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196-146
ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5220 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5220 3J-17 50029227000000 Plug Setting Record 27-Dec-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 196-146 T39937 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:13:13 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 11/22/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5164 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5164 3J-17 50029227000000 Production Profile (PPROF) 11-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 196-146 T39793 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.22 09:39:06 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ,4ECEIVEr'i • • 21--t MAY 10 Zulu WELL LOG TRANSMITTAL#903221446 ACOCC To: Alaska Oil and Gas Conservation Comm. May 6, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 5 Asp/2016 .v1. K.BENDER RE: PPROF, RCBL, MFC: 3J-17 Run Date: 3/30/2016 - 3/31/16 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3.1-17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22700-00 Production Profile Log, Radial Bond Log, Multi-Finger Caliper 1 Color Log ea. 50-029-22700-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating SOAKED Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / ..E:ite."-C PageS~'NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. !J~ ~7 - J~/~ ~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages:::~ Grayscale, halftones, pictures, graphs, charts- Pages: Complete [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other Scanned by: Beverly Di~n~;""~/incent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent ~ Lowell Date:O-/~ /si ~_... • • STATE OF ALASKA • ALAa,:A OIL AND GAS CONSERVATION COMIv. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Perforate r Other (;r SC Repair Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r - 196 -146 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 - 50- 029 - 22700 -00 -- 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025630 a — 3J -17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): r K uparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8154 feet Plugs (measured) None true vertical 6537 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7135 true vertical 0 feet (true vertucal) 5750 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 1640 630 SURFACE 4409 10 4450 3737 6890 4790 PRODUCTION 7427 5.5 7457 5991 7000 4990 LINER 927 3.97 8153 6536 10160 10540 Sleeve 17" 8" .500 wall 44# Perforation depth: Measured depth: 7640 -7660, 7831 -7851, 7872 -7896 RECEIVED True Vertical Depth: 6128 -6143, 6274 -6290, 6306 -6325 JUL 0 6 2012 Tubing (size, grade, MD, and TVD) 3.5, L -80, 7217 MD, 5812 TVD AOGCC Packers & SSSV (type, MD, and TVD) PACKER - BAKER SABL - PACKER @ 7135 MD and 5750 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): na t_ iET JUL 2 4 2012 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation na na na na na Subsequent to operation na na na • na na 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r ■ Service r Stratigraphic r 16. Well Status after work: o Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -185 Contact Martin Walters / MJ Loveland Printed Name MJ Loveland Title Well Integrity Supervisor Signature ��� hie: 659 -7043 Date 7-4-12 1 1 RBDMS JUL 00 t % 3/1' , 7. 7/2_ 0T�4 Form 10-404 Revised 11/2011 Submit Original Only ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 July 04, 2012 R ° cE, VED J tiL 0 6 Commissioner Dan Seamount 4OG Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 3J -17, PTD 196 -146, Sundry 312 -185 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, 6/2J M oveland ConocoPhillips Well Integrity Projects Supervisor 4110 4111 . • • 3J -17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/11/12 SET 2.75" PXX PLUG @ 7209' RKB, SET JUNK CATCHER @ 7200' SLM, LRS TO LOAD TBG/ IA w/ BRINE. COMPLETE.145 BBL 11 ppg brine and u tubed 40 bbl deisel 06/05/121 Cut one 18" X 20" window in conductor I 06/06/12 Cut another 18" X 20" window in conductor and removed cement. Cleaned sealant out of conductor. Buffed surface casing for corrosion inspection, 06/10/12 Removed 8' 1" long 16" conductor and chipped cement off surface casing. Pressured OA to 500 psi with N2 to locate leak point. Leak located 17.5" below OA VLV (1" below starter head). Buffed starter head and surface casing. 06/11/121CaII stateman (Bob Noble) for opportunity to witness damage to SC - he waived. 1 ✓ 06 /17 /12IInstalled and welded 17 "of 8" 44# .500 wall sleeve on to surface casing. 1 06/18/12 Post SC repair MIT -OA (PASSED),Initial T /I /O= Si0/0/0. Pressured up OA to 1800 psi and started one hour test.Starting pressure- Si0 /0/1800 15 min- Si0 /0/1800 30 min- Si0 /0/1800 45 min- Si0 /0/1800 Final - Si0 /0/1800 Bled OA back to 0 PSI. Took approx. 4 BBLS of diesel to reach 1800 PSI. Final T /I /O= 0/0/0. 06 /23 /12IWelded 7' 11" of 16" 62.58# .375 conductor pipe extension onto existing conductor. 1 .1. 11 ‘ 0 -$ ' 4,40,7- .0, .. ii. I n ©ConocoPhillips Alaska, Inc This photo is copyright by ConocoPhillips Alaska, Inc. Ii '144 and cannot be released or published without express written consent of ConocoPhillips Alaska 1' 1 f ill ''.- II ilk .. �. ,, v" y.; t } . a 4 F 1111 \ rot* 4 111‘ 1 7411 el k twoi 1 -1111 s‘ I ar \ 10 „.• c r 1. *MI 1 , 2 fi '44Q, i •ii v , 1444 4 ,.'"' i V IIIIMat (.1144110 ... ' f ol r --;;..c. , Ili . "..s..1 / k '''' ' . .;--,. ' , . . , , Z \) ,. 1 ' eNseIy sdpl!gdo p;uasuoo uau!iM ssaJdxa Tno43uu� pagsi�gnd 1 Jo pasealai aq }ouueo pue *' *out 'e )1seiy sdpI!4d000uo0 y Aq ag6!Adoo si ()loud si4J, x. oui 'efseiy sdffii4d000uo00 t . 0iIIINA ,IS • r - . �� ! $ ' i ., I 1 41 • • sITAKir[E AR SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM11HSSIOAT ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Martin Walters t 4 °ZQ� Well Integrity Supervisor 4. 1111) ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 4C,- 1 ; Re: Kuparuk River Field, Kuparuk River Oil Pool, 3J -17 Sundry Number: 312 -185 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this Z7 day of May, 2012. Encl. • • • Conoco Phillips Alaska P.O. BOX 100360 RECOO ANCHORAGE, ALASKA A 99510 -0360 Y MAY 1 72012 May 14, 2012 AOGCC Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3J-17, PTD 196 -146 surface casing inspection and repair. Please contact MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, fira/4 Martin Walters ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA R E E I T V {{ E D AMA OIL AND GAS CONSERVATION COMSION ,� v MA 17 Z c APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 C 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change A Pv QgQn r Suspend r Plug Perforations r Perforate f Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate ^ Alter casing r r Other: SC Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J , Exploratory r 196 -146 • 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22700 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No J 3J - • 9. Property Designation (Lease Number): 10. Field / Pool(s): 1 ADL0025630 ' Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8154 ' 6537 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' 1640 630 SURFACE 4409 7 -5/8 4450' 3737' 6890 4790 PRODUCTION 7427 5.5 7457' 5991' 7000 4990 LINER 927 3.5 8153' 6536' 10160 10540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7640 - 7660,7831 7851,7872 - 7896 6128 6143,6274 6290,6306 - 6325 3.5 L - 80 7217 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER = BAKER SABL -3 PACKER MD = 7135 TVD = 5750 SSSV = CAMCO DS NIPPLE MD = 518 TVD = 517 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/16/2012 Oil I Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Printed Name Martin Walters _ /� /� Title: Well Integrity Supervisor Signature ,' fi r` ` 't/ . Z Phone: 659 -7043 Date: 05/14/12 Commission Use Only Sundry Number& 12s 1 3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity T BOP Test r Mechanical Integrity Test r Location Clearance r Other N o f l f 7 /'1 O6 e e i'r► 5 p e tO r e `` c S l et G/ C Gt it U ` pro ✓ /'di /7 Md � CIo Gvv�fr7m , ,G'►'1 aF r C P lit - I /— ; Subsequent Form Required: y APPROVED BY Approved by: ,. A14,.... . COMMISSIONER THE COMMISSION D -te: S- Z.y --/ Z Fi S HAY 242011''. / '� / itin Du II ,v Form 10 -403 Re ised 1 /2010 5723/ ORIGIN Duplicate , \ • . , • • ConocoPhillips Alaska, Inc. Kuparuk Well 3J -17 (PTD 196 -146) SUNDRY NOTICE 10 -403 APPROVAL REQUEST May 15, 2012 This application for Sundry approval for Kuparuk well 3J -17 is for the inspection and repair of surface casing. Currently part of the surface casing on this well is exposed to the atmosphere and it appears there is corrosion taking place. 3J -17 has been determined to have a surface casing leak within an estimated 5' from surface. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with plug(s), kill weight fluid, and/or BPV. 2. Remove the floor grate, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and build —9' working cellar. 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform MITOA 9. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and /or BPV and return the well to production. 13. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 5/15/2012 KUP 3J -17 a ConocoPhillips Well Attributes Max Angle & MD TD �' Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) ,a 11tta ) 500292270000 KUPARUK RIVER UNIT PROD 45.07 6,100.00 8,017.0 C.axxa"" 1 r, Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date --- SSSV: NIPPLE _ 110 12/20/2010 Last WO: 4/28/2004 77.00 10/6/1996 _ We'. COnn g . - -1 1 26i 2 C121144.12AM Scnema. - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,891.0 9/12/2011 Rev Reason: SET PLUG & CATCHER ninam 1/26/2012 HANGER,27 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.625 40.5 4,449.6 3,737.4 29.70 L -80 BTC -MOD ® RP Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd t' PRODUCTION 5 1/2 4.950 30.1 7,457.0 5,991.2 15.50 L-80 LTC -MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ; LINER 31/2 2.992 7,226.2 8,153.0 9.30 L -80 ABM -BTC Liner Details CONDUCTOR, 1 Top Depth 42 -121 (TVD) Top Inc' Norni... NIPPLE, 515 A.. Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 7,226.2 5,818.6 41.41 PACKER BAKER SABL -3 PERMANENT LINER TOP PACKER 3.000 I Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd TUBING 31/2 2.992 26.7 7,230.6 5,821.9 9.30 L -80 EUE8rdABMOD Completion Details Top Depth MI (TVD) Top Inc! Nomi... GAS LIFT, _ (ftKB) (ftKB) ( ") Item Description Comment ID (In) 3,057 - - - - 26.7 26.7 -0.02 HANGER FMC HANGER 3.500 517.9 517.3 6.48 NIPPLE CAMCO DS LANDING NIPPLE 2.875 7,112.2 5,732.5 41.05 NIPPLE CAMCO DS NIPPLE 2.812 fl 7,119.3 5,737.8 41.04 LOCATOR BAKER LOCATOR 3.000 7,121.6 5,739.6 41.03 PBR BAKER 8040 PBR, 12' STROKE, 4" SEAL BORE 3.000 SURFACE, 7,135.4 5,749.9 41.00 PACKER BAKER SABL -3 PACKER 2.780 41.4,450 7,209.4 5,806.0 41.45 NIPPLE HALLIBURTON X NIPPLE 2.750 7,216.8 5,811.6 41.43 LOCATOR BAKER LOCATOR 3.000 GAS 4 625 7,219.7 5,813.7 41.43 SEAL ASSY BAKER SEAL ASSEMBLY W/O SEALS - STUNG INTO EXISTING 3.000 COMPLETION Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, _ (TVD) Top Intl 5,455 Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) = 7,200 5,799.0 41.47 CATCHER JUNK CATCHER (OAL= 125 ") 1/11/2012 0.000 7,209 5,806.0 41.45 PLUG 2.75 "PXXPLUG 1/11/2012 0.000 GAS LIFT, 7,226 5,818.4 41.41 ANCHOR K- ANCHOR IS LATCHED INTO SABL -3 PACKER /HANGER 12/2/1996 3.000 5,973 la - AT TOP OF LINER (original completion) 7,550 6,060.6 41.70 PLUG COMPOSITE BRIDGE PLUG 1/11/2012 0.000 Perforations & Slots GAS LIFT. _- Shot 1 6,615 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (s Type Type Comment IIII 7,640 7,660 6,128.1 6,143.2 C-3, C-2, C -1, 3/30/1999 4.0 RPERF 2.5" DP, +/- 90 deg phasing UNIT B, 3J -17 GAS LIFT. 7,059 - 7,831 7,851 6,273.7 6,289.7 A -4, A -3, 3J -17 12/21/1996 4.0 IPERF ' 2 1/2" BH, 180 deg. phasing � - 7,872 7,896 6,305.7 6,324.5 A -2, 3J -17 12/18/2007 6.0 APERF 2" PJ, 60 deg. random NIPPLE, 7,112 - - Notes: General & Safety t End Date Annotation 7/22/2010 NOTE: View Schematic w/ Alaska Schematic9.0 LOCATOR, 7,119 11/1/2011 NOTE: CONFIRMED TUBING LEAK © GLM 6615' RKB w/ LDL PBR, 7,122 11/1/2011 NOTE: PROBABLE CASING LEAK IN 51/2 @ 6830' RKB BASED ON LDL PACKER, 7,135 Mi CATCHER, 7,200 ■ IJ!4,I PLUG, 7,209 ■F NIPPLE, 7,209 i LOCATOR. ■® 7.217 f SEAL ASSY, 7,220 ANCHOR, 7,226 PRODUCTION, 30.7,457 PLUG. 7,550 P Mandrel Details RF, Top Depth Top Port 7, El III Top Intl OD Valve Latch Size TRO Run Stn Top (RKB) (RKB) (1 Make Model (in) Sery Type Type (!n) (Psi) Run Date Com... 1 3,056.9 2,658.4 39.44 CAMCO KBG2 -9 1 GAS LIFT DMY BTM 0.000 0.0 10/24/2011 2 4,624.6 3,874.5 38.21 CAMCO KBG2 -9 1 GAS LIFT DMY ' BTM 0.000 0.0 10/24/2011 IPERF, 7,831-7,851 al III 3 5,454.6 4,517.4 39.96 CAMCO KBG2 -9 1 GAS LIFT DMY BTM 0.000 0.0 10/24/2011 4 5,972.6 4,904.7 41.37 CAMCO KBG2 -9 1 GAS LIFT DMY BTM 0.000 0.0 10/24/2011 APERF, 7,872 -7,898 M IIII 5 6,615.0 5,363.5 45.02 CAMCO KBG2 -9 1 GAS LIFT DMY BTM 0.000 0.0 10/28/2011 Ext Pkg TD. 8,017 6 7,068.8 5,699.8 41.19 CAMCO KBG2 -9 1 GAS LIFT DMY BTM 0.000 0.0 9/12/2011 LINER, b 7,2266,153 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 4, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log: 3J -17 Run Date: 9/30/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3J -17 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22700 -00 SLA NED Mg a Z01Z PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 4/1'4 1 Signed: a WELL LOG TRANSMITTAL t9Ci t41C To: Alaska Oil and Gas Conservation Comm. November 4, 2011 Attn.: Howard Okland t 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 G'�,j RE: Leak Detect Log: 3J -17 Run Date: 11/1/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3J -17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22700 -00 4ANAIED MAY 3 i 2D12 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: itObi Signed: Ahmtklf4_8d,d4 • Nipv RECEIVE Conoco Phillips FEB 11 20h Alaska f► P.O. BOX 100360 ?Wm ON & Gas Cons. Commission ANCHORAGE, ALASKA 99510 -0360 Anchorage February 14, 2011 Commissioner Dan Seamount -.E 0"11-14/7 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped February 10 -12, 2011.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface C4sing Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 2/15/2011 1B,1D,1E,1Q,1Y /3F,3G,3J PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped _ cement date _ inhibitor sealant date ft bbls ft gal 1B-01 50029204650000 1800400 SF N/A 19" N/A 1.4 2/11/2011 1D -119 50029228360000 1972220 2" N/A 23" N/A 4.2 2/10/2011 1E-117 50029232510000 _ 2050260 12" N/A 12" N/A 4.2 2/12/2011 1E-121 50029232380000 2042460 6" N/A _ 18" N/A 4.4 2/12/2011 1Q-21 50029225910000 1951330 5" N/A _ 5" N/A 5.2 2/12/2011 1Q -22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y -06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y -08 50029209440000 1830620 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A _ 18" N/A 3 2/11/2011 3J -17 50029227000000 1 961460 SF N/A 19" N/A 3.3 2/11/2011 /' ~ ,~ f ~~ r ;~ ~~~~~~~~~~ ~ ~ ~ ; 'iii `', Schlumberger -DCS - ' '" 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~'~''°~~`` ~~~ $ ~ ~~~~ ATTN: Beth • Well Job # Log Description N0.4792 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/24/08 1A-06 12080402 INJECTION PROFILE ~ ( - ( 07/06/08 1 1 3C-17 11964626 SFRT p$- 07/12/06 1 1 1Y-04 12096505 INJECTION PROFILE - - (, 07/13/08 1 1 1 G-06 12061729 INJECTION PROFILE a ` 07/13/08 1 1 i F-06 12096506 PRODUCTION PROFILE - ~ 07/14/08 1 1 3M-08 12096516 SBHP SURVEY 07/21/08 1 1 3M-09 12096515 SBHP SURVEY (o (p 07/21/08 1 1 3N-13 12096517 SBHP SURVEY ~ C (o - 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFILE ~ =. 07/16/08 1 1 1F-06 12096510 PRODUCTION PROFILE -/C( 07/17/08 1 1 2A-02 12096511 INJECTION PROFILE 07/18/08 1 1 3J-17 12096514 SBHP SURVEY Al !~~ ~- s 07/20/08 1 1 3J-07A 12097409 SBHP SURVEY ®/_~~~ ~(~(m'3~ 07/20/08 1 1 3C-15A 12097406 USIT / ~ 07/17/08 1 1 2A-05 12096512 SCMT L - 07/19/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. N~~_____ 06/10/08 ~~~~~~~ NO. 4741 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~NNE®JUN ~ ~ 2008 Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2W-13 11970689 GLS/PROD PROFILE - 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE !~ - ~ 05/28!08 1 1 2M-08 11996642 PROD PROFILE/DEFT / C/ 06/03/08 1 1 i B-10 11994672 PROD PROFILE/DEFT G 05/31/08 1 1 1A-20 11994673 PROD PROFILE/DEFT -/ 06/01/08 1 1 1G-13 11994674 PROD PROFILE/DEFT 3 ^ ~~~~d 06/02/08 1 1 1A-03 11994673 PRODPROFILE/DEFT - /(pa~~y 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT .( ®~~~ 06/05/08 1 1 1C-125 11994677 INJECTION PROFILE ~- - c~/~~ 06/05/08 1 1 1C-127 11994675 INJECTION PROFILE ~J _ L 8~~~, 06/03/08 1 1 1 F-09 11994671 PROD PROFILE/DEFT -/ /~~~ 05/30/08 1 1 iC-27 11994679 SBHP SURVEY `~ ®~f~/ 06/07/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ -o~o~r RE~I\!~Q- STATE OF ALASKA ~~~ 1 ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIq~~a piI ~ ~~$ ~~+~~. Cnimm~eriun 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Othe RC Qf~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 196-146 / ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22700-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 2T 3J-17 ~ 8. Property Designation: 10. Field/Pool(s): ~ ADL 25630, ALK 2563 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8154' ~ feet true vertical 6537' ' feet Plugs (measured) Effective Depth measured 7988' feet Junk (measured) true vertical 6399' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 4423' 7-5/8" 4450' 3738' PROD. CASING 7421' 5-1/2" 7448' 5985' LINER 927' 3-1/2" 8153' 6536' Perforation depth: Measured depth: 7640'-7660', 7831'-7851', 7872'-7896' true vertical depth: 6128'-6143', 6274'-6289', 6306'-6324' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7226' MD. ~~ JA1~ ~ 7 208 Packers & SSSV (type & measured depth) Baker SABL-3 (2) @ 7135', 7227' Camco'DS' njpple @ 518' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 131 642 1043 -- 114 Subsequent to operation 457 1203 1009 -- 124 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/a, if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Schwa Title Wells Group Engineer Signature ~ ~' Phone CC~ l Date f . ~(~'- (> ~i ~~ J ~ ~' ~ S/ ~ Pre aced b Sharon All u Drake 263-4612 ~~ ,i.~(~ x 100 Form 10-404 Revised 04/2006 ~ ~ t ( ~ L~ Submit Original Only • 3J-17 Well Events Summary • DATE Summary 12/18/07 PERFORATED WITH 2" HSD POWERJET FROM 7872-7896' TIED INTO OPEN HOLE PHASOR INDUCTION - SFL LOG DATED 30-MAR-1996. TOP ZONE DISCUSSION NEEDED PRIOR TO ADDITION OF PERFS. • ~~ ~ Cor'M~aP~l~~lps Alaska, ~t'I<c. €3J-17 _ API: 500 -rueiNC SSSV Type: Nipple (0-7226, OD:3.500, iD2ssz) ~ Annular Fluid: • KRU 3J-17 42 deg C~ 7585 34 deg @ 8154 jCassnge5tr~~ing IgALL STRLNGS I MaxHoleAr,gle•~45deg!an6200 ~ ~ LINER 3.500 7226 8153 8153 9.30 L-80 BTC & AB-Mod _ uhing String -TUBING -- ~_____ Size Top Bottom TVD Wt Grade Thread 3 500 0 _ 722E 5813 __ 9.30 L 80 AE-Mod __ Perforations Summary ~ Interval ND Zone Status Ft SPF Date T Comment 7640 - 7660 6128 - 6143 ;C-2,C-1,U 20 4 3/30/1999 RPERF 2.5" DP, +/- 90 deg phasing B 7831- 7851 6274 - 6289 A-4,A-3 20 4 12/21/1996 IPERF 2 1/2" BH, 180 de basin 7872 - 7896 6306 - 6324 A-2 24 6 12/1812007 APERF 2" PJ. 60 deg. random '`has Lift Mandrel5Nalves -- _ _ _ - St MD TVD Man Mfr _ _ _ Man Type V Mfr V Type V OD Latch Port TRO Date Run VW Cmnt 1 3057 2658 CAMCO KBG-2-9 GLV 1.0 BTM 0.156 1300 8/19/2007 2 4625 3875 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 8/19/2007 3 5455 4518 CAMCO KBG-2-9 GLV 1.0 BTM 0.156 1305 8/18/2007 4 5973 4905 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 4/28/2004 5 6615 5363 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 4/28/2004 6 7069 5700 CAMCO KBG-2-9 OV 1.0 BTM 0.250. 0 A11812Q07 -__ _ Other lu s,equip.~etc .)-JEWELRY _ __ _ De h TVD T e Descri flon i0 27 27 HANGER 2.992 518 517 NIP CAMCO'DS' LANDING NIPPLE 2.875 7209 5806 NIP HALLIBURTON'X'NIPPLE 2.750 7220 5814 SEAL BAKER SEAL ASSEMBLY W/O SEALS -STUNG INTO EXISTING 3.000 COMPLETION 7226 5818 ANCHOR K-ANCHOR IS LATCHED INTO SABL-3 PACKER/HANGER AT TOP OF 3.000 SEAL (7220.7226, OD:3.970) ANCHOR (7226-7227, OD:3.970) Pert (7640-7660) LINER (7226-8153, OD:3.500, Wt 9.30) Perf (7631-7851) Perf (7872-7896) 05/09/06 Schlumberger NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Artn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 {p Kuparuk C\ Cc'" \\.1; \ r] \ ?~/ 8Ci"iNNEf', J¡ }r,J : () .".. 't.} Field: Well Job# Log Description Color CD Date BL 1Y-29 11213739 PRODUCTION PROFILE W/DEFT ,1rl( - ("II:\. , 04/28/06 1 3M-25A N/A SHUT IN 8HP I C\L. - GO(., 04/23/06 1 2N-303 N/A LDL 'Ç)Cl' - }t.-,c; 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT \ ~ I - t \ 3 04/25/06 1 3F-07 N/A INJECTION PROFILE I "ir",- - 946,- 04/23/06 1 1 8-16 11235353 PRODUCTION PROFILE W/DEFT IC¡ I..'-IY~~ 04/04/06 1 38-15 11213741 INJECTION PROFILE ·,¡C~ - ¡¡ rl~- , 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT ¡ "( :+ - :=:10 \ 04/19/06 1 1A-20 11235356 PRODUCTION LOG W/DEFT ¡QO-J//-';.) 04/26/06 1 1 H-18 N/A INJECTION PROFILE ¡c(¡1, - C):lb 04/24/06 1 1R-12 11213738 PRODUCTION LOG W/DEFT I ~5" ~OC¡?i 04/27/06 1 1Y-13 11213740 INJECTION PROFILE I"'IS'?) - t'"') \ Ç" 04/29/06 1 2N-318 11213742 LDL dOC -loD 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE 'ì ''1 -I'C, ''2, 05/02/06 1 1G-01 11213744 INJECTION PROFILE ¡......~ - I)I,D ~ 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT íC,lc - 14"0- 05/04/06 1 1 R-26 11258705 INJECTION PROFILE 'j (') I - ()~ ';:).. 05/05/06 1 2A-04 11249902 INJECTION PROFILE ¡ ~LI_ i~<~ 05/06/06 1 1 G-06 11249903 INJECTION PROFILE J 15' rl - ~~t-, 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE 1..;(;2, - -, (.., 05/07/06 1 1G-14 11249904 INJECTION PROFILE /4<"":l, -- J ';'11 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e Schlumbel'ger NO. 3231 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 0/06/04 Company: Alaska Oil & Gas Cons Comm AUn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL RfJt{-p3( J 1E-119 10884033 SCMT 1 0/04/04 I qt) - ~:31 /1 L-09 10802915 PRODUCTION PROFILE W/DEFT 07/26/04 1 /Yr5- t)~1 J2V-14 10884026 PRODUCTION PROFILE W/DEFT 09/27/04 1 / 8~- I^ I 2K-02 10884027 PRODUCTION PROFILE W/DEFT 09/28/04 1 / q~ - 1t/'dJ 3J-17 10884031 PRODUCTION PROFILE 10/02/04 1 /~.7 - 22.:; . 3A-07 10884030 INJECTION PROFILE 10/01/04 1 /80 -057 f 1E-04 10884023 INJECTION PROFILE 09/24/04 1 1 E-11 10884024 INJECTION PROFILE 09/25/04 1 ,/ Yo( - OSI J 2H-12 10884022 PRODUCTION PROFILE 09/23/04 1 i <85 - ~(p?- RÚ -lt~ SCANNED NO" (I 5 2004 DATE: 1')/ Please sign and retur 0 e copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk ~ Color CD 1 ~ ,-..., ~ Mike Mooney Wells Group Team Leader Drilling & Wells ConocÓPhilii pS P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 21, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3J-17 (APD # 196-146) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk weIl3J-17. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M,klfYÞ? M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED MAY 25 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGiNAL 1. Operations Performed: ~ ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D Alter Casing D D RepairWell 0 Pull Tubing 0 Operat. ShutdownD Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 77' 8. Property Designation: ADL 25630, ALK 2563 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Perforation depth: measured 8154' feet true vertical 6537' feet measured 8021' feet true vertical feet Length Size MD 121' 16" 121' 4373' 7-5/8" 4450' 7371' 5-1/2" 7448' 927' 3-1/2" 8153' Measured depth: 7640'-7660',7840'-7860' true vertical depth: 6128'-6143',6281'-6296' Tubing (size, grade, and measured depth) 3-1/2" , L-80. 7226' MD. Plug Perforations D Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - 0 Stratigraphic 0 Stimulate D Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 196-146/ 6. API Number: 50-029-22700-00 Exploratory D Service 0 9. Well Name and Number: 3J-17 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 121' 3738' 5985' 6536' RECEIVED MAY 25 2004 Alaska Oil & Gas Cons. Commission Anchorage Packers & sssv (type & measured depth) Baker SABL-3 pkrs @ 7135',7227' SSSV= Cameo 'OS' nipple SSSV= 518' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl SI 340 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Casinq Pressure Tubinq Pressure 618 2241 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oil0 Gas 0 WAGD 136 Service D GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Printed Name Mike Mooney @ 265-4374 M}J Jonda::) Form 10-404 Revised 04/2004 ABDMS 8fL Signature Title Wells Group Team leader Phone Date '7 / t..f.~ð Prepared bv Sharon I ra 6 6 . ~ ~~~ I NA L Wt~ü~~fê ~~fL ~Ü . MAY U Submit Original Only TUBING (0-7226, OD:3.500. ID:2.992) SEAL (7220-7226. OD:3,970) ANCHOR (7226-7227, OD'3,970) Perf (7640-7660) Perf (7840-7860) ,-..., ConocoPhillips Alaska, Inc. 3'J~U - - - - - - . r'\ KRU API: 500292270000 SSSV Type: Nipple Angle @ TS: 42 deg @ 7585 Angle @ TD: 34 deg @ 8154 Annular Fluid: Reference Log: 26.75' RKB Last Tag: 8021 Last Tag Date: 5/9/2004 a_log ¡String' ~Ât.:I4'smRING$ Description SUR. CASING PROD. CASING CONDUCTOR LINER Well Type: PROD Orig 10/6/1996 Completion: Last W/O: 4/28/2004 Rev Reason: Tag fill, pull RHC/Ball-Rod, GLV design Last Update: 5/14/2004 Ref Log Date: TD: 8153 ftKB Max ~ole Angle: 45 d~g @ 6200 Size 7.625 5.500 3J-17 Top Bottom TVD Wt Grade Thread 0 4450 3738 29.70 J-55 BTC 0 7448 5985 15.50 L-80 BTC& ModBTC 0 121 121 62.50 H-40 WELDED 7226 8153 8153 9.30 L-SO BTC& AB-Mod .. TVD Wt Thread 5818 9.30 AB-Mod 16.000 3.500 Bottom 7226 " Status Ft SPF Date Type Comment 20 4 3/30/1999 APERF 2.5" DP, +/- 90 deg phasing Port TRO 4 12121!1996 IPERF 21/~" BH:.180 d~g. phasing Vlv Cmnt 20 V Mfr V Type VOD Latch GLV 1.0 BTM GLV 1.0 BTM OV 1.0 BTM DMY 1.0 BTM DMY 1.0 BTM DMY 1.0 BTM Description 0.156 1332 0.188 1362 0.250 0 0.000 0 0.000 0 0.000 0 Date Run 5/212004 5/212004 5/212004 4/28/2004 4/28/2004 5/2/2004 TûliiaSiing -TI.JSiNG Size I Top 3.500 0 PèrfofãtiôQs'SummaÌÝL w. Interval TVD Zone 7640 - 7660 6128 - 6143 3,C-2,C-1,Ut B A-3 7840 - 7860 6281 - 6296 GasUftiM,Îin'attlsJValyu ,""¡". St MD TVD Man Man Type Mfr 1 3057 2658 CAMCO KBG-2-9 2 4625 3875 CAMCO KBG-2-9 3 5455 4518 CAMCO KBG-2-9 4 5973 4905 CAMCO KBG-2-9 5 6615 5363 CAMCO KBG-2-9 6 7069 5700 CAMCO KBG-2-9 btb$í"(PlûI:ìSi!.eqúip;;ietC.l.~,JaWELRY . Depth TVD Type 27 27 HANGER 518 517 NIP 7112 5732 NIP 7122 5740 PBR - 7135 5750 PACKER 7209 5806 NIP 7220 5814 SEAL CAMCO 'DS' LANDING NIPPLE CAMCO 'DS' NIPPLE BAKER 80-40 PBR, 12' STROKE, 4" SEAL BORE BAKER SABL-3 PACKER HALLIBURTON 'X' NIPPLE BAKER SEAL ASSEMBLY W/O SEALS - STUNG INTO EXISTING COMPLETION 7226 5818 ANCHOR K-ANCHOR IS LATCHED INTO SABL-3 PACKER/HANGER AT TOP OF LINER (original completion) 7227 5819 PACKER BAKER SABL-3 PACKER (original completion) Ge.neÍ'al NÔ(U""i.. "':. Date I Note 4/28/2004 TREE: FMC GEN IV 3.5" TBG HANGER W/DBL PIN PUP, 3.5" EUE LAND THD TREE CAP CONNECTION: OTIS ACME 3.5" EUE .. ID 2,992 2.875 2.812 3.000 2,780 2.750 3.000 3.000 3.000 ,-..., r'\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3J-17 3J-17 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 4/25/2004 Rig Release: Rig Number: Spud Date: 9/29/1996 End: Group: 4/25/2004 05:00 -11:00 6.00 MOVE RURD MOVE Rig down from previous loco 1L-09. 11:00-15:00 4.00 MOVE MOVE MOVE Moved to new location at 3J-17. 15:00 - 22:00 7.00 MOVE RURD MOVE Spotted up rig and began rig up. 22:00 - 00:00 2.00 CMPL TN CIRC RIGUP Accepted the rig at 22:00 hours. Prep to circulate fluid around the tubing to IA. 4/26/2004 00:00 - 02:00 2.00 MOVE RURD MOVE Continue to hook up pump line and load pits with initial circulation fluids. Pull BPV, and get ready to pump. 02:00 - 02:45 0.75 WELCTL SFTY WRKOVR Pre-spud meeting. 02:45 - 03:15 0.50 WELCTL CIRC WRKOVR Prep to begin pumping. Small issue with pump. Clutch would not engage. 03:15 - 05:30 2.25 WELCTL CIRC WRKOVR Begin to circulate down tubing taking returns up the IA. ISIP = 100# Gas cap on well. Pump 130 BBLS 165 Deg. sea water. Followed by 160 BBLS of 9.6# Brine. 05:30 - 07:30 2.00 WELCTL NUND WRKOVR Set blanking plug; notified AOGCC of upcoming BOP test. John Crisp waved witnessing test. 07:30 - 09:30 2.00 WELCTL NUND WRKOVR Tree nippled down; begin NU BOP stack. 09:30 -11:00 1.50 WELCTL BOPE WRKOVR Pick up BOPE. Install on well. set kill lines and function test all cumy lines. 11 :00 - 12:00 1.00 WELCTL BOPE WRKOVR Having problems Begin BOP test; having problems getting initial p/t--slow leak. Begin chasing down leak. 12:00 - 18:00 6.00 WELCTL BOPE WRKOVR Attempting several different avenues of pressure testing the BOPE. Still appears to be leaking by plug. 18:00 - 00:00 6.00 WELCTL BOPE CMPL TN Have checked rig equipment, leak appears to be through blanking plug. Pull plug and re-seat. Still having air issues. Bleed and re-bleed. Finnaly able to get a good start on test. Found leaking fitting on rig floor. Split 1/2" JIC fitting and a bad needle valve. Replace both and prep to continiue test. 4/27/2004 00:00 - 01 :00 1.00 WELCTL BOPE CMPL TN Continue with BOPE test. Prep to pull test plug. Called AOGCC for varience on Blind test until after the completion is pulled. All other test have passed. Unable to test blinds at this time due to FMC hanger leak by on plug. 01:00 - 01:30 0.50 CMPL TN TRIP DECOMP Begin initial pull on tubing. Up wt = 65K during the orignal completion. Pulled 95K and tubing began to move. WT migrated up to 135K before pulling all of the way out of PBR. Standard up wt after pulling out = 63K. Begin to pull completion to surface. Monitoring liquid level while POOH. No losses. 01 :30 - 07:30 6.00 CMPL TN TRIP DECOMP Continue to pull completion. Spotted heavy corrosion on tubing walls w/twice the normal amount on the collars. Stand number 88 down will be replaced. GLM #4 no obvious corrosion areas. Started to lay down tubing in pipe shed. 07:30 - 08:00 0.50 CMPL TN TRI P DECOMP Called AOGCC John Crisp for notification on setting the bridge plug at or around 50-100'. At this time we have clearence to perform this duty. Continuing to pooh laying down singles. 08:00 - 10:15 2.25 CMPL TN TRIP DECOMP Continued tripping pipe out of the hole. On surface with seal assembly (which looks to be in good shape). The 36 joints of tubing below GLM #4 @ 5985' show signs of corrosion & pitting. GLM #5 showed some corrosion. GLM #6 showed some corrosion, but gas entry area of manderel was eroded badly. 10:15-11:15 1.00 WELLSR PULD DECOMP Pick up and Make up Baker 5-1/2" Bridge Plug. Verified well is dead. 11:15-13:15 2.00 WELLSR PLGM DECOMP Installed Baker 5-1/2" Bridge Plug @ 63' 13:15 -14:15 1.00 WELLSR SEQT DECOMP Closed blinds and pressure tested between the bridge plug and the blinds 250 / 3600 psi. Charted test and held good. depressured and drained stack and wellhead. Printed: 5/21/2004 9:3939 AM ,-..., ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3J-17 3J-17 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 4/25/2004 Rig Release: Rig Number: Spud Date: 9/29/1996 End: Group: 4/27/2004 14:15 - 15:30 1.25 WELLSF NUND DECOMP 15:30 -16:30 1.00 CMPL TN RURD DECOMP 16:30 - 17:30 1.00 CMPL TN SEaT DECOMP 17:30 - 20:30 3.00 CMPL TN NUND DECOMP 20:30 - 22:00 1.50 FISH OTHR CMPL TN 22:00 - 22:30 0.50 CMPL TN SFTY CMPL TN 22:30 - 00:00 1.50 CMPL TN RUNT CMPL TN 00:00 - 02:00 2.00 CMPL TN RUNT CMPL TN 4/28/2004 02:00 - 05:00 3.00 CMPL TN RUNT CMPL TN 05:00 - 08:30 3.50 CMPL TN RUNT CMPL TN 08:30 - 09:45 1.25 CMPL TN RUNT CMPL TN 09:45 - 10:00 0.25 CMPL TN RUNT CMPL TN 10:00 - 11 :00 1.00 CMPL TN CIRC CMPL TN 11:00 -12:00 1.00 CMPL TN CIRC CMPL TN 12:00 - 12:50 0.83 CMPLTN CIRC CMPLTN 12:50 - 13:50 1.00 CMPL TN PCKR CMPL TN 13:50 - 14:10 0.33 CMPL TN PCKR CMPL TN 14:10 - 14:30 0.33 CMPL TN PCKR CMPL TN 14:30 - 15:00 0.50 CMPL TN DEOT CMPL TN ND stack for Wellhead Pack Off & Adapter replacement. Replace pack off Pressure tested new wellhead pack off to 3000 psi (good test) NU stack post Wellhead Pack Off & Adapter Replacement. Press test to 3,650# high. 250# low. Fish Bridge plug from 60' no problems. PULD 12 singles out of derrick. Prep to have PJSM prior to installing completion. Pre-job safety meeting. Talk about hazards on pinch points, proper PPE, and good comunication. prep to RIH. RIH with new completion jewelry. Baker seal assy w/o seals, 2.75" x nipple, SABL-3 packer, PBR 80-40, DS 2.812" nipple, and various GLV. Tripping in with new completion jewelry. Baker seal assy w/o seals, 2.75" x nipple (w/2.75" RHC plug installed), SABL-3 packer, PBR 80-40, DS 2.812" nipple, and 6 new KBG-2-9 GLMs (the deepest one has shear valve in it). the first 56 joints of tbg to go in the well are new 3-1/2" EUE 9.3# L-80 tubing. After joint #56, the old tubing also 3-1/2" EUE 9.3# L-80 pulled from the well will be run back in on completion.. Drifting all pipe with (2.867") rabbit. Continue to RIH with new completion. Using old 3-1/2" EUE 9.3# L-80 tubing Drifting all pipe with (2.867") rabbit. Also inspecting each joint thoroughly. Continue to RIH with new completion. Using old 3-1/2" EUE 9.3# L-80 tubing Drifting all pipe with (2.867") rabbit. Also inspecting each joint thoroughly. Same as prior entry. Installed 2.875" cameo DS nipple in the completion string. Rabbited all tubing above the DS nipple to 2.91" Landed seal assembly in seal bore. Slid right in with no problems. 15.5' in on Jt #227,7225.5'. Pulled back out of seal bore up to 7210' Rigged up to head pin to pump down tubing. Pressure tested head pin and surface line to 4500 psi. Began circulating down tubing and taking returns to pits @ 2 bpm /400 psi. started lowering pipe down as seal assy entered the seal bore 6' in on Jt #227 saw pressure increase to 600 psi. Kicked off pump and allowed pressure to bled off. Continued lowering pipe down to 15.5' in on Jt #227, 7225.5' indicating seal assy traveling into seal bore full stroke. Pulled back up to 7210'. Pumped 15 bbls of 1% corrosion inhibited 9.6# brine followed by 60 bbls of 9.6# brine spotting the corrosion inhibited brine in 3-12/" x 5-1/2" annulus between 7210' - 6202' and in the 3-1/2" tubing between 7210'- 6865'. Pump rate kept @ 1.5 bpm /60 psi on tubing (no losses). Break out head pin. Drop ball & rod ( Dimensions as follows, length = 6.79', fishing neck 1-3/8", Fins 1-1/2",1-5/16" Ball, & 5/8" rod). Allow time for ball & rod to fall. Repostioned pipe for setting of packer. Spaced out seal assy 2.5' from full insertion w/ nose of seal assy @ 7223'. Pressured up against Ball & Rod to 4200 psi. PBR sheared and pipe jumped & moved up the hole 2'. The tubing pressure dropped to 3700 psi. Allowed pressure to sit for 5 mins. Depressured tubing to 0 psi as pressure came down pipe slid back down. Raised pipe 3' and then lowered back down and tagged packer. Packer is set. picked up 2' and hung pipe in neutral position. Up wt 70K & Dwn wt 47k. Pressure test IA to 100 psi to insure that packer is set. IA held good at Printed. 5/21/2004 9:39:39 AM ,-..., ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3J-17 3J-17 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 4/25/2004 Rig Release: Rig Number: Spud Date: 9/29/1996 End: Group: 4/28/2004 14:30 - 15:00 0.50 CMPL TN DEOT CMPL TN 1000 psi. Bled pressure back to 0 psi. 15:00 - 16:00 1.00 CMPL TN SOHO CMPL TN Spaced out as needed. removed jt #227 & #226. Buried 18' of pups, 1 jt from hanger under Jt #225. Installed hgr & hgr pup. 16:00-16:45 0.75 CMPL TN SOHO CMPL TN Drained the Stack and Landed Hanger. RILDS. 16:45 - 17:30 0.75 CMPLTN DEOT CMPL TN Open up annulus valves to monitor returns. Pressured up on the tubing to 2500 psi.and monitored pressure. Pressure dropped from 2500 psi down to 2200 psi in 20 mins. No visible returns from annulus. Decided to re-pressure the tubing back up to 2500 psi. Pressured up and monitored. Charted and good flat line test of 15 mins. 17:30 - 18:00 0.50 CMPL TN DEOT CMPL TN Depressured the tubing back to 1500 psi. Pressured up on the annulus to 2500 psi and charted test. Good Flat line test. 18:00 - 18:30 0.50 CMPL TN DEOT CMPL TN Bled tubing down but shear valve @ GLM #6 failed to shear. Pressured up on annulus to 2600 psi and sheared DCK. 18:30 - 22:00 3.50 CMPL TN NUND CMPL TN Torque lock down screws to 450 ft/lb. Install BPV. Begin to nopple down BOPE and prep rig for move to 2G-pad. 22:00 - 00:00 2.00 CMPL TN NUND CMPL TN Install inspected tree. Pressure test packoffs and tree to 5,000#. Tree passed. Release rig. Printed: 5/21/2004 9:3939 AM ~ ~ 3J-17 Well Events Date Summary 03/06/04 BAILED ON PLUG @ 7205' RKB, IN PROGRESSD [ANN COM ISSUES] 03/08/04 PULLED CA-2 BLANKING PLUG @ 7205' RKBD [ANN COM ISSUES, Open-Close A Sand] 03/10104 POT-T - passed, PPPOT-T - passed, POT-IC - failed, PPPOT-IC - passed, Function test LDS's - passed, MITOA - failedD [ANN COM ISSUES, WH Maintenance] 03/30/04 DRIFT TO 8016' RKB. MAKE UNSUCCESSFUL ATTEMPT TO SET 1" DGLV IN STA #4. IN PROGRESS.D [Tag, GLV] 03/31/04 ATTEMPT TO SET 1" DGLV IN STA #4.IN PROGRESSD [ANN COM ISSUES] 04/01/04 STATIC @ 7750' MD = 3766 PSI & 7620' RKB = 3726 PSI, ATTEMPT TO PULL DV @ 7152' RKB, IN PROGRESSD [Pressure Data] 04/02/04 ATTEMPTED TO PULL DV @ 7152' RKB, IN PROGRESSD [ANN COM ISSUES, GLV] 04/04/04 ATTEMPTED TO PULL DV'S @ 7152' & 6646' RKBD [GLV, ANN COM ISSUES] 04/10/04 SET WEATHERFORD WRP (2.70" OD X 3.75' LONG) IN 3.5" LINER AT 7320' (CENTER OF ELEMENT). TOP OF PLUG AT 7318.2'. DID NOT TAG TD. WELL LEFT SHUT IN.D [Workover prep] 04/11/04 DISPLACED TUBING & IA TO SEAWATER, FREEZE PROTECTED W/ DIESEL DOWN TO 2500'. CMIT OF 2500 PSI PASSED. DRAWDOWN BOTH TUBING AND IA TO 0 PSI AND HELD GOOD. D [Workover prep] 04/12/04 SET 2.72" X 7'4" JUNK CATCHER @ 7292' WLM COMPLETE.D [Open-Close C Sand] 04/18/04 MITOA failed, LLR of 9 gpm @ 1500 psiD [ANN COM ISSUES, WH Maintenance] 05/01/04 PULL RHC PLUG. PUMP 100 BBLS SEAWATER, 50 BBLS DIESEL DOWN lA, RETURNS UP TBG TO FLOWLINE. THEN U-TUBE IA TO TBG TO FREEZE PROTECT TBG. PULL DCK SHEAR VLV FROM STA 6 AT 7069' RKB. LAY DOWN FOR NIGHT. 05/02/04 PULL 1" DV'S, BTM LATCH FROM STA 1, STA 2 AND STA 3. SET 1" GLV, BTM LATCH IN STA 1 AND STA 2. SET 1" OV, BTM LATCH IN STA 3. SET 1" DV, BTM LATCH IN STA 6.. ATTEMPT TO PULL JUNK CATCHER. SAT DOWN HIGH. RAN BAILER. RECOVERED SAND/FRAC SAND FROM 7275' SLM. 05/03/04 BAIL DOWN TO 7280' SLM. ATTEMPT TO LATCH JUNK CATCHER. COULD NOT LATCH UP. 05/04/04 BAILED DOWN TO JUNK CATCHER. MADE TWO ATTEMPTS TO PULL. LAY DOWN FOR NIGHT. 05/05/04 BEAT UP ON JUNK CATCHER FOR 41/2 HOURS. NO MOVEMENT. 05/06/04 BAILED OUT INSIDE OF JUNK CATCHER. PULLED JUNK CATCHER. DIFFICULT TO GET THROUGH NIPPLES. FISHING NECK BENT UP. 3 SMALL PIECES OF BRASS INSIDE CATCHER. 05/07/04 BAILED FRAC SAND DOWN TO WRP. GOT LIB PICTURE OF TOP OF FISHING NECK. MADE HYDROSTATIC BAILER RUN WI EXTENDED EQUALIZING BOTTOM. PRESSURED UP ON TBG TO 2500 PSI. NO PRESSURE DROP, COULD NOT PUMP DOWN THROUGH PLUG. Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2860 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 05~28~03 Well Job # Log Description Date BL Color CD 2N-343 ~ ~ ~ 'O~ ~ INJECTION PROFILE 05102103 4 2N-34S ~)~ -. ~ t-[~iNJECTION PROFILE 05/01/03 ~ 2P-420~~ ~ MEM PSP INJECTION PROFILE 05/06/03 1 3J-17 /~ ~ i ~'-i ~ [~ MEMORY LDL 05108/03 ~ DATE: RECEIVED MAY ~0 200~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~CANN~ OCT 1 ~ 2003 ~.,.,,.'>,', ~ ,-7-. ~,\~'~, ~ Alaska O~i & Gas Cons. CommJeeicm STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ 4. Location of well at surface 4565' FNL, 4717' FEL, Sec. 3, T12N, R9E, UM At top of productive interval At effective depth At total depth 2898' FNL, 1908' FEL, Sec. 10, T12N, R9E, UM (asp's 519543, 6002396) (asp's 522368, 5998792) 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3J-17 9. Permit number / approval number 196-146 / 10. APl number 50-029-22700 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8154 feet 6537 feet Plugs (measured) Effective depth: measured true vertical Casing Length Size CONDUCTOR 121' 16" SUR. CASING 4373' 7-5/8" PROD. CASING 7371' 5-1/2" LINER 927' 3-1/2" LINER feet feet Junk (measured) Cemented Measured Depth 121' 4450' 7448' 8153' True vertical Depth 121' Perforation depth: measured 7640-7660', 7840-7860' true vertical 6128-6143', 6281-6296' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7226' MD. Packers & SSSV (type & measured depth) K @ 5972' MD; E @ 6002' MD; B @ 7227' MD; C @ 497' MD. RECEIVED NOV 1 2 2002 Alaska 011 & Gas Cons. commis¢or' Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Oil-Bbl Prior to well operation 1317 Subsequent to operation 1913 Representative Daily Avera,qe Production or Iniection Data Gas-Mcf Water-Bbl 3862 7590 2859 4615 Casing Pressure Tubing Pressure - 302 26O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil__ X Gas__ Suspended__ Service%'_¢;c, tcr~_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Problem Well Supervisor / Jerald C. Dethlefs ~' ~/ Date Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk Well 3J-17 (PTD 1961460) SUNDRY NOTICE 10-404 11/06/02 Phillips Kupamk well 3J-17 tubing was patched 12/01/02 to repair a split in GLM #8. The patch was an Eclipse 3-1/2", 20-feet long, retrievable. On 04/24/02 a Sundry 10-404 was submitted to the AOGCC post patch. The patch was found to be leaking, and the following activities have taken place since the patch was set 12/01/02: · 02/23/02: SL running dummy gaslift valves · 02/25/02: Load IA and MIT attempt (failed), 1 bpm injection rate · 03/01/02: leak detect log (LDL) could not get through patch, no leaks above, 1/8 bpm @ 2500 psi · 05/22/02: SL memory LDL found leak at top of patch. Needs pull and re-run. · 05/26/02: SL pulled top packer and extension, will reset with packoff · 06/07/02: Set Patch (apparently slip-stop not set) SET PATCH W/K~3 PACKER @ 5986' · 07/15/02: Patch still leaking; patch to be pulled · 07/17/02: Pulled K-3 packoff and patch extension (lower packer still in hole) · 07/21/02: EL attempt to PPROF, could not get through lower packer. To be pulled. · 09/18/02: SL ran retrievable patch. RUN UPPER K-3 PACK OFF, SPACER PIPE & STINGER SET ON TOP OF LOWER K-3 PACK OFF LOCATED @ 5996' SLM. TEST UPPER ELEMENT TO 2500 PSI, GOOD. · 10/14/02: Still indications of leaking patch. Future plans are to pull and replace the leaking patch. NSK Problem Well Supervisor 11/08/02 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY NiP (497-498, ~ OD:3.500) (O-7226, OD:3.500, ID:2.992) SLI PSTOP (5972-5974, OD:3.500) PATCH (5974-5997, OD:2.992) PACKOFF (5997-6oo¢ 0D:3.500) NIP OD:3.500) PBR (7212-7213, 0D:3.500) NiP (7226-7227, OD:3.500) Peff (7640-7~) Perf (7~4O.78~0) KRU 3J-17 AP1:1500292270000 SSSV Type:I Nipple Annular Fluid:I Reference Log:I Last Ta~l:18001 Last Ta~l Date:17~26~2002 Well Type:[ PROD Orig [ 10/6/1996 Completion:J Last W/O:I Ref Log Date:J TD:18153 ftKB Max Hole An~lle:]45 deg (~ 6200 Angle @ TS:J42 deg @ 7585 Angle @ TD:I34 deg @ 8154 I Rev Reason: Set slipstop, I packoff by ImO Last Update:19/28/2002 I Ca~i~g iSi~in~ ~ ~EL STRINGS:: ::: Description Size Top PROD. CASING 15.5oo I o CONDUCTOR I 16.000 I 0 SUR. CASING 17.625 I LINER I 3.500 I Tubihg S~ihg: ~ TUB!NC :, : 3.500 0 7226 Boffom 7448 121 0 4450 7226 8153 TVD I wt [Grade 5985 115.50 J-55 121 162.50l H-40 3738 129.70 J-55 8153 I 9.30 J-55 Thread TVD I Wt IGrade I Thread 5818 I 9.30 I J-55 I EUE AB MOD p~rforati:~S s~mmar7 :: : ::::: Interval TVD / Zone /Status[F, ISPFI Date I Type I Comment 7840-7860 6281-6296 ! A-3 ! I20 I 4 [12/21/199q IPERFI21/2"BH, 180deg. / / I I I / Iphasing G~ :Ei~:M~nd:~l~:~alves: St I MD I TVDI Man I Man I V Mfr Iv Type I V OD I Latch I Po. I TRO I Date I Vlv I I I 'rlT Pel I I I l"unl 1 3049 2652 DST ~ CAMCO D~ 1.0 T-1 0.125 1282 2/24/2002 214~641 35~61 BeTI ~ I C~MCOI DMY I ~.0J T-~ 10.188 J1345J2/24/2002I 3 I 5~071 42531 BeT I~ I C~MCO ID~ I ~.0I T-~ I 0.250 1~434 12/25/20021 4159861 49~51 BeTI ~ I C~MCOI EMP~I ~.0 I T-1 10.2501 0 IS/~5/~00~1 ¢) 51~I 5385j BeTI ~ I C~MCOI DMV I ~.0 J T-~ 10.0001 0 I9/~W2000J 617~521 57621 BeT I ~ I CAMCOI DMY I ~.0 I T-1 10.0001 0 17/25d9991 1. Video/o~ 9/12/01 shows leak in wall; metal strip sheared o~ ~6~ (Pi d~s, ~aiP~: etc. ~, JEWELRY DepthJTVDI 497 I 497 I 5972 149051 597414906I 5974 149061 5997 149231 6000 149251 7205 15803I 7212 15808I 7226 15818I 7227 15819 I Type NIP SLIPSTOP PATCH Description NIP Camco 'DS' Landing Set 9/17/2002 SPACER PIPE PATCH (W/SLIPSTOPS & PACKOFFS assembly approximately 30') set 9/17/2002 K-3 PACKOFF Set 9/17/2002 2.812 Camco 'D' Nipple NIP 1.500 1.750 PACKOFF 1.437 PACKOFF K-3 PACKOFF Set 9/17/2002 1.437 SLIPSTOP SET 9/17/2002 1.500 2.750 3.000 PBR Baker 10' stroke NIP Baker 'KBH-22' Anchor Seal 3.000 PKR Baker 'SABL-3' 3.000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 77 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 4565' FNL, 4717' FEL, Sec. 3, T12N, R9E, UM (asp's 519543, 6002396) 3J-17 At top of productive interval 9. Permit number / approval number 2638' FSL, 2135' FEL, Sec. 10, T12N, R93, UM 196-146/ At effective depth 10. APl number 2404' FSL, 1963' FEL, Sec. 10, T12N, R9E, UM 50-029-22700 At total depth 11. Field / Pool 2898' FNL, 1908' FEL, Sec. 10, T12N, R9E, UM (asp's 522368, 5998792) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8154 feet Plugs (measured) true vertical 6537 feet Effective depth: measured 8052 feet Junk (measured) true vertical 6440 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 290 Sx AS I 121' 121' SUR. CASING 4373' 7-5/8" 119o Sx AS III & 352 Sx Class G 4450' 3738' PROD. CASING 7371' 5-1/2" 190 Sx Class G 7448' 5991' LINER 927' 3-1/2" 114 sx Class G 8153' 6536' LINER Perforation depth: measured 7640-7660', 7840-7860' ,:... ?~.~ ~.. ~ ,~. ~, :;-.~ ~ .~; true vertical 6128-6143', 6281-6296' -, .;~.. · , ..': ~; / Tubing (size, grade, and measured depth) 3-1/2% 9.3#, J-55 Tbg @ 7226' MD. Packers & SSSV (type & measured depth) BAKER 'SABL-3' @ 7227' MD. CAMCO 'DS' LANDING @ 497' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casino] Pressure Tubin.q Pressure Prior to well operation 281 76 996 1297 179 Subsequent to operation 381 233 1351 1301 163 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Tubing patch Oil __ X Gas __ Suspended _ Service _ 17. I hereby certify that the foregoing is~t~ue and correct to the best of my knowledge. Signed ~¢~¢,~'~ ~' '------" ~'¢¢"~/ ~ Title Problem Well Supervisor Date ~//~' ~ ~ Jerry DetlClefs Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Phillips Alaska, Inc. Kuparuk Well 3J-17 SUNDRY NOTICE 10-404 04/24/02 Phillips Kupamk well 3J-17 robing was patched 12/01/02 to repair a split in GLM #8. The patch is an Eclipse 3-1/2", 20-feet long, retrievable. The following is a summary from the Well Service Report dated 12/01/01: SET ECLIPSE PATCH ACROSS GLM g4. TOP OF PATCH AT 5974' ELM, BTM OF PATCH AT 6002' ELM. 1.75" MIN ID, 26.6' OVERALL LENGTH OF UPPER ASSEMBLY (PACKER, SPACER, AND SEAL W/LATCH). SET LOWER ECLIPSE PATCH PACKER WITH MID ELEMENT AT 6001' MAKE MULTIPLE ATTEMPTS TO LATCH INTO LOWER PACKER AT INCREASING CABLE SPEEDS (60,100,150,200 AND 230 FPM) LATCHED IN WITH A DOWN SPEED OF 230 FPM - PULLED 800# OVER LINE WEIGHT TO VERIFY SLACK OFF LINE AND SET UPPER PACKER WITH MID ELEMENT AT 5976.8' (TOP OF PATCH AT 5974.2') NSK Problem Well Supervisor 06/23/01 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 24, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report Of Sundry Well Operations for Phillips Alaska, Inc., well 3J-17. The Sundry is to report placement of a tubing patch. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs Phillips Problem Well Supervisor Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate_ Plugging _ Perforate X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 32' RKB, 45' PAl- 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 710' FSL, 563' FWL, Sec 3, T12N, RgE, UM 3J-17 At top of productive interval: 9. Permit number/approval number: 2638' FSL, 2135' FEL, Sec 10, T12N, RgE, UM 96-146 At effective depth: 10. APl number: 2404' FSL, 1963' FEL, Sec 10, T12N, RgE, UM 50-029~22700-00 At total depth: ! 1, Field/Pool: 2368' FSL, 1918' FEL, Sec 10, T12N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 8154 feet Plugs (measured) None true vertical 6491 feet Effective Deptt measured 8052 feet Junk(measured) None true vertical 6440 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 290 Sx AS I 121' 121' Surface 4409' 7.625" 1190 Sx AS III & Zl4EE]' 3738' 352 Sx Class G w/60 sx AS I top job Production 7419' 5.5" 190 Sx Class G 7457' 5991' Liner 927' 3.5" 114 Class G 8153' 6536' Perforation Depth measured 7640'-7660'; 7840'-7860' true vertical 6128'-6143'; 6281'-6296' Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, J-55 @ 7226' ... - - Packers and SSSV (type and measured depth) c~. Pkr: Baker Anchor seal @ 7226' & SABL-3 7227'; None, Nipple @ 497' 13. Stimulation or cement squeeze summary Perforate 'C' sands on 3/30/99. Intervals treated (measured) 7640'-7660' Treatment description including volumes used and final pressure Perforated using 2.5" HC guns w/DP charges @ 4spt, final pressure was 450 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 400 906 587 1382 168 Subsequent to operation 428 1170 1147 1389 175 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations_ZX Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed j~~ Title: Production Engineering Supervisor Date ,, Form 10-404 R6~ ~/15/88 SUBMIT IN DUPLICA'r,E,, Alaska, Inc. KUPARUK RIVER UNIT ..ELL SERVICE REPORT K1(3J-17(W4-6)) WELL JOB SCOPE JOB NUMBER 3J-17 PERFORATIONS-E-LINE 0325991750.2 DATE 03/30/99 DAY 1 FIELD ESTIMATE DAILY WORK GR LOG/PERF OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ~'~ Yes O No ~'~ Yes O No SWS-JOHNSON AFC# ICC# IDA, LYCOST ACCUM COST K85174 230 DS36JL $9,981 $10,907 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ITTLSize 250PSII 450PSI! 1300PSI 1300PSI 700PSII 700PSII 3.500 " UNIT NUMBER 2128 SUPERVISOR GOBER Signed .~ IMin ID- ' 2.750" Depth{ 7205 FT DALLY SUMMARY RUN GUN GAMMA - TIE IN TO DITE 11/29/96 - PERF 7640-7660 W/2.5"HC/DP/4 SPF/180 DEG PHASING +/- 90 DEG I I FROIVI LOW SIDE [Perf] TIME LOG ENTRY 08:30 MI RU SWS 10:00 TGSM - ESTABLISH MUSTER AREA - DISCUSS JOB PLAN 10:15 CALL FOR RADIO SILENCE - ARM GUN 10:30 PRESSURE TEST LUBRICATOR TO 3000 PSI - ALL OK 11:00 RIH W/6' X 1 11/16" WEIGHT BAR, POWERED GUN GAMMA TOOL W/CCL, MAGNETICE POSITIONING DEVICE, SAFE FIRE HEAD, AND 20' 2.5" HC PERF GUN 12:05 RUN GR/CCL LOG 7673' - 7100' - TIE IN TO DITE DATED 11/29/96 - PRODUCTION ENGINEER ON SITE TO PICK PERFS 12:52 PERF 7640-7660 W/2.5" HC/DP/4 SPF/180 DEG PHASING +/- 90 DEG FROM LOW SIDE OF HOLE - CHARGES: 31J U J, 10.7 GR HMX - PENETRATION = 17.3" - HOLE DIA = 0.29" - LOG UP AFTER PERFORATING 13:00 POOH 13:30 OUT OF HOLE W/PERF GUN - ALL SHOTS FIRED - BD TOOLS 14:15 NOTIFY DSO WELL READY FOR PRODUCTION 15:30 RDMO SWS SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $40.00 APC $550.00 $550.00 HALLIBURTON $0.00 $446.00 Lrl-I'LE RED $0.00 $440.00 SCHLUMBERGER $9,431.00~ $9,431.00 TOTAL FIELD ESTIMATE $9,981.00 $10,907.00 PERMIT DATA 96-146 PIL/SFL 96-146 7575 96-146 DIR SRVY AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~7~00-7957 ~jScHLU~ ~L/S~L/~R ~ARCO 0-8017. Page: 1 Date: 11/25/98 RUN RECVD ............. FINAL 01/17/97 1 01/17/97 06/19/97 10-407 %'MPLETION DATE )~/~//~%/ DAILY WELL OPS R A~e dry ditch samples required? yes no And received? Was the well cored? yes no Are well tests required? yes Well is in compliance Initial COMMENTS yes no Analysis & description received? yes no Received? yes no no ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 18, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3J-17 (Permit No. 96-146)Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3J-17. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Develo >ment WS!/skad ORIGINAL : :-' STATE OF ALASKA : ALASK,. ~JIL AND GAS CONSERVATION C_. ~iMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '"'i. Status of Well 'Classification 0f Service 'Well ...... [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-146 §. Address 8. APl'Number P. O. Box 100360, Anchorage, Alaska 99510 i?~:_~,.~_ ~ . . .~?_:_._ _:.~. ~.. 50-029-22700 4. Location of well at S~rfac~ .......... I. '.,~F'~;,~T',?;F,7;-'t. ._~,~¢,,~ _ j- 9. Unit Or Lease Name "' _ ~.~,~,. ~.r~ ; !:J_,'.~ 710' FSL, 563' FWL, Sec. 3, T12N, PgE, UM i ~ifi'~ · ~~~. i Kuparuk River Unit At top of productive interval Z_~,Z'~_.,.Z~¢'~_~ 10. Well Number 2638' FSL, 2135' FEL, Sec. 10, T12N, R9E, UM !~~D~/~.,~i,- i ;.,.,~ ! 3J-17 At total depth -~--_ ~.~ 11. Field and Pool 2368' FSL, 1918' FEL, Sec. 10, T12N, R9E, UM Kuparuk River 5. Elevation in feet (indicate KB,' DF, etc.) 16. Lease Designation and Serial No. Rig RKB 32', Pad 45'I ADL 25630, ALK 2563 i¥2. Date SPUdded ,131 Date T.D. Reached, 14. Date Comp., SUsp., °r Aband.,15. Water depti% if offSho~:e ,161 No~ of ComPletiOns 9/29/96I 11/27/961 12/21/96I N/A MSLI One ":i'7. Total Depth (MD+TVD)118. Plug Back Depth (MD+'I-VD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrosl 8154 6491 F~ 8052 6440 F~ (~Yes [~No ] N/A MD! 1465' (Approx.) 22. Type Electric or Other Logs Run Slim-1 GR,GR/CCL/SLTJ 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE VV-I-. PER ET. GRADE ToP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.58# H-40 Surf. 121' 24" 290 sxAS I 7.625" 29.7# L-80 Surf. 4450' 9.875" 1190 sxAS III, 352 sx Class G, 60 sxAS I 5.5" 15.5# L-80 Surf. 7457' 6.75" 190 sx Class G 3.5" 9.3# L-80 7226' 8153' 4.75" 114'"sx class G .............. ....... 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7226' 7226' MD TVD MD TVD ... 7840'-7860' 6281 '-6296' 4 spf 126. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED 7840'-7860' Total proppant pumped 264301# (29465# ..... of #20/40, 220118# of #12/18, and 14718# of #10/14). Put 254924# in the formation w/#12 '" ppa of #10/14 @ perfs'. L~f~' 9377# in 'wellbOre 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) .......... 12/29/96 I Gas Lift 'bate of Test Hours Tested pRoDUCT]ON FOR OIL-BBL GAS-MCF WATER-'BBL" CHOKE"SIZE I GAS-OIL HA:rIO 4/21/97 17.8 TEST PERIOD · 1159 1755 62 0I 1206 Flow Tubing Casing Pressur~ OALCULATED. OIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 213 1163 24-HOUR RATE 1425 1718 83 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL ,.,: ' .,,,s~ Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Ma'~'-- 30. ' Formation Tests -- Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 7584' 6086' Bottom Kuparuk C Top Kuparuk A 7806' 6254' Bottom Kuparuk A 7898' 6326' Annulus left open - freeze protected well with diesel. 31. 'List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Prepared By Name/Number: 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. I'rEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 4/11/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3J-17 RIG:NORDIC WELL ID: AK8621 TYPE: AFC: AK8621 AFC EST/UL:$ 1033M/ llSOM STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:09/29/96 START COMP: FINAL: WI: 55% SECURITY:0 API NUMBER: 50-029-22700-00 09/28/96 (D1) TD: 121' (121) S UP V: RLM DAILY: $ 09/29/96 (D2) TD: 3309' (3188) SUPV: RLM DAILY:$ 09/30/96 (D3) TD: 4469' (1160) SUPV: RLM DAILY:$ 10/01/96 (D4) TD: 4469' ( 0) SUPV:GRW DAILY: $ 10/02/96 (DS) TD: 4775' (306) S UP V: GRW DAILY: $ 10/03/96 (D6) TD: 7046' (2271) SUPV: GRW DAILY: $ 10/04/96 (D7) TD: 7455' (409) S UPV: GRW DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MAKE UP BHA Move rig 204' from 3J-19 to 3J-17. 32,469 CUM:$ 32,469 ETD:$ 50,000 EFC:$ 1,015,769 MW: 9.2 VISC: 66 PV/YP: 27/23 APIWL: 6.8 DRILLIN Accept rig @ 0130 hrs. 9/29/96. Directional drill 9-7/8" hole from 121' to 3309'. 80,433 CUM:$ 112,902 ETD:$ 126,542 EFC:$ 1,019,660 7-5/8"@ 4449' MW: 9.1 VISC: 56 PV/YP: 20/20 APIWL: CEMENT CASING Directional drill 9-7/8" hole from 3309' to 4469' Wipe hole from 4469' to 3778', hole free. Hole got tight and began swabbing. Backream out from 3778' to 1470'. Hole trying to packoff while reaming out. Pulled from 1470' to 1285' hole free. Held pre-job safety meeting to run 7-5/8" casing. Ran 7-5/8" casing to 1946' 156,215 CUM:$ 269,117 ETD:$ 175,570 EFC:$ 1,126,847 4.8 7-5/8"@ 4449' MW: 9.2 VISC: 53 PV/YP: 21/18 APIWL: 5.6 CEMENT CASING Run casing from 1946' to 4449'. Pump cement. CIP @ 0529. Pump second stage cement. CIP @ 8:02. Lost returns second stage. Got contaminated returns to surface. Did deep top job to 422' per AOGCC. Test all BOPE equipment. 125,098 CUM:$ 394,215 ETD:$ 175,570 EFC:$ 1,251,945 7-5/8"@ 4449' MW: 8.4 VISC: 33 PV/YP: 5/ 4 APIWL: 17.6 CEMENT CASING Set wear ring, blow down kill/choke lines. Test casing above stage collar. Drill cement and stage collar. Drill cement, float collar, shoe joints, float shoe and 10' of new hole to 4479'. Run FIT to 16.3 ppg EMW. Drill from 4479' to 4519'. Run FIT to 18.3 ppg EMW. Drill from 4519' to 4775'. 77,561 CUM:$ 471,776 ETD:$ 218,328 EFC:$ 1,286,748 7-5/8"@ 4449' MW: 8.9 VISC: 41 PV/YP: 18/ 7 APIWL: DRILLING @ 7340' Drill 4775' to 7046'. Circ and add barafiber. Lost 40 bbl mud while weighting up. 90,452 CUM:$ 562,228 ETD:$ 535,657 EFC:$ 1,059,871 7.4 3-1/2"@ 8242' MW: 10.8 VISC: 42 PV/YP: 14/ 8 APIWL. RU TO RUN CASING Drill 7046' to 7448'. Perform LOT to 11.6 ppg EMW. Drill from 7448' to 7455' 85,351 CUM:$ 647,579 ETD:$ 592,807 EFC:$ 1,088,072 5.8 Date: 4/11/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/05/96 (D8) TD: 7457' ( SUPV: GRW 2) DAILY:$ 10/06/96 (D9) TD: 7457' ( SUPV: GRW 0) DAILY:$ 11/20/96 (D10) TD: 7457' ( 0) SUPV:DEB DAILY:$ 11/21/96 (Dll) TD: 7457' ( 0) SUPV:DEB DAILY: $ 11/22/96 (D12) TD: 7457' ( 0) SUPV:DEB DAILY:$ 11/23/96 (D13) TD: 7726' (269) SUPV: DEB DAILY: $ 11/24/96 (D14) TD: 7848' ( 122} SUPV:DEB DAILY:$ 11/25/96 (D15) TD: 7848' ( 0) SUPV: DEB DAILY:$ 3-1/2"@ 8242' MW: 0.0 vise: 42 PV/YP: 14/ 9 APIWL: 5.6 FREEZE PROTECTING Drill 7455'-7457'. Run 5.5" casing to 7455'. Pipe stuck and packed off 40' off bottom. Worked pipe free and regained returns. Lost 95 bbl mud. N/D BOPE. Cut casing. 70,271 CUM:$ 717,850 ETD:$ 593,087 EFC:$ 1,158,063 3-1/2"@ 8242' MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: RIG RELEASED Set. packoff. Freeze protect. Release rig @ 0700 hrs. 10/6/96. 118,914 CUM:$ 836,764 ETD:$ 593,087 EFC:$ 1,276,977 0.0 3-1/2"@ 8242' MW: 0.0 VISC: 42 PV/YP: 14/ 9 APIWL: NU BOPE Move rig off well 3J-07. Move rig over 3J-17. Accept rig @ 0500 hrs. 11/20/96. ND tree. NU BOPE. 13,972 CUM:$ 850,736 ETD:$ 593,087 EFC:$ 1,290,949 5.6 3-1/2"@ 8242' MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 POH W/OEDP ND tree. NU BOPE. Test BOPE to 250/5000 psi. Test 5.5" casing to 3500 psi for 30 minutes, lost 200 psi. Retest to 3500 psi for 30 minutes, lost 50 psi, OK. RIH with OEDP, PU DP. Tag ice plug @ 353'. POH w/OEDP. 33,932 CUM:$ 884,668 ETD:$ 593,087 EFC:$ 1,324,881 3-1/2"@ 8242' MW: 11.8 VISC: 52 PV/YP: 28/18 APIWL: 4.8 DRILLING CEMENT @ 7337' Test casing to 3500 psi for 30 minutes, OK. MU kelly. Test upper and lower kelly cocks to 250 psi & 5000 psi. Wash down from 7117' to 7131'. Drill plugs and cement from 7131' to 7337'. Drilling cement at 7337' @ 0600. 66,739 CUM:$ 951,407 ETD:$ 593,087 EFC:$ 1,391,620 3-1/2"@ 8242' MW: 12.0 VISC: 50 PV/YP: 26/21 APIWL: CIRC & WEIGHT UP TO 12.3 PPG Drill cement from 7337' to shoe @ 7448'. Drill out casing shoe & drill 10' new formation to 7458' Test formation. Drill from 7458' to 7726' Gas cut mud at surface. Well flowing, shut-in well. No gain. Kill well - load well with 12.3 ppg mud. 50,251 CUM:$ 1,001,658 ETD:$ 630,674 EFC:$ 1,404,284 4.8 3-1/2"@ 8242' MW: 12.6 VISC: 51 PV/YP: 32/21 APIWL: 4.6 WEIGHT UP TO 12.8 PPG Circulate out gas/oil cut mud & circulate 12.5 ppg mud around choke & degasser. Monitor well - no flow. Drill from 7726' to 7809' Still had some connection gas when drilling resumed. Brought MW up to 12.6 ppg. Drill from 7809' to 7848'. 41,201 CUM:$ 1,042,859 ETD:$ 647,722 EFC:$ 1,428,437 3-1/2"@ 8242' MW: 13.8 VISC: 50 PV/YP: 32/21 APIWL: POH Continue to monitor well and weight up anchcirculate around. Flowing slowly. Continue to weigh~~~ ~ JI.IIV ? 9, 129Y .Oil.& ~as Cons. 4.6 Date: 4/11/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/26/96 (D16) TD: 7858' ( 10} SUPV:DEB DAILY:$ 3-1/2"@ 8242' MW: 13.8 VISC: 50 PV/YP: 32/15 APIWL: 4.8 DRILLING @ 7858' Continue to have problems with bit. Break in new bit & drill from 7848' to 7858', drilling ahead. 53,747 CUM:$ 1,136,874 ETD:$ 649,119 EFC:$ 1,521,055 11/27/96 (D17) TD: 8061' (203) SUPV:DW DAILY:$ 3-1/2"@ 8242' MW: 13.0 VISC: 50 PV/YP: 29/21 APIWL: DRILLING @ 8061' Continue drilling 4.75" hole from 7848' to 7960'. Started losing fluid while drilling. Continued to drill from 7960' to 7963'. Fluid loss @ 40 bph. Stopped drilling brought pump rate back to 35 spm 1500 psi. Work pipe. Drill from 7963' to 8061'. Continue fluid loss, continue to cut mud weight. 49,203 CUM:$ 1,186,077 ETD:$ 677,484 EFC:$ 1,541,893 4.6 11/28/96 (D18} TD: 8154' ( 93) SUPV:DW DAILY:$ 3-1/2"@ 8242' MW: 12.7 VISC: 50 PV/¥P: 29/21 APIWL: 4.6 STUCK @ 8116' Continue drilling 4.75" hole from 8061' with 13.0 ppg mud weight. Well flowing. Drill to TD @ 8154'. Weight up mud to 13.7 ppg. Observe well. Well dead. RIH slowly to 8116' while picking up single pipe stuck. Stuck above jars @ 7950'. Work pipe unable to free. No jar or bumper movement. Circulate and drop mud weight to 12.7 ppg while working pipe. 45,509 CUM:$ 1,231,586 ETD:$ 1,130,000 EFC:$ 1,134,886 11/29/96 (D19) TD: 8154' ( 0) SUPV: DW DAILY:$ 3-1/2"@ 8242' MW: 13.7 VlSC: 50 PV/YP: 30/22 APIWL: 4.8 POOH FOR E-LOGS Continue to work stuck pipe w/bit @ 8112' & top of collars @ 7771', TD of 4.75" hole @ 8154'. Lower mud weight to 12.0 ppg and pipe came free. 45,605 CUM:$ 1,277,191 ETD:$ 1,130,000 EFC:$ 1,180,491 11/30/96 (D20) TD: 8154' ( 0) SUPV:DW DAILY:$ 3-1/2"@ 8242' MW: 13.3 VISC: 50 PV/YP: 29/21 APIWL: CIRC @ LINER TOP 7226' Run 3.5" liner and packer. Pump cement. 102,181 CUM:$ 1,379,372 ETD:$ 1,130,000 EFC:$ 1,282,672 4.8 12/01/96 (D21) TD: 8154' ( 0) SUPV:DW DAILY:$ 3-1/2"@ 8242' MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 L/D 2-7/8" DP & BHA Load pipe house w/3.5" tubing and completion equipment. Test casing and liner lap to 3500 psi for 30 min. OK. R/U to run 3.5" completion. 33,432 CUM:$ 1,412,804 ETD:$ 1,130,000 EFC:$ 1,316,104 12/02/96 (D22) TD: 8154' ( 0) SUPV:DW DAILY:$ 3-1/2"@ 8242' MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: N/U TREE Run 3.5" completion. 140,417 CUM:$ 1,553,221 ETD:$ 1,130,000 EFC:$ 1,456,521 0.0 12/03/96 (D23) TD: 8154' ( 0) SUPV:DW DAILY:$ 3-1/2"@ 8242' MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RELEASE RIG @ 1200 HRS. N/D BOP's, N/U tree. Test packoff to 5000 psi, OK. Test tree to 5000 psi OK. Shut in well and secure. Release rig @ 1200 hrs. 12/2/96. 8,237 CUM:$ 1,561,458 ETD:$ 1,130,000 EFC:$ 1,464,758 End of WellSummary for Well:AK8621 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3J-17(W4-6)) W~ I. JOB SCOPE JOB NUMBER 3J-17 PERFORATE, PERF SUPPORT 1204961721.3 DATE DAILY WORK 12/21/96 PERFORATE F/7840 - 7860 ~ ELM DAY OPERATION COMPLEIE I SUCCESSFUL 2 YES I YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSI 1200 PSI 1800 PSI DAILY SUMMARY [PERFORATED F/7840 TO 7860 FT ELM KEY PERSON SWS-BAILEY UNIT NUMBER UNIT #1 SUPERVISOR BLACK Final Inner Ann I 1800 PSI I Initial Outer Ann ~ Final Outer Ann 0 PSI! 0 PSI TIME 09:00 i1:30 12:30 14:30 LOG ENTRY MIRU SWS (BAILEY & CREW). TGSM - GUN SAFE fY & MUSTER POINT. NUll. FY DWS Ul' CREW ON LOCATION OF PERF ACFIV1TIES. MU GUN ASSEMBLY (20 FT 2-1/2" BH GUNS / CCL ) TL - 23.5 FF. PT BOPE 3500 PS/. RIH W/GUN ASSEMBLY TO 7950 FI' ELM. TIE INTO 11/29/96 PHASOR INDUu'IION LOG & 12/16/96 PDC LOG. CONFIRM DEPTHS. SHOOT F/7840 - 7860 FT ELM (4 SPF TOTAL ~. OVER BALANCE +/- 200 PSI. POOH W/GUN ASSEMBLY. AI.I. SHOTS FIRED. RD SWS. TURN WELL TO PRODUCTION F/FRAC. MOVE TO 3H-13. Memory Multi-Finger Caliper Log Results Summary Company: Phillips Alaska, Inc. Well: 3J-17 Log Date: October7, 2001 Field: Kuparuk Log No.: 4423 State: Alaska Run No.: 1 APl No.: 50-029-22700-00 Pipe Desc.: 3.5" 9.3 lb. E.U.E. Top Log Intvl: 2,998 Ft. (MD) Pipe Use: Tubing Bot. Log Intvl: 7,254 Ft. (MD) Inspection Type ' Corrosive Damage I Patch Candidate Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the tubing is in good condition. An isolated pit was recorded in the make-up between joint 191.3 and 192, just below GLM 4. A cross sectional diagram is included in this report. No other wall penetrations in excess of 19% wall thickness are recorded throughout the interval logged. No areas of significant cross-sectional metal loss or areas of significant ID restriction are recorded throughout the interval logged. The distribution of corrosive penetrations recorded throughout the tubing string is illustrated in the Body Region Overview sheet of this report. Note: Because the interval logged did not reach the surface, the joint count is a speculative assumption of the joint numbering at the depth of 3,000 ft. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (46%) Jt. 191.3 @ 6,000' MD No other penetrations in excess of 19% wall thickness are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall-loss (in excess of 5%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No areas of significant ID restriction (in excess of 5%) are recorded throughout the interval logged. I Field Engineer' L. Koehn Analyst: M. Lawrence Witness: T. Johns ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-i369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Weih August 9, 2001 Field: Kuparuk Company: Phillips Alaska, Inc. Countw: USA PDS Caliper Overview Body Region Analysis Survey Date: October 7, 2001 Tool Type: MFC24 No.99812 Tool Size: 1.69" No. of Fingers: 24 Analysed: M. Lawrence Tubing; Size Weight Grade & Thread Nora. OD Nom. ID Nora. Upset 3~5 ins 9.3 ppf }-55 EUE 3.5 ins 2.992 ins 3.5 ins penetration body ~5~4 metal loss body 0 to I to 10 to 20 to 40 to above 1% 10% 20% 40% 85% 85% ~umber of}oints analysed to~al = 142) Pene 0 72 69 0 I 0 loss 7 135 0 0 0 0 40i Damage Con~g~m§on ( ~od¥ ) Number ofjoints damagpd (total = 40) 34 6 0 0 0 Damage Profile (% penetration body ~ metal toss body 0 50 GLM 6 GLM 5 145 GLM 4 GLM 3 GLM 2 GLM 1 Bottom of Survey = 228 100 PDS JOINT TABULATION SHEET~ Pipe: 3.5 ins 9.3 ppf J-55 EUE Wall thickness. Body: 0.254ins Upsel = 0.254ins Nominal ID: 2.992 ins Well: August 9, 2001 Field: Kul)amk Company: Phillips Alaska, Inc. Country: USA Date: October 7, 2001 , inches inches % % 1oo.11 o o o o i o .o2,u, ~ ~, 0 .02 i 9i 2 0 .02 9 2 0 .03 ~ 1 5 .03 3 1 /06i 0 i .02 0 [ .03 o .04 lO91 o .02 ~, o .03 Metal Projection Minimum Loss [Jpset jBody ID inches inches inches 0 0 2.90 0 0 2.90 0 i 2.90 0 .03 2.90 0 .06 ' 2.91 0 0 2.93 0 2,93 0 2.89 o i 2.89 .031 2.90 0 .05 2.87 81 0 I .03 2.90 1.3 ! 0 I .04J 2.87 ';!!;! 0 i .02 8i , 0 ', 0 itl4 i 0 .o-~j 15j 4 0 i .04J 2.88 0 .03 116 I 0 .02 9[ 117 i o .o3~gi 118 0 i .02 9 j.o i .o3 0 J .02 121 i 0 [ .03i 13 122 0 .03J 1 123 0 .03 l ,02 8 125 3 0 .05 2.90 2 0 j .04 2.88 2 9~[[ .04 2.86 0 .04[ 2.92 0 ~03~ 290 0 [ .03 2.90 o I .o4 2.89 0 .03 i 2.91 .05 2.87 0 0 ] 2.90 PUP PUP Shallow 126 0 .02 1 127 0 .02 128 0 .03 129 0 .02 0 .03 13t 0 .04 14 132 0 .04 0 i .03 101 o .02 0 i .02! 135.11 0 .02 J 6 0 0 01 .03 11i o .04 [ [137 0 .04 j 1138 0 ' .02 I 8J 0 I IL~9~ o J .o3 ~ ,~ o [ 140 0 I .02 8 i 0 i o o I ? 143 j 0 .02 9 , I 0 [144 [ 0 I .0~ 6, ) L 0 91 0 91 0 121 0 8 0 10 0 .04~ i o I o i o o o i o [ os o I o o 0 0 0 I .041 0 .041 0 .03 0 2.91 2.90 .04 } 2.92 0 2.91 Shallow corrosion. } Lt Shallow lit. 2.89 J Shallow 2.94 2.91 Lt. Deposits. 2.91 PUP 2.89 GLM 2 (l~tch @ 6:00) PUP 2.89 I Shallow 2.91 2.92 2.86 2.92 2,92 2.92 Shallow pitlin g. penetration body metal loss body Damage profile (% wall) 50 I00 Pipe Tabulations page 1 PDS CALI JOINT TABULATION SHEEY Pipe: 35 ins 9.3 ppf F55 [iff Well: Augusi 9. 2001 Walt lhicbless Body; 0 254ins Upsel = 0 254Ms tMd: Kuparuk ,145 03 10J 3 0 i 0 292 , ~47 , 0 02 , 9 ) , 0 04L 2.~}~ Si . ) . ( 4 [ 0 04 29J lghalk)w !~ 0 O? 8i 2 i 0 01. 2.91 6 . ( , (3 . 5 2 , 0 , (~[ 27~ fihallow 162 = 0 ~ .O~ , 9 0 ~ 0 , 292 ~ ,163 0 ~ 02, 8 2 0 0 292 ~64 0 03 ~ ~ 3 0 , .04 290 i 165 0 02 8 i 3 0 i ~ (,6 o [ .O2 9 3 0 167 0 02 9 2 , 0 168 0 03 169 0 02 170 0 02 171 0 03 172 0 .03 173 0 03 10i 3 0 7 4 0 9 2 0 { 11 3 0 12 i ~ o !0 4 0 [174 . 0 _ 03 t3, 4 i 0 J ( 4 i 2 90 0 2.91 O) 290 0 290 (14 289 .04 288 04 i 291 [ Shallow 0 i ¥9J , ' 'i 02 9i 1 ~ ( 0 4 0 i .(14 i 2.90 '~Y , !~ , .q2, g -~ o 04 2.9:, 2 0 , 3 0 4 0 2 0 4 o .05 4 o .o~ 3 0 05 5' 0 05 i 2 0 .04 0 2 93 0 2,9~ 05 290 .05 292 .04 292 2 87 2.88 2.87 Shallow corlosion. '2 0 i .o5 i ~.8 i Damage plofiie ., wall} 50 100 PDS JOINT TABULATION Pipe: 3.5 ins 93 ppi 1-55 IlJE Wall thick,less Body: 0.25&~s tlp'~et = 0254i~1s Nbminal ID: 2 992 Wdl: Au[;ust 9, 2001 Field: Kq)aruk Melal Proiedion [ Minimum i Damage 19~ 2 i 191.3 0 12 46 2 02 0 291 PllP Isolaied i~% J 0 03 ~2i 2 0 i OS 29( j 1% i ( I3 11 [ 2 , 0 .04 2.92 l 201 0 03 12 2 0 0'~ 2 9'. 202 0 02 7 i 4 0 05 2 9~ 2 ~3 _ 0 03 10 2 [ 0 1)4 2.90 ~ 204 0 . O~ . l~ ] 2 [ 0 . .05 2.89 [Shallow piilir~ ]208 0 -0~, ~3, 2 ~ 0 ~ .04] 2.88 [ i210 0 i 0 , 0[ 0 0 0 2.[)1 (]lM4 (lald~@2:00) 0 03 10 i 2 0 02 9 [ ¸2 0 1 0 05 291 05 i !88 05 [ 291 i Shallow pilting O3 13 i i223 i 0 i 03 i 12 2 i 0 05i 291 22,1 (} O~ 8 ~ 0 03 ~91 122721 0 i 04 i 14 i 5 [ 0 i 04i 2)3 PUP 2274 0 0 ] 0i 0 0 0 296 IV, ri<ER PDS CAI.MR JOINT TABULATION SHEE~ Pipe: 3.5 ins 9.3ppf }-~l il' Wall thk:kf~ ss Body: 0 254itls Upsol = 0 254ins Nomil~al ID: 2.992 ins Well: August 9, 2001 Field: Kupalnk ( ompally: Phillips Alaska, Ill( ~ pel~etration llody joirtt PeitetratMn Met,~l Projection Minimum i ] l)amage profile NO Upset [ Body loss IJpset jPx,dy ID (omn~ent, (% wall} J inches [ i~ch~5 % % inches [inches Mches D 50 I00 PDS Caliper Sections We[h Augusl 9, 2001 St~rvey Date: October 7, 2001 Field: Kuparuk Tool Type: MFC24 No,99812 Company: Phillips A}aska, ]nc. Tool Size: 1,69' Country; USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf t-55 EUE Ana}\,s~d: M. Lawrence CrosS section roi' Joint 191.3 at depth 6000.44 ft Tool speed -- 4l Hem]rial iD = 2.992 Nomil~al OD ~ 3.500 Rernai~ing wall area = 94 % In Upse] Region Tool deviation = 48 ° Finger 1 Penetraiio~ = 0. 116 ins Isolated pit 0.12 in = 46% Wal} Penetratio~a HIGII SIDE = U P PDS C, ,LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint i100.1 lO0.2 100.3 101 Depth feet Length feet 3024.82 15.13 3039.95 6.26 3046.21 3061.52 15.31 31.47 3.002 nominal 102 3092.99 31.62 3.005 103 3124.61 29.37 3.005 104 3153.98 31.62 nominal 3185.60 105 106 1107 108 3214.60 29.00 inches I 3.003 / Pup nominal ] Giro 1 · Pup 3.001 31.05 2.996 31.38 nominal 3245.65 3277.03 29.71 2,990 109 3306.74 31.68 2.997 10 3338.42 3t.62 2.990 11 3370.04 30.47 2.996 112 3400.51 31.79 3.003 13 3432,30 31.31 2,996 114 3463.61 30.76 nominal 115 3494.37 31.40 nominal 116 3525.77 30.34 3.001 117 3556.11 31.87 118 3587.98 119 t 3619.34 31.36 26 27 ~128 30,49 2.998 3.003 2.995 120 3649.83 28.30 2.995 121 3678.13 31.81 2.990 I 122 3709.94 30.51 2.997 23 3740.45 31.51 2.997 .. 24 3771.96 31.60 2.984 125 3803.56 31.50 2~988 3835.06 31,39 3.004 I i 29 t30 3866.45 29,75 2.998 3896.20 30,41 3926.61 31.68 .984 .996 2.988 ] 3958.29 31.53 131 3989.82 29.52 2.988 132 4019.34 28.32 . 2.991 133 4047.66 3027 [ 2.994 31.33 4077.93 4109.26 4140.73 31.47 15.06 4155.79 6.31 4162.10 15.40 31.45 4177.50 42O8.95 31.61 34 135 135.1 1135.21 [135.31 1137 i I139 I 31.50 4240.56 2.996 2.994 2.997 l Pup i nominal 3.000 ]Pup 2.986 3,002 2.996 2.990 2.996 4272.06 31.66 i140 i 4303.72 ' 31.40 !141 [ 4335.12 31,44 3.004 I 142 [ 4366.56 31.63 3.003 [143 j 4398.19 30.58 3.001 [ , ~144 [ 4428.77 31.53 2.990 Well: Field: Company: CountEy: Date: [Joint No. i145 ]146 !147 1148 [149 !150 151 152 153 54 155 156 August9,2001 Kuparuk Phillips Alaska, Inc. USA Oc~ber g 2001 Depth feet 4460.30 4491.87 4523.28 Length feet 31.57 31.41 30.36 Measured ID inches 2.996 2.985 nominal Type 4553.64 30.57 3.000 4584.21 31.51 3.004 4615.72 31.67 2.998 4647.39 29.55 2.999 4676.94 31.34 2.998 3.001 30.79 4708.28 4739.07 31.35 2.996 4770.42 31.53 nominal 31.54 4801.95 157 ] 4833.49 31.47 158 i 4864.96 I 31.49 159 4896.45 [ 30.55 160 ! 4927.00 31.53 31.76 61 162 163 164 64.1 64.2] 164.31 165 [ 4958.53 166 167 I 168~ 169 170 171 172 I173 Jt74 t17s /176 4990.29 31.58 2.983 5021.87 31.51 2.998 5053.38 31.81 2.998 180 181 182 183 184 185 186 5085.19 15.17 3.006 5100.36 6.20 nominal 5106.56 15.32 3.007 2.999 ]__~,, 3.002 nominal 3.005 2.999 j ~ 3.003 I i ?up ~ Pup I 5121.88 31.48 3.001 5153.36 31.42 2.986 5184.78 31.61 3.002 5216.39 30.57 2.987 5246.96 31.65 2.990 5278.61 31.61 nominal 5310.22 31.61 2.994 5341.83 31.38 nominal 5373.21 31.57 2.984 5404.78 30.44 2.986 5435.22 31.52 2.996 2.987 5466.74 29.64 nominal 5775.39 31.82 177 I 5496.38 29.38 2.985 5525.76 31.56 2.995 5557.32 31.43 2.988 5588.75 31.52 2.991 5620.27 31.55 2.994 5651.82 31.41 2.995 5683.23 29.64 2.982 5712.87 31.28 nominal 5744.15 31.24 2.986 187I 5807.21 31.46 2.981 5838.67 31.39 2.995 31.36 2.981 i188 i 189 190 191 5870.06 5901.42 31.37 nominal 5932.79 31.64 2.991 i Joint Tally page 1 PDS C,~LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins !Joint i No. [191.1 Depth I Length Measured Type Pup 5964.43 [ 15.33 ! nominal 195 6095.11! 31.59 1196 ~ 6126.70 [ 30.50 1197 198 !199 i191.2 5979.76 i 6.38 [ nominal [ GIm 4 [191.3 5986.14 ] 15.18 nominal [Pup !192 6001.32 I 31.19 2.991 1193 6032.51 I 31.45 2.988 1194 6063.96 i 31.15 nominal 2.994 3.001 2.995 ~ nominal 6220.451 30.23 2.979 6250.68[ 3t.80 2.997 3.000 i200 [201 6157.20 I 31.42 6188.62I 31.83 6282.48[ 31.38 [ 6313.86 [ 31.39 6345.25! 31.51 2.983 6376.76[ 31.49 6408.25] 3t.32 6439.57 ] 31.52 [202 1203 [204 [205 [206 6471.09[ 31.18 i208 !209 1210 1211 6502.27 31.34 6533.61 I 30.12 6563.73 i 29.39 6593.12 31.50 6624.62 [ t5.09 6639.71i 5.95 6645.66 ] 15.54 ]211.1 [211.2 '214 215 1216 , [217 !218 681 7.73 i 31.47 2.982 2.988 2.997 2.981 2.983 2.989 2.997 3.006 2.986 2.994 Pup nominal Ghn 5 nominal I Pup [211.3 i212 6661.20 ! 31.61 2.984 i213 6692.81 ] 31.33 2.984 6724.14 I 30.59 2.990 I 31.33 nominal 6754.73 i 6786.06 [ 31.67 2.979 6849.20 i 31.46 6880.66 ] 31.39 i219 nominal 2.996 2.987 [220 6912.05 i 31.40 2.990 221 6943.45[ 31.48 i222 ] 6974.93 I 31.28 223 ! 7006.21 i 31.82 nominal 2.995 2.988 224 i 7038.03 I 3t.38 2.983 ] 225 [ 7069.41 ] 3t_19 2.989 t 226!7100.60131.75 226.11 7132.35 I 14.65 226.2[ 7147.00 7.09 1227 I 7169.41 I 31.19 2.997 , [227.1[ 7200.60i 1.83 nominal /D-Nip l [22 7.2] 7202.43 i 5.07 1227.3[ 7207.50 1 12.80 !227.4[ 7220.30 I 3.20 : i227.5i 7223.50 ] 5.01 2.998 }Pup nominal 3.003 ]Pup 2.971 3.000 iPupPup Packer nominal I KBH Nil~ nominal , Wel[: August 9, 2001 Field: Kuparuk Company: Phillips Alaska, Inc. Country.: USA Date: October 7, 2001 Joint Depth Length Measured Type No. ID feet feet inches 228 7228.51 unknown 3.005 i f! ri Joint Tally page 2 A Gyro d a t a D i r e c t i o n a i Survey ARCO ALASKA INC. WELL: 3J-17, 3.5"TBG Location: 3J PAD, KRU UNIT, Job Number: AK1296C375 NORTH SLOPE, AK MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERT I CAL SECTION feet 0.0 -.0 - .2 -1.9 -6.4 0.0 0.00 0.00 0.0 100.0 .07 221.98 100.0 200.0 .19 207.02 200.0 300.0 1.80 196.31 300.0 400.0 3.53 188.62 399.9 DUPLICATE Page 1 DEPTH feet d ~~%~~t d~ feet -86.0 0.00 .0 0.00 N 0.00 E 14.0 .~,~/~' .... 1 222 0 04 S 04 W 114.0 .3 213.3 .24 S .16 W 214.0 1.61 2.0 199.6 1.89 S .67 W 313.9 1.77 6.6 193.7 6.44 S 1.58 W 500.0 6.02 176.76 499.5 601.0 8.60 165.90 599.7 700.0 10.90 160.50 697.3 800.0 13.82 151.61 794.9 901.0 16.90 147.98 892.3 -14.7 -27.3 -43.3 -62.8 -85.8 413.5 2.66 14.8 186.7 14.72 S 1.74 W 513.7 2.89 27.3 179.2 27.33 S .40 E 611.3 2.50 43.7 173.0 43.34 S 5.33 E 708.9 3.48 64.3 167.3 62.76 S 14.16 E '806.3 3.19 90.2 162.1 85.83 S 27.69 E 1000.0 18.52 145.60 986.6 1050.0 19.38 144.47 1033.9 .1100.0 20.10 143.62 1081.0 1150.0 21.24 142.97 1127.8 1200.0 22.43 142.15 1174.2 -111 -124 -138 -152 -166 .0 .3 .0 .1 .9 900.6 1.79 119.5 158.3 111.01 S 44.20 E 947.9 1.86 135.3 156.7 124.31 S 53.51 E 995.0 1.55 151.9 155.3 137.98 S 63.43 E 1041.8 2.34 169.2 154.1 152.13 S 73.98 E 1088.2 2.45 187.4 152.9 166.89 S 85.29 E 1250.0 24.63 140.21 1220.0 1300.0 25..80 139.33 1265.2 1350.0 27.00 139.46 1310.0 1400.0 28.45 140.43 1354.3 1450.0 30.76 141.86 1397.8 -182 -198 -215 -233 -252 .4 .7 .6 .4 .6 1134.0 4.65 207.0 151.8 182.43 S 97.81 E 1179.2 2.46 227.9 150.7 198.69 S 111.57 E 1224.0 2.42 249.7 149.7 215.57 S 126.04 E 1268.3 3.02 272.7 148.9 233.38 S 141.00 E 1311.8 4.84 297.2 148.2 252.62 S 156.48 E 1500.0 32.79 141.85 1440.3 1550.0 34.14 141.01 1482.0 1600.0 35.01 139.73 1523.1 1650.0 35.51 139.16 1564.0 1700.0 36.28 138.76 1604.5 -273.3 -294.9 -316.7 -338.7 -360.8 1354.3 4.06 323.3 147.7 273.33 S 172.75 E 1396.0 2.84 350.8 147.2 294.88 S 189.94 E 1437.1 2.27 378.9 146.7 316.73 S 208.03 E 1478.0 1.19 407.6 146.2 338.66 S 226.80 E 1518.5 1.63 436.7 145.7 360.77 S 246.05 E A Gyrodata Di ARCO ALASKA INC. WELL: 3J-17, 3.5"TBG Location: 3J PAD, KRU UNIT, Job Number: AK1296C375 NORTH SLOPE, AK MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 1750.0 37.46 138.21 1644.5 .800.0 38.49 137.89 1683.9 1850.0 38.87 137.68 1722.9 1900.0 38.50 137.54 1762.0 1950.0 37.92 137.42 1801.2 2000.0 37.74 137.45 1840.7 2050.0 38.19 137.61 1880.2 2100.0 39.23 138.14 1919.2 2150.0 39.70 138.20 1957.8 2200.0 40.56 138.31 1996.0 2250.0 40.66 138.43 2300.0 40.48 138.35 2350.0 40.10 138.49 2400.0 39.96 138.43 2450.0 39.50 138.20 ~500.0 39.19 137.95 2550.0 39.02 137.79 2600.0 38.58 137.46 2650.0 38.47 137.54 2700.0 38.89 137.70 2750.0 39.52 137.87 2800.0 39.29 138.04 2850.0 38.93 138.07 2900.0 38.81 138.07 2950.0 38.60 138.32 -383.2 -406.1 -429.3 -452.3 -475.1 -497.7 -520.4 -543.6 -567.3 -591.3 r e c t i o n a 1 Survey SUBSEA DEPTH feet 1558.5 1597.9 1636.9 1676.0 1715.2 Page 2 1754.7 1794.2 1833.2 1871.8 1910.0 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 2.43 466.5 145.2 2.11 497.0 144.8 .80 528.0 144.4 .76 559.1 144.0 1.18 589.8 143.7 .35 620.3 143.4 · 92 650.9 143.1 2.18 682.1 142.8 · 95 713.7 142.6 1.72 745.9 142.4 2034.0 -615.7 1948.0 .26 778.3 142.3 2071.9 -640.0 1985.9 .38 810.8 142.1 2110.1 -664.2 2024.1 .78 843.1 142.0 2148.4 -688.2 2062.4 .28 875.2 141.9 2186.8 -712.1 2100.8 .96 907.1 141.7 2225.5 -735.7 2139.5 .71 938.7 141.6 2264.3 -759.1 2178.3 .38 970.2 141.5 2303.2 -782.2 2217.2 .97 1001.4 141.4 2342.4 -805.2 2256.4 .24 1032.5 141.2 2381.4 -828.3 2295.4 .86 1063.7 141.1 2420.1 -851.7 2334.1 1.28 1095.2 141.0 2458.8 -875.2 2372.8 .51 1126.9 141.0 2497.6 -898.7 2411.6 .71 1158.4 140.9 2536.5 -922.0 2450.5 .24 1189.8 140.8 2575.5 -945.3 2489.5 .52 1221.0 140.7 HORIZONTAL COORDINATES feet 383.23 S 265.93 E 406.11 S 286.50 E 429.26 S 307.49 E 452.34 S 328.56 E 475.13 S 349.46 E 497.72 S 370.21 E 520.41 S 390.98 E 543.60 S 411.95 E 567.28 S 433.14 E 591.33 S 454.60 E 615.65 S 476.22 E 639.97 S 497.82 E 664.15 S 519.27 E 688.22 S 540.60 E 712.09 S 561.86 E 735.68 S 583.03 E 759.06 S 604.19 E 782.21 S 625.31 E 805.17 S 646.35 E 828.25 S 667.41 E 851.66 S 688.65 E 875.23 S 709.90 E 898.69 S 730.98 E 922.04 S 751.95 E 945.35 S 772.79 E A Gyroda t a D i r e c t i on a i Survey ARCO ALASKA INC. WELL: 3J-17, 3.5"TBG Location: 3J PAD, KRU UNIT, Job Number: AK1296C375 NORTH SLOPE, AK Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. H 0 R I Z O N T A L COORDINATES feet 000.0 39.33 138.51 2614.4 -968.9 2528.4 1.48 1252.4 140.7 968.87 S 793.66 E 3050.0 39.50 138.58 2653.0 -992.7 2567.0 .36 1284.2 140.6 992.66 S 814.68 E 3100.0 39.08 138.66 2691.7 -1016.4 2605.7 .84 1315.8 140.6 1016.42 S 835.62 E 3150.0 39.01 138.82 2730.5 -1040.1 2644.5 .25 1347.3 140.5 1040.10 S 856.39 E 3200.0 39.65 139.02 2769.2 -1064.0 2683.2 1.30 1379.0 140.5 1063.99 S 877.22 E 3250.0 39.65 138.89 2807.7 -1088.0 2721.7 .16 1410.9 140.5 1088.05 S 898.17 E 3300.0 39.19 138.89 2846.3 -1112.0 2760.3 .91 1442.6 140.4 1111.97 S 919.04 E 3350.0 38.83 138.84 2885.2 -1135.7 2799.2 .72 1474.1 140.4 1135.68 S 939.75 E 3400.0 38.64 138.76 2924.2 -1159.2 2838.2 .41 1505.3 140.4 1159.22 S 960.35 E 3450.0 39.03 138.86 2963.1 -1182.8 2877.1 .80 1536.7 140.3 1182.81 S 981.0'0 E 3500.0 39.91 139.69 3001.7 -1206.9 2915.7 2.05 1568.5 140.3 1206.90 S 1001.73 E 3550.0 39.67 140.28 3040.1 -1231.4 2954.1 .89 1600.5 140.3 1231.41 S 1022.31 E 3600.0 39.26 140.43 3078.7 -1255.9 2992.7 .84 1632.2 140.3 1255.88 S 1042.59 E 3650.0 39.45 140.48 3117.4 -1280.3 3031.4 .38 1664.0 140.3 1280.33 S 1062.77 E ~00.0 39.78 140.37 3155.9 -1304.9 3069.9 .67 1695.8 140.3 1304.91 S 1083.08 E 3750.0 39.32 140.05 3194.5 -1329.4 3108.5 1.01 1727.7 140.3 1329.37 S 1103.46 E 3800.0 39.16 139.79 3233.2 -1353.6 3147.2 .45 1759.3 140.3 1353.57 S 1123.82 E 3850.0 38.71 139.76 3272.1 -1377.6 3186.1 .90 1790.7 140.3 1377.56 S 1144.11 E 3900.0 38.85 139.35 3311.1 -1401.4 3225.1 .59 1822.0 140.3 1401.40 S 1164.43 E 3950.0 39.63 139.17 3349.:8 -1425.4 3263.8 1.57 1853.7 140.3 1425.36 S 1185.07 E 4000.0 39.67 139.21 3388.3 -1449.5 3302.3 .09 1885.6 140.2 1449.51 S 1205.92 E 4050.0 39.15 139.19 3426.9 -1473.5 3340.9 1.03 1917.3 140.2 1473.54 S 1226.67 E 4150.0 39.22 138.82 3504.9 -1520.8 3418~L ~ ~.%21~0~¢ ~.~ 979 9 140.2 1520.82 S 1267.75 E 4200.0 39.72 138.75 3543.5 -1544.7 3457.5 1.00 2011.7 140.2 1544.73 S 1288.69 E '~ ii~l ] ti,i 1997 ~ i ~ ~' .... ~i~ i'.~ '~ [.ii .... LL[[[[[[![ [[1~! [![[ [ [[ I I.I ~lI [ Illlllll ..................... Illlll ................................. A Gyrodat ARCO ALASKA INC. WELL: 3J-17, 3.5"TBG Location: 3J PAD, KRU UNIT, Job Number: AK1296C375 NORTH SLOPE, AK MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet a Di re c t i ona 1 Survey SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 4250.0 39.36 138.46 3582.0 -1568.6 3496.0 .79 2043.5 140.1 1300.0 39.47 138.45 3620.7 -1592.4 3534.7 .21 2075.2 140.1 4350.0 38.81 138.56 3659.4 -1616.0 3573.4 1.33 2106.8 140.1 4400.0 38.50 138.52 3698.5 -1639.4 3612.5 .62 2138.0 140.1 4450.0 38.18 138.71 3737.7 -1662.7 3651.7 .69 2169.0 140.0 4500.0 38.39 139.17 3777.0 -1686.0 3691.0 .71 2200.0 140.0 4550.0 38.61 139.30 3816.1 -1709.6 3730.1 .48 2231.1 140.0 4600.0 38.44 139.33 3855.2 -1733.2 3769.2 .34 2262.3 140.0 4650.0 38.16 139.67 3894.4 -1756.8 3808.4 .71 2293.2 140.0 4700.0 38.06 139.92 3933.8 -1780.4 3847.8 .37 2324.1 140.0 4750.0 37.63 139.85 3973.3 -1803.8 3887.3 .86 2354.8 140.0 4800.0 37.57 140.12 4012.9 -1827.2 3926.9 .35 2385.3 140.0 4850.0 37.38 140.40 4052.6 -1850.6 3966.6 .51 2415.7 140.0 4900.0 37.14 140.63 4092.4 -1873.9 4006.4 .55 2446.0 140.0 4950.0 37.69 141.55 4132.1 -1897.6 4046.1 1.57 2476.3 140.0 JO0.O 39.75 147.01 4171.1 -1923.0 4085.1 7.98 2507.5 140.1 5050.0 40.34 148.10 4209.4 -1950.1 4123.4 1.83 2539.4 140.2 5100.0 40.16 148.25 4247.5 -1977.6 4161.5 .42 2571.4 140.3 5150.0 40.28 148.52 4285.7 -2005.1 4199.7 .42 2603.4 140.4 5200.0 40.53 148.86 4323.8 -2032.8 4237.8 .67 2635.4 140.5 5250.0 40.69 149.21 4361.7 -2060.7 4275.7 .55 2667.6 140.6 5300.0 40.78 149.53 4399.6 -2088.7 4313.6 .45 2699.9 140.7 5350.0 40.40 149.74 4437.6 -2116.8 4351.6 .80 2732.0 140.8 5400.0 40.38 150.05 4475.7 -2144.8 4389.7 .40 2764.0 140.9 5450.0 39.97 150.35 4513.9 -2172.8 4427.9 .91 2795.8 141.0 Page 4 HORIZONTAL COORDINATES feet 1568.61 S 1309.73 E 1592.37 S 1330.79 E 1616.01 S 1351.70 E 1639.42 S 1372.37 E 1662.69 S 1392.88 E 1686..04 S 1413.23 E 1709.62 S 1433.55 E 1733.23 S 1453.85 E 1756.80 S 1473.98 E 1780.37 S 1493.90 E 1803.83 S 1513.66 E 1827.20 S 1533.28 E 1850.59 S 1552.73 E 1873.95 S 1571.98 E 1897.59 S 1591.06 E 1922.98 S 1609.27 E 1950.13 S 1626.53 E 1977.58 S 1643.56 E 2005.07 S 1660.48 E 2032.76 S 1677.33 E 2060.67 S 1694.0~7 E 2088.74 S 1710.69 E 2116.81 S 1727.14 E 2144.84 S 1743.39 E 2172.83 S 1759.42 E A Gyrodata ARCO ALASKA INC. WELL: 3J-17, 3.5"TBG Location: 3J PAD, KRU UNIT, Job Number: AK1296C375 NORTH SLOPE, AK MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet Directional Survey VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. ;00.0 39.84 150.79 4552.2 -2200.8 4466.2 .62 2827.5 141.1 5550.0 39.82 151.24 4590.6 -2228.8 4504.6 .57 2859.0 141.2 5600.0 39.77 151.49 4629.1 -2256.9 4543.1 .34 2890.5 141.3 5650.0 40.07 151.75 4667.4 -2285.1 4581.4 .69 2922.1 141.4 5700.0 42.87 148.83 4704.9 -2313.8 4618.9 6.81 2954.8 141.5 5750.0 43.09 148.30 4741.4 -2342.9 4655.4 .84 2988.7 141.6 5800.0 43.12 148.87 4778.0 -2372.1 4692.0 .79 3022.6 141.7 5850.0 42.57 149.40 4814.6 -2401.3 4728.6 1.32 3056.3 141.8 5900.0 42.53 149.95 4851.4 -2430.4 4765.4 .75 3089.8 141.9 5950.0 42.45 150.50 4888.3 -2459.8 4802.3 .76 3123.2 142.0 6000.0 42.43 151.12 4925.2 -2489.2 4839.2 .84 3156.6 142.1 6050.0 44.37 147.68 4961.5 -2518.8 4875.5 6.11 3190.6 142.1 6100.0 45.07 146.09 4997.1 -2548.2 4911.1 2.65 3225.7 142.2 6150.0 45.04 146.30 5032.4 -2577.6 4946.4 .31 3261.0 142.2 ~.r'00.0 45.07 146.63 5067.7 -2607.1 4981.7 .47 3296.3 142.3 6250.0 44.84 147.05 5103.1 -2636.7 5017.1 .75 3331.5 142.3 6300.0 44.90 147.49 5138.5 -2666.4 5052.5 .62 3366.6 142.4 6350.0 44.45 147.98 5174.1 -2696.1 5088.1 1.13 3401.6 142.4 6400.0 44.83 148.15 5209.7 -2725.9 5123.7 .78 3436.6 142.5 6450.0 44.45 148.66 5245.3 -2755.9 5159.2 1.04 3471.6 142.5 6500.0 44.73 146.41 5280.8 -2785.5 5194.8 3.21 3506.5 142.6 6550.0 44.45 141.46 5316.5 -2813.8 5230.5 6.97 3541.6 142.6 6600.0 44.11 141.41 5352.3 -2841.1 5266.3 .68 3576.5 142.6 6650.0 44.08 141.59 5388.2 -2868.4 5302.2 .27 3611.3 142.6 6700.0 42.74 139.99 5424.5 -2895.0 5338.5 3.48 3645.6 142.6 Page 5 HORIZONTAL COORDINATES feet 2200.77 S 2228.78 S 2256.87 S 2285.10 S 2313.84 S 2342.92 S 2372.08 S 2401.26 S 2430.45 S 2459.76 S 2489.22 S 2518.77 S 2548.24 S 2577.64 S 2607.15 S 2636.72 S 2666.40 S 2696.12 S 2725.94 S 2755.86 S 2785.47 S 2813.83 S 2841.12 S 2868.35 S 2894.98 S 1775.18 E 1790.70 E 1806.03 E 1821.28 E 1837.71 E 1855.49 E 1873.30 E 1890.74 E 1907.82 E 1924.59 E 1941.04 E 1958.54 E 1977.76 E 1997.45 E 2017.00 E 2036.32 E 2055.39 E 2074.16 E 2092.74 E 2111.15 E 2129.99 E 2150.64 E 2172.40 E 2194.06 E 2215.78 E A Gyrodata ARCO ALASKA INC. WELL: 3J-17, 3.5"TBG Location: 3J PAD, KRU UNIT, Job Number: AK1296C375 NORTH SLOPE, AK MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet ~50.0 41.97 138.69 5461.4 6800 . 0 41 . 80 138 . 85 5498 . 7 6850 . 0 41 . 65 138 . 89 5536 . 0 6900.0 41.85 139.00 5573.3 6950.0 41.43 139.21 5610.7 7000.0 41.59 139.19 5648.1 7050.0 41.25 139.50 5685.6 7100.0 41.09 139.61 5723.2 7150.0 40.97 139.63 5761.0 7200.0 40.86 139.59 5798.7 7250.0 41.36 139.48 5836.4 7300.0 41.25 139.29 5874.0 7350.0 41.60 139.22 5911.5 7400.0 41.76 139.34 5948.8 i 50.0 42.04 139.67 5986.0 7500.0 41.69 140.05 6023.3 7550.0 41.70 140.30 6060.6 7600.0 41.44 140.32 6098.0 7650.0 41.06 140.58 6135.6 7700.0 40.86 140.51 6173.3 7750.0 40.32 140.84 6211.3 7800.0 39.74 141.32 6249.6 7850.0 38.97 141.28 6288.3 7900.0 37.25 141.50 6327.6 7950.0 35.17 141.42 6367.9 -2920.5 -2945.6 -2970.7 -2995.8 -3020.9 -3046.0 -3071.1 -3096.1 -3121.2 -3146.1 -3171.1 -3196.2 -3221.2 -3246.4 -3271.8 -3297.3 -3322.9 -3348.4 -3373.8 -3399.1 -3424.3 -3449.3 -3474.1 -3498.2 -3521.3 Directional Survey SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 5375.4 2.33 3679.3 142.5 5412.7 .39 3712.6 142.5 5450.0 .31 3745.8 142.5 5487.3 .42 3779.0 142.4 5524.7 .87 3812.2 142.4 5562.1 .32 3845.3 142.4 5599.6 .81 3878.3 142.4 5637.2 .34 3911.2 142.3 5675.0 .24 3944.0 142.3 5712.7 .24 3976.7 142.3 5750.4 1.02 4009.5 142.3 5788.0 .34 4042.5 142.2 5825.5 .70 4075.5 142.2 5862.8 .36 4108.7 142.2 5900.0 .72 4142.1 142.2 5937.3 .87 4175.4 142.2 5974.6 .34 4208.6 142.1 6012 . 0 . 52 4241 · 8 142 · 1 6049 . 6 . 84 4274 · 8 142 . 1 6087.3 .41 4307.5 142.1 6125.3 1.17 4340.0 142.1 6163.6 1.30 4372.2 142.1 6202.3 1.55 4403.9 142.1 6241.6 3.45 4434.7 142.1 6281.9 4.16 4464.3 142.1 Page 6 HORIZONTAL COORDINATES feet 2920.53 S 2237.72 E 2945.63 S 2259.72 E 2970.70 S 2281.61 E 2995.80 S 2303.48 E 3020.92 S 2325.23 E 3046.00 S 3071.10 S 3096.15 S 3121.15 S 3146.09 S 3171.10 S 3196.16 S 3221.22 S 3246.42 S 3271.82 S 3297.33 S 3322.87 S 3348.40 S 3373.82 S 3399.12 S 3424.29 S 3449.31 S 3474.05 S 3498.16 S 3521.26 S 2346.88 2368.43 E 2389.78 E 2411.05 E 2432.27 E 2453.61 E 2475.09 E 2496.68 E 2518.37 E 2540.05 E 2561.57 E 2582.86 E 2604.05 E 2625.04 E 2645.87 E 2666.49 E 2686.69 E 2706.52 E 2725.77 E 2744.17 E A Gyroda t a D i r e c t i on a i Survey ARCO ALASKA INC. WELL: 3J-17, 3.5"TBG Location: 3J PAD, KRU UNIT, NORTH SLOPE, AK Job Number: AK1296C375 MEASURED I N C L AZIMUTH VERTICAL VERTICAL SUBSEA DEPTH DEPTH SECTION DEPTH feet deg. deg. feet feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 8000.0 34.19 141.62 6409.1 -3543.5 6323.1 8017.0 34.14 141.59 6423.1 -3551.0 6337.1 Final Station Closure: Distance: 4502.27 ft 1.96 .31 Az: 4492.7 142 . 1 4502.3 142.1 142.07 deg. Page 7 H 0 R I Z O N T A L COORDINATES feet 3543.53 S 3551.01 S 2761.87 E 2767.80 E GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10710 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1/17/97 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape ~13J-17 ~ '7 :~'7 ~;'- 97014 PHASOR INDUCTION-SFL & GR 961129 1 3J-17 9701 4 PHASOR INDUCTION-SFL 9611 29 1 1 .~3J-19 ~ '7.-~ 96288 MWD ARC5/ADN4 9611 01 1 3J-19 96288 ARC5 961101 I 1 3J-19 96288 ADN4 961101 I I S I G N E D- ~~ ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 15, 1996 William S. Isaacson Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: request for waiver to 20 AAC 25.080(d)(~4), Annular Disposal of Drilling Waste Dear Mr. Isaacson: ¢ ~fl~~ The Commission has received your request for waiver to 20 AAC 25.080(d)(4), which restricts annular disposal of drilling waste from drilling operations in wells on the same pad. The request for waiver is intended for well'.BJ:17., i: ~5: ARCO seeks authorization to inject drilling wastes from the 4 3/4" hole section of well 3J-17 into the annulus of well lC-11 on lC pad. The 4 3/4" section of the 3J-17 well will be drilled by Nordic #2, which does not have the ability to dispose of waste by annular injection. ARCO has indicated that all solids generated by the drilling operation will be hauled to CC-2A for grind and inject and drilling waste fluids will be hauled to Parker 245 for annular injection. Well 1C-11 was approved for annular injection on November 8, 1996. Well 3J-17 was originally drilled by Parker 245 and lost circulation problems required that a 5 1/2" casing string be set before TD was reached. Drilling plans were then modified to allow Nordic #2 to drill the remaining hole section and run a 3 1/2" liner to TD. The Commission hereby ~ants a waiver to ARCO Alaska, Inc. for well 3J-17 from the limitations of 20 AAC 25.080(d)(4). Under the circumstances, the Commission finds that it would be imprudent to limit annular disposal to a well on 3J pad. The drilling xvastes from well 3J-17 may be taken to Parker 245 for annular disposal into well lC-11, subject to the other terms and conditions of the Commission's authorization covering the latter well. Chairman MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 1, 1996 Blair Wondzeil, -¢'.'.~~ P. I. Supervisor Ce/'~ Petroleum Inspector FILE NO: GGXIJADD.doc Cement - Sur. Csg. KRU - 3J-17 PTD# 96-0146 Tuesday, October 1, 1996: I was contacted at 8:30 AM by Bobby Morrison, ARCO rig rep., Informing me that he did not get cement to surface on the 7" surface casing. He said that he was trying to contact his supervisor in Anchorage and would stay in touch with me. He also advised me that he was going to town and would be relieved by Guy Whitiock, not his usual relief. ! called Blair Wondzeil and informed of the problem and he told me to go to the rig as soon as I could and stay there until the problem was corrected. I ardved at the rig and talked with Mr. Whitlock about the problem. Guy, who has not worked on the rigs on the slope since March of 1996, said he was going to run 1" pipe in to below the conductor casing and do a top job. I explained what the policy of the AOGCC on "top jobs" and he decided to try to find the TOC. The 1' pipe was run in the hole to 137' RKB, - 97' from the casing head, where it stopped and he ask me if he could pump cement. I told him no so the hole was circulated out with fresh water. There was some contaminated mud circulated out but that did not suit me so the 1" pipe was run in the hole to 400' where it seemed to be in cement. The crew was having to push the pipe in the hole and got the pipe to 421'. The well was again circulated out and some cement and contaminated mud was circulated out. The samples were checked by the onsite mud engineer and the Ph ran between 9 and 11.5. I contacted Blair and discussed the situation with him. it was decided to let them pump cement at that time. The "remedial cement job" consisted of 159 Sacks of Articset 3 ( 55 bbis.) and good 12 Cf cement was circulated back to surface. Summary: I witnessed the tagging of the surface cement job and remedial cement job on ARCO KRU well 3J-17. 'Attachment: X Unclassified Confidential Confidential (Unclassified if doc. removed ) Materials Class G Lafarge D53 - Gypsum D44 - Salt D65- Dispersant D13 - Retarder D46 - Antifoam D24 - Gilsonite D79- Extender S1 - Accelerator LBS/SK Blend Bulk Volume Slurry Density Mix Water Slurry Yield DOwell ARCTICSET CEMENT ARCTICSET I 30.00 45.00 3.77 0.37 0.23 0.14 ___ 79.51 Ib/sk 1.00 cuft/sk ARCT~CSET II ARCTICSET II! 27.54 45.63 41.55 22.82 3.48 12.02 0.34 --- 0.33 0.12 0.14 4.06 --- --- 0.91 --- 0.91 77.42 Ib/sk 82.43 Ib/sk 1.00 cuft/sk 1.00 cuft/sk ARCTICSET IV 45.63 22.82 12.02 0.62 0.14 _-- 1.10 0.91 83.24 Ib/sk 1.00 cuft/sk 15.70 ppg 3.59 gps 0.93 cuft/sk Slurry Properties ARCTiCSET II ARCTICSET III 15.20 ppg~=~-~o.~ 12.07 ppg 3.59 gps'b~'.r~..~' 11.11 gps 0 93 cuft/sid~ ~'~,r,~__ 1 .94 cuft/sk Fann 35 ARCTICSET IV 12.07 ppg 11.11 gps 1.94 cuft/sk Reading ARC~CSETI ARC~CSET# ARC~CSETm ARC~CSETIV 600 142 158 13 13 300 71 85 8 7 200 48 55 7 4 100 25 30 4 3 Temp. 40 deg. F 70 deg. F. ARCTICSET I + 2 hrs + 4 hrs Thickening Time ARCTICSET II + 2 hrs + 4 hrs ARCTICSET III + 6 hrs + 6 hrs ARCTICSET IV + 6 hrs + 6 hrs Compressure Strength (40 deg F) Time ARCTICSET I ARCT~CSET # ARCTICSET III ARCTICSET IV 12 hrs 520 psi 430 pSi NS NS 24 hrs 730 psi 490 psi 20 psi 15 psi 48 hrs ...... 40 psi 35 psi Cement Temp. 40 deg F 20 deg F 0 deg F -20 deg F -40 deg F Acceptable Mix Water Temp. Range ARCTICSET I & !1 Slurry - 60 deg F. 70 deg F 85 deg F 95 deg F 103 deg F 112 deg F Slurry - 80 deg F. 100 deg F 110 deg F 120 deg F 120 deg F 130 deg F ARCTICSET I!1 & IV Slurry - 60 deg F. 63 deg F 67 deg F 70 deg F 75 deg F 77 deg F Slurry - 70 deg F. 74 deg F 77 deg F 83 deg F 87 deg F 90 deg F TONY KNOWLE$, GOVERNOR SKA OIL AND GAS CONSERVATION COMMISSION September 13, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi, Drlg Engr Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 3J- 17 ARCO Alaska, Inc. 96-146 710'FSL, 563'FWL, Sec 03, T12N, R09E, UM 2775'FNL, 1847'FEL, Sec 10, T12N, R09E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. --. ~hyai~RD~- ~IvlISSION - dlf/encl c: Dept ofFish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ; ALA;dKA OIL AND GAS CONSERVATION COMMISb~ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry ~ Deepen [] Service [] Development Gas [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. Rig RKB 41' Pad 45' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25630, ALK 2563 4. Location of well at surface 7. Unit or property Name I 1. Type Bond (see 20 AAC 25.025) 710' FSL, 563' FWL, Sec. 3, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2454' FNL, 2116' FEL, Sec. 10, T12N, R9E, UM 3J-17 #U-630610 At total depth 9. Approximate spud date Amount 2775' FNL, 1847' FEL, Sec. 10, T12N, R9E, UM 9/1 3/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) property line 3J-01 8079' MD 1847 @ TD feet 30'~ 20' feet 2560 6517' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 39.4° Maximumsudace 2123 psig At total depth (TV•) 3300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Length MD TVD MD TVD (include stage data/ 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 4245' 41' 41' 4286' 3586' 1020 Sx Arcticset III & HF-ERW 340 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 7398' 41' 41' 7439' 6023' HF-ERW 220 Sx Class G 6.75" 3.5" 9.3# L-80 EUE8rdM 640' 7439' 6023' 8079' 651 7' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size Cemented Measure[[~.~d~t~. El ~l~gcal depth Conductor Surface intermediate Production~,UG P_ 0 1996 Liner Perforation depth: measured Alaska 0il & Gas C0ns. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the fj)regoing is tr~e and~(lt~ ~'/~ correct to the best of my knowledge ~'(~ ,~?¢ Signed . Title Drill Site Develop. Supv. Date '"-- Commission Use Only iI Approva, date ~,~, I See cover ,etter for . 5 O- ~ 2-~-- 2....2- ~ (~ ~ ~,/~::~-" other rec~uirements Conditions of approval Samples required r-~ Yes .[~ No Mud Icg required FI Yes [~ No Hydrogen sulfide measures ~] Yes [] No Directional survey required ~i~ Yes [] No Required working pressure for BOPE [] 2M ~ 3M r-~ 5M [] 1OM ~] 15M Other: :,!ha! Signed By ': by order of ....~,~,~ Approved by : d W. Johnston Commissioner the commission Date ~'--/J Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3J-1 7 , , . 10. 11. 12. 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,286')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (8,079') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 3-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3J-17 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Dri Iling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,123 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3J-17 is 3J-01. As designed, the minimum distance between the two wells would be 30' @ 20'. Drilling Area Risks- Risks in the 3J-17 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3J-17 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr)in pumping operations. The 3J-17 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3J-17 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3J surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3738 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). AUG 2 0 0ii & Gas Cc-,r~s A.nchoraoe ARCO ALASKA, Inc. Pad 3J Well : 17 slot #17 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 17 Version #3 Our ref : prop1619 License : Date printed : 1-Aug-96 Date created : 1-May-96 Last revised : 1-Aug-96 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w149 50 43.336 Slot location is n70 25 3.723,w149 50 26.828 Slot Grid coordinates are N 6002392.361, E 519546.096 Slot local coordinates are 710.00 N 563.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 DECREASING CLEARANCES of [ess than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PGMS <O-9650'>,,1,Pad 3J 8-Nov-91 30.0 20.0 20.0 PGMS <O-9466'>,,2,Pad 3J 8-Nov-91 54.7 300.0 300.0 PGMS <O-8496'>,,3,Pad 3J 8-Nov-91 79.8 240.0 240.0 PGMS <O-8544'>,,4,Pad 3J 8-Nov-91 104.9 240.0 1800.0 PGMS <O-8750'>,,5,Pad 3J 8-Nov-91 129.3 300.0 300.0 PGMS <O-8627'>,,6,Pad 3J 8-Nov-91 154.3 300.0 300.0 PGMS <O-7650'>,,7,Pad 3J 8-Nov-91 179.8 300.0 300.0 PGMS <O-irJ20'>,,8,Pad 3J 8-Nov-91 205.0 20.0 20.0 PGMS <O-6790'>,,9,Pad 3J 8-Nov-91 280.0 20.0 325.0 PGMS <O-7344~>,,10;Pad 3J 8-Nov-91 305.0 20.0 20.0 PGMS <O-7865'>o,11,Pad 3J 8-Nov-91 329.9 300.0 300.0 PGMS <O-8296'>o,12,Pad 3J 8-Nov-91 355.0 140.0 140.0 PGMS <O-7670'>,,13,Pad 3J 8-Nov-91 378.6 300.0 300.0 PGMS <O-8130~>o,14,Pad 3J 8-Nov-91 405.0 20.0 20.0 PGMS <O-8659'>,,15,Pad 3J 8-Nov-91 430.0 20.0 20.0 PGMS <O-8860'>,,16,Pad 3J 8-Nov-91 455.0 20.0 20.0 18 Version #6,,18,Pad 3J 1-Aug-96 15.0 280.0 280.0 19 Version #5,,19,Pad 3J 1-Aug-96 220.0 300.0 300.0 Creoted by jones For: D PETRASH O~te I~otted : 1-g~Jg-g6 Plot Reference is 17 Version ARCO ALASKA, Inc. Structure : Pod 5J Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 400 0 400 800 1200 1600 2000 2400 2800 3200 I I II I I II II II I I I I I I 400 S 3 o 4E DE G E ~I I suR~^cE LOC^*,ON: I ~J, _ t~ 1710' FSL, 563' FWLI 0 4096'(T0 TARGET) ~ %, I~[c. ~, ~,~., ~ I ***Plane of Proposol*** 400 400 ~ 800 I KOP WD=300 mD=300 D[P=O ~ 3 O0 ~ 7 5/8 Casm'g 1600 400 [ 8.34 ~ 1~;~. DLS: 3.00 deg per lO0 f[ X/~ 2000 800 ~ ~9.88 X~- I ~ 22.85 %~ V ~ 25.80 %~ ~. ~ 1200 % 28.78 . %~ z~uu % 31.75 ' ~ 34.73 ~600 ~ EOC WD=1554 1MD=1657 DIP=437 ~ 2800 ~ B/ PEEMAFEOSI ~D=1701 1MD=1847 DEP=SS8 ~ ~ ~ I 2454' FNL, 2116~EL I I ~ T/ UGNU SNDS WD=2181 TMD=2468 DEP=952 I-~' ~ ~D=6007 ~ 1MD=7420 3600 ~ SO~H 31fi4 - ~ST 2601 ~ T/ W SAK SNDS WD:2956 TMD=3471 DEP=1589 I lB LOCATION: ~ I 2775' FNL, 1847' FELI ~ I SEC. ~o, T~2., R~E I %Xx~B/w sAK SNDS ~D=3386 1MB=4027 DEP=1942 %~ ~/8" CSG PT ~D=3586 TMD=4286 DEP=2107 - - % AVERAGE ANGLE ............................... ~ 39.41 DEG 4800 COLVILLE SNDS WD=4806 ~MD=5865 DEP=3109 5200 B/ HRZ ~D~800 TMD=7152 DEP=3926 ~ x T/ UNITA ~D~242 TM~7724 DEP=4289 ~ T/ UNIT B ~D=6127 TMD=7575 DEP=4194 6800 ~ i t ~ ~ B ~ I ~ I I I I ~ I ~ I I I I I I I I I I I Vertical %ecfion (feet) -> Azimuth 140.58 with reference 0.00 N, 0.00 E from slot ~17 A!;~:: U:;Z "'~,'~:,~S. Commission ~ .... _ ~. . ...., . -.. 2000 2400 2800 3200 3600 4000 4400 Cr~oted by ]on~ For: D PETRASH Dote p~okt~d: l-Aug-g6 I Plat Reference ie 17 Vem~n ~. [ C~rd~not~ o~ ;n feet re~erence s~ ~17. ] 160 120 120 80 40 2700 'ARCO ALASKA, Inc. Structure : Pad 3J Well: 17 Field : Kuparuk River Unit Location : North Slope, Alaska 7OO East (feet) -> 0 40 80 120 160 200 240 280 .320 2900 1300 3100 1500 90C 1700 700 )50O 700 3300 360 400 i i i 1900 440 48O 160 120 120 16O 200 24O 280 320 360 40O 44O 480 1300 170( 1300 1900 3700 1500 1500 1700 120 160 2OO 240 280 320 360 400 440 48O 0 52O 4100 520 56O 6OO 64O 120 80 4O 0 40 80 120 160 200 240 280 East (feet) -> 4300 320 360 400 440 480 56O 600 640 KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 3 1 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER RECEIVED EDF 3/10/92 J h , ,6 , 5 4 13 5/8" 5000 PSi STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURETHAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3, OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOPSTACKTEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHEC~ THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3, CLOSE ANNULAR PREVENTER AND CFIOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VN.VES. ~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. E OPEN TOP PIPE RAMS AND CLOSE BOTFOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PS! AND 3(XX) PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLF_ CLOSE BLIND RAMS AND TEST TO 3(X)O PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 1~_ TEST KELLY CC(~S AND INSIDE BOP TO 3000 PSI WiTH KOOMEY PUMP. 1:~ RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS W1LL ACCOMODATE ;~1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 1. 16' - 2(XX) PSI STARTING HEAD 2_ 11' - 3000 PS! CASING HEAD 11" - 3000 PSI X 1~5/8' - 5000 PSI SPACER SPOOL 4. 13~/6-- ~~ RPE ~ 5. 13~3/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL MNES ~ 1;~5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR · WELL PERMIT CHECKLIST COMPANY ,~e._,~ W~LLNAME z/~,~'/-~ ,~ / 7 PROGRAM:expEl dev~i~,'/redrtl El servE] wellboreseg Clann. disposaipamreq ~ FIELD & POOL g'/'1~'4:3./'4::3,,"J INIT CLASS /2~z-/ /'"',.-~.,, ~/ GEOL AREA <~:' _~ ~ UNIT# //'/~'~ ON/OFF SHORE_ 63 ~ ~D~iNiSTRATiON ............ 'EN~21NEERiNG . 8. 9. 10. 11. 12. 13. 1. Permit fee attached ...................... 2. Lease numberappmpriate .................. 3. Unique well name and number ............... 4. Well located in a defined pool ................ 5. Well located proper distance from ddg unit boundary... 6. Well located proper distance from other wells ........ Sufficient acreage available in drilling unit. ......... If deviated, is wellborn plat included ............. Operator only affected party ................. Operator has appropriate bond in force ........... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. ,. Can permit be approved before 15-day wait. ....... .Y N N N N N N N N N N N N REMARKS 14. Conductor string provided .................. ~1-. '2. N 15. Surface casing protects all known USDWs ......... ~.N 16. CMT vol adequate to circulate on conductor & surf csg .'~.. 17. CMT' vol adequate to de-in long string to surf csg ...... ..,~ CUT, , .ow. produc , ho zo.. ......... 19. Casing designs adequate for C, T, B & permaJmsL ..... N 20. Adequate tankage or reserve pit. ............... (~N 21. If a re-dOll, has a 10-403 for abndnmnt been approved .... ~'/'~ 22. Adequate wellbore separation proposed ............ (..Y~NN 23. If diverter required, is it adequate ................ list adequate. 24. Drilling fluid program schematic & equip . . . N 25. BOPEs adequate ...................... N 26. BOPE press rating adequate; test to ~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ...... 28. Work will occur without operation shutdown .......... 29. Is presence of H2S gas probable .............. GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N // -- 31. Data presented on potential overpmssum zones ....... Y 32. Seismic analysis of shailow gas zones ............. /Y/N ' 33. Seabed condition survey (if off-shore) ........... ~. Y N 34. Contact name/phone for weekly progress reports .... /'.. Y N [e,,vp[oraWry only] GEOLOGY: ENGINEERING: COMMISSION: BEW~¢f ¢.~ DWJ~ JDH ~ JDN Comments/Instructions: HOWdjb - A,'~-OR~s~ rev 4/96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically. organize this category of information. LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/01/14 ORIGIN : FLIC REEL NABiE : 97014 CONTINUATION # : PREVIOUS REEL : CO~E4ENT : ARCO ALASKA INC, 3J-17, KUPARUK, API #50-029-22700-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/01/14 ORIGIN : FLIC TAPE NAME : 97014 CONTINUATION # : 1 PREVIOUS TAPE : CO~k~ENT : ARCO ALASKA INC, 3J-17, KUPARUK, API #50-029-22700-00 TAPE HEADER KUPARUK RIVER UNIT OPEN HOLE WIRELINE LOGS WELL NA~E : API NU~ZBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUlV~ LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3J-17 500292270000 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 14-JAN-97 RUN 1 97014 BAILEY DON WESTER RUN 2 RUN 3 3 12N 9E 710 563 77.00 77.00 41.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 5.500 7448.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 3RD STRING PRODUCTION STRING RE~HL~KS: CONTAINED HEREIN IS T~E OPEN HOLE PHASOR INDUCTION- SFL DATA AQUIRED ON ARCO ALASKA'S 3J-17 WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCRE~F2TT: 0.5000 FILE SU~k~RY LDWG TOOL CODE DTE $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH ..................... 7962.0 7448.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ RE~NLRKS: THIS FILE CONTAINS THE DTE DATA AQUIRED IN OPEN HOLE AND CLIPPED AT CASING. THIS DATA HAS BEEN ADJUSTED TO REFLECT THE NORDIC 2 RKB OF 77 '. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE RUN NO. PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELEM CODE (HEX) DEPT FT 100620 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE 0P~4~100620 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OH~MlO0620 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OH~MlO0620 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~M 100620 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE OH~MlO0620 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 100620 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 100620 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 100620 O0 000 O0 0 1 1 1 4 68 0000000000 ~I~ESDTE OH~ff4100620 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDTE DEGF 100620 O0 000 O0 0 ! 1 1 4 68 0000000000 SP DTE MV 100620 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7962. 000 IDPH. DTE -999. 250 IMPH. DTE -999. 250 ILD. DTE ILM. DTE -999.250 SFL.DTE -999.250 GR.DTE -999.250 TEND.DTE TENS.DTE 3530. 000 Ri~ES.DTE O. 648 MTEM.DTE 126.219 SP.DTE DEPT. 7448.000 IDPH. DTE -999.250 IMPH.DTE -999.250 ILD.DTE ILM. DTE -999.250 SFL.DTE -999.250 GR.DTE 113.813 TEND,DTE TENS.DTE 3060.000 MRES.DTE 0.679 MTEM. DTE 118.512 SP.DTE -999,250 534,500 -999.250 -999,250 523.500 -999,250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * FILE HEADER * * * * FILE NAME : EDIT . 002 SERVICE : FLIC VERSION : O01CO1 DATE · 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREbTE1VT : O . 5000 FILE SUA~4ARY LDWG TOOL CODE START DEPTH DTE 7448.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH .......... 7050.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE ....... REMARKS: THIS FILE CONTAINS THE GR FROM THE MAIN LOG AQUIRED UP INTO CASING. THIS DATA HAS BEEN ADJUSTED TO REFLECT THE NORDIC 2 RKB OF 77'. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ! ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~UMB SAMP ELEM CODE (HEX) DEPT FT 100620 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 100620 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DTE LB 100620 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 100620 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7448.000 GRCH.DTE 113.813 TEND.DTE 523.500 TENS.DTE DEPT. 7050.000 GRCH. DTE 105.250 TEND.DTE 507.750 TENS.DTE 3060.000 3010.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE · 97/01/14 MAX R~C SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN 19IIMBER : 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUAmiARY VENDOR TOOL CODE START DEPTH STOP DEPTH 7988.5 7448.0 DTE $ LOG HEADER DATA DATE LOGGED: 29-NOV- 96 SOFTWARE VERSION: CP44.2 TIME CIRCULATION ENDED: 300 29-NOV-96 TIME LOGGER ON BOTTOM: 1030 29-NOV-96 TD DRILLER (FT) : 8154.0 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 7050.0 BOTTOM LOG INTERVAL (FT) : 7962.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DTE RESISTIVITY CART. AMS AUX. MEASURMENT CART. TOOL NUMBER DIC-EC-44 AMS 774 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: GR GAM~b% RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : SGC-SA-404 6.750 7448.0 7453.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 13.70 MUD VISCOSITY (S) : 50.0 MUD PH: 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 126.0 RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 420 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 961 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 920 MUD CAKE AT (BHT) : 56.0 58.0 58.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL WITH MARKED E-LINE. RAN DITE W/O CENTRALIZATION DUE TO HOLE SIZE. LOG DEPTHS REFERENCED TO NORDIC 2 RIG DEPTHS. LOGGED GR UP TO 7100' TO SHOW TIE-BACK TO LWD LOG. SAT DOWN AT 7955' ON INITIAL DOWN LOG. IM~4EDIATELY LOGGED BACK UP INTO CASING DUE TO HOLE PROBLEMS. TRIED TO LOG DOWN AGAIN BUT COULDN'T GET BELOW 7550'. CANCELED FURTHER LOGGING. DOWN LOG USED AS REPEAT SECTION THIS FILE CONTAINS THE RAW OPEN HOLE MAIN LOG DATA CLIPPED AT CASING. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100620 O0 000 O0 0 3 1 1 4 68 0000000000 CIDP DTE f4~!HO 100620 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH DTE 0H~I~100620 O0 000 O0 0 3 1 1 4 68 0000000000 CIMP DTE M~!HO 100620 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH DTE 0P~4~100620 O0 000 O0 0 3 1 1 4 68 0000000000 CILDDTE M~J~O 100620 O0 000 O0 0 3 1 1 4 68 0000000000 ILD DTE OH~MlO0620 O0 000 O0 0 3 1 1 4 68 0000000000 CILMDTE M~HO 100620 O0 000 O0 0 3 1 1 4 68 0000000000 ILM DTE Oh?4MlO0620 O0 000 O0 0 3 1 1 4 68 0000000000 IFREDTE HZ 100620 O0 000 O0 0 3 1 1 4 68 0000000000 IDQF DTE 100620 O0 000 O0 0 3 1 1 4 68 0000000000 IMQF DTE 100620 O0 000 O0 0 3 1 1 4 68 0000000000 IIRDDTE M~4~O 100620 O0 000 O0 0 3 1 1 4 68 0000000000 IIXDDTE f4FI40100620 O0 000 O0 0 3 1 1 4 68 0000000000 IIRMDTE FI~!HO100620 O0 000 O0 0 3 1 1 4 68 0000000000 IIX~DTE ~4FiHO100620 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU DTE OPH~flO0620 O0 000 O0 0 3 1 1 4 68 0000000000 SP DTE MV 100620 O0 000 O0 0 3 1 1 4 68 0000000000 GR DTE GAPI 100620 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DTE LB 100620 O0 000 O0 0 3 1 1 4 68 0000000000 MTE~DTE DEGF 100620 O0 000 O0 0 3 i 1 4 68 0000000000 FIRES DTE OPi~qlO0620 O0 000 O0 0 3 1 1 4 68 0000000000 HTENDTE LB 100620 O0 000 O0 0 3 ! 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: ** DATA DEPT. 7988. 500 CIDP, DTE IMPH.DTE 3.1 O0 CILD.DTE ILM.DTE 3. 084 IFRE,DTE IIRD. DTE 23 O. 875 IIXD, DTE SFLU. DTE 4.230 SP, DTE MTEM. DTE 126.219 AiP~ES . DTE DEPT. 7448. 000 CIDP,DTE IMPH.DTE O. 797 CILD.DTE ILM. DTE O. 860 IFRE. DTE IIRD.DTE 1074. 000 IIXD,DTE SFLU. DTE 2.336 SP. DTE MTEM. DTE 118. 512 MRES. DTE 270.000 IDPH.DTE 272.000 ILD.DTE 20.000 IDQF.DTE 31.188 IIRM. DTE 6.914 GR.DTE 0.648 HTEN. DTE 1708.000 IDPH.DTE 1872.000 ILD.DTE 20.000 IDQF.DTE -754.500 IIRM. DTE -3.197 GR.DTE 0.679 HTEN.DTE 3.701 CIMP.DTE 3.672 CILM. DTE 3.000 IMQF.DTE 302.250 IIX~.DTE 75.188 TENS.DTE -2072.000 0.585 CIMP.DTE 0.534 CILM. DTE 0.000 IMQF.DTE 1028.000 IIXM. DTE 113.813 TENS.DTE 523.500 322.500 324.000 2.000 17.953 3515.000 1254.000 1161.000 0.000 -1090.000 3060.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAI~E : EDIT .003 SERVICE : FLIC VERSION : O01COI DATE : 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN~ER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE StC4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PA GE: 10 DTE $ LOG HEADER DATA 7448.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIt~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 7642.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DTE RESISTIVITY CART. AMS AUX. MEASURMENT CART. GR GA~ff4A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS fEUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS 29-NOV-96 CP4 4 . 2 300 29-NOV-96 1030 29-NOV-96 8154.0 7050.0 7962.0 TOOL NUMBER DIC-EC-44 AMS 774 SGC-SA-404 6.750 7448.0 7453.0 LSND 13.70 50.0 9.1 126.0 1. 420 56.0 O. 961 58.0 1. 920 58.0 USED PRIMARY DEPTH CONTROL WITH MARKED E-LINE. RAN DITE W/O CENTRALIZATION DUE TO HOLE SIZE. LOG DEPTHS REFERENCED TO NORDIC 2 RIG DEPTHS. LOGGED GR UP TO 7100' TO SHOW TIE-BACK TO LWD LOG. SAT DOWN AT 7955' ON INITIAL DOWN LOG. I~fEDIATELY LOGGED LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 11 BACK UP INTO CASING DUE TO HOLE PROBLEMS. TRIED TO LO~ DOWN AGAIN BUT COULDN'T GET BELOW 7550'. CANCELED FURTHER LOGGING. DOWN LOG USED AS REPEAT SECTION THIS FILE CONTAINS THE RAW OPEN HOLE REPEAT PASS CLIPPED AT CASING. THIS PASS WAS ACQUIRED LOGGING UPHOLE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100620 O0 000 O0 0 4 1 1 4 68 0000000000 CIDP DTE [z~iHO 100620 O0 000 O0 0 4 1 1 4 68 0000000000 IDPH DTE 0t~4~100620 O0 000 O0 0 4 1 1 4 68 0000000000 CIMP DTE N2viHo 100620 O0 000 O0 0 4 1 1 4 68 0000000000 IMPH DTE OHFff4100620 O0 000 O0 0 4 1 1 4 68 0000000000 CILDDTE ~g~iHO 100620 O0 000 O0 0 4 1 1 4 68 0000000000 ILD DTE 0H~4~100620 O0 000 O0 0 4 1 1 4 68 0000000000 CILMDTE [~4HO 100620 O0 000 O0 0 4 1 1 4 68 0000000000 ILM DTE 0H34~100620 O0 000 O0 0 4 1 1 4 68 0000000000 IFRE DTE HZ 100620 O0 000 O0 0 4 1 1 4 68 0000000000 IDQF DTE 100620 O0 000 O0 0 4 1 1 4 68 0000000000 IMQF DTE 100620 O0 000 O0 0 4 1 1 4 68 0000000000 IIRD DTE M~!HO 100620 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 12 NA~E SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) IIXD DTE I~IHO 100620 O0 000 O0 0 4 1 1 4 68 0000000000 IIRM DTE F~4}tO 100620 O0 000 O0 0 4 1 1 4 68 IIX~ DTE MFiHO 100620 O0 000 O0 0 4 1 1 4 68 SFLU DTE OP~4~ 100620 O0 000 O0 0 4 1 1 4 68 SP DTE MV 100620 O0 000 O0 0 4 1 1 4 68 GR DTE GAPI 100620 O0 000 O0 0 4 1 1 4 68 TENS DTE LB 100620 O0 000 O0 0 4 1 1 4 68 MTEM DTE DEGF 100620 O0 000 O0 0 4 1 1 4 68 ~4RESDTE OH~4 100620 O0 000 O0 0 4 1 1 4 68 HTEN DTE LB 100620 O0 000 O0 0 4 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 7448.000 CIDP.DTE 1783.875 IDPH.DTE 0.561 CIMP.DTE IMPH. DTE 1.189 CILD.DTE 1736.438 ILD.DTE 0.576 CILM. DTE ILM. DTE 0.926 IFRE. DTE 20.000 IDQF.DTE 0.000 IMQF.DTE IIRD.DTE 1018.469 IIXD.DTE -721.031 IIRM. DTE 961.000 IIX~.DTE SFLU. DTE 2.468 SP.DTE -54.070 GR.DTE 88.078 TENS.DTE MTEM. DTE 111.875 ~RES.DTE 0.746 HTEN. DTE 304.504 DEPT. 7642.000 CIDP.DTE 172.609 IDPH.DTE 5.791 CIMP.DTE IMPH. DTE 5.080 CILD.DTE 173.133 ILD.DTE 5.774 CILM.DTE ILM. DTE 5.387 IFRE. DTE 20.000 IDQF.DTE 0.000 IMQF. DTE IIRD.DTE 150.875 IIXD.DTE 16.957 IIRM.DTE 174.938 IIX~.DTE SFLU. DTE 3.902 SP.DTE 10.377 GR.DTE 92.953 TENS.DTE MTEM. DTE 120.188 ~4RES.DTE 0.647 HTEN. DTE 353.922 897.000 1080.625 0.000 -1067.125 966.688 196.639 185.906 0.000 -13.250 1010.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE : 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH DTE 7448.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TDDRILLER (FT): STOP DEPTH .......... 7050.0 TD LOGGER (FT) '. TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 29-NOV-96 CP44.2 300 29-NOV-96 1030 29-NOV-96 8154.0 7050.0 7962.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DTE RESISTIVITY CART. DIC-EC-44 AMS AUX. MEASURMENT CART. AMS 774 GR GA~4MA RAY SGC-SA-404 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): 6.750 7448.0 7453.0 LSND 13.70 50.0 9.1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 14 MAXIMO?~ RECORDED TE~IPERATURE (DEGF) : 126.0 RESISTIVITY (OIqMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (PIT): 1. 420 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 961 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 920 MUD CAKE AT (BHT) : 56.0 58.0 58.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL WITH MARKED E-LINE. RAN DITEW/O CENTRALIZATION DUE TO HOLE SIZE. LOG DEPTHS REFERENCED TO NORDIC 2 RIG DEPTHS. LOGGED GR UP TO 7100' TO SHOW TIE-BACK TO LWD LOG. SAT DOWN AT 7955' ON INITIAL DOWN LOG. II~4EDIATELY LOGGED BACK UP INTO CASING DUE TO HOLE PROBLEMS. TRIED TO LOG DOWN AGAIN BUT COULDN'T GET BELOW 7550'. CANCELED FURTHER LOGGING. DOWN LOG USED AS REPEAT SECTION THIS FILE CONTAINS THE RAW MAIN PASS GR ACQUIRED UP INTO CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 15 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100620 O0 000 O0 0 5 1 1 4 68 0000000000 GR DTE GAPI 100620 O0 000 O0 0 5 1 1 4 68 0000000000 TENS DTE LB 100620 O0 000 O0 0 5 1 1 4 68 0000000000 HTENDTE LB 100620 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 7448.000 GR.DTE 113.813 TENS.DTE 3060.000 HTEN. DTE DEPT. 7050. 000 GR.DTE 105. 250 TENS.DTE 3010. 000 HTEN. DTE 523.500 507.750 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE : 97/01/14 MA3fREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION ' O01CO1 DATE · 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CASED HOLE REPEAT PASSES Curves and log header data for each pass in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 16 PASS NUMBER: 1 DEPTH INCREMENT'. 0.5000 FILE SUf~4ARY VENDOR TOOL CODE START DEPTH DTE 743 O. 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 7448.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DTE RESISTIVITY CART. AMS AUX. MEAS~T CART. GR GA~CzA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) '. BOREHOLE CONDITIONS MUD TYPE'. MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MA TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) 29-NOV-96 CP44.2 300 29-NOV-96 1030 29-NOV-96 8154.0 7050.0 7962.0 TOOL NUMBER DIC-EC-44 AMS 774 SGC-SA-404 6. 750 7448.0 7453.0 LSND 13.70 50.0 9.1 126.0 1. 420 56.0 O. 961 58.0 1. 920 58.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 17 REMARKS: USED PRIMARY DEPTH CONTROL WITH MARKED E-LINE. RAN DITE W/O CENTRALIZATION DUE TO HOLE SIZE. LOG DEPTHS REFERENCED TO NORDIC 2 RIG DEPTHS. LOGGED GR UP TO 7100' TO SHOW TIE-BACK TO LWD LOG. SAT DOWN AT 7955' ON INITIAL DOWNLOG. I~fl~zEDIATELY LOGGED BACK UP INTO CASING DUE TO HOLE PROBLEMS. TRIED TO LOG DOWN AGAIN BUT COULDN'T GET BELOW 7550'. CANCELED FURTHER LOGGING. DOWN LOG USED AS REPEAT SECTION THIS FILE CONTAINS THE RAW REPEAT DATA ACQUIRED INTO CASING. THIS DATA WAS ACQUIRED LOGGING DOWNHOLE. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100620 O0 000 O0 0 6 1 1 4 68 0000000000 GR DTE GAPI 100620 O0 000 O0 0 6 1 1 4 68 0000000000 TENS DTE LB 100620 O0 000 O0 0 6 1 1 4 68 0000000000 HTENDTE LB 100620 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JAN-1997 13:21 PAGE: 18 ** DATA ** DEPT. 7430. 000 GR.DTE DEPT. 7448.000 GR.DTE 67. 703 TENS. DTE 88.078 TENS.DTE 1057.063 HTEN. DTE 966.688 HTEN. DTE 365. 177 304.504 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION ' O01CO1 DATE · 97/01/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/01/14 ORIGIN : FLIC TAPE NAME : 97014 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT · ARCO ALASKA INC, 3J-17, KUPARUK, API #50-029-22700-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 97/01/14 ORIGIN : FLIC REEL NAME : 97014 CONTINUATION # : PREVIOUS REEL : COI¢~4ENT : ARCO ALASKA INC, 3J-17, KUPARUK, API #50-029-22700-00
