Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
191-108
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 1E-07A 50-029-20495-01 909619502 Kuparuk River Packer Setting Record Field- Final 20-Oct-24 0 12 1E-28A 50-029-20832-01 n/a Kuparuk River Packer Setting Record Field- Final 16-Jan-25 0 13 1F-08 50-029-20836-00 909737879 Kuparuk River Plug Setting Record Field- Final 3-Dec-24 0 14 1H-101 50-029-23585-00 909606936 Kuparuk River Multi Finger Caliper Field & Processed 28-Oct-24 0 15 1R-20 50-029-22207-00 909678505 Kuparuk River Packer Setting Record Field- Final 11-Nov-24 0 16 2A-16 50-103-20042-00 909780661 Kuparuk River Multi Finger Caliper Field & Processed 1-Jan-25 0 17 2C-03 50-029-20968-00 909740014 Kuparuk River Plug Setting Record Field- Final 14-Jan-25 0 18 2M-07 50-103-20178-00 909618938 Kuparuk River Plug Setting Record Field- Final 25-Oct-24 0 19 2W-01 50-029-21273-00 909740411 Kuparuk River Radial Bond Record Field- Final 7-Jan-25 0 110 3B-04 50-029-21323-00 909740412 Kuparuk River Multi Finger Caliper Field & Processed 3-Jan-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39999T40000T40001T40002T40003T40004T40005T40006T40007211-062213-095182-162217-138191-108185-147183-089192-080185-010185-061T400081/23/2025217 138191-108185 14751R-2050-029-22207-00909678505Kuparuk RiverPacker Setting RecordField- Final11-Nov-2401Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:13:51 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10080'feet None feet true vertical 7073' feet 10000' feet Effective Depth measured 10080'feet 3901', 3931', 9233', 9413' feet true vertical 7073'feet 3034', 3054', 6531', 6645' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-7/8" L-80/ J-55 9454' MD 6671' TVD Packers and SSSV (type, measured and true vertical depth) 3901' MD 3931' MD 9233' MD 9413' MD N/A 3034' MD 3054' TVD 6531' MD 6645' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 5550' 4162' Burst Collapse Production Liner 10021' Casing 7064'10063' 5508' 122'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-108 50-029-22207-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025628, ADL0025635 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1R-20 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 122' ~ ~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker FHL EUE bxp Packer Packer: Baker D Perm Packer SSSV: None Shelby Sumrall shelby.sumrall@conocophillips.com (907) 265-6678Staff Well Integrity Engineer 9350-9387', 9591-9648' 6605-6629', 6759-6796' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:50 pm, Nov 20, 2024 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.11.20 12:22:59-09'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall DTTMSTART JOBTYP SUMMARYOPS 11/9/2024 ACQUIRE DATA PULLED 2.71" BAIT SUB & EQ PRONG @ 9249' RKB. IN PROGRESS. 11/10/2024 ACQUIRE DATA PULLED 2.81 PXX PLUG BODY @ 9257' RKB, BRUSH & FLUSH PATCH AREA FROM 4000' TO 3800' RKB, CLEAN DRIFT W/ 2.72" x 34' DUMMY PATCH TO 4000' RKB, SET LOWER 2.72" P2P @ 3933' RKB (CE) (OAL 4.01' / SN:CPP35365), SET 3 1/2 TTS TEST TOOL IN LOWER PACKER @ 3933' RKB CMIT TBG x IA 2500 PSI ( PASS ). IN PROGRESS. 11/11/2024 ACQUIRE DATA PULLED 3 1/2 TTS TEST TOOL @ 3930' RKB, SET UPPER 2.72" PATCH ASSEMBLY @ 3903' RKB (CE) TOP @ 3900.55' RKB (OAL 30.89' / SN: CPP35089 / CPAL35211), SET 3 1/2 TTS TEST TOOL IN UPPER PACKER @ 3900.55' RKB, MIT TBG 2500 PSI (PASS), MIT IA 2500 PSI (PASS), PULLED DV @ 3189' RKB SET 1.5" OV @ SAME ( 3/16" PORT), MIT TBG 2500 PSI (PASS), PULLED 3 1/2 TTS TEST TOOL @ 3900' RKB. JOB COMPLETE. 1R-20 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,703.0 1R-20 2/16/2021 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Tbg Patch 1R-20 11/11/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 5/30/2019 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 43.0 122.0 122.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 42.2 5,550.5 4,161.6 36.00 J-55 BTC PRODUCTION 7 6.28 42.2 10,063.4 7,063.6 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.6 Set Depth 9,413.0 Set Depth 6,645.2 String Max No 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD AB- Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 38.6 38.6 0.22 HANGER 6.000 Tubing Hanger FMC Gen IV (6" x 3 1/2" EUE) FMC Gen IV 2.992 3,189.3 2,563.3 49.53 GAS LIFT 5.968 GLM Camco 3-1/2" x 1-1/2" MMG (SN# 100AG09) 3158' CAMCO MMG 2.915 5,199.7 3,914.3 45.90 GAS LIFT 5.968 GLM Camco 3-1/2" x 1-1/2" MMG (SN#164AG09) 5174' CAMCO MMG 2.915 6,275.3 4,667.7 48.64 GAS LIFT 5.968 GLM Camco 3-1/2" x 1-1/2" MMG (SN#013AJ07) 6254' CAMCO MMG 2.915 7,474.1 5,426.6 51.19 GAS LIFT 5.968 GLM Camco 3-1/2" x 1-1/2" MMG (SN#172AG07) 7430' CAMCO MMG 2.915 8,421.8 6,023.5 51.64 GAS LIFT 5.968 GLM Camco 3-1/2" x 1-1/2" MMG (SN# 031AJ07) 8386' CAMCO MMG 2.915 9,218.8 6,521.4 50.53 LOCATOR 5.880 Locator OAL .97, and seals ~2ft off no go Baker 2.990 9,220.7 6,522.7 50.53 PBR 5.000 80-40 PBR Baker 80-40 4.000 9,233.4 6,530.8 50.53 PACKER 6.990 Packer Baker FHL EUE bxp Baker FHL 2.930 9,257.3 6,546.0 50.51 NIPPLE 5.900 X-Nipple, 2.813" X (SN# 2727A-3- 4 ) drifted 2.808 Halliburt on "X" 2.813 9,278.6 6,559.5 50.50 Mandrel PROD 5.968 GLM Camco 3-1/2" x 1-1/2" MMG (SN# 269AG09) CAMCO MMG 2.915 9,307.9 6,578.1 50.47 Mandrel PROD 5.968 GLM Camco 3-1/2" x 1-1/2" MMG (SN#008AJ08) CAMCO MMG 2.915 9,336.6 6,596.4 50.40 BLAST JOINT 3.500 Blast Rings 3 1/2" 9.3#, L-80 BTC PESI Blast rings 2.992 9,409.7 6,643.0 50.24 SEAL ASSY 3.250 Locator (1ft OAL) Seal assy Baker (7.44' OAL) Baker 80-32 2.380 Top (ftKB) 9,413.0 Set Depth 9,453.7 Set Depth 6,671.3 String Max No 2 7/8 Tubing Description Tubing Completion Lower Wt (lb/ft) 6.50 Grade J-55 Top Connection AB MOD-EUE ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,413.0 6,645.2 50.24 PACKER 5.667 BAKER D PERMANENT PACKER 3.250 9,416.6 6,647.5 50.24 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 9,436.8 6,660.4 50.21 NIPPLE 5.900 OTIS XN NIPPLE 2.25" ID NO GO w/ 2.313" PACKING BORE 2.250 9,453.0 6,670.8 50.19 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,900.6 3,033.6 48.02 PACKER - PATCH - UPR 3-1/2" P2P UPR PATCH PKR MID-ELEMENT AT 3903' RKB W/ ANCHOR LATCH AND SPACER PIPE, OAL 30' TTS P2P CPP3 5089 / CPAL 35211 11/11/2024 1.625 3,904.2 3,036.1 48.02 SPACER PIPE 2-1/16" P-110 SPACER PIPE 11/11/2024 1.550 3,919.0 3,046.0 48.05 LEAK LEAK AT 3919' RKB IDENTIFIED BY ACOUSTIC LDL (0.3 BPM, 2500 PSI) 8/21/2024 2.992 3,930.6 3,053.7 48.07 PACKER - PATCH - LWR 3-1/2" P2P LWR PATCH PKR MID-ELEMENT AT 3933' RKB, OAL 4.01' TTS P2P CPP3 5365 11/10/2024 1.625 10,000.0 7,022.8 49.90 FISH FISH GLV @2907 w/broken latch; latch in rathole - LOST 6/29/99 4/19/1997 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,189.3 2,563.3 49.53 1 GAS LIFT OV RK 1 1/2 0.0 11/11/2024 07:00 Camco MMG 0.188 5,199.7 3,914.3 45.90 2 GAS LIFT DMY RK 1 1/2 0.0 8/5/2019 12:00 0.000 6,275.3 4,667.7 48.64 3 GAS LIFT DMY RK 1 1/2 5/16/2019 11:00 7,474.1 5,426.6 51.19 4 GAS LIFT DMY RK 1 1/2 5/16/2019 07:00 8,421.8 6,023.5 51.64 5 GAS LIFT DMY RK 1 1/2 0.0 8/4/2024 05:00 0.000 9,278.6 6,559.5 50.50 6 PROD DMY RK 1 1/2 0.0 7/27/2024 0.000 1R-20, 11/15/2024 3:43:30 PM Vertical schematic (actual) PRODUCTION; 42.2-10,063.4 FLOAT SHOE; 10,061.9- 10,063.4 FISH; 10,000.0 FLOAT COLLAR; 9,976.7- 9,978.1 IPERF; 9,591.0-9,648.0 SOS; 9,453.0 NIPPLE; 9,436.8 SBE; 9,416.6 PACKER; 9,413.0 IPERF; 9,350.0-9,387.0 Mandrel PROD; 9,307.9 Mandrel PROD; 9,278.6 NIPPLE; 9,257.3 PACKER; 9,233.4 PBR ; 9,220.7 LOCATOR; 9,218.8 GAS LIFT; 8,421.8 GAS LIFT; 7,474.1 GAS LIFT; 6,275.3 SURFACE; 42.2-5,550.5 FLOAT SHOE; 5,548.8-5,550.5 FLOAT COLLAR; 5,464.7- 5,465.9 GAS LIFT; 5,199.7 PACKER - PATCH - LWR; 3,930.5 LEAK; 3,919.0 SPACER PIPE; 3,904.2 PACKER - PATCH - UPR; 3,900.6 GAS LIFT; 3,189.3 CONDUCTOR; 43.0-122.0 HANGER; 42.2-46.7 HANGER; 38.6 KUP PROD KB-Grd (ft) 42.99 RR Date 9/11/1991 Other Elev 1R-20 ... TD Act Btm (ftKB) 10,080.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292220700 Wellbore Status PROD Max Angle & MD Incl (°) 54.13 MD (ftKB) 2,000.00 WELLNAME WELLBORE1R-20 Annotation Last WO: End Date 5/4/2019 H2S (ppm) 50 Date 7/15/2019 Comment SSSV: NONE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 9,307.9 6,578.1 50.47 7 PROD DMY RK 1 1/2 0.0 7/26/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,350.0 9,387.0 6,604.9 6,628.6 C-1, 1R-20 1/7/1992 12.0 IPERF 4.5" Csg Guns; 45 deg 9,591.0 9,648.0 6,759.2 6,795.8 A-4, A-3, 1R-20 1/7/1992 4.0 IPERF 4.5" Csg Guns; 180 deg 1R-20, 11/15/2024 3:43:31 PM Vertical schematic (actual) PRODUCTION; 42.2-10,063.4 FLOAT SHOE; 10,061.9- 10,063.4 FISH; 10,000.0 FLOAT COLLAR; 9,976.7- 9,978.1 IPERF; 9,591.0-9,648.0 SOS; 9,453.0 NIPPLE; 9,436.8 SBE; 9,416.6 PACKER; 9,413.0 IPERF; 9,350.0-9,387.0 Mandrel PROD; 9,307.9 Mandrel PROD; 9,278.6 NIPPLE; 9,257.3 PACKER; 9,233.4 PBR ; 9,220.7 LOCATOR; 9,218.8 GAS LIFT; 8,421.8 GAS LIFT; 7,474.1 GAS LIFT; 6,275.3 SURFACE; 42.2-5,550.5 FLOAT SHOE; 5,548.8-5,550.5 FLOAT COLLAR; 5,464.7- 5,465.9 GAS LIFT; 5,199.7 PACKER - PATCH - LWR; 3,930.5 LEAK; 3,919.0 SPACER PIPE; 3,904.2 PACKER - PATCH - UPR; 3,900.6 GAS LIFT; 3,189.3 CONDUCTOR; 43.0-122.0 HANGER; 42.2-46.7 HANGER; 38.6 KUP PROD 1R-20 ... WELLNAME WELLBORE1R-20 Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11LͲ28 50Ͳ029Ͳ22951Ͳ00 ALSL764Ͳ003 Kuparuk River Plug Setting Record FieldͲFinal 17ͲSepͲ24 0 121LͲ28 50Ͳ029Ͳ22951Ͳ00 ALSL764Ͳ003 Kuparuk River SBHP RecordFieldͲFinal 17ͲSepͲ24 0 131QͲ09 50Ͳ029Ͳ21209Ͳ00 909524807 Kuparuk River Packer Setting Record FieldͲFinal 27ͲAugͲ24 0 141RͲ05 50Ͳ029Ͳ21330Ͳ00 ALSL764Ͳ001 Kuparuk River Leak Detect Log FieldͲFinal 12ͲSepͲ24 0 151RͲ05 50Ͳ029Ͳ21330Ͳ00 ALSL764Ͳ001 Kuparuk River Multi Finger CaliperField & Processed 13ͲSepͲ24 0 161RͲ05 50Ͳ029Ͳ21330Ͳ00 ALSL764Ͳ001 Kuparuk River Plug Setting Record FieldͲFinal 12ͲSepͲ24 0 171RͲ20 50Ͳ029Ͳ22207Ͳ00 909524808 Kuparuk River Multi Finger CaliperField & Processed 28ͲAugͲ24 0 181YͲ27 50Ͳ029Ͳ22379Ͳ00 909524542 Kuparuk River Leak Detect Log FieldͲFinal 22ͲAugͲ24 0 191YͲ27 50Ͳ029Ͳ22379Ͳ00 909524542 Kuparuk River Multi Finger CaliperField & Processed 22ͲAugͲ24 0 110 2AͲ04 50Ͳ103Ͳ20026Ͳ00 909593148 Kuparuk River Multi Finger CaliperField & Processed 22ͲSepͲ24 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:T39684T39684T39685T39686T39686T39686T39687T39688T3968810/21/2024199-098184-192185-070191-108193-088184-053T39689Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:39:57 -08'00'1RͲ2050Ͳ029Ͳ22207Ͳ00 909524808KuparukRiverMultiFingerCaliperField&Processed28ͲAugͲ2401T39687185 070191-108193 088 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-08-21_23045_KRU_1R-20_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23045 KRU 1R-20 502-029-22207-00 LeakPoint Survey 21-Aug-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 191-108 T39489 8/26/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.26 14:37:58 -08'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϵϭϭϬϴϬ Ͳ^Ğƚ͗ϯϲϮϰϳJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May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y Samantha Carlisle at 9:04 am, Jul 13, 2020 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2020-07-10 16:44:45 Foxit PhantomPDF Version: 9.7.0 Roger Mouser SFD 7/13/2020VTL 7/27/20 RBDMS HEW 7/13/2020 DSR-7/13/2020 SFD 7/13/2020 7,074 10,080 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2020-07-10 16:43:57 Foxit PhantomPDF Version: 9.7.0 Roger Mouser ' "((#) *+" ' "((#)$ !"# $% & '& (! & '$) (% !" '$% (% )' ** ( !! "!#$%&'()$(*+ ,-. ! /&01/ " # 2 $ % & % ' 2 3 0 0 ! #145/ " # 2 $ % 2 & % ' 6 7/ ! $01/8& " # 2 2 $ % & % ' 6 7/ 90 ( ( ! 178&: $01/8& % # % 2 $ % 2 & ' ! 1 057 9* ) $ # ! * # ) ) + ) # 5&: (.;!!<49/:!8+=>? > 1 @ 2 /5 A<5 !*B ! $7 2$7 2 2 $5/C $AD<7D<4 1 .?' 2 &8$$ % &;'' >%=#&E 5 2F%%'(@*<;* 2 2 75#68& 7;! >E 7/ 2 2 2 # 55##G A<= 5@#H7D<=22 5@ ( ! 8:8&5 3 /9$ 8& % # 22 2 % 2 $ % & ' 6 ! 5790 1 ) $ # ! * # ) ) + ) # 2 2 2 $5/C 75C 0$ 95& &$5/C 2 2 2 #7 75C # 57 % & 2 2 &8$$ 8#%&&8$$ >80&:F >$5/C8&:7 2 ## 75C # 51#17 22 " # , (- -()- - !. $ # ! * ) ( # + 2 2 >$%&$( >$%&$(=$ $<! .;(.@$( 7*HI >7;*$ $<!I > 2 48# 48#:+J F.<D!A KA ;! < # 2 / 0 ) $ )$ 1 2 & ) 2 / 8$ 4 2 >/:(!K2 * 2 5 2 5 2 8$ 4 2 >/:(!K * # + & $ 1 " $ ! / 3 " ( ( ) /59/ 99: :5#84 $ & '! 2 /59/ 99: :5#84 09G C 2 /59/ 99: :5#84 09G C 2 22 2 /59/ 99: :5#84 09G C 2 /59/ 99: :5#84 09G C /59/ 99: :5#84 /+ C$ 2 # < ( +" /59/ 99: :5#84 /+ C 2 + 4' 0 & +;F#A -;AF5D#A -;A !"#$% &'() )( *%+,') % -*' ) (.) + +' () &% /-' ( ). +0-' ( ) #1-' () % -*' ) . ) 2+/%*$' ) 2+/%*$' .) &% /-' ) ).3 4& 5' ( ) #1-' )( 0' ) / #$ ' .). 2+/%*$'.(). 2+/%*$' ( () 2+/%*$' ) +"*#-'()) 2+/%*$' ) 2+/%*$'. ) # &!"#$ '()) ,&2-'.) 5// " 6' 2 7 689 ... !) ( : +) C1$51C8+ 1&8 /#&5# ( $0 ; 0 # !* 2 + " 7 689 3 2 ,8 ) )) ###+&& STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS � 415M.T L-116gt 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 2] Operations shutdgwii ❑ v, 11—p Performed: Suspend C]Perforate E]Other StimulateE]Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 17 Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development P ❑ Exploratory E]191 Stratigraphic❑ Service ❑ 108 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-22207-00-00 7. Property Designation (Lease Number): 8. Well Name and Number ADL 25638, ADL 25635 I(RU 1 R-20 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,080 feet Plugs measured None feel true vertical 7074 feet Junk measured 10,000 feet Effective Depth measured 10,063 feet Packer measured 9233, 9413 feet true vertical 7,064 feet true vertical 6531, 6645 feet Casing Length Sim MD TVD Burst Collapse CONDUCTOR 79 feet 16 122' MD 122' TVD SURFACE 5,508 feet 9 5/8 " 5,551' MD 4162' TVD PRODUCTION 10,021 feet 7 10,063' MD 7064' TVD Perforation depth: Measured depth: 9350-9387. 9591-9648 feet True Vertical depth: 6605-6629. 6759-6796 feet Tubing (size, grade, measured and true vertical depth) 3 1/2 x 2 7/8 L -80/J-55 9,454' MD 6,671' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - PACKER BAKER FHL 9,233' MD 6,531' TVD PACKER - BAKER D PERMNTPACKER 9,413' MD 6,645' TVD SSSV - NONE N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: o 0 o e 190 Subsequent to operation: 1 303 270 1 3850 1370 1 225 14. Attachments (required Per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 10 Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Ej Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-118 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton contact Email: kyle.hampton@cop.com Authorized Title: Sr. Wellsineer A A Contact Phone: (907) 263-4627 Authorized Si nature: Date. I rorm 1d-404 Revised 4/Z017 r v,� 77p/G Submit Original Only ( I l � `�l%� RBDMS��JUN 1 8 2019 KUP PROD WELLNAME IR -20 WELLBORE 1R-20 Well Attributes Max Angle& MD TD Conoco• "'"'im+!N Alaska. Inc.PURARUK (tt�(� (�� %0PSS1S1V11Nt0NE Name Wellh re APV Wellbme3a ue MO (XK91 ACL BIm K9) RIVER UNIT 50029222D]00 PROD 0.13 2,000.00 10,0800 Ni5ppm1 Dale AnnolalKn En40ale KRGMIfl) RIP ReWwDah Last WO: 5/48019 42.99 9/11/1991 Last Tag Mt 2c 617120195iU1 PM I Vkraur rcmmklacMal) Annommon Rome EM DaN WNIEore IJst MaJ By ...._ -__... ... .,,, ....... Last Tag- 9,]060 ))5200] 1R-20 Conversion INfA^EP, 306 Last Rev Reason BALK PREO&JRE VALVE 396 AnnoNlion EnE pate WBIIODre LastMW By Rev Reason: PVIIB Replace Tubing.',u IFnnalt Casing Strings Casing.-wrtarn ODllnl I ODnI Top IflKB) Se10ep01flKB) Set DepXI(M)...VIIILen g... Gr We Top TMeW CONDUCTOR ib 150fi 410 122.0 1220 625p H-00 WELDED Lasing pes.NPBonOp (")IO(m) '-ppo I smI kmvti staneplll(NOI... WIILen (I... GrYle nm Thamon SURFACE 9518 8.92 42.2 5,550.5 4,1616 36.00 J-55 Inc 00lln) SURFACE CONWGTOR 40-IM0 Fpesarlptian Ip (n iopIXK81 sm,,Ih IXKBI ., DtpU 1TV0)....mait...tUi Tap Tl, reatl PRODUCTION 7 628 42.2 10,063.4 ],0636 2600 J-55 BTC -MOD Tubing Strings iuEinO pascripLon SNinB Ma... TUBING 312 IOIInI 2.99 TOPI"an 386 BN Chi IX..BNaepRGVD)I... 9.4130 6,6452 V/I nNXI 9.30 6+a0e LA0 T7AConneclion EUE8ROAB- GMS UFT, 3+89.3 PRODUCTION I Mot Completion Details Top RAID) Top mal Nominal r mrca) (') Item D® Cam to (ml GAs uFT.s1YJ> 0 38.6 0.22 HANGER Tubing Hanger FMC Gen IV IF x 3112 EUE) 2992 . 6,521A 50.53 LOCATOR Locator OAL 97, ant seals -2ft off no go 2. ] 6,522 ] 50.53 PBR 0 PER 4_A ,508 50.53 PACKER Packer Baker FHL EUE Dump 2.93 P9,218, ,546.0 50.51 NIPPLE X -Nipple, 2.813'X (Si 2T21A-3-0wIXXN, Lriftet 2808 2.813 SURFAcerz2s.ss0s- 6 6,59fi.4 5040 BLA TJOINTBlast Rings31I283k, LA BTC 2.992 .] 66430 5024 SEAL ASSY LOwtor IIB OALI Seal easy Baker 1244' OAL)2J80 UFr;B3]sa eem 1Plin mr, Ma...ar IGINAL 2]18 lln) 244 TOPIflkBI 94130 SM -e Ift 9,453.) SM peW1I-)I...Wpli 6,6]13 650 01. J-55 TopCennMNGAS AS MOD-EUE TION Completion Details OMr UST: 7..1 TaP�FVp) Topmd Nominal Top IflKB) mKB) ea )°) hem pCom ID Pn) 9,4130 6.6452 5024PACHER BAKERDPERMANENT PACKER 3250 9,4166 6,64)5 5024 SBE BAKER . 111KEEXTENSION 3250 9,4368 6.660.4 50.21 NIPPLE OTISXNNIPPLE2n IDNOGOw12.313`PACKINGBORE 2250 oAa uFr: e.4as 9,053.0 6,6]0.8 50.19 SOS 1 BAKER SHEAR OUT SUB 2441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top TOPRRSA Bonn Toplaal I°I Dire Com Run ob"IDllnl 38.6 38.6 0.22 BAC A K BPV 5202019 mcA1DR.2nb PRESSURE VALVE PBR 9..1 PACKFR;em4 1 ,0000 ].0228 49.90 FISH FISH LV ]wNmken let MUM ramose- LOST 629/99 .191199] 0000 NIPPLE;%ai3 Perforations S Slots Shot Dens GAS LIFT: 91 Top (WD) SUB (WD) Ue. TePmKB) BM1nIKKB) MB) been MnkeE Zane I Data I I Type Co. 9,3500 9,38].0 0.'1: 6, C-1, 1ft-20 1011992 12.0 (PERF 4.5'Csg Guns; 45 teg Das un:e.mT.e ,5910 1 9,6480 1 6,7592 6,795. A1,AA,1R-20 111,11nall 1 4.0 IFOH, 1..,, 11 Guns; 18 --I Mandrel Inserts ri NTop(TVD) Valve Latah PDXgW TRo Run TWMB) IBKB) Make Mki OD(m Sery Type Treat(In) (Ps9 Run Cam Cam 1 j,ispr3j 2,563.3 1 CAMCO MMG GAS LIFT GLV 0188 1,2350151221201 2 5,199.] 3,914.3 CAMCO MM 1112 GAS LIFT OV 0250 5122/201 IPERF;s,aso",ar o- 8,2753 4,6fi)] CAMCO MM 112 GAS LIFT DMY 5116201 4 ],4]4.1 5,426.6 CAMCO MM 112 GAS LIFT DMY 5/16201 5 8,4218 6,023.5 CAMCO MMG 112 GAS LIFT DMY 5[16201 6 9,2786 6,5595 Ckki MM 112 GAS LIFT CV 5/24201 7 9,307.9 6,578.1 CAMCO DID 1112 GAS LIFT CV 52.2019 Notes: General 8 Safety PACKEB:d4IIo Anndumn trifficiii 5+3W2019 NOTE: View Schematic wl Alaska SchemaGC1D.0 SPPLE;8.439.8 Do3:RA530 IPERF', Spm 68649.0 FISH. iRDI PRODUCTION, 43.2-1O,DR Operations Summary (with Timelog Depths) 1 R-20 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stare Time 5/4/2019 End Time 5/4/2019 Dur(hd 18.00 Phase MIRU Op Code MOVE Activity Code Time P-T-xStan Operation Depth (WB) End Depth (XKB) 00:00 1800 MOB P Move rig from 1R-26 to 1R-20. And spot sub Base and Spot pits and Hook up all lines Berm up PiLSub box Spot Flow Back Tanks and Choke house R/U All hard line to tanks . 5/4/2019 5/5/2019 6.00 WI-RU WELCTL SEQP P Continue R/U on well w/ FMC lub on 18:00 00:00 tree and Pulled BPV w/1300 psi on well Rig Accepted @1800 Hrs R/U high line power UD FMC tub and R/U to Kill well. 5/5/2019 5/5/2019 1.00 MIRU WELCTL PRTS P Test all lines to tigertanks. 00:00 01:00 5/5/2019 5/5/2019 3.00 MIRU WELCTL CIRC P Circuate well bore to 8.5 ppg 01:00 0400 seawater. Pump 530 bbls down tubing at 3bpm at 990 psi taking returns up IA to tiger tank. Tubing and IA pressure after the circulation is 600 psi. 5/5/2019 5/5/2019 9.50 MIRU WELCTL KLWL P Circulate wellbore to 10.6 ppg brine 04:00 1330 kill fluid. 527 bbls pumped, lost 257 bbls and go 270 bbls back to tiger -tank. 5/5/2019 13:30 5/5/2019 4.50 'W-IRU WHDBOP -NOND Set BPV. NU/ND tree, pull tree 18:00 adapter, set blanking plug, NU riser and spacer spools. 58019 18:0:0 0 5/5/2019 5.50 -91-RU WHDBOP NUND P NO BOPS. Grease valves. Fill stack 23:30 and choke with fresh water 585/2019 23:30 5/6/2019 0.50 MIRU WHDBOP BOPE P Test BOPS 250 psi low/ 3000 psi high. 00:00 AOGCC Brian Bixby waived witness. 5/6/2019 00:00 5/6/2019 9.50 WI-RU WHDBOP TOPE P Test BOPS 250 psi low/ 3000 psi high. 09:30 AOGCC Brian Bixby waived witness. 5/6/2019 09:30 586/2019 10.00 MIRU WHDBOP RGRP T Due to annular testing and make 19:30 several attempts no go t/ 250/2500 Psi; would not hold high pressure. Leaking by the rubber element. R/D test equipment and R/U tool to pull off annular top and C/O rubber element and seals on hydril 13 5/8" screw type Hydril. MU blanking plug to test joint and RU test hose. 5/6/2019 19:30 5/6/2019 4.00 MIRU WHDBOP TOPE P Test BOP Annular with 3-1/2" test joint 23:30 to 250 psi low/2500 psi high. LD test tool and pull BPV 5/6/2019 5/7/2019 0.50 COMPZN RPCOMP CIRC P Circulate 10.6 ppg until we get good 23:30 00:00 10.6 ppg returns to surface. 5/7/2019 00:00 5/7/2019 2.50 COMPZN RPCOMP CIRC P Finished circulating the well to kill 02:30 weight 10.6 ppg brine. Flow test well for 30 min. Good test. BOLDS on tubing hanger. 5/7/2019 02:30 5/7/2019 0.50 COMPZN RPCOMP PULL P Pull 20 K over string weight and tubing 03:00 hanger and completion pulled free. 5/7/2019 03:00 5/7/2019 3.00 COMPZN RPCOMP PULL P PUII 3-1/2J-55 completion with SSSV 06:00 control line to 1772'. SS clamps ran 30, pulled 23 Tot SSV bands recovered missing 7 ssv bands and UD sssv and Rin spooler . 5/7/2019 06:00 5/7/2019 10.00 COMPZN RPCOMP PULL P Continue UD 3 1/2" 8rd eue tubing 16:00 Tot 287 full joints and joint 288 cut 14.55',7 GLM Fmc Hanger and pup SSSV .Tot UD Page 1110 Report Printed: 5/23/2019 Operations Summary (with Timelog Depths) 1 R-20 Job: RECOMPLETION Rig: NABORS 7ES Time Log start Depth Start Time End Time our(hn Phase Op Code Activity Code Time P -T -X Operation (MB) Entl Depth(ftKB) 5/7/2019 5/7/2019 —4 00 COMPZN RPCOMP BHAH P Clean up floor ,and R/D tubing 1600 20:00 euipment and Load pipe shed w/6 4 3/4" D.0 , install wear ring bushing R/U to M/U BHA # 1 w/ Baker over shot 5/7/2019 5/8/2019 —4 00 COMPZN RPCOMP PULD P MU drill pipe singles from shed and 20:00 00:00 RIH with BHA#1 Baker overshot. Depth at midnight is 4954'. UP WT=108K, DN WT=74K. 5/8/2019 5/8/2019 4.50 COMPZN RPCOMP PULD P MU drill pipe singles from shed and RIH with BHA#1 Baker overshot and 00:00 04:30 jars. UP WT=185K, DN WT=90K at 8990''. -51-8/201 —9 -51-81201 —9 1.00 COMPZN RPCOMP FISH P Start Wash down to top of fish @ 3 0430 05:30 bbls 500 psi Tag top fish @ 8991' Work over fish, latch up on Fish PUW 200K and work up, down F/ 2251/160 set jars off wl 251kand 30k over pulled Pulled pkr free w/ PUW 198k Cont Pull and work tight spot 80' up hole it seems that we have the lower section. Loss rate when pumping 60 bbls per hr —and 5/8/2019 5/8/2019 2.50 COMPZN RPCOMP CIRC P CBU w/ 3 bbls min W/ 550 psi 05:30 08:00 spot Hi vis w/ 1 sack HEC in pill on bottom 26 bbls Lost rate 12 bbls hr after 2 hrs 5/8/2019 5/8/2019 —6 00 COMPZN RPCOMP TRIP P Shut down Monitor 30 mins All good 08:00 14:00 POOH -5/-8/201 —9 5/8/2019 —2 00 COMPZN RPCOMP BHAH P Continue stand back BHA and I/D 3 1400 16:00 1/2" tubing J GLM , Seal Assy w/ patch in joint 291, recover 3, SS bands 5 left in hole Tot 25 out of hole Tot joints L/D 296' 5/8/2019 5/812019 1.50 COMPZN RPCOMP BHAH P Clean up Rig floor and RID 3 112" 16:00 17:30 tubing tong R/U to M/U BHA # 2. 5/8/2019 5/8/2019 —5 50 COMPZN RPCOMP TRIP P MU and RIH with BHA#2 Baker spear and jars to top of packer at 9256'. UP 1730 23:00 WT=180K, DN WT=90K at 9023'. 5/8/2019 5/8/2019 0.75 COMPZN RPCOMP JAR P Jarring on fish pumping 2 bpm at 290 23:00 23:45 psi. Work jars from 225K to 285K. Brine WT is 10.4 ppg. 5/8/2019 5/9/2019 0.25 COMPZN RPCOMP IfIRC P Letting packer relax and circulating a 23:45 00:00 bottoms up to clear wellbore of packer gas. 5/9/2019 5/9/2019 4.00 15OMPZN RPCOMP CIRC P Letting packer relax and circulating a bottoms up to clear wellbore of packer 00:00 04:00 gas. 5/9/2019 5/9/2019 4.00 COMPZN RPCOMP CIRC P Shut well in and we have 30 psi on well. Waiting up from 10.4 ppg to 10.5 04:00 08:00 ppg. Truck load of 10.6 ppg will be here at 6 am. Continue to Monitor well and Pull 5 stand in derrick and first 2 stands the PKR was swabbing, Clean up on #3 stand, Monitor loss rate 10 to20 bbls hr , for 1 hr All good Keeping Fluid @ 10.4 Brine 5/9/2019 5/9/2019 7.50 COMPZN RPCOMP TRIP P Continue POOH w/ loss rate @ 15 bbls hr and Stand Back 4 3/4" D.0 08:00 15:30 and L/D 17.80' fish parted of the PKR Pic in S -Drive Loss Rate 8 bbls hr Page 2/10 Report Printed: 5/23/2019 Operations Summary (with Timelog Depths) 1 R-20 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Cade Tim P -T -x Operation (RKB) End Depth(ftKB) 519/2019 519/2019 1.50 COMPZN RPCOMP SVRG P Discuss with town which BHA to Run. 15:30 17:00 Service Rig. 5/9/2019 5/9/2019 2.00 COMPZN RPCOMP WAIT T Waiting on Baker Fishing tools to RIH 17:00 19:00 and mill and fish. 5/9/2019 5/9/2019 1.50 COMPZN RPCOMP BHAH P PU and MU BHA #3 19:00 20:30 5/9/2019 5/9/2019 2.75 COMPZN RPCOMP TRIP P TIH from Nom 225' to 5331'. 20:30 23:15 5/9/2019 5/10/2019 0.75 COMPZN RPCOMP RGRP T Broke a chain on the draw works. 23:15 00:00 5/10/2019 5/10/2019 3.50 COMPZN RPCOMP RGRP T Fixing chain on draw works. 00:00 03:30 5/10/2019 5/10/2019 2.00 COMPZN RPCOMP TRIP P TIH from 5331'to parted packer at 03:30 05:30 9254'.and Tag up @ 9267' DPM M/U Top Drive 5/10/2019 5110/2019 4.00 COMPZN RPCOMP MILL P PUW 190 SOW 95K Rot Wt 130K Wt 05:30 09:30 on shoe @ 4-81K pumping @ 2 bbls w/ 215 psi Milling on PKR F/ 9267' T/ 9267' No footage made, Spot 35 BBls pill on bottom 5/10/2019 5/10/2019 4.50 COMPZN RPCOMP TRIP P Monitor well 15 mins All Good POOH 09:30 14:00 and stand back BHA# 3 5110/2019 5/10/2019 1.50 COMPZN RPCOMP BHAH P UD Milling shoe 70%worn M/U BHA 14:00 15:30 # 4 w/ Baker spear RIH w/ 3 1/2" Work -string 5/10/2019 5/10/2019 4.00 COMPZN RPCOMP TRIP P RIH w/ 3 112" DP stands out of derrick 15:30 19:30 to 7316'. UP WT=153K, DN WT=83K. 5/10/2019 5/10/2019 1.50 COMPZN RPCOMP SLPC P Slip and cul 101' of drill line. 19:30 21:00 5/10/2019 2.00 COMPZN RPCOMP TRIP P RIH to 9267'. UP WT=195K, DN 23:00 WT=90K. Set down on fish 20K. PU 25K over string WT then string weight fell off. E23:OO 5/11/2019 1.00 COMPZN RPCOMP TRIP P Monitor well for Wow 10 min. No Flow. 00:00 TOOH from 9267'to 9208'. 5/11/2019 5.00 COMPZN RPCOMP TRIP P TOOH from 9208'to surface. 05:00 5/11/2019 2.50 COMPZN RPCOMP BHAH P Stand Back BHA# 4 and UD 16" of 05:00 07:30 patch pie in S -Drive M/U BHA# 5 w/ Junk Mills 2 3/4" and 6.125" w/ 6.125 string mill 5/11/2019 5/11/2019 4.00 COMPZN RPCOMP TRIP P RIH w/ 31/2" HT -38 Work -string tag 07:30 11:30 1 1up @ 9267' 5/11/2019 5/11/2019 4.50 COMPZN RPCOMP MILL P Start Milling on Junk @ 9267' Mill T/ 11:30 16:00 9269.5 @ 1 .250 bola min w/ 475 psi Loss Rate 35 bbls hr 5/1112019 5/11/2019 2.00 COMPZN RPCOMP CIRC P Spot hi vis HEC pills on Bofom 40 16:00 18:00 1 bbls and 35 bbls Pill 5/11/2019 5111/2019 5.00 COMPZN RPCOMP TRIP P POOH w/ 3 1/2" HT work string 18:00 23:00 5/11/2019 5/12/2019 1.00 COMPZN RPCOMP BHAH P LD BHA *5. We on mill indicates we 23:00 00:00 were down inside the 3-1/2"x7" packer milling on the patch. Mill was complelly worn out. BHA 06 is the same BHA with a new PRT mill. 5112/2019 5/12/2019 0.50 COMPZN RPCOMP SHAH P MU BHA #6 with new PRT mill. RIH to 00:00 00:30 j I mill on parted tubing patch inside parted 3-1/2"x7" HB packer. 5/1212019 5/12/2019 3.00 COMPZN RPCOMP TRIP P TIH with BHA #6. RIH t/ 9268.5' 00:30 03:30 1 Page 3110 Report Printed: 512312019, Operations Summary (with Timelog Depths) 1 R-20 Rig: NABORS 7ES Job: RECOMPLETION Time Log sten Depth Start Time End Time Dur (hr) phase Op Code Activdy Code Time P -T -X Operation (HKB) End Depth (8KB) 5/12/2019 5/12/2019 2.00 COMPZN RPCOMP MILL P Milling F/ 9268.5 t/ 9271' WOB 1-3 03:30 05:30 ROT 130K PUW 170k SOW 102K Tq 8-5 80 RPM pumping @ 1.5 BBIs w/ 185 psi 5/12/2019 5/12/2019 6.00 COMPZN RPCOMP TRIP P Flow Check 15 mins Allgood POOH 5 05:30 11:30 stand Flow Check 5 mins All good POOH loss rate 7 bbls per hr 5/12/2019 5/12/2019 2.00 COMPZN RPCOMP BHAH P Stand Back BHA #6 and LID Junk mill 11:30 13:30 and M/U BHA# 7 w/ Baker Spear 5/12/2019 5/12/2019 5.00 COMPZN RPCOMP TRIP P RIH w/ 3 1/2" HT 38 Work -string, BHA 13:30 18:30 # 7 wl Baker Spear. Parameters 1.5 bpm @ 675 psi, UP WT=175K, DN WT -100K. RIH to top of fish. Jar twice to 225K and pulled free. Flow check well for 10 minutes. 5/12/2019 5/12/2019 4.00 COMPZN RPCOMP TRIP P POOH F/9271'. 18:30 22:30 5/12/2019 5/12/2019 1.00 COMPZN RPCOMP BHAH P LD BHA #7 with no fish on spear. 22:30 23:30 5/12/2019 5/13/2019 0.50 COMPZN RPCOMP WAIT P Call town and discuss plan forward. 23:30 00:00 5/13/2019 5/13/2019 2.00 COMPZN RPCOMP BHAH P MU BHA#8, packer mill for 3-1/2"x7" 00:00 02:00 HB packer. 5/13/2019 5/13/2019 4.00 COMPZN RPCOMP TRIP P TIH with BHA#8 on 3 1/2" HT 38 drill 02:00 06:00 pipe. 5/13/2019 5/13/2019 2.50 COMPZN RPCOMP MILL P Tag up @ 9270' Start milling F/ 9270' 06:00 08:30 T/ 9271.5 Tot PUW 170K SOW 102K ROT130K WT ON MILL 4-7K 5/13/2019 5113/2019 4.50 COMPZN RPCOMP OWFF P Monitor well, static no loss POOH W/ 08:30 13:00 3 1 /2"H.T DP if 333' 5/13/2019 5/1312019 2.00 COMPZN RPCOMP SLPC P Cut and Slip Drilling line and service 13:00 15:00 rig. 5/13/2019 5/1312019 1.00 COMPZN RPCOMP TRIP P LD BHA# 8 and recovered 2 packer 15:00 16:00 slip dies in junk basket. 5/13/2019 5/13/2019 0.50 COMPZN RPCOMP BHAH P PU BHA #9 with a 6.125" junk mill. 16:00 16:30 5/1312019 5/13/2019 4.00 COMPZN RPCOMP TRIP P TIH with 8HA#9 on 3 1/2" HT 38 drill 16:30 20:30 pipe. 5/13/2019 5/14/2019 3.50 COMPZN RPCOMP MILL P Tag up @ 9268.5' Start milling, 20:30 00:00 PUW=172K, SOW=100K, ROT=132K, 3BPM@465psi, 70 RPM. Free TQ=9.5K, TQ-ON=10.5 to 12K FIBS, WOB=1-22K. While milling we lost -50 bph. 5/14/2019 5/14/2019 2.50 COMPZN RPCOMP MILL P Added more weight on mill up to 22K. 00:00 02:30 Stopped circulating and milled for 30 minutes trying to get packer to heat up and stop rotating. Didn't work. Then we spuded the mill onto the packer several times, but it continued to spin while trying to mill. While milling we lost -50 bph. 5/14/2019 5/1412019 0.50 COMPZN RPCOMP TRIP P Call town engineer and decided with 02:30 03:00 the Baker fishing hand to POOH. Next run will be a PRT mill with a -5' stinger and bullnose to mill another 2' of patch out of the inside of the packer to give us a clean place to spear the patch or run a chem cutter to cut just below the packer. POOH standing back the OF. Page 4/10 Report Printed: 5/23/2019 Operations Summary (with Timelog Depths) 1 R-20 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Operation (nKE) End Depth(ftKB) 5/14/2019 5/14/2019 1.00 COMPZN RPCOMP TRIP P Spot 30 bbl pill, 10.4ppg hi -vis at 2 03:00 04:00 bpm and 500 psi. Remove blower hose, blow dow top drive. Monitor Well Flow Check 15 min All good POOH and Stand Back 3 1/2" HT 38 Work -String 5/14/2019 5/14/2019 6.00 COMPZN RPCOMP TRIP P POOH from 8828' to 311'. Up wt 04:00 10:00 170k. Monitor well for 10 mins. Well static. 5/14/2019 5/14/2019 0.50 COMPZN RPCOMP SHAH P Lay down BHA#9, clean boot baskets. 10:00 10:30 Observed approximately 1/2 of 5 gallon bucket full of metal cuttings. 5/14/2019 5/14/2019 1.00 COMPZN RPCOMP BHAH P Pick up and make up BHA# 10 as 10:30 11:30 follows: Bull nose junk mill, XO, Extension, Packer mill, Triple connect drive sub, 2- boot baskets, bit sub, 6 1/8" sting mill, 4 3/4" bumper sub, 4 3/4" oil jars, 6- 4 3/4" drill collars, pump out sub and XO. 5/14/2019 5/14/2019 0.50 COMPZN RPCOMP TRIP P RIH from 231'to 1650'. 11:30 12:00 5/14/2019 5/14/2019 0.50 COMPZN RPCOMP SVRG P Perform rig service. Adjust RPM 12:00 12:30 sensor. Grease black jack and blocks. 5/14/2019 5/14/2019 3.50 COMPZN RPCOMP TRIP P Trip in hole from 1650'to 9220'. 12:30 16:00 5/14/2019 5/14/2019 2.00 COMPZN RPCOMP MILL P Begin milling operations at 9268' with 16:00 18:00 following parameters: 2 bpm, 285 psi, 70 rpm, free TO 9.5k fibs, Milling TO 10.5k- 12k ftlbs, and WOB 1-5k. Up wt 172k down wt 95k and Rot 132k. Able to mill the internal of the packer from 9268'to 9274'. Upper packer mill milling on HB packer at 9274', appears to be spinning, little to no progress with packer mill. Loss rate while milling 48bph. 5/14/2019 5/15/2019 6.00 COMPZN RPCOMP TRIP P Flow check, spot 30bbl hi vis pill, 18:00 00:00 POOH 5 std, monitor well. POOH standing back DP. Well static. 5/15/2019 5/15/2019 2.00 COMPZN RPCOMP SHAH P LD BHA#10. No metal recovered in 00:00 02:00 boot basket. Mills look good. PU BHA #11 spear easy. 5/15/2019 5/15/2019 3.00 COMPZN RPCOMP TRIP P TIH w/ BHA#11 to 9268'. Establish 02:00 05:00 parameters UP wt 165K, DN 107K, 1.5bpm 1020psi. 5/15/2019 5/15/2019 4.00 COMPZN RPCOMP FISH P Latch onto fish at 9274.5' pressure 05:00 09:00 increase observed. shut down pump. Work pipe f/125k to 275k. Pick up to 220k wt fell off to 165k. Attemp to circ at 2bpm, no returns. Drop 1 7/8" ball, pressure up to 3200psi to open pump out sub. Establish circ 2bpm with returns 230 psi. SD pump. 5/15/2019 5/15/2019 5.50 COMPZN RPCOMP TRIP P Monitor well 15min, static. UP wt 09:00 14:30 167k DN wt 106K. POOH w/ BHA #11 and fish to BHA. 5/15/2019 5/15/2019 8.00 COMPZN RPCOMP BHAH P Rack back collars. LD spear, packer, 14:30 22:30 GLM, remove blast rings, LD joints and seal assembly. Observed corrosion and holes in fish. Clean and clear rig Floor. Page 5110 ReportPrinted: 512 312 01 9 NABORS7ES Operations Summary (with Timelog Depths) 1 R-20 Start Time 1. I End Time I Dur(hr) I Ph I op Cade I Activity Code ITime P -T -X 22:30 1 00:00 01:30 01:30 to 2084'. PU wt 62K, DN wt 60K. PU Baker storm packer RIH one stand and set packer, release and stand back. ND BOP, set back ion stump wellhead hand. Remove both IA valves. Remove every other stud and install hydratight rods and jacks on spool. Allow casing to grow 1-3/4", Job: RECOMPLETION 5/16/2019 04:00 5/16/2019 05:00 1.00 COMPZN WELLPR NUND P RD hydratight. Prepare cellar and nipple down tubing 5/16/2019 5/16/2019 3.00 COMPZN WELLPR NUND P Remove 05:00 08:00 Make up 7 casing spear and RIH. Spear 7" casing stub, pick up to 100k over, re -set slips. Set slips with 100k intension. Release spear and laydown the same. Casing stretched 5/16/2019 08:00 5/16/2019 4.00 COMPZN WELLPR NUND P an additional 20". Rig up FMC Wachs cutter and 12:00 make final cut on 7" casing stub, cutting approximately 16" off. Clean well head profile. Set new 7" primary pack off. Install new tubing spool and torque bolts. Test pack off to 250 psi low for 5 mins and 3000 psi high for 10 mins. Successful test. Install IA gate valve and torque bolts. Install 5/16/2019 12:00 5/16/2019 1400 2.00 COMPZN WELLPR NUND P est plug. Nipple up 7" x 11' 5k adapter, 11"x 13 5/8" 5k DSA. Nipple up BOP stack and torque all bolts. Install turn 019 019 0.50 COMPZN WELLPR PRTS P buckles and riser. 4:00 14:00 14 30 430 Fill BOP stack. Close blind rams to test well head/BOP connection, Pressure test to 250 psi low for 5 minutes and 3000 psi high for 5 minutes. Good test. Pull BOP test 5/16/2019 14:30 5/16/2019 15:00 0.50 COMPZN WELLPR OTHR P Install plug. wear bushing in tubing spool 5/16/2019 15:00 5/16/2019 1800 3.00 COMPZN WELLPR TRIP P profile. Engage storm packer, flow check, well static. POOH, LD storm packer. Rack 019 5/16/2019 1.50 COMPZN WELLPR BHAH back P PU DP, DC. clean out BHA #12 18:00 18:00 19:30 5/16/2019 5/16/2019 19.30 22.30 3.00 COMPZN WELLPR TRIP P Trip in hole with clean out assembly t/9301'took weight. Page 0110 ReportPrinted: 5/23/2019 Operations Summary (with Timelog Depths) 1 R-20 Rig' NABORS 7ES Time Log Job: RECOMPLETION Slant Time End Time Dur (m) Phase 5/16/2019 5/17/2019 2.00 COMPZN Op Code Activity Code Time P-T-XStart Depth Operation (ftKB) WELLPR CIRC End Depth(RKB) 22.30 0030 p Wash dawn 2bpm 240psi through, RIH to 9347' took weight wash and work scraper through peifs to 9395'. Wash down, tag and sting in with stinger, set down at 9403' saw pressure increase to confirm. UP wl 165K, DN wl 105K. RIH dry, stab into packer, set down at 9402' several times. Bring on pump at 4bpm, 650psi stab in saw pressure increase to 815psi. Check infectivity into lower perfs. Close annular bullhead 5bbl away at 550psi 3bpm. 5/17/2019 5/17/2019 0.50 COMPZN Total LC the duration. t WELLPR TRIP 00:00 00:30 P POOH two stalnds First stand +/-10K more drag than second. 5/17/2019 5/17/2019 1.50 COMPZN Flow check, observe balooning. WELLPR SLPC 00:30 02:00 p Slip and cut drill line (Well flowed back 27bbi in 1st 30min, 16bbl in 2nd 30min and 121bb) in 3rd 5/17/2019 5/17/2019 0.50 COMPZN 0200 0230 30min.) WELLPR SVRG P Service top tlrive grease blocks and 02:30 019 06:00 019 3.50 COMPZN 02:30 Ofi:00 crown. WELLPR TRIP P POOH LD DP from 9224'to 6732'. Well balloning at a rate of approximately 1.1-1.3 bbls every 5 06:00 019 13:00 019 7.00 COMPZN 06:00 13:00 WELLPR 0 F P Perform Now check, monitor well. Well ballooning at approximately 1.1 bbls every 2 mins. No pressure observed on drill pipe or casing. Line up and circulate bottoms up through choke as precautionary measure. No gas observed on bottoms up. Lost approximately 65 bbls while circulating bottoms up. Observe well, continuing to balloon 10.4 ppg brine back, flow back rate declined from approximately 1 A bbl/2 mins to 0.2 bbls/2 mins. Note: Simultaneously mixing 50 5/17/2019 5/17/2019 9.00 COMPZN bbls10.8 ppg heavy pill in pill tank. WELLPR TRIP 13:00 22:00 P POOH LD to 6353'. Pump 25bb1 slug 10.8ppg POOH LD to 4966'. Pump 25bbi slub 10.8ppg POOH LD, to 2577', 161bph Loss rate. TIH with remaining stands out of derrick to 3135', 15bph loss rate. POOH LD DP to BHA. Monitor well 10 min 12bph loss rate. (Cumulative mud losses for the day 5/17/2019 5/17/2019 1.00 COMPZN WELLPR Entire well BHAH P 22:00 23:00 Recovered sand rabbi) LDI6HAI. 5/17/2019t 5/17/2019 0.50 COMPZN WELLPR no CLEN P 23:00 23:30 Cleanand cleaalFloor. 5/17/2019 5/18/2019 0.50 COMPZN RPCOMP 23:30 00:00 WWWH P Pull wear ring. Clear pipe shed and bring in completion jewelry. Page 7/10 Report Printed: 5/23/2019 . Operations Summary (with Timelog Depths) +� 1 R-20 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time 5/18/2019 End Tme 5/18/2019 Dur(hr) 1.00 Phase COMPZN Do Cede RPCOMP Activity Code b Time P -T- % Operation Start Depth (flKB) End Depth (flKB) 00:00 01:00 WWWH P Jet stack with 10 bpm at 1250 psi. Blow down surface equipment. 5/18/2019 5/18/2019 —1 .00 COMPZN RPCOMP RURD P Rig up tubing tongs. Change out 01:00 0200 handling equipment. 5/18/2019 5/18/2019 4.00 COMPZN RPCOMP PUTB P Pre job safety meeting. PU Sealbore 02:00 06:00 assembly, pup joint and blast joints (approx. 68.83' of coverage). RIH with the same. Clean and clear floor, RDMO PEST. Pick up completion string as per tally Pick up 2- GLM's, X nipple assembly and 3 1/2" x 7" FHL packer and RIH. While attempting to RIH tagged up at approximately 203'. Drain BOP stack to observe down well to ensure Packer was not hanging up in wellhead. Packer was not hanging up in wellhead. Pick up to surface to observe if any damage on Packer, none observed. 5/18/2019 5/18/2019 6.00 COMPZN RPCOMP PUTB T Lay down packer POOH and re 06:00 12.00 . orient GLM's to line up in the same direction, due to GLM's oblonged shape and facing opposing directions. Pick up on slick joint of 3 1/2" tubing to perform drift run through wellhead. Tagged up at same spot approximately 203', no wellhead obstruction. Link tilted out with Top drive and able to get past obstruction. Appeared to have dislodged something free allowing to get past obstruction. Decision made to POOH lay down 2-GLMs, nipple assembly and inspect blast ring joints to confirm still all there. All blast rings and equipment still intact. Pick up 2- GLM's and nipple asssembly and 2 joints of 3 1/2" tubing and RIH to see if obstruction still there. Able to RIH with no obstruction. Suspectiunk in hole. Decision made -5/—1 to lay out completion string. 8/201-9 5/18/2019 2.00 COMPZN RPCOMP PULD T Lay down completion jewelry and blast 12:00 14:00 -!T11 joints. 5/18/2019 8/201-9 4.50 COMPZN RPCOMP SLKL 7 PJSM with rig crew and slick line unit. 14:00 18:30 Rig up slick line unit. Make up 5.95" gauge ring and junk basket. RIH with slick line from surface to 9325'. POOH with slick line. Observed minimal debri in junk basket. RDMO slick line. 019 5/18/2019 2.50 COMPZN RPCOMP PUTB T Pre job safety meeting. PU Sealbore 18:30 18:30 21:00 assembly, pup joint and blast joints (approx. 68.83' of covereage). RIH with the same. Clean and clear floor, RDMO PEST. Pick up completion string as per tally. Pick up 2- GLM's, X nipple assembly and 3 1/2" x 7" FHL packer and RIH. 5/18/2019 5/19/2019 3.00 COMPZN RPCOMP PUTB P Continue running 3 1/2" completion as 21:00 00:00 per tally to—2100ft. Daily losses 77.5bbi, cumulative well losses 2,668.7bbl Page 8/10 Report Printed: 5/23/2019 NABORS7ES Operations Summary (with Timelog Depths) 1 R-20 Fn .3 Sten Time 5/19/2019 End Time 5/19/2019 Our(hr) 11.00 Phase -CO—RPCOMP Op Code Activity Code PUTB Time P -T -X Operation Start Depth (ftKB) Entl Depth (ftKB) 00:00 11:00 P RIH with 3 1/2" 9.3# L-80 EUEM from 2100'to 9281'. Torque each connection to 2240 ftlbs. Observed approximately 7 bbls/hr loss rate. Up weight 100k and down weight 72k. 5/19/2019 5/19/2019 1.00 COMPZN RPCOMP PUTB P Rig up to circulate down tubing. Pump 11:00 1200 3 bpm at 280 psi. Observe pressure increase as seal bore assembly entered PBR at 9402.29'. Good indication seals entered PBR. Slack off approximately 10-15k for seal bore assembly to enter PBR, stacked off to 9405.74'. Approximately 3.45' of seals engaged in PBR. Unable to locate po- go due to seal drag in PBR. Decision made to set packer. Top of blast rings at approx. 9339.6' ORKB 5/19/2019 12:00 5/19/2019 2.00 COMPZN RPCOMP PACK P Drop 1 5/16" ball and rod. Allow to 14:00 fall. Pressure up to approximately 1900 psi and observe packer sleeve shift, packer set. Pressure up to 2600 psi, hold for 5 mins. Pressure up to 3100 psi. While pressuring up to 3100 Psi observe all pressure bleed off at 3100 psi. Picked up to confirm packer set, pick up 10k over. Packer confirmed set at 9233' (original KB). Pick up to approximately 140k (40 k over normal pick up weight) to shear out of PBR. Top of PBR at approximately at 9207.45'. Space out approximately 1' off seal bore locator. Approximately 26.79' of space out pups needed. Layout 1 one joint of 3 1/2" tubing. 5/19/2019 14:00 5/19/2019 1.00 COMPZN RPCOMP CIRC P While laying out tubing well began to u 15:00 -tube up 3 1/2" tubing. Make up top drive and circulate 10.4 ppg brine to balance well. 5/19/2019 15:00 5/19/2019 1.00 COMPZN RPCOMP PUTB P Continue to lay out 2 joints of 3 1/2- 16:00 tubing. Pick up 3 112" space pups (26.79') and one joint of 3 1/2" tubing. Pick up tubing hanger/pup and landing J oint. 5/19/2019 16:00 5/19/2019 1.00 COMPZN RPCOMP CIRC P Spat 115 bbls 10.4 ppg with 1 % CRW- 17:00 132 corrosion inhibitor in IA. 5/19/2019 17:00 5/19/2019 1.50 COMPZN RPCOMP TR—TS P Land hanger, RILDS. Attempt to 18:30 pressure test tubing, would not pressure up. Pressure test IA to 1000psi 30 min. IA tested good. Call town and discuss plan forward. LD landing joint, circ across top of well, call for slickline unit. Page 9/10 Report Printed: 5/23/2019 .. Operations Summary (with Timelog Depths) ,.. 1 R-20 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time 5/79/2019 End Time 5/20/2019 Dur (hr) 5.50 Phase COMPZN Op Code RPCOMP Activity Code SLKL Tlme P-T-X Operation Stan Depth (WB) End Depth(ftKB) 18.30 00:00 T Monitor well, 7bph loss rate. MIRU Pollard slickline (the objective to pull B+R, RHC plug and set a new plug in order to pressure test tubing and BPV). Prejob safety meeting. RU on well while circ across top to monitor losses. RIH, sat down in GLM #1 and #4. Found ball and rod on depth, retrieve ball and rod, some wear on sides, some nicks on lop no large gouges. Losing 7 bph. PU GS, RIH to retrieve RHC plug body, attempt to latch, POOH to check. Losses for day 117bb1 Cumulative losses for well 2,620bb) 5/20/2019 5/20/2019 3.50 COMPZN RPCOMP SLKL T Pull RHC, found Fluid scouring, one 00:00 0330 missing packoff. RIH with XX plug, set in X nipple at 9260' wlm. fluid losses ceased. POOH S/L. LD running tools. 5/20/2079 5/20/2019 1.50 COMPZN RPCOMP PRTS P PU tootling joint, RU to pump down 03:30 05:00 tubing. Pressure test tubing to 2500psi for 15 minutes, good test. Bleed tubing to 1500psi, Pressure test IA to 2500psi for 30 mins. Test good. Bleed down tubing to 0 psi, shear open SOV Rig down circulating iron, lay out landing joint and blow down equipment. 5/20/2019 5/20/2019 7.00 COMPZN WH_ DBOP _MP SP P Set BPV and tell from below. 05:00 06:00 Pressure up against BPV to 1200 psi for 10 mins. Test good. 5/20/2019 5/20/2019 1.00 COMPZN WHDBOP RURD P Rig down Alaska E-line slickline 06:00 07:00 equipment. 5/20/2019 5/20/2019 4.00 COMPZN WHDBOP NUND P Nipple down BOP Blow down 07:00 11:00 circulating equipment. Remove riser, turn buckles, Koomey lines, and set BOP back on stump. Remove BOP adapter flanges. Install tree adapter and tree test plug. Open SSV. Test tubing adapter to 250 psi low for 5 mins and 5000 psi high for 10 mins. Test good and witnessed by COP rep. Nipple up production tree and torque bolts. Test tree to 250 psi for 5 mins and 5000 psi high for 5 mins. Test good. 5120/2019 5/20/2019 0.50 COMPZN WHDBOP MPSP P Pull tree lest plug and BPV. 11:00 11:30 5/20/2019 5/20/2019 3.50 COMPZN MOVE FRZP P PJSM with rig crew -and LRS. 11:30 15:00 Pressure test LRS pumping lines to 2500 psi, test good. Pump 84 bbls of diesel down IA at 3 bpm at 600 psi. Taking returns to flowback tank. Line up IA and tubing to equalize and allow well to U-tube. 0 psi on Tubing and IA. Rig down LRS. 5/20/2019 5/20/2019 1.00 COMPZN MOVE NUND P Install Cameron H typle BPV w/ tbar. 15:00 16:00 NU tree valves. Rig released at 16:00 Page 10/10 Report Printed: 5/23/2019 p r.D Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, April 30, 2019 9:36 AM To: Hampton, Kyle Subject: RE: 1 R-20 Rig Change Kyle, Approval is granted as written. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoo(Malaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding if, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or ViclorIo.Loeop@alaska.aov From: Hampton, Kyle <Kyle.Hampton @conocophill ips.com> Sent: Monday, April 29, 2019 11:48 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: 111-20 Rig Change Victoria, We would like to change which rig performs the workover on 111-20, from Nordic 1 to Nabors 7ES. 7ES is much better suited for the work on 111-20 and it is already on the pad. I have attached the BOP schematic. Do you approve of the change? Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Kyle Hampton Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1 R-20 Permit to Drill Number: 191-108 Sundry Number: 319-118 Dear Mr. Hampton: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.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, Daniel T. eamount, Jr. Commissioner DATED this day of March, 2019. iBDM� MAR 191019 STATE OF ALASKA MAN 1 1 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A 0 G Q Q 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well EJ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing El Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Stretigraphic ❑ Service ❑ 3. Address: 6. API Number: P.O. Box Box 100360, Anchorage, AK 99510 .6ggg0�00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1R-20 18/Ig19 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): rr , s. 10. Field/Pool(s): ADL0025628 %4O Z 3 3/r2/f9 KUPARUK RIVER'/ KUPARUK OIL 11 "�' "" •rc PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10080 7074 10063 7064 2,562 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 79 16" 122 122 Surface 5508 9-5/8" 5551 4162 Intermediate Production 10026 7" 10063 7064 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft):t Tubing Grade: Tubing MD (ft): 9350' - 9387', 9591'- 9648' 6605'- 6629', 6759'- 6796'3-1/2" J-55 9430 Packers and SSSV Type: Packer (HB Retrievable) Packers and SSSV MD (ft) and TVD (ft): Packer (9254' MD / 6544' TVD) Packer (D Permanent) Packer (9389' MD / 6630' TVD) SSSV (TRDP-1A) SSV (1772' MD / 1652' TVD) 12. Attachments: Proposal Summary ❑� Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Strati re hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/21/2018 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: Kyle Hampton Contact Name: Kyle Hampton Authorized Title: Sr. Wells Engineer Contact Email: k le.ham ton CO .Com Contact Phone: 263-4627 3 9 Authorized Signature: Date: �� �-Oj COMMfSSlhN USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n i C4 _ I .`"l1 Plug Integrity F-1BOPTest n Mechanical Integrity Test ❑ Location Clearance ❑ Other: dap frsi- fio 22005-4,1 250 r J !7` JAS' ijnnv/ate tprlvsvr t r St fo Post Initial Injection MIT Req'd? Yes ❑ No 1 9 2019 ppMS�MAR Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10-104 RV APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ( !/ Y71- :3/75//y �� � • Submit in Form and Form 70-403 Revised 4/2077 Approved appli tr v I 1 '_/�pl_+ om the date of approval. Attachments in Duplicate G� solm 1-4f n � P. Is. 3/,z/It ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 11 March, 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1R-20 (PTD# 191-108). ' Well 1 R-20 was drilled and completed in September 1991 as a Kuparuk producer well. In October 2000, there was an issue closing the SSSV; scale was cleared and well was brought back online. In September 2002, it was determined a patch was needed to cover a leaking production mandrel. Patch was set and additional diagnostics were run, replacing GLVs and rerunning patches. Well was eventually put back online October 2004 after passing pressure tests. In 2006, TxIA communication issues were encountered, and the patch was attempted to be pulled. While fishing the patch, the upper assembly was lodged in the upper production packer. While pulling the slip stop, a single slip die fell out and became lodged between the outer fishing neck of the patch and the inside of the packer. Well was shut-in afterward. In January 2018, a leak detect log was run and identified tubing leaks at 8,983', 8,876', 8,584', and 8,565'. In February 2019, the wel pal ssed MITOA to 1800 psi and passed POT -T and PPPOT-T; the wel faileT d POT -IC and PPPOT-IC. The objective of this rig workover is to pull upper 3-1/2" tubing from seals at 9241' RKB. Run in hole on drillpipe and pull lower tubing out of seals at 9388' RKB. Mill packer at 9389' RKB and push to bottom. Run new selective completion (nipple profile, packer, sleeve, blast joints, production mandrel, nipple, packer, GLMs as needed). If you have any questions or require any further information, please contact me at 263-4627. Sinclerely, l Kyle H pion Senior Wells Engineer CPAI Drilling and Wells IR -20 RWO Procedure Kuparuk Producer PTD #191-108 Current Status: The well is currently shut in. In February 2019, the well passed MITOA to 1800 psi and passed POT -T and PPPOT-T; the well failed POT -IC and PPPOT-IC. Scope of Work: Pull upper 3-1/2" tubing from seals at 9241' RKB. Run in hole on drillpipe and pull lower tubing out of seals at 9388' RKB. Mill packer at 9389' RKB and push to bottom. Run new selective completion (nipple profile, packer, sleeve, blast joints, production mandrel, nipple, packer, GLMs as needed). General Well info: MPSP: 2,562 psi (using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Kuparuk — 3,219 psi / 6,572' TVD (9.4 ppg EMW) 9.6 ppg KWF Wellhead type/pressure rating: FMC Gen IV, 3 1/8" 5M BOP Config: Annular / Variable Pipe Ram / Blind Ram / Variable Pipe Ram MIT results: MIT -OA— Passed to 1,800 psig / 0 psig on 2/10/2019 Well Type: Producer Estimated Start Date: April 16, 2018 Production Engineers: Brian Lewis (263-4535 ( Brian.M.Lewis@conocophillips.com) Workover Engineer: Kyle Hampton (263-4627 1 Kyle.Hampton@conocophiIlips.com) Remaining Pre -Rig Work 1. Pull lower GLV. 2. Swap to dry hole tree configuration for RU. 3. Install BPV. Rig Work MIRU 1. MIRU on well location. 2. Pull BPV and pump KWF from surface to surface. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure, and weightup fluid as necessary. Complete 30 -minute NFT. Verify well is dead. �/ 3. Set BPV, ND Tree, NU BOPE and test to 250 / 2,800 psi. Test annular 250 / 2,500 psi. a. Notify AOGCC of BOP test 24 hours prior to nipple up and every 7 days thereafter or when the stack is broken. Retrieve Tubing 4. Pull BPV and MU landing joint. S. Pull 3-1/2" tubing from seals at 9241' RKB and lay down the tubing. 6. Pick up drillpipe and overshot. Trip in and latch onto PBR. Pull to disengage packer at 9,254' RKB and pull out of seals at 9,388' RKB. a. If unable to pull out of the seals, pick up collar splitter and split collar between packer at 9,298' and bottom of stuck patch at 9,278'. 7. Pickup packer mill and mill D permanent packer at 9,389' RKB and push into rat hole at 10,000' RKB. Page 1 of 2 IR -20 RWO Procedure Kuparuk Producer PTD #191-108 Install in 3-%" Tubing 8. MU 3'/:" lower completion with wireline entry guide, nipple profile, packer, and PBR. RIH and set packer at 9,440' RKB. Set packer with ball and rod. 9.rete test inner annulus to 2,500 psi for 30 minutes on chart. 10. MU 3 %" selective upper completion with upper seals, sliding sleeve, blast joints, production mandrel, nipple profile, packer, PBR, and remaining tubing. 11. RIH and set packer at 9,190' RKB. Set packer with ball and rod. 12. Pressure test tubing to 1,500 psi for 15 minutes. ✓ 13. Pressure test inner annulus to 2,500 psi for 30 minutes on chart. ✓ ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. 16. ND BOPE. NU dry hole tree. 17. Freeze protect well. 18. RDMO. Page 2 of 2 Well 1R-20 API 5002922207 PTD 191-108 Rig (RKB) Nordic 1 Max DLS 7.3°1100% @ 1,900' RKB Max Pad H25 600 ppm Well Category Category 3 ConocoPhillips Network # (Drilling) Network # (Wells) AFE Cost AFETime Max Angle 54.1° @ 2,000' RKB Max Well H2S 150 ppm 1125 Radius of Exposure 12 ppm Wellhead FMC Gen IV ProductionTree Tubing Hanger Tubing Head Tbg Head Adapter WELL OBJECTIVE Pull upper 34/2" tubing from seals at 9241' RKB. RIH on drlllpipe and pull lower tubing out of seals at 9388' RKB. Mill packer at 9389' RKB and push to bottom. Run new selective completion (nipple profile, packer, sleeve, blast joints, production mandrel, nipple, packer, GLMs as needed(. ed and completed in September 1991 as a Kuparuk producer well. In October 2000, there was an issue closing the SSSV; scale was cleared well was brought back online. In September 2002, It was determined a patch was needed to cover a leaking production mandrel. Patch set and additional diagnostics were run, replacing GLVs and rerunning patches. Well was eventually put back online October 2004 after ling pressure tests. In 2006, TxIA communication issues were encountered, and the patch was attempted to be pulled. While fishing the :h, the upper assembly was lodged in the upper production packer. While pulling the slip stop, a single slip die fell out and became lodged veen the outer fishing neck of the patch and the inside of the packer. Well was shut-in afterward. In January 2018, a leak detect log was and identified tubing leaks at 8,983', 8,876, 8,584', and 8,565'. In February 2019, the well passed MITOA to 1800 psi and passed POT -T and HSE CONSIDERATIONS Open perfs m A and C sands. The blast joints are not fully covering the C sand, so the tubing is most likely eroded and compromisetl. CASING INFO MD (ft RKB) TVD (R RKB) OD ID (in) (in) Weight ON Grade Thread (top) Thread (btm) Conductor 122' 122' 16" 62.5 H40 Welded Surface 5,551' 4,162' 9-5/8" 45.5 L-80 BTCM BTCM Production 10,063' 7,064' 7" 26 J-55 BTCM BTCM Liner Tubing (Previous) 9,430' 6,6561 3-1/2" 9.3 L-80 EUEM EUEM Tubing (Proposed) 9,460' 6,675' 3-1/2" 9.3 L-80 EUEM EUEM Top Perf PERFORATIONS (RKB) Bottom Perf (RKB) KuparukC 9,350' 9,387' Ku arukA 9,648'1 9,591' 9.4 PH I IKWF Gas Column 657 psi I@ 'psi/ft) FLUIDS PRESSURE CALCULATIONS SBHP 1 3,219 PTtF 6,572'TVD 6/9/2017 EMW 9.4 PH I IKWF Gas Column 657 psi I@ 'psi/ft) 9.6 ppg MPSP 2,562 psi FLUIDS lWeight Comments/ Additives Workover Fluid 9.6 ppg NaCl brine MPrima Batk-u Workover Fluid I IKWF in hole, no back up fluid Corrosion Inhibitor 9.6 ppg Inhibited brine w/1%CRW-132 Freeze Protection Diesel MD OD ID Thread PROPOSED TALLY Length (it) (ft RKB) (in) (in) Thread (top) (btm) Comments 3-1/2" Tubing Hanger V FMC 3-1/2" x 1" GLM (4) 3-1/2" %Nipple (2.813") 3-1/2" x 7" Packer Premier 3-1/2"%Nipple 2.813") 3-1/2" x 1" Prod Mandrel 3-1/2" Blast Joints 3-1/2" CMU 3-1/2" x T' Packer 3-1/2"% Nipple (2.813") 3-1/2" WLEG m' KUP PROD 1R-20 ConocCiPfUlflps Well Attributes ---- -_-- Max Angled TO Neta xame wmeoas A.. wRlbo.a.ma .", laminas, naelm lrtnB) KUPAR-i RIVER UNIT 50029222D700 PROD 4.13 2,000.00 101080.0 Alaska, 111 c. SSSV�TRDP ms(ppm/ Date Ed IAD: 1181992 42 9m 1191111 1. .1991. Dara 1 P A. 4,143.41 B 11 B 1 B FM Last Tag Veai[al xFemai¢lanuea MmYtlon Ena Dale pepN mKB) Ictal Moa as Last Tag: 715/200] 9,7460 U`11M Conversion Last Rev Reason Xudi W 6 AnnotationEna pate Iael M W ay Rev Reason: Set hold open sleeve 8115-2018 telgV4D Cal Strings et DepIM1 ITVp1... VNIRn B... Geaae Taplhreaa Cauls, pesONpaon OD DnI 10 al Top MKB) Sm d.*PM..I 102 CONDUCTOR 16 15.06 43.0 122.0 122.0 62,50 H-00 WELDED C0.(M.4sal. Caalnp mounpaOn OD gni ID DnI 1 0pl1 .pepmmKBl I Bel Deem lNp)...-cm II... Grade Tap 1M1IW SURFACE 95/8 8.92 42.2 5,5505 4,161.6 3600 J-55 BTC COIng De'nomnDO 410)ID (in)Top as., fiat DapmmK81 Sn Dmmlrvpl.. wtten D --tract. Top TMW PRODUCTION > 628 37.3 10,06: 7,Ofi36 2600 J-55 BTC -MOD Few Ski 1,TTZD Tubing Strings SAFEnvEV. 7722 T"n"Deaanptmn samo ma... TUBING WO 31/2 ID Im) 299 1,Pop' 38.6 sal Depm ln_sel 9429 ] Depm lrvpl l... 6.655.9 wl Dun/ 9.30 mase J-55 Top connecaon EUEBIOABMOD ,'.all @939]' ."O'C:zad6n Compiegon Details TOP") TaPInOI NOTlnal ws U1.4..0 Topmna) mNel PI hem Dm cam mde) US 38.6 0,22 HANGER FMC GEN V TUBING HANGER 3500 1]72.2 1,651] 42.19 SAFETY VLV CAMCO TRDP-IA SAFETY VALVE 2.812 52000 6,509.5 5055 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 WMACE4226taid- 9,240.6 13.535.3 50.52 PBR BAKER PER vi/ 4.T BORE 3,000 9,254.4 6,544.1 50.51 PACKER BAKER HB RETRIEVABLE PACKER 2.890 GAS LET: 6.M.a 9,313.2 (LUIS 50.45 BLASTRINGS CARBIDE BLAST RINGS (2) 2.992 soul sews 9,379.2 6,623.6 50.30 NIPPLE AVA BPL PORTED NIPPLE 2.687 9,389.0 6,629.9 5028 PACKER BAKER D PERMANENT PACKER 3.250 GAS LET. 7, .5 9,392.7 6,6322 5027 SBE BAKER SEAL BORE EXTENSION 3.250 9,39].0 6,6350 5026 I KO Reducing CROSSOVER 3.5 x 2.875 2875 GAs uEr; 79P7 9,612.8 6.8950 50.24 1 NIPPLE JOTISXN NIPPLE 2.25" ID NO GO al 2.313' PACKING BORE 2.250 9.4290 6,6556 5022 506 BAKER SHEAR OUT SUB 2441 GASUITTEdi y Other In HoleIreiine retrievable Plugs, IyV p gs, valves, pumps, fish, etc.) TOP OVID) Tap Incl R�,Ol9.o Top mKBl MKS) (-I Oea Com Run Dab IDtinl 1]]20 1,651.5 42.18 Frac Sleeve SO hold open sifieve. 130"DAL w/231"ID 81162018 2310 \Citi 70080 6,388.1 5111 PATCH HALLISURTON 3.P PERMANENT PATCH DAL 31' 7IW2007 2360 �Q�00 Lj 9,254.0 6.543.8 W51 K3 PACK -OFF K-3PACK0FFw/SNAPIATCH #9280 set 611812004 61IW2004 1.400 GAS UFT; 8.153.6 STUCKINPBR (24.4'OAL) 9.751.0 6,543.8 5051 FISH FISH SLIP FflOM 3"TUBING STOP LOST 43118006 111/2006 0000 9,3040 6,575.6 WAS LOWER LOWER ECLIPSE PACKER (1 JS'ID@ 9304' set 60820M 1,750 NIPPLE; SiECLIPSE M22003; C -SAND STRADDLE PATCH. PACKER eI 9,379.2 7623.6 50.30 SLEEVE -C AVA 2.75' NEW STYLE TPI, ISOLATE C -SANDS 1/m/2003 Two P. Spas 1%1X10.0 7,0228 49.90 FISH FISH GLV @2907 w0rOket 1810,, Iemh In pothole- 4/911997 0.1300 LOST W29199 FIEY 0 9, Perforations It Slots PACKERR:. B.LM4 KJ PPCWOFF STICKIN PBR: OSM1Shot8]54.0 en9 TopIND) Ban I1VDl (aholsm To mKe) elm mKe) (KKaI (IIKeI unxea zone om I ryP. cam 9,350.0 9,3870 8,606.9 6,628.6 C-1.172-211 10/1992 12.0 1 WERE 14 5' Gun4H5 deg PRODUCTION: 9.¢58.3 UpP ER ECUPSE PACKER: 9.591.91 9,618.0 6,759.2 6,7958 Ay I. -2D 10/1992 1 40 1PERF 45' CSB Guns. 180 deg 5x.46 Mandrel Inserts at M an 'v Topmke TOpf1VD1 wne Lab. Flats. 10 Ran MKS) Mab Me4M Opan) sem Tyq To. 0) (MLI Run Vam cam 2.9068 2,381 CAMCO KBUG- 1 TAS LIFT GLV BTM 0.188 1.250.0 81 M IPERF:98TG� ...%3 2 4,8640 3,681.6 CAMCO KBUG- 1 GAS LIFT OV BK 0250 0.0 83872018 M SUEEVI 9,3M' NIFPLEst.l.o 3 6,018.6 4,494.9 CAMEO KBUG- 1 GASLIFT DMY BK 013110 0.0 1@212007 M 4 6,6446 4,906.4 CAMCO KBUG- 1 GASLIFT DMY BK 0.000 0.0 4/1111997 M 5 7,2695 5.298.9 CARCO KBUG- 1 GASLIFT FM -Y- BK 0.000 00 4/2/1997 PACKER,..3 89E:9S[.6 Poill M B ],921) 5,7092 CARCO KBUG- i GAB LIFT OMT BK 0.000 0.0 3/11/1993 M ] 8,551.7 6,1039 OTIS LB 1111 IGAS LIFT IPATC RM 0.000 0.0 518/2003 H NmxE:94¢a 8 9,1538 6,680.1 OTIB LB 11/2 PROD DMT RM 0.0130 0.0 4/12/997 605:9.938.0 9 %I'm3 6,5]20 ONS LB 11/2 PROD PATC RM 0.000 00 4/512001 Cease H d Notes: General 8 Safety Ena Dale ammumon 383/200] NOTE, TBG LEAK FOUND@9025'Ho35'RKB 711MO07 Ni FOLLOWING PATCH, NEW TUBING LEAK DETECTED @8565' 1W1912010 NOTE: View Schem.tic wl Abska SchemeaS0 1011912010 NOTE: mandrel @8552 -Mandrel still leaking. needs Met 1014/06 (PERF: 9.x1096850- 10/1812012 NOTE: ORIGINAL RIG RKa vs WORK0 ER RIG RKB ACCCOUNTS FOR TBGICSG TOPS FlSH: Moopc PR0 TCTION.37.}10.06!J Nordic 1 • 1- iI , , L I Il .0 > 3 r0 > rD UJ h mv, Y ° O u a j Fa- Y p ` r0 s'-' ° Ln ) <r v aa C C + O Nc a r0 Y N .0 .4-, 'p H CU O v a (13 < px 0 L u a C < J W N r- r- N r- r- r- r- N F- r " U) E p m J d N L N u p (n er. r O C C C C C C C C C C C E '-i o 7 7 7 7 7 7 3 7 J a '6 2 N I-- N O N N Co O O 0 N N in N 0 *' C z Q u '0 CO LO .-, r i 0 v > E v O C o 0 Q1 'p N u O 0 0 0 0 0 0 0 0 0 0 C `- a 0 L W J J J J J J J J J J Jbij O } W W W W W W W W W W W ,n N i U 4- WH LL LL LL LL LL LL LL LL LL LL LL .-, N a) Q) 0 0 Q J J J J J J J J J J J a L > .0 C S0 Q Q Q Q Q Q Q Q Q Q Q a) L ,4,_ O O) 4 Z Z Z Z Z Z Z Z Z Z Z u L a) 0 v r5) ca a)LL LL LL LL LL LL LL LL LL LL LL cc ,.0 t > (0 Y > .- a) U) C yj Cli a u N O ?% Z a N u Rf O C O w CU ONE. U w R. m N - u L C Z Smme O O a LL F U C (u0 Q O O t0 - >> -p Q CD a ,n C a U f0 Lu Lu U- LL > LL O CB N, E S, O 0 J ~ O a N 0 d J a J G m a O 0 CC m 0 40 a U 5 W a ~ -I r : til - o td m df > o -14 a O z ,4 a' "3 .‹) W O S al 0 W 'U a J J J J J J J J J J J � 3 3 3 3 3 � zao WL du 0 CLCGCLMCCecectcerYce 7 � - z W W W W W W W W W W W V W > > > > > > > > > > > 4 yA ixeccrcerececexcectce z Y Y Y Y Y Y Y Y Y Y Y O > > > > > > > > > > > w Q Q Q Q Q Q Q Q Q Q Q CI W d d d a G. a a a a a CL O 0700000070 n 0 O ' Y Y Y Y Y Y Y Y Y Y Y roC L- ill _ o W CO Co N O N M 0 0 . . X to 0 co N O M M M M M O) O O as N o 0 0 0 0 0 0 0 o .- NMI U O o 0 0 0 0 0 0 0 0 0 0 0) LU I.1 x 0 0 0 0 0 0 0 0 0 0 0 V t� r� r� CV Co 0 0 0 0 0 0 CO 0 0 ro> ' ` > co 7 cn fA (n N cn u v ZLL, 0 0 0 0 0 0 0 0 0 0 0 Q c x i U m (Q Y W 0 O 0 0 0 0 0 0 0 0 0 0 �'' O CU CC lD O O O O O O O O O O O V Q Q N tom) V O) N N N N O U!) N . N CO N U) N O 0 (O M N « •- a (+') lk IL R U) N N N N co N V to O M0 0 0 M N N 0 N N d N N N N N N N N N N N N L L N Q M O Of M C) O O M O) 0) C 0 a N N N N 0 0 N N 0 N N 01 co O 0 0 0 0 0 0 ti. 0 U °u O O O O O O O O O O O �+ « C O Co C U) U) U) U) U) In U) U) U) U) U) Q. 'C 0 C co:n F Cr) re u C i v Q) E 4) - d C. Z O c !i7 W E E n3 co 4) e z v N d Q 0 7 M (�, O O ,_ N O N O a~-, E C) Q) a) _ 00 d � rr) Z - r .- r E C a Q O N -, M N N Z C1 N N O O _ _ I rl Wc c ca N '-1 v h (0 E y E E O � d3c � r` a` aF°-- �° XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢/"//~/ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED · [] ' Logs-of vadous kinds . [] Other COMMENTS: Scanned by: E~ver~ D~athan Lowell [] TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si . . WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 1, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 1R -20 ‘91 - 1 p Run Date: 6/30/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22207 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 22207 -00 .,� '� ., , w tt SEA' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: q / / k\ Signed: iti,„ ICI ~ LJ Con P ' ' oco hill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: L~ s ! SEP 0 2 2009 Al~~k~ A~I ~ f~s ~Ana,.Go 'ssion l~n~ho~~ 1, ~ ~~ ~~ ~ - ~" ~.` ~ . ~,~:,~,, °~r ' ; :- ~ l U s3 ... .~ . . . ~ n Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23id 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29th 2009. T'he attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, f~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ~-: ~ ~,~ ~ ° k~ °~ ~'~ `~ ~ ~ ~~~~ FJ' /.~ L~..J.. . . ..., k o . _ _ P _. . . , ~ +' x ... ' _ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/29/09 1 R PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosia~ inhibitor Corrosion inhibitor! sealant date ft bbls ft al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" 8/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23l2009 4.7 6l28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" S/15/2009 3.8 8/28J2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28/2009 1 R-08 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1R-10 50029213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8/28/2009 1R-11 50029213520000 1850970 47' 6.00 38" 8l15/2009 13.9 8/28/2009 1R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8115/2009 12 S/29/2009 1 R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1 R-18 50029221880000 1910870 9'4" 1.20 21" 8l15l2009 3.7 8/28/2009 1R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1 R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8115/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8@3/2009 13.9 8/28/2009 1R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1 R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009. 07/23/07 Scblumberger NO. 4336 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth L. 2 5 Z007 SCANNED JUL 2 7 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 fì'a,<ìka Oil 8, Cons. Commission l~nchof¡1gù l ~ ( - I O"ð ~ Field: Kuparuk Well Date CD BL Color Job# Log Description \/!:J 2M-20 11629044 PRODUCTION PROFILE 07/11/07 1 3M-20 11665456 INJECTION PROFILE 07/13/07 1 2M-27 11665457 INJECTION PROFILE 07/14/07 1 1R-20 11632727 LDL 07/12/07 1 2M-17 11632731 INJECTION PROFILE 07/14/07 1 3M-27 11632732 lDL 07/15/07 1 1R-15 11632734 INJECTION PROFILE 07/17/07 1 2l-327 11665460 TEMPERATURE SURVEY 07/17/07 1 2V-08A 11665459 UslT 07/16/07 1 2Z-16 11665458 sCMT 07/15/07 1 2N-343 11665463 INJECTION PROFILE 07/20/07 1 1L-07 11632735 INJECTION PROFilE 07/20/07 1 1A-09 11632736 INJECTION PROFILE 07/21/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 07/12/07 Scblumberger RECE\VED NO. 4332 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth dUL 2. 5 zom Alaska Oil ß" Gat; Cons. Commission Company: Anchorage 2, '1 1.\)\)1 S~NeDj\JL Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 19/-/00 Field: Kuparuk Well Job# Log Description Date BL Color CD 1C-125 (REDO) N/A MEM INJECTION PROFILE 05/05/07 1 1 E-31 11629042 Gls 07/09/07 1 1R·20 11839632 lDL 07/06/07 1 3F-19A 11839634 PRODUCTION PROFILE 07/08/07 1 2L-309 11839633 GLs 07/07/07 1 1 J-122 11629039 UslT 07/05/07 1 2N-342 11629036 FMI 07/04/07 1 /) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . ~/ ConocoPhillips Alaska RE.(~E.\\lE~) JUL 1 9 2GíS7 . 1" n.mffi\SSIOf\ Î~ '0" \",,1" m\ ~'i GasjJ ": !.\!'\!.'.ho~a\1cl ¡, ~.. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 14, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCA."1NED AUG 0 3 2007 Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notice for ConocoPhillips Alaska, Inc., welllR-20 (PTD 191-108). The Sundry Notice is for an attempt to repair the well with a tbg patch after the patch was pulled for a production profile log. This notice also reports the initial tbg patch work completed in 10/2004 as it was inadvertently overlooked. v/ ./ Due to multiple tbg leaks, the attempt to repair the well has been abandoned at this time. lR-20 has been left shut-in long term until a rig repair is possible. Please call Marie McConnell or Perry Klein at 907-659-7224 if you have any questions. ~ø~ Marie McConnell ConocoPhillips Problem Well Supervisor Attachments Iql .....(0"'6 . RECEIVED " 1. Operations Performed: Abandon D Repair Well 0 ~ Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 191-108 , 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22207-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 88' , 1 R-20 " 8. Property Designation: 10. Field/Pool(s): ADL25628 .- ALK2561 Kuparuk River Field 1 Kuparuk Oil Pool ,- 11. Present Well Condition Summary: Total Depth measured 1 0080' r feet true vertical 7063' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 122' 16" 122' 122' SURF CASING 5462' 9-5/8" 5550' 4161' PROD CASING 9975' 7" 1 0063' 7063' Perforation depth: Measured depth: 9350 - 9387, 9591 - 9648 true vertical depth: 6605 - 6629, 6759 - 6796 Tubing (size, grade, and measured depth) 3 1/2" J-55 & L-80, 0 - 9398' MD 2-718" J-55, 9398- 9430' MD Packers & SSSV (type & measured depth) pkr= BAKER 'HB' RETR.; BAKER 'D' PERM pkr= 9254'; 9389' SSSV= SSSV SSSV= 1772' 12. Stimulation or cement squeeze summa N/A RBDMS BFL AUG 0 1 2007 Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Marie McConnell/Perry Klein Printed Name Marie McConnell / Title Problem Wells Supervisor Signature æ~// ~tfLA Phone 659-7224 Date 7/14/07 // . STATE OF ALASKA JUL. 1 9 200/ ALASKA OIL AND GAS CONSERVATION COMMISSION ..··1 k 01 & G' S GOI1S, CammÎssioQ REPORT OF SUNDRY WELL OPERA TIONSA as a I ð. Form 10-404 Revised 04/2004 ORIGINAL A-~I\ ~ 7/il,4>1 Submit~1 ~~_ ~ ~r/ ?'f/o/ . 1 R-20 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 05/09/03 Replaced DV in GLM#7 with new DVs, still leaking. 10/09/04ISet tubing patch at GLM #7. 10/14/04 IA drawdown test & MITrA passed post patch. Pressure up IA with diesel to 2000 psi, start MITIA TIIIO= 300/2000/200, 15 minute reading TIIIO= 300/2050/200, 30 minute reading TIIIO= 300/2050/200 Bleed down IA to 1400 psi, monitor for 30 minutes. Final TIIIO= 300/1450/200 04/11/06IPulled ret tbg patch at 8541' over tbg leak at GLM #7 for PPROF 12/07/06 SET WEATHERFORD 'ER' PACKER AS LOWER ELEMENT OF A PATCH TO COVER GLM#7. MID ELEMENT SET AT 8574' (LDL DEPTH) APPROX NINE FEET BELOW TOP OF FIRST FULL JOINT BELOW GLM. 12/13/06 SET UPPER PATCH ASSEMBLY PACKER MID-ELEMENT AT 8546.7', 12/24/06ITIFL Failed post patch 02/16/07 Pulled retrievable patch at 8547'. 05/30/07 LDL located second leak @ 9024' 07/06/07ISET HES 3-1/2" PERMANENT PATCH (PATCH ID= 2.36") OVER 9008'- 9039.2' 07/12/07 LEAK DETECTION LOG: CONFIRMED KNOWN LEAK BY GLM #7 AT 8565', PATCH OVER LEAK AT 9024' IS HOLDING. FOUND 3RD LEAK AT 8876', LOCATED AT THE BOTTOM OF A TBG COLLAR. Due to multiple tbg leaks, abandoned attempt to repair at this time. Well left Sllong term 06/08/07 Schlumbel'gel' NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 1 1.007 Cn\'ì~,ç~xNkED JUN 142007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 (C) I - / D-t ~~. Field: Kuparuk Well Job # Log Description Date Color CD BL 2M-13 11665442 SBHP SURVEY OS/28/07 1 1J-105 11632710 GLS OS/26/07 1 2N-305 11632713 SBHP SURVEY OS/29/07 1 1 R-20 11665444 LDL 05/30/07 1 10-03 11630480 PRODUCTION PROFILE 06/01/07 1 3S-18 11629016 PRODUCTION PROFILE 06/03/07 1 2M-02 N/A SBHP SURVEY 06/04/07 1 2M-06 11628958 SBHP SURVEY 06/05/07 1 2M-04 11629022 SBHP SURVEY 06/05/07 1 1H-11 11629026 PRODUCTION PROFILE 06/07/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1J~ . . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. " To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / 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 : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1] 1 Report / EOE 2] 3] 4] 5] 6] 7] 1 R - 20 Caliper Report 01-Apr-07 ~ APR 11 ,OU1 1'7/-/0'6 It 14~3 Signed: 0- tL-- APR 1 {} ¡no"" ~V ! . ;;~~t"i¡¡\)'''',,,,,,,, . ' Oa~""' ~M ~ ~ !..Cn:\!. COmmL<1"ion ¿;1m'iCI'©'Qe Print Name: (lkrì~t-~ IÅ .Q ~O~A PRoAcTIVE DIAGNOSTIC SERVICES, INc., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245..s952 E-MAIL: ?DSANCHORAGE@MEMORYLOG.COM WEBSITE: V\f\j\JW.MEMORYLOG.COM D:'Master _Copy _ OQ _ PDSANC-2OxxIZ _ Word\Distribution\TransmittaI _ Sheets\TransITÚt_ OriginaLdoc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No, : Run No.: Pipe1 Desc.: Pipe1 Use: Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 1 R-20 Kuparuk Alaska 50-029-22207-00 Surface 9,252 Ft. (MD) ConocoPhillips Alaska, Inc. April 1 , 2007 8585 2 3.5" 9.3Ib. J-55 Tubing Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This log is tied into the Landing Nipple @ 9,200' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good to fair condition, with the exception of a hole in pup joint 274.3 located below GLM 7 (8,565'). The damage appears mainly in the forms of isolated pitting and lines of pits. No significant areas of cross-sectional wall are recorded. Deposits are recorded in joint 296, with a recorded minimum 10 of 2.74" at 9,246'. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. This is the second time a PDS caliper has been run in this well, the first of this tubing. MAXIMUM RECORDED WALL PENETRA 110NS : Holes Isolated Pitting Line of pits Line of pits Isolated Pitting 274.3 @ 276 @ 280 @ 289 @ 217 @ 8,565 Ft. (MD) 8,600 Ft. (MD) 8,746 Ft. (MD) 8,996 Ft. (MD) 6.754 Ft. (MD) ( 100%) ( 31%) ( 31%) ( 27%) ( 25%) Jt. Jt. Jt. Jt. Jt. MAXIMUM RECORDED CROSS-SECll0NAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded. MAXIMUM RECORDED ID RESTRICll0NS : Deposits 9,246 FT. (MD) Minimum 10 = 2.74" Jt. 296 @ No other significant 1.0. restrictions are recorded. I Field Engineer: K. Mil/er Analyst: M. Tahtouh Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P,C. Box 1369[ Stafford,. n: 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 IPt I-/O~ tt 14643 I I I Well: Field: Company: Country: lR-20 Kuparuk ConocoPhillíps Alaska, Ine. USA I Weight 9.3 f Grade & Thread -55 Tubing: Nom.OD 3.5 ins I I Penetration and Metal loss (% wall) I metal loss body I I o to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% 1 o I I Damage Configuration ( body ) 80 I 60 40 I 20 o I isolated general line ring hole I poss pitting corrosion corrosion corrosfon ¡bie hole I I I PDS Report Overview Body Region Analysis penetration body o o Survey Date: Tool Type: Too! Size: No. of Fingers: Anal st: Nom.lD 2.992 ins GlM 1 GlM2 GlM 3 GlM4 GLM 5 GlM6 GlM 7 GlM8 Bottom of Survey = 296 Analysis Overview page 2 I I April 1, 2007 MFC 24 Ext. No. 40665 1.69 24 M. T ahtouh Nom. Upset 3.5 ins Upper len. 6.0 ins Lower len, 6.0 ins Damage Profile (% wall) metal loss body 50 100 I I Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-10.1' - 9238.5') Well: Field: Company: Country: Survey Date: 1 R-20 Kuparuk ConocoPhiHips Alaska, Inc. USA April 1 , 2007 I I I Approx. Tool Deviation Approx. Borehole Profile -4 743 1512 2305 eLM 1 3093 3873 4640 eLM2 (¡¡ 5428 ..!:) ..; E LL. eLM3 .!:: z 6210 ..- ¡: eLM4 6987 eLM5 eLM6 7771 GLM7 8566 GLM8 9239 50 100 Damage Profile wall) I Tool Deviation (degrees) I I I I I I I I I I I I ßottom of Survey = 296 I I I I PDS REPORT JOINT TABULATION SH I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-20 Kuparuk ConocoPhillíps Alaska, tne. USA April 1, 2007 I Joint JI. Depth ¡'en Pen. Pen. Me'!;']! Min. Damage Profile No. (Ft.) Body 1.0. Comments (%w all) (Ii) (Ins.) (Ins.) 0 50 100 .1 -10 ¡ 0.01 Ii 0 2.97 PUP 1 -4 i 0.03 I Ii 2.90 Shallow Dittim;:. It. DeDosíts. 11II 1.1 28 I 0.D1 s ! 2.94 PUP 2 35 ( 0.01 (, 2.90 3 66 I 0.03 1 2.89 4 97 0 0.01 2,90 5 128 0 0.02 I 2,90 6 160 0 0.01 ( 2.91 7 190 0 0.02 (I I 2.92 8 222 ( 0.03 ¡ 2 2.91 9 254 ( 0.03 ? 2.89 10 283 ( 0.02 1 2.91 11 I 115 I 0.02 t 2.90 12 I 346 i 0.04 2 2.90 Shallow nittiml. 13 I 378 0 0.03 2 2.90 14 406 0 0.02 It 2 2.90 15 437 0 0.02 9 ¡ 2.89 16 468 0 0.02 a 2.90 17 499 0 0.02 q 2.89 18 529 0 0.03 2.89 19 560 0 0.03 2.90 Shallow Dittim;:. 20 592 0 0.03 2,91 Shallow Ditting, 21 623 0 0.03 2.90 22 655 0 0.02 9 2.92 23 684 0 0,03 10 2.92 I 24 712 I 0.03 12 5 2.92 25 743 0 0.03 1 2.91 26 775 0 0.03 2.91 Shallow Ditting. 27 806 0 0.03 2,92 28 834 0 0.03 2.91 29 866 0 0.02 2.93 30 896 0 0.02 9 2.92 31 927 0 0.02 a 2.92 32 959 it 0,02 a I 2.91 33 987 0 0.03 1: 2 2,91 34 1015 0 0.03 '¡ 2 2.91 35 1047 0 0.02 2.91 36 1078 0 0.02 2.93 37 1109 0 0.ü2 2.95 38 1140 0 0.02 ) 2.91 39 1172 0 0.02 ) 2.92 40 1202 0 0.02 (I 2 2,90 41 1234 0 0.03 H 2.92 JI 42 1265 0 0.03 1. 2.91 Shallow Dittim;:. 43 1296 0 0.03 1 2.93 44 1328 0 0.03 I 2.90 45 1359 0 0.02 ( 2.93 46 1390 0 0.05 I 2.93 Shallow oíttímz. 47 1420 0 0.02 (I 2.92 Lt. Denosits. 48 1451 0 0.02 a 2 2.92 Lt. Deoosits. I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I REPORT INT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominall.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-20 Kuparuk ConocoPhillips Alaska, Inc. USA April 1, 2007 I I I Joint Jt. Depth Pel1 Pen. Pen. \i\.elal Min. Damag e Profile No, (Ft.) \;:;~(;I Body 1.fJ, Comments (% wall) (Ins.) (Ins.) 0 50 100 49 1482 I) 0.03 I 10 1 2.92 50 1512 I) 0.04 I 14 I) 2.90 Shallow nittin<>. 51 1543 I) 0.02 1 2.92 52 1571 I 0.02 2.91 53 1602 I 0.03 2.90 Shallow oittin2. 54 1633 I 0.03 2.90 Shallow niWnQ. 55 1663 I 0.03 2.93 Shallow nittim1.. 56 1692 I) I 0.01 2.93 57 1723 0 0.03 13 2.90 Shallow nitting. It. Denosits. 57.1 1754 0 0.01 4. 2.92 PUP 57,2 1762 I) 0 I) Ö 2.81 SSSV 57.3 1772 [!~ 2.96 PUP 58 1780 2.89 59 1812 2.91 60 1844 2,89 Shallow nitting. 61 1875 I) 0.ü3 2.90 62 1906 0.ü3 ¡ 2.91 63 1938 I) 0.02 C) I) 2.90 64 1968 I) ! om B 5 2.94 65 2000 I) 0.02 ::±=± 2.92 66 2031 I) 0.02 2.93 67 2062 I) 0.03 I 2.91 68 2094 I) 0.03 I) 2,91 69 2126 0 0.02 2.92 70 2154 I) 0.02 2.91 71 2185 0 0.02 9 2.93 72 2215 I) 0.02 7 2.92 73 2247 I) 0,04 I, i 2.90 Shallow nittinçc 74 2275 I) 0.03 1 'j I) 2.92 75 2305 0 0.02 I) 2.95 76 2337 0 0.03 n I) 2.92 Shallow nittinQ. 77 2369 I) 0.02 1 2.95 78 2400 I) 0.02 I 2.94 79 2431 0 0.02 ß 1 2.94 80 2462 0.02 7 2.95 81 2493 0.04 ,1 2.91 Shallow nittinq. Deoosits. 82 2524 0.02 2.96 83 2554 0.ü3 2.91 Shallow oittin2. 84 2586 0.ü3 2,89 Shallow nittill\1.. 85 2617 I) 0.02 9 I 2.92 86 2649 I) 0.02 I) 2.94 87 2680 I) 0.02 q 1 2.94 88 2710 I) 0.02 q I) 2.92 89 2742 I) 0.04 5 2.92 Shallow nittínQ. 11II 90 2774 0.04 2.92 Shallow "ittin". 11II 91 2806 ( 0.03 11 2.92 92 2836 I 0.01 2.91 93 2868 I 0.02 e 2.95 93.1 2899 I) 0 I) N/A GlM 1 (Latch @ 9:00\ 94 2908 I) 0.01 (; 2.95 I I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I PDS REPORT JOINT TABU ON SH I I Pipe: Body Wall: Upset Wall: Nominal!.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-20 Kuparuk ConocoPhillips Alaska, Inc. USA April 1 , 2007 I Joint J!. Depth Pel1. Pen. PelL ,'VIr'I;'11 Min. Damag e Profile No. (F!.) 'I Body !D. Comments wall) ) (Ins,) (Ins.) 0 50 100 95 2937 0 0.04 16 I 2 I 2.91 Sha!low oittin2. III 96 2969 0 0,03 12 2 I 2.94 97 3000 () 0.02 ') , I 2.94 ¡ 98 3032 () 0.03 13 2.90 Shallow oittim;~. 99 3064 () 0.03 1'1 2.94 Sha!low oittim;¡. 100 3093 () 0.03 n 2.91 Shallow oittimz. 101 3123 0 0.02 q 2.94 102 3154 0 0.02 q 2.94 103 3185 0 0.03 12 2 2.90 104 3217 0 0.D3 13 2 2.93 Shallow oittin2, 105 3249 0 0.02 a 3 2,93 106 3280 0 0.04 '') 2.92 Shallow oittin2. 107 3312 () I 0.04 4. 2.92 Shallow aittim;¡. lOa 3343 () 0.02 2.94 109 3373 u 0.04 I 291 Shallow oittinq. 110 3404 0 0.D2 I 2.94 111 3436 0 0.02 a 2.95 112 3467 0 0.02 7 2.93 113 3499 0 0.02 7 4. 2,94 114 3531 0 0.02 B 2 2.94 115 3563 i 0.03 13 2 2.93 Shallow oittim:. 116 3595 I 0.02 1 2.94 117 3620 I 0,04 7 2.93 Shallow aittìm;¡. 118 3653 I 0.02 2.94 119 3684 0.03 10 : I 2.92 120 3715 0 0.02 ') 2.88 121 3747 0 0,03 1 2.90 Shallow nittin2. 122 3779 0 0.03 J 2.87 Shallow oittin2. 123 3811 0 0,03 J 2.97 Shallow oittin2. Deoosits. 124 3841 0 0.D3 1 2.91 125 3873 0 0,04 2.93 Shallow oitting. 126 3905 iJ 0.05 2.91 Shallow pitting. 127 3936 0 0.D2 2.92 128 3964 0 0,03 11 2.90 129 3996 :J 0.02 q t 2,94 ¡ 130 4025 :J 0,04 2 2.92 Shallow oittin2, II! 131 4055 0.02 2 2.93 132 4086 OJ13 2 2.93 133 4117 0.D3 2.93 I 134 4148 0,04 2,90 Shallow pittim;¡. 135 4177 0.02 2.92 136 4208 0 0.03 1 2.94 137 A")'YL 0 0.03 2 2.83 138 4269 0 0,02 ß 2 2.91 139 4299 0 0.02 ß 2,93 140 4330 0 0.01 1 291 141 4361 0 0.03 1 2.89 142 4392 0 0.04 1 2.88 Shallow oitting. I 143 4424 0 0.04 1 2.89 Shallow oiUinQ. I 144 4455 0 0.03 13 2 2.88 Shallow oitlÍ!lQ. I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I I PDS REPORT JOINT TABULATION S I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-20 Kuparuk ConocoPhillips Alaska, Inc. USA April 1, 2007 I Joint Jt. Depth Pen Pen, Pen Metal Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) ) (Ins.) (Ins.) 0 50 100 *4486 n 0.02 9 ) 2.91 ~ 1 4518 0 0.04 ,; '¡ 2.91 Shallow nittinQ. 1 4548 0.02 11 ±j2.89 148 4579 0.ü3 2.93 Shallow nittinQ. 149 4610 0.02 2.91 150 4640 I 0.03 ) 2.91 151 4672 0 0.02 " 2.95 152 4703 0 0.01 2.93 153 4733 0 0,02 2.96 154 4764 0 0.02 9 2.90 155 4796 n 0.02 7 ': 2.94 156 4827 I 0.01 f ') 2.93 156.1 4859 0 f 0 N/A GLM 2 (Latch @ 8:301 157 4868 0.01 7 2.95 158 4897 0.02 ) 2.92 159 4929 0.02 ) 2.94 160 4960 o~ 7 2,92 161 4991 o I (, 2.94 162 5023 n 2 B I 7 2.95 163 5053 0.02 7 2.92 164 5085 0.02 7 2,93 165 5116 0.01 7 2.92 166 5148 0.03 10 ) 2.95 167 5178 ( 0,02 2.92 168 5208 0.02 2.92 169 5241 0 0,04 15 ) 2.93 Shallow nittinº. U. Denosits. 170 5271 0 0.02 7 ) 2.94 171 5304 I 0 0.01 5 7 2,95 172 5335 n 0.02 7 ) 2,93 173 5365 0 0.03 2 2.92 174 5398 0 0,02 ) 2.93 175 5428 0 0.ü2 I 2,93 176 5460 0 0.ü2 I 2.91 177 5491 0 om ;; 2.93 " 178 5522 () 0,02 I 2.89 !II 179 5553 0 0.02 7 2.91 !II 180 5585 n 0.01 f: 2.91 181 5615 II 0.01 2.89 182 5644 II 0.01 2,90 183 5676 II 0.ü2 2.90 ~ 184 5707 () 0.02 2.91 Lt. Denosits. II 185 5738 () om ~ ~ 186 5768 0 0.ü3 I f: I 187 5799 0 0.ü3 10 ) 2.92 !III 188 5831 0 0.03 -; 2.89 Shallow nittinQ, !III 189 5862 II 0.04 4 2.92 Shallow nittinQ. II 190 5891 () 0.03 2.90 Shallow nittinQ. !III 191 5923 () 0.04 2.89 Shallow oittin\!. ~fM 192 5954 () 0.01 6 2.93 193 5986 0 0.ü2 B 2.92 !II I I I I I I I I I I I I Penetration Body Metal Loss Body Page 4 I I I PDS REPORT JOINT TABULATION SHEET I I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf J-55 0.254 in 0,254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-20 Kuparuk ConocoPhillips Alaska, Inc. USA April 1, 2007 I Joint ]t. Depth I\'!I Pen. Pen Metal Min. Damag e Profile No. (Ft.) Body W, Comments (% wall) .) (Ins.) (Ins.) 0 50 100 193.1 6016 0 0 0 0 N/A GlM 3 (latch @ 12:3Oì 194 6024 0 0.Q1 5 -:; 2.91 195 6054 0 0.02 9 ì 2.92 196 6085 0 0.03 0 1 2.92 197 6117 I 0 0.02 I 2.90 198 6147 0 .291 199 6179 0 0.02 2.88 '" 200 6210 0 0.02 I 2.91 201 6242 0 2.90 Shallow nittin<>. 202 6273 0 0.02 ) 2.89 U. Denosi ts. 203 6304 0 0.02) 2.89 204 6336 ( 0.02 CI 2.89 205 6365 ( 0.02 c ) j C:¡1 206 6397 ! 0.03 0 ) 2.90 207 6428 0.02 2 2.88 ~ 0 0.03 I 2.95 2 9 0 0.03 " 2,91 210 6519 0 0.02 " 2.95 211 6549 0 0.02 " 2.94 212 6581 0 0.02 9 j 2.94 213 6612 0 0.01 j 2.91 213.1 6643 0 0 0 N/A GLM 4 (latch @ 11 :oOì 214 6649 0 0.02 I) 2,95 '" 215 6681 0 0.02 1 2.94 pill 216 6712 0 0.02 ! 2.94 pill 217 6744 0 0.06 25 ;; 2.89 Isolated nittin<'. !III 218 6776 0 0.02 7 I 2.95 219 6807 0 0.02 B j 2.93 220 6838 0.02 c ) 2.94 221 6868 0.02 E I 2.93 222 6899 O.O'i i! if. 2.92 Shallow oittÎrJQl. 223 6928 0,02 ¡ 2.92 !I 224 6956 0.02 I 2.95 !II 225 6987 0.02 1 2.92 226 7017 ( 0.03 [) ) 2.90 227 7050 0 0.01 ;; 2.95 228 7080 0 0.02 " 2.94 229 7110 0 0.01 f 1 2.97 230 7141 0.Q1 2.91 231 7174 0.02 2.92 !i 232 7205 0.02 2.94 F' 233 7236 0.03 11 2.89 WI!! 233.1 7267 I 0 ( N/A GlM 5 (latch @ 7:301 234 7277 () 0.01 2.93 235 7306 ( 0.02 2.95 236 7338 ( 0.02 ., 2.93 237 7368 0.Q1 2.92 238 7399 0.01 2.95 239 7431 0.02 2,93 240 7460 (I 0.03 10 2.92 I I I I I I I I I I I I I I Body Metal loss Body Page 5 I I I I PDS REPORT JOINT TABULATION S Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-20 Kuparuk ConocoPhillips Alaska, Inc. USA April 1 , 2007 I I I Joint Jt. Depth Pen Pen, Pen. !vlf'!ai Min. Damage Profile No. (Ft.) pse! Body 1.0, Comments (%w all) (ins) (Ins.) (Ins.) 0 50 100 241 7490 0.01 ,4 2.90 242 7522 0.ü3 1 2.94 243 7554 0.02 1 2.94 ~ 7583 ( 0.03 1 2.92 7615 ( 0.02 "2 2.94 246 7647 ( 0.02 ( 2.95 247 7678 ( 0.03 3 2.90 Shallow nittinQ. 248 7710 0 0.01 e¡ 2 2.94 249 7741 0 0.02 a 2 2.94 250 7771 , ~II 2 2.90 2'11 7804 ( B :> 2.93 252 17m3 ì [) ¡ 2.94 Shallow pitting. I 253 7862 ( 0.01 ¡ 2.91 ¡ 254 7892 ( 0.02 I 2.94 254.1 7919 0 0 0 NJA GlM 6 (latch @ 5:30\ 255 7930 0 0.01 4 2 2.95 2'1(, I 7959 0 0.02 3 2.93 257 7990 0 0.03 0 2.89 258 8023 0 0.04 2.92 Shallow piHimr. II 259 8052 0 0.02 2.94 260 8083 0 0.02 2.96 261 8114 0 0.02 ¡ 2.92 262 8144 0 0.02 3 2.92 263 8175 0 0.ü3 13 "2 2.91 Shallow oittim2. 264 8206 ( 0.03 10 ¡ 2.93 265 ~ () 0.02 2.89 266 I) 0,02 )92 It. Deposits. 267 8300 I) 0.01 2.93 268 8331 0 0.02 2.92 269 8361 0 0.02 2.94 270 8390 0 0.02 2.94 271 I 8422 0 0.ü1 5 2 2.96 27) 8453 0 0.02 a 2 2.95 273 8482 0 0,02 9 2 2.95 274 8515 0 0.05 2 2 2.95 Isolated oitting. 274.1 8545 0 0.01 t 2,89 PUP 274.2 8552 I) 0 C N/A GlM 7 (Latch @ 2:301 274.3 8562 0 0.39 I n iD 2.93 PUP Multiple HOLES! 275 8566 I) 0.05 2.89 Line of nits. 276 8597 0 0.08 2.90 Isolated nitting:, 277 8628 (I 0.04 4 1 2.94 Line of shallow nits. 278 8660 0 0.03 ¡ 2 2,94 279 8691 0 0.03 ) 2 2.91 280 8719 I) 0.08 4 2.91 Line of pits. 281 8751 0 0.02 2 2.92 282 8784 0 0,02 1 2.93 283 8813 0 0.ü3 ¡ 2.91 Shallow nininQ. 284 8844 0 0.02 B 3 2.92 285 8874 0 0.01 (, 0 2.91 286 8904 [) 0.ü3 12 0 2.84 Shallow oittimr. \I I I I I I I I I I I I Body Metal Loss Body Page 6 I I REPORT INTTABULATION SH I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 1 R-20 Kuparuk ConocoPhillips Alaska, Inc. USA April 1, 2007 I Joint Jt. Depth h'l Pen. ....~ "",1('(al Min. Damage Profile No. (Ft.) 'I Body LD. Comments (%wall) (Ins.) (Ins,) 0 50 100 287 8936 0 0.02 ~ ) 2.89 m 288 8964 0 0.02 1 2.88 289 8995 0 0.07 'I 2.87 Line corrosion. It. Denosits. 290 9025 0 0.02 0 2.90 291 9054 0 0.02 á ;I 2.90 292 9085 0 0.05 )T ¡ 2.87 Isolated nittinº. 293 9116 0 0.03 12 0 2.89 Lt. Denosi ts. 293.1 9148 0 0.02 B 0 2.87 PUP 293.2 9152 0 0 n n N/A Latch 9:30\ 293.3 9166 0 0.01 tt 2,91 PUP 294 9170 0 2.88 Lt. Denosits. Slioht bend unner bodv, I!!I 294.1 9200 0 0 2.81 X LANDING NIPPLE 295 9203 0 0.04 ¡ 2.83 Shallow nittin<>. Sliqht bend unner bodv. IIi 295.1 9231 0 0 0 2,89 PACKER 296 9239 0 0,04 fit 0 2.74 Shallow nittina. Denosits. I I I I Body Metal Loss Body I I I I I I I I I Page 7 I I ............ Well: Field: Company: Country: Tubin : .. .. 1R·20 Kuparuk ConocoPhillips Alaska, Inc. USA 3,5 ins 9.3 f -55 Cross Section for Joint 2 Tool speed = 53 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 66 0 ........ .. ........ PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: April 1, 2007 MFC 24 Ext. No. 40665 1.69 24 M. Tahtouh at depth 8564.957 ft Finger 23 Penetration = 0.39 ins HOLE 0.39 ins = 100% Penetration HIGH SIDE = UP Cross Sections page 1 .. - ............ ...... .. .... .. - -.... Well: Field: Company: Country: Tubin : PDS Report ross Sections 1R-20 Kuparuk ConocoPhillips Alaska, Inc. USA 3,5 ins 9.3 f -55 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: April 1, 2007 MfC 24 Ext. No. 40665 1,69 24 M. Tahtouh Cross Section for Joint 276 at depth 8600.023 it Tool speed = 53 Nominal 10 = 2.992 Nominal 00 = 3,500 Remaining wall area = 98 % Tool deviation 650 Finger 2 Penetration = 0.08 ins Isolated Pitting 0.08 ins = 31 % Penetration HIGH SIDE = UP Cross Sections page 2 .. .. ------ ------- - - -- - - P S Report Cro Secti s Well: Field: Company: Country: Tubin : 1R-20 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f -55 Survey Date: Tool Type: Tool Size: ,~o. of Fingers: Anal st: April 1, 2007 MFC 24 Ext. No. 40665 1.69 24 M, Tahtouh Section for Joint 296 at depth Tool speed ~ 43 Nominal 10 ~ 2.992 Nominal 00 3.500 Remaining wall area ~ 100 % Tool deviation ~ 770 79 ft Finger 8 Projection ~ -0.204 ins Deposits Minimum 10 ~ 2.74 ins HIGH SIDE ~ UP Cross Sections page 3 I I .r - ,. A" . KRU 1 R-20 . I sssv SSSV Type: TRDP OriQ Completion: 9/11/1991 Angle @ TD: 50 cleo @ 10080 (1772-1773, Annular Fluid: Last W/O: 1/811992 Rev Reason: GLV CIO OD3.500) LastTao: TD: 10080 ftKB 6 MaxH DescriDtion Size Top Bottom TV!) wt Grade Thread CONDUCTOR 16.000 0 122 122 62.50 H-40 SURF CASING 9.625 0 5550 4161 36.00 J-55 PROD CASING 7.000 0 10063 7063 26.00 J-55 Size Top Bottom TV!) wt Grade Thread 3.500 0 9261 6548 9.30 J-55 AB MOD EUE 8RD 3.500 9261 9398 6636 9.30 L-80 AB MOD EUE 8RD 2.875 9398 9430 6656 6.50 J-55 ABMOD EUE Comment St MD TVD Man Man Type V Mfr V Type VOD latch Port TRO Date Run Vlv Mfr Cmnt f 1 2907 2384 Cameo KBUG-M GLV 1.0 BTM 0.156 1260 1/23/2007 2 4864 3682 Cameo KBUG-M OV 1.0 BK 0.188 0 1/22/2007 3 6019 4495 Cameo KBUG-M DMY 1.0 BK 0.000 0 1/22/2007 I 4 6645 4907 Cameo KBUG-M DMY 1.0 BK 0.000 0 4/1111997 5 7270 5299 Cameo KBUG-M DMY 1.0 BK 0.000 0 4/211997 6 7922 5709 Cameo KBUG-M DMY 1.0 BK 0.000 0 3/11/1993 7 8552 6104 Otis LB DMY 1.5 RM 0.000 0 5/8/2003 (1) 8 9154 6480 Otis LB DMY 1.5 RM 0.000 0 4/12/1997 NIP (9200-9201, OD:3.672) PBR (9241-9242, 00:3.500) DeDth TVDe DescriDtion ID 1772 1651 SSSV Cameo'TRDP-1A' 2.812 PKR 8546 6100 PATCH Set WF 'ER' Lower PACKER for straddle PATCH @ 8547' on 1217/2006, Set 1.750 (9254-9255, 00:6.063) upper PATCH ASSY, upper PACKERset @ 8546' on 12/13/2006, 30.16' OAL PATCH 9200 6510 NIP Otis 'J<: Selective Landino 2.813 (9280-9304, 9241 6536 PBR Baker 4.0" Bore 3.000 00:3500) 9254 6544 PKR Baker'HB'Retr. 2.890 9280 6560 PATCH C-SAND STRADDLE PATCH - LOWER ECLIPSE PACKER (1.75" ID @ 2.310 9304' set 4/2/2003; K-3 PACKOFF w/SNAP LATCH #9280' set 6/18/2004 9379 6623 NIP AVA BPL Ported Nipple 2.750 9379 6623 SLEEVE-C AVA 2.75" NEW STYLE TPI ISOLATE C-SANDS set 1/10/2003 2.310 9389 6630 PKR Baker 'D' Perm 3.250 - 9397 6635 SSE XO to 2 7/S 3.000 -- 9413 6645 NIP Otis 'XN' Nipple NO GO w/2,313" oackina bore. 2.250 - - -.- - 9429 6655 SOS Baker 2.441 -- - Perf (9350-9387) Deoth Description Comment 9303 I FISH I SLIP FROM 3" TUBING STOP LOST 4/11/2006 PKR 10000 ¡FISH I GL V @2907 w/broken latch' latch in rathole - LOST 6/29/99 (9389-9390, 00:6063) NIP (9413-9414, 00:2.875) - -- Perf -- (9591-9648) - - - . I I I I I I I I I I I I I I I I I 12/06/06 Schlumbel'gep NO. 4061 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth C"u'" ;!i.~~'r,\EÙ ""v~\i-'" (\ () Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /C) 1- ¡ ö í Field: Kuparuk . Well Job # Log Description Date BL Color CD 1G-16 11486083 INJECTION PROFILE 11/26/06 1 1C-133 11486084 INJECTION PROFILE 11/27/06 1 1R-20 11486085 LDL 11/28/06 1 m-05 11486086 INJECTION PROFILE 11/29/06 1 1 D-03 N/A SBHP 11/25/06 1 1 D-09 N/A SBHP 11/25/06 1 2T-18 11477636 INJECTION PROFILE 12/01/06 1 1 R-03A 11483497 INJECTION PROFILE 11/30/06 1 2X-03 11483499 INJECTION PROFILE 12/02/06 1 1E-04 11477639 INJECTION PROFILE 12/04/06 1 . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Page 1 of3 Maunder, Thomas E (DOA) \<i. \- YD~ From: Sent: To: NSK Problem Well Supv [n1617@conocophillips.com] Monday, November 06, 2006 5:43 PM Thomas Maunder Subject: RE: FW: 1R-20 (PTO 191-108) Tom, Plans to temporarily flow 1 R-20 with TxlA communication for production logging have been cancelled. The tbg patch over GLM#7 was pulled, but attempts to pull the C sand straddle tbg patch were unsuccessful due to debris above the patch. A slip fell alongside the lower straddle patch during pulling operations. The well remains SI. The tbg patch will be reinstalled over GLM#7 to restore tbg integrity and return the well to production. A 10-404 report will be submitted once patch work has been completed. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com SCANNED AU G 0 1 2007 -~--_._--- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, March 15, 2006 2:43 PM To: NSK Problem Well Supv Subject: Re: FW: 1R-20 (PTD 191-108) MJ, What you propose is acceptable. Please keep me informed as to how things progress. I agree with your assessment that one of more of the WL pulling activities could be complicated by scale. A 404 should be submitted when the work is completed. Good luck. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 3/14/2006 4:57 PM: Tom, ConocoPhillips requests approval to flow 1 R-20 (PTO 191-108) with TubingxlA communication for 2- 4 weeks after pulling a tubing patch covering known tubing leak at GLM # 7 ( 8552' KKB). The tubing patch and a C sand patch below the tubing patch will be pulled to allow clearance for casing hole logging tools used to evaluate the A sand potential. After the data has been obtained and depending on the results the well will be SI and placed on the rig workover list or the patches will be replaced. No abnormal casing pressures are expected and the well will remain on gas lift during the testing. Upon approval we will proceed with well work to pull the patches, it may take a few weeks to recover them as we expect scale issues. 8/1/2007 . Page 2 of3 . Please let me know if you have any questions. «1 R-20.pdf» MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Versteeg, Joseph R Sent: Monday, March 13, 2006 5:48 PM To: NSK Problem Well Supv Subject: RE: 1R-20 MJ, The A sand has significant reserves @ risk, and although I expect the interval to produce some water, I expect it to be a good incremental target compared to the 97% C sand production. Due to the uncertainty of the A sand WC wI the proximity to the aquifer, this data is important for the RWO justification (or the possible NRWO repair based on the LDL data). If at any point during the operation we run into significant scaling problems and escalating costs, then I agree that we should re-consider the value of the data in the RWO decision. Please pursue the variance. Thanks, Joe -----Originat Message---- From: NSK Problem Well Supv Sent: Monday, March 13, 2006 4:23 PM To: Versteeg, Joseph R Subject: RE: 1R-20 Joe, I did a little more research and was reminded that the SSSV control line has issues on this well. It cannot be locked out due to scale and a frac sleeve must be run in order to keep it open. This means we have to pull the frac sleeve, pull the K2 PO, Pull the eclipse, then pull the C sand patch parts, then re run the Frac Sleeve. Then get the log (frac sleeve 102.3"). This well has a significant history of scale problems, so it is likely that one or more of the steps listed above will have scale complications. I have not applied for the variance yet (ran out of time and have to report back to the IMT for the 2M spill) and wanted another opinion from you given the rest of the data. Let me know if you still want to pursue the variance. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 8/1/2007 ... .......... ., 8/1/2007 . Page 3 of3 . -----Original Message--- From: Versteeg, Joseph R Sent: Monday, March 13, 2006 11:24 AM To: NSK Problem Well Supv Cc: CPFl Prod Engr; Harris, Marvin L.; Burd, James A Subject: 1R-20 MJ, As I discussed wI you this morning, I would like to submit a request to pull the two patches in 1 R-20 to allow for a lOl of the tubing string and a Pprof wI OEFT of the A sand. The well is currently producing - 3300 bfpd @ 96-97% WC. The lOllog data will be used to determine if a non-patched interval is leaking and may be corrected with an additional patch. The Pprof wI DEFT data will be used to determine if there is a viable target in the A sand to justify a RWO if re-patching is unsuccessful. A variance of two weeks is requested to allow for well stabilization after SOL and the surveillance logs that will follow. If you need more information, please let me know. Joe Re: FW: 1R-20 (PTD 191-108) . . MJ, What you propose is acceptable. Please keep me informed as to how things progress. I agree with your assessment that one of more of the WL pulling activities could be complicated by scale. A 404 should be submitted when the work is completed. Good luck. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 3/14/2006 4:57 PM: Tom, ConocoPhillips requests approval to flow 1 R-20 (PTD 191-108) with TubingxlA communication for 2-4 weeks after pulling a tubing patch covering known tubing leak at GLM # 7 ( 8552' KKB). The tubing patch and a C sand patch below the tubing patch will be pulled to allow clearance for casing hole logging tools used to evaluate the A sand potential. After the data has been obtained and depending on the results the well will be SI and placed on the rig workover list or the patches will be replaced. No abnormal casing pressures are expected and the well will remain on gas lift during the testing. Upon approval we will proceed with well work to pull the patches, it may take a few weeks to recover them as we expect scale issues. Please let me know if you have any questions. «1 R-20.pdf» MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 ,~" '"j -----Original Message----- From: Versteeg, Joseph R Sent: Monday, March 13, 2006 5:48 PM To: NSK Problem Well Supv Subject: RE: lR-20 MJ, The A sand has significant reserves @ risk, and although I expect the interval to produce some water, I expect it to be a good incremental target compared to the 97% C sand production. Due to the uncertainty of the A sand WC wi the proximity to the aquifer, this data is important for the RWO justification (or the possible NRWO repair based on the LDL data). If at any point during the operation we run into significant scaling problems and escalating costs, then I agree that we should 10f2 3/15/20062:43 PM · re-consider the value of the data in the RWO decision. Please pursue the variance. - Re: FW: lR-20 (PTD 191-108) Thanks, Joe -----Original Message----- From: NSK Problem Well Supv Sent: Monday, March 13, 2006 4:23 PM To: Versteeg, Joseph R Subject: RE: lR-20 Joe, I did a little more research and was reminded that the SSSV control line has issues on this well. It cannot be locked out due to scale and a frac sleeve must be run in order to keep it open. This means we have to pull the frac sleeve, pull the K2 PO, Pull the eclipse, then pull the C sand patch parts, then re run the Frac Sleeve. Then get the log (frac sleeve JD 2.3"). This well has a significant history of scale problems, so it is likely that one or more ofthe steps listed above will have scale complications. I have not applied for the variance yet (ran out of time and have to report back to the IMT for the 2M spill) and wanted another opinion from you given the rest of the data. Let me know if you still want to pursue the variance. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Versteeg, Joseph R Sent: Monday, March 13,200611:24 AM To: NSK Problem Well Supv Cc: CPFl Prod Engr; Harris, Marvin L.; Burd, James A Subject: lR-20 MJ, As I discussed wI you this morning, I would like to submit a request to pull the two patches in 1 R-20 to allow for a LDL of the tubing string and a Pprof wI DEFT of the A sand. The well is currently producing - 3300 bfpd @ 96-97% WC. The LDL log data will be used to determine if a non-patched interval is leaking and may be corrected with an additional patch. The Pprof wI DEFT data will be used to determine if there is a viable target in the A sand to justify a RWO if re-patching is unsuccessful. A variance of two weeks is requested to allow for well stabilization after BOL and the surveillance logs that will follow. If you need more information, please let me know. Joe 20f2 3/15/20062:43 PM . . . KRU 1 R-20 API: 500292220700 Well TVDe: PROD Anole (ãJ TS: 51 deo (ãJ 9274 SLEEVE SSSV Type: TRDP Orig 9/11/1991 Angle @ TD: 50 deg @ 10080 (1772-1773, ComDletion: 00:2.813) Annular Fluid: Last W/O: 1/8/1992 Rev Reason: Rerun FRAC Slv, Set GL V Reference Loa: Ref Loa Date: Last Uodate: 4/20/2005 Last Taa: 9527' WLM TO: 1 0080 ftKB Last Taa Date: 6/18/2004 Max Hole Anale: 54.2000 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 122 122 62.50 H-40 SURF CASING 9.625 0 5550 4161 36.00 J-55 PROD CASING 7.000 0 10063 7063 26.00 J-55 mr·1.iiil~lill Size Top Bottom TVD Wt Grade Thread 3.500 0 9261 6548 9.30 J-55 AB MOD EUE 8RD 3.500 9261 9398 6636 9.30 L-80 AB MOD EUE 8RD 2.875 9398 9430 6656 6,50 J-55 AB MOD EUE Interval TVD I Zone I Status I Ft 1 SPF I Date I Type 1 Comment 1 9350 - 9387 6605 - 6629 I C-1 I 1 37 I 12 1 1/7/1992 I IPERF 14.5" Cso Guns; 45 dea 1 9591 - 9648 6759 - 6796 I A-4 A-3 I 1 57 1 4 I 1n/1992 I IPERF 14.5" CSQ Guns; 180 deo I St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2907 2384 Camco KBUG-M GLV 1.0 BTM 0.156 1272 4/18/2005 TUBING 2 4864 3682 Camco KBUG-M GLV 1.0 BK 0.188 1317 4/19/2005 (0-9261. 3 6019 4495 Camco KBUG-M OV 1.0 BK 0.250 0 4/19/2005 00:3.500, 4 6645 4907 Cameo KBUG-M DMY 1.0 BK 0.000 0 4/11/1997 10:2.992) 5 7270 5299 Camco KBUG-M DMY 1.0 BK 0.000 0 4/2/1997 6 7922 5709 Camco KBUG-M DMY 1.0 BK 0.000 0 3/11/1993 7 8552 6104 Otis LB DMY 1.5 RM 0.000 0 518/2003 (1) 8 9154 6480 Otis LB DMY 1.5 RM 0.000 0 4/12/1997 1. EXTPKG St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt I 9 1 92981 65721 Otis LB 1 I DMY 1 1.5 I RM I 0.000 0 I 4/5/2001 1 Closed Depth TVD Tvpe Description ID NIP 1772 1651 SLEEVE 2.81" (OAL 10') LONG FRAC SLEEVE set 4/19/2005 2.300 (9200-9201, 1772 1651 SSSV Cameo 'TRDP-1A' 2.812 00:3.672) 8541 6097 Slipstop/ 3" SLlPSTOP (1.5" ID) AND k-3 PACKOFF W/ANCHOR (snap latch) 1.438 PBR Packott '(1.4375" ID) SET ON TOP OF ECLIPSE PACKER 10/9/2004 (9241-9242, 8568 6114 PACKER 3.5" ECLIPSE PACKER set 10/8/04 1.812 00:3.500) 9200 6510 NIP Otis 'X' Selective LandinQ 2.813 9241 6536 PBR Baker 4.0" Bore 3.000 PKR 9254 6544 PKR Baker 'HB' Retr, 2.890 (9254-9255, 00:6.063) 9304 6576 PACKER ECLIPSE PACKER (1.75" ID) set 4/2/2003; KNOCKED OUT SHEAR DISC 1.812 6/18/2004 9379 6623 SLEEVE-C AVA 2.75" NEW STYLE TPI, ISOLATE C-SANDS set 1/10/2003 2.310 9379 6623 NIP AVA BPL Ported NiDPle 2.750 ..........- .. .. ..._-.-.. 9389 6630 PKR Baker 'D' Perm 3,250 - - 9397 6635 SBE XO to 2 7/8 3.000 .....-.-.. .. .- --- 9413 6645 NIP Otis 'XN' NiPDle NO GO w/2.313" Dackina bore. 2.250 - - 9429 6655 SOS Baker 2.441 Perf - - (9350-9387) .... ... .. .. 9430 6656 TTL 2.441 - - ·..._n. . ..-..... I Depth I Description I Comment 1 PKR 10000 I FISH I ,From¡Ob on 4/13/97 - GLV @2907 w/broken latch; latch in rathole (9389-9390, 00:6.063) TUBING Date I Note (9261-9398, 00:3.500, 5/3/1997 I Scale Inhibitor Squeeze on 5/3/97; History of HEAVY SCALE in Well 10:2.992) NIP (9413-9414, 00:2.875) TUBING (9398-9430, 00:2.875, 10:2.441) '..m. Perf (9591-9648) ----..-..- . .. ......... ........ . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: PHILLIPS Alaska, Inc. September 26, 2002 4799 1 3.5" 9.3 lb. J-55 Tubing 2.875" 6.5 lb. J-55 Tubing Tail Well: IR-20 Field: Kuparuk State: Alaska APl No.: 50-029-22207-00 Top Log Intvll.: 8,765 Ft. (MD) Bot. Log Intvll.: 9,397 Ft. (MD) Top Log Intvll.: 9,398 Ft. (MD) Bot. Log Intvll.: 9,435 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This Icg was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to fair condition. Penetrations from 20% to 38% are recorded throughout the tubing logged. The damage appears in the forms of General Corrosion with deeper Isolated Pitting and Line Corrosion. The caliper recordings indicate a hole in the Packer ~ 9,267.' A cross-sectional drawing of the packer bore at the location of this hole is included in the report. No areas of significant cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate that the 2.875' tubing tail is in good to fair condition. The caliper recorded a 38% corrosive wall penetration in pup joint 0.1. The remainder of the tubing tail logged appears to be in good condition. No areas of significant cross-sectional wall loss or I.D. restrictions are recorded. Cross-sectional drawings of the most significant events are included in this report. The distribution of penetrations is illustrated in the Body Region Analysis Page of this report. The joint numbering used in this report is an estimate based on the average joint length recorded and top depth of the icg interval. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: HOLES recorded in Packer @ 9,267' Corrosion (38%) Jt. 299.1 @ 9,162 Ft. (MD) Corrosion (31%) Jt. 299 @ 9,153 Ft. (MD) Corrosion (26%) Jt. 293 @ 8,945 Ft. (MD) Corrosion (25%) Jt. 291 @ 8,885 Ft. (MD) Corrosion (24%) Jt. 292 @ 8,942 Ft. (MD) 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 8%) are recorded throughout the 3.5" tubing logged. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS · No significant I.D. restdctions are recorded throughout the 3.5" tubing logged. RECEIVEI) OCT 0 4 2002 ProActive Diagnostic Services, ]:nc. / P.O. Box 1369, Stafford, -IX ~aft~ 0il & Gas Cons. commission Phone: (281) or (888) 565-9085 Fax: (281) 565-:~369 E-mail: PDS@memorylog.cont~flCh0rage Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-23:~~, ,SCANNED NOV 2 2002 2.875" TUBING TAIL - MAXIMUM RECORDED WALL PENETRATIONS: Corrosion (38%) Jr. 0.1 @ 9,398 Ft. (MD) 2.875" TUBING TAIL - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 8%) are recorded throughout the 2.875" tubing logged. 2.875" TUBING TAIL - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the 2.875" tubing logged. Field Engineer:. D. Cain Analyst: M. Lawrence Witness: M. Chaney ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77q97 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 PDS Report Overview' Body Region Analysis Weft: 1 R-20 Survey Dam: September 26, 2002 Field: Kuparuk Tool ~ype: MFC 40 No. 00432 Company: PHILtIPS Alaska, Inc, Tool Size: 2.75 Country: USA No. o( Fingers: 24 AnaIy~!; M Lawreoce __ Tubing: Nora. OD Weight Grade & Thread Nora.iD Nom. Upset Upper Ion. lower len, : 3.5 ir!~ 9.~ [~pf t-55 2.992 ins 'tS ins 1.2 ~1~ 1.2 ins 0 1o t lo 10 to 20 to 40 to over I% 10% 20% 40% 85°,4 85% Number of ioints analysed (total = loss 14 13 0 0 0 0 Damage Cm-tfiguration ( body ) 20~ 10 ~3 4 o I i Damage Profile % wall/ 50 287 301 Bo t )m of Survey - 304.2 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 iris 9.3 ppf j-55 Well: 1R-20 WaJJ thickness: Body - 0.254 ins Upset = 0.254 ins Field: Kupmuk Nominal ID: 2.992 ins Company: PHiLLiPS Alaska, Country: USA Survey Date: September 26, 2802 joint Penetration Meta{ P~oiection Minimum No UpseI Bd@Up Body Loss Cplng Body ID J Cornm~nt~ ~ches nches inches % % nches inches inches 287 0 0 .03 13 5 .09 .06 2.83 Shallow pitting. LL Deposits. Lt. Deposits. 289 0 ) . .05 t 8 I .09 . i4 Z81 Sha[Jow corrosion. Lt. DepoMs. 290 0 ~ :0~ 06 , 22 , 2 , .08 .09 2.82 Corrosion. Lt. Deposits. ~9 _ 0 .03 . .06 25 ~ I .09 .08 ~ 2.8l Cor¢os]on. Lt. Deposits. 292 0 02 .06 24 2 .09 , ~ ~3 ~grtgsi~ ~p~pgsi~: 29~ 0 0 07 ~G ~ .09 .39 2.60 Corrosion. Deposits. 294 0 0 .05 20 [ 0 .10 2.83 L ne shalJow corrosion. L~. D~ppsJts~ ?:~ ~) 02 0~ 2'~ ~ ~9 69 B? '~co,:~O' u r~epos , 297 0 05 .05 19 1 .09 .09 ¢ 2.82 Shallow corros[om Lt. DepgsiU: 398 i 0 ~ ~ 22 2 : 08 : 12 2.79 Corrosion. LL Deposks. ~9 0 i 0 708 31 I .08 .107 2:82 Gurroskm: k% DppP~itS. 299~1 0 .Oe~ _ AO 38 ~ 8 _ .1( . 3 , 2.80 ~UPCotrosioa~ Lt.~eposits: 299:2 0 0 0 0 0 0 0 NZA GIM 8 (Lalfh ~ 12:00) 101 0 0 05 20 3 08 08 2.81 Shallow corrosion~ Lt. Deposits 301.1 0 O .05 ?0 7 0 )B 2 89 PUP Corrosion. 301.2 0 0 0 0 0 ) 0 3.0C PbR ~11.3 0 0 .40 t00 0 O 0 2.89 PACKFR Hole! 302 0 0 . .03 12 2 . 0 .08 2.98 Lt. Deposits. 3f12.1 0 0 .05 18 1 . .07 .07 2.83 PUP Shallow corrosion. Lt. Deposits 3022 0 .~ 0 0 U 0 0 0 N/A PROD MANDREL (Latch@O:00) 302.3 0 .05 .04 17 0 0 . .05 2.77 PUP Mash. ShaJJow pitting. Lt. Deposits. 303 0 0 _ .03 12 2 0 :25 2,90 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wail thickness Ring ~ damage area exceeds 65% of circumference, but depth range does not exceed I ~ pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General ~ damage depth ~ange exceeds t * pipe IDand/or extends more than 20% of circumference Isolat(,d - damage depth range does not exceed 5 ~ pipe ID or extend more than 20% of circumference Damage repo~ting threshold = 30 thou inches deviation in body, 50 tho~ in coup{lng. Modal tine length = 0.207 feet. PDS Report Cross Sections Cross Section for Joint 301,3 at depth 9267,19 ft Tool speed- 54 Nominal ID = 2.890 Nomil~al OD = 3,500 I~temaining wall area = 69 % Tool deviation -- 57 ° PDS Report Cross Sections Well: 1 R20 Sur~,ey Date: Seplembel 26, 2002 Field: Kupa~uk Tool Type; MFC 40 No. 00432 (omi}any: PHILLIPS Alaska, Ira. Tool Size: 2.75 Cross Section for loint 299,1 at depth 9162,19 ft ¥oo[ speed S5 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area ,= 90 Tool de¥iaticm = 60" Ooss Sections page 2 Pipe: 3.5 ins 9.3 ppf J-55 Wall thickness: Body = 0.254 ins Nominal ID: 2.992 ins Depth feet 8766.12 8790.91 8821.49 8850.85 8882.13 8912.08 8942.78 8974.32 9001.14 9032.54 9062.93 9093.41 9124.31 9154.39 9162.37 9171.18 9176.71 9207.89 9208.91 9241.33 9247.34 9259.92 9268.08 9299.13 9306.56 9315.04 9323.01 9350.30 9381.38 9396.68 PDS REPORT JOINT TALLY SHEET Upset = 0.254 ins Type :Im )br ,rod. sleeve over Well: 1 R-20 Field: Kuparuk Company: PHILLIPS Alaska, Inc. Country: USA Survey Date: September 26, 2002 Joint Tally page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 2,875 ins 6.5 ppf J-55 Well: 1R-20 Wall thickness: Body = 0.217 ]ns Upset = @217 ins Field: Kupamk NorninaJ JJ): 2.44i ins Company: ['hilL[ IPS Alaska, Inc. Countn/: USA Survey Date: September 26, 2002 joint ] Penetration Metal Proi~'ction Minimum No. Upset Bd@Up Body Loss Cplng Body ID Comments incbes inches .inc:hes ~ , @, . inches inches h~ches ~ 0 ~ 08 08 38~ 8 0 .05 ..,a3 PUP Corrosion. Lt. 2 0 0 .0l 6 5 0 0 2.34 PUP .3 0 0 . 0 0 0 0 0 2.25 [XN NIP .4 0 0 .01 ) 6 0 0 2,35 [PUP metal loss body Danlage Profile (% wall) 0 50 100 Penetration / projection class, in order o~ damag~ severity Hole - penetration exceeds 85% of nominal wall thickness Ring ~ damage area exceeds 65% of circumference, but depth range does not exceed I "pipe ID Line - damage depth range exceeds 5 ' pipe ID, but extends less tha?~ 20% of circumference. Gene~a[ - damage deplh range exceeds 1 * pipe IDand/or extends mom than 20% of circumference. Isolated damage depth range does not exceed 5 * pipe iD or extend more than 20% of circumf~=rence. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line length = 0.203 feet. Pipe TabuJations page PDS Report Cross Sections WeJl: 1B-20 Survey Date: 5eptembe~ 26, 2002 Field: Kuparuk Tool Type: MFC 40 No. 00432 Company: PHILIiPS Alaska, h~(. Too[ Size: 2,75 Countlv: USA No. of Fh~ge~s: 24 TLib~H~: 2:~5 ~ns 6:~ppl }-~ AnaJys~ M: Lawre?e Cross Section for joint 0,1 Tool speed = 51 at depth 939Z8 ft PDS REPORT JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf J-55 Wall thickness: Body = 0.217 ins Upset = 0.217 ins Nominal ID: 2.441 ins o, I / /ID tID / ID J OD / _~ feet .I feet I inches l.l_!~c..hes ~. inches l. inches_~__ ............... I_~,3 L 9422.32 J-~~'~O.,'_~-~i~~'~--Z--i':~~ ............. Well: 1 R-20 Field: Kuparuk Company: PHILLIPS Alaska, Inc. Country: USA Survey Date: September 26, 2002 [ '-J~]-~ t~ Depth '[~ ~-n-g'~i~l-'T-I~E~-~'i'-"'l'"~-~l-r ~-'-[-~-~-I~'i ~'~'['- ] ~,~ ~:)~ ~~' ]~-~ ~ .................. No.I ] J ID JID ) ID ] OD / ~iIifeet feet inches inches inches inches ii'iiiJ. Joint Tally page 1 OR Bt{t ORE E E W P- L--- T E AOGCC Individual Well Geological Materials inventory P age: 1 Date: 12/17/93 PERMIT DATA T DATA_PLUS 91-102 CBT L 91-108 CDR-LWD L 91-108 CET L 91-108 ~LWD CO~ L 91-108 '1P0~7 R 91-108 DAILY WELL OP R 91-108 SURVEY R 91-108 5124 T R1,8678-9968 R1-2,5568-10080 R1,8678-9968 R1,5568-10080 COMP DATE:01/09/92 09/02/91-01/09/92 SS DIRECTIONAL OH-CDR/CDN,7420-10082 SCALE DATE_RECVD 5 2/5 5 2/5 09/23/1991 09/09/1992 09/23/199! 09/09/1992 02/27/1992 02/27/1992 05/22/1992 11/27/1991 Are dry ditch samples required? yes co~_~nd z_~l~~s no Was the well cored? yes ~Ananlysis & description rec~v~.~ yes Are well tests required~yes. ~Re?~~.yes no ~ Well is in compliance ~ k~ no Comments ARCO Alaska, Inc. Date' May 22, 1992 Transmittal #: 8442 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Sub-Surface Directional 9 - 1 2 - 9 1 75076 Survey Sub-Surface Directional 8 - 2 7- 9 1 75073 Survey Receipt Acknowledged' Date' D&M State of Alaska (2 copies) RECEIVED MAY 2_ 2_ 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3Q-03 LIS Tape and Listing I -27-92 92095 3 R- 12 D LIS Tape and Listing 2 - 4 - 9 2 92115 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY RECEIVED WITH THIS ONE. THANK YOU. )'/'"'//¢ I R - 1 7 :~/-'/~& 1R-20 9/--//) 1 R-21 ,?/_/o?' 1R-22 ~/.-/ot 1R-23 ¢/....?$ 1R-24 ~,/....~,~ 1 R-26 ?/...,, o~- 1 R-27 ?/- ?F 1R-29 ?/-..&l 1R-19 ?1-/.~/ 2M-21 ¢/--/~-2 M - 1 9 ¢/---~- 1 L-23 ¢/~-~' 1 L-24 ¢/-?o 1 L-25 ¢/---~¢¢ 1 L-26 LIS Tape and Listing 9 - 1 9 - 91 92026 LIS Tape and Listing 9 - 9 - 9 1 92026 LIS Tape and Listing I 0 - 6 - 91 92026 LIS Tape and Listing 9 - 2 4 - 91 92026 LIS Tape and Listing 1 0 - 2 2 - 91 92026 LIS Tape and Listing 7 - 3 0 - 91 92026 LIS Tape and Listing 7 - 1 8 - 91 92026 LIS Tape and Listing 8 - 31 - 91 92026 LIS Tape and Listing - 8-14-91 92026 LIS Tape and Listing 6 - 1 9 - 91 92026 LIS Tape and Listing 1 1 - 1 I - 91 92026 LIS Tape and Listing 1 1 - 1 7 - 91 92026 LIS Tape and Listing 5 - 9 - 9 1 92026 LIS Tape and Listing 5 - 1 9 - 91 92026 LIS Tape and Listing 5 - 2 6 - 91 92026 LIS Tape and Listing 6-3- 9 1 92026 Receipt Acknowledged' R-EC--E VE D DISTRIBUTION: Lynn Goettinger FEB 2 8 1992 Alaska 0il & Gas Cons. Commission Anchorage State of AlaSka ' STATE OF ALASKA 0 R ~ ~ ~ '~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , . 1 Status of Well Classification of Service Wall OIL ~ GAS E~ SUSPENDED r~ ABANDONED ~] SERVICE r-'-] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-108 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22207 4 Location of well at surface 9 Unit or Lease Name 666' FSL, 146' FWL, SEC 17, T12N,R10E, UM : ~ '~''~:;~I !~'~ ~ -.r~ ..........~ KUPARUK RIVER At Top Producing Interval :.~: ,~ ~ ~ ,~:..i ~ i '.' ..... \'[ I'~J~'~S'~ 10 Well Number · · ~ ..'::/_/~./.i. · 11 Field and Pool At Total Depth ; ~ ; · 1199' FSL, 1641' FEL, SEC 8, T12N, R10E, UM ' ~ ' ~i.I" . ? KUPARUK RIVER FIELD 5 Elavation in feet (indicate KB, DF, ate.) I 6 Lease Designation and S~rial No. KUPARUK RIVER elL ~OOk t RKB 88', PAD 45' GLI ADL 25628, ALK 2561 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 09/02/91. 09/08/91. 01/09/92.[ N A feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 10,080' MD, 7073' TVD 9977' MD, 7007' TVD YES ~-~ NO E~] 1772' feet MD 1700' APPROX 22 Type Electric or Other Logs Run CD N/CDR/GR/CET/CBT/GYRO 23 CASING, LINER AND CEMENTING RECORD I SE-I-I-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5# H-40 SURF 123' 24' 329 SX ASI 9-5/8' 36# J-55 SURF 5550' 12-1/4' 11100 SX TYPE E, 520 SX CLASS G 7' 26# J-55 SURF 10,063' 8-1/2' 250 SX CLASS G 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) (3-1/2' 9.3#) (2-7/8' 6.5~) :9388', 9430' 9254', 9389' 9350' - 9387' W/4-1/2" CSG GUN @ 12 SPF MD 6604' - 6628' TVD 9591' - 9648' W/4-1/2' CSG GUN @ 4 SPF MD 6758' - 6795' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE · 28 CORE DATA Brief description of litholegy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit eom chips. E( EIV D FEB ? Alaska 0il & (;as Cons. ~;u~-nrnissio~ ~nnhoraoe Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. - ' ~ ~' ;; 'r 30. GEOLCGIC ~RS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9274' 6555' NA KUPARUK C BOTTOM 9390' 6629' KUPARUK A TOP 9569' 6744' KUPARUK A BO-II-OM 9752' 6862' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed .... ~_, __~__.__~__~__~ Title AREA DRILLING ENGINEEI~ Date _'~_.--_~?~._._~ // INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: 1R-20 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25628 ALK 2561 A?I: 50-029-22207 PERMIT 91-108 APPROVAL: ACCEPT: 09/02/91 SPUD: 09/02/91 RELEASE: 09/10/91 OPERATION: DRILLING RIG: POOL 7 AFE: AK5890 WI: 55.252072 09/02/91 (1) TD: 122'( 122) SUPV:JRR 09/03/91 (2) TD: 2424' (2302) SUPV:JRR 09/04/91 (3) TD: 5568' (3144) SUPV:JRR 09/05/91 ( 4) TD: 5568'( SUPV:KKL o) 09/06/91 ( 5) TD: 6930' (1362) SUPV:KKL 09/07/91( 6) TD: 9018' (2088) SUPV:KKL 09/08/91 ( 7) TD:10080' (1062) SUPV:KKL 09/09/91 (8) TD:10080' ( SUPV:KKL o) 09/10/91 ( 9) TD:10080' ( SUPV:KKL 0) NU DIVERTER MW: 0.0 VIS: 0 MOVED RIG FROM 1R-27 TO 1R-20. ACCEPTED RIG 0500 9/2/91. DAILY: $15,086 CUM: $15,086 ETD: $15,086 EFC: $1, 690, 000 DRLG AT 2424' NU DIVERTER. DRLD 122'-2424'. MW: 9.2 VIS: 62 DAILY:S65,544 CUM:$80,630 ETD:S80,630 EFC:$1,690,000 SHORT TRIP 9-5/8"@ 5550' MW: 9.6 VIS: 45 DRLD TO 3157'. TRIP FOR BIT. DRLD TO 5568', 9-5/8" CSG PT. DAILY:S74,563 CUM:$155,193 ETD:S155,193 EFC:$1,690,000 NU BOP 9-5/8"@ 5550' MW: 9.7 VIS: 44 CIRC. POH. RAN 9-5/8" CSG & CMTD W/ 1100 SX PERMAFROST E & 520 SX G. CIRC CMT TO SURF. ND DIVERTER. NU BRADENHD. DAILY:S218,572 CUM:$373,765 ETD:S373,765 EFC:$1,690,000 DRLG AT 6930' 9-5/8"@ 5550' MW: 9.2 VIS: 37 NU BOP. RIH. DRLD CMT & FC. TEST CSG TO 2000 PSI. DRLD FS & 10' NEW HOLE. TEST FORMATION TO 12.5 PPG EMW. DRLD 5578'-6930' -- DAILY:S69,121 CUM:$442,886 ETD:S442,886 EFC:$1,690,000 DRLG AT 9018' 9-5/8"@ 5550' MW: 9.8 VIS: 36 DRLD TO 7556'. TRIP FOR LWD FAILURE. DRLD TO 9018' DAILY:S48,464 CUM:$491,350 ETD:S491,350 EFC:$1,690,000 DRLG AT TD 9-5/8"@ 5550' MW:ll.0 VIS: 43 DRLD 9018'-10080'. DAILY:S77,188 CUM:$568,538 ETD:S568,538 EFC:$1,690,000 POH 9-5/8"@ 5550' MW:ll.4 VIS: 41 CIRC AT TD.POH, HOLE SWABBING & MUD THICK. INCREASE MW & THIN MUD. POH TO 7748'. DAILY:S57,992 CUM:$626,530 ETD:S626,530 EFC:$1,690,000 RUNNING 7" CSG 7"@10063' MW:ll.5 VIS: 46 POH. RIH W/ SLICK BHA. CIRC. POH. RUNNING 7" CSG. DAILY:S150,616 CUM:$777,146 ETD:S777,146 EFC:$1,690,000 RECEIVED FEB 2 7 ' 992 Alaska Oil & Gas Cons. Commission Anchorage WELL: OPERATION: RIG: 1R-20 DRILLING POOL 7 PAGE: 09/11/91 (10) TD:10080' ( SUPV:KKL o) RELEASED RIG 7"@10063' MW:ll.4 VIS: 0 FINISHED RUNNING 7" CSG. CMTD W/ 250 SX CL G W/ ADDITIVES. ND BOP & SET SLIPS. DAILY:S167,095 CUM:$944,241 ETD:S944,241 EFC:$1,690,00 SIGNATURE: ' I LIN~ SUPERINTEND~WT L" DATE: RECEIVED Alaska Oil & Gas Cons. Anchorage ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 1R-20 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25628 ALK 2561 50-029-22207 91-108 ACCEPT: 01/06/92 SPUD: RELEASE: 01/09/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK5890 WI: 55.252072 01/07/92 (11) TD:10080 PB: 9977 SUPV:DB/LH 01/08/92 (12) TD:10080 PB: 9977 SUPV:GB/TB 01/09/92 (13) TD:10080 PB: 9977 SUPV:GB/TB PERFORATING 7"@10063' MW:ll.4 NaCl/Br MOVE RIG FROM 1R-23 TO 1R-20,ACCEPT RIG AT 20:30 HRS,ND TREE NU BOPE,TEST SAME TO 3000 PSI,OK, RU SWS,TEST LUBRICATOR TO 1500 PSI,PERFORATE 'A' AND 'C' SANDS AS PER PROCEDURE,GUN#I: 9628-9648',4 SPF, 180 DEG, GUN#2 9608-9628',4 SPF, 180DEG RIH W/GUN #3 DAILY:S56,110 CUM:$1,000,351 ETD:SO EFC:$2,690,351 RIH W/COMPLETION 7"@10063' MW:ll.4 NaCl/Br CONT PERFORATE WELL AS PER PROCEDURE,GUN#3:9591-9608,4 SPF 180 DEG, GUN#4:9367- 9387,12 SPF, 45 DEG, GUN#5:9350-9367,12 SPF, 45 DEG, POH,MU 6.05" GR/JB, RIH TO 9600'WLM, POH,RECOVER JUNK, REPEAT,MU BAKER MODEL D PKR AND TAIL ASSY AS PER PROCEDURE,RIH AND SET PACKER ON W/L AT 9413'WLM, POH,RD SWS RU TO RUN COMP,RUN COMPLETION AS PER PROCEDURE,MU SSSV AND C-LINE,TEST SAME TO 5000 PSI,OK, CONT RIH W/COMP DAILY:S76,506 CUM:$1,076,857 ETD:SO EFC:$2,766,857 RIG RELEASED AT 05:00 HRS 7"@10063' MW:ll.3 NaCl/Br STAB INTO PERM PKR, VERIFY POSITION, SPACE OUT COMP,MU HGR AND C-LINE,TEST SAME TO 5000 PSI,OK,MU LANDING JT,DRAIN BOP STACK, LAND TBG, RILDS,PRESS TBG TO 2500 TO SET PKR, TBG WILL NOT HOLD PRESS,NO RETURNS,CHECK SURFACE EQUIP FOR LEAKS,OK CALL OUT OTIS W/L,RU SLICKLINE,TEST LUBRICATOR TO 2000 PSI RIH AND SET STD VLV IN XN NIPPLE,PRESS TEST TBG TO 2000 PSI SLOW LEAK, RETR. STD VLV, PRESS TEST TBG TO 2000 PSI,SLOW LEAK PRESS UP TO 3200 PSI,SHEAR SOS,INJECT 4 BBL BRINE,RIH W/ 2.22 DRIFT,POH, RIH AND SET STD VLV IN XN NIPPLE,PRESS TEST TBG TO 2500 PSI, SLOW LEAK, POH,RIH W/GR AND TAG STD VLV, POH RIH AND PULL AVA SLEEVE,REDRESS SLEEVE,RIH AND SET AVA SLEEVE,PRESS TBG TO 2500 PSI F/15 MIN, OK, PRESS CSG TO 1000 PSI F/15 MIN, OK, POH,RD SLICKLINE,PRESS TBG TO 1500 PSI,PULL 105K# SHEAR PBR, RELAND TBG, RILDS,PRESS CSG TO 2500 PSI,OK TEST SSSV W/500 PSI DIFF,OK, RU OTIS SLICKLINE AND RETR STD VLV, RD SLICKLINE,PULL LDG JT,SET BPV,ND BOPE,NU TREE,TEST TREE AND PACKOFF TO 5000 PSI,OK, DISPLACE ANNULUS WITH 13.5 BBLS DIESEL,BULLHEAD 5 BBLS DIESEL DOWN TBG, SECURE WELL SITP=250 PSI,SICP=0,SIAP= 300 PSI,RELEASE RIG AT 05:00 HRS DAILY:S44,251 CUM:$1,121,108 ETD:SO EFC:$2,811,108 SIGNATURE: DRILLING SUPERINTENDENT 9'/-/o'2' SUB - S URFA CE DIRECTIONAL SURVEY J~l UIDANCE r~-! ONTINUOUS ~ OOL Company ARCO ALASKA, INC. Well Name 1R-20(666'FSL,146'FWL,SEC 17,T12N,R10E) Field/Location KUPARUK,NORTH SLOPE,ALASKA Job Reference No. 75076 Locjoed By: K. BARNARD Date 12-SEP-91 Computed By: S. DEES GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA SURVEY DATE: 12-SEP-91 ENGINEER: K. BARNARD METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST, PROdECTED ONTO A TARGET AZIMUTH OF NORTH 32 DEG 25 MIN EAST COMPUTATION DATE: 2-NOV-91 PAGE 1 ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 12-5EP-91 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: K. BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL. DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 50O O0 600 O0 700 O0 8OO OO 900 O0 0 O0 100 O0 199 99 299 99 399 96 499 86 599 39 697 78 794 69 890 03 -88 O0 0 0 12 O0 0 34 111 99 0 38 211 99 0 54 311 96 1 47 411 86 3 37 511 39 7 2~ 609 78 12 53 7O6 69 15 3~ 802 03 19 37 N 0 0 E N 21 39 W N 22 50 W N 15 25 W N 10 13 E N 24 35 E N 29 52 E N 32 36 E N 33 42 E N 34 49 E 0 O0 0 10 0 69 1 47 3 27 7 5~ 16 95 34 6~ 59 22 89 30 0 O0 0 O0 0 O0 0 50 1 29 371 ,4 33 3 39 3 2~ 4 63 0 O0 N 0 16 N 1 12 N 2 33 N 4 48 N 8 63 N 16 96 N 32 O0 N 52 62 N 77 45 N 0 O0 E 0 06 W 0 48 W 0 92 W 0 96 W 0 48 E 4 9~ E 14 17 E 27 61 E ,44 61 E 0 O0 N 0 0 E 0 1 2 4 8 17 35 59 89 17 N 21 29 W 22 N 23 17 W 50 N 21 32 W 58 N 12 6 W 6,4 N 3 10 E 65 N 16 8 E O0 N 23 53 E 42 N 27 41 E 38 N 29 56 E 1000 O0 983.38 1100 1200 1300 1400 1500 1600 1700 1800 1900 895 38 21 32 O0 1076.55 988 55 21 21 O0 1169.01 1081 01 23 48 O0 1259.34 1171 34 27 10 O0 1346.83 1258 83 30 31 O0 1432.37 1344 37 31 40 O0 1516.69 1428 69 33 42 O0 1597.24 1509 24 39 24 N 35 18 E N 35 27 E N 35 57 E N 35 51 E N 36 17 E N 35 59 E N 35 54 E N 32 6 E O0 1671.95 1583 O0 1740.85 1652 125 09 161 199 242 290 342 395 454 95 43 16 N 30 8 E 521 85 50 33 N 29 39 E 593 38 38 17 45 13 79 91 31 59 0 64 081 3 O0 3 56 221 1 20 3 33 7 46 3 20 9 44 106 78 N 136 167 202 241 282 326 375 432 495 65 20 E '125 11 N 31 25 E 42 N 86 30 N 108 O3 N 133 15 N t62 95 N 192 51N 224 37 N 257 50 N 291 24 N 327 23 E 161 47 E 199 59 E 242 08 E 290 65 E 342 15 E 396 48 E 455 38 E 521 43 E 593 38 N 32 18 E 39 N 32 57 E 21 N 33 28 E 55 N 33 54 E 31 N 34 15 E 04 N 34 28 E 19 N 34 27 E 50 N 33 58 E 69 N 33 28 E 2000 O0 1800.87 1712 87 54 8 2100 2200 2300 2400 2500 2600 2700 2800 2900 N 30 5 E O0 1859.91 1771 O0 1921.48 1833 O0 1985 05 1897 O0 2049 76 1961 O0 2115 02 2027 O0 2180 91 2092 O0 2247 89 2159 O0 2314 85 2226 O0 2378.63 2290 673 46 91 52 56 N 30 33 E 754 48 51 9 N 30 12 E 832 05 49 58 N 30 31 E 910 76 49 26 N 31 10 E 986 02 49 2 N 31 43 E ]061 9] 48 30 N 32 25 E 1~37 89 47 32 N 33 15 E 1211 85 48 55 N 32 12 E 1285 63 51 9 N 30 20 E 1362 12 86 O0 21 97 ~.9 44 70 68 3000.00 2441.54 2353.54 50 52 N 30 55 E 1440.37 3100.00 2504.85 2416.85 50 26 N 31 37 E 1517.76 3200.00 2569.37 2481.37 49 26 N 32 22 E 1594.16 3300,00 2634.55 2546.55 49 11 N 32 52 E 1669.99 3400.00 2700.23 2612 23 48 42 N 33 26 E 1745.39 3500.00 2766.40 2678 40 48 35 N 34 0 E 1820,35 3600.00 2832.42 2744 42 48 48 N 34 15 E 1895.43 3700.00 2898.58 2810 58 48 11 N 34 49 E 1970.36 3800.00 2965.46 2877 46 47 54 N 35 10 E 2044.63 3900.00 3032.41 2944 41 48 1 N 35 30 E 21~8.82 0 70 2 69 1 81 0 88 0 56 0 63 091 0 42 4 44 0 78 0 42 1 44 0 42 0 37 0 86 0 36 0 42 0 94 0 42 0 39 564 62 N 367 17 E 673 50 N 33 2 E 634 702 768 834 899 962 1025 1087 1153 28 N 407 25 N 447 90 N 486 36 N 525 O0 N 565 76 N 605 13 N 645 39 N 686 46 N 725 94 E 754 77 E 832 72 E 910 80 E 986 33 E 1061 24 E 1137 53 E 1211 02 E 1285 57 E 1362 13 N 32 45 E 86 N 32 31 E O0 N 32 20 E 21 N 32 13 E 98 N 32 10 E 2O N 32 9 E 45 N 32 12 E 71 N 32 15 E 69 N 32 10 E 1220 34 N 765 17 E 1440 39 N 32 5 E 1286 1351 1415 1478 1540 1602 1664 1725 1786 53 N 8O5 3O N 845 16 N 886 32 N 927 66 N 969 82 N 1011 60 N 1054 51 N 1096 11 N 1139 31 E 1517 79 N 32 3 E 8,4 E 1594 19 N 32 3 E 73 E 1670 02 N 32 4 E 93 E 1745 42 N 32 7 E 59 E 1820 36 N 32 11 E 75 E 1895 43 N 32 16 E 24 E 1970 36 N 32 21 E 87 E 2044.63 N 32 27 E 83 E 2118.82 N 32 33 E COMPUTATION DATE: 2-NOV-91 PAGE 2 ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 12-SEP-91 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: K. BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUT~ EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3099.35 3011 35 48 12 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3165.66 3077 O0 3232.55 3144 O0 3300.14 3212 O0 3368.55 3280 O0 3436.92 3348 O0 3504.65 3416 O0 3571.26 3483 O0 3637.86 3549 O0 3705.05 3617 66 48 28 55 47 39 14 47 10 55 46 46 92 46 56 65 48 3 26 48 9 86 48 11 05 47 22 N 34 55 E 2193 O0 N 34 41 E 2267 N 34 58 E 2342 N 35 51 E 2415 N 36 ll E 2488 N 36 12 E 2561 N 34 32 E 2634 N 34 16 E 2709 N 32 ~ E 2783 N 32 6 E 2857 79 O6 67 46 27 73 27 85 92 5000.00 3773 52 3685.52 46 4 5100.00 3843 5200.00 3913 53O0.00 3983 5400.00 4054 5500.00 4124 5600.00 4196 5700.00 4268 5800.00 4340 5900.00 4411 62 3755.62 45 12 N 30 43 E 3002 42 3825.42 45 54 N 28 43 E 3073 66 3895.66 44 54 N 29 0 E 3144 55 3966.55 45 10 N 29 59 E 3215 61 4036.61 45 18 N 30 26 E 3286 29 4108.29 43 27 N 30 49 E 3356 65 4180.65 43 46 N 30 45 E 3425 72 4252.72 44 15 N 31 17 E 3494 52 4323.52 45 19 N 32 12 E 3564 N 32 6 E 2930 79 10 61 64 07 38 07 06 35 97 6000.00 4481.35 4393 35 46 29 6100.00 4549.33 4461 6200.00 4616.77 4528 6300 O0 4682.93 4594 6400 O0 4748.71 4660 6500 O0 4813.80 4725 6600 O0 4877.26 4789 6700 O0 4940.09 4852 6800 O0 5002.83 4914 6900 O0 5065.53 4977 33 47 23 77 48 3 93 48 5O 71 48 57 80 50 5 26 50 52 09 51 7 83 51 10 53 51 3 N 32 5 E 3636 55 N 31 37 E 3709 N 31 25 E 3783 N 31 49 E 3858 N 31 12 E 3933 N 31 44 E 4009 N 32 23 E 4087 N 31 58 E 4164 N 31 31 E 4242 N 31 8 E 4320 89 71 68 99 89 17 97 84 72 7000 O0 5128 52 5040 52 50 50 7100 7200 73OO 7400 7500 76OO 7700 7800 7900 O0 5191 O0 5254 O0 5316 O0 5378 O0 5441 O0 5504 O0 5567 O0 5631 O0 5694 57 5103 57 51 0 24 5166 24 51 21 55 5228 55 51 31 92 5290 92 51 20 53 5353 53 51 9 60 5416.60 50 44 84 5479.84 50 48 05 5543.05 50 48 18 5606.18 50 50 N 30 45 E 4398 37 N 30 17 E 4475 94 N 29 49 E 4553 80 N 29 19 E 4631 91 N 28 45 E 4709 95 N 28 7 E 4787 73 N 29 38 E 4865.14 N 31 22 E 4942.57 N 31 4 E 5020.05 N 30 49 E 5097.57 1 39 0 59 0 45 1 11 021 0 48 2 03 C 65 0 95 091 1846 67 N 1182 85 E 2193 02 N 32 38 .E 1908 1969 2029 2088 2147 2207 2268 2331 2393 25 N 1225 27 N 1267 38 N 1310 31 N 1353 21 N 1396 05 N 1439 67 N 148! I~ N 1522 86 N 1561 40 E 2267 86 E 2342 49 E 2415 48 E 2488 56 E 2561 35 E 2634 37 E 2709 17 E 2784 52 E 2858 82 N 32 42 E 11 N 32 46 E 74 N 32 51 E 56 N 32 57 E 42 N 33 2 E 92 N 33 7 E 49 N 3'~,., 9 E 08 N 33 9 E 13 N 33 7 E I 37 271 1 06 0 58 1 74 0 98 0 75 010 2 40 0 09 2455 59 N 1600 26 E 2931 O0 N 33 5 E 2516 2578 2640 2702 2764 2824 2883 2942 3002 27 N 1637 63 N 1672 98 N 1707 41 N 1741 03 N 1777 03 N 1813 31 N 1848 86 N 1884 77 N 1921 72 E 3002 92 E 3073 23 E 3144 89 E 3215 86 E 3286 37 E 3356 72 E 3425 21 E 3494 6O E 3564 29 N 33 3 E 76 N 32 58 E 74 N 32 53 E 15 N 32 48 E 43 N 32 45 E 11 N 32 42 E 09 N 32 40 E 38 N 32 38 E 99 N 32 37 E 221 1 08 1 77 0 44 0 64 2 15 051 051 0 32 0 57 3063.40 N 1959.64 E 3636 57 N 32 36 E 3125.63 N 1998.46 E 3709 3188.73 N 2036.80 E 3783 3252.44 N 2076 33 E 3858 3316.65 N 2115 70 E 3934 3381.53 N 2155 11 E 4009 3446.87 N 2196 39 E 4087 3512.71 N 2237 82 E 4164 3578.94 N 2278 80 E 4242 3645.48 N 2319 30 E 4320 91 N 32 36 E 72 N 32 34 E 69 N 32 33 E O0 N 32 32 E 89 N 32 31 E 18 N 32 3O E 97 N 32 30 E 84 N 32 29 E 73 N 32 28 E 0 47 3712.11 N 2359 21 E 4398 37 N 32 26 E 60 3778.97 N 2398 37 3846.41 N 2437 37 3914.44 N 2476 49 3982.78 N 2514 73 4051.36 N 2551 83 4119.63 N 2588 27 4186.05 N 2628 51 4252.34 N 2668 38 4318.82 N 2708 63 E 4475 67 E 4553 25 E 4631 21 E 4709 31 E 4787 20 E 4865 04 E 4942 18 E 5020 11 E 5097 94 N 32 24 E 80 N 32 22 E 92 N 32 19 E 97 N 32 16 E 76 N 32 12 E 20 N 32 8 E 64 N 32 7 E 12 N 32 6 E 65 N 32 5 E COMPUTATION DATE: 2-NOV-91 PAGE 3 ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 12-SEP-91 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: K. BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000 O0 5757.28 5669.28 50 56 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5820.33 5732.33 50 56 O0 5883.46 5795.46 50 49 O0 5946.41 5858.41 51 14 O0 6008.81 5920.81 51 36 O0 6070.80 5982.80 5] 49 O0 6132.63 6044.63 51 4~ O0 6194.56 6106.56 5t 4~ O0 6256.75 6168.75 51 22 O0 6319.27 6231.27 51 20 N 30 35 E 5175 12 N 30 20 E 5252 N 30 2 E 533O N 29 56 E 5407 N 29 39 E 5485 N 29 28 E 5564 N 29 12 E 5642 N 28 41 E 5721 N 27 48 E 5799 N 26 59 E 5876 69 18 82 88 25 73 10 20 95 0 29 0 29 0 38 0 37 0 55 0 38 0 56 1 O3 1 03 0 38 4385 53 N 2747.73 E 5175 21 N 32 4 E 4452 4519 4586 4654 4722 4791 4860 4928 4998 45 N 2787.05 E 5252 48 N 2826.05 E 5330 77 N 2864 90 E 5407 58 N 2903 72 E 5486 82 N 2942 46 E 5564 36 N 2980 94 E 5642 03 N 3018 98 E 572~ 99 N 3056 10 E 5799 31 N 3091 96 E 5877 80 N 32 3 E 31 N 32 1 E 97 N 31 59 E 05 N 31 57 E 45 N 31 55 E 97 N 31 53 E 38 N 3~ 5't E N 3; 48 E 35 N 3'1 /44 E 9000 O0 6381.91 6293.91 51 9 9100 9200 9300 9400 95O0 9600 9700 98OO 9900 O0 6444.81 6356 81 50 43 O0 6508.14 6420 O0 6571.79 6483 O0 6635.65 6547 O0 6699.69 6611 O0 6763.76 6675 O0 6828.13 6740 O0 6892.68 6804 O0 6957.21 6869 14 50 33 79 50 29 65 50 15 69 50 8 76 50 9 13 49 52 68 49 52 21 49 44 N 26 35 E 5954.52 N 26 22 E 6031.84 N 26 17 E 6108.80 N 26 9 E 6185.47 N 25 58 E 6261.96 N 25 55 E 6338.27 N 25 50 E 6414.55 N 25 40 E 6490.56 N 25 52 E 6566.41 N 26 43 E 6642.37 0 34 051 0 80 0 36 0 55 0 34 0 61 0 35 091 0 82 5067.91 N 3127.06 E 5955 01 N 3~ 41 E 5137.52 N 3161.68 E 6032 5206.86 N 3196.04 E 6109 5276.09 N 3230.04 E 6186 5345 16 N 3263.97 E 6262 5414 27 N 3297.50 E 6339 5483 32 N 3331.05 E 6415 5552 26 N 3364.28 E 6491 5621 11 N 3397.34 E 6568 5689 55 N 3431.27 E 6644 44 N 31 37 E 51 N 31 33 E 30 N 31 29 E 93 N 31 25 E 38 N 31 21 E 82 N 31 17 E 99 N 31 13 E 01 N 31 9 E 14 N 31 6 E 10000.00 7021.67 6933.67 49 54 N 26 43 E 6718.66 0.00 5758.20 N 3465.48 E 6720.59 N 31 2 E 10080.00 7073.20 6985.20 49 54 N 26 43 E 6779.55 0.00 5812.86 N 3492.98 E 6781.61 N 31 0 E COMPUTATION DATE: 2-NOV-91 PAGE 4 ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 12-SEP-91 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: K. BARNARD INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTORE SECTION SEVERITY NORTH/SOUTH EAST/WES7 DIST. AZZMUT~: FEET DEG,/IOC FEET FEET FEET DEG 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 -88 O0 0 0 O0 983 38 895 38 21 32 O0 1800 87 1712 87 54 8 O0 2441 54 2353 54 50 52 O0 3099 35 3011 35 48 12 O0 3773 52 3685 52 46 4 O0 4481 35 4393 35 46 29 O0 5128 52 5040 52 50 50 N 0 0 E O0 5757 O0 6381 28 5669 91 6293 0 O0 N 35 18 E 125 N 30 5 E 673 N 3O 55 E 1440 N 34 55 E 2193 N 32 6 E 2930 N 32 5 E 3636 N 30 45 E 4398 28 50 56 N 30 35 E 5175 91 51 9 N 26 35 E 5954 09 46 37 O0 79 55 37 12 52 0 O0 0 64 0 70 0 42 1 39 1 37 2 2~ 0 47 0 29 0 34 0 O0 N 106 564 1220 1846 2455 3063 3712 4385 5067 0.00 E 78 N 65.20 E 125 62 N 367.17 E 673 34 N 765.17 E 1440 67 N 1182.85 E 2193 59 N 1600.26 E 2931 40 N 1959.64 E 3636 11 N 2359.21 E 4398 53 N 2747.73 E 5175 91 N 3127.06 E 5955 0 O0 N 0 0 E 11 N 31 25 E 50 N 33 2 E 39 N 32 5 E 02 N 32 38 E O0 N 33 5 E 57 N 32 36 E 37 N 32 26 E 21 N 32 4 E 01 N 3t 41 E 10000.00 7021.67 6933.67 49 54 N 26 43 E 6718.66 10080.00 7073.20 6985.20 49 54 N 26 43 E 6779.55 0.00 5758.20 N 3465.48 E 6720.59 N 31 2 E 0.00 5812.86 N 3492.98 E 6781.61 N 31 0 E COMPUTATION DATE: 2-NOV-91 PAGE 5 ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 12-SEP-91 KELLY BUSHING ELEVATION: 88,00 FT ENGINEER: K. BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 88 O0 188 01 288 01 388 03 488 12 588 52 690 O0 793 05 897 84 0 O0 88 O0 188 O0 288 O0 388 O0 488 O0 588 O0 688 O0 788 O0 888 O0 -88.00 0 0 N 0 0 E 0,00 0 33 N 21 30 W 100 O0 0 37 200 O0 0 51 3OO O0 1 39 400 O0 3 15 500 O0 6 5a 600 O0 12 24 700 O0 15 21 800 O0 19 31 0,00 0,03 N 23 36 W 0,61 N 17 21 W 1.35 N 7 37 E 2,93 N 23 23 E 6,84 N 29 27 E 15,53 N 32 27 E 32,50 N 33 35 E 57,35 N 34 48 E 88.56 0 O0 0 O0 0 O0 051 1 31 321 441 4 32 301 4 70 0 O0 N 0 05 N 1 O0 N 2 15 N 4 12 N 7 98 N 15 73 N 30 22 N 51 06 N 76.85 N 0 O0 E 0 02 W 0 43 W 0 87 W 1 02 W 0 19 E 4 20 E 1304 E 26.57 E 44,19 E 0 O0 N 0 0 E 0 2 4 7 16 32 57 88 06 N 22 3 W 09 N 23 18 W 32 N 21 54 W 25 N 13 55 W 98 N 1 21 E 28 N 14 58 E 91 N 23 20 E 56 N 27 29 E 64 N 29 54 E 1004,96 9BB.O0 900,00 21 29 1112,30 1088,00 1000.00 21 27 1220,80 1188.00 1100,00 24 26 1332.40 1288,00 1200,00 28 23 1448,00 1388,00 1300,00 31 14 1565,70 1488,00 1400,00 32 44 1688,01 1588,00 1500,00 38 37 1822.22 1688,00 1600,00 44 13 1978,05 1788,00 1700.00 54 6 2146,09 1888,00 1800,00 52 3 N 35 18 E 126,91 N 35 30 E 165,85 N 35 55 E 207.85 N 35 57 E 257,23 N 36 13 E 315,07 N 35 53 E 377,03 N 32 42 E 447,26 N 30 4 E 536,66 N 29 56 E 655,69 N 30 23 E 790,63 0 82 1 24 2 77 3 98 091 2 44 8,39 5,30 0,58 1 ,50 108,26 N 66,26 E 126,93 N 31 28 E 140,06 N 88,82 E 165,85 N 32 23 E 174.18 N 113,45 E 207,87 N 33 5 E 214.26 N 142,44 E 257,29 N 33 37 E 261.04 N 176,66 E 315,20 N 34 5 E 311,28 N 213.13 E 377,25 N 34 24 E 368,88 N 253.44 E 447,56 N 34 29 E 445,80 N 299.09 E 536,83 N 33 51 E 549.21 N 358,28 E 655,74 N 33 7 E 665,76 N 426,46 E 790,64 N 32 39 E 2304.59 1988 O0 1900 O0 49 56 2458 69 2088 2610 68 2188 2759 57 2288 2914 93 2388 3073 48 2488 3228 63 2588 3381 45 2688 3532 67 2788 3684 09 2888 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 49 14 O0 48 23 O0 47 55 O0 51 7 O0 50 40 O0 49 22 O0 48 47 O0 48 39 O0 48 20 N 3O 32 E 913,51 N 31 30 E 1030 73 N 32 30 E 1145 N 33 10 E 1255 N 3O 25 E 1374 N 31 22 E 1497 N 32 31 E 1615 N 33 18 E 1731 N 34 7 E 1844 N 34 44 E 1958 18 47 29 28 90 44 85 49 0,87 0 64 1 19 1 59 0 69 0 86 0 48 071 0,30 1 ,00 771.92 N 488,51 E 913.51 N 32 20 E 872.39 N 548,96 E 1030.73 N 32 11 E 969,50 N 609,53 E 1145.19 N 32 9 E 1061,96 N 669,69 E 1255.48 N 32 14 E 1163.49 N 731,45 E 1374,31 N 32 9 E 1269,06 N 794.61 E 1497,31 N 32 3 E 1369.64 N 857.50 E 1615,93 N 32 3 E 1466.66 N 920,26 E 1731.47 N 32 6 E 1560.96 N 983.32 E 1844,86 N 32 13 E 1654,84 N 1047,47 E 1958,49 N 32 20 E 3833 63 2988 O0 2900 O0 47 56 3983 O0 3088 4133 59 3188 4282 12 3288 4428 41 3388 4575 18 3488 4725 10 3588 4874.78 3688 5020,82 3788 5163.44 3888 O0 3000 O0 3100 O0 3200. O0 3300. O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 48 2 O0 48 11 O0 47 19 O0 46 50 O0 47 39 O0 48 13 O0 47 35 O0 45 50 O0 45 59 N 35 17 E 2069,56 N 35 10 E 2180,36 N 34 48 E 2292.86 N 35 40 E 2402,56 N 36 10 E 2509,12 N 35 6 E 2616,33 N 33 50 E 2727,97 N 32 4 E 2839,34 N 32 4 E 2945.76 N 29 1 E 3047,38 0,38 1 ,55 1 .17 1 0.19 2.83 2.01 0.79 0.85 1 ,22 1745,90 N 1111.27 E 2069,56 N 32 29 E 1836.31 N 1175,58 E 2180,38 N 32 38 E 1928,86 N 1239,69 E 2292,89 N 32 44 E 2018 73 N 1302,82 E 2402,63 N 32 50 E 2105 03 N 1365.71 E 2509,24 N 32 58 E 2191 93 N 1428,85 E 2616,52 N 33 6 E 2284 17 N 1491.85 E 2728.19 N 33 9 E 2378 12 N 1551,65 E 2839,56 N 33 7 E 2468 27 N 1608,21 E 2945,96 N 33 5 E 2555 61 N 1660,23 E 3047,54 N 33 1 E ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPUTATION DATE: 2-NOV-91 PAGE 6 DATE OF SURVEY: 12-SEP-91 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: K. BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MIN 5306 12 3988.00 3900 O0 44 52 N 29 2 E 3148 95 5447 5588 5726 5866 6009 6157 6307 6460 6617 69 4088.00 4000 58 4188.00 4100 79 4288.00 4200 59 4388.00 4300 69 4488.00 4400 17 4588.00 4500 70 4688.00 4600 04 4788.00 4700 04 4888.00 4800 O0 45 44 N 30 19 E 3249 O0 43 22 N 30 48 E 3348 O0 43 47 N 30 40 E 3443 O0 45 11 N 32 13 E 3541 O0 46 41 N 32 6 E 3643 O0 47 35 N 31 7 E 3751 O0 48 51 N 3~ 47 E 3864 O0 49 26 N 31 12 E 3979 O0 50 57 N 32 18 E 4100 6776 35 4988.00 4900 O0 51 11 6935 7094 7254 7414 7573 7731 7890 8048 8207 72 5088.00 5000 32 5188.00 5100 12 5288.00 5200 53 5388 O0 5300 76 5488 O0 5400 90 5588 O0 5500 21 5688 O0 5600 73 5788 O0 5700 19 5888 O0 5800 O0 50 59 N 30 58 E 4348 O0 50 59 N 30 19 E 4471 O0 51 29 N 29 32 E 4596 O0 51 18 N 28 38 E 4721 O0 50 47 N 28 34 E 4844 O0 50 50 N 31 15 E 4967 O0 50 50. N 30 52 E 5089 O0 50 54 N 30 26 E 5212 O0 50 49 N 30 1 E 5335 04 21 59 24 60 99 48 39 40 8366.56 5988 O0 5900 O0 51 26 8527.82 6088 8689.40 6188 8849.98 6288 9009.70 6388 9168.25 6488 9325.45 6588 9481.77 6688 9637.75 6788 9792.74 6888 O0 6000 O0 6100 O0 6200 oo 6300 O0 6400 O0 6500 O0 6600 O0 670O O0 6800 O0 51 49 O0 51 44 O0 51 17 O0 51 10 oo 50,43 O0 50 23 O0 5O 7 O0 49 55 O0 49 51 N 31 37 E 4224 4; 48 53 05 27 86 29 98 93 75 N 29 43 E 5459 73 O8 79 O8 O3 39 97 37 29 89 N 29 23 E 5586 N 28 46 E 5712 N 27 2O E 5838 N 26 34 E 5962 N 26 23 E 6084 N 26 14 E 6204 N 25 52 E 6324 N 25 45 E 6443 N 25 48 E 6560 0 58 1 33 0 59 0 33 0 82 1 97 0 38 1 61 0 8O 2644.75 N 1709 33 E 3149 05 N 32 52 E 2731.80 N 1758 2817.29 N 1809 2899 25 N 1858 2982 69 N 1908 3069 37 N 1963 3161 60 N 202O 3257 36 N 2079 3355 51 N 2139 3458 05 N 2203 97 E 3249 34 E 3348 19 E 3443 96 E 3541 39 E 3643 35 E 3752 38 E 3864 19 E 3979 46 E 4100 11 N 32 47 E 26 N 32 43 E 62 N 32 39 E 26 N 32-37 E 62 N 32 36 E O0 N 32 35 E 49 N 32 33 E 39 N 32 3~ E N 32 30 E 0.55 O.35 3669 0.60 3775 0.68 3883 0.68 3992 2.56 4101 0.42 4207 0.40 4312 0.26 4418 0.41 4524 3563 24 N 2269. 15 E 4224 4'i N 32 29 E 27 N 2333.62 E 4348 16 N 2396.41 E 4471 16 N 2458.61 E 4596 73 N 2519.65 E 4721 88 N 2578.32 E 4844 18 N 2640.89 E 4967 31 N 2704.21 E 5090 12 N 2766.93 E 5213 30 N 2828.84 E 5335 48 N 32 27 E 53 N 32 24 E 05 N 32 20 E 29 N 32 15 E 91 N 32 9 E 36 N 32 7 E 06 N 32 5 E 03 N 32 3 E 88 N 32 1 E 0.54 0.15 4741 0.92 4852 O.69 4963 0 35 5074 0 74 5184 0 66 5293 0 33 5401 0 56 5509 0 87 N 2953.20 E 5586 74 N 3014.98 E 5713 57 N 3074.15 E 5838 67 N 3130.44 E 5962 87 N 3185.16 E 6085 69 N 3238.70 E 6205 68 N ,3291.39 E 6325 37 N 3343.64 E 6444 85 5616.12 N 3394.92 E 6562 4631 84 N 2890.76 E 5459 89 N 31 58 E 30 N 31 55 E 07 N 31 51 E 44 N 31 46 E 54 N 31 40 E 07 N 31 34 E 83 N 31 28 E 45 N 31 21 E 62 N 31 15 E 49 N 31 9 E 9947.72 6988.00 6900.00 49 54 N 26 43 E 6678.87 0.00 5722.48 N 3447.50 E 6680.72 N 31 4 E 10080.00 7073.20 6985.20 49 54 N 26 43 E 6779.55 0.00 5812.86 N 3492.98 E 6781.61 N 31 0 E COMPUTATION DATE: 2-NOV-91 PAGE 7 ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA MARKER BOTTOM 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD TOP 7" CASING TD DATE OF SURVEY: 12-SEP-91 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: K. BARNARD INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 666' FSL & 146' FWL, SEC17 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5550.00 9274.00 9390.00 9569.00 9752.00 9929.99 9977.00 10063.0O 10080.00 4160 12 6555 24 6629 26 6743 90 6861 70 6976 58 7006 86 7062 25 7073 20 4072.12 6467.24 6541.26 6655.90 6773.70 6888.58 6918.86 6974.25 6985.20 2794 36 N 5258 O9 N 5338 2~ N 5461 90 N 5588 08 r., 57t0 OC t~ 5742 ~8 N 580~ 24 N 5812 86 N 1795.73 E. 3221.21 E 3260.61 E 332O.66 E 338~.44 E 3441.56 E 3457.57 E 3487.14 E 3492.98 E ARCO ALASKA INC. 1R-20 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE; 2-NOV-91 PAGE 8 DATE OF SURVEY: 12-SEP-gl KELLY BUSHING ELEVATION: 88,00 FT ENGINEER: K. BARNARD ************ STRATIGRAPHI£ SUMMARY SURFACE LOCATION = 666' FSL & 146' FWL, SEC17 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9274.00 9390.00 9569.00 9752.00 9977.0O 10080.00 6555 24 6629 26 6743 90 6861 70 7006 86 7073 20 6467.24 6541.26 6655.90 6773.70 6918.86 6985.2O 5258 09 N 5338 24 N 5461 90 N 5588 08 N 5742 48 N 5812 86 N 3221.21 E 3260.61 E 3320.66 E 3381.44 E 3457.57 E 3492.98 E FZNAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10080.00 7073.20 6985.20 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6781.61 N 31 0 E RECEIVED FEB 2 7 1992 ,Alaska Oil & Gas Cons. Commission Anchorage DIRECTIONAL SURVEY COMP~ ARCO ALASKA INC. FIELD KUPARUK RIVER UNIT Wk'LL 1 R-20 COUNTRY U~A ONE DATE L~ 12 - SEP - 91 DF. PT. UNIT FEET h~ELL· 1R-20 (666' FSL,146' FWL,SEC 17,T12NR10E) HORIZONTAL PROJECTION 7000 IOO0 : : ; : : : : : : : : : : : : : : : : : : : : : : : : ; : : : : . : : : : : : . : : : : · --.' - -.:---.:-.-~ ..... ~--.'.'-..i-.-.: ...... i---h-~.--! ..... i---.~--.h--'.· ...... i---~---~-.-~ ...... :---:-.-:--.: ...... :---:---:---: ...... :-.-:-.-:.--: ...... :...:...:..4 ...... :_.:..,:...: ..... :...:...~...: .................... : : : : : : : ; : ; : : : : : ~ : : : : : : : : ...... · .-?-k.-h--i ..... h--~.-.h.-~ ...... i-.-.:---h--i ..... i-.-."---~-.~ ...... .:--.,:---h--! ..... i--.i-..i.-..; ...... ~---i---i---~ ...... i---!---~.--i ...... ~.--i.-.i...! ...... ~---~---i.-.i ...... h--i--.~-.-~ ....... i-..i-..i-.-~ ...... i..-~--.h--i ...... i---~--.i-- "'!'"!'":'"'! ..... ;'":""!'":' ...... F"F".""".' ..... !'"'.'"'~"'! ...... !'"!"':"!'" "'!"'?!'"! ...... !"':":"! ...... !'"!'"!'"! ..... i'-'!-'!'"!"' '"!"'!"'!'"! ..... !'"~'"!"'~ ....... ~'"~'"~"'~ ...... i---i...i--.i ...... · -i'-?-!-?'"!'"!'"!'"i ..... h'?i"i'".'-i'"i'"!-'! ..... i--i.-i--+-----i---i---!--!--~--i---~--i-i ...... i---h+--i ...... ~--i---~---! ....... i--i-.-!---i ...... i.-.~.--i..i ....... ..:.._:...:. ....... ;.........,:...:, ..... :...:,..?...: ............. :-':---! ............ i'--i ...... !-'i ...... i"i"i'-'~ ...... h'i"i---~ ...... .~.-+.-~...~.-- --i'-k'-i--'i-'q'--k'i-"!'-','-'i'-'!-'-iq ..... b-i---k'i ...... i-"!-q---i ..... i---i.--i---! ..... !--'i---i---b'.--i--.i---i---i ..... i.--!---b-i ...... "--i---i'-- ....... ':-..:--: · ";'-;'";"'; ..... :'"';'"y"? ...... :""!'",.'"'; ..... ;'"P"!"'~ ...... ~' ";"'F";'", "'!'"?:'"'y" :"?'.:'"F"! ..... i'"i-"i ...... '"i"':"-'i ...... , ............ i ......:--::---~-~---i.-.~---h. ...... i--.i..-~.--~ ...... :[::k:J:i": ::i:J::i::i:i :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :i:i:i'"i ....... i'"i'"i'"i ....... bi-..!--.i ...... ~:.-.i...i...i...i.-.i...i...i...!...i ..... i'"!'"!'-'i ...... i...i...i...i ...... i'-'i...i...i .... ::F:i:::: :::i:::!::::::: :---i:::!:::i:::: :::i:::i:::Fi::: ::!:::::i::: :::: :::i::::::: ::::: ::::::: ::::i:::::::i::: ::::i:::::::i::: :::!::? ~/~'"'"""~"' i i i i iii! i ! i i ! :,' · : : : ; : : ! ; ' : : : : ; : : : : : : : "';'"."'";'"~ ...... ??"." ...... ?": ..... :'": ...... :':": ...... ::'":"~ ...... ?'?"~ .......... ,'":"-, ...... ,"'."",'", .......... , ....... ~"-f':'~4-.i ..... i.-.~.-: ...... ?.i--.!.--t ....... ~-..~-.-~...~ :::i:::i:::i::: ::J:::i:::::: :::i::::::i::: ::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::i:::i::: :::i::: :::i:::i:::~!'~.:~ :::::::i:::;:: :::::i:::!::: ::::::::: :::: :::i:::i::? :i:? % :%:?? -:'?".""'! ..... ."'"r'?":' ...... i'"J'"'f-'."' ..... ?"."'"!~'i ...... !"?".""'! ...... !"'P"."'"~ ...... !'"i'"i'"i ...... h"-:'"!'"i ...... ~"'~'"!'"i ...... i---i-..i- . ..... i--.i--.i...i ..... i...h-i--.i ...... ~-.-i.-.h-.i ...... i....'-..-i,.-~ ...... i--~...i.-.i ...... i.-.!,-.h-4-., -:.: "!'-!'!'"! ..... !'"!'"!'"! ...... !'"!"!"'! ..... !"'!'"!! ...... !'"!'"f"'! ...... i'"!'"?"! ...... !"'!"'!'"! ...... !"!'"!'"! ...... !-.-!---!--.!.,'/:-..: ..... ~-.-:.--~-.;.>-~.-i--.~ ....... ¢-.-~...i...~ ...... :-..¢..-~ ...... :---~-..:..-~-.-:-.>-. ?'!'"!-! ...._.......____"M?!'"!'"!'"! ...... !'"!'"!"'! ..... !"'!'"!"': ...... ?"!"'!'": ...... ?'!'"!'"! ..... !'"!'"!'"! ...... !'":'"i'"! ...... ?i..:..!..-i...i..-!...!...:.-,,...:...:...!.! ...... !"':'-!'"! ...... ..i--!--.!...! ........ i-..}-..! ......... !-.i ....... i ........ i ......... i ............ i ...... i.-.i...:-..i.--i-..i...i ..... i...~...~...i .... ~i...~...i...i...L.i ...... i...i...i...i ...... i...i.-i...i ....... ,.,.i.-L. :-,..L.C..:...i...i...! ..... ~...~...~...i ..... [...i...i...] ...... !...i...i...! ..... i,..i..]...i ..... [,,.[...!..,~ ..... [...::.. :...[ ...... i..]...i...~ ...... [...i...!,..i ...... L..;...!,..i ...... :._L.:.: ..... i...i...i...i...._i...~...i...i .... }...i...i...i...:...i...~:..i ....... i---:---h-i .......~--j.-y_h-;---~.-: .... i.--L.i---i ...... i--.L-i.--; ...... : ......................... ......... ..... ....... ...... ':::::: :]::::i : :::::]: ::: i:: :::::!:::::':::::::: ::::~?:::i :::::':::::"::"?"! :'"! · -:i::i::: :~:::::::: :::!::i:::i::::::::L-.!:::::::::::i:::i:::!:::i---:::::::::i:::: ~'.': :::::::i:::i::: :::i:::J: :i::i::: ::: :::::: ::: i: ::: ::::::: :::: :::: i: :::' ::::i::;: ii:ii iii: ii:ii :'-:'!'"! .... !"T'i'"~ ...... F'!'"F'i ...... FT'T"~ ...... !"T'T"i ...... Fi'"!'".~T"FT"i ...... i"'i'"!'"i ...... :"!'"F-~ ...... f"T":"! ...... F':"f"'¢ ...... i"':-!"'! ...... i'"!'":'"! ..... i'"!'"!'"; ...... i'"! ~-h~-.H ..... i---h.H.-.,.-h.i.--;"-.i ...... i---i..-'~-.i ...... !---L-i---i ..... i..-i...L.-i...i.7... ..... i...i.4...i ...... ~...~...~...~ ...... i-..~..-~...~ ..... ~...i...~...~ ....... i...i...i.-.~ ...... i...;--~--.~ ...... ~...i...i...~ ..... ::~::t'::l:::i:: :::::::::::::::::::::::::::::::::::::::::::::::::::: :::!:::i:::!:::!::: :::i::':.~:i~::[:::!::: :::!:::[:::i:::!::: :::i:::i:::!:::!:: :::i:::i:::i:::i:::::::i:::i:::i:::i:: :::i:::!::i:::!::: ::!:::i:::!:::!:::! ::[:::::i: :::::: :::::::: ::i:: :: i::: :::i:: :::i:: '..i:: :::::::::::::::::::::::::::::::::::: ::i::i:::i:" :i::i::::::i ::i:?:i i: :--!ii :. i i:i .... i ..... -.:'...i ..... i...;...:z~.: .... ~ ...... ~...:...L...i...i...L.i ..... L.i...i...i ..... :...:...:._: ...... i...[...i...: ...... :...;...:...: ...... ::::::::::::::::::::::::: :¢?t~: ¢$%:: :::i:::i::i:::i::: ::%::i:::!:: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::i::i:::;:::i::: :::?i:::i::i::' -4.-.:..~-.~ '-F-f-i-~'- .4.q- :~q-, '-k-i-~-~ ...... i'--~'-'!-'-i ....... i--i-'-!'--! ...... i'-'.--'i'--i ....... !"-i'--!--i ....... i-i--i--i ...... i-'-i'.i---! ...... :--!'--k--. ..... i"-;'--!'-i ...... i"i--i---! ...... !...i..-r-.! ...... !--i.--!..-! ..... ~ ..... t · ; ........... ; ' ; ........................................ · -?-?;.,-,~ .................... ; ............... , .......................................................................... : .......................................................................................... ~:~: :::i::i:: ~:~i:: ::::::::::::::::::::::::::::::::::::i::i::i:::i::i:::i:::i:::i:::::::::::::::::::::::::::::::::::::::::::i:::i:::i:::i::i:::i:::i:::i:::i:: :::::::::::::::::::::::::::::::::::::::::i:::i:::i::ii.. ::::::::::::::::::::::::::::::::::::: "~-f .... ".."T'.'T"!:'" '--.',"f"'..'-'F .... F"F'FT"F-FT"!'"! ...... :"!"T"~ ..... !'"f"T"f ..... F'!"T"~ .... "..'"'!'"!'-~ ...... f"'f"'~'"~ ..... F'F'f'"f ..... :"!'-i'"~ ...... f'"!'"f'"~ ...... !"T"F'~ ..... :'f"T"f ..... · ~ELL' 1R-20 (666' FSL,146' FWL,SEC 17,T12N,R10E) VERTICAL PROJECTION ::::::: ::::---!..-i..-}--., ...... i.-.i.-.i .......... ?.i ......... !---i---~ .......... i-.~!.--i--.i ...... i-.-i...i.-~... ::!::!::i::!:~ ,..i...i...i ....... ::-.. :: :-.. ::!::....:.........,...~ ...... ,...~-.., .......... :.+.i ......... i...~...i..? ...... i...i...; ......... i...Li ....... '":"'"'":"'" ...... ""':'": ......... ""'"'"" ......... }'"}"'i'--: ...... i---h--~---.: ...... ~'"~'"~'-~ ..... ~.--i---'.- .......... :.-.:...:...: .......... L..~ ............. '....: .......... '-...:.-;..-: ...... : ....... :...: ..... L..!...:. ....... ---!--.i.--i.-.i ...... !--.i.--i..-i ...... !.--!-.-i .......... i-..~..-i ......... .~..+..~ .......... i-..i.-.i...i ....... i---i---i--i ..... ~...i...i .......... i...i...i .......... i..-i...i .......... ::...L.::...i .......... i .................. i...! .......... L.L.L.~ ...... i...L.: ......... L.!...i ....... -i"'?'!"i ..... !"'!"'i"i ...... !"i'"i'"-" ...... }"'}'"!"'~ ..... ~'i ...... !'"i'"i'"i ...... ~'"i'"i"~ ...... ~"'!"'i .......... ~'"~'"~ .......... ~-.-i.-! .............. ;...L.i .......... i...L.: .......... i...~ .......... i...i...hi ..... i...;...i .......... ~...L.~ ...... .... · . . ; . : ~ : . . : . : ..4...i...i...i ..... }...}...}...} ...... i..-i--i---..- ...... i-..i-.-i--i .... i.--i---i-.-J ..... i...i-..i...i ...... i-..i...;.~i ....... ~.-i...i ......... ~...i...; .............. ~...~ .............. ~...~...~ .......... L.;..~ .......... i...L.[ ..... L.::...L.: ...... L.::...~ .............. --'~"-i---i'-'i ..... !'-i'-i---! ...... i'-i--i---! ..... i-..hi.-i ..... ~.--~--.!-.-! ...... i---J---i---i ....... i.--i...~--i ...... ~-..~-..~ .............. i...i ............. i...i...~ .......... i...;...: ......... ~.J...i ........ L.i...i ..... !...L.!...i ...... L.i...: .............. L.i...L. ............................................................... ~'"~'-': .......... ~'"~ .......... ~'"i'"i-"i'-', ...... .... ~-.-).--~--:: ...... ~--~---~-.-~ ...... ~---i.--i.--i ...... i--.i---!---i ...... i.--i---hl .......... ~.l.i...i ......... i---i--i .......... ~.--~-.-~ ........ i...i....~ ..... :...i...i...i ...... i..-i...i...i ...... ~..i_.i.l.i ...... ~...i.l.i...! .......... i...i...i ......... i...i.] ...... ........................................................ ii ....... ~'"~'"~' ..... )'"~'"~'"~'" iiiii:i!iiii~]ii~]'''~'''L'~'''~ .......... ~"'~'"~ .......... ~'"~'": ..... · .-~.-?--?---! ......... i--i-,-i .......... ?-.?~ .......... ?~ ..... ~-~ ......... !"i'"! ..... i,+-i--! ......... !-?--? ...... ?...! ...... ~--.i--i--! .......... i.--!---~ ...... !...!.l.i..l~ ......... ?..!.-,i ...... :'"il''i'''! ....... ~---i.-,!,-,i ......... hi :;:i:~::i:: --.:-.-!---hi---, ~-.~--~----,---, .......... ~.-,..-~... '?.. i.-)- : :::i::: ::: ::: :::, .-.~---~--.?-.:---, : ::: ::: :: ::: -..i--i-.-!--.i .......... !.-!...i... ::":::i:::i:::i::: :::!:::i:::!:::i::: ::::::::::::::::::::::::::::::::::::: .... ?'?"~ .......... i.-?-~ ...... ;..-!.--?!: ..... ;--.i.--i-..! ......... i.--i--+.--:ii-..i.--!-.-! .......... h¢-..;.- · ..i-.i..;...j ..... ~...L.L.L., · ....... i...i...i ...... ..... ......... .......... i...i...i ......... ...... ....... ...... ...... ......... .......... · . . ' ...... i'-i---! ..... ..'"'!"i'-i" ,-.-:---i-.-:.--i ......... i.-.i-..i .......... i..+..! ......... !--i...i ...... ......:...~...~...I...i...L..L..~ ...... i._!...L..~ .......... :...L..~ .......... L..i...i .......... L..:...~... ....... i"'i"'i ........ i'"i"i .......... i'"i"i ......... i"i"i ........ ~"';"'~ ...... .:--+--~---~ ....... :----i---i-i .......... L.i...~ .......... i--.i.-.i ......... 1-4-.-i ...... !...i...i...i ....... !...i...i...; ...... LJ...L..~ ...... i...L..L.'; .......... ;...i...:, .......... i...i...i... "?"?-¢ .... !"i'"?! ......... 7! .......... i'"!'"i ......... ;" '~'--~ ...... i.--i---i.--! ........ f...i.-i ........ i---i..-¢ .......... i'"i'"¢ ..... ¢.--i--i-..! ....... i'";'"i"'! ...... !-.-i--.i-.-i ...... !...i...i--.; ...... i...i...~...i .......... i-..i...i ......... i.-.i...i... ,,. ~ ~'~ ...... · : ~ · , . .... . , . . : . . · : .--i.--i---i---i ...... !---!---!.-.! ...... ~-..i-..i.--; ...... ,...i...i..-i ..... ?!--.i.-.i ....... ~...i...i.--i .......... :...i.-~ ......... ¢..-i...i ...... -..i..-i...i ..... i...;.-i...; ....... i--.i-.-i.-.i ...... ;...;...i...', .......... :...L.; .......... ~...~ .............. :...i...;, ......... ;...~...L. "'-.:"i"i'--~ ...... i"i'--!'-i ...... i'"i'"i'--i ....... ~...;...i.-.; ..... i'-i-'i"i .......... i'-'i-"i ......... i'--i'-i .......... '.....~...i ......... i...;...i ...... i...;.-;...i ....... !"i"i"i ...... i...;...;...; .......... ~.--;.-.i .......... ;...i...; .......... :,...;..4 ........ ;...:...L. :"+".~"'~ .......... ~"+".~ ...... i'"i--i'-i ....... ~...~-.4...~.. ~...i.-.~-.:-..~ .......... .:.-+...: ......... ~...:..-~ ......... i...~-..i ......... ~...~...i ...... ~...~.~..-~ .......................... L..L..~...~ .......... :...i...~ .......... i...;...; ......... ~...~...~ ...... L..i...i...:;.. 1; ..... ¢"'i"-¢ ......... i"'i"'¢ ...... '"'i'"!"'i ...... ~" ';'''~' ''; .... ~--.~-.-~--.; .......... !.-.i...i ......... i'"!'-i ........ ~"'""~'" . · ...... ~...i_.~ ......... i...i...! ......... !...i...i .......... .:...~...~ ......... ~....: ............. ~...~...~ .......... !...!._i .......... ~...~...~ ...... ~...!...i...; .......... ;...i...i .......... ~...~...; ...... ~...~...L.~ .......... ~....i...~ ......... i..L..; ..... !...Li...i .......... ;...!...i.. · --....i...!--.i ........ i-.-i.--i .......... i.-.i..-i .......... ;...;...i ......... i...i...i .......... i...i...i ...... i...i...i.-; ...... i-i...i...i ...... L.L.i...i .......... !._:...: .......... L.:...~ ...... L.:...:.,.'. .......... ',...L.: .......... !...L.~ ......... i...:...: .......... :...:....;... '"i"i"!'-i ..... !:'i"i"'i ...... .-'"i"i"'i ........ i...i...i ........ i...~...; ..... .:-.-i...i--.i ...... i-..i-..i.-i ....... i...i...!...i ...... .:...i...i...i .......... i.~i..] .......... !...i...i ..... ;...~...i...;, ........ ;...i...i ......... !..]...:, ...... i...L..i...:, ......... i..]...i... .... !'"i'"!'"! ..... !"'!'"!"'i ...... ?'? ...... !.--i...i---i ........ ~-.-'-.-' ...... '---'---'---~... - :~m ~( .... i...!...!.-! ...... ~...;...!...; .......... L.i-..i ......... ,i.-.i...i ......... i--.i...i ..... ;...;.-.i...; ....... ...i...;...i .......... i...;...i ...... !...i...L.', .......... i...¢...;... ..4...i..4...i ...... i...i..4...i ...... i..4...i..~ ..... i...i..i...! .... :...i...i...i ...... ~...~...i...i .... ~...i...i._i... ~: i ;'~ i;i ':~ ;:ii · ~, .,;i i . ....... .~-..-....- .......... ,...~...: .......... .. ...... , .......... i...L..~ ...... ~...~..+..~ ......... ;...!...i ...... i...i...L..~ .......... i...i ............. ~...;...L. --.--~--4--.! ..... ,.-.i..-i..-i ...... i.-.~..i...~- ..... i---:-..'.-...' ..... i..-~.-.i...i ....... :.---i...¢...i ......... i---i.-i .......... L..i...~ .......... i...!...i ......... i...i...! ...... !...i...!...~ ....... i...!...:...; ...... i...;...i...i ...... i...i...i .............. i...i...; ..... ~ ....... L.i... · .-.'...!...!...! ......... ~..4-.~ ...... ~..-..'...;...~ ....... i---;.-!..-i ..... i.-.i---!---! .......... ;-.-~---~ ......... i.--i.-! .......... i...i...i ......... ;...i...i ..... i...;.-i...i ....... hi...;..-i ...... ;...i...;...; ...... L.;...i...i .......... ':...L.~ .......... L.~...; ..... ....... .... ....................... ' ..... :::i::?:;:i::: , , ...... , , , .............. .......... .......... ...... " ................ hi...i ......... i...::...i ......... ....... i"i"i ......... ?'..'~--~ .......... i...~--.i .......... i.-J-.-i ......... ~...i...~ .......... i---':....! ............ : ....................................... i ..... L..L_i...~ .......... L..~...~ ...... L.:...~..: ......... ~...:...~ .......... ;...~...: ......... !...:....:: .......... !...i...::.. AOGCC GEOLOGICAL .MATEP. IALS INVENTORY LIST COMPLETION DATE ! I ~ I '~"L-CO. CONTACT & NO. A for~'J ,r recei,~ed .... I r~c~iYed da~e--I comme'nts ~03 yes no sund~ application 404 yes no repod of ~Undw application ,J ~ ~ , ,,, , · h°le Io.o hole Io.o I MUD GCT / TEMP "DIL~sFL " CNL PnOD DLL ' ' 'CBT / .... /.../ PRESS BHCISL CET ~'itc/Ai~'' 'EPT OTHER DATA I_SS 'PEFI_F ' Survey FIEC sss -J~AcKER .............. Di~lital FDc- Well CNL Te~t.~ h FDC R'~,'D requi-r~j-' received SAMPLES reqUi[e~' ~cccivcd MWD .,. ~ CYBER core LOOK , An.a.!¥si.s .. ..... RFT NG _ ..... , , , ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return o. ne signed copy of this transmittal. 2M-10 2M-10 3Q-04 3Q-04 Litho-Density & Casing Neutron Porosity Data Litho-Density & Casing Neutron Raw Data CCtq ,./ 1-12-16-92 CDR ,., 1-12-16-92 1 1-29-91 & 12-29-91 I 1-29-91 & 12-29-91 Please acknowledge receipt 7000'7756,~ ~ 7000-7669 7000-7756 7000-7669 4517.7-7720 4517.7-7720 i3Q_03 ~ ,..2 1-24-27-92 5090-9640 3Q-03 CCR ¢ 1-24-27-92 5090-9640 THE FOLLOWING LOGS ARE CORRECTED COPIES, IT HAS BEEN REQUESTED THAT YOU THROW OUT THE PREVIOUS (UNCORREC~ COPY OF THIS LOG. ~ ~HANK Y~U. ~ ~ 5-9'i3:91 -. . 5237-10476 ~ ~ .... 5225-10065 )' 1 L- 2 6 (¢q-~ ~ 6-3-6-91 2M-1 9~ 2M-21~ ~ 11-17-'91 3835-9250 '-- / , 1 1-1 1-91 3914-10599 1R-17~, ~ 9-15-19-91 5698-10345 1R_19J/ ~ 6-19-23-91 · 5390-9841 __ - 1R-20J ~ 9-9-91 5568-10080 1R-21~ ~ 10-6-11-91 5070-10180 ~t".~Ol R-22 ~ ~ 9--24-29-91 6001-10813 ff{~'~[1R-23 ~/ ~ 10-22-91 6330-12188 1R-24~ ~ ~ 7-30/8-5-91 6753-12972 .?~1R-26 ' ~ ~ 7-18-21-91 5591-10218 ~1~1R-27~ ~ / 8-31 -91 6547-9250 8-14-91 1R-29 ~ ~// 6042-11368 1L-24 / ~ ~ 5-1 9-22-91 5081-9241 1L-25 ~ ~ ¢ 5-26-29-91 4978 9352 ~ FEB 1 1 199 . Alaska 0il & Gas 6~ns. ~mmission Anchorage ARCO Alaska, Inc. Date: November 22, 1991 Transmittal Ct: 8290 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items, Please· acknowledge receipt and return one signed~py of this transmittal. ¢/"/°"~' 1R-27 ,~ LISTapeand Listing -'~,5"/''~','~ 8-31-91 74904 ¢/"'? ¢ I R-29 -'" / LIS Tape and I_isting~,5-/~ ? 8 - 1 4 - 91 74854 ¢/"/°~ 1R-20.'// LIS Tape and Listing .~5-/~-~ .... 9-9-91 74922 ,e/.-?/p/ 1 R- 1 7 */'/ LIS Tape and Listing .W' j-/..~d' ' 9- 1 9- 9 1 7 4 9 3 4 ?/_/~, 1R-23~/' LIS Tape and Listing j~j--/~J'--:!~--: 10-22-91--:-'-:75103 Receipt Acknowledged: ..~.- ~ DISTRIBUTION: RECEIVED Lynn Goettinger State of A~laska ¢ N0V 2 7 1991 Alaska 0ii & Gas Cons. Commission · ~-~i-~' Anchorage ARCO Alaska, Inc. Date: September 20, 1991 Transmittal #: 8227 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. O%1 R-27 O~' 1 R-27 /¢C1 B-03 03 .~.- 3~ 14 ~,,,...,~\'1. //2 ~06 1 2o q~.~O~ (11R-20 B-03 ~1~¢1B'03 Receipt Drilling Cement Bond Log Cement Evaluation Log ,/Cement Bond Log ,,,Cement Evaluation Log .~,lavPac Log ~lavPac Log /Gamma Collar Log ,-Cement Evaluation Log Cement Bond bog 9-8-91 10382-12250 9-8-91 10382-12250 9-1 I-91 6705-7558 9-1 1-91 6705-7550 8-26-91 6400-6700 7-20-91 7810-8000 7-20-91 7810-8000 9-1 2-91 8678-9968 9-12-91 8678-9968 6705-7556 6705-7558 .,.Cement Bond Log -b D/- ~- ~ 1,...4,:,91 ,-Cement Evaluation LOg.,, I~ E I~. ~ J ~/: ~ 1. Acknowledge: .~--~f~te''~ ' " S :9 1 D · ,~/~/' Alaska"O~. Ga.s Cons. Cgnlmission · <" State of ARCO Alaska, Inc. Date: September 20, 1991 Transmittal #: 8231 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. . CDR 9-9-91 5568-10080' ~ 9-9-91 5568-10080 CDN (Replacement) ~, 4-7-9-91 4 5 6 5~,8,7.0,j3r., ~ ~ ~.. r~ Receipt Acknowledged: ~__~~,~~ate. Anchorage DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 =, August 28, 1991 A W McBride Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well No. Kuparuk River Unit 1R-20 Revised Company ARCO Alaska Inc Permit No 91-108 Surf Loc 666'FSL, 146'FWL, Sec 17, T12N, R10E, UM Btmhole Loc 1089'FSL, 1513'FEL, Sec 08, T12N, R10E, UM Dear Mr McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated August 1, 1991 are in effect for this revision. Sincerely, Russell A Douglass Commissioner BY ORDER OF THE COMMISSION jo/encl c' Dept of Fish & Game, Habitat Section, w/o encl Dept of Environmental conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of Work Drill X Redrill D I lb. Type of Well Exploratory D Stratigraphic Test D Development Oil X Re-Entry m-1 Deepen DI Service D Development Gas r'l single Zone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 88', Pad 45' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628, ALK 2561 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 666' FSL, 146' FWL, Sec. 17, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 550' FSL, 1855' FEL, Sec. 8, T12N, R10E, UM 1R-20 #UG30610 At total depth 9. Approximate spud date Amount 1089' FSL, 1513' FEL, Sec. 8, T12N, R10E, UM 8/28/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1R-19 10,056 MD 1089' @ TD feet 30' @ Surface feet 2437 7,053' 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 49° Maximum surface 2438 psig At total depth (TVD) 3570 psig 18, Casing program Setting Depth size Specifications Top Bottom Quantit)/ of cement Hole Casin~l Weicjht Grade Couplin0 Len~lth IVD TVD IVl] TVD (include stacje data) 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' +_200 CF 12.25" 9.625" 36.0# J-55 BTC 5495' 43' 43' 5,538' 4,118' 1110 Sx Permafrost E & HF-ERW 520 Sx Class G 8.5" 7" 26.0# J-55 BTC 10013 43' 43' 10,056 7,053' 235Sx ClassG HF-ERW Top 500' above 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 ,~u°~dacU~t°rRECEIVED Intermediate Production AU G 2:3 t99t Liner Perforation depth: measuredAlaska 0il & Gas Cons. C0mm'tssten true verticalAnchorage 20. Attachments Filing fee D Property plat D BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [-~ Refraction analysis r'l Seabed report r'l 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~'~'~//~ ~'~ - Commission Title Use OnlyArea Drilling) En0ineer Date ~/~'~'/~'/ Permit Number I APl number~_... I ^p,~o~, ,~,e I See cover letter for ~C~,/_/~"~ 50- ~.~ '~-~.~-<~---~::)p ~'-/'-~'/ ~r requirements Conditions of approval Samples required [~] Yes ~ No Mud log required D Yes No Hydrogen sulfide measures D Yes ~ No Directional survey required ~ Yes r'~ No 15M~ Required working pressure for BOPE 2M ~ 3M F.~ 5M ~] 10M Other: Approved by Commissioner the commission Date 7 "~'- ~ ! Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. ~ , Post Office Box 1003&0 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 22, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Well 1R-20 API 50-029-22207 Permit Number 91-108 Gentlemen: ARCO requests approval of revised application for permit to drill Kuparuk River Unit well 1R-20 due to a bottom hole location change. The original permit to drill was approved on 8/1/91. Drilling operations have not yet started. If you have any questions, please contact Ellen Fitzpatrick at 263-4638. Sincerely yours, Area Drilling Engineer RECEIVED AU G ~ 3 t991 Alas_~a 0il & Gas Cons. Comr{l'tssleIt "L~horage STATE OF N_ASKA ~ _3KA OIL AND GAS CONSERVATION ~~ION PERMIT TO DRILL 2O AAC 25.O05 la. Type of Work Drill J~ Redrill [~1 lb. Type of Well Exploratory [~] Stratigraphio Test [] Development Oil [] Re-Entry [~] Deepen r~I Service E~] Development ~ Name of ~rator 5. Da~m Elevati~ (DF ~ KB) 10. Reid and P~I ARCO Alaska~ Inc. RKB 88'~ Pad 45' GL feet Kuparuk River Field 3, Address 6. Pro~r~ ~signation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628, ALK 2561 4. Lo~tion of well at surfa~ 7. Unit or ~o~r~ Name 11. Ty~ Bond (~e 20 AAC ~.~5) 666' FSL, 146' FWL, Sec. 17, T12N, R10E, UM Kuparuk River Unit Statewide At mp of ~od~ve interval (~ TARGET ) 8, Well numar Number 1115' FSL, 1~0' FEL, Sec. 8, T12N, R10E, UM 1R-20 ~UG30610 At total depth 9. A~roximate s~d date Amount 1684' FSL, 1073' FEL, Sec. 8, T12N, R10E, UM 9/30/91 $200,000 12. Distance to nearest 13. ~st~ce to ~arest w~l 14. Num~ of a~es in ~o~ 15. Pro~sed depth (MD ~d ~D) property line 1R-19 10,591' MD 1073' ~ TD ~eet 30' ~ Sudace feet 2560 6,987' TVD feet 16. To ~ ~m~et~ for deviated wells 17. Antici~t~ ~essure (s~ ~ ~C 25.035(e)(2)) Kickoff depth 400 feet Maximum hole angle 53° Maximum =ud~, 2438 pslg At tot~ depth (~D) 3555 pstg 18. Casing ~ram SeEin~ Depth size Specifications Top Bottom Quanti~ of cement Hole Casing Weight Grade Coupling Length ~ ~D ~ ~D (include sta~e data) 24" 16" 62.5~ H-40 Weld 80' 43' 43' 123' 123' ~200 CF 12.25" 9.625" 36.0~ J-55 BTC 5773' 43' 43' 5,816' 4,118' 1200 Sx Permafrost E & HF~ 550 Sx Class G 8.5" 7" 26.0~ J-55 BTC 10548 43' 43' 10,591' 6,987' 240SxClassG HF~ Top 500' above Kuparuk 19. To ~ complet~ for Red~ll, Re.ent~, and ~n O~rations. Present well condition summa~ Total depth: measured feet Plugs (measure) true vertical feet Effective depth: measured feet ~unk (measure) true vertical feet Casing Length Size Cemented Measured dep~ True Ve~ical depth s,.uc,..a, RECEIVED Conductor ~-:~ ~' /-- ~- ~ - '~ ~'~ Intermediate ..o.uc,,o. '~ :' ~' '~ '~'":~' AUG 2 3 199~ Liner .~ ...... ~_..~ ,~ :~ :'.::~; ..... .. 0il & Bas Cons. C0ramissie' true vertical ~"::~" .... 20. Atta~ment= Filing fee ~ Pro~r~ plat ~ BOP Sketch Drilling fluid program ~ ~me vs depm ~ot ~ Refraction analysis 21, I here~ cera~ ~at the forgoing is true and ~rr~t to the ~st of my knowl~ge Signed ~~~~ Title Area Drillin~ Engineer ~ - commissi~ use Onl~ Pe~i~ Numar I API numar i A~roval/d~e I See cover leEer for - ~ ~' 50-~~-- ~ ~ ~ ~ ~/~/~[ ~ther. requirements Other: v~~~~ ~ by order of A~ro Commissioner the commission Date ~. -- . .~ . .. Form 10-401 Sub in triplica~.e DRILLING FLUID PROGRAM (1R-20) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2438 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1R-20 is 1 R-19. As designed, the minimum distance between the two wells would be 30' @ Surface. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. RECEIVED AU G ~ ) t99t Alaska 0il & Gas Cons. Anchorage ARC0 ALASKA, Structure' Pad 1R , Well · 20 Field · Kuporuk River Unit Location · North Slope, Alaska Created by : jones For: E FITZPATRICK Date plotted : 22-Aug-91 IPIot Reference is 20 Version t4. ]Coordinates are in feet reference spot 120. JTrue Vertical Depths are reference wellhead. | I~J~EASTMAN ] !Z/fl/IUCH RISTENSEN ! & Boke.r Hugh# compriI N .52 DEC; 25 MINE 6117' (TO TARC;ET) 0 04 - · '400 - _ O 800 - - 1200- _ -t-- 2O0O- _ 2400- _ 3200- - 3600- 4000- ~ 4400- _ 4800- I I 5200- V - 560~- RKB ELEVATION: 88' TARGET TVD=6507 TMD=9215 OEP=6117 NORTH 5164 FAST 5279 TARGET LOCATION: 550' FSL, 1855' FEL SEC. 8, T12N, R1OE East ==> 0 400 800 1200 1 BDO2000 2400 2800 3200 3600 4000 I I II II II I I II II II II II I 6000 _ I TD LOCATION: I -5s00 lO89, FSL, 1515' F'EL _ SEC. 8, T12N~ RIOE _ _ -4400 _ I I KOP TVD=400 TMD=400 DEP=O - . 6.00 -2800 Z ~ 12.00 - t'~ % 18.00 BU,LD $ OEO / 100' -240'0 ====~ ~,~ 24.00 - ~ ~ 30.00 -20~ ~ ~ 36.00 _ ~ 42.00 B/ PERM~ROST WD=1668 ~D=1787 DEP=~2 -~6~ 00 EOC ~=~852 TMD=2050 DEP=669 T/ UGN~NDS ~ ~ WB~5 TMB=3467 ~P=17~7 ~ - ~ WD~D=~491 DEP=2525 ~ /666' FSL, 146' ~L J ~ JSEC. 17, T12N, RiOEJ - ~ ~ ~=52~ DE~50~ ~ AU G 2 3 t991 ~~ Alaska .0ii &,Gas Cons. 6ommisSien chorage AVERAGE ANOLE ~-5 ~=6058 ~D=8495 D B/ KUP SNDS ~=6925 TMD=9856 DEP=660~ ~ TO / LOOOING PT TVD=7053 TMD=10056 DEP=6756 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0 400 800 1200 1 E¢30 20~302400 2800 5200 3600 4000 4400 4800 5200 5600 6000 6400 8800 $cole 1 ' 200.00 Verfical Secfion on 32.41 azimuth w[fh reference 0.00 N, 0.00 E from slot #20 3OO 250 200 ~50 lO0 5O 5O lO0 ,mm. m m m mm m m . m 5O I i ARCO P.d ALASKA, 1R, W. II 800 / / 6O0 / / 400/' soo / ! .~ / 400 5O m No' 20 100 ! 1200 1000 / / t / "1000 / / / / / / 1200 O0 3000 / / / / / 3400 150 i / / / I / / / i ~4oo 200 250 , . - ~,.m, 3600 800 RECEIVED 28OO 1600 ......... AUG 2 ~ 1991 j Alas_ka Oil & Gas Cons. Commisslen ~.Anchorage -J i 100 I 150 i I 200 250 _:300 250 200 150 100 5O 5O 100 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-20 I . . . . . . , . . 10. 11, 12. 13. 14. 15. 16. 17. Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,538') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (10,056) according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED AUG 2 3 t99l Alaska Oil & Gas Cons. ¢ommissien Anchorage 7 6 5 4 I3 13 5/8" 5000 Fol BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL wI'rH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 30(X) PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5(X)O PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED AUG 2 3 1991 OJJ & Gas Cons, Oommissien Anchorage ~-~,~UPARUK RIVER UN~' 20" DIVERTER SCHEMATIC I I 6 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 5 4 5 5 MAINTENANCE & OPERATION 3 2 , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2,000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. . RECEIVED g!~_~'Oil .& Gas Cons. Commission ~Anchorago 10" HCR GATE VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 20" - 2000 PSI ANNULAR PREVENTER MLP 8/14/91 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 1, 1991 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 1R-20 ARCO Alaska, Inc. Permit No. 91-108 Sur. Loc. 666'FSL, 146'FWL, Sec. 17, T12N, R10E, UM Btmhole Loc. 1684'FSL, 1073'FEL, Sec. 8, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Alaska Oil Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental-Conservation w/o encl. ' STATE OF ALASKA AI..~KA OIL AND C-.-.-.-.-.-.-.-.~ CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of Work Drill ,~ Redrill I-I I lb. Type of Well Exploratory E] Stratigraphic Test E] Development Oil [] Re-Entry [] Deepen E]I Service E] Development Gas [] Single Zone [] Multiple Zone r~ ?_. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 88', Pad 45' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628, ALK 2561 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) 666' FSL, 146' FWL, Sec. 17, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1115' FSL, 1440' FEL, Sec. 8, T12N, R10E, UM 1R-20 #UG30610 At total depth 9. Approximate spud date Amount 1684' FSL, 1073' FEL, Sec. 8, T12N, R10E, UM 9/30/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1R-19 10,591' MD 1073' ~ TD feet 30' ~ Surface feet 2560 6,987' 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 53° Maximum surface 2438 psig At total depth (TVD) 3555 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of cement Hole Casin~ Weight Grade Coupling Length M3 TVD IVD 'IVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' _+200 CF 12.25" 9.625" 36.0# J-55 BTC 5773' 43' 43' 5,816' 4,118' 1200 Sx Permafrost E & HF-ERW 550 Sx Class G 8.5" 7" 26.0# J-55 BTC 10548 43' 43' 10,591' 6,987' 240SxClassG HF-ERW Top 500' above 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 ~ ~ ~-~G.e~.?t~t~.. ~ ~ ~ Measured depth True Vertical depth Structural~. ~ ~ ~ I~ ~,~., ~ ~ Conductor ~=' ~ ~ ~ ~ Surface Intermediate -, · ', ..~ ~.,~ ~. Production ~t, !.~ L- ? '~ Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat ~ BOP Sketch [~ Diverter Sketch [] Drilling program [] Drilling fluid program ~ Time vs depth plot D Refraction analysis D Seabed report [~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~/~ Title Area Drillin~l En~lineer Date ~)/~.~j/~ / // ~ ' Commission Use Only ' Permit Number IAPInumber ~ IApproval~d~e/Ieee cover letter for <~',/-- ,/'~) ~ 50- O ~ ~:~ - ~--- ~- 2_ ~ t~./~/f~j' other requirements Conditions of approval Samples required ~ Yes No Mud log required ~ Yes /]~' No Hydrogen sulfide measures ~ Yes ~' No Directional survey required ~ Yes ~ No R quirea wor,i.g pressure aOP I-I 2M E] SM E] 10M I-I Other: by order of Appro commissioner the commission Date Form 10-401 Rev. 7-24-,8g ~, Submit '~n triplicate DRILLING FLUID PROGRAM (1R-20) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.6-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System' Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2438 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1 R-20 is 1 R-19. As designed, the minimum distance between the two wells would be 30' @ Surface. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or Kuparuk Field well with open annulus used for disposal. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. AI CO ALASKA, ][ne. Sfrucfure · Pod 1R Well · 20 : Field · Kuporuk River UnH Locofion ' Nodh Slope, Alosko Creoted by : rickb For: E FITZPATRICK Date plotted : 15-Jul-91 Plot Reference is 20 Version 15. Coordinates ore in feet reference slot ~20. True Verticol Depths are reference wellhead ~J~ E A S T M A N ~/211IC H RISTEN SEN A e~lk~r Hughls com]~3ny 0 Cq - · 400 ~ Q) ~ coo- _ 1200- - 1600- - ~ 2000- (19 - 2400- _ '-~ 2800- © - ~ 3200- _ 3800- _ I~ 4000- -'5 - - I 4800- I - V 5200- RK8 ELEVATION: 88' .%00 KOP TVD=400 TMD=400 DEP=O 9.00 5.00 BUILD 5 DEG/IO0' 1.00 .00 .00 9.00 OOB/ PERMAFROST ]%'0=1668 TMD=1787 0EP=482 · 1.00 EOC '[VD-1927 TMD-2169 DEP-762 Easf --> 600 0 600 1200 1800 2400 3000 3600 4200 I I I II II II II II II II T/ W SAK SNDSTVD=3438 TMD=4684 DEP=2775 TARGET LOCATION: 1115' FSL, 1440' FEL SEC. 8, T12N, RIOE TARGET TVD=6478 TMD=9743 DEP=6817 NORTH .5729 EAST 3694 TD LOCATION: I 1684' FSL, 107.3' FEL SEC. 8, T12N. RIOE T/ UGNU SNDS TV0=2775 TMD=5577 DEP=1888 K-5 '[V0=6058 TMD=9011 DEP=6251 8/ W SAK SNDS ]VI)=5918 TMD=5485 DEP=$411 9 5/8" CASING PT '[VD=4118 TMD=5816 DEP=5677 K-lO TV0=4253 TMD=6007 DEP=5830 AVERAGE ANGLE 55 DEG 4 MIN N .32 DEG 49 MINE 6595' (TO TARGET) SURFACE LOCATION: 666' FSL, 14-6' FWL SEC. 17, T12N, RIOE -6600 -1800 ~' - -120(:1 o. 0 o 8OO o TARGET 'rVD=6478 TMD=9743 DEP=6817 T/ ZONE C TV0=6576 TMD=9906 DEP=6947 Td/ZK%NpEA '1VD=6756 TMD=10206 DEP=7186 SNDS 3V0=6867 T.D=10391 DEP=7334 TD/ LOGGING PT 1~D=6987 TMD=10591 DEP=7494 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0 400 800 1200 1600 20(20 2400 2800 3200 3600 40(:10 4400 4800 5200 56~0 6000 6400 6800 7200 7600 Scole 1 ' 200.00 Vertical Section on 32.81 dzimufh wifh reference 0.00 N, 0.00 E from slot #20 700. 650 600. 550 500. 450 400. 350 . 100 I i I I 1 50 200 250 :300 350 400 450 500 550 600 -='"' //i / "I 300 oo , .z'- .~-~ 0 ! ~ 3300 .Bo~' -~o ,~oo - I F too ~/ 90 3100 ~ q~' ~ 650 ~ ~~ ..... ~ .... ~:} 600 .- .-r~oo / " I ' · 3oo I I I I I I I I I I 350 300 150 200 250 300 350 400 450 500 550 600 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-20 . , o . , ! . , , 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,816') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform'leak off test to 12.5 ppg EMW. Ddll 8-1/2" hole logging while drilling to total depth (10,591') according to directional plan. Run .and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. _ Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. . Shut in and secure well. Clean location and release rig. 7 , 6 5 4 I3 13 5/8" 5000 I, l BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLYAND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TESTANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BO'I-I'OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR ,~_.JPARUK RIVER UNI~-~ 20" DIVERTER SCHEMATIC I I 6 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 5 HCR 4 5 HCR MAINTENANCE ~, OPERATION 3 ! . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR ~'~!.~: 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 1(7' OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE [2 thru $] (3) Admin' [~'92%hru ¢/2~3'/~'i'13 ] [10 & 13] (4) Casg ~.,~.~¢~ ~-~7-e/ [14 thru 22] [23 thru 28] (6) Other X~¢ r~ [ 29 th . 10. 11. 12. 13. 14. 15. Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool ............................... ~ 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. /¢ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ........... / ~ Is a ¢onserYation order needed ....................................... Is administrative a~rova~ ~eeded .................................... Is ~ease ~er a~ro~riate .......................................... Does well have a unique name & nLrnber ................................ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Is conductor string provided ......................................... Will_.,~rface casing protect all zones reasonably expected to serve-as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ //~ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Lease g Well ~/¢~_ 2~/~.~' / YES NO Is a diverter system required ........................................ ~ Is drilling fluid program schematic & list of equipment adequate ..... /,¢~- Are necessary diagrams & descriptions of diverter & BOPE attached .... /~ , , , Does BOPE have sufficient pressure rating -- test to ~o~ psig ..... ~(_ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... · , , Additional requirements ............................................. REMARKS ,/ ~.// / ' , ' / .,/ O -4 2EZ ~O geology.? eng i neer i ng.; ~ DWd~/ MT~ LCS~ ....... RP~ BEW ~ P-,AD~'~ rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE , , Additional remarks' ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE D~ATE/ [2 thru'8] (3) Admin~)1 ~ [9 thru [10 & 13] [14 thru 22] [23 thru 28] (6) Other ~~ ru 3~u~] j [ 29 th i. 0 3. 4 5 6 7 8 , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Company /~F ~ Is permit fee attached ............................................... Is well to be located in a defined pool ............................... Is well located proper distance from property line ................... Is well located proper distance from other wells .... Is sufficient undedicated acreage available in this pool Is well to be deviated & is wellbore plat included ...... Is operator the only affected party ................. Can permit be approved before 15-day wait ...................... Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Lease & Well NO Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. 23. 24. 25. 26. 27. 28. 29. 30. 31. Is Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~o~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLOP~4TORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... a diverter system required ........................................ /~ 32. Additional requirements ............................................. REMARKS geology' eng i neer i ng: DWJ MTM__~ LCS ~ RPC~ BEW~__ RAD' ~ rev 03/29/91 jo/6.011 INITIAL GEO] UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE //;co Additional remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX.' ,. No special effort has been made to chronologically organize this category of information. .o * ALASKA! COMPUTiNG CENTER * ,. , ******************************** ******************************* WELL NAME ~ 1R-20 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE ~ ~L~SFA AP! NUMBER : 50-0~9-22207 REFERENCE NO : 9~026 RECEIVED FEB 2 $ 1~92 Alaska 0tl & ~3~s Oons. Commi$$io. Anchorage IS TaPe Yer.~f.Ication Listing cblumberger Alas~.a Computing Center 22-JAN-1992 15:19 **** REEL MiEADER **** ORIGIN : FLIC REEl, NAME , : 74922 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~', ~R-~0, KUPARUK RIVER, 50-029'2~207-00 **** TAPE HEADKRI ****. SERVICE NAME : EDIT DATE ~ q2/01/~2 O~i~I'N : FbIC T:.~P~ ~AME ~ : 74922 CO~TINU,~TIO~ # : P~EVIOUS TAPE , CO~ME~T : ARCO AL.ASKA INC,, IR-20, KUPARUK RIVER, 50-0~9~2207-00 **'** FILE HEADER **** FILM 'NAME : EDIT SERVICE : FLIC VERSION : 00ia06 ~X R~C~SIZE ~ ~024 FILE TYPE : LO LAST FILE : ****************************************************************************** FILE - EOIT.O01 ARCO ALASKA INC. KI!PARUK RIVER 50-029-22207 MAIN PASS LWD LOG DAT~ TEE DENSITY DATA PRESENTED ON THIS LIBRARY TAPE IS FROM '~HOB MAX' DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TO~L EXTENSION TOOL TYPE USED NA~E RGS .LWD LOGGING WHILE DRILLING RESIST!VITY/GR 5568' TO 10017' NOS .LWD LOGGING WMILE DRILLING NEUTRON/DENSITY 5568' TO 9954' chlumberger Alaska Computinq Center COMpUTI~<~ =CENTER R~A~S [:20-JAN-92): THIS I~=IBRARY~APE HAS BEEN REV!S', ~RD TO, INCL[IDE RECA~IBRATED CDN DENSi=TY.=DATA FRO~ T.D, TO 7430' ONh¥, DATA PRESENTED IS FRON 'RHOB MAX' TAB[,E TYPE'~ CONS ....... TUNI V~LU DEFI ....... TYPE C~ F" FL S~CT COU~ ST~T NAT! LATI WlT~ L~F EG~ TeD TDL DFP~ DFV DFL ~$T R~FS ~FST RPCS ~CST STE~ BHT KiJPAR[,I !V~E' 50-029-22207 666' FSL & i46' F~L 17 NORTH sLOPE ALASKA USA sgg 78 0 FT 88, FT 88, FT 88, FT 45, FT ~0080,: ~T 10080o ~T 10080, FT 5568, LSND CP DEGF OH~ DEGF ~EGF -999,25 DEGF 154, ~ompan Name APl: Serial Number Field:Location Section Townsht~ ange ounty State!"or Prov~nCe on N:at~tude Let Long~..tude witness': Name Service Order Number Per Ele Loq Ele Elevat Total Total Bottom Top Lo Drilll Drllli Drilli Drilli Drtlli Pesist Nud Sa Resist Mud. Fi Resist ~udCa Surfac Botto~ manent datum · vation of perm, Da ~easured From VE PERM~NE.NT DATU~ vation of Kelly vatton o~ Derrlc~ ion of Ground b DePth - Driller DePth - Logger boq Interval g Imterval nq Fluid TyPe. ~ Fluid Densit n~ Fluid Ph n~ Flu~.d Viscos n~ Fluid Loss iVlty of Mud Sa mple Temperatur ivttY of mud fi ltrate Sample T lvltY of ~ud Ca ke Sample Tempe e Temperature Hole Temperatu ZONE ZO~F ZONE ZONE ZONE Is ?aCe, V'~ri~:iCati, on bist;ing chlumbergeraska, Computing center TYPE TUNI BDEP 'TDEP DFPH :.,,, 1 FT: 0,:~ 0.,: 0.,: 0,i 0,~ 0,: . O. TABLE TYPE ~ CURV DMF! . DEP? Demth ~hannel..Name RO$~ SS~RHO Dens'it¥ RHOM ~Ulk: Density D~NO Delta: ,RHO PEF Photoelectric Facto. r DCA[, Differential Cal. lper DPHI Density ~oros~,ty DPO. Density Poro$it9 uutPut, from an APP,licat:i°n Program TNPH Thermal Neu'tron',Po~oSit.¥ ATR RGS BHC ATTENUAIION RESISTIVITY PSR ~G8 RHC PHASE SHXFT R~SISTIVXTY DER DXE~ECTRIC RESXSTIVITY FROM ROPE' RATE OF DRILLING PENETRATION Gamma ** BATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EF ** TYPE REP~ CODE V~LUE 1 66 0 2 66 0 ] 73 56 4 ~6 5 66 6 73 7 65 8 68 0 5 9 ~5 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 ! 0 66 0 .IS Tape Verificatl~on LXStXn~ chlumberae, r AlasKa ComPuttn6 Center 22-JAN-I. 992 15::19 NAME ** SET TYPE - CH~N ** $£RV UNIT SERVICE API AP! API API FILE NUMB Nil'MB SIZE REP PROCESS ID ORDER # LOG TYPE Ct, ASS MOD NUMB SAM'P El, EM CODE (HFX) D~P? FT 599378 00 O00 0O 0 I I I 0000000000 ROS~ bWD G/C3 599378 00 000 00 0 I I ) 4 68 0000000000 RHOB LWD G/C3~9.9378 00 000 00 0 1 ~ ~ 4 6~ 0000000000 D~HO 5WP G/C3 599378 00 000 00 0 1 I 1 4 68 0000000000 P~F LWD 599378 O0 000 O0 0 ~ 1 ! 4 68 0000000000 DC,~L LwD IN 599378 00 000 00 0 I ~ ~ 4 68 O000000000 DPH! LWD PU 599378 00 000 00 0 ~ ! 1 4 68 0000000000 DPOR LW9 PU 599378 00 000 00 0 I 1 I 4 68 0000000000 TNPH bW~ PU 599378 00 000 00 0 1 I 1 4 68 0000000000 ATR !.~WD OHMN 599378 00 000 00 0 1 1 1 4 68 0000000000 PSR LWD OHMN 599378 00 000 00 0 I ! I 4 68 0000000000 DER LWD OH~ 599378 00 000 00 0 ! 1 ~ 4 68 0000000000 ROPE 5WD F/HR 59937~ 00 000 00 0 ! 1 4 68 0000000000 ~R LWD. GAPI 599378 00 000 00 0 ~ ~ 4 68 0000000000 ** DATA ** D~PTDEF,L~D. ~082,.500 RO$2,L~D -999,:2:S0 RHOB,~GWD 2999':250 DRHO'I~WD 99Q,:250 DCAS,GWD '999.~50 DPHI.,GWD ,999,2L50 DPOR,bWD TNPH.bWD -999.250 ATR.:LWD '999,~50 PSR.':5WD 999.250 DER.LWD RODF.LWD 57.~4~ ~R.bWD '999.~50 DEPT 10000'=000 RD8~ 5WD -999,250 RHOB,bWD '999,.250 DRHO*LWD PEF:LwD -999,~50 DCA~::LWD -999,~50 DPHI,LWD -999,~50 DPOR,LWD TNP~ LWD -999,250 AT~,LWD 3,06~ PSR,LWD =3,206 DE~,LWD ROPF~LWD 94,21.9 GR,LWD 77.769 DEPT, 9900,000 ROS~,LWD 2 518 R~0B.LWD ~ .518 PEF,LWD '3,782 DCAL,LWD 0:999 DPHI,LWD o. :000 DPO~,LWD TNPH.LWD 35,$00 ATR,LWD 2 38, pSR LWD 2 569 DER,LWD ROP~.LwD 74,915 GR,LWD 83:07i * * DEPT, 9800,000 ROSg,LWD 2.420 RHOB,LWD ~.420 DRHO,LWD PEF.LWD 3,859 DCAL.LWD 0,410 DPHI,LWD 14,000 DPOR,LWD TNP~.LWD 45,300 ATR.LWD 2 46] PSR.LWO ~.~77 DER.LWD RODE.LWD ~1.15~ GR.bWD 83~651 DEDT, 9700,000 ROS2,LWD 2.434 RHOB.LWD 2.434 DRHO.LWD PEF.LWD 4,349 DCAL.LWD 0.472 DPHI.LWD 13.100 DPDR.LWD T~Pg.LWD 34.900 ATR,LWD 4.524 PSR.LwD 4.427 DER.LWD ROD~.LWD 31,658 GR.LWD 70.677 D~DT. 9600,000 ROS2.LWD 2,434 RHOB,LWD 2.434 DEF,LWD 3,942 DCAL,LWD 0.553 DPHI.LWD 13.)00 DPOR.LWD TNDg,LWD 31,g00 ATD,LWD 6.777 PSR,LWD 6.49~ D~R.LWD ROPF,LWD 6),698 GR,LWD 63,318 '2999'~50 99:9.2.50 '999,250 '9991,~50 '999,250 3,152 0,008 8,000 2,490 0,007 14.000 2,695 0.0~6 13,100 4,457 0,024 ~3,100 6,5~0 ,IS TaPe Verificat{on ;chlurnberger. AlasKa CoDnpUttn~ Center PEF,LWD 3,~97 DCAL-LWD TNPN:,LWD 32, O0 ATR,LWD ROP~,LWD 65,455 GR,LWD PEF,LWD ],928 DCAL,LWD TS~PR,LWD 36'300 ATR-LWD ROPE,LWD 61'310 GR:.L:WD 9 oo.ooo PEF~LWD ,,4,593 DCAL-LWD TNPH,,LWD 32,400 ATR:,.LWD ROPF,LWD 49,999 GR,LWD D~PT, :9200.000 ROS~'LWD PEF,SWD 4,907 DCAL.,LWD TNPg,LWD 39,~00 ATR,SWD ROPF,LWD 55,053 GR.,LWD Ioo.ooo PEF,LWD 4,046 DCAL,:,LWD TNPg,LWD 44,800 ATR,,LWD R, OP~,LWD 98,363 GR,LWD TNPH,LWD~ 51 400 ATR.,LWD ROP~.LWD 159~551 G~oLWD D~P? 8900,000 ROS~,LWD P~!LWD 3,481 DCA~,SWD TNpR LWD .46 200 ATR,LWD ~O~.LWD 156:518 PEF.LWD 4.333 DCAL.LWD TNP",LWD 46,000 ATR.LWD ROP~.LWD 133.336 GR.LWD 87o0.ooo Ros? TNPH.SwD 45.700 A?R.SWD ROP~,SWD ~71,49~ D~P~. 8600.000 RO$2.SWD PEF.SWD 3,24~ DCAS.SWD TNPH,SWD 44.300 ATR.SWD ROP~,5WD 149,002 ~R.SWD D~DT 8500.000 ROS2,bWD .EF:LWD 2,935 DCAL,LWD TNPM.LWD 38,300 ATR,LWD ROP~,LWD 154,104 GR,LW~ 22..JAN-1992 1.5:1g , 69, ! 2 ~76 104, , 01 1 9: , 105. 2 0 1 89 2 0 155 2 0 2 190. . O, 87. ~00 66 :840 937 22 059 658 395 7~5 501 267 ~02 .502 .27§ .877 ,352 .144 .229 .510 .320 .145 .75! 739 381 519 RHOB.LWD DPHI,bWD PSR,SWD RHOB.5WD= D P CH I, b w O P.R, %WD RHOB..LWD~ DPHI,LWD P,R,LWD R HO B * :L W D DPH I ,:SW D P $ R. :b W D RHOB.LWD DPHI.LWD PSR,LWD DPHI,LWD PSR,LWD RHOB,LWD DPHI,LWD PSR,LWD RHOB,LWD DPHI,LWD PSR,LWD RHOB.bWD DPHI.bWD PSR.hWD RHOB,LWD DPHI,bWD PSR.LWD RHOB,LWD DPHI,LWD PSR,LWD 2,'400 154-100 .659 { ' 387 I ,~000 · .477 ' 589 32-:7 O0 3.0 2 3 2,446 12.400 1.946 2:0.2 0 0 1.7 94 434 .807 2.502 9,000 2,075 2.352 18.100 3.767 2.320 20.000 3.347 2.381 16.300 1.993 DRHO,LWD DPOR, LWD DER, LWD DRHO.LWD DPOR,LWD DER'LWD: DRH~Oi LWD DDO LWD DER LWD DRH~.LWD DPO,..LWD D~R'LWD DRHO. LWD DPOR.LWD DER, 5WD DRHO.5WD DPOR, b WD DER. D~HO LWD DPOR ! LWD DER LWD DRHO.LWD DPOR,LWD bWD DRHO,LWD DPOR.LWD DER.LWD DRHO.L~D DPOR.LWD DER.BWD DRHO.LWD DPOR.LWD DER.LWD PAGE: 0.003 15,100 4.713 0.:026 16,000 4,549 '~,014 ,?00 2,869 0.,019 .,500 ,620 10,,005 2,400 1.912 0,007 20.200 1.650 0,004 13,1 O0 1,740 0.017 9.000 2,011 0,001 18,100 3,544 0,000 20.000 3.0~0 0.010 16.300 2.047 ;chlumberqer laska Comput ,., center DEPT. 8400.000 PEF,bWD: 2.733 T~P~I:,SWD 40,300 LWD. 196,O37 PEF,LwD· 2,910 TNPH,LWD ~39,300 ROPF'LWD 1:38,!:1.44 TNPH,LWD' ~6,500 ROPF,LWD 2 5,B92 ..5. F.LWD 3.111 TNPH.LWD 39..3.00 ~OPF,LWD 2.22,362 DFP?,.: 7900,000 TNPH.LWD 34,100 ROP~.LWD 234,400 DEPT 7800.O00 ROUR.LWD 356.432 DFPT. 7700.000 PEF,LWD 2,805 T~PN.LWD 35.600 ROPF,LW9 223,049 DEPT. 7600.000 UEF.LWD 2,953 TNPH.LWD ]7.600 RODF.LWD 130.793 DEPT. 7500.000 PEF.LWD 2,691 T~PP.LWD 38,600 ROPF.LWD 2~0,261 D~PT 7420,000 PEF:LWD -999,250 TNP~,LWD 32,400 RnOF,LWD 203.541 Os2' WD DCAh:,LWD ATR.LWD: DCAL.bWD ATR,SWD ,LWD GR,LWD DCAS.'~SWD ATR,LWD ~R'LWD: .. DCAL,LWD A~T~,bWD~ GR.LWD DCA LWD .ATR LWD GR LWD Ros ATR.LWD GR,bWO DCAL,LWD GR,LWD ROS2.LWD DCAL.LWD AT~,LWD GR.LWD ROS2,LWD DCAL,LWD ATR.LWD GR.LWD ROS~.LWD DCAb,LWD ATR.LWD GP.LWD 2.396 RHOB,6WD 0'276 DPHI.LWD 1,619 PSR,hWD 88.356 RHOB,,b:WD DPHI,[i,:WD !2!~059 2'37{ RHOB,LWD 0,145 DPHI,[,WD . :0'll PSR,bWD 6 ,670 ~,420 RHOB,:LWD 0-249 DPHI,LWD 2,06~ PSR,'LWD 94,339 2.407 RHOB,LWD 0,125 DPHI,ihWD ],081 PS~.LWD~ 94,665 2.371 RHOB,LWD 0 178 DP~I,LWD 2i443 PSR,LWD 84 348 2,390 ~HOB,LWD 0,135 DPHI,LWD 2,558 PSR,LWD 87.~87 2.364 RMOB.LWD 0.360 DPHI.LWD 3.254 PSR.LWD 97,153 -999 250 RHOB.LWD 0]224 DPHI,LWD 2.~81 PSR,LWD 71.656 15.,400 i,563 25.9 514, 2 ,800 .005 12 42.0 2.13~ 2 407 700 1~ 2.382 16.200 2.272 2.371 16.900 2.710 15.B00 2.500 2.364 17.300 3.141 -999.~50 -999.250 ?.7~1 PAGE: 0.019 15,400 1..584 0 O0 2,310 -o'oov 17,700 2,579 -0.003 16.800 2.007 9OO 0.004 ..700 11,049 0 003 1'6: oo 2,253 -0,004 16.900 2,599 0.004 15.800 2.521 -0,007 17,300 3,179 ~999,25o 999.250 2,815 chlt)mberger aska COmputing center 22'JAN-1992 !5:19 PAGE: ** END OF DATA ** **** FIbM TRAIbER **** FILE NAME : EDIT ,O01 SERVICE : FLIC VERSION : OO1A06 D.~TE : 92/01/22 MAX REC::$IZE: ::: 1024 FILE TYPE : [,0 **** TAPE TRAILER **** $~:RVICE NAME: : EDIT O~'I~IN : ~L~'C T~PF.NAME : 74922 CONTINUATI0, N # : PREVIOUS T.APE COMMENT : ARC0 AL,ASKA= iNC.,, 1R-20, KUPARUK RIVER, 50'029-~2207'00 **** REEL: TRAIbER **** SERVICE NAME : EDIT D~TM : 92/01/22 ORIGIN : ~LIC REKL NAME' : 74922 CONTINttATION # : P~EVIOUS REEL : CO~ENT ~ ARCO ALASKA INC., iR-20, KUPARUK RIVER, 50'029-22207-00
