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188-008
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-02-09_24005_KRU_3H-21_VividLeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24005 KRU 3H-21 50-103-20094-00 VIVID Leak Detect Log 09-Feb-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 188-008 T40151 2/25/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.25 08:18:50 -09'00' Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 3B-04 50-029-21323-00 909740412 Kuparuk River Plug Setting Record Field- Final 3-Jan-25 0 12 3H-21 50-103-20094-00 909740216 Kuparuk River Multi Finger Caliper Field & Processed 5-Jan-25 0 13 3H-21 50-103-20094-00 909740216 Kuparuk River Plug Setting Record Field- Final 6-Jan-25 0 14 3H-33A 50-103-20578-01 909740217 Kuparuk River Plug Setting Record Field- Final 29-Dec-24 0 15 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 2-Nov-24 0 16 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 3-Nov-24 0 17 3K-24 50-029-22935-00 909619038 Kuparuk River Multi Finger Caliper Field & Processed 7-Nov-24 0 18 3K-24 50-029-22935-00 909619503 Kuparuk River Plug Setting Record Field- Final 30-Oct-24 0 19 3Q-14A 50-029-21665-01 909740219 Kuparuk River Leak Detect Log Field- Final 8-Dec-24 0 110 3Q-14A 50-029-21665-01 909740219 Kuparuk River Multi Finger Caliper Field & Processed 9-Dec-24 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:T40008T40009T40009T40010T40011T40011T40012T40012185-061188-008209-103189-025198-249214-082T40013T400131/23/20253H-2150-103-20094-00909740216Kuparuk RiverMulti Finger CaliperField & Processed5-Jan-250133H-2150-103-20094-00909740216Kuparuk RiverPlug Setting RecordField- Final6-Jan-2501185 061188-008209 103Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:18:26 -09'00' Originated:Delivered to:6-Apr-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-23 50-029-22131-00 906975765 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-21 0 1 2 1B-11 50-029-20657-00 907041775 Kuparuk River Multi Finger Caliper Field & Processed 20-Mar-21 0 1 3 1D-101 50-029-22986-00 n/a West Sak Packer Setting Record Field- Final 14-Mar-21 0 1 4 1D-130 50-029-22815-00 907025874 West Sak Packer Setting Record Field- Final 13-Mar-21 0 1 5 1F-19 50-029-22660-00 906994361 Kuparuk River Packer Setting Record Field- Final 24-Feb-21 0 1 6 1G-02 50-029-20813-00 906996811 Kuparuk River Multi Finger Caliper Field & Processed 24-Feb-21 0 1 7 1L-11 50-029-22034-00 906914692 Kuparuk River Leak Detect Log Field- Final 15-Jan-21 0 1 8 1Q-10 50-029-21215-00 907035266 Kuparuk River Packer Setting Record Field- Final 18-Mar-21 0 1 9 2H-09 50-103-20050-00 907042522 Kuparuk River Packer Setting Record Field- Final 19-Mar-21 0 1 10 3H-21 50-103-20094-00 907045708 Kuparuk River Packer Setting Record Field- Final 22-Mar-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 04/07/2021 PTD: 1880080 E-Set: 34912 04/07/2021 Originated:Delivered to:6-Apr-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-21 50-103-20094-00 907019707 Kuparuk River Leak Detect Log Field- Final 12-Mar-21 0 1 2 3H-21 50-103-20094-00 907019707 Kuparuk River Plug Setting Record Field- Final 12-Mar-21 0 1 3 WSW-06 50-029-20851-00 906976270 Shallow Sands Multi Finger Caliper Field & Processed 13-Feb-21 0 1 4 5 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 04/07/2021 PTD: 1880080 E-Set: 34911 04/07/2021 Originated:Delivered to:6-Apr-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-21 50-103-20094-00 907019707 Kuparuk River Leak Detect Log Field- Final 12-Mar-21 0 1 2 3H-21 50-103-20094-00 907019707 Kuparuk River Plug Setting Record Field- Final 12-Mar-21 0 1 3 WSW-06 50-029-20851-00 906976270 Shallow Sands Multi Finger Caliper Field & Processed 13-Feb-21 0 1 4 5 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 04/07/2021 PTD: 1880080 E-Set: 34910 04/07/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing patch ConocoPhillips Alaska, Inc.Development Exploratory 3. Address: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 11346 feet NA feet true vertical 6373 feet NA feet Effective Depth measured 10802 feet 10600 feet true vertical 6113 feet 6013 feet Perforation depth Measured depth 10774 - 11072 feet True Vertical depth 6100 - 6244 feet Tubing (size, grade, measured and true vertical depth)3.5 J-55 10672 6049 Packers and SSSV (type, measured and true vertical depth)Baker FHL Packer 10600 / 6013 Camco TRDP-1A-SSA 1803 / 1642 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: 3/29/2021 Contact Phone: N/A Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist ----- ----- N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Conductor 79 16 115 115 N/A N/A N/A Production 6317 7 11300 6352 N/A N/A Surface 3048 9.625 4620 3084 N/A Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River / Kuparuk River Oil Plugs measured Junk measured Burst Collapse 188-008 50103200940000 ADL0025523 / ADL0025531 KRU 3H-21 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: t Fra O 6. A G L PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:48 am, Mar 30, 2021 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨 宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰 宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷 宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室 宇室宷宨孽季孵孳孵孴孱孳孶孱孵孼季孴孶孽孵孺孽孳孼孰孳孻孪孳孳孪 安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孳 Jan Byrne SFD 4/1/2021VTL 5/5/21 RBDMS HEW 3/30/2021 DSR-4/1/21 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 29, 2021 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 report for well operations from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across known tubing leaks in producer KRU 3H-21 (PTD 188- 008). Please contact us at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨 宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季 守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰 宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷 宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室 宇室宷宨孽季孵孳孵孴孱孳孶孱孵孼季孴孶孽孵孹孽學孴孰孳孻孪孳孳孪 安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孳 Jan Byrne Date Event Summary Executive Summary 3H-21 Failed a waiver compliance TIFL on 1/8/21. Slickline diagnostics indicated that gas lift mandel # 6 at 10,538' was leaking. A leak detect log confirmed the leak at the gas lift mandrel and an additional leak at 10,562'. The well was circ'd out and passed a CMIT. A 2.72" OD, ~38' OAL, TTS retrievable tubing patch using Paragon 2 Packers was set from 10,569.5' to 10,532'. A passing MITT and CMIT TxIA were acquired post patch set. Pertinent well work is copied below. 03/12/21 PULLED CATCHER @ D&D PLUG ASSEMBLY @ 10,602' RKB (MISSING ELEMENT); DRIFT W/ 2.62" CENT, BRUSH, & BAILER ASSEMBLY DOWN TO 10,650' RKB; (UTILIZING EDPU) SET 2.72" RBP W/ MID ELEMENT @ 10,577' RKB (7.97' OAL / CPP352198 / CPEQ35052); DEPLOY 3 1/2" AVA CATCHER & PERFORM LDL LOG FROM 10575' RKB TO 10490' RKB (IDENTIFY LEAK 17' ABOVE PLUG @ 10,562' & @ MANDREL @ 10,538' RKB) NO OTHER LEAKS OBSERVED; PULLED EXT PKG DV @ 10,538' RKB. LRS ON LOCATION PERFORMING CIRC OUT & CMIT 03/13/21 CIRC-OUT DOWN TUBING, UP IA, TAKING RETURNS TO 3H-34 FLOWLINE PUMPED 286 BBL SEAWATER CONTAINING 120 GALS CRW-132 PUMPED 84 BBL DIESEL U-TUBED TUBING AND IA FREEZE PROTECT FOR 1 HOUR CMIT-TxIA TO 2500 PSI PASSED (SEE LOG FOR DETAILS) JOB COMPLETE CMIT= INITIAL T/I/O= 950/900/1080 LOADED TUBING AND IA W/ 2.3 BBL 50* DIESEL START T/I/O= 2625/2575/1180 15 MIN T/I/O= 2600/2550/1220 (-25,-25,+40) 30 MIN T/I/O=2575/2525/1220(-25,-25) 45 MIN T/I/O= 2550/2500/1210 (-25,-25,-10) 60 MIN T/I/O= 2550/2500/1200 (-0,-0,-10) 03/22/21 (UTILIZING EDPU) SET LOWER 2.72" P2P (CPP35314) W/ MID ELEMENT @ 10,568'; RAN TEST TOOL TO LOWER PACKER & ATTEMPT TO CMIT (FAILED 3 MIN. INTO TEST W/ PACKER MOVING DOWNHOLE); PULL 2.72" P2P @ 10,600' RKB (BODY LOCK RING SUGGEST PACKER FULL SET, SLIPS PACKED WITH SCALE); (UTILIZING EXPLOSIVES) FLUSH TBG W/ 20 BBLS OF DIESEL & SET 2.72" LOWER P2P (4.01' OAL / CPP35210) W/ MID ELEMENT @ 10,569.5' RKB; RAN TEST TOOL TO LOWER PACKER @ CMIT TBG X IA TO 2500 PSI (PASS). IN PROGRESS. PRE CMIT T/I/O= 1525/1325/900, PRESSURE UP (1.6 BBLS) T/I/O= 2575/2375/980, 15 MIN T/I/O= 2575/2375/980, 30 MIN T/I/O= 2575/2375/980 03/23/21 SET UPPER 2.72" P2P SPACER & ANCHOR LATCH (OAL 35.36' / SN:CPP35282 / CPAL35105) @ 10531.98' RKB (ME), MIT TBG W/ TEST TOOL IN UPPER PACKER @ 10531.98' RKB MITT 2500 PSI (PASS), CMIT TBG x IA 2500 (PASS). COMPLETE. PRE MITT T/I/O= 1500/1300/880, (.5 BBLS) 2550/1350/880, 15 MIN T/I/O= 2500/1350/880, 30 MIN T/I/O= 2475/1350/880 (PASS) PRESSURE TBG x IA FOR COMBO (1.2 BBLS) T/I/O= 2600/2440/880, 15 MIN T/I/O= 2600/2425/880, 30 MIN T/I/O= 2600/2425/880 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (All 212' of A-sands are Covered / All C-sands are Open) 10,829.0 2/4/2019 3H-21 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Catch/RBP & Set Lower Patch Packer 3/22/2021 3H-21 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) (ftK 115.0 Wt/Len (lb/ft 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,620.6 Set Depth (TVD) (ftK 3,083.9 Wt/Len (lb/ft 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 11,300.3 Set Depth (TVD) (ftK 6,352.0 Wt/Len (lb/ft 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Max No 3 1/2 ID (in) 2.99 Top (ftKB) 35.1 Set Depth (ftKB) 10,672.4 Set Depth (TVD) (ftKB 6,049.4 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC AB-MOD Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°) Item Des Com Nominal ID (in) 35.1 35.1 0.05 HANGER MEVOY TUBING HANGER 3.500 1,803.1 1,642.0 44.73 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE (LOCKED OUT 12/26/88) 2.812 10,579.9 6,003.1 59.73 PBR BAKER PBR 3.000 10,599.6 6,013.0 59.83 PACKER BAKER FHL PACKER 2.992 10,638.2 6,032.3 60.01 NIPPLE - MILLED OUT CAMCO D NIPPLE NO GO (MILLED TO 2.80" ON 3/31/19) 2.800 10,671.4 6,048.9 60.17 SOS BAKER SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) Top Incl (°)Des Com Run Date ID (in) SN 10,532. 0 5,978.9 59.50 Packer Patch Upper 3.5" Upper packer assembly 3.68' with spacer pipe attached 3/23/2021 1.625 10,535. 7 5,980.7 59.52 Spacer Pipe Assembly 3.5" Anchor latch assembly with spacer pipe 30.84' plus upper packer 3.68' (OAL= 34.52') 3/23/2021 1.600 10,567. 5 5,996.8 59.67 PACKER - PATCH - LWR LOWER 2.72" P2P (4.01' OAL) 3/21/2021 1.625 10,621. 0 6,023.7 59.93 TUBING PERFORATION 2', 3 SPF, 120 Deg Phase Tubing Perf Gun 4/27/2019 2.990 10,801. 0 6,112.9 60.61 ***POSSIBLE CASING DAMAGE*** UNABLE TO FCO PAST 10801' W/ 2.0" DJN, TRIED 2.73 MILL AND 2.13" MOTOR, 8 STALLS AND ONE OVERPULL AT THIS DEPTH, 4/1/19 4/1/2019 6.280 11,029. 0 6,223.8 61.35 FISH 1 1/2" OV Empty Pocket; Assume Fell to Rathole 7/18/1996 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,774.0 10,804.0 6,099.6 6,114.4 C-4, 3H-21 11/14/1988 6.0 IPERF 2 1/8" EnerJet, Zero° ph 10,776.0 10,795.0 6,100.6 6,110.0 C-4, 3H-21 5/2/2018 6.0 RPERF 2 1/8" PowerSpiral Enerjet 60° ph 10,795.0 10,814.0 6,110.0 6,119.3 C-4, 3H-21 5/1/2018 6.0 RPERF 2 1/8" PowerSpiral Enerjet 60° ph 10,804.0 10,814.0 6,114.4 6,119.3 C-4, 3H-21 11/14/1988 12.0 IPERF 2 1/8" EnerJet, 60° ph 10,860.0 10,890.0 6,141.8 6,156.5 A-3, 3H-21 5/31/1996 4.0 RPERF 2 1/8" EnerJet,180° phasing; (+/-) 90° F/ Lowside 10,868.0 10,887.0 6,145.8 6,155.0 A-3, 3H-21 5/1/2018 6.0 RPERF 2 1/8" PowerSpiral EnerJet, 60° ph 10,904.0 10,907.0 6,163.4 6,164.8 A-2, 3H-21 4/30/2018 6.0 RPERF 2 1/8" PowerSpiral EnerJet, 60° ph 10,904.0 10,909.3 6,163.4 6,165.9 A-2, 3H-21 4/30/2018 6.0 RPERF 2 1/8" PowerSpiral EnerJet, 60° ph 10,910.0 10,930.0 6,166.3 6,176.0 A-2, 3H-21 8/25/1988 8.0 IPERF Gearhart Big Hole, 60° phasing 10,923.0 10,942.0 6,172.6 6,181.9 A-2, 3H-21 4/30/2018 6.0 RPERF 2 1/8" PowerSpiral EnerJet, 60° ph 10,954.0 10,956.0 6,187.7 6,188.7 A-1, 3H-21 4/27/2018 6.0 RPERF 2 1/8" PowerSpiral EnerJet, 60° ph 10,954.0 10,973.0 6,187.7 6,196.9 A-1, 3H-21 4/28/2018 6.0 RPERF 2 1/8" PowerSpiral EnerJet, 60° ph 10,965.0 10,985.0 6,193.0 6,202.7 A-1, 3H-21 7/3/1999 6.0 APERF 2.5" HSD/DP, 60 deg ph, spiral chg 10,973.0 10,992.0 6,196.9 6,206.0 A-1, 3H-21 4/27/2018 6.0 RPERF 2 1/8" PowerSpiral EnerJet, 60° ph 11,010.0 11,030.0 6,214.7 6,224.3 A-1, 3H-21 11/14/1999 4.0 APERF 2 1/8" Enerjet DP, 180 deg +/- 90 deg 11,030.0 11,050.0 6,224.3 6,233.9 A-1, 3H-21 7/3/1999 6.0 APERF 2.5" HSD/DP, 60 deg pH, spiral chg 11,058.0 11,072.0 6,237.7 6,244.4 A-1, 3H-21 8/25/1988 4.0 IPERF 4.5" Ultra Pack, 120 deg ph Mandrel Inserts St ati on N Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,191.3 2,423.2 CAMCO KBUG 1 GAS LIFT GLV BK-2 0.156 1,225.0 3/26/2019 2 6,683.4 4,026.6 CAMCO KBUG 1 GAS LIFT GLV BK-2 0.188 1,255.0 3/26/2019 3 8,591.5 4,970.7 CAMCO KBUG 1 GAS LIFT OV BK-2 0.250 0.0 3/25/2019 4 9,575.6 5,482.7 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 3/25/2019 5 10,099.0 5,755.0 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/13/1993 6 10,538.2 5,982.0 CAMCO MMG-2 1 1/2 GAS LIFT OPEN OPEN 0.000 0.0 3/12/2021 3H-21, 3/29/2021 12:12:15 PM Vertical schematic (actual) PRODUCTION; 35.0-11,300.3 IPERF; 11,058.0-11,072.0 APERF; 11,030.0-11,050.0 FISH; 11,029.0 APERF; 11,010.0-11,030.0 RPERF; 10,973.0-10,992.0 APERF; 10,965.0-10,985.0 RPERF; 10,954.0-10,973.0 RPERF; 10,954.0-10,956.0 RPERF; 10,923.0-10,942.0 IPERF; 10,910.0-10,930.0 RPERF; 10,904.0-10,909.3 RPERF; 10,904.0-10,907.0 RPERF; 10,868.0-10,887.0 RPERF; 10,860.0-10,890.0 IPERF; 10,804.0-10,814.0 ***POSSIBLE CASING DAMAGE***; 10,801.0 RPERF; 10,795.0-10,814.0 IPERF; 10,774.0-10,804.0 RPERF; 10,776.0-10,795.0 SOS; 10,671.4 NIPPLE - MILLED OUT; 10,638.2 TUBING PERFORATION; 10,621.0 PACKER; 10,599.6 PBR; 10,579.9 PACKER - PATCH - LWR; 10,567.5 Spacer Pipe Assembly; 10,535.7 GAS LIFT; 10,538.2 Packer Patch Upper; 10,532.0 GAS LIFT; 10,099.0 GAS LIFT; 9,575.6 GAS LIFT; 8,591.5 GAS LIFT; 6,683.4 SURFACE; 35.0-4,620.6 GAS LIFT; 3,191.3 SAFETY VLV; 1,803.1 CONDUCTOR; 36.0-115.0 HANGER; 35.1 KUP PROD KB-Grd (ft) 36.99 Rig Release Date 5/1/1988 3H-21 ... TD Act Btm (ftKB) 11,346.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009400 Wellbore Status PROD Max Angle & MD Incl (°) 65.94 MD (ftKB) 5,800.00 WELLNAME WELLBORE3H-21 Annotation Last WO: End DateH2S (ppm) 200 Date 11/25/2016 Comment SSSV: LOCKED OUT Notes: General & Safety End Date Annotation 12/5/2005 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 3H-21, 3/29/2021 12:12:15 PM Vertical schematic (actual) PRODUCTION; 35.0-11,300.3 IPERF; 11,058.0-11,072.0 APERF; 11,030.0-11,050.0 FISH; 11,029.0 APERF; 11,010.0-11,030.0 RPERF; 10,973.0-10,992.0 APERF; 10,965.0-10,985.0 RPERF; 10,954.0-10,973.0 RPERF; 10,954.0-10,956.0 RPERF; 10,923.0-10,942.0 IPERF; 10,910.0-10,930.0 RPERF; 10,904.0-10,909.3 RPERF; 10,904.0-10,907.0 RPERF; 10,868.0-10,887.0 RPERF; 10,860.0-10,890.0 IPERF; 10,804.0-10,814.0 ***POSSIBLE CASING DAMAGE***; 10,801.0 RPERF; 10,795.0-10,814.0 IPERF; 10,774.0-10,804.0 RPERF; 10,776.0-10,795.0 SOS; 10,671.4 NIPPLE - MILLED OUT; 10,638.2 TUBING PERFORATION; 10,621.0 PACKER; 10,599.6 PBR; 10,579.9 PACKER - PATCH - LWR; 10,567.5 Spacer Pipe Assembly; 10,535.7 GAS LIFT; 10,538.2 Packer Patch Upper; 10,532.0 GAS LIFT; 10,099.0 GAS LIFT; 9,575.6 GAS LIFT; 8,591.5 GAS LIFT; 6,683.4 SURFACE; 35.0-4,620.6 GAS LIFT; 3,191.3 SAFETY VLV; 1,803.1 CONDUCTOR; 36.0-115.0 HANGER; 35.1 KUP PROD 3H-21 ... WELLNAME WELLBORE3H-21 3124 1 WELL LOG TRANSMITTAL #905919689 To: Alaska Oil and Gas Conservation Comm. September 20, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Records: 31-1-21 Run Date: 08/06/2019, 08/10/2019, and 08/20/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3H-21 Digital Data in LAS format, Digital Log Image file RECEIVED 1 CD Rom 50-103-20094-00 SEP 2 4 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: l/` f 2W Signed: ji sp PROACTIVE DIAGNOSTIC SERVICES, INC. WELL L®G TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection (Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: 188000, 30 82 5 ProActive Diagnostic Services, Inc. RECEIVED Attn: Diane Williams Wr"ii 2 , --.- 130 West International Airport Road Suite C AOGCC Anchorage, AK 99518 Pdsanchoraae(memorvloa cam 14 -Apr -19 3H-21 CD 50-103-20094-00 Date : L U V I PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOGCOM WEBSITE: WWW,MEMORYLOGCOM D: Achveshlasteff=PlateFilea\Templates\Distnbubmn Tmn mittaShats'ConowPhillips_Transmitdom Ji S Company: ConocoPhillips Alaska, Inc. Log Date: April 14, 2019 Log No.: 14737 Run No.: 1 Pipe Description: 3.5 inch 9.2 Ib. J-55 BTC AB -MOD Pipe Use: Tubing Pipe Description: 7 inch 26 Ib. J-55 BTC 30 82 5 Memory Multi -Finger Caliper Log Results Summary Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Bottom Log Interval: Inspection Type : Whipstock Setting Inspection COMMENTS: This caliper data is tied into the Gamma K1 Log at 10,713 feet (Driller's Depth). 3H-21 Kuparu k Alaska 50-103-20094-00 Surface 10,658 Ft. (MD) 10,658 Ft. (MD) 10,803 Ft. (MD) This log was run to assess the condition of the tubing and casing prior to setting a whipstock. The caliper recordings indicate the 7 inch casing logged appears to be in poor condition with respect to internal corrosive and mechanical damage, with multiple holes / splits recorded in 3 of the 6 joints logged. Outside of the perforation intervals, cross-sectional wall loss from 16% to 26% are recorded throughout the 7 inch casing logged. No significant ID restrictions are recorded throughout the 7 inch casing logged. A 3-D log plot of the caliper recordings across the 7 inch casing logged is included in this report. The caliper recordings indicate the 3.5 inch tubing appears to be in good to fair condition with respect to internal corrosive and mechanical damage, with a maximum recorded wall penetration of 26% in a line of corrosion in joint 294 (9,108 ft). Other recorded damage appears as isolated pitting and line of pits. No significant areas of cross-sectional wall loss or ID restrictions are recoded. Caliper recordings of the 3.5 inch tubing indicate moderate buckling from —950 feet to —1,980 feet, and from -2,150 feet to the end of the tubing. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion 26 294 9,108 Ft. (MD) Line Corrosion 24 282 8,739 Ft. (MD) Line Corrosion 24 114 3,570 Ft. (MD) Line of Pits 21 313 9,715 Ft. (MD) Isolated Pitting 21 92 2,886 Ft. (MD) 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the 3.5 inch tubing. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (284) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalvsis(dmemorvloa com Prudhoe Bay Feld Office Phone: (907) 659-2307 Fax: (907) 659-2314 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: Multiple Holes 100 3 10,746 Ft. (MD) Multiple Holes 100 1 10,676 Ft. (MD) Multiple Holes 100 4 10,758 Ft. (MD) Corrosion 41 2 10,710 Ft. (MD) Corrosion 35 2.1 10,716 Ft. (MD) 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Multiple Holes 26 1 10,676 Ft. (MD) Corrosion 25 1.2 10,692 Ft. (MD) Multiple Holes 24 3 10,748 Ft. (MD) Corrosion 18 2.1 10,716 Ft. (MD) Corrosion 17 2 10,694 Ft. (MD) 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the 7 inch casing logged. C. Goerdt HY. Yang J. Fama ProActive Diagnostic Services, Inc. / P.C. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 e-mail: PDSAnalvsisCa)memorvloa com Prudhoe Bay Feld Office Phone: (907) 659-2307 Fax: (907) 659-2314 PDS Multifinger Caliper 3D Log Plot ks Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Well: 31-1-21 Date : April 14, 2019 Description : Detail of Caliper Recordings Across 7 Casing Logged Ib �tt .: t Correlation of Recorded Damage to Borehole Profile 'Pipe 1 3.5 in (8.0'- 10,658.0') Well: 3H-21 Pipe 2 7. in (10,658.0'- 10,803.0') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 14, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 12 50 1,533 GLM 1 3,106 150 4,658 3 LL C Z 200 6,203 GLM 2 o v 250 7,746 GLM 3 300 9,285 GLM 4 GLM 5 GLM 6 1 10,658 _. ,.. 5 10,795 0 50 100 Damage Profile (%wall)/Tool Deviation (degrees) Bottom of Survey = 5 ■ Perforations Pipe Non D Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BTC AB -MOD 2.992 in 8 ft 10,65 0 658 ft Damage Configuration (body) 50 40 30 20 10 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 20 0 42 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 GLM 1 (12:30) GLM 2 (9:30) GLM 3 (12:00) GLM 4 (2:00) GLM 5 (7:00) GLM 6 (1:30) Bottom of Survey = 342.2 PDS Report Overview .S Body Region Analysis Well: 3H-21 Survey Date: April 14, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.2 ppf J-55 BTC AB -MOD Analyst: Yang Pipe Non D Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BTC AB -MOD 2.992 in 8 ft 10,65 0 658 ft Damage Configuration (body) 50 40 30 20 10 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 20 0 42 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 GLM 1 (12:30) GLM 2 (9:30) GLM 3 (12:00) GLM 4 (2:00) GLM 5 (7:00) GLM 6 (1:30) Bottom of Survey = 342.2 ji�� PDS Report Joint Tabulation Sheet Well: 31-1-21 Survey Date: April 14, 2019 Field: Kuparuk Analyst: Yang Company: ConocoPhillips Alaska, Inc. Pipe Descripfion 3.5 in. 9.2 ppf J-55 BTC AB -MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 8 ft. 10,658 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 0.1 0 001 5 2 2.93 P t. ne osits. 1 12 0 0.02 9 2 2.92 Lt. Deposits. 2 40 0 0.02 7 2 2.90 Lt. Deposits. 3 72 0 0.01 6 2 2.91 Lt. Deposits. 103 0 0.02 9 3 2.91 Lt. Deposits. 5 135 0 0.02 7 2 2.89 Lt. Deposits. 6 164 0 0.02 9 1 3 2.94 7 196 0 0.03 13 4 2.9 . Deposits. 8 227 0 0.02 9 2 2.92 Lt. Deposits. 258 0 0.02 9 2.94 10 290 0 0.02 7 2 2.92 Lt. Deposits. 11 321 0.04 14 4 2. 12 53 0 2 2 2.95 13 384 0 0.03 13 2 2.92 Lt. Deposits. 41 0.04 0.04 14 4 2.94 15 446 0.05 0. 14 3 2.89 Deposits. 16 476 0 0.03 13 3 2.92 Lt. Deposits. 17 0 0 12 2.94 18 540 0.0 11 4 92 Lt. Deposits. 19 571 0 0.03 10 2 2.92 Lt. Deposits. 20 0 14 2 2.90 t. sits. 21 6 3 0 0.02 2 2.94 22 661 0 0.03 13 2 2.94 23 6 2 0 4 74 2 .91 t. osits. 24 723 0.03 10 2 .9 25 755 0 0.03 13 3 2.92 Lt. Deposits, 26&8790 0.03 10 2 If osits. 270.02 8 2 2.93 Lt. Deposits. 28 3 11 2 2.93 sits. 290.03 11 3 2.90 Lt. sits. 300.03 10 22.93 Lt. De osits. 31 10 3 2.93 osits. klin . 320.03 12 3 3 33 0.03 10 2 2.92 Lt. De osits. 4 0.04 14 2 2.90 U. Deposits. 35 1068 0 0.03 11 3 2.92 Lt. Deposits. 36 1099 0 0.02 9 4 2.93 1 Lt. Deposits. Buckling. 7 1131 0 0.03 10 2 2.93 38 1162 0 0.02 Lt. De osits. 39 1191 0.04 0.05 20 4 2.92 Line Corrosion. Lt. Deposits. 40 1222 0 0.03 13 4 2.95 41 1253 0 0.03 11 1 2 2.93 Buckli 42 1285 0 0.03 11 3 2.94 4 1316 0 0.02 7 2 2.92 osits. 44 1347 0 0.02 8 2 2.92 Lt. Deposits. 45 1378 0 003 11 3 2. 46 14090 0.03 11 3 2.95 cklin . 47 1441 0 0.02 8 2 2.92 Lt. Deposits. 48 471 0 0.03 11 3 1 2.93 Lt. Deposits. 49 1502 0 0.04 14 5 1 2.92 1 Lt. Deposits. Penetration Body Metal Loss Body Page 1 ii-S Well: 31-1-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc PDS Report Joint Tabulation Survey Date: April 14, 2019 Analyst: Yang Sheet Pipe Description 3.5 in. 9.2 ppf J-55 BTC AB-MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 8 ft. 10,658 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 50 1533 0 R04 17 3 2.95 Sh II w Line of Pits. 51 1564 0 O.o2 7 3 2.96 Bucklinq. 52 1594 0 0.03 12 2 2.91 Lt. Deposits. 53 1625 00.0 9 = 2.91 Lt. QEj2Qsit,. 54 1655 0 0.02 8 3 2.95 55 1687 0 0.02 9 3 2.94 56 1716 0 0.03 11 2 2.95 Buckling. 7 1746 0 0.03 12 3 2.91 Lt. De o. 57.1 1778 0 0.01 4 1 2.94 Pu 12 57.2 17 0 0 0 2.80 CAM CO P-1 A- A SAF VALVE 57.3 1793 0 0.01 4 1 2.95 Pu 58 1 5 0 0.02 7 2 2.94 9 1827 0 .03 13 5 .98 cklin . 60 1858 0 0.03 13 4 2.90 Lt. De osits 61 1 0 0.03 1: 4 2.93 62 1921 0 4 14 4 4 63 1952 0 0.02 7 2 2.91 Lt. De osits. 4 1983 0 7 2 2.91 e osi ucklin . 65 2015 0 0.0 9 2.91 Lt. sits. 66 2045 0 0.04 14 3 2.92 Lt. De osits. 7 2077 0 3 11 2 .90 e osit . 68 108 0 0.0 10 2 8 Lt. osits. 69 2140 0 0.04 15 4 2.87 Shallow Line of Pits. Lt. De osits. Bucklin . 7 2171 0 12 3 5 71 02 0.03 13 4 2. 4 72 2234 0 0.02 9 2 2.92 Lt. De osits. 73 2264 0 11 2.90 t. osits. 74 2296 11 2 2.90 Lt. De osits. Bucklin . 5 2328 17 3 .89 Sh low Lin of Pits. osit . 76 358 11 2.94 77 2390 gOO J0.4 15 6 2.92 Shallow Line of Pits. LC De osits. 78 2419 17 .887 45180 2483 12 4 2.9281 251 14 2.90 2 1 2546 1 0 0.02-12 3 2.91 It e osits. 83 1 2577 0 0.04 144 2.92 Lt. De osit . 84 2608 0 7 2 2.96 Buckling. 85 1 2638 0 0.0 11 2.93 862668 0 0.03 12 3 2.91 Lt De osits. 87 2699 0 0.02 9 .91 e osit . 8 1 2731 0 0.03 12 2 2.93 1 Lt. DeDOSIN. 89 1 2762 0 0.03 10 4 2.93 Lt. De osits. Bucklin . 27 2 0 .OS 18 4 3 allow Lin of Pits. 91 2823 0 0.03 11 2 2.92 Lt. De osits. 92 2855 0 05 21 4 2.91 Is fated Pittin t. a osits. 93 2687 9 2 2.95 94 2918 0 0.02 9 3 2921 Lt. Deposits. Bucklin 95 2950 0 0.03 10 3 2.21 1 Lt. Deposits. 96 2982 0 6.03 10 4 2.92 1 Lt. Deposits. Penetration Body Metal Loss Body Page 2 ji4s PDS Report Joint Tabulation Sheet Well: 31-1-21 Survey Date: April 14, 2019 Field: Kuparuk Analyst: Yang Company: ConocoPhiGips Alaska, Inc Pipe Description 3.5 in. 9.2 ppf J-55 BTC AB-MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 8 ft. 10,658 ft. Joint No. It. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 7 1 0 0.02 9 3 95 98 3045 0 0.04 14 4 2.89 Lt. DeDOSIK 99 3075 0 0.03 12 2 2.92 Lt. Deposits. Buckling. 100 1 0.04 0.04 15 2.90 Shallow Fitting. t. DeDQ5 its. 101 3138 0 0.03 11 3 2.93 101.1 3169 0 0 0 0 2.89 GLM 1 Latch @ 12:30 1 2 3175 0 0.02 7 2 2.88 Lt. Deposits. 103 3205 0 0.03 12 2 2.93 Lt. De its. 104 3237 0 0.04 16 4 2.98 Shallow Line of Pits. Buckling. i 3268 4 0.04 15 2. 4 Shallow Line of Pi 106 3299 0 FO.03 12 4 2.91 Lt. Deposits. 1 7 3329 0 1 am 1' 4 2.91 Lt. D osits. 108 3358 0 0.03 11 4 2.95 109 3389 0 0.03 11 3 2.92 Lt. Deposits. Buckling. 110 3421 0 0.02 9 2 2.90 Lt. Denosits. 111 3451 0 0.02 2 1 2.91 1 t. Deposits. 112 3482 0 0.03 12 4 2.94 113 35121 0 0.02 9 4 2.97 114 354 05 0. 0. 6 1 24 6 2.93 Ling Corrosion. Buckling. 115 3573 1 0 0.03 13 4 2.96 116 3605 1 0 0.03 11 4 2.93 Lt. Deposits. 117 1 3636 1 0 0.01 10 2 2.92 L. DeDosits. 118 1 3668 1 0 0.02 8 2 2.90 Lt. Deposits. 19 3699 0 0.03 12 4 2.94 Buckling. 120 3729 0 0.02 9 2 294 121 3759 0 4 2.91 Lt. Deposits. 122 37 1 it 2 2.92Deposits. 123 3823 0 2 2.91 Lt. Deposits. 124 54 0.0 5 2.93 Line Corrosion. Lt. Deposits. ucklin . 125 3885 0 $0.0417 4 2.93 126 3914 0 2 2.90 Lt. Deposits. 127 946 0 2 2.93 t. Deposits. 128 7 0 7 2.93 Sh Ilow Lin Corrosion. t. De o it . 129 4009 0 4 2.95 Buckling. 130 4040 0.04 0.04 15 5 2.93 Shallow Lin of Pits. Lt. De osit . 131 4069 0.02 9 1 2 Lt. Derposits. 132 4100 0 0.04 14 1 4 2.90 Lt. Derposits. 133 4130 .03 11 4 .94 134 4161 0 0.03 11 2 2.91 osits. BLickling. 135 4193 0 0.03 10 1 2.91 Lt. Del2osits. 136 4223 0 0.04 14 3 2.90 t. De sit . 137 4 53 0 0.03 11 5 2.94 138 4284 0.04 0.04 15 6 2.93 Shallow Line of Pits. Lt. De osits. 139 12 0 0.04 14 2 2.93t. De . Buckling. 140 4344 0 0.03 11 4 2.93 Lt. De osits. 4376 0. 5 111 2. Shall w of Pits Lt. De its. 4408 0.04 04 7 4 2.94 Shallow in of Pit . &43 4439 0 0.03 13 4 2.90 LtDe osits 447 0 02 2. 8 Lt. osits. B kin . 4501 0.03 11 0 2.8 t. De its. Penetration Body Metal Loss Body Page 3 ii4-s Well: 3H-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: April 14, 2019 Analyst: Yang Sheet Pipe Description 3.5 in. 9.2 ppf J-55 BTC AB -MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 8 ft. 10,658 ft. Joint It. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 146 4 0.0 13 6 294 147 4564 0 .02 9 3 2.94 148 4596 0 0.03 10 5 2.93 Lt. Deposits. 14 462 .02 9 2 2.91 Lt. D sits. Buckling. 5 4658 0 0.03 11 3 2.91 t Deposits. 151 4689 0 0.03 12 3 2.92 Lt. De osits. 1 2 471 0 0.03 12 3 2.93 Lt. De sits. 153 1 4748 0 0.03 13 4 .89 . De osi s. 154 4779 0 0.02 9 2 2.92 Lt. De osits.Bucklin . 15 481 .0 8 1 .90 t. Deposits, 156 4842 0 0.03 13 4 2.92 Lt. Deposits. 157 4873 0 0.04 14 4 2.94 158 4905 Q.04 0.04 16 6 2.91 Shallow Pit' . Lt. sits. 159 4934 0 0.02 9 3 2.91 Lt. Deposits. Buckling 160 4965 0 0.02 7 2.91 osit . 161 4 7 0 0.03 11 3 2.91 Lt. e osits. 162 5029 0 0.03 13 3 2.90 Lt. De osits. 163 5060 0 0.02 9 2 2.95 64 1 5091 0 0.03 13 2.94 Bucklin . 165 5121 0 0.03 11 3 2.90 Lt. De osits. 166 151 0.0 11 2 2.92 Lt. osits: 167 51 3 0 0.02 3 2.92 Lt. D osits. 168 5214 0 0.03 11 5 2.90 Lt. De osits. 169 4 0 0.02 9 1 2. If osits. ucklin 170 527 0 0.03 11 2 2.8 L De os ts. 171 5307 0 0.03 12 1 2.88 Lt. De osits. 172 5 0 0.03 11 4 2. 1 Lt. DpDositq. 173 1 5370 1 0 0.03 10 3 2.94 17440 0.03 11 1 Lt. e osits. ucklin . 175 5434 0 0.04 14 3 2. t. sits. 176 1 5465 1 0 0.04 14 2 2.88 Lt. De osits. 177 1 5495 1 0 0.02 9 2 2. Lt. osits. 178 1 5527 1 0 0.03 12 4 2.92 t. De sits. 179 1 5557 1 0 0.03 10 3 2.95 BL-111;-- ucklin . 18Q1 1805589 0 0.02 8 2. 2 Lt. osits. 181 562 0 0.03 124 2. Lt. De sits. 182 5650 0 0.03 11 3 2.90 Lt. De osits. 183 681 tt 0.03 1' 2 2. 0 Lt. osits. 71 18 52 0 0.02 9 2 2. Lt. De osits. Bucklin . 185 1 5740 0 0.03 11 3 2.91 Lt. De osits. 186 1 57720.02 8 2 4 187 1 5803 0 0.03 11 2.93 188 5835 0 0.03 10 4 2.92 Lt. De osits. 189 865 0.03 13 2. 1 Lt. e osits. ucklin 190 5896 0 0.02 8 3 2.93 Lt. De osits. 1 1 5927 0 10 2 2.89 Lt. Denosits. 192 5959 0 .03 10 = 2.90 osits. 1935990 0 0.03 11 2 2.91 LL De osits. 1 4 6021 21 6 2.92 Line Corrosion. Lt. Deposits. Buckling. 195 1 6052 10 0. 4 15 2 2.93 Shallow Line of Pits. Penetration Body Metal Loss Body Page 4 (Rs� Well: 3H-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: April 14, 2019 Analyst: Yang Pipe Description 3.5 in. 9.2 ppf J-55 BTC AB -MOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 8 ft. Bottom Depth 10,658 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 196 6084 0.0 2 2. t. De sits. 197 6116 0 0.03 11 1 2.87 Lt. De12osits. 198 6145 0 0.02 7 1 2.90 Lt. Deposits. 199 1750 0.02 7 2 2. 2 Lt. Deposits. Buckling, 200 6203 0 0.02 9 2 2.94 201 6232 0 0.02 9 3 2.90 Lt. Deposits. 02 6264 0 0.02 9 3 2.90 Lt, Deposits. 203 6295 0 .03 10 2 2.88 1 Lt. DeDositq. 204 63270 0.02 9 1 2.88 Lt. De osits. Buckling. 5 6360 0 4 14 3 .89 t. osit 206 1 6390 0 1 0.02 9 1 2.89 Lt. De osits. 207 6420 0 .0 8 2 2.92 e osit . 2 6450 0 11 2. 1 Lt. osits. 209 6482 0 0.02 9 3 2.95 Bucklin . 0 6512 0 3 11 4 osi ts. 211 6 43 0. 9 1 2. Lt. osits. 212 6574 0 0.03 12 2 2.89 Lt. De osits. 1 6604 0 0. 11 Lt. osits. 214 6636 0.04 0.04 16 4 2.91 Shallow Line of Pits. Lt. Denosits. Bucklin 214.1 6667 00 0 2.89 GLM 2 Latch CEJ 9:30 215 6673 0 0.03 11 3 2. Lt. QQ12Qsits. 216 6703 1 0 1 0.03 12 3 2.88 Lt. De its. 217 6734 1 0 1 0.03 13 3 2.91 Lt. Deposits. 218 1 6764 0 0.02 7 1 2 t. De its. 19 6725 0 0.04 14 2 2.89 Lt. De o i s. Buckling, 220 6827 0 0.03 13 0 2.88 Lt. Deposits. 221 1 6857 o f 0.03 13 2 2.86 Lt. Dej2QSjts. 2226886 0 1 0.04 15 4 2.91 Shallow Pitting. Lt. Delposits. 22 6919 0 1 0.02 9 2 2.91 Lt. Deposits. 224 6951 0 1 0.03 12 2 2.90 Lt. De its. Bt cklin 225 6982 0 1 0.04 15 3 2.92 Shallow Line of Pits. Lt. Deposits. 226 7013 0 0.02 8 2 2.87 Lt. De its. 227 7042 1 0 0.02 9 0 2.85 Lt De o it . 228 7072 0 0.02 7 0 2.88 Lt. Deposits. 229 7102 0 0.04 15 1 2.89 Shallow Pitting. . De o i Buckling. 230 7132 0 0.04 15 1 2.8 Shallow Pitting. Lt. e osits. 231 7163 0 0.03 10 2 2.91 Lt. Deposits. 7194 00.04 16 3 2.91 Shallow Lin of Pils. I t. D osits. 233 7223 0 0.03 13 2 2.89 Lt. De i s 234 7255 0 0.03 10 0 2.88 Lt. Deposits. Bucklin 2 5 7284 0 0.02 8 1 2-88 Lt. Denosits. 236 7315 0 1 0.03 13 2 2.88 Lt. De its. 237 7344 0 1 0.03 13 1 2.87 Lt. Deposits. 238 1 75 0InO 2 3 2. t. osits. 239 7405 0 12 2.90 Lt. De osits. Buckling, 40 435 012 Lt. osits. 1 7466 12 2 2 Lt. its. 242 7496 0 9 2 2.91 Lt. De osits. 243 752 09 2.88 . DP sit . 4 7557 011 2 .8 Lt. Deposits. Buckling. Penetration Body Metal Loss Body Page 5 ji-�s Well: 3H-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: April 14, 2019 Analyst: Yang Sheet Pipe Description 3.5 in. 9.2 ppf J-55 BTC AB -MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 8 ft. 10,658 ft. Joint No. )t. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 245 8 0 0.04 14 2. Lt. Deposits. 46 7619 0 0. 11 1 2.8 . De osi . 247 7651 0 0.03 12 1 2.90 Lt. Deposits. 248 768 0n.040 14 2 2. t. Deposits. 249 7714 0 0.02 7 0 2.89 . Deposits. Buckling. 250 7746 0 0.02 9 2 2.89 Lt. Deposits. 1 7777 0.04 15 2 .90 Pittin . t.Deposits. 252 7808 0 .03 12 1 2.85 -Shallow Lt. osits. 253 7839 0 0.03 11 1 2.88 Lt. Deposits. 254 7870 0.03 11 1 .89 Lt. osits. Buckling, 255 7902 0 0.03 13 2 2.89 Lt. Deposits. 256 7931 0.03 1 -2-2.88 U. Deposits. 257 7961 0 0.04 16 1 Sh II w Line of Pi Lt. Deposits. 258 7992 0 0.04 15 4 2.91 S hallow Line of Pits. Lt. Deposits. 25 8 23 0 0.03 12 3 .91 t. osits. u I' 260 0 0 0.03 11 1 989 Lt. De osits. 261 8085 0 0.03 12 4 2.91 Lt. Deposits. 262 1 5 0.04 0.04 15 89 Shallow ine of Pi . Lt. De 263 81 7 0 ?6 3 2.89 Shallow Pit ting. Lt. osits. 264 8178 0 0.04 14 2 2.89 Lt. Deposits. Buckling. 265 8207 0 0.0312 2 2.89 Lt. Deposits. 266 8238 0 0.02 9 1 2.91 I t. De osi s. 267 1 8269 0 0.03 11 1 2.90 Lt. Deposit . 268 1 8300 0 0.02 9 1 2. Lt De its. 69 1 8331 0 0.04 14 2 2.91 It. De osi . Buckling. 270 8361 0 0.03 11 4 2.91 Lt. De osits. 271 8392 0 0.04 15 4 2.91 Shallow Pitting. It. DenQsits. 272 8421 0.04 0.03 13 3 2.92 Lt. Deposits. 273 452 0 .03 12 4 2. Lt. De its. 274 8482 0 0.0 12 1 2.88 t. De o i Buckling. 275 8513 0 0.05 19 0 2.88 Shallow Pitting. Lt. Deposits, 276 4 0 9 2. It De its. 276.1 8575 0 0 0 0 2.87 LM 3 Latch @ 12:00 277 8582 0 0.05 20 3 2.91 Line of Pits. Lt. Deposits. 278 1 0 .0 12 1 2.90 Lt. De it . 279 864 0 0.04 16 2 2. Shallow Pitting. It. Deposits. Buckling. 280 1 8675 0 0.03 12 4 2.92 Lt. Deposits. 281 8704 0 0.04 1 15 4 2.92 Shallow Pittiniz. Lt. Deposits. 282 8737 0.05 0. 4 4 2.8 Line Corrosion. Lt. Deposits. 283 8769 0 0.03 1 12 3 2.88 Lt. De osits. 2 4 8800 0 0.03 13 2 2.89 Lt. Deposits. Buckling. 285 8830 0 0.04 16 1 2.91 Shallow Pitting. Lt. De osits. 286 8860 0 0.04 1.5 2 2.90 Shallow Line of Pits. Lt. Deiposits. 287 0 0.05 18 2.91 ShalloLine of Pits. I t. Deposits. 288 8920 0 0.02 9 3 2.92 Lt. Deposits, 289 18950 0 0.03 11 4 .94 Utickliog, 22Q I 982 0 0.04 15 3 2.89 Shall ine of Pits. Lt. Deposits. 291 9011 0 0.03 13 3 2.87 Lt. Deposits. 292 904 0.04 14 2 .90 e osits. 0 0.02 9 1 .90 L . osits. 107 'Penetration Body Metal Loss Body Page 6 V -s Well: 3H-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: April 14, 2019 Analyst: Yang Sheet Pipe Description 3.5 in. 9.2 ppf J-55 BTC AB -MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 8 ft. 10,658 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % I.D. (in.)0 Min.Mkl,, Co(%wall) Damage Profile 50 100 294 9098 0 0.07 1 2. Line Corrosion. Lt. Dbuckling. 95 9129 0 0.03 12 1 .89 . Deposits. 296 9158 0 0.03 12 3 2.90 Lt. Deposits. 297 191 0 0.03 11 2 2.92 L . -Deposits, 8 227 0 4 14 4 0 t. e osits. 299 9253 0 0.05 21 0 2.88 Line of Pits. Lt. Deposits. Buckling, . 00 2 0 4 14 2 2.90 L. posit . 1 9316 0 0.04 14 2.88 Lt. sits. 302 9346 0 0.03 12 1 2.89 Lt. De -sits. 3 9378 0 18 4 .9 Sh II Line f Pits. It.. 304 9408 0 0.02 9 2 2.92 Lt. Deposits. Buckling. 05 943 0 .05 19 4 2.89 Shallow Lin f Pits. LtDeposits. 3 9468 0 0. 12 2 2. Lt. osits. 307 9499 0 0.02 9 0 2.89 t. De --sits, 8 9530 0 17 5 2 2 .308.1 9562 0 0 0 2.3 L 9 9568 0 0.05 19 4 2.91 hallow Line of Pits. LtDeposits. Bucklin . 31 9598 0.03 11 2 2. Lt. De sits. 311 9629 0 0.04 15 3 2.91 ShIlow Pitfin .L. e osis. 312 9659 0 0.03 13 3 2.91 Lt. De -sits. 313 69 0 0.05 21 2. ine of Pits. Lt. -sits. 314 7 0 0.03 13 7 2.91 . D------ stsBucklin . 315 315 9751 0 0.03 12 3 2.92 Lt. Deposits. 316 9781 0 0.04 14 3 2. Lt. it . 317 81 0 0.05 2 4 .92 Line of Pits. U. Deposits. 318 9844 0 0.03 13 3 2.92 Lt. Deposits. 319 74 0 0.04 1 2 2.88 hallow Pitting. Lt. Deposits. Buckling. 320 9903 0 0.03 11 4 2.90 Lt. Deposits, 321 935 0.03 11 2 2.8 it D sits. 322 9 65 0 0.02 9 1 2.89 t. Deposits, 323 9993 0 .03 11 2 2.90 Lt. Deposits. 324 10023 .OS 18 4 2.91 hallowPit'n .Lt. e osits. Buckling. 325 1 54 0 0.04 17 3 2.89 Shallow Pitting. Lt. Deposits. 325.1 10085 0 0 0 0 2.83 GLM 5 Latch @ 7:00 32 10091 0.05 19 3 2.90 Shallow Line of Pits. I t._DeQQ$its. 327 1 122 0 0.03 13 1 2.88 Lt. Denosits. 328 1 10153 0 0.03 13 1 2.90 Lt. Deposits. 329 1 10183 0 0.05 0 4 2.88 Isolated Pitting. Lt. DepositS. Buckling. 10216 0 0.04 17 6 2.91 hallow Line of Pits. t. De osits. 10246 0 0.03 13 4 2.92 Lt. Deposits. 10277 0 0.02 9 0 2.8 L Deposits. N33 10305 0 0.04 14 0 2.85 t. Deposits. 10336 0 0.03 12 2 2.86 Lt. De -sits. Bucklin . 10367 0 0.0- 1 2 2. 1 Lt. De its. 36 10397 0 0.04 14 2 2.91 Lt. De -sits. 37 10428 0 0.03 13 2 28 Lt. -sits. 8 10461 0 0. 12 2 2. Lt. D its. 9 10493 0 0.03 13 0 2.88 Lt. De -sits. Bucklin . 139.1 1052 0 0 2.87 10534 8 0. 5 19 4 2. 0 Shallow Pittin DWOSitS. 'Penetration Body Metal Loss Body Page 7 ji-S Well: 3H-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: April 14, 2019 Analyst: Yang Pipe Description 3.5 in. 9.2 ppf J-55 BTC AB -MOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 8 ft. Bottom Depth 10,658 ft. Joint Jt. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 40.1 2.91 BAK R PBR 40.2 10572 0 0.04 16 1 2.93 Pu Shallow Pitting, 340.3 10585 0 0 0 0VBAKERER FHL Packer .4 1 8 0.05 0.04 17 3Shallow in of Pits. 34 10592 0.26 .05 18 4 in set! Sh llow Line of Pi . Lt. e osits.341.1 10623 0 0 0 0 O D NIPPLE NO CO 34 1062 0 .05 19 2low in of Pi . De sits. 42.1 10658 0 0 342.2 10658 0 0 0 0n Tail Penetration Body Metal Loss Body Page 8 iiS PDS Report Cross Sections Well: 3H-21 Survev Date: April 14, 2019 Field: Kuparuk Tool Type: UW MFC 24 Fxt. f!o. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1,69 Country: USA No. of Fingers: 24 Cross Section for Joint 294 at depth 9,107.680 ft. Tool speed = 54 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 98% Tool deviation = 59° Finger = 3 Penetration = 0.066 in. Line Corrosion 0.07 in. = 26% Wall Penetration HIGH SIDE = UP PDS Report Cross Sections Well: 3H-21 Survey Date: April 14, 2019 Field: Kuparuk Tool Type: UW IeIFC 24 Ext. No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Cross Section for Joint 282 at depth 8,739.390 ft. Tool speed = 55 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 55° Finger= 22 Penetration = 0.063 in. Line Corrosion 0.06 in. = 24% Wall Penetration HIGH SIDE = UP PDS Report Overview s Body Region Analysis Well: 3H-21 Survey Date: April 14, 2019 Field: Kuparuk Tool Type: UW MFC 24 &t. No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf -55 BTC Analyst, Yang Pipe Nom.OD Weight Grade & Thread Nom -D Top Depth Bottom Depth L 7 in. 26 ppf J-55 BTC 6.276 in 10,658 ft 10,803 ft Damage Configuration (body) 10 8 6 4 2 0 Isolated Pitting General Line Other Corrosion Corrosion Damage Hole/ Pos. Hole Number of io nts damaged (total = 6) 0 4 0 0 2 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 1 1.1 1.2 2 2.1 3 4....__..-_- .._ 5 Bottom of Survey = 5 Perforations ii S— PDS Report Joint Tabulation Sheet Well: 31-1-21 Survey Date: April 14, 2019 Field: Kuparuk Analyst: Yang Company: ConocoPhillips Alaska, Inc. Pipe Descripfion Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf J-55 BTC Casing 6.276 in 0.362 in 10 658 ft 10,803 ft Joint Jr. Depth Pen. Pen. Pen. Metal in. No. (Ft.) Upset Body % Loss 1. D. Comments (in.) (in.) (in.) I 10658 0.4 0. 100 26 6.23 Mul i le Holes! 1.1 10683 012 0.11 31 16 6.2 u Corrosion. 1.2 10691 0.13 0.13 35 25 6.41 Pu Corrosion. Lal 2 10692 .13 0.15 41 17 .2 Corr n. .1 1 714 0.12 0.13 5 18 6.32 Pu Corrosion- orrosi n.3 310717 0.15 0.69 100 24 6.11 Multi le Holesl Lt. De osits. 4 10758 0. 8 6.301 Perforations d M l i le Hol I 5 10795 O'bO 0.82 1 100 1 74 1 6.51 1 Perforations Penetration Perforations Metal Loss Perforations Page 1 'Penetration Body Metal Loss Body jiS Field: Company: Country: 3H-21 Kuparuk ConocoPhillips Alaska, Inc. USA 7 in. 26 ppf 1-55 BTC PDS Report Cross Sections Survey Date: April 14, 2019 Tool Type: UW MFC 24 Ext. No. 211390 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 3 at depth 10,745.601 ft. Tool speed = 35 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 79% Tool deviation = 57° Finger = 2 Penetration = C Multiple Holes 0.69 in. = 100% Wall Penetration HIGH SIDE = UP JPS, Well: Field: Company: Country: 3H-21 Kuparuk Conoco Phillips Alaska, Inc. USA PDS Report Cross Sections Survey Date: April 14, 2019 Tool Type: UW MFC 24 &t No. 211390 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 1 at depth 10,676.281 ft. Tool speed = 49 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 74% Tool deviation = 71° Finger = 20 Penetration = 0.661 in. Multiple Holes 0.66 in. = 100% Wall Penetration HIGH SIDE = UP V's Well: Field: Company: Country: 3H-21 Kuparuk ConocoPhillips Alaska, Inc. USA 7 in. 26 ppf 1-55 BTC Cross Section for Joint Tool speed = 49 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 74% Tool deviation = 710 PDS Report Cross Sections Survey Date: April 14, 2019 Tool Type: UW MFC 24 Fxt. No. 211390 Tool Size: 1.69 No. of Fingers: 24 at depth 10,676.281 ft. Finger =20 Penetration = 0.661 in. Multiple Holes 26% Cross -Sectional Wall Loss HIGH SIDE = UP `PS, Well: Field: Company: Country: 3H-21 Kuparuk ConocoPhillips Alaska, Inc. USA BTC PDS Report Cross Sections Survey Date: April 14, 2019 Tool Type: UW MFC 24 Ext. No. 211390 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 1.2 at depth 10,691.771 ft. Tool speed = 47 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = .'S% Tool deviation = 57° Finger = 22 Penetration = 0.121 in. Corrosion 25% Cross -Sectional Wall Loss HIGH SIDE = UP Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760tax Delivered to: -� .4% AOGCC ,. ATTN: Natural Resources Technician II Alaska Oil &Gas Conservation Commision '•� 333 W. 7th Ave, Suite loo Anchorage, AK 99501 180008 i TRANSM11TALDATE TRANSMITPAl H Schlumberger -Private THE STATE ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 31-1-21 Permit to Drill Number: 188-008 Sundry Number: 319-216 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vvv✓w. aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, '-4� Daniel T. Seamount, Jr. Commissioner DATED this Z day of May, 2019. OWSLEIMAy 011019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 APR 2 5 2019 AQGGG 1. Type of Request: Abandon ❑ Plug Perforations ❑Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑Q Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: —Whipstock_❑Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑' Stratigraphic ❑ Service ❑ 188-008 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-103-20094-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3H-21 Will planned perforations require a spacing exception? Yes ❑ No ❑Q ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25523:ADL 25531 Kuparuk River Field /Kuparuk River Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11346' 6373' 11218' 6314' 4362 N/A 11029' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 4586' 9-5/8" 4621' 3084' Production 11265' 7" 11300' 6352' Liner Perforation Depth MD (ft):Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10774'-10814', 10860'-10890' 6099' - 6119', 6141'- 6156' 10904'-10942', 10954'-10992' 6163'- 6182', 6187' - 6206' 3-1/2" J-55 10672' 11010'-11050', 11058'-11072' 6214' - 6233', 6237'- 6244' Packers and SSSV Type: Baker FHL Packer Packers and SSSV MD (ft) and TVD (ft): 10600' MD / 6013' TVD Camco TRDP-1A-SSA 1803' MD / 1642' TVD 12. Attachments: Proposal Summary ❑' Wellbore schematic ❑' 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/1/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑Q GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. /. Authorized Name: James Ohlinger Contact Name: Keith Herring Authorized Title: Staff CTD Engineer Contact Email: Keith. E. Herrin CO .Com Contact Phone: 2634321 p Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: G BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Plug Integrity F1M Other: 00P -fr'S t fo 48 01'7 e 5 r r��r5 t to ZSoo �s r S flnvtvla✓ P ! //2C� A/¢fr"a-yG bvq �l✓t %a/�/�r o vsd D er oho �tftC 25 /o/acry, p Post Initial Injection MIT Req'd? Yes ❑ No p� 2 Spacing Exception g� / Required? Yes ❑ No Q' Subsequent Form Required: RBDMS&J MAY 0 2 2019ppp APPROVED BY Approved by: zg�e� COMMISSIONER THE COMMISSION Date: ( 1 1 Il l�Pti to io'd 3`Revise2017 / Approved applicat o0 iRill Gil hArryn the date of approval. Submit Form and A`tt me s in Duplicate T x��j9 9.CAW74111 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 24, 2019 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 Sundry Application (10-403) to change the approved program (Sundry #319-132) in order to plug for re -drill KRU 31-1-21 (PTD #188-008). The perforations will be cemented and a mechanical whipstock will be set in order to drill a dual lateral out of KRU 31-1-21 using the coiled tubing drilling rig, Nabors CDR3-AC. A Sundry application is attached to plug the KRU 31-1-21 perforations. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 26.112(c)(1) to plug the perforations in this manner. Attached to this application are the following documents: - 10-403 Sundry Application for KRU 31-1-21 - 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 907-263-4321. Sincerely, Keith Herring ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 3H-21 (PTD #188-008) CTD Summary for Sundry Summary of Operations: KRU well 3H-21 is a Kuparuk A -Sand and C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the northeast of 31-1-21. The laterals will increase A -sand resource recovery and throughput. Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail at 10,643' MD. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the perforations in this manner. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 11,030' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 11,000' MD. The two laterals will be comrileted with 2 3/8'_ slotted liner from TD with the final liner top located inside the_3-1 /2" tubing tailZ ctyn cu Using the maximum formation pressure in the area of 4,983 psi in 31-1-22, the maximum potential surface st'll pressure in 31-1-21, assuming a gas gradient of 0.1 psi/ft, would be 4,362 psi./cefy BOP Test Pressure = 4,800 psi CTD Drill and Complete 3H-21 Laterals: Mav 2019 Al Pre -CTD Work 1. RU E -line: Punch 2' of holes in the 3-1/2" tubing tail. r� 2. RU Pumping Unit: Perform injectivity test down tubing. 3. RU Service Coil: Cement squeeze the perforations up to the holes in tubing tail. 4. RU Slickline: Tag top of cement. h 5. Prep site for Nabors CDR3-AC. IZ� `V Rin Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H -21A Lateral (Al sand - Northeast) a. Mill 2.80" high side pilot hole through cement to 11,030' MD. b. Caliper pilot hole and set top of whipstock at 11,000' MD. c. Mill 2.80" window at 11,000' MD. d. Drill 3" bi-center lateral to TD of 14,000' MD. J e. Run 2%" slotted liner with an aluminum billet from TD up to 11,350' MD. 3. 3H-21AL1 Lateral (A2/A3 sand - Northeast) a. Kickoff of the aluminum billet at 11,350' MD. b. Drill 3" bi-center lateral to TD of 14,000' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 10,995' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production Page 1 of 1 4/24/2019 31-1-21 Proposed CTD Schematic 16" 62# H40 shoe @ 115' MD C -sand parts 110774'- 10814' MD KbF011,000' MD Aland per s 10860'- 10890' MD 10910'- 10930' MD 10965'- 10985'MD 11010'- 11072'MD 7" 28# J-55 shoe @ 11300' MD 3-1/2" Cameo TRDP-IA-SSA SV @ 1803' MD - locked out 12/26/88 3-12" 9.2# J-55 BTC AB -Mod Tubing to surface 3-1/2" Cameo gas lift mandrels @ 3191', 6683', 85921, 9576', 10,099', 8 70,538' MD Baker 3-12" PBR @ 10,580' MD (3" ID) Baker FHL packer @ 10,600' MD (2.992" ID) 3-7/2" Camco D landing nipple @ 10,638' MD (milled to 2.80" ID) 3-1/2" SOS @ 10,671' MD / 7"casing damge at 70807' CTMD. i3H-21AL1 wp02 (Plan TD: 14,000' MD 'Top of liner. 10,633' MD 34-21A wp03 Plan TD: 14,000' MD Top of liner: 11,350' MD AgJFQI%+ KUP PROD WELLNAME 3H-21 WELLBORE 3H-21 ConOCOr111IIipS "} .I Attributes Max Angle&MO TD Ree xameweIIWre P➢uulM Video,. memo KUPARUK RIVER UNIT 501032009400 PROD nn -I MD mI(61 ACI Btm mKe) 5.96 5,800.00 11,34fi.0 Alaska. IRC. Comment H35typm1 Oate Annotation ane Dale K asdpd Rg Rek Deb SSSV: LOCKEDOUT 200 111252016 "pawn: MAI BOOM sh" enoam a 59: E9 pM Last Tag one-1ac1emalic (feat Annotation Depth deal EM Date WeIIIutMM BY -"""-- - - Last TagRKB(A11212- of Aelands are Covere! l All C- sends are Open) 10829.0 2/412019 311-21 iembaej ----r--- XMGER. 35.1 i Last Rev Reason oPOSSIBL Em one welnpe. Iasi Mo]Bv eoNDICioR,sp.nSo Rev Reason: MILLED DNIPPLE, POBSBLE CASING DAMAGE 4/12019 311-21 contlijw Casing Strings SAFETVULV, 1,89.1 Casing DoscNpllan OD'in) IO(in) Top VsKBl $el DepM 11IK81 Set Depth [NDI... WLLen (I... Geeee Top Tarea] CONDUCTOR 16 15.06 360 115.0 115.0 62.50 ,=WELDED 11I OA9LIFT;3.191d Geeing Denlption 00th, IDlln) ToPin 9N DepIM1 mKBI .Drym 11V01... Waten (I... GrMa Tap TM1real SURFACE 9518 8.92 35.0 4.620.6 3,0839 3600 J55 BTC Ching Deacrme OD(in; lopm TophdGh BADepm InKB1 Ssmand DVD)... WIM1en(I,,.Gram, Top Throe PRODUCTION 7 628 350 11,300.3 0352.0 2600 J-55 BTC Tubin Strings Tubing Deecriplion Sning Ma.. ID(n) iop lnKS) SaDeplh (k. Sel Depth 1TVD)I... IM (IhXI) Graee Top Connecnen 90RFACE: 380.4,6M8- TUBING 3112 299 35.1 10.6]24 6,0494 9.20 J-55 BTC AB -MOD 1 Completion Details GASUFT6.Eai4 TopinD) TDpmn Nominal TM mKe) mKW (°I Isom Do. con Ho (m) 35.1 35.1 0.051HANGER MEVOYTUBING HANGER .500 GAS UFT; 8591.5 1,803.1 1.642.0 46.7 SAFEWVLV CAMCO TRDP-IA-SSA SAFETY VALVE(LOC6ED OUT 1226188) 2.81 GASUrT:A575.e 10,579.9 B.M.1 59.73 PER BAKER PER 3.000 10,599.6 6,013.0 59.83 PACKER BAKER FHL PACKER 2aW GAS UFT 10 .08.0 10. 6032.3 60.01 NIPPLE- CAMCO D NIPPLE NO GO(MILLE TO 2.80' ON313U19) 2.800 MILLED OUT DAs LIFT; p%Mai 10,916 6.048.9 60.17 SOS BAKER SHEAR OUT SUB 3.000 MR, 113,5710- Otberin Hole(Wireline retrievable plugs, valves, pumps, fish, etc.) PMR) I Tnp and PACKER, losse.8 T2EhaMU mKBI (° Des Cam Run Dai H. him 108010 6,112.9 60.61 ^'PO BIBLE UNABLE TO FCO PAST 10801' W12.0' PIN, TRIED 4110019 6.2 PIPPLE-MLLEDOUR 10.6313 CASING DAMAGE... 2.73 MILLAND2.IWMOTOR, SSTALLSAND ONE OVERPULL AT THIS DEPTH, 411119 11,029.0 6.223.8 fi1.35 FISH 11/2"OVEmply Poeket;Assume FelltORathole 711WI996 sos,a.n1.4 ', Perforations & Slob _ she Den etm Rw) (alwim 710(74. B1mmKB) Ralph mRe) Llnkee2ane Dai 1 Type Com 10,776.0 W.804.0 611 .099.6 5114A C-0, 3N-21 1111411988 6.0 /PERF 2118" EnerJel, Zero deg pM1 10,776.0 10,AG.o 6.100.6 6,110.0 C4,3H-21 531018 6.0 RPERE 2118'PavrerSpira Enerjet 60 deg ph ftPERFaa.T]64ta,.,1- IMIFF 1. n4&,09'.71,0- 10,]95.0 10814.0 6.110.0 0119.3 C-0, 311-21 5/12018 SO WERE 21AP Powers al Eneret pk I 60 deg ph RI ID 111,o-11 114 1 P0oasm-FCA9ING 10.804.0 10,814.0 6,1144 6,119.3 C4, 311. 1 11114119M 12.0 (PERF 2 IAP Speeded W deg ph m9agcE": wand /PERF', f00.0.1"a010� 10 .0 ,860.0 1 5141.8 6,156.5 A$3H-21 53111996 4.0 RPERF 2 118" Eamna,180 deg phasing; Pool 90 deg. FI LOwside 10,868.0 10,887.0 6.145.8 6,155.0 A-3,311-21 51112018 6.0 WERE 2 U8' Pov2rSP8a1 EnerJel 60 deg ph 10,904.0 10,W7.0 6,163.4 6.164.8 A-2, 3H- 1 41302018 60 RPERF 2118" PauerSVal EnerJel, 60 deg ph 10-, 6o 10.909.3 6.163.4 6,165.9 A -2,31-p21 41M2018 6.0 WERE 21 B"Poever pira EnerJel, W deg ph 10910.0 10,930.0 6,166.3 6.176A A-2,311-21 812511988 8.0 IPERF Seethed Big Hole, 60 deg phasing RPERF;,0.a5a.0.10.6W10 RPERF, IO.MS IO.W..0� 109230 10,992.0 6,1726 6,181.9 A-2,311-21 &300018 6.0 WERE 21/8'PwrerSpiral EnerJel 60 deg ph 10,954.0 10,956.0 6,187.7 6,188.7 A-1. 3H -2I 4272018 6,0 RPERF 21/8" PoeerSppal EnerJel 601 ph 10,951.0 10,973.0 6,187.7 6.196.9 A-1,311-21 4/28/2018 6.0 WERE 2118" Power3pea1 EnerJel anam 1DW4.a1P90].OL RPERF, 30.904.090.Aea� 66 deg ph 10965.0 10.985.0 6,193.0 6,2027 A -1.3H -21 7 -WIN -96.0 RPERE 2.5" HSD1DP, 60 deg ph, spiral tleg 10,973.0 10,992.0 8,196.9 6,206.0 A -1,3H-21 61272018 6.0 WERE 21/8- PO.ve Speal EnerJel /PERF', 10.810.610.930.0 60 deg ph RPERF 109M.0 -109I 11,010.0 11,030.0 6,214.7 6.224.3 A-1, 311-21 11/1&1999 4.0 APERF 2118" Emaget OF. 188 deg H-90 deg 11,030.0 11,050.0 0221.3 6,23.7.9 M1,311.21 ](31999 6.0 RPERF 2.5"HS01DP,fi0 deg pH, spiral 0, R........ m4.ot6ssap- 11,058.0 11,072.0 8237) 6244.4 A-1, 311-21 &2511988 4.0 ]PERF 4.5' Ullm Radio 120 deg ph RPERF: fO Sla, mRA- Mandrel Inserts S, elitism, ,09aS0.10,9a5,0� ea RI109T3.0.10.sap on TopDwI Valor Latah pod She TRO Ran N Top MKB) 111 Meke 11.0 00 (in) Sen, Type Tyye gn) (Fail Ramona Com 3,191.3 2,4232 CAM KBUG 1 GAS LIFT GLV BK -2 0.313 1,225.0 326/2019 2 6,683.4 4, .6 CAMCO KBUG 1 GAS LIFT GLV BK -2 0.188 1,225. 3 ,591.5 4,970.7 CAMCO KBU 1 A LIFT OV BK -2 0.25 0.0 3]5ID19 Apel n.01n.a1tmo.o- 4 9,956 54827 CAM 0 KBUG 1 GASLIFT DMY BK- 0.0 3242019 10,088.0 . 55. AMCO KBUG 1 G LIFT DMY BK -2 0.000 0. It 199 Flmil t?0?06 10,5 5.982.0 CAMCO MMG-2 1 ASLIFT DMY RK 0.0 3030019 AMU, 11 Ot0611.600 Notes: General &Safety_.......,- Ena Ome Annnbton IPFAF I1,011OR.0- 12/52005 NOTE: WAIVEREDWELL IAXUACOMMUNICATION 922010 N TE: View lUmonatle wl Alaska Sonamd .O PROODCTKIN: 15.0.11 3 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Operations Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Pool, KRU 31-1-21 Permit to Drill Number: 188-008 Sundry Number: 319-132 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely±nt, Daniel T Jr. Commissioner DATED this 27day of March, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 19 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Re air Well ❑ p pera idns shu tlown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Whipstock El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development El, Stratigraphic ❑ Service ❑ 188-008 3. Address:6. API Number: PO Box 100360, Anchorage AK 99510 50-103-20094-00—bw�' 7. If perforating: 8. Well Name and Number: �. za, F/ What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3H-21 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field/Pool(s): 74 bZ— LS 5W ADL 25523 1 Kuparuk River Field / Kuparuk River Oil Pool , 11. 7�, 2,-', /19t PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11346' 6373' 11218' 6314' 4362 N/A 11029' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 4586' 9-5/8" 4621' 3084' Production 11265' 7" 11300' 6352' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD 10774'-10814', 10860'-10890' 6099'- 6119', 6141' - 6156' 10904'-10942', 109541-10992' 6163' - 61821, 6187'- 6206' 3-1/2" J-55 10672' 11010'-11050', 11058'-11072' 6214'- 6233', 6237'- 6244' Packers and SSSV Type: Baker FHL Packer Packers and SSSV MD (ft) and TVD (ft): 10600' MD / 6013' TVD Camco TRDP-1A-SSA 1803' MD / 1642' TVD 12. Attachments: Proposal Summary Q Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/4/2019 OIL ❑� • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Keith Herring Authorized Title: Staff CTD Engineer Contact Email: Keith. E.Herrirl CO .Com Contact Phone: 263-4321 3/�`1//�• Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 -�32 Plug Integrity ❑ BOP Test e Mechanical Integrity Test ❑ Location Clearance ❑ Other: 60P 1t5t �D 48(O pScS 71 v/rn vla✓ p/—CV fvl �f7pt5 -,Y� 't� ZSo q q f1 Post Initial Injection MIT Req'd? Yes E] No �BD'yl. .,"" MAR L % 209 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10403 Revised 412017 Approved applicat n i h he date Of approve . ,,,,A%achments in Duplicate �� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2019 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 Sundry Application (10-403) to set a High Expansion Wedge in KRU 31-1-21 (PTD #188-008) in order to drill two CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC. Attached to this application are the following documents: - 10-403 Sundry Application for KRU 3H-21 - 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 907-263-4321. Sincerely, Keith Herring ConocoPhillips Alaska Coiled Tubing Drilling Engineer Loepp, Victoria T (DOA) From: Ohlinger, James 1 <James.J.Ohlinger@conocophillips.com> Sent: Tuesday, March 26, 2019 11:03 AM To: Loepp, Victoria T (DOA) Cc: McLaughlin, Ryan; Starck, Kai Subject: RE: [EXTERNAL]KRU 3H-21 (PTD 188-008, Sundry 319-132) BOP Test Pressure 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,800 psi. Using the maximum formation pressure in the area of 4,983 psi in 3H-22 (i.e. 15.5 ppg EMW), the maximum potential surface pressure in 3H-21, assuming a gas gradient of 0.1 psi/ft. would be 4,362 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, March 26, 2019 10:51 AM To: Herring, Keith E <Keith.E.Herring@conocophillips.com> Cc: Ohlinger, James 1 <James.J.Ohlinger@conocophill ips.com> Subject: [EXTERNAL]KRU 3H-21(PTD 188-008, Sundry 319-132) BOP Test Pressure Keith, Please provide the BOP test pressure. Tha nx, 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. Loeoono alaska gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal low. 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 Loeop;4_alaska-gov KRU 3H-21 (PTD #188-008) CTD Summary for Sundry Summary of Operations: KRU well 3H-21 is a Kuparuk A -Sand and C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the northeast of 3H-21. The laterals will increase A -sand resource recovery and throughput. E -line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 11,000' MD. CDR3-AC will mill a window in the 7" casing at 11,000' MD and the 3H-21 L1 lateral will be drilled to TD at 14,000' MD, targeting the A -sand to the northeast. It will be completed with 2- 3/8" slotted liner from TD up to 11,350' MD with an aluminum billet for kicking off the 3H- 21 L1-01 lateral. The 31-1-211-1-01 lateral will drill to a TD of 14,000' MD targeting the A -sand to the northeast. It will be completed with 2-3/8" slotted liner from TD up into the 7" production casing at 10,995' MD with a deployment sleeve. CTD Drill and Complete 3H-21 Laterals: April 2019 Pre -CTD Work 1. RU Slick -line: Change out GLV design and conduct dummy whipstock drift. 2. RU Service Coil: Mill out nipple and conduct fill cleanout. 3. RU E -line: Caliper 7" casing and 3-1/2" tubing, set High Expansion Wedge. 4. Prep site for Nabors CDR3-AC. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H-21 L1 Lateral (Al sand - Northeast) a. Mill 2.80" window at 11,000' MD. b. Drill 3" bi-center lateral to TD of 14,000' MD. c. Run 23/8" slotted liner with an aluminum billet from TD up to 11,350' MD. 3. 3H-21 L1-01 Lateral (A2/A3 sand - Northeast) a. Kickoff of the aluminum billet at 11,350' MD. b. Drill 3" bi-center lateral to TD of 14,000' MD. c. Run 23/" slotted liner with deployment sleeve from TD up to 10,995' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Ria Work 1. Return to production Page 1 of 1 3/19/2019 3H-21 Proposed CTD Schematic 16" 62# H-40 shoe @ 115' MD 9-5/8" 36# J-55 shoe A 4621' MD C -sand Paris 10774'- 10814' MD KOP @ N,000' MD sand parts 10860'- 10890' MD 10910'- 10930' MD 10965'- 10985' MD 11010'- 11072' MD T' 26# J-55 shoe @ 11300' MD 3-1/2" Camco TRDP-IA-SSA SV @ 1803' MD - locked out 12126/88 3-1/2" 9.2# J-55 BTC AB -Mod Tubing to surface 3-1/2" Carrico gas lift mandrels (013191', 6683', 8592', 9576', 10,099', & 10,538' MD Baker 3-1/2" PBR @ 10,580' MD (3" ID) Baker FHL packer @ 10,600' MD (2.992" ID) 3-1/2" Camco D landing nipple @ 10,638' MD (2.75" min ID, No -Go) 3-1/2" SOS @ 10,671' MD 3H-211.1-01 wp01 'Plan TD: 14,000' MD Top of liner: 10,995' MD (3H -21L1 wp02 Plan TD: 14,000' MD ,Top of liner: 11,350' MD Loepp, Victoria T (DOA) From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Tuesday, March 26, 2019 11:03 AM To: Loepp, Victoria T (DOA) Cc: McLaughlin, Ryan; Starck, Kai Subject: RE: [EXTERNAL]KRU 3H-21(PTD 188-008, Sundry 319-132) BOP Test Pressure 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,800 psi. Using the maximum formation pressure in the area of 4,983 psi in 311-22 (i.e. 15.5 ppg EMW), the maximum potential surface pressure in 3H-21, assuming a gas gradient of 0.1 psilft, would be 4,362 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, March 26, 2019 10:51 AM To: Herring, Keith E <Keith.E.Herring@conocophillips.com> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: [EXTERNAL]KRU 3H-21(PTD 188-008, Sundry 319-132) BOP Test Pressure Keith, Please provide the 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(cDalaska.goy 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)7931247 or Victoria Loo@alaska.cJov 00 4111 O M • CD UD w N > o o 11-4: N 1m O'1 VI Y• O @ O u N � > p co a-, OU N O v a` a c• a) c +, 0• 0 -a a - c 0 °' > a p w 0 0 ao 00 00 0o CO CO CO CO CO CO co CO .s-, 6 m • 0 J CC i ,. 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They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /_c~~- Z~_~~ Well History File Identifier Organization (done) RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: ~Two-Sided DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES' I/'~''~ NOTES: ORGANIZED BYi BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: D Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Isl Project Proofing [] By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES' //~ (at the time of scanning) SCANNED BY~ BEVERLY BREN VlNCEN~ARIA LOWELL ReScanned (done) RESCANNED BY: ~REN VINCENT SHERYL MARIA LOWELL /SI ~ General Notes or Comments about this file: Quality Checked (done) Iq=u1 NC)T.e,r.nnm~J w~d • ID Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 c' 1 31 7 rr T:7 A in. r li March 9, 2012 Commissioner Dan Seamount 4 +> , Ny: °,. , Co o& ;, ��.siut'. ,. -'i3 ,. , y .'�� 30 ':d��iic'S2as _i��d'):(� , Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 = _ =a Anchorage, AK 99501 16)6-003 Commissioner Dan Seamount: 314-- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement 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 in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerel , MJ veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3 -09 -2012 3A,3G,3H,3K PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 3A -17A 50029226910100 2101130 3'6" NA 13" NA 5.95 2/14/2012 3G-20 50103201410000 1901230 SF NA 24" NA 3.83 2/14/2012 3H-17 50103200810000 1870990 19" NA 19" NA c .> 31421 50103200940000 1880080 8" NA 15" NA 4.25 2/14/2012 3H -23A 50103202040100 1961860 6" NA 12" NA 6.38 2/14/2012 3K-102 50029233780000 2071650 SF NA 16" NA 6.8 2/14/2012 ~ ~ • • ConocoPh ~ I I ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ' ~;;~~.~`i W.,~ (~ ~' 4~ ~~ ~~~' ~ ~ ~ . ~flQ$ ~~ ~ . ~ .~ 3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. 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 annulax 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 June 26~', 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. - Please ca11 MJ Loveland or Perry I£lein at 907-659-7043, if you have any questions. Sincerel , ~ Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (10-404) Kuparuk Field Date 7/18/09 3H, 31 & 3Q PAD Well Name API # PTD # Initial top o cement VoI. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitoN sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27:' NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 ~ 7/16/2009 3H-24 501032023500 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA ~ 2.97 7/16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 191126Q SF NA 5" NA 0.9 6/30/2009 3Q-O6 500292168300 1861950 43' 6.30 26" 6/26/2009 6.8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/30/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6f26l2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30/2009 I ..¡ ~"'. .... ~ ConocoPh ill i pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 2, 2004 Mr. Tom Maunder )x j) rJ11 Alaska Oil & Gas Commission ¡J<J. r 5 'f 0 ~ 333 West ih Avenue, Suite 10 11.-\-- Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells fÌ'om the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on April 29, 2004. Dowell-Schlumberger batch-mixed Arctic Set II cement to 15.7 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, ~.~.~~s-<--~çv'(c;",_\,<'-.~ c.s...,,>\~\o ~~~~Ç:: (-~-\ . \ ~ ~ \ \ "'"> "0 "-- U ~ '::I>~>... \ ~ \ -\,-\,,(:0 Cc: oV\..~ I,~T .....ò \? ~ \l. ~ \ \ \JQ~ ~( " t~ \ \ <-- G': \\'-'~ \!"- \- \a ~~ \: \,~ +-\'--G::~ .~\ \ ~ '-.J-)Cè~~ '-.ì~\.\.,C-;,- \/'--- .\-\~- \~. G::.>¿'-Ò '-'J C ~ 'k '£- -tr1 "5 ('"\ -C!j fL-tc~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment RECEIVED MAY 042004 Alaska Oil & Gas Cons. commission Anchorage -t ConocoPhillips Alaska, Inc. -"'-' Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field April 29, 2004 WELL PTD# SERVICE CEMENT TOP VOLUME '--.(; '-.J\. t: NAME TYPE ft BBLS '~--.I. .:: \jC) \;.j~"- e. 2C-09 1842210 Producer 54.0 9 ~ \:) \ 2M-33 1960720 Producer 40.0 5 ~.~( 3H-21 1880080 Producer 34.0 5 L-\ I L\ 3H-24 1960150 Injector 25.0 3 ~: J 3H-28 1960370 Producer 20.0 4 ;) , .Cc 3H-32 2000010 Producer 10.0 2 l ¡ ':) 3K-12 1861650 Injector 48.0 10 ~,J. ~ Arctic Set 1115.7 PPG Cement II ~I\-~ 'Í'~/" - \ ~ ---'7 .r;~./ L'-> \ \ j --..¡."\ - ~ U. ,,",- "\ . \ ' * \(j~ b ~ I-Ç\- PE?'LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 June 26,2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3H-21 (188-008) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the frac treatment on the KRU well 3H-21. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney -~ Staff Engineer Phillips Drilling MM/skad RECEIVED JUN 26 2001 Alaska 011 & Gas Cons. Gommissior~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 980' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At top of productive interval 3948' FNL, 505' FEL, Sec. 35, T13N, R8E, UM At effective depth At total depth 3457' FNL, 323' FEL, Sec. 35, T13N, R8E, UM 5. Type of Well: Development ._X Exploratory _ Stratigraphic _ Service__ (asp's 498656, 6000675) (asp's 502091, 6008269) (asp's 502272, 6008758) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-21 9. Permit number / approval number 188-O08 / 10. APl number 50-103-20094 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 11346 feet Plugs (measured) 6373 feet Effective depth: measured 11004 feet Junk (measured) true vertical 6212 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 250 sx AS I 115' 115' SUR. CASING 4544' 9-5/8" 2000 sx AS III, 400 sx Class G 4620' 3084' PROD. CASING 11224' 7" 1050 sx Class G, 175 sx AS I 11300' 6352' ~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:-:~:~:~:`:~:~:~~~:~:~:.:~:~:~:~:`:~:~:.:.:.:.:~:~:~:~:~:~:~:.:.:.:.:.:~:~:~:~:~:~:~:~:.:.:.:.:.:-:~:~:~:~:~:.:.:.:.:.:~:~:~:~:~ JUN 26 2001 Packers & SSSV (type & measured depth) ,,,,,, .......... :::::::::::::::::::::::::::::::::::::::::::::::::: .:::::::.-.-..::. :-.-.:--:-: .... %>........ ..................... ................................... 13. Stimulation or cement squeeze summary .... .... , .... ,,, ,,., .... ,, . ;~;i;;;;;;;;;~-~'~;.l~.~~ ? : ~~:~~~::~~:~~~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::~~55::::::::::::::::::::::::::~~~~:~~:~::::~:::~~::~~:~~~:~~:~~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data ............ (~!l;Bb! .............................. Gas:ac~. .......................... Wa~er;Bb! .......... Cas!ng Pressure. .... Tubir~g ~mssur.e · :.: :-:.:-:.:.:.:.: :.: :.: :-:.:,:.:.:.:.:.:.: :::::::::::::::::::::::::::::::::::: :-: :.: :-: :-:.:-:.:.:.:-: :.: :.: :-: :-:.:.:.:.:.:.: :.: :.: :-:.:.:.:.:.:.: :.: :::::::::::::::::::::: :.: :-: :.:.:.: :-:.:.: :.: :.: :.: :.: :.: :. :.: :.: :..:.:.:.:.: :.: .: :..: :.: .:..: :.: · .::.: > :o. < >: >: :.. >:x >: · >: < x<< 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Michael Mooney t Title Staff Engineer Date~"_, C~.~ ~ Prepared by ~'~aroln AIIs~D~R* Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 3H-21 Event History 0~0~01 05/05/01 05/06/01 05/07/01 DRIFT TBG & TAGGED FILL @ 11083' RKB EST. 11' RAT HOLE PULLED OV F/10538' RKB LIFT POCKET EMPTY IN PROGRESS.~ [Frac-Refrac] REPLACE GLV'S W/DV'S @ 8591', 6683', 3190', RKB, SET 2.75" SV @ 10638' RKB, DESPLACED IA W/53 BBLS DIESEL, 240 BBLS SW, MADE TWO ATTEMPTS TO SET DV @ 10538' RKB,WILL TRY IN MORNING W/LIGHT WEIGHT DV, IN PROGRESS.~ [Frac-Refrac] SET DV @ 10538' RKB, PRESSURE TESTED TBG / CSG SEPARATELY TO 3000 PSI GOOD, PULLED 2.75" SV F/10638' RKB, SET 2.813" FRAC SLV @ 1803' RKB. COMPLETEI [Frac-Refrac] PUMPED REFRAC STIMULATION. DEVELOPED TSO, THEN HAD NWBSO WITH 9 PPA ON PERFS. PLACED 173M# BEHIND PIPE, 9 PPA ON PERFS (DESIGN 208M#, 9 PPA). LEFT 28M# IN WELLBORE. ~ [Frac-Refrac] 05/09/01 CLEANED FRAC SAND/FILL WITH SEAWATER J313, SLICK DIESEL, AND DIESEL GEL TO 11,172 CTM (EST. 100' OF RATHOLE) BEFORE TAGGING HARD FILL. SLOW WASH PASSES MADE OVER MANDRELS. WELL SHUT IN AND FREEZE PROTECTED W/DIESEL.~ [FCO] 05/11/01 PULLED 2.813" X 119" FRAC SLEEVE @ 1778' WLM (1803" RKB). 05/12/01 TAGGED FILL @ 11,004' RKB, REPLACED DV W/GLV @ 3191' RKB, IN PROGRESS~ [-I'ag, GEV] 05/13/01 NEW GAS LIFT DESIGN @ 6683', 9576' & OV @ 10,538' RKB, PT TBG TO 2500# HELD~ [GLV, PT Tbg-Csg] Page 1 of 1 6/25/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 76 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 980' FNL, 4997' FEL, Sec. 12, T12N, RSE, UM (asp's 498656, 6000675) 3H-21 At top of productive interval 9. Permit number / approval number 3948' FNL, 505' FEL, Sec. 35, T13N, R8E, UM (asp's 502091, 6008269) 188-008 At effective depth 10. APl number 50-103-20094 At total depth 11. Field / Pool 3457' FNL, 323' FEL, Sec. 35, T13N, R8E, UM (asp's 502272, 6008758) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 11346 feet Plugs (measured) Tagged Fill (3/18/00) @ 11080' MD. true vertical 6373 feet Effective depth: measured 11080 feet Junk (measured) true vertical 6248 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 250 Sx AS I 115' 115' SURF CSG 4544' 9-5/8" 2000 Sx AS III, & 400 G 4620' 3084' PROD CSG 11224' 7" 1050 Sx G & 175 AS I 11300' 6352' Perforation depth: measured 10774- 10814'; 10860- 10890'; 10910- 10930'; 10965- 10985'; 11010- 11050'; 11058- 11072' true vertical 6100 - 6119'; 6142 - 6157'; 6166 - 6176'; 6193 - 6203'; 6215 - 6234'; 6238 - 6244' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55, Tubing @ 10672' MD. /~ "~CL~/[/'~,D Packers& SSSV (type & measured depth) BAKER 'FHL' Packer @ 10600' MD. MD.t/~'~/r~ CAMCO 'TRDP-1A-SSA' (LOCK OUT 12/26/88) @ 1803' 0//~ ,~;.., 13. Stimulation or cement squeeze summary ""," Intervals treated (measured) (see a~ached) ~n'Ch°r~.qe' Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 377 173 43 170 Subsequent to operation 700 245 65 149 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ /~~-a,,,,--~ Title: Date Prepared Dy John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3H-21 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/3/99: MIRU & PT equipment. RIH w/perforating guns & shot 40' of perforations as follows: Added perforations: 10965 - 10985' MD 11030 - 11050' MD Used 2-1/2" HSD carriers & shot the perfs at 6 spf at 60 degree phasing. POOH w/guns. RD. 11/14/99: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations as follows: Added perforations: 11010 - 11030' MD Used 2-1/8" Enerjet carriers & shot the perfs at 4 spf at 180 degree phasing. POOH w/guns. RD. 3/18/'00: RIH & tagged fill @ 11080' MD. Returned the well to production w/gas lift and obtained a valid well test, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 31' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 982' FNL, 282' FWL, Sec 12, T12N, R8E, UM 3H-21 At top of productive interval: 9. Permit number/approval number: 1349' FSL, 507' FEL, Sec 35, T12N, R8E, UM 88-08 At effective depth: 10. APl number: 1708' FSL, 368' FEL, Sec 35, T12N, R8E, UM 50-103-20094-00 At total depth: 11. Field/Pool: 1821' FSL, 332' FEL, Sec 35, T12N, R8E, UM Kuparuk River Field ! Oil Pool 12. Present well condition summary Total Depth: measured 11281 feet Plugs (measured) None true vertical 6236 feet Effective Deptl measured 11029 feet Junk (measured) 1.5" GLV in rathole true vertical 6190 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 229 Sx PFC 115' 115' Surface 4651' 9.625" 638 Sx PFE 4630' 3120' Production 11331' 7" 204 Sx Class G 11300' 6373' Liner Perforation Depth measured 10774'-10814', 10860'-10890', 10910'-10930', 10965'-10985', 11030'-11050', 11058'-11072' true vedical 6100'-6119', 6142'-6157', 6166'-6176', 6193'-6203', 6224'-6234', 6238'-6244' Tubing (size, grode, and meosured depth) 3.5", 9.3 Ib/ft, J-55/L-80 @ 10672' Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 10600'; SSSV: Camco TRDP-1A-SSA @ 1803' 13. Stimulation or cement squeeze summary Perforated 'A' sands on 7~3/99. Intervals treated (measured) A~tct ~ora~j~ 10965'-10985', 11030'-11050' Treatment description including volumes used and final pressure Perforated using 2-1/2" HSD guns w/DP charges @ 6 spf, final pressure was 1100 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 377 173 43 1246 170 Subsequent to operation 791 442 83 1111 158 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations _X Oil _X Gas Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Production Engineering Supervisor Date ,/D/~/~r~ Form 10-404 Re~ ~88 SUBMIT IN DUPLICA,T~ ~ ,~RCO Alaska, Inc. KUPARUK RIVER UNIT ELL SERVICE REPORT 3H-21(4-1)) WELL JOB SCOPE JOB NUMBER 3H-21 PERFORATIONS-E-LINE 0702990802.1 DATE 07/03/99 DAY 1 FIELD ESTIMATE DAILY WORK PERF 10965-10985', 11030-11050' (Al SAND) OPERATION COMPLETE I SUCCESSFUL j'~ Yes I0 NOJ ~ Yes 0 No JDAILY COST IKEY PERSON SWS-VETROMILE ACCUM COST $39,552 AFC# J CC# K85174 230DS36HL $21,947 Initial Tbg IFinal Tbg I Initial IA I Final IA I Initial OA IFinal OA ITTL Size,, 1100PSII 1100PSII 1300PSII 1300PSII 1300PSII 1300PSII 3.500 UNIT NUMBER 2145 SUPERVISOR SCHUDEL IMin ID Depth 2.750" 10638 FT' DALLY SUMMARY IPERF 1°965'1°985'' 11°3°-11°5°' WITH 2 1/2" HSD' DEEP PEN' 6 SPF' 6° DEG PH' SPIRAL cHG (Al SAND)[Perf] TIME LOG ENTRY 08:30 SWS ON LOCATION, WAITING FOR SLICK LINE TO DRIFT AND TAG. 14:00 SWS MIRU 14:30 TEST TOOL ON SURFACE 14:45 CALL FOR RADIO SILENCE, PUT SIGNS OUT, HAVE SAFETY MEETING WITH HOT OIL. 15:00 ARM TOOL AND STAB ONTO WELL HEAD 15:10 PT TO 3000 15:15 RIH, W/20' 2 1/2" HSD DP 31J UJ GUN, ROLLERS, CCL, SAFE 17:25 TIE IN TO SWS CET DATED 29-APR-88 TAGGED PBTD AT 11063' 17:40 WHP = 1100 PSI, SHOT GUN, GOOD INDICATION, LOG OFF 17:50 POOH 18:30 BUMP UP, BLEED DOWN 18:40 START RIG DOWN AND RUG UP GUN 2 18:55 STAB LUB ONTO WELL HEAD 19:00 RIH, W/20' 2 1/2" HSD DP 31J UJ GUN, ROLLERS, CCL, SAFE 20:50 TIE IN 21:00 WHP = 1100 PSI, SHOT GUN, GOOD INDICATION, LOG OFF 21:05 POOH 21:50 BUMP UP, BLEED DOWN 22:00 UNSTAB LUB AND START RIG DOWN 23:00 RDMO , , i SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $20.00 $20.00 APC $100.00 $5,700.00 ARCO $0.00 $100.00 , DOWELL $0.00 $8,001.00 HALLIBURTON $1,784.00 $1,784.00 LITTLE RED $2,263.00 $2,263.00 MI FLUIDS $0.00 $500.00 SCHLUMBERGER $21,184.00 $21,184.00 TOTAL FIELD ESTIMATE $25,351.00 $39,552.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 982' FNL, 282' FWL, Sec. 12, T12N, At top of productive interval 1349' FSL, 507' FEL, Sec. 35, T13N, At effective depth 1715' FSL, 371' FEL, Sec. 35, T13N, At total depth 1821' FSL, 332' FEL, Sec. 35, T13N, R8E, UM R8E, UM R8E, UM 12. Present Well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-21 9. Permit number/approval number 88-08 10. APl number 50-103-20094 11. Field/Pool R8E, UM 1 1 346 feet 6373 feet Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 1 1 21 8 feet true vertical 631 4 feet Junk (measured) 1.5" GLV @ 11218' 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4586' 9-5/8" 11265' 7" measured 1 0774' - true vertical 10814', Cemented Measured depth True vertical depth 250 Sx AS I 1 15' 1 15' 2000 Sx AS III & 4621' 3084' 400 Sx Class G 1050 Sx Class G 1 1300' 6352' 175 Sx AS I 10860'-10890', 10910'-10930', 11058'-11072' 6100' - 6120', 6142' - 6157', 6167' - 6176', 6238' - 6245' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 10672' Packers and SSSV (type and measured depth) PKR: Baker FH @ 10600'; SSSV: Camco TRDP-1A-SSA @ i803' (Locked out) Stimulation or cement squeeze summary Fracture Stimulate 'A' and 'C' Sands on 6/6/96 RECEIVED MAR 2 0 1997 Intervals treated (measured) ~llkll0~ & ~ C01311. ~ 10774' - 10814', 10860'-10890', 10910'-10930', 11058'-11072' AltChol'a~ Treatment description including volumes used and final pressure Pumped 128.4 Mlbs of 20/40 and12/18 ceramic proppant into formation., fp was 8000 psi Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 441 349 18 1052 156 Subsequent to operation 722 461 99 1043 162 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Wells Superintendent Form 10~O4 ~Rev (~6/'~/81~ - ' ORIGINAL Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. ' .... " KUPARUK RIVER UNIT ' WELL SERVICE REPORT K1(3H.21(W4-6)) WELL JOB SCOPE JOB NUMBER 3H-21 FRAC, FRAC SUPPORT 0602961836.2 DATE DAILY WORK UNIT NUMBER 06/06/96 'A' SAND REFRAC DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 1' (~ Yes O NoI ® Yes O No DS-GALLEGOS PENR}~S~ /~'// ESTIMATE KM1175 230DS36H L $124,979 $134,709 Initial Tb.(:l Press Final Tb.cj Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ann ~ Final Outer Ann 50 PSI 0 PSI 850 PSI 500 PSII 500 PSII 500 PSI DALLY SUMMARY REFRAC'D 'A' SAND - SCREENED OUT EARLY WITH 128,428 LBS PROPPANT BEHIND PIPE (OUT OF 225,000 PLANNED). 30,153 LBS LEFT IN WELLBORE. 10 PPA PROPPANT BEHIND PIPE AND IN WELLBORE. USED 10,694 LBS 20/40 AND 147,887 LBS 12/18 PROPPANT. TIME 06:30 08:00 09:05 09:20 10:30 10:55 12:20 12:45 12:50 13:20 13:30 16:30 LOG ENTRY MIRU DOWELL PUMPING EQUIP AND APC SUPPORT EQUIP. HOLD PRE-JOB SAFETY MEETING, WORK UP & QC FLUIDS, PRIME PUMPING EQUIPMENT, PRESSURE TEST TO 9,000 PSI. PRESSURE UP 7" ANNULUS TO 3,000 PSI. START PUMPING CONDITIONING STAGE. FINISH CONDITIONING STAGE, S/D. FFP = 4,760 PSI, ISIP = 1,915 PSI. CONDUCT PULSE TESTING. START PUMPING DATAFRAC. FINISH DATAFRAC, S/D. FFP = 4,216 PSI, ISlP = 1,930 PSI. MONITOR PRESSURES. START FRAC - PUMP PAD FINISH PAD, START 20/40 PROPPANT @ 2 PPA. SWITCH TO 12/18 PROPPANT @ 2 pPA, RAMP UP TO 10 PPA, THEN PLATEAU @ 10 PPA. FLUID SAMPLES STOPPED CROSS-LINKING .NEAR END OF RAMP-UP TO 10 PPA. SCREEN OUT - S/D W/937 BBLS OF FRAC AWAY (OUT OF PLANNED 1,249 BBLS). 12/18 PROPPANT @ 10 PPA IN WELLBORE FROM SURFACE TO PERFS. 128,428 LBS PROPPANT BEHIND PIPE, 30,153 LBS PROPPANT LEFT IN WELLBORE. CLEAR PUMPS AND LINES. RDMO DOWELL EQUIP. WELL SECURED, EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $529.00 APC $1,300.00 $3,700.00 ARCO $276.00 $276.00 DOWELL $118,686.00 $118,686.00 HAI~LIBURTON $0.00 $3,801.00 LITTLE RED $4,717.00 $4,717.00 PETREDAT $0.00 $3,000.00 TOTAL FIELD ESTIMATE $124,979.00 $134,709.00 ARCO Alaska, Inc.,. Date: January 13, 1989 Transmittal #: 7408 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and retUrn one signed copy of this transmittal. ~3A-01 '""-~ 3A-01 '--,.2W-01 -~-- 2X-14 '--3K-06 -,.-3K-06 ---, 3H-21 "-"3F-16 ~--~,3 K- 0 6 ~ 2Z-01 Kuparuk Fluid Level Report (2:15) I - 0 5- 8 9 Casing Kupaurk Fluid Level Report (1015) 1-05-89 Casing Kuparuk Fluid Level Report I - 0 5 - 8 9 Casing Kuparuk Fluid Level Report I - 0 5 - 8 9 Casing Kuparuk Fluid Level Report I - 0 5 - 8 9 Casing Kuparuk Fluid Level Report I 2-1 3- 8 8 Casing Kuparuk Fluid Level Report I 2 - 1 3 - 8 8 Casing Kuparuk Fluid Level Report 1 2-1 9 - 8 8 Tubing Kuparuk Fluid Level Report 12-17-88 Casing Kuapruk Fluid Level Report 1 2-1 8 - 8 8 Tubing Receipt Acknowledged: ............... : a qit & cas DISTRIBUTION: D&M State of Alaska Chevron SAPC · . Unocal Mobil STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised to reflect added perforations Classification of Service Well 1. Status of Well OIL ~. GAS [-] SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-08 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 103-20094 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3H-21 11. Field and Pool Kuparuk River Field Location of well at surface 982' FNL, 282' FWL, Seco12, T12N, R8E, UM At Top Producing Interval 1349' FSL, 507' FEL, 5ec.35, T13N, R8E, UM At Total Depth 1821' FSL, 332' FEL, Sec.35, T13N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 76' I ADL 25523 ALK 2559 12. Date Spudded 113. DateT.d. Reached I 14. Date Comp.,Susp. or Aband. / 15. Water Depth, if offshore 116. No. of Completions 02/03/88 I 02/15/88 I O'~Z~'8~ ~///'$' / X/~¢~ N/A feet MSL I 1 ,7. Tota, Depth (MD+TVD) 1,8. P,u, Sack Depth(UD+TVD)/,,. Directiona, Survey/ I 20. Depth where SSSV set I 21. Thickness of Permafrost 11346'MD, 6373'TVp 11218'MD, 6314'TVpYES [] NO [] [ 1803 feet MD I 1600' (approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/Cal , CET, (;CT 23. CASING, LINER AND CEMENTING RECORD ~/T. PER FT. GRADE CASING SIZE 16" 62.5# H-40 9-5/8" 36.0# J-55 7" J-55 TOP SETTING DEPTH MD BOTTOM Surf 115 Surf 4621 Surf 11300 26.0# HOLE SIZE 24" 12-1/L ,, 8-1/2" CEMENTING RECORD 250 sx AS I 2000 sx AS III & 40( 1050 sx Class G & 1; AMOUNT PULLED SX Cl aSS G 5 sx AS I 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 10672 ' 10600 ' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Perforated w/6 spf, 30° phasing 10774 ' -10804 'MD/6100 ' -6115 'TVD Perforated w/12 spf, 60° phasing 10804 ' -10814 'MD/6115 ' -6120 'TVD Perforated w/8 spf 10910 ' -10930 ' MD/6167 ' -6176 'TVD Perforated w/4 spf, 120° phasing 11058 ' -11 072 ' MD/R2RR ' -62/~ ~; 'TVD , iDEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED lAN U'~ iq,qO S.e att~ch~.d Acl~lend,,m dat~_d 11/17/RR_ [ for fracture da~a. Date Fi~Sroduction I Method of Operation {Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Drilled RR 2/17/88. Perforated well & tubing run 5/1/88. Fractured well 5/29/88. Added perforations 11/15/88. WC4/80: DAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. '". 30. ' - GEOLOGIc MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRuE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10772' 6099' N/A Base Kuparuk C 10818' 6122' Top Kuparuk A 10842' 6133' Base Kuparuk A 11123' 6269' · 31. LIST OF ATTACHMENTS Addendum (dated 11/17/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . Area Drilling Engineer ;3, Signed ~'~y T,tle__ Dr"__ing Engi~ Date [ z/~7/~,'~ 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 ADDENDUM WELL: 5117188 5/29188 7/18/88 8/19/88 8/25/88 8/26/88 8/27/88 3H-21 RU GSL equip. Tst Ins to 3000 psi. Mx & heat 21 bbls diesel + 5% Musol @ 145° F. Pmp 21 bbls 5% Musol/diesel & .75 BPM, 2900 psi. Displ w/106 bbls, 145°F diesel @ .75 BPM, 2900 psi. Did not witness drop in press as Musol entered perfs. RD GSL. Notified Production. Frac Kuparuk "A" sand perfs 11,058'-11,072' in eight stages per procedure dated 5/10/88 as follows: Stage 1: 200 bbls gelled diesel @ 25 BPM, 6550'-6200 psi Stage 2: 652 bbls gelled diesel @ 25 BPM, 5100-4450 psi Stage 3: 61 bbls gelled diesel 16/20, 2 ppg @ 25 B?M, 4450-4420 psi Stage 4: 151 bbls gelled diesel, 16/20, 4 ppg @ 25 BPM, 4420-5750 psi Stage 5: 91 bbls gelled diesel, 16/20, 6 ppg @ 25 BPM, 5750-7200 psi Sanded out. No flush in tbg. RD. Fluid to Recover: Sand In Zone: Sand in Csg: Avg Press: 1100 bbls 23,200# 21,000# 5800 psi RU CTU. Press test and RIH to 11,020'; no sand tagged. CBU. Well flow w/ 400 psi on choke @ 200 bbl/hr. No sand across btm perfs. RU CTU, pressure tst to 4000 psi. GIH to 6000', break circ .5 BPM. GIH to 10,538'; unable to wrk past GLM, POOH. RIH w/2.5", GIH, stop @ TT. RU BJ, clean out well bsh'g in 50' bits. CBU. Switch to cln diesel, POOH. Secure well. RU Gearhart. Perf well f/10,910'-10,930' MD @ 8 spf. RU hot oil unit & pmp 20 bbls diesel w/10% Musol. Displ thru A2 sand perfs w/100 bbls diesel. Secure well. Attempt frac Kuparuk A2 sands per procedure dated 6/27/88. Pmp'd ramp frac slightly behind schedule w/steady inc'g uniform wt. Pressure started to increase uniformly w/lst stage thru perfs and pressure spiked w/total screen out at end of Stage 4 thru perfs. A D D E N D U M (cont'd) WELL: 3H-21 8/30/88 10/17/88 10/18/88 10/19/88 11/02/88 11/04/88 11/12/88 RU CTU, tst ins to 4000 psi. RIH, tag fill @ 7336' CTM. Wsh 7336' to TT w/gel diesel @ .5 BPM, 300 scf N~/bbl. Wsh f/TT to 11,205' CTM w/gel diesel @ 1BPM, 306 scf N2/bbl. CBU w/gel diesel Displ CTU & partial tbg volume to diesel while PO~. Secure well. RU CTU. Tst BOPE & coil to 4000 psi. RIH to 600'; broke bearing on injector head. POOH & replace bearing. RIH w/CT pmp'g @ min rate of .3 BPM to 10,600'. Inc fluid rate to 1.75 BPM & start N. @ 350 scf/min. CO to PBTD @ 11,172' CTM while holding ~50-350 psi back pressure. Inc N2 rate to 600 scf/min & circ 100 bbls gel/diesel while recip f/PBTD to TT. Flush w/clean diesel while POOH. RD & secure well. TT @ 10,672'. CTU cleanout to 11,172'. RIH w/tl string; tl sliding down hole very slowly. POOH. RIH w/1-3/4" swage to 10,720'; still very slow from 3000' down. RU hot oiler to pmp tls past 4500' to 6000'. POOH, RD. Production to flow well overnight. MIRU S/L unit, tst lubr to 2500 psi; OK. RIH w/1-7/8" tl string & 2-1/8" stem w/1-3/4" swage to 10,032'; appeared to be pushing proppant ahead @ this point. POOH, RD S/L. Secure well. Production to continue flowing. RU CTU, tst lubr; OK. RIH to 6200', start gel/diesel @ .5 BPM holding 150-350 psi back pressure. RIH to 10,560', pmp No @ 400 scf/min. Tag fill @ 11,125', wsh sand to 11,190+ CTM. Increase N2 to 600 scf/min. POOH to 10,000'. RIH, increase No to 1200 scf. POOH to 10,000'. RIH, pmp additional 50 bbls gel w/o N2. Displ w/diesel while POOH. Secure well. RU Otis S/L unit. RIH; tls stopped @ 3024' WLM. POOH; tls covered w/Carbolite propant. RIH, tls stopped @ 3024' WLM, POOH; tls covered w/Carbolite propant. (Fill tagged @ 3024' WLM). RU S/L unit, tst lubr to 2500 psi; OK. RIH w/gauge ring; tls stopped @ 9900', POOH. Tls covered w/crushed Carbolite. Secure well. A D D E N D U M (cont'd) WELL: 3H-21 11/15/88 RU E-line, tst lubr to 2500 psi. Perf "C" sands f/10,774'-10,804' @ 6 spf, 30° phasing & 10,804'-10,814' w/12 spf @ 60° phasing. Attempt to perf A-3; unable to get below 10,865'. Secure well. Drilling Supervisor Date ARCO Alaska, Inc. Date: December 15, 1988 Transmittal #: 7375 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted hereWith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3 H- 1 4 Kuparuk Fluid Level Report '1 2- 1 0- 8 8 Casing ~ 3 H- 1 5 Kuparuk Fluid Level Report I 2- 0 9 - 8 8 Tubing · 3 H- 1 7 Kuparuk Fluid Level Report I 2 - 0 9 - 8 8 Casing · 3 M - 1 9 Kuparuk Fluid Level Report I 2 - 0 9 - 8 8 Casing · 3 H- 0 6 Kuparuk Fluid Level Report 1 2- 0 8 - 8 8 Tubing ' 3 H- 0 9 Kuparuk Fluid Level Report I 2- 1 3 - 8 8 Casing · 3 H- 21 Kuparuk Fluid Level Report I 2 - 1 3 - 8 8 Casing · 3 K- 0 6 Kupaurk Fluid Level Report 1 2 - 1 2 - 8 8 Casing ~, 3 H - 21 Kuparuk Fluid Level Report 1 2- 1 2 - 8 8 Casing · 1 Y- 0 6 Kuparuk Fluid Level Report I 2- 1 2 - 8 8 Casing ~ 30-07 BHP Report 1 1-27-88 Receipt Acknowledged: Alaska 0il & C~c Cch:. Ccmrniss~or~ Date: ............ DISTRIBUTION; State of Alaska D&M Unocal SAPC Chevron Mobil ' STATE OF ALASKA .~~;~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILx] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 88-08 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20094 4. Location of well at surface 9. Unit or Lease Name 982' FNL, 282' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1349' FSL, 507' FEL, Sec.35, T13N, R8E, UM 3H-21 At Total Depth 11. Field and Pool 1821' FSL, 332' FEL, Sec.35, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 76'JADL 25523 ALK 2559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions I 02/03/88 ~ _,~"/~/~ ,~f~' N/A feet MSL 1 02/15/88 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11346'MD, 6373'TVD 11218'MD, 6314'TVD YES [~ NO [] 1803 feetMD 1600' (approx) 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR/Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 250 sx AS I 9-5/8" 36.0# J-55 Surf 4621' 12-1/4" 2000 sx AS Ill & 400 sx Class G 7" 26.0# J-55 Surf 11300' 8-1/2" 1050 sx Class G & 175 ,s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 120° phasing 3-1/2" 10672' 10600' 11058'-11072'MD 6238'-6245'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addend~m dated 6/1/88. for fracture da~ a. 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS~OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED JUN 2 3 1988 Alaska 011 & Gas Cons. Commission *Note: Drilled RR 2/17/88. Perforated well & tubing run 5/1/88. Anchorage Fractured well 5/29/88. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC4/80:DANi '...~ 30. ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTI- GOR, and time of each phase. Top Kuparuk C 10772 ' 6099' N/A Base Kuparuk C 10818' 6122' Top Kuparuk A 10842' 6133' Base Kuparuk A 11123' 6269' 31. LIST OF ATTACHMENTS Addendum (dated 6/1/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge // - INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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". ADDENDUM WELL: 5/17/88 5~29/88 3H-21 RU GSL equip. Tst ins to 3000 psi. Mx & heat 21 bbls diesel + 5% Musol @ 145° F. ?mp 21 bbls 5% Musol/diesel & .75 BPM, 2900 psi. Displ w/lO6 bbls, 145°F diesel @ .75 BPM, 2900 psi. Did not witness drop in press as Musol entered perfs. RD GSL. Notified Production. Frac Kuparuk "A" sand perfs 11,058'-11,072' in eight stages per procedure dated 5/10/88 as follows: Stage 1: 200 bbls gelled diesel @ 25 BPM, 6550'-6200 psi Stage 2: 652 bbls gelled diesel @ 25 BPM, 5100-4450 psi Stage 3: 61 bbls gelled diesel 16/20, 2 ppg @ 25 BPM, 4450-4420 psi Stage 4: 151 bbls gelled diesel, 16/20, 4 ppg @ 25 BPM, 4420-5750 psi Stage 5: 91 bbls gelled diesel, 16/20, 6 ppg @ 25 BPM, 5750-7200 psi Sanded out. No flush in tbg. RD. Fluid to Recover: Sand In Zone: Sand in Csg: Avg Press: 1100 bbls 23,20O# 21,000# 5800 psi ' Superx~or RECEIVED JUN 2 3 1988 Alaska Oil & Gas Cons. Commission Anchorage Date SUB.SURFACE DIRECTIONAL SURVEY [~] UIDANCE F~ ONTINUOUS r-fl OOL Company ARCO ALASKA~ INC. Well Name 3H-21 (982' FNL,282' FW.L,SEC..12,T12N~R8E,UM) Field/Location, KU.PARUK.~ . NORTH SLOP. E.,. ALASKA .. Job Reference No. 72737 Locj:ed By: SARBER Date 30-APR-88 Computed By: KOHRING GCT DIReCTiONAL SURVEY CUSTOMER LISTING ARCO ALASKA, INC, 3H'2i KUPANUK NORTH SLOPE, ALASKA SURVEY DATE: 30-APR-B8 ENGINEER: 5ARBER METHODS OF CONPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HL)RIZ. DIST. PROOECTED ONTO A TARGET AZlMLITH OF NORTH 23 DEG 14 MIN EAST ARCO ALASKA~ INC, 3H'21 KUPARUK NORTH SLOPE, AbASKA £UMPUTA~ION DATE: PAGE DATE UF SURV'E~ 30-APR-8~ KEbI, Y ~USHING EG~VATiUN~ 76,00 FT ENGZNgEA{ SARBgR INTERPObATED VALUES FOR EV£N !00 FEET OF M£AGURED DEPTH TRLig SUB-SBA COURSE MEASURED VERTICAL VBRTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN PEG MIN 0 O0 100 O0 2OO O0 300 O0 400 O0 500 O0 600 O0 7OO O0 8O0 O0 900 O0 0,00 -76 O0 0 0 [4 0 0 E 100,05 24:05 O 8 N 67 44 W 200,05 124,05 0 13 N 9 44 W ~00 05 224,05 0 26 N 29 57 E 400:04 324.04 1 27 N 26 15 g 499,78 423,78 6 14 N 22 3 E 598 69 522.69 10 52 N 18 59 E 696111 620,11 14 53 N 19 29 E 791.99 715.99 17 47 N 20 9 E 886,5~ ~10.58 19 59 N 24 10 ti 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 979.7~ 903.78 22 25 O0 1.071 O~ 995.0~ 25 57 O0 1159~80 1083'80 28 26 O0 1246.72 1170,72 31 13 O0 1330.67 1254.67 34 26 O0 1412.10 1330.10 36 52 O0 1490.99 1414,99 38 42 O0 1567'04 1491,04 42 10 O0 1639.64 1563.64 44 37 O0 1709,25 lb33.25 47 ]7 VERTICAL DOGLEG RECTANGUbAR COORDINATES HORIZ, DEPARTURE S~CTIOU SEVERITY NORTH/S~UTH EAST/W~ST DIST, AZIMUTH FEET DEG/IO0 FEET f'EET FEET DEG MIN 2000 O0 1773.9~ 1697.98 51 21 2100 O0 1834.9'! 1758.97 53 24 2200 2300 2400 25OO 26OO 27OO 28OO 29OO O0 1893.39 1817.39 54 40 O0 1951.17 1875,17 55 15 O0 2005.45 1929.45 58 31 O0 2058.1~ 1982.18 57 49 O0 2112 09 2036.09 56 41 O0 2168132 2092,32 55 22 O0 2225,51 2149,51 54 49 O0 2281,96 2205,96 57 !8 0.00 0,00 O,OO N 0,00 '0,08 0.00 0,04 N 0.29 0.10 0,35 0,30 N 0,44 0.68 0.29 0,80 N 0,29 1,98 2,87 2,02 N 0,31 8,70 3,43 8,11 N 3,01 23.15 5 88 21,73 N 8.07 45 55 ,79 42,98 N 15,3U 73:92 3,32 b9,7b N 24,91 106,31 2,97 99,75 N 37,19 3000 00 2332 14 3100 O0 2379:22 3200 330O 340O 350O 360O 3700 3800 3900 2256.14 61 46 2303.22 61 36 O0 2427,18 2351.18 61 16 O0 2475.19 2399.19 61 22 O0 2522 96 244b.96 61 31 O0 2570~38 2494.38 61 59 O0 2616'90 2540.90 62 26 O0 26~3,09 2587.09 ~2 30 O0 2709,08 2633.08 62 41 O0 2754.65 2578.65 63 4 N 25 1E 142,53 N 24 20 E 183,26 N 22 28 E 229,36 N 23 5b g 278,79 N 26 51E 333.04 N 26 42 E $90,95 N 25 57 E 452.30 N 27 4 E 517,10 N 25 37 g 585,75 N 25 40 E 557,47 i~ 25 25 g 733.b0 N 23 4 E 812.82 a 21 31E 893.95 a 22 45 E 975.55 a 22 54 E 1059'51 N 22 38 E 1144.48 h 22 34 E 1228,59 ~ 22 52 E 1311,39 N 23 15 E 1393,41 h 23 4 E 1475.94 N 22 19 E 1562,39 N 22 lO E lb50,61 N 21 53 E 1738.34 N 21 50 E 1826.03 a 22 1 E 1913.86 N 22 20 E 2001.88 N 22 33 E 2090.40 N 22 44 E 2*79.09 N 22 44 E 2267.88 N 22 33 E 2356,89 0,00 N 0 0 E 0 29 N 82 43 W 0 54 N 55 54 W 0 91 N 18 36 W 2 04 N 8 5~ ,E 8,71 N 20 1 23,18 N 20 2~ 45,65 N 19 41E 74,05 N 19 39 E 106,43 N 20 27 E 2.47 4,19 1,49 4,05 1,89 4,23 2,76 2,80 2,23 4,58 132.60 N 52,44 E 142 59 N 21 34 g 169.62 N b9,47 E 183:29 N 22 16 E 211,93 N 87,7b E 229,38 N 22 29 E 257,47 m 106,99 E 278 81 N 22 33 E 306 40 N 1~0 51 E 333 04 N 23 '4 E 358 1~ t~ 156~70 E 390 9b N 23 37 E .413 2b N 1~3,9~ E 452 34 N 23 b9 E 471 3~ N 212,86 E 517 20 ~ 24 18 E 532 9~ N 243,44 E 585,90 N 2% 33 E 597 7b N 274,2U E 657,6~ N 24 38 E 2.44 3,33 1.39 3 36 0139' 0 77 2 27 0,33 0,41 5,28 656,42 N 307.31E 733,85 N 24 45 E 738,60 N 339,97 E 813,09 N 24 42 E 813,91N 3'/0,21E 894,15 N 24 27 E 889,44 N 401,13 E 975,71 N 24 16 E 966,82 N 433,74 E 1059,65 N 24 9 E 1045.10 N 456 77 ~ 1144,~0 N 24 ' ~ 1122,90 N 499:04 ~ 1228.79 N 23 [ 1199,18 N 530'97 E 1311,47 N 23 5~ 1274.69 N 553,09 E 1393.49 N 23 50 E 1350,4~ N 595,68 B 1476.02 N 23 48 E 0,83 0,11 0,42 0,20 0,84 0.16 0,40 0,20 0,54 1430,2J N 1511,91N 1593,2b N 1674,68 N 1756 19 N 1837 71N 1919 53.N 2001 40 N 2083 21 N 2165 42 N 29.06 E 1562.46 N 23 44 E 62.40 E 1650.65 N 23 39 E 95,29 E 1738,37 N 23 34 E 27,94 g 1826,05 N 23 29 E b0,72 E 1913,87 N 23 25 E 93,95 E 200~.89 N 23 21E 827,77 ~ 2090,40 N 23 19 E 851,87 E 2179.09 N 23 17 E 896,24 ~ 2267,88 N 23 16 E 930.54 ~ 2356,89 N 23 15 E ARCO ALASKA, INC, 3H-21 KUPARUK NORTH ~LOPE, ALASKA COMPUTATION DATE: 10-MA¥-88 PAGE 2 DATE OF ~URV'E¥= 30-APR-8~ KELLY BUSHING ELEVATION: 76,00 FT ENGINEER= 8ARBER INTERPOLATE;D VALUES FOR EVEN !0(,) FEET OF MEASURED DEPTH TRUE SUB-flEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATE~ HORIZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/~OUTH EAST/~EMT UIST, AZIMUTH DEPTH DEPTH DEPTH DEG 4000 O0 2800 O0 2724,00 62 36 4100 O0 2846]29 2770.29 62 26 4200 00 2892.30 2816 30 62 45 4300 00 2938.02 2862:02 62 42 4400 00 2983.74 2907,74 63 3 4500 O0 3029.02 2953.02 63 8 4600 O0 3074,1t 2998,16 63 1 4700 O0 3119.63 3043.63 63 5 4800 O0 3165.25 3089.25 62 31 4900,00 3211,82 3135.82 61 59 5000 O0 3258 47 3182.47 62 40 5100 O0 3303 90 3227.96 63 29 5200 53OO 540O 5500 5600 5700 5800 5900 O0 3347 27 3271,27 64 57 O0 3390 32 3314.32 64 12 O0 3433 57 3357,57 64 35 00 3476 12 3400,12 65 3 O0 3518.02 3442.02 65 22 O0 3559.42 3483,42 b5 41 O0 3600.36 3524,36 65 56 O0 3642,11 3566,11 64 8 6000 00 3687,95 3611,95 61 48 6100 00 3736 18 3786~13 3710,13 59 56 6200 6300 6400 6500 6600 6700 6800 6900 3660,18 60 23 00 00 3836,18 3760,18 60 0 00 3886,09 3810,09 b0 3 O0 3935.95 3859.95 60 3 O0 3985,91 3909,91 60 12 O0 4034,56 3958,65 bl 9 O0 4082,98 4006,98 61 2 00 4131,56 4055.56 60 51 7000 00 4180,31 4104,31 bO 46 7100 00 4229 2b 4153,26 60 34 7200 O0 4278:2b 4202.26 60 53 7300 O0 4327.03 4251.03 60 48 7400 O0 4375.76 4299.76 60 49 7500 O0 4424.49 4348.49 60 48 7600 O0 4473.27 4397.27 60 58 7700 00 4521 38 4445.38 61 26 7800 O0 4569115 4493.15 61 39 7900.00 4616.84 4540.84 61 25 DEG ~IN FEEl' OEG/IO0 f'EET FEET N 24 8 E 2446,01 N 25 12 E 2534,61 N 25 11E 2623,34 N 25 20 E 2712,22 N 25 17 g 2801,10 N 25 16 E 2890.20 N 25 1.1 E 2979.38 N 25 10 E 3068.40 N 25 13 E 3157,33 N 25 21 E 3245.77 N 25 28 E 3334,15 N 26 7 g 3423,12 N 26 50 E 3513,10 N 27 13 g 3603,16 N 27 25 E 3693,09 N 27 29 E 3783,34 N 27 30 E 3873.89 N 27 30 E 3964 66 N 27 36 E 4055:64 N 27 11E 4146.26 N 26 45 E 4234.94 N 24 31E 4322.43 N 22 54 E 4409.06 N 22 24 E 4495.63 N 22 20 E 4582.27 N 22 23 E 4668.94 N 22 44 E 4755.56 N 24 18 E 4842.87 N 24 21E 4930.40 N 24 23 E 5017.79 N 24 27 E 5105.09 ~ 24 36 E 5192.26 N 24 45 E 5279,4! N 24 46 E 5366.68 N 24 42 E 5453.97 N 24 22 E 5541.27 N 23 59 E 562M.55 N 2] 45 E 5716.21 N 23 30 E 5804.07 N 23 24 E 5891.96 FEET DEG NIN 3.22 0,37 0.29 0 8 0,61 0,78 0,17 0.74 0,52 2247.42 N 965 43 E 2446 O1 N 23 14 E 2327 80 N 1002 80 E 2534 2408:14 N 1040 60 E 2623 2488:57 a 1078 56 ~ 2712 2568 95 N 1116 62 E 2801 2649.5~ N 1154'70 f 2890 27~0,2~ N 1192 75 E 2979 2810,88 N 61 N 23 18 E 35 N 23 22 E 24 N 23 25 E 24 N 23 3 ~ 44 N 23 3~ , 1230,64 E 3068 48 N 23 38 E 2891,40 N 1268,53 E 3157 43 N 23 41E 2971,42 a 1306,33 E 3245.89 N 23 43 E I 61 2~17 1.20 0,25 0,39 0,36 0.39 0.27 0,10 3,52 305~!30 N 1344i30 E 3334,30 N 23 46 E 313 50 N 1382 90 E 3423,31 N 23 49 E 321 17 N 1423 20 E 3513,34 N 23 53 E 3292,58 a 1464 2! E 3603,47 N 23 58 E 5372,68 N 1505.59 E 3693,48 N 24 3 E 3452'98 N 1547,31E 3783,82 N 2% 8 E 3533'52 N 1589.25 E 3874,47 N 24 12 E 3614'26 N 1631.28 E 3965,35 N 24 17 E 3695 15 N 1673.49 E 4056,44 N 24 21E 3775:79 N 1715.36 E 4147.17 N 24 25 E ~ 0.53 3 15 0 6O 0 14 0 42 0 25 1,77 0,41 0.23 0,13 3855 00 N 1755,65.E 4235 95 N 24 29 E 3933 81 N 1793 86 E 4323 51 N 24 30 E 4013 24 N 1828143 E 44~0 13 N 24 29 E 4093 111 N 186~.73 ~ 4496 6~ N 24 2~ E 4173 28 N 1894.72 E 4583 2b N 24 25 E 4253.45 N 1927.69 g ,669.8~ N 24 4333,4~ N 1960.84 E 4756.47 N 24 ; 4413,49 N ~995,79 E ~843.77 N 24 ~ 4493.25 N 2031.87 E 4931,31 N 24 lq E 4572.8~ N 2067,94 E 5018,72 N 24 20 E 0,24 0,26 0,29 0,21 0.22 0 57 0:15 0.45 0.62 0,05 4652,38 N 2104,04 E 5106,04 i~ 24 20 E 4731,70 N 2140,24 E 5193,23 N 24 20 E 4810,92 N 2176,64 E 5280,40 N 2~ 20 E 4890.19 a 2213,20 E 5367.71 N 24 21 E 4969.4~ N 2249.79 E 5455.02 N 24 21 E 5048.9! N 2286.07 E 5542.35 N 24 21E 5128,57 N 2321,77 E 5629.64 N 24 21E 5208.74 N 2357.24 E 5717.30 N 24 20 E 52U9.25 N 2392.45 E 5805.16 N 24 20 E 5369.87 N 2427.42 E 5893.0~ N 24 19 E ARCO ALASKA, 1NC, 3H-21 KUPARUK NORTH SLOPE, AbASKA COMPUTATION DATE: 10-MA¥-88 PAGE DATg OF SURVEY: 30-APR-a~ KELLY BUSHING EGEVATION: '76,00 FT ENGINEER: ~ARBER INTERPOL, ATED YAL, Ui~$ FOR EVEN 100 FEET' OF MEASURED DEPTH TRUE SUB-6EA COURSE MEASURED VERTICAb VERTICAL DEVIATION AZIMUTH VERTICAL DOGG~G RECTANGULAR COORDINATES HORIZ, DEPARTUR'E SECTION SEVERITY NORTH/$OUTH EAS~li/WEIST DI~T, AZIMUTM FEET DEG/IO0 FEET DEG MIN DEPTH DEPTH DEPXH DEG MIN 8000 O0 4555.32 4589,32 60 20 8100 O0 4715,25 4639,25 59 57 4590,11 8200 8300 8400 8500 8600 8700 8800 89O0 O0 4756,11 58 43 O0 4818,35 4742,36 58 25 O0 4870,69 4794,69 58 25 O0 4923,00 4847,06 58 26 00 4975,37 4899,]7 58 29 O0 5027,57 4951,57 58 37 O0 5079,53 500J,53 58 42 O0 5131,25 5055,25 58 47 9000 O0 5183,39 5107.39 58 32 9100 O0 5235,60 5159,60 58 29 9200 9]00 9400 950O 9600 9700 9800 9900 O0 5288,11 5212,11 58 21 O0 5340.31 5264,31 58 33 O0 5392,34 531b,34 58 48 O0 5444 02 5368,02 58 53 O0 5495:49 5419.49 59 4 O0 5546,92 5470,92 58 5b O0 5598,70 5522,70 58 47 00 5650,66 5574.66 58 25 10000.00 5703,10 5027,10 58 lB 10100.00 5755,53 5579,53 58 22 10200°00 5807,90 5731.90 58 35 10300.00 5859,85 5783,85 58 50 10400,00 5911,52 58~b,52 58 59 10500 00 5962,7~ 588~.78 59 20 10600:00 b013,41 5937,~1 59 50 10700,00 6053,35 5987,35 60 18 10800,00 6112,72 0035,72 bO 3~ 10900,00 61~1,~2 6085,82 60 43 000 100 11200 11300 11346 O0 6210,2~ 6134,20 61 lb O0 6257.91 6181,91 bi 32 O0 6305,06 6229,06 52 3 O0 6351,92 6275,92 62 3 O0 6373,48 6297.48 52 3 N 23 57 E 5979,42 N 25 5 E 6066,03 N 2b 22 E b152,05 N 26 39 ~: 6237,16 N 26 ]b E 6322,23 N 26 28 E 6407,28 N 26 lb E 6492,38 N 26 13 E 6577,56 N 25 56 E 6662,88 N 25 59 E 6748,~8 N 25 58 f; b833,bl N 25 50 g 6918,80 N 25 3b g 7003,82 N 25 18 E 7089,05 N 24 5~ E 7174,41 N 24 34 E 7260,00 N 24 lb E 7345,71 N 23 59 E 7431,47 N 23 44 E 7517,00 N 23 18 E 7602,44 N 23 I E 7687,5g N 22 40 E 7772.74 N 22 12 E 7857.93 N 21 53 g 7943.35 ~ 21 33 E 8028,94 ~ 2~ 2~ E 8114,76 h 21 4 E 8200,96 N 20 52 E 8287,52 N 20 42 E 8374,40 N 20 30 E 8461,42 N 20 25 E 8548,84 N 20 21 g 8535,62 N 20 e E 8724,68 a 20 b E 8812,89 ~ 20 b E 8853,47 2,17 0,74 1,3~ 0,50 0.12 0,14 O,Oj 0,45 0,39 i,26 0,19 0 64 0:47 0,77 o 33 0:46 0,23 0.33 0,54 0 3u 0:47 0,79 0,27 0,40 0,35 0,60 1,22 0,87 0,84 0,40 1,lb 0,00 0,00 0,00 FEET FEET 5450,05 N 2462,33 E 5980,48 N 24 18 E 5528,81N 2498 45 E 60~7,13 N 24 19 E 5606,41N 2535:75 E 6153,20 N 24 20 E 5682,6~ N 2573,90 E 6238,39 N 24 22 E 5758'83 N 2612,11E 6323,55 N 24 23 E 5835'0~ N 2650,19 E 6408,67 N 24 2r ~ 5911,39 N 2688,06 E 6493,85 N 2~ 2', 5987,90 N 2725,75 E 6579,11 N 24 28 E ~064,60 h 2763,39 E 5654,51 N 24 29 E b141,5~ N 28~0.78 E 6750,08 N 24 30 E .. 5218,27 N 2838 22 E 6835,38 N 24 32 E ~294,99 N 2875 45 E 6920,64 N 24 33 E 5371,65 N 2912 40 E 7005,72 N 24 33 E ,01 6448,65 N 2949 11 E 7091 N 24 34 E ~526,01N 2985 31E 7176 41 N 24 34 E ~603,77 N 3021 13 E 7252:03 N 24 35 E ~681,83 N 3056 57 E 7347,75 N 24 34 E 6760.11N 3091,63 E 7433,52 N 24 34 E 5838.34 N 3126.23 E 7519,05 N 24 34 E 5916,65 N 3150,38 E 7604,48 N 24 33 E ~994.93 ~ 3193,88 E 7689,60 N 24 32 E 7073,40 N 3226,96 E 7774,72 N 24 31E 7152,15 a 3259,47 E 7859,85 N 24 30 E 7231,35 N 3291,54 E 7945,23 N 24 28 E 7310,88 N 3323,24 E 8030,75 N 24 26 E 7390,79 N 3354,63 E 8115,49 N 24 2~ E 7471,19 N 3385,87 E 8202,bl N 24 2 7552,09 N 3416,85 E 8289,0~ N 24 2~ 7633 3~ N 3447,72 E 8375,88 N 24 18 E 7714:93 N 3478,35 E 8462,81 N 2~ 16 E 7796,92 N 3508,98 E 8550,15 N 24 13 E 7879,30 N 3539,61 E 8637,83 N ~4 Il E 7962,08 N 3570,01 E 8725,~0 N 24 9 E 8045 04 N 3600,37 E 8813,9~ N 24 6 E 8083:20 N 3614,34 E 8854,47 N 24 5 E ARCO ALASKA, 1NC. 3H-21 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: PAGE 4 [)ATE OF SURVEY: 30-APR-SB KELLY BU~H1NG ELE'VATION~ ~76.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET UF ~EASURgP DEPTR TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZI~iU'rH DEPTH DEPTH DEPTH DEG MiN DEG 0.00 0 O0 '76.00 0 0 1000.00 979:78 903,78 22 25 2000.00 1773,98 1697.98 51 21 3000.00 2332.14 2256.14 61 46 4000 O0 2800.00 2724.00 62 36 5000 O0 325~.47 3182,47 62 40 6000 O0 3§87.95 3611.95 61 48 7000 O0 4180 31 4104,31 60 45 8000 O0 4665~32 45~9,32 60 20 9000 O0 51:83,39 5107,39 58 32 10000,00 5703 10 5627,10 58 18 11000.00 6210:2~ 6134.20 61 16 11346.00 6373.40 6297,48 62 3 VERTICAL DOGLEG RECTANGULAR COORDINATES HOR!Z, DEPARTURE SECTION SEVERITY NURTH/SOUIH EAST/WEST DI~T, AZIMUTH f'EET DEG/IO0 P'EET FEET FEET DEG MIN N 0 0 ~; 0.00 N 25 1 g 142.53 h 25 25 E 733.60 N 22 19 E 1562.3g N 24 8 E 2446,01 N 25 28 E 3334.15 a 26 45 E 4234,94 N 24 27 E 5105,09 a 23 57 E 5979,42 N 25 58 E 6833.61 0 O0 2:47 2,44 1,80 3,22 1,61 0,63 0,24 2.17 0.13 O,3U 0,40 0,00 N 23 1 g 7687 59 N 20 26 E 8548:84 N 20 6 E 8853,47 O,OU N 0,00 g 0,00 N 0 0 132,~U N 62,44 E 142,59 N 21 34 E 666,42 N 307.31 E 733,86 N 24 45 E 1430,23 N 629,06 E 1562 45 N 23 44 2247 42 !~ 965'43 E 2446 0! N 30bl 30 N 1344,30 E 3334 30 N 3855 OU a 1765.66 E 4235 95 N 24 4652 ]~ N 2104,04 E 5106 04 N 24 20 5450,0~ N 24~2,33 E 5980,4~ N 24 18 E ~218,27 N 2838,22 E 68~5,$~ N 24 32 E · . 6994,9~ N 3193,88 E 7689 60 N 24 32 E 7796,92 N 3508.98 E 8550:~5 N 24 ~3 E 8083,20 N 3614,34 E 8854'47 N 24 '5 E · ARCO ALASKA, ZNC, 3H-21 KUPARUK NORTH SLOPE, ALASKA ¢ONP[}TA~ION t)ATE: 10-MA¥-88 PAGE 5 DATE OF SURV~X~ 30-APR-SM KEhbY bUSHING 'ELEVATION~ 75,00 FT ENGINEER~ BARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MOb-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL I)EVIATION AZIMUTH DEPTH DEPTH DEPTH DEG SiN DgG 0 O0 75 95 175 95 275 95 375 96 476 11 576 94 679 22 783 23 888 76 0,00 -76,00 0 0 N 0 0 E 76 O0 0,00 0 9 N 74 3U W 176:00 I00,00 0 12 N 21 55 W 276 00 200,00 0 23 N 23 22 E 376:00 ]00,00 0 59 N 24 52 E 476,00 400,00 5 19 N 22 32 E 576,00 bOO,O0 9 32 N 19 42 E 6'16,00 bO0,O0 14 3 N 19 9 E 776.00 700,00 17 32 N 19 53 E 876.00 800,00 19 44 h 23 48 g 995,91 976,00 900,00 22 lB 1105,49 1076,00 1000,00 26 11 1218,44 1176,00 I100,00 28 43 1334,45 1276,00 1200,00 32 24 1455,33 1376,00 1300,00 35 29 1580.83 1476,00 1400,00 38 19 1712,10 1576.00 1500,00 42 29 1851,59 1676 O0 1600,00 45 46 2003,26 1776:00 1700,00 51 25 2169.9b 1876,00 IBO0.OO 54 35 VERTICAL DOGLEG RECTANGU6AR COORDINATES HORiZ, DEPARTURk SECTION ~EVERiTY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FE~T DEG 2344 54 1976.00 1900.00 57 4 2533 37 20'16.00 2000,00 57 3'1 2713 51 2176,00 2100,00 55 20 2888 92 2276,00 2200.00 56 43 3093 21 2376,0o 2300,00 61 40 3301,68 2476,00 2400,00 O1 23 3947.]728 00 2676,00 2~00,00 62 .]4 .25 2776,00 2700,00 63 11 4164.46 2876,00 2800.00 02 ]9 0,00 0,00 0,00 '0,07 0,00 0 02 0,03 0,00 0,21 0.51 0.29 0,71 1,47 1,52 1,50 6,28 4,66 5,94 19.06 5,57 17,85 40.36 4,23 38.05 68,84 1,84 64,9'/ 102,52 2,66 96,2e 4382 97 29'16,00 2900.00 62 58 4604 04 3076,00 3000,00 53 0 4823 24 3176,00 3100,00 b2 22 5038 28 3276,00 3200,00 62 47 5267 05 3376,00 3300,00 64 1~ 5499 71 3476,00 3400.00 55 3 5740 37 3576.00 3500.00 65 48 5974 60 3676,00 3600,00 62 3 6179 79 3776.00 3700.00 59 56 6379 78 3876.00 3800.00 60 4 N 25 2 E 140,95 N 24 lb E 185,68 N 22 22 E 238,17 N 25 16 E 296,94 N 26 50 E 364,~9 ~ 26 3 g 440,38 N 27 3 E 525,22 N 25 18 g 522,31 ~ 25 22 E 736.15 N 21 21E 869.46 N 22 52 E 1012 52 ~ 22 29 E 1172:69 N 22 54 E 1322.50 h 23 8 E 1466,61 N 22 11 E 1644,62 ~ 21 50 E 1827,50 N 22 21E 2012,47 N 22 48 E 2203,93 N 22 48 E 2399,04 ~ 25 11E 2591,78 ~ 25 18 E 2785,94 h 25 11E 2982,97 N 25 14 f 3177.92 N 25 32 g 3368,15 N 27 5 E 3573,55 ~ 27 29 E 3783,08 N 27 32 E 4001,37 N 26 51E 4212,56 N 23 4 E 4391,56 N 22 20 E 45~4.75 2,42 4.15 1,78 3,99 2,24 1,77 2 84 2:74 2,50 1,27 4,59 1,07 0.54 4,88 0,98 0,39 0,80 0,47 1,21 0,35 0,78 0,72 0,47 1,21 0,79 0,37 0,29 1,32 0,70 0,49 131,17 171,82 0,00 0,22 0,42 O,37 0,10 2,09 0,00 N 0 0 E 0,23 N 85 27 W 0,47 N 63 1 W O, 80 N 27 26 W 1,57 N 3 32 E 19 2:' > N 20 3t 6,29 N 13,bb E 4 44 N 19 44 E 23,17 E 68,98 N 19 37 E 35,65 E 102,66 N 20 19 E 51,77 E 141,01 N 21 32 E ?0,4b E 185,71 N 22 17 E 220,0'1N 91,13 E 238,19 N 22 29 E 273,9'1N 114,54 E 296,95 ~ 22 41E 334,6~ N 144,84 E ~64,69 N 23 24 E 402 5~ N 178,70 E 440,41 N 23 56 E 478 6I a 216,56 E 525,32 N 24 20 E 5bb 98 N 259,16 E 622 49 N 24 36 E 668 73 N 308,40 E 736:41 N 24 45 E 791 11 N 361,26 E 869; 69 N 24 32 E .. , 923,52 N 415,47 'E 1012,68 h 24 13 E 1071'1~ N 477,59 E 1172 81 N 24 ! E 1209 41N 535,]0 E 1322:5~ N 23 52 E 1341 89: N 5V2,02 E 1466,6B N 23 4B E 1506']7 N hbO,15 E 1644,67 N 23 J9 E 1676.05 N 728,49 E 1827,52 h 23 2° E 1847.51 N 7N7,98 E 2012.48 N 2~ 2 2024,31 N 871,49 E 2203,93 N 23 1. '. 2204,32 N 946,77 ~ 2399,04 N 23 14 E 2379,5~ N 1027,1~ E 2591,7~ N 2~ 20 E 2555,26 N 1110,13 E 2';85,97 N 23 28 E 27~3,55 N 1194,28 E 29~],0~ N 2~ 36 E 2910 O~ N 1277,32 E 3178 02 N ~] 41E ~082:01 m 1358,95 E 3358:3~ N 25 47 E 1256,1/ N ~450,65 E 3573,8~ N 2~ 56 E ~452,7~ N 1547,19 E 3785,55 N 24 '8 E 3646,90 N 1648.29 ~ 4002,09 N 24 19 E 38~4,99 N 1745,54 E 4213.55 N 24 28 E 3997,14 N 1821,60 E 4392,64 N 24 29 E 4157,0~ N 18~8,05 E 4565,75 N ~4 25 E ., ARCO AbASKA~ INC, 3H-21 KUPARUK NORTH 8LOPE~ AbASKA CONPUTAI'ION DATE: IO-MA)-~8 PAGE DATE OF SURVEY: 30-APR-8~ BUSHING gbEVATION: ~76,00 FT ENGINEER: 5ARBER INTERPOLATED VALUES [;'OR EVEN 100 FEET OF SUm-SEA DEPTH TRUE SUB-SEA COURSE VERTICAb DOGLEG RECTANGULAR COORDINATES HOR1Z, DEPARTUR'E MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEL 6580 12 3976,00 3900.00 60 2 6785 59 4076,00 4000,00 61 3 6991 ~7 4176. ,00 4200 O0 4300:00 60 49 7195 7400 7605 7814 8021 8219 8410 O0 4100,00 60 46 36 4276 60 52 50 4376.00 64 4476.00 4400,00 61 0 43 4576,00 4500,00 61 40 49 4676,00 4600.00 60 6 02 4776.00 4700.00 58 34 14 4876.00 4800.00 58 24 8601,21 8793.20 8985, 9368 ' 9756 0139 * . 58'1 . 4976,00 4900.00 58 29 5076,00 5000.00 58 42 5100.00 58 31 5200,00 58 14 5300,00 58 41 5400,00 59 6 5500.00 58 45 5600,00 5R 23 5700.00 58 21 5~00,00 58 49 10525 96 5976.00 5900.u0 59 26 10725 54 6076.00 6o00.o0 60 19 10929 11 6176,00 blOO,O0 bO 59 11138 08 6276.00 6200.00 61 42 11346 O0 6373.4~ 6297.48 62 3 DEL MIN FEET DEG/IO0 N 22 33 E 4738.33 N 24 21E 4917.79 N 24 27 E 5097.38 N 24 45 E 5275.36 h 24 42 E 5454.40 N 23 58 E 5633.49 N 23 28 E 5816,76 N 24 19 E 5998,07 N 26 30 E b168,27 N 26 3b E 0~30,86 N 26 15 g b493.41 N 25 58 E b657.08 N 25 59 E 6821,56 N 25 38 E b984.21 N 24 59 E 7147.5! N 24 2] E 7313'16 N 23 50 E 7479.55 N 23 10 E 7643.~5 N 22 29 E 7~05.96 N 2! 47 E 7970.06 h 21 !8 E 8137.09 ~ 20 49 g 8309,69 N 20 29 E 6486.82 N 20 8 E 8670.08 ~ 20 6 E 885~.47 0,7~ 0,22 0,33 0 37 0~22 0,30 0,42 1,69 0,73 0,13 0,04 0.44 0,17 0 31 0:63 0.53 0,21 0,61 0.48 0,27 0.57 0,80 0.92 2 63 0:00 FEET FELT FEET DEL MIN 4317.5~ N 1954.20 E 4739,24 N 24 21E ~481,76 N 2026'67 E 4918,70 N 24 19 E ~645,36 N 2100'85 E 5098,~} N 24 20 E 4807,24 N 2174 95 E 5276,~5 N 24 20 E 5133,0U N 2323 77 E 5634,58 N 24 2" 6300 8~ N 2397 52 ~ 5817,85 h 24 2~ .... 54~7:0~ iv 2459,96 E 5999,14 N 24 ~8 E 5620,9~ N 2542,98 E 6159,4J N 24 20 E 57~6,5u N 2~15,98 E 6~J2,1~ N 24 24 E 6912 3~ N 2688,52 E 6494,89 N 24 27 E 6069:38 N 27~0.84 E 5658,71 N 24 29 E 6207,4~ N 2852,93 E 6823,]2 N 24 31E ~]~3,95 N 2903,92 E 6986,10 N 24 ~3 E ~501,60 N 2973,96 E 7149,50 N 24 J4 E ~652,1i N 304],16 ~ 7315,20 N 24 J4 E ~804.0~ N 3111.13 ~ 7481,60 N 24 J4 E 6954,52 ~ J176.64 E 7645,68 N 24 ~2 E 7104,0Y N 32J9,7! E 7807,92 N 24 JO E 7256,14 N ]~01.48 E 7971,91 N 24 27 E 7411,60 N 33~2,77 E 8138,80 N 24 24 E 7572'8J N 3424,75 ~ 8311.2~ N 24 20 E 77~8'7~ N 34~7,27 E 84~8.19 N 24 15 E 7910.73 N 3551.21 E 8671,26 N 24 10 E 8083,20 N 3514,34 £ 8854,47 h 24 '5 E ARCO ALASKA, INC, 3H-21 KUPARUK NORTH SLOPE, ALASKA ~ARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARU~ A BASE KUPARUK A PBTD TD CO~IPL!TATION DATE: IO-MA~-B8 PAGE 7 DAT~ OF SURVEY: 30-APR~B~ KELLY BUSHING ELEVATION: 7b. O0 FT INTERPOLATED VAL~E$ FUR CHOSEN MEASUR~iD DEPTH BELOW AB SURFACE LOCATION ' ORiGiN=TVD 982 FNL, 282 RECTANGULAR CUORDINATgS 10772,00 609B.gb, bO22,gb 7b10.59 N 10818,00 6121.56 6045,5b 7648 06 N 10842.0U 6133.36 b057,36 7667:62 N ~218.00 6313.50 b2J7.50 7977.9! N 3439 OB E 3453 25 E 3460 bl E 354b 63 F-% 3575 47 L 3614 34 E CONPUTATION WAT~: 10-~A~-88 PAGE ARCO ALASKA, INC. 3H'21 KUPARUK NORTH SLOP£w ALASKA DATE OF SURVEY{ ~O-APR-SU KELLY BUSHING EbEVATION~ 76,00 ENGINEERI SARBER ************ STRATiGRAPHIC SUMMARY MARKER MEA$[IRf:D DEPTH SORFACB LOCATION AT ORIGIN= 982 FNL, 282 FWL, SEC 12w T12N RSE UM TVD RECTANGULAR CUORD~NATE~ FROM K~ SUB-SEA NORTH/SOUTH EAST/WEST TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD 10772,O0 10818,00 10842,00 11123 00 11218:00 11346,00 6098.90 6022,96 7610,59 N 3439 08 6121,56 6045,56 7648,06 N 3453:25 6133.36 6057,36 7667,62 N 3460,61 6268,85 b192'85 7898,28 N 3546,63 6313,50 6237,50 7977 01 N 357b,47 6373,48 6297,48 808~:20 N ~6~4,34 FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VEHTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 11346,00 6373,48 6297,48 8854.47 n 24 5 E SCHLUMBERGER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA. INC. 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Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H - 21 Cement Evaluation Log 4 - 2 0 - 8 8 4 6 0 0 - 1 1 1 9 8 3 H - 1 8 Cement Evaluation Log 5 - 0 5 - 8 8 8 8 9 3 - 1 0 0 81 30-16A Cement Evaluation Log 5 - 0 9 - 8 8 90-8111 3 O- 1 8 Cement Evaluation Log 5 - 0 9 - 8 8 2 6 9 0 - 7 51 5 3 O- 1 7 Cement Evaluation Log 5 - 0 9 - 8 8 2 4 9 0 - 7 9 6 8 3 H - 1 6 Cement Evaluation Log 5 - 2 1 - 8 8 7 7 9 5 - 9 61 4 If you have any questions, concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: NSK (+sepia) 0il & Gas Cons. C0mm. issi0r~ STATE OF ALASKA -'"' ALAS. , OIL AND GAS CONSERVATION COMI~..,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other ~ C0NPLETE 2. Name of Operator ARCO Alaska, lnco 3. Address 6. P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 7. 982' FNL, 282' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1349' FSL, 507' FEL, Sec.35, T13N, R8E, UM At effective depth 1715' FSL, 371' FEL, Sec.35, T13N, RSE, UM At total depth 1821' FSL, 332' FEL, Sec.35, T13N, R8E, UN 5. Datum elevation (DF or KB) RKB 76 ' Unit or Property name Kuparuk River Unit Well number 3H-21 8. Approval number 8-144 9. APl number 50-- 103-2QO~Zf 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4586' 11265' Production 11346 'MD feet Plugs (measured) None 6373 ' TVD feet 11218'MD feet Junk (measured) None 6314 'TVD feet Size Cemented Measured depth 16" 250 sx AS I 115'MD 9-5/8" 2000 sx AS III & 4621 'MD 400 sx Class G .7" 1050 sx Class G & 11300'MD 175 sx AS I True Vertical depth 115 'TVD 3084 ' TVD 6352'TVD Perforation depth: measured 11058' - 11072'MD true vertical 6238 '-6245 'TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail @ 10672' Packers and SSSV (type and measured depth) FHL pkr ~ 10600' & TRDP-1A-SSA SSSV @ 1803' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to. well operation Subsequent to operation Representative Daily Average Production or Inj. ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Wel,], Daily Report of Well Operations History) Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (Dani) 5W03/107 Submit in Duplicate Feet ARCO Oil and Gas Company "~ Well History- Initial Report- Daily Inatructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2645 ICounty. parish or borough NORTH SLOPE-KUPARUK Lease or Unit ADL: 25523 Title COMPLETION 3H-21 JWell no. API: 50-103-20094 Operator ARCO Spudded or W.O. begun IDate ACCEPT I 04/27/88 Date and depth as of 8:00 a.m. 04/27/88 ( TD: PB: SUPV: SC/WM 04/28/88 ( TD: PB: SUPV: DL 04/29/88 ( TD: PB: SUPV: DL 04/30/88 ( TD: PB: SUPV: DL Complete record for each day reported NORDIC I JHour IARCO W.t. 56.0000 Prior status if a W.O. 0030 HRS TIH WITH BIT 7"@11300' MW:10.0 NACL/NABR MOVED RIG FROM 3H-22 TO 3H-21. ACCEPTED RIG @ 0030 HRS, 4/27/88. ND DHT. NU BOPE & TESTED TO 3500 PSI - OK. LOADED PIPE SHED. SET WEAR BUSHING. MU 6-1/8" BIT, JB, BS, & DC'S. TIH ON 3-1/2" DP. DAILY:S17,875 CUM:$1,374,772 ETD:S1,374,772 EFC:$1,736,000 DRILLING CEMENT 7"@11300' MW:10.0 NACL/NABR SERVICED RIG. RIH WITH BIT TO TOC @ 10480'. TESTED UPPER AND LOWER KELLY COCKS TO 3500 PSI. DRILLED CMT TO 10803'. CIRCULATE BOTTOMS UP. DRILLED CMT TO 10975'. DAILY:S28,282 CUM:$1,403,054 ETD:S1,403,054 EFC:$1,736,000 TESTED CSG TO 3500 PSI 7"@11300' MW:10.0 NACL/NABR SERVICED RIG. DRILLED CEMENT TO 11200'. DISPLACED WELL WITH CLEAN BRINE. POH WITH BIT. RIH WITH SCRAPER TO PBTD. REVERSE CIRCULATE WELL AND FILTER WATER. TESTED CASING TO 3500 PSI. DAILY:S28,782 CUM:$1,431,836 ETD:S1,431,836 EFC:$1,736,000 RUN 6.125" GAUGE RING & JB 7"@11300' MW:10.0 NACL/NABR TESTED CASING TO 3500 PSI~ POH WITH BIT. LD 90 JTS DP. RU SCHLUMBERGER. RAN CET F/WLTD 11204' WITH GR TO SURFACE. RAN GCT. PERFORATED 'A' SAND F/ 11058'-11072' WITH 4 SPF, 120 RAN 6.125" GAUGE RING TO 11000' CUM~$1,457,626 ETD:S1,457,626 EFC:$1,736,000 DEGREE PHASING. DAILY:S25,790 The above is correct Signature For form preparatiol~Jand distribution, see Procedures Mail,iai, Section 10, Drilling, Pages 86 and 87. IDate AGGOC, IATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report operation if space is available. Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Repolf" form may be used for reporting the entire IAccounting cost center code ICounty or Parish Stat I NORTH SLOPE-KUPARUK ~ I Lease or Unit I ADL: 25523 I Title I COMPLETION District 3H-21 IWell no. ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2645 Operator ARCO I AR.Co. Spudded or W.O. begun IDate I ACCEPT Date and depth as of 8:00 a.m. 05/01/88 ( TD: PB:10218 SUPV:DL Complete record for each day reported NORDIC I API: 50-103-20094 W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56,0000 Jabandonment of this well I /IH°ur I Prlor status if a W.O. 04/27/88 / 0030 HRS RIG RELEASED 7"@11300' MW:6.9 DIESEL POOH W/ 6.125" GR. RIH W/ 3-1/2" COMP EQUIPMENT. DROP BALL. PRESS TBG TO 2500 PSI TO SET PKR. TEST TBG AND ANNULUS TO.2500 PSI. SHEAR PBR. SHEAR BALL. TEST SSSV TO 1500 PSI. ND BOPE. NU TREE AND TEST TO 5000 PSI. DISP WELL TO DIESEL. TEST ORIFICE VALVE TO 1000 PSI. SET BPV. SECURE WELL. RIG RELEASED AT 0400 HRS 5/1/88. TRDP-1A-SSA SSSV @ 1803', FHL PKR @ 10600', TAIL @ 10672' DAILY:S213,037 CUM:$1,670,663 ETD:S1,670,663 EFC:$1,736,000 ' Old TD Released rig INew TD Date Classifications (oil, gas, etc.) Producing method Potential test data PB Depth Kind of rig JType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C,P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ~r ~11 i~r;°,~ ~ar~ r:M~ '~a~nUd~8 7S.i[~l~nbu~)°' n' Date ITitle 5'-2.o A,~3CIATEENGINEER ARCO Alaska, Inc. Post Office bvx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 15, 1988 Transmittal # 7117 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole Tape and Listing - 2-14-88 //o? t~ #72599 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. is a SuOsidiary of AtlanticRichfieldCompany · "'" STATE OF ALASKA ALASK. ,.)IL AND GAS CONSERVATION COMM..dION APPLICATION FOR SUNDRY APPROVALS II 1. Type of Request: Abandon [] Suspend [] Operation Shutdown'~E] Re-enter suspended well [] Alter casing Q Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-02~60 4. Location of well at surface 982' FNL, 282' FWL, Sec.12, T12N, At top of productive interval R8E, UM 5. Datum elevation(DF or KB) RKB 76' 6. UnitorProperty name Kuparuk River Unit 7. Well number 3H-21 8. Permit number 1320' FSL, 690' At effective depth I 804 ' FSL , 394 ' At total depth 1699' FSL, 434' 11. Present well condition summary Total depth: measured true vertical FEL, Sec.35, T13N, R8E, UM (approx) FEL, Sec.35, T13N, RSE, UM (approx) FEL, Sec.35, T13N~ R8E~ UM (approx1 11346'MD feet Plugs(measured) 6430'TVD feet 88-0R 9. APl number 50-- 103-200~4 10. Pool Kuparuk River Oil Pool None Effective depth: measured 11218'MD true vertical 6369'TVD Casing Length Size Conductor 80' 16" Surface 4586' 9-5/8" Production 11265' 7'! feet Junk (measured) feet None Cemented Measured depth 115'MD 4621 'MD 11300'MD 250 sx AS I 2000 sx AS II1 & 400 sx Class G 1050 sx Class G feet Perforation depth: measured None true vertical No ne Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED' ,-'.. :. ~> ~ Oil & Gas Cons. Commisslo:; Anchorage 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation March, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Sioned-- Tit,e A..oo a,. Commission Use Only (Dani) Date 5A3/66 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ~ue Verticaldepth 115~TVD 3106~TVD 6408~TVD Approved by BINAL SIGNED~Y' ! ,. .:ii- r, ,',:,~l~"u LONNIE C, SMITH" Approved Copy Returned .. Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District j cou.ty, parish or borough Sta 1 ARCO Alaska, Inc. NORTH SLOPE-KUPARUK ] ~ Field Lease or Unit Well no. KUPARUK RIVER FIELD ADL: 25523 3H-21 Auth, or W.O. no. ~Title AK2645 I DRILL API: 50-103-20094 Operator ARCO SPUD 02/02/88 1730 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 ARCO W.I. 56.0000 JPr or status if a w,o, 02/03/88 ( TD: 1319'( SUPV:RCB 02/04/88 ( TD: 2980'( SUPV:JP 02/05/88 ( TD: 4640'( SUPV:JP 02/06/88 ( TD: 4640'( SUPV:JP 02/07/88 ( TD: 5032'( SUPV:JP 02/08/88 ( TD: 5853'( SUPV:JP 02/09/88 ( TD: 7813' ( 1 SUPV:JP .) 1 ;19) :) 1 ;61) DRILLING 16"@ 115' MW: 9.0 VIS: 60 MOVED RIG FROM 3H-19 TO 3H-21. NU DIVERTER, FLOW LINES, MUD LINES. STEAMED & STRAP BHA, ORIENT. FUNCTION TESTED DIVERTER SYSTEM-OK. DRILLED 20' ICE PLUG. SPUDDED WELL @ 1730 HRS, 2/2/88. NAVI-DRILLED 12-1/4" HOLE TO 1319' DAILY:S67,627 CUM:$67,627 ETD:S67,627 EFC:$1,736,000 DRILLING ' 16"@ 115' MW: 9.0 VIS: 78 DRILLED 12-1/4" HOLE TO 2211'. CIRC. BOTTOMS UP. POH. CHANGED BHA. TIH. WASHED 200' TO BOTTOM. DRILLED TO 2980'. DAILY:S57,385 CUM:$192,639 ETD:S125,012 EFC:$1,803,627 ) 1 60) POOH TO RUN CASING 9-5/8"@ 4621' MW: 9.1 VIS: 70 DRILLED 12-1/4" HOLE TO 4640'. CIRCULATE BOTTOMS UP. SHORT TRIP TO HWDP. WORKED THROUGH TIGHT SPOT F/1950'-1800'. CIRC. HOLE CLEAN. DROPPED SURVEY & PUMPED PILL. POH TO RUN 9-5/8" CASING. DAILY:S45,889 CUM:$238,528 ETD:S170,901 EFC:$1,803,627 0) TESTING BOP'S 9-5/8"@ 4621' MW: 8.3 VIS: FIN POOH. LD BHA. RU AND RUN 117 JTS OF 9-5/8" 36#, J-55 BTC CSG W/ FS AT 4620' AND FC AT 4539' CIRC AND COND MUD. TEST LINES TO 3000 PSI. PUMP 80 BBLS OF H20. MIX AND PUMP 2000 SXS OF AS III AT 12.1 PPG. TAIL W/ 400 SXS OF CLASS G CMENT AT 15.8 PPG. BUMP PLUG. CIP AT 2045 HRS, 2/5/88. LD LANDING JT AND INSTALL BRADENHEAD. NU BOPS. RU AND TEST BOPS. DAILY:S234,686 CUM:$473,214 ETD:S405,587 EFC:$1,803,627 ,) 92) 21) ) ~60) DRILLING 9-5/8"@ 4621' MW: 8.7 VIS: 32 INSTALL WEAR RING. MU BHA. CUT DRILL LINE. RIH TO FC. TEST CASING. DRLD FLOAT EQUIP AND 15' NEW FORMATION. RUN LOT TO EMW OF 12.5 PPG. DRLD 8-1/2" HOLE F/ 4655' TO 5028' POOH. MU NEW BIT AND TIH. REAM 60' TO BTM. DRLD 8-1/2" HOLE F/ 5028' TO 5032. DAILY:S48,882 CUM:$522,096 ETD:S454,469. EFC:$1,803,627 POOH 9'5/8"@ 4621' MW: 9.1 VIS: 34 DRLD 8-1/2" HOLE TO 5286'. POOH. CHANGE BHAAND ORIENT. RIH. DRLG 8-1/2" HOLE F/ 5286' TO 5853' TURBINE FAILED. POOH. DAILY:S75,682 CUM:$597,778 ETD:S530,151 EFC:$1,803,627 J:~ska 0il & ~as Cons. C0mmis~[~:~ DRILLING 9-5/8"@ 4621' MW: 9.2 VIS: 36 FIN POOH. LD TURBINE. MU DTU. TEST AND ORIENT. RIH. DRILLED 8-1/2" HOLE F/ 5853' TO 7813'. DAILY:S43,074 CUM:$640,852 ETD:S573,225 EFC:$1,803,627 The above is correct For form preparation and ¢~tribution, I Title I ^SSO~ATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District iCounty or Parish J State ARCO Alaska, Inc. I NORTH SLOPE-KUPARUK I AK Field JLease or Unit Complete record for each clay while drilling or workover in progress DOYON 14 Date and depth as of 8:00 a,m, O2/lO/88 ( 8 TD: 9813'( 20 SUPV:JP ) 30) 02/11/88 ( 91 TD:ll300' (1437) SUPV:RB 02/12/88 ( 10 TD:11300' ( SUPV:RB 02/13/88 ( 11 TD:l1300' ( SUPV:RB 02/14/88 ( 121 TD:l1300' ( SUPV:RB o) o) o) o) 02/15/88 ( 13 TD:ll300'( SUPV:RB DRILLING 9-5/8"@ 4621' MW: 9.4 VIS: 37 DRLD 8-1/2" HOLE TO 9018' SHORT TRIP TO CASING SHOE. CUT DRILL LINE. TIH. DRLD 8-1/2" HOLE F/ 9018' TO 9813'. DAILY:S42,998 CUM:$683,850 ETD:S616,223 EFC:$1,803,627 POOH F/ SHORT TRIP 9-5/8"@ 4621' MW:10.0 VIS: 41 DRLD 8-1/2" HOLE F/ 9813' TO 11159'. REPAIR RIG. DRLD 8-1/2" HOLE F/ 11159' TO 11300' CIRCULATE. POOH F/ SHORT TRIP. DAILY:S47,407 CUM:$731,257 ETD:S663,630 EFC:$1,803,627 RIH F/ WIPER RUN 9-5/8"@ 4621' MW:10.1 VIS: 44 POOH F/ SHORT TRIP. RIH. CIRCULATE. DROP SURVEY AND SPOT DIESEL PILL. POOH F/ LOGS. RU SOS. RIH W/ DIL/FDC/CNL/GR TO 5242' LOG COLVILE F/ 5242' TO 4620'. RIH SLICK W/ DIL/FDC/CNL/GR TO 4680' COULD NOT GET PAST. POOH. RIH W/ WHEELS AND SAME WIRELINE TO 5240', COULD NOT GET PAST. POOH AND RD SOS. PU BHA AND RIH F/ WIPER TRIP. DAILY:S48,299 CUM~$779,556 ETD:S711,929 EFC:$1,803,627 RIH WITH LOGS ON DP 9-5/8"@ 4621' MW:10.0 VIS: 39 RIH TO SHOE. CUT DRLG LINE. RIH. CIRCULATE AND SPOT DIESEL PILL. POOH. RU LOGGERS AND MAKE 2 ATTEMPTS TO LOG. POOH. RD LOGGERS. RU LOGGERS SHEAVE @ CROWN. MU LOGGERS TLC TOOL AND TEST. MU DP TOOLS AND RIH. DAILY:S97,365 CUM:$876,921 ETD:S809,294 EFC:$1,803,627 POOH WITH LOGGING TOOLS 9-5/8"@ 4621' MW:10.1 VIS: 44 TIH WIH LOGGERS TLC TO 9587'. MU LOGGERS SIDE ENTRY AND PUMP WIRELINE. RIH WITH DP AND WIRELINE TO 11204'. BREAK CIRCULATION & POOH LOGGING W/DIL/FDC/CNL/GR/CAL F/11204'-9590'. RIH WITH DP AND WIRELINE. POOH LOGGING WITH SAME F/11213'-9590'. RD LOGGERS. POOH WITH WIRELINE. POOH WITH DP. RD LOGGERS TLC TOOL AND RU FOR COLVILLE. RIH WITH COLVILLE LOG TO 5205'. COULD NOT GET PAST. POOH WITH WIRELINE. DAILY:S36,754 CUM:$913,675 ETD:S846,048 EFC:$1,803,627 ~ASH AND REAM TO BOTTOM 9-5/8"@ 4621' MW:10.0 VIS: 38 ATTEMPT LOGS. COULD NOT GET PAST 4655'. RD LOGGERS. TIH TO SHOE AND CUT DRLG LINE. RI~ TO 10639'. PU KELLY, HOLE PACKING OFF-. POOH TO 10450'. CIRCULATE. WASH AND'REAM TO 11300' TWICE. ENDED UP REAMING @ 10241'. POOH TO 111~4'. RIG REPAiR..ATTEMPT TO REAM FROM 11114'. POOH TO 10733'. WASH AND REAM TO 11150' DAILY:S127,615 CUM:$1,041,290 ETD:S973,663 EFC:$1,803,627 JWell no. The above is correct For form preparation an, dj distribution see Procedures Manua~/~ection 10, Drilling, Pages 86 and{~r/ JTitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests seqUentially. Attach description of all cores. Work performed by Producing SeCtion will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, District [Stat~ Field ARCO Alaska, Inc. ICounty or Parish Lease or Unit 3H-21 KUPARUK RIVER FIELD IWell no. Date and deptl~ as of 8:00 a.m. 02/16/88 ( 1 TD:11346' ( SUPV:RB ComCete record for each day while drilling or workover in progress DO¥ON 14 =) 46) RUNNING 7" CASING 9-5/8"@ 4621' MW:10.0 VIS: 38 WASH FROM 11150-11300'. DRILL 8 1/2" HOLE TO 11346'. REAM AND WASH NEW HOLE. SHORT TRIP 7 STANDS. CIRCULATE AND SPOT DIESEL PILL. POOH. STAND BACK 60 STDS. LD BHA. RU AND RUN 7" CASING. DAILY:S44,496 CUM:$1,085,786 ETD:S1,018,159 EFC:$1,803,627 The above is correct Signature For form preparation an.~d~stribution see Procedures Manua~ection 10, Drilling, Pages 86 and~ JDate .-n ITM ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State ARCO Alaska, Inc. NORTH SLOPE-KUPARUK AK Field KUPARUK RIVER FIELD Auth. or W.O, no, AK2645 Lease or Unit ADL: 25523 3H-21 Title DRILL JWell no. API: 50-103-20094 Operator AR.Co. W.l. jTotal number of wells (active or inactive) on thisI Icost center prior to plugging and 1 ARCO 56. 0000 labandonment of this well Spudded or W.O. begun Date IHour I Prtor status if a W.O. SPUD 02/02/88 J 1770 ' I Date and depth !Complete record for each day reported as of 8:00 a.m. DOYON 14 Old TD Released r~g RIG RELEASED 7"@11300' MW:10.0 VIS: RAN 287 JTS OF 7" 26~ J-55 BTC CASING. FLOAT SHOE @ 11300'. CEMENT CASING WITH 500 SX OF 12.0 PPG 50/50 POZ LEAD, FOLLOWED BY 420 SX CLASS G. PUMPED ADDITIONAL 130 SX CLASS G. CIP @ 2230 HRS 2/16/88. NU TBG HEAD AND LOWER MASTER. TEST FLANGE TO 3000 P$£. INJECT FREEZE PROTECTION. RELEASE RIG @ 0600 HRS 2/17/88. DAILY:S271,111 CUM:$1,356,897 ETD:S1,289,270 EFC:$1,803,627 02/17/88 ( 1 TD:11346' ( SUPV:RB Classifications (oil, gas, etc.) Producing method Potehtial test data ) o) Date New TD J PB Depth J Kind of rig J Type completion (iingle, dual, etc.) .. J Official reservoir name(s). Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation an/~distribution, see Procedures Manua¥,Section 10, Drilling, Pages 86 and ~7. Date ,~ JTitle ASGOCIATE ENGINEER ARCO Alaska, Inc. ~'~ Post Office B,. i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 19, 1988 Transmittal #: 7096 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. i~~3H-11 OH Edit Tape and Listing 12-25-87 #72596 .~-3H-14 OH Edit Tape and Listing 12-13-87 #72595 -'~~ Open Hole Tape and Listing 2-14-88 #72599 ~ Naska 0il &'Gas Cons. C0mmissi0 Anchorage Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger Date: State of Alaska ARCO Alaska, Inc. Is a Subsidiary of AllanllcRichfieldCompany ARCO Alaska, Inc. Post Of~'''' ~'' 100360 Anchor~.l_ , ~,aska 99510-0360 Telephone 907 276 1215 Date: February 19, 1988 Transmittal #: 7100 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Natural Gamma Ray Spectrometry Log Electromagnetic Propagation~Lpg~ 2" & 5" Dual Induction 2" & 5" Porosity FDC 2" & 5" Raw FDC Cyberlook 2-14-88 4850-5170 2-14-88 4850-5170 2-14-88 4620-11204 2-14-88 4620-11184 2-14-88 4620-11184 2'14-88 4620-11184 Anchorage Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & H Date: State of Alaska(+sepia) Lucille Johnston ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany January 29, 1988 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100'360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3H-21 ARCO Alaska, Inc. Permit No. 88-8 Sur. Loc. 98-2 ' FNL, Btmhole Loc. 1620'FSL, Telecopy: (907) 276-7542 282'FWL, Sec. 12, T12N, RSE, UM. 561'FEL, Sec. 35, T13N, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To'aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very _truly yours, :~d~nie C. ~i~th Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASiI OIL AND GAS CONSERVATION _,OMMISSlON PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepenr-11 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 76', PAD 39' feet Kuparuk River Field Kuparuk River 0il Poo 3. Address 6. Property Designation P.0. Box 1002;60, Anchorage, AK 99510-02;60 ADL 25522; ALK 2559 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 982'FNL, 282'FWL, Sec.12, T12N, R8E, UN Kuparuk River Unit Statewide At top of productive interval (@ target) 8. Well nd.tuber Number 12;20'FSL, 690'FEL, Sec.2;5, T13N, R8E, UM 2;H-21 #8088-26-27 At total depth 9. Approximate spud date Amount 1620'FSL, 561 'FEL, Sec.2;5, T12;N, R8E, UH 02/5 /88 $500,000 12. Distance to nearest 13. I~i~ta2n(~e to nearest well 14. Number of acres in property 115~ Prop. osed depth(MB and TVD) - 1 75 'MD property line 561 '~ TD feet 25' @ Surface feet 2560 (6400'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 400 feet Maximum hole angle 60 0 Maximum surface 1 850 psig At total depth C'VD) 2;028 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.54 H-40 Weld 80' 2;5' 2;5' 115' 115' +200 cf 12-1/4 9-5/8" 2;6.0¢/ J-55 BTC 4529' 2;5' :55' 4564' 3126' 1255 sx AS II I & HF-E~W 400 sx Class G blend 8-1/2" 7" 26.0¢ J-55 BTC 11141' 2;4' 2;4' 11175' 6400' 200 sx Class G(minimur HI--P_~W TOC 500' abcve top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate ,., .,. · . Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ Diverter Sketch [] Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby ce/~y/~hat the fo/~,~ true and correct to the best of my knowledge / Si-ned / / ~ '/~'~ ' ~'~ ' Title Regional Drilling Engi // / /' Commission Use Only (AWM) PD2/69 . ~ ./ Permit Number . I APl number I Approval date I See cover letter I~--¢¢~ J 50--10,~. 'Zooq~l,- I 01/29/88 J !or other requirements Conditions of approval Samples required [] Yes [i;;~-'~o Mud Icg required L-] Yes Ji~/No Hydrogen sulfide measures [] Yes E~No Directional survey required EB'"Yes [] No Required working pressure for B,C)PE []2M;/~J~ 3M; [] 5M; [] 10M; [] 15M Other: ,~~ ~~~(' by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1,85 L. Submit in triplicate GENERAL DRILLING PROCEDUIO~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install FMC diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and I0' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. ~ 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. DEGASSER MUD CLEANER SHALE SHAKERS LNK4/ih TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & 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 (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, 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 shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5/ih KUPARUK RIVER UNIT 20" D IVERTER SCHEMATIC .I Ii DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD ,.'3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLING SPOOL W/lO" OUTLETS 5. 10" HCR BALL VALVES W/1 O" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE D(TW~WIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REOUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.O35(b) MAINT[NANCE & OPt~RATION . . 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. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 7 L_ i > > DIAGRAM #1 1~.5/8' 5000 PSI RSRRA BOP STACK !. 16' - 2000 PSI T/tN(CO 2. II' - 3000 PSI CASII~ 4. 1~5/8" - ~ ~I PI~ ~ 1~5/8" - ~ ~] ~]LL]~ KILL LZ~S 7. ~5/8~ - ~ ~Z ~~ A~AT(jR CAPACZTY TEST I. Q-ECK ~ FILL ~TOR RESERVOIR TO PROPER LEVEL WITH HYDRN. LIC FLUID. 2. ASSURE THAT AC~ATCR I~ IS 3000 PSI WITH 1500 PSI ~TREAM CF' THE REGLLATOR. 3. CBSEEVE TIIVE, THEN Q.CEE ALL UN]TS SIMJLTN~EOLISLY N~ EEQ:I~ THE TIldE ~ PRESSURE REleI~ININ$ AFTER ALL UNITS ARE CLOSED WITH CHARGING PLIVP CFF. 4. RE~ ON NO,DC REPORT, THE ~ABLE LOlr~ LIMIT IS 45 SEO]q:~ CLOSING TIM~ Ai~D 12(X) PSI RENRINING 5 4 ,I 3-5/8" BOP STACK ,TEST~ I. FILL BOP STACK AN3 (~ ~FOLD WITH ARCTIC DIESEL. 2. (I-ECl( THAT ALL LOCi( EO~N SCRE~ IN N~I. LHEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN WITH ~ING JT ~ Fa.N IN L(3CKI:X3~N SCRERS. 3. CLOSE ~ PREVENTE]~ ~ MMIJAL KILL ~,~ LIllE VALVES ADJN:ENT TO BOP STACK. ALL OTHER VALVES N~)~ SHCU.D BE 4. PRES~LRE UP TO 250 PSI AI~ HOLD FOR I0 MIN. IN- CREASE PRESSLRE TO 3~X3 PSI AI~ HQ.D F(3R I0 MIN. m_FED PRESSLRE TO 0 PSI. 5, CI=EN/~NIN;~ PREVENTER AhD ~ KILL AN3 CH(3<E LIllE VALVES. CLOSE TCP PIPE ~ ~ HCR VALVES ON KILL /~) CH(3(E LIHES. 6, TEST TO 250 PSI ~ 5(330 PSI AS IN STEP 4. 7. CCNTIN, E TESTING ALL VALVES, LII~.S~ ~ Q-13KES WITH A 250 PSI LOW N~D 3000 PSI HIGH, TEST AS IN 'P4. DO NDT PRE_~I RE TE~"T ~ CHC~(E THAT IS A FULL CLOSING POSITIVE SEN. Q-EI(E. CN.Y F~[ICN rEST Q-E~E$ ]HAT DO I~0~[FULLY CLOSE. 8. (]PEN TCP PIPE R/~IS AI~ CLOSE BOTTOM PIPE RAI~. TEST BOTT~ PIPE RAMS TO 250 PSI N~) 3(XX) PSI. 9. (]3EN BOTTOM PIPE RAb~ BACK OUT ~NG JT PU_L OUT (3F HOLE. I0, CLOSE BLII~D RNV~ N~ TEST TO 250 PSI ~ 3000 PSI. II. CPEN BLII~ RN~ ~ RETRIEVE TEST PLUG, bl~(E SIJRE MN~IFCLD AN:) LIliES ARE FLI.L C~' NON-FREEZING FLUID. SET ALL VALVES IN ERILLING PQSITIOI% 12. TEST STAhl]:~IPE VALVES, KELLY, KELLY COQ<S, DRILL PIPE SAFETY VALVE, N~ II~IDE BOP TO 250 PSI ~X)O PSI. 13. RECCRD TEST IhFCRI~TION CN BLONlrr PREVENTER TEST FORM, SIGN, ~ ~ TO DRILLING SUPERVI~. 14. PERFCI~I CI:M3LETE B(]3E TEST AFTE~ NIPPLING UP VEEKLY THEREAFTER FI. NCTI~¥~LY ~TE BCPE E~ILY. Pud 314, W~II No~ 2'1 Pr'opo$~d Kuperuk Fle4d, North SI ope, Alaska 0 IOQQ~ RI(B** F_LEYAT{O#t ?6' KOP TVD=400 THD-400 DEP-O 9 BUZLD 3 DEe ~ tO0 FT _a,l~: ~ PE'RHAFROST TVD-1$g! Tr'ID-1686 OEP-41?. T'/ W SAK SNDS TVD-2616' THD*3$3$ DEP-]941' K-lt2 TVD-2926 TI'ID'4161~ DEP-2484i COLVILLE TVD 3176 THD 4665 :,St. T/ UGNU SNDS TYD-1956, THDi-2219:DEP-802 ' ~---- EO~::-*TVD-2OS'g ;TI~-'Z4T'O- ' DEF""'96~'4- .......... ; ......................... : 4000. 5.000 K-5 TVD-4626 THD-7593 DEP-5466 AVERAGE ANGLE 60 DEG 19 MI N 6000 7000 I I 1000 2000 T/ ZONE D TVD-6106 TMD-10581 DEP-8062 T/ ZONE C TVD-6126 THD-10622 DEP-8097 T/ ZONE A TVD-6158 THD-!0686 DEP-8153 TARGET CNTR TVD-6214 THD-lO799 DEP-8252 B/ KUP SNDS TVD-6301 THD-109?$ DEP-8404 TD (LOG PT) TVD-6400 THD-11175 DEP-8578 ! I I '1 3000 4000 5000 6000 VERTICAL SECTION I ?000 I 8000 · HORIZONTAL , ROJECTION SCALE 1 IN. = 1000 FEET ARCO ALASKA, INC. Pld 3H. W. II No~ 21 P~opoeed Kupeeuk Field, Noe~h S/°po, Aleeke 8000 ZOO0 _ 6000 _ 5000 _ .4000 _ .-?. I .... ::x: .... 3000 1000_ 1DO0 _ 1000 WEST-EAST 0 1000 2000 I I I ~000 TARGET CENTER TVD-~I 4 TI'ID- t O?99 DEP=8252 NOR1.H 7'51t2 EAST 3256 SURFAOE: LOCATION, ~2' FNLo ~2' FWL SEC. 12, 1'12N, RSE N 23 DEO 14 I"IIN E 8252' (TO TAROET) 4000 TO LOCATION s 1620' FSL. 561' FEL SEC. 35. T13N. RSE TARGET LOCATION ~ 1320' FSI.. 690' FEI. SEC. 35. I'13N, RSE 150 2oo 25o 3o0 35o 400 45O 8oo 1,.1 5Q I =. 200 150 200 I ! I / I \ I / ~J31~O /1100 I / \, I ' / 2500 ~ 1100 '900 2100 1100 ~0 300 O0 _ . 2700' I I 2500 FO0 I0 , m i I I 250 3;00 350 400 i 450 · 800 . 850 1 000 1050 1100 115C I1 20C Alaska, In~.~ ARCO _ Post Office vox 100360 Anchorage, Alaska 9.9510-0360 Telephone 907 276 1215 January 15, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' Conductor As-Built Location Plat - 3H Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG'pk GRU1/86 Enclosure If you have RECEIVED JAN 1 9 AI~ska 0ii & Gas Cons. C0mmiss[0[t Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfleldCompany SCALE I"" 2 MILES S I. ALL COORDINATES ARE A.S.P., ZONE 4. ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-87-19, 35-44 ~ L-87-11, 29-32. 5. O.G. ELEVATIONS FROM CED-RlXX- 3471Z~ 6. HORIZONTAL POSITION BASEDON 3H CONTROL MONUMENTS PER LOUNSBURYS~ Assoc. Y' ASPs 'X' 6,000,110.73 6,000, 135.51 6,000, 160.57 6,000, 185.28 6,000, 210.66 6,000, 235. 50 6,000, 260.34 6,000,285.82 6,000,310. :50 6,000, 335.43 6,000,42 5.37 6,000,450.51 6,000,475.46 6,000, 500.41 6,000, 525.44 6,000,550.46 6,000,575.45 6,000,600.44 6,000,625.20 6,000,650.45 6,000,675.40 6,000,700.42 498,655.44 498,655.43 498,655.39 498,655.43 498,655.47 498,655.40 498,655.41 498,655.44 498,6.55.45 498,655.44 4 98,655.44 498,655.$8 498,655.42 498,655.43 498,655.41 498,655.47 498,655. 55 498,655.59 498,655.52 498,655.49 498,655.63 49 8,655.75 LATITUDE 70° 24'41.531" 70° 24'41. 775" 70024'42.022'' 70° ;)4 42.514' 70o z4:4z. 758;: 70° 24 43.00:5 70° 24:43.25t" 70° 24 43.494" 70o24'43.741'' 7002¥44626" 70024'44.873'' 70°:~ 4' 45.119" 70024: 45-364," 70°24 45.610 70024'45.856'' ?0824'46. IOZ" 70o24' 46.348" 70o24'46.592" 70°24'46.84d' 70o24'47.085" 70° 24'47. 3::51" LONGITUDE 150° 00' 39.416' 150000' 39.417' 150° 00'39.418" 15 0° 00' 39.417 150° 00' 39.4 6" ,50° 00; 150° O0 39.418 150° 00' 39.417" 150° 00', 39.417" 150° O0 39.417" 150o00' 39.418'' 150o 00'39.431~' 150° 00' 39.419" 150° O_C): $9. 150800 39.41~~ 150°00' 39.417" 150°00' 39.415" 150000' 39.4;4" 150o00'39.417" 150o00'$9.418'' 15 0°00' :39.4 I 150o00'39.410" Dist F N. L. 1546' 1522' 149 7/ 1472, 1446 1422', 1397 1371' 1232' 1207' 1182' 1107' 1082' 1057' 1032' 1007' 982' 957' Dist FW.L. ! 281 281' 2811 281 281' 281~ 281 281', 281' 281' 281' 281', 281 281' 28 2' 282' 282' 282:' 282' 282' O.G. Elev. 34.0' 34.0' 33.9: 33.8, 33.7 33,7: 33.6 33.6' 33.6', 33.6 33.?' 33,8' 33.8' 33.8', 33.8 33.8' 33.8' 35.8' 33.8' 33.9' 33.9' 33.9' Pod Elev. 38.8' 38.8' 38.7~ 38.7 38.8' 38.8: 38.9 38.7', 38.6, 38.6 38.7' 38.8' 38.8' 38.7; 38.7 38.7' 38.8' 38.9' 38.7' 38.7' 38.6' 38.6' IHEREBY CERTIFY THAT lAM PROPERLY ! ae-~,~,~ a, , , REGISTERED ANDLICENCEDTOPRAC- --'Il- ! /:),I~L,;IJ /:t, lOSKO Inc. TICE LAND SURVEYING INTHE -~~F .~~. , ~[ '~~~[ ~ ~ ~'~~ ~" STATE OF ALASKA AND THAT THIS ~~,.""'h~*~- [! ' -- .... PLAT REPRESENTS A LOCATION ~Z~.," A I q SURVEY MADE BY ME OR UNDER ~ ~* ' ~TH '~ ~ ~ ~ ~ ~'''~ [' ~ : :'~ '"' MY SUPERVISION, AND THAT ALL ~ ~ ~ ~-- f~ ' *,~W { ! ', .... . ~.~,.~ .,-..~,.......~.......,.. ****************--******* I, ~~;o~umou~u~ ~ UU~L~ ARE CORRECT AS OF 6/9/87. ~.~-~' ~~'~'1" ~ ~ _eeeee~eeeeeeee-~ee~Oee~ I "' . I PREPAR ~ ~- ~546 / · . ... ~ ~ ~l~~~ / ANCHORAGE ALASKA REV. ~ ,00 COND. ~9 ~- 6-ee ~~ / DWN BY: ~JW CHK BY: JWT REV.~ ADD CONO.~O,~I,~. 7-30-87 ~ ~9~ ~6.308-d~ II 112 I I1: I ~ll VICINITY MAP S~.ALE I"' ~ HiL~-s ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. NOTES I. ALL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE I.P.M.S.L. 4. REFER. FIELD BOOK L-17-19,35-44 ~L47-II, ~9-32. B. O.g. ELEVATIONS FROM CED-RIXX- $471,~ 6. HOR,ZONTAL POSITION ,ASEDON SH CONTROL ASPs 'X' 6,000,tl0.73 6,000,135.51 6,000,16057 6,000,185.28 6,000,210.66 6,000, 235.50 6,000,260.34 6,000,285.82 6,000,310.30 6,000, 3 35.43 6,000,425.37 6, 000,45,0.51 6,000,475.46 6,000,500.41 6,000, 525.44 6,000,550.46 6,000,575.45 1,000,600.44 6,000,650.45 6,000,675.40 6,000,700A2 498,655.4 4 498,655.43 498,655.39 498,655.43 498,6.55.47 498,655.40 498,655.41 498,655.44 498,65.5.45 498,655.44 498,655.44 498,655.38 498,655.42 498,655.43 498,655.41 498,65.5.47 498,655.55 498,655.59 498,655.49 498,655.65 498,655.73 LATITUDE 70o 24'41.531'' 70024'41. 775" 70024'42.022'' 70° 24' 42 265" 70° 24' 42 ..514" 70° 24'43.00~ 70° 24'43.253,", 70° 24' 43.494' 70°24'43.741" 70O 24',14.626' 70024'44.873'' 70024'4 5.119'' 70e24' 45.3_64~' 70o24'45.610 70o24'45.856'' 1,0o24'46.102.' ?0824' 4&.$48" A LONGITUDE jDist £N.L. 70o24'46.840'' 70°P4'47.085' 70° 24'47. 3 31 150° 00' 39.416'1 150000. 39.417'1 150° 00:39.418" 150° 00, 39.417': 150° 04:) 39.416' 150° 0_0: 39.4~8", 150° O0 ~9.418' 150e 00' 39.417" 150° 00'. 39.4 ~7" 150° 00' 39.417" 150000' ~9.418" 150° 00'39.421~ 150° 00'39.419" 150° 00'39. 150° 00' 39.414 150° 00' 39.417"1 t 50°00'39.415"1 Isa°oD' ~9.4~'I 150o00'39.4 le"l 150o00'39.413"1 150o00'39.410''l 1 ~la~ka Oil 1522' 149 7,' 1472, 1446 142 2', 1397 1371' 347' 1322' 1232' 1207' 1182' II07' 1082' 1057' I HEREBY CERTIFY THAT I REGISTERED AND LICENCED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. AM PROPERLY G2~Cons. Co~mi~d~'. Ara~kd, raga / $4.0' 281 33.91 281' $3.8, 281° 33.7 28,: 32.7: ~I 33.6 Dis! F.'W~L~! O,G. F'!ev. i pod I~l~v. 38.8' 388' ;50.7' 3~.6' 3e.e', · ~.9 281 ~3.6 s .e' 2~1 33.~ 3~.T 2~1' 33.~' 36.7' ~ 2' 33.9' 3 6.~' 262' 5~.6' 3~.9' 1007' 282' 33.9' 982' 282' $3.9' 957' 262' $3.9' 36.6' II iii ii ARCOAlaska Inc. D.S. 3H w AS- ,U,L.T ~R~PAH£D aY ....... LOUNSBURY 8: Associates ANCHORAGE ,l ALASKA DWN BY'- PJW i "'CHKBy;JwT ! CHECK LIST FOR NEW WELL PERMITS Company A~CO ~{ ~%K~ ~ I~C-. Lease & ITEM APPROVE DATE YES '(1) Fee ~w~ I-~Y-~ 1. Is the permit fee attached .......................................... Well No. ~p~M ff;~w0~ NO REMARKS (2) Loc WW~ 1.% ~-~ (2 thru 8) (8) (3) Admin ,~.~.~< /- ~- fF 9. (9 thru 13) 10. . ~ ~, z ~-~ 11, (10 and 13) 12. 13. (4) Casg ~.~.~ ~-~-~. (14 thru 22) (~) ~0PE ~~/-~-~ (23 thru 28) 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 ............ v~ 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 ...................... ~ .. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 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 ......................... __~ Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. o ~z tqm (29 thru 31) For 29. 30. 31. 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 32. Additional requirements ............................................. Geolosy: En$ineerin$: rev: 01/28/87 ~ nil INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. -.. o .. $ch 1,umbel~c~er Page 2 I..~ i S T A P ~; VERIFICATION LIf~TiNG ompany Name ~'<ell ~ame FlelO Name County State AP1 Mumber Run ~umber Date Logged Service order Pate Computed 72599 ARCO A. bASB. A, 3H-21 PARUK ~RTi! 6LOP~ A b AS K A ~/ EDI~rED FDC CIrri, Schlumberger uff's~"ore Services AlasKa [.~lvj,$1on Cc.:,:.~uter Ce~ter 5o0 west Internatlor'~a! Airport ~oad Anchoraqe, AlasKa 99518 gO .... ~'~ I t~ C, SchIumbe~ger LIST Reel Leader 72599 DAT~ ORIGIN REEL NAME CONTINUATION PREVIOUS REEL CO~E~T Tape header ['12599] LISA ** EDIT FLIC ?~599 EDIT bI$~ARC{,} KIIb'ARUK, 72559 ** 7'APE: HEADER SERVICE NA~E DATF : O~IGIN TAPF NAME CONTINUATION PREVIOUS TAPE COg~ENT : ** EOIT 98/0~/ 8 FLIC 7?559 1 E[,.IT LIS,ARC() KtIPARUK (EOF) ** FILE FILE NA~E SERVICE VERSIO~ ~ DATE ~AX. REC. LEN FILE PRE~ IOUS FiLE T ,00I ** EDIT FLIC O01A02 ~8103/ 1024 ,001 3M-21,API ~ 50- 103-20094 3H-21,AP1 # 50-103-,20094 8-~AR-88 16:46:52 Page * , SCHLUMBERG[R * ALASKA COMPUTING CENTER COMPANY : INC ~ELL : API ~ - 50-103 20094 FIELD = KOPARIIK COUNTY = NORTH SLOPE STATE ~ A~ASKA JOb NUMBER AT AKCC: 72599 RU~ # ,['.~A, TE LOGGED: 1,4 FEB-88 '~ "iCl< CASING : 9.625" 0 4620' ER) TYPE FLUID = bSND-POLY~ER DENSITY : I0 LB/G ~ISCO$ITY = 43 S aiT SIZ~.3 = 8.5" TO II300'(DRILL 4,46 ~ 58 4.1B e 65 Schlumbe~,ner LIST !<TA(): [72599] LISA ,DA~r; 8-~AR-88 16~46:52 Page DF Pi.! = 8 5 R;~%C :: 3,42 9 60 FLdI!) /,DSS = 4,0 C3 ~ AT BHT = 1,907 ~ 14 ~TRIX SANDST(]~E NOTE: 1,)FILE ~OIT.O01 CONTAINS DATA OF OUAL INDUCTION (DID), FORMATiO m DENSITY (FDC), COMPENSATED NEUTRON (CNL), NATURAL GAMMA RAY SPECTROMETRY (NGT) E~EC1~ROMAGN~TIC PROPAGATION bOG (EPT) SAMPLED ~ .5' 2.)FI[,E EDiT,O02 CONTAINS DATA OF KLEiCTROMAGNETIC PROPAGATION bOG (EPT ) SA~:qPLED ~ 166' EDiT 3,)FILE 003 CONTAINS H~ RES FORMATION DENSITY (Fl)M), CO~PENSATE~ ~'~EUTRO~,~ (CNH~ SA~PLED ia 1,2 4.)F[)C AND CN[, DATA IS AFFECTED BY DETEC]70R OVERFLOW ~iI[,E DRILL PIPE C.)N~ECTIONS WEaE HADE, THESE DATA HAVE BEE~i EDITED AND LINEARLY li'~iTERPO[~ATEO OV~:R THE F()!.,LL)WING INTERVAl',S: FDC MAIN PASS - 11175 - 11172 i~080 - ~1077 10985 - 10982 10888,5 - 10885,5 10700 - ~0~97 I©604.5 - I~60~..5 10510 - 10507 10q15 .... - 10412,5 9~42 - 9939 DATA OVER THESE INTERVAL~ ~IAVE BEEN EDITED A~D REINTERPOf~ATED~ * TO REMOVE SPIKES A'I~ DRILL PIPE * CONNECTION, DATA AT THESE * INTERVALS IS INACCURATE AND * ~UST Bg USED WI H CAUTION, ************************************** CN[,~ i'.4AI~} PAS8 1(')969, - 10966, I0873 - 10870 1.1079.5 - 11077 10983 ,- 10982 10603.5 - 106()4.5 t Schlumberger I,,iS~' ~'~['A0;[7259g]LISA.f)~T; 8-MAR-88 16146;52 Page 109~7.5 - 10966 *** THIS DATA HAS NOT BEEN DEPTit SHIFTED - OVERLAYS FIELD PRINTS *** LOGS INCLUD~D ~iTH THIS MAGNETIC TAPE'- i)OAL INDUCTI{'~N SP.HERICALbY FOCUSED bOG (OIL) DATA AVAILABLE: 11204' TO 9591' DATA AVAIL, A~:~bE;: 5812' TO 4620' FO'R~ATION ~')~iNSIT'Y' COMPENSATED LOG_(FDC) DATA AVAILABLE: 11184' TO 959i ' DAT ~A AVAILABLE: 5218' TO 4586' COMPENSATE9 i*~EI)TRON LOG (CNL) · DATA AV.AII,~ABLF,: 11173 TD 959~' NATURAU (;A~!MA RAY SP~SCTROMETRJ ~?G (NGT) DATA ~VAIbABLE: 5170 ~,,) 484~' E[,ECTR(~!~AG(,~ETIC PROPAGATION b~G (EPT) DATA ,~VAIbABI~E, 5180 TO 4848' FORMATION OENSlTY COMPENSATED ~[}~ HI RES 1,2" DATA AVAILA~LEI 11170 ~.~0 10539' COMPENSATED NEDTRON' bOG MI R~'S 1 o,, (CHH . 539 , , , , , , , , , , , , , , , , , , , * , , , , , , , , , Table type CONS Listing O~ set 110 type CONS OBJNA~ TUNI, , VALU DEFI .......... .... -,,-,,,,,,.-.-,-..,...,,.,,,. ......... CM ARuu -~m~a u ~ ny Name, IN , C mpa FN KUPARUK Field ~game ~", 3H-21 Well Name Nation ~nTI STAT COUN SECT RANG LATI LONG USA AL~, KA ~2 12N SeC~ TOw ~ Longl rude ovlnce $cblumbevqer LIST mTA0:[72599]LISA,DAT; r)PER ~ALLARY Operator's Code SO~ 72599 Service grder Number APIN 50-103-2u094 APl Serial Number End o se Table type CURV Listing of set ~1~ [¥pe CURV ...... ........ ........ ........................ .--..--..-................. ..... . .... ........................... D,,PT TH CMA GR TENS [~CFT R C b~ T CFTC CgTC GR TE N S [)PHI DR~]O FFOC CALl GR CS POT,~ ~ 3~G C (; R FVR MD SFL Umaveraged Ib-~edium Resistivity Ib~Deep ~es!sttvlt~ Sp ntaneous Potent al Gamma Tenslon Neutron Poroslt[ CALIBRATED THMR AL ME[JTRON RATIO Raw Thermal Neutron Ratio RAW FAR CNL COUNT RATE RAW NEAR CNf, COUNT RATE DEAD TI~E CORRECTED FAR CNL COUNT RATE DEAD TIME CORRECTED NEAR CNL COUNT RATE Gamma Ray Tension Density PoroS2ty Delta tho 8ul~ Density ~ear MDC Cot~nt Rate ~ar FDC Count Rate Caliper Gamma Ray Tension Cable Speed Tension Uranium Thorium Potassium ~Indow 5 (2 ~!ndow 3 Clol - Window Co,~P~ted {;am~a Ray fr6$ Thorium, ~.ranium, and Potassium soectroscopy {;ammO-Ray Soectroscopy Gamma-Ray Near Voltage ~e~erence Far ¥oltaqe reference Tension barge Arm S~all Arm Hole Diameter 16146152 Page $cblumberqer LIST P~TA0:[72599]LISh.DAT; 8-MAR-88 16146:52 Paoe E d Of setn [~ata for~nat specification recoro Listing Ot set ! type 6.¢EB object 0 E ~1T R ¥ V A I, 11E ~ E P C 0 D E $ I Z E I 0 66 2 0 66 3 172 73 4 4 1 66 1 R 0.5 68 4 9 FT 65 2 ~ 5 66 13 0 66 I 14 Fr 65 2 15 68 66 l 16 I 66 0 0 66 mmmmmmmmm#mmmmmmm~#m~mmmmm#mmmmm E~d of set Listing of set o type CHAN [INIT SERVI ~f: API APl AP1 API FILE NUMB NUMB SIZE ~EPR PROCLSS C = ~ "~ ORDER ~ LOG rYP,~ CSASS MOD NUMB Eb~ SA~P CODE (HEX) DEPT FT SFI,[I DIL IL~ OIh OHMM ILD SP GR bib GAPI TENS D:I5 LB NPHI CNL TNRA C~L RTNR CNL RCFT CNL CPS CNT C~JL CPS FTC CMb CPS ~ C ~ L G A P I LB PU D~HO FDC G/C3 R~OB FDC NFDC FDC CP~ FFDC FDC CPS CALI FDC I~4 GR FDC GAPI TENS ~OC C8 ~GT F/~R TENS NGT U~AN NGT PP~ TH(JR NGI P P ~,~ ( 0 1 1 o 1 0 I 1 o 1 o I 1 o I 1 o 1 1 o I 1 o ! 0 I I 1 o I I 1 0 1 I I 0 i 1 o° 11 ~ 0 1 1 o I I 1 0 o 1 o o 1 ! 0 1 0 i o 1 1 o I 1 1 I 4 I 4 I 4 I 4 1 4 1 4 I 4 I 4 68 O0000000OO 68 0000000000 8 0000000000 8 0000000000 b8 0000000000 68 0000000000 68 0000000000 68 0000000000 68 00000:00000 68 0000000000 0000000000 o000o00000 4 68 000000:0000 4 68 o000o00000 4 68 0000000000 4 68 o000000000 68 0000000000 ~ 68 000o000000 4 68 ~000000000 4 68 .0000000000 i ,i 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000o00000 ~ 68 0000000000 4 68 0000000000 ooo ,:!ooooo 6~ 0o0oo00066? $cblumber-qer LIST 16:46152 Page 8 MD EPT I ~ 0 1 . End of set 0 1 1 I 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 I 1 4 68 O000OO0000 0 I I 1 4 68 0000000000 0 1 ! 1 4 68 0000000000 0 1 I 1 4 68 0000000000 0 1 1 I 4 68 0000000000 0 1 i 1 4 68 0000000000 0 1 I 1 4 68 0000000000 0 ! 1 I 4 68 0000000000 0 1 1 I 4 68 000O000000 0 1 1 1 4 68 0000000000 0 1 I 1 4 68 0000000000 Data record type o [)EPT .I1213.5 FT 3417.875 >~ GR 179,12~ TE~$ 9~5. aPHI .49.42854 TaRA 3.659271 RTNR ~.945i55 RCFT 433,2913 ~C~T 1731.346 CFTC ~87.9769 CNTC 1752.559 GR 179~125 TEN~ 955, OPHi 46.18523 DRHO .'0.0i378585 RMU8 ~.887944 NFDC 788, FF?~ 1.767, C~[.,I 5.7~7813 GR ~79.125 'I'E~8 9~5. CS -999,25 TEi~I~ -999,25 [}RAN -999,25 THOR 999,25 PO'IA ~999,~5 WSNG 1999;25 ~!?G -~,~ ~(] -999,25 W2NG -9 25 ~ING -999,25 CGR -999,25 ~Ga -~99,25 ~GR -999;25 NVR ~5 FVR -999,25 TENS -.,'999,25 [,A -999' 25 ~,A -999' 25 MD 25 Data recor~ type o DMPT 11113,5 FT 3387,395 DEPT 1111.3.5 SFI'..U 6,521362 2" TE~S 1850 GR 86 ~ , 1978.362 TENS i850. DP!ti 24.6065 FFDC 815,5 C~.bI 8.59315 T~;b:S -999,25 URea '999,25 ~4~OG '999,25 W3~G 999,25 SGR '9~9.25 SGR 1999,25 hA -~99.25 8~ -999,25a lb~ 6~470908 NPHI 41,03103 CFTC 608.6149 DRHO 0,02814557 GR 86.25 ~HO~ 999,25 W2NG -9~9,25 MVR '999,25 MD '999.25 TN85 ~ 8989 RTNE 3.25724~ CNTC .74 G~ 86,25 RHOB 2,243993 NFDC' 69t- TENS 1850, CS , -999,25 POTA -999,~ ~SNG -999,25 WING -999,~5 C~R -999,2~ FVR -999'25 TENS -999,25 Data record type 0 ()EPT 11o13.5 FT 3356.915 ~ ..... ""'"'"'""'"'"'"'"""'""""'"'"'"""'"'" ~F~t~ 23.53225 I.h~ 23.00264 GR 5~43~ r~a8 2234, NPHI 29'12075 TNRA 2~.65:; .96 RTNR 2. R~FT 936,5599 RC?~]J 2';35,925 CFTC 1028"702 CNTC 27'36' .5 GR 5~ TE~:$ 22]4. [:PMi 20.23~86 DRH6 -0,01964215 RH?B 2,316 NFDC ~.64,5 FF~C (~07, CALl 8.210~38 GR ' 55~4375 TE~S 2~34' CS 99§,25 Schrumberqer I, IST MTAO: [72599]DISA,DAT= 8-~AR-88 16346:52 Paqe 9 Tg{'~S -999,25 i]RA~~ :999,25 THOR -999,25 POTA -999,Y§ ~SNG -999,2§ W4"~G -9~9,25 ',~:3~G.999,25 ~2NG -999,25 '~I~G -999,25 CGR '999,25 SGR -999.25 SGR 999.25 NVR '999.25 FYR -999,25 TENS '999.25 LA -9gq,25 SA -9g~,25 t-~0 -999.~5 Data recoro tyoe 0 l~:PT 10913.5 FI 3326.435 a '''' ',,',,,,,''''''-'----,-,-------...-............... OEPT 10913.5 SFLU 15.91062 ~bN 18,~25.? I~[') 18.604t8 SP '32.46875 GR. 745625 TE~S 2150, NPH131i1661 TNRA 2.$1258 RTNR RC~T 75~,5759 RC:'~T 2417.46 ~FTC 894.8192 CNTC 2447-973 GR TE~ 2156, DPH~ 19,50452 PRHO ' "' " ' -0°004602269 RHOB 2,~28176 ~99~.2596 FF~C 6~1.5 CALl ~.445313 GR 74.5625 T~NS 2t50, ~5~'~G -099,25 ~41~ -999,25 ~3NG -~,~ ~2N(; -999,25 Wl~G -999,~5 CGR -~9g.25 SG~ -999,25 SGR :999.25 ~VR :999,25 FVR -999;25 Data record type 0 DKPT 10813.5 FT 3295,955 ~ [~,Pr 10813.5 Ib~ 11.01772 ILD 17.80727 SP -2 20313 TE~S , ~C~T 237~,18i DP~116,18238 TE~S 999~25 ~4':~G -999.25 RCFT 775.2207 T~:~$ 2050' '~ ~80.5 ~,OC CS 999,25 NP~I 30.42995 TNRA 2 ~06152 RTNR 12 CFTC 89665588 C~TC 2~8,843 Ga 8 DRHO -0. 01729721 RHOB 2 TENS 2 CA~I ~.96875 GR 82~5 ~3~G -99 ,25 h2NG -999,~2~ ~ING -99 25 C,..,R -999~25 SGR -999,25 SGR :999,25 t~VR -999,~ FVR-99925 TEN~; -99q,25 L.A -999.25 SA 999.25 HD -999, [)ata record type 0 D~.!:P'~r 1 0713.5 FT 3265.~75 ~ Gar...,, 161,3. 5 TE!~$.. 90], NP~I 46,87444 TNRA 725185 R ..... FI' 452.0922 RC!>~T !7 '12S CFTC ~0~ii746 , <'NT~ TENS 19~5, .. ~FDC 610. FFOC 6'75 CALl 8.aO4~a8 G~ 1o1,375 6617 CS -999.25 TE~S -99~,25 [/~A~ -999,'25 THOR &999,25 WLNG -999.25 ~4:i~G -99q,25 W~NG ~999~25 W2N:G -999;25 '25 SGR -999,25 SGR -999'25 NV~' -~99,2~ FVR '999 TENS -999.25 La -999,25 SA -999.25 SI) '999;25 · 9 Data recorc~ type 0 ~ ..... DER~! 10613,5 FT .3234,995 DEP,' 10~I,~,5 ~.F'!,U 2.343583 lh~ 2,63~812 iLD 2'775819 SP '11.64063 GR 110.4375 ~IF;aS I94~. ~:~H149,26~}~ 'I:~A ~3,861~:~ RTNR 4,157744 Schlumbezger LIGT ~TAO: [72599]LIS~,DAT; 8-~AR-88 16~46~52 Page 10 RCFT 395 395 RC!,~T 1~07 521 CFTC 452,4381 CNIC 1689~241 GR 110,4575 F~DC 35 ~LI ~7 GR 110.4375 TE~S 1940. CS -999,25 TuC:g$ 99~,25 {JR~N ~99 25 THOR -999.25 POTA -999,25 W5NG -999,25 Data re GU RCFT 41 TE~]S 19 FFDC 61 TE~$ -9 cord type 0 DgPT 10513.5 FT 3204,515 51125 SFI, U 3~40983 I~ 3.30105 IbD 3.294507 $~ 'I$.44511 9.1875 TE~$ 1~70. NFHI 50,80241 T~RA 3.901656 ~INR 4.395349 2,0062 RC~T 1709.748 CFTC 461,6292 CN~C !750~49 GR 119,~$75 70, DPt.t~ 18.59393 3 5 ~.bI 8.335938 GR 119.1875 TENS 1970,' CS -999,2'5 9~,25 b~A~ 2999,25 THOR -999.25 POTA -~99,25 W5MG -999,25 99,25 ~3NG 999;25 W2NG -999,25 WING -999,25 ' CGR -999~25 99.25 SGR -999,25 NVR -999;25 FVR -999'25 TENS -999,25 99:~5 SA -999;25 .HD -999'25 Data RCFT ~ F~C T E ~ S ~4~G .>kPI 10413.5 FT 3174.035 ~ record type 0 i' '~ 10413,5 $~b{ 3,666462 IL~ ~,642663 ILD 3,602438 SP 128,25 ',CE!~S 2i54, NPHI 50.34998 TNRA 3,934686 RTNR. 4.086956 391,6053 RCNT 1793;845 CFTC 460,3921 CNTC 1738,021 GR 128,25 2154, I'!FHI 20,27~53 OReO 0.008994u67 RHOB 2.315487 NFDC 627; 652.8133 CA!.,] 9,0~6875 ~R 128,25 TENS 2{54 CS -990,25 !)RAN i09~;25' ~i,~OR -999.25 POT~ -§9~:25 WSNG -999~25 -~99.~5 ~(; -999,~5 WING -999,~5 WING -999~25 ~GR -999,~5 -999,25 SGR -§99,~5 ~R -999,25 FVR -999;25 ~ENS -999'25 -999,25 SA -999,125 HD -999,25 . . ' '"' ' 5 FT 3143,555 ~ Oata record 'type 00~.~,PT 10313, GR., 222,75 TE;V$ 2080, ' ~P~I 43 7 59 TN~A 3;56788 RTNR ~'~4 RCF~ 440.2474 RC.NT I 8.027 CF~=C 49 CNtC ~743'422 G~ ,75 OR : 222 7~ TENS 2080 S~,[;RW4NG -999'999'2,25' 5 ~'3MG~. > -999 ~5 'W2NG' -999,25 WXNG -99~ oG~. -999 25 NVR -999125 FVR '99 $cbtumberoer [,IST ~TAO:[72599JLI$^,[)AT; 8-MAR-88 16546:52 Paqe 11 Data record type o DF~PT 10213,5 FT 3113,075 lq DEPT 10213 5 SFSU ~ 807.~5 Ib~ 3,91218 ILD 3,876511 SP -11-35156 GR 399.7~ TENS 660. NPHI 4~.37863 TNRA 3.430282 RTNR 3.84507 RCFT o62,2999 RCNT ~218 628 CFTC 760.07~2 CNTC 2416.224 GR TENS 2060, ~Pgi ~ 94~37! ~RH(] -0'02849991 RHO8 2,485951 NFDC 482 399,75 cs I~NS~c -999.m5 POTA -999,~5 W5N~ 999.25 SC ~' 2999'~5 {~3NG -999,25 W2NG -999,25 WXNG -999,25 CGR 999,25 .~R 999,25 SGR -999.25 NVR -999,25 FVR -999.25 TENS -999,~5 LA -999,25 SA -999.25 HD -9g9,25 Data record type n DCPT 10113,5 FT 3082.595 Oata record type 0 DEPT 1001].5 FT 3052.115 g GR , i66, ~Ei~S 1865, NPHI 45.40244 TNRA 3 R~F7 .462;0068 RC.~T 1869.304 ~FTC 50§~5197 CNTC 1 T~N~ I865, ~PHI 20.~0689 DRMQ 0,003021932 RHOB 2.30 F~?C ~57. CALl 8'92~87~ ~R 166. TENS 1~65, T~N~ 999.~5 [!RAN -999~25 ~'0 1999.25 POTA -999. W4~G -9q9,25 ~3MG -~99,~5 ~N 999,25 ~ING -999 ~G~ 99.:~,25 SGR 999 25 NVR -999'25 F'V~-999, L~ -999,~5 SA -Qq9:25 ~{D -999'25 ~ ' 5 ,25 ~.SNG '999, 5 CGR -999~ TENS -999,25 Oata recora type 0~PT 9913.5 GR. 93~875 ~.C F' ~ {~58,3727 TENS 2180. DPHI I0,I~872 DRHO 0.0444153 ~.HO~ ~.48 F[~[)C .i~i.5 CALl ~,90'25 Ga 93.875 I~NS 2180,:5 ~{ ,t a! G -999,25 8GR -999,25 SGR -999, .~5 NVR 999.25 FVR -999 42 W5NG ~999,~5 ~G'~ 999,25 ~NS '999,25 Schlumberger LIST ~TAO:[72599]LISA,DAT; 8-~AR-88 16:46{52 Page 12 bA -999,25 SA -999,25 MO '999,25 ~ata recorO PT 981 RcF'r 533 TE;'J5 211 FFDC 155 TE~S 99 w4~G 99 SGR 99 LA 99 tvpe 0 DEPT 9~13,5 F.r 2991,155 M ;;' .625 TE.~$ 2114. NPHI 37,6~ ~ 7 ~ ~9 Ti:aRA 3.290 RTNR 3.514285 3875 RCNT 1974~285 CFTC 597, 5 9 CNTC 1966, 5 G~ I~6,625 %, DP!i! 14.2209 QRHO 0,04~96~5 RHOB 2.415355 NFDC 61 ~.5m CAbI ~.671875 GR ~I6.~25 TENS 2114, CS -999 25 ~,25 UR.~'~ 999,25 THOR ~999 25 POTA -999.25 WSNG ~999 25 9.~5 W3~G -g99,25 W2NG -999 25 WING -999,25 CGR 999 ~5 g,~ S~R :999,25 NVR -999'25 FVR -999,~5 TENS -999 25 9.29 SA 999.25 .HD -999:25 Data GR RCFT TENS FFDC TENS LA record type 0 DEPT 9713,5 FT 2960.675 M 291 ~ '27.17188 q3 75 TE~S 1720, NPHI 3~,8096~ TNRA 3~ 0573 RTNR 3,294117 )~.~ '993 RCNT 2427,556 CFTC 816.915 CNTC ~3 1,531 GR 93.9375 ! 720. DPi.~I 14,4i149 DRMO -0,00191959 RH(]B 2.41~21 NFDC 568. ()0~95 CALI 9.648~38 GR 93.9~75 TENS 1720 CS ~999,2§ 99~.25 ()R.A~ -999 25 THO~ -999,25 POT~ -999,25 WSNG -999,25 -999,25 w3N(; -999 ~5 W2NG 999,25 ~ING -999,25 ~GR ~999e~5 -q99~25 SG~ -999 25 ~'VR -999.25 FVR -999.25 ENS -999,25 ~999,~5 SA -999 25 HD '999,25 File Data TENS FFDC W4NG trall, e record type o LLF~ 9613,5 FT 2930,t95 ~ i40,i2"~ lE~:'t~ 2045, , N~Hi[ 48,54.51 TNRA 3'853177 ~TNR 4.18 ~23~93 RCN~ 1875,489 C~TC 509,22~ CNTC: 189'8,99 GR 140, 25 2045. DP~ti[ .1'1.66286 DRH[] O,Q~q}l RHO8 ~.35§563 ~FDC 618~ 594,5 CALl 9.25 ~a 140~I2~ TENS 2045,, C$ , &99~ 2:5 99~,25 l-iRAN -999,25 tHOR -~99,25 POTA -999L25 h5NG -999,~5 ,25 W3r~l(; -999,25 W2NG -999,~ WING -999,25 CGR -999,25 8GR -999'25 MVR -9~,25 FVR -999 25 TENS -999,25 -999.25 SA -999.25 HD -9~9,~ ' r ~ D [ T 001 . ~ SchlumberQer LIS? iv~'.TAO:[725993LISA.DnT; 8-~IAR-88 16:46:52 Page FILE NA~E : EDIT SERVICE ?tA~+E : FLIC VERSION ~ : O01A02 DATE : 88/03/ ~AX, ~EC. LEN. FILE T'~PE : LO NEXT FILE .00! FILE ~LR #PR ,NC # · PI_UiulT6 MAXPI MINPI ''''''''76~ .............. 769 0 DEPT 3417, DEPT ',1. I~ 1345620 1150§00, {EOF) File header EDIT ,002 ** FILE HEADER ~ FILE NAME : EDIT SERVICE NA~E : FLIC VERSION # : O01A02 DATE: : 88/03/ ~AX, REC, bEN.I 1024 FILE T'~PE : L~ PREVIOUS FILE : (O2 Table type CONS bLsting of set 2 type CONS V A L U OBJN A~,~ TUNI CN ARCO ALASKA, . F~'~ K[,IPAR[tK ~N 3H-21 ~ell Name ~,~ A T i U S A ~"~g a t i o n o~a, ALASKA State or Province :UUh NORTH SLOPE CouBt TO~t~ 12N Towns~ p ~AN(; 8E ~ange I'.,ATi Latitude bONG 5ongitude . . {.~PgR ~ A [.,t.~A~ ~ ~perator'S Cooe '~o~'~ Service Order Number APIi'~ AP1 Serial Number End of set $chlumberfler hIST ~TA0:[725993btSA.;>AT; 8-~,~AR-88 16:46:52 Paqe Table type [,/stlnq of set 3 type CdRV FI .~ PT I)FPTH CHA S~'bU SFL Unavera~ed IL~4 IL-~edium Resistivity SP Sp ntaneous Poteni al (;g Gamma Ray TEN~ Tension t,~PH I {'~eu t ton Porosit~ T~RA CAblBRATED THER~,~IAL i~EUTRO~ RATIO RT~R Raw Thermal :'~eutron Ratio RCf'T RAk~ FAR C~{L C~')U{',}T RATE RCNT RA~' ~EAR C~I., COU~'~T RATg CFTC DEAD TIag CORR5;CTED FAR C[~L COUNT RATE CNI~C OEAO Ting CORRECTED t*~EAR CNL COUNT RATE GR Gamma Ray TENS Tension DPMI Density Porosity DRHO Delta tho RHOB BUlk Density ~IFDC {,~ear FDC Count Rate FFDC Far FDC Count Rate CALI Caliper GR Gamma Ray TE~,,~S Tension CS Cable Speed TE~S Tension URAN uran~ um TMON Thorium POTA Potassium %~;5~G window 5 (2 - 3 ,~EV) ~'4~G win~ow 4 (1.6 - 2 ~EV) W2NG Wi~dow 2 CGR Com~uted frown Thorium, uranium, s, a~d Potassium S~R Spectroscopy ~ Ray GG'~ spectroscopy Gamma-Ra9 ~{V'R ~ear Voltage Reference FVR Far voltage reference T~$ Tension LA Large Arm SA Small MD ~ole Diameter ~:nd O~ set 14 ( SChlumberger I, IST MTA0: [725993blSA.DAT; Data format speciflcmtion recorO sting of set 3 type 64EB NTRY V~LUE REPCODE SIZE 0 66 ~ hi 2 0 66 3 172 73 4 4 1 66 1 ~ 0 5 68 4 11 5 66 ti 0 ~6 1 14 FT 65 2 15 6~ 66 1 16 1 66 1 0 I 66 1 Ehd of set object 0 8-NAR-B8 16;46:52 Page 15 Listing of set 0 type C~am ..... '"'""::: t") E p T F T o 2 SFLU DIL OHMM 0 2 ILM DIL (3H~ 0 2 ILD DIL OH~,~~ 0 2 SP DIG ~ V 0 2 ~R DIL GAPI 0 TENS OIL [.,,B 0 2 NPHI CNL PU 0 2 T~RA CNL 0 2 RTNR CNL o 2 RCFT CNL CPS 0 2 RCNT CNL CPS 0 2 CFTC CNL CPS 0 C~TC CNL CPS 0 2 GR C~L GAP1 o 2 TENS CNG LB 0 2 DPHI: SAN PU t') 2 DR~O FDC G/C] 0 2 RNOB FDC G/C] 0 NFDC FDC CPS 0 2 t~, DC FDC CPS CAb] FDC IN 0 2 GR FDC GAPI: 0 2 T,..~S FDC b~ 0 C S ~ G T F / H R 0 URAN NL, T PP~ 0 2 T~'O~ NGT P'P~ 0 2 PoTa NGT PU 0 W5~G NGT CPS 0 2 W4NG ~GT CPS 0 2 ( IDE . Q~B NUVO SIZE EPR PROCESS ~UM8 ELE~ SAMP CODE (HEX~ 1 4 68 0000000000 I q 68 O00000000O ! 4 6B 0000000000 4 68 O000000~OO ~ 4 68 0000(~00000 I 4 68 0000000000 1 4 68 OOO0OO0()O0 4 68 OOOO000000 ,. 4 68 0000000000 I 4 oooooo:oooo 4 68 o000000000 ~ 4 OB 000000000'0 ,1 4 68 0000:.)000o0 4 68 o0ooooo0o0 4 08 oooooooooo I ~ 68 0000000000 ~ 4 o~ ooooooo666 4 68 00:(~0000000 ~ 4 68 0000000000 4 68 0000000000 4 68 0000()00000 4 68 0000000000 ~ 68 0000000000 I 1 4 68 0000700000 1 1 4 6~ OOOOjO0000 } } ~ ~ 0000000000 ~ O000000OO0 ~ I 4 ~ oooooooooo i 4 ~ 000ooooooo ~ ~ 4 6~ oooooooooo ~ 4 ~ oooooooooo ( , ( $cblomber'oer LIST ~3NG NGT CPS w2NG NGT CPS WING NGT CPS CGR ~GT GAPI SGR NGT GAPI SG~ EPT GAPI FVR EPT V TENS EPT LB SA EPT HD EPT IN 8-MAR-88 16146~52 Page 0 2 I ! 4 68 0000000000 0 2 ! I 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 1 1 4 68 0oo0000o00 0 2 1 ! 4 68 0000000000 0 2 I I 4 68 0000000000 0 2 l 1 4 68 0000000000 0 2 I 1 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 i 1 4 68 0000o00000 0 2 1 1 4 68 0000000000 0 2 1 1 4 6~ 0000000000 End o~ set Data record type o DEPT 5850, FT 1783.08 ~ DEPT 5850. GR -999.25 RCFT -999.25 TE~i$ -999 25 FFDC -999 ~5 TENS -999 25 W4NG -999 25 S(;R -999,25 LA -999.25 SFLLt -999 25 TENS -999 ~CNT -999 DPHI -999 CALI -999 [1RAM -999 w3NG -999 SGP -999 SA -999 Ib~ -999,25 25 NPHI -999,25 25 CFTC -999.25 DR!:{O -999,25 25 GR -999,25 25 THOR -999,25 25 W2NG -999,25 25 NV~ 25 HO ILD -999,25 TN~A -999,25 CNTC -999,25 RHQB -999,25 TENS -999,25 POTA -999 25 W1NG -999 25 FV~( -999,25 SP '999,25 RTNR -999,~5 GR -9991 5 ~FDC -999:25 CS -999,25 ~:5NG -999,25 CGR -999~5 TENS -999,25 '"T FT 1752.6 ~ Data record type 0 DE, F 5750. DEP.~ '5,50 c.~bU 3,834093 G~. 1.05.625 TENS 3024 RC~T -999.'52; RC~ "~' -~99 ~5 GR TF~S -999,25 DPHI -999 25 ORHO -999.25 RHC)[~ 25 NFDC 25 FFDC -999.25 CALI -999 2. GR -999,25 TENS .99 25 TENS -999,25 [3RAN -999 25 THOR -9~9.25 POTA -99 25 ~4NG -999.25 ~3~',~'G -999 ~5 w2NG -999,~5 WING -9 25 CGR -9:9:9 SGR -999,25 SGR -99q 25 NVR -9~9.25 FVR -99 25 TENS -9 99 LA -9.99 ~ 25 SA -999 25 MD , · , ' 7 '' Data record type o OEPT 5650 F~ i 22.12 TENS -999, FFDC -999~ TENS -9~9 W 4~G -9'99 SGR -999 25 25 25 25 25 25 SFbU 3.82655 TENS 2970 RC~ -999 25 D[~Hi -999 25 CA.hi -999 25 k!~Ai~ -999 25 ~3NG -99q ~5 Daao -999,25 aaoD , 999,.2 ~R -999'25 TEN8 999, ~5 25 W2~G -999,~5 WING -999, NV '999.25 FVR -999. a '999, 'R ~FDC kC8 ,999 5NG "999 ENS -999 Schlumberoer I~IST ~TAO:[72599]LISn.DAT; 8-~AR-88 16:46:52 Page 17 LA -999,25 SA -999.25 HO -999.25 Data record type DEPT 5550, GR 1~ 1 , i875 RCFT -999,25 TE~S :999,25 FFDC 999,25 TENS -999,25 W4NG -999,25 SGR -99g,25 LA "999,25 0 DEPT 5550. FT 1691,64 M '"' ...... " .... '"'"i" '"' :'!: ! TENS !890, NPMI 9 .2 TNR 999 25 ~CNT 999~5 CFTC 99.2 CNTC 999,25 [)PHI -999,25 DRHO '999,25 RHOB 999,25 CAsI -999.25 GR '999,25 TENS ~999,R5 U~AN '999,25 THOR '999,~5 POTA -999,~5 !43i~G '999.25 dRNG '999. 5 WING ~999,~5 SGR ~999,25 MVR '999,~5 FVR -999,25 SA 999.~5 HD -999.~5 '''''''''''''';i''6GRRTNRSPNFDC '999,'46'.999,.999, CS -999,i5 WSNG -999, CGR "999, TENS -999,25 106. -999,25 ~999,25 999.25 -99q,~5 -999,~5 0 D~PT 5450. TENS ~§64, RCNT 999,25 OPitl -999~25 CAbI -999,25 [JP~!~ -999;25 G~ 999,25 1661.16 M IhS 3,986966 ~PHI -999,25 TNRA -999. 25 CFtC 999,25 CNTC '999~ 25 DRHO-999,~5 RHbS -999 25 GR -999,25 TENS '999 25 TI{DR -999,25 PUTA -9.99 25 W2NG -999'~,5 WlNG -999 25 NVR -999",2,5 FVR -999 25 5 SP '49.59375 RTNR -999,25 NFDC -999,25 W5NG -999,25 TENS 999,25 Data record type ....... RC. FT '999,25 ~DC -999,~5 ~LNS 999,25 LA "999 00EPT 53'50, FT 1630,6.8: M ~--...-... ....... ~---.~....~, ...... .................................... ,3FLU 5.109818 Ib.~. 5.99~.~9 IbP 6,10574 SP ~52. '5. .t.L. o 2940, [~PHl -999 25 TNRA -999,25 R~'NR '99~ ~5 RCNI -999,25 ' * " ....... - '"* ' C~TC -999 25 C~TC -999,25 GR -999 ~5 DPH] :999,25 D~HO '999 25 ~}':i(.!B -999;~5 NFDC -99~ ~5 CALI 999~25 GR :-999. ~5 I'ENS -999,25 ~S '999 25 UPAN-999:25 THO~ -999 25 POTA -999,25 W5NG -999 25 ~G-999,25 W2NG-999 25 WINO -999,25 CGR -999 25 Su~ -999,25 NVR -999 25 FVR -999;25 TENS -999 2~ SA -999,25 HD -999 25 Data record type 0 DE:PT 5250, FT 1600,2 ~ ' ) .... 55.90625 GR 85.12~ TE~S.. 2970, NPHi 999.25 TNRA -999'25 RTNR :999,25 R~T -999,2§ RC~T '99~,25 C~TC-999,25 CNTC 2999,25 G.~ -999,2~ TF]{,}S -99g'25 [)PHI '99 .25 D:RHO -999'25 RHOB 999~25 N~DC-999~25 FFDC -999,25 CALl -999,25 GR -gg9'2:5 TENS -999,25 CS -999,~5 Schlumberger LIST ~T.A0:[72599]LISA.[Al.:J '~ 8-MAR-S8 16:46152 Page I8 TENS -999.,,525 U~AN -999,25· T~{OR -999.25_ POTA -999,25 W5NG -999,25 W4~qG -g99,2. ':{3f~G -99g,25 ~2NG -9q9,25 WlNG -999,25 CGR -999,25 SGR -999,25 SGR -999,25 NVR' -999,25 FVR -999,25 TENS -999,25 LA -999,25 SA -999,25 H~ -9Q9,25 · Data DEPT GR RCFT T~NS FFDC TENS W4NG SGR LA record type 0 DEPT 5150, FT 1569,72 P 5150, SFt,U 20 40034 ILM 23.64554 ILD ~9.59301 BP -78.~75 62.0625 TENS 29~0, NPHi ~6.5~]76 TNRA 3,401908 RTNR ] 507692 )80~, DP!'~133-z~197 DRHO 0.00213849 RMOB 2.101013 NFDC 7105 1076. CAb11403906 GR ~3.1~75 Tf~.NS 3804, CS 88~ 2644, URAN 2 ~58654 THOR 6,97731 POTA 1.740946 WSNG ~ 24{09 4192872 ~3~,,G 2~.10901 w2NG I1~1593 WiNG 256.~134 CGR 2644.5§'66484 7! 87364 SG~ 7~ 87364 NVR 4, 1875 FVR 0.734863~ TENS $_ ~59375 SA 2.615625 HD 7,37b Data recor~ type o DEPT 5050. FT !519.24 ~ OEPT 50~o SFhU ~04,0979 !LM 121.8064 ILD 137 ~317 SP -9 25 GR 56 4~'75 TENS 2974,7 NPMI 28.07209 TNRA 2 9~737 RTNR ~ R~T ~C~T 2215 51 CFTC 80 CN~C 2'~,557 GR ~ TE,_$ DPM122.~882 DRHO -0 RHOB ~84214 NFDC ~P )C ~79.5 CALl ~7 9688 TENS 84 6128~ U~AN ~ 943 937 56 266~_722 w3N(~ ~ 15~09375 Sa 0 I~ CS TENS W5NG ~4NG CGR SGR Data recor<~ type 0 L. ,P'.~ 4950, FT 1.50876 M e:pT 4 5o. "'"'''""'''""'""'""''""'""'''""'"''"""'""'"""'"''" R(.~.F 37o,4..>! · -~. ; .' .... :..' ' . ,", ..'" . ' : GR 106,0625 TE:..~S 3584. DP~I 26,51333 DRHO 0,02620658 RHOB 2.21253' NFDC 7 7 F~DC 877, CA.[~I 13,64063 GR 106 0625 TENS 245q, {.IRAN 2.3.64308 T~O~ 1~,~ ~7 ~OTA 2 ,~? 8 W~G 8.359455 ~3~G 5~.29~5~ W2NG 13~' 2 ~iNG 3 SGR 97,9993 SGR 97.9993 NVR 4,X' ~ LA 14,.1.0938 SA 0,8066406 HD ~' 8 Data record type 0 D~PT 4850, FT 1478.28 s~ D~PT_ 4850, S~L~. 3,9724.17 IbM 4,751721 ILD 5,18948 SP -'70 5 GR 97.~875 TENS 2554, NPM144'997~9 TNRA 3,~46318 RTNR 4,24117 Schtumberqer LIST ~TA0; [72599]LISA,DhTl RCFT 422 2387 RCNT 17.00 625 CFTC 464,3777 Tf~S 3~9~ DPHI 26 518b DRHO 0.0244571 FFDC 874 ~ CAI.,I 13 3i25 GR 108'9375 'tENS 241~' UR.AN 3 ~53031 THOR 11,5048~ W4~G ~4 6{]78 S3aG 4g 02902 ;~2~G 176.4092 Sr;R 10g~9021 SGR 10~' 9(')21 SVR 4.175781 bA !2' i875 SA 0.8~66406 MD 13,53125 8-NAR-SB 16546:52 Page C~C 1746,133 G~ I08,9375 RHOB 2.212115 aFDC 704.5 TENS 3294. CS 2.2252]8 WSNG 9,394571 POmA 1890. ~iNG 319.4t54 CGE 81.35522 FVR 0,7382813 TENS 2414, 19 Data record type 0 D..Pf 4750. f'T 1447.8 ~ '"' '"';'i .... '"'""""'"'""'""'""'"'"'""'"'"'"'"""'",oo. DEP; ;?50. ';~ ; ;;62 I[,~ 3.944231 ZED 4,008445 $~ '68.25 Ga 90,31 5 TE{gS g , NPHI 42,53561 TaRA 3.687838 R.rNR 4.285714 RCFT 465.414 RCgT 658 ~12 CFTC 480,2586 CgTC 1704,604 GR 104.6875 TENSB3440' !)PHI 6 ~ 14 ORHO 0.02i40079 RMOE 2,21i015 aFDC F~DC '70, CAI, I !2' 9844 GR 104,6875 TENS 3440. CS -999,25' TENS ~99g,25 iJR~{~ 9~9,25 THOR -999.25 POT~ -999'25 W~NG -999,25 W4NG~999,25 W]NG -999,25 ~2NG -999'25 WING -999,25 C~R -999~25 SGR 990,25 SGR -99g,25 NVR -999'25 F¥R -99g,25 TENS -999~25 LA 999,25 SA -999,25 HO -999'25 Data record type 0 D~PT 4650, FT lqlT.].~ ~ '"' .... . o ooz G~. 99,5625 TENS 2504, NP~,I 48.59511 ~R~ 3;99519~ ~N~ 4,2~595 ~T 340.0383 RCNT 1616;834 CFtC 403,4346 CNTC 160~,351 GR 98 ~5 YENS 356~, DPHI 27'02485 DRH(~] 0'~0~29470~ R~O~ ~6~9 ~;DC FFDC 910,5 ~AbI 11.5 G.~ 98,5 TEN~ 3564, CS TENS-999,25 dRA~'~i-999,~5 T.~iOR-999,25 ~OTA '999'25 m5NG b4NG -999.25 ~3NG -999,25 W2NG -999,25 ~.~I~G -999,25 SGR -999,25 SGR ~999,25 NVR '999,25 FVR -999~25 bA -999.25 SA 999,25 HD ~999~25 File trailer EDIT .002 FILE NAME : EDIT ,002 SERVICE NA~E : FLIt VERSION ~ : O01A02 D~TE ~ 88/03/ 8 MAX. REt, LEa.. 1 24 FILE T Y P[,i : NEXT FILE ( ( ( Schlumberger, LI'S"r ~.~TAO:[72599]LISA,DAT; 8-~AR-88 16)46~52 Page 20 ( EOF ) File header ** FILE FILE NA~ SERVIC~ NAMfl VERSION ~ DATM ~AX, REC, LEN. FILE TYPE PREVIOUS FILE IT ,003 R ~ EDIT : F~,IC : O01A02 : : 1024 : ,003 Table type Listing OBI STAT' COiJ~ S~CT RAHG L A T I bONG ftPE~ CONS of se T[}~ I t 2 type CONS VALU DEFI ARCQ AbAS':A, INC, Compan~ Name KUPARUK ~'~ie Id .lame 3H-21 Well Name LISA Natlon ALASKA State or Province NORTH Sb!.)PE Count 12 SectiOn 12~! Towns~]ip ~E Range Latitude MALLARY 72599 50-103-20094 Code Service Order Number API Serial NumDer End of set Table type CURV bistlng of set 3 type Ct.)RV OMO t~iA Fi r)~FI DEPT f)~PTH CHAHNEL NAM~ ~IVU Near Voltage UP FvU Far voltage up ~VD Near Voltane ~own FVO Far voltaqe dnwn EATT ~PT Attenuation $chli~mberqer LIS? MTAO: [72599]LISA,DAT: TPL Time of propac~ation in loss¥ formation EPHI EPT porosity ~IMv )4icro-Inverse Resistivity End of set Data format specltication record Listing of set, 5 type 64Ek,% object 0 E~)TR¥ VALUE REPCODE SIZE I · 66 1 0 2 0 66 3 4O 73 4 4 1 66 R (.),.16666~73 68 9 F 65 2 il 25 66 13 0 66 14 ~T ~5 2 15 68 66 1 16 I b6 1 0 1 66 I of set 8-~AR-B8 16~46~52 Page 21 5lstln9 o~ set 0 type CHAi~ ID ORDER ~ LOG TYPE CLASS MOD NUMB ELEM 6AMP CODE (HEX) ,~;"~. ~ ....... ~ ............. '"' .... " ...... o' .............................. ~ ~ ~ ~ ~. oooooooooo' .... ' 0 3 I I .4 68 0000000000 ~¥U EPT V FVU EPT V NV'D FPT EATT EPT DB/~ TPL EPT N$/~ EPMI EPT PU ~INV EPT ~0~ EPT OHM~ 0 3 I 1 4 0 ! I 4 0 3 I I 4 0 3 1 I 4 0 3 i I 4 o 3 I I 4 o 3 1 I 4 68 0000000000 68 0000000000 68 ~000000000 68 0000000000 68 0000000000 68 O0000OO000 ~B O0000OO000 0 3 I 1 .4 68 0000000000 set Data record type 0 DEPT 5204,333 FT 1586,281 ~ '"'""!"' ..... '""i""'""'"'"'"'"'""' .... DE..T 520 ,3~3 ~Vt) ,0~8359 FVU :0,487793 i NVD 0 E~,.iI b7.578i3 ~I,~V 0'3286133 aNOR O' Schlumberger LIST ~TA0:[72599]L[SA,DAT: 8-MAR-88 I6146:52 Page Data record type 0 DEPT 5004,333 FT 1525.32! N "' ..... '"'"'" ....... !" '""'"'!' "" '~ i" '"'~;r'~: ;'~ii EATT 137,25 TPL i~ 95,313 EPHI 1~ 4043 ~IN 0 3286133 MNOR 0,~3~15 5 Data record type 4 FVD 0,357¢219 EATT 284,5 iFPL 15,7 ~ EPH~ ~ .~ ~ ~,32~13~ NNOE 0;03515625 Fil. e trailer Et)IT .0<)3 ** FILE TRAIbER FILE NA~E : EDIT .003 SERVICE NA~E : FLIC VERSION ~ ~ 001A02 D~TE : 88/03/ UAX, REC~ LEN.: 1024 FILE TYPE : ~E×T FILE FILE ~,LP ~PR ~f,,~C gDR ~FM PI PI.UN .... TS ~AXPI ~tlNPI 92 93 0 86 21~8 DF]PT FT 52]4~{ 3 4 DEPT .M 1586 1~7'1 2!~ (EOF) File header EDIT ,O04 ' ' N FiLE NA~,E : EDIT 004 SERVICE NA~E : FLIC VERSION ~ : 001A0~ DATE : 88/03/ 8 MAX. REC, L,.;t~.: 1024 FI.L~: TYPE I LO PREVIOUS FILE $cblumbePqer LIST ~iTA0:[72599]I, II;&.DAT~ Table type CONS OBJNA~:~ TUNI 'VALU DEF~ '"'"'"'""~'~'x~';;x"~:'"~:~'"~.~ ~.~,~~ ~ ~ . ~. ~ ~'~'~ .... '"'"' w~l IH-21 Well Name ;',! A t' ] USA Ma t I on ,STA'I ALASKA 8tare or Province Co!JL NORTH SL(] F F, County 7'O ~' ~(~ 12N RA~G 8E Range bONG Longitude {]PE~ ~,~ALLA~Y operator's Code So~ 72599 Service Order NumDer ~PI~ 50-~o3-2oo94 API Sera, al Nu~ber End o~ set Table type CURV b~stl, ng of. set 3 LyPe CURV F)EP~ f EPI~H CNANN iL ~ P H I. r,~eu Cron Porosl}~ RTN~ Raw Tbe. rma3 N~Utro~, Ratio RCFT RA~ FAF~ CNL COUe~T PATE RCNT RAW NEAR. CNL COUNT RATE CFTC DEAD TI~Ig CORRECTED FAR CNb COUNT RATE CNTC DEAD TI~E CORRECTED NEAR CNL COUNT RATE C;R Gam~a Ray TENS Tension DP~I Density Porosity DRHO oelta ~FDC ~ear FDC Coua~ Rate FFDC Far FDC Count CALI TENS Tension ~nd oi set 8-~AR-88 16t46:52 Page 2¸3 $chl~mberoer LIST MTAO: [7259q]LISA.DAT; {Data format specification record Listing oi set 7 t~pe ENTRY VALUE RE,, CODE I o 66 2 0 66 3 72 73 4 4 !. 66 ! 8 0,09999999 68 9 FT 65 2 11 14 66 1 !] 0 6~ 1 14 FT 55 2 15 68 66 1 16 I 66 1 0 1 6b 1 B End of set o~Ject 0 8-MAR-88 16146{52 24 bistlng of set 0 type CHAN init SERVICE API APl AP1 AP1 ID ORDER ~ LOG TYPE CbASS NOD NUMB I)EpT FT 0 4 ~PH! C~H PU 0 4 TNR~ C~ 0 4 RTH~ CNa 0 4 RCFT C~ CPS 0 4 RC~T C~H CPS 0 4 CFTC C~H C.,aP~' 0 4 C~TC C~ CPS o 4 G~ C~ G~P~ 0 4 T~NS C~h LB 0 4 [)PHI FDa PU 0 4 ORHO FDH G/C3 0 4 RHOB F~H G/C3 0 4 NFDC F'DH CPS 0 4 ~)C [o~ cps o 4 CILI FD~ .IN O 4 ~E~S POH (;A~I u 4 End oi set EL, MN SAMP CODE (HEX) oouooooooo 68 ~ooooooo0o 00o0000000 68 0000~00000 68 uoO(~O00000 68 0000000000 oB 0000000000 O000000OO0 ()o00000000 6:8 0000000000 68 000o000000 68 0.000000000 0000000000 08 0000000000 68 ooo0000000 68 0:000000000 o000000000 i 4 68 0000000000 . 9E,{-r ti200,1. FT 3,413,79 Data record type 0 .987456 RCFT 438.6476 RC~)~ 1772,025 CFTC 494,0092 CN 179~936 : 4~: ~ ~. ,,,., ~ ,. · ~' ~ TC ~.:. ~ .~ ~, ~2,5 TEN~ I850, OF}~I q9,8365~ ~)R.H[] -0,62082053 RHO~3 I~2978 i:'~Fi~C 799,5 FFDC 2014'; CAbI 4,492188 GR a2.5 TE~$ ~85~,' ....... Schlumberger LlSq~ ~TAO:[72599]LISA.OAT; 8-~AR-88 16146;52 Page 25 Oata record type 0 [>5;PT 111o0,I FT 3383.31 M DEPT 11100 1 ~P~{I 37 ]~1623 TNRA 3,095936 RTNR 3 ~82759 RCF'T 60i.625 RCNT 2039_~ __~27 CFTC 66~ 834R CNTC 2026.164 GR 9~.3125 TEN~ 2035, DPHI 2~ 0~025 DRY{{] 0 0~)7484442 RHOB 2,285969 NF'~C 640.5 FFDC 699, CAbI 7.~94531 GR 9}'3125 TENS 2035. Data record type 0 DEPT ~1000,i ~T 3352,83 M "i '"""'"'"'"'"'"'""'"'"'"'"'"'i'"'"'"'"" Data record type 0 D~:PT 10900,.I FT 3322,35 ~ '''' ~I 32.31036 TNRA 2,9065'79 RTNR 3.367386 RCFT 734,3143 ' '"'""'""'"'"'"'""'""'"'"""'"'""'""'"'"'"'""'" "" RCNT 2391~51 CFTC 822,13~1 CNTC 2342,85 Ga ×9,5625 TEN~ 177'6, DPHI 15,1~ 5'7 [)PHO -0.004254i~42, RHOB 2.399776 NFDC 567, FFDC 513,. CALl 8,664.06.3 GR 79,5625 TENS 1770, Data record type o DEPT 10800,I FT 3291,87 M .... ................................................................. E. T 807,1 NPH! 38,45609 TNRA 3,252951 RTNR 3.75 R 'CF~ 61{-461~~ RC~T 1924 B57 CF~.C 639.6.383 C.'~rC 2073,613 ¢.,R 77, T~NS 1935' DPHI 1.0,82588 DRanO-0,0120964 RMOB 2,47152 NFDC 520,5 FfDC 4~, CAbi 8,648438 GR 77' TENS 1935, Data record type 0 OEPT 10700.1. FT 3261.~g ~ DEPT 10'?00~ i~PgI 52.83411 TNRA 4,02574 RTNR 5.4 _ RCFT 418 2446 RCNT I599' CFrC"~ 423~1~93" C~C~' ' I691,433' '' GR"~ ' 1t9,9375~ TENS' 1996, Data record type 00EPT 10600,1FT 3230.91 EPT 10600,I RCNT 15~7,37 CFTC 45 9292 Ci~TC 1~q7,~4~ Sch !~]mber. qer LIST File trailer ** FILE IRAILE FILE NA~{E : SERVICE ..N A ~ E : ~ ERSION ~ DATE ~A P!~ REC, L, EN. TYPE NEXT FILE O: [?2599]LISA.DAT: 8-i4AR-88 16J46~52 Page 26 5313 G~ 10~.i~75 T E ~.~; 1920. IT ,004 EL)IT ,004 FL, IC O01 ~02 8~103/ 8 1024 F'IbE SUmmARY . 479 480 0 473 6617 DEFT rt 1.12oo 1. 10538 DEFT ~ 3413 ~9 3212 OEFT .lI~ 1344~12. F) Tape trailer 72559 ** TAPE TRAILER ** SERVICE NAME : EDIT DATE : 88/03/ B ORIGIN : FbIC T~PF NA~E : 72559 CONTINUATION #: i NFxT TAPE : CO,PENT I EDIT LIS,ARCO KUPARUK 3H-21,API ~ 50'103"20094 TAPE 'FIL~S 4 l, B50 1~62 Reeltraller 72599 ** RFE:L TRAIDER ** SERVICE i~A~E : EDIT DATE : 88/03/ 8 ORIGIn.! : FLIC REEL NA~E : 72'599 CONTINUATION #: NEXT ~EEL ~ CO~EMT : ~I)IT LIS,ARCO KUPARU~<~ 3H-21,API # 50-103-20094 $chtu.~berqer I,IST ~iTA0:[72599]LfSA.D.AT; 8-SAR-08 16~46:52 Page 27 ............ .... . ..... ....... .... FILES. '''''''''''''''''''i'''''''''''''52 1864 (.EOF) (EOD) ........ .... . .... ..............~... .... 4 1 I 1852 1864 ! ' End o~ list~n~) ~T~O:I'7~sg9]LISA.DAT; . , .. · RECE]VEI) VERIFICATION blBTING LIS TAPE VERIFICATION LISTING bVP '010,M02 VERIFiCATIOg LISTING PAGE ** REEL HEADER SERVICE NAME :8810211? REEL NAME 572599 CONTINUATION # SOt PREVIOUS REEL COMMENTS :EDIT ** TAPE HEADER SERVICE NAME DATE 588/02/17 ORIG~N :7259 TAPE NAME CONTINUATION # :01 PREVIOUS ~APE : COMMENTS ,EDIT LIS,ARCO KUPARUK 3H-21,AP! # 50-I03-20094 EOF ** FIbE HEADER ** FILE NAME IEDIT ,001 SERVICE NAME : VERSION # : DATE :~ HAXIHU~ LENGTH I 1024 FILE TYPE ~ PREVIOUS FILE : ** INFORMATION RECORDS CONTENTS UNIT TYPZ CATE SIZE CODE CN : ARCO ALASKA, INC, 000 000 017 065 WN : 3H-21 000 000 006 065 FN : KUPARUK 000 000 008 065 RANG: BE 000 000 002 065 TOWN: 12N 000 000 004 065 SECT: 12 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 006 065 CTRYI USA 000 000 003 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE RES: E 000 000 001 065 * COMMENTS ** ******************************************************************************** ~VP '010,H02 VERI~Z~ATION bIS?ING PA~ ~ * SCHLUMBERGER * ALASKA COMPUTING CENTER COMPANY = ARCO ALASKA INC WELL = 3H-21 API# = 50-103-20094 FIELD = KUPARUK COUNTY = NORTH SLOPE 8OROUGH STATE -- ALASKA dOB NUMBER AT AKCCI 72599 RUN MI, DATE LOGGED= 14-F~B-BB EDP: RIC~ KRUW£LL CASING TYPE FLUID DENSITY VISCOSITY PH 9.625" ~ 4620' bSND'POLYMER 10 LB/G 43 $ 8,5 4,0 C3 MATRIX SANDSTONE ~0 11300'(DRIbbER) NOTE= :1,)FILE EDIT.O01 CONTAINS DATA OF DUAL INDUCTION (DIb), FORMATION DENSITY (FDC), COMPENSATED NEUTRON (CNL), NATURAL GAMMA RAY SPECTROMETRY (NGT), R/~ = 4.46 ~ 58 DF RMF = 4.lB {a 65 DF RMC =3; 42 9 60 DF RM AT BHT = 1,907 ~ 145 DF LvP 'O10,H02 VERIFICATION LISTING PAGE ELECTROMAGNETIC PROPAGATION bOG (EPT) SAMPLED 2,)FILE EDIT,002 CONTAINS DATA OF ELECTROMAGNETIC P~OPAGATION bOG (EPT) SAMPLED ~ .166' 3,)FILE EDIT.O0] CONTAINS HI RES FORMATION DENSITY (FDH)~ COMPENSATED NEUTRON (CNH) SAMPLED ~ THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS It:~CLUDED WITH THIS MAGNETIC DUAL INDUCTION SPHERICALLY FOCUSED bOG DATA AVAILABLEt 11204' TO 9591 DATA AVAILABLE{ 5842' TO 4620' FORMATION DENSITY COMPENSATED LOG CFDC) DATA AVAIhABLE{ 11184' TO 959 DATA AVAILABLE{ 5218' TO 4586' COMPENSATED NEUTRON LOG DATA AVAILABLE~ 11173' TO 959~' DATA AVAI~ABbEI 5210' TO 4586 NATURAL GA..A RAY SPECTRONETR¥ LOG (NOT) , DATA AVAILABLe{ 5~70' TO EI, ECTROMAGNETIC PROPAGATION bOG (EPT) LYP 'OIO,H02 VERIFICATION LISTING PAGE DATA AVAILABLE: 5180' TO 4848' * FORAATZON DENSITY COMPENSATED LOG HI RES 1,2" (FDH) * COMPENSATED NEUTRON'LOG HI RES 1~#(CNH~ * DATA AVAILABLE: i1160' 10559 * ~* DATA FORMAT RECORD ~* ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 I 66 1 8 4 73 60 9 4 65 ,lin 16 ! 66 i 0 1 66 0 DATUN SPECIFICATION BLOCKS MNE~ SERVICE SERVICE UNIT API API API API FILE SIZE SP~ REPR DEPT SFLU SP GR TENS DIh GE FDC TENS FDC CALl FDC ~H00 FDC )RHO FDC )PH! FDC {FDC FDC FFDC FDC TNRA CNU RTNR CML NPHI .CNL RCNT CNh RCFT CML CFTC CML PROCESS ORDER # hOG TYPE Ch,ASS NOD NO,., CODE (OCTAL) oo ooo oo,, o o 4 oooooooooooooo OH~ O0 220 O1 0 0 4 i 6800000000000000 O.M~ 00 ~20 ~ o o ~. 1 o~ oooooooooooooo o... oo~2o ~4 o o ~ ~ os oooooooooooooo ~v oo olo o! o o 4 I 08 oooooooooooooo o~ oo ~ol ol o o 4 i o8 oooooooooooooo ~ oo ~3s 2.1 o o ~ 1 ~8 oooooooooooooo GAP! O0 3~0 O! 0 0 4 I 68 00000000000000 ~ oo 6~s 2~ o o 4 1 o~ oooooooooooooo ~ oo ~oo~ o o ~ i o~ oooooooooooooo ~/c~ oo ~oo~ o o 4 ~ o. oooooooooooooo o/c~ oo ~o~ o o ~ ~ ~ oooooooooooooo .u oo ,,o ~ o o ~ ~ o~ oooooooooooooo c.soo ~4o~ o o. ~ ~ ~ oooooooooooooo c~soo ~s~ 02 o o 4 ~ ~ oooooooooooooo O0 420 01 0 0 4 1 68 00000000000000 oo ooo oo o o ~ ~ ~ oooooooooooooo ~u oo ~ooo o o 4 ~ ~ oooooooooooooo c~soo ooo oo o o ~ ~ s~ oooooooooooooo c~soo ooo oo o o ~ ~ ~ oooooooooooooo cpsoo ooo oo o o 4 ~ s~ oooooooooooooo ~VP '010,H02 VERIFICATION bISTING PAGE 5 CNTC CNb CPS O0 000 TENS CNL bB O0 635 OR CNL GAP! O0 310 SGR NGT GAPI O0 310 CGR NGT GAP! O0 310 URAN NGT PPM O0 792 THOR NGT PPM O0 790 POTA ~GT PU O0 W5~G NGT CPS O0 3i0 W4NG NGT CPS O0 310 W3NG NGT CPS O0 310 W2NG ~GT CPS O0 310 WiNG NGT CPS O0 310 CS NGT F/HR O0 636 TENS NGT LB O0 635 NVR EPT V O0 000 FVR EPT v O0 000 LA EPT IN O0 280 SA EPT IN O0 280 HD EPT IN O0 280 SGR EPT GAPI O0 310 TENS EPT LB O0 635 O0 0 0 4 21 0 0 4 01 0 0 4 O1 0 0 4 01 0 0 4 50 0 0 4 50 0 0 4 50 0 0 4 01 0 0 4 01 0 0 4 01 0 0 4 O1 0 0 4 Ol 0 0 4 21 0 0 4 21 0 0 4 O0 0 0 4 O0 0 0 4 01 0 0 4 O1 0 0 4 01 0 0 4 0i 0 0 4 21 0 0 4 DATA DEPT SP uPH! RTNR CFTC POTA W2~G NVR HD 1121~ 955 46 3 487 -999 '999 "999 "999 '999 5000 SFLU 3594 GR 0000 CAL! 1906 NFDC 9455 NPHI 9769 CNTC 2500 CGR 2500 w'5NG 2500 2500 FVR 2500 SGR 3 8173 179 5 788 49 1752 -999 -999 '999 -999 '999 2 50 TENS 578 RHOB 0000 FFDC 4285 RCNT 5593 TENS 2500 URAN 2500 W4NG 2500 CS 2500 bA 2500 TENS DEPT SP TENS DpH! RTNR CFTC POTA 1t200 0000 SFLU -! 8 9219 GR 2334 0000 CA,bi 46 3 487 '999 -999 -999 -999 -999 1906 NFDC 9455 NPH! ,9769 CNTC 2500 CGR 2500 WSNG 2500 WiNG 2500 FVR 2500 SGR 4 8019 179 5 788 49 !752 -999 -999 -999 -999 -999 1250 TENS 578 RHOB 0000 FFDC 4285 RCNT 5593 TENS 2500 URAN 2500 W4NG 2500 CS 2500 bA 2500 TENS EPT 11100,0000 SFLU 2172 SP~ -38'6875 GR "e88 4766 1875 RHoBTENS TE~.;$ 1820,0000 CAL! "5000 FFDC ! 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 3,8957 IbM 955,0000 GR 1,8879 DRHO 1767 0000 TNRA 731 3464 RCFT 1955 0000 GR -999 2500 THOR '999 2500 W3NG -9992500 TENS -999 2500 SA -999 2500 3, 9433 IbM 2334 0000 GR 1731 2334 '999 '999 '999 '999 "999 8879 DRHO 0000 TNRA 3464 RCFT 0000 GR 2500 THOR 2500 N3NG 2500 TENS 2500 SA 2500 8,7363 182~,0000 GR ,3899 DRHO 591,0000 TNRA 3 9862 179 1250 -0 0138 3 6593 433 29t3 1791250 -999 2500 -999 ~500 -999 500 -999 2500 3,6939 !79,1250 "0,0138 3,6593 433,2913 179,1250 '999,2500 "999,2500 '999,2500 "999,2500 80'10435 LVP 'OlO,H02 VERIFICATION LISTING PAGE 6 RTNR CFTC POTA W2NG NVR 3 2339 NPHI 674 1681 CNTC -999 2500 CGR -999 2500 W5NG -999 2500 WlNG -999 2500 FVR -999 2500 SGR 36 2!41 -999 -999 -999 -999 -999 8616 RCNT 1821 TENS 2500 URAN 2500 W4NG 2500 CS 2500 bA 2500 TENS DEPT SP ~ENS RTNR CFTC SGR POTA W2NG HD I1000 0000 SFLU -36 2000 16 109~ -999 -999 -999 -999 -999 1562 GR 0000 CALI 2008 NFDC 7714 NPHI 2397 CNTC 2500 CGR 2500 W5NG 2500 wING 2500 FVR 2500 SGR 19 2666 IbD 58 8 555 27 2777 -999 -999 -999 -999 -999 9062 TENS 3750 RHOB 5000 FFDC 850 RCNT 659 TENS 2500 URAN 2500 W4NG 2500 CS 2500 2500 S DEPT SP DPHI RTNR CFTC POTA W2NG HD ,0000 -2 GR 2044,0 ~ CALl 14.3548 NFDC 6851 CNTC -999 2500 CGR -999 2500 WSNG '999 2500 WiNG '999 2500 FVR -999 2500 SGR 9 2291 85 3750 TENS 8 572 29 ~329 999 -999 -999 -999 -999 6641 RHOB 5000 FFDC 7194 RCNT 7622 TENS 2500 URAN 2500 W4NG 2500 CS 2500 LA 2500 TENS DEPT DPH! RTNR CFTC SGR POTA W2NG NVR HD 10800 0000 SFbU -27 4063 GR 1960 7 3 671 -999 -999 "999 -999 -999 0000 CAbI 3722 NFDC 7273 NPHI 7654 CNTC 2500 CGR 2500 WSNG 25O0 wi~O 2500 FVR 2500 SGR 38 2149 -999 -999 -999 -999 -999 bD 0 FFDC 9419 RCNT 9687 TENS 2500 URAN 25OO 250O 2500 bA 2500 T~NS DEPT TEES CFTC POTA W2NG NVP 10700 0000 SFLU -12 2054 22 4 433 -999 -999 -999 -999 9609 GR 0000 CAb! 0137 NFDC 4524 NPH! 0473 CNTC 2500 CGR 2500 W5NG 2500 W1NG 2500 FVR 2 3408 IbD 114 0000 TENS 6016 RHOB 639 5000 FFDC 504627 RCNT 1699 ~405 TENS -999 O0 URAN -999 2500 W4NG -.999~2500 CS -9992500 ~ 2158 4717 RCFT ~820 0000 GR 999 2500 THOR -999 2500 W3NG '999 2500 TENS '999.2500 SA '999,2500 23 1068 IbM 20O0 2 525 2862 2000 -999 -999 -999 -999 -999 0000 GR 3828 DRHO 5000 TNRA 0942 RCFT 0000 GR 2500 THOR 2500 ~3NG 2500 TENS 2500 SA 2500 13 1569 502 2389 2045 '999 -999 '999 '999 '999 0000 GR 4133 DRHO 500 TNRA 107 RCFT 0000 GR 500 THOR 500 W3NG 2500 TENS 2500 SA 2500 19~ 7 0 2048 1960 -999 '999 '999 '999 "999 6856 lbH 0000 GR 5285 DRHO 5000 TNRA 9204 RCFT 0000 GR 2500 THOR 2500 W3NG 2500 TENS 0 0 GR )~: 869 DRHO 2500 THOR -99 O0 3NG 500 TE~$ -999~2500 SA 8 574.59~5 -999,2500 '999,2500 '999,2500 18 0262 58 9062 -0 0118 2 5679 967 86~ 58 90 -999 2500 -999,2500 -999 2500 -999 2500 11,5~16 85,{ 50 0.0002 771, 4 85, 50 999' O0 999,2500 999,2500 999,2500 27 ~132 74 250 '0 0069 3 3479 5995811 74 6250 -999 250O -999 ~500 -999 500 -999 2500 ~,0:0 110,00 ,0084 11~,0000 . 5oo -999'2500 '999~2500 '999,2500 LVP 010,H02 VERIFICATION LISTING PAGE 7 HD -999,2500 SGR -999,2500 TENS DEPT Sp TENS DpHI RTNR CFTC OTA ~2NG NVR fiD 10600 0000 SFLU 475 -999 -9 -999 -999 1641 GR 0000 CAb! 4401 NFDC 8349 NPH! 2500 WSNG 2500 WtNG 2500 FVR 2500 SGR 9568 XLD 120 8 6t4 47 1708 -999 -999 -999 -999 -999 4375 TENS 2813 RHOB 5000 FFDC 0964 RCNT 5261 TENS 2500 URAN 2500 W4NG 2500 CS 2500 bA 2500 TENS DEPT Sp TENS DpHI RTN~ CFTC POTA i2NG YR D 1995 2O 4 43O -999 -999 -999 -999 -999 0000 SrbU 3438 GR 0000 CALl NFDC 0404 CNTC 250O CGR 2500 WSNG 2500 W1NG 2500 FVR 2500 2 9972 XLD 621 52 1702 -999 -999 -999 -999 -999 12 0 TENS 67~7 RHOB 0000 FFDC ~78 RCNT 08 TENS 2500 URAN 0 CS 00 LA DEPT SP TENS DpHI RTNR qr?C W2NG HD 19 4 495 '999 '999 -999 -999 -999 ,0000 SF~U 87 OR ?0?3 NFDC 0980 NPHi 3755 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR 2500 SGR 3 116 9 618 47 1826 -999 -999 -999 -999 '999 iGS ZbD 00~ RHOB 0000 FFDC 0731 RCNT URAN O0 CS 2500 bA 2500 TENS DEPT SP TENS DPH! RTNR CFTC POTA W2NG NVR HD 10300 0000 SFLU -20 2000 12 3 644 -999 -999 -ggg -gg9 -ggg 3906 GR 0000 CAbI 0968 NrDC 45 CNTC ::2500 2500 W5NG 2500 W1NG ~500 FVR 500 SGR 4,6088 ZbD 196,1250 TENS e'7109 RHOB 509,7500 FFDC '37.1479 RCNT 21411!001 TENS "999,2500 URAN -999,2500 W4NG -999,2500 CS -999'2500 LA -999'2500 TENS EPT SP TENS DPHI 1:0200,0000 SFLU -9,8906 GR 2270,0000 CALl 18,9470 NFDC 3 169 9 585 5593 ZbD 0000 TENS 4219 RHOB 5000 FFDC '999,2500 2,0583 1875,0000 GR 2,3459 DRHO 604,5000 TNRA 1650,9133 RCFT 1875,0000 OR -999,2500 THOR -999,2500 W3NG -999,2500 TENS -999,2500 SA '999,2500 646 1672 ~995 999 -999 -999 '999 -999 0000 . 3121 DRHO 5000 TNRA 5889 RCFT 0000 GR 500 THOR 500 W3NG 500 TENS 500 SA 2500 192~ 1762 99 -999 .999 -999 -999 5640 IbM 0000 GR 3250 ORHO 0000 TNRA 360t RCFT 0000 GR 2500 THOR ~500 W3NG 500 TENS 2500 SA 2500 4,9550 IbM 200~ 0000 GR 5 DRHO 2276 2O0O -999 -999 -999 -999 -999 2695 RCFT 0000 GR 2500 THOR 2500 W3NG 2500 TENS 2500 SA 2500 3,2613 IbM 2270.0000 GR 2,3375 DRHO 594;0000 T.NRA 2 0306 120 4375 0 0083 3 6947 407 6711 120 4375 -9992500 -999 2500 -999 2500 -999 2500 3 2763 12~ 1250 0031 3 9978 1250 999 2500 '999 2500 -999 2500 -999 2500 3 6439 116 2500 0 0047 2275 2500 -999 2500 .999 2500 -999 2500 4,8758 -0 .208 3 1861 575 7277 196 '999 ~500 '999 500 -999 2500 3 1962 169 0000 '0 073 3 .~099 bVP '010,H02 VERIFICATION LISTING PAGE 8 RTNR 3 CFTC 555 SGR -999 POTA -999 W2NG -999 NVR -999 HD -999 9048 NPHI 1816 CNTC 2500 CGR 2500 HSNG 2500 WlNG 2500 FVR 2500 SGR DEPT 10100 SP -22 TENS 2114 DPHI 21 RTNR 3 CFTC 501 SGR -999 POTA -999 ~2NG -999 VR -999 -999 0000 SFhU 2344 GR 0000 CALl 3573 NFDC 8167 NPHI 9979 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR 2500 SGR DEPT 10000 -22 ~N$ 2140 DPH! 11 RTNR 3 CFTC 666 SGR -999 POTA -999 2NG -999 .,VR -999 HD -999 0000 SFLU 4063 GR 0000 CALl 6267 NFDC · 2844 NPHI 4540 CNTC 2500 CG~ 2500 WSNG 2500 WlNG 2500 FV~ 2500 SGR DEPT 9900 SP -22 TENS 1935 DPHI 14 RTNR 3 CFTC 644 SGR -999 POTA -999 W2NG -999 NVE -999 MD -999 0000 SFLU 9062 GR 0000 CALl 6238 NFDC 2763 NPHI 4960 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 PV~ 2500 SGR DEPT 9800 SP -26 TENS 2045 DpH! 19 ETNR 3 CFTC 549 POTA -999 ~2NG -999 NVR "999 0000 SFLU 3750 GR 0000 CAL! 8066 NFDC 7064 NPHI 3455 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR 42 1945 -999 -999 -999 -999 -999 4 173 8 639 1724 -999 -999 -999 -999 -999 5 97 9 615 34 2071 -999 -999 -999 -999 -999 4 I08 9 593 35 2091 -999 -999 -999 -999 -999 122 9 639 39~ 1872 -999 -9991 -999 -999 0068 9065 2500 2500 2500 2500 2500 7550 8750 9375 5000 4298 6392 2500 2500 2500 2500 2500 3367 6250 5938 0000 I526 0317 2500 2500 2500 500 50O 5727 8125 7891 0000 7413 6440 2:500 ,2500 2500 2500 2500 5585 5000 9766 0000 8293 ~418 500 2500 2500 2500 RCNT TENS URAN W4NG CS TENS TENS RHOB FFDC RCNT TENS URAN W4NG CS TENS ILD TENS RHOB FFDC RCNT TENS URAN W4NG CS bA TENS ILO TENS FFDC RCNT TENS URAN W4NG CS TENS TENS RHOB ~FDC RCNT TENS URAN W4NG CS 1892 1658 2270 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999:2500 4 9906 211~!0000 2977 684 0000 1780:2i46 2114,0000 '999,2500 -999 2500 -999:2500 -999 2500 -999:2500 4,9412 2140,0000 2,4583 500 0000 2094 3228 2140 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 5,1977 1935'0000 2'4088 522,5000 2048~3267 ~935,0000 999,2500 -999,2500 -999,2500 -999,2500 -999.2500 4 897! 2045 0000 2 3233 653 5000 192~ 7380 204 0000 -999 2500 '999 2500 -999 2500 -999 2500 RCFT THOR W3NG TENS IbM GR DRHO TNRA RCFT GR THOR ~3NG TEN~ IbM GR DRHO TNRA RCFT THOR W3NG SA IbM GR DRHO TNRA RCFT GR THOR N3NG TENS SA ibm GR DRHO TNRA RCFT THOR W3NG TENS 489 6635 169 0000 -999 2500 -999 2500 -999 2500 -999 2500 4 9625 173 8750 0 0102 3 5482 434 1472 173 8750 -999 2500 -999 2500 -999 2500 -999 2500 4 8713 97 6250 0 0435 3 0947 610 8982 97,6250 -999 2500 -999 2500 -999~2500 -999,2500 5 2007 108 8125 0 0122 3 979 550 ~478 I08~8125 "999,2500 '999 2500 -999 O0 4:8893 122 5000 :0 ~173 3 362 4852429 ooo :2500 -999 2500 -999 2500 -999 2500 bYP'OIO,H02 VERIFICATION LISTING PAGE 9 HD -999,2500 SGR DEPT SP -30 TENS 1970 DpHI 15 CFTC 793 SGR -999 POTA -999 W2NG -999 NVR -999 HO -999 DEPT Sp TENS DpHI RT~R CFTC SGR POTA W2NG DEPT SP TENS DPHI BTNR CFTC POTA W2NG DEPT D'pH! RTNR CFTC POTA 2NS YR 9700 0000 SFLU '999,2500 TENS 9375 GR 83 0000 CAbI 9 5403 NFDC 589 628.1 NPH! 35 6763 CNTC 2407 2500 CGR -999 2500 ~SNG -999 2500 WING -999 2500 F'VR -999 2500 SGR -999 9600 0000 SFLU 6 6550 IbD -21 1975 3 568 -999 -999 -999 -999 -9gg -999,2500 5,699B 500 TENS 1970,0000 GR ~875 RHOB 2,3937 DRHO ooo rroc 711 TENS 1970,0000 GR 500 URAN -999,~500 THOR 2500 W4NG -999. 500 W~NG 2500 CS -999.2500 TgNS 2500 bA -999.2500 SA 2500 TENS -999,2500 4 3354 i6D 1875 GR 106 0000 CALI 9 7166 NFDC 647 5469 NPHI 38 9670 CNTC 1934 2500 CGR '999 2500 WSNG -999 2500 WiNG -999 2500 FVR -999 2500 SGR -999 9500 0000 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CAb! 2500 NFDC 2500 NPH[ 2500 CN~C 2500 CGR 2500 W5NG 2500 WiNG 2500 FVR 2500 SGR 9400 0000 SFLU 2500 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 WSNG 2500 W~NG 2500 FVR 2500 SGR =999 -999 -999 -999 -999 -999 -999 -999 -999 '999 9375 TENS 5313 RHOB 0000 FFDC 4449 RCNT 0022 TENS 2500 URAN 2500 W4NG 2500 CS 2500 LA 2500 TENS -999 2500 IbD -999 '''''999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 2500 rFOC 2500 RCNT 2500 TENS 2500 URAN 2500 W4NG 2500 Cs 2500 bA 2500 TENS -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500. URA~ 2500 ~4NG 250O CS 2500 6A 2500 TENS -9gg 2:500 XLD -999 2500 TENS -999 2500 RHOB -999 2500 FFDC DEPT 9300,0000 SFLU SP -999"2500 OR TENS -999.2500 CALl DPH! -999,2500 NFDC 3 8648 I6~ 197{: 57 1935 1975 -999 -999 -999 -999 -999 3 DRHO 0000 TNRA 9404 RCFT 0000 GR 2500 THOR 0 TENS o 0 -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 DRHO 2500 TNRA 2500 RCFT 2500 GR 2500 THOR 2500 W3NG 2500 TENS 2500 SA 2500 -999 2500 IbM -999 -999 -999 -999 -999 -999 -999 '''999 -999 -999 2500 GR 2500 DRHO' 2500 TNRA 2500 RCFT 2500 GR 2500 THOR 2500 W3NG 2500 TENS 2500 SA 2500 -999,2500 IbM '999,2500 GR -999,2500 DRHO -999,2500 TNRA 6 0696 83 2500 0 0056 3 1303 734 9t13 83 2500 -999 2500 -9 2500 -999 2500 3 918O 75 0 3 5 106 9375 -999 2500 999 -999 2500 -999 2500 -999 2500 -9992500 -9992500 -9992500 -999 2500 -999 2500 -999 2500 -999 2500 -9992500 -999,2500 -999 2500 -999 2500 -999 -999 2500 -9992500 '999:2500 '9992500 '999,2500 -999,2500 '999' 2500 '"999,2500 "999' 2500 bVP 010,H02 VERIFICATION bISTiNG PAGE 10 RTNR ~999,2500 NPHI CFTC .999,2500 CNTC SGR .999,2500 CGR POTA 999,2500 WSNG W2NG -ggg,2500 WING NVR -999.2500 FVR HO -999,2500 SGR 199912500 RCNT 999 2500 TENS -999 2500 URAk -ggg 2500 W4NG -999 2500 CS -999 )500 bA -999 500 TENS DEPT SP .ggg TENS -ggg DPHX .ggg RTNR -ggg CFTC -ggg SGR -999 POTA -ggg W2NG -999 NVR -999 HD -ggg 9200 0000 SFbU 2500 GR 2500 CAL! 2500 NFDC 2500 NPH! 2500 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR 2500 SGR -999 -ggg -ggg -ggg -ggg -999 -999 -ggg -999 -9gg -ggg 500 ILD 500 TENS 2500 RHOB 500 FFDC 500 RCNT 2500 TENS 2500 URAN 2500 W4NG 2500 CS 2500 ~A 2500 TENS DEPT SP TENS DPH! RTNR CFTC POTA W2NG 9100 0000 SFSU -999 -ggg -999 -gg9 -gg9 -999 -999 -ggg -999 -gg9 00 GR O0 CAbI NFDC 2500 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 ~VR 2500 SGR -gg9 2500 ILD -999 -999 -999 -999 -ggg -999 -999 -999 -ggg -999 500 TENS i~500 O0 FFDC ~00 RCNT 2500 TENS 2500 URAN 2500 W4NG 2500 CS 2500 ~A 2500 TENS .~EPT )PHI ~TNR 3FTC SGR POTA 2NG V~ 9000 0000 SFbU -999 'ggg -999 -999 -999 -999 -999 -999 -999 -999 2500 OR 2500 CALI 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 500 W5NG 500 WiNG 2500 FVR 2500 SGR -999 2500 -ggg -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 URAN 2500 W4:NG 2500 CS A 2500 ~ENS 2500 TENS ~DpH ! TNR CFTC ~2NG. NVR 8900 0000 SFLU -9gg -999 -999 -ggg -9gg -ggg -999 -999 -9gg 2500 GR 2500 CAbI 500 NFDC ~500 NPH! 2500 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 500 ILD 500 TENS 2500 RHOB 500 FFDC 500 RCNT 2500 TENS 2500 URAN 2500 W4NG. 2500 CS 2500 LA '999,2500 RCFT '999,2500 GR -999,2500 THOR -999,2500 W3NG -999,2500 TENS -999,2500 SA -999,2500 -999 2500 ILM -gg9 -ggg -999 -999 -999 -9gg -999 -9gg -999 -9gg 2500 GR 2500 DRHO 2500 TNRA 2500 RCFT 2500 GR 2500 THOR 500 W3NG 500 TENS 2500 SA 25O0 -999 2500 Ib~ -999 -999 -999 -999 -ggg -999 -999 -999 -999 -9gg 500 GR 500 DRHO 500 TNRA 500 RCFT 2500 GR 2500 THOR 2500 W3NG 500 TENS 1500 SA 2500 '999.2500 '999'2500 GR '999,2500 DRHO '999'2500 TNRA '999 2500 RCFT -999 2500 GR -999 2500 THOR -999 2500 W3NG -999 2500 TENS -999 2500 SA -999 2500 -ggg -ggg -999 ~999 -999 -999 -999 -gg9 -999 -999 ,500 Ib~ 500 GR 500 DRHO 2500 TNRA 2500 RCFT 2500 GR 2500 THOR 2500 W3NG 2500 TENS 2500 SA -999 2500 -999i2500 -999 ~500 -999, 500 -999,2500 -999,2500 -999 2500 -999 2500 '999 2500 '999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -ggg 2500 -999 2500 -999 2500 -999 2500 -9gg 2500 -ggg 2500 -999 2500 -999 2500 ~999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -ggg 2~00 -999 2 O0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -ggg, 2500 -999 2500 -999 2500 -99~ 2500 -99 2500 -99~2500 -99 2500 -999.2500 -999 2500 -999 2500 LVP '010,H02 VERIFICATION LISTING PAGE 1! HD -999,2500 SGR -999,2500 TENS DEPT SP TENS DPHI RTNR CFTC SGR POTA ~2NG VR HO 8800 0000 SFLO -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CAHI 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 W5NG 2500 WlNG 2500 FVR 2500 SGR -999 2500 IbD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB O0 2500 TENS 2500 URAN 2500 ~4NG 2500 CS 2500 LA 2500 TENS DEPT TENS DPHI RTNR CFTC POTA W2NG NVR HD 8700 0000 SFLU -999 -999 -999 -999 -999 -999 -999, -999 -999 -999 2500 GR 2500 CALl 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 ~5NG 2500 W1NG 2500 FVR 2500 SGR -999 2500 IbD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 URAN 2500 W4NG 2500 CS 2500 bA 2500 TE~S DEPT TENM DPHI ~T~R CFTC POTA HD 8600 0000 SFHU -999 -999 ,'999 '999 "999 '999 '999 ,''999 '999 "999 2500 GR 2500 CAL! 500 NFDC 500 NPHI 2500 CNTC 2500 CGR 2500 ~LNG 2500 WING 2500 FVR 2500 SGR -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 500 TENS 500 RH06 2500 FFDC 2500 RCNT 250O TEnS 0 ~.4NG 2500 CS 50 bA 50° 0 TENS DEPT SP RTNR CFTC SGR POTA W2NG 8500 0000 SFbU -999 -999 -999 -999 -999 -999 .-999 -999 -999 2500 GR 2500 CAb! 2500 NFDC 2500 NPH! 2500 CNTC 2500 ~00 W5NG 00 WiNG 2500 FVR 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 500 500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 :ORAN 2500 W4NG 2500 CS 2500 bA 2500 TENS DEPT SP TEnS DPHI 8400,0000 SFLU '"999,2500 999,2500 GR '-999,2500 TENS -999,2500 CAbI --999, 500 RHOB -999;2500 NFDC -999; 500 FFDC '999,2500 -999 2500 Ibm -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 DRHO 2500 TNRA 2500 RCFT 2500 GE 2500 THOR 500 W3NG 500 TENS 2500 SA -999o2500 -999 2500 IbM -999 2500 GR '999 2500 DRHO -999 2500 TNRA -999 2500 RCFT -999 2500 GR -999 2500 THOR '999'2500 ~3NG '999'2500 TENS -999,2500 SA -999,2500 =999 2500 IbM '999 ~500 GR -999 500 -999 "999 "999 '999 '999 "999 '999 '999~ DRHO 2500 TNRA 2500 RCFT "' R O0 ~HOR 2500 W3NG 2500 TENS 2500 :SA 2500 -,999 2500 -999 -999 -999 -999 -999 -999 -999 ~999 -999 ~999 2500 GR 2500 DRHO 500 TNRA 500 RCFT 2500 GR 2500 T~OR 2500 W3NG 2500 TENS 2500 SA 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 '999,2500 -999.25.00 -999~2500 -999,:2500 -999,:~00 ~999,! O0 "999: 5'00 ,'999 .999~i 5'00 -999 2500 -999,2500 -999 2500 -999~500 -999, 560 '999 2500 ~999 2500 '999 '999.2500 "999,2500 Ib~ -999,2500 '999,2500 GR -999,2500 -999'2500 DRHO ,,999,2500 -999,2500 TNRA .999~2500 LVP OlO,N*02 VERIFICATION LISTING PAGE 12 RTNR -999 CFTC -999 SGR -999 POTA -999 W2NG -999 NVR -999 HD -999 2500 NPHI 2500 CNTC 2500 CGR 250O WSNG 2500 WiNG 2500 FVR 2500 SGR DEPT 8300 Sp -999 TENS -999 DPH! -999 RTNR -999 CFTC -999 SGR -999 POTA -999 ~2NG -999 VR -999 HD -999 0000 SFLU 2500 GR 2500 CALI 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 w5NG 2500 W1NG 250O FVR 2500 DEPT ~20o SP .999 TENS 999 DPHX -999 RTNR -999 CFTC SGR POTA '999 VR ~D -999 ,0000 SFLU .2500 GR .2500 CALX 2500 NFDC 0 CNTC 500 CGR 500 W5NG 2500 WiNG 0 DEPT SPN -99~ TES -99 DPHI '999 RTNR -999 C~TC -999 SGR -999 POTA '999 W2NG -999 NVR '999 HD -999 0000 SFLU 2500 GR 2500 CALl 2500 2500 CNTC 2500 CGR WSNG 2500 FVR 2500 SGR DEPT 8000 SP -999 TkN$ -999 DPHI -999 RTNR -999 CFTC .-999 SGR -999 POTA -999 W2NG -999 NVE -999 0000 SFLU 2500 GR 2500 CALI 2500 NFDC 2500 NPH! 2500 CNTC 2500 CGR 2500 W5NG 2500 ~iNO 2500 FVR -999 -999 -999 -999 -999 -999 -999 '99~ -999 -999 -999 -999 '999 '999 '999 '999 '999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ,2500 ,)500 500 .2500 ,~500 500 .2500 2500 2500 2500 500 500 2500 2500 2500 2500 2500 2500 500 50O 50O 2500 250O 500 500 500 50O 2500 !500 2500 2500 2500 2500 2500 2500 2500 2500 500 500 2500 ,2500 '2500 ,2500 ,2500 ,2500 ;2500 ;2500 ,2500 ,2500 '2500 RCNT TENS URAN W4NG CS LA TENS XLD TENS RHOB FFDC RCNT TENS URAN W4NG CS LA TENS TENS RHOB FFDC RCNT TENS URAN W~NG LA TENS XLD TENS RHOB FFDC RCNT TENS URAN 54NS LA TENS FFDC RCNT TENS URAN W4NG CS LA -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999, -999, -9 -999, '999, '999 '999 .999 999 -999 ~999 -999 ~999 -999 -999 -999 -999 -999 -999 '999 :-999 -999 999 '999 '999 -999 '999 '999 -999 -999 -999 -999 '999 '999 '999 .2500 .)500 , 500 .2500 .~500 , 500 .2500 25OO 25OO 500 50O 500 500 2500 500 500 500 500 500 50O 2500 2500 500 $00 500 2500 25OO 2500 500 5OO 5OO 2500 2500 ,2500 500 500 2500 2500 2500 2500 ~500 :500 2500 RCFT GR THOR W3NG TENS IL~ GR DRHO TNRA RCFT GR THOR W3NG TENS IbM GR DRHO TNRA RCFT GR THOR GR DRHO TNRA RCFT GR THOR W3NG TENS SA GR DRHO TNRA RCFT THOR ~3NG TENS SA '999,2500 -9991 O0 -999 500 -999 500 -999 500 -999.~500 '999, 500 '999,2500 -999.2500 : gl. soo ' °° 99, O0 '999,2500 -9992500 -999 ~ .,,, -999 2500 -9992500 -999 250O -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -9992500 -999 2500 -999 2500 -999 ~500 '999 500 '999 25'~0 -999 25 0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 '999 2500 -999 2500 LVP 010,H02 VERIFICATION LISTING PAGE HD '999.2500 SGR DEPT SP TENS DPMI RTNR CFTC POTA 2NG 7900 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 SFLU GR CALl NFDC CNTC CGR W5NG WiNG FVR DPH! RTNR CFTC POTA W2NG NVR HD 7800,0000 500 "999"~50 '999. 0 -999,)500 =999, 500 "999,2500 "999,2500 '999,2500 -999*2500 -999,2500 -999.2500 SFLU CALl NFDC NPH! CNTC CGR W5NG WiNG rVR SGR DEPT SP TENS DPH! RTNR CFTC POTA W2NG NVR 7700 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 500 500 2500 2500 2500 500 500 2500 2500 SFbU GR CAbI NFDC NPH! CNTC CGR WLNG FVR 8GR DPH~ RTNR cFtC POTA W~NG NVR HD 7600 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 0000 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 SFLU GR CALl NFDC NPH! CNTC' CGm. WLNG SGR DEPT TENS DPHI 7500.0000 "'999,2500 '999 * 2500 -999,2500 GR CALI NFDC -999.2500 -999 2500 -999 2500 -9992500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 i500 -999 50O -999 500 -999 2500 -999 2500 "999 2.500 '999 2500 '999 2500 '999 ~500 -999 500 -999 0 -999 2500 oo "999 0 '999 ~ 0 O0 -999 ~500 -'999 500 -999 2500 O0 -99-999 ,50o-999 500 -999 ~500 -999 2500 -999 2 .9992~ O0 O0 -999 2500 -999 2500 '999 .'2500 -999 '2500 · '999. 2500 '999.2500 TENS RHOB rrOC RCNT TENS URAN W4NG CS TENS TENS RHOB FFDC RCNT TENS URAN W4NG CS bA TENS TENS RHOB FFDC RCNT TENS URAN W4NG CS 5A TENS TENS RHOB FFDC TENS URAN W4NG, CS TENS TENS FFDC -999.2500 -999 250O -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 25O0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ]500 -999 500 -99~ 1500 - 9 500 ,-999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999 !500 -999 500 -999 500 "999 500 '999 2500 -999 500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 IbM GR DRHO TNRA RCFT GR THOR w NG T~N8 SA Ib~ GR DRHO TNRA RCFT GR THOR W3NG TENS SA IbM GR DRHO TNRA RCFT GR THOR W3NG TENS SA IbM GR DRHO TNRA RCFT ~R THOR W3NG SA IbM GR DRHO TNRA -999,2500 -999 2500 -9992500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 '999 !500 -999 500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 .999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 .999 2500 -999 2500 -999 2500 "999 ~500 '999 500 -999 2500 LVP 'OlO.H02 VERIFICATION LISTING PAGE 14 RTNR :999,2500 NPHI CFTC .999.2500 CHTC SGR .999,2500 CGR POTA .999.2500 WSNG W2NG .999.2500 WlNG NVR .999.2500 FVR HO 999.2500 SGR ~999,~500 RCNT -99 2500 ORAN -999.~500 W4NG -99~i 500 CS - 9 2500 bA -~9 2500 TENS DEPT SP -999 TENS -999 DPH! -999 RTNR -999 CFTC -999 SGR -999 POTA -999 : 2NG '999 VR -999 HD -999 7400 0000 SFbU 2500 GE 25O0 CALl 2500 NFDC 2500 NPH! 2500 CNTC 25O0 CGR 2500 WSNG 2500 WING 2500 FVR 2500 SGR -999 2500 IbD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 25OO FFDC 2500 RCNT 25OO TENS 2500 URAN 2500 W4NG 2500 C$ 2500 LA 2500 TENS DEPT DPHI RTNR CFTC POTA W2NG NV'R 7300 0000 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CALI 2500 NFDC 2500 NPH! 2500 CNTC 2500 CGR 2500 W5NG 2500 WlNG 25O0 FVR 2500 -999 2500 IbD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB SO0 rroc 500 RCNT 2500 TENS 2500 URAN 2500 W4NG :2500 CS 2500 bA 250~0 TE~S DEPT SP TENS PPHI RTNR CFTC POTA W2NG NVR HD 7200 0000 SFbU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CALl 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 W5NG 2500 WlNG 2500 FVR 2500 SGR -999 2500 ibD -999 -999 -999 "999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS ,2500 URAN 2500 W4NG 2500 CS 2500 bA 2500 TEaS DEPT RTNR CFTC POTA W2NG 7100 0000 SFbU -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CALI 2500 NFDC 2500 NPH! 2500 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR -999 2500 -999, '999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB ~5~0 FFDC RCNT 2500 TENS 2500 25OO O0 LA :999 2500 RCFT 500 GR -999. O0 -999,2500 ~3NG '999,2500 ~EN$ "999,2500 SA '999,2500 '999,~00 IbH '999. O0 GR '999,2500 DRHO -999,2500 TNRA -999,2500 RCFT '999,2500 GR "999.2500 THOR 2500 ~3NG :!99'2500 SA '999.2500 "999.2500 '999.2500 '999,2500 '999.2500 "999.2500 '999. 500 .999,~ 500 '999,2500 '999,2500 -999, '999, GR ORHO TNRA RCFT GR THOR ~3NG TENS 5OO S~ 50O "999,2500 IbN '999,i500 GR '999. 500 DRHO "999' 500 TNRA -999,2500 RCFT -999,2500 -999,2500 THOR :999,2500 W3NG .999,:2500 TENS ,999.2500 SA 999.2500 ' -99 0 IbN .99~'250 · 2500 Ga -999,2500 DRHO -999'2500 TNRA -999,2500 ECFT -99~'2500 GR "99 '2500 THOR -999'2500 W3NG -999:,2500 TENS -999,2500 SA '999.2500 '999.2500 -999,2500 "999,2500 -999,2500 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 500 -999 2500 -999 ]500 -999 500 -999 2500 -999 2500 -999 2500 '999 2500 -999 ~500 -999 500 "9992500 -999 2500 '999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -9992500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ,250O LVP OlO,H02 VERIFICATION LISTING PAGE 15 HD '999,2500 SGR -999,2500 TENS DEPT SP TENS DpH! RTNR CFTC SGR POTA W2NG 7000 0000 SFLU -999 -999 -999 -999 -999 -999 -99~ -99 -999 -999 2500 2500 CALl 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 WSNG 2500 WING 2500 FVR 2500 -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 URAN 2500 W4NG 2500 CS 25O0 bA 2500 TENS DEPT SP TENS DPHI RTNR CFTC POTA W2NG HD 6900 0000 SFLU -999 -999 -999 -999 :999 999 999 999 -999 -999 2500 GR 2500 CALZ 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR 2500 SGR -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 0 TENS 2500 FFDC 2500 RCNT 2500 TENS 2500 URAN 0 'W4NG 2500 bA 2500 TENS DEPT TENS R. TNR CFTC POTA W2NG HD 680O 0000 SFbU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 OR 2500 CAb! 2500 NFDC 2500 NPH! 2500 CNTC 2500 CGR 2500 W5NG 2500 WiNG 2500 FVR 2500 SGR -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 IbD 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 URAN 2500 W4NG. 2500 C$ 2500 bA 2500 TENS DEPT TENS DPHI RTNR CFTC POTA W2NG NVR HD ~700, 999 -999 -999 -999 -999 -999 -999 -999 -999 -999 0000 SFbU 2500 GR 2500 CAbI 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 W5NG 2500 WiNG 2500 FVR 2500 SGR -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 500 RBOB ~500 FFDC 2500 ECNT 2500 TENS ,2500 URAN 500 W4NG 500 CS O0 bA )~00 TENS DEPT TENS DPH! 6600 0000 SFbU '999~2500 GR '999,2500 CAb! '999,2500 NFDC -999,2500 lbD -999,2500 ~ElS -999,2500 RHOB '999,2500 FFDC '999,2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 IbM 0 DRHO 2500 TNRA 2500 RCFT 2500 GR 2500 THOR 2500 W3NG 2500 TENS -999,2500 SA -999'2500 -999,2500 IbM -999,2500 GR -~99,2500 DRHO ' 99.2500 TNRA '999,2500 RCFT -999.2500 OR '999.2500 THOR '999°2500 ~3NG -999~2500 -999,2500 SA -999°2500 '999,2500 IbM '999,2500 GR -999.2500 DRHO -999 "999 -999 -999 -999 -999 -999 -999 2500 TNRA 2500 RCFT 2500 GR 2500 THOR 2500 W3NG 2500 TENS 2500 SA 2500 -999,2500 -999,2500 GR '999,2500 DRHO -999,2500 TNRA -999,2500 RCF? -999.2500 GR -999~2500 -~99.2500 W3NG ' 99,2500 TENS -~99,2500 SA ' 99,2500 999,2500 ,2500 DRHO -999,2500 TNEA -99~,2500 -99 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 ~999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -9992500 9 ~ O0 .oo -999 ~500 '999 500 -999 2500 ~50 -999 0 -999 500 ~999 2500 -999 2500 -999 2500 :999 2500 .999 2500 -999 2500 -999 2500 -999 .2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 LVP 'OlO,H02 VERIFICATION LISTING PAGE RTNR -999,2500 ~PHI ~999,2500 ~CNT CFTC -999,2500 C~TC .999,2500 TENS SGR ~999,2500 CGR 999,2500 POTA 999,2500 ~SNG -999.2500 W4NG W2NG -999,2500 W1NG -999.2500 NVR -999,2500 FVR -999,2500 LA HD -999,2500 SGR -999,2500 TENS DEPT SP -999 TENS -999 DPHI -999 RTNR -999 CFTC -999 SGR -999 POTA -999. W2~G -999 NVR -999 HD '999 6500 0000 SrbU 25OO GR 2500 CALl 2500 NFDC 2500 NPHI 2500 CNTC 25OO CGR 2500 W5NG 2500 W1NG O0 FVR -999 2500 XLD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 250O TEnS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 URAN 500 W4NG 500 CS 2500 LA 2500 TENS DEPT 640~i SP -99 TENS -999 DPH! -999 RTNR -999 CFTC -999 SGR '999 POTA -999 W2NG -999 NVR -999 HD -999 0000 SFLU 2500 GR 2500 CAb! 2500 NFDC 2500 NPH! 2500 CNTC 2500 CGR 2500 W5NG 2500 W1NG 2500 FVR 2500 SGR '999. 500 iLD -999, 500 TENS -999. 500 RHOB -999,250 FFDC -999.250~ RCNT -999~2500 TENS -999.2500 URA~ -999 )500 W4NG -999:1 SO0 CS soo T .s D:EPT RTN~ CFTC SGR POTA W2NG VR 6300 0000 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CAb! 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 W5NG 2500 WI~G ~500 FV'~ 500 SGR -99~ -99 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 lbo 2500 TENS 2500 RHOB 500 FFDC 500 RCNT 2500 TENS 2500 URAN 2500 W4NG 25OO CS 2500 bA 2500 TENS DEPT Sp TENS DPHI RT~R CFTC SGR POTA W2NG NVR 6200~0000 -999 -999 -999 -999 -999 -999 -999 SFLU 2500 GR 2500 CALI 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR -999.2500 ILD -999.2500 TENS -999"2500 RHOB -999.2500 FFDC -999~.2500 RCNT -999.2500 TENS -999,2500 URAN -999,2500 W.4NG '999.2500 CS -999~2500 LA '999.2500 RCFT '999.2500 GR '999.2500 THOR '999,2500 W3NG -99~,2500 TENS -99 .2500 SA -999,2500 -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 500 GR SO0 DRHO 2500 TNRA 2500 RCFT 2500 OR 2500 THOR 2500 W3NG 2500 TENS 2500 SA 2500 -999,2500 -999,2500 GR -999,2500 DRHO -999,2500 TNRA -999.2500 RCFT -999.2500 GR W3NG ,2500 -999,2500 TENS '999,'2500 SA '999.2500 '999~2500 '999 '999 '999 '999 '999 '999. '999 '999 -999 -999 250O 2500 DRHO 500 TNRA 500 RCFT 2500 GR 2500 THOR :2500 W3NG 2500 TENS 2500 SA 2500 :999,2500 IbM 999,2500 GR -999;.2500 DRHO -999.2500 TNRA -999 2500 RCFT -999 0 THOR -999 2500 W3NG -999 2500 TENS -999 2500 SA -999 2500 '999' ,2500 -999,2500 -999,2500 '999,2500 '999,2500 -999 0 -999 ~50 50O -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 25O0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999~50.0 -999 500 -999 2500 -999 2500 -999.2500 -99 ~ 500 -999~2500 -9992500 -999 2500 -999 2500 -999 2500 -999 2500 -9992500 -999 2500 -999 2500 -9992500 -9992500 -9992500' bVP '010,H02 VERIFICATION GISTING PAGE HD '999,2500 SGR '999,2500 TENS DEPT DpH! RTNR FTC POTA ~2NG HD 6100 0000 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CAbI 2500 NFDC 2500 NPH! 2500 CNTC 250O CGR 2500 WSNG 2500 WING 2500 FVR 2500 SGR -999 2500 ILD -999 -999 =999 -999 -999 -999 -999 -999 -999 =999 2500 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 URAN 2500 W4NG 2500 Cs 2500 bA 2500 TENS DEPT TENS DPH! RTNR CFTC POTA W2NG HD ~000, 999, -999. -999 -999 -999 =999 -999 -999 -999 -999 0000 SFLU 2500 2500 CALl 2500 NFDC 2500 NPHI 2500 CNTC 2500 2500 W5NG 2500 ,lNG 2500 FVR 2500 SGR -9992500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 500 TENS 500 RHOB 2500 FFDC 00 RCNT ~00 TENS 2500 URAN CS 2500 LA 2500 TENS DEPT SP vp i RTNR CFTC POTA ~2~ 5900 0000 8FLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 CALI 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 w5NG 2500 WiNG 2500 FVR 2500 SGR -999 2500 ISD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 RHOB 0 ~CNT 2500 TENS 2500 2500 2500 CS 2500 2500 TENS EN$ CFTC SGR ~OTA ~V~ 5.803~ ~0000 SFbU GR -999 -999 -999 -999 -99 -999 -999 2500 NFD¢ 2500 NPHI 2500 CNTC 2500 CGR 500 WSNG ~500 WiNG 2500 FVR 2500 SGR -999,2500 ~EPT 57.00,0000 SFbU 99 2500 NFDC -999,2500 IbM =999 2500 GR -999 -999 -999 -999 -999 -999 -999 -999 -999 500 DRHO 500 TNRA 2500 RCFT 2500 GR 2500 THOR 2500 W3NG 2500 TENS 2500 SA 2500 -999 2500 IbM -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 DRHO 2500 TNRA 2500 RCFT 2500 GR 2500 THOR 500 W3NG 500 TENS 2500 SA 2500 -999 2500 IbM -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 3,6957 IbP 4 133,3750 TENS ~020 -999,2500 RHOB =999 -999~2500 FFDC 999 -999,2500 RCNT -999 -999,2500 T~NS :999 -999,:2500 URAN 999 -999;~500 W4NG -999 -999,2500 CS -999 '999.2500 LA -999 -999.2500 TENS -999 98,8125 TENS -999,2500 RHOB -999,2500 FFDC 500 GR 00 DRHO 00 TNRA 500 RCFT 2500 GR 2500 THOR 2500 W3NG 500 TENS 500 SA 2500 4669 IbM 0000 OR 2500 DRHO 2500 TNRA 2500 RCFT 2500 OR 2500 THOR 2500 W3NG 2500 TENS 2500 SA 2500 0000 GR .999.2500 DRXO 999,2500 TSRA -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 25O0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 )500 "999 500 ~999 0 -999 2500 -999 2500 -999 2500 -999 2500 =999 2500 4 3102 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 5540 -999 2500 ,,999 2500 -999 2500 [,VP OlO,H'02 VERIFICATION I~ISTINC PAGE 18 RTNR -999,2500 NPHI CFTC -999,2500 CNTC SGR -999,2500 CGR POTA 999,2500 WSNG VR -999,2500 FVR HD -999,2500 -999 2500 RC~T -999 2500 TENS -999 2500 ORAN -999 2500 W4NG -999 2500 CS -999 2500 LA -999 2500 TENS DEPT SP RTN*R CFTC SGR POTA W2~G H~ 5600 0000 -42 -999 -999 -999 -999 -999 -999 -999 -999 -999 5625 GR 2500 CAb! 2500 NFDC 2500 NPHI 2500 CNTC 2500 CGR 2500 WSNG 2500 ~ING 500 FVR 500 SGR 3 6022 107 -999 -999 -999 -999 -999 -999 -999 *999 -999 25 TENS 2500 FFDC 2500 RCNT 2500 TENS 2500 ORAN 500 W4NG 5OO CS 2500 LA 2500 TENS DEPT SP TENS PHI CFTC POT~ 2~G VP 5500 0000 SFLU '999 '99 '999, '999 '9'99 '999 '999 '999 437 GR 5OO CAb! 2500 NFDC 2500 NPHI 2500 C~TC 2500 CGR 250O WSNG 2500 ~!NG 2500 rvR 2500 SGR 3 97 '999 '999 '999 '999 '999 '999 '999 '999 '999 5303 lbo 3125 TENS 2500 RHO~ 500 FFDC 500 RC~T 2500 TENS 2500 URA~ 2500 ~4~G 2500 CS 2500 bA 2500 TENS DEPT SP DPHI RTNR CFTC POTA ~2NG aV~ 5400 0000 8FbU -52 7813 GR -999 2500 CAbI -9 2500 NPHI '999 ~500 CNTC -999 500 CGR '999!~500 WSNG '999 500 ~ING '999 ~0 FVR -999:2 .0 SGR 90 '999 '999 '999 -999 ~999 -999 -999 "999 '999 8791 lbo 8750 TENS 2500 RHOB 500 FFDC 500 RC~T 500 TENS 50O URAN 2500 ~4NG 500 CS DEPT SP~_ RTNR CFTC POTA :~VR' 5300.0000 SrbU -52,~750 GR -999. 500 CAb! :999'25~0 NrOC 9.25 o .999 2500 C TC -999 2500 -999 2500 ~SNG -999 2500 -999 250O FVR -999.2500 RCFT -999 2500 GR -999 2500 THOR -999 2500 W3NG -999 2500 TENS -999 2500 SA -999 2500 4,4547 9 -99 -999 -999 -999 -999 *999 -999 -999 4 ~940 999 -999 -999 -999 -999 -999 -999 -9 IbM 0000 GR 2500 DRHO 2500 TNRA 500 RCFT 500 GR 2500 THOR 500 W3NG 500 TENS 560 SA 2500 : 2894 -999 -999 -999 ' 9 -999 -999 *999 -999 GR 2500 DRHO 500 TNRA 500 RCFT 2500 GR 2500 THOR 2500 ~3NG 2500 TENS 2500 SA 2500 4,8!87 IbD 6 .981,8750 TENS 2930 ~:.2500 RHO~ '999 ., , ,oo -999,2500 .999,! oo TE S ?99 *999, O0 URA~ .999 '999 500 ~4~G 999 -999:2500 CS -999 -999,2500 hA '999 750000 IR 2500 DRHO THOR 500 N3NG 500 TENS 2500 SA 2500 0000 500 DRHO 500 ~NRA 500 RCFT 2500 GR 2500 THO~ 2500 W3NG 2500 TENS 2500 SA -999 2500 -999 -999 2500 -999 2500 -999 2500 4 1969 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 *999 1500 -999 500 -999 2500 -99~ 0690 2500 -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 -999 2500 -999 2500 -999 2500 -999 ~ -999 ~500 -999 2500 -999 2500 -999 2500 '999 0 .,,, -999 2500 -999 2500 . 5 b505 :999 2500 999 2500 :9~9 2500 ..999 2500 -999 2500 -999 2500 -999 2500 -999 2500 '999 2500 LVP 010,H02 VERIFICATION bISTING PAGE 19 -999,2500 SGR DEPT 5200 NS 3780 PHI 28 RTNR 4 CFTC 46 A 0 2NG 114 ~VR 4 HD 6 0000 SFLU 4375 GR 0000 CAb1 9861 NFDC 4681 NPHI CGR 0000 WSNG 9700 WiNG 1719 FVR 9062 SGR DEPT 5100 SP -87 TENS 3714 DpH! 3~ RTNR CFTC 581 SGR 71. POTA ~ W2NG 1! NVR 4 HD 8 0000 SrLU 1875 GR 0000 CAb! 8966 NrDC 8529 NPH! 6129 CNTC 4613 CGR 2 WING 1758 FVR 4063 SGR DEPT 5000 SPN- "94 TBs 3724 DPH! 20 RTNR CFTC 779 SGR 44 POTA 1 W2NG 79 NVR 4 HD 16 0000 SFbU 1250 GR 0000 CAb! 8982 NFDC 0123 NPH! 2132 WSNG 4979 WiNG 1758 FVR 4531 SGR DEPT 4900 PN =72 'E.S 3430 DPH! 22 RTNR 3 CFTC 470 SGR 114 POTA 3 W2HG 182 ~VR 4 HO 13 0000 $FbU 2500 GR 0000 CAb! 4~'!5 NFDC 7~17 NPHI 6152 CNTC 4123 CGR 0402 ~SNG 7843 WiNG 1719 FUR 2344 SGR DEPT 4800,0000 SFLU "69.0000 GR E S 3264,0000 CAbI DPHI 26,5676 NFDC -999 3 717 43 1758 0 5 208 0 0 43 60 14 722 38 1916 56 10 202 0 7! 9¸7 42 14 631 28 218i 3 0 4 101 41 1762 88 8 342 0 3 100 13 667 ,2500 2876 8750 5469 000 547 467O 0000 0 7349 0000 8578 250 750 5000 3467 9487 5450 4712 0942 7339 46!3 0224 8437 2969 0000 1695 23 .0893 ,7500 000 3387 2942 2473 5016 1891 7373 4123 .9217 ,4375 ,3516 ,5000 TENS ibD TENS RHOB FFDC RCNT TENS URAN W4NG CS bA TENS TENS RHOB FFOC RCNT TENS URAN W4NG CS bA TENS TENS RHOB FFDC RCNT TENS URAN W4NG TENS ILD: TENS RHOB FFDC RCNT TENS URAN W4NG CS ~A TENS TENS RHOB FFDC -999,2500 6 0530 IbM 300~ 0000 GR 1718 DRHO ~i 5000 TNRA 1 4365 RCFT 3780 0000 GR 0 0000 THOR 5,9880 W3NG 187~,0000 TENS 1440,0117 SA ,0000 63 733 IbM 000 2,~238 DRHO l~il. 000 TNRA 714,6184 RCFT ,0000 GR 47 2 W3NG 42 2900 2 6:66 2228 3724 I 4 !890 15 2674 8212 IbM 0000 GR 3053 DRHO 0000 TNRA 7207 RCFT )000 GR )460 THOR 841 W3NG 0000 TENS 344 SA 000 4,9278 lbN 000 GR 3,4341 THOR 881 W3NG 3, 000 TENS 18~19'4297 SA 24~,0000 0000 GR 2,21018 DRHO 830,0 O0 TNRA 5 3608 587 5000 0 0199 3 6975 453 5016 587 5000 0 0000 40 7186 1440 0000 I 8936 44 8885 71 8125 0 0086 92 5~½ 6125 183 36 6492 2664 0000 I 3691 56 5O 0 007! 2 8916 671 7596 5~ 3750 ,9665 26.4,0000 0,7241 4 7287 1161250 · 0 0088 3 6696 412 8229 116 1250 :9 9136 61 6366 2424 0000 0 8066 4,5270 I00,875'0 0,0029 3,694! bVP OlO,H02 VERIFICATION LISTING PAGE 20 RTNR 3 CFTC 461 SGR -999 POTA -999 W2NG -999 NVR -999 ~D -999 9560 NPH! 5847 CNTC 2500 CGR 2500 W5NG 2500 WING 2500 FVR 2500 SGR DEPT 4700 SP -72 TENS 3750 DPHI 26 RTNR 4 CFTC 489 SGR -999 POTA -999 2NG -999 VR -999 HD -999 0000 SFLU 2500 GR 0000 CALl 1480 NFDC 1527 NPHI 2536 CNTC 2500 CGR 2500 W5NG 2500 WiNG 2500 FVR 2500 SGR DEPT 4600 SP -57 TEHS 3320 DpHI 34 CFTt 317 SGR -999 POTA -999 W2~G -999 NVR -999 HD -999 0000 SFLU 5313 GR 0000 CAb! 7652 NFDC 5429 NPHI 1613 CNTC 2500 CGR 2500 WLNG 2500 ~ING 2500 FVR 2500 SGR DEPT TENS DpHI RTNR CFTC SGR POTA W2NG NVR 4585 0000 -999 2500 3370 0000 6233 31 4211 304 5222 -999 2500 -999 2500 -999;2500 ~999,2500 999,2500 SFLU GR CALl' NFDC NPHI CNTC CGR WLNG WING FVR ** FILE TRAILER FILB NAME ~EDIT ,001 DATE ,~ ~AXI~U~ 5ENGTH ~ 1024 FILE TYPE NEXT FILE NAME 42 ~946 1646 603 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 1622 102 3125 12 9297 676 5000 42 8032 1742 9033 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2000 0000 60 4063 9 72 52 3936 1303 2703 -999 2500 -999 ~500 "999 500 -999 2500 "999 2500 -999.2500 1 1308,9836 ,999,2500 999.2500 -999;2500 "999'2500 '999,2500 RCNT TENS URAN W4NG bA TENS TENS RHOB FFDC RCNT TENS URAN W4NG CS TENS TENS RHOB FFDC RCNT TENS URAN W4NG CS bA TENS ILD TENS RHOB FFDC RCNT TENS URAN W4NG: CS TENS 11~,8801 RCFT 3 .0000 GR -999,2500 THOR -999,2500 W3NG '999.2500 TENS '999,2500 SA '999,2500 4.8413 2640.0000 2.2187 829 5000 1671 7456 3750 0000 "999 2500 -999 2500 -999 2500 -999 2500 -999 2500 12 0886 2584 0000 2.0765 523 0000 283 6677 : .oooo ,2500 -999.2500 -999'2500 ,2500 -999.2500 :999'2500 !,9963 )! .oooo ,4055 3 0.000o -99 2500 '999,2500 -999,250;0 '999,2500 l.bM GR DRHO TNRA RCFT GR THOR W3NG TENS SA IbM GR DRHO TNRA RCFT THOR W3NG TENS .GR DRHO TNRA RCFT GR THOR W3HG TENS 414.5020 100.8750 -999.2500 -999,2500 -999.2500 '999,2500 4 6508 114 5000 0 0097 3 7163 430 8356 114 5000 -999 2500 -999 2500 -999 2500 "999 2500 2000 0000 77 8125 -0 3201 4 0591 310 9407 77 8125 -999 2500 '999 2500 '999 2500 -999 2500 '999,25'00 72,3750 "0.3259 4;1948 276,7420 72,3750 -999,2500 -999,2500 -999,2500 -999;2500 LVP O10,H02 VERIFICATION LISTING PAGE 21 ** FILE HEADER FILE .A~E IEDIT ,00~ SER¥ICE VERSION # DATE = "A~I.U. LENGTH : 1024 FX£E TYPE PREVXOUS FXLE : ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 ~ 1 66 1 8 4 73 20 9 4 65 .lin 16 1 66 1 0 I 66 0 DATU~ SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 AP1 APl AP1 FILE SiZE SPL REPR ID DEPT NVU EPT FYU EPT NVD EPT FVD EPT EATT EPT TPB ~PT EPHI EPT ~I~V EPT ~'NOR EPT ORDER # LOG TYPE CLASS MOD NO, CODE (OCTAL) FT O0 000 O0 0 0 4 I 68 00000000000000 V O0 000 O0 0 0 4 1 68 00000000000000 V O0 000 O0 0 0 4 1 68 00000000000000 V O0 000 O0 0 0 4 I 68 00000000000000 V O0 000 O0 0 0 4 I 68 00000000000000 DB/~ 00 130 01 0 0 4 1 68 00000000000000 NS/M O0 132 01 0 0 4 1 68 00000000000000 PU 00 890 00 0 0 4 1. 68 00000000000000 OHMM 00 250 00 0 0 4 1 68 00000000000000 OHMM O0 252 00 0 0 4 I 68 00000000000000 ** DATA DEPT FVD MINV 520.4,3330 NVU 0,~769 EATT O, 286 MNOR 1,0684 FVU ~:4878 NVD V ~ 81 0.0352 E PT 5200,1660 NVU 1.0684 FVU 0,4878 NVD 0,7192 VD 0,2769 EATT 1.17,{,250 TPL 22,2813 EPHI 6'1,8711 MINV 0,3286 MNOR O. 0352 DEPT FVD 5100,1660 NVU 0, .3032 EATT O, 328:6 MNOR 1.5576 FVU 0,2778 NVD 5-1'98732 338'5000 TPb 19,7813 EPHI ,0508 0,0352 FDEPT VD MINV 5000,1660 NVU .. 0 3286 1,3711 FVU 0.7446 NVD 1,3i64 154,2500 TPL !t,8281. EPHI 13.5254 0,0352 LVP OlO,H02 VERIFfCATZON LISTING PAGE 22 DEPT 4900,1660 NVU 1,3936 FYU FVD' 0,3276 EATT 270,5000 TPL ~INV 0,3286 MNOR 0,0352 0.3062 NVD 16,1562 EP~I 1, 3 DEPT 4846,5000 NVU 1,6836 FVU FVD 0,4150 EATT 318.5000 TPL I~INV 0,3{286 MNOR 0.0352 0.3872 NVD 15,8906 EPHX 1,9072 31.7383 FILE NAME ~EDXT ,002 SERVICE NAME VERSION ~ DATE I ~AXIVU~ LENGTH { 1024 FILE TYPE NEXT FILE NAME ** FILE HEADER FILE NAME IEDXT ,003 SERVICE NAME VERSION # DATE{ NAXI~U~ LENGTH I 1024 FILE TYPE PREVIOUS FILE **.DATA FORMAT RECORD ~NTRY FLOCKS TYPE SiZE REPR CODE ENTRY 2 ! 66 0 4 1 66 1 8 4 73 12 9 4 65 ,lin 10 I 0 DATU~ SPECIFICATION BLOCKS M.NE~ SERVICE SERVICE UNIT APl APl APl APl FILE SIZE SPb REPR ID DEPT GR FDM TE~S FDH CA[ii FDH RHOB FDH DRHO FDH DPHI FDH NFDC FDH FFDC FDH TNRA CNH PROCESS S CODE (OCTAL) ORDER # I, OG TYPE CbAS NOD NO, FT O0 000 O0 0 0 4 1 68 00000000000000 GAPI O0 3!0 O1 0 0 4 I 68 00000000000000 LB O0 635 21 0 0 4 t 68 00000000000000 IN O0 280 O1 0 0 4 I 68 00000000000000 G/C3 O0 350 02 0 0 4 1 68 00000000000000 G/C3 O0 356 O1 0 0 4 ! 68 00000000000000 PU O0 890 O0 0 0 4 i 68 00000000000000 CP~ O0 354 O1 0 0 4 1 68 00000000000000 CPS O0 354 02 0 0 4 I 68 00000000000000 O0 420 01 0 0 4 1 68 00000000000000 RTNR CNH O0 000 NPH! CNH PU O0 890 RCNT CNH CPS O0 000 RCFT CNH CPS O0 000 CFTC C.H CPS O0 000 CNTC CNH CPS O0 000 TENS CNH LB O0 635 GR CNH GAP! O0 310 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 21 0 0 4 O1 0 0 4 DATA DEPT RHOB FFDC RCNT TENS 11200 0996 GR 1 8278 DRHO 2014 0000 TNRA 1772 0251 RCFT 1850 0000 GR DEPT RHOB FFDC RCNT TENS 11100 2988 OR 2 3307 DRHO 713 0000 TNRA 1932 4055 RCFT 1995 0000 GR DEPT RHOB FFDC BCNT TENS 11000 2988 GR 2 4455 DRHO 478 0000 TNRA 2329 5947 RCFT 1980 0000 GE DEPT RHOB FFDC RCNT TENS !090~,2988 G.R ,3958 DRHO 513,0000 TNRA .0000 GE DEPT FFDC RC~T TENS 10800.2988 GR 2.5120 DI~HO 364.2500 TNRA 1977'3967 RCFT 1945.0000 GR DEPT RHOB FFDC RCNT TENS 107002,2988 OR ,2820 DRHO 721,5000 TNRA 1755,6897 RCFT 1995,0000 OR D~ EPT RHOB FFDC RCNT TENS 10600,2988 GR 2'357I DRHO 649,0000 TNRA 1658' 8201 RCFT 1940,0000 GR 82 5000 TENS -0 0208 DPHI 3 6982 RTNR 438 6476 CFTC 82 5000 89 1250 TENS 0:0602 DPHI 3,0536 RTNR 626,4521 CFTC 89,1250 66 0 2 783 66 4 DPHI 7890 RTNR 68' 82.6875 TENS '0.O085 DPH! 2,9080 RTNR 702~9844 CFTC 82,6875 73,5000 TENS '0,03~5 DPHi 3,33 9 RTN~ 5~9,481. I CFTC 3.5000 119,3750 TENS 9719 RTNR 32,5436 CFTC 1! 9,3750 117.1250 TENS .0484 DPHI ~.8907 RTNR 348,8729 CFTC 117.1250 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1850.0000 CALI 49,8365 NFDC 3,9875 NPH! 494,0092 CNTC :4922 79 5000 51,5341 1793,7363 1995.0000 CAbI 19.3617 NFDC 3.3103 NPHI 659.9751 CNTC 7 3633 698i0000 36 5758 2017 7407 1980,0§00 CALl 906,6086 CNTC 8.4297 578,0000 30,8322 2456,6006 !790,0000 CALl 15,4160 NFDC 3,2051 NPH1 829,9357 CNTC 8,6641 558,0000 32,3321 2344,6333 1945 0000 CALl 8 3751 NFDC 3 4839 NPHI 641 5148 CNTC .8,6641 467,5000 40,0364 2071,2012 1995.0000 CAbI 8.5156 22,31 !5 NFDC 656,5000 4,0000 NPHX 51.8248 426.8099 CNTC 1689,3394 1940,0000 CAb! 460.~000 NPHI 548 CNTC 8,1953 8.58000 1699..4 22 LVP 010,~02 V£RIFICATION LISTING PAGE 24 DEPT 10538,5000 GR 111 7500 TENS FFDC 58u,0000 TNRA 3,8~04 RTNR RCNT 1637,423] RCFT 439,5737 CFTC TENS 1860,0000 GR 111,7500 ** FILE TRAILER ** FILE NA~E IEDIT ,00] VERSION # DATE { ~AXI~UM L~NGTH = 1024 FILE TYPE NEXT FILE NAME ******~*** EOF 1860 0000 CALl 18:1054 NFDC 3,7391 NPHI 453,3463 CNTC 8 539{ 590' 48,0000 1743 ,8308 ,4675 ** TAPE TRAILER SERVICE NAME DATE t88/02/17 ORIGIN 17259 TAPE NA, ME CONTINUATION # =01 NEXT TAPE NAME COMMENTS {EDiT LIS,ARCO KUPARUK 3H'21,API # 50-103-20094 ** REEL TRAILER SERVICE NAME =EDIT DATE 88/02/17 ORiGIn= REEL NA~E =72599 CONTINUATION# NEXT REEL NA~E COMMENTS ~EDIT bIS,ARCO KUPARUK 3H-21,API # 50-103-20094 EOF EOF
