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188-029
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-17 KUPARUK RIV UNIT 3O-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-17 50-029-21795-00-00 188-029-0 W SPT 6390 1880290 1800 2075 2075 2075 2075 680 2000 1900 1900 REQVAR P Adam Earl 6/24/2025 MIT-OA tested as per AIO 2C.026 to 1800psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3O-17 Inspection Date: Tubing OA Packer Depth 300 375 375 375IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625084400 BBL Pumped:0.5 BBL Returned:0.4 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-17 KUPARUK RIV UNIT 3O-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-17 50-029-21795-00-00 188-029-0 W SPT 6390 1880290 3000 2075 2075 2075 2075 700 1100 1100 1100 REQVAR P Adam Earl 6/24/2025 MIT-IA tested as per AIO 2C.026 to max. ant. Inj. Psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3O-17 Inspection Date: Tubing OA Packer Depth 300 3325 3250 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625084037 BBL Pumped:2.5 BBL Returned:2.4 Tuesday, July 22, 2025 Page 1 of 1 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Braden Head Repair 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 9,263' feet N/A feet true vertical 6,844' feet 9,088' feet Effective Depth measured feet 8,643' feet true vertical feet 6,395' feet Perforation depth Measured depth 8,886' - 8,992' feet True Vertical depth 6,571' - 6,649' feet Tubing (size, grade, measured and true vertical depth)2 7/8" J-55 8,724' MD 6,453' TVD Packers and SSSV (type, measured and true vertical depth)SSSV: BAKER 'FVLD' 1,801' MD 1,693' TVD Packer: BAKER 'DB' 8,643' MD 6,395' TVD 12. Stimulation or cement squeeze summary: N/A 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: 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: 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. Brennen Green & Roger Mouser N1927@conocophillips.com 907-659-7506W.I. Field Supervisor Gas-Mcf MD 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) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-029 5002921795-00-00P.O. Box 100360, Anchorage, Alaska 99510 3. Address: N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025520 KUPARUK RIVER / KUPARUK RIVER OIL ConocoPhillips Alaska, Ink. KUPARUK RIV UNIT 3O-17 N/A Length 80' 2,694' 115'Conductor Surface 16" 9 5/8" Size 115' 7" 5" 8,618' 9,107' 6,732' Plugs Junk measured Production Liner 8,583' 871' Casing measured TVD 6,376' 2,729' 2,348' Burst Collapse p k ft t Fra O s 188 6. A G L PG , r Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.12.18 09:49:16-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green By Grace Christianson at 11:03 am, Dec 18, 2023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 18, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find enclosed the10-404 from ConocoPhillips Alaska, Inc. for the Braden Head repair on well KRU 3O-17 (PTD 188-029). If you have any questions, please feel free to contact me or my alternate, Roger Mouser, at 659- 7506 Sincerely, Well Integrity Field Supervisor N1927@conocophillips.com ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E =n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.12.18 09:48:54-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green Date Event Summary Executive Summary Repair Braden Head by seal welding leak area. 11/16/23 (BH-REPAIR) T-POT (PASSED) T-PPPOT (PASSED) IC-POT (PASSED) IC-PPPOT (PASSED) MIT-OA (PASSED TO 1800 PSI) MIT-IA (PASSED TO 3000 PSI) IA & OA DDT (IN-PROGRESS) 11/22/23 (BH REPAIR) BUFF BRADEN HEAD (COMPLETE) NDE BRADEN HEAD (COMPLETE) 12/03/23 (BH REPAIR) IA-DDT (PASS), OA-DDT (PASS), INSTALLED OA PURGE JEWERLY. 12/15/23 (BH REPAIR) PURGE OA WITH N2 (COMPLETE) RIG UP INDUCTION HEATING UNIT (COMPLETE) 12/16/23 (BH REPAIR) SEAL WELD THE BH (COMPLETE) 12/17/23 (BH REPAIR) RIG DOWN THE INDUCTION HEATING UNIT (COMPLETE) MT THE BH WELDS (PASSED) GMIT-OA (PASSED TO 1369 PSI) MIT-OA (PASSED TO 1800 PSI) Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) 115.0 Wt/Len (l 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 35.0 Set Depth (ftKB) 2,729.3 Set Depth (TVD) 2,348.0 Wt/Len (l 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 35.0 Set Depth (ftKB) 8,617.6 Set Depth (TVD) 6,376.1 Wt/Len (l 26.00 Grade J-55 Top Thread BTC Casing Description LINER OD (in) 5 ID (in) 4.151 Top (ftKB) 8,236.1 Set Depth (ftKB) 9,107.0 Set Depth (TVD) 6,731.8 Wt/Len (l 18.00 Grade L-80 Top Thread LTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,236.1 6,102.4 44.90 TIE BACK TIE BACK SLEEVE 5.000 8,243.4 6,107.5 44.87 HANGER BROWN HMC LINER HANGER 5.000 Tubing Strings Tubing Description TUBING String Ma 2 7/8 ID (in) 2.441 Top (ftKB) 35.0 Set Depth (ft 8,723.9 Set Depth (TVD) ( 6,453.4 Wt (lb/ft) 6.50 Grade J-55 Top Connection 8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.13 HANGER CAMERON TUBING HANGER 2.875 1,800.9 1,692.5 37.32 SAFETY VLV BAKER 'FVLD' SAFETY VALVE, AS PER DESIGN, 2.31" FVLD FLAPPER CANNOT BE LOCKED OPEN. HYDRAULIC SHEAR SLEEVE CAN OPENED. 2.310 8,149.0 6,040.8 45.03 XO Reducing TBG CROSSOVER 2.875"x2.375" 2.375 8,641.5 6,393.4 43.28 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/40-26 g-22 locator w/12' seals 2.300 8,643.3 6,394.8 43.28 PACKER BAKER 'DB' PACKER 2.688 8,646.3 6,396.9 43.28 SBE SEAL BORE EXTENSION 32-26 2.688 8,688.7 6,427.8 43.31 NIPPLE CAMCO 'D' NIPPLE 1.812 8,723.0 6,452.8 43.34 SOS BAKER SHEAR OUT SUB 1.995 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 9,088.0 6,718.1 43.96 FISH 2 - Cones off Bit Lost downhole (4 1/2" Cones) 6/16/1988 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 8,886.0 8,906.0 6,571.3 6,585.9 A-3, 3O-17 5/23/1989 12.0 APERF 1-11/16" EnerJet; 60 deg phasing 8,915.0 8,940.0 6,592.4 6,610.7 A-2, 3O-17 5/23/1989 12.0 APERF 1-11/16" EnerJet; 60 deg phasing 8,972.0 8,992.0 6,634.0 6,648.6 A-1, 3O-17 6/17/1988 6.0 IPERF 3-3/8" Csg Gun; 60 deg phasing Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,035.9 2,563.7 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/16/1997 2 5,432.1 4,187.5 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/29/1993 3 6,834.0 5,132.8 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 2/21/1994 4 7,552.2 5,625.4 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/29/1993 5 8,110.2 6,013.3 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 10/24/2000 6 8,602.8 6,365.3 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/16/1997 Notes: General & Safety End Date Annotation 5/26/2010 NOTE: View Schematic w/ Alaska Schematic9.0 8/28/2015 NOTE: WAIVERED FOR IA x OA Comment SSSV: TRDP3O-17, 8/28/2015 9:10:59 AM Vertical schematic (actual) LINER; 8,236.1-9,107.0 FISH; 9,088.0 IPERF; 8,972.0-8,992.0 APERF; 8,915.0-8,940.0 APERF; 8,886.0-8,906.0 SOS; 8,723.0 NIPPLE; 8,688.7 SBE; 8,646.3 PACKER; 8,643.3 SEAL ASSY; 8,641.5 PRODUCTION; 35.0-8,617.6 GAS LIFT; 8,602.8 GAS LIFT; 8,110.2 GAS LIFT; 7,552.2 GAS LIFT; 6,834.0 GAS LIFT; 5,432.1 GAS LIFT; 3,035.9 SURFACE; 35.0-2,729.3 SAFETY VLV; 1,800.9 CONDUCTOR; 35.0-115.0 HANGER; 35.0 Annotation Last Tag: SLM Depth (ftKB) 9,035.0 End Date 8/12/2008 Annotation Rev Reason: ADD WAIVER NOTE Last Mod By hipshkf End Date 8/28/2015 KUP INJ KB-Grd (ft) 34.98 Rig Release Date 4/15/1988 Annotation Last WO: End Date 3O-17 H2S (ppm) Date... TD Act Btm (ftKB) 9,263.0 Well Attributes Wellbore API/UWI 500292179500 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 49.34 MD (ftKB) 4,300.00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-17 KUPARUK RIV UNIT 3O-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 3O-17 50-029-21795-00-00 188-029-0 W SPT 6390 1880290 1800 2720 2720 2720 2720 150 2000 1870 1830 REQVAR P Austin McLeod 6/16/2023 Two year MITOA to 1800psi. AIO 2C.026. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3O-17 Inspection Date: Tubing OA Packer Depth 440 540 540 540IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230617185715 BBL Pumped:0.6 BBL Returned:0.6 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Two year MITOA James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 11:26:37 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-17 KUPARUK RIV UNIT 3O-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 3O-17 50-029-21795-00-00 188-029-0 W SPT 6390 1880290 3000 2720 2720 2720 2720 220 600 630 630 REQVAR P Austin McLeod 6/16/2023 Two year to MAIP. AIO 2C.026. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3O-17 Inspection Date: Tubing OA Packer Depth 450 3510 3440 3415IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230617185500 BBL Pumped:2.3 BBL Returned:2.4 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg -Rp P.L Supervisor "'C4G� �'(j1�L( FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConccoPhillips Alaska, Inc. 30-17 KUPARUK RIV UNIT 30-17 Src: Inspector Reviewed B P.I. Supre Comm Well Name KUPARUK RN UNIT 30.17 API Well Number 50-029-21795-00-00 Inspector Name: Adam Earl Permit Number: 188-029-0 Inspection Date: 6/32021 Insp Num: mitAGE210607110232 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-17 Typelnj w -TVD 6390 - Tubing 2600, 2600 - 2600 - 2600 PTD 1890290 - Type Test SPT Test psi 3000 - IA 610 3300 - 3240 - 3210 BBL Pumped: 2.2 " BBL Returned: 2.1 OA 340 670- 1 690 690 Interval _.. _ REQVAR P/F P Notes: MIT IA Tested as per A10 2C.026 to Max. AnLlnj. Psi ✓ Tuesday, June 8, 2021 Page 1 of l MEMORANDUM TO: Jim Regg � P.I.Supervisor PI p11i''�t7 L1 FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConoccPhillips Alaska, Inc. 30-17 KUPARUK RIV UNIT 30-17 Sre: Inspector Reviewed By: P.I. Sup" Comm Well Name KUPARUK RIV UNIT 30-17 API Well Number 50-029-21795-00-00 Inspector Name: Adam Earl Permit Number: 188-029-0 Inspection Date: 6/32021 Insp Num: mitAGE210607110745 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-17 Type Inj w , TVD 6390 'Tubing 2600 , 2600 2600- 2600 PTD '880290 Type Test sPT Test psi 1800. IA 620 - no 710 - 710 BBL Pumped: 1 0.7 - IBBL Returned: 0.6 . OA 260 1980 1860 1830 ' Interval IREQVAR P/F P Notes: MIT -OA tested as per AIO 2C.026 to I800psi. ✓ Tuesday, June 8, 2021 Peee I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday, July I, 2019 P.I. Supervisor Jlk SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 30-17 FROM: Brian Bixby KUPARUK RIV UNIT 30-17 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Suprv� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-17 Insp Num: mitBDB190619120045 Rel Insp Num: API Well Number 50-029-21795-00-00 Inspector Name: Brian Bixby Permit Number: 188-029-0 Inspection Date: 6/16/2019 Packer Depth Well 30-17 ITYpe Inj W VD 6390 " PTD 1191290 Type Test SPT Test psi 1800 BBL Pumped: IBBL Returned: 0.6 Intervals REQVAR P/F P Notes: MITOA to 1800 psi per AIO 2C.026 Pretest Initial 15 Min 30 Min 45 Min 60 Min TubingF460 00 2800 2900 3800 IA75- 760 ' 775 - 773 OA 2000 1920 1900 - Monday, July I, 2019 Page I of I MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg �/7�'" 1511 DATE: Monday, July 1, 2019 Mechanical Integrity Tests P.I. Supervisor I \�ylf SUBJECT: i t ConocoPhillips Alaska, Inc. 6390 - 'Tubing 30-17 FROM: Brian Bixby KUPARUK RIV UNIT 30-17 Petroleum Inspector PTD le4n'i0 Src: Inspector 3000 IA Reviewed By: 3480 P.I. Supry E 3380 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-17 Insp Num: mitBDB190619115821 Rel Insp Num: API Well Number 50-029-21795-00-00 Inspector Name: Brian Bixby Permit Number: 188-029-0 Inspection Date: 6/16/2019 Monday, July 1, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well '0-17 T% PC Ind W- TVD 6390 - 'Tubing 2800 2800 - 2800 2800 PTD le4n'i0 Type Test SPT Test psi 3000 IA 600 3480 3410 3380 RBL Pumped: ''-4 Returned: BBL 2.1 QA 460 770 760 760 Interval REQVAR P/F P Notes: MITIA to maximum anticipated injection pressure per AIO 2C.026 Monday, July 1, 2019 Page 1 of 1 • 2317 1111 WELL LOG TRANSMIT AL PROACTIVE DINNOSTIC SERVICES, INC. RECEIVED\� DATA LOGGED 1/l"IPLU1 7 K. BENDER JUL 13 2017 To: AOGCC AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 salt' a AUG 0 3 2011, 1) Caliper Report 14&17-Jun-17 30-17 (run2) 1 Report /CD 50-029-21795-00 2) Signed : t� Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEt DMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx I�CE!!/Et� • k2-:%3-17 �g�o 2'� 2-:%3-1 7 JUL 1 3 2017 Memory Multi-Finger Caliper AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 30-17 Log Date: June 14&17, 2017 Field: Kuparuk Log No.: 14258/14260 State: Alaska Run No.: 1 &2 API No. 50-029-21795-00 Pipe Description: 2.875 inch 6.5 lb. J-55 8RD MOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,149 Ft.(MD) Pipe Description: 2.375 inch 4.7 lb. J-55 8RD MOD Top Log Interval: 8,149 Ft. (MD) Pipe Use: Tubing Tail Bottom Log Interval: 8,694 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the 2.875 inch x 2.375 inch cross-over at 8,149 feet(Driller's Depth). During logging operations, the tool string pulled out of the rope socket near the SSSV and was temporarily left in hole. A second caliper run was made after the tool string was recovered to log the interval of missing data. This report is a combination of the two caliper runs. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 2.875 inch tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate the 2.375 inch tubing tail logged appears to be in good condition with respect to internal corrosive and mechanical damage,with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate slight to moderate cork-screwed tubing from-4,325 feet to 8,694 feet(end of log). 3-D log plot overlays of the centered and un-centered caliper recordings from 1,824 feet to 8,149 feet (end of tubing)of the 2.875 inch tubing and the full interval of 2.375 inch tubing tail logged are included in this report. 2.875 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations(> 18%) are recorded throughout the tubing logged. 2.875 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss(> 9%)are recorded throughout the tubing logged. 2.875 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. 2.375 INCH TUBING TAIL - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 16%)are recorded throughout the tubing tail logged. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • 2.375 INCH TUBING TAIL - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%)are recorded throughout the tubing tail logged. 2.375 INCH TUBING TAIL - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing tail logged. C. Goerdt C. Waldrop J. Fama nod igii leer(s) r ndJvsf`,$) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • S PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 30-17 Date : June 14, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordings From 1,824 Feet to 8,149 Feet. Nominal I.D./O.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 2 inches 3 1.600 0° 0° 90° 180°270° 0° 0° 0° 90° 180°270° 0° Maximum I.D. I I 2 inches 3 Minimum I.D. I I 2 inches 3 Maximum Radius 1 inches 1.5 Minimum Radius I 1 inches 1.5 O .c ;..,;,,, 1850 .1• 0, L 1.. . , .. 1875 ,_ - ,i' 1900 _ —4— it'" — '^a - ""y ') i 1925 ' Y - • 1950 i _ y, 1975 ,- r' °- . 1....._.2000 a a 2025 - • ;.j i.. 2050 :: .... ',., . .�� 2075 ^: . 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Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 1.5 inches 2.5 1.600 0° 0° 90° 180°270° 0° 0° 0° 90° 180°270° 0° • • Correlation of Recorded Damage to Borehole Profile IPipe 1 2.875 in (-2.8'-8,149.1') Well: 30-17 Pipe 2 2.375 in (8,149.1'-8,693.6') Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: June 17,2017 ■ Approx.Tool Deviation ■ Approx. Borehole Profile 1 11 25 792 I 50 a 1,605 GLM1 Z L_ C Q v GLM 2 GLM3 GLM 4 GLM 5 - 1 8,149 GLM 6 16 8,662 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=16 • • PDS Report Overview IRS. Body Region Analysis Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Tool Type: UW MFC 24 No.211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 2.875 in. 6.5 ppf J-55 8RD MOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 2.875 in. 6.5 ppf J-55 8RD MOD 2.441 in. -3 ft. 8,149 ft. Penetration (%wall) Damage Profile(%wall) 300 gm Penetration body IN= Metal loss body 0 50 100 0.1 1 - 250 e_ 200 c c 150 E 100 50 50 r01,..w- 0 — 0 to 20 to 40 to over t 20% 40% 85% 85% GLM 1 (11:00) Number of joints analyzed(total=250) 98 250 0 0 0 r- r r Damage Configuration(body) =. 30 �- r- i II GLM 2 (8:00) l= 20 10 197 - i GLM 3 (9:00) i 148 0 I- Isolated General Line Other Hole/ GLM 4(10:00) L Pitting Corrosion Corrosion Damage Pos.Hole 245 Number of joints damaged(total=31) GLM 5 (5:00) 7 0 24 0 0 Bottom of Survey=249.1 • • 1111 til 0, PDS Report Joint Tabulation Sheet Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf J-55 8RD MOD Tubing 2.441 in. 0.217 in. -3 ft. 8,149 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 -3 0 0.02 7 2 2.37 Pup Lt. Deposits. C 1 11 0 0.02 10 2 2.37 Lt.Deposits. 2 44 0 0.02 8 1 2.39 • 3 76 0 0.02 9 1 2.39 • 4 109 0 0.03 13 1 2.37 Lt.Deposits. 5 142 _ 0 0.03 12 1 2.39 6 174 0 0.03 12 3 2.36 Lt.Deposits. • 7 207 0 0.02 10 7 2.37 Lt.Deposits. C 8 239 0 0.02 10 1 2.38 9 271 0 0.02 8 1 2.39 • 10 304 0 0.02 11 1 2.36 Lt.Deposits. U 11 337 0 0.02 9 2 2.38 Lt.Deposits. • 12 369 0 0.02 11 3 2.36 Lt.Deposits. C 13 402 0 0.02 11 1 2.38 Lt.Deposits. 14 435 0 0.03 12 3 2.38 Lt.Deposits. C 15 467 0 0.02 11 3 2.38 Lt.Deposits. C 16 500 0 0.02 8 1 2.37 Lt.Deposits. 17 532 0 0.03 12 2 2.39 C 18 565 0 0.02 8 1 2.38 19 598 0 0.02 8 1 2.36 Lt.Deposits. • 20 630 0 0.02 11 2 2.36 Lt.Deposits. • 21 663 0 0.02 9 1 2.40 • 22 695 0 0.02 8 2 2.39 • 23 728 0 0.02 10 3 2.41 a 24 760 0 0.02 7 1 2.36 Lt.Deposits. 25 792 0 0.03 12 6 2.39 C 26 824 0 0.02 11 2 2.38 27 856 0 0.02 9 2 2.37 Lt.Deposits. 28 889 0 0.02 9 2 2.38 Lt.Deposits. 29 921 0 0.02 8 2 2.37 Lt.Deposits. • 30 954 0 0.02 11 1 2.37 Lt.Deposits. • 31 986 0 0.02 9 1 2.37 Lt.Deposits. • 32 1018 0 0.02 8 1 2.37 Lt.Deposits. • 33 1051 0 0.02 8 2 2.37 Lt.Deposits. C 34 1084 0 0.02 8 2 2.37 Lt.Deposits. 35 1116 0 0.02 9 1 2.38 Lt.Deposits. a 36 1149 0 0.02 8 1 2.37 Lt.Deposits. • 37 1182 0 0.02 9 1 2.40 N 38 1214 0 0.02 10 1 2.38 • 39 1247 0 0.02 8 1 2.36 Lt.Deposits. • 40 1280 0 0.02 8 2 2.37 Lt.Deposits. a 41 1311 0 0.02 9 1 2.37 Lt.Deposits. • 42 1344 0 0.02 7 2 2.36 Lt.Deposits. • 43 1377 0 0.02 9 1 2.37 Lt.Deposits. a 44 1409 0 0.02 11 1 2.38 Lt.Deposits. • 45 1442 0 0.02 10 2 2.37 Lt.Deposits. • 46 1475 0 0.02 8 2 2.38 • 47 1507 0 0.02 10 1 2.38 Lt.Deposits. ■ 48 1540 0 0.02 9 1 2.36 Lt.Deposits. • 49 1573 0 0.02 11 2 2.38 Lt.Deposits. 111 IPenetration Body Metal Loss Body Page 1 • • ill PDS Report Joint Tabulation Sheet 4--i 11111- Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf J-55 8RD MOD Tubing 2.441 in. 0.217 in. -3 ft. 8,149 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 50 1605 0 0.03 15 5 2.37 Shallow Line of Pits.Lt. Deposits. 51 1638 0 0.02 9 1 2.39 52 1670 0 0.02 7 1 2.38 53 1703 0 0.02 8 1 2.37 Lt.Deposits. 54 1736 0.04 0.03 12 1 2.38 Lt.Deposits. 54.1 1768 0 0 0 0 2.31 BAKER SSSV 55 1777 0 0.02 8 1 2.38 Lt.Deposits. 56 1842 0 0.02 10 2 2.38 Lt.Deposits. • 57 1875 0 0.02 10 2 2.38 Lt.Deposits. ■ 58 1908 0 0.03 12 1 2.38 Lt.Deposits. ■ 59 1940 0 0.03 14 2 2.39 ■ 60 1973 0 0.02 11 2 2.39 ■ 61 2005 0 0.02 11 2 2.39 ■ 62 2037 0 0.03 15 2 2.38 Shallow Pitting. ■ 63 2070 0 0.03 12 3 2.39 is 64 2102 0 0.03 14 1 2.37 Lt.Deposits. sl 65 2135 0 0.02 9 2 2.39 sl 66 2167 0 0.03 12 2 2.35 Lt.Deposits. 67 2200 0 0.02 10 2 2.36 Lt.Deposits. 68 2232 0 0.03 12 2 2.36 Lt.Deposits. • 69 2264 0 0.02 11 2 2.37 Lt.Deposits. ■ 70 2296 0 0.03 13 2 2.38 Lt.Deposits. in 71 2328 0 0.04 16 8 2.38 Shallow Pitting. Lt Deposits. 72 2360 0 0.02 10 3 2.39 73 2389 0 0.03 12 2 2.34 Lt.Deposits. • 74 2422 0 0.03 12 1 2.36 Lt.Deposits. ■ 75 2454 0 0.03 12 2 2.35 Lt.Deposits. ■ 76 2487 0 0.02 11 2 2.39 ■ 77 2519 0 0.03 12 2 2.37 Lt.Deposits. ■ 78 2552 0 0.03 14 2 2.37 Lt.Deposits. • 79 2584 0 0.03 15 3 2.35 Shallow Line of Pits.Lt. Deposits. ■ 80 2617 0 0.03 14 2 2.35 Lt.Deposits. ■ 81 2648 0 0.03 12 3 2.35 Lt.Deposits. ■ 82 2681 0 0.03 14 3 2.37 Lt.Deposits. ■ 83 2713 0 0.03 14 3 2.37 Lt.Deposits. 1 84 2745 0 0.02 10 2 2.36 Lt.Deposits. r 85 2778 0 0.04 17 5 2.36 Shallow Line of Pits.Lt. Deposits. ■ 86 2810 0 0.03 12 2 2.36 Lt.Deposits. w 87 2843 0 0.03 13 2 2.36 Lt.Deposits. ■ 88 2875 0 0.02 11 4 2.37 Lt.Deposits. ■ 89 2907 0 0.02 11 2 2.38 Lt.Deposits. 90 2939 0 0.02 10 2 2.37 Lt.Deposits. 91 2972 0 0.03 14 5 2.38 a 92 3003 0 0.02 10 3 2.39 92.1 3036 0 0 0 0 2.35 GLM 1 (LATCH ® 11:00) I 93 3042 0 0.03 14 2 2.37 Lt.Deposits. ■ 94 3075 0 0.03 12 2 2.37 Lt.Deposits. ■ 95 3107 0 0.03 13 3 2.35 Lt.Deposits. ■ 96 3140 0 0.02 11 2 2.36 Lt.Deposits. ■ 97 3173 0 0.03 12 2 2.38 Lt.Deposits. IPenetration Body Metal Loss Body Page 2 • • III t-ii Wit PDS Report Joint Tabulation Sheet Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf J-55 8RD MOD Tubing 2.441 in. 0.217 in. -3 ft. 8,149 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 98 3205 0 0.02 11 3 2.34 Lt.Deposits. 99 3238 0 0.03 12 4 2.36 Lt.Deposits. 100 3270 0 0.03 13 3 2.37 Lt.Deposits. 101 3303 0 0.02 11 2 2.38 Lt.Deposits. 102 3335 0 0.03 14 2 2.35 Lt.Deposits. IN 103 3365 0 0.03 14 2 2.36 Lt.Deposits. No 104 3397 0 0.04 17 2 2.34 Shallow Line of Pits.Lt. Deposits. - 105 3430 0 0.03 13 2 2.35 Lt.Deposits. U 106 3461 0 0.03 12 1 2.36 Lt.Deposits. ■ 107 3494 0 0.03 12 1 2.38 MI 108 3526 0 0.02 11 2 2.37 Lt.Deposits. W 109 3559 0 0.03 15 3 2.35 Shallow Pitting. Lt Deposits. In 110 3591 0 0.03 16 2 2.36 Shallow Line of Pits.Lt. Deposits. la 111 3624 0 0.03 14 2 2.36 Lt.Deposits. 112 3656 0 0.03 14 1 2.37 Lt.Deposits. iim 113 3689 0 0.03 12 3 2.36 Lt.Deposits. t• 114 3721 0 0.03 13 4 2.35 Lt.Deposits. C 115 3753 0 0.02 11 2 2.38 Lt.Deposits. 116 3786 0 0.03 12 2 2.38 Lt.Deposits. 117 3818 0 0.02 10 2 2.38 Lt.Deposits. • 118 3851 0 0.02 11 1 2.36 Lt.Deposits. 119 3883 0 0.03 12 2 2.40 120 3912 0 0.03 15 2 2.40 Shallow Line of Pits. E 121 3945 0 0.03 12 2 2.36 Lt.Deposits. 122 3977 0 0.03 14 3 2.38 123 4009 0 0.03 12 3 2.37 Lt.Deposits. ` 124 4042 0 0.03 12 1 2.37 Lt.Deposits. 125 4074 0 0.02 10 2 2.36 Lt.Deposits. • 126 4107 0 0.02 11 2 2.39 IN 127 4139 0 0.03 14 2 2.38 mg 128 4172 0 0.03 12 3 2.36 Lt.Deposits. C 129 4201 0 0.03 14 2 2.36 Lt.Deposits. 130 4234 0 0.03 12 4 2.37 Lt.Deposits. C 131 4266 0 0.03 12 2 2.36 Lt.Deposits. 132 4298 0 0.02 10 1 2.37 Lt.Deposits. U 133 4331 0 0.02 11 2 2.36 Lt.Deposits. 134 4364 0 0.03 13 3 2.38 Lt.Deposits. r 135 4396 0 0.02 10 2 2.38 Lt.Deposits. • 136 4429 0 0.03 12 3 2.38 Lt.Deposits. in 137 4460 0 0.03 13 2 2.36 Lt.Deposits. is 138 4493 0 0.02 11 2 2.39 a 139 4525 0 0.03 12 3 2.36 Lt.Deposits. I•1 140 4558 0 0.02 9 2 2.39 ■ 141 4590 0 0.03 12 2 2.35 Lt.Deposits. 142 4623 0 0.02 11 2 2.37 Lt.Deposits. III 143 4654 0 0.03 12 3 2.38 Lt.Deposits. mi 144 4687 0 0.04 17 3 2.36 Shallow Line of Pits.Lt. Deposits. 145 4719 0 0.03 13 2 2.37 Lt.Deposits. isi 146 4752 0 0.02 10 2 2.37 Lt.Deposits. • 147 4781 0 0.03 12 2 2.37 Lt.Deposits. m IPenetration Body Metal Loss Body Page 3 • • pi cii lit PDS Report Joint Tabulation Sheet Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf J-55 8RD MOD Tubing 2.441 in. 0.217 in. -3 ft. 8,149 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 148 4813 0 0.03 15 3 2.37 Shallow Pitting. Lt Deposits. ■ 149 4846 0 0.02 11 3 2.38 Lt.Deposits. • 150 4878 0 0.03 14 2 2.37 Lt.Deposits. • 151 4911 0 0.03 12 2 2.38 Lt.Deposits. • 152 4944 0 0.03 13 2 2.38 Lt.Deposits. • 153 4976 0 0.03 12 2 2.37 Lt.Deposits. au 154 5009 0 0.03 15 5 2.34 Shallow Pitting. Lt Deposits. ■ 155 5041 0 0.03 12 4 2.38 Lt.Deposits. • 156 5074 0 0.03 12 3 2.38 • 157 5106 0 0.03 13 2 2.37 Lt.Deposits. • 158 5139 0 0.03 12 2 2.37 Lt.Deposits. • 159 5171 0 0.03 15 2 2.34 Shallow Line of Pits.Lt. Deposits. ■ 160 5204 0 0.02 11 4 2.35 Lt.Deposits. • 161 5237 0 0.02 11 2 2.38 • 162 5269 0 0.03 12 2 2.38 Lt.Deposits. • 163 5301 0 0.03 12 3 2.34 Lt.Deposits. • 164 5334 0 0.03 12 3 2.35 Lt.Deposits. • 165 5366 0 0.02 11 2 2.37 Lt.Deposits. • 166 5399 0 0.03 12 2 2.37 Lt.Deposits. 166.1 5431 0 0 0 0 2.34 GLM 2(LATCH @ 8:00) 167 5437 0 0.03 13 2 2.34 Lt.Deposits. • 168 5470 0 0.02 11 2 2.38 Lt.Deposits. • 169 5502 0 0.02 11 3 2.39 w 170 5535 0 0.03 13 2 2.40 • 171 5567 0 0.02 11 3 2.36 Lt.Deposits. • 172 5600 0 0.03 . 14 2 2.36 Lt.Deposits. i 173 5632 0 0.03 14 2 2.38 Lt.Deposits. • 174 5665 0 0.03 14 3 2.38 Lt.Deposits. a 175 5696 0 0.03 12 2 2.35 Lt.Deposits. • 176 5729 0 0.03 13 4 2.34 Lt.Deposits. ■ 177 5761 0 0.03 14 2 2.37 Lt.Deposits. • 178 5794 0 0.03 14 3 2.38 Lt.Deposits. • 179 5826 0 0.03 15 2 2.36 Shallow Line of Pits.Lt. Deposits. ■ 180 5859 0 0.03 13 4 2.36 Lt.Deposits. • 181 5891 0 0.03 15 2 2.36 Shallow Line of Pits.Lt. Deposits. ■ 182 5924 0 0.04 18 3 2.34 Shallow Line of Pits.Lt. Deposits. ■ 183 5956 0 0.03 12 3 2.40 • 184 5989 0 0.04 16 3 2.39 Shallow Line of Pits. ■ 185 6021 0 0.03 15 4 2.38 Shallow Line of Pits.Lt. Deposits. ■ 186 6054 0 0.03 14 2 2.34 Lt.Deposits. a 187 6086 0 0.03 13 3 2.39 • 188 6119 0 0.03 14 2 2.39 • 189 6151 0 0.03 13 3 2.40 • 190 6183 0 0.03 . 14 2 2.36 Lt.Deposits. s 191 6216 0 0.03 12 2 2.37 Lt.Deposits. • 192 6248 0 0.03 14 2 2.38 Lt.Deposits. • 193 6281 0 0.03 12 3 2.37 Lt.Deposits. • 194 6313 0 0.03 15 2 2.34 Shallow Line of Pits.Lt. Deposits. ■ 195 6346 0 0.03 14 3 2.40 • 196 6378 0 0.03 14 3 2.40 IPenetration Body Metal Loss Body Page 4 • 0 Pi 41.21 0 PDS Report Joint Tabulation Sheet Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf J-55 8RD MOD Tubing 2.441 in. 0.217 in. -3 ft. 8,149 ft. Joint Jt.Depth Pen. Pen. Pen, Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 197 6411 0 0.03 14 3 2.35 Lt.Deposits. • 198 6443 0 0.03 12 3 2.35 Lt.Deposits. ■ 199 6476 0 0.04 17 4 2.35 Shallow Line of Pits.Lt. Deposits. ■ 200 6508 0 0.03 16 3 2.35 Shallow Line of Pits.Lt. Deposits. ■ 201 6541 0 0.02 11 3 2.36 Lt.Deposits. si 202 6573 0 0.03 13 3 2.36 Lt.Deposits. • 203 6606 0 0.03 15 3 2.35 Shallow Line of Pits.Lt. Deposits. ■ 204 6639 0 0.03 14 3 2.36 Lt.Deposits. a 205 6671 0 0.03 15 3 2.38 Shallow Line of Pits.Lt. Deposits. ■ 206 6704 0 0.03 15 3 2.35 Shallow Line of Pits.Lt. Deposits. 207 6736 0 0.02 9 2 2.37 Lt.Deposits. 208 6768 0 0.03 14 2 2.38 Lt.Deposits. • 209 6801 0 0.03 12 2 2.36 Lt.Deposits. 209.1 6833 0 0 0 0 2.36 GLM 3(LATCH @ 9:00) 210 6840 0 0.03 13 6 2.35 Lt.Deposits. 211 6872 0 0.02 10 3 2.36 Lt.Deposits. ■ 212 6905 0 0.02 11 3 2.40 is 213 6937 0 0.03 14 3 2.34 Lt.Deposits. s 214 6970 0 0.02 11 3 2.36 Lt.Deposits. • 215 7002 0 0.03 13 2 2.38 Lt.Deposits. ■ 216 7035 0 0.03 14 2 2.36 Lt.Deposits. • 217 7067 0 0.02 11 3 2.38 Lt.Deposits. • 218 7100 0 0.03 16 3 2.37 Shallow Line of Pits.Lt. Deposits. ■ 219 7132 0 0.03 15 4 2.36 Shallow Line of Pits.Lt. Deposits. ■ 220 7161 0 0.03 14 3 2.36 Lt.Deposits. ■ 221 7194 0 0.03 14 4 2.38 Lt.Deposits. • 222 7227 0 0.03 14 2 2.37 Lt.Deposits. • 223 7259 0 0.03 14 2 2.35 Lt.Deposits. • 224 7291 0 0.03 13 3 2.35 Lt.Deposits. • 225 7324 0 0.03 14 3 2.35 Lt.Deposits. • 226 7357 0 0.03 13 3 2.33 Lt.Deposits. • 227 7389 0 0.03 14 2 2.33 Lt.Deposits. • 228 7422 0 0.03 14 3 2.35 Lt.Deposits. • 229 7454 0 0.03 14 3 2.34 Lt.Deposits. • 230 7487 0 0.03 15 3 2.35 Shallow Line of Pits.Lt. Deposits. ■ 231 7519 0 0.04 17 4 2.35 Shallow Line of Pits.Lt. Deposits. 231.1 7552 0 0 0 0 2.34 GLM 4(LATCH @ 10:00) I 232 7558 0 0.03 14 3 2.40 • 233 7590 0 0.03 15 3 2.38 Shallow Pitting. Lt Deposits. ■ 234 7623 0 0.03 14 3 2.38 Lt.Deposits. ■ 235 7655 0 0.03 13 2 2.34 Lt.Deposits. • 236 7688 0 0.03 14 2 2.35 Lt.Deposits. • 237 7721 0 0.03 14 3 2.35 Lt.Deposits. • 238 7753 0 0.03 13 3 2.38 Lt.Deposits. s 239 7785 0 0.03 14 2 2.36 Lt.Deposits. • 240 7818 0 0.03 13 3 2.35 Lt.Deposits. • 241 7851 0 0.03 12 4 2.36 Lt.Deposits. ■ 242 7883 0 0.03 13 3 2.35 Lt.Deposits. • 243 7915 0 0.03 12 3 2.40 III 244 7948 0 0.03 13 2 2.37 Lt.Deposits. IPenetration Body Metal Loss Body Page 5 • . IIII 41A 0, PDS Report Joint Tabulation Sheet Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf J-55 8RD MOD Tubing 2.441 in. 0.217 in. -3 ft. 8,149 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body (Y0 Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 245 7980 0 0.02 9 3 2.37 Lt.Deposits. 246 8012 0 0.03 15 5 2.35 Shallow Line of Pits.Lt. Deposits. 247 8045 0 0.03 12 3 2.38 248 8077 0 0.03 14 2 2.34 Lt.Deposits. 248.1 8110 0 0 0 0 2.32 GLM 5(LATCH CO 5:00) 249 8116 0 0.03 15 3 2.39 Shallow Pitting. 249.1 8149 0 0 0 0 2.29 2.875"X 2.375"CROSS-OVER IPenetration Body Metal Loss Body Page 6 • • ili PDS Report Overview 4-1.0L_ Body Region Analysis Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Tool Type: UW MFC 24 No.211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 2.375 in. 4.7 ppf J-55 8RD MOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 2.375 in. 4.7 ppf J-55 8RD MOD 1.995 in. 8,149 ft. 8,694 ft. Penetration(%wall) Damage Profile(%wall) 20 illi m= Penetration body Metal loss body 0 50 100 1 - 15 - I 10 - I III5 IIIII I0 6 - 0 to 20 to 40 to over 20% 40% 85% 85% 01 Number of joints analyzed(total= 16) ill 16 0 0 0 MI I Damage Configuration(body) - II 10 - I 8 11 - I 6 III I 4 I. 2 - 1 GLM 6(7:00) 15 - 1 0 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole ■ Number of joints damaged(total=6) ' 2 0 4 0 0 Bottom of Survey= 16 • PDS Report Joint Tabulation Sheet Well: 30-17 Survey Date: June 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.375 in. 4.7 ppf J-55 8RD MOD Tubing Tail 1.995 in. 0.19 in. 8,149 ft. 8,694 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 1 8149 0 0.03 13 4 1.92 Lt.Deposits. 2 8181 0 0.03 15 5 1.92 Shallow Pitting. Lt Deposits. 3 8214 0 0.03 15 3 1.94 Shallow Pitting. 4 8246 0 0.02 12 3 1.93 Lt.Deposits. 5 8279 0 0.03 13 4 1.93 Lt.Deposits. 6 8311 0 0.03 16 8 1.91 Shallow Line Corrosion. Lt. Deposits. 7 8344 0 0.03 15 3 1.94 Shallow Line of Pits. 8 8376 0 0.03 14 4 1.92 Lt.Deposits. 9 8409 0 0.03 15 7 1.93 Shallow Line of Pits.Lt. Deposits. 10 8441 0 0.03 14 4 1.93 Lt.Deposits. 11 8474 0 0.03 14 3 1.94 12 8506 0 0.03 14 3 1.93 Lt.Deposits. 13 8539 0 0.02 12 3 1.94 14 8571 0.03 0.03 16 4 1.94 Shallow Line of Pits. 14.1 8603 0 0 0 0 1.95 GLM 6(LATCH c 7:00) 15 8610 0.03 0.02 11 2 1.92 Lt.Deposits. 15.1 8641 0 0 0 0 1.95 BAKER LOCATOR SEAL ASSEMBLY 15.2 8653 0 0 0 0 2.00 BAKER'DB'PACKER 16 8662 0 0.02 11 3 1.95 IPenetration Body Metal Loss Body Pagel • • KUP INJ 30-17 ConocoPhillips '. $, Well Attributes Max Angle 8.MD TD Alaska.Inc- Wellbore APIIUW1 Field Nem! atlao to Statue ec1 I) M 111011 Act Stn(RKR) t,».,,,,,t,,,l,l„ ., 500292179500 KUPARUK RIVER UNIT IWINJ D49:34 4,300.00 9.2630 -.. Comment 1424(ppm) Date Annotetlon 'End Date K111.0 id(n) Rig Release Date 30-17.62820 0 9 10 59 Ant SSSV: TRDP Last WO: 3498 4/15/1988 Y«raua x.laanoec 1446.46/ 'Annotation Depth(Met end Date Annotation Last Mod ey end Oats Last Tag:SLM 9.035.0 8,12,2008 Rev Reason:ADD WAIVER NOTE hipshLt 8/28/2015 1.LN ,. •I8414. j 'X � r inNCa g strings ill Cssmg 6ea Strings n OD t el ID iln) Top MK 51 Set Depth INKS) Set Deptn IND)... WUlen(I...Grade Top Thread CONDUCTOR 16 15062 350 115.0 115,0 82.50 H-40 WELDED teems Description OD(In) lb Orn Top Mile) Set Depth(RKRI .Set Depth(13./Ch... Wt/Len(L..Orale Top Thread "~SURFACE 9 518 8 921 35.0 2,729.3 2.348.0 38.00 J-55 BTC CONDUCTOR.35.0.115 0 g A Casing Description OD(in) ID(in) Top(WEN Set Depth lows) Set Depth(TVD)...'WULen()...Grade Top Thread PRODUCTION 7 6276 350 8,617 b 6..376.1 26.00 J-55 ETC SAFETY VLV,1,900.8 r• IalnR Description 06(int ID tett Top(BKet Sat Depth(hKR) Set Depth(TVD)... WC/Lan(1...Grade Top Thread LINER5 4151 8.236.1 9,1070 6.731.8 18.00 L-80 LTC Liner Details Nenlnal ID Top(ekE) Top(T901111651 Top Incl() 110111 DeS Cort) 1101 8.235.1 6.102.4 44 90 TIE BACK TIE BACK SLEEVE 5.000 8,43.4 6.107 5 44 87 MANGER BROWN HMC LINER HANGER 5.000 SURFACE,7502.7293 Tubing Strings Tubing Description I String Me_,.IID(Ith ITop(hKR) ISet Depth(h..I Set Depth(TVD)(...I WI11b/h) I0rede I Top Connection GAS LIFT.3,0351 -1 TUBING 2 7 6 2 441 35 0 8,3:'.3 9 6-753-1 6 50 J-55 5,81400 Completion Details Nominal ID GAS LIFT,5,431). • Top(FMK) Top(TVD1 MKS/ Top 1101('I Item Das Cum (In) • 35.0 35.0 0.13 HANGER CAMERON TUBING HANGER 2.875 1,800.9 1,692.5 37.32 SAFETY VLV BAKER`FVLD'SAFETY VALVE.AS PER DESIGN.2.31" 2.310 GAS LIFT,6,9341, FVLD FLAPPER CANNOT BE LOCKED OPEN. HYDRAULIC SHEAR SLEEVE CAN OPENED. 8,149.0 6,040.8 45 03 XO Reducing TEG CROSSOVER 2,875"x2,375" 2.375 GAS LIFT.7,552: 8,641.5 8,393.4 43.28 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/40-26 g-22 2.300 locator w/12'seals 8.843.3 6.394 8 43.28 PACKER BAKER'OB'PACKER 2,888 GAS LIFT.6.119_ 8,6463 8.398.9 4328 SBE SEAL BORE EXTENSION 32-26 2-688 8,688.7 6,427.8 43.31 NIPPLE CAMCO'D'NIPPLE 1.812 8.723 0 6.452 8 43 34 SOS BAKER SHEAR OUT SUB 1.995 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 90 SP Toy(nKeTop(nKID) Top incl j NR ( I Dee Corn I Run Date 10(1n) i9 003 0I 6 71)8.1 43.961 FISH 2-Cones off Bit Lost downhole 14 1/2"Cones) 8116/1988 1.000 Perforations&Slots 111 Shot Dens Top(WO/ Stm(TVD) Isheiur Top(riKel Sim(1108) (RKR) IRKS) Zone Data t) Type Com +I 8,886.0 8.906.0 6,571.3 6,685.9 A-3.30-17 5.23/1989 120 APERF 1-11/16"EnerJet',60 deg phasing 8,915.0 8,940.0 6.592.4 6,610.7 A-2.30-17 5/23(1980 12.0 APERF 1-11/16"EnerJet;60 deg phasing GAS LIFT,8 802 ft 8,972.0 8_992 0 6.634.0 6,648.6 A.1,20.17 607/1988 60 IPERF 3.318"Csg Gun;80 deg phasing Mandrel Inserts PRODUCTION.350-6.6176 51 eu SEAL.ASSY.6.641 S T" IND) Valve Latch Port Slea TRO Run Thy IRKS) IttKR) Mahe Model OD PM Sons Type Type (In) (pal) Run Date t Cont PACKER.6,6473 • l•' ' N To'' 3.035.9 2,563.7 McMurry Fh1HO 1 GAS LIFT OMY BK 0000 0,0 111611907 `•0 3 5,432.1 4.187.5 MCMurry PTAH() 1 GAS LIFT DMY BK 0.000 0.0 7129/1993 585,6,6463 3 8.834.0 5,1328 McMuny FMHO 1 GAS LIFT DMY BK 0.000 0.0 2/21/1994 f._:. 4 7,552.2 5,625.4 McMuny FMHO - 1 GAS LIFT OMY BK 0.000 0.0 7/29/1993 S 8.110,2 8.013.3 MCMurry FMHO 1 GAS LIFT DMY 8K 0.000 0.0 10/24.12000 ^8 8,6028 6,565.3 McMurry FMHO 1 GAS LIFT DMY BK 0.000 O.O 1+?6 1'337 NIPPLE,6.68/1: Notes:General&Safety end Date Annotation 5(26'2010 NOTE.V)e::Schematic wl Alaska Schematic9 0 . &2812015 NOTE- WAIVERED FOR IA x 06 505.872306.0 f APERF.8.168 0-11.9 0 E APERF 69150-8,9400 IPERF..8.972 08,902 0 I ) FISH.,9,088.0 9 LINER 02301.0,1070 i • 4,44 IN 1 TUBING / LINER SAIL DILL SITE 30 - 1. ARCO Masks, inc. 40 DATE #• r-. iublMHry el A64011oRkhhode0ffipH1y Page- 0+.,____Z-_____ pdp®1 OITEM$ COMPLETE DISCRf PTION OF EQUIPMENT RUN LENGTH •EPTH 1 L >r• { • +r _4.3.5.:,....01‘.......) ' ._ r . :, 1I it," i Ir +'il r . �a �' "/ = . .,�Aid'AS Ib { tion N � ,..:_: .. ILA( I 1,± "J +• '.... al _ AI _ r li , I J... )r ',! r 4 -'5•] P 9 ti c'J S S . i , .. a"I C- I.0.I - r .. i-b i. it nN X 11 �t E t►t0 L2 .40 Pio _ 30z J ,•iz39, l n: Tlaa ,...,____,..,..... ......13165:b___... ._.S._...-438 1 rt_:.41 -- 1�► ... e+/fir ®f `/:,. 1 i 2i811 174 ,t1 :1n Li 0z 'C *..- ._. ,),64, . !q<f f �. IDA $(4)e► . -AM d lx6 1' V R 1 ± 20(4 I e.ci12 r ' 1 it ._...:: Y r. '0V e r ,' -.71 .4.42. :.� Y •+ P BOTTOM OF TUBING TAIL numimiticapternmunmormamimmummummos acturea ARC- €9.1116 R.Suplrviear a . • ,M8lN !TUBING 1 LINER MIL Kvised DRILL SITE •-1'7 ARCO Alaska, Inc. 40 DATE I Subsldtuy of AginfloRichfleittCompany Page 7. of pages WITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH vQ,r !7 . L,$© Ide ' v 23/8" R" 4 /fir ' ,y p_ + •- )110r -�_.,_ _ 33 r.7 '7 $6-'° • • BOTTOM OF TUBING TML Remaarks . • 2-76 14S24ALL LCA TRANSMITTAL DATA LOGGED il' Ai/2011 PROACTIVE DIAGNOSTIC SERVICES, INc. M.K.BENDER RECEIVED JUL 13 2017 To: AOGCC Makana Bender AOGCC 333 West 7th Avenue A V Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED AUG 4 32017, 1) Caliper Report 14-Jun-17 30-17 1 Report /CD 50-029-21795-00 2) Caliper Report 15-Jun-17 3Q-16 1 Report /CD 50-029-21667-00 Signed : G�,�LKZGI.1z� ,-E;�k: Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx •ECEIVED • 2_<6 .E.21t JUL132017 Memory Multi-Finger Caliper Lit NO AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 30-17 Log Date: June 14, 2017 Field: Kuparuk Log No.: 14258 State: Alaska Run No.: 1 API No. 50-029-21795-00 Pipe Description: 2.875 inch 6.5 lb. J-55 8RD MOD Top Log Interval: 1,824 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 8,149 Ft. (MD) Pipe Description: 2.375 inch 4.7 lb. J-55 8RD MOD Top Log Interval: 8,149 Ft. (MD) Pipe Use: Tubing Tail Bottom Log Interval: 8,694 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the 2.875 inch x 2.375 inch cross-over at 8,149 feet(Driller's Depth). During logging operations, the tool string pulled out of the rope socket near the SSSV and was temporarily left in hole. No data was collected from surface to 1,824 feet. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 2.875 inch tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate the 2.375 inch tubing tail logged appears to be in good condition with respect to internal corrosive and mechanical damage,with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate slight to moderate cork-screwed tubing from 4,325 feet to 8,694 feet(end of log). 3-D log plot overlays of the centered and un-centered caliper recordings across the 2.875 inch tubing and the 2.375 inch tubing tail logged are included in this report. 2.875 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 18%)are recorded throughout the tubing logged. 2.875 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 9%)are recorded throughout the tubing logged. 2.875 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. 2.375 INCH TUBING TAIL - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 16%)are recorded throughout the tubing tail logged. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • 2.375 INCH TUBING TAIL - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%)are recorded throughout the tubing tail logged. 2.375 INCH TUBING TAIL - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing tail logged. C. Goerdt C. Waldrop J. Fama F i41,S E ng nt E r r._,y.t(s) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot .....14..-.) Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 30-17 Date : June 14, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordings Across 2.875 Inch Tubing. Nominal I.D./O.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 2 inches 3 1:600 0° 0° 90° 180°270° 0° 0° 0° 90° 180°270 0° Maximum I.D. H. I 2 inches 3 Minimum I.D. I I 2 inches 3 Maximum Radius I • 1 inches 1.5 Minimum Radius 1 inches 1.5 iaca _ ...* ilLei . "Mm.:;" I:: — •' ,.:.. 1850 i -s ,A I : ''''',1: 1 1 t, 1875 - = _ _ __ 1. 1900 _ "- 1925 - r ' 1950 r ;,.. j :a. 1975 a—. L -�: '' 2000 --?: 2025 '' ... . f t'' 2050 „, R -tet •�•• • •ytH1f.. • �. • —'... .. 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Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) tlt 1 MK ii Rif 2 inches 3 1.600 0° 0° 90° 180° 270° 0° 0° 0° 90° 180°270° 0° • • kS PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 30-17 Date : June 14, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordings Across 2.375 Inch Tubing Tail. Nominal I.D./O.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 1.5 inches 2.5 1.600 0° 0° 90° 180°270° 0° 0° 0° 90° 180°270° 0° Maximum Diameter I 1 1.5 inches 2.5 Minimum Diameter 1 I 1.5 inches 2.5 Maximum Radius 0.75 inches 1.25 Minimum Radius 0.75 inches 1.25 ....:!-....:'�:,.i 8150 '► P 8175 - . 4I g :.• ---8200 _ . - 8225 8250 - ". ., 8275 ;.,.-- .,..:.. ..2 _ ro rt r it: , ',, 8300 : '' .—a ,,.. ... 8325 - - - .R• l - { r ,, 8350 'T::.N 8375 8400 — 8425 ,I hie m s r tJ 8450 "e".`"""_. , i, r. 8475 - :; <:, «• i _ • • 8500 •....... 8525 : --. � - :. :.. >fNI� ; _ _ �� t 8550 - az -sfm.m• 8575 '° i - 'f __..-._ it[t•o_ .a: _ • ��=11 ••• is =;•.•..... �f��� 8600 ii `r =. war Sti - - �,I•::. . �MctWI■IIE- 8625 1 a. - .0  Top Incl() Item 005 Com (1111 8,238.1 6,102.4 44.90 TIE BACK TIE BACK SLEEVE 5.200 8,243.4 6 107.5 44 87 HANGER BROWN HMC LINER HANGER 5 000 cLIRFACE,350.2.7203 Tubing Strings Tubing Description String Ma,..ID(in) I3,72Top(r1KB) Set Depth(R. Set J Set Depth(TVD)I...Wt(Ib1R) Grade Top Connection GASLlFT,3,0359it TUBING _78 =441 35. 0 39 6.4534 6.50 -55 8101100 Completion Details Nominal ID 1;0.5 LIFT 1' Top(MSS) Top(IVO)(TM at Top Incl() Item Des Com (In) 35.0 350 0.13 HANGER CAMERON TUBING HANGER 2.875 ® 1.800,9 1.6925 37.32 SAFETY VLV BAKER'FVLD'SAFETY VALVE.AS PER DESIGN.2.31" 2.311) GAS OF I.6.0:11 u FVLD FLAPPER CANNOT BE LOCKED OPEN. III HYDRAULIC SHEAR SLEEVE CAN OPENED. 111 8.149.0 6,040.8 45.03 XO Reducing TEG CROSSOVER 2.875-x2..375" ...375 GAS LIFT,7,552.2 8,841.5 8.393.4 43.28 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w140-26 g-22 _.300 locator wr12'seals 8,643,3 6.394.8 43.28 PACKER BAKER'DB'PACKER 2.688 GAS LIFT 8,115, 8,646.3 6,398-9 432eSBE SEAL BORE EXTENSION 32.26 2.338 8.688.7 6.427.8' 43.31 NIPPLE CAMCO'D'NIPPLE 1.812 8,723.0 6,452.8 4334 SOS BAKER SHEAR OUT SUB 1.999 Other In Hole(Wirellne retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top met Top MKS) IRKS) LI Des Com Run Date I„(ml j 1 9,088.0 5 718.1 43.9E FISH _.Cones o11 Bit Lost downhole(4 1)2"Cones) 8116(1988 '000 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (andlaH Top(nKB) Blot(MO) 111KB) (RICO) Zone Date LI Type Com 8,888.0' 8,906.0 6.571.3 6,585.9 0.-3,30-17 512311989 120 APERF 1-11)16"EnerJet:60 deg I . ', phasing 8,915.0 8.940.0 8,592.4 8,810.7 A-2.30-17 5/23/1989 12.0 APERF 1-11/16"EnerJet:60 deg phasing GAS LIFT.S.892 0 8.972 0 8.992.0 8.634.0 6,848.6 A-1,30.17 '6/17'1988 8 0 (PERE 3.3/8"Csg Gun:60 deg phasing Mandrel Inserts PRODUCTION.350-8.8176 BI . SEAL ASSY.8,641.5 ' N Top(TVD) Valve Latch Pon Slee TRO Run Top 1nMKS)KB) Make Model oD(in) Story Type pe (Int (pal) Run Date Com PACKER,6,6493 e a 1 3.035.9 2,563.7 McMunLIFT .0 y FMHO I GAS DMY BK 0000 O 1:16.1 997 a ia`Se ' 25.432.1 4.187-5 McMurry FMHO ' 1 GAS LIFT -DMY 'BK 2.000 00 7+29+1993 086.0,6463 3 6.834.0 5,132.8 MEMurry FMHO 1 GAS LIFT DMY BK 3.000 0.0 22111994 r4 7.552,2 5,625.4 McMuny FMHO ' 1 GAS LIFT DMY BK 0.000 0.0 729'1993 F S 8.t 10.2 6,013.3 McMurry FMHO 1 GAS LIFT DMY BK 0.000 0.0 102412000 6 8.602.8 6.365,3 Mch4urry FMHO 1 GAS LIFT DMY BK r 0.000 0.0 1)1811997 NIPPLe Notes:General&Safety End Date Anno:cllon I 6'26!2010 NOTE-Vie,v Schematic w+Alaska Schematic6.0 828112015 NOTE- WAIVERED FOR IA x OA SOS--,8,721[• .. nPERF.6.980 041,906 I. APERF 0,0150-6,0401' !PERF 8,0720-5902 9-... I 1 ! FISH.9,088.0 LINER,8.230 1'0107 0 • ! 4,ASING 1 TUBING i LINER _ tiiL DRILL SITE 3 D ` 1 ARCO I ska, Inc. DATE . 6.1e-8 _ _- UpstBl1rr of Allenllduchtle deem$ y Page i 01 - pages COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH •EPTH ,,,, ; ' L 0- 1.... S", l)) 0 .... .:.... f . t —71iv" ,vel .a • r -1/ r ? '?! . ,J, • ._ - 00 r - AI : 4 •• ... a1 r / 1 fl.Alli i r , a, i Q ) ( ta l { y ! r • , 0 r MIFe =0 _ q s a!t• �, CO .il NM I + e '?/ r M it+ M. . 4.1 1 14H • �r:< TCL' MIEN % u . ... • MAW: )1014 • UMW/ 64:1 J1 MEM Y c G7 •it s €? V•N ,fin - • I2.0 , 1111MINE R: — mu lv T "I. - , :ft! ,10/ • f,6` i M .,,; a 1111111111.11K . .,tea _. .. r . :s BOTTOM OF TUBING TAIL Ria �tks crr r ' ARO, PM i AO R,Supimieor . • ,MIN !TUBING 1 LINER D. MIL 1`eotse4 DRILL SITE .3O 11 ARCO Alaska, Inc, 4> DATE subsidiary of assorweiontraidcomploy Page 7. - of _ pages WITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 7d :• 4. � i!• i z Zp '— cc r im nom'- ..rte fJ+ / `` ,7 L-$o :q91 23/8" R" : .) P i` -d it tr ��.,. 7 — z.7. 431` r 64eAr 69J- s ip,c9f ,96S) + ' '0 • 60 raw BOTTOM OF TUBING TAIL Re :rite n.... a R..- • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: P.I.JmRapgg er g016/1 SUBJECT: Mechanical Integrity Tests P.I.Supervisor �� , L CONOCOPHILLIPS ALASKA INC 30-17 FROM: Lou Laubenstein KUPARUK RIV UNIT 30-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry TA/1-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-17 API Well Number 50-029-21795-00-00 Inspector Name: Lou Laubenstein Permit Number: 188-029-0 Inspection Date: 6/6/2017 ✓ Insp Num: mitLOL170607161053 Rd Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-17 Type Inj W" TVD 6390 - Tubing 2800 • 2800 . 2800' 2800 ' PTD 1880290 - Type Test PPT Test psi 3000 s IA 800 3500 ' 3420 3410 ' BBL Pumped: 2.4 - BBL Returned: 2.3 " OA 410 680 - 680 ' 680 - Interval REQVAR P/F P ✓ Notes: MITIA per A10 2C.026 to MAIP ✓ SCANNED SEP 0 5 201 Thursday,June 15,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: P.1.Jim Suupeerr visor � DATE: Thursday,June 15,2017 1p (R(1 6 �l r �7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-17 FROM: Lou Laubenstein KUPARUK RIV UNIT 30-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-17 API Well Number 50-029-21795-00-00 Inspector Name: Lou Laubenstein Permit Number: 188-029-0 Inspection Date: 6/6/2017 ✓ Insp Num: mitLOL170607161708 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-17 Type Inj W- TVD 6390 - Tubing 2800 2800 - 2800 - 2800 • PTD 1880290 - Type Test SPT Test psi 1800 - IA 800 975 975 975 BBL Pumped: 0.6 `BBL Returned: 0.7 OA 410 2000 - 1920 - 1910 ' Interval REQVAR P/F P ✓ Notes: MITOA to 1800 psi per AIO 2C.026 i SCANNED SEP 0 5 20]-/ Thursday,June 15,2017 Page 1 of 1 . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 26,2015 TO: Jim Regg I P.I.Supervisor Ic. e1- C?(-5I/S SUBJECT: Mechanical Integrity Tests 111 CONOCOPHILLIPS ALASKA INC 30-17 FROM: Johnnie Hill KUPARUK RIV UNIT 30-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 13°— NON-CONFIDENTIAL 3 –NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-17 API Well Number 50-029-21795-00-00 Inspector Name: Johnnie Hill Permit Number: 188-029-0 Inspection Date: 8/5/2015 Insp Num: mitJWH150809135717 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-17 a In' �' TVD _ 6390 Tubing 2925 - 2925 - 2925 2925 - TYP J g; _ PTD 1880290 !Type Test SPT Test psi 3000 - IA i 950 3500 3440 - 3430 . Interval 1REQVAR P/F P ✓ OA ' 420 630 - 630 630 Notes: MITIA per AIO 2C.026 MITIA to max anticipated inject psi ✓ SCANNED :r Wednesday,August 26,2015 Page 1 of I • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg X26 j1(1 DATE: Wednesday,August 26,2015 P.I.Supervisor 6Z SUBJECT: Mechanical Integrity Tests C. CONOCOPHILLIPS ALASKA INC 30-17 FROM: Johnnie Hill KUPARUK RIV UNIT 30-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry�e— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-17API Well Number 50-029-21795-00-00 Inspector Name: Johnnie Hill Permit Number: 188-029-0 Inspection Date: 8/5/2015 Insp Num: mitJWH150809140043 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-17 Type Inj W'TVD 6390 - i Tubing 2925 - 2925 2925 2925 - -r- PTD 1880290 - Type Test SPT Test psi 1800 I IA 600 - I 700 - 700 700 Interval REQVAR P/F P s7 OA 350 2000 - 1950 1940 - Notes: MITOA per 2C.026 MITOA to 1800 psi SCONE).l e =I - Wednesday,August 26,2015 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, May 20, 2015 10:32 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Kuparuk injector 30-17 (PTD# 188-029) Unexplained increase in OA pressure. Attachments: image001.png; 30-17.pdf; 30-17 90 Day TIO plot.JPG Chris- Kuparuk injector 30-17 (PTD# 188-029) has an unexplained increase in OA pressure. The well has slowly built pressure over a period of time and was bled yesterday to separate the OA from the IA. It is CPAIs intentions to perform initial diagnostics consisting of a MIT-OA and IC pack of tests. If the MIT-OA passes the OA will be bled down and monitored for 30 days for OA pressure build up. If the OA pressure continues to build, the IA will be bled off lower than the OA and monitored for an additional 30 days to verify the pressure source. Depending on the results of the diagnostic monitor periods the proper notifications for continued injection or initiation of the AA process for water injection only with IAxOA communication will be submitted. Please let me know if you have any questions or disagree with the plan. Attached are a 90 day T/I/0 plot and a well bore schematic. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 SGM41183 MAY 2 22015 WELLS TEAM c«,«oirps 1 KUP 30-17 ConocoPhillips A. Well Attributes Max Angle&MD TD Alaska,Inc. WeIlbore API/UWI Field Name Well Status Inel I') MD(ftKB)500292179500 KUPARUK RIVER UNIT INJ 49.34 4,300.00 9,263.0 Comment H23(ppm) Date Annotation End Date KB-Ord(rt) Rig Release Date "' SSSV:TRDP Last WO: 34.98 4/15/1988 Well Coneg:-30-17,3252012 10:35:33 AM Scheme8c-Acael Annotation Depth MKS) End Delo Annotation Last Mod...End Date Last Tag:SLM 9,035.0 8/12/2008 Rev Reason:SSSV NOTE ninam 3/25/2012 HANGER,35 Casing Strings r Casing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(TVD)...String Wt...String•••String Top Thrd CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(f l(B) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 35.0 2,729.3 2,348.1 36.00 J-55 BTC r Casing Description String 0... String ID...Top(NKR) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUcrOR,_� PRODUCTION 7 6.276 35.0 8,617.6 6,376.0 26.00 J-55 BTC 35-N5 Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)..-String Wt...String..•String Top Thrd LINER 5 4.151 8,236.1 9,107.0 6,731.8 18.00 L-80 LTC SAFETY LV. o Liner Details FTop Depth I _ (TVD) Top Incl Nornl... Top IMKB) ((1KB) r) into Description Comment ID(In) 8,236.1 6,102.4 44.82 TIE BACK TIE BACK SLEEVE 5.000 8,243.4 6,107.5 44.80 HANGER BROWN HMC LINER HANGER 5.000 SURFACE,__- L Tubing Strings 55-2.729 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 1 r TUBING 2 7/8 2.441 35.0 8,723.9 6,453.4 6.50 J-55 8rdMOD GASFT. 3ICompletion Details Top Depth _ (TVD) Top Incl Norni... GAS LIFT, Top(NKB) Pt" 11 horn Description comment ID 9n) 5.432 35.0 35.0 0.36 HANGER CAMERON TUBING HANGER 2.875 ff=4 1,800.9 1,690.2 36.80 SAFETY VLV BAKER'FVLD'SAFETY VALVE,AS PER DESIGN,2.31"FVLD 2.310 GAS LIFT. FLAPPER CANNOT BE LOCKED OPEN.HYDRAULIC SHEAR 9,894 SLEEVE CAN OPENED. 8,149.0 6,040.8 45.03 XO Reducing TBG CROSSOVER 2.875"x2.375" 2.375 GAs7.552 8,641.5 6,393.4 43.26 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/40-26 g-22 locator w/12'seals 2.300 8,643.3 6,394.7 43.26 PACKER BAKER'DB'PACKER 2.688 GM LIFT, 8,646.3 6,396.9 43.26 SBE SEAL BORE EXTENSION 32-26 2.688 6.110 8,688.7 6,427.8 43.30 NIPPLE CAMCO'D'NIPPLE 1.812 8,723.0 6,452.8 43.34 SOS BAKER SHEAR OUT SUB 1.995 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl ` Top(M(B) OMB)) (') Description Comment Run Date ID(in) Jr 9,088 6,718.1 44.06 FISH 2-Cones off Bit Lost downhole(4 12"Cones) 6/16/1988 1.000 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(NOMB)Btm B) (MKB) (ftKB) Zone Dab Oh- Type Comment ' 8,886 8,906 6,571.3 6,585.9 A-3,30-17 5/23/1989 12.0 APERF 1-11/16"EnerJet;60 deg phasing 8,915 8,940 6,592.4 6,610.7 A-2,30-17 5/23/1989 12.0 APERF 1-11/16"EnerJet;60 deg phasing 8,972 8,992 6,634.0' 6,648.6 A-1,30-17 6/17/1988 6.0 IPERF 3-3/8"Csg Gun;60 deg phasing GAS LIFT• -( m.e0 Notes:General&Safety 8'503 L. End Date Annotation 5/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUssaCTI.eleON, a SEAL ASSY, 8,042 PACKER.8,643 50E,8,610- NIPPLE,8.680 -43 • SOS.8,723 /Z- APERF. -. 8 880-9.906 -. AP-ERF, - 8,815-8,940 PERF, Mandrel Details 0,972.8,992 • - Top Depth Top Port (TVD) Inel OD Valve Latch Sin TRO Run Stn Top(MO) (MKS) P) Make Model (In) Sery Typo Type (In) (pal) Run Dab Can... 1 3,035.9 2,564.1 46.47 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/16/1997 2 5,432.2 4,187.4 47.94 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/29/1993 3 6,834.0 5,132.7 46.45 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 2/21/1994 4 7,552.2 5,625.4 46.79 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 729/1993 5 8,110.2 6,013.3 45.03 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 10/24/2000 6 8,602.8 6,365.2 43.22 McMu...FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/16/1997 FISH,0088- - :2 LINER, 8,230-0,107 TD,0,263 W U r w En a (.9 CL IL N I- a D U 0 N LU to CC -t CL C o to • Lu c, a ¢ Lr, E a -a o a a) w m H O LL )n cc s a t I- N ^-tf LL., CV ~ itr 0 JI -. J 7 i [) r+ c-, lllI „ 36ap r .-1 fJ .L-J CO . C� C. Ur •! V C I I 1 i I I I I c � - c 2. S r ta U C eaI \.......... .............,,,..... I.......m 3 GO 1 Ii d}i a'7 `� 0rr: I w ....-f \ 7:-. 2 En I . O O t O m � o Y .. M e-- N N tff a a r SSo= ur Ur E 93 1 I Q, Q ' QQkuyy IC 03 O CJ c_D v C_J . . c, Q Q li Q u u Y H �• u_ T Q (5 O U U U U LJ U y N U Ur U Ur CJ Ur L to O C) C`r V t, �1!WV. a) es T"0 ISd N O w Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the Original file, may be scanned dudng the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, NoFFype TOTAL PAGES: NOTES: ORGANIZEO BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing E] OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: ISl Staff Proof PROOFED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE. I$1 Scanned (done) SCANNEOBY' ~EVERLY BREN VINCEN] SHERYIQ LOWELt I$1 RE SCANrJE0 BY' ~ BR£N VINCEr~'i SHERYL M~-~IA LOWELL -- Coeneral Notes or Comments about this file PAGES: Ouality Checked Revlt401Sr..~nn~'~d ¢ PT i e6o zyo Regg, James B (DOA) From: NSK Problem Well Supv[n1617 @conocophillips.com] Sent: Tuesday, October 01, 2013 8:51 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Dethlefs, Jerry C; NSK Problem Well Supv Subject: KRU state witnessed MITIA's: 1Q-11 (PTD#1841990); 2C-05 (PTD#1830990); 2T-28 (PTD# 1950920); 2U-07A(PTD#1850910); 30-17 (PTD#1880290); 30-05 (PTD#1861960) Attachments: MIT KRU 1Q-11 9-27-13.xls; MIT KRU 2C-05 09-27-13.xls; MIT KRU 2T-28 09-27-13.xls; MIT KRU 2U-07A 9-27-13.xls; MIT KRU 30-17 9-27-13.xls; MIT KRU 3Q-05 09-27-13.xls Please find attached forms for recently performed MIT's at KRU. The initial test pressures for well 3Q-05 (PTD #1861960) were not recorded before rigging down the pump truck and sending it to the next location, in an attempt to efficiently progress the work. Unfortunately, due to that the test pressure dropped below the lower threshold, despite passing parameters. This well was called a fail and will be scheduled for a re-test at first opportunity, and an inspector will be invited to witness. Please let me know if you have any questions. Thanks, Ron Wilson / Roger Mouser CPAI Field Supervisor, DHD Office: 659-7022 Cell: 943-0167 Pager: 659-7000; #121 OH DEL I 1 ti • • - - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(Dalaska.gov; AOGCC.Insoectors(D.alaska.gov; phoebe.brooks @alaska.aov chris.wallace(8 alaska.00v OPERATOR: ConocoPhillips Alaska,Inc °l//i3 FIELD/UNIT/PAD: Kuparuk/KRU/30 Pad DATE: 09/27/13 OPERATOR REP: Byrne/Freeborn AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 30-17 ' Type Inj. G ' TVD '6,395' Tubing -3,600 - 3,600 -3,600 `3,600 Interval 4 P.T.D. 1880290 / Type test P Test psi '1598.75 Casing '525 2,500 2,470 2,470 P/F P Notes:Waived witness by Chuck Scheve. OA 240 260 - 260 260 - Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 30-17 9-27-13(2).xls ~ MEMORANDUM TO: Jim Regg ~~~ ~(~~(pc~ P.I. Supervisor ~ FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oif and Gas Conservation Commission DATE: Wednesday, July O1, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-17 KUPARLJK RIV LJNIT 30-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV iJNIT 30-17 Insp Num: mitCS090630093504 Rel Insp Num: API Well Number: 50-029-21795-00-00 Permit Number: 188-029-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/27/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 30-17 Type Inj. G~ T~ 6390 jA 900 2480 ~ 2460 2460 ~ P.T.D 1880290 TypeTest SPT Test psi 1597.5 =~ QA 60 60 60 60 Interval 4YRTST P~ P ~ Tubing 3900 3900 3900 3900 Notes: ,'~ ~(1C`t~ 1 rx•; .~t~,~ ~ t " .. ~..~ 4 ~ f4 b . . . Wednesday, July O1, 2009 Page 1 of 1 ~~ ~. ~F.~' i3 `~ It1~Ji ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~N~~ ~~~ a ~ 2~~8 Well Job # Log Description NO 4852 ~p~r,, ,: Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 08/28/08 2W-11 12100437 PROD PROFILE b~, - 08/06/08 1 1 1 F-14 12096521 PROD PROFILE - ~ 08/08/08 1 1 1Y-05 12096520 LDL / ~ 08/07/08 1 1 30-02A 12097415 SBHP SURVEY ~ "~-- a 08/10/08 1 1 1 E-114 12096524 INJ PROFILE - 08/10/08 1 1 2A-24 12097417 PROD PROFILE - ~ ~- 08/11/08 1 1 1G-10A 12097418 PROD PROFILE ' 08/12/08 1 1 1 L-14 10228963 INJ PROFILE C} ~- f v 08/12/08 1 1 30-17 11966273 SBHP SURVEY - 08/15/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 5t` _-- -- ---__- a • • ~f> ~~~ ~ _ ~~ A{aska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2007 NIr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~;;~ ~C~~ ~: ~ 2007 Enclosed please find a spreadsheet.with.aGistof wells from the I~uparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. Asper 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 top jobs were pumped on October 19, 2007 and the corrosion inhibitor/sealant was pumped on October 28, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor .r ;~ ~ ~i {~ t ~~~. y~ • Surface Casing by Conductor Annulus Cerrtent, Cc~~°r®sl~n inhlblt®r, Sealant T®p~~ff Report of sundry Operations (10-404) Kuparuk Field naf® 10/28/2QQ7 Well Name PTD # Initial .top of cement Vol. of cement um ed Fina{ top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 30-7 188-077 26' 4.2 10" 10/19/2007 3 10/28!2007 30-17 188-029 49'8" 7 16" 10119/2007 5 10/28/2007 1 D-11 199-072 4'1" n/a 4'1" n/a 16.5 10/2$/2007 ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reaa -'7"") 00 1- ""-. P.I. Supervisor '"\F-fi DATE: Wednesday, June 14,2006 SUB.JECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA fNC 30-17 KUPARUK RIV UNIT 30-17 Src: Inspector n~ "oryq -\lo FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,:1BJ?-- Comm Well Name: KUPARUK RIV UNIT 30-17 Insp Num: mitJCr060613132926 Rei Insp Num API Well Number 50-029-21795-00-00 Permit Number: 188-029-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 30-17 ¡Type InJTG I TVD 1--- 6391--TIA-¡--"2i60-T--~ I 2800J--Z800 ---¡-----r------- P:T:JIsiõ2~ ITypeTest I SPT Test psi 115977~ i OA jIsõ~;oo _+--,""-+_200--j-- ---J~~~ Interval ._ 4YRT~~__PIE____.~_______!~bing l_~~_~_.~_~650 i !650 _h~.~--L___ ¡ Notes .5 bbl's pumped for test. SCANNED JUN 2 V"l 2005 Wednesday, June 14,2006 Page 1 of 1 S~T ~:~COA~S~ ; 5- 1-99 ; 8:51PM ; K P$/Wi~II.S/CNST/PROJ-, ARCO Alaska, Ino. Kuparuk Operations Post Olfioe Box 196106 Anchorage, Ala~lm 99519-6105 30-17 Monitoring Report o T CHOEE 907 276 7542;# 4/ 8 SI DATA OAS WATF/{ GAS C 7" 10# LIFT INJ INJ H M O AMB CSO CSG VOL VOL VOL R I D 04/01 A SW 50 2611 61 -21 2900W 300 0 1080 0.000 0000 0 04102 A SW 04/03 A SW 04/04 A SW 04/05 A SW 04/06 A SW 50 2791 62 -13 2900W 300 50 2785 62 -8 2900W 300 50 2783 62 -11 2900W 300 50 2783 59 -9 2900W 300 50 2788 59 -4 2900W 400 0 891 0.000 0000 0 0 885 0,000 0000 0 0 844 0.000 0000 0 0 870 0,000 0000 0 0 878 0,000 0000 0 04/07 A SW 04/08 A SW 04/09 A SW 04/10 A S~ 04t1~ A SW 50 2793 65 2 2900W 400 50 2795 66 1 2900W 400 50 2797 66 -5 2900W 400 50 2798 64 -9 2900W 400 50 2799 63 -8 2900W 400 0 857 0,000 0000 0 0 883 0.000 0000 0 0 883 0.000 0000 O' 0 880 0.000 0000 0 0 ~79 0.000 0000 0 04/12 A SW 04/13 A SW 04/14 A SW 04/15 A SW 04/16 A SW 50 2'/9~ 62 -10 2900W 400 50 2796 62 -16 2900W 400 50 2785 62 -13 2900W 400 50 2805 61 -6 2900W 400 50 2804 62 2 2900W ~00 0 877 0.000 0000 0 0 8?4 0.000 0000 0 0 857 0.000 0000 0 0 900 0.000 0000 0 0 870 0,000 0000 0 04/~7 A SW 04/18 A SW 04/19 A SW 04/20 A SW 04/21 A SW 50 2756 66 6 2900W 400 50 2784 65 1] 2900W 400 50 2788 61 8 2900W 400 50 2783 59 8 2900W 400 50 2785 6~ 3 2900W 400 0 785 0.000 0000 0 0 863 O,O00 0000 0 0 852 0,000 0000 0 0 845 0,000 0000 0 0 846 0.000 0000 0 04/22 A SW 04/23 A SW 04/24 A SW 04/25 A SW 04/26 A SW 50 2789 66 -6 2900W 400 50 2789 64 -4 2900W 400 50 ~790 67 -7 2900W 400 50 2783 66 -5 2900W 400 50 2781 64 -6 2900W 400 0 846 0.000 0000 0 0 838 0.000 0000 0 0 838 0,000 0000 0 0 833 0.000 0000 0 0 821 0.000 0000 0 04/27 A SW 0 824 0.000 0000 0 04/28 A SW 0 818 0.000 0000 0 04/29 A SW 0 817 0.000 O000 0 04/30 A SW 0 793 0,000 0000 0 ~e~ to Blai~ Won~zell, 8~a~e o£ ~aska (276-75&2) ~ 5/X/99. ARCO Alarm. Inc. la . 50 2778 62 -4 2900W 400 50 ~777 63 0 2900W 400 50 27'77 63 3 2900W 400 50 2768 64 19 2900W 400 SENT BY :ARCO ALASKA ; ~- 9-/t9 ; 9:O1A~I ; KPS/WF.I.IS/CNST/PROJ-, ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 907 276 7542'# 4/ 7 30-17 Monitoring Report Z S O T CHOKE N A O1{ DATE E T % -- ---- 8I DATA GA9 WATiBR GAS 7" 10" LIFT INJ INJ H AM~ CSG C~G VOL VOX, VOL R FTP FTT TEMP PSI PSI MSCF BBLS MMSCF S 02/01 A SW 02/02 A SW 02/03 A SW 02/04 A SW 50 2?Al 59 -38 2900W 200 50 2767 59 -33 ~900W 200 50 2770 59 -23 2900W 250 50 2773 59 -30 2900W 250 0 1092 O.OOO @O00 0 0 1385 0,000 0000 0 0 1144 0,000 0000 0 0 1144 0.000 0000 0 02/05 A SW 02/06 A SW 02/07 A SW 02/08 A SW 02/09 A SW 50 2772 61 -35 2900W 250 50 2790 59 -36 2900W 250 50 2773 58 -31 2900W 250 50 2773 57 -38 2900W 200 50 2773 58 -45 2908W 200 U 115'1 0,000 0000 0 0 1188 0.000 0000 0 0 1142 0.000 0000 0 0 1144 0.000 0000 0 0 1144 0.000 0000 0 02/10 A SW 02/11 A SW 02/12 A SW 02/13 A SW 02/14 A SW 50 2756 58 -43 2900w 200 50 2772 59 -24 2900w 200 50 2'771 61 -10 2900W 200 50 277% 62 -15 2900W 200 50 2769 60 -15 2900W 200 o 11o~ O.000 0000 0 0 1138 0,000 0000 0 0 1117 0_000 0000 0 0 1124 0.000 0000 0 0 1123 0.000 0000 0 02/15 a SW 02/16 A SW 02/17 A SW 02/18 A SW 02/19 A SW 50 2771 62 -19 2900W 200 50 2773 65 -15 2900W 200 50 2773 65 -17 2900W 200 50 2773 65 -4 2900W 200 50 2777 65 -3 ~900W 200 0 1133 0,000 0000 0 0 1116 0.000 0000 0 0 1111 0.000 0000 0 0 1113 0.000 0000 0 0 1135 0,000 0000 0 02/20 A SW 02/21 A SW 02/22 A SW 02/23 A SW 02/24 A SW 50 2781 64 -7 2900W 200 50 2755 63 -10 2900W 200 50 2777 60 -5 2900W 200 ~(] ]7RI 61 -13 2900W 200 50 2768 62 -14 2900W 200 [[3U O,O00 0000 0 10~9 0.000 0000 0 1132 0.0(}0 0000 0 1132 0.000 0000 0 1088 O.OOO 0147 36 0~t25 A SW 02/26 A MW 02/27 A SW 02/28 A SW 50 2769 62 ..,6 2900W 50 2782 61 -10 2900W 380 50 2760 62 -10 2900W 380 50 2740 64 -16 2900W 380 0 1124 0,000 0000 0 0 1151 0,000 0000 0 0 1070 0,000 0000 0 0 1071 0.000 0000 0 SHUT-IN CODE 36 = FLOW LIATE MAINTENANCE Fmxs~ to Blal= Won~e11, Bt~te oZ &1ask& (276-9542) on 3/Sl99. AH(JO Alaal~a. Inc. la a ~ul~ldlW'y of Allantlc Riddivld C~mpa.¥ DEC 1 9 2002 MEMORANDUM TO: Camille Taylor Chair State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 28, 2002 THRU: Tom Maunder ~_~_~._ P.I. Supervisor/TM//' 'Il ~,,--0')..~ SUBJECT: Mechanical Integrity Tests PAl ~30 multiple FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ~ WellI 30-14 ITypelnj.I G I T.V.D. I 6420 I Tubing'l 3700I~,oo I I ~00 Ilntervall 4 P.T.D.I 1880390 I Type testI P I Testpsil 1605 I CasingI 1500I 2080I 2080 I 2080 I PIE I P Notes: we,I 30-16A I Type,nj.I G. I ~.v.o. I~ I"~-ubingl~ I~0 I~0 I~0 I,nterva, I 4 "P.T.D.I 1880430 ITypetestl P ITestpsil 1581 I Casingl 1880125401254012520I P/F I_.P Notes: WellI 30-17 I Typelnj. I G I T.V.D. I 6391 I Tubingl 3850 I I I ~,,0 I lntervall 4 ' P.T.D.I 1880290 ITypetestl 'P ITestpsil 1598 ICasingI 2075I 2450I 2450I 2450I P/F I _PP' Notes: P.T.D. I Type test I Notes: P.T.D. I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) Test's Details Page 2 of 2. As noted on the preceeding test report forms, no failures were observed. Jon Arend (APC) was the PAl company rep. M.I.T.'s performed: 3 Attachments: none Number of Failures: _0 Total Time during tests: 2 cc: none MIT report form 5/12/00 L.G. 020628-mit(2) kru 30 js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 59 feet 3. Address ' Explorato~,_ 7. Unit or Propert~ name P. O. Box 100360 Strafigraphic_ Anchorage, AK 99510-0360 ... ServicLX Kuparuk Unit .. 4. Location of well at surface 8. Well number 1126' FNL, 3204' FEL, Sec. 22, T13N, R9E, UM (asp's525711, 6021692) 30-17 ,At top of productive interval -~ 9. Permit number / approval number 1302' FNL, 1808' FWL, Sec. 27, T13N, R9E, UM 188-029/ ,At effective depth 10. APl number 50-029-21795 At total depth 11. Field ! Pool 1645' FNL, 3448' FEL, Sec. 27, T13N, R9E, UM (asp's 525498, 6015892) Kuparuk Oil Pool 12. Present well condition sUmmary 'rotal depth: measured 9263 feet Plugs (measured) true vertical 6844 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 175 sx AS I 115' 115' ~URF. CASING ' 2670' 9-5/8" 9o0 sx AS m 2729' 2348' PROD. CASING 8559' 7" 51o sx TLW & 490 sx Class G 8618' 6376' LINER 871' 5" 250 sx Class G 9107' 6732' LINER Perforation depth: measured i', i, RECEIVED ubing (size, grade, and measured depth) ~i :ii ? :. i! iii ?!; i ackers & SSSV (type&measured depth) ~ iii{iii?i ?ii}!!!ii:iii' iiliii !i!ii!i !!i ii:iiii !)i?:'i~~~i!?i!!!i:iiii!:,!i!!iiiii 13. Stimulation or oement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure , 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attaohments Copies of Logs and Surveys run ~ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 ~,gned ~,,~, ~, f..~~~.~.~-- ~' Title Production Engineering Supervisor Date j~ ~ ~/. ~__~.~ ,Jeff A Spencer, Prepamcl by Robert Christensen 659-7535 Form 10-404 Rev 06/15/88 · SUi~MIT IN DUPLICATE ' Mar-1 requeet ll'10. Allot casing_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Repalr weft_ Plugg~ng _ P- O. Box 100360 1126' FNL, 3204' FEL, Sec. 22, TI3N~ RgE UM A~ ~p of productive/nb~ ' 1302' FNL, 1808' ~L, Sec. 27, T13N. RgE, UM At effaet~ depth 1~5' FNL. 182g' ~L, Sec. ~7, ~13N, RgE, UM At total dep~ UM well summary Total depth: measured true vertical EffectiVe depth; measured lrue vertical Casfn~ Length CONDUCTOR 115' SURF. CASING 2670' PROD, CASING 85~9' LINER 871' ~INER (asp~5~5711, 6021692) Re.enter suspende(l well _ 33me exlenelon _ Stim,l~te _ e~) RKB 59 feet / name Unit 30-17 number / approval number 88-029 number 795 Oil Pool 9263 feet Plugs (meaeured) 6844 feet g088 feet Junk (measured) 8718 'feet Size Cemented 16" Measured Deplh True vertical 17~ ~xAS I 1 15' 9-5/8" SO0 ~xAS ,~ 1 15' 2729' 7" s~o sxTLw & 4so sx Class G 8618' 2348' S" ~SO ~x cl~ e 6376' 9107' 6732' Pertoration depth: 8886'8906',8915-8940,,8972.8992. 6571-6586', 6592-6644', 6634-864~ RECEIVED Fablng (size, grade, and 131easured depth 2-7/8",6.5~r, J-55 Tbg ~ 8149' MD; ~3/8",4.7~, J-55 ~g ~ 871g. MD. ' ,. , (~pe & measured do .... . ";I., , ~V (~pe & me~ P~) BAKER 'DB' ~ 8638' .... ~USpended -~ ~_ O~ginal Skned By - , Commissioner Da' ~ / ' ~ /~ ~ Form 10-403 Rev 08/75/88 · ORIGINAL (uparuk 10-403 requeSt 3A-02 & 30-17 Subject: Kuparuk 10-403 request 3A-02 & 30-17 Date: Mon, 11 Mar 2002 23:17:29 -0900 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom_maunder@admin.state.ak, us CC: "CPF3 Prod Engrs" <n1223@ppco.com> Tom I have attached the 10-403 applications and the supporting documents for 3A-02 and 30-17. I have also faxed you the signed 403 copies as timing for approval is getting tight. 3A-02 is an injector that has a tubing leak. You gave Jerry an email apProval to proceed with the patching procedure. Initial plans were to run the patch this week, but the job needed to be bumped and should be run sometime next week. (See attached file: 3A-02 Sundry Discussion 03-11-02.doc)(See attached file: 3A-02 Sundry 03-08-02.xIs)(See attached file: 3A-02.pdf) 30-17 is an injector that was thought to have tbg x IA communication. After extensive diagnostics and AOGCC permission to inject MI for 1 month there is no indication of communication. The approval for temporary MI injection ends on Thursday (3/15). We are asking to place this well on normal status with nO restrictions. Instead of going through the process of converting. everything back to water injection we would like to continue MI injection · until the 403 is reviewed and a decision is made. (See attached file: 30-17 Sundry Discussion 03-11-01 .doc)(See attached file: 30-17 Sundry 10-403 03-08-02.xls)(See attached file: 30-17.pdf) Peter Nezaticky Phillips Problem Wells ['-~3A-02 Sundry Discussion 03-11-02.doc Name: 3A-02 Sundry Discussion 03-11-02.docl Type: WINWORD File (application/msword) Encoding: base64 ~3A-02 Sundry 03-08-02.xls~ Type: EXCEL File (application/msexcel)t '~' IEncoding: base64 .t ~- ..................................... i Name: 3A-02.pdf L~3A-02.pdf~ Type: Acrobat (application/pdf) :,.:.,~. ........ _.,.,_.,~ ........ .. ................... 1.,E~n.co...,~!,n,,?....b.ase.6? ................................................................... ................................................................... ~ ............................ : ............ ;-'"* ................................................................................... Name: 30-17 Sundry Discussion 03-11-01 .doc ID30-17 Sundry Discussion 03-11-01.doc Type: WlNWORD File (application/msword) E.n.c.o..d!ng:....,b.as?.64 30-17 SUndry 10-403 03-08-02.xlsI Encoding: base64 Name: 30-17 Sundry 10-403 03-08-02.xls Type: EXCEL File (application/msexcel) L~30-17.pdft Type: Acrobat (application/pdf) ................................................................ I..~.n~c_od.i_ng!_bas. e~.4~ .......................................................................... 3/12/02 7:32 AM Phillips Alaska, Inc. Kuparuk Well 30-17 SUNDRY NOTICE 10-403 CONVERSION REQUEST 03/11/02 The purpose of this Sundry Notice request is to change the permitted service for Phillips Kuparuk well 30-17 and update the status from the previously issued Sundry #398-180. The Sundry restricted the well to water-only service and 2-year MIT' s after a report of T x IA communication. Prior to consideration of a workover to repair the suspected T x IA communication an effort has been made to identify and repair the leak path../Diagnostics have recently been completed, none of which indicate communication is present[ The wellhead packoffs are competent, MIT's show/casing and tubing integrity, and a video log was run in the tubing which did not find a leak. ~ AOGCC approval was obtained for temporary MI injection to test for annular communication in MI service. MI injection was started 02/15/02 and indicates no annular communication is evident Phillips requests approval for well 30-17 permitted service to be changed from water injector to WAG injector, with no additional requirements assigned beyond those of normal injection wells. Should communication problems become evident in the future the AOGCC will be notified and appropriate steps taken at that time. ~ NSK Problem Well Supervisor PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 30-17 SSSV (1801-1802, -- OD:2.875) TUBING (0-8149, OD:2.875, ID:2.441) PBR (8635-8636, OD:2.375) PKR (8638-8639, OD:4.151) NIP (8684-8685, OD:2.375) SOS (8718-8719, OD:2.375) Pen' (8886-8906) Pen' (8915-8940) Pen, (8972-8992) - KRU 30-17 APh!500292179500 SSSV Type: I Baker 'FVLD' Annular Fluid:i Reference! Log:l Last Tag: 9046 Last Tag 4/21/00 Date: i i Description r'Size J CONDUCTOR i 16.000 SURF. CASING 9.625 i PROD. CASING 7.000 LINER I 5.000 1 T~ubing Strings - All D~escription Size TUBING 2.875 TUBING 2.375 Perforations Summary Interval TVD 8886- 8906 6571 - 6586 . 8915- 8940 6592- 6611 i A-2 8972 - 8992 6634 - 6649 i A-1 sGaS Lift Mandrels/Valves ti MD TVD~ i Man ~l Err Type 1 303612563 MMH FHMO ~ i543214187 MMH FHMO 3 6834i5133 MMI~ I 4 '~7552 5625 MMH FHMO 5 8110 6013 MMH FHMO Well TYPe: IN_J___ Angle (~ TS: 43 deg @ 8750 iQrig Com~n: 4_/1_5/88 . i Angle @ TD: 44 deg @ 9263 Last W/O: Rev Reason: New Valve date; . by JWP Ref Log Date: Last Update: 11/8/00 Zone A-3 Top 8236 TD: 9263 ftKB Max Hole 49 deg @ 4300 Angle:. BoSom TVD Wt Grade 115 115 62.50 H-40 2729 2348 36.00 J-55 8618 6376' 26.00 ' J-55 _ _ . 9107 6732 18.00 L-80 Top Bottom 8149 Thread 8149~ 8719 TVD Wt Grade Thread 6041 6.50 J-55 8RD AB MOD _ . 6450 4.70 J-55 8RD AB MOD _ . Stat~--SPF~-- Date' Typei Comment 2~--12 ' 5/23/89 'APERF~ 1-11/16" EnerJet; 60 deg . phasing · . 25 12 5/23/89 APERF 1-11/16" EnerJet; 60 deg phasing ! -~20-'-6 ' 6/17/88 ' PERF'3-3/8"Csg Gun; 60deg _ ............ phasing V Mfr V Type V OD Latch--' POrt r T'R0 Date Vlv DMY 1.0 DMY 1.0 . . . DMY 1.0 DMY 1.0 ._ . DMY 1.0 BK DMY 1.0 BK Descri priori . i 6 8603 6365 Merla TMPDX Merla ~ OL0t_ther (plugs, equip;, etc.)_- JEWELRY Depth TVDi T pyp~ 1801 1693 i SSSV 'Baker'FVLD' 8635 6389, PBR rBaker 8638 6391I PKR B~er-'DB' 8684 6424 NIP 8718 ¢ 6449 I SOS CamcOBaker 'D' Nipple NO GO 8719 r6450' ~~ Fish - FISH Depth Description ~ 2 - Cones off Bit BR' d.000 BK 0.000 BK BK 0.000 0.000 0.000 0.000 Comment Lost downhole (4 1/2" Cones) Run _l C~nt 0 '- 1/16/97 0 7/29/93 0 2/21/94 0 7/29/93 0 10/24/00 0 1/16/97 ID 2.310 2.300 2.688 1.812 i 1.995 1.995 ,Jan-1 I-OZ OS:lSpm From-KUP WELLS CHST PROJ +gO?-85g-?314 T-$40 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type ofrequest Abandon_ Suspend_ Operational shutdewn ,_ Re-enter suspen~e~l well _ A~ter casing _ Repair well _ Plugging _ Time extension _ ~lmulate _ Change approved program _X Pull tubing _ variance _ Perforate _ Other_ 2, Name of Operator Phillips Alaska, Inc, 3. Address P. O. Box 100360 Anchorage, AK 99510.0360 5, Type of Well: Developmen! Exploratory ~ $lrattgraphlc Servlce__X 4. Location of well at surface ,~' vf v/ 1126' FNL, ,32_04' FEL, Sec. 22, T13N, ROE , UM At top of productive interval 1:202' FNL, 1808' FWL, Sec. 27, T13N, RgE, UM At effective depth 1625' FNL, 1829' FWL, Sec, 27, T13N, RgE, UM At total dopth ~ 646' FNL, 9448: FEL, Sec, 27, T1 ~N, RgE, UM (asp~$£5711, 6021692) (aSp's 525~98, 12, Present well condition summer Total depth: measured 9263 feet ''/' ._Plugs (measured) ...................... true vertical .. . 6844 feet Effective depth: measured 9088 feet Junk (measured) true vertical 6718 feet Casing Lellgth Size Cemented CONDUCTOR 116' 16" 176 ex AS I SURF, C;ASlN(2 2670' 9-$/8" O00 sx AS PROD. CASING 85S9' ?" 510 ax TLW & 490 sx Cla..w~ LINER 871' 5" 2s0 ~ Ciasa LINER 6, Da~Jm elevstion (DF or KB feet) RKB $~a feet 7. Unit or Property name Kuparuk Un!t 8. Well number 30-17 9. Permit nurnb.,er,~,approval number 1 @8-029 %/ 10. APl number 50-029-21795 x/ 11, Field / Pool Kuparuk Oil Pool Measured Deptll 115' 2_729' 8618' 9107' True vertical Depfll 1 2348' 6376' 67,.12' Perforation depth: ~easured 8886,8906', 8915-8940', 8972-8992' true vertical Tubing (size, grade, and measured d~pth Packers & $$$V (b/ps & measured depth) 6571-6586',6592-6644',66S4-6649' 2-7/8",6.$#, J-55 'POg ~ 8149' MD; 2-3/8",4.7#, J-55 'fbg ~ 871e' MD. BAKER 'DB' @ 8638' MD, BAKER 'FVLD' @ 1801' MD, 13, Attachlllellts Description summary of proposal _~X Detailed operations program ~ BOP sketch __ 14, Estimated date for commencing operation i ASAP 16. if proposal was verbally approved Oil ~ Name of approver Date approved . Service 17, I hereby certify_that the foregoing Is Ipae-~d corre~ lo Iilo boa! el my krlowledge. FOR'COMMISSION USE 15. Status of well ~lae~Ifloatton as; Gas ~ ...Water. Injection Suspended __ Questions? Call Jerry Dett~lef~ 659--7~24 · ' ~ Conditions of approval: Notify Commission so representative may Witness Pl"g Integrlty__ BOP ToSt __ Location oiearance __ , Mechanical Intemi~ Te~ ~ Subse~ent 10~ required Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 30-17 (PTD 1880290) SUNDRY NOTICE 10-403 VARIANCE REQUEST 01/11/02 The purpose of this Sundry Notice request is for approval to temporarily put Phillips Kuparuk well 30-17 on gas injection (WAG service). There is an existing Sundry (#398-180) from 1998 restricting it to water-only service and 2-year MIT's after a report ofT x IA communication. The well has had a history of the IA tracking the tubing pressure while on injecton and has been on monthly reports to the AOGCC. 30-17 is in a favorable injection pattern to benefit from MI injection. Prior to consideration of a workover to repair the T x IA communication an effort has been made to identify and repair the leak path. Diagnostics have recently been completed, none of which indicate communication is present. The wellhead packoffs are competent, MIT's show casing and tubing integrity, and a video log was run in the tubing which did not find a leak. Phillips would like to put the well on MI injection to determine if a leak still exists. The following is a summary of the diagnostics performed: 9/26/01: Wellhead packoff tests passed. 9/25/01: Video Log tubing for leak detect. Could not establish leak with N2 displaced tubing and 3000 psi IA pressure. 01/13/01: Bleed IA from 1700 psi down to 1200 psi. IA increased to 1300 psi in 1 month. 10/26/00: CMIT T x IA Passed ~ 3000 psi (not witnessed) against tubing plug. 10/24/00: Gaslift valve change, MIT-Tubing ~ 3500 psi Proposed Action: 1. Receive AOGCC approval to put 30-17 on MI injection to test the well for T x IA communication; 2. MI injection not to exceed February 28, 2002 without review and approval by the AOGCC; 3. Return the well to water-only injection by the end of February, or prior to that if T x IA communication is confirmed; 4. Continue to report monthly on the Failed MIT Report to the AOGCC; 5. If T x IA communication is not found submit a separate 10-403 for permanent WAG injection status. SSSV (1801-1802, ---- APl: 500292179500 j Wel Type: INJ Angle ~ TS: 43 dog ~ ~8~ OD:2.875) ~Type: Baker'FVLD' OdgCompltn: 4/1588 · AOge~TD 44 dog (~ 9263 Annular Fluid: Last W/O: Rev Reason:New Valve date; by JWP Reference Ref Log Date: Last Update: 11/8/00 Log: L_~( T~g; ~ . TD; 9263 ftKB ~ Last Tag 4/21/00 Max Hole 49 dog @ 4300 TUBING (0-8149, OD:2.875, ID:2.441) PBR (8635-8636, OD:2.375) PKR (86384639, NiP (86844685, OD:2.375) SOS (87184719, OD:2.375) Perf (88864906) Perf (8915-8940) Perf (89724992) Phillips 30-17 Sundry Subject: Pl~illips 30-17 Sundry Date: Fri, 11 Jan 2002 16:18:18 -0900 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom maunder@admin.state.ak, us CC: "NSK Problem Well Supv" <n1617@ppco.com> Tom' Attached is the supporting documents for 30-17 10-403 I just sent you by fax. Let me know if you need more information. If you approve the Sundry, we would like to get this on gas injection sometime this coming week. Thanks! Jerry Dethlefs Phillips Problem Well Supervisor(See attached file: 30-17.pdf)(See attached file: 30-17 Sundry 10-403 01-11-02.xls)(See attached file: 30-17 10-403 Discussion 01-11-02.doc) 30-17.pdfI Type: Acrobat (application/pdf) ----I.o.u,_Encoding: base64 ¢~__~30-17 Sundry 10-403 01-11-02.xls Name: 30-17 Sundry 10-403 01-11-02.xls Type: EXCEL File (application/msexcel) Encoding: base64 30-17 10-403 Discussion 01-11-02.docii Type: WINWORD File (application/msword) ~ i! Enc0ding· base64 1 of 1 1/15/02 10:39 AM .Jan-11-0Z 05:1?pm From-KUP WELLS CNST P~OJ +gO?-$$g-?$14 T-$40 P.01/02 F-g?2 Problem Well Supervisor 907-6S9-7224 Fax To: Tom Maunder From; Jerry Dethlefs Fax.' 27&7542 Pa~les: 2 Phone-" 279-1433-250 Date; 01/11/02 Re: ~tO-17 Sundry 10-403 CC: [] Urgent E] For Review Fl Please Comment [] Please Reply [] Plesse Recycle Tom: Attached is a signed Sundry 10-403 variance request for Phillips Alaska, Inc., well 30-17, ! have emailed supporting documents for this Sundry so they will be easier to read. Let me know if you need the original hardcopy of this and I will snail-mail it. Thanks. Jerry Dethlefs Attachment 1 Request for Variance Kuparuk Well 30-17 As per Area Injection Order No. 2, Rule 7, ARCO Alaska is hereby notifying the Commission of a slight pressure communication between the tubing and casing in Water Injection Well 30-17. As set forth in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exemPted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As such, continued injection will not endanger any Underground Source of Drinking Water (USDW). Well 30-17 began injection on August 22, 1989 after being converted from an oil producer and is currently injecting approximately 924 BWPD at an average surface injection pressure of 2850 psi. Diagnostic work has been unable to establish any leak rates. The well has pasSed a simultaneous tubing x casing test on 5/26/94, witnessed by John Spaulding. This test shows that there are no external casing leaks in this injection well and injection fluids are confined to the Kuparuk River Sands. Casing and tubing pressures will continue to be monitored and reported as per Area Injection Order No. 2, Rule 4 to ensure that the casing pressure does not exceed 70% of the casing's minimum yield strength. MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend __ Operation Shutdown __ R~enter suspended well __ Alter casing __ Repair well __ Plugging _ Time extension __ Stimulate __ Chan,qe approved pro,qram Pull tubin,q __ Variance _~X Perforate -~ Other ~ 2, Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska~ Inc. Development ~ 58' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic __ Anchoracje, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1127' FNL, 2073' FWL, Sec 22, T13N, R9E, UM 30-17 At top of productive interval: 9. Permit number: 1302' FNL, 1808' FWL, Sec 27, T13N, R9E, UM 88-0029 At effective depth: 10. APl number: 1525' FNL, 1829' FWL, Sec 27, T13N, R9E, UM 50-029-21795-0O At total depth: 11, Field/Pooh 1646' FNL, 1842' FWL, Sec 27, T13N, RgE, UM Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 9263 feet Plugs (measured) true vertical 6844 feet Effective Depth: measured 9088 feet Junk (measured) true vertical 6718 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 16" 175 sx AS I 11 O' 11 O' Surface 2729' 10-3/4" 900sx AS III 2729' 2348 Production 8618' 7" 510 sx TLW & 8618' 6376 490 sx Class G Liner 871' 5" 250 sx Class G 8236'-9107' 6102'-6732' Perforation Depth measured 8972'-8992', 8886'-8906', 8915'-8940' true vertical 6634'-6648', 6571 '-6586', 6592'-6611' Tubing (size, grade, and measured depth) 2-7/8" and 2-3/8", J-55, Tubing @ 8719' MD.. Packers and SSSV (type and measured depth) Baker DB Packer @ 8638' MD; Baker FVLD SSSV @ 1801' MD. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch ~ 14. Estimated date for commencing operation 15. Status of well classification as: Variance to continue iniection Oil _ Gas __ Suspended __ 16. If proposal was verbally approved Name of approver Date approved Service__. WAG 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Signed ~ .~_~ ~ ,-~'~ .~ Title: Wells Superindendent Date ~,/~- -~//(~/~:' I Conditions of approval: Notify omission so representitive may witness Approval Plug integrety __ BOP test__ Location clearance __ Mechanical integrety test__ Subsequent form required 10- Form 10-403 Rev 06/15/88 Oavid W~ Johnston 00~ SUBMIT IN TRIPLICATE STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION C, OlV~kS~ION REPORT OF SUNDRY WELL OPERATIONS iown m__ Stimulate ~ Plugging . Perforate m Alter casing Repair well Other 1. Operations Performed: Pull tubing 2. Name of Operator Operation Shutdown 5. Type of Well: Development Exploratory J Stratigraphic Service R9E, UM R9E, UM R9E, UM R9E, UM 263 feet 844' feet ARCO Alaska. Inc. 3. Address P, O, Box 100360, Anchorage, AK 99510 4. Location of well at surface 1127' FNL, 2073' FWL, SEC.22, T13N, At top of productive interval 1302' FNL, 1808' FWL, SEC.27, T13N, At effective depth 1525' FNL, 1829' FWL, SEC.27, T13N, At total depth 1646' FNL, 1842' FWL~ SEC.27~ T13N~ 12. Present well condition summary Total Depth: measured 9 true vertical 6 6. Datum elevation (DF or KB) RKB 58' 7. Unit or Property name Kuparuk River Unit feet Plugs (measured) 8. Well number 30-17 9. Permit number/approval number 88-29 / 9-405 10. APl number 50-029-~179500 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 9088' feet Junk (measured) 671 8' feet 13, Casing Length Structural Conductor 80' Surface 2 6 9 4' Intermediate Production 8 5 8 3' Size Cemented 1 6" 175 SX AS 1 9 - 5 / 8" 900 SX AS III & 3O0 SX AS II 7" 510 SX TLW & 490 SX CLASS G 5 " 250 SX CLASS G 8886'-8906', 8915'-8940' 6571'-6586', 6592'-6611' Liner 871' Perforation depth: measured 8972'-8992', true vertical 6634'-6648', Tubing (size, grade, and measured depth) 2-7/8 AND 2-3/8, J-55 TO 8719' Packers and SSSV (type and measured depth) DB PKR ~ 8638'~ FVLD SSSV ~ 1801' Stimulation or cement squeeze summary Measured depth True vertical depth 115' 115' 2729' 2348' 8618' 6376' M.{R 0 5 995 Alaska Oil & Gas Cons. Commission Anchorage CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL C) hJ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 308 126 0 1140 Tubing Pressure 150 Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 0 0 1752 2O3O 16. Status of well classification as: Water Injector _X Oil __ Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Petroleum Engineer SUBMIT IN DUPLICATE Date: ARCO Alaska, Inc. August 11, 1989 Transmittal #: 7536 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt, and return one signed copy of this transmittal. 30-1 7 Kuparuk Well Pressue Report I - 2 3 - 8 9 Sand 'A' 3 O- 1 2 Sub-Surface Pressure Survey I - 1 2 - 8 9 # 71 6 0 5 3 H- 1 1 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing 3 H - 1 6 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing 3 H - 1 8 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing 3 H - 1 3 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing Receipt Acknowledged: DISTRIBUTION: BP Chevron Unocal Mobil State of Alaska D&M ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal Ct: 7470 Oil & Gas Cons. ~'~ ~-, · Anchorage Transmitted herewith are the following items. one signed copy of this transmittal. 30-18 . .~3A-03 ~"3A-08 '%"30-11 '~"'"3 O- 13 '~"30-17 33B'14 D 08 ~&~3H-IO ~3A-08 ~30-12 "~30 18 2B 14 ~1 R-02 ~, 3F-16 "~' 3F-16 ~1 R-02 '~"1Y-06 "~" 2T-07 '"'~,1 E-25 Please acknowledge receipt and return Sub-Surface Pressure Survey 2- 1 5 - 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4- 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4- 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 4- 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4- 3 0- 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 5-03-89 Kuparuk Fluid Level Report 5 - 0 4 - 8 9 Kuparuk Fluid Level Report 5- 0 3 - 8 9 Kuparuk Fluid Level Report 5 - 0 8 - 8 9 Kuparuk Fluid Level Report 5- 0 7- 8 9 Kuparuk Well Presure Report 1 I - 0 7- 8 Ct64613 Casing Casing Casing Casing Casing Casing Casing Casing CasIng Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M ~ SAPC Chevron Mobil Unocal STATE OF ~ ALASKA OIL AND ~ CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well Change approved program _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other .Z.. 2. Name of Operator ARCO Alaska. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1127' FNL, 2073' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1302' FNL, 1808' FWL, Sec. 27, T13N, R9E, UM 6. Datum elevation (DF or KB) RKB 58 7. Unit or Property name Kuparuk River Unit 8. Well number 30-17 9. Permit number 88-29 At effective depth 1525' FNL, 1829' FWL, Sec. 27, T13N, At total depth 1646' FNL, 1842' FWL, Sec. 27, T13N, 12. Present well condition summary Total Depth: measured true vertical R9E, UM R9E, UM 9263' feet 6844' feet Plugs (measured) 10. APl number 50-029-21 795 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 9088' feet Junk (measured) 6 71 8' feet Norle Casingi Length Conductor 8 O' Surface 2694' Intermediate Production 8583' Size Cemented 1 6" 175 Sx AS I 9 5/8" 900 Sx AS III & 300 Sx AS II 7" 510 Sx TLW & 490 Sx Class G 5" 250 $x Class G 8886'-8906', 8915'-8940' - ' 6571 '-6586', 6592'-6611' Liner 8 71 ' Perforation depth: measured 8972'-8992', true vertical 6634'-6648', Tubing (size, grade, and measured depth 2 7/8" + 2 3/8", J-55 to 8719' Packers and SSSV (type and measured depth) FVLD SSSV @ 1801' DB Packer @ 8638' 13. Attachments Description summary of proposal _ Convert well from oil producer to water injector. 14. Estimated date for commencing operation 06.-01 .---89 16. If propoSal was verbally approved Name of~ approver Date approved Measured depth True vertical depth 115' 115' 2729' 2348' 8618' 6376' 8236-9107 6102-6732 Detailed operation program _ BOP sketch _ 15. Status of well classification as: Oil .X Gas m Suspended Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test ~ SubSequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 i~IGINAL SIGNED' ~lV t. nNNIF C_ ~;MITH 10- IApproval No. 4:~ .~ ~./(~,~. .Approved Cop9 Returned Commissioner Date --[ '-'"'-,/,~2,._ o~1 SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kuparuk River Unit Wells 30-5,10,12,17 Conversion to Water Injection Service Wells 30-5,10,12, and 17 are currently oil producers, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to convert these four wells to water injection service. A Wireline BOPE will be used during the portions of the conversion procedure which require wireline work. Expected static bottom-hole pressures for each well are listed below. No workover fluid will be used during the conversion procedure. MIT's, as required by the State, will be performed on these wells prior to conversion, and the MIT form will be forwarded to the State upon completion. .WELL Expected SBHP 30-5 2800 psi 30-10 2300 psi 30-12 2450 psi 30-17 2500 psi 1. S000 P.~I ?" WELLHEAI:) CONNECTOR FLANGE: 2. ~000 PSI WIR[LIN£ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRI~~ 4. 5000 PSI 4 1/6" FL~ TUBE PACK-OFF 2 N]REL]NE BOP EOU]PHENT ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7462 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-18 Sub-Surface Pressure Survey 2-1 1 -89 #6461 3 30-08 Bottom Hole Pressure Surveyq 2-26-89 #962636 30-05 Sub-Surface Pressure Survey 2- 1 6-89 #29855 30-14 Sub-Surfece Pressure Survey 1-23-89 #72655 3 O- 18 Kuparuk Well Pressure Report 2 - 1 1 - 8 9 Sand 'A' 30-14 Kuparuk Well Pressure Report 1 - 2 3 - 8 9 Sand 'A' 30-08 Kuparuk Well Pressure Report 2-23-89 Sand'A' 3 O- 17 Kuparuk Well Pressure Report 3 - 0 4 - 8 9 Sand 'A' Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska SAPC Mobil Chevron Unocal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~' GAS ~ SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permi~._u2~ber ARCO Alaska, Inc. 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 029-21795 Classification of Service Well 4. Location of well at surface 1127' FNL, 2073' FWL, 5ec.22, T13N, R9E, UN At Top Producing Interval 1302' FNL, 1808' FWL, Sec.27, T13N, R9E, UN At Total Depth 1646' FNL, 1842' FWL, 5ec.27, T13N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 58 ' 6. Lease Designation and Serial No. ADL 25520 ALK 2556 12. Date Spudded 04/02/88 17. Total Depth (MD+TVD) 9263 ' MD/6844 'TVD 13. Date T.D. Reached { 14. Date Comp., Susp. or Aband. I 18. Plug Back Depth (MD+I'VD)[ 19. Direct(onal survey { 9088'MD/6718'TVDlYES ~ NO [] I 9. Unit or Lease Name Kuparuk River 10. Well Number 30-17 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 15. Water Depth, if offshore 16. No. of Completions N/A feet MSL 1 20. Depth where SSSV set 21. Thickness of Permafrost 1 801 ' feet MD 1 700' (approx) 22. Type Electric or Other Logs Run DIL/C;R/SP/SFL, FDC/CNL, CAL, GR, CET~ Gyro 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE 16" 62.5# H-40 9-5/8" 36.0# J-55 26.0# 71I J-55 TOP 5" 1 8.0# L-80 SETTING DEPTH MD I BOTTOM Surf 115' Surf 2729' Surf ! ~fi18' 8236'I 9107' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Perforated w/6 spf, 60° phasing 8972'-8992'MD/6634'-6648'TVD 27. N/A' HOLE SIZE 24" 12-1/4' R-l/?' 8-1~2' CEMENTING RECORD AMOUNT PULLED AS II ss C & !75 sx AS 25. TUBING RECORD I DEPTH SET (MD) PACKER SET (MD) SIZE 2- 7/8"/2-3 / 8r' 8719' 8638' I 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) / AMOUNT & KIN;~ OF MATERIAL USED See attached Addendum, dated 1-25-89 for fractlre data. PRODUCTION TEST Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. IMethod of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR IOIL-BBL GAS-MCF TEST PERIOD ~ CALCULATED . JOIL-BBL 24-HOUR RATE I~ GAS-MCF WATER-BBL WATER-BBL CORE DATA tCHOKESIZE IGAS'OILRATIO OIL GRAVITY-APl (cor;[ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None NOTE: Drilled RR 4/15/88. Perforated well and ran tubing 6/19/88. Fractured well 12/1/88. Form 10-407 101/WC5 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk-A GEOLOGIC MARKERS MEAS. DEPTH 8763' 8792' 8874' 9030' TRUE VERT. DEPTH 6482' 6503' 6563' ~676' 30. · FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A i . . 31. LIST OF ATTACHMENTS Addendum (dated 8/10/88 & 1/25/89) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' .Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16-and 24: If this well is completed for separate production from more than one interval (multiple completion), $o state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 1 O-407 ADDENDUM WELL: 7/23/88 7/26/88 30-17 Thaw annulus w/ 40 bbls, 180° diesel. Displ ann w/ 65 bbls, 170° cln diesel. Turn over to Production w/o Arctic Pak. Arctic Pak well w/ 175 sx ASI. ADDENDUM WELL: 5/09/88 8/05/88 11/15/88 11/22/88 12/01/88 1/02/89 30-17 RU Schl. Rn 6-1/8" GR to 2194'; unable to get lower. GR full of drlg mud. Rn CET f/7974'-2500'. RD Schl. RU hot oil unit. Pressure tst to 3000 psi. Pmp 21 bbls hot diesel w/5% Muson. Displ w/58 bbls cln diesel. Turn well over to Production. Attempt to frac well w/o success. Lost pump packings 50 bbls before start of 1st sand stage. Clear perfs w/flush & low temperature breaker. Attempt to frac well w/o success. Tree saver failed. Frac Kuparuk "A" sand perfs 8972'-8992' WLM in seven stages per procedure dated 11/17/88 as follows: Stage 1: Pmp 100 bbls gel diesel pre-pad @ 12.5-20 BPM, 6850-5100 psi Stage 2: Pmp 650 bbls gel diesel pad @ 20 BPM, 5400-5040 psi Stage 3: 50 bbls gell diesel, 2 ppg 16/20 Carbolite @ 20 BPM, 5254-5162 psi Stage 4: 85 bbls gel diesel, 4 ppg 16/20 Carbolite @ 20 BPM, 5492-5742 psi Stage 5: 98 bbls gel diesel, 6 ppg 16/20 Carbolite @ 20-18 BPM, 5870-5962 psi Stage 6: 26 bbls gel diesel, 10 ppg 16/20 Carbolite @ 18 BPM, 6400 psi Stage 7: 51 bbls gel diesel flush @ 18-11BPM, 6400/6900/6200 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 2169 bbls 42,607# 840# 5300 psi RU CTU. Attempt to cln out well. At 9080', tagged up on hard fill. Made 3 attempts to wsh further w/o success. CBU w/gelled diesel & N2 @ 9075'. Displ 7" csg w/cln diesel. POH & RD CTU. Turn well over to Production. Drilling S~perviso~ / D%te SUB. SURFACE DIRECTIONAL SURVEY F~UIDANCE F'~IONTINUOUS F'~OOL Company ARCO ALASKA, I~l~, , W~ m~m~ 30-17 (1127' FNL, 2073' FWL, SEC 22, T13N, R9E, UN), Field/Location KUPARUK, NORTH SLOPE, ALASKA , Job Reference No. Date 72834 17- JUNE-88 Logaed By; Computed By; ,MCBRIDE KOHRING GCT DI~ECTZONAL SURVEY CUS'TOMER LISTING FOR 6. RC0 ALASKA~ INC. 3 KUPARUK NORTH SLOPE~ ALASKA SURVEY DATE: 17-JUN-B$ ENGINEER: T. WEST METHODS DF COMPUTATION TOOL LOC&TION: TANGENTIAL- ~VERIGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 2 DEG Zl MIN WEST ARCO ALASKA, INC. 3 0-17 KUPARUK NORTH SLOPEs ALASKA COMPUTATION O&TE: 29-JUN-B8 PAGE I DATE OF SURVEY: 17-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG MIN 0.00 0.00 -58.00 0 0 N 0 0 E 100.00 100.00 42.00 0 23 N 62 12 E 200.00 200.00 142.00 0 25 N 66 57 E 300.00 299.99 241.99 0 29 N 72 B E 400.00 399.99 341.99 0 28 N 71 41 E 500.00 499.98 441.98 1 18 S 26 36 E 600.00 599.84 541.84 4 28 S 21.. 37 W 700.00 699.24 641.24 8 I S 17 31 W 800.00 797.70 739.70 11 52 S 15 9 W 900.00 894.93 836.93 14 52 S 10 19 W 1000.00 990.83 932.83 18 8 1100.00 1085.08 1027.08 20 32 1ZO0.O0 1177.86 1119.86 23 29 1300.00 1268.61 1210.61 25 58 1400.00 1357.71 1299.71 28 2 1500.00 144.4.79 1386.78 31 5 1600.00 1528.95 1470.95 34 4 1700.00 1611.06 1553.06 35 23 1800.00 1691.62 1633.62 37 17 1900.00 1769.54 1711.54 40 31 2000.00 1843.32 1785.32 44 16 2100.00 1913.36 1855.36 46 26 2200.00 1981.78 1923.78 46 39 2300.00 2052.05 1994.05 44 29 2400.00 2122.82 2064.82 45 30 2500.00 2191.83 2133.33 47 3 2600.00 2259.95 2201.95 47 Z 2700.00 2327.66 2269.66 47 42 2800.00 2395,71 2337.71 46 33 2900.00 2465.58 2407.58 44 36 3000.00 2537.72 2479.72 43 37 3100.00 2608.15 2550.15 47 10 3200.00 2675.08 2617.08 48 16 3300.00 2742.05 2684.05 47 29 3400.00 2810.34 2752.34 46 30 3500.00 7879.67 2821.67 45 41 3600.00 2949.68 2891.65 45 28 3700.00 3020.14 2962.14 44 54 3800.00 3091.27 3033.27 44 35 3900.00 3162.64:3104.~,~4 ....... 44 19 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAS'T/WEST DIST. AZIMUTH FEET DES/lO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E -0.14 0.32 0.13 N 0.26 E -0.46 0.00 0.42 N 0.93 E -0.77 0.00 0.70 N 1.69 E -1.06 0.06 0.96 N 2.4.5 E -0.80 3.68 0.66 N 3.33 E 3.99 3.66 4.10 S 2.49 E 14.42 3.70 14.38 S 1.14 W 31.21 3.52 30.99 S 6.04 W 54.21 2.42 53.81 S 10,93 W S 13 24 W 82.09 S 16 7 W 114.68 S 19 57 W 150.62 S 22 35 W 190.20 S 20 29 W 233.07 S 19 15 W 279.96 S 19 10 W 331.59 S 15 51 W 386.61 S 15 0 W 444.38 S 16 43 W 505.29 S 18 5 W 570.43 S 21 50 W 638.61 S ZO 32 W 707.28 S 16 50 W 775.58 S 13 45 W 844.44 S 10 4 W 915.75 S 4 46 W 988.65 $ 3 4 Z{ 1062.22 S 3 19 W 1135.48 S 3 16 W 1207.00 S 3 48 W 1276.24 S 5 43 W 1347.14 S 5 48 W 1421.29 S 5 29 W 1495.43 S 5 0 W 1568.38 S 4 40 W 1640.38 S 4 31 W 1711.72 S 3 58 W 1782.65 S 3 33 W 1852.91 S 2 57 W 1922.95 0.00 N 0 0 E 0.29 N 64 5 E 1.OZ N 65 46 E 1.83 N 67 21 E 2.63 N 68 39 E 3.39 N 78 44 E 4.80 S 31 18 E \ 14.43 S 4 31 W / 31.57 S 11 I W 54.91 S 11 28 W 3.40 1.74 4.35 2.22 2.07 3.38 2.35 2.88 2.43 3.82 81.47 S 16.63 W 83.15 S 11 32 W 113.74 S 25.28 W 116.52 S 1Z 31 W 149.24 S 36.62 W 153.67 S 13 47 W 188.22 S 52.21 W 195.33 S 15 30 W 230.44 S 68.87 W 240.51 S 16 38 W 276.69 S 85.48 W 289.59 S 17 I0 W 327.63 S 103.29 W 343.53 S 17 29 W 381.98 S 120.64 W 400.58 S 17 31 W 439.17 S 136.0~1 W 459.77 S 17 12 W 499.43 S 153.23 W 522.40 S 17 3 W 3.44 4.04 4.49 2.75 3.36 3.65 3.68 1.78 1.27 2.36 563.80 S 173.43 W 589.87 S 17 5 631.05 S 197.27 W 661.17 S 17 21 W 698.66 S 224.59 W 733.87 S 17 49 W 766.09 S 247.22 W 804.99 S 17 53 W 834.24 S 265.82 W 875.56 S 17 40 W 905.00 S 280.88 W 947.58 S 17 14 W 977.57 S 290.35 W 1019.77 S 16 32 W 1051.02 S 294.5/' W 1091.52 S 15 39 W ) 1124.18 S 298.83 W 1163.22 S 14 53 W 1195.59 S 302.96 W 1233.37 S 14 13 W 1.89 3.61 0.37 1.15 0.29 0.52 0.26 0.85 0.39 0.47 1264.71 S 307.09 W 1301.46 S 13 38 W 1335.42 S 313.00 W 1371.62 S 13 11 W 1409.33 S 320.58 W 1445.33 S 12 48 W 1483.23 S 327.90 W 1519.04 S 12 27 W 1555.97 S 334.63 W 1591.55 S 1Z 8 W 1627.78 S 340.70 W 1663.05 S 11 49 W 1698.95 S 346.46 W 1733.91 S 11 31 W 1769.72 S 351.68 W 1804.32 S 11 14 W 1839.84 S 356.31 W 1874.03 S 10 57 W 1909.79 S 360.27 W 1943.47 S 10 40 W ARCO ALASKA, INC. 3 0-17 KUP~RUK NORTH SLOPE, ALASKA COMPUTATION DATE: 29-JUN-~8 PAGE ' 2 ' DATE OF SURVEY: 17-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR'TURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3234.17 3176.17 44 21 4100.00 3305.15 3247.15 45 22 4200.00 3373.13 3.31 5..13 48 49 4300.00 3438.4~3 3380.48 49 20 4400.00 3503.99 344 5.99 48 58 4500,00 3569,53 3511.53 49 4 4600.00 3635.03 3577.03 48 59 4700.00 3700.60 3642.60 49 1 4800.00 3766.19 3708.19 49 1 4900,00 3832.22 3774.22 48 29 5000.00 3898.59 3840.59 48 19 5100.00 3965.35 3907.35 47 58 5200.00 4032.24 3974.Z4 48 4 5300.00 4099.01 4041.01 48 10 5400,00 4165,66 4!07,66 48 9 5500,00 4232.54 4174,54 47 54 5600.00 4299.59 4241.59 47 50 5700,00 ~.366,77 4308.77 47 44 5800.00 4434.00 4376.00 47 45 5900.00 4501.13 4443.13 47 49 6000.00 4568.24 4510.24 47 56 6100.00 4635.19 4577.19 47 58 6200.00 4702.15 4644.15 47 55 6300.00 4769.00 4711. O0 48 8 6400,00 4835.65 4 777.,55 48 14 6500.00 4902.52 4844.52 47 25 6600.00 4971.07 4913.07 46 25 6700.00 5040.03 4982.03 46 25 6800.00 5108.95 5050.95 46 25 6900,00 5177,76 5119.76 46 31 7000,00 5246,55 5188,55 46 37 7100,00 5315,21 51757.21 46 41 7200.00 5383.77 5325.77 46 43 7300.00 5452.27 5394.27 46 48 7400.00 5520.77 5462.77 46 45 7500.00 5589.25 5431.25 46 46 7600.00 5657.76 5599.76 46 48 7700.00 5726.24 5668.24 46 43 7800.00 5794.92 5736.92 46 28 7900.00 5864'59 ' 5'806.50 45 12 S 2 35 W 1992.82 S 2 25 W 2063.27 S 2 41 W 2136.58 S 2 50 W 2212.26 S 2 33 W 2287.81 S 2 21 W 2363.34 S 2 7 W 2438.91 S 1 57 W 2514.41 S 1 5t W 2589.99 S 1 42 W 2664.99 S I 31 W 2739.78 S 0 59 W 2814.22 S 0 40 W 2888.53 S 0 28 W 2962.94 S 0 15 W 3037.44 S 0 1Z W 3111.74 S 0 5 W 3185.~7 S 0 5 E 325'9.38 S 0 18 E 3333.84 S 0 33 E 3407.~6 S 0 44 E 3481.90 S 0 58 E 3556.06 S 1 10 E 3630.21 S 1 18 E 3704,43 S 1 21 E 3778.82 S 2 24 E 3852.99 S 3 49 E 3925.43 S 3 47 E 3997.44 S 3 47 E 4069.47 S 3 46 E 4141.62 S 3 45 E 4213.79 S 3 43 E 4286.09 S 3 37 E 4358.47 S 3 26 E 4430.94 S 3 22 E 4503.43 S 3 21 E 4575.94 S 3 19 E 4648.42 S 3 31 E 4720.93 S 3 52 E 4793.22 S 5 24 E 4864.49 0.86 2.15 1.77 1.09 0 0.37 0.12 0.38 0.65 0.28 0.80 0.29 0.29 0.22 0.26 0.20 0.15 0.14 0.34 0.27 0 0.49 0.39 0.00 0.08 3.55 0.18 0.15 0.31 0.15 0.15 0.14 0.20 0.24 0.13 0.14 0.73 0.29 0.62 1.05 1979.57 S 363.67 W Z012.70 S I0 24 W 2049.96 S 366.73 W 3082.50 $ 10 8 W 2123.20 S 369.91 W 2155.18 S 9 52 W 2198.79 S 373.63 W 2230.31 S 9 38 W 2274.26 S 377.18 W 2305.32 S 9 25 W 2349.72 S 380.40 W 2380.31 S 9 11 W 2425.23 S 383.36 W 2455.34 S 8 58 W 2500.68 S 386.06 W 2530.31 S 8 46 t,, ) 2576.12 S 388.59 W 2605.26 S 8 34 W 2651.19 S 390.92 W 2679.86 S 8 23 W 2725.95 S 393.06 W 2754.15 S 8 12 W 2800.39 S 394.72 W 2828.07 S 8 I W 2874.72 S 395.81 W 2901.84 S 7 50 W 2949.16 S 396.55 W 2975.70 S 7 39 W · 3023.71 S 397.02 W 3049.66 S 7 28 W 3098.05 S 397.31 W 3123.42 S 7 18 W 3172.24 S 397.51 W 3197.05 S 7 8 W 3246.31 S 397.51 W 3270.56 S 6 58 W 3320.34 S 397.27 W 3344.03 S 6 49 W 3394.45 S 396.69 W 3417.55 S 6 39 W 3468.59 S 395.85 W 3491.10 S 6 30 W 3542.86 S 394.73 W 3564.78 S 6 21 W 3617.12 S 393.35 W 3638.44 S 6 1Z W 3691,47 S 391.71 W 3712.20 .S 6 3 W 3766.00 S 389.98 W 3786.1'4 S 5 54 W 3840.32 S 357.84 W 3859.86 S 5 46 W 3913.00 S 383.52 W 3931.75 S 5 35 W 3985.26 S 378.71 W 4003.22 S 5 25 W 4057.55 S 373.93 W 4074.75 S 5 15 W 4129.96 S 369.13 W 4146.42 S 5 6 W 4202.38 S 364.34 W 4218.15 S 4 57 W 4274.94 S 359.59 W 4290.03 S 4 48 W 4347,57 S 354,91 W 4362,04 S 4 40 W 4420.29 S 350.43 W 4434.16 S 4 31 W 4493.01 S 346.08 W 4506.32 S ¢ 24 W 4565.76 S 341.81 W 4578.54 S 4 16 W 4638.48 S 337,55 W 4650.75 S 4 9 W 4711.23 S 333.17 W 4722.99 S 4 2 W 4783.77 S 328.53 W 4795.04 S 3 55 W 4855.34 S 322.74 W 4866.05 S 3 48 W ARCO ALASKA, INC. 3 0-17 KUPARUK NORTH SLOPEm ALASKA COMPUTATION DATE: 29-JUN-88 PAGE 3 DATE OF SURVEY: .t7-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR' COORDINATES HORIZ. DEPARTURE ' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN 8000.00 5935.05 5877.05 45 7 8100.00 6005.67 5947.67 45 8200.00 6076.32 6018.32 45 1 8300.00 6147.15 6089.15 44 39 8400.00 6218.47 6160.47 44 24 8500.00 6290.20 6232.20 43 51 8600.00 6362.70 6304.70 43 15 8700.00 6435.40 6377.40 43 18 8800.00 6508.72 6450.72 43 24 8gO0.O0 6581.48 6523.48 43 11 9000.00 6654.41 6596.41 43 14 9100.00 6726.55 6668.55 44 3 9200.00 6798.41 6740.41 44 3 9263.00 6843.68 6785°68 44 3 S 5 35 E 4934.70 S 5 34 E 5004.83 S 5 33 E 5074.92 S 5 40 E 5144.82 S 5 45 E 521-~.22 S 5 39 E 5283.20 S 5 33 E 5351.43 S 4 23 E 5419.47 S 5 10 E 5486.91 S 5 19 E 5554.89 S 5 42 E 5622.68 S 5 41 E 5691.24 S 5 41 E 5760.10 S 5 41 E 5803.48 0.28 0.15 0.46 0.30 0.36 0.76 1.22 1.46 1.80 1.04 I .11 0.00 0.00 0.00 5617.18 S 249.48 W 5622.7Z S 2 32 W 5686.08 S 242.51 W 5691.24 S Z 26 W 5755.28 S 235.62 W 5760.10 S Z 20 W 5798.87 S 231.28 W 5803.48 S 2 17 W ARCO ALASKA, INC. 3 0-17 KUP~RUK NORTH SLOPE, ALASKA COMPUTATION DATE:' 29-JUN-S8 PAGE 4 DATE OF SURVEY: 17-JUN-88 KELLY 'BUSHING ELEVATION: 58.00 FT ENGINEER: T. WEST INTERPOLATEO VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VER'TICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -58.00 0 0 1000.00 990.83 932.83 18 ~ 2000.00 1843.32 1785.32 44 16 3000.00 2537.72 2479.72 43 37 4000.00 3234.17 3176.17 44 21 5000.00 3898.59 3840.59 ,48 19 6000.00 4568.24 4510.24 47 56 7000.00 5246.55 5188.55 46 37 8000.00 5935.05 5877.05 45 7 9000.00 6654.41 6596.41 43 14 N 0 0 E 0.00 S 13 24 W 82.09 S 18 5 W 570.43 S 3 48 W 1276.24 S 2 36 W 1992.82 S 1 31 W 2739.78 S 0 44 E 3481.90 S 3 45 E 4213.79 S ~ 35 E 4934.70 S 5 42 E 5622.68 0.00 3.40 3.44 1.89 0.86 0.80 0.24 0.15 0.28 1.11 0.00 N 0.00 E 0.00 N 0 0 E 81.47 S 16.63 W 83.15 S 11 32 W 563.80 S 173.43 W 589.87 S 17 5 W 1264.71 S 307.09 W 1301.46 S 13 38 W 1979.57 S 363.67 W 2012.70 S 10 24 W 2725.95 S 393.06 W 2754.15 S 8 12 W 3468.59 S 395.85 W 3491.10 S 6 30 V · 4202.38 S 3~4.3% W %218.15 S 4 57 4925.89 S 315.92 W 4936.01 S 3 40 W 5617.18 S 249.48 W 5622.7Z S 2 32 W 9263.00 6843.68 6785.68 4~ 3 S 5 41 E 5803.48 0.00 5798.87 S 231.28 W 5803.48 S 2 17 W ARCO ALASKA, INC. 3 0-17 KUPARUK NORTH SLOPEp ALASKA COMPUTATION DATE: zg-JUN-88 PAGE 5 D~TE OF SURVEY: 17-JUN-8~ KELLY BUSHING ELEVATION= 58.00 FT ENGINEER: T. WEST 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 0.00 0.00 -58.00 0 0 N 0 0 E 58.00 58.00 0.00 0 18 N 68 29 5 158.00 158.00 100.00 0 25 N 67 1 E 258.01 258.00 200.00 0 28 N 70 ! E 358.01 358.00 300.00 0 27 N 71 52 E 458.01 458.00 400.00 0 29 S 87 24 E 558.07 558.00 500.00 3 3 S 11 48 W 658.42 658.00 600.00 6 37 S 19 I W 759.54 758.00 700.00 10 22 S 16 25 W 861.88 858.00 800.00 13 54 S 11 1] W 965.57 958.00 900.00 16 55 1071.12 1058.00 1000.00 20 5 1178.41 1158.00 1100.00 22 44 1288.21 1258.00 1200.00 25 42 1400.33 1358.00 1300.00 28 3 1515.¢4 1458.00 1400.00 31 36 1635.20 1558.00 150.0.00 34 41 1757.97 1658.00 1600.00 :36 29 1884.87 1758.00 1700.00 39 57 2020.62 1858.00 1800.00 44 54 2165.22 1958.00 1900.00 47 2 2308.35 2058.00 2000.00 44 33 2450.61 2158.00 2100.00 46 24 2597.14 2258.00 2200.00 47 1 2744.86 2358.00 2300.00 47 9 2889.35 2458.00 2400.00 44 51 3028.18 2558.00 2500.00 44 17 3174.34 2658.00 2600.00 48 17 3323.53 2758.00 2700.00 47 12 3468.92 2858.00 2800.00 45 55 3611.85 2958.00 2900.00 45 25 3753.28 3058.00 3000.00 44 35 3893.51 3158.00 3100.00 44 ZO 4033.40 3258.00 3200.00 44 36 4177.09 3358.00 3300.00 48 19 4329.89 3458.00 3400.00 49 9 4482.39 3558.00 3500.00 49 2 4635.01 3658.00 3600.30 49 0 4787.51 3758.00 3700.00 49 5 4938.89 3858.00 3800.00 48 27 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E -0.02 0.25 O.OZ N 0.04 E -0.33 0.06 0.30 N 0.65 E -0.64 0.08 0.59 N 1.35 E -0.94 0.05 0.85 N 2.13 E -1.16 0.82 1.05 N 2.91 E 1.36 3.87 1.50 S 3.36 E 9.29 4.37 9.32 S 0.52 E 23.64 4.02 23.50 S 3.92 W 44.85 2.87 44.51 S 9.17 W S 12 I W 71.88 S 15 35 W 104.93 S 18 44 W 142.52 S 22 41 W 185.36 S ZO 28 W 233.21 S 19 12 W 287.60 S 18 24 W 350.65 S 14 51 W 419.76 S 16 30 W 495.81 S 18 24 W 584.36 S 22 6 W 683.29 S 16 33 W '781.28 S 12 6 W 880.21 S 4 55 W 986.56 S 3 25 W 1095.26 S 3 17 W 1199.52 S 4 16 W 1295.80 S 5 52 W 1402.18 S 5 25 W 1512.?0 S 4 44 W 1618.12 S 4 26 W 1720.16 S 3 4.A w 1820.12 S 2 59 W 1918.42 S 2 30 w 2016.22 S 2 32 w 2119.38 S 2 44 W 2234.90 S 2 22 W 2350.04 S 2 4 W 2465.34 S I 52 W 2580.46 S I 40 W 2694.10 0.00 N 0 0 E 0.04 .N 67 40 E 0.71 N 65 11 E 1.47 N 66 23 E 2.29 N 68 14 E 3.09 N 70 13 E 3.68 S 65 55 r '~ 23.82 S 9 28 W 45.44 S 11 38 W 4.12 1.78 4.16 2.09 2.06 3.07 2.33 1.75 3.80 3.28 71.35 S 14.34 W 72.78 S 11 21 W 104.09 S 22.54 W 106.50 S 12 12 W 141.25 S 33.81 W 145.24 S 13 27 W 183.45 S 50.23 W 190.20 S 15 18 W 230.58 S 68.92 W 240.66 S 16 38 W 284.23 S 88.12 W 297.57 S 17 13 W 346.&5 S 109.69 W 363.40 S 17 34 W 414.80 S 129.5'9 W 434.57 S 17 21 W 490.05 S 150.43 W 512.62 S 17 3 W 577.55 S 177.98 W 604.35 S 17 7 W 2.84 2.66 3.13 3.61 1.11 2.39 3.54 0.19 1.32 0.97 675.02 S 215.34 W 708.54 S 17 41'W 771.72 S 248.86 W 810.85 S 17 52 W 869.71 S 273.93 W 911.83 S 17 28 W 975.48 S 290.18 W 1017.72 S 16 33 W 1084.02 S 296.46 W 1123.82 S 15 17 W 1188.11 S 302.53 W 1226.02 S 14 17 W 1284.24 S 308.48 W 1320.76 S 13 30 W } 1~90.28 S 318.64 W 1426.33 S 1Z 54 W 1500.45 S 329.54 W 1536.21 S 12 23 W 1605.57 S 338.86 W 1640.94 S 11 55 W 0.64 0 0.47 0.87 3.32 1.10 0.10 0.24 0.25 0.43 1707.36 S 347.11 W 1742.29 S 11 29 W 1807.12 S 354.21 W 1841.51 S 11 5 W 1905.26 S 360.03 W 1938.98 S 10 42 W 2002.95 S 364.71 W Z035.89 S 10 19 W 2106.02 S 369.12 W 2138.12 S 9 56 W 2221.41 S 374.74 W 2252.79 S 9 34 W 2336.43 S 379.85 W 2367.10 S 9 14 W 2451.64 S 384.33 W 2481.58 S 8 54 W 2566.70 S 388.28 W 2595.90 S 8 36 W 2680.29 S 391.78 W 2708.77 S 8 18 W COMPUTATION DATE: 29-JUN-85 PAGE ' 6 ARCO ALASKA, INC. 3 0-17 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 17-JUN-8~ KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUO-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 gIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5089.02 3958.00 3900.00 47 58 5238.56 4058.00 4000.00 48 5 5388.51 4158.00 4100.00 48 10 5537.98 4258.00 4200.00 47 54 5686.96 4358.00 4300.00 47 44 5835.73 4458.00 4400.00 47 49 5984.72 4558.00 4500.00 47 55 6134.07 4658.00 4600.00 47 59 6283.52 4758.00 4700.00 48 7 6433.55 4858.00 4800.00 48 13 S 1 2 W 2806.06 S 0 34 W 2917.21 S 0 17 W 3028.89 S 0 9 W3139.90 S 0 4 E 3250.24 S 0 25 E 3360.27 S 0 42 E 3470.57 S 1 1 E 3581.33 S 1 18 E 3692.18 S I 24 E 3803.80 0 0.16 0.28 0.20 0.12 0.30 0.29 0.47 0.09 0.15 2792.23 S 394.57 W 2819.97 S $ 2 W 2903.41 S 396.13 W 2930.31 S 7 46 W 3015.15 S 396.98 W 3041.17 S 7 30 W 31Z6.24 S 397.40 W 3151.40 S 7 14 W 3236.66 S 397.53 W 3260.98 S 7 0 W 3346.81 S 397.09 W 3370.28 S 6 45 W 3457.24 S 396.00 W 3479.85 S 6 32 W - 3568.17 $ 394.29 [4 3589.89 S 6 18 k ) · 3679.20 S 391.99 W 3700.02 S 6 4 W 3791.02 S 389.37 W 3810.97 S 5 51 W 6581.04 4958.00 4900.00 46 27 6726.07 5058.00 5000.00 46 25 6871.27 5158.00 5100.00 46 32 7016.68 5258.00 5200.00 46 37 7162.41 '5358.00 5300.00 46 42 7308.37 5458.00 5400.00 46 48 7454.36 5558.00 5500.00 46 47 7600.35 5658.00 5500.00 46 48 7746.3! 5758.00 5700.00 46 39 7890.77 5858.00 5800.00 45 18 S 3 50 E 3911.77 S 3 47 6 4016.22 S 3 47 E 4120.89 S 3 45 E 4225.84 S 3 41 E 4331.26 S 3 26 E 4437.01 S 3 21 F 4542o84 S 3 19 E 4648.68 S 3 37 E 4754.45 S 5 20 E 4857.99 0.13 0.14 0.04 0.16 0.22 0.23 0.09 0.73 0.49 1.57 3899.29 S 384.44 W 3918.19 S 5 37 W 4004.11 S 377.46 W 4021.86 S 5 23 W 4109.15 S 370.50 W 417.5.82 S 5 9 W 4214.48 S 363.55 W 4230.13 S 4 55 W 4320.27 S 356.65 W 4334.95 S 4 43 W 4426.38 S 350.07 W 4440.20 S 4 31 W 4532.56 S 343.76 W 4545.57 S 4 20 W 4638.74 S 337.54 W 4651.00 S 4 9 W 4744.86 S 331.07 W 4756.40 S 3 59 W 4848.81 S 323.35 W 4859.58 S 3 48 W 8032.53 5958.00 5900.00 45 5 8174.08 6058.00 6000.00 45 2 8315.24 6158.00 6100.00 44 35 8455.22 6258.00 6200.00 44 9 8593.55 6358.00 6300.00 43 15 8730.78 6458.00 6400.00 42 17 8867.74 6558.00 6500.00 43 23 9004.93 5658.00 6600.00 43 15 9263.00 6843.69 6785.68 44 3 S 5 36 E 4957.52 S 5 33 E 5056.75 S 5 42 E 5155.43 S 5 40 E 5252.40 S 5 25 E 5347.05 S 4 47 E 5440.19 S 5 21 E 5532.97 S 5 45 E 5626.03 S 5 41 E 5803.48 0.15 0.58 0.41 0.63 0.68 4.01 0.21 1.31 0.00 4948.82 S 313.67 W 4958.75 S 3 37'W 5048.54 S 303.92 W 5057.68 S 3 26 W 5147.70 S 294.14 W 5156-09 S 3 16 W 5245.15 S 294.33 W 5252.85 S 3 6 W 5340.27 S 275.01 W 5347.34 S 2 56 W 5433.84 S 266.38 W 5440.36 S 2 48 W 5527.04 S 258.00 W 5533.06 S Z 40 W 5620.54 S 249.14 W 5626.06 S Z 32 W 5798.87 S 231.28 W 5803.48 S 2 17 W ARCO ALASKA, INC. 3 0-17 KUPARUK NORTH SLOPE, ALASKA MARKER TOP KUP~RUK C BASE KUPARUK C TOP KUP~RUK BASE KUPARUK TD COMPUTATION DATE: INTERPOLATED VALUES MEASURED DEPTH BELOW KB 8763.00 8792.00 8874.00 9030.00 9263.00 oo 2g-JUN-88 FOR CHOSEN HORI[ONS ORIGIN: 1127 TVO FROM KB SUB-SEA 6481.80 6423.80 6502.91 6444.91 6562.55 6504.55 6676.19 6618.19 66-S'7.5i 663~.6i 6843.68 6785.68 KELLY PA~E 7 DATE OF SURVEY: 17-JUN-88 BUSHING ELEVATION: 58.00 FT ENGINEER: T. WEST FNL, 2073 SURFACE LOCATION AT FWL, SEC 22, T13N, RgE, REC'TANGUL~R COORDINATES NORTH/SOUTH EAST/WEST 5455.48 S 264.50 W 5475.28 S 262.73 W 5531.32 S 257.60 W 5637.70 S 247.37 W 5658.40 S 245.27 W 5798.B7 S 231.28 W -5(~-/7, 7 2 $' '~q'5,-/2 UM ARCO ALASKA~ INC. 3 0-17 KUPARUK NORTH SLOPEe ALASKA COMPUTATION OATc' 29-JUN-S8 KELLY DATE OF SURVEY: BUSHING ELEV&TION:' .. PAGE B 17-JUN-8~ 58. O0 FT ENGINEER: T. WEST ~~~ STRATIGRAPHIC SUMMARY MARKER TOP KUPARUK C B~SE KUPARUK C TOP KUPARUK A BASE KUPARUK A TO PE~'TO FINAL MEASURED ~EPTH 9263.00 WELL LOCATION TRUE VERTICAL DEPTH 6543.68 ORIGIN= 1127 FNL, MEASURED OEPTH TVD BELOW KB FROM KB SUB-SE~ 8763.00 6~81o$0 6423.80 8792.00 6502.91 64~4.9! 8874.00 6562.55 6504.55 9030.00 6676.19 66~8.~9 ~06O.OO 669T.81 663~.81 9263.00 6843.68 6785.68 AT TO: SUB-SEA VERTICAL DEPTH 6785.68 HORIZONTAL DEPARTURE DISTANCE ~ZIMUTH FEET DEG MIN 5803.~8 S 2 17 W 2073 SURFACE LOCATION AT FWL, SEC Z2, T13N, ROE, RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 264. 262. Z57. 247. Z45. 231. 5455.48 S 5475.28 S 5531.32 S 5637.70 S 5658.4G S 5798.87 S UM 50 W 73 W 60 W 37 W 28 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, I NC. 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L~..+4 ..... ~.444 ...... ~-.~...;-.~... ::::~:::~:::~:::~::::::::::::::::::::::::.--;..-~-..~.-~--. · --,....~ :: :J::....;.--;--;...~ ..... ~.-.;-.~---: ...... ~-.-~...~..-~-.- :::~:: ::: :::~::: ...~--.~---~...? ...... ~---~.--*..~ ...... ~-.~.--~--.'---~---'-.-~-..~-.-~---~---~---~-.-~-.+.- -'f-H--'f--':"-H-"?'-~ ....... H-"f--?'- -4000 -BO00 -2000 - 1000 0 1000 2000 8000 4000 EAST WELL 30-17 ' (1127' F)IL, 2073' FWL, SEC 22, T13N, R9E, UM) VERTICAL PROJECTION - ! 000 0 0 ! 000 ~000 @000 ~000 ~000 ~000 18~, PROJECTION ON VERTICAL PLANE 182. - SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT STATE OF ALASKA -~'~ ALAS~,,,, OIL AND GAS CONSERVATION COM~,.,,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other ~ COMPLETE 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1127' FNL, 2073' FWL, 5ec.22, T13N, RgE, UM At top of productive interval 1302' FNL, 1808' FWL, Sec.27, T13N, RgE, UN At effective depth 1525' FNL, 1829' FWL, Sec.27, T13N, RgE, UM At total depth 1646' FNL, 1842' FWL, 5ec.27, T13N, R9E, UN Perforate [~ Pull tubing 5. Datum elevation (DF or KB) RKB 58' 6. Unit or Property name Kuparuk River Unit 7. Well number 30-17 8. Approval number 8-335 9. APl number 50-- 029-21795 10. Pool Kuparuk River Oil Pool Feet 6376 ' TVD 6102 ' -673 2 ' TVD Date ~'-/~ - ~3 Submit in Duplicate 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2694' Production 8583' Li net 871 ' Perforation depth: measured 9263 ' MD 6844 ' TVD 9088 'MD 6718 'TVD Size 16" 9-5/8" 7" 5'1 8972 ' -8992 'MD feet feet feet feet Plugs (measured) None Junk (measured) None Cemented 175 sx AS I 900 sx AS III & 300 sx AS Ii 510 sx TLW & 490 sx Class G 250 sx Class G Measured depth 115'MD 2729'MD 8618'MD 8236'-9107'MD True Vertical depth 115'TVD 2348 ' TVD true vertical 6634 ' -6648 'TVD 12. Tubing (size, grade and measured depth) 2-7/8"/2-3/8", J-55, tbg w/tail ~ 8719' Packers and SSSV (type and measured depth) FVLD SSSV ~ 1801'~ DB pkr (~ 8638' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Inj. ection Data Oil-Bbl Gas-Mc, Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl. Well H~tory) Daily Report of Well Operations ~ Copies of Logs and Surveys Run X3 Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Associate Engineer (Dani) 5W03/015 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25520 Title COMPLETE [ Sta~.K 30-17 IWell no. KUPARUK RIVER UNIT Auth. or W.O, no. AK3099 API: 50-029-21795 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m, 06/13/88 (l~i) TD: 9263 PB: SUPV: TA 06/14/88 (lt;) TD: 9263 PB: SUPV: TA 06/15/88 ( 1'~) TD: 9263 PB: SUPV: TA 06/16/88 (1~) TD: 9263 PB: SUPV: TA 06/17/88 ( 1 ~) TD: 9263 PB: 9088 SUPV: WM 06/18/88 ( 2~ ) TD: 9263 PB: 9088 SUPV: WM I ARCO wi. 06/12/88 1345 HRS 1Pri°r Complete record for each day reported NORDIC I CLEANING PITS 5"@ 9107' MW: NACL/NABR MOVED RIG FROM 30-18 TO 30-17. ACCEPTED RIG @ 1345 HRS, 6/12/88. ND LOWER TREE. NU BOPE AND TESTED TO 3000 PSI-OK. (WITNESSING OF INSPECTION WAIVED BY BOBBY FOSTER, AOGCC) STRAP AND CALIP DC. FINISHED LOADING DP. INSTALLED WEAR RING. PU 3-1/2" DP TO 2100'. CLEANING PITS. PREPARING TO TAKE ON MUD. DAILY:S37,225 CUM:$1,209,519 ETD:S1,209,519 EFC:$1,350,000 RIH TO CLEAN OUT LINER 5"@ 9107' MW: 9.7 NACL/NABR CLEAN PITS. TAKE ON MUD AND COND. DISP BRINE. RIH TO LINER TOP AT 8236'. TEST LAP TO 2500 PSI. OK. POOH. RU BHA AND RIH. DAILY:S30,839 CUM:$1,240,358 ETD:S1,240,358 EFC:$1,350,000 START POOH 5"@ 9107' MW: 9.7 NACL/NABR RIH. TAG LINER TOP AT 8236'. DRLD 8236' TO 8240'. RIH TO CMT TOP AT 8921'. DRLD TO 9059'. DRL LC AT 9059' AND FC AT 9061'. STUCK AT 9061'. WORKED LOOSE. DRLD TO 9088' CIRC CLEAN. TEST LINER TO 2500 PSI. OK. START POOH. DAILY:S34,453 CUM:$1,274,811 ETD:S1,274,811 EFC:$1,350,000 RIH 5"@ 9107' MW: 9.7 NACL/NABR POOH. RIH W/ PKR AND SET AT 8226'. DIFF TEST LINER LAP W/ FULL COLUMN OF DIESEL. POOH. MU 4" MILL AND SCRAPER. TIH. DAILY:S31,400 CUM:$1,306,211 ETD:S1,306,211 EFC:$1,350,000 POOH AND LDDP 5"@ 9107' MW:10.0 NACL/NABR RIH W/MILL AND SCRAPER. DISP MUD TO BRINE AND POOH. DAILY:S31,100 CUM:$1,337,311 ETD:S1,337,311 EFC:$1,350,000 RIH WITH COMPLETION 5"@ 9107' MW:10.0 NACL/NABR POOH DP. RUN CET/GCT. PERF INTERVAL 8972'-8992' W/6 SPF, 60 DEGREE PHASING. RUN GR/JB TO8850'. POOH. RIH WITH PACKER ASSEMBLY ON WIRELINE. SET PACKER. RIH WITH COMPLETION ASSEMBLY. DAILY:S103,062 CUM:$1,440,373 ETD:S1,440,373 EFC:$1,350,000 The above is correct For form preparation ~ distribution, see Procedures Manu~l/Section 10, Drilling, Pages 86 and~87. JDate J Title -/'-/0-,~ ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Reporl" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State ARCO ALASKA INC. I NORTH SLOPE AK Field ILease or Unit IWell no. KUPARUK RIVER UNIT I ADL: 25520 30-17 Auth. or W.O. no. ITitle AK3099 ~ COMPLETE API: 50-029-21795 Operator IA'R'C°' w'l' icostrr°tal number °f wells (active °r inactive) °n thisIcenter prior to plugging and J~RCO 56. 0000 Jabandonment of this well Spudded or W.O, begunACCEPT JDate 06/12/88 / 1345 HRS IH°ur rPri°r slatus tfa W'O' Date and depth as of 8:00 a.m. 06/19/88 (21) TD: 9263 PB: 9088 SUPV:WM Complete record for each day reported NORDIC 1 RIG RELEASED 5"@ 9107' MW: DIESEL RUN 249 JTS OF 6.5# J-55 AB MOD 2-7/8" TUBING. TAIL @ 8719', 'FVLD' SSSV @ 1801', 'DB' PACKER @ 8628'. TESTED ALL RELATED EQUIPMENT. DISPLACE HOLE WITH DIESEL. SECURED WELL AND RELEASED RIG @ 0130 HRS 6/19/88. DAILY:S133,325 CUM:$1,573,698 ETD:S1,573,698 EFC:$1,350,000 Released rig I Date Kind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method IOfficial reservoir name(s) I Potential test data IWell no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test !Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and dis~/bution, see Procedures Manual, Sect~)n 10, Drilling, Pages 86 and 87. ASSOCIATE ENGINEER ARCO Alaska, inc. · . Date: Transmittal #: 7209 July 1, 1988 RETURN TO: ARCO Alaska, inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 1 0 Cement Evaluation Log 6 - 1 9 - 8 8 7 3 4 6 - 8 71 5 3 O- 11 Cement Evaluation Log 6 - 1 9 - 8 8 5 9 71 - 7 6 4 2 30-12 Cement Bond Log 6-1 7-88 4798-6860 3 O- 1 7 Cement Evaluation Log 6 - 1 7 - 8 8 7 5 9 5 - 9 0 8 7 Receipt Acknowledged' DISTRIBUTION: NSK Drilling state of Alaska(.,+sepia) XEROX TELECOOP i Ef:~ ?;~:.~: F ~: C H ARCO Alaska, Inc. Date: May 26, 1988 TranSmittal #: 7168 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H - 21 Cement Evaluation Log 4 - 2 0 - 8 8 4 6 0 0 - 1 1 1 9 8 ' 3 H- 1 8 Cement Evaluation Log "~ .... .?~ 5 - 0 5 - 8 8 8 8 9 3 - 1 0 0 81 30-1 6A Cement Evaluation Log ~' 5 - 0 9 - 8 8 90-8111 .. 3 O- 1 8 '- Cement Evaluation Log 5 - 0 9 - 8 8 2 6 9 0 - 7 51 5 3 O- 1 7 · Cement Evaluation Log 5 - 0 9 - 8 8. 2 4 9 0 - 7 9 6 8 3 H - 1 6 Cement Evaluation Log 5 - 2 1 - 8 8 7 7 9 5 - 9 61 4 If you have any questions, concerning this or any other transmittals please call me at 265-6835. -, Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: NSK ~_~ ~,,~ .... D~ka (+sepia) ARCO Alaska, Inc. Date: May 3, 1988 Transmittal #: 7157 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '"'=~J~'~*~~~. Cyberlook 4 - 0 9 - 8 8 2721 - 9213 2" & 5" Porosity FDC 4-09-88 2721-9213 2" Dual Induction 4 - 0 9 - 8 8 2721 - 9213 30-17 2" & 5" Raw Data FDC 4-09-88 2721 -9213 30-17 .... 5" Dual Induction 4-09- 88 2721 -9213 30-16 2" Dual Induction 4-22-88 2377-81 72 30-16 5" Dual Induction 4-22- 88 7760-81 72 30-16 Cyberlook 4- 2 2- 8 8 7760- 81 50 30-16 2" & 5" Porosity FDC 4-22-88 2377-81 56 30-16 2" & 5" Raw Data FDC 4-22-88 2377-8156 'RECE ¥ED AlaSt~ U~l a ~ias Cons. ~m~llSs~ /~,ch0ra~e ' If you have any questions concerning this or any other transmittals, please call me at 265-6835. Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M Date: ................... State of Alaska(+sepia), Lucille Johnston(vendor package) ARCO Alaska, Inc. Date: May 3, 1988 Transmittal #: 7154 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Edit Tape and Listing OH Edit Tape and Listing 4-23-88 #72673 4-22-88 #72659 MAY 0 4 1988 uu ~, ~as Cons. Comntlsslmt If you have any questions concerning this or any other transmittals, please call me at 265-6835. Receipt Acknowledged' DISTRIBUTION: Lynn Goettinger Date' State of Alaska STATE OF ALASKA. ALASK.. OIL AND GAS CONSERVATION COMN,._SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ¢ Operation Shutdown~ Re-enter suspended well [] Alter casing C-i Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing '~ Amend order [] Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 59' feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1127' FNL, 2073' FWL, Sec.22, T13N, RgE, At top of productive interval 1320' FNL, 18/+8' At effective depth 150/+' FNL, 1818' At total depth 16/+2' FNL, 1829' 11. Present well condition summary Total depth: measured true vertical UM FWL, Sec.27, T13N, R9E, UH (approx) FWL, Sec.27, T13N, R9E, UM (approx) FWL, Sec.27, T13N, R9E~ UM (approx) 9263'MD feet Plugs(measured) 6850'TVD feet 7. Well number 30-17 8. Permit number 88-29 9. APl number 50-- 029-21 795 10. Pool Kuparuk River 0il None Pool Effective depth: measured 9060 ' MD feet true vertical feet 6701 ' TVD Casing Length Size Junk (measured) None Cemented Measured depth True Vertical depth Conductor 80' Surface 2694' 1 6" 9-5/8" 7" Producti on 8583 ' Li net 871 ' Perforation depth: measured true vertical None None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 175 sx AS I 900 sx AS II I & 300 sx AS II 510 sx TLW & 490 sx Class G 250 sx Class G 115'MD ll5'TVD 2729'MD 2360'TVD 8618'MD 6382'TVD 8236'-9107'MD 6108'-6736'TVD 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation June, 1988 14. If proposal was verbally approved Name of approver Subseqnent Wor]~- .lq,eportecl on ,, ~,/' Fo,m, No. O' TD t a Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢ ~ ~ ~ Title A~o~;iat,~ E n g ineer- ~ Commission Use Only (Dani) 5A3/84 Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Form 10-403 Re~"1'2~-85 Approved Copy Returned Commissioner IApproval No. by order of the commission Date S)d~o m/i n triplicate ARCO O, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of lime. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I Stat ARCO Alaska, Inc. ._. KUPARUK RIVER UNIT County or Parish NORTH SLOPE-KUPARUK ILease or Unit ADL: 25520 Title DRILL 30-17 [Well no. Field Auth. or W.O. no. AK3099 API: 50-029-21795 Operator A.R.Co. W.I. ARCO 56.0000 Spudded or W.O, begun Date SPUD 04/02/88 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our Prior status if a W.O, 1900 Date and depth as of 8:00 a.m. 04/16/88 ( 1 TD: 9263'( SUPV:RB Complete record for each day reported DOYON 14 RIG RELEASED 5"@ 9107' MW: 9.8 VIS: 49 POOH LDDP. DISPLACE TOP 2000' WITH 10.0 PPG BRINE. CHANGE OUT TUBING HEAD AND RETEST TO 3000 PSI. INJECT 33 BBLS DIESEL DOWN 30-17. RELEASE RIG @1900 HRS 4/15/88. DAILY:S30,000 CUM:$1,172,294 ETD:S1,172,294 EFC:$1,350,000 Old TD J New TD PB Depth II Released rig Date JK nd of rg Classifications (oil, gas, etc.) Producing method Potentia~ test data Type completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval ;Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date JTi,,e ASSO~A~ ENGINEER For form prepara~/~/n and distribution, see Procedures t4anual, Section 10, Drilling, Pages 86 and 87, AR3B-459-3-C JNumber ell daily well history forms consecutively as they are prepared for each well. iPage no, Olvll/on of AllantlcRIchfleldCompany ARCO Oil a,~ ,~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lrllerlm" sheets when filled out but not less frequently then every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish I NORTH ARCO Alaskar Inc. ILease or UnitSLOPE I KUPARUK RIVER UNIT ~ 30-17 Complete record for each day while drilling or workover in progress 04/10/88 ( TD: 9263'( SUPV:RB 04/11/88 ( TD: 9263'( SUPV:RB 04/12/88 ( TD: 9263'( SUPV:RB 04/13/88 ( TD: 9263'( SUPV:RB 04/14/88 ( TD: 9263'( SUPV:RB 04/15/88 ( TD: 9263'( SUPV:RB J StateAK DOYON 14 Well no, ~8) 41) 9) 0) .o) o) 1) o) 2) O) 3) 0) . CIRC STUCK CSG 7"@ 8618' MW: 9.9 VIS: 38 PU BIT #4 AND BHA AND RIH. WASH TO 9222'. DRLD TO 9263'. CIRC BU. SPOT PILL. POOH. LD DP AND BHA. RU AND RUN 216 JTS OF 7" CSG. BROKE CIRC AT 8617'. PIPE STUCK. DAILY:S43,882 CUM:$638,486 ETD:S638,486 EFC:$1,350,000 RIH W/ 3-1/2" DP 7"@ 8618' MW: 9.9 VIS: 46 ATTEMPT TO WORK STUCK PIPE. SPOT PILL. WORK PIPE. RU DOWELL AND CIRC HOLE. PUMP SPACERS. MIX AND PUMP 510 SX TLW AT 11.9 PPG. MIX AND PUMP 490 SX OF CLASS G AT 15.8 PPG. BUMPED PLUG W/3500 PSI. CIP AT 1530 HRS 4/10/88. SET 7" SLIPS. CUT CSG. MU TBG HEAD ADAPTER. PU 3-1/2" TOOLS AND RIH. DAILY:S276,767 CUM:$915,253 ETD:S915,253 EFC:$1,350,000 WASHING AND REAMING 7"@ 8618' MW: 9.9 VIS: 37 RIH W/ 3-1/2" DP. TAG FC AT 8538'. ATTEMPT TO DRL FC. NO GOOD. POOH. LD STAB AND PU BIT #5. RIH. DRLD FC AND CMT TO 8555' STOPPED DRLG. LD KELLY JUNK SUB AND KELLY SAVER SUB. DRLD TO 8655' DAILY:S42,171 CUM:$957,424 ETD:S957,424 EFC:$1,350,000 WASHING & REAMING TO BTM 7"@ 8618' MW: 9.8 VIS: 46 DRLD TO 8660'. POH. PU BIT # 6 AND RIH. WASH BACK TO 8660'. DRLD TO 8833'. WASH F/ 8833' TO 9085'. TWISTED OFF XO F/ KELLY. PU FISHING TOOLS AND LATCH ONTO FISH. POOH W/ FISH. PU KELLY, ATTEMPT TO WASH BACK TO BTM. DAILY:S43,412 CUM:$1,000,836 ETD:S1,000,836 EFC:$1,350,000 CIRC BTM UP 7"@ 8618' MW: 9.8 VIS: 44 POOH W/ FISH. MU BHA AND RIH. WASH AND REAM F/ 8617' TO 9127'.~HOLE PACKING AND STICKING. SHORT TRIP TO CSG SHOE. CIRC BTMS UP. DAILY:S44,244 CUM:$1,045,080 ETD:S1,045,080 EFC:$1,350,000 LD 3-1/2" DP 5"8 9107' MW: 9.8 VIS: 49 POOH. RU AND RUN 19 JTS OF 5" 18# L-80 CSG. CMT W/ 250 SXS OF CLASS G CMT AT 15.8 PPG. CIP AT 19:30 HRS 4/14/88. MU BIT AND SLICK BHA. TIH. TAG CMT AT 8138' DRLD HARD CMT TO TOP OF LINER AT 8236'. CIRC. PUMP PILL AND POOH. LD 3-1/2" DP. DAILY:S97,214 CUM:$1,142,294 ETD:S1,142,294 EFC:$1,350,000 The above is correct Signature For form preparation/~r{d distribution see Procedures Mart'uJal Section 10, Drilling, Pages 86 ah/d 87 Date AR3B-459-2-B INumber all daily well history forms consecutively lPage no. as Ihey are prepared for each well. I ARCO Oil and Gas Company "~' Well History Initial Report - Daily Instructiona: Prepare and submit the "initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District IIC°unty' parish or borough I Sta~ ARCO Alaska, Inc. I NORTH SLOPE Field ILease or Unit IWell no. KUPARUK RIVER UNIT I ADL: 25520 30-17 ! Auth. or W.O. no. ITitle AK3099 I DRILL API: 50-029-21795 Operator ARCO ARCO W.I. JHour 56. 0000 Pr or status if a W.O. 1900 Spudded or W.O. begun SPUD 04/09/88 ( TD: 9222'( SUPV:RB Date and depth as of 8:00 a.m. 04/03/88 ( ) TD: 1345'( I 45) SUPV:JP 04/04/88 ( ) TD: 2750'( 1 05) SUPV:JP 04/05/88 (3) TD: 3960'(1210) SUPV:JP 04/06/88 (4) TD: 6880'(2~20) SUPV:JP 04/07/88 (~) TD: 7888'(1(08) SUPV:RB 04/08/88 ( t TD: 8967'( 1 79) SUPV:RB ) 55) IDate 04/02/88 complete record for each day reported DOYON 14 DRILLING 16"@ 115' MW: 9.1 VIS: 83 MOVED RIG FROM 30-18 TO 30-17. NU 20" DIVERTER & RU RIG FLOOR. MU MWD & ORIENT SAME. FUNCTION TESTED DIVERTER SYSTEM. SPUDDED WELL @ 1900 HRS, 4/2/88. DAILY:S39,050 CUM:$39,050 ETD:S39,050 EFC:$1,350,000 ND DIVERTER SYSTEM 9-5/8"@ 2729' MW: 9.0 VIS: 58 DRILLED 12-1/4" HOLE TO 2750' CIRCULATE; DROPPED SURVEY. POOH. LD BHA. RAN 68 JTS 9-5/8", 36#, J-55, BTC CASING WITH SHOE @ 2729'. CMTD W/900 SX AS III & 300 SX AS II. CIP @ 0415 HRS, 4/3/88. ND DIVERTER SYSTEM. DAILY:S169,863 CUM:$208,913 ETD:$2O8,913 EFC:$1,350,000 DRILLING 9-5/8"@ 2729' MW: 9.3 VIS: 44 INSTALLED BRADENHEAD. NU BOPE AND TESTED. MU BHA #2 AND ORIENT MWD. TIH TO FC. TESTED CASING TO 2000 PSI - OK. DRILLED FC, CMT, FS & 10' NEW FORMATION. PERFORMED LOT WITH 8.5 PPG. DRILLED 8-1/2" HOLE TO 3960' WITH TURBINE. DAILY:S57,846 CUM:$266,759 ETD:S266,759 EFC:$1,350,000 DRILLING 9-5/8"@ 2729' MW: 9.3 VIS: 34 DRILLED 8-1/2" HOLE WITH TURBINE TO 6880' DAILY:S71,528 CUM:$338,287 ETD:S338,287 EFC:$1,350,000 DRILLING 9-5/8"@ 2729' MW: 9.3 VIS: 33 DRILLED 8-1/2" HOLE TO 7730'. TAKE MWD SURVEY, PUMPED DRY JOB, POOH. TESTED TURBINE, CHANGED OUT BIT, ORIENT, RIH. CUT DRLG LINE. RIH, HIT TIGHT SPOT @ 6100'-6130'. RIH. LD 7 JTS & WASHED/REAMED F/7498'-7730'. DRILLED TO 7888'. DAILY:S58,558 CUM:$396,845 ETD:S396,845 EFC:$1,350,000 DRILLING 9-5/8"@ 2729' MW:10.0 VIS: 43 DRILLED 8-1/2" HOLE TO 8967'. DAILY:S53,971 CUM:$450,816 ETD:S450,816 EFC:$1,350,000 RD SOS 9-5/8"@ 2729' MW:10.0 VIS: 40 DRLD 8-1/2" HOLE F/ 8967' TO 9222'. CIRC. SHORT TRIP. SPOT PILL. POOH. RU SOS. RIH AND LOG W/ DIL/GR/SP/SFL F~ 9222' TO 2729'. FDC/CNL F/ 9222' TO 7850'. CAL F/ 9222' TO 2729'. RD SOS. DAILY:S134,788 CUM:$594,604 ETD:S594,604 EFC:$1,350,000 The above is correct S,gnatur. ~ ~~ I Date 4 'Z~-- For form preparation and ~t~/~tribution, see Procedures Manual, S~J~tion 10, Drilling, Pages 86 and 87.w ITit,e ASSOOIATi~ L:NC-I_.IN_I~'_~' AR3B-459-1-D JNumber all daily well history forms consecutively as they are prepared for each well. Page no, Y RECEIVED APR 0 Alaska Oil & Gas Cons. Commission Anchorage March 30, 1988 Telecopy: (907) 276-7542 Mr. J. B. Kew±n Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 AnchOrage, Alaska 99510-0360 Re: Kuparuk River Unit 30-17 ARCO Alaska, Inc. Permit No. 88-29 Sur. Loc. l127'FNL, 2073'FWL, Sec. 22, T13N, R9E, UM. Btmhoie Loc. 1523'FNL, 1840'FWL, Sec. 27, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Com~n~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the. shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI-~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA .'~'- ALASKA ~IL AND GAS CONSERVATION C,,MMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenE]I Service [] Developement Gas [] Single Zone-J~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Kuparuk River Field ARCO Alaska, Inc. RKB 59', PAD 24' feet Kuparuk River Oil Poo 3. Address 6. Property Designation P.O. Box 100:560, Anchorage, AK 99510-0360 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1127'FNL, 2073'FWL, Sec.22, T13N, R9E, UM Kuparuk River Unit Statewide (~ target) At top of productive interval 8. Well nu .mber Number 1320'FNL, 1848'FWL, Sec.27, T13N, R9E, UM 30-17 #8088-26-27 At total depth 9. Approximate spud date Amount 1523'FNL, 1840'FWL, Sec.27, T13N, R9E, UN 04/04/88 $500,000 12. Distance to nearest 13. I~i(~t_a.~e to nearest well 14. Number of acres in property 1591P,~c~p,o~l~d depth (MD and TVD) oroperty line 523'@ TD feet 25' ~ Surface feet 2560 (6798'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 460 Maximum surface 1140 psig At total depth O'VD) 3056 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5 H-40 Weld 80' 35' 35' 115 115' :b200 cf 12-1/4" 9-5/8" 36.0~ J-55 BTC 2495' 35' 35' 2530' 2219' 900 sx AS II I & HF-ERw 300 sx AS II .... 8-1/2" 7" 26.0~ J-55 BTC 9087' 34' 34' 9121' 6798' 450 sx TLW lead & HI--bNW 200 sx Class G tail , 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~uc .buu' above UL;NU Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface I nte rmed iate Production ~ :~;~.T'? '~ ;, Liner Perforation depth: measured i~[3.3~.5 0~ & Gas 60t15. Anchorage true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ~ Diverter Sketch ~L Drilling program Drilling fluid program ~, Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby c~ify t~at the foregoin§ is~ true and correct to the best of my knowledge S'gned ~¢¢ Title Regional Drilling Engineer Date:~'./_~/~. ,,j-- ¢ ,,//_~, .¢ . Commission Use Only ~,t¢.~~ ,TFM).~Op_n?/80&~,) Permit NucCCber / I APl number I Approval dat~ ' I See cover letter 8&-~Z9 J 5o- ozg--Zl79.~ J 03/30/88 J for other requirements Condition8 of approval Samples required E~ Yes ~ No Mud Icg required E0 Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required wo~~ .,.~.~~[] 10M; ~ 15M Other: by order of Approved bye( ~'"~ /, ~k ~¢~'~~ Comm,ssloner the commission Dat Form 10-401 , [riplicate GENERAL DRILLING PROCEDUI~ KUPARUI( RIVER FIELD DEVELOPHENT WELLS 1. Move in 2. Install FMC diver~er system. 3. Drill 12¥' hole to 9-5/8" surface casin$ point accordin$ to directional plan. 4. Run and cement 9-5/8" casin$. 5. Install and test blow out preventer. Test. casin$ to 2000 psis. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole co lo$$in$ point accordin$ to directional plan. 8. Run open hole loss. 9. COntinue drillin$ 8½" hole to provide 100' between plus back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casin$. Pressure test to 3500 psis. 11. Dovasqueeze A~ctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple do~a blow out preventer and install temporaz7 Xmas tree. 13. Secure well and release tis. 14. run cased hole loss. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casins scraper and tubins, trip in bole to plus back total depth. Circulate hole with clean brine and trip out of bole standin~ tubins back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out prevemter and install Xmas tree. 19. Chanse over to diesel. 20. Flow well co canks. Shut in. 21. Secure well and release ri$. 22. Fracture stimulate. DEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR MUD CLEANER CENTRIFUGE L~(4 ] ih TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.0 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. T,W~5 / ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. RECEIV ,..,,.:~,,;,,,~ ()il ~,, ~as Cons. Commissjm-~ Anchorage PadAR~0-';~0o~'ALA'~'K~We I I ...... Noin ~,; ..... 1 ? Pr'opoeed 4~ Kuparuk E.[~ld.: North SI ope. Al~ek~ ..... .... RKB. ELEVAY. LON.~.. 5g,._ ~ 21~ ~R 1~ FT ' ~ - 3e B/ PERHAFROST TVD-IZ1g T~D-1822 DEP-44G ~ EOC TVD-1874 THD-2033 DEP-583 '.. =~21g T~= - DE~:gAO i , - - , T/ ~NU' SNDS TVD-268g T~-320~ DE~-142T ~ T~ ~ SAK SNDS ........... '/'~ .......................... :" ~ '- ' : TVD'343g T~'4286 O~'~03' '. ' ~ TVD 3844 THD 48 g DEP 26;23 '= ' 'AVERAOE ANOLE RErEl ~. I t i I ' /' ' 0 1 000 2000 3000 4000 5000 6000 - -- VERTICAL SECT[ON HOR. Ii ~NTAL~ PROJECTION SCALE 1 IN. = 1000 FEET ARCO ALASKA, ! ne. Pad ;30. Well No, 1Z P~'oposecl Kupa~-uk Field. Nor. th Slope. Ale,ka 1,000, 112~" Fat:. 2e13' Fla. SEC. ::~o, TI31~ RgE" WEST-EAST 2000 1000 0 1000 I.. c: ..................... ,::_ ...... 3000_.. 4000.. 5000 TD LOCATION, · ! 523' FILL. I 8,10' FWL ~. ~7'. 1'13#, RaE 6000. 2000 S 2 DEG 21 MIN W 5478' (TO TARGET) TARGET CENTER TVD-6~02 TI'ID-8~39 DEP-~4,?8 SOUTH $4T3 WEST 225 TARa'ET LOOAT[O#, 1320' FILL. 1848' FWL SEC. 27. T! 3#. RglE ...... ~ .... ] 900i I 000 1050. _ 1100 _ 1150_. 120Q ..... 125,0 30.0 35..0_ 400 ..... i 950 2000 I/ 1 gooi 950 1 go0 gOO / / /' l?OO / 500 I 2000 2050 21 O0 I I ,t ..,' 300 /" 300 ~ ¢.~ot / F, oF~ / 1300 : 300 ~ '1' 0.0 ~o~ ~oo . 300 ,oo ~ ~00 \ I \ I '~700 I \ I \ t1100 \ I \ I ~, go0 I I \ I \ I \ I \ 1' 1 ;300 \ I I I I I I I I I 2050 21 O0 21 50 2200 I I ~1100 \ \ \ \ \ \ \ i 2150 2200 .. _ 100C _ 105C _ 110(~ _ 115(:: _ 1 20C .125C .1 300 _ 1350 .1 400 K UPARUK RI VER UN I T 20' DIVERTER SCHEHATIC II I J L 4 DESCRIPTION 1. 16" CONDUCT~ 2. FHC SLIP-ON WELD STARTII~ HEAD 3. FHC DIVERTER ASSEI~LY WITH ~ 2-1/16' 2000 ~1B~ VALES 4. 20' 2~ PSI ~1~1~ ~ W/10' ~E~ S. 10' ~R A SI~E V~VE CL~ ~~Y C~~ TO A~~ ~1~ DIVE~I~. 6. 20' 2~ PSI ARCO ALA~A, I~., ~S~ A~~AL ~ THIS DIVER~R SYS~H AS A VARIANCE FR~ 20AAC25.035(b) HAINTENANCE & OPERATION 3 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLO~/AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN iNFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CiI~CUHSTANCE5 i ii 4 · 3 2 DIAERM4 #1 13-r-~8· 5CX]3 P~! R~;RRA ~ STAC~ ACOJvLLATCR CAPACITY TEST I. C}.EC~ ~ FILL ,M:~TCR RLrgERVOIR TO I~ LEVEL WITH ~IC FLUID. 2. ~ THAT A~~ ~ I:~ ]13130 PSI WITH I SO0 I~I [:~ ~ TIE REGLLATCR, 3. CI~ERVE TII~... ~ ~ ~4.l. UNI'I'g SIMJI. TAI~OL~.Y AN3 I~CCI~ ~.~ TII~ ~ ~ 1~I~4INII~ AFTE~ 4. RE~ C]N ~ I~o ~ AC~.I~I.E LI311~R LIMIT 1 5/8" STACK TEST DIESEL 2. C~CX THAT ALL LOI:X ~ SC:RE~ IN V~LU-EaD A~ FLLLY I:~TRACTE~ ~.AT T~$T PLUG IN ~ W/TH RLI~IhO ..IT AI~ ~ IN LO::XI::O~ sa~ 3. 0.0"~"___ ~ ~ ~ ~ KILL 4. PI~S~LI~ UP TO 2~d3 ~ Ai~ 141:I.D FlOR I0 Mi:N, I~- ~ F~E~I. RE TO 3(X]3 F"3Z AM) HaD FCR I0 BLEED PRE~LI;E TO 0 /Zr~E VALVES. O. CSE TCP P]FE ~ AM) HCR VALv~_S C]~ KILL ~ ~ LII~. 6. TEST TO~]P~I ~0~1:~I A~ INSTEP4. ?. O:]~IN.E T~S'I'II~ ~ V,~i.V~, LII~ ~ WITH A ZSO PS! LOW N~) 3000 I:~I HIGI'I, 'I'L~T 8. ~ TCP PIPE RAt4~ ~ CLI2SE BOTTOM Pll:~: R.a~. TEST BOTTCM PIPE ~ TO ~ PSI ~ 3CX~O PSI. 9. ~ BOTTCM PIPE: ~ BACX OUT RILeJ~NG JT ~ ICL CLO~IE BLIM:) RAk~ ,lAD TEST TO ~ PSI AM:) 30C0 PSI. ~1. CI:~N 81. II~D RAIk~ AM:) RETR]:EVE TEST ~ MaX~: SJ~ MN~FCLD A6D LIltS ARE FLLL C~ NI~N-~EZING FLUID. SET ALL VALVF. S IN CRILL. ING I:~ITICN, 12. TEST S'T~IPE VALVI~. I(~ Yo KELLY COQ<~ ~RI~. PIPE SAFETY VALVF., ~ II~II~ BI~ TO 250 PSI ~ ~)00 P~I. 13. ~:CO~ TEST I~='~TICIN CN BLI3t3JT ~ER ~ FC3R~ SIGN, AI~D ~ TO []~ILLIN~ ~LI:~RVI~I~. VEI:'KLY TI-EI~'rE~ [:'~lCI~I.LY ~TE ~ C~ Ij I f~'~1400 Ij ID:~]:{~U,'CI/NU/DR!LLING i i ALL WELLS lOCATED IN SEC. 22 T. I$ N., R. 9F_, UMIAT MERIDIAN. TEL NOTES I, AU. COORDINATES MtE A.S.P., ZONE 4. 2~ ALL DISTANCES SHOWN ARE TRUE 3, ELEVATIONS &RE 4. REFE~L FIELD ~OOK L-ea-~ m-SS. 5. GE ELEVATIONS FROM CED-RIXX-$365& 6, HORIZONTAL POSITION BASED ON ~0 CONTROL MONUMENTS P~R LDUN$SURY & ....................................O~ST.OiST.o,~,P~o--' Well" Y ASPs X LAT!.T_UDE .... LONGITUDE FNL [WL Liar. EJev_ · I 6~02 2,095.27 525,478.27 ~° ~8' 17,358" 1490 47'$0.897" 724' 1842' 17.5~ 23,9' 2 6,022,075. 89 525 ~490.94 70028' 17,128" 149°47'$0.5~6'' 745' 11~$5' 17.7: 5 6,022,052. 13 525,505,67 70°.2~' 16,915 ' 149°47'$0, 154" 764 1867' t?.9 2~7 4 6,022,030.55 525,515.56 70~281 86.70i 149 47 29.e06 109: 1879', le,.oI $ 6,022,008.67 525,528.:58 70ezs, '* 149e 47' 29.4~," 81 i, lm2T5, 149047:29,07, ~ 032, 1904, la. i', 6 ~,02, ,907, i2 525,54o.75 '~' 1~485,, loo2, m, ~ ? 6,021 ~965.~ 5~$ ~$$$.46 16.059 149°47 28,699. 81~_4; 1~17, I~.~, ~1 , ~$,e45~,,. ~9 47,28.~.. 876: 19~9, ~8.,~; 8 6,0Zl ,943. 75 5~ ,~.~ ~, o ' " ~ 6~021 ,~2~. 12 $~ ,578.27 i5.632 149° 47 27.974 ~9T 1941 18.4 23.2 I0 6~02l ~84~ 525 ~623.61 ~' 14.~3" 149047'26.6~'' 975' 1986' 18.?' Il 6,021,822. ~ 525,6~5.71 ~" 14.651" 149e 4T'26.Z95' ~7' 1998' 18.8' 23.5' ~2 6,02I ,8~.87 525,648.~' 7~28~ 14, 437'" 149~47',~.9~" I019' 201/' 18.8' 251~ f3 6,021,779. 16 525,66t ,~ ~o~, 14. 223" 149°47 25.~" 1041', Z~4', 18.9', 23.0, 15 6,021,735. 76 525 ,~6. S2 ~' l~.~5 ~49°47 24, a~ 1084 2048, 19.0, 16 6,021,714. 15 585,6~. 17 ~028' 13.~3' 149047'~4.4~" l l~ 20~, 19. i 2z9 17 6,0zi ~69~ 5~5,710.85 ~' 13. S6~" /49047'Z4.0~' 112~ 2073 ]9.0' i8 6,02 I ,670.97 525,7~.~ ~25' 13. 157" 149°47'8~,7~' 1149' 2085' 19.0' 23.5' lU · i , -,~,1 , ,,, .... .__ .-ARCO Alaska ,D'S' $-0 .. WELL COUNSBURY soci tes ITEM (1) Fee CHECK LIST FOR NEW WELL PERMITS Company ./,~dO Lease & Well No. ~ ~ APPROVE DATE YES NO ~~ 1. Is the permit fee attached .......................................... (2 thru 8) (3) Admin ~~. ,,,g/~,/89 9. (9 thru 13) 10. (10 and 13) 12. 13. (14 thru 22) (5) BOPE , , (23 thru 28) 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~ ,, 4. Is well located proper distance from other wells .................... ~ __ 5. Is sufficient undedicated acreage available in this pool ............ ~ , .... 6. Is well to be deviated and is wellbore plat included ................ ~ .... 7. Is operator the only affected party ................................. _~ ,,, 8. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. .~ Is a conservation order needed ...................................... , ....... Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ ,, . 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate~w~ , ,, Are necessary diagrams and descriptions of diverter and BOPE attached. ~4~ . . Does BOPE have sufficient pressure rating - Test to ~OOo psig .. ~, , Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. .~. (29 thru (6) Add: ~~ .?-~-~W For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones .......... .....~/ If an offshore loc., are survey results of seabed conditions pressed 32. Additional requirements ............................................. ~ 0 mm Geology: En give_er lng: rev: 02/17/88 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not padicularly 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. TAPE .rlON 5I~TING bVP OlO,H02 VERIFICATION LISTING PAGE 1. ** REEL HEADER SERVICE NAME IEDIT DATE 188/04/23 ORIG~N ~ REEL NAME I72673 CONTINUATION # 101 PREVIOUS REEL COMMENTS Ibis TAPE, ARCO ALASKA, INC, ]O-17w APl ** TAPE HEADER SERVICE NAME 1EDIT ORIGIN TAPEINAME CONT NUATION # P~EVIOUS TAPE C ~M~NT$ ~LIS TAPE, ARCO ALASKA, INC, 30-17, APl 50-029-21795 *$ FILE HEADER FILE N~ME :EDIT ,001 SERVICE NAME VERB:ION # LENGTH I 1024 F P INFORMATION RECORDS MNEM CONTENT& CN I ARCO ALASKA, INC, 9E 22 NORTH SLOPE 000 000 0t7 065 000 000 006 065 bVP 010,H02 VERIFICATION bISTiNG PAGE 2 , $CHbUMBERGER , AbASKA COMPUTING CENTER CONPANY = ARCO AbASKA~ INC. WB~b m 30-17 FIEbD = KUPARUK COUNTY m NORTH SbOPE BOROUGH STATE a AbASKA ~OB NUMBER AT AKCCI 72673 RUN #1w DATE bOGGEDI 09-APR-g8 bDel d. KOHRING DATE PROCESSEDI 22-APR~Bg CASING = 9~25" e2721'(LOGGER) ' BlT SIZE - 8,5" TO 9219'(LOGGER) ~YPE rbulP = b D PObYMER DENSITY = 10,0 LB/G RH = 4,42 ~ 64 DF VISCOSITY · 43.0 $ RMF : 3,82 ~ 62 DF 40 i 62 DF PH · 8,5 RMC = FbUID b058 m 4,2 C3 RN AT BHT { :974 { 152 DF FIEbD REMARKS1 1 t/2" STANDOFF USED ON Dlbl ~ATRIX DENSITY s SAND FbUID DEN&ITY s 1.0 G/C31HBbE CORRECTION = CAb~PER (2,65)~ BHS = OPEN~ bVP 010,H02 VERIFICATION LISTING PAGE 3 TOOL TYPES/NUMBERS~ DIS-EC-2140 DIC'DA'2191 PGE'HE"lO26 CNC-A-1449 SGC-dC-2259 PGC-H-1041 THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERbA~'$ FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE CEDIT,001)I <SEE FZbE EDIT,O02 FOR 1,2" SAMPLED FDC/CNL DATA> DUAL INDUCTION SPHERICALLY FOCUSED LOG (cOIL) FIRST TO bAST READINGI 9200' TO 272~' COMPENSATED NEUTRON bOG (.CNb) FIRST TO bAST READINGI 9165' TO 7850' ¥ IN CASING (.CHh) GAMMA FIRRAs'T TO bAST READINGI 2798' TO 989' LVP 010,N02 VERIFICATION LISTING PAGE 4 ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE 2 1 66 0 4 8 4 73 60 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 AP1 AP1 AP1 FILE &IZE SPb REPR ID DEPT TENS DIL SFLU ILO DIb 8P GR TENS FDC DPHI FDC RHOB FDC DR.O ZDC ~LI FDC FDC ~ENS tnb PH! CNb ~ CNb CNb CNb CNb CNb GR CHL ORDER # PROCESS FT bU O0 6 OHMM O0 2 OHMN O0 1 OHMM O0 1 M.V O0 0 GAPI O0 3 U OO G/C3 O0 G/C3 O0 Ii~0 ~6 IN O0 28O GAPI O0 30 oo ~ ~ O0 420 O0 000 PS O0 000 PS O0 000 CPS O0 000 CPS O0 000 B O0 GAP! O0 310 bOG TYPE CLASS MOD NO, O0 0 0 O0 0 0 0 0 0 0 0 0 0 0 ioo o o 0 0 o o° 0 0 0 0 0 0 0 0 0 0 0 0 o 0 o °o 0 0 0 0 ° o oO o 0 0 0 4 ) 46 4 44 4 Ol 4 O! Ol 4 O! O0 O0 O0 O0 Ol I 68 oooooooo0oo0oo ! 68 0oooo0oo00oooo I 68 00000000000000 I 68 00000000000000 68 00000000000000 ! 68 00000000000000 I 68 oooooooo0ooooo I 68 oooo0oo00ooooo 1 68 00000000000000 ooo 4 I 68 00000000000000 DATA 9209 0000 TENS 2050~1143 GR 7152 0000 SFbU GR DR:HO 71! 122 TENS 12¸ 2500 2 9728 715~ · ,999 2500 NS RCNT TENS 12 1.9 -999 ( bVP 010,H02 VERIFICATION LISTING PAGE 5 DEPT DPH! RTNR CNTC DEPT Oe, I GR R?NR CNTC DEPT R RTNR CNTC EPT CNTC DEPT CNTC ~PHI ~TNR DEPT O0 TENS . TENS 181~.5179 ~FT .0820 9000.0000 TENS RHOB 88,3750 TENS '~:0805 RCFT 227 0205 GR 89~ 0000 0353 2438 62 TENS SP RHOB TENS 8800.0000 TENS 4410 RHOB 78,6250 TENS 9170 GR 3 2084 8600 0000 85010 !9 110 I72:~ 840:0,0000 16'' 123.7500 IENS P RHOB TENS ! TENS RHOB GR TENS TENS 7528 0000 -14 0000 2 3627 7528 0000 45O 0602 124 9375 7368,0000 -18,5000 2,3943 736800000 70001079 88,3750 7760 0000 *49 0000 2 2941 7760 0000 9687 7352 0000 =2~ 5000 4117 oooo ,1956 78 6250 oooo 5000 724~ 48¢5 0000 617 8068 12i 5000 7204 0000 5708 105 1250 ~76 ! 7224,00.0'0 0000 3750 7224.0000 SFLU GR DRHO NPH! RCNT TENS &FLU GR DRHO NPHZ RCNT TEN& SFLU GR DRHO NPHZ RCNT TENS SFLU GR DRHO NPH! RCNT TENS SFLU GR DRHO NPHI RCNT TENS SFLU NPHI RCNT TENS GR &:FLU NPHI 2,718! 124;9375 2674 1812.9392 '999,2500 6 3361 88 3750 0 0227 34 2347 2236 8257 -999 2500 5269 9687 0 0684 3~ 6714 2500 XLD TENS CALl TNRA CFTC GR TENS CALl TNRA CFTC ILD TENS CALl TNRA 11,2438 ILD 7§,'6250 TENS *0191 CALl 32,5301 TNRA 225:0'6465 CFTC '999,2500 GR 4 '"999 2500 GR S 0 ' AZ 0 2'5 CAb 7'325 TNR . 2,1.252 !23,7500 TEN 0;0234 CAb 44.8448 TNRA 2,5048 7528,0000 9,1484 3,6109 511'5764 -999,2500 6,1975 7368'0000 :,o47 O349 791;5238 -99902500 9782 oooo 54 2500 8154 7 5044 73592 -999 10,0000 .68~::i3:770774 999;2500 9807 -999 2500 72 3 4 LVP OlO,H02 VERIFICATION LISTING PAGE 6 RTNR ~:7679 RCFT CNTC 181 7288 GR DEPT 8300. ?E SP DpHI 6525 RHOB GR 1½ 0 TENS 75O RTNR 1545 RCFT CNTC 178 221 GR DEPT 8200.0000 TENS FT CNTC 211 9404 GR DpH! GR R CN?C 14 6707 140 275.00 8000 0000 2084 1880 RHOB TENS TENS RHOB HI 7800 0000 ...... FT O0 GR O0 - NS C~ 7600.0000 TENS 2.9672 SP 446,~672 123, 500 RCNT TENS .00 8 GR ~PH! 408 RCNT 1740 TENS 677! 0000 ' I 6 64 2 364 0000 6664 0000 -18 5000 666~ 40~9 O0 0 60 6640 0000 -2~ 0000 0000 0?04 105 3125 6764, -99g [500 SFbU GR DRHO NPHI RCNT TENS SFLU GR DRHO NPHI RCNT TENS SFLU RHO NPH! RCNT TENS SFLU GR DRHO TENS 6528.00'00 Srb13 -42.2913 GR 1779.1313 CFTC '999,2500 GR 4.0290 ILD 174.7500 TENS '0,0061 CALX 45,2192 TNRA 1762,9551 CFTC -999,2500 GR 1.9422 364,0000 TENS 0,0186 CALl 35,4290 TNRA 2046'1899 CFTC '999,2500 GR 14~ 7997 2500 -0 0,028 36 9393 1991 4246 -999 2500 6~: ILD TENS CALX TNRA CFTC GR 975'5 ILD -999 ) GR TC 2 ,': 7786 I:bP 121,0000 TENS 511 7901 -999~2500 ~,7050 6828;0000 9'5000 3,6917 .495,6846 999,2500 I 6166 67729 0000 2!87 -999 2500 66642 8104 0000 2,315'8 664~ : ,: 0753 .00 -999 500 2.9474 '999,2500 LVP OlO,H02 VERIFICATIOn; LISTING PAGE DPH! GR RTNR CNTC DEPT IbM DPH! GR R?NR CNT¢ OpHI GR RTNR CN?C EPT DpH! GR )~NR CNTC CI C T '999,2500 RHOB '999,2500 TENS -999,2500 RCFT '999,2500 GR 7500,0000 TENS '999.~ TENsRHOB -999,2500 RCFT -999'2500 GR 7400 0000 '99~ 8998 2500 -999 2500 -999 2500 -999 2500 730~ 0000 0376 -999 2500 -999 2500 -999 2500 -999 2500 7200 ~00 -999 ? o : ooo 5045 -999, '9991 7000 - 99:~: 2500 ~9999 - 99 TENS SP RHOB TENS RCFT GR s HOB TENS RHOB TEN RCFT 'R T~NS S. RHOB TENS TENS RCFT '999,2500 '999,2500 '999,2500 "999,2500 o 8.oooo 9541 -999~2500 -999,2500 -999, O0 '999.~00 °° 6308i' O0 -99~ 95 -99 500 -999; 500 6200 0000 -9 5O0O -999 :0 -999 2500 -999 2500 6'04'0,0000 '~,7578 '99'2500 '999,2500 '999;2500 '999,2500 5O0 5O0 ~500 ~500 58 00:00 -999 57~ 5O0 50O DRHO NPHI RCNT TENS DRHO NPH]: RCNT TENS SFLU GR DRHO NPH! RCNT TENS SFbU GR DRHO NPHI CNT SFbU NPH! RCNT TENS GR DRHO NPH! RCNT TENS SFLU NPH! TENS bU RHO PHI -999 -999 -999 -999 250O 2500 2500 2500 CALl TNRA CFTC GR 2,5738 101'1975 =999,2500 '999,2500 "999,2500 '999;2500 bD ~ENS CAb! TNRA FTC R 2,6614 .106,1250 .999'2500 .999,2500 .999'2500 999,2500 TEN6 CALl TNRA CFTC GR -999 -999 8796 5625 TENS 50 TNRA 2500 CFTC 2'500 GR .] '999 2500 GR 4288 XbD -999, ~500 GR -999 -:999 -999:~500 -999 500 -999 ~500 -999~ 500 . 2,6324 999,2500 "9 , 500 .191.1 oo "999,2500 '999,2500 ,8978 "99~,2500 "999,2500 '999,2500 -999;2500 -999,2500 .99~'0090 ;25oo '2.500 -999,2500 '999,2500 -999 O0 '999 ",ii,',O0 -999 2500 999 -9,99 '999 2,5911 999,2500 999;2500 "999,2500 "9:99:;:25!00 -999,2500 LVP 010,H02 VERIFICATION LISTING PAGE 8 /DEPT ~80~,0000 TENS bM 0465 SP DPHI 99 ;2500 RHOB "999,:)500 TENS RG~N" '999. 500 RCFT CNTC -999.2500 GR 5628 0000 SFLU 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 TENS DEPT 6700,0000 TENS 5572,0000 SFbU Ib~ 3,1792 SP -24,5513 GR DPHI -999.2500 RHOB -999.2500 DRHO GR -999.2500 TENS "999.2500 NPHI RTNR ~999.2500 RCFT -999.2500 RCNT CNTC 999.2500 GR -999,2500 TENS 6600 0000 TENS DE.PT PHI GR RTNR CNTC DPHI GR CNTC 2 -999 -999 -999 -999 I89 8P O0 RHOB 5 0 TENS 5~0 RCFT 2500 GR 6500. 000 067 2500 RHOB -999'2500 TENS '999, GR 6400 0000 TENS SP RH'OB 500 TENS 500 R~FT -999 500 G 630~ -999 ~99'9 ,,999 ,-999 0000 TENS 1078 SP TENS RC.FT GR 6200i -999 ' 9.99 -999 TENS 2500 GR 6t0;~ -999 2500 RCFT RTNR 5728 -20 -999 -999 -999 -999 )000 SFbU ~500 GR }500 DRHO }500 NPHI 2500 RCNT 2500 TENS 5292 -999 -999 -999 -999 o00o 2500 2500 DRHO 2500 NPH! 2500 RCNT 2500 TENS 5060 0000 SFbU "99~ GR DEHO RCNT -999 2500 TENS -9' -999 -999 SFGU 0 0 TENS LU 500 RCNT 1875 TENS 2500 CAb! -999,2500 TNRA -999"2500 CFTC -999,2500 GE 2 9791 108 6250 TENS -999 2500 CAb! -999 2500 TNRA -999 2500 CFTC '999,2500 GR 2 5436 lbD .108 3750 TENS 999 2500 CAbl -999 0 -999 )50 TNRA 500 CFTC -999 2500 GR .10~,4178 XLD ~{250 TENS ?NRA ,2500 ~FTC ;2500 G~ 2 "'999, ~500 GR -999 6 :XbD 2500 GR -999 '999 '"999 2500 CFTC . 3,0612 999. 0 '999,2500 "999,2500 "999,2500 2~00 0 '999. -999.2500 '999.2500 2,7644 -999,2500 -999,2500 '999,2500 -999;2500 -999.2500 -999 -999 -999 -999 2: 4 -999 -999 2500 -999 2.500 -999 2500 LVP 010,H02 VERIFICATION LISTING PAGE CNTC '999,2500 GR DEPT 6000,0000 TENS IbM DPN! .99~,9883 SP "2500 RHOB GR -999.2500 TENS RTNR -999.2500 RCFT CNTC -999,2500 GR DEPT 5900 IbM 3 DPHI -999 GR -999 RTNR -999 CNTC '999 DBPT 5800 PHI "99~ GR -999 RTNR -999 CNTC -999 DE.PT 570~ ~H! -999 ~999 "999 "999 PT 5600 "99~ "99~ '99 -999 ,0000 TENS 1459 8P 2500 RHOB 2500 TENS 250O RCrT 2500 GR 0000 TENS 1253 8P 2500 RHOB 2500 TENS 2500 RcrT 2500 GR ,0000 8586 2500 RHOB 2500 TENS 500 RCFT 500 GR 0000 2500 TENS TENS RCFT GR -~99 - 99 5400 R CNTC '999 GR 530~,0000 TENS :, 8005 8 P -999,2500 RHOB '999.2500 4951,0000 '4~ 5000 -99',:25oo '999, "999.2500 4828,0000 ."42'2900 999'2500 '999;2500 '999.2500 '999.2500 4700 0000 ~43 2500 - 99 2500 -999 2500 -999 '2500 -999 2500 TENS SFLU GR DRHO NPHI RCNT TENS SFbU GR DRHO NPH! RCNT TENS SFbU NPH]: RCNT TENS 4652,0000 SFbU "43,3125 GR '999,2500 DRHO '999,2500 NPH! "999,2500 RCNT "999.2500 TENS 4744 I0 -999 2500 44 - 2500 4320 0.00.0 -999 "999: -999 2500 .., 2500 -999,2500 NPHI RCNT TENS DRH NPH¥ RCNT TENS SFLU DRHO '999.2500 GR 6845 500 o 2500 2,7436 . 84,3i25 999.2500 2999;2500 9:~ O0 ~ 9625 6250 -9: 2500 -999 2500 -999 2500 -999 2500 .0954 ,3750 IbD TENS CAbI CFTC GR CAbI TNRA CFTC TENS CALl TNRA CFTC GR I bD TENS CAb]: TNRA 10. 2500 GR -999, $ 2500 CALl -999,2500 ,0860 "99 ,2500 "999,2500 "999,2500 "999,2500 "999,2500 3,2191 '999,2500 -999.2500 -999.2500 -999.2500 -999;2500 . 3,2146 ~999, '999,2500 -999~2:500 -999.2500 · -999 999 -999 -999 25.00 9:9~ ,' ~999, O0 LVP 010,H02 VERIFICATXON LISTING PAGE GR CN?C DPH! GR CNTC DEPT DPHI OR RTNR CNTC DEPT GR R?NR CNTC D CNTC CNTC DEPT '999,2500 "999,2500 '999,2500 5200 0000 o 2 5707 999 2500 -999 2500 -999 2500 -999 2500 510~,0000 6633 -999~2500 -999;2500 -999,2500 -999.2500 5000 0000 3 096 -999 250§ '999 2500 -999 2500 -999 2500 4900 0000 298I -999 2500 '999 2500 4800 0000 -999 2500 470~: 9'9 TENS ReFT TENS RHOB TENS RCFT GR TENS RHOB TENS TENS TENS RCFT GR HOB RCFT GR TENS GR TENS 4600 0000 TENS -999 2500 GR 4500.0000 TENS '999.2500 "999,2500 -999,2500 4112,0000 'y~,2500 -99~,2500 "99~,2500 -999,2500 4084, .49,1000 -999' 500 "999, 3970 0000 500 -999 ~ O0 -999 ~00 3980 0000 '26 7969 -9999 2500 "99 2'500 38t0 00:00 -999 ,00 37i O0 O0 373'4 -999 1500 3470,0000 NPHX RCNT TENS SrbU GR DRHO NPHI RCNT TENS SFLU GR DRHO NPHI RCNT TENS SFLU GR DRHO NPHI RCNT TENS SFLU GR DRHO NPH! RCNT TENS SFLU TENS SFLU GR TENS, -999,2500 TNRA "999,2500 CFTC '999.2500 GR 2,4039 ILD -99 25 0 CAL! -999,2500 TNRA -99 := oo -99 2500 GR 2 2638 88 3t25 -999 2500 -999 2500 -999 2500 -999 2500 -999 "999 -999 2 -999 -999 -999 -999 -999 ILD -99t TENS CALl -999 TNRA -999 CFTC -999 GR -999 2,7734 XLD 3 87,8750 TENS -999 -999 12500 CFTC -999.2500 GR -999 9.99 2,8541 IbD 3 90'1875 TENS -999 '999~::2500 CAb! '~)9 -999, ;00 T~RA -999 -999, iO0 GR -999 .250o , O0 .6795 ,2500 ,2500 ,2500 ,2500 ,2500 8427 2500 .~500 500 2935 500 50O 2500 2500 -99 30:29 i. LD 3 8995 06.25 TENS 5O0 -999 2500 OR -999 !500 500 10 bVP 010,H02 VERIFICATION bISTING ][I.,M 5,255i Si:' -18 DPHZ ,,999,2500 RH00 -999 '999,2500 TENS '999 ~TNR '999.2500 REFT '999 CNTC '999'2500 GR '999 DEPT 4400,0000 TENS I~N . 5,1069 SP DPH! ,999"2500 RHOB GR 999,2500 TENS RTNR -999'2500 REFT CNTC -999,2500 GR DEPT R R DEPT DP:HI GR RTNR CNTC C{ 4300 0000 4 4801 -999 2500 -999 2500 -999 250 -999 250~ 4200 0000 5 -999 :999 999 -999 4100 TENS 8P RHOB TENS e83 aP 500 RHOB 500 TENS 500 REFT 2500 GR 0000 TENS 1704 SP RHOB TENS 4000 0000 .999~ TEN& SP RHOB TENS REFT GR ,,999 ,"999 RCFT GR 3800 0000 TENS 28 '999 ,''999 2500 GR .7500 ,2500 ,2500 ,2500 ,2500 GR DRHO NPHI RENT TENS 3370°0000 = {.5ooo -~,2500 -222,25oo '~,2500 -999,2500 SFbU DRHO NPHZ RENT TENS 328 -99 -99~ -99 0000 SFbU 2813 GR 00 DRHO O0 ~PHI 00 RENT O0 TENS 3250 -999 '-999 -999 0000 SFbU 5000 GR 2500 ORHO 2500 NPHZ 2500 RENT 2500 TENS 3264 0000 7813 2500 DRHO 2500 NPHI 2 oo 2500 ~000 SFLU GR DR:HO TENS 3044 R¸N FbU: -999 2500 TENS PAGE 88,0000 TENS -g99.2500 CAbI -999,2500 TNRA '999,2500 CFTC '999,2500 GR 4,5023 IbD 87,8750 TENS :999,2500 CAbi 999,2500 TNRA '999'2500 CFTC -999.2500 GR 9652 :7500 '9~9,,!500 CAb! -999,2500 TNRA -999. '500 5,2759 ZbD ~ 5000 TENS '9' :25'00 CAb! "999 TNRA -999 CFTC -999 50O GR ,,9 "999,2500 '999,2500 '999,2500 '999, 500 '999,~500 5,5472 :999.2500 999.~500 '999,2500 :999;2500 999.2500 4 8637 -999 2500 :999 2500 999 2500 -999 2500 -999 2500 . 6,5471 ,,,999' 2500 '999,2500 3 '999 !500 G.R ,2303 .D ',,999, bi ""999~ 99:93 ibD -999 2500 TNRA -999 2500 2500 CFTC -~§ 2500 -99.9 2500 GR ..999 2500 11 bVP 010,H02 VERIFICATION blSTING PAGE 12 DEPT ~700,0000 TENS Xb~ 43,9520 SP DPN! 999,2500 RHOB GR -999,2500 TENS RT~R "999,2500 RCFT C~TC '999'2500 GR DEPT PHI 9~9 GR -999 TNR -999 NTC -999 3600 0000 TENS DEPT 3500 IbM 12 DPHI '999 GR -g99 TNR -999 NTC '999 DEpT D~HI ¢ 500 TENS 500 RCFT 2500 GR 0000 8776 500 RHOB 500 ?ENS 2,500 2500 3400 0000 11:8376 :999,2500 RHOB 9:99,, 500 GR RHOB TENS 3200 "9 -999, GR 3000 0000 TENS SP RHL]B ,,,999 2500 TENS 2914,0000 SFbU -69,2500 GR -999,2500 DRHO -999,2500 NPHI -999.2500 RCNT -999.2500 TENS 2720 0000 SFbU ooo 2500 DRHO -999 2500 NPH! -999 2500 RCNT -999 2500 TENS 2594,0000 SFLU -7i,2500 GR '999,2500 DRXO -999,2500 NPH! -999,2500 RCN? -999.2500 TENS 2584 -999 0000 6FLU 7500 GR 2500 DRHO RCNT 2500 TENS 500 DRHO NPHi T~CNT 2484 0000 SFbU -999 TENS -999 NPH! ~999,2500 .999,2500 999'2500 -999,2500 TENS CAL! TNRA CFTC ,3314 500 -999,2500 IbD TNRA CFTC GR -99~ -999 -999 50 ! D 2500 CALl }500 ?NRA ~00 I6,5662 IbP CALX -999 25OO -999,2500 '999,2500 .999' 12 8324 :999 0 ,,, -999 2500 -999 2500 -999 2500 2500 -999 2500 -999 2500 -999 2500 -999 2500 II ! ' ,,, , "999,2500 :999 2500 CFTC =999 999 2500 GR i~:~9 -999 ) GR 2500 · , 9'9~, ! TC 9~10:!562 TEN~ -999 ,2500 CA:bi ',,999'2500 TNRA ,,,999 2500 bVP O10,H02 VERIFICATION LISTING PAGE 13 i~TNIR -999. 2500 RCFT 9999~ 2500 RCNT -999. 2500 CFTC -999. 2500 CNTC: -999.2500 GR ~99 2500 TENS -999.2500 GR ,,,999.2500 DEPT 2900,000 TENS I~ . 14,190~ SP DPHI 999,2500 RHOB GR -999.2500 TENS ,TNR -999.2500 ~FT C.TC -999.2500 DEPT IbM DPHI GR RTNR CNTC yEPT DpHI GR RTNR DEPT PH! CNTC DEPT IbM 2800 0000 TENS 6 7683 SP -999 2500 RHOB -999 2500 TENS -999 2500 RCFT -999 2500 GR 00 0000 TENS O0 0000 SP -999 2500 RHOB -999 2500 TENS '999 250 RCFT '99':9 250g GR 2600 0000 TENS ' 0 '999,25*:0 SP '999,2500 RHOB '999,~500 TENS -999'~500 ReFT -999,2500 GR 2500 RHOB 2500 TENS 2400 0000 TENS R:HOB TENS RCFT 2500 OR 2200,0000 TENS '999,2500 SP o.oooo 4,2500GR i 99,2500 DRHO 99,2500 NPH! 99,2500 RCNT 99,2500 TENS i 240.0000 SFbU ~67,2500 GR 99,2500 DRHO 99~,2500 NPHI 99 ,2500 RCNT 999,2500 TENS -999 -999 ,,,999 -999 00 SFbU 13 GR 500 DRHO 500 NPH! 50 RCNT 50~ TENS -999 '999 '999 '999 '999 '999 2500 SFGU 2500 GR 2500 DRHO 2500 NPH! 2500 ReNT 2500 TENS -999 -999 ,,999 '999 ' 0 5 0 SFbU ~500 GR 2500 DRHO 2500 N'PH! RCNT TENS -999 2500 SFGO -999 2500 TENS 1{,5259 IGD . 51'3750 TENS 999,2500 CAbI -999'2500 TNRA :999,2500 CFTC 999'2500 GR 5 5453 IbD 86 2500 TENS -999 2500 CAbI -999 2500 TNRA -999 2500 CFTC -999 2500 GR 2000 0000 36 8125 TENS -999 2500 CAb! -999 2500 TNRR -999:2500 IbD 2114 0000 GR 500 5,00 TEN 2500 CFTC 0000 GR '999,2500 ILO :999,2500 TZNS 999'25:00 CAb,! -9! ,2500 TNRA ;:250:0 CFTC 201 ,0000 GR DRH N:PH~ '999,:2500 SFbU : '999 '999,2500 GR '999 ~o TENS 17,9132 -999,2500 -999,2500 -999,2500 "999,2500 -999'2500 8 3173 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -9~ b741 2500 -999 2500 -999 2500 2500 3125 -999 2500 -9 ¸9 35 562.5 '999,2500 '999'2'500 '999,2500 -999;2:500 250O -999 2500 -999 -999 7813 ,2500 -9' ,2500 LVP OlO,H02 VERIFICATION LISTING PAGE 14 DPHi EPTb~ DPH1 GR RT~R CN?C 2100 0000 .999 2500 -999 2500 RHOB .999 2500 TENS "999 2500 RCFT -999 2500 GR -999 250O SFbU '''999 2500 GR -999 2500 DRHO -999: 2500 NPH! -999 2500 RCNT -999 2500 TENS DEFT DPH! GR RTNR CNTC 2000 0000 TENS -999 2500 SP -999 2500 RHOB -999 ~500 TENS -999 500 RCFT '999 2500 GE -999 250O CAGI -999:2500 TNRA "999.2500 CFTC 1885,0000 GR b~ D~HI G N?C ~900 999 -999 -999 -999 -999 000 TENS 500 SP TENS 2500 RCFT 2500 GR -999,2500 -999.2500 TENS -999,2500 -999'2500 TNRA -999,2500 CFTC 1855'0000 GR CNTC 1800 0000 TENS RHO.B -999 2500 GR '999.2500 SFLU '999,2500 IbD -999,2500 GR -999,2500 TENS -999,2500 DRHO -999,2500 CAb! -999.2500 NPHX ~999,2500 TNRA -999,2500 RCNT 999,2500 CFTC -999,2500 TENS 1790,0000 GR DPH! G~ · TENS "999.2500 SFbU ~999.2500 GR -999,2500 DRHO -999'2500 NPH! -999,2500 RCNT -999~2500 TENS CNTC I600 0000 TENS "999~ -9'99.~ HOB '999::.. "9:9::9~ -999,2500 GR 000TENS 500 8P 500 RHOB 500 TENS 500 RCFT 5'00 GR '999 2500 ,soo ''':999 2500 SFbU -999 TENS -999 -999 2500 lbD 2500 TENS 0000 -999 1745 000 IbD GR '999.2500 '999,2500 '999.2500 51.5313 "999,250 -999;250~ -999,250 ---999',250~ '999.250~ 21.968 -999,2500 -999,2500 -999'2500 -999,2500 -999,2500 53.96~? -999 2500 -999 2500 -999 .-999 2500 39 3438 ~:9:99 1675 ...999 TC ..999 29 :50'0 I-L':D -999: -9 9 -99:9 .,999 8437 "9:99 ~VP OlO,H02 V~RI~ICA?ION bI$?IN~ PA~ 15 DEFT ~400,oooo TENS 15~ ~999.2500 OPHI 999,2500 RHOB GR -999,2500 TENS RTNR "999,2500 RCFT CNTC '999,2500 DEPT 1300 IbM "999 DPHI '999 GR "999 RTNR "999 CNTC '999 999 DPH! -999 GR -999 RTNR -999 CNTC -999 PH! CNT:C ,Hz .1100 999 -999 -999 2500 2500 RHOB 2500 TENS 2500 R~FT 2500 G 0000 TENS 2500 SP 2500 RHOB 2500 TENS 2500 RCFT 2500 GR 000 TENS 500 SP 2500 RHOB 2500 TENS 2500 ~: ~000,0000 2500 :999, :999;2500 999,2500 -9:99.2'50:0 '999,2500 988 5000 '999 2500 -999 -999 HOB RCFT TENS SP RHOB TENS '999,2500 "999,2500 "999.2500 ~999,2500 .'999,2500 999,2500 "999,2500 '999,2500 -999,~500 ~999, 500 999,~500 '999, 500 -999 2500 -999 500 -999 500 -999 2500 -999 2500 -999 2500 -99 -99~ 2500 2500 '999 2500 '999 2500 -999 2500 -99~ 2500 -99 2500 2500 2500 -999 2500 2500 2500 2500 2'500 SFLU GR DRHO NPHI RCNT TENS SFLU GR DRHO NPH! RCNT TENS SFbU GR DRHO NPH! RCNT TENS SFbU GR URHO NPHI TENS SFLU e RHO NPH! RCNT RHD TENS ,O01 NAME # I bENGTH = 1024 EOF $********* -999.2500 -999 2500 -999:2500 99.2500 1570,0000 '999,2500 "999,2500 "999,2500 -999'2500 -999,2500 1540.0000 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 t485 0000 =999 2500 2500 0000 ILD TENS cabI TNRA CFTC XbD TENS CAb! TNRA CFTC GR TENS CAbI TNRA CFTC GR ZbD TENS AbI NRA CFTC -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 42 7188 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 43 0313 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 47 6250 999 2500 999 2500 -999 -999 999'2500 999, -999' '999; 56,5938 -999 58 bVP OlO,H02 VERIFICATION 5ISTING PAGE 16 [I** bE; HEADER ** Fib NANE IEDIT ,002 ERV[CE NAME = DATE :_ ~AXINU~ LENGTH I 1024 FILE TYPE l PREVIOUS FILE ~ THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAY& FIELD PRINTS SCHLUMBERGER bOGS INCLUDED WITH THIS FILE (EDIT,O02)t <SEE FILE EDIT,O01 FOR 6" SANPLED D/b,/FDC/CNb/GR DATA> ~ADINGI 9180 TO 85:50' 9165' TO 8550' LVP OlO,HO2 VERIFICATION LISTING PAGE 17 DATA FORMAT RECORD ** ENTRY BbOCKS TYPE SIZE REPR CODE ENTRY 2 I ~6 0 4 9 4 65 ,lIN 16 I 66 1 0 1 66 0 DATUH SPECIFICATION BbOCKS ID ORDER # DEPT O0 0 0 TENS FDH DPH! FDH HOB FDH RHO FDH C~:bI FDH G FDH TENS CNH NP, H:! CNH T CNH R' CNH R.t CNH CNH CNH GR CNH PROCESS bOG TYPE CLASS NOD NO, FT O0 000 4 bB O0 635 21 0 0 4 PU O0 890 oo 0 0 4 /~] OO 350 02 0 0 4 / O0 3Sb 01 0 0 4 IN O0 280 01 0 0 GAP! O0 10 O1 0 O bB O0~ 0 PU O0 ~ ~ 21 0 0 4 4 O0 0 oo o o O0 000 0 0 CPS O0 000 O0 0 ~ ~ CPS O0 000 O0 0 CPS O0 000 O0 0 CPS O0 000 O0 0 GAPI O0 310 O1 0 0 CODE ¢OCTAb) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000.000 4 I 68 00000000000000 9'227 ~729 TENS CFTC ,8120 21~123;0039 ~7729 9100 ;2988 TENS 0 43 1819 2876 CFTC 5208,0000 DPH! 797,2004 CNTC 66,8860 RHOB I 5464 .: 0 TENS 5208 , I R'CFT 729~. 218.3, I OR 1 Ob 500 76845,0000 DPH! ,3828 GR ,7837 I~T~R _ 7544 508 DPH! GR RTNR CNTC I9 2,3271 10] 7544, 471' 1800,7866 GR ' 109,562 bVP 020,H02 VERIFICATION bISTING PAGE 18 DE:PT DRHO NpH! RC:NT 9000,2988 TENS 7160 0,0464 CAb! 8 32,1839 TNRA 2 2237,9780 CFTC 838 DE:PT 8900 DRHO 0 NPHI 35 RCNT 2075 2988 TENS 742~ 0688 CALl 0527 TNRA 3 9487 CFTC 776 DEPT 8800.2988 DRHO ~,0267 NpH! 3 ,8998 RCNT 2063,7671 DEPT 8700,2988 DRHO 0,0233 NpHl 30).6209 RCNT 19 6011 DEPT 8600 2988 DRHO .0i0052 NpHI 39 2130 RCNT 1801,0532 ,0000 ,7656 .9067 .9235 TENS 7248 CALl 9 TNRA 3 CFTC 732 0000 ;4922 ,0542 ,7998 TENS 7268 CALl 9 TNRA 3 CFTC 671 ,0000 ,1172 .1513 ,9897 TENS 6988 CALl 9 TNRA 3 CFTC 531 ,0000 ,9453 .0944 ,6515 DEPT 854.,9,5996 TENS DRHO O, 0042 CALl NPHl 75501.4097 rNRA R~:NT 1 , i 145 CFTC 0000 ,1813 , 456 ,5695 6920,0000 9957 44 . 1559 DPHI GR RTNR CNTC DPHI OR RTNR CNTC DPHI GR RTNR CNTC DPHI GR RTNR CNTC DPHI GR RTNR CNTC DPHI GR RTNR CNTC 16,0478 RHOB 89,5625 TENS 2,7179 RCFT 2356,7695 GR I], 4184 RHOB ,8750 TENS 226~,8077 RCFT ,0156 OR 13,5464 RHOB 625 TENS 2215,i226 OR 12 , TENS , 9 GR 1 17 1670 GR :3852 6 0000 7~65,6111 89.5625 ,00 o° 2,4265 7248,0000 647,7714 87,0625 2,~118 7268, 000 698,4463 128,7500 2 3362 6988 0000 459 0833 139 8750 0000 ,9197 .500:0 NAME # ~ DATE ~ ~XLE T~PE { NEXT FiLE NAME ,002 1024 23 : EDIT CO:MMEN? : IS' TAPE, ARCO AI,~ASKA,~, INC, 30"17 APl 50"029'2t795 ~VP OlO,H02 VERIfiCATION LISTIN~ PAG~ 19 SERVICE NAME IEDI? DATE :88/04/23 ORIGIN I RBEL NAME ~72673 CONTINUATION # ~01 NEXT R~EL NAME ~ COM'MENT$ Ibis TAPE, ARCO AbASKA, INC, 30-17~ API 50-029-21795
