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Home My WebLink About190-162KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϭͲ&ĞďͲϮϲ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶǇ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶǇƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt>>ED W/η ^Zs/KZZη &/>ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^dηϭ ϭͲϮϬ ϱϬͲϬϮϵͲϮϮϭϭϮͲϬϬ ϵϭϬϱϵϳϯϰϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮͲ&ĞďͲϮϲ Ϭ ϭϮ ϭͲϭϰϱ ϱϬͲϬϮϵͲϮϯϱϮϲͲϬϬ ϵϭϬϱϵϲϳϵϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϳͲ&ĞďͲϮϲ Ϭ ϭϯ ϭ&ͲϬϵ ϱϬͲϬϮϵͲϮϬϵϴϯͲϬϬ ϵϭϬϱϯϵϯϭϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϲͲ:ĂŶͲϮϲ Ϭ ϭϰ ϭ,ͲϭϬϭ ϱϬͲϬϮϵͲϮϯϱϴϱͲϬϬ ϵϭϬϱϯϵϰϯϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϭϴͲ:ĂŶͲϮϲ Ϭ ϭϱ ϮͲϭϰ ϱϬͲϭϬϯͲϮϬϬϰϬͲϬϬ ϵϭϬϱϵϳϯϰϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϳͲ&ĞďͲϮϲ Ϭ ϭϲ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϯͲ:ĂŶͲϮϲ Ϭ ϭϳ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϰͲ:ĂŶͲϮϲ Ϭ ϭϴ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ dƵďŝŶŐWƵŶĐŚZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϱͲ:ĂŶͲϮϲ Ϭ ϭϵϭϬW>^<EKt>'Z/Wdz^/'E/E'EZdhZE/E'KWzK&d,dZE^D/dd>>ddZdKd,ddEd/KEK&͗&ĂŶŶǇ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗190-162214-138183-104217-138185-145223-104T41362T41363T41364T41365T41366T41367T41367T41367190-162214 138ϭϭͲϮϬϱϬͲϬϮϵͲϮϮϭϭϮͲϬϬ ϵϭϬϱϵϳϯϰϯ<ƵƉĂƌƵŬZŝǀĞƌWĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϮͲ&ĞďͲϮϲϬϭGavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.11 13:44:36 -09'00' Originated: Delivered to:7-Mar-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-20 50-029-22112-00 909816971 Kuparuk River Packer Setting Record Field- Final 16-Feb-25 0 1 2 1A-24 50-029-22984-00 909816969 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-25 0 1 3 1A-24 50-029-22984-00 909816969 Kuparuk River Plug Setting Record Field- Final 15-Feb-25 0 1 4 1C-156 50-029-23750-00 909809782 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 1 5 1E-11 50-029-20787-00 909890720 Kuparuk River Leak Detect Log Field- Final 1-Mar-25 0 1 6 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 1-Mar-25 0 1 7 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 28-Feb-25 0 1 8 1E-22 50-029-20884-00 909890664 Kuparuk River Leak Detect Log Field- Final 27-Feb-25 0 1 9 1Q-04 50-029-21250-00 909678506 Kuparuk River SBHP Record Field- Final 9-Nov-24 0 1 10 2B-11 50-029-21089-00 909890473 Kuparuk River Packer Setting Record Field- Final 21-Feb-25 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T40190 T40191 T40191 T40192 T40193 T40193 T40193 T40194 T40195 T40196 190-162 200-181 223-023 182-051 182-214 184-234 184-035 3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.07 10:25:17 -09'00' 190-162 1A-20 50-029-22112-00 909816971 Kuparuk River Packer Setting Record Field- Final 16-Feb-25 0 1 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing 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 9034'feet 8665'feet true vertical 6722' feet None feet Effective Depth measured 8665'feet 6903', 6932', 8265', 8459', 8624' feet true vertical 6471'feet 5237', 5257', 6197', 6331', 6443' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4'x3-1/2"x2-7/8" J-55 8678' MD 6480' TVD Packers and SSSV (type, measured and true vertical depth) 6903' MD 6932' MD 8265' MD 8459' MD 8624' MD 1798' MD 5237' TVD 5257' TVD 6197' TVD 6331' TVD 6443' TVD 1706' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 4960' 3901' Burst Collapse Production Liner 2319' 6667' Casing 2084' 6705' 2343' 9010' 4925' 116'Conductor Surface Production Tie-In 16" 9-5/8" 80' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-162 50-029-22112-00-00 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: ADL0025648 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1A-20 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 1207 Size 116' 3543 1240558 116 2154191 185 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 980 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Shelby Sumrall Shelby.Sumrall@conocophillips.com (907) 265-6678Staff Well Integrity Engineer 8344-8383', 8384-8407', 8426-8434', 8480-8506', 8616-8618', 8747-8755', 8770-8810' 6252-6279', 6279-6295', 6308-6314', 6345-6363', 6438-6439', 6526-6532', 6542-6569' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker HB Rtvbl Packer Packer: Baker HB Rtvbl Packer Packer: TIW SS "BB" Perm Packer SSSV: Camco TRDP-4A SSSV (locked out) By Grace Christianson at 2:15 pm, Mar 12, 2025 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall , E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2025.03.12 10:13:48-08'00' Foxit PDF Editor Version: 13.1.6 Shelby Sumrall 4/8/25 JJL DSR-3/24/25 RBDMS JSB 031325 DTTMSTART JOBTYP SUMMARYOPS 1/22/2025 REPAIR WELL LOG TBG FROM 8376' RKB TO SURFACE W/ 24-ARM CALIPER. SET 2.72" P2P RBP {CPP 35373, CPEQ35032} (M.E. @ 8230' RKB) . ACHIEVED PASSING CMIT TO 2500 PSI. JOB IN PROGRESS. 1/23/2025 REPAIR WELL RAN LDL & IDENTIFIED LEAK @ 6914' RKB (MIDDLE OF SECOND JOINT OF TBG ABOVE ST# 6 GLM @ 6969' RKB). U-TUBED WELL FOR 1 HOUR. JOB IS COMPLETE & READY FOR PLAN FORWARD. 2/16/2025 REPAIR WELL EQUALIZED & PULLED RBP @ 8228' RKB. BRUSH n' FLUSH TBG W/ 2.74" GAUGE RING IN THE PATCH SETTING AREA FROM 6800' RBK TO 7000' RKB. DRIFTED TBG W/ DMY PATCH DRIFT TO 7000' RKB. SET LWR 3.5" P2P PKR {CPP35370} @ 6931.5' RKB (M.E. @ 6934' RKB). SET TTS TEST TOOL IN THE LWR PKR & ATTEMPTED A CMIT TO 2500 PSI (HAD TO SUSPEND TESTING DUE TO OA TRACKING W/ THE IA). JOB IN PROGRESS. 2/17/2025 REPAIR WELL STUNG INTO LWR PKR @ 6931.5' RKB W/ TTS TEST TOOL WHILE DHD WORKED ON OA. OBTAINED A PASSING CMIT TO 2500 PSI. SET UPPER 3.5" P2P PKR {CPP35319} + SPACER PIPE + ANCHOR LATCH {CPAL35135} @ 6900.5' RKB (M.E. @ 6903' RKB). JOB IN PROGRESS. 2/17/2025 REPAIR WELL (AC EVAL) RE ENERGIZE IC PO (COMPLETE), IC POT (PASSED), IC PPPOT (PASSED). 2/18/2025 REPAIR WELL SET TTS TEST TOOL IN UPPER PKR @ 6900' RKB. OBTAINED A PASSING MITT TO 2500 PSI & CMIT T x IA TO 2500 PSI. PULLED DV FROM ST# 3 @ 5094' RKB & REPLACED W/ 5/16" OV. PULLED DV FROM ST#1 @ 3076' RKB & REPLACED W/ GLV. ACHIEVED A PASSING MITT TO 2500 PSI. PULLED TTS TEST TOOL @ 6900' RKB. JOB COMPLETE. 1A-20 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST 146' SAND ON PLUG) 8,519.0 1A-20 11/17/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added upper patch packer assembly 1A-20 2/17/2025 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: 7" TIEBACK RKB TO LOCKDOWN SCREWS; TUBING RKB TO TBG HEAD FLANGE 7/26/1991 osborl 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 36.0 116.0 116.0 65.00 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,960.5 3,901.1 36.00 J-55 BTC PRODUCTION TIE-IN 7 6.28 23.5 2,343.0 2,084.4 26.00 J-66 BTC-ABMOD PRODUCTION Post WO 7 6.28 2,343.0 9,010.3 6,705.4 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.3 Set Depth … 8,677.9 Set Depth … 6,479.6 String Max No… 4 Tubing Description TUBING 4"x3.5"x2.875 Wt (lb/ft) 11.00 Grade J-55 Top Connection DSS-HTC ID (in) 3.48 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) 31.3 31.3 0.05 HANGER 13.000 McEVOY GEN IV TUBING HANGER 4.000 1,797.6 1,705.7 37.17 SAFETY VLV 6.100 CAMCO 4" TRDP-4A SSSV (LOCKED OUT 7/15/05) 3.312 3,075.8 2,586.2 46.15 GAS LIFT 5.898 CAMCO KBMG 3.395 4,192.3 3,354.3 44.21 XO Reducing 4.000 CROSSOVER 4" x 3.5" 3.500 4,256.2 3,400.2 44.02 GAS LIFT 5.312 MACCO SPM-1A 2.867 5,094.3 3,995.5 45.28 GAS LIFT 5.312 MACCO SPM-1A 2.867 5,813.8 4,497.7 46.22 GAS LIFT 5.312 MACCO SPM-1A 2.867 6,375.5 4,882.2 47.41 GAS LIFT 5.312 MACCO SPM-1A 2.867 6,969.1 5,282.9 46.34 GAS LIFT 5.312 MACCO SPM-1A 2.867 7,410.4 5,591.1 45.78 GAS LIFT 5.312 MACCO SPM-1A 2.867 8,199.1 6,151.0 45.33 GAS LIFT 5.750 CAMCO MMG-2 2.867 8,250.9 6,187.3 45.73 PBR 5.125 BAKER PBR 10 STROKE 3.000 8,264.6 6,196.9 45.84 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.870 8,307.9 6,226.9 46.15 PRODUCTION 5.960 MERLA TGPDC 2.875 8,322.4 6,237.0 46.23 BLAST RINGS 3.500 BLAST RINGS (4) 2.992 8,448.4 6,323.6 46.85 Sliding Sleeve - Closed 5.750 CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE (CLOSED 12/20/2017) 2.812 8,458.9 6,330.8 46.90 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 63K # PULL OR ROTATION RELEASE 2.870 8,556.5 6,397.3 47.26 PRODUCTION 5.960 MERLA TGPDC 2.875 8,608.0 6,432.2 47.38 Sliding Sleeve - Open 5.750 CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE (OPEN 12/20/2017) 2.750 8,622.4 6,441.9 47.37 SEAL ASSY 4.750 TIW LOCATOR/SEAL ASSEMBLY w/MULE SHOE ON BTM 3.000 8,624.3 6,443.2 47.36 PACKER 5.850 TIW SS 'BB' PERMANENT PACKER 4.000 8,628.1 6,445.7 47.36 SBE 5.850 TIW SEAL BORE EXTENSION - ** CROSSOVER TO 2 7/8" TBG** 4.000 8,665.5 6,471.1 47.32 NIPPLE 3.668 CAMCO 'D' NIPPLE, 2.25" PACKING BORE NO GO PROFILE ***below CTD liner*** 2.250 8,677.2 6,479.0 47.31 SOS 2.875 ELMD TTL @ 8674' during PPROF on 6/1/2008 / BAKER SHEAR OUT SUB 2.441 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) 6,902.6 5,237.1 46.72 PACKER - PATCH - UPR 2.72 PIIP UPPER PATCH PACKER, MOE = 6903' RKB, OAL = 4.1'. UPPER PACKER + SPACER PIPE OAL = 32.1' TTS PIIP CPP3 5319 2/17/2025 1.625 6,906.7 5,239.9 46.69 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH, OAL = 31' 2/17/2025 1.600 6,914.0 5,245.0 46.65 LEAK - TUBING TUBING LEAK 1/23/2025 2.992 6,931.6 5,257.0 46.55 PACKER - PATCH - LWR 2.72" PIIP LOWER PATCH PACHER, MOE = 6934', OAL = 4.01' TTS PIIP CPP3 5370 2/16/2025 1.625 8,269.0 6,199.9 45.87 TUBING LEAK TUBING LEAK - LEAK IN UPPER C-SAND SELECTIVE 12/22/2017 8,579.0 6,412.5 47.32 CTD 2 3/8" Liner Top CTD 2 3/8" L1-02 Liner Top, Ran back up into 3.5" TBG. 1/31/2018 1.995 1A-20, 3/12/2025 9:48:48 AM Vertical schematic (actual) PRODUCTION Post WO; 2,343.0-9,010.3 IPERF; 8,770.0-8,810.0 IPERF; 8,747.0-8,755.0 PLUG; 8,665.0 PACKER; 8,624.3 APERF; 8,616.0-8,618.0 Cement Squeeze; 8,605.0 ftKB Cement Retainer; 8,604.0 WHIPSTOCK - MONOBORE; 8,587.0 CTD 2 3/8" Liner Top; 8,579.0 L1-02 LINER; 8,579.4-10,980.0 PRODUCTION; 8,556.5 IPERF; 8,480.0-8,506.0 PACKER; 8,458.9 IPERF; 8,426.0-8,434.0 IPERF; 8,384.0-8,407.0 IPERF; 8,344.0-8,383.0 PRODUCTION; 8,307.9 TUBING LEAK; 8,269.0 PACKER; 8,264.6 GAS LIFT; 8,199.1 GAS LIFT; 7,410.4 GAS LIFT; 6,969.1 PACKER - PATCH - LWR; 6,931.5 ANCHOR LATCH ON SPACER PIPE; 6,906.7 LEAK - TUBING; 6,914.0 PACKER - PATCH - UPR; 6,902.5 GAS LIFT; 6,375.5 GAS LIFT; 5,813.8 GAS LIFT; 5,094.3 SURFACE; 35.0-4,960.5 GAS LIFT; 4,256.2 GAS LIFT; 3,075.8 PRODUCTION TIE-IN; 23.5- 2,343.0 SAFETY VLV; 1,797.6 CONDUCTOR; 36.0-116.0 KUP PROD KB-Grd (ft) 35.01 RR Date 12/21/199 0 Other Elev… 1A-20 ... TD Act Btm (ftKB) 9,034.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211200 Wellbore Status PROD Max Angle & MD Incl (°) 48.50 MD (ftKB) 2,100.00 WELLNAME WELLBORE1A-20 Annotation Last WO: End Date 7/26/1991 H2S (ppm) 80 Date 8/22/2017 Comment SSSV: LOCKED OUT 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) 8,587.0 6,417.9 47.35 WHIPSTOCK - MONOBORE Window Whipstock for CTD 1/6/2018 8,604.0 6,429.5 47.39 Cement Retainer Weatherford FH One-Trip Cement Retainer 12/26/2017 8,665.0 6,470.8 47.32 PLUG CA-2 PLUG (OAL 26'') (A-SANDS ISOLATED) 4/17/2017 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) 3,075.8 2,586.2 46.15 1 GAS LIFT GLV BK 1 1,165.0 2/18/2025 0.188 4,256.2 3,400.2 44.02 2 GAS LIFT DMY BK 1 0.0 12/24/2024 2:00 0.000 5,094.3 3,995.5 45.28 3 GAS LIFT OV BK 1 0.0 2/18/2025 0.313 5,813.8 4,497.7 46.22 4 GAS LIFT DMY BK 1 0.0 12/27/2024 12:30 0.000 6,375.5 4,882.2 47.41 5 GAS LIFT DMY BK 1 0.0 12/28/2024 8:00 0.000 6,969.1 5,282.9 46.34 6 GAS LIFT DMY BK 1 0.0 12/18/2017 12:00 0.000 7,410.4 5,591.1 45.78 7 GAS LIFT DMY BK 1 0.0 7/20/2016 4:00 0.000 8,199.1 6,151.0 45.33 8 GAS LIFT DMY RK 1 1/2 0.0 7/22/2016 11:00 0.000 8,307.9 6,226.9 46.15 9 PROD DMY RK 1 1/2 0.0 2/14/1992 10:30 Clsd 0.000 8,556.5 6,397.3 47.26 1 0 PROD DMY RK 1 1/2 0.0 2/14/1992 9:00 Clsd 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,344.0 8,383.0 6,251.9 6,278.8 C-4, 1A-20 8/3/1991 10.0 IPERF HLS 4.5" CG 8,384.0 8,407.0 6,279.5 6,295.3 C-3, 1A-20 8/3/1991 6.0 IPERF HLS 4.5" CG 8,426.0 8,434.0 6,308.3 6,313.8 C-2, 1A-20 8/3/1991 5.0 IPERF HLS 4.5" CG 8,480.0 8,506.0 6,345.2 6,362.9 C-1, 1A-20 8/3/1991 10.0 IPERF HLS 4.5" CG 8,616.0 8,618.0 6,437.6 6,438.9 A-4, 1A-20 12/22/2017 4.0 APERF 2' x 1.56" TBG PUNCH (4 SHOTS PER FT / 0° PHASING) 8,747.0 8,755.0 6,526.4 6,531.8 A-5, 1A-20 8/3/1991 4.0 IPERF HLS 4.5" CG 8,770.0 8,810.0 6,542.0 6,569.0 A-4, 1A-20 8/3/1991 4.0 IPERF HLS 4.5" CG Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,480.0 8,618.0 6,345.2 6,438.9 Cement Squeeze 12/26/2017 1A-20, 3/12/2025 9:48:49 AM Vertical schematic (actual) PRODUCTION Post WO; 2,343.0-9,010.3 IPERF; 8,770.0-8,810.0 IPERF; 8,747.0-8,755.0 PLUG; 8,665.0 PACKER; 8,624.3 APERF; 8,616.0-8,618.0 Cement Squeeze; 8,605.0 ftKB Cement Retainer; 8,604.0 WHIPSTOCK - MONOBORE; 8,587.0 CTD 2 3/8" Liner Top; 8,579.0 L1-02 LINER; 8,579.4-10,980.0 PRODUCTION; 8,556.5 IPERF; 8,480.0-8,506.0 PACKER; 8,458.9 IPERF; 8,426.0-8,434.0 IPERF; 8,384.0-8,407.0 IPERF; 8,344.0-8,383.0 PRODUCTION; 8,307.9 TUBING LEAK; 8,269.0 PACKER; 8,264.6 GAS LIFT; 8,199.1 GAS LIFT; 7,410.4 GAS LIFT; 6,969.1 PACKER - PATCH - LWR; 6,931.5 ANCHOR LATCH ON SPACER PIPE; 6,906.7 LEAK - TUBING; 6,914.0 PACKER - PATCH - UPR; 6,902.5 GAS LIFT; 6,375.5 GAS LIFT; 5,813.8 GAS LIFT; 5,094.3 SURFACE; 35.0-4,960.5 GAS LIFT; 4,256.2 GAS LIFT; 3,075.8 PRODUCTION TIE-IN; 23.5- 2,343.0 SAFETY VLV; 1,797.6 CONDUCTOR; 36.0-116.0 KUP PROD 1A-20 ... WELLNAME WELLBORE1A-20 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1A-20L1 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: MULTILAT 1A-20L1 2/20/2018 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE:jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 LINER 2 3/8 1.99 9,477.4 11,575.0 6,258.0 4.70 L-80 ST-L 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) 9,477.4 6,290.3 102.8 7 Aluminum Billet + anchor 2.630 OH Anchor & Aluminum Billet BOT Billet 1.920 9,529.5 6,279.1 101.6 1 Shorty Deployment Sleeve Shorty Deployment Sleeve 10,530.0 6,272.3 91.31 Bull Nose (Ported) Bull Nose (Ported) 10,530.4 6,272.3 91.30 Shorty Deployment Sleeve (with hex profile) Shorty Deployment Sleeve (with hex profile) 11,574.6 6,258.0 89.15 Bull Nose (Ported) Bull Nose (Ported) 1A-20L1, 3/12/2025 9:48:49 AM Vertical schematic (actual) L1 LINER; 9,477.4-11,575.0 L1-01LINER; 9,310.2-11,750.0 Cement Squeeze; 8,605.0 ftKB PRODUCTION Post WO; 2,343.0-9,010.3 WHIPSTOCK - MONOBORE; 8,587.0 CTD 2 3/8" Liner Top; 8,579.0 L1-02 LINER; 8,579.4-10,980.0 PRODUCTION; 8,556.5 IPERF; 8,480.0-8,506.0 PACKER; 8,458.9 IPERF; 8,426.0-8,434.0 IPERF; 8,384.0-8,407.0 IPERF; 8,344.0-8,383.0 PRODUCTION; 8,307.9 TUBING LEAK; 8,269.0 PACKER; 8,264.6 GAS LIFT; 8,199.1 GAS LIFT; 7,410.4 GAS LIFT; 6,969.1 PACKER - PATCH - LWR; 6,931.5 ANCHOR LATCH ON SPACER PIPE; 6,906.7 LEAK - TUBING; 6,914.0 PACKER - PATCH - UPR; 6,902.5 GAS LIFT; 6,375.5 GAS LIFT; 5,813.8 GAS LIFT; 5,094.3 SURFACE; 35.0-4,960.5 GAS LIFT; 4,256.2 GAS LIFT; 3,075.8 PRODUCTION TIE-IN; 23.5- 2,343.0 SAFETY VLV; 1,797.6 CONDUCTOR; 36.0-116.0 KUP PROD KB-Grd (ft) 35.01 RR Date 12/21/199 0 Other Elev… 1A-20L1 ... TD Act Btm (ftKB) 12,028.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211260 Wellbore Status PROD Max Angle & MD Incl (°) 104.12 MD (ftKB) 8,755.74 WELLNAME WELLBORE1A-20 Annotation LAST WO: End DateH2S (ppm) 80 Date 8/22/2017 Comment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1A-20L1-01 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: MULTILAT 1A-20L1- 01 2/20/2018 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE:jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01LINER 2 3/8 1.99 9,310.2 11,750.0 6,282.6 4.60 L-80 STL 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) 9,310.2 6,327.2 102.5 8 Aluminum Billet 2.630 OH Anchor & Aluminum Billet BOT Billet 1.920 9,504.7 6,285.2 98.40 Deployment Sleeve 2.375 Shorty Deployment Sleeve Baker 1.000 10,955.2 6,291.0 86.77 Deployment Sleeve 2.375 Shorty Deployment Sleeve Baker 1.000 1A-20L1-01, 3/12/2025 9:48:50 AM Vertical schematic (actual) L1-01LINER; 9,310.2-11,750.0 L1 LINER; 9,477.4-11,575.0 Cement Squeeze; 8,605.0 ftKB PRODUCTION Post WO; 2,343.0-9,010.3 WHIPSTOCK - MONOBORE; 8,587.0 CTD 2 3/8" Liner Top; 8,579.0 L1-02 LINER; 8,579.4-10,980.0 PRODUCTION; 8,556.5 IPERF; 8,480.0-8,506.0 PACKER; 8,458.9 IPERF; 8,426.0-8,434.0 IPERF; 8,384.0-8,407.0 IPERF; 8,344.0-8,383.0 PRODUCTION; 8,307.9 TUBING LEAK; 8,269.0 PACKER; 8,264.6 GAS LIFT; 8,199.1 GAS LIFT; 7,410.4 GAS LIFT; 6,969.1 PACKER - PATCH - LWR; 6,931.5 ANCHOR LATCH ON SPACER PIPE; 6,906.7 LEAK - TUBING; 6,914.0 PACKER - PATCH - UPR; 6,902.5 GAS LIFT; 6,375.5 GAS LIFT; 5,813.8 GAS LIFT; 5,094.3 SURFACE; 35.0-4,960.5 GAS LIFT; 4,256.2 GAS LIFT; 3,075.8 PRODUCTION TIE-IN; 23.5- 2,343.0 SAFETY VLV; 1,797.6 CONDUCTOR; 36.0-116.0 KUP PROD KB-Grd (ft) 35.01 RR Date 12/21/199 0 Other Elev… 1A-20L1-01 ... TD Act Btm (ftKB) 12,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211261 Wellbore Status PROD Max Angle & MD Incl (°) 104.12 MD (ftKB) 8,755.74 WELLNAME WELLBORE1A-20 Annotation LAST WO: End DateH2S (ppm) 80 Date 8/22/2017 Comment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1A-20L1-02 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: MULTILAT 1A-20L1- 02 2/20/2018 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE:jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 LINER 2 3/8 1.99 8,579.4 10,980.0 6,364.9 4.60 L-80 STL 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) 8,579.4 6,412.8 47.32 Deployment Sleeve 2.630 Shorty Deployment Sleeve Baker Aluminum 1.920 9,971.3 6,353.7 89.95 Deployment Sleeve 2.375 Shorty Deployment Sleeve Baker Aluminum 1.920 1A-20L1-02, 3/12/2025 9:48:50 AM Vertical schematic (actual) L1-02 LINER; 8,579.4-10,980.0 Cement Squeeze; 8,605.0 ftKB PRODUCTION Post WO; 2,343.0-9,010.3 CTD 2 3/8" Liner Top; 8,579.0 PRODUCTION; 8,556.5 IPERF; 8,480.0-8,506.0 PACKER; 8,458.9 IPERF; 8,426.0-8,434.0 IPERF; 8,384.0-8,407.0 IPERF; 8,344.0-8,383.0 PRODUCTION; 8,307.9 TUBING LEAK; 8,269.0 PACKER; 8,264.6 GAS LIFT; 8,199.1 GAS LIFT; 7,410.4 GAS LIFT; 6,969.1 PACKER - PATCH - LWR; 6,931.5 ANCHOR LATCH ON SPACER PIPE; 6,906.7 LEAK - TUBING; 6,914.0 PACKER - PATCH - UPR; 6,902.5 GAS LIFT; 6,375.5 GAS LIFT; 5,813.8 GAS LIFT; 5,094.3 SURFACE; 35.0-4,960.5 GAS LIFT; 4,256.2 GAS LIFT; 3,075.8 PRODUCTION TIE-IN; 23.5- 2,343.0 SAFETY VLV; 1,797.6 CONDUCTOR; 36.0-116.0 KUP PROD KB-Grd (ft) 35.01 RR Date 12/21/199 0 Other Elev… 1A-20L1-02 ... TD Act Btm (ftKB) 10,980.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211262 Wellbore Status PROD Max Angle & MD Incl (°) 104.12 MD (ftKB) 8,755.74 WELLNAME WELLBORE1A-20 Annotation LAST WO: End DateH2S (ppm) 80 Date 8/22/2017 Comment Originated: Delivered to:19-Feb-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 TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-20 50-029-22112-00 909816966 Kuparuk River Leak Detect Log Field- Final 23-Jan-25 0 12 1A-20 50-029-22112-00 909816966 Kuparuk River Multi Finger Caliper Field & Processed 22-Jan-25 0 13 1A-20 50-029-22112-00 909816966 Kuparuk River Plug Setting Record Field- Final 22-Jan-25 0 14 1D-38 50-029-22961-00 909594223 Kuparuk River Multi Finger Caliper Field & Processed 16-Jan-25 0 15 1E-17 50-029-20793-00 909817737 Kuparuk River Plug Setting Record Field- Final 4-Feb-25 0 16 1E-22 50-029-20884-00 909817740 Kuparuk River Multi Finger Caliper Field & Processed 2-Feb-25 0 17 1E-22 50-029-20884-00 909817740 Kuparuk River Plug Setting Record Field- Final 3-Feb-25 0 18 1H-01 50-029-22330-00 909817089 Kuparuk River Multi Finger Caliper Field & Processed 7-Feb-25 0 19 1H-01 50-029-22330-00 909817089 Kuparuk River Plug Setting Record Field- Final 7-Feb-25 0 110 1H-110 50-029-23601-00 909817451 Kuparuk River Plug Setting Record Field- Final 24-Jan-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40111T40111T40111T40112T40113T40114T40114T40115T40115T40116190-162200-077182-116182-214193-006218-0312/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.02.20 11:39:57 -09'00'190-16211A-2050-029-22112-00 909816966Kuparuk RiverLeakDetect LogField- Final23-Jan-250121A-2050-029-22112-00 909816966Kuparuk RiverMulti Finger CaliperField & Processed22-Jan-250131A-2050-029-22112-00 909816966Kuparuk RiverPlug Setting RecordField- Final22-Jan-2501T40111T40111T40111 i • STATE OF ALASKA RECEIVED IDASKA OIL AND GAS CONSERVATION COISSION REPORT OF SUNDRY WELL OPERATIONS APR 0 q 2018 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing El A*• - • 1 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Chd'ng2 p •l'- ro rani ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: I ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 190-162 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-22112-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU A-20 ADL 25648 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,034 feet Plugs measured 8604 feet true vertical 6,722 feet Junk measured NONE feet Effective Depth measured 8,604 feet Packer measured 8265,8459,8624 feet true vertical 6,430 feet true vertical 6197,6331,6443 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 54 feet 16 " 90' MD 90'ND SURFACE 4,926 feet 9 5/8" 4,961'MD 3901'ND PRODUCTION 2,320 feet 7 2,343' MD 2084'ND PRODUCTION 6,667 feet 7 9,010' MD 6705'ND Perforation depth: Measured depth: 8344-8383, 8384-8407, 8426-8434 feet True Vertical depth: 6252-6279, 6279-6295, 6308-6314 feet Tubing(size,grade,measured and true vertical depth) 4 x 3 1/2 x 2 7/8 J-55 8,677' MD 6,479'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER HB RETRIEVABLE PACKER 8,265' MD 6,197'TVD', PACKER-BAKER HB RETRIEVABLE PACKER 63K 8,459' MD 6,331'ND, PACKER-TIW SS'BB'PERMANENT PACKER 8,624'MD 6,443'ND SAFETY VLV-CAMCO 4"TRDP-4A SSSV 1,798'MD 1,706'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Tubing Punch, 8616-8618'MD Cement Retainer 8604'MD SCANO -' -.::s Treatment descriptions including volumes used and final pressure: Cement Squeeze 8480-8618'MD 7 bbls 15.8#Class G 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: - - - - - Subsequent to operation: - - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development 0 Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSIL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-544 Contact Name: William R. Long Authorized Name: William R.Long Contact Email: William.R.Long@cop.com Authorized Title: Staff CTD Engineer-, Authorized signature: 147. //(', - uate:6-Apt_. 2 g Contact Phone: (907)263-4372 Form 10-404 Revised 4/2017 /2Z7,r 7"` 4127/i RBDMS.SC APR 10 Y018 Submit Original Only 111."- ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 6, 2018 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Please find attached Report of Sundry Well Operations (10-404) for KRU 1A-20 (PTD: 190-162). This report has been prepared for Sundry 317-544. This work was completed in preparation for the CTD sidetrack project. Completion reports were previously sent for the 1A-20 CTD laterals drilled: 1A-20L1, 1A20L1-01, and 1A-20L1-02. This Report of Sundry Well Operations for the primary wellbore was accidently over looked and not included with the new lateral completion reports. I apologize for the delay in submitting this report. If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, "7-// William R. Long ConocoPhillips Alaska Coiled Tubing Drilling Engineer • 1 A-20 PLUG PERFORATIONS DTTMSTAI JOBTYP SUMMARYOPS 12/22/17 DRILLING IDENTIFY LEAK IN UPPER C-SAND SELECTIVE @ APPROX 8269' RKB SUPPORT- (NO SPINNER RESPONSE BELOW LEAK PUMPING 5 BPM © 1100 PSI). CAPITAL PERFORATE FROM 8616'TO 8618' RKB WITH 2' x 1.56"TBG PUNCH (4 SHOTS PER FT/0° PHASING). READY FOR CTU. 12/24/17 ANNCOMM (WC) : RE-ENERGIZE IC-PO (IN PROGRESS). 12/25/17 DRILLING RIH WITH HES GAMMA RAY CCL MEMORY LOGGING TOOLS, TAG SUPPORT- 8655.85' RKB, LOG UP TO 8600', PAINT WHT FLAG, CONTINUE CAPITAL LOGGING UP TO 8000', OOH DOWNLOAD DATA, GOT GOOD DATA, JOB IN PROGRESS 12/26/17 DRILLING RIH WITH WEATHERFORD 1 TRIP CEMENT RETAINER, TAG CMU AT SUPPORT- 8608' RKB, CORRECT DEPTH AND SET TOP OF RETAINER AT 8604' CAPITAL RKB (MID ELEMENT AT 8604.5' RKB), PUMP 7 BBLS OF 15.8#CLASS G CEMENT THROUGH RETAINER, UNSTRING FROM RETAINER AND CHASE OOH AT 80%WASHING ACROSS ALL JEWELRY, F/P TO 8604' RKB, ALLOW 72 HOURS TO CURE BEFORE S/L DUMMY WHIPSTOCK DRIFT, JOB IN PROGRESS. 12/27/17 DRILLING DRIFT W/2.625" DMY WHIPSTOCK TO CEMENT RETAINER @ 8,604' SUPPORT- RKB.TBG CLEAR, READY FOR E-LINE. CAPITAL KUP PROD • 1A-20 ConocoPhillips . Well Attributes Max Angle&MD TD r I 1 11 Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,) c, 500292211200 KUPARUK RIVER UNIT PROD 48.50 2,100.00 9,034.0 (Crv/APte16�v, Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date -.- SSSV'LOCKED OUT 80 8/22/2017 Last WO: 7/26/1991 35.01 12/21/1990 1A-20,4/6/2018 9:29:26 AM Last Tag Venial schematic{actua) Annotation Depth)ftKB) End Date Last Mod By Last Tag: RKB(EST 146'SAND ON PLUG) -18,519.0 11/17/2017 pproven HANGER.31.3_ Last Rev Reason ut_,.,:„, puy;;,.„eren''uuuuua' . . u.,Annotation End Date Last Mod By Rev Reason:Cement Squeeze(12/26/2017) 4/6/2018 longwr � Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread CONDUCTOR 16 15.062 36.0 90.0 90.0 65.00 H-40 WELDED CONDUCTOR;36.0-90.0 Casing Description OD(in ID To p ) (in) p(RKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread y. MII SURFACE 95/8 8.921 35.0 4,960.5 3,901.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread SAFETY VLV;1,797.6 PRODUCTION 7"TIE- 7 6.276 23.5 2,343.0 2,084.4 26.00 J-66 BTC- --- . IN ABMOD Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) 'Set Depth(TVD)... WI/Len(I...Grade Top Thread iI II PRODUCTION Post WO 7 6.276 2,343.0 9,010.3 6,705.4 26.00 K-55 BTC Tubing Strings PRODUCTION 7"TIE-IN;23.5- ,; - Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 2,343.0 I._ _.1 TUBING 4 3.476 31.3 8,677.9 6,479.6 11.00 J-55 DSS-HTC GAS LIFT;3,075.8 - 4"X3.5"x2.875 IN Completion Details Top(TVD) Top Incl Nominal II Top)ftKB) (ftKB) CI Item Des Com ID(in) GAS LIFT;4,256.2 31.3 31.3 0.05 HANGER McEVOY GEN IV TUBING HANGER 4.000 1,797.6 1,705.7 37.17 SAFETY VLV CAMCO 4"TRDP-4A SSSV(LOCKED OUT 7/15/05) 3.312 4,192.3 3,354.3 44.21 XO Reducing CROSSOVER 4"x 3.5" 3.500 1 8,250.9 6,187.3 45.73 PBR BAKER PBR 10 STROKE 3.000 SURFACE;35.0-4,960.5--� 8,264.6 6,196.9 45.84 PACKER BAKER HB RETRIEVABLE PACKER 2.870 GAS UFT;5,094.3 8,322.4 6,237.0 46.23 BLAST RINGS BLAST RINGS(4) 2.992 GAS UFT;5,813.8 gll 8,448.4 6,323.6 46.85 Siding Sleeve- CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE(CLOSED 2.812 L■ Closed 12/20/2017) GAS UFT;6,375.5 r 8,458.9 6,330.8 46.90 PACKER BAKER HB RETRIEVABLE PACKER 63K 4 PULL OR ROTATION 2.870 RELEASE GAS UFT;6,969.1 8,608.0 6,432.2 47.38 Sliding Sleeve- CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE(OPEN 2.750 11. Open 12/20/2017) GAS LIFT;7,410.4 8,622.4 6,441.9 47.37 SEAL ASSY TIW LOCATOR/SEAL ASSEMBLY w/MULE SHOE ON BTM 3.000 8,624.3 6,443.2 47.36 PACKER TIW SS'BB'PERMANENT PACKER 4.000 GAS UFT;8,199.111. 8,628.1 6,445.7 47.36 SBE TIW SEAL BORE EXTENSION-"CROSSOVER TO 2 7/8"TBG" 4.000 nii 8,665.5 6,471.1 47.32 NIPPLE CAMCO'D'NIPPLE,2.25"PACKING BORE NO GO PROFILE 2.250 PBR;8,250.9 5--7 8,677.2 6,479.0 47.31 SOS ELMD TTL @ 8674'during PPROF on 6/1/2008/BAKER SHEAR 2.441 PACKER;8,264.6 Lir i OUT SUB TUBING LEAK;8,269.0 A" Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) _ C) Des Com Run Date ID(in) PRODUCTION;8,307.9 / 8,269.0 6,199.9 45.87 TUBING LEAK TUBING LEAK-LEAK IN UPPER C-SAND SELECTIVE 12/22/201 7 8,587.0 6,417.9 47.35 WHIPSTOCK- Window Whipstock for CTD 1/6/2018 IPERF;8,344.08,383.0- I ' I MONOBORE I I 8,604.0 6,429.5 47.39 Cement Retainer Weatherford FH One-Trip Cement Retainer 12/26/201 IPERF;8,384.08,407.0- I I 7 IPERF;8,426.08,434.0- I4 I 8,665.0 6,470.8 47.32 PLUG CA-2 PLUG(OAL 26") 4/17/2017 - 0.000 la (A-SANDS ISOLATED) Sliding Sleeve-Closed;8,448.4 Perforations&Slots I Shot PACKER;8,458.9 -" `' Dens I Top(TVD) Btm(TVD) (shots/ft Top(RKB) Btm(ftKB) (ftKB) (ftKB) Zone Date I Type Co"' 8,344.0 8,383.0 6,251.9 6,278.8'C-4,1A-20 8/3/1991 10.0 IPERF HLS 4.5"CG IPERF;8,480.0-8,506.0- 8,384.0 8,407.0 6,279.5 6,295.3 C-3,1A-20 8/3/1991 6.0 IPERF HLS 4.5"CG i1. ':E 8,426.0 8,434.0 6,308.3 6,313.8 C-2,1A-20 8/3/1991 5.0 IPERF HLS 4.5"CG PRODUCTION;8,556.5 A8,480.0. 8,506.0 6,345.2 6,362.9-C-1,1A-20 8/3/1991 10.0 IPERF HLS 4.5"CG .M 8,616.0 8,618.0 6,437.6 6,438.9 A-4,1A-20 12/22/2017 4.0 APERF 2'x 1.56"TBG PUNCH(4 L1-02 UNER;8,579.410,980.0 SHOTS PER FT/0° ' PHASING) WHIPSTOCK-MONOBORE: u 8,587.0 ...... 8,747.0 8,755.0 6,526.4 6,531.8 A-5,1A-20 8/3/1991 4.0 IPERF HLS 4.5"CG 8,770.0 8,810.0 6,542.0 6,569.0'A-4,1A-20 8/3/1991 4.0 IPERF HLS4.5"CG Cement Retainer;8,604.0 ,'Ii' Cement Squeezes !W. Sliding Sleeve-Open;8,608.0 :" Top(TVD) Btm(TVD) 1:g:':, Top)RKB) Btm(ftKB) (ttK8) (ftKB) Des Start Date Corn APERF;8,616.0 , 8,480.0 8,618.0 6,345.2 6,438.9 Cement Squeeze 12/26/201 7 BBLs 15.8#Class G Cement Squeeze;8,480.0 RKB 7 SEAL ASSY;8,622.4 -- Mandrel Inserts t a PACKER;8,624.3 on SBE;8,628.0 Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (RKB( Make Model OD(in) Seen Type Type (in) (psi) Run Date Com f 3,075.8 2,586.2 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,251.0 2/5/2018 1:00 • PLUG;8,665.0, jr" 2 4,256.2 3,400.2 MACCO SPM-1A 1 GAS LIFT GLV BK 0.188' 1,278.0 2/5/2018 2:00 NIPPLE;8,665.5 .1/. SOS;8,677.2 > II 3 5,094.3' 3,995.5 MACCO SPM-1A 1 GAS LIFT OV BK 0.250 0.0 2/4/2018 4:00 4 5,813.8 4,497.7 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 12/18/2017 12:30 IPERF;8,747.0.8,755.0 5 6,375.5 4,882.2 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 12/18/2017 8:00 6 6,969.1 5,282.9 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 12/18/2017 12:00 IPERF;8,770.0.8,810.0 7 7,410.4 5,591.1 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 7/20/2016 4:00 8 8,199.1 6,151.0 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/22/2016 11:00 PRODUCTION Post WO; 2,343.0-9,010.3 . a KUP PROD • 1A-20 Con©coPhillips 2 Alaska,Inc, CagctiPtu.ps ...•• 1 A-20,4/62018 9.29:27 AM Vertical schema.(actual)................. HANGER,31.3— )j � �� Mandrel Inserts St ati CONDUCTOR;36.0410.0 Top fTVO) Valve latch Port Size TRO Run N Top(RKB) (RKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com 6 9' 8,307.9 6,226.9 MERLA 'TGPDC 1 1/2 PROD DMY RK 0.000 0.0 2/14/1992 10:30 SAFETY VLV,1,797.6 ` ■..,l Close d ,I I` 1 8,556.5 6,397.3 MERLA -TGPOC 1 1/2 PROD DMY RK 0.000 0.0 2/14/1992 9:00 0 Close d PRODUCTION r TIE-IN;23.5- �, Notes:General&Safety 2,343.0 ' ' , End Date Annotation GAS UFT,3,075.8 7/26/1991 NOTE:7"TIEBACK RKB TO LOCKDOWN SCREWS;TUBING RKB TO TBG HEAD FLANGE 2/2/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 111 GAS UFT,4,256.2 j I SURFACE;35.04,960.5—J l GAS UFT;5,094.3 GAS LIFT;5,813.8 ' GAS UFT;6,375.5 111. oc GAS UFT;6,969.1 4* I GAS UFT;7,410.4 Lf— GAS UFT;8,199.1 PBR;8,250.9 PACKER;8,264.6 i_it—(.,/ TUBING LEAK;8,269.0 111 PRODUCTION;8,307.9 .. � IPERF,8,344.0-8,363.0 IPERF;8,384.0-8,407.0 IPERF;8,426.0-8,434.0 _ Sliding Sleeve-Closed;8,448.4 PACKER;8,458.9 IPERF,8,480.0-8,506.0— PRODUCTION;8,556.5 c L1-02 USER;8,579.410,980.0 0 WHIPSTOCK-MONOBOR8,580 x A M �. Cement Retainer,8,604.0 11 II: IV Sliding Sleeve-Open,8,608.0 ;.f APERF,8,Squeeze, 0,480.0 8.0 Cement Sguveze;8,480.0 ftKB SEAL ASSY,8,622.4 -- PACKER,8,624.3 SBE,8,628.0 - q�/ NIPPLE,8,665.5, �p/�- SOS',8,677.2 El ERF;8,747.68,7550 IP IPERF,8,770.0.8,810.0 PRODUCTION Post WO; 2,343.69,010.3' RECEIVED 1 9 0 1 62 MAR 19 2018 WELL LOG TRANSMITTAL#904529248 2 9 14 1 AOCC To: Alaska Oil and Gas Conservation Comm. February 20, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch and Coil Flag Records: 1A-20 Run Date: 12/22/2017 and 12/25/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.com 1A-20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22112-00 Tubing Punch and Coil Flag Records (Field Print) 1 color log-each 50-029-22112-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Saris 1 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS ANC@halliburton.com Date: 31291 I I() Signed: A 11°. 8., OF Thr • • 44,��\I%/y7 s, THE STATE Alaska Oil and Gas � ?;-s_=� �, o A TLAsl1 T� � Conservation Commission ___ fAJ��LZ Witt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASS"' Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. SCANNED JAN 0 4 2013 PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-20 Permit to Drill Number: 190-162 Sundry Number: 317-544 Dear Mr. Ohlinger: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 1 day of December, 2017. RBDIMMS ( v 0 5 2017 • • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 17 201? APPLICATION FOR SUNDRY APPROVALS ars I 2.11 ¢I 17 20 AAC 25.280 AO G�,j�j 1.Type of Request: Abandon 111 Plug Perforations E• Fracture Stimulate ❑ Repair Well 111 Operations shutdown❑ Suspend ❑ (x." Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill , ' Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development E• 190-162 ` 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service PO Box 100360,Anchorage,AK 99510 50-029-22112-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Kuparuk River Unit Will planned perforations require a spacing exception? Yes ❑ No u 1A-20 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25648 ' Kuparuk River Field/Kuparuk Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9034' , 6721', 9010' \ 6705' • 2892 8665' Casing Length Size MD TVD Burst Collapse Structural Conductor 54' 16" 90' 90' 1640 630 Surface 4925' 9-5/8" 4961' 3901' 3520 2020 Intermediate Production 8987' 7" 9010' 6705' 4980 4330 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8344'-8506',8747'-8810' • 6252'-6363',6526'-6569' 4"x 3-1/2" J-55 x L-80 8678' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): , ' Baker HB Retrievable(x2),TIW BB Permanent Packer,Camco SSSV 8265'/6197',8459'/6331',8622'/6442',1798', 1706' 12.Attachments: Proposal Summary 2 Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 22-Nov-17 OIL J \111/ WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Mike Callahan /� Authorized Title: Staff CTD Engineer Contact Email: Mike.Callahan@ConocoPhillips.com Contact Phone: 907-263-4180 Authorized Signature: i,�" / Date: //��(//7 /' -- �_ COMMISSION U5E ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _,till Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: oo p t7-5-t- to 5-60 p 6-1_ `j Z s biC) P S 4 A-r/ /� vlarprc vlvi . E /–P-5J- Post Initial Injection MIT Req'd? Yes ❑ No RBDI S L✓ CEC C 5 2017 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 1 U —40 62C2CC APPROVED BY I y Itq Approved by: COMMISSIONER THE COMMISSION Date: 1 'AcNic A fgA ��Il>�l�� 7z 47 I Z/o2 /i - Submit Form and /�.JC Form 10-403 Revised 4/2017 Approved application is valid011 ,1tIrc1n11Ihd e ta.pproval. Attachments in Duplicate v • S ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 16, 2017 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to abandon the C Sand perforations in KRU 1A-20 by cementing between two production packers across the C-Sand. This will set the well up to for CTD operations to drill a dual-lateral out of the KRU 1A-20 using the coiled tubing drilling rig, Nabors CDR3-AC. ✓ A sundry application is attached to plug the 1A-20 (190-162) perfs to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the C-sand perfs in 1A-20. A permit to drill for the two proposed CTD laterals will be submitted at a later date. Attached to this application are the following documents: - 10-403 Sundry Application to Abandon KRU 1A-20 (190-162) - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 1A-20 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 1A-20 is a Kuparuk NC-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will target the C sands. The laterals will access stranded resources in multiple fault blocks. Prior to CTD operations we will pump cement between two production packers and squeeze off the C sand perfs. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the C-sand perforations in this manner. Following the cement squeeze, cement will be milled out in tubing and a whip-stock will be set. Following this Nabors CDR3-AC will drill laterals to recover additional resources in the C sand. Permit to drill applications will be submitted once well plans are finalized. Using the maximum formation pressure in the area of 10.8 PPG in 1A-04, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2892 psi. CTD Drill and Complete 1A-20 Laterals: Pre-CTD Work 1. Slick-line: Pull gas lift valves and dummy. 2. E-Line: Punch holes in tubing at from 8587' - 8589' and 8468' - 8470' 3. Coiled Tubing: Pump cement from 8608' to 8468', squeeze C sand. 4. Coiled Tubing: Mill and under-ream cement in tubing. 5. Slick-line: Drift whip-stock down to set depth. 6. E-line: Set whip-stock Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1A-20L1 Lateral a. Mill 2.80" window through production tubing and casing at -8587'. b. Drill lateral with bi-center bit to 12,000' and run 2%" slotted liner with an aluminum billet top at 9200'. 3. 1A-20L1-01 Lateral a. Kick off the aluminum billet in at 9200'. b. Drill lateral with bi-center bit to -12,500' and run 2%" slotted liner with deployment sleeve back inside tubing 4. Freeze protect, obtain SBHP, set BPV, ND BOPE, and RDMO Nabors CRD3- AC. co,ftear: t C< 61,l( ,60 e-2 1/er1X/War Post-Rig Work 1(4er- Alck inTd �X/��`�ol k1.c.Cr‘re So 1t 1A-,q/ 1. Pull BPV be able ra rzf The /eSer,,ef TA( well ,f 2. Install gas lift design 3. Return to production Currt'" frvo(vcr^f�( 100 7 Page 1 of 1 11/16/2017 • • 'i ❑ ,: 'I ,, o ,, 0 ' N i' ❑ N :' CO ,i 2 ,i H ❑ Ln �� O O@ O'� QOM a0 ; 3 O ,' 3 0 c 1i 0 ci) co 0 ,. < 0 O ,; N '-J 0 CE N - N Ln tt' _ L N , ' ',N U — v (2 0 (y 0 0 (y N ,L '- 6) _— 2 ❑ ,' ', co m 0 O ❑ Co — ' M j N o r Co V- co 2 i' i O C6 ❑ O o) N N CO 00 N LLf co CO ❑ CO ''` I i 0 N- LC) C 00 M CO I ,, Op C moo`` N ��\\ o - U� `) U� ' ❑• cmco ❑ CA .O ) 0) V ~ — N > N a) EN - V • '� r•-• -O Ln N a) O N a) M • ' H co N N -6 U 774 V 'a N EC° a) N U `) ` Li., M 0O C C, 00 C U U ❑ )-- C6 • > © E C © E c Q E ' u) = m m w a a Y °° co ,, U) Cn COE 0 co Y C Y O aa)i U N C = , U) co = X = co CL v — U) U) U) . ,' ❑ — - — J - ca U 0 U n' /�� C O - ', Q cc V- U N_ co_ C Q C ' U m V co C ', '' LO a) ❑ Com`) 7 m 2 CO m 2 CO C6 co w a -5 ,, O -) 0 0 0 2 O CO I C1 0 = Q 0 0 U) m 0 ct 0 UU Z.".,4 ° C6 0 CE 0 J U) Cr) 0 `, H H E 0 E0) E Y E _ E - 0 0 U 00 CO Co on 2 0 co 2 0 F_— H 1— U N , , i ;' i i , 0 i ,---- ,,..., ! I ii. I 4-+ I iuIiimJi ■ I 1111111.� V ....„ ,, . „m„ .„ a) -c,N I , • — III L` O ❑ c, © a 2 't a) CI CI o L CO M co a.� to M LU L 'C O LO V MLn U) CO (4 ' CO ❑ L() N 12, © ❑ , co ❑ ❑ ss Q < , Y N C vo LU Cv 0 C - LU0 Q� I6) CO � COC' Y coo N — Q a veo as U °� U °, r` t—I as M to N C6 .0 rn V ' Cl0) KUP PROD • IA-20 ConocoPhillips - Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) ,:mocoanlupl: 500292211200 KUPARUK RIVER UNIT PROD 48.50 2,100.00 9,034.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-20,5/29/201711:4645 AM SSSV:LOCKED OUT 50 9/10/2016 Last WO: 7/26/1991 35.01 12/210990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,,,,,N,3,,.31 VsVhV.:11 u T I Last Tag: RKB 8,814.0 4/17/2017 Rev Reason:OPEN CMU(to produce the C- pproven 5/29/2017 r sand) I Casing Strings Casing Description 00 (i n) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I Grade Top Thread -ICONDUCTOR 16 15.062 36.0 90.0 90 0 65.00 H 40 WELDED r Casng Description OD(in) ID(In) Tap(RKB)350 4,9Set Depth(RKB) Sat Depth(TVD)... (I...Grade Top Thread fl SURFACE 9 5/8 8.921 60.5 Wt/Len 3,901.1 36.00 J 55 BTC IJ'l Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread j . .. PRODUCTION 7" 7 6.276 23.5 2,343.0 2,084.4 26.00 J-66 BT CONDUCTOR,36.0-90.0 TIE-IN BTC - CONDUCTOR; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' MI PRODUCTION Post 7 6.276 2,343.0 9,010.3 6,705.4 26.00 K-55 BTC WO SAFETY VLV;1,797.8 .ti Tubing Strings Tubing Description String Ma...ID(in) I Top(ftKB)31.3 I Set Depth(9..Set Depth(TVD)(...I Wt(Ib/ft) Grade Top Connection TUBING Ma.., 3.476 8,677.9 6,479.6 11.00 J-55 DSS-HTC 4x3.5"x2.875 Completion Details PRODUCTION 5-TIE-IN; _ Nominal ID 23.5-2,343.0 � Top(RKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;3,075.8 Y 31.3 31.3 0.05 HANGER McEVOY GEN IV TUBING HANGER 4.000 1,797.6 1,705.7 37.17 SAFETY VLV CAMCO 4"TRDP-4A SSSV(LOCKED OUT 7/15/05) 3.312 4,192.3 3,354.3 44.21 XO Reducing CROSSOVER 4"x 3.5" 3.500 GAS LIFT;4,2562 8,250.9 6,187.3 45.73 PBR BAKER PBR 10 STROKE 3.000 8,264.6 6,196.9 45.84 PACKER BAKER HE RETRIEVABLE PACKER 2.870 8,322.4 6,237.0 46.23 BLAST RINGS BLAST RINGS(4) 2.992 1 8,448.4 6,323.6 46.85 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE 2.812 SURFACE;35.0-0 ` ,960.5-a (OPENED 5/28/2017) 8,458.9 6,330.8 46.90 PACKER BAKER HB RETRIEVABLE PACKER 63K#PULL OR 2.870 GAS LIFT;5,094.3 ROTATION RELEASE GAS LIFT;5,813.8 8,608.0 6,432.2 47.36 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE 2.750 (CLOSED 2/19/96) GAS LIFT;6,375.5 IC. 8,622.4 6,441.9 47.37 SEAL ASSY TIW LOCATOR/SEAL ASSEMBLY w/MULE SHOE ON 3.000 BTM GAS LIFT;6,969.1 ® 8,624.3 6,443.2 47.36 PACKER TIW SS'BB'PERMANENT PACKER 4.000 8,628.1 6,445.7 47.36 SBE TIW SEAL BORE EXTENSION-'"CROSSOVER TO 2 4.000 GAS LIFT;7,410.4 3 7/8"TBG** I 8,665.5 6,471.1 47.32 NIPPLE CAMCO'D'NIPPLE,225"PACKING BORE NO GO 2.250 PROFILE GAS LIFT;8,199.1 - 8,677.2 6,479.0 47.31 SOS ELMD TTL @ 8674'during PPROF on 6/1/2008/BAKER 2.441 _ SHEAR OUT SUB I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PBR;8,250.9 --- Top(TVD) Top Incl PACKER;8,264.6 -•- Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,665.0 6,470.6' 47.32 PLUG CA-2 PLUG(OAL 26") 4/17/2017 0.000 (A-SANDS ISOLATED) ri PRODUCTION;8,307.9 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f IPERF;8,344.0-8,383.0- Top(ftKB) Btm(986) (RKB) (ftKB) Zone Date t) Type Com 8,344.0 8,383.0 6,251.9 6,278.8 C-4,1A-20 8/3/1991 10.0 IPERF 'HLS 4.5"CG IPERF;8,384.0-8,407.0- 8,364.0 8,407.0 6,279.5 6,295.3 C-3,1A-20 8/3/1991 6.0 IPERF HLS 4.5"CG IPERF;e,426.0-e.434.0- 8,426.0' 8,434.0' 6,308.3 6,313.8 C-2,1A-20 8/3/1991 5.0 IPERF HLS 4.5"CG i 8,480.0 8,506.0 6,345.2 6,362.9 C-1,1A-20 8/3/1991 10.0 IPERF HLS 4.5"CG 8,747.0 8,755.0 6,526.4 6,531.8 A-5,1A-20 8/3/1991 4.0 IPERF HLS 4.5"CG SLEEVE-C;8,448.4 8,770.0 8,810.0 6,542.0 6,569.0 A-4,1A-20 8/3/1991 4.0 IPERF HLS 4.5"CG PACKER;8,458.9 -' Mandrel Inserts _ St a6 I on Top(TVD) Valve Latch Port Size TRO Run IPERF;8,480.0-8,506.0- N Top(RKB) (RKB) Make Model OD(in) Sary Type Type (in) (psi) Run Date Cam 1,.. � 3,075.8 2,586.2 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,305.0 6/6/2015 1:00 2 4,256.2 3,400.2 MACCO SPM-1A 1 GAS LIFT GLV BK 0.156 1,291.0 6/7/2015 2:00 PRODUCTION;8,556.5 • 3 5,094.3 3,995.5 MACCO SPM-1A 1 GAS LIFT GLV BK 0.156 1,276.0 6/5/2015 4:00 4 5,813.8 4,497.7 MACCO SPM-1A 1 GAS LIFT GLV BK 0.156 1,261.0 6/5/2015 12:30 SLEEVE-C;8,608.0 , 5 6,375.5 4,882.2 MACCO SPM-1A 1 GAS LIFT GLV BK 0.188 1,283.0 6/4/2015 8:00 SEAL ASSY;8,622.4 -_ 6 6,969.1 5,282.9 MACCO SPM-1A 1 GAS LIFT OV BK 0.250 7/22/2016 PACKER;8,824.3 SBE;8,628.0 • 7 7,410.4 5,591.1 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 7/20/2016 pp0///��nl 8 8,199.1 6,151.0 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/22/2016 PLUG;0,865.0 Ira:NIPPLE;8,865.51 7p/// 9 8,307.9 6,226.9 MERLA TGPDC 1 1/2 PROD DMY RK 0.000 0.0 2/14/1992 10:30 Close d SOS;8,877.2 Y. 1 8,556.5 6,397.3 MERLA TGPDC 11/2 PROD DMY RK 0.000 0.0 2/14/1992 9:00 0 Close _ d IPERF;8,747.0-ea55.0- - Notes:General&Safety - End Date Annotation - 7/26/1991 NOTE'.7"TIEBACK RKB TO LOCKDOWN SCREWS;TUBING RKB TO TBG HEAD FLANGE IPERF;8,770.0-8,810.0- 2/2/2009 NOTE'.VIEW SCHEMATIC w/Alaska Schematic9.0 PRODUCTION Post WO; 2,343.0-9,010.3 1 I Loepp, Victoria T (DOA) From: ' Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Monday, November 27,2017 11:44 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]KRU 1A-20(PTD 190-162, Sundry 317-544) Plug Peri in Prep for CT Laterals Good morning Victoria, • That is correct,the A Sand perforations will remain open,so it should be a plug perforations sundry. Planned BOP test pressure is 3500 psi (2500 psi for the annular) based on a MPSP of 2892 psi. Please let me know if you have any further questions. Thanks, Mike Callahan CTD Engineer ConocoPhillips Alaska ATO 660 Office: (907)263-4180 Cell: (907)231-2176 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, November 27,2017 11:04 AM To:Callahan, Mike S<Mike.Callahan@conocophillips.com> Subject: [EXTERNAL]KRU 1A-20(PTD 190-162,Sundry 317-544)Plug Perf in Prep for CT Laterals Mike, Wanted to confirm that the A Sand will still be open in 1A-20? If so,this would be just a plug perforations sundry. However,the rig up of CDR3-AC would still be on this sundry until the window is milled. What is the planned BOP test pressure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�.alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 STATE OF ALASKA AlIKA OIL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull Tubing E Operations Shutdown Performed: Suspend 1 Perforate r" Other Stimulate fl Alter Casing E Change Approved Program 1' Plug for Redrill E Perforate New Pool E Repair Well E Re-enter Susp Well E Other: Tubing Patch 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 190-162 3.Address: 6.API Number: Stratigraphic Service 1-- P. P.O.Box 100360,Anchorage,Alaska 99510 50-029-22112-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25648 KRU 1A-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9034 feet Plugs(measured) None true vertical 6722 feet Junk(measured) None Effective Depth measured 8914 feet Packer(measured) 8265,8459,8624 true vertical 6640 feet (true vertical) 6197,6331,6443 Casing Length Size MD TVD Burst Collapse CONDUCTOR 54 16 90 90 SURFACE 4926 9 5/8 4961 3901 PRODUCTION 2320 7 2343 2084 PRODUCTION 6667 7 9010 6705 NOVRECEIVED 2 2016 Perforation depth: Measured depth: 8344-8383,8384-8407,8426-8434,8480-8506,8747-8755,8770-8810 True Vertical Depth: 6252-6279,6279-6295,6308-6314,6345-6363,6526-6532,6542-6569 AOGCC Tubing(size,grade,MD,and ND) 4",J-55,4192 MD,3354 TVD,3.5",J-55/L-80,8632 MD,6448 TVD,2.875".,J-55,8678 MD,6480 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER HB RETRIEVABLE PACKER @ 8265 MD and 6197 ND PACKER-BAKER HB RETRIEVABLE PACKER 63K#PULL OR ROTATION RELEASE @ 8459 MD and 6331 TVD PACKER-TIW SS'BB'PERMANENT PACKER @ 8624 MD and 6443 ND SAFETY VLV-CAMCO 4"TRDP-4A SSSV(LOCKED OUT 7/15/05)@ 1798 MD and 1706 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 21 417 507 - 187 Subsequent to operation 20 173 122 - 173 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service E Stratigraphic E Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas E WDSPL t' Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ E WAG r GINJ E SUSP fl SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact John Peircea(7.265-6471 Email John.W.Peirce a(,conocoohillips.com Printed Name John Peirce Title Sr.Wells Engineer Signature fel44 ._ Phone:265-6471 Date i 1/291/6 Form 10-40/4 Revised 5/2015 � �6 �'" RBDMS LL DEC - 6 2016 Submit Original Only • • 1 A-20 DTTMSTP JOBTYP SUMMARYOPS 10/28/16 TUBING/ BRUSH & FLUSHED 8230' -8290' RKB. IN PROGRESS. CASING PATCH 10/29/16 TUBING/ PRE-PATCH DRIFT TO 8292' RKB. READY FOR E-LINE. CASING PATCH 10/30/16 TUBING/ MIRU. RIH W/3.5 PIIP PACKER. SET PACKER AT 8274' (SER# CASING CPP 35009). CCL TO ME= 11.5', CCL STOP DEPTH = 8262.5'. PATCH LOG CORRELATED TO TUBING TALLY DATED 8/6/91. POOH. RDMO. 11/2/16 TUBING/ SET UPPER PERAGON II PACKER AND PATCH ASSEMBLY @ CASING 8246' RKB. SET TTS TEST TOOL @ SAME. MITT*PASSED* PATCH PULLED TTS TEST TOOL @ 8246' RKB. JOB COMPLETE. 11/20/16 PUMPING PUMPED 26 BBLS DSL DOWN TBG. TRACKING PUMPED 24 BBLS NEAT METH. DOWN FLOWLIN ONLY ( JOB COMPLEAT ) a KUP P�D � 1A-20 ConocoPhillips '/ Well Attribute Max Angle TD Alaska.Ir)t:. Wellbore API/UWI Field Name Wellbore Status ncl(7 MD(ftKB) Act Btm(ftKB) Cano,,3"-iliK, 500292211200 KUPARUK RIVER UNIT PROD 48.50 2,100.00 9,034.0 -.. .....< Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-20,11/2812016 11:05:17 AM SSSV:LOCKED OUT 40 12/21/2015 Last WO: 7/26/1991 35.01 12/21/1990 Vertical sGxmatw:(eptuary Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 8,783.0 8/5/2016 Rev Reason:SET PATCH 8 PACKERS pproven 11/15/2016 HANGER;31.3-.M.-2:4:4.4.n Casing Strings • '""'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread I 'Fj�l CONDUCTOR 16 15.062 36.0 90.0 90.0 65.00 H-00 WELDED rr.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 4,960.5 3,901.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR;36.0-90.o PRODUCTION 7" 7 6.276 23.5 2,343.0 2,084.4 26.00 J-66 BTC- TIE-IN ABMOD ill asing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION Post 7 6.276 2,343.0 9,010.3 6,705.4 26.00 K-55 BTC WO SAFETY VLV;1,797.6 rA Tubing Strings 1:', I� Tubing Description String Ma...ID Orb Top(ftKB) Set Depth(ft..{Set Depth(ND)I...Wt(Ib/ft) Grade Top Connection TUBING I 4 3.476 31.3 8,677.91 6,479.6 11.00 J-55 DSS-HTC 4"x3.5"x2.875 PRODUCTION T TIE-IN; ..,._ Completion Details 23.5-2,343.0 1'1 ', Nominal ID GAS LIFT;3,075.8 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.3 31.3 0.05 HANGER McEVOY GEN IV TUBING HANGER 4.000 al 1,797.6 1,705.7 37.17 SAFETY VLV CAMCO 4"TRDP-4A SSSV(LOCKED OUT 7/15/05) 3.312 4,192.3 3,354.3 44.21 XO Reducing CROSSOVER 4"x 3.5" 3.500 GAS LIFT,4,256.2 Z. 8,250.9 6,187.3 45.73 PBR BAKER PBR 10 STROKE 3.000 8,264.6 6,196.9 45.84 PACKER BAKER HE RETRIEVABLE PACKER 2.870 8,322.4 6,237.0 46.23 BLAST BLAST RINGS(4) 2.992 RINGS SURFACE;35.04,960.5- L 8,448.4 6,323.6 46.85 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE 2.812 (CLOSED 12/5/12) GAS LIFT;5,084.38,458.9 6,330.8 46.90 PACKER BAKER HE RETRIEVABLE PACKER 63K#PULL OR 2.870 0 A ROTATION RELEASE GAS LIFT;5,813.8 g 8,608.0 6,4322 47.38 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE NO GO PROFILE 2.750 111 (CLOSED 2/19/96) GAS LIFT;6,375.5 8,622.4 6,441.9 47.37 SEAL ASSY TIW LOCATOR/SEAL ASSEMBLY w/MULE SHOE ON 3.000 GAS LIFT;8,969.1 BTM ■ 8,624.3 6,443.2 47.36 PACKER TIW SS'BB'PERMANENT PACKER 4.000 GAS LIFT;7,410.4 8,628.1 6,445.7 47.36 SBE TIW SEAL BORE EXTENSION-'•CROSSOVER TO 2 4.000 ill 7/8"TBG 8,665.5 6,471.1 47.32 NIPPLE CAMCO'D'NIPPLE,2.25"PACKING BORE NO GO 2250 GAS UFT;8,199.1PROFILE 8,677.2 6,479.0 47.31 SOS ELMD TTL @ 8674'during PPROF on 6/1/2008/BAKER 2.441 • SHEAR OUT SUB Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PBR;8,250.9 • PATCH;8,248.0 55.- Top(TVD) Top Incl PACKER;8,264.6 Top(ftKB) (ftKB) CI Des Com Run Date ID(in) !. j 8,246.0 6,183.9 45.69 PATCH UPPER PARAGON PACKER,SPACER PIPE, 11/2/2016 1.630 PATCH;8,274.0 I ANCHOR/LATCH ASSEMBLY.(PATCH OAL= '. 33.87',MAX O.D.=2.72.I.D:1.63")(31.86'MID ELEMENT TO MID ELEMENT)- UPPER PARAGON II PACKER SN:CPP35009 lid PRODUCTION;0,307.9 8,274.0 6,203.4 45.91 PATCH 3.5 PIIP PACKER(SER#CPP 35009)OAL=25 10/30/2016 1.630 Perforations&Slots IPERF;8,3440.8,383.0 Shot Dens Top(ND) Btm(ND) (shots/ IPERF;8,384.08,407.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,344.0 8,383.0 6,251.9 6,278.8 C-4,10-20 8/3/1991 10.0 IPERF HLS 4.5"CG IPERF;8,426.0-8,434.0 8,384.0 8,407.0 6,279.5 6,295.3 C-3,1A-20 8/3/1991 6.0 (PERF HLS 4.5"CG 1 8,426.0 8,434.0 6,308.3 6,313.8 C-2,1A-20 8/3/1991 5.0 (PERF HLS 4.5"CG SLEEVE;8,448.4 8,480.0 8,506.0 6,345.2 6,362.9 C-1,1A-20 8/3/1991 10.0 (PERF HLS 4.5"CG 8,747.0 8,755.0 6,526.4 6,531.8 A-5,1A-20 8/3/1991 4.0 (PERF HLS 4.5"CG PACKER;8,458,9 8,770.0 8,810.0 6,542.0 6,569.0 A-4,1A-20 8/3/1991 4.0 IPERF HLS 4.5"CG Mandrel Inserts (PERF;8,480.0-8,506.0--1 I St atii N Top(ND) Valve Latch Port Sae TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PRODUCTION;8,556.5111 2 1 . 166/76//22001155II X;11 •• 1 1 1 1 11 194 • 1 1,276.0 1 4:00 SLEEVE-C;B,fi0B.0 • 0.1561 1 1 SEAL ASSY;8,822.4 ill 5 6,375.5 4,882.2 • a188 1,283.0 1 11 PACKER;8,624.3 SBE;8,628.0 b • • 0.250 1 NIPPLE, 16 fi 1A 0,665.5 _ ,1 • • 0.000 0.0 7/20/2016 .,-� 8 •• 6,151.0 • • 0.000 11 1 sos,8,677.2 8,307.9 '• '••• DMY RK 0.000 11 10:30 Close (PERF;8,747.0-B,755.0-. 1 8,556.5 6,397.3 MERLA •• PROD DMY RK 0.000 0.0 •11 1 Close IPERF;8,770.0-8,810.0---. Notes:General&Safety End Date Annotation 7/26/1991 NOTE:7"TIEBACK RKB TO LOCKDOWN SCREWS,TUBING RKB TO TBG HEAD FLANGE 11• • 1 PRODUCTION Post WO; 2,343.0-9,010.3 cJ p •_ • •• /� N N f04 ? ❑ X (0 1 L.9 �° N 3 0- 0 L N ° L `/ . _. +, qua) W W 0 ,C r r r r r r r r r r r r r f0 O N O L 0 o Z V a Q c c - O o-w N 4� +>' O Jim co O a Q c 1t la-\Y ❑ .c U E Q 3 Q -i Q i 0 CD CD CO ID (D CO LD CD LD !D CD co h a) - O 6 m a i E L -0 p in h 0 o 0 0 0 0 0 0 0 0 0 0 > 4-,+- N -' 0 0 0 0 0 0 0 0 0 0 0 O C c s CD N N r) v Lc t- c) o o ? c C ,' v vi Z Q N N N N N N N C) C) M 0 ..6 N O Q O 2 N E V > -O E) LY. L L O L N CD a O ❑ O ❑ ❑ O O O O O O O O C aJ L ', J J J J J J J J J J J J :� O } W W W W W W W W W W W W N- a! .i7- U "' M F- LL LL LL LL LL LL LL LL LL LL LL LL 4- cu a.) O .0 O x Q J J J J J J J J J J J J O- - > 4, N I- < < < < < < < < < < < < v N c 4-- -_ p0-, a Z Z Z Z Z Z Z Z Z Z Z Z v t v L O a G" LL LL L. U. U. U. LL LL LL LL LL lL = --. E' > v u o �- Qvuv U t° g C O - c Y C O O a C co H > u cui .c U - •@ Y = c ca Q O O Q Q Q N C Q U b tZ v) m LL ` G y o J CO am .1IIi- z ,� • x1. al▪ co m y 0 ✓ CO J - d J J J J J J J O J J J J ro iO M .. 3 3 3 3 3 3 3E 3 3 3 3 ft w b.."1?-"Ir. 1 LsJ w > > > > > > > > > > > > at z 2. Y Y Y Y Y Y Y Y Y Y Y Y w < < < < < < < < < < < < L N In LI n. a a a a a a a a a a a CO > > > > > > > > > > DD @ a Y Y Y Y Y Y Y Y Y Y Y Y 1 c L tit op O z C7 w In N CD N cD N N 0) O N X N .CD C'V C� 0 C) 0 0 0 0 CO CD C) CD N N N C te O O O M O O 0 O E 1e. 222228282222 v O 0 U U U U U Li Li 1 Li Li Li Li @ 0o co co 00 0o F— E— 0F— F— F— F- > 0 0 0 0 0 0 0 O LL 0000 u ® � CD Lu O 0 CO CO CC U ❑ ❑ ❑ ❑ Q c Mdd z I�• x N U In W E Y or o O cD 0 0 0 0 0 0 0 0 0 0 0 ++ 0 m 0 0 0 0 0 0 0 0 0 0 0 0 u Q a 4 C') V I� O V N LD N M N In CD • N 0 M 0 CO CD 0 N r D) CD N N = a N D) N r r) N M r N 0 N N N N N N N N N N N N N r C) 6 o) o) o) o) C) C) C) C) C) a) C o a. O N N N N N N N N N N N 0 @ 0 0 C1 0 0 0 0 0 0 0 0 0 0 0 t, 0 u 0 0 0 0 0 0 0 0 0 0 0 0 ,+ 4-, , O _,,, c N In In In In In If) In In In In I) Q 'o 0 C c a) w = o L z E a) a LL u N E E Q g '0 co ca 9 �� r N ptu j roti Q In In M Q 1n co N O N nt M yam. C�C C �I Z OD z r O r r r r N 0 O +' E a) aJ a) OC - J X m Q O Q E N N S { ^ W r N N r N N C z V).0 w O O ra F- a` O. F°- � (pJ M 11 V Q n U VI V O ft l'' > a) cuc '� w5w " Q L �... C7 is p o a Ur NZ � a) v O a 0 W , ; _c C N Y U ro O ro QHS a v rn > Y ,�� 4 a c o `o C 'o Q it O `O , ro Q Q CO J W t0 /0 t0 t0 t0 t0 t0 ro OrtS m Q Q L u N E L J Fr 0 6 6 6 C. O. 0. & Qi O V1 Y v) 0 Q a a !n <n N In N C E' r F aO 0) N N A M 4 = -O - Q > N Q O r N N N C C L c'2": a) Z O Q u - O >. ii 001...j QC O O D O C v u L n- �V 6 y W W W W W W W to c C p OL ♦- LL LL LL LL LL LL U. N 2 -c N O o F- < a < < < < < 2- _ O rt, v 0 c aIz Z Z z Z Z Z v O p a O '3; •I LL LL LL LL LL LL LL v - 41 U v Z V y O v C Q v, E ° 4-° 2 U H O a a) " C o _oC v Z _, Q C r6 R1 `_' r V,, Q a) _C Ou > 4" L) ; 14, X LL LL W LL LL LL LL it E M O 0000_ 0000 w O , CertCe1Z ... J a a a. a a a 'CI 0 m - - v a a a a cc m co a >: PI u co ru ti al v .0 .i 12 AI40 g a N iL7 m LL, O' 2os 'co > 2 J J J J J J J ''')./.. ...."111141. W 0 LIJ W W W W W W W > > > > > > > • Z Y Y Y Y Y Y Y OJ CC CC O: W a' R CC a w Q Q Q Q a a Q LL a a a a a O. a A C. C > D > > > > Y Y Y Y Y Y Y .; Llo 0 W N N N 0 e- X (.71 O. Cl N 0 r r r t0 CO 0) 0) O `� O 0 0 0 0 0 0 0 Usil 0 O - O 0 0 0 0 CO N - co co H H o 03 co co y 0000000C; 5 E MVO c. W O O O O O O O ro aKY 44 +w K � of > LU 0$ C �• 0 0 0 o O o u 0 0 o O O o O E - ro 111 Cl) Cr N t0 N r M a0 N W �0+ O ro T O O) N P I. (0 .," M M M h N 0 T ro u Q 4'Sy'• N M M 0 — 0 N N a+ • v, t�.!- .,n, N N N N N N N n .,.:' O) C) O) 0) M C) 0) E — 0 N N N N O N N y) • L 01 O O O O O O C O — ` 0 0 0 0 0 0 0 f0 u O )f) 0 )f) )() 10 )l) 10 - 0 u O co CC W � O. -0 O CO co cr, E U C ; u am U Q N g _ 0 °C `) E E 9 �� h M N R O M "O ro ro 01 0 it z N 0 0 0 0 N r E i " ,= 2 V) D. n J Y 2 3 2 Q m Y CU rn P' a 2 a N W M N M E z N N IP ea r3-4 dgi a) E 8 C/� a Ir .'"-----) F a s 1°- 1- Lot o- 'c2 2-1 M 0 2U1 WELL LOG TRANSMITTAL#903253445 ADCC To: Alaska Oil and Gas Conservation Comm. May 6, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 5 it6/2o1G M.K.BENDER RE: Multi Finger Caliper: 1A-20 Run Date: 4/16/2016 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 1A-20 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22112-00 Multi Finger Caliper(Field Log) 1 color log 50-029-22112-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett SCONE 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ; Pages NOT Scanned in this Well History File XHVZE 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 Complete RESCAN [] 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 vadous kinds [] Other COMMENTS: Scanned by: Beverly Dianna Vincent Nathan Lowell · TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: is~ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 ~~~N~~ ~~~ k 208 Dear Mr. Maunder: • - ~4 ___ s,_ ~ q~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6',2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor 5~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date • 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1 J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6!2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 8" NA 8" NA 1.28 9/6/2008 ~ /; 06/10/08 NO. 4741 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 y Attn: Christine Mahnken ATTN: Beth ~ ~~~~ JUN ~. ~ 2008 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD Please sign and return one copy of this transmittal to Beth at the above address ar fax to (907) 561-8317. Thank you. 2W-13 11970689 GLS/PROD PROFILE (~ 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE /~ - J 05/28/08 1 1 2M-08 11996642 PROD PROFILE/DEFT / fj 06/03!08 1 1 iB-10 11994672 PROD PROFILE/DEFT G 05/31/08 1 1 1A-20 11994673 PROD PROFILE/DEFT _/ 06/01/08 1 1 1G-13 11994674 PROD PROFILE/DEFT 3- ~(oS/5/~ 06/02/08 1 1 1A-03 11994673 PROD PROFILE/DEFT p~zr~y 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT _~ ~ ®~~~ 06/05/08 1 1 1C-125 11994677 INJECTION PROFILE -T - `.~!/i~/3fo 06/05/08 1 1 1C-127 11994675 INJECTION PROFILE _ L ~~t,~ , 06/03/08 1 1 1 F-09 11994671 PROD PROFILE/DEFT -/ ®~e.~~ 05/30/08 1 1 iC-27 11994679 SBHP SURVEY ~`(~ ®~e/ 06/07/08 1 1 • • Scblumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job# 1R·27 31-08 2M-19 3G-26 1R-18 1Y-01 2C-08 3H-32 1Y -10 3G-08 1A-06 2N-337B 2U-08 1G-12 2N-343 2N-327 2N-327 3K-01 2X-04 2Z-29 2X-19 1A-20 1 F-13 1H-10 1Q-10 2U-05 2D-12 2H-06 11850425 11839638 11813070 11813071 11837482 11813072 11813073 11837483 11837485 11813075 11837486 11837489 11813076 11837490 11745232 11837491 11837491 11632749 11846430 11850419 11850420 11850421 11850422 11846432 11846431 11846433 11846434 11846435 (5, NO. 4384 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 2 '7 LOG7 J '1no,? ....n t>.\}G ~ 1 I ,,'J SíJANNt;.ioI Log Description Date BL Color CD FPIT ¡q / - 10;) LDL 1'1r(,,-rHt\ INJECTION PROFILE 11...1' .0, I - ~2 LDL ,0,'1 -/")-;¡.-¿:; SBHP/DDL JC7/ -.I"\'f>'?- INJECTION PROFILe U~ - /'x3-c:fÇå INJECTION PROFILE' OTI" /1r:"Z. -{·~:t< LDL ..::Jt'ñ - Ñ1 t INJECTION PROFILE U:t.Q.. 1'5f~ -rfÇ""" ~ PRODUCTION PROFILE· ¡"h - (J c.,S- INJECTION PROFILE U-r.~ ./"ifI-I1l.-. PRODUCTION PROFILE ·,qN ~ -If..., LDL WI7t I~-~I PRODUCTION PROFILE I~?.. - I?';), MEM INJECTION PROFILE . ()T(' ¡4"1r-,-A::J SONIC SCANNER Db -:t-o<ot:'!¡ SONIC SCANNER-FMI ~h",,-,...,r.L:I. PRODUCTION PROFILE . l"'iff.o - IDf INJECTION PROFILE (J'T..(' loSI~ -1I"k SBHP SURVEY I~';')::A SBHP SURVEY I q ö - ¡',kÇ SBHPSURVEY I~h-H_~ SBHPSURVEY ljJù0 /~~~~~ SBHP SURVEY Jq~ -~ SBHP SURVEY 1'1f4 - JC:Vx INJECTION PROFILE I 1-:I:t". /!ir.-Ç" - tìI--K PRODUCTION PROFILE I ~I.I - rl74 LDL J¿¡ç,C; -/IAC{ 08/18/07 07/28/07 07/29/07 07/30/07 07/31/07 07/31/07 08/01/07 08/01/07 08/03/07 08/04/07 08/04/07 08/06/07 08/06/07 08/07/07 08/08/07 08/08/07 08/08/07 08/12/07 08/13/07 08/13/07 08/13/07 08/14/07 08/14/07 08/14/07 08/14/07 08/15/07 08/16/07 08/17/07 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ';)7{ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 08/22/07 . . 09/15/06 Scblumbel'gel' RECEJVEC~ NO. 3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SEP 1 5 2nn~ V·,U Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ C'Ü & Gas Cons. Ccmlr~jçn Anchorage . n lJJÛ~) /00 - / rod 'C c£\ì 1. CJ C'í"".I,~Nf1:.1 v Field: ".,w~" Kuparuk Well Log Description Job# Date BL Color CD 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 USIT 09/11/06 1 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 SBHP 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. . . 05/09/06 Scblumbel'gel' NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ \~'l/ Kuparuk \ ~ 0 ç~';~1I'o.!^!.' n:..C; JUN ~~n~'\1;,\1~-'j A",! tJ Field: Well CD Job # Log Description Date BL Color 1 Y -29 11213739 PRODUCTION PROFILE W/DEFT L~- (..~ I 04/28/06 1 3M-25A N/A SHUT IN BHP ! ~L.I - aGC:O 04/23/06 1 2N-303 N/A LDL :;).:0 -I¿~c; 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT \~ \- H3 04/25/06 1 3F-07 N/A INJECTION PROFILE /'Í(")-~ A4....- 04/23/06 1 1B-16 11235353 PRODUCTION PROFILE W/DEFT /c, I..../_(,"''":} 04/04/06 1 3B-15 11213741 INJECTION PROFILE ¡ 4<',<" , (~ ;:¡"'~ 04/30/06 1 1G-07 N/A PRODUCTION LOG W/DEFT I ~ :+ - rlf' \ 04/19/06 1 1A-20 11235356 PRODUCTION LOG W/DEFT I'ÎO - /ir.'.J 04/26/06 1 1H-18 N/A INJECTION PROFILE iCt ';4.- 1":16 04/24/06 1 1R-12 11213738 PRODUCTION LOG WIDEFT 1~5 -0'171 04/27/06 1 1 Y -13 11213740 INJECTION PROFILE 1""6~ _ C' \ ¿;;;u 04/29/06 1 2N-318 11213742 LDL dDC -¡OO 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE t c.; ''1 -¡,c.-:l, 05/02/06 1 1G-01 11213744 INJECTION PROFILE ¡ý'~- l~D 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT ¡c, (c, - r í..1"1- 05/04/06 1 1 R-26 11258705 INJECTION PROFILE ¡ c) I - (, C. ':::l. 05/05/06 1 2A-04 11249902 INJECTION PROFILE ¡ ,:,!.../ - I' <=? 05/06/06 1 1G-06 11249903 INJECTION PROFILE /1.f d - ;:}~D 05/07/06 1 1 E-1 8 11216193 MEMORY PRODUCTION PROFILE {"'(2,- ..., (.., 05/07/06 1 1G-14 11249904 INJECTION PROFILE ¡~3--1':"11 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 P E E L E W A T ER IA L U N D E TH IS M ARK ER R STATE OF ALASKA AL~;sKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RI=COMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS [~] SUSPENDED ~ ABANDONED [~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-162 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of welt at surface 1091' FSL, 314' FWL, SE(:; 5, T11N, R10E, UM At Top Producing Interval 2232' FSL, 40' FWL, SEC 4, T11N, R10E, UM At Total Depth 2256' FSL, 546' FWL, SEC 4, T11N, R10E, UM 5 Elevation in feet (indicate KB, DF, etc.) RKB 102', PAD 67' GL 12 Date Spudded 12/13/90. 17 Total Depth (MD+TVD) 9034' MD, 6721' TVD 13 Date T.D. Reached 12/18/90. 6 Lease Designation and Sedal No. ADL 25848 ALK 466 14 Date Comp., Susp. or Al)end. 08/06/91. 19 Directional Survey 18 Plug Back Depth (MD+TVD) 8923'MD, 6647' TVD APl Numbs' 50-029-22112 g Unit or Lease Name KUPARUK RIVER 10 Well Number 1A-20 11 Fidd and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 15 Water Depth, if offshore ]16 No. of Completions NA feet MSL] 1 20 Depth where SSSV set 21 Thickness of permafrost 1798' feet MD 1500' APPROX 22 Type Electric or Other Logs Run DI L-/S FL/ML/CET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD J SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I'TOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 116' 24' 222 SX ASl 9-5/8' 36~ J-55 SURF 4960' 12-1/4" 1300 SX AS II1,470 SX 7" 26~ J-55 SURF 9010° 8-1/2" 275 SX CLASS G 24 Perforations open to Production (MD+TVD of Te interval, size and number) 8344'-8407' W/4-1/2" CSG GUN @ 10/5 SPF MD 8426'-8434' W/4-1/Z' CSG GUN @ 5 SPF MD 8480'-8506' W/4-1/2' CSG GUN @ 10 SPF MD 8747-8755' W/4-1/2" CSG GUN @ 4 SPF MD 8770'-8810' W/4-1/2' CSG GUN @ 4 SPF MD and BoRom and 6251'-6295' TVD ~'-6313 'I'VD 6345'-6363' TVD 6526'-6531' TVD 654Z-6569' TVD 25 TUBING RECORD SIZE DEPTH SET (MD) 4", 3-1/2", 2-7/8' 8677' 'PACKER SET (MD) 8265', 8459', 8624' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL IMD} I AMOUNT & KIND OF MATERIAL USED I 8610'-8612', 8570'-8572' [30BBLS CLASS G CMT. 8448'-8450' I1 BBLS CLASS G CMT. 27 PRODUCTION TEST tDate First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL [ CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ FiowTubing . Casing Press[ue CALCULATED OIL-BBL GAS-MCF WATER-BBL JOIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ I 28 CORE DATA ..~ ~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE !29. - 30, ~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 8343 6251 NA KUPARUK C BOTTOM 8505 6362 KUPARUK A TOP 8733 6517 KUPARUK A BOTrOM 8897 6628 31. LIST OF A'I"TACHMENTS GYRO, REPORT OF OPERATIONS ) ~ ~ ~_ / ~Jr', ~ 32. I hereby certify that the foregoing is true and correct t~) the best of my knowledge ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. 'item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: RECEIVED NORTH SLOPE KU?ARUK RIVER UNZT KUPARUK RIVER FIELD ADL 25648 ALK 466 - 4 t992 50-029-22112 90-162 Alaska Oil& ~as Cons.~ommiss~on chqrage ACCEPT: 07/22/91 SPUD: RELEASE: 08/06/91 OPERATION: COMPLETION RIG: NORDIC AFE: AK5458 WI: 55.252072 07/23/91 (21) TD: 0 PB: 8923 SUPV:DB 07/24/91 (22) TD: 0 PB: 8923 SUPV:DB 07/25/91 (23) TD: 0 PB: 8923 SUPV: DB 07/26/91 (24) TD: 0 PB: 8923 SUPV:DB 07/27/91 (25) TD: 0 PB: 8923 SUPV: DB TESTING BOPE 7"@ 9010' MW:10.6 NaCl/Br ACCEPT RIG @ 2300 HRS 7/22/91,ND DRY HOLE TREE & TBG SPOOL NU 11" 3K X 5K DSA, HANG 11" BOP STACK AND FLOW NIPPLE IN CELLAR, MOVE OVER WELL,LEVEL RIG, NU 11" 5K BOPE & FLOW NIPPLE TEST BOPE DAILY:S38,347 CUM:$1,504,002 ETD:S1,504,002 EFC:$1,820,000 WORK ON WEIGHT INDICATOR 7"@ 9010' MW:10.6 NaC1/Br CHANGE PIPE RAMS TO 3-1/2",CONT TEST BOPE,PULL TEST PLUG, SET WEAR BUSHING, RACK AND TALLY 3-1/2" DP,RIH OPEN ENDED TO 3008' (DID NOT SEE TOP OF 7" @ 2316'), CIRC ONE HOLE VOL.,MIX AND PUMP DRY JOB, POH,MU BHA#1:8-1/2" SWAGE, XO, BUMPER JAR, OIL JAR, XO, 8 6-1/4" DC,XO,12 4-3/4" DC, RIH W/BHA#1,TOOK 2K WEIGHT @ 524'- 527',SWAGE TO 8-1/2",SWAGE OTHER TIGHT SPOTS @ 579' -581',589'-594',693'-747', WORK SWAGE THRU TIGHT SPOTS 2-3 TIMES,WORK ON WEIGHT INDICATOR DAILY:S32,500 CUM:$1,536,502 ETD:S1,536,502 EFC:$1,820,000 BACK OFF 7" CSG STUB 7"@ 9010' MW:10.6 NaC1/Br SERVICE RIG, C/O WEIGHT INDICATOR, CONT. SWAGE TO 747',RIH TO 2312',CBU @ 2-1/4 BPM/250 P$I,POH,C/O SWAGE TO 8-5/8",RIH TO 521',WORK SWAGE THRU TIGHT SECTION TO 747',CONT RIH TO 2310' CBU @ 3 BPM/400 PSI,POH, LD 6-1/4" DC/SWAGE/JARS/BSUB RIH W/10 STDS 3-1/2" DP/12 4-3/4" DC,MURIH W/ TRISTATE BACKOFF TOOL, SET BACK- OFF TOOL, BREAK CONNECTION W/1500 PSI @ 2343' DAILY:S28,147 CUM:$1,564,649 ETD:S1,564,649 EFC:$1,820,000 CIRC BRINE/MIX CEMENT 7"@ 9010' MW:10.6 NaCl/Br SHEAR PUMPOUT SUB, REVERSE OUT DP, POH W/TRISTATE BACKOFF TOOL,MU SPEAR, SLIP & CUT DRLG LINE,RIH W/ SPEAR ON 3-1/2" DP CHECK TORQUE ON DP GOING IN, KELLY UP ATTEMPT TO SPEAR & BACKOFF 7" CSG STUB, STAND BACK KELLY,POH W/SPEAR-NO FISH, C/O GRAPPLE AND ADD 15' PUP BETWEEN STOP SUB AND XO,RIH W/ SPEAR, KELLY UP, SPEAR AND BACK OFF 7" CSG STUB, STAND BACK KELLY,POH W/SPEAR AND FISH, LD SPEAR AND 27.2' CSG STUB,PULL WEAR RING, RU TO RUN 7" CSG, MU SCREW IN ADAPTER, 1JT 7", STAGE COLLAR, LEFT AND RT HAND CENTRALIZERS,RIH W/7" CSG, TAG 3' OUT ON JT# 56, SCREW INTO 7" CSG, PULL 140K,MU CMT LINES,MIX CMT CIRC BRINE TO ENSURE CSG IS CLEAR DAILY: $29,303 CUM:$1,593,952 ETD:S1,593,952 EFC:$1,820,000 TESTING KELLY - 3000 PSI 7"@ 9010' MW:10.4 NaC1/Br CIRC. BRINE,MIX/PUMP CMT,GOOD RETURNS THRU-OUT JOB, BUMPED PLUG W/2000 PSI,PLUG HELD,FLUSH/BLOW DN LINES,ND/FLUSH STACK PICK UP 130K#,SET SLIPS,CUT OFF 7"CSG, LD LANDING JT, SET PACKOFF,NU TBG SPOOL, TEST PACKOFF-3000 PSI,RU TO RIH W/BIT, REPAIR/TEST #3 VALVE ON CHOKE MANIFOLD-3000 PSI,RIH W/BIT ON 3-1/2" DP,TAG CMT @ 2292',PU KELLY,DRLG PLUG/FC, RACK/TALLY DP,CONT. RIH W/DP TO 7999',PU KELLY, DRLG EZSV, TEST KELLY-3000 PSI DAILY:S87,274 CUM:$1,681,226 ETD:S1,681,226 EFC:$1,820,000 WELL: lA-20 OPERATION: COMPLETION RIG: NORDIC PAGE: 2 07/28/91 (26) TD: 0 PB: 8923 SUPV:DB 07/29/91 (27) TD: 0 PB: 8923 SUPV:DB 07/30/91 (28) TD: 0 PB: 8923 SUPV:DB RIH W/CMT RET. ON E-LINE 7"@ 9010' MW:10.5 NaC1/Br SERVICE RIG, BLOW DN KELLY/STAND BACK, RIH W/BIT,PUSH PLUG TO BTM-8897',TEST 7" CSG, LOST 120 PSI/30 MIN, CBU, REV CIRC 2 DP VOL, POH W/BIT,MU 7" CSG SCRAPER/BIT, RIH TO 2360',REAM 2274'-2317'/10 TIMES,POH W/7" CSG SCRAPER/BIT,RU SWS,MU PERF GUN, PRESS TEST LUBR TO 500 PSI,RIH/TIE IN/SHOOT 8610'-8612' & 8448'-8450'/4SPF POH,MU GR/JB, RIH TO 8820',POH RECOVER IRON & BRASS,MAKE TWO MORE PASSES TO 8820',POH RECOVER IRON & BRASS,LD GR/JB,MU HALLIBURTON EZSV ON E-LINE RIH/SET @ 8640' (WLM),POH,MU CMT RETAINER, RIH DAILY:S60,244 CUM:$1,741,470 ETD:S1,741,470 EFC:$1,820,000 POH W/BIT 7"@ 9010' MW:10.5 NaCl/Br CONT RIH W/CMT RET, SET SAME @ 8475' (WLM),POH/RD SWS,RU FLOW NIPPLE/LINE,MU HALLIBURTON CMT RET. STINGER/PLUG CATCHER ON 3-1/2" DP,TIH TO CMT RET. @ 8465' (NORDIC RKB),RU HALLIBURTON LINES/CMT HEAD,BREAK CIRC, STING INTO RET ATTEMPT TO EST INJ. RATE ON BTM SQUEEZE PERFS 8610'-8612' PRESS TO 3000 PSI,UNABLE TO INJ, SURGE PRESS TO BRK DN FORMATION, PRESS TO 3500 PSI,UNABLE TO INJ, PRESS UP TO 3500 PSI & UNSTING FROM RET W/PRESS ON PIPE,STING BACK INTO RET AND SAW PRESS INCR. ON DP,PRES TO 3500 PSI & HOLD PRESS ON FORMATION, PRESS BLED TO 2100 PSI IN 6 MIN, CONT TO SURGE FORM. W/3500 PSI,LOST SEAL IN RETAINER, UNSTING CLOSE ANNULAR & EST INJ. RATE ON TOP PERFS @ 8448'-8450'/2 BPM-2400 PSI RD HALLIBURTON, POH LD PLUG CATCHER & STINGER,MU 6-1/8" BIT, 2 JB, TIH TO CMT RET @ 8465',DRILL UP RET.,PUSH JUNK DOWNHOLE TO BRIDGE PLUG AT 8638' (DPM),BLOW DOWN STAND BACK KELLY,REV CIRC HOLE, SLIP & CT DRLG LINE,PULLING OUT OF HOLE W/BIT#2 DAILY:S53,141 CUM:$1,794,611 ETD:S1,794,611 EFC:$1,820,000 CIRC/WAIT ON HOWCO 7"@ 9010' MW:10.5 NaC1/Br FPOH, EMPTY JB, PU 7" CSG SCRAPER, TIH TO BP,PU KELLY,VERIFY TAG ON BP,STD BACK KELLY, REV CIRC HOLE CLEAN, POH SLM (2' CORRECTION ON DP STRAP),BP @ 8627' (DPM) RU SWS,TEST LUBR. MU 3-3/8" PERF GUN/4 SPF,RIH SHOOT SQUEEZE PERFS F/8570'-72' POH, LD PERF GUN, PU 6.05" GR/JB, RIH TO 8520' (WLM) POH, LD GR/JB,MU HOWCO CMT RET RIH & SET @ 8479' (WLM),POH, RD SWS,RU FLOW NIPPLE/LINE,MU HOWCO STINGER & PLUG CATCHER ON DP,RIH TAG CMT RET @ 8469' (DPM),RU HOWCO LINES,BREAK CIRC STING INTO RET,EST INJ. RATE-2 BPM/3150 PSI,WAIT ON HOWCO (UNIT HAD FLAT TIRE ON WAY TO RIG-WHEEL COMING FROM PRUDHOE) DAILY:S39,997 CUM:$1,834,608 ETD:S1,834,608 EFC:$1,820,000 RECEIVED FEB - 4 '199 Alaska Oil & i~as Cons. Commission Anchorage WELL: lA-20 OPERATION: COMPLETION RIG: NORDIC PAGE: 3 07/31/91 (29) TD: 0 PB: 8923 SUPV: GB 08/01/91 (30) TD: 0 PB: 8923 SUPV:GB 08/02/91 (31) TD: 0 PB: 8923 SUPV:GB/DB CIRC HOLE CLEAN 7"@ 9010' MW:10.5 NaC1/Br CIRC/WAIT ON HOWCO,BATCH MIX 150 SX CLASS 'G' CMT @ 15.8 PPG TEST LINES-3500# PUMP 25 BBLS H20,30 BBLS CMT, 1 BBL H20,DROP WIPER BALL, PUMP 4 BBLS H20,HOLD BACK PRESS W/CHOKE, SPOT CMT @ RET.,STING INTO RET,DISPLACE CMT W/51 BBLS BRINE INITIAL SQUEEZE PRESS=2500 PSI @ 1.5 BPM, FINAL SQUEEZE PRESS=2950 PSI @ 1 BPM, UNSTING FROM RET, REV OUT 1 BBL CMT F/DP,BATCH MIX 150 SX CLASS 'G' CMT @ 15.8 PPG, PUMP 10 BBLS H20,30 BBLS CMT, 1 BBL H20, DROP WIPER BALL,PUMP 1.5 BBL H20, DISPLACE W/31 BBL BRINE, PUMP PRESS INCREASED F/1600 PSI TO 3550 PSI DP PLUGGED OFF WITH 22.5 BBLS CMT IN DP,7.5 BBLS CMT IN ANNULUS,SURGE PRESS IN ATTEMPT TO UNPLUG DP,ATTEMPT TO UNPLUG BY REV CIRC,UNABLE TO MOVE CMT, LEFT 3421' CMT IN DP POH 12 STDS,CLOSE ANNULAR BAG AND INJ 12 BBLS BRINE DOWN ANNULUS TO CLEAN OUT SQUEEZE PERFS,POH 47 STDS,CLOSE ANNULAR AND INJ 11 BBLS DOWN ANNULUS TO KEEP SQUEEZE PERFS @ 8450-52' (WLM) OPEN, CONT POH,FOUND TOP OF CMT IN STD #79, CONT POH BREAKING SINGLES & WASHING OUT CMT F/DP,CMT TO FIRM TO WASH OUT W/ HOSE @ STD #100,POH AND STD REMAINING DP IN DERRICK, LD HOWCO STINGER AND BALL CATCHER, RIH W/DP AND BLOW OUT CMT W/RIG PUMP,CLEANED CMT OUT OF 89 JTS,LEFT CMT IN 20 JTS,LAY DN SAME,TIH W/98 JTS CMT CONT. DP,CIRC TO CLEAN UP SAME,DROP WIPER DART & PUMP THRU DP,POH,MU 6-1/8" BIT ON DC'S,TIH, TAG FILL @ 8388' (DPM), PU KELLY,WASH DN TO 8437' DRILL FIRM CMT F/8437'-49',CLOSE ANNULAR & INJ INTO SQUEEZE PERFS @ 2 BPM/2000 PSI,CIRC HOLE CLEAN DAILY:S28,147 CUM:$1,862,755 ETD:S1,862,755 EFC:$1,820,000 RIH W/6 1/8" BIT ON DP 7"@ 9010' MW:10.5 NaCl/Br CONT CIRC,CHANGE SHAKER SCREEN TO 80 MESH,BLOW DN/STD BK KELLY, PU SINGLE AND POH TO 8442',REV CIRC HOLE VOL @ 4 BPM/1250 PSI,SLIP/CUT DRLG LINE, SERVICE RIG POH W/DP & BHA EST INJ RATE 2.1 BPM/1700 PSI,HOLD SAFETY MTG, RIH W/3 1/2" DP OPEN ENDED, TAG CMT @ 8449',RU HOWCO, TEST LINES TO 3500 PSI,EST INJ RATE 2 1/4 BPM/2250 PSI,BATCH MIX 150 SX CMT (CFR-3,HR-5,HALAD 344-L),PUMP 10 BBL H20,30 BBL CMT, 1 BBL H20,DROP DART,PUMP 1.5 BBL H20,46 BBL BRINE,BREAK OFF CIRC HEAD POH 19 STDS DP,ATTEMPT TO SQUEEZE CMT @ 3500 PSI,PUMPED 3 BBLS,RELEASED PRESS 2 BBLS BACK, CBU @ 4 BPM/900 PSI,PRESS DP TO 3500 PSI,HOLD PRESS,RD HOWCO,WOC W/3500 PSI ON DP,POH W/DP,DRIFT DP WHILE POH,MU 6 1/8" BIT ON DP & RIH DAILY:S75,729 CUM:$1,938,484 ETD:S1,938,484 EFC:$1,820,000 DRILLING EZSV @ 8625' 7"@ 9010' MW:10.5 NaCl/Br SERVICE RIG, CHECK CROWN-O-MATIC, FUNCTION TEST BOPE,CONT RIH TAG CMT @ 7739',PU & SERVICE KELLY, DRILL CMT F/7739--8457' CBU, TEST PERFS @ 8448'-8450'WLM 1960 PSI F/30 MIN, LOST 130 PSI,BLEED OFF PRESS,CONT DRLG CMT/EZSV F/8457'-8580',CBU TEST PERFS @ 8570'-72'WLM 2020 PSI F/30 MIN, LOST 140 PSI BLEED OFF PRESS,CONT DRLG CMT AND EZSV F/8580'-8610',CB TEST PERF$ @ 8610'-12'WLM 2000 PSI F/30 MIN, LOST 110 PSI BLEED OFF PRESS,CONT DRLG CMT/EZSV F/8610'-8625',TAG & DRILL EZSV @ 8625' DAILY:S39,555 CUM:$1,978,039 ETD:S1,978,039 EFC:$1,820,000 WELL: lA-20 OPERATION: COMPLETION RIG: NORDIC PAGE: 4 08/03/91 (32) TD: 0 PB: 8923 SUPV:GB/DB 08/04/91 (33) TD: 0 PB: 8923 SUPV:GB/DB 08/05/91 (34) TD: 0 PB: 8923 SUPV: GB/DB 08/06/91 (35) TD: 0 PB: 8923 SUPV:GB/DB ?OH W/3-1/2" DP AND BHA 7"6 9010' MW:10.5 NaC1/Br CONT DRLG EZSV @ 8625',SERVICE RIG/KELLY, BLOW DN/STD BK KELLY, PUSH EZSV TO 8897'DPM (8907' WLM),CIRC HOLE CLEAN @ 4 BPM/ll00 PSI,CHANGE LWR SHAKER SCREEN TO 100 MESH,POH W/3 1/2" DP AND BHA, RU SWS,MU CET,CBL, GR, CCL, RIH TO 8800',LOG UP TO 7700'WLM, POH TO 3000'WLM, LOG TO SURFACE,RD SWS,RIH W/6 1/8" BIT AND 7" CSG SCRAPER ON DP,TAG FILL @ 8886'DPM, WASH DN F/8886' TO 8893',CLEAN PITS, TRANSFER 200 BBLS 10.5 PPG CLEAN BRINE TO RIG PITS,REV CIRC HOLE TO 10.5 PPG CLEAN BRINE @ 4 BPM/1550 PSI,?OH W/DP AND BHA DAILY:S53,528 CUM:$2,031,567 ETD:S2,031,567 EFC:$1,820,000 PERFORATING 7"6 9010' MW:10.5 NaC1/Br CONT ?OH W/3 1/2" DP AND BHA, LD BIT AND SCRAPER, RU HLS,TEST LUBRICATOR TO 650 PSI,PERFORATE WELL W/4 1/2" CSG GUNS AS FOLLOWS: GUN#l-4 SPF F/8790'-8810',GUN #2-4 SPF F/8770'-8790',GUN#3-8'@4 SPF/8'@5 SPF F/8747'-8755' (TOP 8'NSF),GUN#4- 5 SPF F/8427'-8435',GUN#5-ORIENTATION FAILURE GUN#5 RERUN-ORIENTATION FAILURE, GUN#5 RERUN-NAVPACK FAILURE CUT 250' E-LINE,REHEAD,GUN#5 RERUN-5 SPF F/8486'- 8506' GUN#6-5 SPF F/8486'-8506',GUN#7-5 SPF F/8428'-8434',GUN#8-5 SPF F/8480'- 8486' DAILY:S29,162 CUM:$2,060,729 ETD:S2,060,729 EFC:$1,820,000 ?OH LAYING DOWN DP 7"6 9010' MW:10.5 NaCl/Br CONT PERF W/4 1/2" CSG GUNS: GUN#9-5 SPF F/8384'-8407' (20% MISFIRED SHOTS), GUN#10-5 SPF F/8364'-8384',GUN#ll-5 SPF F/8364'-8384',GUN#12-5 SPF F/8364'- 8384',GUN#13-5 SPF F/8344'-8364',GUN#9 RERUN-2 SPF F/8387'-8407',RIH W/6.05" GR/JB TO 8740',MAKE 4 PASSES ACROSS PERF INTERVALS,POH,MU TAILPIPE(2 7/8"SOS, 2 7/8" X 10' PUP, 2 7/8" 'D' NIPPLE W/2.25" NO-GO,1 JT 2 7/8" TUBING) AND PERM PACKER (3 1/2" TIW 'SS BB'W/5' SBE),RIH ON E-LINE, SET PACKER AT 8623'WLM ?OH W/PACKER SETTING TOOL, RD HLS,RU/RIH W/12 DC'S,POH AND LD SAME,RIH W/3 1/2" DP ?OH LD SAME DAILY:S34,454 CUM:$2,095,183 ETD:S2,095,183 EFC:$1,820,000 WAIT ON SLICKLINE 7"6 9010' MW:10.5 NaC1/Br CONT POH & LD DP,LOAD OUT DP F/PIPE SHED,PULL WEAR RING, RU TO RUN COMP,RACK & TALLY 4" & 3 1/2" TBG, DRIFT& INSTALL SEAL RINGS,PU AND RIH W/4" X 3 1/2" TRIPLE PACKER COMP. AS PER WELL PLAN,?U/MU CAMCO TRDP-4A SSSV, MU C-LINE & TEST TO 5000 PSI,CONT RIH W/COMP,PU LANDING JT,S?ACE OUT,MU TBG HGR ATTACH C-LINE, TEST TO 5000 PSI F/10 MIN, LAND TBG, RILDS PRESS TBG TO 3500 PSI TO SET PKR, SOS SHEARED EARLY AT 350 PSI (PINNED TO SHEAR @ 4200 PSI),WAIT ON SLICKLINE TO SET STANDING VALVE IN 'D' NIPPLE DAILY:S116,281 CUM:$2,211,464 ETD:S2,211,464 EFC:$1,820,000 RECEIVED FEB - 4 t992 Alaska Oil & Gas Cons. Commission Annhnrar~e WELL: lA-20 OPERATION: COMPLETION RIG: NORDIC PAGE: 5 08/07/91 (36) TD: 0 PB: 8923 SUPV:GB/DB RIG RELEASED 7"@ 9010' MW:10.5 NaCl/Br WAIT ON OTIS SLICKLINE, LOAD OUT UNUSED TBG F/PIPE SHED,RU SLICKLINE,RIH/SET STANDING VALVE IN D NIPPLE @ 8665',POH W/SLICKLINE,PRESS TO 3500 PSI TO SET BAKER 'HB' PKRS,HOLD PRESS ON TBG @ 3500 PSI,PRESS ANNULUS TO 1000 PSI FOR 15 MIN BLEED OFF ANN/TBG TO 1200 PSI,BACK OUT LDS,PU AND SHEAR PBR @ 94K UP WT, RELAND TBG AND PRESS TEST SSSV W/500 PSI DIFF PRESS TEST ANNULUS TO 2500 PSI F/15 MIN, RIH W/SLICKLINE AND RETRIEVE STANDING VALVE,RD SLICKLINE, SET BPV, ND FLOW RISER AND BOPE,NU MCEVOY GEN IV TREE,TEST TBG HD TO 5000 PSI,TREE TO 250/ 5000 PSI,DISPLACE ANNULUS W/ll BBLS DIESEL,BULLHEAD 5 BBLS DIESEL DOWN TBG, SECURE WELL, RELEASE RIG AT 1600 HRS 8/7/91,MOVE TO 1D-06 DAILY:S420,669 CUM:$2,632,133 ETD:S2,632,133 EFC:$1,820,000 ADDENDUM lA-20 FRA C/S TIMULATI O N SUMMARY 09/20/91 #995100 1A-20 Stage 1. Stage 2 ISIP: 2375 Stage 3 Stage 4 Stage 5 Stage 6 *Stage 7 Frac KRU "A" sand peals from 8747'-8755', 8770'-8810' @ 4 spf in 7 stages as follows: Prop 3oobbls 240D XL GW H20 Prepad @ 24-40 bpm 7800- 6790psi Pmp 90bbls 240D Non XL Flush@ 40 bpm 6790-6960psi FRAC GRAD: .80 PERF FRIC: 1029 Pump 500bbls 240D XL Gel H20 Pad@ 40bpm 6220-6820psi Pmp 156 bbls 240D XL GW w/2ppg 16/20 Carbolite@ 40 bpm 6820- 6920psi Pmp 85 bbls 240D XL GW w/4ppg 12/18 Carbolite @ 40 bpm 6920- 6880 psi Pmp 103 bbls 240D XL GW w/6ppg 12/18 Carbolite @ 40/35 bpm 6880-6350-6480 psi Pmp 67bbls 240D XL GW w/8ppg 12/18 Carbolite @ 35/30 bpm 6480- 8100psi * Screenout to 8100 w/6.5ppg 12/18 Carbolite @ peals Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 6,800 psi 1244bbls H20,57 Diesel 49,555 # 16/120Carbolite 21,850 # 12/18 Carbolite Drill~g ~~up tehden~ Date RECEIVED FEB - 4 992 Alaska Oil & Gas Cons. budlmissiOn Anchorage A G':/~.-odata Dir. ectional ARCO Alaska~ Irlc. ~. .m t") Kupar. uk Rive~- Un'it.~ Well J~.-...._ No~th Slope Bu~eau~ Alaska Oate_ Il / ~]/ RECEIVED FE 9 - 4 t99~_ Alaska Oil & 13as uons. Anchorage Submi4;ted By: G~r-odata Set-vices, inc. 3 ~' 05 Lal.::e,~hor-e Dp.,, A-304 Anchor-ac~e, Alaska 9,¢1~ ~Az ~'~ (907) ~.~-=.z,~c~l ( ) "'~' , . . REAT LAND DIRECTIONAL DRILLING, INC. lient .... : ARCO ALASKA, INC. ield ..... : KUPARUK RIVER UNIT ell ...... : KRU lA-20 ection at: N,77.28,E urveyors.: J.C. STUART/T. STODDARD for Gyrodata Services, Inc. Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Number .... : 01/24/91 RADIUS OF CURVATURE 01/03/91 102.00 ft AK0191G262 50-029-22112 MEAS INCLN DEPTH ANGLE VERTICAL-DEPTHS BKB SUB-SEA 0 0.00 0.0 -102.0 100 0.15 100.0 -2.0 200 0.28 200.0 98.0 300 0.44 300.0 198.0 400 0.66 400.0 298.0 RECORD OF SURVEY SECTION DIRECTION DISTNCE BEARING 0.0 N 0.00 E 0.1 N 81.60 E 0.5 N 84.99 E 1.1 N 86.63 E 2.0 N 82.23 E RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DL DISTNCE BEARING /100 0.0 N 0.0 E 0.0 N 90.00 E 0.00 0.1 N 0.1 E 0.1 N 40.80 E 0.15 0.1 N 0.5 E 0.5 N 73.37 E 0.13 0.2 N 1.1 E 1.1 N 80.49 E 0.16 0.3 N 2.0 E 2.1 N 82.33 E 0.22 500 2.05 500.0 398.0 4.4 N 79.45 E 600 5.23 599.7 497.7 10.7 N 78.54 E 700 8.46 699.0 597.0 22.7 N 76.63 E 800 12.3.5 797.4 695.4 40.7 N 74.46 E 900 14.24 894.7 792.7 63.7 N 77.92 E 0.7 N 4.4 E 4.4 N 81.53 E 1.39 1.9 N 10.6 E 10.8 N 80.04 E 3.18 4.4 N 22.2 E -22.7 N 78.75 E 3.23 8.9 N 39.7 E 40.7 N 77.33 E 3.89 14.4 N 62.0 E 63.7 N 76.92 E 1.90 1000 16.12 991.2 889.2 89.9 N 80.83 E '1100 17.90 1086.8 984.8 119.0 N 82.17 E 1200 19.46 1181.5 1079.5 150.9 N 83.82 E 1300 22.47 1274.9 1172.9 186.4 N 85.21 E 1400 24.94 1366.5 1264.5 226.3 N 84.26 E 19.2 N 87.8 E 89.9 N 77.63 E 1.89 23.6 N 116.7 E 119.1 N 78.58 E 1.78 27.5 N 148.5 E 151.0 N 79.52 E 1.57 30.9 N 184.1 E 186.7 N 80.47 E 3.02 34.6 N 224.1 E 226.8 N 81.23 E 2.48 1500 27.36 1456.2 1354.2 270.0 N 83.77 E 1600 32.46 1542.9 1440.9 319.6 N 81.70 E 1700 34.14 1626.4 1524.4 374.4 N 80.38 E 1800 37.25 1707.6 1605.6 432.7 N 79.10 E 1900 42.54 1784.3 1682.3 496.8 N 77.53 E 39.2 N 268.0 E 270.8 N 81.68 E 2.42 45.5 N 317.4 E 320.7 N 81.85 E 5.13 54.0 N 371.6 E 375.5 N 81.73 E 1.73 64.4 N 429.0 E 433.9 N 81.46 E 3..15 77.4 N 491.8 E 497.9 N 81.06 E 5.34 2000 47.11 1855.2 1753.2 567.3 N 76.61 E 93.2 N 560.5 E 568.2 N 80.56 E 4.60 Survey Codes: 7/GYRO KRU1A20G) RU lA-20 Page 2 01/24/91 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 2100 48.50, 1922.4 1820.4 641.4 N 78.09 E 109.4 N 632.8 E 2200 48.19 1988.9 1886.9 716.1 N 78.05 E 124.8 N 705.9 E 2300 48.05 2055.6 1953.6 790.5 N 78.44 E 140.0 N 778.8 E 2400 47.91 2122.6 2020.6 864.8 N 77.63 E 155.4 N 851.5 E 2500 47.31 2190.0 2088.0 938.7 N 78.25 E 170.8 N 923.7 E 2600 46.80 2258.1 2156.1 1011.8 N 78.38 E 2700 46.53 2326.7. 2224.7 1084.5 N 79.61 E 2800 46.30 2395.7 2293.7 1156.9 N 79.38 E 2900 46.48 2464.7 2362.7 1229.3 N 78.03 E 3000 46.22 2533.7 2431.7 1301.6 N 78.93 E 3100~ 46.13 2602.9 2500.9 1373.7 3200 46.40 2672.1 2570.1 1445.9 3300 47.67 2740.2 2638.2 1519.1 3400 47.60 2807.6 2705.6 1592.9 3500 46.84 2875.5 2773.5 1666.3 N 79.57 E N 79.41 E N 78.95 E N 79.10 E N 79.35 E 185.7 N 995.4 E 199.6 N 1066.8 E 212.8 N 1138.0 E 226.9 N 1209.0 E 241.4 N 1279.9 E 3600 46.71 2944.0 2842.0 1739.1 3700 47.45 3012.1 2910.1 1812.4 3800 47.20 3079.9 2977.9 1885.9 5900 46.29 3148.4 3046.4 1958.7 4000 45.36 3218.1 3116.1 2030.4 254.9 N 1350.8 E 268.0 N 1421.8 E 281.8 N 1493.7 E 295.8 N 1566.2 E 309.6 N 1638.3 E N 77.85 E 324.0 N 1709.8 E N 76.77 E 340.0 N 1781.2 E N 76.79 E 356.9 N 1852,8 E N 76.69 E 373.6 N 1923.7 E N 76.70 E 390.1 N 1993.5 E 4100 45.01 3588.6 3186.6 2101.3 N 75.63 E 4200 44.14 3359.'8 3257.8 2171.5 N 76.10 E 4300 43.93 3431.7 3329.7 2241.0 N 77.00 E 4400 44.63 3503.3 3401.3 2310.8 N 77.21 E ,4500 44.31 3574.7 3472.7 2380.9 N 77.87 E 4600 44.07 3646.4 3544.4 2450.6 N 78.11 E ;u~vey Codes: 7/GYRO 407.0 N 2062.3 E 424.2 N 2130.4 E 440.3 N 2198.0 E 455.9 N 2266.1 E 471.0 N 2334.5 E 485.5 N 2402.6 E CLOSURE DL DiSTNCE BEARING /100 642.2 N 80.19 E 1.62 716.9 N 79.97 E 0.31 791.3 N 79.81 E 0.26 865.5 N 79.66 E 0.47 939.4 N 79.52 E 0.69 1012.6 N 79.43 E 0.51 1085.3 N 79.40 E 0.70 1157.7 N 79.41 E 0.26 1230.1 N 79.37 E 0.73 1302.5 N 79.32 E 0.54 1374.6 N 79.32 E 0.34 1446.9 N 79.32 E 0.28 1520.0 N 79.32 E 1.'29 1593.9 N 79.30 E 0.11 1667.3 N 79.30 E 0.77 1740.2 N 79.27 E 0.81 1813.4 N 79.19 E 0.94 1886.8 N 79.10 E 0.25 1959.6 N 79.01 E 0.91 2031.3 N 78.93 E 0.93 2102.1 N 78,84 E 0.64 2172.2 N 78.74 E 0.90 2241.7 N 78.67 E 0.48 2311.5 N 78.62 E 0.71 2381.5 N 78.59 E 0.45 2451.2 N 78.58 E 0.27 ~U lA-20 Page 3 01/24/91 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE DIRECTION BEARING 4700 45.48 3717.4 3615.4 2521.0 N 75.80 E 4800 45.51 3787.4 3685.4 2592.3 N 75.68 E 4900 44.64 3858.1 3756.1 2663.1 N 75.66 E 5000 45.02 3929.0 3827.0 2733.5 N 75.43 E 5100 45.30 3999.5 3897.5 2804.4 N 75.18 E 5200 45.54 4069.7 3967.7 2875.6 N 75.04 E 5300 45.56 4139.7 4037.7 2946.9 N 75.60 E 5400 45.86 4209.5 4107.5 3018.5 N 74.94 E 5500 45.54 4279.4 4177.4 3090.0 N 74.87 E 5600 45.83 4349.2 4247.2 3161.5 N 75.06 E 5700 46.04 4418.8 4316.8 3233.3 5800 46.20 4488.1 4386.1 3305.3 5900 46.34 4557.2 4455.2 3377.5 6000 46.63 4626.1 4524.1 3450.0 6100 46.91 4694.6 4592.6 3522.8 6200 46.93 4762.9 4660.9 3595.8 6300 47.21 4831.0 4729.0 3668.9 6400 47.47 4898.8 4796.8 3742.4 ~500 47.55 4966.3 4864.3 3816.1 6600 47.80 5033.6 4931.6 3889.9 N 74.76 E N 75.11 E N 75.28 E N 75.29 E N 75.54 E N 75.22 E N 74.84 E N 74.45 E N 74.71 E N 74.45 E 6700 47.95 5100.7 4998.7 3964.0 N 73.70 E 6800 48.05 5167.6 5065.6 4038.2 N 74.20 E 6900 46.73 5235.3 5133.3 4111.6 N 73.91 E 7000 46.17 5304.2 5202.2 4184.0 N 74.06 E 7100 45.76 5373.7 5271.7 4255.7 N 73.39 E 7200 45.57 5443.6 5341.6 4327.2 u~vey Codes: 7 / GYRO N 74.78 E RELATIVE-COORDINATES FROM-WELL-HEAD 501.4 N 2471.2 E 519.0 N 2540.4 E 536.5 N 2609.0 E 554.1 N 2677.2 E 572.1 N 2745.8 E 590.4 N 2814.7 E 608.5 N 2883.7 E 626.7 N 2952.9 E 645.3 N 3022.0 E 663.9 N 3091.1 E 682.6 N 3160.5 E 701.3 N 3230.1 E 719.8 N 3300.0 E 738.2 N 3370.1 E 756.6 N 3440.6 E 775.0 N 3511.3 E 793.9 N 3582.0 E 813.4 N 3653.0 E 833.0 N 3724.0 E 852.7 N 3795.3 E 873.0 N 893.6 N 913.8 N 933.8 N 953.9 N 973.5 N 3866.6 E 3938.1 E 4008.8 E 4078.5 E 4147.5 ~216.3 I LIJ CLOSURE DiSTNCE BEARING 2521.6 N 78.53 E 2592.8 N 78.45 E 2663.6 N 78.38 E 2734.0 N 78.31 E 2804.8 N 78.23 E 2875.9 N 78.15 E 2947.2 N 78.08 E 3018.7 N 78.02 E 3090.2 N 77.95 E 3161.6 N 77.88 E 3233.4 N 77.81 E 3305.4 N 77.75 E 3377.6 N 77.70 E 3450.0 N 77.64 E 3522.8 N 77.60 E DL /lOO 1.83 0.07 0.87 0.40 0.31 0.25 .0.29 0.45 0.32 0.31 O e- 0.26 0.24 0.17 0.29 0.31 3595.8 N 77.55 E 0.17 3669.0 N 77.50 E 0.35 3742.4 N 77.45 E 0.34 3816.1 N 77.39 E 0.16 3889.9 N 77.34 E 0.29 3964.0 N 77.28 E 0.44 4038.2 N 77.22 E 0.29 4111.6 N 77.16 E 1.33 4184.0 N 77.10 E 0.57 4255.8 N 77.05 E 0.54 4327.2 N 77.00 E 0.73 RU lA-20 Page 4 01/24/91 MEAS INCLN DEPTH ANGLE 7300 45.30 7400 45.81 7500 45.57 7600 44.40 7700 44.69 7800 44.95 7900 44.35 8000 44.26 8100 44.49 8200 45.34 8300 46.11 8400 46.64 8500 47.08 8600 47.39 8700 47.28 8800 47.43 8900 47.01 8908 47.00 ')034 47.00 Eurvey Codes: RECORD OF SURVEY VERTICAL-DEPTHS SECTION BKB SUB-SEA DISTNCE 5513.8 5411.8 4398.4 5583.8 5481.8 4469.7 5653.7 5551.7 4541.3 5724.4 5622.4 4612.0 5795.7 5693.7 4682.1 5866.6 5764.6 4752.6 5937.7 5835.7 4822.9 6009.3 5907.3 4892.7 6080.8 5978.8 4962.7 6151.6 6049.6 5033.1 6221.4 6119.4 5104.1 6290.4 6188.4 5175.5 6358.8 6256.8 5247.3 6426.7 6324.7 5319.6 6494.4 6392.4 5392.1 6562.2 6460.2 5464.5 6630.1 6528.1 5537.0 6635.6 6533.6 5542.7 6721.5 6619.5 5633.3 7/GYRO X/EXTRAPOLATED DIRECTION BEARING N 75.91 E N 75.99 E N 76.30 E N 77.31 E N 77.07 E N 76.57 E N 77.01 E N 76.69 E N 78.37 E N 82.83 E N 86.52 E N 87.49 E N 87.50 E N 86.85 E N 87.14 E N 87.07 E N 86.22 E N 87.95 E N 87.95 E RELATIVE-COORDINATES FROM-WELL-HEAD 991.6 N 4285.2 E 1008.9 N 4354.5 E 1026.0 N 4423.9 E 1042.2 N 4492.8 E 1057.7 N 4561.2 E 1073.8 N 4629.8 E 1089.8 N 4698.2 E 1105.7 N 4766.2 E 1120.8 N 4834.5 E 1132.4 N 4904.1 E 1139.0 N 4975.4 E 1142.8 N 5047.7 E 1146.0 N 5120.6 E 1149.6 N 5193.9 E 1153.5 N 5267.4 E 1157.2 N 5340.8 E 1161.5 N 5414.1 E 1161.8 N 5419.9 E 1165.1 N 5512.0 E CLOSURE DiSTNCE BEARING 4398.4 N 76.97 E 4469.8 N 76.96 E 4541.4 N 76.94 E 4612.0 N 76.94 E 4682.2 N 76.94 E 4752.7 N 76.94 E 4823.0 N 76.94 E 4892.8 N 76.94 E 4962.7 N 76.95 E 5033.2 N 77.00 E 5104.1 N 77.11 E 5175.5 N 77.24 E 5247.3 N 77.39 E 5319.6 N 77.52 E 5392.2 N 77.65 E ,5464.8 N 77.77 E 5537.3 N 77.89 E 5543.1 N 77.90 E 5633.8 N 78.07 E 0 /lOO 0.63 0.51 0.29 1.27 0.31 0.36 0.64 0.18 0~.86 2.41 2.07 0.74 0.44 0.47 0.19 0.15 0.62 11.57 0.00 [RU 1A-20 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 5 01/24/91 ',UBSEA ~EPTH -100 0 100 200 300 400 5O0 600 700 800 900 1000 1100 1200 1300 1400 4500 300 1700 1800 1900 2000 2100 2200 ~.300 MEAS DEPTH 2 102 202 302 402 502 602 703 805 908 1011 1116 1222 1329 1439 1552 1671 1793 1924 2069 2220 2369 2518 2664 2809 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 0.00 2 0 0 N 81.60 E 0.00 N 0.00 E 0.15 102 0 0 N 81.67 E 0.09 N 0.08 E 0.28 202 0 0 N 85.02 E 0.14 N 0.46 E 0.44 302 0 0 N 86.54 E 0.18 N 1.09 E 0.69 402 0 0 N 82.17 E 0.28 N 2.06 E 2.11 502 0 0 N 79.43 E 0.66 N 4.44 E 5.30 602 0 0 N 78.'50 E 1.90 N 10.80 E 8.58 702 1 1 N 76.56 E 4.53 N 22.67 E 12.44 802 3 2 N 74.62 E 9.20 N 40.70 E 14.38 902 6 3 N 78.14 E 14.81 N 63.88 E 16.32 1002 9 4 N 80.98 E 18.15 1102 14 5 N 82.43 E 20.11 1202 20 6 N 84.12 E 23.20 1302 27 8 N 84.93 E 25.89 1402 37 10 N 84.07 E 30.02 1502 50 13 N 82.69 E 33.65 1602 69 18 N 80.77 E 37.03 1702 91 22 N 79.19 E 43.65 1802 122 31 N 77.31 E 48.07 1902 167 45 N 77.64 E 48.16 2002 218 50 N 78.13 E 47.95 210'2 267 50 N 77.88 E 47.22 2202 316 48 N 78.27 E 46.63 2302 362 46 N 79.17 E 46.32 2402 407 45 N 79.26 E 19.74 N 90.89 E 24.23 N 121.61 E 28.25 N 155.82 E 31.88 N 195.48 E 36.30 N 240.94 E 42.13 N 292.85 E 51.35 N 355.44 E 63.62 N 424.85 E 81.01 N 507.95 E 104.58 N 610.41 E 127.87 N 720.25 E 150.58 N 829.20 E 173.49 N 936.43 E 194.74 N 1041.08 E 213.99 N 1144.49 E 2400 2954 46.34 2502 452 45 N 78.52 E 234.92 N 1247.40 E [RU lA-20 Page 6 01/24/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL UBSEA MEAS INCLN .EPTH DEPTH ANGLE TVD BKB 2500 3099 46.13 2602 2600 3244 46.95 2702 2700 3392 47.61 2802 300 3539 46.79 2902 z900 3685 47.34 3002 3000 3832 46.90 3102 3100 3977 45.57 3202 3200 4119 44.85 3302 3300 4259 44.02 3402 3400 4398 44.62 3502 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 497 45 N 79.56 E 254.68 N 1349.82 E 542 45 N 79.21 E 273.92 N 1453.01 E 590 48 N 79.09 E 294.67 N 1560.20 E 637 47 N 78.77 E 314.91 N 1666.03 E 683 46 N 76.93 E 337.55 N 1770.50 E 730 47 N 76.76 E 362.29 N 1875.90 E 775 45 N 76.70 E 386.30 N 1977.53 E 817 42 N 75.72 E 410.34 N 2075.31 E 857 40 N 76.63 E 433.80 N 2170.10 E 896 39 N 77.21 E 455.64 N 2264.81 E 3500 4538 44.22 3602 3600 4678 45.17 3702 3700 4821 45.33 3802 3800 4962 44.88 3902 3900 5104 45.31 4002 936 40 N 77.96 E 476.61 N 2360.51 E 976 40 N 76.30 E 497.70 N 2456.18 E 1019 43 N 75.68 E 522.66 N 2554.68 E 1060 41 N 75.52 E 547.37 N 2651.16 E 1102 42 N 75.18 E 572.76 N 2748.27 E 4000 5246 45.55 4102 4100 5389 .45.83 4202 4200 5532 45.63 4302 ,d0 5676 45.99 4402 ~00 5820 46.23 4502 1144 43 N 75.30 E 598.85 N 2846.50 E 1187 43 N 75.01 E 624.69 N 2945.44 E 1230 43 N 74.93 E 651.36 N 3044.33 E 1274 44 N 74.83 E 678.05 N 3143.73 E 1318 44 N 75.14 E 705.07 N 3244.13 E 4500 5965 46.53 4602 4600 6111 46.91 4702 4700 6257 47.09 4802 4800 6405 47.47 4902 4900 6553 47.68 5002 5000 6702 47.95 5102 4 1363 45 N 75.29 E 731.76 N 3345.50 E 1409 46 N 75.51 E 758.56 N 3448.32 E 1455 47 N 75.00 E 785.80 N 3551.87 E 1503 47 N 74.46 E 814.35 N 3656.36 E 1551 48 N 74.57 E 843.37 N 3761.76 E 1600 49 N 73.71 E 873.42 N 3868.01 E RU 1A-20 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 01/24/91 UBSEA MEAS INCLN EPTH DEPTH ANGLE TVD BKB 5100 6851 47.38 5202 5200 6997 46.19 5302 5300 7140 45.68 5402 [00 7283 45.35 5502 u500 7426 45.75 5602 5600 7569 44.77 5702 5700 7709 44.71 5802 5800 7850 44.65 5902 5900 7990 44.27 6002 6000 8130 44.74 6102 6100 8272 45.89 6202 6200 8417 46.71 6302 6300 8564 47.28 6402 6400 8711 47.30 6502 6500 8859 47.18 6602 6600 9005 47.00 6702 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1649 49 N 74.05 E 903.90 N 3974.41 E 1695 46 N 74.06 E 933.14 N 4076.26 E 1738 44 N 73.95 E 962.07 N 4175.31 E 1781 43 N 75.72 E 988.64 N 4273.64 E 1824 43 N 76.07 E 1013.40 N 4372.60 E 1867 42 N 76.99 E 1037.26 N 4471.24 E 1907 40 N 77.03 E 1059.12 N 4567.27 E 1948 41 N 76.79 E 1081.89 N 4664.00 E 1988 40 N 76.72 E 1104.10 'N 4759.30 E 2028 40 N 79.70 E 1124.82 N 4855.06 E 2070 42 N 85.49 E 1137.61 N 4955.38 E 2115 45 N 87.49 E 1143.33 N 5060.00 E 2162 47 N 87.09 E 1148.19 N 5167.20 E 2209 48 N 87.13 E 1153.87 N 5275.54 E 2257 48 N 86.57 E 1159.57 N 5383.91 E 2303 47 N 87.95 E 1164.31 N 5491.14 E RU lA-20 Page 8 01/24/91 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 0 0.00 0 -102 0 N 0.00 E ~.000 16.12 991 889 90 N 80.83 E 2000 47.11 1855 1753 567 N 76.61 E 3000 46.22 2534 2432 1302 N 78.93 E 4000 45.36 3218 3116 2030 N 76.70 E DL/ 100 0 N 19 N 93 N 241 N 390 N 0 E 0 N 90.00 E 0.0 88 E 90 N 77.63 E 1.9 561 E 568 N 80.56 E 4.6 1280 E 1302 N 79.32 E 0.5 1993 E 2031 N 78.93 E 0.9 5000 45.02 3929 3827 2734 N 75.43 E 554 N 6000 46.63 4626 4524 3450 N 75.29 E 738 N 7000 46.17 5304 5202 4184 N 74.06 E 934 N 8000 44.26 6009 5907 4893 N 76.69 E 1106 N 9000 47.00 6698 6596 5609 N 87.95 E 1164 N 2677 E 2734 N 78.31 E 0.4 3370 E 3450 N 77.64 E 0.3 4078 E 4184 N 77.10 E 0.6 4766 E 4893 N 76.94 E 0.2 5487 E 5609 N 78.02 E 0.0 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 01/24/91 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT . Well ...... : KRU 1H-20 Section at: N, 77.28,E Surveyors.: J.C. STUART/T. STODDARD Computation...: RADIUS OF CURVATURE Survey Date...: 01/03/91 RKB Elevation.: 102.00 ft Job Number .... : AK0191G262 API Number .... : 50-029-22112 INTERPOLATED MARKERS REPORT Surface Location: 1091 NSL 314 EWL S5 T11N R10E MARKER MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES IDENTIFICATION DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD KB 0 0.00 0 -102 0 N 0.00 E 0 N 0 E 9-5/8" CASING 4960 44.87 3901 3799 2705 N 75.52 E 547 N 2650 E TOP KUPARUK C 8343 46.34 6251 6149 5135 N 86.94 E 1141 N 5006 E BASE KUPARUK C 8505 47.10 6362 6260 5251 N 87.47 E 1146 N 5124 E TOP KUPARUK A 8733 47.33 6517 6415 5416 N 87.12 E 1155 N 5292 E BASE KUPARUK A 8897 47.02 6628 6526 5535 N 86.25 E 1161 N 5412 E 7" CASING 9010 47.00 6705 6603 5616 N 87.95 E 1164 N 5494 E PROJECTED TD 9034 47.00 6721 6619 5633 N 87.95 E 1165 N 5512 E RECEIVED - 4 t992 Alaska Oil & Was Cons. buri~lnissiol~ Anchorage Gpust L sn~ Directional Drilling. <KB>O 550 iiO0 i650 2200 2750 3300 3850 4400 4950 5500 8050 8800 7i50 7700 8250 8800 9350 9900 550 VERTICAL SECTION VIEW ~ ~I1 I ~HE ~ I ~UI~ V IL~ ARCO ALASKA, INC. KRU ~A-20 I Section at: N 77.28 E ....... TVB Scale.' ! inch = l!O0 feet Dep Scale.' ! inch = ilO0 feet ! ~, Drawn ' 0~/24/9! ~arke~ Identification HO TVO SECTN AJ KB 0 0 0 .. '~ B} PROJECTED TD 9034 672i 5633 ...... I ......... · ..... ...... , ..... INCLN 0.00 .00 0 550 iiO0 i650 2PO0 2750 3300 3850 4400 4950 5500 Section Departure Sreat Land Directional Drilling, _I-NC. ~arker Idenblflcab~on HD N/S ~)KB 0 ON OE PROJECTED TD 9034 ~65 N 55~2 E RECEIVED FEB - 4 t992 Alaska O~l & t~as uons. uommissio~ PLAN VIEW ARCO ALASKA, INC. KRU iA-20 CLOSURE ..... : 5634 ft N 78.07 E DECLINATION.: 0,00 E SCALE ....... : i inch = ilO0 feet DRANN ....... : 0t/24/9! 3850 3300 2750 2200 i850 iio0 550 0 550 iiO0 i850 2200 2750 3300 3850 550 0 550 iiO0 i650 2200 2750 3300 3850 4400 4950 5500 6050 <- NEST · EAST -> AOGCC GEOLOGICAL MATERIALS INVENTORY LIST COMPLETION DATE, ~ I ~ / ~ ! CO. CONTACT & NO.A ~'~ for~n received received dat~ comments 40, .... ~~' no , , .......... ~n~i~io~ ~'1~. "' / / .. 403 yes no sundry application 4U4 yes no tepolt of sundry application 6pen requir~'d received~ C-~s~d required i;ecei~-~d-produc~ioe~eq-~i~ed- rec-eiv~! hole log hole log log , MUD GCT ~ TEMP Omm~s~ ~ ~ ~ CNL PROD ,, DLL CH'T /I /~ PRESS , .... BHC/SL CET ~ / / / SPINNER LSS 'PEnF Su~ey sss '-' p~cKER Data '" ~C~ D ~¢ka~ Weft CNL ;~~:~ ~ ~ Tests , FDC RWD required ~eccived SAMPLES required received MWD , ,, , , , , ~, , d~ dilch yes no " ML / / ,PGa~¢~ / ~ core ~~no CYBER core yes no LOOK .... _~ / Analysis , . NGT ,, , , .... & .... i ~__ i i i i . L I I I PEFIMIT# ~'[9_ COMPLETION DATE AOGCC GEOLOGICAL MATERIALS INYF'NTOR¥ LIST 1~- WELL NAME ~ ~ ! lin ~ !, Co t cji CO. CONTACT check off or list data as it is received? ist received date for 407. if not re. quired list as NFl 407 I * 3. l ~ I c~ :2"drilling'hi'stow v" survey J vI well tests O ! core ,d, cs~:riptiod · cored intervals core analysis dry' ditch intervals digital data .... ' ' u -ls' ' LOG TYPE RUN INTERYALS SCALE , NO. (to thc nearest fo,ot~ , [inchllO0'| i i i i i ~ i I1 ARCO Alaska, Inc. Date: August 16, 1 991 Transmittal #: 8198 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1 1 1 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 A - 2 0 Cement Bond Log 8 - 2 - 9 1 1 0 0 - 8 8 0 7 1 A - 2 0 Cement Evaluation Log 8 - 2 - 9 1 1 0 0 - 8 8 3 2 Receipt Acknowledge' ~~'~-~-- Date' ----:~- .......... D r illi n g State of Alaska(+sepia) NSK ARCO Alaska, Inc. Date: July 26, 1991 Transmittal #: 8181 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1A-20 Ultrasonic Imager 7-12-91 191-2255 Receipt Drilling Acknowledge' ~J~-- ~--- State of Alaska(+sepia) Date: NSK RECEIVED d U L.~a,_. 1991 Alaska 0il & Oas Cons. ommisslo~ Anchorage STATE OF ALASKA 0 ~ OIL AND GAS ~SERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK Suspend _ Alter casing _ Repair well ~X Plugging _ Change approved program _ Pull tubing _ 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ 99510 Service 4. Location of well at surface 1091' FSL, 314' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 2232' FSL, 40' FWL, Sec. 4, T11N, R10E, UM At effective depth 2255' FSL, 528' FWL, Sec.4, T11N, R10E, UM At total depth 2256' FSL, 546' FWL, Sec. 4,T11N, R10E, UM 12. Present well condition summary Total Depth: Operation Shutdown Re-enter suspended well Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) RKB 102'. PAD 67' G1 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-20 9. Permit number 90-162 10. APl number 50-029-22112 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool measured 90 3 4' true vertical 67 21 ' feet Plugs (measured) feet EZSV @ 8000' Effective depth: measured 891 4' true vertical 66 4 0' feet Junk (measured) feet None 13. Casing Length Size Structural 8 0' 1 6" Conductor Surface 4960' 9 5/8" Intermediate Production 6682' 7" Liner Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Attachments Description summary of proposal ..~ Cemented Measured depth True vertical depth 222 SX AS I 1 15' 1 15' 1300 Sx AS III & 4960' 3901' 470 Sx Class G 275 Sx Class G 2328'-901 0' 2074'-6705' RECEIVED d U L. 1 2. Alaska 0il & Gas Cons. Commissi, on Detailed operation program X, BOP sketch X 14. Estimated date for commencing operation July 20, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ;K Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~_~_/,~/~¢~~' -FoRTitle COMMISSIoNArea DrillingUSEEngineeroNLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test t Location clearance m Mechanical Integrity Test m Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Co~)r~i~nc' SMITH Date Commissioner IApproval No. SUBMIT I1~ TRI"iBLIO, AT¢_ Form 10-403 Rev 06/15/88 Approved Copy Returaed ..... C .inq Repair General Proceuure KRU 1A-20 Procedure 1. ND dry-hole valve and NU BOP stack. Test BOPE. 2. PU 8-1/2" swage ass'y and make gage run to top of 7" stub. POH and LD swage. 3. PU back-off tool and GIH. Back off 27.3' cut joint of 7" casing. 4. POH and LD cut joint. LD back-off tool. 5. RU to run 7" casing. 6. PU screw-in adapter for 7" 26# BTC 7. PU 1 jt 7" 26# csg . 8. PU Weatherford 7" 26# LTC stage cementing collar. 9. Run additional 7" 26# J-55 BTC AB Mod casing and screw-in to top of 7" casing @ +/- 2344'. NOTE: Centralize as follows: One 8-3/8" x 7" rigid centalizer on every joint above the stage collar. Alternate right hand and left hand spirals. Allow centralizers to float between casing couplings. (57 ordered) 10. Circulate approximately 90 bbls brine through the stage collar to ensure the casing is clear. NOTES: 7" capacity = .0382 bpf 9-5/8" x 7" annulus = .0297 bpf Attempt to minimize circulation time prior to the cement job. (Minimize thawing.) ~lask~ ~t & Gas Cons, comrnis~io~ ~rlch.o. ra§.~ -' C. ~inq Repair General Proce~,are KRU 1A-20 11. Batch-mix 600 sx Permafrost cement @ 14.9 ppg, (45% excess.) Mix 50 bbls, 300 sx, in one pod of the batch mixer with 1/4 #/sk Flocele, (cellophane flakes.) Pump this pod first! Mix the other 50 bbls, 300 sx, without any additives. P 12. Pump 25 bbls of viscosified 11.0 ppg brine spacer followed by 50 bbls cement slurry with Flocele followed by 50 bbls slurry without Flocele. Drop closing plug and displace with 10.6 ppg brine. Bump plug and pressure up to 2000 psi to close stage collar. Bleed off pressure to see if collar shifted close. NOTES: Be prepared to handle excess cement returns to surface. If cement was not circulated to surface, log surface casing to identify TOC. (Temperature log is recommended.) Perforate and circulate Permafrost Type 'E' cmt from that point to surface using cement retainer. Once casing is cleaned out, patch 7" casing across these perforations. Permafrost cement has following properties: Density: Water: Yield: Pump Time: Liquid Phase Freeze Point: 14.9 ppg 3.5 gals / sk .93 cu ft / sk 4.5 - 6.5 hrs @ 40°F 13° F 13. Break and PU BOP stack. Pull 100K on 7" casing. Set slips and make rough cut on 7" casing. LD cut joint. Make final cut and re- install tubing spool. Test void to 3000 psi. NU BOP stack and test. 14. Pick up 6-1/8" bit and 4-3/4" drill collars. GIH and tag stage collar. Drill out plug and collar. Test casing to 3000 psi. GIH to 8000' and drill up EZSV. Push all junk to bottom. 15. Squeeze and Complete per orignal procedures for 1A-20. LRC 7-8-91 Alaska Oil & Gas Cons. Anchora§o 1A-20 Present Condition Inte~als of 9-5/8" csg swaged to 8.5" a 574'-581' b 697 - 724' c 738'- 746' ToD of 7" stub = 2316' Nordic RKB % (Cut joint = approx 27.3') Top of cmt in annulus = +/- 2470'~ LRC 5-24-91 10.6 pDq NaCI/Br brine pH = 11.5 -12 deg FP Interval tested 486' to surf 1100 psi ' Top of a split @ 488' "Bottom of split @ ? Top of pipe that holds +/- 1050 psi @ 786' or higher Split exists between 1139' - 1549' .I Top of a split @ 1550' ! .- ? ! Bottom of split · .I extends below ! 1581' RTTS was set @ +/-2250' when shoe was successfully cmt'd w/lO00 psi maximum ~';~';i 'nl pressure ~,~=. . , ~ 9-5/8 @ 496O EZSV @ 8000' PBD = 8902' 7' ~ 9010' TD = 9O34' 1A-20 Proposed Repair of 9-5/8" Casinq Intervals of 9-5/8" csg swaged to 8.5" a 574'- 581' b 697 - 724' c 738'- 746' Interval tested 486' to surf 1100 psi Top of a split @ 488' =-- Bottom of split @ ? Top of pipe that holds +/- 1050 psi @ 786' or higher 7" casing cemented to surface inside of 9-5/8" casing Weathertord Stage Cementing @ +/- 2300' Screw-in sub @ +/-2344' Nordic RKB 10.6 pp.q NaCI/Br brine pH = ~.5 -12 deg FP Top of cmt in annulus = +/- 2470' LRC 7-8-91 ! ~ Split exists between -- 1139' - 1549' I '1- .I Top of a split @ 1550' I ,. ! · Bottom of split extends below 1581' Deepest damage @ +/- 2000' RTTS was set @ +/-2250' when shoe was successfully cmt'd w/lO00 psi maximum inj pressure 9-5/8" @ 4960' EZSV @ 8000' PBD = 89O2' 7" ~ 9010' TD = 9O34' STATE OF ALASKA AL,-,,.,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 13. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1091' FSL, 314' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 2232' FSL, 40' FWL, Sec. 4, T11N, R10E, UM At effective depth 2255' FSL, 528' FWL, Sec.4, T11N, R10E, UM At total depth 2256' FSL, 546' FWL, Sec. 4,T11N, R10E, UM Present well condition summary Total Depth: measured true vertical 9034' 6721' feet Plugs (measured) feet EZSV @ 8000' 6. Datum elevation (DF or KB) KB 102'. PAD 67' GL feet 7. Unit or Property name Kup_~ruk River Unit ,~/~ell n'b~ber k/1 _A-2.~o.? 9y--I~rmit number 90-162 10. APl number 50-029-22112 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured true vertical 8914' 664O' feet Junk (measured) feet None 13. Casing Length Structural 8 0° Conductor Surface 4 9 6 0' Intermediate Production 66 82' Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 16" 222SXAS I 115' 115' 9 5/8" 1300 Sx AS III & 4960' 3901' 470 Sx Class G 7" 275 Sx Class G 2328'-901 0' 2074'-6705' None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Ayerage Production or In!ection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil _ Gas Suspended. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned Form 1~-4D~, R~v/~5/17/89 Title Area Drilling Engineer Date 5/~.////¢/ SUBMIT IN DUPLICATE 1A-20 Present Condition Intervals of 9-5/8" csg swaged to 8.5' a 574'- 581' b 697'- 724' c 738'- 746' Top of 7" stub = 2316' Nordic RKB (Cut joint = approx 27.3') Top of cmt in annulus = +/- 2470'~ 10,6 pp(~ NaCl/Br brine pH = -12 deg FP Damaged casing 500' - 2,000' -RTTS was set @ +/-2250' when shoe was successfully cmt'd w/lO00 psi maximum Inj pressure ~ 9-5/8 ~ 4960 LRC 5-24-91 ~ EZSV @ 8000' PBD = 8902' 7' ~ 9010' TD = 9O34' KRU 1A-20 Form 404 Supplement The subject well was discovered to have a hole in the 9-5/8" surface casing during annular pumping operations while drilling a subsequent lA well. A temperature log was run and verified a hole existed in the neighborhood of 500'. Plans were made at that time to repair the damaged surface casing as part of the completion operations when Nordic #1 arrived on the pad. Since moving the rig onto the well, the 7" casing was removed from 2316' to surface. Multiple holes were identified in the 9-5/8" surface casing. The 9-5/8" x 7" annulus was cemented f/ +/-2470' to the 9-5/8" shoe @ 4960'. The well has a 7" EZSV set @ 8000' and is loaded with 10.6 ppg brine. A 7-1/16" 5M psi master valve was installed on top of the tubing spool. The completion rig moved off of the well 5-23-91. Diagnostic logs were obtained in the 9-5/8" casing. Once the Kuparuk River bridge is reinstalled, the materials for repair operations or a P&A will be available. LRC 6-19-91 ARCO ALASKA INC. DAILY OPERATIONS PAGE 1 WELL: 1A-20 BOROUGH: NORTH SLOPE FIELD: KUPARUK RIVER FIELD UNIT: KUPARUK RIVER UNIT LEASE: ADL 25648 ALK 466 API: 50-029-22112 PERMIT 90-162 APPROVAL: 91-57 AFE: AK45458 WI: 55.252072 ACCEPT: 02/20/91 12:30 SPUD: 12/13/90 16:30 RELEASE: 03/04/91 03:00 OPERATION: DRILL RIG: DOYON 14 12/14/90 ( 1) TD: 2010' (2010) SUPV:JMM 12/15/90 ( 2) TD: 4980'(2970) SUPV:JMM 12/16/90 (3) TD: 4980'( SUPV:JMM o) 12/17/90 ( 4) TD: 7161' (2181) SUPV:JMM 12/18/90 ( 5) TD: 8058' ( 897) SUPV:JMM 12/19/90 (6) TD: 9034' ( 976) SUPV:JMM DOYON 14 DRILLING AT 2010' MW: 9.3 VIS: 68 ACCEPT RIG AT 1A-20 AT 12:30 HRS 13-DEC-90. NU DIVERTER, MU BHA, SPUD AT 16:30 HRS 13-DEC-90. DRILL TO 2010'. DAILY:S70,467 CUM:$70,467 ETD:S70,467 EFC:$1,820,000 CIRC AT CASING POINT 9-5/8"@ 4960' MW: 9.6 VIS: 50 DRILL FROM 2010' TO 4980' CIRC BU, PREP TO POOH FOR CASING. DAILY:S56,323 CUM:$126,790 ETD:S126,790 EFC:$1,820,000 PU BHA#2 9-5/8"@ 4960' MW: 9.9 VIS: 45 SHORT TRIP TO HWT DP, CIRC HOLE CLEAN, POOH. RUN 119 JTS 9-5/8" J-55, 36#, BTC CSG TO 4960' CIRC AND REDUCE YP OF MUD. PUMP 80 BBL FRESH WATER SPACER, 449 BBL ASIII (1300 SX) 12.1 PPG LEAD CEMENT, 97 BBL (474) SX CLASS G 15.8 PPG TAIL CEMENT. DISPALCE WITH 380 BBL WATER, DID NOT BUMP PLUG. CIP @ 23:30 HRS 15-DEC-90. FLOATS HELD OK. FULL RETURNS THRUOUT CEMENT JOB. 11.9 PPG CEMENT RETURNS TO SURFACE AT 200 BBL INTO DISPLACEMENT. ND DIVERTER, NU BOPE AND TO 3000 PSI. MU AND ORIENT TURBINE BHA. DAILY:S257,450 CUM:$384,240 ETD:S384,240 EFC:$1,820,000 DRILLING AT 7161 9-5/8"@ 4960' MW: 9.6 VIS: 38 RIH WITH PDC BIT AND TURBINE. DRILL FLOAT COLLAR, TEST CASING TO 2000 PSI. DRILL FLOAT SHOE AND 10' OF NEW FORMATION. PERFORM FORMATION INTEGRITY TEST TO 12.0 PPG EMW AT 4940'. DRILL TO 7161'. DAILY:S65,977 CUM:$450,217 ETD:S420,217 EFC:$1,820,000 RIH WITH ROTARY ASSY 9-5/8"@ 4960' MW: 9.6 VIS: 38 DRILL FROM 7161' TO 8058' CBU, POOH TO 9-5/8" SHOE. PERFORM FORMATION INT- EGRITY TEST TO 11.1 PPG EMW. POOH AND CHANGE TO ROTARY ASSY WITH SPERRY REAL- TIME LOGGING MPT TOOL. RIH, LOG ACROSS COLVILLE, RIH TO CONTINUE DRILLING. DAILY:S71,002 CUM:$521,219 ETD:S521,219 EFC:$1,820,000 WIPER TRIP PRIOR TO LOGGING 9-5/8"@ 4960' MW:10.5 VIS: 38 BREAK CIRC, REAM TO BOTTOM, DRILL WITH ROTARY FROM 8058' TO 9034'. CIRC, MAKE WIPER TRIP PRIOR TO LOGGING, TIGHT AT 6TH AND llTH STANDS, PULLED 350K+. DAILY:S65,258 CUM:$586,477 ETD:S586,477 EFC:$1,820,000 ARCO ALASKA INC. DAILY OPERATIONS PAGE 2 WELL: 1A-20 OPERATION: DRILLING RIG: DOYON 14 12/20/90 (7) TD: 9034'( SUPV:JMM 12/21/90 (8) TD: 9034'( SUPV:JMM o) o) POOH LDDP 7"@ 9010' MW:10.7 VIS: 44 FINISH MAKING 20 STAND WIPER TRIP. SPOT DIESEL PILL, POOH AND DOWNLOAD MPT LOG. RU HLS, RIH AND LOG WITH TRIPLE COMBO FROM 8920' TO 100'. LOGS STUCK AT 8400', PULLED FREE AT 10500 LBS. DECIDED NOT TO MAKE REPEAT PASS AND ABORTED RFT SURVEYS DUE TO HOLE PROBLEMS. RD HLS, RIH FOR WIPER TRIP, SPOT DIESEL PILL AND POOH LDDP. DAILY:S76,432 CUM:$662,909 ETD:S662,909 EFC:$1,820,000 MOVING RIG TO 1A-25 7"@ 9010' MW:10.5 VIS: 0 FINISH POOH LDDP , RUN 212 JTS 7' J-55, 269 BTC CASING. PUMP 10 BBL PRE-WASH 35 BBL SPACER, 57 BBL 15.7 PPG CLASS G CEMENT. DISPLACE WITH 346 BBL OF 10.6 PPG BRINE, BUMP PLUG WITH 3000 PSI, FLOATS OK. ND BOPE, SET SLIPS, NU TREE, FAILED PRESSURE TEST, INJECT PLASTIC PACKING IN PACKOFF AREA TEST TREE OK. RELEASE RIG FROM lA-20 AT 03:00 HRS 21/21/90. MOVE RIG TO 1A-25. DAILY:S276,495 CUM:$939,404 ETD:S939,404 EFC:$1,820,000 SIGNATURE: DR~ ~~~ UPERINTEN~T DATE: ARCO ALASKA INC. WELL: lA-20 DAILY OPERATIONS BOROUGH: NORTH SLOPE FIELD: KUPARUK RIVER FIELD UNIT: KUPARUK RIVER UNIT LEASE: ADL 25648 ALK 466 API: 50-029-22112 PERMIT 90-162 APPROVAL: 91-57 AFE: AK45458 WI: 55.252072 SPUD: 12/13/90 16:30 ACCEPT: 05/12/91 17:00 RELEASE: 05/23/91 15:30 OPERATION: WORKOVER RIG: NORDIC 1 05/13/91 ( 9) TD: 9034 PB: 8923 SUPV:GB/WLM 05/14/91 (10) TD: 9034 PB: 8923 SUPV:GB/WLM 05/15/91 (11) TD: 9034 PB: 8923 SUPV:GB/WLM 05/16/91 (12) TD: 9034 PB: 8923 SUPV:DB 05/17/91 (13) TD: 9034 PB: 8923 SUPV:DB NORDIC 1 CIRCULATE OUT DIESEL 7"@ 9010' MW:10.6 NaBr BLEED OFF 1-1/4" TBG. ND TREE. NU BOP'S AND TEST. POH AND LD 1-1/4" TBG. PU O/S AND BHA AND GIH TO 1719'. CIRC OUT DIESEL W/ 10.6 PPG BRINE. DAILY:S86,659 CUM:$1,026,063 ETD:S1,026,063 EFC:$1,820,000 POH 7"@ 9010' MW:10.6 NaBr CONTINUE IN HOLE AND TAGGED TOF @ 8792' ATT TO LATCH FISH AND POH. NO RECOVERY. MU FISHING ASS'Y #2 AND GIH. TAGGED TOF @ 8736'. ATT TO LATCH FISH. POH. DAILY:S28,147 CUM:$1,054,210 ETD:S1,054,210 EFC:$1,820,000 POH W/ RTTS 7"@ 9010' MW:10.5 NaBr FPOH AND REC'D 6' 1-1/4" TBG. PU 7" CSG CUTTER. GIH TO 606' AND CUT 7" CSG. ND BOP'S AND TBG SPOOL. REMOVE 7" SLIPS. NU BOP'S. PULL AND LD 584' OF 7" CSG. PU 9-5/8" RTTS AND DP. GIH TO 1730' (RTTS @ 586') AND CIRC AND HEAT BRINE. ATT TO PUMP BELOW RTTS. CIRCULATES. POH TO INSPECT RTTS. HOLE TIGHT F/586'-571'. GIH W/ RTTS. TEST CSG DOWN TO 446'. OK. LEAKED AT 511'. HELD AT 486' TEST AT 536' · CIRCULATES. ATT TO GIH TO 590' COULD NOT GET RTTS BELOW 571'. POH-W/ RTTS. DAILY:S57,163 CUM:$1,111,373 ETD:Si,ii1,373 EFC:$1,820,000 SWAGING 9-5/8" CSG. 7"@ 9010' MW:10.5 NaBr GIH W/8-1/2" BIT. TAG UP @ 574' COULD NOT GET PAST 575' TRIP FOR 8" SWAGE. WORK DOWN TO TOP OF 7" CSG STUB. TRIP FOR 7" CSG CUTTER. CUT 7" @ 1629'. TRIP FOR 7" SPEAR. CSG WOULD NOT PULL. TRIP FOR 7" CSG CUTTER. CUT 7" @ 1634' TRIP FOR SPEAR. LATCH 7" CSG @ 606'. POH AND LD 24 JTS PLUS CUT JOINT OF 7" CSG. MU 8-1/2" SWAGE AND GIH. TAG TIGHT SPOT @ 574' SWAGE CSG OUT TO 8-1/2" F/ 574' - 577' DAILY:S29,715 ~UM:$1,141,088 ETD:S1,141,088 EFC:$1,820,~00 MU RTTS & PREP TO RIH 7"@ 9010' MW:10.5 NaC1/Br CONT SWAGING OUT CSG TO 8.5" F/577' TO 579', POH, STAND BACK DP, RIH, CONT SWAGING F/579'-581', DROPPED THRU @ 581', SWAGE F/697'-720, SLOW PROGRESS, POH RIH W/8.25" SWAG F/721'-724', 738'-741', TAG STUB @ 1632', RU CIRC HEAD, CIRC HEATED BRINE TO CLEAN & WARM WELLBORE, POH, RIH W/8.5" SWAGE, BUMP THRU PREV SWAGED, SWAGE OUT TO 8.5" F/720'-724', 738'-746', RIH TO 7" STUB, BREAK CIRC & CIRC AROUND, POH, 8.5" SWAGE DRAGS 10K-20K# OVERPULL THRU SWAGED OUT SPOTS, LD 8.5" SWAGE, RIH W/8-3/8" GUIDE SHOE TO 1632', SLIGHT DRAG THRU SWAGED AREAS CBU, POH, RIH W/HALLIBURTON RBP & SET @ 1600', POH, RIH W/HALLIBURTON RTTS. DAILY:S35,446 CUM:$1,176,534 ETD:S1,176,534 EFC:$1,820,000 ARCO ALASKA INC. DAILY OPERATIONS PAGE 2 WELL: lA-20 OPERATION: WORKOVER RIG: NORDIC 1 05/18/91 (14) TD: 9034 PB: 8923 SUPV:DB 05/19/91 (15) TD: 9034 PB: 8923 SUPV:DB 05/20/91 (16) TD: 9034 PB: 8923 SUPV:DB 05/21/91 (17) TD: 9034 PB: 8923 SUPV:DB 05/22/91 (18) TD: 9034 PB: 8923 SUPV:DB 05/23/91 (19) TD: 9034 PB: 8923 SUPV:DB 05/24/91 (20) TD: 9034 PB: 8923 SUPV:DB SIGNATURE: POH 7"@ 9010' MW:10.6 NaC1/Br GIH W/ RTTS. SET @ 786' TEST BELOW TO 500 PSI. OK. PUMPS IN @ 1050 PSI. RESET @ 1139' PUMPS IN BELOW. RESET @ 1581'. TEST BELOW TO 500 PSI. OK. TEST TO 1000 PSI. OK. CIRCULATES AT 1300 PSI. TEST BELOW @ SEVERAL INTERVALS UP TO 1550 THAT CIRCULATE. PUMPS IN @ 1549' (TOP OF SPLIT.) POH AND SET RTTS @ 486' TEST ABOVE TO 1~50 PSI. OK. RESET @ 489' TEST ABOVE TO 1000 PSI. OK. RESET @ 492' TEST ABOVE C~RCULATES UP DP. (TOP OF SPLIT.) POH AND LD RTTS. PULL RETRIEVABLE BP. MU FISHING ASS'Y. GIH. TAG 1-1/4" TBG @ 8736'. WASH OVER FISH TO 8791' POH. DAILY:S29,323 CUM:$1,205,857 ETD:$1,205,8~7 EFC:$1,820,000 GIH W/ FISHING TOOLS 7"@ 9010' MW:10.6 NaC1/Br FPOH. REC'D 3 JTS 1-1/4" TBG. GIH W/ FISHING ASS'Y. COULD NOT GET INTO 7" STUB. TRIP DIFFERENT GUIDE. TAG TOF @ 8857'. WORK OVER FISH TO 8894'. POH. REC'D 2 JTS TBG. GIH W/ FISHING ASS'Y. DAILY:S28,147 CUM:$1,234,004 ETD:S1,234,004 EFC:$1,820,000 PREP TO POH 7"@ 9010' MW:10.6 NaCl/Br COULD NOT GET FISHING ASS'Y INTO 7" STUB. TRIP FOR CRIPPLE SHOE. TAG TOF ? 8898' WORK OVER FISH TO PBD PON. REC'D 1 JT TBG LESS 5 MU ~SG CUTTER AND GIH TO 23~8'. CUT 7" CSG. PREP TO POH. DAILY:S49,186 CUM:$1,283,190 ETD:S1,283,190 EFC:$1,820,000 GIH W/ RTTS 7"@ 9010' MW:10.6 NaCl/Br POH LD CUTTER. GIH AND SPEAR 7" CSG. POH. REC'D 15 JTS PLUS 2 CUT JTS. GIH W/ 6-1/8" BIT ON TAIL PIPE RTTS. WORK BIT INTO 7" CSG. SET RTTS AND EST INJ RATE @ 2 BPM AND 850 PSI. UNSEAT RTTS AND ATT TO DROP BIT BACK INTO 7" CSG. NO GO. POH AND LD RTTS. PU TAPER MILL. DRESS OFF TOP OF 7" CUT @ 2316'. POH AND PU 7" EZSV. GIH AND SET SAME @ 2360' TRIP FOR RTTS. DAILY:S30,147 CUM:$1,313,337 ETD:S1,313,337 EFC:$1,820,000 DRILLING 7" EZSV 7"@ 9010' MW:10.6 NaCl/Br FGIH AND SET RTTS @ 2250'. INJECT 100 BBLS WTR AND SQZ ANNULUS WITH 380 SX PERM 'C' CMT @ 15.6 PPG. WOC 12 HRS. POH AND LD RTTS. GIH W/ 6-1/8" BIT. DRILLED CMT STRINGERS IN 7" CSG F/ 2318' - 2357' DRILLED ON EZSV @ 2360' DAILY:S54,913 CUM:$1,36~,250 ETD:S1,368,250 EFC:$~,820,000 POH 7"@ 9010' MW:10.6 NaC1/Br DRILLED OUT EZSV. PUSH TO BOTTOM. TOP OF JUNK = 8902', (8912' ORIG RKB.) MU 7" EZSV AND GIH. SET EZSV @ 8000' POH. DAILY:S72,289 CUM:$1,440,539 ETD:S1,440,539 EFC:$1,820,000 WELL SUSPENDED/ RIG RELEASED 7"@ 9010' MW:10.6 NaCl/Br FPOH. LD SETTING TOOL. MADE 8-3/8" GUAGE RUN WITH SHOE TO TOP OF 7" STUB. SLIGHT DRAG 723' - 734' POH. NU TBG SPOOL AND 7-1/16" MASTER VALVE. RELEASED RIG ~ 1530 HRS 5-23-91. DAILY:S25,116 DRILLING~SERINTEND~ CUM:$1,465,655 ETD:S1,465,655 EFC:$1,820,000 DATE: ARCO Alaska, Inc. Date' June 14, 1991 Transmittal #: 8133 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. '~-/(~,~ 1 A-2 0 1A-20 ~:~/-~p~,.1L-2 3 1L-23 ~'f-~/¢ 1 L-24 1 L-24 L-25 a/-""~oll L. 2 5 Cement Bond Log ,/ Cement Evaluation & Thicknes~ Cement Evaluation Log t/ Cement Bond Log ¢' Cement Evaluation Logy/ Cement Bond Log v/ Cement Evaluation Log~/ Cement Bond Log v/ Receipt Acknowledge- 6-6-91 6-6-91 6-2-91 6-2-91 6-2-91 6-4-91 6-4-91 6-4-91 Please acknowledge receipt and Date' 90-2274 1 00-2270 8850-10237 8850-10237 7500-9141 7500-9143 7800-9088 7800-9065 Drilling State of Alaska(+sepia) NSK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ~ Operation Shutdown__ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 4. Location of well at surface 1091' FSL, 314' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 2232' FSL, 40' FWL, Sec. 4, T11N, R10E, UM At effective depth 2255' FSL, 528' FWL, Sec.4, TllN, R10E, UM At total depth 2256' FSL, 546' FWL, Sec. 4,T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 9O34' 6721 ' 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB) RKB 102', PAD 67' Gl 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-20 9. Permit number 90-162 10. APl number 50-029-22112 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool feet Plugs (measured) feet EZSV @ 8000' Effective depth: measured true vertical 8914' 6640' feet Junk (measured) feet None Casing Length Structural 8 0' Conductor Surface 49 60' Intermediate Production 6682' Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 16" 222SXAS I 115' 115' 9 5/8" 1300 Sx AS III & 4960' 3901' 470 Sx Class G 7" 275 Sx Class G 2328'-901 0' 2074'-6705' None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED MAY 9 t991 Alaslm 0il & Gas Cons. C0rnmisst0n ch0rage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch_ 14. Estimated date for commencing operation JUNE 1991 16. If proposal was verbally approved Name of approver Russ Douglass 5-24-91 Date approved 15. Status of well classification as: Oil ;~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~-~ ,/~~ Title Area Drilling] En~]ineer FOR OOMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-'¢~7 IApproval No. Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. RMITH Commissioner Date~ Approved Cou,~ ~! ~:~n~ed SUBMIT IN TRIPLICATE KRU 1A-20 Form 403 Supplement The subject well was discovered to have a hole in the 9-5/8" surface casing during annular pumping operations while drilling a subsequent lA well. A temperature Icg was run and verified a hole existed in the neighborhood of 500'. Plans were made at that time to repair the damaged surface casing as part of the completion operations when Nordic #1 arrived on the pad. Since moving the rig onto the well, the 7" casing was removed from 2316' to surface. Multiple holes were identified in the 9-5/8" surface casing. The 9-5/8" x 7" annulus was cemented f/ +/-2470' to the 9-5/8" shoe @ 4960'. The well has a 7" EZSV set @ 8000' and is loaded with 10.6 ppg brine. A 7-1/16" 5M psi master valve was installed on top of the tubing spool. The completion rig will be off of the well while diagnostic logs are obtained in the 9-5/8" casing. Once the rig is finished completing the remaining lA wells, it will move back onto 1A-20 to repair the damaged surface casing and to complete the well. LRC 5-24-91 RECEIVED MAY 2 9 t99,~ Alaska 0il .& Gas Cons. 6ommiSS[Ot~ Anchorage 1A-20 Present Condition a Intervals of 9-5/8" csg swaged to 8.5' a 574' - 581' b 697' - 724' b c 738' - 746' c Top of 7" stub = 2316' Nordic RKB ~ Top of cmt in annulus = +/- 2470'~ LRC 5-24-91 10.6 pDa NaCI/Br brine pH = 11.5 -12 deg FP Interval tested 486' to surf 1100 psi -' Top of a split @ 488' ~ Bottom of split @ ? Top of pipe that holds +/- 1050 psi @ 786' or higher Split exists between 1139' - 1549' .- ! Top of a split @ 1550' ! .- ? .I Bottom of split ! extends below ! 1581' R'I-rS was set @ +/-2250' when shoe was successfully cmt'd w/lO00 psi maximum ,~,~ ~ , . ~.~i InJ pressure ~[~[~ 9-5/8" ~ 4960 EZSV @ 8000' PBD = 8902' 7" (~ 9010' TD = 9034' R[¢EIVED MAY 2 9 1~99~ /~laska OJJ & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: March 22, 1991 Transmittal #: 8040 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Receipt Drilling Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Cement Bond Log 1 -2-91 I -2-91 12-31-90 1 1-23-90 11-15-90 3-13-91 Cement Evaluation Log ..~ ///3- 1 3 - 91 Acknowledg~~ate' i× Stlte of'~iaska ' ' 6421 -8926 5894-8927 5400-8435 8464-11508 4170-7268 9500-12269 9500-12269 RECEIVED NSK Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 11, 1991 Transmittal #: 7983 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ; 1 A- 2 0 High Resolution Induction DFL 1 2 - 1 9 - 9 0 0-8912 5"Log ~/1 A- 2 0 High Resolution Induction DFL 1 2 - 1 9 - 9 0 0 - 8 9 1 2 2"Log ,~ 1A-20 High Resolution Induction DFL 1 2-1 9-90 0-8912 Raw Data Log ~/1A-20 Microlog 5" and 10" 1 2-I 9-90 8100-8870 J1A-20 Spectral Density Dual Spaced 1 2-1 9-90 5200-8881 Neutron Raw Data ,/1 A-20 Spectral Density Dual Spaced 1 2 - 1 9 - 9 0 5200-8881 Neutron Porosity Log ¥ 1 A - 2 0 Spectral Density Dual Spaced 1 2 - 1 9 - 9 0 81 0 0 - 8 8 8 0 Neutron High Resolution Receipt Acknowledged: ~..~~~~0'~1 ...... Date' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: January 11, 1991 Transmittal #: 7982 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 1 A-2 0 LIS Tape and Listing KRU State #2 LIS Tape and Listing Please acknowledge receipt and return Receipt 12-19-90 3-9-90 Acknowledged' 38-8923 6763-7279 Date' - ......... DISTRIBUTION: Lynn Goettinger State of Alaska ?,ia:-ska Oi! f.,'.,. Oas Cons. 6ominissior~ ARCO Alaska, Inc. Date: January 4, 1991 Transmittal #: 7973 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 A- 2 0 Dual Gamma Ray-Compensated 1 2- 1 9 - 9 0 8 0 5 8 - 9 0 3 2 Neutron Porosity-Simultaneous Formation Density 1A-20 Dual Gamma Ray-Electromagnetic 12-1 9-90 8058-9032 Wave Resistivity-Formation Exposure Time Spectral Density Dual Spaced Neutron High Resolution Pass High Resolution Induction DFL 2"/100' High Resolution Induction DFL Raw X and Raw R Microiog Spectral 'Density Dual Spaced Neutron Raw Data Spectral Density Dual Spaced Neutron Porosity High Resolution Induction 5"/100' 1A-19 12-7-90 0-4362 1A-19 12-7-90 0-4362 1A-19 I 2-7-90 0-4362 1 A- 1 9 I 2 - 7 - 9 0 0-4362 1 A - 1 9 1 2 - 7 - 9 0 0-4362 1A-19 1 2-7-90 0-4362 1A-19 1 2-7-90 0-4362 Receipt Acknowledged: ~--~~~~-- Date' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ' .ECEIVED JAN ~?, '1991 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 4, 1991' Transmittal Ct: 7972 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 1A-20 1A-19 Receipt Acknowledged: Please acknowledge receipt and return LIS Tape and Listing 12-21-90 AKMM901252 LIS Tape and Listing 12-11-90 3663.25-7960 DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED JAN 8 1991 Alaska 0il & Gas Cons. Commission Anchorage TO: THRU: FROM: MEMORANoUM State of Alaska .ALASKA OIL A~,D GAS CONSERJ~ATION CO~4ISSION Lonnie C. Smi ~'~:~ DATE: December 26, 1990 Core, is s ioner FILE NO: JT.LG. 1226.6 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI KRF #lA-20 Kuparuk Rv Field Louis R. Grimaldi Petroleum inspeccor Wednesday 12/19/90: i perfoznned a RiG/BOPE i~?pec[io_n on Doyon /~14 rig drilling for %RCO Kuparuk CPF #1 well #A-20. I found the rig to be in good shape with the only discrepancy being the inside kill valve did not have a handwheel on it. i informed the toolpusher, Jim ~cCautey, who assured me the handwheei would be installed today. in summary: Doyon 14 is in good shape for drilling ARCO Kuparuk 1A-20. 02-00lA (Rev. 6/89) 20/117MI~MO1.PM3 Telecopy No. (907) 276-7542 November 29, i990 A W McBride Area Drilling Engineer ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit iA-20 ARCO Alaska inc Permit # 90-162 Surf Loc 1091'FSL, 314'F~U~, Sec 5, TilN, R10E, UM Btmhole Loc 2288'FSL, 503'FWL, Sec 4, TllN, R10E, UM Dear ~r McBride: Enclosed is the approved application for permit to drill the above roferemced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, David W J oh~nst~n Chairman BY O~ER OF THE COI~ISSION jo encl C; Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA AL.A~KA OIL AND GAS CONSERVATION COMMI~:,o~ON PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry ~ Deepen --I Service _ Development Gas m Single Zone X~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 102', Pad 67' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25648 ALK 466 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1091' FSL, 314' FWL, Sec. 5, T11N, R10E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 2175' FSL, 15' FEL, Sec. 5, T11N, R10E, UM 1A-20 #U630610 At total depth 9. Approximate spud date Amount 2288' FSL, 503' FWL, Sec 4, TllN, R10E, UM 05-DEC-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 A-1 4 8988' MD 503'@ TD feet 34' at 1350' MD feet 2560 6692' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 500' feet Maximum hole an(~tle 46° Maximum surface 2300 psig At total depth (TVD) 3830psi~ @ 6692' 18. Casing program Setting Depth size specification Top Bottom Quantity of cement Hole Casin~ Weic~ht Grade Couplin~ Lenc~th IVD TVD IVD TVD linclude stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 4912 35' 35' 4947 3892' 2510 Cu. Ft. AS III & HF-ERW 550 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MO[ 4912' 35' 35' 4947' 3892' 270 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 4041' 4947' 3892' 8988' 6692' Top 500' above Kuparuk 19. To be completed for Redritl, 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 verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~. . Conductor Cu. Ft. :i i~ ~ ..... ~. ~.L . ~, Sudace Cu. Ft. ~',,~" ~ ?' '~ ~ ' intermediate Production Liner ,-~'.,. :':! ,~ Perforation depth: measured ...~],~:~,'~_~,~d. -~iJ .~ .~aS C0~h~.;. true vertical ~-~.o~'"J .~J,j~ · 'i .... ~[":' , -'-" ." ' 20. Attachments Filing fee _~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling progra~'!!]_,~0ra(~:P, Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge S i~ned ~ /~/'~ Title Area Drillincj Engineer Date ~ Commission Use Only Perm,t Number, I AP, number I .a :t/29/90 I cover ,otter ?~ -/~ 5 O- 0 Z?"' 'Z_ ~- ~7/.~ other requirements Conditions of approval Samples required ~Y e s 'x" N o Mud log required~ Y e s .,~ N o Hydrogen sulfide measures~ Yes .2~ N o Directional survey required ~.Yes ~ N o Required working pressure for BOPE ~2M; .~ 3 M' ~ 5 M' ~ 1 0 M; ~ 1 5 M Other: by order of Approve commissioner the commission Date Il. ? Form 10-401 Rev. 7-~ Submit in triplicate DRILLING FLUID PROGRAM (1A-20) Spud to 9-5/8" Drill out to surface casing weight uo Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4-8 APl Filtrate 10-1 2 8-1 0 pH 9-1 0 8.5-9 % Solids 10 +/- 4-7 Weight up to TD 11.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2300 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 1A-20 will be 1A-19. As designed, the minimum distance between the two wells would be 24' at 630' MD. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARO0 ALASKA. Inc Pmd lA, Well No: ~-0 Propoeed Kupmruk Field, North Slope, Alaeka 0 _ RKB ELEVATION, 102' 1000 _ 2000 _ 3000_ 4000_ 5000 _ 6000 _ rooo = KOP TVD=500 TMD=500 DEP=O 3 BUILD 3 DE9 g PER i00 FT 15 21 B/ PERMAFROST TVD=1502 TMD=1555 DEP=284 39 45 EOC TVD=1877 TMD=2038 DEP=587 T/ UGNU SNDS TVD=2702 TMD=3229 DEP=1445 T/ W SAK SNDS TvD=3277 TMD=4059 DEP=2044 AVERAGE ANGLE 46 DEG 9 MI N B/ W SAK SNDS TVD=3692 TMD=4658 DEP=2476 9 5/8" CSG PT TVD=3892 TMD=4947 DEP=2684 K-lO TVD=4112 TMD=5264 DEP=2913 K-5 TVD=5142 TMD=6751 DEP=3986 TARGET - T/ ZONE C TVD=6182 TMD=8252 DEP=5068 T/ ZONE A TVD=6455 TMB=8646 DEP=5352 B/ KUP SNDS TVD=6553 TMD=8788 DEP=5455 TD / LOG PT TVD=6692 TMD=8988 DEP=5599 I I i I · % % 1 000 2000 3000 4000 VERTICAL SECTION \ \ \ \ I 5000 I 6000 HORIZONTAL SCALE 1 IN. PROJECTION = 1 000 FEET 3000 2OOO 1000 lOOO ARCO ALASKA. Inc. Pmd lA. Well No~ 20 Kupmruk Field. North 1000 0 I SURFACE SURFACE LOCAT ! ON, 1091' FSL. 314' FWL SEC. 5. TIlN. RIOE Proposed Slope, Alaska WEST-EAST 1000 2000 3000 I I I N 77 DEG 39 MI N E 5068' (TO TARGET) 4000 5000 §000 I I I TARGET TVD=6182 THD=8252 OEP=5068 NORTH 1084 EAST 4951 TAROET LOCATION, 217S' FSL. 15' FEL SEC. 5. TllN. RIOE TD LOCATION' 2288' FSL. 503' FWL SEC. 4. TIIN. RIOE 50 1 O0 1 50 I I I \ io ~ ~oo · "2,.100 200 250 :300 350 400 I I I I ~ 900 "',2-1 oo \ '~ J,900 700 450 I 500 550 ~ I . oo $oo 500 ~q?oo ~ $oo ~t~6~,500 I I I I I 50 1 O0 1 50 200 250 ;oo 1700 900 5OO I -"' ~"1:300 300 '~0 "3~.~oo --~oo I I I I I 350 400 450 500 550 1550 1 500 450 1 40C 1 35C 130C 1 25C 120C 115C 110C I05C 1 00( 950 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD lA PAD . . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to 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. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. 5 4 I I 13 5/8" 5000 F ol BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TESTTO 250 PSI AND 3000 PSI AS IN STEP 4. 7, CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'FI'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI, 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKSAND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 30(X) PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5(X)O PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 ,.UPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 6 4 3 r---O_ ~ 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENAN(;;E & OPERATION , . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OFANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ? 18 19 DS 1H )35 T12N VICINITY MAP NOTES: 1. BASIS OF LOCATION AND ELEVATION IS D.S. MONUMENTATION PER LOUNSBURY & ASSOCIATES. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 5. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 4. LOCATED WITHIN PROTRAOTED SECTION 5, T 11 N, R 10 UMIA T MERIDIAN, ALASKA. NO. 17L 16A 79H 20M 21G 22B 251 24F 25C 26J 27E 28D 5971570.96 5971251.02 59 71203. 06 59 71179. 05 5971155.00 5971150.99 5971011. I0 5970915.06 5970819.05 5970723.15 5970699.09 540180.24 540180.20 540180.24 540180.17 540180.25 540180.19 540180.26 540780.25 540180.28 540180.21 540180.20 540180.27 LAT. LONG. F.S.L. F.W.L. O.G. PAD 59 706 75. I0 _,,.5Q~,~'~'~,,,l~ ¢.0 '2 6. , - -.: 49~~ RECIS~RED AND LICENSED TO PRAC~CE , LAND SUR~N, IN ~E STA~ OF ALASKA AND ~A T ~IS PLA T REPRESENTS A SURLY DON E BY ME OR UNDER MY DIRECT SUPER~SION AND ~A T ALL DIMENSIONS AND O~ER ~ETAILS ARE OORREOT AS OF OCTOBER 2~, 1990. 0/30/90 Ohonge F.N.L. ~o F.S.L. Dar e D escri~ tion 70' 19'57.794" 149' 40",26.654" 1285' ,.]15' 59.6' 67.0' 70' 19'56.614" 149' 40'26.654" 1165' 314' 61.0' 66.5' 70'19'56.143" 149'40'26.660" 1115' 514' 61.7' 66.8' 70'19'55.906" 149' 40'26.666" 1091' 514' 62.0' 67.0' 70'19'55.670" 149' 40'26.667" 1067' ,314' 62.4' 66.9' 70' 19'55.434" 149' 40'26.67,.7" 1045' 313' 62.8' 67.0' 70' 19'54.255" 14.9' 40'26.689" 925' 312' 63.8' 66.,7' 70'19'53.310" 14.9'40'26.705" 827' 511' 64.0' 66.7' 70'19'52.,.T66' 149' 40'26.719' 7`31' 511' 65.5' 67.0' 70' 19'51.422" 149' 40'26.756" 655' ,:710' 62. 7' 67.2' 70'19'51.186" 149'40'26.740' 611' 310' 62.5' 67.3' 70' 19'50.9. 742" 587' 509' 62.4' 67.2' ARCO ALASKA, INC. D WG// NSDK-1AOO-CEA-D1AX-6101D10 ARCO Alaska,Inc. DRILL SITE 1-A WELL CONDUCTORS t/1 ?-~2B AS-BUiLT LOUNSBURY & ASSOC. Dr. DC~; Chk: A.~ii' REV. I 10/26/90[Dwg: NSIK 6.10~d10 CHECK LIST FOR NEW WELL PERMITS (1) Fee ~ ~f/~~ 1. ( 2 ) L o c /h (2 thru 8 (8) (3) Admire ~/~_~ ~ 9. (19 th~u 13) 10 :.., ...... ,. ,~:~ ,. .... 1t-.~$ .... ~ 11 ~'~ .~,,,,.,. (14 thru 22) (23 thru 28) Company ~_~. .~, Lease & Well No. /q~ YES NO Is the permit fee attached .......................................... ~, ' ~EMARKS ' 2. Is well to be located in a defined pool ............................. 3. ,Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~ · Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ................................... Does the well have a unique name and number ..... ] ................... --~- ' ' 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... ~.~,~,, Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate'~ Are necessary diagrams and descriptions of diverter and BOPE attached. /~,. Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER ~.~_ /.7~/~d (29 thru 31) (6) Add: /~, z> . !.,~-f~- 9~ Geology: EngSneerin~: -- LCS rev: 11/30/90 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE,. 0 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. T° 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 APPENDIXi ,, No special 'effort has been made to chronologically organize this category of information. .o (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/12/21 ORIGIN OF DATA: MPT REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: MPT DATE: 90/12/21 ORIGIN OF DATA: lA20 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED · ._ FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 1A20.MPT SERVICE NAME: MPT VERSION #: V 3.26 DATE: 90/12/21 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: lA-20// API#: 50-029-22112// DATE: 21-DEC-90 LOCATION: 1091' FSL, 314' FWL, SEC. 5, TWP. llN, RANGE 10E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA.// RIG: DOYON 14// CO. REP.: McCAULEY// SSDS MPT ENG: TILLEY, HANIK & KRELL// COMMENTS >>>> NEUTRON AND DENSITY LOGS ARE CALIPER CORRECTED. POST-JOB CALIBRATION FACTORS APPLIED. DGR/CN~/SFD/EWR RECORDED AT 12/18/18/6 SECOND SAMPLE RATES. LOGS MEASURED FROM KB 102' AMSL. Rm=2.0 @ 74 DEG., Rmf= 1.4 @ 74 DEG., Rmc=2.9 @ 74. DEG., MAX. CIRC. TEMP 143 F EWR DISTANCE FROM BIT = 65.08', DGR DFB=44.86', SFD DFB=51.95, CN~ DFB=59.53. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 DDE MWD PPF 0 0 0 0 1 4 0 1 68 FXN MWD HOUR 0 0 0 0 1 4 0 1 68 DDN MWD PPF 0 0 0 0 1 4 0 1 68 NFO MWD CTS 0 0 0 0 1 4 0 1 68 NFl MWD CTS 0 0 0 0 1 4 0 1 68 NN0 MWD CTS 0 0 0 0 1 4 0 1 68 NN1 MWD CTS 0 0 0 0 1 4 0 1 68 FXD MWD HOUR 0 0 0 0 1 4 0 1 68 DDD MWD PPF 0 0 0 0 1 4 0 1 68 GRC MWD API 0 0 0 0 1 4 0 1 68 NPSC MWD P.U. 0 0 0 0 1 4 0 1 68 FXD2 MWD HOUR 0 0 0 0 1 4 0 1 68 RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 DDD2 MWD PPF 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE ID ORDER# DEPT ROP MWD EWR MWD CAL MWD FXE MWD DDE MWD FXN MWD DDN MWD NFO MWD NFl MWD NN0 MWD NN1 MWD FXD MWD DDD MWD GRC MWD NPSC MWD FXD2 MWD RHOB MWD DDD2 MWD LOG TYP CLS MOD NO. FT 0 0 0 0 1 FT/H 0 0 0 0 1 OHMM 0 0 0 0 1 INCH 0 0 0 0 1 HOUR 0 0 0 0 1 PPF 0 0 0 0 1 HOUR 0 0 0 0 1 PPF 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 HOUR 0 0 0 0 1 PPF 0 0 0 0 1 API 0 0 0 0 1 P.U. 0 0 0 0 1 HOUR 0 0 0 0 1 G/C3 0 0 0 0 1 PPF 0 0 0 0 1 SZE PROC SPL REPR LVL CODE 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 ** DATA VERIFICATION (every 100 FT) ** DEPT ROP EWR CAL FXE DDN NF0 NFl NN0 NN1 GRC NPSC FXD2 RHOB DDD2 DDE FXD FXN DDD 7900.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8000.000 -999.250 2.569 -999.250 -999.250 12.500 .741 796.333 740.333 2440.000 2333.333 -999.250 -999.250 38.304 -999.250 -999.250 4.348 -999.250 -999.250 8100.000 59.737 2.275 8.723 1.267 10.000 2.439 567.000 543.000 2376.000 2424.000 -999.250 113.382 47.291 -999.250 2.217 3.846 -999.250 4.348 8200.000 61.422 1.684 8.867 ~.209 8.333 4.000 607.000 559.000 2344.000 2456.000 -999.250 106.254 46.750 -999.250 2.483 5.556 -999.250 2.941 8300.000 55.336 2.014 8.973 2.017 12.500 3.571 511.000 503.000 2296.000 2232.000 -999.250 123.604 50.500 -999.250 2.255 2.000 -999.250 2.778 8400.000 141.166 10.063 8.692 1.089 7.143 2.000 647.000 767.000 3000.000 3096.000 -999.250 55.082 28.239 -999.250 2.296 1.818 -999.250 4.348 8500.000 156.299 29.118 8.665 1.835 9.091 3.704 631.000 655.000 3064.000 2936.000 -999.250 62.951 29.672 -999.250 2.293 3.846 -999.250 3.448 8600.000 40.492 6.759 8.710 1.110 9.091 3.448 695.000 663.000 2936.000 3064.000 -999.250 70.100 29.804 -999.250 2.506 4.167 -999.250 3.704 8700.000 45.449 4.139 8.805 1.552 14.286 3.226 599.000 575.000 2808.000 2808.000 -999.250 88.520 36.174 -999.250 2.430 2.439 -999.250 2.941 8800.000 158.050 22.754 8.804 1.258 12.500 3.846 671.000 679.000 3064.000 3112.000 -999.250 52.529 27.661 -999.250 2.316 7.143 -999.250 3.333 8900.000 41.309 3.087 8.830 1.522 11.111 3.704 639.000 615.000 2456.000 2632.000 -999.250 101.481 40.513 -999.250 2.366 5.882 -999.250 3.704 9000.000 44.878 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9100.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9200.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 212 DATA RECORDS ** FROM 7900.00 TO 9275.00 FT ** FILE TRAILER** FILE NAME: lA20. MPT SERVICE NAME: MPT VERSION #: V 3.26 DATE: 90/12/21 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** '**~TAPE TRAILER** SERVICE NAME: MPT DATE: 90/12/21 ORIGIN OF DATA: la20 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/12/21 ORIGIN OF DATA: MPT REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER ********** DIRECT DIGITAL LOGGING COMPUTER RECEIVED JAN 1 5 199t Atesl~ Oi~ & t~as Cons. D~ PROCESSED ANALYSIS~'''' LLLLLLLLLL LLLLLLLLLL IIIIIIIIII SSSSSS$S IIIIIIIIII SSSS$SSSS$ II SS SS II SS ii SS II SSSSSSSSS II SSSSSSSSS II SS II SS Ii SS SS ililIIilii SSSSSSSSSS IIIIIIIIII SSSSS$$S DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU OD DD UU UU DD DD UU UU DDDDDDDDDD UUUUUUUUUUUU DDDDDDDDD UUUUUUUUUU MM MM MMM MMM HHHM HHHH MN MM MH HH MM MMHH NH MM HH MM MM MM HH MN MN MM MM MM MM PPPPPPPPPPP PPPPPPPPPPP PP P PP P PP P PPPP~FFFPPP PPPPPPPPPPP PP PP PP PP PP II ili I1 11 11 il il 11 il lllliilii 00000000 0000000000 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 00 00 0000000000 00000000 2222222222 222222222222 22 22 22 22 22 22 22 22 22 222222222222 222222222222 JJ JJ JJ JJ JJ JJ JJ JJ JJ JJ JJ JJJJJJJJJJJJ JJJJJJJJJJ 444 4444 44 44 44 44 44 44 4444444,$444 444444444444 44 44 44 44 44 AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 444 4444 44 44 44 44 44 44 44444444444 444444444444 44 44 44 44 44 NN NH NN NN NNN NN NNNN NN NN NN NH tin NN NN NN NN NN NN NN NN NN NN NH NN NNNN NN NNN NN NN m m ~ m i m AR AAAA AA AA AA AA AA AA AA ' AA AAAAAAAAAAAA AAAAAAAAAAAA AA ' AA AA AA AA AA AA AA 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 MN HM MN MM MN MN MM MM HH MN MN H H NH NH HHH MN MM H MHHM H MM H H H H H 11 iii llil 11 ii ii ii ii ii ii iiiiliiiil iiiiiiiiii REEL HEADER Service name: ~:G5FO1 Previous reel: HEADER Data: 91/01/02 Commmnts: Origin: RECORDS Reel name: 492217 Page 1 Continuation #: 01 TAPE HEADER Smrvice name: &GSF01 Previous tape: Date: 91/01/02 Comment~: Origin: Tape name: 492217 Continuation #: 01 FILE HEADER ~ ~ .~ .~ :~ .~ :~ :~..~ :~ :~ .~ .~ :~ .~ ~ .~ ~ :~ ~ :~ :~ File name: ,001 Servic~ name: Version Datm: Maximum length: 1024 Film t~pe: LO Prmviou~ ?ile: NHEH CH UN FH COUN STAT CTRY ~IP-I N LATI LONG SECT TOWN RANG EKB Er.)F EGL PD LHF DHF RUN TINE DATE LCC SON LUN FL LUL ENGI W][TN DD DL CBDi CBL! TLI BLI TCS TLAB BHT .HR T HT MSS DFD HVIS DFPH DFL RM RHF MFST HFSS RHC I NFORMAT I ON RECORDS COHTENTS UN IT ARCO ALASKA IHC. iA-20 KUPARUK NORTH SLOPE ............. ALASKA ............. USA ............. 221 i2. 000 ........................ 0 Deq. 0 Min. 0. 0 Sec. H 0 De~ 0 Min. O. 0 S~c. W 0,5 ...... lin ..... IOE ..... 1 02,000, iOl .000. 67. 000.. MS ...... l?O0. 000. 19/i.c,?90, 492217 7636 NO~TH SLOPE NORTH SLOPE YARBRO/RANDELL BEAL 9035,000 0.000 ..... 4947,000 4952,000 JS. 000,. 8912. 000 I 1 00,000 i700,000 170.000. 170.000. NEWDRZLL C~RCUL~TED 10,700 ..... 41 ,000 ..... 0,000 ...... ~.000 ...... 2,320 ...... 2,080 ...... 77,500 ..... MEAS ..... 2,420 ........... IelllIJJIlIIIlll APi NUN: 50-029-22ii2 ................ DATE LOGGED: 12-19-90 ................ IlIIIIIlIlIIIIII IlIliIIIIIII IJllIIIIlIII i I · I · · i · i · · i i · · · · · 4, · i . III.III IIIlgllIlIIIllIIIIlIlItIlI IIlI.IIIJItlJlIlfIllililI· Iii IIli · Ill I III I · I I · FT FT FT FT FT FT FT FT FT HR HR DEGF DEGF LB/G CP OHNH OHHH DEGF OHHM TYPE CATG 0 0 0 0 0 0 0 0 0 0 0 0 3 3 3 3 3 0 0 0 0 0 0 0 0 0 0 3 3 3 3 3 3 2 4 1 1 2 2 2 2 2 2 2 2 2 2 2 SIZE 4O 4O 4O 2O 2O 20 4 ,34 34 2 4 4 2 2 2 2 4 '2 10 10 20 20 2O 2O 4 4 4 4- 4 .4 4 2O 2O 4 4 4 4 4 4 12 ,4 CODE 65 65 65 65 65 65 68 65 65 79 65 ~S 65 68 68 68 65 65 68 68 68 68 65 68 Pag~ ERROR NCST BS I NFORMAT I OH RECORDS COHTEHTS UH ! T 7.9 -000 .................................................. HE~S ............................................. 9.625 ................................................... 8.500 ................................................... DEGF TYPE CATG SIZE 4 ~2 4 4 CODE 65 F'a9~ ERROR COMMENT RECORDS Well Wel 1 Well Wel 1 Well Well Well Wel I Location Comment i: Location Commmnt 2: Location Comment 3: Location Commmnt 4: File Comment File Comment 2: File Comment J: File Comment 4: TO SURFACE: 1091: F'SL b 314' FWL BOTTOM DEPTH = 8950' & NO REPEAT RAN DUE TO HOLE CONDITIONS. HRI, ML, SDL/DSN RUN IN COMBINATION. HEAD TENSION AND LINE TENSION ARE RECORDED 46.25' DEEP TO THE 80TTOM OF TOOL DUE SOFTWARE ERROR. DXCO = +2.0 MMHOS AND MXCO = -2.0 MMHOS. LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most closely match Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP 80TTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 4850.00 8930.08 ER SDL GAPI GR SDL GAPI 4870.00 8923.00 FDSN DSN2 CPS FDSN DSN2 CPS 4870,00 8923.80 NDSN DSN2 CPS NDSN DSN2 CPS 4870,00 8923,00 NPHI DSN2 DECP NPHI OSN2 DECP 4870.00 8923.00 NEAT DSN2 C/C NEAT DSN2 C/C 4870.00 8923.00 DPHI SDL DECP DPHI SOL DECP 4870.00 8923.00 DRHO SDL G/C3 DRHO SDL G?C3 4870,00 8923,00 FSDL SDL CPS FSDL SDL CPS 4870,00 8923,00 NSDL SDL CPS NSDL SDL CPS 4870.00 8923.00 Page 4 PE SDL PE SDL 4870.00 PELC SDL PELC SDL 4870.00 ~L SDL ~L SDL 4870,00 ~S SDL ~S SDL 4870,00 RHOB SDL G/C3 RHOB SDL ~?C3 4870.00 CAL. I SDL IN CALI SDL IN 4870,00 HINV NL OHHN NINV ML OHM~ 48?0,00 MNOR ML OHMM MNOR ~L OHMM 48?0,00 HDR HRI HDR HRI 4870,00 HDX HRI HDX HRI 4870,00 HHR HRI HNR HRi 4870,00 HHX HRI H(~X HRI 4870,00 HDR$ HRi OHHN HDRS HRI OHMN 4870,00 HMRS HRI OHMN NNR$ HRI OHMN 4870,00 HDCN HRI HHHO HDCH HRI MHHO 48?0,00 HHCN HRI HMHO HHCN HRI MMHO 4870,00 DFL HRI OHM~ DFL HRI OHMM 4870,00 SP HRI MY SP NRI HV 4870,00 TENS .SDL LBS TENS SDL LBS 4870.00 DLOD SDL LBS DLOD SDL LBS 4870,00 892~.00 892~.00 8923.00 8923.00 892~.00 892~.00 892~.00 892~,00 892J.00 892B.~0 892~.00 892~ O0 892~ O0 892~ O0 892~ O0 8923 O0 8923 O0 8923.00 8923.00 8923.00 ~d~':~.4. L. qn~ ,'t_~ol~q uo.~-4, e~.~..~..~::)a ~bn.4. e~] 91. NOIldI~3$3~] 3dA1 · ~ ~H3039 ~3098 A~LN3 ~*~ ~6ed 99 .~ 0 99 ~ 9~ 3~JO~ SNOIi 3I I33dS 3ZIe._, 3dAl ABIH3 **** $.~ 30'18 A.~£N3 DATA FORMAT SPEC I F I CAT IONS DATUM SPECIFICATION BLOCKS **** SERVICE SERVICE API API APl APl FILE MNEN ID ORDER # UNIT LOG TYPE CLASS MOD # DEPT 492217 FT 0 0 0 0 CR SDL 492217 GAPi 94 0 0 FDSN DSN2 492217 CPS 94 0 0 NDSN DSN2 492217 CPS 94 0 0 NPNI DSN2 492217 DECP 94 0 NRAT DSN2 492217 C?C 94 0 DPHI SDL 492217 DECP 94 0 0 DRHO SDL 492217 G/C3 94 0 0 FSDL SDL 492217 CPS 94 0 0 NSDL SDL 492217 CPS 94 0 0 PE SDL 492217 94 PELC SDL 4922i7 94 0 O 1 QL SDL 492217 94 0 0 QS SDL 492217 94 0 0 i RHOB SDL 492217 G/C3 94 0 0 CALl SDL 492217 IN 94 0 0 1 MINV HL 492217 OHHH 94 0 0 MNOR HL 492217 OHHH 94 0 0 HDR HRI 492217 94 0 0 1 HDX HRI 492217 94 0 0 HNR HRI 492217 94 0 HNX HRI 492217 94 0 0 HDR$ HRI 492217 OHMH 94 0 0 1 HMRS HRI 492217 OHMM 94 0 0 HDCN HRI 492217 NMHO 94 0 HMCN HRI 492217 NMHO 94 0 0 1 DFL HRI 492217 OH~H 94 0 0 SP HRI 492217 NV 94 0 0 TENS Sbt.. 492217 LBS 94 0 0 DLOD SDL 492217 LBS 94 0 O PRC # SiZE LVL SMPL RC m~ PROCESS iNDiCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Pag~ D TA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC QL QS RHOB CALi MIHV HHOR HDR HDX HHR HHX HDRS HHRS HDCN HMCH DFL SP TEHS DLOD Page 8923.000 7043,675 1.013 -12345.0O0 8900.000 7043.675 1.013 305.165 8800.OO0 8145.074 5,922 75,117 8700.000 7542.874 2.812 234,157 8600,000 8234. 674 5. 325 138.4:87 8500. ?602.4 6, ,31 8400.0 8614,6' 1,1 110,840 8300,000 7383.675 1,265 522.487 85.692 15553.055 1.188 -12345.000 85.692 15553.055 i.188 313,907 74,313 16704.91 0 6,987 65.982 87.878 16889.195 2.715 234,317 7 !. 093 17 036,199 5,010 1,37.587 58,287 1637;3.770 8.700 30.5'87 52.455 16871.625 1,628 108.520 2099.275 5,173 0,000 20000.000 2099,275 5.173 222,644 3,040 2580.473 3.621 56.643 11,175 2226.670 2.761 1'85.247 :3,919 2747,4'36 2,57O 124.908 8.164 23,73. 094 4,345 51 ,986 53.634 2939,405 3,197 93,769 9,672 15850.879 5.117 0,000 123450000. ,368 ,600 0.000 5356.622 7,981 ,189 -.025 ,333 2,338 8.258 O,O00 -12345,000 -12345.000 710,996 15850,879 ,368 7,981 ,189 -.025 5,117 ,600 ,333 2,338 8,258 49.486 285.182 27,862 3.277 3.186 131,880 5036,389 653,456 17212.156 3.677 10.851 105.087 15853,316 2.950 39.234 125.920 .315 -,027 58.189 6084.424 ,329 .043 211,882 5036,389 .292 ,013 142,412 5021.833 -.027 45,173 12532,748 17475,148 2.279 15,650 118,689 16850,672 5,224 14,354 90.489 7.050 ,218 , 009 . O13 2. 290 8. 523 1 ,915 13,313 15. 156 90.'3.344 7,526 .165 -.008 2.378 15.685 4,271 685,240 6,723 ,200 -, 007 2,320 -4,114 7,221 700,036 7,505 ,203 ,010 2,315 8,281 31 .588 2541 .86,4 ,045 9,4i0 4,268 .030 8,905 7,268 -.001 8,846 32.693 1 7218,4.06 .272 6,192 ,23:9 ,009 3,412 -. 126 , 01 0 2,256, 9,7.38 14,707 1 04,268 3,178 9. 022 9.215 140,02.3 5356,622 772. 920 131 .282 1503. 156 13482.72.3 ,448 9,481 .196 -.016 15913. 055 2,722 ;3.425 -1 , O00 -.429 2.326 9.738 ! , 353 366 , 724 1 08. 978 462 , ;346 49 . 905 t , 9i 4 i . 849 54! , 021 I , 917 123.1 02 5007,277 725,792 DEPT F~DL MINV HDCN ~R HNOR HHCN FDSN PE HDR DFL DATA NDSN PELO HDX SP RECORDS t~PHI QL HMR TEHS HRAT QS HM" DLOD DPHI RHOB HDRS DRHO HHRS Pag~ 8200.000 102,115 1454 5609,074 i5134,055 4 1,467 1,166 429 641.i55 663.221 i 8100.000 124.577 1399 7918,675 16953,195 3 1,686 1.529 380 525.758 531,421 2 8000.000 i97,665 -999 -999,250 -999,250 -999 -999,250 -999,250 262 330,197 337,265 2 7900.000 225.161 -999 -999,250 -999,250 -999 -999,250 -999,250 261 337,454 337.914 3 7800.000 112.930 -999 -999,250 -999,250 -999 -999,250 -999,250 252 317,865 321,951 3 7700,000 115,329 -999 -999,250 -999,250 -999 -999,250 -999,250 262 337,283 337,323 3 7600,000 107,649 -999 -999,250 -999.250 -999 -999,250 -999,250 200 249,239 247,865 4 7500,000 146,265 -999 -999,250 -999,250 -999 -999,250 -999,250 270 342,852 343,561 3 .272 ,186 .313 .47i · 055 .247 .333 · O22 .250 .250 .678 ,971 ,250 .250 ,981 .427 ,250 ,250 .072 ,235 .250 .250 .957 ,633 .250 .250 .922 ,456 ,250 ,250 ,667 ,t05 13855.887 3.684 i34.002 132,765 13287,387 3.657 ii3.730 i29,83i -999,250 -999.258 64.613 124,486 -999,250 -999,250 61,587 i32.767 -999,250 -999,250 58,377 i25,859 -999,250 -999,250 61.432 i25,087 -999,250 -999.250 45,044 129.483 -999,250 -999,250 74,636 133.337 580 4992 467 4934 -999 -999 4967 -999 -999 308 4792 -999 -999 300 4879 -999 -999 317 4757 -999 -999 242 4660 -999 -999 4818 .458 10.07! ,072 -.002 .031 .039 2,531 9,269 .494 66.358 1,560 i.508 ,72i 752.645 . 451 10. 039 . 186 , 041 o 023 . 029 2. 343 1 O, 342 · 198 50. 646 i · 902 i . 882 .497 797. 032 ,250 -999,250 -999,250 -999,250 .250 -999,250 -999,250 il.318 .190 25,323 3,028 2,965 ,557 743,328 .250 -999,250 -999,250 -999,250 .250 -999,250 -999,250 10,324 .053 20.860 2.963 2,959 ,334 704,420 .250 -999,250 -999,250 .250 -999,250 -999,250 .252 21.591 3,146 ,945 715,929 -999,250 1 0,880 3,106 ,250 -999,250 -999.250 -999,250 .250 -999.250 -999,250 lO,OS2 ,070 22,235 2.965 2.965 .289 686,336 ,250 -999,250 -999.250 -999,250 .250 -999,250 -999,250 i 0,571 035 18,516 4,012 4. 034 ' 917 735, i 08 .250 -999,250 -999,250 -999,250 ,250 -999,250 -999,250 10,571 ,875 28,149 2,917 2,911 ,617 781,140 DEPT FSDL HIHV HDCN GR NSDL HNOR HHCN FDSN ---- DFL DATA NDSN PELC HDX SP RECORDS NPH I QL HMR TEHS HRRT HMX DLOD DPHI EH08 .HDRS DRHO CALI HHRS_ Pag~ 7400.000 -999.250 -999.250 514.195 7300.000 -999,250 -999,250 277,934 7200.000 -999.250 -999,250 317,889 ?I00.000 -999.250 -999,250 493,163 7000,000 -999.250 -999,250 335,721 6900.000 -999,250 -999,250 480.53! 6800,000 -999,250 -999,250 461.701 6700.000 -999,250 -999.250 294,695 149.372 -999.250 -999,250 563.498 132,256 -999.250 -999.250 280.667 186.645 -999.250 -999,250 3ti,510 168.713 -999.250 -999,250 509,855 144,120 -999,250 -999.250 363,305 156,997 -999.250 -999,250 498,067 162.761 -999,250 -999,250 473,929 J53.5J8 -999,250 -999,250 297.173 -999,250 - ~':~ .':.J. :..'D U 330.170 -2, i39 -999,250 -999,250 220. 067 3,503 -999,250 -999.250 247,952 3,551 -999,250 -999,250 332,832 1,924 -999,250 -999,250 267,076 5,285 -999,250 -999,250 356,995 1.758 -999,250 -999,250 333,816 J,855 -999,250 -999,250 232,550 3,107 -999.250 -999.250 89.133 i34,604 -999,250 -999.250 48.276 i31.614 -999,250 -999.250 54,7i3 119,271 -999,250 -999.250 99,410 127,825 -999,250 -999.250 84,172 119,740 -999,250 -999,250 109.400 132,718 -999,250 -999.250 95,708 131,387 -999.250 -999.250 53,999 -999 -999 423 4503 -999 -999 264 4669 -999 -999 299 4485 -999 -999 428 4468 -999 -999 349 4406 -999 -999 456 4345 -999 -999 434 4257 -999 -999 281 409! .250 .250 .790 .217 .250 ,250 .519 .678 .250 .250 .677 .694 .250 ,250 .933 ,172 .250 .250 .688 .845 .250 .250 ,247 ,517 .250 .250 .311 .905 ,250 ,250 ,759 ,444 -999.250 -999.250 38.512 726.340 -999.250 -999.250 16.432 726.888 -999,250 -999,250 17.884 755,384 -999.250 -999,250 46.121 735,108 -999,250 -999,250 37,930 725.792 -999,250 -999,250 48,309 733.464 -999.250 -999,250 44,096 677.020 -999,250 -999,250 20,744 627,700 -999,250 -999,250 1,945 -999,250 -999.250 3,598 -999,250 -999,250 3,146 -999,250 -999,250 2.028 -999.250 -999.250 2,979 -999,250 -999.250 2.081 -999,250 -999.250 2,166 -999,250 -999,250 3,393 -999.250 9,87i i ,775 -999,250 10,625 3,563 -999.250 J 0,607 3,2i0 -999.250 9.896 I .961 -999.250 10.136 -999,250 10.398 2.008 -999,250 9,820 2,t10 -999, ~':'" 50 1 0,661 3,."365 DATA RECORDS DEPI GR FDSN NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC QL QS RHOB CALl MIHV MHOR HDR HDX HHR HMX HDRS HHRS HDCN HMCN DFL SP TEHS DLOD 10 6600 -999 -999 460 6500 -999 -999 144 6400 -999 -999 322 ~300 -999 -999 323 6200 -999 -999 343 6100 -999 -999 328 6000 -999 -999 409 5900 -999 -999 375 .000 .250 .250 .t98 .000 .250 .250 .368 ,000 .250 .250 .239 .000 ,250 ,250 .821 ,000 .250 ,250 ,103 ,000 ,250 ,250 ,230 .000 .250 .250 .210 ,000 ,250 ,250 .109 129 -999 -999 498 73 -999 -999 119 112 -999 -999 326 8,3 -999 -999 ,322 73 -999 -999 357 I 05 -999 -999 342 108 -999 -999 430 -999 -999 392 ,998 .250 ,250 .766 .835 · 250 ,250 .498 .425 ,250 ,250 ,573 · 088 ,250 ,250 ,842 ,325 ,250 ,250 ,816 .250 .250 ,970 ,909 .250 ,250 ,314 ,250 ,250 .442 -999 -999 325 1 -999 -999 208 ii -999 -999 252 2 -999 -999 25i 3 -999 -999 246 2 -999 -999 25:3 2 -999 -999 304 2 -999 -999 279 2 ,250 ,250 · 057 · 863 ,250 · 250 ,470 .047 ,250 ,250 ,582 ,95i ,250 ,250 ,605 ,142 .250 ,250 ,ii3 ,537 ,250 ,250 ,537 .722 .250 .250 ,060 ,149 .250 .250 ,255 ,42! -999.250 -999.250 -999 -999.250 -999.250 -999 87.671 425.161 41 i30,815 4082.683 679 -999,250 -999,250 -999 -999,250 -999.250 -999 63.67i 223,390 28 i28.892 4056,400 678 -999.250 -999.250 -999 -999.250 -999.250 -999 65.609 303.175 27 i31,18i 4179,056 7i2 -999,250 -999.250 -999 -999,250 -999,250 -999 62,287 305.2t8 27 i33,775 4i35,250 7i0 -999.250 -999,250 -999 -999,250 -999.250 -999 55.864 311,276 23 133,030 3995,072 718 -999,250 -999,250 -999 -999,250 -999,250 -999 62,608 3i3,295 26 130.083 39i6,222 685 -999,250 -999,250 -999 -999,250 -999,250 -999 83.175 379,845 38 i3i,137 3942,505 753 -999.250 -999.250 -999 -999,250 -999.250 -999 72,682 357.227 34 135,405 3811.088 .250 .250 .824 .212 .250 .250 .19i .250 .250 .702 ,640 ,250 ,250 .337 ,448 .250 ,250 .312 .668 .250 ,250 .7i0 ,240 .250 ,250 .503 ,192 ,250 ,250 ,839 ,904 -999,250 -999.258 2.173 -999.250 -999,250 6.927 -999.250 -999,250 3,i03 -999,250 -999,250 3.088 -999,250 -999,250 2.915 -999,250 -999,250 3,047 -999,250 -999,250 2,444 -999,250 -999,250 2,666 -999.250 i0.643 2,005 -999.250 9,855 8,368 -999,250 i0,475 3,062 -999,250 i 0.48,7 3. 097 -999,250 i0,839 2.796 -999,250 i0,796 2,9i6 -999.250 10,727 2 3~ -999,250 i0,793 2.548 DATA RECORDS DEPT FSDL MIHV HDCN GR NSDL HNOR HHCH FDSN PE HDR DFL NDSN PELC HDX SP NPHI QI. HHR TENS NRAT QS HMX DLOD DPHI RHOB .HDRS DRHO CALl HHRS Pagm ii 5800,000 93 . 523 -999. 250 -999,250 -999,250 -999,250 -999,250 -999. 250 260. ! 55 340. 035 357,859 2,597 5700,000 i 06.614 -.999. 250 -999,250 -999,250 -999,250 -999. 250 -999,250 289. 025 390. 055 426,493 2.18i 5600,000 i05,749 1641,824 911i,674 17463.195 2.754 -999,250 -999,250 277.577 373,557 .400.306 2.i97 5500.000 86,403 2041,232 9087,674 17336,199 2,488 -999,250 -999,250 204,244 257.0tl 267,689 3,458 5400,000 53,652 1667.079 12027,275 18323,625 2,525 -999,250 -999,250 307,414 410,604 456.550 1.983 5300,000 115,321 1625,270 9040,674 17353.484 2.920 -999.250 -999,250 240.853 322,849 352,380 2,532 5200,000 98,419 1906.829 9305. 875 i 740! , 484 2.615 -999,250 -999. 250 189,746 220,173 227.915 3,715 5i00,000 106,446 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 275.875 390,918 429,608 2,123 -999.250 -999,250 65.584 i31,238 -999.250 -999.250 73,348 i29,107 14433,197 2,885 74,391 i33,10! 15856.059 2.773 42,855 i37,701 15130,832 2,628 70,235 i32,339 14441.809 2,953 52.940 i18,241 15351,758 2,789 37,8i4 i09,640 -999,250 -999,250 59.778 93,67i -999,250 -999.250 322,444 3662.149 -999.250 -999,250 373,794 '3635.866 ,402 -,087 354.785 3618,344 ,352 -,068 259,298 3679.671 ,425 -.075 416,333 3469.404 ,410 -,069 308.341 3399,315 ,362 -, 052 230,052 3355,51 0 -999.250 -999.250 361.140 3267.898 -999 -999 30 610 -999 -999 35 553 9 603 8 i7 9 32 563 9 20 569 8 i4 549 -999 -999 23 483 .250 .250 · 786 .712 .250 .250 ,960 ,172 ,292 .018 ,160 .040 .2ii .003 ,128 ,594 .015 .570 .584 .392 008 .944 064 .510 .034 .467 .884 .250 ,250 .778 .576 -999,250 -999,250 2,941 -999,250 -999,250 2.564 ,234 2.264 2,677 .238 2,257 3.891 .337 2,094 2.435 .233 2.265 3.097 ,248 2,241 4.542 -999,250 -999,250 2,55@ -999,250 i0.757 2.794 -999.250 ii .081 2.345 ,043 i i . 236 2,498 ,035 i0.760 3.736 ,036 10.566 2,i90 .039 i0,95i 2,838 ,0,33 ii .iii 4, ..,t u -999,250 ii,272 2.328 DEPT FSDL MINV HDCN GR NSDL MNOR HMCN FDSN PE HDR DFL DATA NDSN PELC HDX SP RECORDS NPHI QL HMR TENS NRAT OS HMX DLOD DPHI RH08 .HDRS DRHO CALl HMRS Page 12 5000,000 -999,250 -999,250 4900,000 -999,250 -999,250 -999,250 Ji4,691 -999,250 -999,250 283,575 54o20i -999,250 -999,250 -999,250 -999,250 -999,250 182.603 J,GJG -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 39,817 85.788 -999,250 -999.250 -999,250 91,642 -999,250 -999,250 219,829 345J,882 -999,250 -999,250 -999,250 3495,688 -999,250 -999,250 i5,348 G03,580 -999,250 -999,250 -999.250 596.464 -999.250 -999,250 4,304 -999,250 -999,250 -999.250 -999,250 i0,44G 3.526 -999,250 0,063 -999.250 FILE TRAILER ************************ File name: ~qGSFOi .001 Maximum length: 1024 TRAILER RECORDS Version #: File tppe: LO Hext f'ile: Date: Page 1.3 FILE HEADER File name: ,002 Service name: Version #: Date: Maximum length: 1024 Film type: LO Previous ~ile: INFORMATION RECORDS Page MNEN l~i~ CH WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKB EDF EGL PD LHF RUN TIME DATE LOC SON LUN FL LUL ENGI WITN DD DL CBD1 CBLi TLI BLI TCS TLA8 BHT HRT HT MSS DFD H¥IS DFPH DFL RM RHF HFST HFSS RHC CONTENTS ARCO ALASKA tA-20 KUPARUK NORTH SLOPE ALASKA USA ....... 22i i2,000 .................. 0 Dcg, O Min. 0 O Sec 0 Deg. 0 Min. 0 0 .~ec 0.5 1 IN ............ iOE ........... 102,000 ....... I01 ,000 ...... 67, CIO0 ....... NS ......... KB ......... k~B ......... 1700,000, . , i9/12/90.. , 30 ......... ~922i7 , ,, NORTH SLOPE NORTH SLOPE YARSRO/RANDELL SEAL 9035, OOO 0,000 .......... 494~, 000 ....... 4952,000 38,000 ......... 89~2,000 ....... ilO0,O00 ....... l~O0.O00 ........ l~O,O00 ......... i~O,O00 ......... NEWDRILL CIRCULATED 10. 70'0 .......... 41 ,000 .......... O. 000 ........... ~,000 ........... 2,320 ........... 2,080 ........... 77,500 .......... HEA~ ..... 2,4~0 ........... INC. ' AP1 NUN: 50-029-22ii2, DATE LOGGED: 12-19-90, llllddllllllllllldlll ilmllllmlllliIlllmlml W IIdIilII · m I ddI ImdidldId iill illlIl*iI iilllliliImiiI m,dm, iIIII I I · d d mm d Iii111 IIIIi ddllmd IIIII IIdld I d.lllIi III a dllamll Iai I IIt.lll IlIII I IIIIIII I · d .idt.li i I IlleIII I i iii Iii .iIliimIi I i iIIlIii iIIilIIIIII i IIiIiIi IIImimliiIIlI dIiiIiIiimIlllIIIlIII iiiIlIIiimlmtIIIlllII IIImmIldII Idmldddml mlllIdIll iililllIIlIIttlilllllIIII ilIiIIllIdII IlIIlIIllIII iliiIIIIlIlIImllllIlIlIII illliiimlIliimllmmIlIlIII iIiliiliiIlI itliililllmI iiitlI.ilimlimmmmIIlI'llI itiiiiiIIIII iiiiiiiIIliiImlmmlIItIlII idl·llllllli dllllIIIIllllmlmmmllltldm UNIT TYPE CATG 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 0 FT 0 3 FT 0 FT 0 3 0 3 0 3 0 3 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 3 FT 0 3 FT 0 3 FT 0 3 FT 0 3 HR 0 2 HR O 4 DEGF 0 1 DEGF 0 0 2 0 2 LB/G 0 2 CP 0 2 0 2 OHMM 0 OHHM 0 DEGF 0 2 0 2 OHMH 0 SIZE CODE ERROR 40 65 40 65 40 65 20 65 ~: 2 0 65 20 65 4 68 .34 65 34 65 2 65 3 65 3 65 4 68 4 68 4 68 2 65 2 65 2 79 4 68 8 65 '2 79 i 0 65 10 G5 20 65 20 G5 20 65 20 G5 4 ~8 4 4 4 4 4 &8 20 65 20 65 4 12 65 NHEN NC, ST MCSS B$ I NFORMAT I ON RECORDS CONTENTS UNIT ?~.000 .................................................. ME~S ............................................. 9.625 ................................................... 8.500 ................................................... DEGF TYPE CATG SIZE 4 4 4 CODE 68 Pag~ ERROR 15 COMMENT RECORDS Well Location Comment I: SURFACE: t091~ FSL & 314~ FWL Well Location Comment 2: Well Location Comment 3: Well Location Comment Well File Comment !: BOTTOM DEPTH = 8950' & NO REPEAT RAN DUE TO HOLE CONDITIONS. Well File Commmnt 2: HRI, ML, SDL/DSN RUN IN COMBINATION. HEAD TENSION AND LINE Well File Comment 3: TEHSION ARE RECORDED 46.25' DEEP TO THE 80TTOM OF TOOL DUE Well File Comment 4: TO SOFTWARE ERROR. DXCO = +2.0 MMHOS AND MXCO = -2.0 MMHOS. · m LIS tape written b,.g: ~N.~HuR~uE COMPUTING CENTER ~.m mm All curve and tool mnemonics used are those which most closely match mm mm Halliburton curve and tool mnemonics, mm 1~'~~ HALLiBURT~i~,ii~ TO SCHLUMBERGER TOP MNE SERVICE iii?~ UNIT MNEM SERVICE UNIT DEPTH DEPT ,!:~i FT DEF'T FT 4850 O0 GRt ~? SDL GAP I GR SDL GAP I 8099.75 FDSNI DSN2 CPS FDSN DSN2 CPS 8099.75 BOTTOM DEPTH 8930 O0 8923 O0 8923 O0 NDSNI DSN2 CPS N~ oN DSN2 CPS 8099.75 NPHI i DSN2 DECP NPHI DSN2 DECP 8 099.75 8923 O0 8923 O0 NRAT! DSN2 C/C NRAT DSN2 C/C 8099.75 DPHI1 SDL DECP DPHI SDL DECP 8099.75 8923 O0 8923 O0 DRH01 SDL G/C3 DRHO SDL G?C3 8099.75 Fsi L. 1 SDL CPS FSDL SDL CPS 8099 75 · NSDL 1 SDL CPS NSDL SDL CPS 8099.75 8923 O0 8923.00 8923.00 Page 16 PEt PELC1 QL1 Q$1 RHOBt CALil TENSt DLODt SDL SDL SDL SDL SDL SDL SDL SDL G/CS IN LBS LBS PE PELC QL QS RHOB CALl TENS DLOD SDL SDL SDL SDL SDL SDL SDL SDL G?C3 IH LBS LBS 099.75 099.75 099.75 099.75 099.75 099.75 099.75 099.75 8923.00 8923.00 8923.00 8923.00 8923.00 8923.00 8923.00 8923.00 NOIIdIBJS30 3dAl 99 l 9~ Z l ~6ed 3003 3ZlS BSAI SNOII~OI~IO3dS DATA FORMAT SPECIFICA TION$ P a CJ ~ 18 SER'4ICE SERVICE MNEM ID ORDER # DEPT -,. ~.~. ~' Q'-'"~ i 7 GR SDL 49221 ? · FDSN DSN2 492217 NDSH DSN2 492217 NPHI DSH2 492217 NRAT DSH2 492217 DPHI SDL 4922~ 7 DRHO SDi. 4922~7 FSDL SDL 4922~ 7 NSDL SDL 4922~ 7 PE SDL 492217 PELC SDL 4922i 7 QL SDL 492217 QS SDL 4922~7 RHOB SDL 4922~7 CRLI SDL 492217 TENS SDL 492217 DLOD SDL 492217 API AP1 AP1 API FILE UNiT LOG TYPE CLASS MOD FT 0 0 O 0 2 GAPI 94 0 0 I CPS 94 O 0 ! CPS 94 0 0 I 1 DECP 94 0 0 1 C/C 94 0 0 ! i DECP 94 0 0 1 i G,..'C3 94 0 0 1 1 CPS 94 0 0 1 i CPS 94 0 0 i 94 0 O ! i 94 0 0 1 94 0 0 1 94 0 0 J i G?C3 94 0 0 ! i IN 94 0 0 i 1 LBS 94 0 0 1 1 LBS 94 0 0 i 1 PRC ~ SIZE LVL SMPL RC 4 0 1 68 4 0 1 GO 4 0 1 Ge 4 8 1 6S 4 0 1 6S 4 0 1 60 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 O 1 Ge 4 0 1 68 4 0 i 6S 4 0 1 68 4 0 i 68 4 0 1 68 4 O 1 68 PROCESS iNDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 OOO000 000000 000000 00000~ 000000 000000 00000 000000 DEPT GR FSDL NgBL TENS DLOD DATA RECORDS FDSN NDSN HPHI HRAT DPHI DRHO PE PELC QL QS RHO8 CALl F'a g ¢ 19 8923.000 85.692 7043.675 15553.055 5356.622 7t0.996 8900. 000 85. 692 7043. 675 15553. 055 5036.389 653.456 8800. 000 74.3i 3 $31 I . 674 i6854. 055 6084. 424 903. 344 8700.000 87.878 7296.675 i6855.055 5036.389 685.240 8600.000 71,093 8486.674 i6979.723 502i,833 700,036 8500.000 58.287 7585.675 16413,387 12532,748 2541.864 8400.000 52,455 8463.674 i6803,055 5356,622 772.920 8300.000 13i,282 7383.675 i5913,055 5007,277 725..9Z ~ ~ $200,000 102, I15 5641 .675 i5256,389 4.992,72i 752 , 645 2099 . 275 15850 . 879 5. 173 5. ! l? 099. 275 15850. 879 5.173 5.117 2543, i43 i 7090,9! 0 3.555 3,727 2164, 082 i6072. 170 Z. u,,9 2. 938 2708.920 1774i .922 2,426 2.242 · ...'349 569 i664i 477 4,388 5,647 2897,553 i7210,875 3,198 3,412 · 368 ,600 · 368 ·600 .316 -, 048 .34i ,131 .300 . 042 .33i -.016 .275 -,135 1432,2 i 9 13588,086 .470 2,722 3,425 -1 . 000 1432 , 219 14288.861 4,458 3. 353 .481 -. 025 7.981 .33;3 7,981 ,333 7.103 ,028 7.850 -.024 6,923 ,028 7.486 -,014 6..278 -. 007 10. 028 -.429 10,545 .091 .189 2.338 .189 2.338 .223 2,282 .i56 2.393 ,215 2.296 .i99 2.321 .235 2.262 ,i96 2,326 ,043 2.578 -.025 8.258 -. 025 8,258 . u 1 .':, 8.523 .050 9.4i0 .025 8.905 ' . 003 8,846 · 009 9. 738 9.738 -.Oi5 9.269 DATA RECORDS DEPT GR FDSN FSDL NSDL PE TENS DLOD NDSH PELC NPH I QL NRAT DPHI RH08 DRHO CALi Page 2O 8100.000 i24.577 i428.098 7445.675 16625.723 3.330 4934,497 797.032 13478.000 3.966 .451 -. 058 9. 976 .0i5 .i74 J 0. 342 :# uo:s~a~ :~ uof~enufquo3 adeI :squa~oO _ 'I6 :aqeq zO/lO,, 09 :ad~ aI!J :ade.~ sno:^~ud l 0 .':I~D"',")., : aU. IE',,J aD ~ P,U S : aqe~3 :# uo~uaA S<I OO3 t 800' lO_-ISO",g :a,~eu a!.:~ MNEM CONTENTS m~m CN FH COUH STAT CTRY APIN LATI LONG SECT TOWN RAHG EKD EDF ECL PD LMF DMF RUN TIHE DATE LCC SOH LUN FL LUL ENGI WITH DO DL CBDI CBLI TLI BLI TCS TLAB BHT MRT DFD ~VIS DFPN DFL RMF NFST NFSS RNC I HFORMAT I OH RECORDS UNIT TYPE CATG ARCO ALASKA iA-20 KUPARUK NORTH SLOPE ALASKA USA 221 i 2. 000 .......... 0 Deq. O Min. 0 0 Oe:~j, 0 Min, 0 1 tN .............. IOE .............. t 02. OOO .......... 'iO! .OOO. 67. 000 ...... HS .......... KB .......... 1700.000 .... 19/12/90 .... 30 .......... 4922i7 .... 763~ . NORTH SLOPE NO,TN SLOPE Y~RBRO/~NbELL 8E~L 9035. 000 ...... ~. 000 ......... 4947,000 ...... 4952. ~ O O ...... 38.8OO ........ 8912. ~00 ...... i100.000 ...... HE,DRILL CZRCUL~TED 10,700 4i . OOO ....... O.OOO ........ 2.320 ........ 2. ~80 ........ 77.580 ....... NE~S. . 2.420 ........ DATE LOGGED 0 umc N 0 Sec td INC, API HUM: 50-029-22!12 12-19-90 Page SIZE CODE ERROR 65 65 65 65 65 65 65 65 65 65 68 68 65 65 79 68 65 65 65 65 65 65 65 68 68 68 68 68 68 68 68 65 65 68 68 68 68 65 68 0 0 40 0 0 40 0 0 40 0 0 20 0 0 20 0 0 20 0 0 4 0 0 34 0 0 34 0 0 2 0 0 0 0 FT O 3 4 FT 0 3 4 FT 0 3 4 0 3 '2 0 3 2 0 3 2 0 0 2 0 0 0 0 0 0 '2 0 0 0 0 I0 0 0 20 0 0 20 0 0 20 0 0 20 FT 0 3 4 FT 0 3 4 FT O 3 4 FT 0 3 4 FT 0 3 4 FT 0 3 4 HR 0 2 4 HR 0 4 4 DEGF 0 1 4 DEGF 0 I 4 0 2 20 0 2 20 LB/G 0 2 4 CP 0 2 4 0 2 4 0 2 4 OHMH 0 2 4 OHHH 0 2 4 DEGF 0 2 4 0 2 12 OHMM 0 2 4 2'2 INFORMATION RECORDS Pag~ 23 MNEM CONTENTS UNiT TYPE CATG SiZE CODE ~uw MCST MCSS OS BS ?9. 000 .................................................. MEAS ............................................. 9.625 8.500 ................................................... DEGF 0 2 4 68 0 2 J2 ~5 0 3 4 68 0 3 4 68 COMMENT RECORDS Well Location Comment l: SURFACE: lOgi' FSL & 314' Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: Well Film Comment i: THIS FILE CONTAiHS GAMMA RAY Well File Comment 2: Well Film Comment 3: FWL IN CASING DATA. Well File Comment 4: ** LiS tape writtmn b~: ANCHORAGE COMPUTING CENTER mm All curve and tool mnmmonics used are those which most closel~ match ~:m Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUHBERGER TOP BOTTOM MHEM S£RVICE UNIT HNEH SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 30.00 5010.00 GR2 HRI GAPI GR HRI GAPI 38.00 4998.00 TENS2 HRi LBS TENS HRi LBS 38.00 4998.00 DLOD2 HRI LBS Di_OO FTR;[ LBS 38.00 4998.00 Pag6 24 N011~I~3530 3~AI **** ~N3939 ~309~ A~IN3 99 ~ 0 99 ~ 9{ 3QO0 3ZIS 3dAl A~IH3 000000 000000 000000 000000 000000 000000 000000 000000 000000 oono00 000000 000000 89 l 0 ~' ,'3_. ~ 0 0 89 $ 0 S, ,.'3'. ~ 0 0 ~6 SSq ~6 SSq IMH qO~O IMH SN3A # OOW S$~9O 3dA! 009 l!N~ # ~3~BO O! 39I~ Id~ ld~ Idff !dff 30!AB35 30IA~35 SNOIIt OIHI338S DE P '1' GR TENS DATA D L 0 D RECORDS 27 4998.000 4900. 000 4800,000 4700. 'O00 4600. 000 4500,000 4400. 000 4300,000 4200. 000 4100,000 4000,000 3900,000 3800,000 3700,000 .3600,000 3500, .000 3400,000 98.139 54,20f 47,209 50,929 58,693 43,844 52, .326 51 ,005 57.672 53 698 38 775 33 8i0 46 678 21 .362 :35 095 2.6,8:32 42,761 :3504,449 · '3495. 688 3302,94.3 3.373,032 3241 ,615 3189. 048 3171 .526 3127,721 3022,587 2996. :304 2917,454 2891 , 2:356,12.6 2:803,559 2759,753 2672, 142 2584,531 606. 596. 529. 546, 551. 537, 526, 522. 495, 498. 477, 529, 515, 509, 510, 328 464 060 856 596 528 280 320 608 484 632 372 000 608 42.8 DEPT GR TEHS DATA DLOD RECORDS Page 3200 3100 ~000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 .000 . 000 .000 . 000 ,000 ,000 000 000 000 000 000 000 000 000 000 000 000 51 54 ~? 49 44 52 52 ~8 56 18 32 29 49 49 .341 · 088 ,521 .583 .468 .665 .403 .644 .I12 .116 ..~06 . 177 ,169 .514 .469 .482 ,757 2567. 009 2470.637 2418. 070 24i8. 070 2339.22 0 2.7, 04.175 2234. 086 2155.2,36 2111 , 431 2i37.714 2023.819 1980. 014 1901 . 164 1892.402 1901. 164 1874.880 1787.269 514.264 503.304 498.372 508.784 484.672 486.864 474.808 459,464 449,600 447.956 470,424 475.356 512,072 530.704 566,872 569,612 530.156 DEPT TENS DATA DLOD RECO'RDS Page 29 600 500 400 300 200 I00 000 900 800 700 600 500 400 300 200 100 .000 .000 .000 .000 O00 000 000 000 000 000 000 000 000 000 000 000 47.278 43.03 0 48. 792 36,375 51 .694 32.534 50.605 35,691 44.86 0 52.932 33. 793 33.314 43. 138 4.'5.91"-) 47,382 22,749 1752,224 1690.897 1629,569 1585.763 1550,719 1515.674 1428,063 1401.780 1305,407 12=-~ 1182,751 · 1147 707 1121,424 ~077.~i8 1033,813 954,962 519.i96 489.604 470,424 470.424 457.820 453,436 461,i08 486,316 533.444 549,336 584.408 608,520 622.220 656,196 694.008 693.460 :Iaa~ ~XaN **** 839I~81 9338 0£ a6e~ :# uo~aA :~mmu a~^uaS S<I OO3 P~OI :q~Bua! wn~xm~ IO0'IO-ISD'8 :~,,,eu atT.-I