 6003 PATCH ECLIPSE PACKER SET FOR 3' OAL PATCH set 4/17/2005 1.750 PBR (5977-5978, 00:5.000) PATCH .~ ---- (6331-6392, 00:2,992) --- ~-- Scale .--- -- Inhibitor --- --- (6474-6494) I I I I I I I I I I I I I I I I I 09/15/06 Scbbunberger RECEi\JF, . I ¡ _.~. NO. 3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SEP 1 c:: "fin¡.:- ~ II L'..'t.L Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ..,~ Oil & Gas wns. ~rr¡ffJ~;:J(. Ar.d1cr'c:ge ..-: C': ()oe¡\:'; Sç"f: t 'j{..\J\,L) ,.rÀ1\.\NE'=~ \...f <'0 t. Field: :;)"'f'J. '? Kuparuk 1 CJ s-- ðS-~ Well Color CD Job# Log Description Date BL 2A-18 11213804 LDL 09/09/06 1 1A-20 11213802 PROD PROFILE W/DEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1 L-28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1 L-1 0 1142164 INJECTION PROFILE 09/09/06 1 1 J-1 02 11421625 US IT 09/11/06 1 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 s8HP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumberger NO. 3213 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1!¿7 09/24/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Color <t'f -O&{ 2- 3C-06 10922465 PRODUCTION PROFILE WIDEFT 09/19/04 1 't5 -05' 2A-18 10802936 PRODUCTION PROFILE WIDEFT 09/12/04 1 1'f- 0'8 28-12 10802934 INJECTION PROFILE 09/10/04 1 ~ lj- I ~ 4 _2X-11 10802933 PRODUCTION PROFILE 09/09/04 1 }~t- ~5 1B-10 10922467 PRODUCTION PROFILE 09/21/04 1 () ... "5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 ra.£-OZ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 t ~'Í - (( 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 f~:z.-,~~ 1H-19 10802940 INJECTION PROFILE 09/14/04 1 r 2. -0 !f 1 H-07 10802939 INJECTION PROFILE 09/14/04 1 ~2 -D(o 1A-14 10802938 INJECTION PROFILE 09/13/04 1 ( '1'" 070 2H-03 10802945 INJECTION PROFILE 09/18/04 1 (ß?J-05' 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 '~~ olf'f 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 '" 7 -H?. 3H-09 10922468 INJECTION PROFILE 09/22/04 1 I ~'-I'/I 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 1t¡()_/f,(p1A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD ~/ -~ ~~i ) Í' ..... .~~ ¿ Sl~ ¡/ -e~ . ¡'.{/a~ SGANNED NOli ¡¡ 8 ZU04 DATE. /t:¡1 ¡h Please sign and retur one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of Alas ka Alaska Oil and Gas Conservation Commission TO' THRU: Camille O. Taylor, C~.Y Chair TOm Maunder, P. I. Supervisor - ~ FROM' Jeff Jones, SUBJECT' Petroleum Inspector DATE: April 7, 2002 Oil Spill Inspection Kuparuk River Field Phillips Alaska inc. Well 2A-18 April 7,, 2002' I traveled to 2A pad in the Kuparuk River Field to inspect a hydrocarbon release that occurred when the flow line from Phillips Alaska Inc.'s well 2A-18 to the manifold building developed a leak. PAl spill response and Alaska Clean Seas Inc. personnel were on site and performing an initial assessment of the incident when ! arrived. I toured the site and noted that an approximately ¼" hole was visible at a bead weld where a CasaSc© :cOrrosiOn fitting had been Welded on the elbow where the 6" flow line from well 2A'18 tUrned upward to enter the manifold building from under the module. At this time holes were being dug in the hard packed snow to determine the area and depth of the escaped fluid. The operator on duty indicated to me 'that he:foUnd the leak While making his rounds and immediately activated the Emergency Shutdown equipment on well 2A-18 stopping the flow from the leak. Shellie ColegroVe, of PAl's Environmental Dept. estimated the released fluid volume at approximately 1200 gals. of fluid, consisting of 92% produced water and 8% crude oil.'Ms. Colegrove stated that she would.keep the AOGCC informed of the findings of the incident investigation as they developed. Summary_' I inspected the site of a hydrocarbon release from the flow line of Phillips Alaska Inc.'s well 2A-18 in the Kuparuk River Field. Attachments' none CC' NON-CONFIDENTIAL 5GAhiNE[ ,JUll 4 2002 Hydrocarbon Release KRU 2A-18 4-7-02 ,lJ 1 .doc t-w: uomptete photo me for u~-z/-~ pipe.ne corrosion . ,, ,, Subject: FW: Complete photo file for DS-2A pipeline corrosion Date' Fri, 17 May 2002 10'16'17 -0800 From' "Ballard, Kirsten" <Kirsten_Ballard@envircon.state.ak.us> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> ..... Original Message ..... From: Bailard, Kirsten Sent: Monday, April 15, 2002 5:23 PM To: 'msw@dnr. state.ak, us' Cc: 'David Zuker Home (E-mail)'; Miner, Lydia; Munson, Dianne; Cederstrom, Elaine Subject: FW: Complete photo file for DS-2A pipeline corrosion FYI-These are the photo's i took of the offending pipe segment. Call if you need anything, this facility's been assigned to me for IPP concerns. Thanks, Kirsten Dsc00039 - KRU - DS-2A pipe spill on conf room board;Dsc00040 - DS-2A pipe corrosion - un-blasted side with hole;Dsc00041 - DS-2A pipe corrosion - cleaned half;Dsc00042 - DS-2^ pipe - Both halves with scale i i Name: Dsc00039- KRU - DS-2A ,.! , pipe spill on conf mom 'i [~Dsc00039- KRU- DS-2A pip..e, spill on conf room board.ip.q,{ board.jpg ~ ' Type' JPEG Image (image/jpeg) i !Encoding' base64 Dsc00040- DS-2A p(pe corrosion- un-blasted side with hole.jpgi Name: Dsc00040- DS-2A pipe corrosion - un-blasted side with hole.jpg Type: JPEG Image (image/jpeg) ~ Encoding: base64 ~i 'j Name' Dsc00041 - DS-2A pipe corrosion ,, · cleaned half.jpg ~ Dsc00041 - DS-2A pipe corrosion - cleaned half.jpg ~ Type: JPEG Image (image/jpeg) :i ~i Encoding: base64 i i Name' Dsc00042 - DS-2A pipe - Both i i halves with scale.jpg ~i ~_..~,~ Dsc00042 - DS-2A ~i~e - Both halves with scale.jp~ Type' JPEG Image (image/jpeg) i :i Encoding' base64 1 of 1 SGANNED J U N 20 02 5/17/02 1:47 PM .'..,,,..,.... J 5C;ANNED JUN ~ 'z~ 2002~ Re: 2A- I8 spill · Subject: Re: 2A-18 spill Date: Mort, 20 May 2002 13:13:43 -0800 From: "NSK Problem Well Supv" <n1617@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, The operator said he shut in everything. He first dumped the system to activate the SSV, then he closed the wing valve and then closed the master. I have enclosed a plot plan for 2A so you can see the distance the leak was from the wellhead. The leak was under the manifold building (facilities on the plot plan), which is several hundred feet of line from the 2A-18. I also added the investigation report that was done by Phillips after the incident, if you need any more information let me know. (See attached file' 2A PlOt PLan.pdf)(See attached file: 2A-18 Fitting Leak Investigation. doc) Also, do you have an update on our SSV database request. Thanks, Peter Nezaticky Phillips Alaska Inc. 659-7224 Tom Maunder <tom_maunder@admin.state.ak. us> 05/17/2002 04:45 PM To: NSK Problem Well Supv/PPCO@Phillips CC' Subiect:.~ 2A:_!~8 spill Jerry or Pete, I was looking at a report from Jeff Jones regarding an inspection when the 2A-18 flowline leak occurred. His report notes that when the operator discovered the leak, he activated the the SD of the well. I presume that he dumped the system to S! the SSV. Is this correct?? How far was the leak point from the well?? I am not surprised that there was insufficient pressure drop to activate the pilot. ! am aware of a leak at a drain valve connection on an Endicott well that was within 5 or 6' of the pilot and it didn't see it. Thanks for the info. Tom (See attached file: tom_maunder, vcf) t of 2 SGANNED JUN 5~20~02 1:43 PM Re: 2.A-18 spill ..... i~ Name' 2A Plot PLan.pdf . Plot PLan.pd~f Type' Acrobat (application/pdf)i ~i Encoding' base64 ~! " i Name: 2A-18 Fitting Leak Investigation doc i ~2A-18 Fitting Leak fnvesti§ation.doci Type' WINWORD File (application/msword) ~' i Encoding' base64 Tom Maunder <tom maunder@admin.state.ak, us> Sr. Petroleum Engineer iAlaska Oil and Gas Conservation Commission 2of2 fSCANNED JUN 2:/~ 2002, 5/20/021.43 PM i NORTH //--EDGE OF PAD ____// 13 14 15 16 r--2 ~ACES · _~_35'-~, I_ ,._3 ~AC~S o, ~-~'=~8~,~, ~ lA 2 ;5 4 ' ' RESERVE PIT ~__ ,, ........... RESERVE PIT RESERVE PIT 17 2321 · · oo&&o 12 11 10 9 ACeS · 2f*--f'=Sl'-I' RESERVE PIT 24 20 19 25 8 7 6 5 4 sPA~ · 2~-.',,~-.'--/--~2 sP^~ · ~-e'=6~-~' i DRILL SI'rE 2A FACILITY TOP HOLE LOCATION SEPTEMBER 3, 1999 LEGEND · Existing Producer & Existing Injector _PHILLIPS Alaska, In~c.~ Health, EnViro~m'~nt, Safety, T~ainin~ and E'm~gency servi'~s INCIDENT INVES TIG~I TION REPORT INVESTIG,4 TION NO. KO2L$Ol l INCIDENT N,4ME: 2,4-18 Cosasco Fitting LeaA Copying, redistribution and de-compilation of this document is restricted by Phillips Alaska, Inc. No part of this document may be reproduced in any form by any means without prior written authorization from the Phillips Alaska, Inc. HEST Supervisor. RISK RANK Injury/Illness EnVironmental I 'Property/Production LOsS Level 4 - High Level 3 - Medium X "' X Level 2 - Low "' l~evel I - Minor Near Incident ..... , ,, TIME AND PLACE OF INCIDENT & INVESTIGATION: Time & Date of Incident: 1030 hrs on 4/7/02 Time & Date Investigation Started: Time & Date of Report: Organization: Department / Work Group: Facility: Specific Location: 1200 hfs on 4/7/02 1200 hfs on 4/13/02 GKBU GKA Operations / CPF-2 CPF 2, 2A Pad Where 2A- 18 enters manifold bldg. DESCRIPTION OF INCIDENT: (The Incident and Events) While making routine rounds, a Drill Site Operator discovered oil leaking from a pipe underneath the manifold building. The leak was coming from the flowline of Well 2A-18, which was immediately shut in and the area supervisor was informed of the situation. The emergency response notification plan was initiated and the proper notifications were made to other affected parties. Once the clean up process was underway, the insulation was removed and the source of the leak identified. The oil had come from a pinhole located just above the weld where a thread-o-let used for Cosasco fitting access had been located just after making a 90° turn up into the manifold building. The spill was estimated to be 1200 gallons of product (8% oil and 92% produced water) and covered approximately 1700 ~. POSITIONS INVOLVED: (Job Titles) Drill Site Operator E_E_QUIPMENT INVOLVED: 2 inch thread-o-let located in 6 inch production line FINDINGS: (The Condition~ and Identified Causal Factors - those condi.,ms would have lessened the severity of or eliminated the incident- identif¥~.a,...u.....s..aJ..~.a..c_tp,..r._s.._.~.!~.~..~.a.....n.......~.) 1. The spill occurred sometime between 0430 and 1030 hrs, because the same area was walked down by the night operator at 0430 hrs. and had not been detected. 2. Due to the size of the hole, the pressure drop in the line was not enough to alarm or shut in the well. 3. During the early 80's the design criteria was to locate thread-o-lets with the Cosasco fittings in a low section of pipe so that when corrosion coupons were screwed into them they would be submerged in the liquid phase of the product to better detect corrosion. 4. The Cosasco fitting is not used for any type of monitoring because the location under the manifold was found to be ergonomically difficult to use due to the cramped quarters and accessibility was limited during the winter months due to snowdrifts. 5. The more recent drill site designs do not have thread-o-lets with Cosasco fittings in this location. 6. Erosion prone areas of this flowline ('S' riser and areas downstream of the choke) have been inspected seven times since 9/20/00. These inspections showed minor damage, but are within acceptable limits. The last inspection downstream of the choke was done on 3/16/02 and showed minor damage, but was within acceptable limits. It's common practice to inspect the most susceptible places where corrosion would occur in flow lines. This section of the flow line was thicker walled, 0.863", larger diameter and not where we have historically found erosion concems. The criteria used to determine problem areas are characteristically turbulent with high velocities, containing solids and/or corrosion product. 10. Another tool used to determine problem areas is the L/R ratio which is actual fluid velocity divided by the theoretical erosion velocity. If the ratio is greater than 1.5 then the line in question is inspected immediately and then again in one month to look for signs of damage. 11. The L/R ratio for 2A-18 had been > 1.5 and that's why it had been recently inspected. 12. Where the failure occurred there are signs of erosion and corrosion in the same area. 13. Experience has shown that where a branch circuit enters into another line there is usually turbulent flow in that area. 14. a, The location of the thread-o-let with the Cosasco fitting at the bottom of the 90° would account for the erosion pattern during high flow high solid conditions and also account for solid buildup and corrosion during low flow conditions. 15. This is the first known incident of this type even though there are many other locations set up exactly the same way. 16. 2A-18 was drilled as an A-sand producer in 05/95. The initial fracture stimulation and re-frac in 1997 did not introduce any significant volume of formation fines or propant into the well bore. A-sand fluid rates averaged 1000 bpd with 1000 GOR. With the C-sand perforations in 1999 the fluid rate increased to 7000 bpd. Starting in 2000 the GOR cycled between 2000 - 4000 scf/stb from the EOR process. Produced fluid rates continue to average 4000 to 6000 bpd. 17. The spool where the erosion/corrosion occurred was first used for Injection Well 2A-02. This well was put into service as a WAG injector in 1984. In 1987 an attempt was made to convert the well from C-sand injector to A-sand producer. The C-sands could not be isolated and the well was returned to injection service. 2A-02 injection line was converted to a production line for 2A- 18 in 1995. o , Listed below are the causal factors and root causes, which the team identified for this incident: 14. a, The location of the fitting at the bottom of the 90° elbow would account for the erosion pattern during high flow high solid conditions and also account for solid buildup and corrosion during low flow conditions. (4PN) Design Specs. Problem Not Anticipated Incident Investigation No. K02L3011 Page 2 WHAT CORRECTIVE MEASURES (HAVE BEEN/WILL BE)_ TAKEN? Recommended Remedial Action Responsible Party/E-Mail Due Date Inspect the rest of the 2A-18 flow line prior to putting it back into service 2. Determine where other similar locations exist at , , KUparuk on drill sites (i.e. thread-o-lets with Cosasco fittings on well lines on the outside radius of 90° elbows). Inspect all the locations identified in #2 using radiography to determine if there's a similar generic problem. Based on the inspection result of #3, develop and implement a long-term inspection and repair plan for the identified problem areas. PAl Corrosion Engineer NSK Corr lnsp Piping NSK DS Fac Engr and CPF Production Supervisors PAl Corrosion Engineer NSK Corr Insp Piping PAI Corrosion Engineer NSK Corr Insp Piping Complete 6/15/02 12/31/02 12/31/02 PS EE ELEMENT L.fFor a PA I E m element(s) that address the cause(s) of the incident) INVESTIGATION TEAM: Name/Title Contact Phone Number E-Mail Address Steve Bradley, PAI CPf2 Prod Supv 659-7502 CPF2 Prod Supv- N 1127@ppco.com Shellie Colegrove, PAI Env Coord 659-7212 NSK Env Coord A1 Dahlquist, PA1 Corrosion Engr 659-7773 NSK Corr Insp Piping '~-r~t~ bo~-~, PAl Prod Engr 659-7519 CPF2 Prod Engr Judy Leonard, PAI NSK DS Fac Engr 659-7234 NSK DS Fac Engr Bob Miner, PAI CPF2 Fac Engr 659-7864 CPF2 Fac Engr Tom Sanchez, PAl Safety Spec 659-7646 CPF2&3 Sfty Spec Greg Stutzer, PAI DS Operator 659-7498 CPF2 DS Operators REFERENCE NUMBER OF OTHER ASSOCIATED REPORTS: ! NAME AND PHONE # OF PERSON RESPONSIBLE FOR THIS REPORT: APPROVALS: LEVEL 3 (ResponSible Superintendent) Michael Wheatall LEVEL 2 (Responsible Supervisor) Steve Bradley None Steve Bradley 659-7502 Approved Date 4/15/02 4/13/02 Incident Investigation No. K02L3011 Page 3 JUN g 2_002 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~"~ DATE' CommissiOner Tom Maunder,/-j-~ P. I. Supervisor ~(~-o~ THRU: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 4, 2001 Safety Valve Tests Kuparuk River Unit -2A Pad Thursday, January 4, .2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2A Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2A-12 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2A Pad in the Kuparuk River Field. KRU 2A Pad, 12 wells, 24 components, 1. failure 4.1% failure rate 21 wellhouse inspections Attachment: SVS KRU 2A Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report OPerator: Phillips Operator Rep: Earnie Barndt AOGCC Rep: Chuck Scheve . Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 2A Pad Separator psi: LPS 96 HPS 1/4/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2A-01A 1840570 2~-02 1840500 2A-03 1840510 ,, 2A-04 1840530 2A-05 1840670 2A-06 1840640 2A-07 1840650 12A-08 1852480 - ~ 2A-09 1860010 96 70 50 P P OIL ,, 2A-10 1860020 96 70 55 P P OILi ,, 2A-11 1860030 96 70 50 P P OIL , 2A-12 1860040 96 70 70 P 4 OIL 2A- 13 1851440 96 70 50 P P OIL 2A-14 1851450 96 70 70 P P OIL 2A- 15 1851460 96 70 . 70 P P OIL 2A-16 1851470 96 70 70 P P 0IL 2A-17 1931400 96 70 50 P P OIL 2A-18 1~}50590 96 70 60 P P OIL 2A-19 1931520 2A-20 1931510 ,,, 2A-21 1931330 2A-22 1950680 96' 70 70 P P OIL 2A-24 1931440 96 70 60 P P 0IL · 2A-25 1960620 , Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1% E]9o var Remarks: Surface Safety on 2A-12 had slow leak, valve to be serviced and retested 1/9/01 Page 1 of 1 SVS KRU 2A Pad 1-4-01 CS.xls STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMISb,dN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well 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 736' FSL, 227' FEL, Sec. 13, T11N, R8E, UM At top of productive interval 1052' FNL, 341' FFL, Sec. 24, T11N, At effective depth 1328' FNL, 342' FEL, Sec. 24, T11N, At total depth 1362' FNL, 342' FEL, Sec. 24, T11N, R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 41 7. Unit or Properly name Kuparuk River Unit 8. Well number 2A-18 9. Permit number/approval number 95-59 10. APl number 5o-103-20220-00 11. Field/Pool R8E, UM 6791 feet 6383 feet Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 6 7 01 true vertical 6297 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 2 9 65' 9 - 5 / 8" Intermediate Production 6154' 7" Liner 8 3 0' 3.5" Perforation depth: measured 6474'-6494' true vertical 6082'-6101' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 5962' Packers and SSSV (type and measured depth) Cemented 200 Cu ft. 710 Sx AS III & 400 Sx Class G 132 Sx Class G 306 Sx Class G Measured depth 121' 3004' 6193' 6789' True vertical depth 121' 2878' 5815' 6380' ORIGIN4L Pkr: Baker GBH-22 LSA @ 5977'; SSSV: None, nipple @ 509' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 1/15/98. Intervals treated (measured) 6474'-6494' Treatment description including volumes used and final pressure Pumped 285 M lbs of 20/40 and 12/18 ceramic proppant into formation, fp was 3500 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 468 497 429 590 3O6 Subsequent to operation 851 1 6 3 8 542 600 313 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. Form 1 O- 4.e/4~" F~ v '~,0~'/1/~ I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE .,~O Alaska, Inc.-~- K:UPARUK RIVER UNIT WELL SERVICE REPORT ~ K1(2A-18(W4-6)) WELL JOB SCOPE JOB NUMBER 2A-18 FRAC, FRAC SUPPORT 1 221 971 056.3 DATE DAILY WORK UNIT NUMBER 01/15/98 "A" SAND REFRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O No (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC# CC~ DAILY COST ACCUM COST Signed ESTIMATE KD1808 230DS28AL $1 58,438 $168,255 InitialTb_qPress FinalTb.qPress Initial lnner Ann Final lnner Ann I Initial Outer Ann J Final Outer Ann 1150PSl 1500PSl 725PSl 500PSlII330PSI , 400PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 285047 LBS OF PROP IN THE FORM W/13.5# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 6000 PSI & F.G. @ (.72). FREEZE PROTECTED WELLBORE DOWN TO 1900' W/17 BBLS OF DIESEL. TIME 07:00 12:00 12:30 13:30 ' 15:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, AND APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9900 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 TO 15 BPM. SLURRY VOLUME PUMPED 400 BBLS. USED 5661 LBS OF #20/40 PROP. MAXIMUM PRESSURE 6000 PI AND ENDING PRESSURE 2000 PSI. STEPPED DOWN RATE @ THE END OF STAGE. S/D AND OBTAINED ISlP OF 1711 PSI W/F.G. @ (.72). MONITORED WHTP AND PULSED TO CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 167 BBLS. MAXIMUM PRESSURE 3100 PSI AND ENDING PRESSURE 2900 PSI. S/D AND OBTAINED ISlP OF 1923 PSI W/F.G. @ (.76). STOOD-BY AMD MONITORED WHTP FOR CLOSURE. DETERMINED CLOSURE TIME OF 11.5 MINS @ 1530 PSI. PAD VOLUME = 630 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 2031 BBLS. MAXIMUM AND ENDING PRESSURE 3500 PSI. COMPLETED THRU FLUSH. TOTAL PROP PUMPED 286114 LBS (21930 LBS OF #20/40 & 264184 LBS OF #12/18). INJECTED 285047 LBS OF PROP IN THE FORMATION W/13.5# PPA OF #12/18 @ THE PERF'S. LEFT1067 LBS OF PROP IN THE WELLBORE AND EST TOP OF FILL @ 6275'. FREEZE PROTECTED WELLBORE DOWN TO 1900' W/17 BBLS OF DIESEL. 17:30 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. 18:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. RDMO DOWELL FRAC EQUIP. WELL SECURED AND NOTIFIED DSO OF STATUS. 19:30 SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $957.00 APC $6,850.00 $6,850.00 DIESEL $400.00 $400.00 DOWELL $148,439.00 $148,439.00 HALLIBURTON $0.00 $5,500.00 LI-I-I-LE RED $2,750.00 $6,110.00 TOTAL FIELD ESTIMATE $158,439.00 $168,256.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well 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 736' FSL, 227' FEL, Sec. 13, T11N, R8E, UM At top of productive interval 1052' FNL, 341' FEL, Sec. 24, T11N, At effective depth 1328' FNL, 342' FEL, Sec. 24, T11N, At total depth 1362' FNL, 342' FEL, Sec. 24, T11N, R8E, UM R8E, UM R8E, UM 6. Datum elevation (DF or KB) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-18 9. Permit number/approval number 95-59 10. APl number 50-103-20220-00 11. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 6 7 91 true vertical 6 3 8 3 feet feet Plugs (measured) None Effective depth: measured 6 7 01 true vertical 6 2 9 7 feet feet Junk (measured) None 13. 14. Casing Length Size Structural Conductor 8 0' 1 6" Surface 2 9 6 5' 9 - 5 / 8" Intermediate Production 6154' 7" Liner 8 3 0' 3.5" Perforation depth: measured 6474'-6494' true vertical 6082'-6101' Cemented 200 Cu ft. 710 Sx AS III & 400 Sx Class G 132 Sx Class G 306 Sx Class G Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 5962' Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 LSA @ 5977'; SSSV: None, nipple..:@.?.509".' Measured depth True vertical depth 121' 3004 6193 6789 121 2878 5815' 6380' Stimulation or cement squeeze summary Fracture stimulate "A" sands on 1/15/98. Intervals treated (measured) 6474'-6494' Treatment description including volumes used and final pressure Pumped 285 M lbs of 20/40 and 12/18 ceramic proppant into formation, fp was 3500 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 468 497 429 590 3O6 Subsequent to operation 851 1638 542 600 313 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date SUBMIT IN DUPLICATE Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~" K1(2A-18(W4-6)) WELL JOB SCOPE JOB NUMBER 2A-18 FRAC, FRAC SUPPORT 1 221 971 056.3 DATE DAILY WORK UNIT NUMBER 01/15/98 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O NoI (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC# CCC DAILY COST ACCUM COST Signed ESTIMATE KD1808 230DS28AL S158,438 $168.255 Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 1150PSI 1500PSI 725PSI 500PSI 330PSI! , 400PSI DAILY SUMMARY I"A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 285047 LBS OF PROP IN THE FORM W/13.5# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 6000 PSI & F.G. @ (.72~. FREEZE PROTECTED WELLBORE DOWN TO 1900' W/17 BBLS OF DIESEL. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, AND APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). 12:00 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9900 PSI. 12:30 13:30 15:00 PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 TO 15 BPM. SLURRY VOLUME PUMPED 400 BBLS. USED 5661 LBS OF #20/40 PROP. MAXIMUM PRESSURE 6000 PI AND ENDING PRESSURE 2000 PSI. STEPPED DOWN RATE @ THE END OF STAGE. S/D AND OBTAINED ISIP OF 1711 PSI W/F.G. @ (.72). MONITORED WHTP AND PULSED TO CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 167 BBLS. MAXIMUM PRESSURE 3100 PSI AND ENDING PRESSURE 2900 PSI. S/D AND OBTAINED ISIP OF 1923 PSI W/F.G. @ (.76). STOOD-BY AMD MONITORED WHTP FOR CLOSURE. DETERMINED CLOSURE TIME OF 11.5 MINS @ 1530 PSI. PAD VOLUME = 630 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 2031 BBLS. MAXIMUM AND ENDING PRESSURE 3500 PSI. COMPLETED THRU FLUSH. TOTAL PROP PUMPED 286114 LBS (21930 LBS OF #20/40 & 264184 LBS OF #12/18). INJECTED 285047 LBS OF PROP IN THE FORMATION W/13.5# PPA OF #12/18 @ THE PERF'S. LEFT1067 LBS OF PROP IN THE WELLBORE AND EST TOP OF FILL @ 6275'. FREEZE PROTECTED WELLBORE DOWN TO 1900' W/17 BBLS OF DIESEL. 17:30 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. 18:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. RDMO DOWELL FRAC EQUIP. WELL SECURED AND NOTIFIED DSO OF STATUS. 19:30 SERVICE COMPANY- SERVICE DALLY COST ACCUM TOTAL $0.00 $957.00 APC $6,850.00 $6,850.00 DIESEL $400.00 $400.00 DOWELL $148,439.00 $148,439.00 HALLI BURTON $0.00 $5,500.00 LITTLE RED $2,750.00 $6,110.00 TOTAL FIELD ESTIMATE S158,439.00 $168,256.00 95~.059 95 -- 9 S 9 (3eo'Jog'ica'J Ha{er"ia'ls Inventor'-y Ar'lc dr"y d{ hcn sampies r"equ Was the v,/eti Ar'e vve'il ~ecei' ved9 7/8/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11127 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor , 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 2A-18 ~ · O~'~ ~--( 5 ! 97284 GR (MWD & CBL) 950515 1 1 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED JUL 1'1 1997 Ant, borage ARCO Alaska, Inc. Date' December 26, 1995 Transmittal #: 9311 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. q,~.,; e~"? All items below include BOTH Blueline and Sepia. ' ~ ~, 2A-i 8 CBL 10/15/95 ,fr-~'.¢,~ 2T-32 CBL 10/19/95 ,Lr- t~.. 2T-36 CBL 1 0/20/95 q-~'-'~ l~,Z. 1Q-26 CBL 10/24/95 c-t~--- ~t 1 Q-23 CBL 1 0/24/95 5800-6655 13130-13636 14990-15325 5900-6885 8700-9866 Acknowledge' Date' DISTRIBUTION: Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 RECEIVED ^laska 0il & Gas Cons. Commission Anchorage Erickson/Zuspan NSK Central Files NSK-box 69 ,CO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 4, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2A-18 (Permit No. 95-59) Well Completion Report Dem' Mr. Commissioner: Enclosed is the well completion report for the recent operations 18. If there are any questions, please call 265-6206. Sincerely, Supervisor Kuparuk Drill Site Development MZ/skad on KRU 2A- STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMN....,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I STatus of Well Classification of Service Well OIL E~ GAS E~ SUSPENDED [~ ABANDONED [] SERVICE [~] '"" ,. ! //'/'-'\ r 2 Name of Operator 7 P~r~it'~ui:nber ~' /. ARCO Alaska, Inc 95-59 / i'/. 3 Address 8 APl Number P.O. Box ' 00360, Anchorage, AK 99510-0360 F~~~ 50-103-20220 4 Location of well al surface ~ ~'-~;~ ', . ._ ~~ ~~ 9 Unit or Lease Name 736'FSL, 227'FWL, Sec. 13, T11N, RSE, UM ;~ ~ . Kuparuk River Unit Al Total~-/~f~" ~:; ~.. ~ : Field and Pool 120' FWL, 1323' FNL, Sec. 24, T11 N, R8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER RKB 41' Pad 94'I ADL25570 ALK 2668 12 Dale Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 16 No. of Completions May 15, 1995 October 6, 1995 15-Oct-95 (~d)[ NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back ~pth (MD+TVD) 19 Directional Su~ey 120 Deplh where SSSV set 21 Thickness of ~rma~ost 6791' MD & 6383' TVD 6701' MD & 6297' TVD YES ~ NO ~I NA feet MD =1380'ss APPROX ., 22 Type Electric or Other Logs Run GR 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE C~E~ ~ 16" 62.58¢ H-40 Surf. 121' 24" · 200 CF 9.625" 40¢ L-80 Surf. 3004' 12.25" 710 sx AS III Lead, 400 sx Class G Tail 7" 26¢ L-80 Surf. 6193' 8.5" 132 sx Class G 3.5" 9.3~ L-80 5959' 6789' 4.75" 306 sx Class G 24 Perforations o~n to Production (MD+TVD of Top and Bo~om and 25 TUBING RECORD inle~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5962' 5977' (PBR) 6474'-6494' M D 4 spf 6082'-6101' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ~74'-6494' 38,887¢ 20/40, 191,000 12/18, 13,013~ 10/14 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) ~t-95~ Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/28/95 24.1 TEST PERIOD E 468 985 3161 176 1246 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 420 1371 24-HOUR RATE ~ 423 528 3150 24~ 28 ~RE DATA Brief description of lithology, ~rosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ...... JAN 0 9 i~ ~.,"~, v ¢~-1~ Form ! 0-407 Submit in duplicate Rev. 7-; -80 CONTIN~JED ON REVERSE SIDE 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 6342' 5957' Base Kuparuk C 6393' 6006' Top Kuparuk A 6434' 6044' Base Kuparuk A 6572' 6175' 31. LIST OF ATTACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~'~, ~ Title DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 n- jection, Gas Injection, Shut-in, Other-explain. . Item 28: If no cores taken, indicate "none". Form 10-407 Date:Il/08/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2A-18 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK7621 AFE: AK7621 TYPE:DEV AFE EST:$ 1318M/ 1850M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20220 FIELD: KUPARUKRIVER SPUD:05/15/95 START COMP: FINAL: 05/14/95 ( 1) TD: 121'(121) SUPV:RLM 05/15/95 (2) TD: 121'( 0) SUPV:PJ_~ 05/16/95 (3) TD: 3014' (2893) SUPV:RLM 05/17/95 (4) TD: 3014' ( 0) SUPV:RLM 05/18/95 (5) TD: 6194'(3180) SUPV:jT 05/19/95 (6) TD: 6194'( 0) SUPV: jT 09/29/95 (7) TD: 0'( 0) SUPV:DLW 09/30/95 (8) TD: 0'( 0) SUPV:DLW MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG Prepare rig for move. Move rig from 2T pad to 2A pad. DAILY:S116,430 CUM:$116,430 ETD:SO EFC:$1,434,930 MW: 9.1 PV/YP: 26/23 APIWL: 12.4 PICK UP AND STAND BACK DP. MIRU. Accept rig at 2130 hrs 5/14/95. Nipple up diverter system. Mix spud mud. Load 9-5/8" casing. Perform rig maintenance. Pick up and stand back BHA and drill pipe. DAILY:S76,628 CUM:$193,058 ETD:SO EFC:$1,511,558 MW: 10.0 PV/YP: 30/36 APIWL: 10.4 RIG TO RUN CASING Spud at 0930 hrs 5/15/95. Directional drill 12.25" hole from 121' to 3014' DAILY:S80,643 CUM:$273,701 ETD:SO EFC:$1,592,201 MW: 8.9 PV/YP: 4/ 3 APIWL: 18.5 DRILL FLOAT COLLAR Run casing hit bridge at 1723'. Worked pipe through 4' bridge. Run in hole with casing to 3004'. Cement casing, CIP at 1335 5/16/95. Well started flowing up 9-5/8" x 16" annulus. Shut in annulus. Cement 9-5/8" x 16" annulus. Nipple up 13-5/8" BOPE. Test BOPE. Test 9-5/8" casing to 2000 psi. DAILY:S167,621 CUM:$441,322 ETD:SO EFC:$1,759,822 MW: 9.6 POOH TO RUN CASING Drilled from 3024 to 6194'. DAILY:S68,923 CUM:$510,245 PV/YP: 11/ 5 ETD:SO APIWL: 5.4 EFC: $1,828,745 MW: 9.6 PV/YP: 12/ 5 APIWL: 6.0 RIG RELEASED Run 7" casing. Cement casing. CIP @ 1915 hrs. Freeze protect well. Release rig 0100 hrs 5/19/95. DAILY:S154,157 CUM:$664,402 ETD:SO EFC:$1,982,902 MW: 11.1 PV/YP: 0/ 0 APIWL: 0.0 N/U BOPE Turn key Pad to Pad rig move. Move rig from 2T to 2A. Accept rig @ 0200 hrs 9/29/95. DAILY:S24,950 CUM:$689,352 ETD:SO EFC:$2,007,852 MW: 10.9 PV/YP: 14/17 APIWL: 4.3 P/U 3-1/2" DP RIH Continue N/U BOPS. Test BOP's and manifold. Load pipe house with drill pipe and BHA ~1. P/U BHA ~1. P/U 3-1/2" DP and RIH. Date:Il/08/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT 10/01/95 ( 9) TD: 0'( 0) SUPV:DLW 10/02/95 (10) TD: 6374' PB: 6455' SUPV:DLW 10/03/95 (11) TD: 6692'(318) SUPV:DLW 10/04/95 (12) TD: 6692'( 0) SUPV:DCL 10/05/95 (13) TD: 6692'( 0) SUPV:DCL 10/06/95 (14) TD: 6692' ( 0) SUPV:DCL 10/07/95 (15) TD: 6692'( 0) SUPV:DCL 10/08/95 (16) TD: 6791'( 99) SUPV:DCL 10/09/95 (17) TD: 6791'( 0) SUPV:DCL DAILY:S31,725 CUM:$721,077 ETD:SO EFC: $2,039,577 MW: 11.2 PV/YP: 21/ 8 C/O CEMENT @ 6122' Continue RIH with 3-1/2" DP. Test casing. DAILY:S35,771 CUM:$756,848 ETD:SO APIWL: 4.0 EFC: $2,075,348 C/O CTU DRILLED HOLE @ 63 MW: 0.0 Continue C/O cement plug from 6122' to 6193' 7" casing shoe. Clean out 6-1/8" hole drilled by CTU. DAILY: $39,941 CUM: $796,789 ETD:SO EFC: $2,115,289 MW: 11.6 PV/YP: 32/29 APIWL: 3.6 CIRC & RAISE MUD WT TO 11.8 Continue clean-out 6-1/8" hole drilled by CTU. Drilling new 6-1/8" hole. DAILY:S33,884 CUM:$790,732 ETD:SO EFC:$2,109,232 MW: 11.9 PV/YP: 35/ 0 APIWL: 3.5 RIH W/ 3-1/2" DP Circ and condition mud. Increase weight. Wash and ream through bridges. Drop tandem single shot gyros. Monitor well. Pump slug. No problems. RIH with Schlumberger triple combo tool. Unable to work below bridge at 6300' . DAILY:S39,062 CUM:$829,794 ETD:SO EFC:$2,148,294 MW: 11.9 PV/YP: 35/45 APIWL: 3.0 SHORT TRIP TO SHOE Continue RIH to shoe. RIH tag bridge at 6300'. Wash and ream bridges and tight hole. Hole sticky and packing off. Sloughing shale. DAILY:S35,759 CUM:$865,553 ETD:SO EFC:$2,184,053 MW: 12.1 PV/YP: 38/48 APIWL: 3.4 CIRC AND CONDITION MUD Run in hole with tripple combo. Unable to work tool below 6215'. Circ. and condition mud. Gas cut mud to surface. Mud extremely thick. DAILY:S58,930 CUM:$924,483 ETD:SO EFC:$2,242,983 MW: 12.1 PV/YP: 38/52 APIWL: 3.8 RIH TO TD Wash and ream through tight hole from 6215' to 6532'. Drilling 6-1/8" hole from 6692' to 6791'. Wash and ream tight hole from 6556' to 6626'. DAILY:S34,134 CUM:$958,617 ETD:SO EFC:$2,277,117 MW: 12.0 PV/YP: 38/52 APIWL: 3.6 PUMP CEMENT Run in hole with 3-1/2" liner to 6190'. MU cement head. Circ and condition mud. RIH w/3-1/2" liner to 6791'. DAILY:S34,446 CUM:$993,063 ETD:SO EFC:$2,311,563 MW: 12.0 PV/YP: 37/48 APIWL: 3.4 RIH WITH 3-1/2" COMPLETION EQU Pump cement. Set packer and hanger. Test BOPE to 250 and 3500 psi. Test annular to 3000 psi. Run in hole with 3-1/2" completion equipment. DAILY:S68,386 CUM:$1,061,449 ETD:SO EFC:$2,379,949 10/10/95 (18) TD: 6791'( 0) SUPV:DCL MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Continue RIH w/ 3-1/2" completion equip. Test casing and liner to 3500 psi for 30 min. Freeze protect well. Test tubing and annulus. Secure well. Release rig at 2000 hrs 10/9/95. DAILY:S107,407 CUM:$1,168,856 ETD:SO EFC:$2,487,356 October 15, 1995 Initial perf of "A" sand with 20' 2-1/~" HC gun with BH charges, 4 spf, 180° phasing (orientation 2 spf 160° C~ from high side, 2 spf 20° CW from high side). Perf interval @ 6474'-6494'. COMPANY LOCATION ATTENTION WELL NAME ' SERVICES · SCHLUMBERGER GEOQUEST INTERPRETATION AND COMPUTING SERVICES 500 W. INTERNATIONAL AIRPORT ROAD . ANCHORAGEi ALASKA 99518 A._~K 0IL _& GAS. CONN. C.0MI~. DATE : -.-,C~ LARRY. GRANT , ,/ //~,. \ ~ 2A-18. '~'~ _- ' "~,~ ~LNAME : i OH EDIT TAPE (~D) ~/ SERVICE8 ' OCTOBER 12~ 1995 NO. OF BOXES: 1 JOB NO. · 95326 ADD'L TAPES · --- NO. OF BOXES: -. JOB NO. · , · ADD'L TAPES ' WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME ' SERVICES · : ' NO. OF BOXES: JOB NO. ' WELL NAME · SERVICES ' ADD'L TAPES ' NO. OF BOXES: WELL NAME SERVICES /~NO. OF BOXES: ADD'L TAPES : DATE DELIVERED: RECEIVED BY: ARCO Alaska, Inc. Date: August 25, 1995 Transmittal #: 9291 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Records Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below am the following items. return one signed copy of this transmittal. 2A-18-~ Directional-Survey 5/18/95 ~~___~A,-22~'~ O ~,(~ Directional Survey 5/19/95 ..~~ -j~ Directional Survey 6/23/95 ~~~~=2~. Directional Survey 6/9/95 ~/, ~.....- ~ ~_.~_~_._,.5 ~~,~2T-28 Directional Survey 7/2/95 '~-~~ Directional Survey 5/31/95 .~,~.~~- c,~ -- ~ Directional Survey 7/11/95 ~'~ ~qJ~_2T- 36_~ Directional Survey 7~26f95~- ~wtt~e dg ed: ~.z~..~'~)/~,~ ~.~ate: Please acknowledge receipt and Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 AK7621 AK8213 AK8173 AK8237 AK9229 AK8157 7/1 1/95 ....... AK8181 AK8253 'Larry Grant (2 copies) 3001 Porcupine Dr. Anchorage, AK 99501 ARCO Alaska, Inc. Date: August 11, 1995 Transmittal #: 9285 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Records Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Ci .b:t 0'~ °~ 2A- 18 Sub-Surface Directional Survey ~~ ~,,~, o,,~....., n',~ .... '------, °~"L"2A-28 SurveySUb-Surface Directional 7/2/95 2T-22 Sub-Surface Directional 6/23/95 Survey Sub-Surface Directional 6/9/95 ~. o'(~_.~T'26 Survey 2T-29 Sub-Surface Directional 5/31/95 Survey 2T-31 , Sub-Surface Directional 7/11/95 Survey Receipt Acknowledged DiSTRiBUTiO :r~/ ,/ ' 5/18/95 AK 7621 ~ _ AK R2-13 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 AK 9229 AK 8173 AK 8237 AK 8157 Date;.. Lar~ Grant (2 copies) 3001 Porcupine Dr. Anchorage, AK 99501 ARCO Alaska, Inc. Post Office .Box 10036,0 Anchorage, Alaska 99510~0360 Telephone 907 276 i2!5 August 1, 1995 Chairman and Commissioners Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Update o~paruk VVeil 2A-18)Ooiled Tubing Drill-out and Future Plans for the Well. Gentlemen: Kuparuk well 2A-18 was ARCO's first effort at coiled tubing drilling in the Kuparuk River Unit. As permitted in May 1995, the well was designed to top-set the Kuparuk Formation with 7" casing using Parker Rig 245 and then under-balance drill an estimated 500' of the Kuparuk interval with a coiled tubing unit (CTU). If CTU operations proved unsuccessful, the well was then to be conventionally drilled using a rig and an over-balanced mud system. During the period of July 7-9, the under-balanced CTU drill-out on well 2A-18 was attempted. After drilling 261' of new hole below the 7" casing shoe, operations were shutdown and the well temporarily plugged back due to unstable hole conditions. Although problems were not encountered while initially drilling the hole, shale intervals above the Kuparuk proved to be unstable after time in an under-balanced state. Despite the hole problems encountered, the overall CTU operations went very smooth and valuable information regarding the limits and capabilities of coiled tubing drilling in Kuparuk was gathered. Current plans for completing drilling operations on well 2A-18 are to move Nordic Rig 1 on the well in late August. Using a weighted mud system, the well will be drilled to TD as per directional plans submitted with the original permit application. All other aspects of the operation, such as production liner design, drilling fluids disposal, and DOPE test requirements, will also be as stated in the original permit application. If you have any questions about this operation please contact Bill Isaacson at 263-4622. Kuparuk Drill Site Development Supervisor / U6 0 4 995 Mca git & Gas cons. commission AR3B-6003-93 242 2003 ~ .CONSERVATION COMMISSION TONY KNOWLE$, GOVEt~NOF! ALASKA OIL ~ND GAS 3oo~ PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 278~7542 May 10, 1995 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc, P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2A-18 ARCO Alaska, Inc. Permit No: 95-59 Sur. Loc. 1736'FSL, 227'FWL, Sec. 13, TllN, R8E, UM Btmhole LoC. 1376'FNL, 88'FWL, Sec. 24, TllN, R8E, UM Dear Mr. Zanghi~; Enclosed is the approved application for permit to drill the above referenced The permit to drill does not exempt you from obtaining additional permits required.by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for a variance from the requirements of 20 AAC 25.033 (a)(1) relating to under balanced coil tubing drilling within the Kuparuk River formation is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field 7. ~airman ~ ~ ~-~ BY ORDER OF THE C ISSiON dlf/Enclosures · !" cc: Departmentlof Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSioN PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill F~ lb Type of Well Exploratory r~ Stratigraphic Test [] Development Oil X Re-Entry [] Deepen [] Service [] Development ems [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF.or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 94' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25570, ALK 2668 4. Location of well at surface 7. Unit or properly Name 1 1. Type Bond (see 20 AAC 25.025) 736' FSL, 227' FWL, Sec. 13, T11N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1205' FNL, 88' FWL, Sec. 24, T11N, RDE, UM 2A-18 #U-630610 At total depth 9. Approximate spud date Amount 1376' FNL, 88' FWL, Sec. 24, T11N, RDE, UM 5/1 0/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) property line 2A-1 & 2A-lA 6806' MD 3900 @ TD feet 17.3' @ 725' MD feet 2560 6367' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 23.6° Maximum surface 1680 psig At total depth (TVD) 3700 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 40.0# L-80 BTC 2964' 41' 41' 3005' 2885' 710 Sx Arcticset Ill & HF-ERW 400 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 6282' 41' 41' 6323' 5925' 85SxClassG 4.75" 3.5" 9.3# L-80 BTCMOE 681' 6125' 5740' 6806' 6367' 185 Sx Class G Spec Cl Top 200' above 7" shoe. 1 9. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth _ _ _ T_rt~. V..~dical depth Structural R E'EEIVED Conductor Surface Intermediate Production MAY - 4 1995 Liner Perforation depth: measured ~Ski~ .Oil .& Gas Cons. Commission true vertical ~ch0rage 20. Attachments Filing fee X Property plat ~] BOPSketch X X Diveder Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis ~] Seabed report [] 20 AAC 25.050 requirements Z 21. I hereby certify ~atj~/the fore/going/ is true and correct to the best of my knowledge Signed ~vf( ,, _~¢,¢_._~ Title Drill Site Develop. Supv. Dat ".--(' ./ ~ Commission Use Only Permit Number ~"""~ J~l number I Approval date,,,- / / fI See cover letter forJ' 'q o-/'o...-- .=_ o o I I other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required [] Yes [~ No Hydrogen sulfide measures J~ Yes [] No Directional survey required ,~ Yes Fi No Required working pressure for BOPE r~ 2M [~] 3M r~ 5M F'] 1OM ~ 15M Other: ~ "'$~"¢ro ,- Cf-(,& Ong na dy by order of ~_~/~ /~ _Approved by David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 ~ triplicate 10. 11. 12. 13. 14. 15. 16. 17 18 19 2O 21 22 23 24 25 26 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2A-18 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3,005')as per directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (6,323') according to directional plan. Run open hole evaluation logs (MWD Gamma Ray Only). Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for CTU drillout. Secure well and release rig. Move in and rig up coiled tubing unit. Drill out 7" float shoe with 6-1/8" bit. Using sea water drill 10' of new 4-3/4" hole. Perfrom formation integrity test to the greater of 12.5 EMW or 0.5 ppg over the EMW of the projected reservoir BHP* (*as determined just prior to drillout). Drill 4-3/4" hole under balanced using sea water to 6,806' MD Run electric line logs as required and as hole conditions allow. Run and cement 3-1/2" liner with 200' of liner lap. Contaminate and circulate out excess cement. Run and set liner top packer. Secure well. Rig down and move out CTU. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3,500 psi. Run 3-1/2" completion assembly. ND BOPE and install and test production tree. Shut in and secure well. Clean location and release rig. Rig up E-line. Test Lubricator. Tie-in with GR-CCL and perforate well. Rig up slickline and run multi-shot gyro survey as required. DRILLING FLUID PROGRAM Well 2A-18 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids *Spud mud should be ad Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to 7" casing depth 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drill out with CTU to TD 8.6 ppg Sea Water -- . Sweeps as Req'd . . -- -- . Jsted to a FV between 50-80 sec/qt to drill gravel beds. Primary Rig Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Fluid Flow Sensor Mud Cleaner, Centrifuges, Degasser Trip Tank Pit Level Indicator (Visual and Audio Alarm) Fluid Agitators CTU Fluid System: (See attached equipment layout diagram). Dual choke manifold Storage / flow back tanks Sea water suction from offset injection well Notes: The producing interval of DS 2A-18 will be drilled with sea water under-balanced and as such ARCO Alaska, Inc. is requesting special permit consideration. Drilling fluid practices with the Parker 245 will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Drilling with the Coiled Tubing Unit will be accomplished by drilling the well under- balanced with sea water taking returns to the plant. By way of this Permit to Drill ARCO Alaska, Inc., il requests approval to deviate from 20 AAC 25.033 for the portion of the well drilled below the 7" ,.. intermediate casing shoe and total depth. /~ Maximum anticipated surface pressure is calculated using a s__u_urface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakcTC~v~ould occur before a surface pressure of 1,700 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to . 3000 psi. The maximum anticipated surface pressure while drilling under-balanced with CTU is anticipated to be less than 3,100 psi (gas gradient to surface with anticipated BHP). Therefore during the CTU drilling operation the BOP equipment will be tested to 3,500 psi. If the CTU drill out is not successful and a drilling rig is required to drill the production hole conventionally over-balanced using mud, the maximum anticipated surface pressure will be calculated using a intermediate casing leak-off of 14.5 ppg EMW and a sea water gradient of 0.45 psi/ff. This calculation would indicate that formation breakdown would occur before a surface pressure of 2,200 psi could be reached In this scenario the BOP equipment will be tested to 3,000 psi. P~ [ 6 F,~V EL ~ N At' - 4 995 Gas Cons. Commission Drilling Fluid Program (cont.) Well DS 2A-18 The nearest well to 2A-18 is 2A-01. As designed, the minimum distance between the two wells would be 17.3' @ 725' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2A-18 surface/production casing annulus will be filled with diesel after setting 7" and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. l'"Risks in the 2A-18 drilling area include lost circulation and high pressures in the Kuparuk formation. Problems with lost circulation should be minimized above the Kuparuk since the formation will be topset with 7" casing; all drilling to that point will be at Iow mud weights. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 p._.___~pg upon drilling out of the surface casing. Gas Cons. Commission Anchora¢ DS 2A-18 CTU Drill Out Completion Schematic 2.812" "D" Nipple 3-1/2" tubing 7" Casing'----~ 2.812 .... W" Nipple 10 ft. x 4" ID SBE 3-1/2" GLM Nordic Runs PBR, latch assembly and 3-1/2" tubing. jSeal Assembly FB-1 Packer, Seal Bore Extension & Seal Assembly 3-1/2" Liner C-Sand Perfs A-Sand Perfs CTU Runs everything from the 3-1/2" liner through the FB-1 Packer and Seal Assembly RE£EIVED MAY - 4 1995 4-3/4" Open Hole ~i~ska Oil & Gas Cons, Comrrlissiorl Anchora~.j~ 4/5/95 jtz iCreated by ' jones For: D PETI~Hi iDate plotted : 15-Mar--95 ?lot Reference is 18 Version #3. i !Coordinates ore in feet reference slot #18. i iTrue Vertical Depths ore reference wellhead.I i --- Baker Hughes INTEQ --- g 300 ~ 600 (/) 900 1200 1500 1800. _ 2100_ - 2400_ 2700_ ,3000_ 3300 ~600l ~9001 q-200 _ 4500_ - RKB ID.,EVATK)N: 13,5' KOP TVD-70~3 TMD-700 DEP-O S.O0 3 D£O / loo' IX.S 9.00 BEG~N TURN TO TARGET TVD=1097 TMD=1100 D~P=3 ARCO ALASKA, InC. Structure : Pad 2A Well : 18 Field : Kuparuk River Unit Location : North Slope, Alaska 10.9,5 ~5.11 T/ U~U SN~ ~=15~ ~0=1573 DEP=61 17.32 19.7~ '~ E~ ~=1942 TMD=19~ DEP'188 T/ W ~ SNDS ~=2274 ~D=2339 DEP=332 B/ W ~ ~DS ~=2~5 ~D=2787 OEP=512 ~ AVERAGE ANGLE 23.61 DEC SURFACE LOCATION: 736' FSL, 227' FWL SEC. 13~ T11N~ R8E S 4.1 DEG W 1946' (TO TARGET) ***PI.,~NE OF PROPOSAL*** 510D_ _ 5400_ _ 5700_ _ 6OOO_ _ 6300_ _ 6600_ T.~d~GET - T/ ZONE C TVD=5975 TMI)=6378 6900 ] I I I I I I I I I I I I I I I I I I I 300 O 300 600 900 1200 15OO 1800 2100 2400 Scala 1 : 150.00 Vedic~31Seot~n en 184.10 uzirmlth with referertce 0.0~3 N, 0.00 [ from slot ~18 <-- West ...... 200 1000 100 200 Top Uq¢~l ~3~dPern'~fl'O~ ToD We~t Sok Bom W~ Sok .~3nd= ~ 5/8 C~ ~ K-Ia TARGET LOCATION K-5 WD=4545 TMD=4817 DE33= 523 : 1205' FNL, 88' FWL SEC. 24, Tl lN, RS~ X TARGET ~ HRZ WD=5845 TMD=6236 DEP=1889 ~ k ~r~ ZONE A ~=~59 mD=6~9 DEP=1983 ~ ~ ~T/ A4 SNDS ~=6091 TMD=6504 DEP=1997 k ~, ~ B/ KUP SNDS ~=618~ TUD=6~6 DEP=2037 = RECEIVED MAY - 4 I995 Gas Cons, Commission Anchora,. ID LOCATION: 1376' FNL, 88' FWL SEC. 24, T11N, R8E 100 100 200 90O 1000 100 O I I V ARCO ALASKA, ][~C. Structure : Pad 2A Well: 18 / 22 Field : Kuparuk River Unit Location : North Slope, Alaska ~oo,e, : ~0.00 E a s t -- -- > 400 36D .320 280 240 200 1 ~0 120 ~0 40 0 40 80 120 160 200 240 2~0 .320 360 400 4-4,0 1200_ 7O0 9O0 lOOO _1160 1000 1200 1080. RECEIVED 120 ,ooo. , MAY - 4 1995 960 920 880 _ 800 760 ~2o 680, A!as~.0il & Gas Cons. Commission ~o-'~ '' ~ch0ra~ / x,,. ,e /2000 ~ 22~ o ~ '4~ X - 320 84o A 720 0 64o 520 _ .~ ~00 - _ 480 _ /1ooo 480 5,, ~ 360 320280 2~ 200 1 ~ 120 ~ 40 0 40 80 120 160 2~ 240 2~ 320 5~ 400 ~,~ ~: ~o.oo E ~ s f - - > ARCO ALASKA, Inc. Structure-Pc~d 2A Well' 18 / 22 : Field · Kupc~ruk River Unit Loc(3fion · North Slope, Aldskc~! ~ 300 .. 2oo 1300 14.00 1600l 1700_.[ _ !800_ 2000 2100 ~o,e, : ~O.OO E a s t - - > I(X~O 900 8~0 700 600 500 4~0 300 200 10(I 0 I00 200 ~ 400 500 600 ?00 800 900 1000 230O 2700 240~ 310(3 I i i i i i 1000 900 800 700 600 500 40.0 34~0 200 100 0 ~100 200 300 400 500 600 700 8430 900 ' o<.x;, · ' Scale 1 : 50.00 Ea st - - > 4100 ~2200 ~"* ~~ MAY -' 4 1995 A~aska 0il & Gas Cons. Cmmission i i i KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC i 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 1. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THATTHE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WFI I RORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, lNG., REQUESTS APPROVAL OF THIS DiVERTER SYSTEM AS A VARIANCE FROM 20AAC25J335(b) 1. 16' CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16-- 2000 PSI BALL VALVE. 4. 20' - 2000 PS! DRILMNG SPOOL WITH ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINF- THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTEFL RECEIVE MAY - 4 ]995 ~il,& Gas Cons. Commission ~nchore, ~' 7 6 5 3 2 i 13 5/8" 50U0 PSI BOP STACK ~CCUM ULATOR CAPACITY TEST CHECK AND FlU.ACCUMULATOR RESERVOIR TO PROPER LEVEL ~ HYDRAUUC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI VVITI-t 1500 PSI DOWNSTREAM OF THE REGULATOR. OI~SERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 46 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FlUE BOP STACK AND MANIFOLD WI'I'H WATER. 2. CHECK THAT ALL HOI. D'~ SCREWS ARE FULLY RETRACTT=D. PREDETERMINE DEPTH THAT~ PLUG WILL SEAT AND SEAT IN WEI.LHEAD. RUN IN LOCK'DOWN SCREtNS IN HEAD. 3. CLOSE ~ PREVENTER ~ CHOKES AND BYPASS VALVES ON THE MAINFOLD. AU. OTHERS OPEN. 4. TES'F ALL COMPONENTS TO 250 PSI AND HOI.D FOR 3 MINUTES. ~ PRESSURE TO ~ PSl AND HOlD FOR 3 MINUTES. 5. ~ ~ PREVENTOR AND MANUAL KIH AND CHOKE MNE VNJ~;S. & Ct.OSE ~ PIPE ~ AND HCR VALVES ON KILLAND CHOK~ ~ CONTI~KIE TEST1NQ ALI. VALVES, I.JNE~ ~ ~ ~ A 250 PSI LOW AND ~_'~'~L~__ PSI HIGI-~ TEST AS IN 81'EP 4. DO NOT PRESSURE TEST 9. OPEN PIPE RAMS. BACKOFF R~ JT AND PULL OUT OF HOI.E. Cl. OS~ B~ RAM~ AND TEST TO ~_'F~__ PSl FOR $ MINUTES. 10. OPEN BLIND RAMS AND ~ 1'EST PLUG. MAKE SURE MANII=EX.D AND I. JNES ARE FUM. OF AFICT1C DIESEL ANO ALL VALVES ARE SET IN THE 11. TEST STA,NDPIPE VALVE~ TO 3lX)0 PS1 FOR ,.1 MINUTES.. 12. TEST KELLY COC~B ~ INSIDE BOP TO 3IXI0 PSI WITH KOC~ PUMP. 13. RECORD TEb"F IIk~.ORMATICN ON B[.QWEX. IT PREVENTER TEST FORM. SIGN ~ SEND TO DRII.JJNQ SUPERVISOR. 14. PERFE)FIM CClMPt.ETE BOPE TESTONCE A WEEK AND FUN~y 5. 1~6~' - 51X10 PSI DFiI.Q SPOOL W/ ~ I~'. S0lX} PS! DOUBLE RAM WI PIPE RAM8 ON 'FOP, BUND RAMS ON BTM 7. A~CO A£~.~A l~ltJ 1' Drillin9 Wellhead Detail DS 2A-18 '"" CT Injector He~d '--"'--- Slurring BOx (Pa¢~.-Ofl), lO,000 psi Wori<ing Pressure Methanol o~, ~" w~ [' ' t 4-111~"!D CTBOP $1a~ =~. ~ Flanged Fire Re,stem Kelly H~se To Du~ ChokeM~i~oid Flsnge / / M~ual VaNe HCR Blind Rams or Corr~in~tion C,III~ ~' CombinaZlon Slip ram~ I~ipa rnm.~ Drilling spoel 7-1/16", 5M by 4~1t16", Annular BOP !Hydrit),7-1/16~' ID 5,000 psi working pressure Alignment Guide Ram TyCe Dual ~ale .----' Manual over Hydraulic 7-1/16"' ID with Pips/slip 7-1/16" ~M Frill Opening Manual Val~e Manual Valves (3-1/2' Vaive~) Tubing -, 1 ~ Alaska Oil & r3:~.s Cons, Fire Reil~lan[ Kelly Hose lo Flange V~lve on DS Hardline 10' from Tree Oasir~§ 9-5'8"x 7" Annulus jtz 4/27/95 2A-18 CTU Drilling Surface Setup Single Choke (2A-01 CTU Work Platform ~'-~ 2A-18 Dual Choke wi Bypass O 2A-22 Tank Manifold From SW Header To Production Header , I 5OO Tiger 5OO Tiger RECEIVED MAY - 4 1995 A!aska 0ii & Gas Cons~ Commission Anch0r~-, Casing Design / Cement Calculations 2A-18 20-Apr-95 Production tail: TMD: 6,328 ft Top of Target, TMD = 6,328 ft Want TOC 500' above top of target = 5,828 ft 5" casing tail top (100' above C sand) =1 6,328 ft 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 87 cf Length of cmt wanted in csg = 0 ft Internal csg volume = 0.2148 Cmt required in casing = 0 cf Total cmt = 87 cf Excess factor = 15% Cement volume required = 100 cf Yield for Class G cmt = 1.19 Cement volume required =1 80 sx! TENSION - Minimum Design Factors are: T{pb)=l.5 and T(1js)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =l 916000 lb 3,005 ft 40.00 lb/fi 120200.0 lb 22154.0 lb 98046.O lb 9.3] Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 979000 lb 3,005 ft 4O.OO Ib/ft 120200.0 lb 22154.O lb 98046.0 lb 10.0} Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 604000 lb 6,328 ft 26.00 Ib/ft 164528.0 lb 30748.3 lb 133779.7 lb 4.8] Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud _R ¢ IV D A!~ska Oil & Gas Con~. Oommission Anchor~, Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 667000 lb 6,328 ft 26.00 Ib/ft 164528.0 lb 30748.3 lb 133779.7 lb $.01 Casing Design / Cement Calculations 2A-18 20-Apr-95 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, C Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2A-18 (I) 3,0O5 ft 2,885 ft 6,328 ft 5,932 ft 2,339 ft 6,328 ft 5,975 ft 3700 psi j~.:~i~!~[~!~,:~:~!~i~,~i~!~:i~f!!~i~i~?~ For Casing Choices 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 2,885 ft {(13.5'0.052)-0.11}*'l'VDshoe =1 1,708 psiI Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 3,700.0 ppg 5,975 ft 150 psi 12.4 PPg l Design lead bottom 500 ft above the Top of West Sak = 1,839 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 626 cf Excess factor = 120% Cement volume required = 1,376 cf Yield for Permafrost Cmt = 1.94 Cement volume required =1 710 sx Surface tail: TMD shoe = 3,005 ft (surface TD - 500' above West Sak) * (Annulus area) = 365 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 399 cf Excess factor = 15% Cement volume required = 459 cf Yield for Class G cmt = 1.15 Cement volume required =! 400 sxJ RECEIVED MAY - 4 1995 A~aska OJJ & Gas Cons. Commission Anchor~, ,~ Casing Design / Cement Calculations 2A-18 20-Apr-95 Production tail: TMD = 6,328 ft Top of Target, TMD = 6,328 ft Want TOC 750' above top of target = 5,578 ft 5" casing tail top (100' above C sand) =1 6,328 ft 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 131 cf Length of cmt wanted in csg = 0 fi Internal csg volume = 0.2148 Cmt required in casing = 0 cf Total cmt = 131 cf Excess factor = 75% Cement volume required = 229 cf Yield for Class G cmt = 1.19 Cement volume required =1 190 sxI TENSION - Minimum Desiqn Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 916000 lb 3,005 ft 40.00 Ib/ft 120200.0 lb 22154.0 lb 98046.0 lb Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 979000 lb 3,005 ft 40.00 Ib/ft 120200.0 lb 22154.0 lb 98046.O lb 10.01 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 604000 lb 6,328 ft 26.00 Ib/ft 164528.0 lb 30748.3 lb 133779.7 lb 4.51 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud MAY "' 4 1995 Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Cons. Commission Anchor~, ~ 667000 lb 6,328 ft 26.00 Ib/ft 164528.0 lb 30748.3 lb 133779.7 lb 5.01 Casing Design / Cement Calculations 2A-18 BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =! COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 20-Apr-95 5750 psi 1707.9 psi 3.41 7240 psi 7322 psi 2745 psi 4577 psi 1.6J 3090 psi 0.644 Ib/ft 923 psi 3.3J 5410 psi 0.644 Ib/ft 3822 psi 1.4J MAY - 4 1995 0ii & Gas Cons. Commission Anchore, Casing Design / Cement Calculations 2A-18 25-Apr-95 Production Liner (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud TENSION - Minimum Design Factors are: T(pb)=1.5 and T(js)=l.8 Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production Liner (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 BURST - Minimum Design Factor = 1.1 Production Liner: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*'rVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Production iner 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 207000 lb 6,328 ft 9.20 lb/fi 58217.6 lb 10550.1 lb 47667.5 lb 4.31 207000 lb 6,328 ft 9.20 Ib/ft 58217.6 lb 10550.1 lb 47667.5 lb 4.31 6980 psi 7322 psi 2745 psi 4577 psi 1.5] 7400 psi 0.644 Ib/ft 3822 psi 1.9j RECEIVED MAY - 4 1995 Alaska Oil & Gas Cons. Commission Anchor~, --~ Casing Design/Cement Calculations 25-Apr-95 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burst 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 3 5.000 4.276 1 8 L-80 5.2746 sq. in. 376000 lb 422000 lb 4 3.500 2.992 9.2 L-80 2.5902 sq. in. 207000 lb 207000 lb Collapse Bumt 541.0 psi 7240 psi 4320 psi 4980 psi 10490 psi 10140 psi 7400 psi 6980 psi RECEIVED MAY - 4 1995 ai~ska Oil & Gas Cons. Commission Anchore, ~, May 3,1995 Chairman and Commissioners Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill Kuparuk Well 2A-18. Coiled Tubing Drillout. Gentlemen' Enclosed is the Permit to Drill for Kuparuk well 2A-18. This project represents ARCO's first effort at coiled tubing drilling in the Kuparuk River Unit. The well is designed to top-set the Kuparuk with 7" casing with Parker Rig 245. A coiled tubing unit (CTU) will then be moved onto the well and approximately 500' of the Kuparuk interval will be drilled under-balanced using sea water. The purpose of using the CTU for drilling the Kuparuk interval is to eliminate the need for drilling the higher pressured Kuparuk sands over-balanced with weighted drilling mud. The key elements being evaluated are whether or not the Kuparuk sands and adjacent shale intervals can be successfully drilled with sea-water in an under-balanced state and also to prove up the ability to successfully run and cement a liner after the CTU drillout. The top portion of the well is scheduled to be drilled in mid- May while the CTU operation is planned for June. By being able to drill the well under-balanced we can reduce, and perhaps on future wells totally eliminate, the need for reducing reservoir pressure prior to drilling. This will minimize or eliminate the lost and deferred production which occurs when reservoir pressures are dropped to accommodate drilling operations. Furthermore, it should also result in higher initial production rates from the new well since the producing bottom hole pressure will subsequently be higher. The well's productivity may also be improved in the process by eliminating the near wellbore formation damage caused by drilling over-balanced with drilling mud. Reservoir pressure in the offset injectors to the 2A-18 infill well will be measured over the next few weeks. If pressures are Iow enough to allow drilling the well without top-setting the Kuparuk with an intermediate casing string, the well will be drilled conventionally to its planned total depth and no CTU drillout will be undertaken on this well. If this should occur a Sundry notice will be submitted to document the change in well design. The CTU drillout would then be evaluated on another Kuparuk we II at a late r date. To ensure we have a safe operation for this Kuparuk test we will be relying heavily on our Prudhoe Bay experience. We will utilize both Contractor and ARCO personnel and equipment which have been at the forefront of coiled tubing drilling technology. If you have any questions about this operation, please call Denise Petrash at 263-4183, or Jim Zernell at 263-4107. ~liukpee Zrv~ts~Jfli0 r c.~~.- Kuparuk Drill Site Development MZ:jtz Attachments RECEIVED MA1' - 4 1995 Oil & Gas Cons. Commission Anchorage WELL PERMIT CHECKLIST COMPANY WELL NAME GEOL AREA UNITS PROGRAM: exp [] dev~ redrll [] serv [] ADMINISTRATION ENGINEERING 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... GEOLOGY 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf osg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic &Aqulp list adequate 25. BOPEs adequate .......... ~... ~.~.. 26. BOPE press rating adequate; test to~/~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2s gas probable ............ 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... .~ Y N 34. Contact name/phone for weekly progress reports . . .~/~ . Y N [exploratory only] GEOLOGY: ENGINEERING: CO~SSION: Commeuts/InstructJ 0 '% - A:~ORMS~cheklist rev 03/94 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. ALASKA COMPUTING CENTER SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2A-18 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA AP1 NUMBER : 50-103-20220-~ REFERENCE NO : 95326 LIS Tape Veri~ica%ion Lis%lng Schlumberger Alaska Computing Cen~er 11-0CT-1995 14:51 *,** REEL HEADER *~ SERVICE NAME : EDIT DATE : 95/10/11 ORIGIN : FLIC REEL NAME : 95326 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2A-18, API #50-103-20220-00 **-, TAPE HEADER **,* SERVICE NAME : EDIT DATE : 95/10/11 ORIGIN : FLIC TAPE NAME : 95326 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2A-~8, API #50-~03-20220-0~ TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2A-18 501032022000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES ~1-0¢T-95 BIT RUN ~ BIT RUN 2 BIT RUN 3 JOB NUMBER: 95326 LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: 13 TOWNSHIP: RANGE: BE FNL: FSL: 736 FEL: FWL: 227 ELEVATION(FT FROM MSL KELLY BUSHING: 135.00 DERRICK FLOOR: 135.0e GROUND LEVEL: 94.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 16.eoe 121.0 2ND STRING 9.625 3004.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-OCT-1995 14:5~ 3RD STRING PRODUCTION STRING REMARKS: THIS IS AN UNSHIFTED MWD GR. NO DEPTH SHIFTS WERE MADE AT ARCO'S REQUEST. THE GR AND ROP WERE INTERPOLATED TO FILL DATA GAPS. THE TAPE IS IN MODIFIED LDWG FORMAT AS PER D, SHAFER. PAGE: **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : DATE : MAX REC SIZE : ~24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: ~ EDITED MERGED MWD CLIPPED AND INTERPOLATED PLUS RAW CURVES; ONE BIT RUN. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH SLWD 6~94.0 300~.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) E~UIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE SLWD 1 3eel.e 6194.0 $ REMARKS: The curves presented are both realtime and interpoiated GR and ROP as per LDWG scope. All data obtained in one bit run. $ LIS FORMAT DATA LIS Tape Veri~icat|on List|ng Schlumberger A~aska Computing Center 11-0CT-1995 14:51 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 16 4 66 5 66 6 73 7 65 8 68 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 0~0 ~0 0 1 1 1 4 68 00000~000 GRRW MWD AAPI 00 0~0 ~0 0 1 1 1 4 68 000~00~000 GRIN MWD AAPI 00 0~ 00 0 1 1 1 4 68 000~000000 ROP MWD FPHR 00 ~0~ ~ 0 I 1 1 4 68 0~0000~000 ** DATA DEPT. 6194.000 GRRW.MWD DEPT. 6900.000 GRRW.MWD DEPT. 590e.eoo GRRW.MWD DEPT. 4000.000 GRRW.MWD DEPT. 3901.000 GRRW.MWD -999.250 GRIN.MWD 267.200. GRIN.MWD -999.250 GRIN.MWD 92.100 GRIN.MWD 51.400 GRIN.MWD -999.25~ ROP.MWD 267.200 ROP.MWD 169.10~ ROP.MWD 92.100 ROP.MWD 51.40~ ROP.MWD -999.250 242.700 448.390 365.590 223.490 END OF DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-OCT-1995 14:5~ PAGE: *,** FILE TRAILER ,*,* FILE NAME : EDIT .001 SERVICE : FLIC VERSION : eOlCei DATE : 95/10/ll MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : ORIGIN : FLIC TAPE NAME : 95326 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2A-~8, API #50-103-2~220-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : ORIGIN : FLIC REEL NAME ': 95326 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~ KUPARUK 2A-~$, AP1 #5~-~03-20220-00 ~ f o's°rago i 84:1 ,-,~.-'....',;~,-,,-. -~ o2'~. t7 YO.,l ~'": :,,..,cc: ~,. 3.':- 13,.22 ,',z.n ?..nt= ' "':'* -'4.':-:, 74._ 4'.::. ?'5 '--'A~..'"~ '-"'"< ,..u~._ ...,, .,,..,,41006.,.,? 9,30 i3,38. -.64,22 ,,-.4+~? 265.,80 "'"'"' '"' !6,77 '2 =o ":,~,'- ,i -:a ::c ..... =. ...,,~ ,:-..,~ ..,~ ..... ':, ....... 0 9o+2_ i194,76 ~';',0 ..... ' .......... -';'";......_,. -i00,:.-'.5 ;v,-,.-,,-'"" '"" 258,56 2,91 · ~-~. ,50 ,:,~,7' '"~= ":" ~2,=.'.'-' -'!'~5,0'9 i!9'.~76 253,96 :~,4'.;' ,..-,.,, .... .'-,:., o,.:.: 41,24 223.-'.;'4 -'-'~. ir' ~'~p.-...~ .... '", ...... ~'v ~c, .,~ r,z ":,.~,-',, .::,~ ........ ~,,.c..,9 '- -." .,.,.....,. . u/ "..::.-:,6 ., ,,,... -,:.~,.82 .-lZ7,ll &~*u:., ,-..z'¢ + ,.,,..,' J...%7.+ .i'. / _. . . ,~., ,a~z. .~.~.. ,A~ ,,"7,39 I¥5,98 -.'-:7.,M ~i'.~g,~.o .... 0,5> .... I'~'~,",3c' 94,2 ~':;0.:.~ ,-- ,z *"*' =" i65+79 ...., . , i .... ,- .... i00,52 *-,,o,.~ z~:,~7 -93.8.',i: -138,69 2.'~6,,.76 4,40 , A,.,.,, 9~,8 .,.,':~:,' ,.,' :: zo r.,'¥,/r. ~7~,nn. 91,9 '="'~" 257,02 20,22 ~'"" . z/r.,..,ol z/7,~o -~,/,~c, -a~o~,.:s ~v~,u,., ~3,!0 2,64 4 t': ~ ' ~ '~ .- ~.~..,~: o~,o~ ~,87 180,35' ~',~ ~' ~ c ' -,n~ =' 0,49 ~05,50 . 281+6 2422,03 438,50 22,68 180,~ -429~58 -!40,25 451,89 198,08 0,07 27~+20 ~.~ =68u,:.; 552,46 z4+v8 ' 561,79 =,.,=,., ~ c ...... 180,39 -'543,76 -14i,18 a~,,.,_ 0,8i ..... n " ,-E99 · A,'-~ -z4_, ~ C:'.3 =<6,~<, .~.w,.~ ,-,~. .... ~ .. ,....'--~ ... ~:' ~ .~0.z ..... '-. ~ . 3~,.~.-;~ 74~ .7 302'?,7! 7.r;-~ ,47 22,59' 17~,73 %93.33 ~:'" "" 706,92 19! ,25 .s,.-.,....- , ....... .,,, .,,~. . . . -.;~M -:,'."J. - ', ....-, -,7~ ~ R2~A,7~. 808+36 22,,B4 ""=' '>' -'~4 .'-": ..... ,~,-s:~,",,/, :, ~ .... ..', y..,~ -6C:0.~62 ...., ............. :'~i ,97 i8:5',5! 0,.37 37W,60 280,8 -=.,= ",a .._ -91J.45 - ~"' -'"~ ....... " o.,..~._,,,. :., 917,31 23,.24 '~85',14 I.~.,,.,. ~.'.~'~-~'? !88,,47 4.007,65 280..,0 3802,9L 202.,7,56 23,03 !82,59 -i020,15' -140,23 '-029,73 !87,82 0.,4:4 428Y,~:/ 2Bi,/' 4~,'-,2.;:,:,' ....... i~A,OA... .22,30 x47A,/\.q ~ "" '" ¢535" ~9:%q.'[4 23,05 -I'~¢:,.3,.~ '"~ "'7 !209~64 , ,~z ,-,: ,'-" ,_o; ,-_', .... ,,t'./ ....... 179,'72 ....... 4664 q'~ : ""~,~ 4~07,74 !282,09 23+64 ,',", ,-.7 .... 9 ...... '"" -l.c,,q.~..?n ·" · , ~',,'/,?, .c.'v'~...~:, -i*~.,,=..-. ........ !85,4Y 0,52 48~.~,~" !,'.:19~:~ 456!,9;; 13~,05 :.23 *" ...... +.'/ ~....-' -' ="" :-'TA - 4~'~l,;;.~t !4&S,_,v ~:~,,:,.; a ., ,:,0 ,~ 28 . . ,:: ""'" "".q '" ..... -!38 ,., ,a:;,lO ~== ~ 5.,;,.., ,OZ 174,65 5695,03 ~ .... 53~,. """ ~ _.. , ~/~. ..... "' -i.=%.m:, . ..... z844+.;: la;,60 0,42 la~ +,' ~, ,o. !844+~. ~,Z6 178~~ 6i94,:~0 ~1~.~, 58~/-,I., 1875,02 22~25 !7~.';'% -~ATt ~'~ -,!~+u'/ [815,iZ !83,52 3446,77 4G07,65 92 J-" :t175 '..'0,6 ; ooo~-:.v' :~,2 v,~ i3,~ 25./+7z -4.72 27,43 i1,87 234+45 -20,31 i33,2 2805,7? .... it,iS i00,52 15,66 !52,57 iZ=+i8 17,$6 177+82 -!!7,N ;~-i~z ... ...... i?.2 ~a/:02 zu+,':" 17c:,58 -;47,~''''' · , 438,50 -,-, ~,,:- ~.ZC, .,0 : ~ U-~..:-, · 557-,46 5413,10 56'55~03 =,' .... .7/. Z79~7 j-7/~.,: .., 9- ..... r',~,~ :'~ :-,-i!?TY SELCd iS iJO4,:'~'N ,.,.: ., ..,-..- AZ!MUTt! 0+00 167+cx:, 21:5 263,20 2-58,69 D~ ') 04 0 ;. ~.,' ~,~, i:- i.575 ~ ~ " .... = ! 7oi .... '" "" - +i"~ : ~'=" + ,-"" -,2 :,,..6 -- 0+66 : 0:.7::$ 0,42 -i~= -'"'" ~,'5,12 !813,52 0,.o0 ARCO ALASKA, Inc. Pad 2A 18 slot #18 Kuparuk River Unit North Slope, Alaska SURVEY LISTING by Baker Hughes I NTEQ Your ref : PMSS <0-6791'> Our ref : svy4616 License : Date printed : 12-Dec-95 Date created : 16-May-95 Last revised : 12-Dec-95 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.315,w150 0 46.817 Slot location is n70 18 8.554,w150 0 40.198 Slot Grid coordinates are N 5960157.170, E 498621.416 Slot local coordinates are 736.00 N 227.00 E Reference North is True North ARCO ALASKA, Inc. Pad 2A,18 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 1 Your ref : PMSS <0-6791'> Last revised : 12-Dec-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 121.00 0.00 0.00 121.00 0.00 N 0.00 E 0.00 0.00 468.88 0.19 167.00 468.88 0.56 S 0.13 E 0.05 0.55 560.24 0.83 275.39 560.24 0.65 S 0.49 W 0.99 0.68 650.85 3.84 271.87 650.76 0.49 S 4.18 W 3.32 0.78 741.36 7.06 271.11 ?40.85 0.28 S 12.77 ~ 3.56 1.19 832.08 9.65 270.99 830.60 0.04 S 25.95 W 2.86 1.89 922.17 13.22 262.85 918.89 1.19 S 43.73 W 4.34 4.31 1012.59 13.38 257.72 1006.89 4.70 S 64.21 ~ 1.32 9.28 1102.80 12.59 246.66 1094.81 10.82 S 83.44 W 2.88 16.75 1194.78 11.87 234.45 1184.71 20.29 S 100.35 ~ 2.91 27.41 1287.50 12.53 223.94 1275.35 33.08 S 115.08 ~ 2.50 41.22 1381.07 12.06 210.60 1366.79 48.81 S 127.11 ~ 3.07 57.76 1476.22 13.18 195.98 1459.67 67.80 S 135.16 ~ 3.55 77.28 1570.39 15.66 182.59 1550.89 90.83 S 138.69 W 4.40 100.50 1663.16 17.86 177.82 1639.72 117.55 S 138.71 ~ 2.79 127.16 1755.08 20.22 179.58 1726.60 147.53 S 138.06 ~ 2.64 157.01 1941.87 21.50 180.85 1901.14 214.04 S 138.33 ~ 0.73 223.37 2223.81 22.87 180.32 2162.21 320.49 S 139.40 ~ 0.49 329.63 2505.60 22.68 180.55 2422.03 429.57 S 140.23 W 0.07 438.49 2788.20 24.98 180.39 2680.52 543.73 S 141.16 ~ 0.81 552.43 2926.40 22.94 179.37 2806.80 599.85 S 141.06 ~ 1.51 608.40 3168.14 22.59 176.73 3029.72 693.32 S 137.90 ~ 0.45 701.40 3446.77 22.84 179.31 3286.74 800.82 S 134.19 ~ 0.37 808.36 3727.60 23.14 182.14 3545.27 910.47 S 135.60 W 0.41 917.83 4007.65 23.03 182.59 3802.90 1020.18 S 140.13 W 0.07 1027.58 4289.37 22.30 182.45 4062.86 1128.63 S 144.90 ~ 0.26 1136.10 4476.63 23.05 179.92 4235.65 1200.79 S 146.37 ~ 0.66 1208.18 4664.04 23.64 177.97 4407.72 1275.03 S 144.99 ~ 0.52 1282.13 4853.81 23.17 178.14 4581.87 1350.37 S 142.43 W 0.25 1357.09 5130.28 23.20 177.21 4836.02 1459.12 S 138.01 ~ 0.13 1465.25 5413.10 23.02 174.65 5096.15 1569.82 S 130.14 ~ 0.36 1575.11 5695.03 22.94 175.69 5355.70 1679.50 S 120.87 ~ 0.15 1683.84 5974.76 22.78 179.54 5613.48 1788.02 $ 116.34 ~ 0.54 1791.76 6112.41 22.26 178.95 5740.63 1840.73 S 115.65 W 0.41 1844.29 6670.00 16.00 174.50 6267.20 2023.01S 106.34 ~ 1.15 2025.44 Magnetic Single Shot 6791.00 16.00 174.50 6383.51 2056.21S 103.14 ~ 0.00 2058.32 Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from slot #18 and TVD from wellhead (135.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 184.10 degrees. Declination is 0.00 degrees, Convergence is -0.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA, Inc. SURVEY LISTING Page 2 Pad 2A,18 Your ref : PMSS <0-6791'> Kuparuk River Unit,North Slope, Alaska Last revised : 12-Dec-95 Comments in wellpath MD TVD Rectangular Coords. Comment 6670.00 6267.20 2023.01S 106.34 W Magnetic Single Shot 6791.00 6383.51 2056.21S 103.14 W Projected Data - NO SURVEY Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 2A-18(I) Rvsd 15-Mar not specified 5975.00 1941.00S 139.00W lO-Feb-93 All data is in feet unless otherwise stated Coordinates from slot #18 and TVD from wellhead (135.00 Ft above mean sea level). Bottom hole distance is 2058.79 on azimuth 182.87 degrees from wellhead. Vertical section is from wellhead on azimuth 184.10 degrees. Declination is 0.00 degrees, Convergence is -0.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ