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The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϱϮϮϲϬͲ^Ğƚ͗ϯϲϭϴϯJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 C:\Users\aebell\Desktop\November 2021 Data Drop\CPA Data Drop 11042021\2021-11-03_20184_KRU_3F-02_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20184 KRU 3F-02 50-029-21447-00 Caliper Survey 03-Nov-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM Abby Bell PTD: 1852260 E-Set: 35915 C:\Users\aebell\Desktop\November 2021 Data Drop\CPA Data Drop 11022021\2021-10-30_20183_KRU_3F-02_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20183 KRU 3F-02 50-029-21447-00 Coil Flag 30-Oct-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM Abby Bell 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7864'4452 7699' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Packer: Baker FHL Packer Packer: 7101' MD and 5710' TVD Packer: Baker FHL Packer Packer: 7173' MD and 5766' TVD Packer: Baker FB-1 Packer Packer: 7434' MD and 5969' TVD 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned James Ohlinger Contact Name:Shane Germann Staff CTD Engineer Contact Email:shane.germann@conocophillips.com Contact Phone:907-263-4597 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 9/27/2021 3-1/2" 3468' 7839' Perforation Depth MD (ft): 7270'-7390', 7561'-7602', 7624'- 7666' 7804' 110' 3505' 6283'7" 16" 9-5/8" 72' 110' 3084' 6213' L-80 TVD Burst 7141' MD 6303' 185-226 PO Box 100360, Anchorage, AK 99510 50-029-21447-00 ConocoPhillips Alaska, Inc. Length Size KRU 3F-02 Kuparuk River Oil Field/ Kuparuk River Oil Pool 7750' 5841'-5934', 6067'-6099', 6116'-6149' Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0025643 None COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): Perforate Repair Wepair Well Exploratory Stratigraphic Development Serviceee ty BtyOP TesssttMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 9:54 am, Sep 17, 2021 321-479 Digitally signed by James Ohlinger DN: CN=James Ohlinger, O=ConocoPhillips, OU=CTD, E=James.J.Ohlinger@conocophillips.com, C=US Reason: I am the author of this documentLocation: your signing location here Date: 2021.09.16 12:18:23-08'00' Foxit PDF Editor Version: 11.0.0 James Ohlinger 10-404 XSet whipstock/CTD Setup DSR-9/17/21VTL 9/22/21 Rig work not included in this sundry -00 DLB XX DLB 09/17/2021 dts 9/24/2021 JLC 9/24/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.24 16:06:24 -08'00' RBDMS HEW 9/27/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 16, 2021 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to cement squeeze into the 3-1/2” x 7” annulus between the C-sand straddle packers in KRU 3F-02 (PTD #185-226) in order to drill one CTD lateral using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in early-November 2021 , though pre-rig work is planned to begin in late September. The CTD objective will be to drill one lateral, KRU 3F-02L1, targeting the Kuparuk A-sand interval. Attached to this application are the following documents: 10-403 Sundry Application for KRU 3F-02 Operations Summary in support of the 10-403 sundry application Current Schematic Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, Shane Germann ConocoPhillips Alaska Coiled Tubing Drilling Engineer Digitally signed by Shane Germann DN: O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@cop.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.16 12:12:17-08'00' Foxit PDF Editor Version: 11.0.0 Page 1 of 1 9/16/2021 KRU 3F-02 (PTD #185-226) CTD Summary for Sundry Steps in bold apply to sundry application (pumping cement plug) Summary of Operations: KRU well 3F-02 is equipped with 3-1/2” tubing and two packers straddling the C-sand interval in 7” production casing. The CTD sidetrack will utilize one lateral to target the A-sands to the south of 3F-02. Prior to setting the whipstock, a cement plug will be squeezed into the 3-1/2” x 7” annulus between the C-sand straddle packers to mechanically stabilize the tubing while milling a window during CTD operations. A 3-1/2” whipstock will then be set at ~7400’ MD to facilitate milling a window in 3-1/2” tubing and 7” casing. CDR3-AC will mill a window in the 3-1/2” tubing and 7” casing at ~7400’ MD and the 3F-02 lateral will be drilled to TD at 11,650’ MD, targeting the A-sands to the south. It will be completed with 2-3/8” slotted liner, solid liner with a swell packer, and a seal-bore assembly from TD up to ~7395’ MD. Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3F-02 was measured at 2489 psi @ 5980’ TVD (8.00 ppg) on 4/25/2018. The maximum downhole pressure in the 3F-02 vicinity is 3F-03 at 5037 psi and 6200’ TVD (15.62 ppg – SWHP 8/16/2019). Using the maximum formation pressure in the area at 5037 psi in 3F-03 (i.e. 15.62 ppg EMW), the maximum potential surface pressure in 3F-02, assuming a gas gradient of 0.1 psi/ft, would be 4452 psi. CTD Pre-Rig, CTD Drill and Complete, & Post Rig 3F-02 Operations: Pre-CTD Work (bold applicable to Sundry Application – other steps for reference) 1. Pre-CTD diagnostics 2. Slickline: Pull TPC sleeve from AVA nipple, set plug, bail sand on top of plug 3. CTU: Pump cement (fill IA within C-sand straddle packers), mill cement 4. Slickline: C/O GLV’s, dummy whipstock drift 5. E-Line: Run caliper, set whipstock at 7400’ MD Rig Work (for reference) 1. MIRU Nabors CDR3-AC rig using 2” coil tubing. NU 7-1/16” BOPE, test. 2. Drill 3F-02L1 Lateral (A-sand - South) a. Mill 2.80” window at ~7400’ MD. b. Drill 3” bi-center lateral to TD of 11,650’ MD. c. Run 2Ǫ” slotted liner, solid liner with swell-packer, & seal-bore assembly from TD up to ~7395’ MD (into tubing string) 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work (for reference) 1. Set liner-top packer 2. Return to production Work not approved with this sundry VTL 9/22/21 3F-02 Proposed CTD Schematic 3-1/2" Camco DS nipple @ 508' MD (2.875" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 2721', 4502', 5604', 6465', 7015' Baker 80-40 PBR @ 7077' MD (4.0" ID) Baker FHL packer @ 7107' MD (2.9" ID) 3-1/2" Camco DS nipple @ 7122' MD (2.812" min ID) Baker PB Overshot @ 7134' MD Baker PBR @ 7160' MD (3.0" ID) Baker FHL packer @ 7173' MD (3.0" ID) 3-1/2" Camco gas lift mandrels @ 7211' MD AVA BPL Landing Nipple @ 7419' MD (2.75" ID) Baker FB-1 packer @ 7434' MD (3.0" ID) Baker SBE @ 7437' MD Camco D nipple @ 7449' MD (2.25" min ID, No-Go) 3-1/2" SOS @ 7456' MD 9-5/8" 36# J-55 shoe @ 3505' MD 7" 26# J-55 shoe @ 7839' MD 16" 62# H-40 shoe @ 110' MD A-sand perfs 7561' - 7666' MD KOP @ 7400' MD C-sand perfs 7270' - 7390' MD Modified by SJG 9/16/21 3F-02L1 wp03 TD ~ 11650' MD Top of Liner ~ 7395' MD • • 5 2-So WELL LOG TRANSMITTAL#904203421 To: Alaska Oil and Gas Conservation Comm. January 26, 2018 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 DATA LOGGG Anchorage,Alaska 99501 r Z'�si2o1 ER g � F'EB Q i 1 2018 K.BENDER AOGCC RE: Leak Detect Log with ACX: 3F-02 Run Date: 7/31/2017 Re-Submit: E-Set# 28909 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 FRS_ANC@halliburton.com 3F-02 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21447-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-275-2605 KAMM _ o FRS ANC@halliburton.com Date: Signed: 07 �.asrcl, 6,e4teat 2.2Cc • • 2\ocl WELL LOG TRANSMITTAL#904203421 To: Alaska Oil and Gas Conservation Comm. November 7, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA/ LL�QQGG�ED Z/201 Anchorage, Alaska 99501 RECEIVED K BENDER DEC 222017 RE: Leak Detect Log: 3F-02 A�Gt✓ Run Date: 7/31/2017 Gl C 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 3F-02 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21447-00 Leak Detect Log (Processed Log) 1 Color Log 50-029-21447-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 SCANNED k FRS_ANC@halliburton.com Date: Signed:7124 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ,,~C~" _ ~:~_~_~ Well History File Identifier Organization (uo.e) ~/'Two-Sided RESCAN Color items: Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/TYpe OVERSIZED (Scannable) r~ Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds n Other TOTAL PAGES:(~ ~''~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL ~LOWELL Project Proofing By: Date: PROOFED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl PAGES: ~'7~ (at the time of scanning) SCANNED BY-' ~EVERLY BREN VINCENT~MAR~ LOWELL RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: ~)/~'~ °C~/O ! DATE: Isl Quality Checked (done) III Rev1 NOTScanned.wpd • • oF 7. ew ` \ \I %%y THE STATE Alaska it and aS E a I r: OfA LAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue p"*Tnnr. , Anchorage, Alaska 99501 -3572 ALAS Y' e Main: 907.279.1433 Fax: 907.276.7542 SCANNED JAN 2 3 2013 Jonathan Coberly Wells Engineer g j ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3F -02 Sundry Number: 312 -463 Dear Mr. Coberly: 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, Daniel T. Seamount, Jr. Commissioner DATED this /day of December, 2012. Encl. STATE OF ALASKA COL 4 4 � KA OIL AND GAS CONSERVATION COM ION I 1 • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell - Change Approved Rogram r Suspend r Rug Perforations r Perforate I Rill Tubing )✓ Time Extension r O Operational Shutdown Re -enter Sus We ll .� p r p• St r Al ter casing � Other: � trr � � -•- � ` �� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 185 -226 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21447 - 00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No Fi 3F -02 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25643 • 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): 7864 - 6303 • 7750' 6213' 7445' 7699' . Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 3468 9.625 3505' 3084' RECEIVED PRODUCTION 7804 7 7839' 6283' DEC 0 6 201<<, 07,5 lam!r2 (rz, AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7270' 7390', 7561' 7602', 7624' - 7666' 5841' 5934', 6067' 6099', 6116' - 6149' 3.5 J - 55 7457 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 7168 TVD= 5762 • PACKER - BAKER FB -1 PACKER MD= 7428 TVD= 5964' SSSV - CAMCO TRDP -1A -SSA MD =1858 TVD =1820 12. Attachments: Description Summary of Roposal 17., 13. Well Class after proposed work: Detailed Operations Program BOP Sketch J" Exploratory r Stratigraphic r Development f • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/26/2013 • Oil P, Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WNJ 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: Jonathan Coberly © 265 -1013 Email: Jonathan .Coberlv(caconocophillips.com Printed Name Jonathan Cobe I Title: Wells Engineer Signature 17;i- Phone: 265 -1013 Date t2 - 5.-it. Commission Use Only Sundry Numbelf � 4/ ^ 3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test /Mechanical Integri Test r Location Clearance r s,F ? D :, zO+c'' Test- NitM °� Other: MS D 13 201 Spacing Exception Required? Yes ❑ No [/J Subsequent Form Required: ` -L f �� APPROVED Y /Z / /Z./ C J Approved by: � COMMISSIONER THE COMMISSION Date: `/ tt 11►► lll �� - ppr - • • app Ica ion is va i • or mon s rom e •• a e o approva . r 0 FI1G1(I�fs�U1tY2012) ! • , L Submit Form and Attachments in Duplicate ( ��\ • • December 4, 2012 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Producer 3F -02 (PTD 185 -226). 3F -02 was originally completed in 1985 as a single selective A and C sand producer that is producing via gas lift. It has been produced through both zones through most of the well's history from 1985 until early 2010 when it was converted to a Kuparuk A -sand only producer. In November 2011 the well was shut in due to leaks in the tubing and surface casing. Before the shut in, the Kuparuk A -sand was producing 60 stbd of oil with a water cut of 74 %. This well has not had a workover throughout the life of the well. The leak in the surface casing at 862' MD was found on 10/27/2011 and additional leaks were found in the tubing between 4,469' MD and 4,504' MD on 11/5/2011. A CMIT TxIA on 12/3/2011 passed. The objective of this workover is to pull the 3 V2" completion tubing, cut and pull the 7" production casing from the top of cement, install and cement new 7" production casing from the top of cement, and run a new 3 ''h" gas lift completion. If you have any questions or require any further information, please contact me at 265 -1013 or Jonathan.Coberly@conocophillips.com. Sincerely, Jonathan Coberly Wells Engineer CPAI Drilling and Wells • • 3F -02 Rig Workover, Tubing and Surface Casing Repair (PTD #: 185 -226) Current Status: Kuparuk well 3F-02 was a single selective A and C sand producer. In 2010 the well was converted to a Kuparuk A -sand only producer, by closing the selective. The well is currently shut in. It has leaks in the tubing and surface casing. Scope of Work: Pull 3 '/2" completion tubing, cut and pull 7" casing from TOC, install and cement new 7" casing from TOC, and run new gas lift completion. General Well info: MASP: 2,152 psi (using 0.1 psi /ft gas gradient) Reservoir pressure/TVD: Kuparuk C -Sand — 2,690 psi / 5,888' TVD (8.8 ppg EMW) measured 7/22/10. Kuparuk A -Sand — 2,750 psi / 5,976' TVD (8.9 ppg EMW) measured 7/23/10. Wellhead type /pressure rating: FMC Gen III, 7 1 / 16 " 5M top x 11" 3M bottom Nordic 3 BOP configuration: Annular / 7" Pipe Rams / Blind Rams / Mud Cross / Variable Pipe Ram MIT results: CMIT TxIA — Passed 12/3/2011 MIT -T — Failed 11/5/2011 Well Type: Producer Estimated Start Date: January 26, 2013 Production Engineers: Evan Riley / Jeremy Mardambek Workover Engineer: Jonathan Coberly (265 -1013 / Jonathan.Coberly @conocophillips.com) Proposed Pre -Rig Work: Slickline 1. RU SL. 2. RIH and pull catcher at 7,412' RKB. 3. RIH to 7,413' RKB and pull AVA 2.75" BPI sleeve. POOH. 4. RIH and pull plug at 7,443' RKB. Allow tubing pressure to stabilize. RIH w/ dual Panex gauges and obtain the combined Kuparuk A &C Sand SBHP. POOH. 5. RIH and set CA -2 plug in 2.25" ID `D' nipple at 7,443' RKB. POOH. 6. RIH to 7,413' RKB and install BPI sliding sleeve. POOH. 7. CMIT TxIA to 3,500 psi. 8. RIH and set catcher in 2.75" ID landing nipple at 7,413' RKB. POOH. 9. Pull 1.5" DV in GLM #9 at 7,105' RKB. Leave GLM open. POOH. 10. Install 1" DV in GLM #3 at 4,528' RKB. POOH. 11. RDMO SL. Other 1. Pressure test the tubing and casing packoffs. Function test the lock down screws. 2. Set BPV within 24 hours prior to rig arrival. Proposed Procedure: 1. MIRU. Pull BPV. Circulate 9.3 ppg brine around until 9.3 ppg brine returns at surface. SI and monitor well for 30 min. Record S1TP & SICP, verify well is dead. If pressure is observed on surface, calculate new KWF and repeat and circulate until well is dead. 2. Set BPV & blanking plug. Pressure test the IA to 1,000 psi to test the BPV from below. ND tree. Install blanking plug and NU BOPE. Test BOPE to 250/3,500 psi. 3. Pull blanking plug & BPV. MU landing joint, BOLDS, and unland tubing hanger. 4. POOH laying down tubing spooling up control line. If tubing does not pull: RU E -Line, RIH and fire string shot at 7,129' RKB, POOH, RIH w/ RCT and cut tubing at 7,129' RKB, POOH, RD E -Line, POOH w/ tubing laying down tubing. • • 5. RIH on drill pipe w/ 7" casing scraper. Cleanout casing to PBR. POOH standing back drill pipe. 6. RU E -line. RIH w/ gyro, caliper, and CAST -M logging tools individually. Log each from PBR to surface. Locate TOC. RIH and fire string shot at the second collar above the TOC. POOH. RD E -Line. 7. RIH on drillpipe and set a RBP --500' below the TOC. PT RBP to 3,000 psi. Drawdown test to 0 psi. Dump 50' of sand on top of RBP. POOH standing back drill pipe. 8. ND BOP. ND tubing head utilizing Hydratight Tensioner. Allow casing to grow. Spear the 7" casing and re -land it in the slips. Cut off excess casin w/ Wachs cutting tool. Ta weld the slips to the casing. NU BOP to the casing head. 34" a s , ( f kcJe . ) 9. RIH w/ 5 %2" Multi- String Cutter on drillpipe. Cut the 7" casing in the middle of the second full casing joint above the TOC. POOH standing back drillpipe. 10. Reverse circulate out the Arctic Pack from the OA with heated diesel and seawater. 11. Spear the 7" casing and POOH laying down the casing. 12. Set a test . lu ! in the casin ! head and pressure test to 250/3 000 • si. (Test pressure is limited by 11" 3M r casing head.) 13. RIH w/ 9 %" casing scraper to the top of the cut casing. Circulate well clean. POOH standing back drillpipe. 14. RIH w/ tandem string mills to gauge the casing for the ES cementer. POOH standing back drillpipe. 15. RIH w/ the dummy drift assembly for the ES cementer. POOH standing back drillpip. 16. RIH w/ the backoff tool to the top of 7" casing stub. Engage the stub and backoff. POOH standing back drillpipe. 17. RIH w/ 7" casing spear on drillpipe. Retrieve the 7" casing stub. POOH standing back drillpipe. 18. RU casing crew. RIH w/ new 7" TC -II casing and ES cementer. Screw into top of 7" casing. Pressure test casing to 3,000 psi. .4 ? 19. RU SLB cementers. Pressure up the casing to 3_,500 psi to open the ES cementer. Cement the 7" x 9 5 /8" annulus to surface. Pump closing plug to close ES cementer. Pressure test the cement plug to 1,500 psi. WOC. 20. ND BOPE. Pull 7" casing in tension and land in the slips. Cut excess casing off with the Wachs cutting tool. Install casing head packoff. NU pew ttatiglaad and BOP. Install BPV and blanking plug. Pressure test BOP to 3,5 psi. Pull BPV. 21. RIH w/ 6 ' /g" mill tooth bit to TOC. Mill up cement, closing plug, and ES cementer. POOH standing back drillpipe. 22. Pressure test the casing to 3,500 psi/Chavf ' 3 23. RIH w/ 6 ' /8" concave mill and mill any remaining debris from top of sand. POOH standing back drillpipe. 24. RIH w/ wash string assembly and circulate out sand on top of the RBP. POOH standing back drillpipe. 25. RIH w/ RBP retrieving head to top of plug. Engage RBP and pull to release. POOH laying down drillpipe. 26. If needed, RIH w/ an overshot fishing assembly. Latch on to the tubing stub and jar the seal assembly free from the PBR. TOOH standing back drillpipe. LD fish. 27. RIH w/ new 3 ' /2" gas lift completion to just above the PBR. Engage the PBR until fully located. Space out 3' off of bottom. Mark the pipe and pull out of the PBR. 28. Space out w/ pups. MU hanger. Swap the well over to corrosion inhibited seawater. Land the hanger../ RILDS. 29. Pressure test the tubing to 3,000 psi. Bleed tubing to 2,500 psi and test IA to 3,500 psi for 30 minutes. Record test on a chart. Bleed the IA to zero. Bleed the tubing to zero. Pressure up the IA quickly to shear the SOV. Bleed tubing and IA to 0 psi. 30. Pull the landing joint and install a BPV. Pressure test from below to 1,000 psi. Bleed IA to 0 psi. Monitor well for flow. 31. ND BOP. NU and test tree. Pull BPV. Install test tree plug. Pressure test the tubing hanger packoff to 250/5000 psi. 32. Remove the test tree plug. 33. Freeze protect the well with diesel to 2,000' TVD through the SOV. Set BPV. 34. RDMO. • • Proposed Post -Rig Work: 1. Pull BPV. 2. RU Slickline: a. Pull the SOV from the bottom GLM #5 and replace w/ a DV. b. Pull catcher sub at 7,412' RKB. c. Pull BPI sleeve at 7,413' RKB. Leave Kuparuk C -Sand open. d. Pull plug at 7,443' RKB. 3. Reset well house(s) and flowlines of adjacent wells. 4. Turn well over to Operations. • • CornocoPhillips Well: 3F -02 2013 RWO PROPOSED COMPLETION API: 500292144700 • Conductor: .4] L PTD: 185-226 16 ", 62.5 #, H-40 to 110' I Wellhead: FMC Gen IV or FMC Gen III X -mas Tree: 3 -1/2 ", 5K psi Ds Surface Casing: Lift Threads: 3 -1/2" 8rd EUE 9.625 ", 36.0 #, J -55 BTC to 3,500' BPV: 3" 'ISA' Proposed 3 Completion J Production Casing: • Tubing, 3'/2', 9.3 ppf, L -80, I 7 ", 26.0 #, J -55 BTC to 7,837' 8rd EUE. J • 2.875" ID 'DS' Nipple at 500' MD. Perforations: 1 MD Zone • PBR at 7,154' MD I \ 7,270' - 7,390' Kuparuk C 1 -4 pi e a 7,561' - 7,602' Kuparuk A 3 -4 • Packer, Baker FHL Retrievable ] d _ 7,570' - 7,600' Kuparuk A 3 Packer at 7, 168' MD. 7,624' - 7,666' Kuparuk A 2 • 1" CAMCO GLM w/ DV at 7,206' MD J 2.875" ID 'DS' Nipple at 500' MD • Sliding Sleeve at 7,413' MD (closed). • 2.75" ID Landing Nipple at 7,413' MD. V 1 - PBR at 7,154' MD • Permanent Baker FB -1 Packer at 7,428' MD. 4 - Baker FHL Retrievable Packer at 7,168' MD • 2.25" ID 'D' Nipple at 7,443' MD. j 4-- CAMCO 1" GLM w/ DV at 7,206' MD • 2.438" ID SOS at 7,450' MD. _ - ss 4 - Sliding Sleeve at 7,413' MD (Closed) NIP 4 - 2.75" ID Landing Nipple at 7,413' MD Gas Lift Mandrels: 1∎00IK Baker Permanent FB -1 Packer at 7,428' MD Type MD TVD ,..... MMG, 1.5" 2,725' 2,503' 'r= MMG, 1.5" 4,508' 3,800' D 4- 2.25" ID 'D' Nipple at 7,443' MD MMG, 1.5" 5,610' 4,600' sos 4- 2.438" ID SOS at 7,450' MD MMG, 1.5" 6,450' 5,218' - - MMG, 1.5" 7,111' 5,718' - - Directional: - - Max Incline: 45.7° @ 3800' - . Max Dogleg: 4.7° @ 1700' :3: <: : :::i: I :/ k 4___ Fish (50% of Grapple and Wire) at 7,699' MD Fill at: 7,684' MD Last Updated: 5- Dec -12 TD: 7,864' RKB Updated by: JRC , . KUPr 3F -02 . ConocoP11llips f °� a. , Well Attributes Max Angie & MD TO Alaska, Inc ", °l; Wellbore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Coxxs9TVipp, ltil 500292144700 KUPARUK RIVER UNIT PROD 45.70 3,800.00 7,864.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• W611 ConMl: -3F 10/17/2012 1 059:31 AM SSSV: Flapper Locked Out 140 1/24/2011 Last WO: 41.00 10/3/1985 Schematic • Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date ° Last Tag: SLM 7,651.0 7/17/2010 Rev Reason: WELL REVIEW osborl 10/17/2012 Casing Strings HANGER, 33 ?' Casing Description String 0.. String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD)... String Wt... String ... String Top Thrd ' ' CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H - 40 WELDED 4 II Casing Description String 0 String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd I SURFACE 95/8 8.921 37.0 3,504.5 3,084.1 36.00 J BTC ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) .. String Wt String ... String Top Thrd CONDUCTOR, PRODUCTION 7 6.276 35.0 7,839.2 6,283.4 26.00 J-55 BTC 36.110 t Tubing Strings III '(W Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1. ,, Set Depth (TVD) ... String Wt... String ... String Top Thrd SAFETY VLV, TUBING 3 1/2 I 2.992 I 33.1 7 ,456 . 7 5,986 J 9.30 I J -55 I EUE 8RD 1.659 /A Completion Details Top Depth GAS LIFT, (TVD) Top Inc! Nomi... 2,423 Top (ftKB) (ftKB) ° Item Dea cription Comment !D (in) 33.1 33.1 11 - 0.02 HANGER FMC TUBING HANGER 3.500 1,858.2 1,820.2 29.85 SAFETY VLV Locked out Flapper only 5/25/98. 2.813 7,159.6 5,755.5 39.33PBR BAKER PBR TRDP -1A -SSA. 3.000 SURFACE, A A. 7,173.3 5,766.1 39.29 PACKER BAKER FHL PACKER 3.000 37 - 3,505 7,249.1 5,824.8 38.91 BLAST JT RICKERT BLAST JOINTS (5) 2.992 GAS LIFT, 7,418.9 5,957.1 39.33 NIPPLE AVA BPL LANDING NIPPLE 05B 2.750 III 7,431.9 5,967.2 39.32 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT, 4,533 7,433.7 5,968.6 39.31 PACKER BAKER FB-1 PACKER 3.000 7,437.1 5,971.2 39.31 SBE BAKER SEAL BORE EXTENSION 4.000 7,441.4 5,974.5 39.30 XO- Reducing 3.5 "x2.875" 2.441 7,448.6 5,980.1 333939...233901 9.29 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,456.0 5,985.8 39.28 SOS CAMCO SHEAROUT SUB 2.438 GAS LIFT, Other in Hole ireiine retrievable plugs, valves, pumps, fish, etc) . 4.973 Illr Top Depth at (TVD) Top Inc! GAS LIF7, Top (508) (ftKB) ( °) Description Comment Run Date ID (in) 5 ,427 ir. 7,413.0 5,952.6 39.34 CATCHER 2.79" CATCHER (OAL =36 ") 11/16/2011 0.000 it 7,418.9 ' 5,957.1 39.33 SLEEVE -C AVA 2.75" BPI sleeve 7/23/2010 2.310 GAS 5!8 0 7,445.0 5,977,3 39.30 PLUG 2.25" CA -2 PLUG 11/16/2011 0.000 illi 7,699.0 6,174.3 38.93 FISH 50% of Grapple 8 Wire Still in hole from 4/1/94 4/2/1994 0.000 GAS LIFT, IF 6,293 Ira, Perforations & Slots Shot GAS LIFT, x Top (TVD) Btm (TVD) D Dens 6,731 Top (ftKB) Mtn (ftKB) (ftKB) (ftKB) Zone Date (.h... Type Comment It GAS LIFT, 7,270.0 7,390.0 5,841.1 5,934.4 C-4, C-3, C -2, 11/30/1985 12.0 IPERF 5" Csg Gun; 120 deg ph 7,110 ir C -1, 3F -02 7,561.0 7,602.0 6,067.2 6,098.9 A-4, A -3, 3F -02 11/30/1985 4.0 IPERF 4" Csg Gun; 90 deg ph 7,570.0 7,600.0 6,074.1 6,097.4 A -3, 3F -02 4/10/1998 4.0 RPERF 2 1/8" Enerjet Bighole; 0 deg ph, 0 PBR, 7,160 { deg orient PACKER, 7,173 7,624.0 7,666.0 6,116.0 6,148.7 A -2, 3F -02 11/30/1985 4.0 IPERF 4" Csg Gun; 90 deg ph at Notes: General & Safety PRODUCTION, End Date Annotation 7,211 4/21/2006 NOTE: 6'1" EXTERNAL CSG PATCH FROM 12 BELOW CONDUCTOR TOP TO 18' 1" ar 5/31/2007 NOTE: LEFT HALF OF PM RETAINER RING FOUND @ 3.5 GU ADAPTER IN HOLE IPERF. 7/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7,270 8/1/2010 NOTE: EL LDL found Leak @ 4614' CATCHER. 7.413 SLEEVE -C, 7,419 " NIPPLE, 7,419 PACKER, 7,434 F SBE, 7,437 it PLUG, 7,445 IL NIPPLE, 7,449 11 505, 7,456 Mandrel Details Top Depth Top Port IPERF, (TVD) Inel OD Valve Latch Size TRO Run 7,561 - 7.602 \ Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com,.. RPERF, \ 1 2,422.9 2,276.1 40.59 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/14/2011 7,570 - 7,600 2 3,880.1 3,354.8 45.62 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/14/2011 3 4,533.3 3,818.2 43.75 CAMCO KBUG 1 GAS LIFT OPEN 0.000 0.0 11/16/2011 IPERF. _ 4 4,972.7 4,136.0 43.46 CAMCO KBUG 1 GAS LIFT DMY BK 0,000 0.0 10/22/1994 7,624 - 7,666 • 5 5,427.4 4,466.8 43.10 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 FISH, 7,699 Z 6 5,859.8 4,782.4 43.01 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 7 6,292.9 5,100.5 42.03 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/22/1994 I 8 6,730.6 5,428.1 41.06 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 9 7,110.5 5,717.6 39.47 MERLA TPDX 1 1/2 GAS LIFT DMY RM 0.000 0.0 7/30/2010 PROD 36 - \\ 10 7,211.4 5,795.5 38.91 CAMCO KBUG 1 PROD DMY RM 0.000 0,0 4/13/1998 TD, 7,664 r * • • 3 1/8 -5000 (9-35) I 4 )'' Ili:1 ":--- - -,:iai ( .I :I. '° A �� 7 I /16 -5000 (R -461 .' 111 d 1111 I ., _ ' 11 'N ; n � it 0 pry 5439 I :II I I . II III �� —U- .I I . � CIC ( .�.I .1 I; 1,A0 I I I % :I © Y I — —1I rin " 4159 0 1111 ! i ; 1U r :�illa:a I: 11 -3 000 (9-53) 19 A ,{. 30.00 1U1 ili 1. _ < 1�1 1 — 1 1925 0 I �: , II O � �I • i ■ .1 1 O lire' J 1_ I I �I I. .II �� 11� I iI I I 1 r A. i 1 .I I �`NI 1 t I © i 3.60 it - --_____! i _ _ 521 I __ � DA/EATER HEAD • 19-100 -230 1 /6" OD y %� 9 5/8' 0D C50 I `v , \ 7"00 CSG 1 �31 /2TBG ARCO ALASKA INC. *TWA,' UK FIELD) I I TEMIIPART NUMBER ll DESCRIPTION I 13 -140 -660 LA140100 RING.16 C -2 5. 0. Ln 0 3 13- 300 -4490 CA IN C HD 4 H OR, 5. 1fl3/4fB 656 x 0 II -3K W/ 2 I /(6-30 sroo OUT O 4 12 090 SLIT BIM ASST. II % 7 REF: 59 -10925 _ O 83- 600-6270 TUBING HD ASS'( TCM- 6T.9 - BG BIM 11 1i16 -SK W/ 2 I /16 -SK DUT'S PM.. o•�E O B 02-043 -61A 6 83 160 - 336 1/UCER BUSH INS, 00.9 % 7 8 0 1 A_4 5K X 3 I/8 -5K -EN, 16 15116X3 0EUE, 15 -A WELLHEAD SYSTEM, W•E a 99 m,,,, O BTM PREP F/ 5095 EN SLICK HGR GEN. IV KUPARUK � , '"°" o 9 12-140 -212 RACKOFF 4551.0 -15.11 X 1 EQUIPMENT _ :se dsvu -.- O ::: 01i9 n DOODD141000549 STATE OF ALASKA ALASKA OIL ND GAS CONSERVATION COMMISSIO. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell 17 Rug Perforations fl Stimulate [Other in Install Patch Alter Casing fl Rill Tubing fl 1 rforate New Pool r Waiver [n Time Extension Change Approved A - ogram ri Operat. Shutdow n [j Perforate [j Re -enter Suspended Well El 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pJ Exploratory f Q 185 - 226 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service r - 50 Or" 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025643 ` .i 3F -02 9. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil. Pool )' 10. Present Well Condition Summary: Total Depth measured 7864 feet Plugs (measured) None true vertical 6303 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7168 true vertical 0 feet (true vertucal) 5762 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 3468 9.625 3505 3084 3520 2020 PRODUCTION 7804 7 7839 6283 4980 4330 ' I t i Perforation depth: Measured depth: 7270 - 7390, 7561- 7602, 7570- 7600, 7624 -7666 F-'. 0 4 IMP True Vertical Depth: 5841 -5934, 6067 -6099, 6074 - 6097, 6116 - 6149 zEn" ' g g. G Cus s Cr 'SSiot1 Tubing (size, grade, MD, and TVD) 3.5, 9.3 PPF, J -55, 7451 MD, 5982 TVD WFT 1.750" ID ER PATCI bMU 96 - 4620 Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 7168 MD and 5762 TVD SAFETY VLV - CAMCO TRDP - IA - SSA WITH Locked out Flapper @ 1852 MD and 1815 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil 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 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory [ Development J' Service 17 Stratigraphic r 15. Well Status after work: t Oil J Gas fl WDSPL Daily Report of Well Operations X GSTOR r WIND r WAG n GINJ r SUSP r SPLUG r 16. 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 NIA or Sundry Number required here Contact Martin Walters / Brent Rogers Printed Name , Martin WaI er Title: Problem Wells Supervisor Signature 7C t: Phone: 907 - 659 -7224 Date: February 1, 2011 RBDMS FEB 04 11 14.-N 2 7-(( Form 10 -404 Revised 10/2010 Submit Original Only • . 3F-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/31/2011 IRE -TIFL (PASSED) SET UPPER PATCH ASS'Y (OAL 23') @ 4596' RKB W/ WEATHERFORD SLICK PUMP. 1/1/2011 SET TEST TOOL IN UPPER ER PKR © 4596' RKB, MITT TO 2575 PSI, PASS. JOB COMPLETE RUN 3.5" TEST TOOL IN ER PACKER © 4620' RKB. BLEED GAS OFF IA & PERFORM 12/22/2010 CMIT TO 2500 PSI. GOOD TEST. PLAN TO REDESIGN /REDRESS PATCH AND RERUN. DSO NOTIFIED TO LEAVE WELL SHUT IN. 12121/2010 SET ER PACKER TEST TOOL @ 4596' RKB. GOOD TBG TEST TO 2500 PSI. PULL TEST TOOL & PATCH © 4596' RKB. JOB IN PROGRESS. 12/1/2010 IRE -TIFL- FAILED SET TEST TOOL IN ER PKR © 4596' RKB. ATTEMPTED TEST TBG, FAILED. RAN 11/15/2010 HOLEFINDER, SUSPECT OV © 3874' RKB LEAKING. REPLACE 1/4" OV WITH NEW. TESTED TBG 2500 PSI, PASSED. PULLED ER TEST TOOL. COMPLETE. 9/25/2010 IRE -TIFL POST PATCH ( FAILED). RAN 3 1/2 ER TEST TOOL TO 4591' SLM / 4620' ELM, PERFORM CMIT;PASS, SET 9/21/2010 20.84'OAL WEATHERFORD PATCH w/ ER PACKERS @ 4591' SLM, RAN ER TEST TOOL TO 4577' SLM, TEST UPPER PKR TO 2750 PSI;PASS, COMPLETE. 9/18/2010 ISET 3.5" WEATHERFORD ER PACKER @ 4620' RAN LEAK DETECTION SURVEY. LEAK WAS IDENTIFIED © 4614' USE LRS TO PUMP 8/112010 DOWN THE TUBING AT 0.5 BPM TAKING RETURNS FROM IA JUMPER TO 3F -01. NO OTHER LEAKS IDENTIFIED. SERVICED WING VLV. CMIT -IA TO 2500 #. ** *PASS * * *. SET DMY VLV w/ RM LATCH © 7/30/2010 7105' RKB. PERFORMED INJECTIVITY TEST TBG TO IA. 1 BPM @ 1200# PUMP PSI WITH 500# BACK PRESSURE (5 BBLS) & 1.5 BPM @ 2075# PUMP PSI WITH 500# BACK PSI (10 BBLS). JOB COMPLETE. DRIFT TBG TO 7443' RKB. RAN CALIPER FROM 7442' RKB TO SURFACE. ** *GOOD 7/29/2010 DATA * * *. PULLED DMY VLV w/ RM LATCH @ 7105' RKB. CIRC OUT 100 BBLS DIESEL TBG TO IA. LRS TO PERFORM 30 MIN CMIT -IA TO 2500 psi. IN PROGRESS. 7/22/2010 IDENTIFIED APPARENT TBG LEAK BETWEEN 4564' -4595' SLM. PULLED BPI @ 7413' RKB. MEASURED C SAND BHP © 7330' RKB: 2690 PSI. IN PROGRESS. STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSICID REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell fl Plug FFrforations fl Stimulate r Other ' Install Patch Alter Casing ' " Pull Tubing r Perforate New Pool r Waiver r Time Extension E Change Approved Rogram r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' Exploratory 185 - 226 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21447 - 00 'COO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25643 `' 3F -02 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool • 10. Present Well Condition Summary: Total Depth measured 7864 feet Plugs (measured) None true vertical 6303 feet Junk (measured) 7699' Effective Depth measured 7750' feet Packer (measured) 4596, 4617,7168, 7428 true vertical 6213 feet (true vertucal) 3864, 3879, 5762, 5964 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 SURFACE 3468 9 -5/8" 3505 3084 PRODUCTION 7804 7 7839 6283 WOWED JAN 3 1 Zu1l Perforation depth: Measured depth: 7270'- 7390', 7561'- 7602', 7624' -7666' 2 0i True Vertical Depth: 5841'- 5934', 6067'- 6099', 6116- 6149' 'k 0 cre g ►3a4 Cons Cr . asion Tubing (size, grade, MD, and TVD) 3.5, J -55, 7450 MD, 5981 TVD 'ttll.'f!0'a€ e Packers & SSSV (type, MD, and TVD) PACKER - UPPER WEATHERFORD ER PACKER @ 4596 MD and 3864 TVD PACKER - LOWER WEATHERFORD ER PACKER @ 4617 MD and 3879 TVD PACKER - BAKER FHL PACKER @ 7168 MD and 5762 TVD PACKER - BAKER FB -1 PACKER @ 7428 MD and 5964 TVD SAFETY VLV - CAMCO TRDP -1A -SSA. @ 1852 MD and 1815 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 268 163 266 -- 146 Subsequent to operation 325 593 290 -- 150 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Developm ent 17 C. Service Stratigraphic y- 15. Well Status after work: ,,, Oil 17 Gas r WDSPL Daily Report of Well Operations XXX GSTOR fl WINJ r WAG r GINJ r SUSP r SPLUG r 16. 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 John Peirce @ 265 -6471 Printed Name John Peirce Title Wells Engineer Signature 4 r .. Phone: 265 - 6471 Date �/Z �/1 t Form 10 %404 Re 10/2010 Z§ 7'2 Submit Or •'nal Only it 3F -02 Well Work Summary DATE SUMMARY 12/21/10 SET ER PACKER TEST TOOL AI 1 17' RKB. GOOD TBG TEST TO 2500 PSI. I.L TEST TOOL & PATCH @ 4597' RKB. JOB IN NPROGRESS. 12/22/10 RUN 3.5" TEST TOOL IN ER PACKER © 4617' RKB. BLEED GAS OFF IA & PERFORM CMIT TO 2500 PSI. GOOD TEST. PLAN TO REDESIGN /REDRESS PATCH AND RERUN. DSO NOTIFIED TO LEAVE WELL SHUT IN. 1/1/11 SET UPPER PATCH ASS'Y (OAL 23') @ 4594' RKB W/ WEATHERFORD SLICK PUMP. SET TEST TOOL IN UPPER ER PKR © 4594' RKB, MITT TO 2575 PSI, PASS. JOB COMPLETE • . KUP • 3F-02 thpS Well 7; I Attributes Max Angle & MD TD AlLi`it° Inn ,�y Wellbore API/UWI Field Name Well Status Inc11") MD (ftK Ad 8) A Btm (ftKB) ts>r.nclh)u 500292144700 I KUPARUK RIVER UNIT PROD 45.70 I 3600 00 7,864 0 " Comment H25 (ppm) Date 'Annotation End Date KB -Grd (ft) RigR lease Date PP P ( ) 1I Well CaSIO 3F 02, 1 :3120117:2316 AM - 00 10/311986 Last Mod ... End Date Last Tag SLM Scnema Art .. I Casing Strings 6551 0 End 7//17/2010 Rev Reason RESET UPPER PATCH ASSY � Imosbor I 1/3/2011 HANGER, 33 - r $ Casing Description String 0... String ID ... Top (ftKB) Set Depth (0.. 'Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 110.0 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 9 5/8 8.921 37.0 3,504.5 3,084.1 36.00 .1 BTC " r m. , •r- Casing Description String 0... String ID... Top (ftKB( Set Depth (f... Set Depth (TVD) ... String Wt... String _. String Top Thrd PRODUCTION 7 6.151 350 7,839.2 6,283.4 26.00 .1-55 BTC � , Tubing Strings Tubing Description 'String 0 I Str ID ... Top (( Set Depth (f Set Depth (TV D) ... St g WI... Sfr ng .. String Top The CTO CON DUR,__" TUBING i 31/2 2992 33 .1 74510 5.9819 9 30 J - 55 I EUE 8RD 36-110 Completion Details Top Depth (TVD) Topincl Nomf... SAFETY1052 Top((tKBl (1568) r Item Description � Comment ID(in) Ili 33.1 33.1 -0.02 HANGER FMC TUBING HANGER 3.500 GAS LIFT, 1,852.4 1,815.2 29.74 SAFETY VLV CAMCO TRDP-1A-SSA. Locked out Flapper only 5/2598. 2.813 2,417 _ _.. 7,153. 5.751.1 39.35 PBR BAKER PBR 3.000 7,167.6 5,761.7 39.31 PACKER BAKER FHL PACKER 3.000 7,243.4 5,820.4 38.91 BLAST JT 2.992 ' . '...: ''':::',:: I 7,413.1 5,952.7 39.34 NIPPLE AVA BPL LANDING NIPPLE 05B 2.750 SURFACE, ,� 37 - 3,505 7,426.2 5,962.8 39.32 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 2.441 GAS LIFT _ _ 7,428.0 5,964.2 39.32 PACKER BAKER FB -1 PACKER 3.000 3, 7,431.3 5,966.7 39.32 SBE BAKER SEAL BORE EXTENSION 2.441 lit GAS LIFT 7,435.6 5,970.1 39.31 XO- Reducing 3.5'x2875" 2.441 4528 7,442.9 5.975.7 39.30 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,450.3 To Depth SOS CAMCO 2.438 PACKER, PATCK4,5167 a -{ Other In e e-_(Wop n PAT - a retrievable plugs, valves, pumps, fish, etc.) ' To (ft613) (868) r) Description Comment Run Date ID (in) 4,596.0 3,863.5 43.72 PACKER UPPER WEATHERFORD ER PACKER 1/1/2011 1.750 496j - " " - -- 4,5980 3,865.0 43.72 PATCH WEATHERFORD PATCH 2.74"x23' OAL 1/1/2011 1.992 fii 4,617.0 3,878.6 43.64 PACKER LOWER WEATHERFORD ER PACKER 9/18/2010 1.750 GAS LIFT, 3 5 52.6 _3 39 3 4 EEVE S C AVA 2.75" BPI I sl l 7 - - - - --- 7,41.0 952.6 9.4 Lsleeve 7/23/2010 2.310 5,422 _ 7,699 0 6,174.3 38.93 FISH 50% of Grapple & Wire Still in hole from 4 /1/94 4/2/1994 0.000 I GAS LIFT. _____- 5,854 Perforations & Slots - - - Shot GAS LIFT, Top (TVD( Btm (TVD) Dens 6,287 r T•• ftKB B1mtftKB) (SKR) (ftKB) Zone Date (sh Type Comment ... , 7,270.0 7,390.0 5,841.1 5,934.4 C - 4, C - 3, C - 2, 11/30/1985 12.0 IPERF 5" Csg Gun; 120 deg ph GAS LIFT, "w C - 3F - 6,725 7,561.0 7,602.0 6,067.2 6,098 .9' A -4, A -3, 36 -02 11 /30/1985 4.0 IPERF 4" Csg Gun; 90 deg ph . _., GAS LIFT, •, 7,570.0 7,600.0 6,074.1 6091.4 A3, 3F -02 4/10/1998 4.0 RPERF 2 1/8" Enerjet Bighole; 0 deg ph, 0 7,105 _ deg orient 7,624 0 7666 0 6,116.0 6,148. / A 2- 3F -02 11/30/1985 4.0 IPERF 4" Csg Gun; 90 deg ph PBR, 7,154 -- { PACKER, 7,158- `""`3• Notes: General & Safety End Date Annotation I 7/8/2002 NO E WAIVERED WELL IA X OA COMMUNICATION PRODUCTION, -. 4/21/2006 NO I E 61" EXTERNAL CSG PATCH FROM 12' BELOW CONDUCTOR TOP TO 18' 1" 5/31/2007 NO I E LEFT HALF OF PM RETAINER RING FOUND @ 3.5 GU ADAPTER IN HOLE 7/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7,270 IPERF, -7,39_ _ 8/1/2010 NOTE: EL LDL found Leak @ 4614' it - SLEEVE-C, 7,413 NIPPLE, 7,413 PACKER, 7,426 SBE, 7,431 - _ >+� 4s ill NIPPLE, 7,443 SOS, 7,450 -.. iNan re etat _ - i Top Depth Top Port IPERF,.' (TVD) Inc! OD Valve Latch Size TRO Run 7,561-7,602 (ftKB) 1 ") Make Model (in) Sery 'We Type 90) (Psi) Run Date Com... RPERF. 4-,e) ` Stn Top (ftKB] 7,570 - 7,600 ':17. •a- 1 2,417.2 2,271.7 40.57 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,266.0 5/31/2007 2 3,874.4 3,350.8 45.67 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 11/13/2010 __ 3 4,527.5 3,814.1 43.75 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/21/2010 IPERF, _ 75244555 4 4,967.0 4,131.8 43.48 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/22/1994 5 5,421.6 4,462.6 43.10 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 FISH, 7,699 6 5,854.1 4,778.2 43.01 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 7 6,287.1 5,096.3 42.04 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/22/1994 8 6,724.9 5,423.8 41.07 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 9 7,104.8 5,713.2 39.49 MERLA TPDX 1 12 GAS LIFT DMY RM 0.000 0.0 7/30/2010 PRODUCTION, - 35 - 7,839 10 7,205.7 5,791.1 38.91 CAMCO KBUG 1 PROD DMY RM 0.000 0.0 4/13/1998 TD, 7,864 - --- -- • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3F-02 Run Date: 8/1/2010 August 4, 2010 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 3F-02 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21447-00 +~,, - . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: l~~ ~~ r9`~~~ klinton.woo 0 Date: AUG 1 1 2010 Signed: i • • ~~~ +~~V ~~~a~~/ II. PROAci1VE DIAGNOSTIC SERVICES ING. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~'~~ . Suite C ' wv. ~ `,i~, ° ~ ~ A !.l ~_- ~.. z, Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 27-Ju1-10 2Z-03 1 Report /EDE 2) Caliper Report 29-Ju1-10 3F-02 1 Report /EDE UZ~ rb3 - o~sS~ 1~~~~ ,~ ~~ _ as c~ l ~ ~ 7 Signed Print Name: 50-029-20040-00 50-029-21447-00 ~~~~~~ Date : ~\I.iG a 5 201D III ` . t7~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pCISdnCllorage(U mem01'VIOq.COm WEB$ITE : v~nNw.memOrVlOg.com C:\Docwnerts and Settings\Diane Williams~Desktop\Trsns¢rit_Conoco.docx • Memory Multi-Finger Caliper Log Results. Summary Company: ConocoPhillips Alaska, Inc. Well: 3F-02 Log Date: July 29, 2010 Field: Kuparuk Log No.: 7435 State: Alaska Run No.: 1 API No.: 50-029-21447-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 EUE 8RD Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvt1.: 7,438 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the AVA BPL Landing Nipple @ 7,413 (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or t.D. restrictions recorded. The caliper recordings indicate slight buckling from -2,400' to --7,150'. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 19%} are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss {> 12%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant l.D. restrictions are recorded throughout the tubing logged. Field Engineer: Wm. McCrossan Analyst: C. Lucasan Witness: C. Kennedy ProACt9va ~iagr~GStic Services, inC. i F,O. o0x 1369, Stafford, TX 77~r97 Phone: (231) or (838) 565-9085 Fax: (281; 565-1369 E-mai!: PDS(amemorylog.com Prudhoe fray Field Office Phone: (907) 659-2307 Fax; (907) 659-2314 • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (11.9' - 7433.1') Wcll: 3F-02 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 29, 2010 A pprox. Tool De viation ^ A pprox. Borehol e Profil e 16 754 1523 GLM 1 2312 3088 GLM 2 38b9 c t a GLM 3 ~ 4645 GLM 4 GLM 5 5428 GLM 6 GLM 7 6193 GLM 8 6979 GLM 9 GLM 10 236.5 7433 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 236.5 1 25 50 100 v j I ~ ~~ Z c I 150 225 • • PDS Report Overview ~,. ~,, Body Region Analysis Well: 3F-02 Survey Date: July 29, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: t69 Country: USA No. of Fingers: 24 Anal st: G Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 EUE 8RD '2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) p penetration body metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10`% 20% 40°/n 85% 85% Number of ~oints anal sed total = 240 pene. 13 202 25 0 0 0 loss 133 106 1 0 0 0 Damage Configuration (body ) 20 101 I 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion iblehole Number of ~oints dama ed total = 11 11 0 0 0 0 Damage Profile (% wall) ~ penetration body .metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GI_M 6 GLM 7 GLM 8 GLM 10 Bottom of Survev = 236.5 Analysis Overview page Z • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 3F-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: July 29, 2010 Joint No. Jt. Depth (Ft.) I',~n. Upset (In.) Pen. Body (Ins.) Pen. % Metal I oss °.~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 12 U 0.01 4 ' 2.96 PUP 1 16 U 0.01 5 1 2.94 2 47 U 0.01 4 ' 2.94 3 77 !? 0.02 ~~ I 2.95 4 108 ! . 0.01 -1 I 2.93 5 139 i) 0.01 5 1 2.95 6 170 l ~ 0.01 4 2.94 ' ~ 7 201 (t 0.01 ? I 2.94 8 232 a 0.01 4 2.95 9 263 t) 0.01 4 !! 2.93 10 293 ~.~ 0.01 `~ I 2.93 11 324 !? 0.02 ~ U 2.93 12 354 U 0.02 ~ ~ i ~ 2.93 13 385 (% 0.01 t~ 2.95 14 416 !~ 0.01 1 2.93 15 447 ! ? 0.01 5 _' 2.93 16 478 .? 0.01 !~~ 2.94 17 509 U 0.01 ~, ' 2.95 18 541 t ~ 0.01 4 2.94 q 19 572 i~ 0.01 t~ 1 2.93 20 602 U 0.01 `> i! 2.93 21 633 !) 0.01 (, a Z.94 22 664 t! 0.01 r, 2.93 23 695 !) 0.02 f 2.94 24 725 !; 0.01 d I 2.92 25 754 O 0.01 -E 1 2.94 26 785 U 0.01 4 1 2.92 2 7 816 U 0.02 ~ ! ~ 2.93 28 846 tt 0.01 b 2.95 29 877 t! 0.02 ~~ 2.93 ~ 30 908 t) 0.02 7 t ~ 2.94 '~ 31 939 !~ 0.02 ~~ I 2.93 32 970 it 0.02 fi 2.93 33 1001 t1 0.02 i t1 2.92 34 1032 t~ 0.01 6 ? 2.92 35 1063 !~ 0.02 8 i) 2.93 36 1094 U 0.03 ll) 1 2.94 37 1124 U 0.01 f> 1 2.94 38 1154 t ~ 0.01 ~ I 2.94 w 39 1 185 i ~ 0.01 S 2.94 40 1216 +.,~ 0.01 4 ~' 2.94 41 1246 t~ 0.01 6 2.94 42 1277 t' 0.01 5 U 2.91 Lt. De osits. 43 1308 ~ ~ 0.02 - ! 2.92 44 1338 i? 0.02 ~i -t 2.94 45 1369 it 0.03 i 1 2.92 Lt De osits. 46 1400 ! % 0.02 ~~ 2.96 47 1431 ! ~ 0.01 - 2.91 48 1462 ! ~ 0.03 l t? 2.92 Lt De osi ts. 49 1493 ! I 0.02 t3 i 2.94 - _ Penetration Body ~1~letal Loss Body Page "I • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 FUE 8RD Well: 3F-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: July 29, 2010 Joint No. )t. Depth (Ft.) I'~~u. Ilps~~1 (Ire.! Pen. Body (Ins.) Pen. % ~lc~(.il los ~~ Min. LD• (Ins.) Cornrnents Damage Profile (%wall) 0 50 100 50 1523 -` 0.01 _' 2.93 51 1554 a.' 0.01 5 i; 2.92 Lt. De osits. 52 1583 t'. 0.02 S 2.94 53 1613 i' 0.01 'i 2.93 54 1644 ! ? 0.02 U 2.94 `~ 55 1676 t? 0.01 6 1 2.96 56 1706 i'~ 0.02 ~~ 1 2.95 57 1737 ~ ~ 0.01 b 1 2.94 58 1768 !' 0.02 ~~ I 2.93 Lt De osits. 59 1800 ! ? 0.01 ' 1 2.93 ' 59.1 1831 :? 0.01 1 2.89 PUP 59.2 1839 U 0 U i1 2.81 Camco SSSV 60 1850 (? 0.01 -1 I 2.94 61 1881 (? 0.01 ~' I 2.92 62 1911 U 0.01 ~ I 2.93 63 1942 (? 0.01 ~ I 2.94 ~ 64 1973 ! ! 0.02 ~~ I 2.92 65 2004 (? 0.01 4 I 2.94 66 2034 !? 0.02 9 (1 2.92 67 2066 i? 0.01 2 1 2.94 68 2096 (! 0.03 11 2.91 69 2127 (? 0.01 5 (? 2.95 70 2157 i? 0.01 4 I 2.93 71 2188 !? 0.02 '? ? 2.95 72 2219 1? 0.02 `~ I 2.93 73 2250 U 0.01 ~' 1 2.93 74 2281 U 0.03 Il I 2.92 75 2312 a 0.03 II O 2.93 76 2342 !? 0.00 1 1 2.92 77 2373 i? 0.01 -1 ' 2.95 77.1 2403 U 0 U O N A GLM 1 Latch @ 8:00 78 2411 U 0.03 11 I 2.93 Lt De osits. 79 2441 (1 0.02 ~ 1 2.91 Sli ht bucklin . 80 2473 U 0.02 ~ U 2.93 81 2503 U 0.02 '? I 2.93 82 2535 r? 0.03 I2 2 2.92 83 2567 U 0.03 1 ~' ~' 2.91 Shallow ittin . 84 2598 t? 0.01 -t I 2.93 Lt. De osits. 85 2629 t? 0.02 9 f 2.92 86 2660 0.01 6 t) 2.91 87 2692 !) 0.02 ti 2 2.93 88 2722 (> 0.03 12 2.93 89 2751 l! 0.01 ~i _' 2.95 ' ~ 90 2781 U 0.00 1 I 2.93 91 2811 t? 0.02 8 2.93 ~ 92 X840 U 0.01 ' I 2.93 93 2871 (? 0.03 12 I 2.92 94 2903 (? 0.02 F3 I 2.92 95 2933 (? 0.00 I i? 2.93 96 2964 !) 0.01 ~' 2.94 ' _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 FUF 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: ILATION SHEET 3 F-02 Kuparuk Conoc~Phillips Alaska, Inc: USA July 29, 2010 Joint No. Jt. Depth (Ft) I'rn. Up~t~l !lug.' Pen. Body (Ins.) Pen. "~~ Met,~l Ins ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 2995 n 0.02 ~t 2.93 98 3027 t~ 0.01 . 2.94 99 3057 ~~~ 0.02 ~l _' 2.93 100 3088 ~ ~ 0.02 9 I 2.92 101 3120 i? 0.01 ~' 1 2.93 102 3151 t ~ 0.02 ~i 2.93 103 3182 i! 0.01 5 I 2.94 104 3213 ! + 0.02 ~i 2.93 105 3244 ! ~ 0.01 ' I 2.95 ~ 106 3274 !~ 0.02 ~~ t) 2.91 107 330(1 U 0.02 8 1 2.94 108 3336 U 0.03 1 'I Z 2.92 109 3368 U 0.02 9 2.94 110 3398 i? 0.02 ~l 2.92 111 3430 ti 0.02 8 ? 2.92 ~ 112 3461 U 0.02 ~) ~' 2.93 113 3492 tl 0.00 i 2.96 114 3523 t1 0.01 2 ! 2.93 115 3554 t) 0.00 1 U 2.93 116 3585 ! ~ 0.02 '~ I 2.92 117 3617 :~ 0.02 ~~ f 2.92 1 18 3648 t7 0.03 7 2 I 2.93 119 3679 ~l 0.01 4 2.95 120 3709 tl 0.02 y 2.94 121 3740 U 0.00 1 I 2.96 122 3771 i~ 0.02 `1 I 2.93 123 3801 I1 0.02 c1 4 2.96 124 3831 ti 0.03 1 "/ 2,92 Shallow ittin Lt. De ositc. 124.1 3862 i~ 0 U t~ N A GLM 2 Latch C~ 5:30 125 3869 i1 0.03 C> 2.92 Shallow ittin . 126 3900 t? 0.02 <i 2.92 Sli ht bucklin . 127 3931 ii 0.01 ~ t) 2.90 128 3963 U 0.02 ~~ I 2.94 129 3993 t ~ 0.03 1 i i 2.93 130 4024 i ~ 0.00 I U 2.93 131 4056 i? 0.02 ~) ! 2.93 132 4087 to 0.01 4 _' 2.94 '~ 133 4118 t~ 0.02 ~ ' 2.93 ~ 134 4149 U 0.02 ~~ 2.93 135 4180 i i 0.02 '> 2.94 136 4210 ~: ~ 0.01 2.92 Sli ht bucklin . 137 4240 t~ 0.04 I i 2.92 Shallow ittin . 138 4271 ~? 0.01 -> 2.93 139 4302 1 ~ 0.02 fi 4 2.93 140 4333 ti 0.01 4 1 2.92 141 4364 i) 0.04 i-t I 2.91 Shallow ittin . 142 4396 t ~ 0.01 4 2.93 143 4424 tl 0.00 1 i 2.89 14-4 4455 t) 0.00 1 I 2.93 145 4486 tw 0.02 ~~ 2.92 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf 1-55 EUE 8RD Well: 3F-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 29, 2010 Joint No. Jt. Depth (Ft) f'c~n. Ul~ct~t (Ins.i Pen. Body (Ins.) P~~n. ",4, VI~~(,~I I vas ",~~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 145.1 4516 (~ 0 U i i N A GLM 3 Latch @ 3:00 146 4522 t' 0.05 I ~) ~ ~ 2.93 Shallow ittin . 147 4552 ~ ~ Q00 i 1 2.93 Sli ht hucklin . 148 4583 ~' 0.01 i 2.92 149 4614 ~' 0.02 ~) I 2.92 ~ 150 4645 i ! 0.02 ~~ ? 2.92 151 4677 i ~ 0.01 5 !~> 2.93 "" 152 4709 (~ 0.01 -t 2.93 ~ 153 4740 O 0.02 ~~ 2.96 154 4771 ! ~ 0.01 (> I 2.94 155 4802 (~ 0.02 1 2.94 156 4832 0.01 1 i 2.92 157 4863 t' 0.01 4 1 2.93 Sli ht hucklin ~~ 158 4894 ! ~ 0.01 1 ~' 2.93 159 4925 0.01 > I 2.95 159.1 4955 i1 0 U ~? N A GLM 4 Latch C~ 7:00 160 4962 0.03 12 ~ 2.93 161 4994 U 0.01 5 -3 2.96 162 5024 !~ 0.02 9 4 291 163 5056 !) 0.02 ~~ 3 2.91 164 5086 (~ 0.01 4 2.94 165 51 16 a 0.01 4 1 2.92 166 5147 U 0.01 5 ~' 2.92 Sli ht hucklin . 167 5178 ti 0.01 ~ 4 2.90 168 5208 U 0.01 4 294 169 5238 (1 0.02 8 I 2.94 170 5269 U 0.00 I I 2.92 171 5301 O 0.03 1 ~ = 2.93 172 5332 n 0.02 ti 2.94 173 5362 ~ ~ 0.02 9 2.92 174 5392 a 0.02 8 2.95 174.1 5422 t~ 0 {) t~ N A GLM 5 Latch ~ 3:00 175 5428 ~;~ 0.01 5 2.94 Sli htbucklin . 176 5457 ! ~ 0.03 1 '~ 2.92 Shallow ittin . 177 5488 r( 0.02 ~~ _' 2.91 178 5518 i l 0.02 y 2.94 179 5548 U 0.01 !~ it 2.92 ~ 180 5577 ~? 0.04 14 I 2.88 Shallow ittin l_t. De osits. 181 5607 ~ 1 0.01 ? I 2.94 182 5638 (1 0.00 1 ~' 2.94 183 5669 l1 0.01 ~' U 2.91 184 5700 ~? 0.01 4 1 2.93 Sli ht hucklin . 185 5731 (? 0.03 12 1 2.92 Shallow ittin . 186 5762 O 0.02 8 t 2.94 Lt. Deposits. 187 5793 ~I 0.02 8 t 2.95 188 5824 0.02 8 294 188.1 5853 0 O ~:~ N A GLM 6 Latch @ 7:00 189 5861 ~. ~ 0.03 1 i) 2.92 190 5890 (~ 0.02 ~t s 2.93 `Y° 191 5919 (~ 0.01 5 -1 2.92 _ Penetration Body Mcta) Loss Body Page 4 • PDS REPORT JOINT TABI Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Cornpany: Nominal LD.: 2.992 in Country: Survey Date • JLATION SHEET 3 F-02 Kuparuk ConocoPhillips Alaska, Inc USA July 29, 2010 Joint No. Jt. Depth (Ft.) ~. 111nrt (Ins.; Pen. Body (Ins.) Pc~n. °~. a1r~t,~l I r~~ss ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 192 5950 + t 0.01 _' 2.93 ' 193 5981 i ~ 0.02 ~~ - 2.94 Sli ht bucklin . 194 601 3 ~ ! 0.01 'i 2.92 ' 195 6042 0.01 0 2.89 ~~ 196 6073 ~ ! 0.02 - Il 2.95 " ~ 197 6102 ! ? 0.01 `i 2.92 198 6132 i ! 0.02 9 _' 2.92 ~ 199 6162 U 0.03 I '1 i 2.91 200 6193 0.01 4 1 2.95 201 6224 ~! 0.01 3 ~ ~ 2.90 Lt De osits. 202 6255 U 0.01 5 2.93 202.1 6286 t! 0 0 t t N A GLM 7 Latch @ 7:00 203 6292 tt 0.01 5 ? 2.93 Sli ht bucklin . 204 6324 U 0.01 5 ~ 2.91 205 6354 r! 0.01 t~ 1 2.92 ~` 206 6385 i ~ 0.01 4 1 2.92 207 6415 ti 0.02 7 ? 2.90 Lt De osits. 208 6446 (i 0.03 1 1 U 2.91 209 6478 !? 0.02 9 t) 2.93 210 6509 ~ i 0.01 6 ~i 2.93 211 6538 a 0.02 ~) C1 2.90 212 6570 n 0.02 '~ ? 2.93 Sli ht bucklin . 213 6600 U 0.02 ~) 2.91 214 6631 n 0.02 E3 2.93 ~ 215 6662 r? 0.01 .5 -1 2.94 216 6693 tt 0.03 11 2.91 216.1 6725 t? 0 1? !) N A GLM 8 Latch @ 2:30 217 6731 rt 0.04 1 -a 2.93 Shallow ittin Lt De osits. 218 6763 (> 0.02 ~~ 2.93 219 6793 tt 0.02 t; 2.93 220 6824 i? 0.01 2 2.92 221 6855 tt 0.01 4 2.92 Sli ht bucklin ~ 222 6886 U 0.01 V 2.95 223 6917 t! 0.02 ~r 2.91 224 6948 t t 0.02 '? 2.92 225 6979 t! 0.01 I 2.91 226 7010 ti 0.02 2.92 227 7042 O 0.01 t 2.91 228 707 3 ~ ~ 0.01 `> 2.93 Sli ht bucklin . 228.1 7105 ~! 0 U +> N A GLM 9 Latch @ 10:00 229 7114 ! 0.04 1 ~~ Z.93 Shallow ittin . 229.1 7145 t! 0.01 5 2.92 PUP ~` 229.2 7154 ~! 0 t) r! N A Seal Assemble 229.3 7165 t) 0 U ;! 3.00 Baker PBR 229.4 7168 tt 0 0 r~~ 3.00 Baker FHL Packer X30 7173 ,t 0.01 ' I x.93 230.1 7205 ti 0 U i~ N A GLM 10 Latch C~? 10:00 231 7212 ;! 0.00 I I 2.93 232 7244 ~' 0.01 ? 2.91 a 233 7273 a 0.02 t3 ~ 2.93 _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUC 8RD Well: 3F-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 29, 2010 Joint No. Jt. Depth (Ft.) I'c•n. Ulr•c~t (Irn.) Pen. Body (Ins.) Pe•n. ~<, ~Ic•t,~l A octi `,'~~ Min. LD• (Ins.) Comments Damage Profile ("/o wall) 0 50 100 234 7303 ~ ~ 0.01 ~' 2.95 235 7335 ~ i 0.01 ~, 12 2.96 236 7367 ~ r 0.01 I 2.95 236.1 7398 ~'~ 0.01 ! 2.96 PUP 236.2 7413 !' 0 U ~ - 2.75 AVA BPL Landin Ni IeW Sleeve-C 236.3 7416 C~ 0 i) ~~: 2.44 Baker Seal Assemble 236.4 7425 ~~~ 0 ~1 1~ 3.00 Baker FB-1 Packer 236.5 7433 i i 0 U ~' 2.44 Baker Seal BoreE Extension __ Penetration Body Metal Loss Body Page 6 ~~~ KUP 3F-02 ConoeoPhillip s r ~ WellAttnbutes Max An le&MD TD not.--r: / Afi WI FI IlimP W IIS C ~ C .F ~I IK I'FF ItJ -. R I I~,'I MC TKR 0t F~ If KR ~,~ N' ~- .-JC_ R J k Cale H2S IV4 n Bate ht~ Entl Daly ME d n Flar. for ~. of .~tl _• 11 -.. - Vi 1 1•w,-• r 1 ~ - - ~ LaN NOn.. ErG CIa!t D-utr lnK6t End Date Mncta[on ~ l iLll 7 u-~- 7 - -_ 3!717 Fy~: F.~.soT.'AG. sel F'Iuy:Gc.+:_I.s. set GFI tosboi 7•J'.C I6 Le~ Tcy~ Casin Strin iwr~_p J- ~ i J p.inn rr+r _..7. ~ srnn0 t!.. 0 D ... -o , 7:: ion incH i 7r,r sn, D M Ir... -u-_~ Sei n.p 1 yr l.. 5tnn0 WL. Sm l0 1-r 147 srr np t ;{I tnrn ,'.r. i-[[, ~. ~ ~ ., uT ~ t.. sennou s Bic ToP'rtKe) s tD m tt s D•Dm lTVq.. s a aw .s >7 s uTM>Tnrn - - 1 ;: ~ ^O Deacnn<<n F'FC'. _~I,I.'TIC:'. s[lnO O.._ Sv rp 10 .. - ; 1-1 Ton iRKB' JC C SeID MI (f... 7.,k39 ^ Set DeP,n fNDl... SnInO W~ 9r lg r ^°. _~ 1 6 J - _ SR'>n Tqr Tnrzl __ - Tubin Strin ma.»Y n=.<„F...~r.n ~ _, v a... s,r~nv le ... T,o ~nKD ~ sm D-vn, [c.. s.. n.PU.IrvDt... .I Snini. T.n, n,rn -LIaMG ,•f11 Ii: _L9: _v i _ __-.J - 551.9 _ EUE "F.C. ccru~.ro6 '~ ~ Com lo tion Det ails FF~ Top itKel Too DeDm ITYpI MKBI ToD Inc! (`I Item Dexcnplio n Gommxn Noml. ~. ID (Inl 1.95 1 1 91 ~ ~ ~'9. 74 SAFETY t/LV CAh1CCi TRDP-1 F-S$A- Locked otn Flnppsr :;n:y -,~''9£ ~E13 _ai- .1__. _., _.1. J 3_ 15 7.161.6 5'Gl ~ 39.31 PACKR BAKER FHL 7A :tCEF 3.OPJ 7 3 1 RjO- 3691 BL.45'JT C99: 7i~ 1 3J.31 NIP'~,LE F. A(:t LANLI if NIC LE USE 2.75V cP-s'E 7A F' 962. 39.3° LCCATC3 B KE. Li:•~ATOR ~AL A.'SEMBLY ~q31 ~ ~ s 7.1113 r9fiF7 .39 1C ":6E F^.KER SEAL B+iP,E E~TENSIDN ~ I". s~ _ rr 7.14. ,^ .. -: 3J. 3v N~.P:".E UAMCU v f.l:^('LE N~ % CCU ._Sfl '__` 7.15C.3 '..9£1.= 3J.7 50Es Clti~A:.U 2.439 Other t o Hole Wirollrla retNsvab le lu s. valves u s. tlsh etc. - r Tnn lfrKRl Top Def+in ,TVeI tl!KB) nP h,ol I-) Dannmriml Rnn Date ID f~nl '. `'rti 7,31'3 "..9.9 3.4.33 S LEEVE-C Al'A=.:S"BPI,r i 7rT.7:=017 _:+1f1 7.443 1.975.9 39.37 P LUG __a't:.1-: PLUG w 'GAUGES 777 _p17 C~.CCrJ w _ < Z6N F.173 5 3R 93 FISH EG%o113rappe F.'711re Sell n hole Frem='1!94 lr~;;1993 C (~0 Perforations S SEots .. r`o_ t IM1KB elm lfiKBl ipp fTVD I f Btm ITVD) MKP1 I Zone Da[s leh.~ v e;'_vT f 7.~7U 7.396 S.Ri L I 5.933.' ~ -1. C~d. C>= '. IrsC~i 15EE -C.] IPERF > lsu Gun-1=0 dey ph -- -- _- 5 Jb,. L Jl3 ~ - J -iF U. _ ~ J F - _cy JJ d:y ph - ~~ ~ 7.57V 7.S V 5.77-.1 S.7A.=A 3F 7C 14a 7...~ 3 I 17 Rf CF 1'13 E~ prt6 ynol!:0 eey ah.C dng c cnl :.. .y 7 6i 7 666 S.': 15. U 6.138.7 A -;. iF-CL 1r3C: 19E5 i 9 IPER'~F i' i.3y ~~un. 97 dey ph '•_~ -- Notes: General & Sete ILnu wt. r'c'a' -3' A.7 ' Ii7G- N l AI1'FFE[7 Yv'ELL IAx P CPdtt'.."~ll II NuTE F 1' Ex-EF2NAL C5G FA fF - !JM: i L _~=ANC LCT.'4 T.:F TCt 1c -° 5131 i~~7i NOTE LEFT rALAITJ R Ih13 =C'.:ND ::, 3.5 GU ADAR ER IN HU - _ 7;75;`Y~ N~-tTF V~":r-hrm9rir n~~Ale An';=hmm~nr4 ~t __' '`/ 3EE'. EC ,.r a . a_: Ma ndrel Details i=EK= •P^ER= \~_. >_=),.T non Sln ToD iflKR~, icP U:mn iTVC'; I IfIKBI Icp Inc! f'7 McVn M«lel iT[I lint Sxv Vn M1e TYp~ LnicM1 TYW von Stxe hnl iRO Rnn fM~l Rev Dnte Gali_ 1 ..4-7C =JAI.'_G K°UG 1 ~~AS LIFT C:LV BK C.1=6 1,=5f+.U :;_1;=1177 3.. 71J !"Alf:~rJ K~IL- l r'~AC UFT +'.\" RK '_i7 7.~;1 7i1 flr"_'O1D In.p= - 4.x_7.9 C'AM~'U KEU(3 1 t~qS LIE" DI;Y EK O.PJ71 JO a~31;_CYJ7 ""~- '~' i 4.45i_C CAI:t~A K3UG 1 GAS LIE' CPJY BK r:l-F.r7 7i~ !1!!__;139+ 5 5A21 6 C:AMCC K5UG 1 GAS LIFT Dh<Y BK C.OC9 7.0 IL!5!1965 6 x.35+.1 CAM::: rJ K"olA3 1 f1A5 UFT Dh:Y BK G.P77 7A 1!5;1935 6_-571 f:AM~'0 H6UG 1 GAS LIFT 'Jhf'r EK niria 70 1U/.^_:t94~ ~5 5.7_1.5 rAAnrt; N9UG 1 GA,S LIFT ,]PiY F1K Oxx~7 'J.O 1_+5;1995 -n~, yr„ 9 7.1]1.£ h'ERLA TrDX 1112 GAS LIFT GMV T-7 G.W7 7.f1 1(41±1951 c .,. ~ ... ~'A '_ d +.: Y _- ~ 311 ~i19 • • Page 1 of 1 Regg, James B (DOA) ~ ~~c,'_ZZ~ From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~ (~~~a~io Sent: Saturday, July 24, 2010 2:23 PM U To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; Smith, Travis T Subject: 3F-02 (PTD# 185-226) Report Of TxIA Communication Attachments: 3F-02 Wellbore Schematic.pdf; 3F-02 TIO Plot.pdf Jim/Tom/Guy, Kuparuk gaslifted producer 3F-02 (PTD# 185-226) is exhibiting signs of TxIA communication following routine wellwork. Slickline has identified the possible location of the leak but is un le to repair. A caliper survey will be scheduled followed by an electric line leak detection log if necessary. The well will be added to the SCP report and will be fixed by or shut in by 8/6/10. Attached are a wellbore schematic and 90 day TIO plot. ~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 , ^ ~ ~ ~ ~,~t= ;` P~ i ~ ~ ~ s ~ ~ [l ~l ~'' Pager 907-659-7000 #909 8/10/2010 I 1 'J ~~`j'~ zz~` Well Name 3F-02 Notes: End Date 7 3012010 Days 120 Start Date 4'1 !2010 Annular Communication Surveillance __.~_ ._.__ -_-__-- - 1 so 1 soo WHP - - - ---- ----- _ IAP - - - - - 140 1400 WHT - - L 120 1200 100 1000 - ~~ LL N 80 d 800 Q a soo i -- -- - - so ~'~ 4n0 -- -- -- - -- - - 40 - - _ _ ~~ 20 X00 0 0 Apr-10 May-10 Jun-10 Jul-10 soo ~DGI aso wMGI f aoo wPWI 350 300 w3Wl o zso ~BLPD ` - - - - ~ 200 ~ - 1500 - - 1000 i 500 0 Apr-10 May-10 Jun-10 Jul-10 Date • • ` ~ ~ KUP >~ - - -- ~ ~ 3F-02 - - le & MD ~TD '~ Max An ' Well Attributes ConocoP~il l l 5 I j ~ i - - - - g RKe) ~ - ' ID -- Act Btm (RKB) - - ( W II St t Inc! ( ... w,.ii r. ten„ -?F-m 7 . _ ~. HANGER, 33 i - , i -{i 70NDUCTOR, !, 38-110 f e I SAFETY VLV, 1,852 GAS LIFT, ,. _J"',. 2,417 SURFACE, 37-3,5(`5 ' GAS LIFT, ~ , _ OO 3.874 ~r GAB LIFT, M 4,528 __. _ GAS LIFT, a~4 4,967 __ 1 GAS LIFT, ~~~ 5,422 ~ ~~ ~~ ~~ GAS LIFT, ~~ 5,854 _ _ GAS LIFT, r~_ - 6,287 L~ __.- I GAS LIFT, ~; 6,725 ~-_ GAS LIFT, r ~~ 7,105 r PBR, 7,154 PACKER, 7,168-ag ~s~ '~ r PRODUCTION, y 7,206 - - IPERF, , 7,270-7,390 f ~ SLEEVE-C, 7,413 NIPPLE, 7,413 .~ 1. -)~ PACKER, 7,428 •' Y+L-~~+- SBE, 7,431 ,- -~ PWG, 7,443 r~? NIPPLE, 7,443 f SOS. 7.450 IPERF, 7 561-7,fi02 RPERF. 7s7o-2600 IPERF, 7,624-7.666 FISH. 7.fi99 ODUCTION. 35-7,839 TD, 7,864 W Ilb APIIUWI Fieltl Name e a us I 500192144700 KUPARUK RIVER UNIT PROD 45.70 3,800 00 7,864.0 C nm ment H25 (ppm) Date SS9V: Flapper Locked Out 350 1123/2009 Annotation Last W0: End Date KB-0rd (R) 41.00 t M Rig Release Date 10/3/1985 E d Date tl _--'- __ A L nnotation Depth (RKB) ast Tag'. SLM 7,651.0 End Date Annotation 7/17/2010 Rev Reason: TAG, set Plug/Gauges, set BPI _ _ _ ~ ... n Las O Imosbor 7202010 _ ,r _ Casing.Strinys Casing Descnphan St ing 0... String VD ... Top (f[KB) Set D pth (f .. Set Depth (ND) .. String Wt... Stn 9 ~~~ String Top 7hrtl CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED - ~~ Casing Deacrlptlon SURFACE String 0... 95/8 String ID .. 8.921 . Top (RKB) 37.0 Set Depth (f... 3,504.5 Set Depth (ND) ... 3,084.1 String Wt... 36.00 String ... J-55 String Top Thrd BTC "~~ Casing Description PRODUCTION String 0... 7 String ID .. 6.151 . Top (RKB) 35.0 Set Depth (T... 7,839.2 Set Depth (ND) ... 6,283.4 String Wt... 26.00 String ... J-55 String Top Thrd BTC Tubing Strin s -~ -- - Tubing Description String 0... 15tnng ID ... Top (ttKB~ Depth (f... Set Depth (ND) .. String W~9~5tri g Top Thrd TUBING 31/2 2.992 33.1 74510 5,981.9 9.30 J55 I EUE_SRD Co_m letion Details Top Depth - ~~ (ND) Top Inc! Top (RKB) (RKB) (°) Item Description Comment Noml... ID (in) 33.1 33.1 -0.02 HANGER FMC TUBING HANGER 3.500 1,852.4 1,815.2 29.74 SAFETY VLV CAMCO TRDP-IA-SSA. Locked out Flapper only 525/98. 2.813 7,153.8 5,751.1 39.35 PBR BAKER PBR 3.000 7,167.6 5,761,7 39.31 PACKER BAKER FHL PACKER 3.000 7,243.4 5,820.4 38.91 BLASTJT 2.992 7,413.1 5,952.7 39.34 NIPPLE AVA BPL LANDING NIPPLE OSB 2.750 7,426.2 5,962.8 39.32 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 2.441 7,428.0 5,964.2 39.32 PACKER BAKER FB-1 PACKER 3.000 7,431.3 5,966.7 39.32 SBE BAKER SEAL BORE EXTENSION 2.441 7,435.6 5,970.1 39.31 XO-Reducing 3.5"x2.875" 2.441 7,442.9 5,975.7 39.30 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,450.3 5,981.4 39.29 SOS CAMCO 2.438 Other I _. n Hole Wireline retrievable lugs v,_alves, pumps, fish, etc•) __ Top (RKB) Top Depth (ND) (RKB) lap Inc! (°) Deacrlptlon Commem Run Date ID (in) 7,413 5,952.6 39.34 SLEEVE-C AVA 2.75" BPI sleeve 7 /17/2010 2.310 7,443 5,975.8 39.30 PLUG 2.25" CA-2 PLUG w/GAUGES 7 /172010 0.000 7,699 6,174.3 38.93 FISH 50%of Grapple & Wire Still in hole from 4/1/94 4 2/1994 0.000 Perfora tions & Slots -- -- - Top (RKB) tm (ttKB) Top (N (RKB) _ D) Btm (ND) (RKB) - - Zone _ Date T Shot Dene (sh~•• ype omment 7,270 7,390 5.841.1 5,934.4 C-4, C-3, C-2, C-1, 3F-02 11/30/1985 12.0 IPERF 5" Csg Gun; 120 deg ph 7,561 7,602 6.067.2 6,098.9 A-4, A-3, 3F-02 11/30/1985 4.0 IPERF 4"Csg Gun; 90 deg ph 7,570 7,600 6,074.1 6,097.4 A-3, 3F-02 4/10/1998 4.0 RPERF 2 1/8" Enerjet Bighole; 0 deg ph, 0 deg orient ~•a 7,624 7,666 6,116.0 6,148.7 A-2, 3F-02 11/30/1985 4,0, IPERF 4" Csg Gun; 90 deg ph -- - - -. Notes: General & Safety _ _ _ _ -_ cnd Data Annotation 7/82002 NOTE: WAIVERED WELL IA X OA COMMUNICATION 4212006 NOTE: 6'1" EXTERNAL CSG PATCH FROM 12' BELOW CONDUCTOR TOP TO 18' 1" 5/312007 NOTE: LEFT HALF OF PM RETAINER RING FOUND @ 3.5 GU ADAPTER IN HOLE 7/162010 NOTE: View Schematic w/ Alaska Schematic9.0 Mandrel Details Stn Top (RKB) Top Depth (ND) (RKB) Top Inel (°) Maka Model OD (in) Sarv Vatve Type Latch Type pO„ Slze gN 7R0 Run (psl) Run Date Com... _ 1 2,417.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,266.0 5/31/2007 2 3,874.4 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 7!18/2010 3 4,527.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/31/2007 4 4,967.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/22/1994 5 5,421.6 CAMCO KBUG 1 GAS LIFT DMV BK 0.000 0.0 12/5/1985 6 5,854.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 7 6,287.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0,0 10/22/1994 8 6,724.9 CAMCO KBUG 1 GAS LIFT DMV BK 0.000 0.0 12/511985 9 7,104.8 MERLA TPDX 112 GAS LIFT DMY T-2 0.000 0.0 1023/1994 10 7,205.7 CAMCO KBUG 1 PROD DMY RM 0.000 0.0 4/13/1998 ~~~~ NO. 5203 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Company: Alaska Oil & Gas Cons Comm ATTN: Beth Attn: Christine Mahnken - q ~'~ `~' =k ~' `?~~~~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3F-03 ANHY-00070 INJECTION PROFILE ' - ( ~ 04/04/09 1 1 2D-03 ANHY-00075 PRODUCTION PROFILE _ - 04/10/09 1 1 1E-29 B04C-00030 PRODUCTION PROFILE l 9 04/14/09 1 1 3G-13 ANHY-00079 INJECTION PROFILE _ t/ 04/15/09 i 1 3F-18 604C-00031 PRODUCTION PROFILE / - 04/15/09 1 1 1 D-117 B14B-00027 INJECTION PROFILE ~, . ~'~-- 04/16/09 1 1 1 D-128 AYS4-00057 INJECTION PROFILE 04/16/09 1 1 1 H-21 6148-00028 PRODUCTION PROFILE G 04/17/09 1 1 1 D-120 AYS4-00058 INJECTION PROFILE 04/17/09 1 1 2K-22 AYS4-00059 IBP/SBHP - 04/18/09 1 1 1 E-15 AYS4-00061 INJECTION PROFILE ~ - 04/20/09 1 1 1Y-04 AYS4-00071 INJECTION PROFILE 04/28/09 1 1 3F-02 AYS4-00063 PRODUCTION PROFILE ~ - 04/22/09 1 1 iG-04 6146-00036 SBHP SURVEY '~, C.. ~~ 04/23/09 1 1 1 R-03A AYS4-00063 SBHP SURVEY i } -1_ ~. ~O~ _ ~ ~1 ~ c~ ~ C.~/(o 04/23/09 1 1 1 G-06 8146.00035 SBHP SURVEY ~ ~~ (~~ _ ~~ ~ Q ,v~'~ 04/23/09 1 1 1R-10 6146-00031 SBHP SURVEY - ( ~ c 04/20/09 1 1 2F-02 AYS4-00060 INJECTION PROFILE v L+ - .~~ ( U 04/19/09 1 1 iR-95 B14B-00032 SBHP SURVEY. - ~ '' ~~~[.~/ 04/20/09 1 i 04/30/09 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 3F-02 PTD # 185-226, Notice of fa~TIFL Regg, James B (DOA) ~~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, September 26, 2007 11:06 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: 3F-02 PTD # 185-226, Notice of failed TIFL Attachments: 3F-02 90 day trn 09-26-07.gif; 3F-02.pdf Tom, 3F-02 PTD # 185-226, gas lift producer failed a TIFL yesterday. T/I/O = 175/1050/1220 prior to the TIFL. Immediate action will be to troubleshot the gas lift string. The well has been added to the SCP report. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager {907) 659-7000 x909 n 1617@conocophillips. com «3F-02 90 day trn 09-26-07.gif» «3F-02.pdf» • Page 1 of 1 ''~~~ ~(Z~~c~? ~~~ NCV ~ ~ 2DD7 9/28!2007 • C. file:///C7llemp/Temporaty Imemet Files/OLIt2A/3F-U2 w day [m (Kt26(17.gif J/2g/2oo7 g 1424 AM file!/ICVtemp/I'cmpurary Interact Files/ULK24/3F-112 vll day tm 119-26-07.gif '~~r~ ~ }- _U "Z _ ~~-(, ~ ~ (7 _ ~Z(! ~ • KRU 3F-02 GonocoPhillips Alaska, Inc. . "V ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ...} ...'''; ; . ~,' , September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 \1ó5'- d-~ () <JQno S<;I\NNED SEP () Q ~ v' Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells fronnhe Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043,.,i{you have any questions. // Sincerely, ~./"", ',;,.. ',' ¿ "// ,~//&7~L/ J f M.J. oveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Well Name PTD# Initial Top of Cement Feet Cement Volume Barrels Final Top of Cement Feet Cement Date Sealant Volume Gallons Sealant Date Schlumbepgep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ',,",,,,,,. ~, ',,-.. ~ n rr-, 0, ~:-\ ;-:¡VC. , \ '_ ....l- - '\ ' ,-,r"-'6 \. ."\ ;1,\,. '.-<' '''; ~L~IJ < ,,','._<;;''' C:r, ,~. C':íf¡jf~} ...¥~,\..;:¡- .- ~ -.... - ¡.;êCx¡ëÇS Log Description Date NO. 3831 Company: Field: BL 06/02/06 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 995~ Kuparuk~6""dw \/ e Color CD 1Y-12 l"ð~ -,~~:)c 11235362 INJECTION PROFILE OS/20/06 1 1 L-06 14!ft./-' ~ 11213748 PRODUCTION PROFILE W/DEFT 05/19/06 1 1Q-24 ¡C;,,\- ¡<~)j 11213849 INJECTION PROFILE OS/20/06 1 1 H-04 11S";~ -, c ~ 11213752 INJECTION PROFILE OS/23/06 1 1 H-08 )";>(':' - ~AZ 11213751 RSTIWFL OS/22/06 1 2Z-02 i"K3 - ~';~c 11235362 INJECTION PROFILE OS/28/06 1 1 H-16 r+;J - (z'¡ 11235365 PRODUCTION PROFILE WIDEFT OS/24/06 1 2A-04 ¡ ¿f« - (,""5-' 11213755 CROSSFLOW DETERMINATION OS/26/06 1 31-10 ¡'jV:'-t:;;\1 11213759 PRODUCTION PROFILE W/DEFT 05/30/06 1 1H-19 ìCJ,':)-i:J-7í 11320975 INJECTION PROFILE OS/29/06 1 2A-13 ;."....;.,- _ iLIL 11320976 LDL 05/30/06 1 2Z-04 í*3-cs,Ç 11213757 INJECTION PROFILE OS/28/06 1 2Z-12A I 'ì,;~- - N'8' 1123568? GLS OS/27/06 1 3F-02 fiIIit"" -~( 11213758 PRODUCTION PROFILE WIDEFT OS/29/06 1 c-Lt - Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. R.EC IVED e e o 1 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Repair Well 0 Pull Tubing D Operat. ShutdownD Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Stimulate D Waiver D Goo1minio Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 93' Re-enter Suspended Well Time Extension D D Exploratory Service D D 5. Permit to Drill Number: 185-226 1 ' 6. API Number: 50-029-21447-00 9. Well Name and Number: 3F-02 ' 8. Property Designation: Kuparuk River Unit .A Þ I.- ). fir, f ~ ~ (;·z· () /# 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool ' Total Depth measured 7864' 6303' feet feet feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE PRODUCTION Length Size MD TVD Burst Collapse 110' 3412' 7746' 16" 7" 110' 3505' 7839' 110' 3086' 6283' 9-518" Perforation depth: Measured depth: Intervals between: 7270 - 7666 t 'f' I~. t~jr...t::~~: i:) \o;Iù"t~ tì;; 11c;::.. '"" C: (\ \J true vertical depth: Intervals between: 5841 - 6149 Tubing (size, grade, and measured depth) 2-7/8", J-55, 7451' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL': BAKER 'FB-1' pkr= 7168'; 7428' sssv= SSSV sssv= 1852' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 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: 305-382 RBDMS 8Ft MA V 0 g 2006 Contact McConnell / Loveland rie McConnell ~ Form 10-404 Revised 04/2004 0 RIG I N A L Title Phone Problem Well Supervisor 659-7224 Date 4/26/2006 Signature tY ,.&'þ,$ 'l- Of.. I:J:--Sf'-4. Submit Original Only ~ 3p/CO e 3F-02 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 4/15/2006 Removed conductor from 10' to 17.5' below conductor top, exposing 9-5/8" casing. Found externally corroded casing with a pin hole leak 13' below conductor top as shown in Photo #1. AOGCC inspector John Spaulding waived witness of casing damage. Inspected 9- 4/21/2006 Installed external surface casing sleeve patch over corroded casing from 12' to 18.1' below conductor top. Repaired 3 pits below patch with depostion welds between 18.25' and 18.75' below conductor top. Patch was a 6', 1" long section of 10-3/4", X65 pipe, 0.5" wall thickness, split and welded to surface casing across the corroded casing as shown in Photo #2. 4/22/2006 MITOA to 1800 psi passed. See attached MITOA test report. Installed denso corrosion ... resistant coating on the patch and exposed surface casing from 10' to 19' below conductor toP. 4/25/2006 Patched conductor window from 10' to 18.8'. Conductor will be topped off with cement and r water proof corrosion inhibitor at a later date. MECHANICAL ~EGRITY TEST CMIT) FORM e WELL NO.: 3F-02 I DATE: 14-22-06 WELL TYPE: ¡PROD AIL I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITOA I i.e., Tbg, IA /9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 PSi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: I Diesel R d II W IIh d P b f d d . T t ecor a e ea ressures e ore an urlno es. START TIME: 11530 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)· (PSI)- (PSI)· (PSI)- FAIL S TUBING 0 0 0 0 T IA 0 0 0 0 PASS OA 0 1800 1775 1765 1 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)· (PSI)·· (PSI)· (PSI)·· FAIL S TUBING T IA OA 2 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)· (PSI)·· FAIL S TUBING T IA OA 3 COMMENTS: rise COMMENTS, · Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. ŒJ -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: 10. Sauvageau / B. Rogers cc: PWS 6/3/00 Photo 1: 3F-02 Surface casing external corrosion damage 4-17-06. Photo 2: 3F-02 Completed surface casing patch 4-22-06. e ~1r~1TŒ (ID~ e ~~~æ&\ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ~ \%7/ Î- Re: KRU 3F -02 Sundry Number: 305-382 <';:f~·.c'\¡'i\i!'--¡ . ,';¡: (, . ·.-!'~n'~: 0t.:·j I;.,; 2 J ~005 Dear Ms. McConnell: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. K. 0 Chairman DATED this /~y of December, 2005 Encl. 1. Type of Request: Abandon . V(.J (~'I$. Æ RECEIVED ALASKA OIL AND ~~;~g~S~~~~ON COMMISSION \")/, ~ DEC 1 3 2005 APPLICATION FOR SUNDRY APPROVAL Alash Oil & Gas Cons. Comml..lon 20 MC 25.280 Anchorage Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Perforate New Pool 0 Re-enter Suspended Well 0 Repair well 0 o Alter casing o o o Pull Tubing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 93' 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: 185-226 6. API Number: 50-029-21447-00 9. Well Name and Number: 3F-02 8. Property Designation: Kuparuk River Unit 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk 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): 7864' 6303' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110 SURFACE 3412' 9-518" 3505' 3086 PRODUCTION 7746' 7" 7839' 6283 Perforation Depth MD (ft): Intervals between: 7270 - 7666 Packers and SSSV Type: pkr= BAKER 'FHL'; BAKER 'FB-1' SSSV= SSSV Perforation Depth TVD (ft): Intervals between: 5841 - 6149 Packers and SSSV MD (ft) pkr= 7168'; 7428' SSSV= 1852' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Tubing Size: 2-7/8" Tubing Grade: J-55 Tubing MD (ft): 7451' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: Service 0 January 1, 2006 Date: Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Marie McConnell , Signature Contact: McConnell 1 Loveland Title: Problem Well Supervisor Phone 659-7224 Date 12/09/05 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ~ ,(\ Other: Q,,-~\c,,> ot\-~ CA.c::.\f'.~~~~~ ~~~\.c~\~~E.~~'o~\~J, c.o,,~\--\-~ ~....-.~?~C~ '" ~Q ,S\<è:.~ ~Q: &ö.~'S- u.J~C!."-(ê:( pose;) Form 10-403 Revised 7/2005../ 0 R \ G \ N At· J/Î\, COMMISSIONER e ConocoPhillips Alaska, Inc. e Kuparuk We1l3F-02 (PTD 1852260) SUNDRY NOTICE 10-403 APPROVAL REQUEST 12/09/05 This application for Sundry approval for Kuparuk well 3F-02 is for the repair of a surface casing leak. The well is an oil producer, completed in October 1985. On November 19, 2005, liquids in the conductor were observed while attempting to perform an MITOA. The AOGCC was notified ofthe problem on November 21,2005. The well was shut in and plugged until repaired since the well has known IAxOA communication to gaslift and will not flow without gaslift. Diagnostics on 12/04/05 found the leak depth at 13' I" below the conductor top. The liquid leak rate is 0.68 gpm at 1800 psi. The conductor cement top was found at 21'. CP AI proposes to repair the casing leak by excavating and removing conductor as needed to expose the damaged surface casing for inspection and repair. Damage is anticipated to extend trom the leak depth into the top few feet of conductor cement. Excavation casing repair jobs have historically been scheduled during the summer season when the ground is thawed. CP AI proposes to repair the leak with a sealant product trom the SealTite International Company to return the well to production until the excavation work can be planned and scheduled during the summer. Excavation repair may be attempted this winter season. If excavation repair is completed this winter season, sealant may not be used prior to completion of the excavation repair. With approval, repair ofthe surface casing will require the following general steps: 1. AOGCC approval of the plan to repair the surface casing leak first with a sealant and then with a mechanical repair once excavation can be scheduled. 2. Repair the casing leak with a sealant provided by the SealTite International Company. 3. MIT the repair after sealant operations. 4. Return well to production under a waiver as notice to Operations ofthe presence of the surface casing leak until excavation repair is scheduled. 5. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 6. Remove the floor grate and equipment from around the wellhead. 7. Excavate gravel away from conductor to ~25'. 8. Install nitrogen purge equipment for the OA and conductor so that hot work may be conducted in a safe manner. 9. Notify AOGCC Field Inspector of repair operation so they may witness the event. 10. Remove conductor casing and cement around surface casing for inspection and repair as needed. Conductor removal will start by cutting an inspection window at 13'. 11. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 12. QA/QC the repair and MIT -OA for a final integrity check. 13. Install anti-corrosion coating to exposed surface casing. 14. Replace the conductor and fill the void with cement and a water proof sealant cap to seal out water and oxygen. 15. Backfill as needed with gravel around the wellhead. 16. Remove plugs and return the well to production. 17. File 10-404 report of repair with the AOGCC. NSK Problem Well Supervisor 04/25/05 e ConocoPhUUpsAlaska, Inc. 3F-02 1'[,', {71'':'4-71~:: 00 ~ ~::::::, t=J ~>(H (7~t:¡;-7 ;¡:;::, OJ fi ':·t:) B)'" : ..I ('i¿.~C .··::fJ~ SL! I ','E-O ~741:~ !'414 O)2 ¡¡:or.; IJ& . nŒIf\.;G :(j "'4"f 0;;::: ~J .:; ¿ ~~~)} I'KR i,;4/H i4Z; OIH~ 11:'f} 'dF-' (:·~·~:::-;~44 OOL :;';':", D Tl}¡!II'JC .741<' "'.1" . ...~ C!..:;; 1:·~ .:; ¡. .~.: 1:. ;-'~11 I ; ~.~ii·ïf.0L; ro:::-.-I' 17{'¡;.1 ¡f·f.f.¡ ." e KRU 3F-02 .. Completion: Annular Fluid: LastW/O: Rev Reason: Tag, Set DMYs, Pull Pluo, Set BPC Reference Log: Ref Log Date: Last Update: 10/28/2005 Last Tao: 7590 TO: 7864 ftKB I I .. lflRt TfI!J Date. 10142005 . Casing String - ALL STRINGS . Description Size CON[)UCTor~ 16.000 SUI~FACE 9.67!> I PRODUCTION _Z...D00 Tubing String - TUBING Size To 3.500 0 2.875 741.6. : Perforations Summary I I TVD nterva one latus t ate Iype omment 7270 - 7390 5841 - 5934 4,C-3,C-2,C 120 12 11/30/1985 IPERF 5" Cso Gun; 120 deo ph 7561 - 7570 6067 - 6074 A-4,A-3 9 4 11/30/1985 IPERF 4" Cso Gun; 90 deo ph 7570 - 7600 6074 - 6097 A-3 30 8 4/10/1998 RPERF 2 1/8" Enerjet Bighole; 0 deg ph, 0 deg orient 7600 - 7602 6097 - 6099 A-3 2 4 11/30/1985 IPERF 4" Cso Gun; 90 deo oh 7624 - 7666 6116 - 6149 A-2 42 4 11/30/1985 IPERF 4" Csg Gun;. 90 deg ph Gas Lift MandrelsNalves St . 'MD TVD' Man :'Man Type V Mfr Mfr 2272 Camco 3351 Cflmco :11111\' Cfll11CO 1\ 1:1/' Cflmc:o ·11\6:1 Cflmr:o 477!! Camc:o 50fl6 Curneo 5424 Cameo 1105 5713 Merlu TPDX 1. NOTE- Trash beside latch 4/20/1998 Production MandrelsNalves St MD TVD' Man Man Type V Mfr V Type Mfr 10 7206' 5791 Cameo KBUG Other (plugs, equip., etc.) - JEWELRY Depth TVD. Type 1!!52 1!!1!) SSSV 7154 5/!>1 PAR /168 5762 I'KI~ /1\1:i 5952 NIP 7413 5952 SLli'VE-O 7428 5964 I'KR 7443 5976 NIP 74S0 59!!1 SOS 74S1 5987 rTL Fish - FISH Depth Description /699 SlY".· uf Grapple & Wn¡¿¡ General Notes Date Note 7íR!2002 'WAIVI HE:D WELL IA X OA COMMUNICATION APi:' -500292144700 SSSV T ypë· . LOCKED OUT Well Type: .PROD. . m___..._...___ Angle @ TS: .39 deg «1) .nfi~ Orig 10131198!'> Angle> @ TO' 39 deg @ l864 Max Hole Angle. 46 deg @ 3800 Top o o o Wt 62.50 :16.00 26.00 Grade Thread H-40 . .'-!is . L. J-55 I Bottom 110 3S0S 7839 TVD 110 3086 6283 Thread 8RD EUE 8RD EUE z T C F SPF S o V OD . Latch TRO ." Vlv Cmnt Port (1) V 00 Latch Port TRO Date Vlv Run Cmnt o 4/13'1998 Closed DMY o~ooo 1.0 RM Description Carnc;o 'TRDP-1 A-SSA'. Loeked uut Fluppur unly 5/25/9!!. l:3aker Baker 'FHL' AVA BPL Landing Nipplo OSB AVA 2.75" III'C sleeve Ret 10/1Sí20n5 BakfJr HI-I' Curneu 'D' Nipple No-Go Camco 10 2.813 3.000 3.000 7./50 2.:HO :1.000 2.2S0 2.4:i8 2.43!! Comment Still in hole from 4/1/94 Re: Proposed Sealtite Repair 3F-02 (185-226) e '~... e Subject: Re: Proposed SeaÏtite Repair 3F-02'{! 8~-226) From: Thomas Maunder <tom...:. maunder@admín.state.ak.us> Date: Thu, 15 Dee 2005 15:03:04 -0900 To: NSK1Ì;oblem WellS:ií'Þy,fhY617@£onó~pphîl1ips.com> Jerry, Thanks for the further information on your application. My questions have been answered. I will endorse your application and move it forward to the Commissioners. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/15/2005 2:57 PM: Tom: I am just getting caught up on emails. 1. 0.68 gpm is considered a fairly small leak rate, the test pressure was at 1800 psi. This indicates a very small hole with high differential, making it suitable for a SealTite repair. We have successfully plugged this type of hole up to several gallons per minute so are well within the range of the product limits. Our longest success so far is 2E-14, first treated in May 2003. That well had 1.5 gpm rate and is still holding up. We have had a few of these break down too, but the intent here is to keep the well on line until an excavation can be made for a permanent repair. 2. This well has been waivered for IA x OA communication, due to lift gas leaks through (most likely) the packoff assembly. The well requires lift gas, so we need to have the surface casing barrier to have the well in service. A six month trend is attached up to the point the casing failed. The OA will operate pretty closely to this trend plot. 3. We have been having serious discussions in the last few days about doing a surface casing excavation this winter. The conductor cement top is about 20 feet, and we located the hole about 13 feet. Our expectation is that there is likely damage down to the cement top so that entire distance must be uncovered. If we keep moving on that option it will happen in the February or March time frame. I don't know at this point if we will try to get the SealTite done prior to that or just hold off until we excavate. This will be a first for winter excavation, but could be considerably better since we should not have water encroachment issues. We will keep you posted as we go along. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 lof2 12/15/20053:05 PM Proposed Sealtite Repair 3F-02 (185-226) , " e e Suh,ject: Proposed Scaltite Repair 3F-02 (185-226) From: Thomas Maunder <tom_ maunder@admin.slalc,ak.us> ()~,tc: Tue, 13 Dee 1005 10:26: 1 0 -0900 To: \iSK Problcm Well Sup\' <NI617@collocophillips.eom> cc: Jim Rcgg <jim .regg@admin.state.ak.us> Marie, I am reviewing the sundry submitted to repair the external leak on the surface casing and have a few questions. 1. .68 gpm seems to be a "large" leak. Has any comparable leak been "fixed" using Sealtite before? If so, has the repair held up? 2. You indicate that the well has known IA x OA communication to gas and the well needs gas-lift to produce. What is the OA pressure history? Do you have TIO information? What is the expected pressure in the OA when producing? Thanks in advance for your replies. Tom Maunder, PE AOGCC 1 of 1 12/13/2005 10:46 AM Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# / Ý!-6S'i 1A-01 J3j- 27[, 3F-09 /~. '-D2<ff' 3N-07 IC¡-;~ /If 0 1 G-13 /C/fS ~Z~~ 3F-06 /35- 0 II·" 2W-03 I ::x - fA -3F-02 fJJ - 2 ~ 'f/ 1 E-114 L 1 ;<0'1 - IIf 1/ 10922488 10922490 10922491 10922487 10922489 10942791 10942790 10687709 Log Description Date NO. 3267 Com pany: 11/19/04 l~-~-Jp Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL 1 1 1 1 1 1 1 ~;: J í sr;;;/Ur! }Im/~~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG PROD PROFILE/DEFT USIT 11/08/04 11/10/04 11//11/04 11/07104 11/09104 10/30/04 1 0/29/04 10/07/04 ~3CÞJ~NED !-\PR 1 5 2005 DATE: .~ Color CD 1 --- /~þ /0 'i ~ STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COMk .,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate_~ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 16. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 93' RKE 3. Address: Exploratory ___, 7. Unit or Property: P.O. Box 100360 Stratagrapic __., Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 14. Location of well at surface: 8. Well number: 78' FNL, 139' FWL, Sec 29, T12N, R9E, UM 3F-O2 At top of productive interval: 9. Permit number/approval number: 1269' FNL, 1514' FEL, Sec 29, T12N, R9E, UM 85-226. At effective depth: 10. APl number: 1348' FNL, 1093' FEL, Sec 29, T12N, R9E, UM 50-029-21447-00 At total depth: 11. Field/Pool: 1363' FNL, 1148' FEL, Sec 29, T12N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7864 feet Plugs (measured) None true vertical 6302 feet Effective Depfl measured 7750 feet Junk (measured) Trash beside latch @ 3874' true vertical 6213 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 270 Sx AS I 110' 110° Surface 3465' 9-5/8" 980 Sx PF E & 3505' 3086' 400 Sx PFC Production 7802' 7" 450 Sx Class G 7839' 6283' Uner Perforation Depth , measured 7270'-7390', 7561'-7602', 7624'-7666' true vertical 5841'-5934', 6067'-6069', 6116'-6149' .. Tubing (size, grade, and measured depth) . i'~.i.~.': ~',i~ ,-;!; :' :i ' ' ' L'.: -. . · 3-1/2", 9.3 Ib/ft, J-55 @ 7416' & 2-7/8" 6.5 Ib/ft J-55 @ 7451' Packers and SSSV (type and measured depth) Packers: Baker FHL @ 7168 & Baker FB-1 @ 7428'; SSSV: Camco TRDP-1A-SSA @ 1852' · 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 4/17/98. Intervals treated (measured) 7561 '-7602', 7624'-7666' . , Treatment description including volumes used and final pressure Pumped 184,243 lbs of 16/20 and 12/18 ceramic proppant into fdrmation, fp was 6200 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Both Sands Prior to well operation 717 458 3000 1210 194 Both Sands Subsequent to operation 929 656 3212 1207 2130 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~~ Title: Production Engineering Supervisor Date ~/g,2.,/~' al Form 10-404 Rev 0 ~88 SUBMIT IN DUPUCAT~ APl(JO AmasKa, mnc. . m . ELL SERVICE REPORT K1(3F-02(W4-6)) WELL ~J~)B SCOPE JOB NUMBER 3F-O2 FRAC, FRAC SUPPORT 0407981012.4 DATE DAILY WORK UNIT NUMBER 04/1 7/98 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes ('~ NoI (~) Yes O No DS-YOKUM JOHNS ESTI MATE KD2028 230DS36FL $132,848 $162,874~,,g~'-~'~ ~c~'- Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann ~ Initial Outer A-~n ' ~ Final Ol~te~y'Ann 1043PSI 0PSI 500PSI 500PSII 800PSII "" 800PSI DAILY SUMMARY PUMP "A" SANDS FRAC, WITH 184,243# PROPPANT TO 10.5# PPA, 12/18 IN PERFS. SCREENED OUT JOB, LEFT 20,000~ PROPPANT IN PIPE. ( JOB DESIGN 260,000#) TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP. , HOT OIL PUMP AND APC VACUUM TRUCK. 07:50 HELD SAFETY MEETING , TALKED ABOUT BREAK UP CONDITIONS 08:11 PRESSURE TEST TREATING LINE TO 7900 PSI. 08:29 PUMPED BREAKDOWN , SCOUR STAGES AND FLUSH. 30 BPM TO 15 BPM. MAX PRESSURE AT 30 BPM 7123 PSI. 12,000# 16/20 FOR SCOUR AND FLUSHED WITH 102 BBLS SEAWATER. 09:38 PUMPED DATA FRAC AND FLUSH , 5 TO 15 BPM ,.4678 PSI . FLUSHED WITH 82 BBLS SEAWATER. SHUT DOWN FOR ISIP, AND CLOSURE CALCULATION. 10:42 PUMPED 450 BBLS PAD WITH 50# GEL 5 TO 15 BPM AND 4783 PSI. . 11:22 PUMPED 15,439# OF 16/20 PROPPANT AT 2PPA, 15 BPM AND 4476 PSI. 11:35 PUMPED 181,809# OF 12/18 AT 2 TO 11#PPA , 15 BPM, SCREENED FRAC OUT WITH. 184,234# ..i PROPPANT'TO 12/18 , 10.5 PPA AT PERFS . MAX TREATING PRESSURE , 6200.PSl. SHUTDOWN , RDMO.. ~:' ; SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,195.00 i , APC $8,000.00 $12,934.00 ARCO $500.00 $500.00 DOWELL $121,148.00 $126,271.00, HALLIBURTON $0.00 $5,798.00 LI'I-i'LE RED. $3,200.00 $6,200.00 SCH LUMBERG ER $0.00 $9,976.00 TOTAL FIELD ESTIMATE $132,848.00: $162,874.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Oth e r 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 78' FNL, 139' FWL, SEC.29, T12N, R9E, UM At top of productive interval 1269' FNL, 1514' FEL, SEC.29, T12N, R9E, UM At effective depth 1348' FNL, 1093' FEL, SEC.29, T12N, R9E, UM At total depth 1363' FNL, 1148' FEL, SEC.29, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7864' 6302' feet Plugs (measured) feet NONE 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well r~umber 3F-02 9. Permit number/approval number 85-226 10. APl number 50-029-2144700 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7 7 5 0' true vertical 6213' feet Junk (measured) feet ~ Casing Length Structural Conductor 73' Surface 3 4 6 5' Intermediate Production 7 8 0 2' Liner Perforation depth: measured 7270'-7390', true vertical 5841 '-5934', Size 16" 9 -5/8" 7" Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 7416', 2-7/8" 6.5# J-55 Packers and SSSV (type and measured depth) Cemented 270 SX AS II 980 SX PF E & 400 SX PFC 450 SX Class G & 200 SX PFC 7561'-7602', 7624'-7666' 6067'-6069', 6116'-6149' @ 7451' Measured depth True vertical depth 110' 110' 3 5 0 5' 3O86' 7839' APR - 6 1995 0it & Gas Cons. Commission Anchor[. SSSV: Camco TRDP-1A-SSA @ 1852', PACKERS: Baker FHL @ 7168', Baker FB-1 @ 7428' 13. stimulation or cement squeeze summary 'C' Sand Marcit profile modification Intervals treated (measured) 7270' 7390' Treatment description including volumes used and final pressure Pumped 2545 BBL X linked polymer. Max Concentration = 4500 PPM. Final WHTP = 1370 PSI 14. Representative Daily Average Production or Injection Dat~l OiI-Bbl Gas-Mcr Water-Bbl Casing Pressm'e Tubing Pressure Prior to well operation 212 1605 6705 1275 140 )eration 452 1190 4836 1100 140 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector __ Daily Report of Well Operations __ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service ,~/,(,~. I~. _~J/....~Title Sr. Petroleum Engineer Form 10-404 Rev 09/12/90 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~,,,.,I~UPARUK RIVER UNIT fi, PR - 6 tW~ELL SERVICE REPORT WELL DESCRIPTION OFWORK 'At~.S~, Uti & Gas Cons. Commission DATE CONTRACTOR/KEY PERSON AFC/CC DAY OPERATION AT REPORT TIME FIELD EST: ACCUMULATED COST ~-~ [[~OMPLETE [--] INCOMPLETE $ 4',~J Z. % $ q :~, O~ TIME LOG ENTRY PAGE 1 OF lEVco ~O~PIKIG SE:co ?P'~ 5T/N~F_ AT ~/d._h t::~t .) ~=_,CO '~PO, ToD L -z~ZZ) PPI'-'~ S I--~ F__ V QLLi r.:'\ ~ ~OC:L.b E t5 L5 1 F'~ I ~, Zoc:o ~Pr", I I~1.5 !~45 [~/CHECK THIS Weather Report AR3B-7031 ~_ t)/ul P t...C TI 0 I,..~. BLOCK IF SUMMARY CONTINUED ON BAcK REMARKS CONTINUED: ~"1 ~ AL ~ ¢'-~'z. · I baA',/ n___c)~r__..c-~_x-rP-._A ~---/o~ 4-5c:~ PPt,-,f. It,J,_1 ~i rT~ AG~ SERVICE COMPANY Jz;~E1J ICLt ~ 'T,Z_ T>, '-- SCA # DA I LY' ACCUM. TOTAL ~LOP¢_ -FE::K. ;" P..,': ' '" '-'-': '__ ~f.( ,....'C¢'~'-L~ ! -"' b-'l ~ ~ (]... "~ ~ ~ ._, ©TI4 E-rE SIGNED t;::)A ~ L'.,,.¢ 'TD-F-A.L TOTAL F! ELD ESTI MATE ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 October 12, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is and Application for Sundry Approval (Form 10-403) and in duplicate a Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. FORM WELL ACTION 10-403 3F-02 10-404 1H-12 Other(Profile modification) Inj Valve Waiver If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (atch only) RECEIVED OCT 1 4 1994 Alaska Oil & Gas Cons. Commission Anch0ra~e ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension Stimulate -- -- Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 78' FNL, 139' FWL, SEC.29, T12N,. R9E, UM At top of productive interval 1269' FNL, 1514' FEL, SEC.29, T12N, R9E, UM At effective depth 1348' FNL, 1093' FEL, SEC.29, T12N, R9E, UM At total depth 1363' FNL, 1148' FEL, SEC.29~ T12N, R9E, UM 12. Present well condition summary Total Depth: measured 7 8 6 4 true vertical 6 3 0 2 feet feet 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3F-02 9. Permit number 85-226 10. APl number ~0-029-2144700 11. Field/Pool Kuparuk River Field/Pool Effective depth: measured 7750 feet true vertical 6213 feet Plugs (measured) NONE Junk (measured) NONE Casing Length Size Cemented Structural Conductor 7'3' 1 6" 270 SX AS II Surface 3465' 9-5/8" 980 SX PF E& Intermediate 400 SX PFC Production 7802' 7" 450 SX Class G Liner Measured depth 110' 3505' 7839' True vertical depth 110' 3086' 6283' Perforation depth: measured 7270'-7390', 7.561 '-7602', true vertical 5841 '-5934', 6067'-6069', Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 7416', 2-7/8" 6.5# J-55 @ 7624'-7666' 6116'-6149' 7451' 0CT 1 4 1994 Alaska Oil & Gas Cons. Commission Anch0ra~e Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA @ 1852', PACKERS: Baker FHL @ 7168'~ Baker FLY-1 @ 7428' 13. Attachments Description summary of proposal X~ Detailed operation program _ Profile Modification using MARCIT Treatment. 14. Estimated date for commencing operation 115. Status of well classification as: November 1994 I Oil X Gas _ 16. If proposal was verbally approved Name of al)prover B. Wondzell 10/10/94 Date approved Service 17. I hereby certify that the foreg~ng is true and correct to the best of my knowledge. Signed~ ~-~ ~'~ Title Wells Superintendent FOR COMMISSION USE ONLY BOP sketch Suspended Date //~'/'~/~,~'~5" Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance__ Mechanical Integrity Test_ Subsequent form require IApproval No. , Approved by order of the Commission Form 10-403 Rev 06/15/88 jriginal Signed By W. Johnston Commissioner Date ~' O//(~/~ ~ SUBMIT IN TRIPLICATE ,.~"~,ved Copy R~turned ARCO Alaska, Inc Date: October 8, 1994 Internal Correspondence ~~ File Code: Well File 3F-02 Subject: From/Location: Well 3F-02 MARCIT Treatment G. Targac NSK-22 RECEIVED Telephone: To/Location: 659-7871 T. Johns/S. Bradley M. Dunn/J. Golden NSK-69 (2 copies) NSK-69 OCT 1 4 1994 Alaska 0il & Gas Cens. Cgmmissl0n Anchorage Attached is a recommended procedure to pump a MARCIT treatment in Well 3F-02. MARCIT is the acronym for MARathon Oil Company's C_.onformance Improvement Treatment and consists of a polyacrylamide crosslinked with chromic acetate for' treating conformance problems in both injectors and producers. The MARC;IT gel technology was selected based on gel chemistry, controllable gellation rates and field successes in treating both fractures and matrix. A similar job was performed in October. 1993 on Well 2W-12 that successfully reduced the producing WOR from 34 to 5~. Three differences in this job versus the 2W-12 job is: 1) 3F-02 treatment is nearly 6 times the 2W-12 treatment volume, 2) 3F-02 concentrations are -1/3 to 1/2 of the 2W-12 concentrations, and 3) gel in 3F-02 is non-selectively placed in the C Sand by bullheading, 2W-12 utilized coiled tubing and a packer. The non-selective placement of the gel necessitates the first two changes. The chance of success should improve by placing a deeper treatment with a thinner gel due to the pressure differential acting over a larger area. BP research in Sunbury has performed core experiments with the proposed system and Kuparuk conditions (permeability contrasts) and show favorable water shutoff results. ARCO Prudhoe · has pumped two successful Marcit treatments in producing wells shutting off 1000- 2500 BWPD with average incremental oil rates of 250 BOPD. Well History Well 3F-02'is a selective single completion currently producing from the A and C Sand at 5200 BFPD (96% WC) with a formation GOR of 650 scf/stb with minimal response from the C Sand WAG on Drill Site 2W. With the current tubing hydraulics, the A Sand is hydraulically shut-in (A Sand reservOir pressure is lower ~'than the current flowing bottom hole preSsure). The A Sand was stimulated in 1993 ~..with a post-frac rate of approximately 200 BOPD with no water. The Iow rate has ~been attributed to a lack of A Sand pressure support. The production plot for Well 3F-02 is shown in Figure 1. Execution The planned volume of the MARClT treatment is 5500 bbls of gel with concentrations of 3000, 4500, and 6000 ppm. An optional 500 bbl 4th stage with 1Memo from G. W. Targac to J. A. Walker titled: "Kuparuk Intra-C Sand Profile Modification Synopsis" dated May 30, 1994. Well 3F-02 MARCI.T Ti..,~ment Page 2 ' October 8, 1994 9000 ppm of. polymer may be added: The DDG skid will be utilized to gel on the fly. By gelling on the fly, gel volume (and concentrations) can be modified accordingly to react to the reservoir response.- Also, exposure to a large volume of waste is greatly reduced. The estimated cost for this job is $85 M with the breakdown shown in Table 1. Tentative rig-up day should be scheduled on November 2. The 5500 bbis of gel is designed tO treat a minimum distance of 60', assuming radial flow. With a fracture system'near the well, the fractures should carry the gel deeper~t~a..~ 60' to a point where drawdOwns are considerably less than near V~ellb'ori~;-! ~e New Chemical Evaluations (NCE) forms fOr the polymer and cross- linker are attached for your reference. Any unused gel can be neutralized and injecte~l into the contaminated fresh water facility at CPF-1. Econ~SmiCs The-lb:~'t lifted weiltest-indicated an 'oil rate of 212 BOPD with 6705 BWPD for a WOR of 31.6. The goal of this treatment is to reduce the water relative permeability of the C1 Sand. If achieved, the Marcit job would eliminate over 3000 BWPD coming from the C1 zone and would allow the C34 zone to produce commingled with the A Sand. The following benefits were identified for a successful gel squeeze in Well 3F-02: 1) reduced water production and associated chemical costs, 2) increased recovery from the C34 Sands, and 3) application of this technology to other wells throughout the field. The project was viewed as recovering additional reserves only and a rate stream was generated from the type'curve model and adjusted for facility limits. No value was assigned to benefit #1 or'benefit #3. History matching the well performance was done using MacSnap with the match parameters shown on Figure 2. The post MARCIT rate from both A and C Sands was estimated by increasing the skin factor on the C1 Sand from -3 to 100. It was assumed the C34 would be slightly damaged.with the skin factor increasing from 0 to 10. Figure 3 shows the resulting rate with a deeper gas lift design yielding 2400 BFPD with a 80% watercut (480 BOPD). Using a 60% chance of success, the initial incremental rate is expected to be 200 BOPD for an additional recovery of 278 MBO over an 8 year period (expected life of gel). Based on $85,000 cost and a 60% chance of success, the economics for the project are a present worth of $365 M and an investment efficiency of 11.4. A sensitivity to expected life was performed assuming a 1 year project life with a resulting PW of $94 M and an IE of 2.9. All charges should be booked to the cost tracking AFC #KD3406. questions or comments, please contact me at the above' number. If you .have any Attachments: Procedure, Cost Estimate, Contacts, Figs 1-3, NCE sheets, Well Schematic xc CPF-3 D.S. LT NSK-22 Jones/Marquez~4~ NSK-22 DSO - 3F: NSK-22 Sanchez/Ligenza NSK-22 Archey/Mazzolini NSK-22 Erin O'Brien-Authier ATO-12 S. P. Kruse NSK-22 Mike Curley ATO-12 Well 3F-02 MARCI.T Treatment Page 3 October 8, 1994 Well 3F-02 MARCIT Job Charge Code: KD3406, SCA Code: 10X17 Pre-Job Slickline 1. MIRU slickline unit. Displace well with 65.bbls of diesel. Run 2.25" SV to Camco 'D' nipple @ 7443' MD-RKB. Pull OV's @ 2417' and 7105' MD-RKB and GLV's @ 4967' and 6287' MD-RKB. . Pull commingling sleeve and set blanking sleeve in AVA nipple at 7413' MD- RKB to isolate C Sand. Pressure test tubing to 2500 psi. Expected pump pressure during the MARCIT. treatment is not expected to exceed 1500 psi. . Puli blanking sleeve from AVA nipple and run a 'BCP' to open C Sand. Leave SV in well as a pre-caution for a leaking BCP to prevent gel damage to the A Sand. . RDMO slickline unit. Inform DSO to leave well Si for.24 hOur WHPFL. After fluid level is obtained and verified, open well to production until skid arrives on location. MARCIT Treatment 1. Prep piping prior to skid rig-up. MIRU DDG skid. After rig-up is complete, contact CPF-3 safety specialist (Sanchez/Ligenza) to conduct a safety orientation for Mol personnel. e Prior to mixing polymer, set treating pressure at -700 psi and adjust as necessary to achieve a rate of I BPM. If system process checks okay during the first half-hour, begin pre-mixing 1% polymer using -60° F seawater during the remainder of pre-cool. Start polymer injection at 1 BPM with the polymer and chrome concentrations shown below. Initially, sample every hour for the first 4 hours and place in 150°F water bath to ensure cross- linking. Afterwards, sample every 4 hours to job finish. Shutdowns should be avoided during pumping due to excessive friction in re-initiating gel movement (especially in Stages 3 & 4). Polymer Specification is Alcoflood 935 with an intrinsic viscosity of 13 (+1) and 9% hydrolysis. Chrome acetate Dilute chrome acetate 10:1 with fresh water and,load into~crosslinker storage tank (Important: ensure adequate mixing of water an§ al'ross-linker). ?. Stage Volume,~ bbls Poly conc, ppm Chrome Acetate, ppm 0 ~ ~90 Seawater Pre-cool I ~2000 "- 3000 4000 (Ratio 44:1) 2 3000 4500 7500 (Ratio 55:1) 3 500 6000 10000 (Ratio 55:1) 4 (Opt) 500 9000 17800 (Ratio 77:1) 5 40 300O 0 6 60 Crude * 7 60 Diesel · Crude should be pipe-line spec and will be @ -125° F. Well 3F-02 MARCI.T Ti,;~,tment Page 4- October 8, 1994 . Expected pump pressure at 1 BPM is 700 psi. Final expected pump pressure is 1400 psi. Maximum pump pressure (with a seawater gradient) should not exceed 1500 psi. Lack of squeeze pressure may require pumping the optional. Stage 4. Adjust volumes as necessary and overflush treatment with Stages 5,6 and 7. The crude overflush is important to ensure communication with the oil-bearing zones. . RDMO DDG skid and ensure ali gel filters and any excess gel are properly disposed. Any unused gel can be broken with 4 pounds per barrel of lithium hypochlorite mixed with 150°F seawater. This fluid can then be injected into the contaminated fresh water facility at CPF-1 (marked for EOR on disposition). . Leave well Si for 5 days. After 5 days, initiate flowback with a maximum flowrate of 2000 BFPD for 3-4 days and obtain a .welltest. Open choke fully after 4 days and re-test. A follow-up slick-line procedure will be forwarded after the C Sand testing is complete and will include a gas lift design. Well 3F-02 MARCI.T Treatment Page 5 October 8, 1994 TABLE I COST ESTIMATE Charge Code: AFC #KD3406 Pump Time ~ 4 Days Slickline Pre- and Post-Job $9,000 Mol Drilling DDG skid manpower $12,500 Polymer: 9900 lbs @ $2.23/Ib $22,000 Chromic Acetate: 2200 lbs @ $3.64/Ib $8,000 DDG skid piping mods DDG skid computer mods Marathon royalty 250 kW generator hookup Skid moving $4,500 $4,000 $3,000 $2,000 $1,5oo Veco Labor (hammer pipe) Pump Truck Vac Truck Crude/Diesel $6,000 $1 ,ooo $1,000 $500 Allocations Contingency Total Estimated Cost $2,000 $8,0oo $85,ooo Upper Limit (+25%) Lower Limit (-25%) $106,25O $63,75O Upper limit includes any CTU work Lower limit includes using less chemicals/skid time OCT 1 4 199a' oil & GaS Cons. Gom~ss%ot~ Page 6 ' . - . i:-:.:~:. ,. October 8, 1994 TABLE 2 Telephone/Radio/Pager~ Contacts for Mo! Drill Site 3F Operator Radio - 338 on Channel 6 CPF-3 Control Room Radio - 320 on Channel 6 Phone - 659-7444 'CPF-3 Drill Site Lead Tech Radio - 330 on Channel 6 Phone - 659-7442 Voice Pager - 182 Well-Supervisor, Tommy Johns 'Office Phone - 659-7221 Voice Pager- 906 Room Phone - 659-3181 Drill Site Engineer- Gary Targac Office Phone - 659-7871 Voice Pager- 328 Room Phone - 659-3422 Radio - 343 on Channel 6 Drill Site Supervisor- Ron Marquez Office Phone - 659-7765 Voice Pager- 208 Room Phone, 659-3062 Radio - 303 on Channel 6 KUPARUK RIVER UNIT 10000 1000 100 Well 3F-02 Well Test Data .................................. ! ......... : .................... ~ ............................ ' r ........................ ~:::::::::::;:::; ................. ~ ..................................... : - . ============================== ............................... t ........................... ~ .............. ~ .................. ~ ............................................................ ................ !1 ............... ' ............. ~' ............. ~ .................................. ~ .............................. " .... ....... "'"~ I~ ............. ......... ~ .... ::,,:::::::::::::::::::::::::::::::::::::::::::~::::::::~ ......................... ! .................................. i ........... ~~,~ ............. .!~ ! .... ! . , ! ! ., ............... tl ............... ' .................................. ' ................................... ~ .................................. ' ........... t'::::~::::::::::: ............... /! .... ',"'"'i':; ......... . ..... ;"~ ....... . ...... i ................. :'~ ............... ! ............. ,"': ................. i ............ ~ .............. 10 · · ~e · · 2500 , , , , 2000 ................ ~ ................................... ~- ' : : : , 1500 ......... ~ .............................. ~ ', ', 500 ............... ' ~ I · 80 ' 0 ................................. I ................. 4O I · ! ! e Water Rate ! 3F-02 Ma;cit Evaiuaii'on ~F-02 A/c Match .... ' 24-Sep-94 15'28 Reservoir Data Wellbore l~essuru ~. :]200 D(:l)tl~ (Mt.)) ~ 7539 WI I I.hus. = 1UO Perm. = 20.000 + Tubing I.D. = 2.992 + Skin = 0.00 +. TGLR = 29 3 2 50 ....... : ........... ~ .......... ; .......... ~ ........... : .......... ~ .......... ; .......... ~ ........... : .......... ; .......... : ........... ~ ........... ~ ....... , ........... ;-"~ L e g e n d ~ : .... IPR Cu~e:. : ~ ...................... ~ , I ...... ~~' I' ........... ~ ........... ~ .......... .~,~.,?, -~~~.~I .................... a . , : ~ : i : i ~-~ /- , . / ~/ . ~ - -Base 3000 ....... ~ .......... ~ .......... ~ .......... { ........... ~ .......... { .......... ~ .......... ~ ........... ~~ Tubing Cu~e: ~ : I : t : i : i , ~ ~ : ~ /~ i : i (scf/bbl) ,_ ' t · , ~ · . ...... . i . ~ ...................... t ............ , ........... t .................... = . 1 - 29.000' ~ ' , ' t ' , ' . . : ~ 2 120.000 ~ : , : ~ : ~ : 3 - 160.000 ~ 2750 ~ ...... : .......... ~ .......... ; .......... i ........... : .......... ~ ......... ~--t ........ i 4 - 230.000 ..... : ........... :...: ....... : ..... ~...~~ .....~ ~ ~ .......... ,' .................... 1~ .......................................................................... ..... ................ ~-~ ..... ~ ..... ~ ..... I ...... i ..... i--' ~' "~ ~ 22so ....... ~ ...........~ .......... ~ .......... ........... ~ .......... ~ ..... ~-.-+ ....... : ~ : t : ~ , 0 1000 2000 3000 4000 5000 6000 7000 8000 To~al Liquid R~te (stbfld) R ~/~R'~c .CZ' zo o zl' ,o - 3 0 '-~53' t4 I~: ctT '~100 3F-02 Marcit Evaluation 3F-02 A/C Post Merci! 25-Sep.94 16:17 Reservoir Data Wellbore Pressure = 3200 Del:)~ (MD) = 7539 WH Pres. = 180 Perm. = 20.000 + Tubing I.D. = 2.992 + ,Skin = 10.00 + Gas Rate = 800 4000 I ' .... : ........... ' ....... i i i i .... ~ Legend ~ . ~ · : ' i IPR Curve: ........ '~ 3000;~-.A _~ .... i ! i ! i i i Tubing Curve: el 2000 ..... : ~o "' .......... E' lOOO · .: 0 1000 2000 3000 4000 Total Liquid Rate (stbf/d) 3F-02 Marcit Evaluation '3F-02 A/C Post Marcit 25-Sep-94 16:17 Reservoir Data Wellbore Pressure = 3200 Def~ (MO) = 7539 WH Pres. = 180 Perm. = 20.000 + Tubing I.D. = 2.992 + Skin = 10.00 + Gas Rate = 800 i t i 40'00 i - ~ - ~ - i · -: - i . i-'-"~. ....... : r, egond i i i i i i ' iRECEiV Di i ii ' ~ i ...~i ! i i Alaskii Oil & Ga~ Con~ CoJnmis~ion i . : i .'~,~ai : ! : i :_ -:. .' : __ ..... i..~....."...~ .... i ..... .'" ..... i ..... [ ..... i.fin.~or~e....." ..... : ..... i. =I : ~ : ! : " : i : i : ! : , .~0 : ! : : i : i : ~ 1000 t-"-"-:,~ ~ - ; . · : · : -, ~ - : :: :: i : ......... 0 1 O0 200 300 400 500 600 700 800 OIL Production Rate (stbo/d) ~',~. lU REVIEW DATE: October 20, 1993 -. NEW CHEMICAL EVALUATION HEALTH & SAFETY CONSIDERATIONS TRADE NAME: ALCOFLOOD 935 DISTRIBUTOR/: MANUFACTURER HAZOX MSDS #: MSDS DATE: Allied Colloids PO Box 820, Suffolk, VA 23434 Fire 1 AAI03955 Health 0 4/1/91 Reactivity __0__ DESCRIPTION OF USE The product will be used for squeeze application in production and injection wells. It will be mmecl into solution with a cross-linker. physical Hazard; Fire: Heavy concentrations of airborne dust can result in an explosive mixture in air. The product is very slippery when mixed with water. · PERSONAL PROTECTIVE EQUIPMENT · Eve ProtectlOl~; Chemical goggles should be worn when using this product. · Goggles, Chemical Soft-sided 123 2347 Vented, padded 297 2026 · Face Shield 194 0341 Headpiece 194 0333 Portable or plumbed eyewash units must be within 10 seconds travel time at every location where the product is used. · Portable Eyewash 162 9018' *Multiple required to meet minimum 15- minute flush time. Use nltrile gloves to prevent skin contact when handling this product. Avoid contact with strong acids and oxidizers such as chlorine, hypochlorites, peroxides, nitdc and sulfuric acids. CorrosIvene~: -.. Not corrosive. ' Health Effects: The following summary is based on information in the literature on individual components as well as information provided in the MSDS. Primary routes of exposure: eye contact, InhalatiOn This product contains: Copolymer of sodium acrylate and acrylamide in powdered form. The product is considered a nuisance dUst...~Heavy 'aiH3°me concentrations may cause minor irritation of eyes, nose, and throat. This product may cause irritation of the'eyes: nose, and throat if high a concentration of airborne dust is present. ' High dust concentrations can present an explosion hazarcl. When in solution, this product will be slippery. Size Item ~D EP.,J33JD 13", 15 mils 18", 22 mils 6 420 6465 N/A 7 420 6505 420 6450 8 420 6575 420 6455 9 420 6610 279 3644 10 420 6585 279 3652 11 420 6615 - 279 3661 Respirators: Dry polymer handling procedures should be designed to minimize the generation of airborne dust. If procedures are not sufficient to prevent respiratory irritation or if the employee chooses, a full face air purifying respirator with OV/HEPA cartridges and dust/mist filter can be used. Prior to respirator use, ensure that: 1) employees are trained and fitted 2) employees are medically certified 3) written operating procedures in place Full-Face (S) 335 4016 444 6375 (U) 281 8914 -- (L) 335 4067 347 8165 (starx:lam) SARA Hazarcl Categories: Acute X Chronic..._. Fire Reactive Pressure Respirator Cartridges OV/HEPA 335 8939 350 3003 Dust/mist 355 7090 330 8600 D/M holder 355 7219 - - Filter cover - - 330 7212 Supplied air Is required In poorly ventilated or confined spaces. NEW CHEMICAL EVALUATION HEALTH & SAFETY CONSIDERATIONS TRADE NAME: DISTRIBUTOR/: CHROMIC ACETATE SOLUTION MANUFACTURER McGean-Rohco, inc 2910 Harvard Av, Cleveland, OH Fire HAZOX MSDS #: AAI03956 Health __ _ MSDS DATE: 10/11/91 Reactivity.._ _ SARA CODES: STY S-PS ~;-TM MOU PS E I 4 99 L DESCRIPTION OF USE The product will be used as an activator with ALCOFLOOD 935 and 254S for squeeze application in production and injection wells. Phvstcal Hazard: Fire: The product is not flammable or combustible. The product is stable. Corrosiveness: The product is moderately acidic with a pH of 2-3. Health Effects:' The following summary is based on information in the literature on individual components as well as information provided in the MSDS. Primary routes of exposure: eye ancl skin contact. This product is a trivalent chromium compound. These compounds have a Iow order of toxicity because they are poorly absomed by the body. Dermatitis has been reported in workers handling them. Allergic contact dermatitis may occur altl~ough most cases result from handling hexavalent chromium compounds (such as chrome plating acid). Eye contact may cause irritation. REVIEW DATE 7/2/92 PERSONAL PROTECTIVE EQUIPMENT Eve Protection; Chemical goggles should be worn when using this product. · Goggles, Chemical '((:3ear) Z48-1090 (Shaded) Z48-1081 Wear nitdle gloves if skin contact with the liquid cannot be avoided. Nltrile Gloves Size tem 13', 15 mils 18", 22 mils 8 263 4724 9 263 4732 279 3644 10 263 4741 279 3652 11 279 3661 Dry polymer handling procedures should be designed to minimize the generation of airborne dust during mixing with the activator. If procedures are not sufficient to prevent respiratory irritation, a dust mask type respirator or an air-purifying cartridge respirator with dust/mist filters or HEPA cartridges can be used. Prior to respirator use, ensure that: 1) employees are trained ancl fitted 2) employees are medically certified 3) written operating procedures in place Scott ~ Ha~-Face (S) 356-2549 319-5996 (M) 355-5755 319-6003 (L) 355-5895 319-7034 Respirator Cartridges HEPA 281 8949 319 6011 Dust/Mist 355 7090 330 8600 DIM Filter Cover 355 7219 330 7212 RECEIVED OCT '1 4 1994 Alaska 0il & Gas Cons. Commission ' Anchora,je KUPARUK WELL PRODUCTION WELL' APT.%: 50-029-21447-00 ADL LEASE: 25643 SPUD DATE: 09/26/85 3F-02 COMPLEi~ONDATE: 11/30/85 SURFACE LOCATION: TOP OF KUPARLVK: ~ LOCATION: PEEMIT~: 78' FNL, 139' FWL, SEC 29, T12N, RgE, UM 1269' FNL, 1514' FEL, SEC 29, TIRN, RgE, UM 1363' FNL, 1148' FEL, SEC 29, T12N, RgE, UM Ail Oepms are MD-RKB to tOl= of equ~oment unless omerwise noted ORIGINAL PJ{B: 93 TUBING SPOOL: 33. PAD. ELEVATION: 56 FMC GEN III 3-t/2" HGR CASING and TUBING DETAILS 16" 62.5 H-40 9.625" 36.0 J-55 7' -26.0 J-55 3.5" 9.3 J-55 2.875" 6.5 J-55 110' 3505' 7839' 7416' 7451' MISC. DATA D~$CRIPT!ON KI~{ OFF POINT: MAX HOLE ANGLE: 46° ANGLE THRU KUP: 39° 1100' 3800' TVD TO UPPER PKR: TVD TO TOP C SD PERF TVD TO TOP A SD PERF 5762' 5841' 6067' VOI//ME TO TT VOL//ME TT TO TOP PERF VDI. LIHE 7" ANNULUS 64.5 BR?~ 4.2 BBLS 188.4 BBLS PERFORATION DATA 7270-7390 C 12 120° 5" CG 7561-7602 A3 4 90e 4" C~ 7624-7666 A2 4 90" 4" CG 1852': CAMCO TRDP-1A-SSA ~ (2.813" I.D.) 2417': CAMCO KBUG 1" ~LH (3/16" OV} 3874': CAMCO KBUG 1" (U~H (DV] 4528': CAMCO KBUG 1" ~M (DV} 4967': CAMCO K~UG 1" ~LM (GLV} 5422': CAMCO KBUG 1" GLM (~;~ 5854': CAMCO KBUG 1" GLM (D~9 6287': CAMCO KBUG I"'GLM (GLV~ 6725': CAMCO KBUG 1" G~,H. (E~D 7105': MERLA TPDX 1.5' GLM (OV) 71'54': BAK]~ ~ 7168': BAKER FHL ~ 7206': CAM~O KBUG I" ~H (DV} 7413': AFA BPC Full O~en (5/13/94) 7416': 3-1/2" X 2-7/8" X-OVE~ 7428': BAKER F~-i 7443': CAMCO D NIPPLE (2.25' I.D.) 7450': CAMCO S~A~ OUT 7699': LAST TAG (04/02/94) 7750": PBTD (6120 SU~-SEA) REVISION DATE: 07/02/94 REASON: GLM C/O BY: SDB: ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 10, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ¢5-;zz~ 3F-02 Stimulate '~?.-2-5 ~'3M-09 Stimulate '"3M-09 Perforate ¢f~,--72 3N-10 Stimulate ~,f,,-¢l t 3N-16 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany 1. Type of Request: 2. Name of Operator STATE OF ALASKA --~ -AI_~oKA OIL AND GAS CONSERVATION COMMIt ~N REPORT OF SUNDRY WELL OPERATIONS Stimulate X Plugging~ Perforate__ Alter casing Repair well O t h e r Operation Shutdown Pull tubing 5. Type of Well: Development ..X Exploratory _ Stratigraphic _ Service _ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-02 9. Permit number/approval number 85-22(} 10. APl number 5o-029-2144700 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) 4. Location of well at surface 78' FNL, 139' FWL, SEC.29, T12N, R9E, UM At top of productive interval 1269' FNL, 1514' FEL, SEC.29, T12N, R9E, UM At effective depth 1348' FNL, 1093' FEL, SEC.29, T12N, R9E, UM At total depth 1363' FNL~ 1148' FEL~ SEC.29~ T12N~ R9E~ UM 12. Present well condition summary Total Depth: measured 7864' feet true vertical 6302' feet feet Effective depth: measured 775 0' feet true vertical 621 3' feet Junk (measured) Casing Length Size Structural Conductor 73' 1 6" Surface 3465' 9 -5/8" Intermediate Production 7802' 7" Liner Perforation depth: measured 7270'-7390', true vertical 5841 '-5934', Tubing (size, grade, and measured depth) Cemented 270 SX AS II 980 SX PF E & 400 SX PFC 450 SX Class G & 200 SX PFC 7561'-7602', 7624'-7666' 6067'-6069', 6116'-6149' 3-1/2" 9.3# J-55 @ 7416', 2-7/8" 6.5# J-55 @ 7451' Packers and SSSV (type and measured depth) Measured depth 110' 3505' 7839' True ve~ical depth 110' 3086' 6283' RECEIVED NOV 1 5 199 Alaska Oit & Gas Cons. Commission Anchorage SSSV: Camco TRDP-1A-SSA @ 1852', PACKERS: Baker FHL @ 7168', Baker FB-1 @ 7428' 13. Stimulation or cement squeeze summary A SAND FRACTURE STIMULATION Intervals treated (measured) 7561 '-7602', 7624'-7666' Treatment description including volumes used and final pressure Pumped 134 Mbbls of 16/20 & 12/18. Tot. Fluids: Water 1141 bbls, Dsl 28 bbls, Addi. 76 bbls (see WSR) 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 369 223 4906 1207 35O 924 15 1451 Tubing Pressure 175 140 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas ~ Suspended Service 17. I hereby ~,r~ify that the foregoing is true and correct to the best of my knowledge. Signed~ V ~/~,' '~--'~ Title Sr. Petroleum Engineer Form 10-404 Rev 09/12/90 Date / ['"-/~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. O' Subsidiary of Atlm~i~ Richfield Co~ WELL |! . . PBTD (Ri~) ~ _ .,/; D ,.': D ~ .,.--, ,~,,, ?ETfiOLEUM KUPARUK RIVER UNIT WELL SERVICE I~k'a'ORT PERSON CO~T LAST TAG (RKB)/DATE COST g'13o ' CHECK THIS BLOCK IF~RY CONTINUED ON BACK °F °F miim INCO~ REMA Rir~ CONTINUlgD: ACCUM. SERVICE COMPANY .~ DAILY TOTAL '~ .~,~,~,~-' ' ' ' / · · , ~ , ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ' 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F--15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re aort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re aort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Re3ort Kupaurk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12 12 12 -03-87 -18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 -04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-2O-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin~,~,j~ Casin{[ Casinc~ 'w//C/lo/'o,,qO 3H-01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B- 1 3 Kupaurk Fluid Level Report 2-17-89 Casing I E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M-1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 @HP Report 2-13-89 BHP Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC -Unocal Mobil Chevron ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted-herewith ar_e the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Kuparuk Well Pressure Report Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuapruk Ku ~aruk Ku ~aruk Ku :~aruk Ku :~aruk Ku:)aruk Ku ~aruk Ku ~aruk Ku :)aruk Ku:~aruk Ku ~aruk Ku~aruk Ku~aruk Ku~:~aruk Ku )aruk Kul~aruk Ku )aruk 10-06-88 8-29-88 Well Pressure Report I 2- 20 - 88 Well Pressure Report 8 - 29 - 87 Well Pressure Report 8 - 29 - 87 Well Pressure Report 8 - 29 - 89 Well Pressure Report 8 - 1 7- 87 Well Pressure Report 8 - 1 7- 87 Well Pressure Report 8 - 29 - 87 Well Pressure Report 6 - 26 - 87 Well Pressure Report 12- 12 - 88 Well Pressure Report 1 2- 31 - 88 Well Pressure Report 6 - 11 - 87 Well Pressure Report 6 - 11 o 87 Well Pressure Report 9 - 01 - 87 Fluid Level Report 5 - 04 - 87 Fluid Level Report 2 - 13 - 89 Fluid Level Report 2 - 10 - 89 Fluid Level Report 2 - 10- 89 Fluid Level Report 6 - 05 - 87 Fluid Level Report 6 - 09 - 87 Fluid Level Report 6 - 18 - 87 Fluid Level Report 6 - 16 - 87 Fluid Level Report 6 - 21 - 87 Fluid Level Report 5 - 08 - 87 Fluid Level Report 8 - 18 - 87 Fluid Level Report 8 - 24 - 87 Fluid Level Report 6 - 05 o 87 Fluid Level Report 6 - 2/3 - 87 Fluid Level Report 8 - 5 - 8 7 Fluid Level Report 6 - 5 - 87 Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Cornr~issjo,~ Casing ,'~ch0rage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Acknowledged: Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report 9 - 11 - 87 Report I 2 - 06 - 86 Report 9 - 1 I - 87 Report I 0 - 1 I - 87 Report 9 - 1 6 - 87 Report 4- 11 - 88 Report 4 - 08 - 88 Report 4 - 01 - 88 Report 3 - 26 - 88 Report I - 3 0 - 88 Report I 0 - 1 2 - 87 Report 1 0 - 1 5 - 87 Report I 0 - 28 - 87 Report I 0 - 28 - 87 Report I 0 - 28 - 87 Report I 0 - 28 - 87 Report 3 - 1 9 - 87 Report 9-1 2- 87 Report 9 - 1 0 - 98 Report 9 - 1 0 - 87 Report 9 - 1 0 - 87 Report 9 - 1 2 - 87 Report 9 - 08 - 87 Report 9 - 01 - 87 Report 9-01 -87 Report 9 - 06 - 87 Report 9 - 0 6 - 87 Report 9 - 06 - 87 Report 9 - 06 - 87 Report 6 - 01 - 87 Report 5 - 31 - 87 Report 6 - 03 - 87 Report 6 - 06 - 87 Report .6 - 0 8 - 8 7 Report 6 - 0 9 - 87 Report 6 - 2 5 - 87 Report 4 - 1 7 - 87 Report 4 - 1 8 - 87 Report 6 - 1 7 - 87 Report 6 - 2 0 - 87 Report 5 - 0 7 - 87 Report 8 - 24 - 87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing .,,,,/3 ~.~ .. Alaska Oil & G3s Cons. DISTRIBUTION: D&M State of Alaska ; Mobil Chevron Unocal SAPC ARCO Alaska, inc. Post Office Bo~/~0360 ' . Anchorage, AL ,99510-0360 ' Te,ephone 907 276 1215 October 31, 1986 RETURN TO' ARCO ALASKA, INC. ATTN- Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5805 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final '"~ 1A-8 Prints- CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL .: CET/CEL CET/CEL 1-03-86 12-21-85 10-22-85 10-09-85 12-15-85 10-30-85 10-17-85 12-17-85 10-05-85 10-19-85 Run #1 Run #1 Run ~3 Run #2 Run #1 Run #1 Run #1 Run #2 Run #1 Run #1 5600' - 6300' 4800' - 7521' 8490' - 8830' 6800' - 7406' 5496' - 6870' 5350' - 8342' 5925' - 7726' 8595' - 9110' 6624' - 8367' 5350' - 7527' Receipt Acknowl edged. _ Distribution' -'~tate .of Alaska(+ ~ BPAE Chevron Mobil NSK Drilling Vault(1 film) SAPC Union ·. ARCO Alask--, inc. is a Subsidiary o! AtlanticRichfiel~lComoany ._,-, ~' ~' STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION CO,vfMISSION :::': W_ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well · OIL YI~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-226 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21447 4. Location of well at surface 9. Unit or Lease Name 78' FNL, 139' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit 10. Well Number At Top Producing Interval 1269' FNL, 1514' FEL, Sec.29, T12N, R9E, UM 3F-2 At Total Depth 11. Field and Pool 1363' FNL, 1148' FEL, Sec.29, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI ADL 25643 ALK 2574 · , 12. Date Spudded 13. Date T.D, Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/26/85 10/01/85 10/03/85* N/A feet MSL 1 17. Total Depth {MD+TVD)' 18.Plug Back Depth {MI~-I'VDI 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7864 'MD ,6302 'TVD 7750 'MD ,6213 'TVD YESX[~I NO [] 1852 feetMD 1500' (approx) 22. Type Electric or Other Logs Run DIL/CR/SP/SFL, FDC/CNL, Cal, CET, Gyro 23. CASING, LINER /~ND CEMENTING RECORD .. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb" 62.5# H-40 Surf 110' " '24,' '" 270 sx AS II , 9-5/8" 36.0# J-55 Surf 3505' 12-1/4" 980 sx PF "E" & 400 sx FF "C" 7" 26.0# J-55 Surf 7839' 8-1/2" 450 sx Class G & 200 sx PF "C" , , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25.' TUBING RECORD interval, size and number) SIZE. DEPTH SET (MD) PACKER SET (MD) 7666' - 7624' w/4 spf, 90° phasing 3-1/2" 7451' 7168' & 7428' 7602' - 7561' ~6. ' ' ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7390' - 7270' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUN'~& KIND OF MATERIALU'SED see addendum attac~.ed to Well Completion Repor.t dated 3/31/86. 27. N/A PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) -- , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Fiow Tubing Casing Pressure CALCULATED OIL-BBL ' '~3~S-MCF WATER-B~L OIL GRAVITY-APl (corr)' Press. 24-HOUR RATE ~ · 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alas!" ...... /.., ,:~ ,~.~ .-.~ · , ,, Form 10-407 * NOTE: Tubing was run and the well perforated 11/30/85. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WCl/043 Submit in duplicate ! ? 29. : ~--:? . . . -.. -GEOLOG. Ic MARKERS~ i '"' :":..- . FORMATION TESTS ' - ' ' ' ' ';, 4 :. ..~.~ ; ..... ;,~ . .. . ;;..:;- '_.. ...~ .... ,... .. · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7264' 5835' N/A Base Kuparuk C 7390 ¢' 5933' Top Kuparuk A 7550' 6057' Base Kuparuk A '7711' 6183' 31, LIST OF ATTACHMENTS None 32. I hereby certify that the forego!ng is true and correct to the best of my knowledge Signed /~~ ~/~J Title Associate Engineer Date ~I~'24~B~1 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of ServiCe Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 - ' ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-226 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21447 4. Location of well at surface 9. Unit or Lease Name 78' FNL, 139' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1269' FNL, 1514' FEL, Sec.29, T12N, R9E, UM 3F-2 At Total Depth 11. Field and Pool 1363' FNL, 1148' FEL, Sec.29, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKB ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/26/85 1 0/01/85 1 0/03/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 7864'MD,6302'TVD 7750 'MD ,6213 'TVD YES I~KX NO [] 1852 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" Conductor report has rot been received. 9-5/8" 36.0# J-55 Surf 3505' 12-1/4" 980 sx PF "E" & 400 s~ PF "C" 7" 26.0# J-55 Surf 7839' 8-1/2" 450 sx Class G & 200 ,,x PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7666' - 7624' w/4 spf, 90° phasing 3-1/2" 7451' 7168' & 7428' 7602' - 7561' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7390' - 7270' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Add.,~ndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD J~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE .~r 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneREC£1V D APRO 1986 A~ka 0~ & r~s Cons. "" mm~rnrn~-n An~orage Form 10-407 * NOTE: Tubing was run and the well perforated 11/30/85. GRU13/WC11 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate0,j~ 29. GEOLOGIC MARKERS NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A FORMATION TESTS MEAS. DEPTH TRUE VERT. DEPTH 7264' 7390' 7550' 7711' 5835, 5933' 6057 ' 6183 ' Include interval tested, pressure data, al GOR,.and time of each phase. N/A fluids recovered and gravity, 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Signed ~ ~-~L.~ Title Date -- INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Ite~i 23'.-.~-~1~C1~'ed ~upplemental records for this well should show the details of any multiple stage cement- ing 'and the location of the cementing tool. Item .27' Me~d of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- iection, Ga.,5,1 njection;.ShlJf-in, Other-explain. Item 28: If'no cores taken, indicate "none". Form 10407 ADDENDUM WELL: 3F-2 FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1307 hrs, 1/24/86. Frac Kuparuk "A" sand perfs 7561'-7602' & 7624'-7666' in 7 stages per 12/23/85 (modified) procedure using gelled diesel w/Musol, 100 mesh, & 20/40 sand. Press'd ann to 1450 psi w/diesel. Tst ins to 8900 psi; OK. Stage 1: Pmp'd 45 bbls 5% U-66 Musol @ 2.1BPM w/final press of 2540 psi. Stage .2: 37 bbls gelled diesel pad @ 2 BPM w/final press of 2900 psi. Stage 3: 21 bbls gelled diesel w/100 mesh, 1 ppg, sand @ 5 BPM w/final press @ 3230 psi. Stage 4: 68 bbls gelled diesel spacer @ 19 BPM w/final press of 4060 psi. Stage 5*: 16 bbls gelled diesel w/20/40 mesh sand, 3 ppg, @ final press of 3800 psi. Stage 6*: 40 bbls gelled diesel w/20/40 mesh, 8 ppg sand, @ avg of 17 BPM w/final press of 3800 psi. Stage 7*: 67 bbls gelled diesel flush @ avg of 15 BPM w/final press of 3750 psi. *Unable to keep 20 BPM rate due to frac tank outlet or in blockage. Pmp'd 900# 100 mesh, 1 ppg sand, 1900# 20/40 mesh 3 ppg & 9482# 20/40 8 ppg sand, underflushed by 2 bbls, in 7" csg. Load to recover 298 bbls of diesel. Job complete @ 1400 hrs, 1/24/86. APR 0 1986 AI~ Oil & Gas Oons. L;ommissio" ,anchorage Drilling S~perintendent / Dante · ARCO Alaska, Inc. ' Post Office Bo,, 100360 Anchorage, Alaska 99510'0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3F-2 Dear Mr. Chatterton' Enclosed is a copy of the 3F-2 Well History (completion details) to include with the Well Completion Report, dated 12/13/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L93 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany ARCO-Oil .and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Finel Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Spudded or W.O. begun Complete 11 / 29/85 I Accounting cost center code District Ic°unty °r Parish Istate Al. asEa Alaska North Slope Borough Field ILease or Unit I Well no. Kuparuk River ADL 25643 3F-2 Auth. or W.O. no. ~Title AFE AK0405 I Completion Nordic 1 API 50-029-21447 Operator [A.R.Co. W.I. ARCO Alaska, Inc. 56.24% r ate Date and depth as of 8:00 a.m. 11/30/85 12/01/85 Complete record for each day reported I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well I our ~Prlor status if a W.O. 0930 hrs. I 7" @ 7838' 7734' WL PBTD, RR 7.1 Diesel Accept rig @ 0930 hrs, 11/29/85. NU &tst BOPE. RU Schl, perf w/4" guns, 4 SPF, 90° phasing f/7561'-7602', 7624'-7666'. Perf w/5" guns, 12 SPF, 120° phasing f/7270'-7390'. TIH w/6-1/8" gage ring/JB to 7600', rec'd handfull of trash. TIE w/7" Bkr FB-1 pkr & tailpipe, set pkr @ 7428', RD Schl. RIH w/231 jts, 3~", 9.3#, J-55 8RD EUE IPC compl& ind. Set pkr, bled tbg, sheared PBR. Tst SSSV. Set BPV. ND BOPE, NU &tst tree. RR @ 1500 hfs, 11/30/85. FHL pkr @ 6168', FB-1 pkr @ 7428', "D" Nipple @ 7443', TT @ 7451', SSSV @ 1852' Old TD Released rig 1500 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data New 7734 PBTD TD PB Depth ! Date ~Kind of r g 11/30/85 I Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation an~distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3F-2 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for 3F-2. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L127 Enclosures RECEIVED DEC 1 9 1985 AlaSka Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany --- STATE OF ALASKA ALASKAC i ANDGASCONSERVATION CO; IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL F~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-226 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21447 , 4. Location of well at surface LOCATIONS 9. Unit or Lease Name 78' FNL, 139' FWL, 5ec.29, T12N, RgE, UN VERIFIED Kuparuk River Unit At Top Producing Interval Surf, ~;~ 10. Well Number 1269' FNL, 1514' FEL, Sec.29, T12N, RgE, UN B.H. '8 3F-2 At Total Depth ~ 11. Field and Pool 1363' FNL, 1148' FEL, Sec.29, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River' 0i 1 Pool 9:~' RKB ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 09/26/85 10/01/85 10/03/85* N/A feet MSLI 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey i 20. Depth where SSSV set I 21. Thickness of Permafrost 7864'HD,6302'TVD 7750'MD,6213'TVD YES I~ NO [] 1852 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Ca1, GET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 . Surf 110' 24" Conductor report has n(t been received. 9-5/8" 36.0# J-55 Surf 3505' 12-1/4" 980 sx PF "E" & 400 sx PF "C" 7" 26.0# J-55 Surf 7839' 8-1/2" 450 sx Class G & 200 s; PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7666' - 7624' w/4 spf~ 90° phasing 3-1/2" 7451' 7168' & 7428' 7602' - 7561' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7390' - 7270' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of OPeration (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure iCALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (Corr) Press. 24-HOUR RATE J~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED DEC ! 9 ]985 Alaska Oil & 6as Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run and the well perforated 11/30/85. TEMP3/WC12 ":' Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. .,,.[(.. '- ,'" .~'. .... '-:ii' ::". -:: :':_:: ' ~ -- '" .... '"- ' !'FO' 0 .... ' '" . . '-- · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7264' 5835' N/A Base Kuparuk C 7390' 5933' Top Kuparuk A 7550' 6057' Base Kuparuk A 7711' 6183' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of mY knowledge ~ Associate Engineer Signed ~ Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). .. Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-2 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L83 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany / . '---. STATE OF ALASKA ~-- ALASKA t_ __ AND GAS CONSERVATION CC, .VllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-226 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21447 4. Location of well at surface 9. Unit or Lease Name 79' FNL, 139' FWL, 5ec.29, T12N, RgE, UN (approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 3F-2 At Total Depth 1'1. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 09/26/85 10/01/85 10/03/85J N/A feet MSL N/A 17. Total Depth (MD+TVD)18.Plug Back Depth (MD+TVD)19. Directional Survey 7864 'MD 7750'MD YES [~X NO [] I20' Depth Where sssv seIN/A feet MD ] 21. Thickness of Permafrost1500. (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" Conductor report has mt been received. 9-5/8" 36.0# J-55 Surf 3505' 12-1/4" 980 sx PF "E" & 400 sx PF "C" 7" 26.0# J-55 Surf 7839' 8-1/2" 450 sx Class G & 200 s; PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A ,, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None t~? ~CL~"/VL~'D - .... . :~ ., ,~ ;'~Ztska Oil '~,~Gas COl?b,, Form 10-407 TEMP2/WC55 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... /.'.'-:-'-' ........ . ....... ; , . 29. - ;;.:-!':-i [~ .? i,~ -"--"-' % r ..: .... ' ~"' ':'"" ;~'" ...... ':.: t .; ,:":~;,-'"e: '?_::~,;i':i..-...':.':':'. q' :"~':' ' ;': ':FORMATION TESTS '~ ...... . . . ': GEOh'OGiCMARKERS. ._ · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . To be submitted wt .~n gyro is rece~ /ed. N/A . . , .. -. 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~_~ : Title Associate Engineer Date /"/4-~' /I- U INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1'-Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), So state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fnrm I g-4n? UB. SURFACE DIRECI'IONAI. SURVEY [~UIDANCE [~ONTINUOU$ E~OOL Company , Well Name Field/Location ATLANTIC RICHFIELD COMPANY ,. 3F-2, ~78' FNL. 1~9' YWI, L R2q. Tl?~_ P~_ ~? _. ,KUPARUK; NOR,TH SLOPE~ ALASKA,, _ Jo~ Refer.rice No. 70965 LESNIE I I I I I I I Oat..._~e 18-NOVEMBER-85 Computed 8~. BOLAM SCHLUMBERGER '-~ ~,,,~ GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3F-2 KUPARUK NORTH SLDPE,~LASKA SURVEY DATE: 18 OCT 85 ENGINEER: LESNIE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION ~ND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 72 DEG 0 MIN EAST ARCO ALASKA, INC. 3F-Z KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 15-NOV-85 PAGE DATE OF SURVEY: 18 OCT 85 KELLY 'BUSHING ELEVATION: ENGINEER: LESNIE 93.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0,00 0,00 -93,00 0 0 N 0 0 E 100,00 100.00 7,00 0 I S 19 32 W 200.00 200.00 107.00 0 5 S 40 8 E 300,00 300,00 207,00 0 4 S 25 13 E 400.00 400.00 307,00 0 2 S 8 21 E 500.00 500.00 407.00 0 6 S 23 9 E 600.00 600.00 507.00 0 11 S 41 41 E 700,00 TO0,O0 607,00 0 11 S 57 29 E 800,00 800,00 707.00 0 13 S 65 26 E 900.00 900.00 807.00 0 19 S 58 27 E 1000.00 999.99 906.99 1 6 1100.00 1099.87 1006.87 4 9 1200o00 1199.32 1106.32 7 43 1300.00 1298.05 1205.05 10 5 1400.00 1396.04 1303.04 13 21 1500.00 1492.62 1399.62 16 37 1600.00 1587.43 1494.43 20 29 1700.00 1679.59 1586.59 24 56 1800,00 1768,93 1675,93 27 51 1900,00 1856,32 1763,32 30 36 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SDUTH EAST/WEST DIST. &ZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 2000,00 1941,48 1848,48 32 24 2100,00 2024,75 1931,75 34 47 2200,00 2105.38 2012,38 37 44 2300.00 2182.89 2089.89 40 21 2400.00 2258.60 2165.60 41 1 2500,00'2333,98 2240.98 40 54 2600.00 2409,40 2316,40 41 18 2700.00 2484,16 2391.16 41 54 2800.00 2558.54 2465.54 41 53 2900.00 2633.10 2540.10 41 40 0.00 0.00 0.00 N 0.00 E -0.06 0.16 0.01 S 0.07 W 0.03 0.09 0.11 S 0.01 W 0,15 0,04 0.25 S 0.08 E 0.21 0.04 0.36 S 0.10 E 0.29 0.09 0.47 S 0,16 E 0.48 0.11 0.69 S 0.28 E 0.79 0.10 0.91 S 0.54 E 1.15 0.03 1.08 S 0.86 E 1.57 0.33 1,27 S 1.24 E 3000,00 2707,96 2614,96 41 39 3100.00 2782.,54 2689,54 41 51 S 50 26 E 2,51 2,08 S 57 52 E 6,88 3,06 S 64 13 E 17,00 4,03 S 71 48 E 32.81 2.49 S 76 41 E 52.67 3.86 S 74 52 E 78.46 3,93 S 73 48 E 110.18 4.71 S 69 40 E 148.89 5.05 S 65 58 E 193.62 1.82 S 66 38 E 241.93 3.11 S 66 39 E 294.15 2.57 S 66 44 E 349,20 2.95 S 68 37 E 408.16 3,33 S 68 46 E 471.26 1.90 S 67 14 E 536.40 0.90 S 65 58 E 601.84 1.24 S 65 22 E 567.08 0.49 S 65 21 E 733.05 0.31 S 65 13 E 799.43 0.28 S 64 44 E 865.58 0.39 S 64 30 E S 64 1 E O. O0 N 0 0 E 0.07 S 82 12 W 0.11 S 4 12 W 0.26 S 16 51 E 0.38 S 16 14 F ,. 0.50 S 18 14 ) 0.74 S 22 9 t~ 1.06 S 30 28 E 1.38 S 38 32 E 1.78 S 44 17 E 1.85 S 2.04 E 2.75 $ 47 49 E 4.46 S 5.78 E 7.30 S 52 22 E '9.42 S 14.81 E 17.55 S 57 32 E 15,25 S 29.54 E 33.24 S 62 42 E 20.33 S 48.78 E 52.84 S 67 22 E 26.57 S 73,87 E 78,50 S 70 12 E 35.21 S 104.41 E 110.19 S 71 21 E 47.06 S 141.26 E 148.89 S 71 34 E 64.41 'S 182.65 E 193.68 S 70 34 E 84.22 S 227.02 E 242.14 S 69 38 E 104.73 S 275.26 E 294.51 S 69 10 E 127.15 S 325.86 E 349.79 S 68 41 E 149.68 S 380.53 E 408.91 S 68 31 E 172.08 S 439.60 E 472.08 S 58 37 E 196.68 S 500.10 E 537.38 S 68 31 E 222.61 S 560.49 E 603.08 S 68 20 [ 249.80 S 620.25 E 668.66 S 68 3 277.53 S 680.60 E 735.01 S 67 48 E 305.44 S 741,32 E 801.T$ S 67 36 E 333.62 S 801.73 E 868.37 S 67 24 E 931.33 0.48 997.34 0.32 362.02 S 861.63 E 934.59 S 67 12 E 390.96 S 921.63 E 1001.13 S 67 0 E 3200.00 2857,02 2764,02 41 45 3300,00 2931,82 2838,82 41 29 3400.00 3006.70 2913.70 41 35 3500.00 3081.42 2988.42 41 53 3600.00 3155.29 3062.29 42 51 3700,00 3227,67 3134.67 44 30 3800.00 3298.12 3205.12 45 42 3900.00 3367.92 3274.92 45 28 S 63 36 E 1063.39 S 63 16 E 1129.02 S 62 49 E 1194.48 S 62 28 E 1260.06 S 62 50 E 1326.53 S 66 51 E 1394.90 S 70 23 E 1465.75 S 73 36 E 1537.35 0.88 0.48 0.37 0.90 1.45 3.92 2.28 2.42 420.43 S 981.51 E 1067.76 S 66 48 E 450.10 S 1040.87 E 1134.02 S 65 36 E 480.15 S 1099.94 E 1200.17 S 66 25 E 510.71 S 1158.96 E 1266.50 S 66 13 E 541.81 S 1218.75 E 1333.76 S 66 1 E 571.59 S 1280.97 E 1402.71 S 65 57 E 597.17 S 1347.15 E 1473.58 S 66 5 E 519.21 S 1415.27 E 1544.80 S 66 22 E COMPUTATION DATE: 15-NOV-85 PAGE 2 ARCO ALASKA, INC. 3F-2 KUPARUK NORTH SLOPE,ALASKA 0ATE OF SURVEY: 18 OCT 85 KELLY BUSHING ELEVATION: ENGINEER: LESNIE 93.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000.00 3438.66 3345.66 44 42 4100.00 3509.67 3416.67 44 58 '4200.00 3580.18 3487.18 45 15 4300.00 3650.42 3557.42 45 23 4400.00 3721o31 3628.31 44 5 4500.00 3793.41 3700.41 43 50 4600.00 3865.62 3772.62 43 43 4700.00 3937.91 3844.91 43 41 4800.00 4010.25 3917.25 43 44 4900.00 4082.47 3989.47 43 40 5000.00 4155.0I 4062.01 43 23 5100.00 4227.63 4134.63 43 25 5200.00 4300.28 4207.28 43 29 5300.00 4372.84 4279.84 43 24 5400,00 4445.69 4352.69 42 53 5500,00 4518.89 4425.89 43 5 5600.00 4592.06 4499.06 43 3 5700.00 4664.96 4571.96 43 17 5800.00 4737.83 4644.83 43 6 5900.00 4810.89 4717.89 43 0 6000.00 4884.00 4791.00 42 59 6100.00 4957.20 4864.20 42 48 6200.00 5030.80 4937.80 42 26 6300.00 5104.87 5011.87 42 1 6400.00 5179.22 5086.22 41 51 6500.00'5253.79 5160.79 41 35 6600,00 5328.74 5235.74 41 21 6700.00 5403.92 5310.92 41 7 6800.00 5479.35 5386.35 40 55 6900.00 5555°07 5462.07 40 34 7000.00 5631.34 5538.34 39 55 7100,.00 5708.29 5615.29 39 30 7200.00 5785.58 5692.58 39 13 7300.00 5863.24 5770.24 38 55 7400.00 5941.02 5848.02 38 56 7500.00 6018.63 5925,63 39 13 7600.00 6096.21 6003.21 39 5 7700.00 6173.98 6080.98 38 56 7800.00 6251.76 6158.76 38 56 7864,00 6301,54 6208,54 38 56 DEG MIN FEET' DEG/iO0 FEET FEET FEET DEG MIN S 75 51 E 1607.92 S 76 12 E 1678.15 S 76 19 E 1748.87 S 76 26 E 1819,84 S 76 4 E 1890,16 S 75 52 E 1959.29 S 75 45 E 2028.31 S 75 41 E 2097.27 S 75 37 E 2166.17 S 75 27 E 2235.21 S 75 27 E 2303.91 S 75 24 E 2372.53 S 75 24 E 2441.14 S 75 33 E 2509.83 S 75 44 E 2578.18 S 75 19 E 2646,18 S 75 7 E 2714.24 S 75 17 E 2782.58 S 75 30 E 2850.94 S 75 49 E 2919.09 S 75 52 E 2987.16 S 74 29 E 3055.17 S 74 17 E 3122.81 S 74 27 E 3189.94 S 74 43 E 3256.75 S 75 0 E 3323.29 S 74 59 E 3389.40 S 75 11 E 3455.24 S 75 22 E 3520.78 S 75 40 E 3585,99 S 76 2 E 3650.52 S 76 6 E 3714.22 S 76 5 E 3777.49 S 76 5 E 3840.34 S 76 7 E 3903,03 S 75 59 E 3965,93 S 75 27 E 4028.89 S 74 59 E 4091,67 S 74 59 E 4154.43 S 74 59 E 4194,60 0.55 0.42 0.20 0.33 1.26 0.07 0.08 0.17 0.48 0.32 0.27 0.07 0.52 0.17 1.10 0.45 0.16 0.19 0.24 0.12 0.26 1.01 0.45 0.21 0.40 0.50 0.20 0.19 0.29 0.80 0.64 0.44 0.44 0.47 0.49 0.28 0.23 0.00 0.00 0.00 637,45 S 1483,55 E 1614,70 S 66 44 E 654,37 S 1551,90 E 1684,22 S 67 8 E 671.22 S 1620.78 E 1754.27 S 67 30 E 687.95 S 1689.96 E 1824.62 S 67 50 E 704,64 S 1758,48 E 1894.41 S 68 9 ~ ~ 721.48 S 1825.70 E 196,3.09 S 68 26 ~! 738.42 S 1892.?? E 2031.71 S 68 41 E 755.47 S 19,59.73 E 2100.30 S 68 55 E 772.57 S 2026.62 E 2168.88 S 69 7 E 789.87 S Z093.60 E 2237.64 S 69 19 E 807.15 S 2160.21 E 2306.08 S 69 30 E 824.43 S 2226.75 E 2374.47 S 6'9 41 E 841.79 S 2293.25 E 2442.87 S 69 50 E 859,05 S 2359,86 E 2511,36 S 69 59 E 876,00 S 24.26,23 E 2579,52 S 70 8 E 892.98 S 2492,22 E 2647,37 S 70 1~7 E 910,44 S 2558,11 E 2715.29 S 70 24 E 927.91 S 2624.28 E 2783.50 S 70 31 E 945.19 S 2690.55 E 2851.74 S 70 38 E 962,07 S 2756,71 E 2919,77 S 70 45 E 978.73 S 2822.88 E 2987.73 S 70 52 E 996.00 S 2888.77 E 3055.66 S 70 58 E 1014.41 S 2953.92 E 3123.25 S 71 2 E 1032.50 S 3018.62 E 3190.32 S 71 7 E 1050.31 S 3083.08 E 3257.07 S 71 11 1067.67 S 3147.41 E 3323.57 S 71 15 E 1084.81 S 3211.35 E 3389.63 S 71 ZO E 1101.78 S 3275.06 E 3455,42 S 71 24 E 1118,48 S 3338,55 E 3520.93 S 71 28 E 1134.85 S 3401,80 E 3586.10 S 71 33 E 1150.59 S 3464.53 E 3650.59 S 71 37 E 1165.95 S 3526.52 E 3714.27 S 71 42 E 1181.18 S 3588.10 E 3777.52 S 71 46 E 1196.35 S 3649.25 E 3840.35 S T1 50 E 1211.45 S 3710.26 E 3903.03 S 71 55 E 1226.60 S 3771,48 ~ 3965,93 S 71 59 E 1242,14 S 3832.63 E 4028,89 S 72 Z E 1258.22 S 3893,41 E 4091,67 S 72 5 E 1274,50 S 3954.11 E 4154,44 S 72 8 E 1284,92 S 3992,96 E 4194,61 S 72 9 E COMPUTATION DATE: 15-NOV-85 PAGE 3 ARCO ALASKA, INC. 3F-2 KUPARUK NORTH SLOPE,ALASKA D4TE OF SURVEY: 18 OCT 85 KELLY BUSHING ELEVATION: ENGINEER: LESNIE 93. O0 F'T IN'TERPOLATED VA'LUES FOR EVEN 1000 FEET OF MEASURED OEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -93.00 0 0 1000.00 999.99 906.99 1 6 2000.00 1941.48 1848.48 32 24 3000.00 2707.96 2614.96 41 39 4000.00 3438.66 3345.66 44 42 5000.00 4155.01 4062.01 43 23 6000.00 4884.00 4791.00 42 59 7000.00 5631.34 5538.34 39 55 7864.00 6301.54 6208.54 38 56 VERTICAL DOGLEG RECTANGULAR COORDINATES MDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 50 26 E 2.51 S 66 39 E 294.15 S 64 30 E 931.33 S 75 51 E 1607.92 S T5 27 E 2303.91 S 75 52 E 2987.16 S 76 2 E 3650.52 S 74 59 E 4194.60 0.00 Z.08 2.57 0.48 0.55 0.27 0.26 0.64 0.00 0.00 N 0.00 E 0.00 N 0 0 E 1.85 S 2.04 E 2.75 S 47 49 E 104.73 S 275.26 E 294.51 S 69 10 E 362.02 S 861.63 E 934.59 S 67 12 E 637.45 S 1483.55 E 1614.70 S 66 44 807.15 S 2160.21 E 2306.08 S 69 30 978.73 S 2822.88 E 2987.73 S 70 52 E 1150.59 S ,3464.53 E 3650.59 S 71 37 E 1284.92 S 3992.96 E 4194.61 S 72 9 E COMPUTATION ARCO ALASKA~ INC. 3F-2 KUPARUK NORTH SLOPE~ALASKA INTERPOLATED VALUES FOR TRU MEASURED VERTI DEPTH OEP E SUB-SEA CAL VERTICAL TH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 0.00 0 93.00 93 193.00 193 293.00 293 393.00 393 493.00 493 593.00 593 693.00 693 793.00 793 893.00 893 · 00 -93.00 · 00 0.00 · 00 100.00 .00 200.00 ,00 300.00 ,00 400.00 .00 500.00 .00 600.00 · 00 TO0.O0 .00 800.00 0 0 N 0 0 E 0 1 S 24 33 W 0 5 S 39 47 E 0 4 S 25 20 E 0 2 S 4 33 E 0 6 S 22 49 E 0 10 S 40 17 E 0 11 S 56 20 E 0 13 S 65 14 E 0 17 S 59 21 E 993.01 993. 1093.11 1093. 1193.62 1193. 1294.87 1293. 1396.89 1393. 1500.40 1493. 1605.96 1593, 1714.78 1693. 1827.28 1793. 1942.88 1893, O0 900.00 O0 1000.00 O0 1100.00 O0 1200.00 O0 1300.00 O0 1400.00 O0 1500.00 O0 1600.00 O0 1700.00 O0 1800.00 0 58 S 50 40 E 3 $7 S 57 37 E 7 28 S 63 38 E 9 59 S 71 23 E 13 13 S 76 38 E 16 38 S 74 52 E 20 46 S 73 41 E 25 34 S 68 44 E 28 26 S 65 45 E 31 30 S 67 0 E 2061.57 1993. 2184.40 2093. 2313.30 2193. 2445.68 2293. 2578.17 2393. 2711.88 2493. 2846.27 2593. 2979.99 2693. 3114.05 2793. 3248.12 2893- O0 1900.00 O0 2000.00 O0 2100.00 O0 2200.00 O0 2300.00 O0 2400.00 O0 2500.00 O0 2600.00 O0 2700.00 O0 2800.00 33 51 S 66 2 E 37 17 S 68 13 E 40 32 S 68 31 E 41 8 S 66 51 E 41 12 S 65 26 E 41 55 S 65 20 E 41 48 S 65 0 E 41 33 S 54 34 E 41 51 S 63 57 E 41 35 S 63 26 E 3381.68 2993. 3515,54 3093. 3651.71 3193. 3792.67 3293. 3935.64 3393. 4076.45 3493. 4218.21 3593. 4360.42 3693. 4499.44 3793. 4637.88 3893. O0 2900.00 O0 3000,00 O0 3100.00 O0 3200,00 O0 3300.00 O0 3400.00 O0 3500.00 O0 3600.00 O0 3700.00 O0 3800.00 41 33 S 62 54 E 42 2 S 62 27 E 43 38 S 64 17 E 45 39 S 70 11 E 45 4 S 74 43 E 44 51 S 76 lO E 45 18 S 76 21 E 44 43 S 76 16 E 43 50 S 75 52 E 43 42 S 75 43 E DATE: 15-NOV-85 EVEN 100 FEET OF PAGE DATE OF SURVEY: 18 OCT 85 KELLY BUSHING .ELEVATION: ENGINEER: LESNIE SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. FEET DEG/IO0 FEET FEET FEET 0.00 0,00 -0.06 0.14 0.02 0.09 0.14 0.04 0.21 0.05 0.29 0.10 0.46 0.16 0.77 0.13 1,13 0.03 1.53 0.36 2.40 1.83 6.41 3.08 16.15 3.76 31.92 2.38 51.98 3.93 78.57 3.95 112.29 4.81 155,10 5.21 206.38 2.61 264.07 1.60 327.67 2.43 398.68 3.29 479.88 1.60 566.35 0.93 652.78 0.58 740.94 0.24 830.09 0.54 918.15 0.59 1006.62 0.39 1094.99 0.13 4 93.00 1182.47 0.37 1270.28 1.38 1361.51 3.79 1460.51 2.15 1562.65 2.58 1561.57 0.53 1761.77 0.36 1862.58 Z.01 1958.90 0.07 2054.45 0.14 0.00 N 0.00 E 0.00 0.01 S 0.07 W 0.07 0.10 S 0.01 W 0.10 0.24 S 0.07 E 0.25 0.36 S 0.10 E, 0.37 0.46 S 0.15 E 0.49 0.67 S 0.27 E 0.72 0.90 S 0.52 E 1.04 1.07 S 0.84 E ,1.36 1.25 S 1.21 E 1.74 1.77 S 1.95 E 2,63 4.20 S 5.37 E 6.82 9.05 S 14.04 E 16.?0 14.96 S 28.71 E 32.37 20.17 S 48.10 E 52.16 26.60 S 73.98 E 7B.61 35.80 S 106.43 E 112.29 49.22 S 147.09 E 155.11 69.69 S 194.36 E 206.48 92.93 S 247.46 E 264.33 118.45 S 306.05 E 328.17 146.18 S 371.70 E 399.41 175.23 S 447.64 E 480.71 208.37 S 527.79 E 567.43 243.81 S 607.16 E 654.28 280.84 S 687.82 E 742.94 318.44 S 769.35 E 832.64 356.32 S 849.63 E 921.32 395.08 S 930.06 E 1010.49 434.68 S 1010.11 E 1099.67 474.60 S lOB9.1Z E 1188.04 515.51 S 1168.15 E 1276.84 557.73 S 1250.36 E 1369.11 595.38 S 1342.22 E 1468.34 626.13 S 1439.63 E 1569.89 650.40 S 1535.75 E 1667.80 674.27 S 1633.35 E 1767.05 598.03 S 1731.63 E 1867.03 721.38 S 1825.32 E 1962.70 744.87 S 1918.15 E 2057.70 DEPARTURE AZIMUTH DEG MIN N 0 0 E S 84 14 W S $ 34 W S 16 27 E S 16 19 F S 18 5 t S 21 30 E S 29 52 E S 38 0 E S 43 59 E S 47 42 E S 51 59 E S 57 12 E S 62 28 E S 67 14 E S 70 13 E S 71 24 E S 71 29 E S 70 16 E S 69 25 E S 68 50 E S 63 31 E S 68 37 E S 68 27 E S 68 7 E S 67 47 E S 67 30 E S 67 14 E S 66 59 E S 66 42 E S 65 27 E S 65 11 E S 65 57 E S 66 4 E S 66 29 E S $7 Z E S 67 34 E S 68 2 E S 68 26 E S 68 46 E FT COMPUTATION DATE: 15-NOV-S5 PAGE 5 ARCO ALASKA, INC. 3F-2 KUPARUK NORTH SLOPE,ALASKA D4TE OF SURVEY: 18 OCT 85 KELLY BUSHING ELEVATION: ENGINEER: LESNIE 93.00 FT' INTERPOLATED VALUES FOR EVEN 1.00 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE ~EASURED VERTICAL VERTIC4L DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4776.15 3993.00 3900.00 43 41 4914.56 4093.00 4000.00 43 37 5052.31 4193.00 4100.00 43 26 5189.98 4293,00 4200.00 43 28 5327.76 4393.00 4300.00 43 21 5464.53 4493.00 4400.00 43 2 5601.29 4593.00 4500.00 43 3 5738.54 4693.00 4600.00 43 15 5875.53 4793.00 4700.00 43 2 6012.30 4893.00 4800,00 42 58 6148.73 4993.00 4900.00 42 35 6284.02 5093.00 5000.00 42 3 6418.49 5193.00 5100.00 41 51 6552.34 5293.00 5200.00 41 26 6685.49 5393.00 5300.00 41 9 6818.06 5493.00 5400.00 40 52 6949.84 5593,00 5500,00 40 20 7080.17 5693.00 5600.00 39 35 7209.57 5793.00 5700.00 39 10 7338.24 5893.00 5800.00 38 56 7466.92 5993.00 5900.00 39 10 7595.87 6093.00 6000.00 39 5 7724.46 6193.00 6100.00 38 56 7853.02 6293.00 6200.00 38 56 7864.00 6301.54 6208.54 38 56 DEG MIN FEET OEG/IO0 FEET FEET FEET DEG MIN S 75 37 E 2149.73 S 75 27 E 2245.25 S 75 26 E 2339.81 $ 75 23 E 2434.27 S 75 36 E 2528.86 S 75 29 E 2621.97 S 75 7 E 2715.13 S 75 21 E 2808.98 S 75 46 E 2902.43 S 75 47 E 2995.52 S 74 9 E 3088.20 S 74 25 E 3179.25. S 74 47 E 3269.06 S 74 59 E 3357.92 S 75 10 E 3445.71 S 75 25 E 3532.59 S 75 54 E 3618.25 S 76 5 E 3701.61 S 76 5 E 3783.53 S 76 5 E 3864.29 S 76 3 E 3945.07 S 75 29 E 4016.29 S 74 59 E 4107.02 S 74 59 E 4187.70 S 74 59 E 4194.60 0.25 0.40 0.21 0.41 0.33 0.70 0.14 0.55 0.22 0.48 0.50 0.30 0.33 0.09 0.2.0 0.34 0.69 0.26 0.40 0.23 0.19 0.25 0.00 0.00 0.00 768.49 S 2010.66 E 2152,52 S 69 4 E 792.39 S 2103.33 E 2247.64 S 69 21 E 816.18 S 2195.03 E 2341.86 S 69 36 E 840.06 S 2286.60 E 2436.02 $ 69 49 E 863.80 S 2378.34 E 2530.34 S 70 2 E 886.87 S 2468,74 E 2623.21 S 70 14 E .~ · 910,66 S 2558,96 E 2716,17 S 70 24 E 934,62 S 2649,86 E 2809,85 S 70 34 E '957,98 S 2740,52 E 2903,14 S 70 43 E 980,78 S 2831,00 E 2996.08 S 70 53 E 1004.98 S 2920,59 E 3088.66 S 71 0 E 1029,63 S 3008.32 E 3179,64 S 71 6 E 1053.54 S 3094.97 E 3269.38 S 71 12 E 1076.64 S 3180.90 E 3358.17 S 7'1 18 E 1099.34 S 3265.84 E 3445.90 S 71 23 E 1121.46 S 3350.00 E 3532.73 S 71 29 E 1142.76 S 3433.14 E 3618.34 S 71 35 E 1162.90 S 3514.26 E 3701.67 S 71 41 E 1182.63 S 3593.97 E 3783.55 S 71 47 E 1202.10 S 3672.57 E 3864.30 S 71 52 E 1221.56 S 3751.19 E 3945.07 S 71 57 E 1241.49 S 3830.10 E 4026.29 S 72 2 E 1262,20 S 3908,26 E 4107.02 S 72 6 E 1283,13 S 3986.30 E 4187.72 S 72 9 E 1284.92 S 3992.96 E 4194.61 S 72 9 E ~ ! COMPUTATION DATE: 15-NOV,-85 6 ARCO ALASKA, INC. 3F-2 KUPARUK NORTM SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD 'TD PAGE DATE OF SURVEY: i8 OCT 85 KELLY BU.SHING ELEVATION: ENGINEER: LESNIE 93.oo Fi INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION ORIGIN= 78' FNL, 139' FWL, SEC 29, TIZN~ R9E, UM MEASURED DEPTH BELOW KB TVD FRaM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 7264.00 7390.00 7550.00 771[o00 7750.00 7864°00 5835.25 5742.25 1190.89 $ 3627.28 E 5933.24 5840.24 1209.95 S 3704.16 E 6057.39 5964.39 1234.30 S 3802.11 E 6182.53 6089.53 1260.01 S 3900.09 : 6212.87 6119.87 1266.36 $ 3923.76 ~ 6301.54 6208.54 1284.92 S 3992,96 E ARCO ALASKA~ INC. 3F-2 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: ~~~ STRATIGRA~HIC MEASURED DEPTH BELOW KB 7264.00 7390.00 7550.00 7711.00 7750.00 7864.00 IS-NOV-85 PAGE 7 DATE OF SURVEY: 18 OCT 85 KELLY BUSHING ELEVATION: 93.00 ENGINEER: LESNIE SUMMARY ORIGIN= 78' FNL, TVD FROM KB SUB-SEA 5835.25 5742.25 5933.24 5840.24 6057.39 5964.39 5182.53 6089.53 6212.87 6119.87 6301.54 6Z05.54 139 ' FW REC NO SURF L, S TANG RTH/ 190. 209. 234. 260. 266. 284. ACE LOCATION AT EC 29, TlZN, RgE, ULAR COORDINATES SOUTH EAST/WEST 89 S 3627.28 E 95 S 3704.16 E 30 S 3802.11 E O1 S 3900.09 E 36 S 3923.76 E 92 S 3992.96 E FY UM FINAL MEASURED DEPTH 7864.00 WELL LOCATION TRUE VERTICAL DEPTH 6301.5¢ AT TO: SUB-SEA VERTICAL DEPTH 6208.54 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4194.61 S 72 9 SCHLUMBEROER O f RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. 8-2 WELL 3F-2 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 00007098S WELL NAM~: 3F-2 Sb~FACE LOCATION: 78'FNL, 39'FWL, S29, T12N, R9E, UM A. ~88. VERTICAL PROJECTION -MO00 - 1000 0 0 ! 000 MO00 ~000 4000 SOO0 I i .~ ~ i i ~ i i i ! i I ~ ~T' ~ ;- i ~ ~ i i ! ~ ~ ~ ~ ,- ~ -'T...-TTT'T'T'TT'~ 'FT'~ ~ I~T- : T'T... T T T"~ T TT" T -T.?.:'"- -'i ~ i ~ i -~ ~ -~ ~ -': :' i i [ '~ i i i i i J i ! i i t ..I ! :: [ i i ."~" ~ ! i J [ ,.~..~.,~I~., ~ ? ~'~ i ~ ~ ~ ~ ,'~'."~"t ....... 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T";'";"7","T-'~-T"-T'T"F'T ...... T'"FT"T ..... ?'"T'"T":'"l'"T'"T"'?'r"l'"T'i'"~"T"i .... :-t . 7 ; i T T . ~ T · · ........... ~--~-~ .....J Jt--*t"-t~ ..... T-*'?-t---?- --,--??--~ ...... ~???---.---?-??-?--J---?--, .........~ ~---?--?--~---?--??~ ...... ,---~.--, ....... , .......... ? .+ ..... ,..., ..... ~-., ....... ~ ....... ~ ............. ~ ....... ~ ......... ~ .~... ~. ~-~ J ~ i-: ~ ~ : : i _ '._.~__L..~ ...... ~...i..~...~_. ~.: ~ ..: ..... ~ ..~..&_~ ..,.~..:_2...: ...... :. 5..'...:..~.: .~...~ ......... ~--:---~.--;---L.~--.~;.--~--.~ ...... ~-.-~ ....... ;..L..L.;...~... ...... ;...;.. ~ ..... ~ ...... 2..2 .~ .... ~-~--~:7:~4~:~:-f~ :--~:7:~t~---~-~-~-'~ ...... -1000 0 1000 ZOO0 3000 4000 5000 6000 E~T Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'OPERATOR, W~ELL ~AME AND NUMBER RepOrts and Materials to be received by: / / -/o~ - · Date Required Date Received Remarks Completion Report 7~~ / i~_ / ?~ ~_~_.~ ~____~f~__ Samples ' Hud Log Core Description ., / Inclination..~. Survey .'X~X ~" 6/( Drill Stem Test Reports Production Test Reports Digitized Data ' ARCO Oil and Gas Company Well History - Initial Report- Daily Inlli'~cti~nl: Prepare and submit the "1,~1t RI~' on the first Wednesday after a well is spudded or worl<over operations are starled. Daily wori< prior to sm,~ldlng should be summarized on the form giving inclusive dates only. District Alaska IState I County, pari~ or borough North Slope Borough Field I Lease or Unit Kuparuk River I ADL 25643 Auth, or W,O, fiD. ITitle AFE AK0405 I Drill~ Doyon 9 AP1 50-029-21447 Alaska Iwell no. 31;-2 Operator ARCO Alaska, Inc. Spudded or W,O, begun ARCO W.I. Prior stalUl it s W,O. 56.24% Spudded Date and depth as of 8:00 a,m, 9/26/85 9/27/85 9/28/85 thru 9/30/85 lO/01/85 9/26/85 Complete record for each day reported 0400 hrs. 16" @ ±100' 348', (238'), Drlg NU diverter sys. Accept rig @ 0200 hfs, 9/26/85. Spud well @ 0400 hfs, 9/26/85. Drl to 348'. 16" @ ±100' 2764', (2416'), Drlg Wt. 9.5, PV 14, YP 24, PH 9.0, WL 10+, Sol 9 Drl & surv 12¼" hole to 2764'. 1063', 3.1°, S56.75E, 1063 TVD, 6 VS, 6S, 4E 1306', 10.4°, S73.75E, 1304 TVD, 36 VS, 19S, 31E 1556', 18.9°, S74.75E, 1546 TVD, 99 VS, 34S, 93E 1754', 26.9°, S68.75E, 1728 TVD, 176 rS, 58S, 166E 2118', 35.2°, S68.75E, 2039 TVD, 365 VS, 126S, 342E 2307', 41.0~, S69.75E, 2187 TVD, 482 VS, 163S, 454E 9-5/8" @ 3505' 6342', (3578'), Navi-Drl Wt. 9.4, PV 7, YP 4, PH 10.5, WL 7.2, Sol 8 Drl & surv 12¼" hole to 3520', CBU, short trip, POOH. RU & rn 81 ]ts, 9-5/8", 36#, 3-55 BTC csg w/FS @ 3505', FC @ 3415'. Cmt csg w/980 sx PF "E", followed by 400 sx PF "C" w/.65#/sx PF retarder. CIP @ 0210 hfs, 9/28/85. ND diverter, NU & tst BOPE. RIH w/8½" BHA to FC @ 3415', tst csg to 1500 psi. DO fit equip & cmt + 15' new hole. Conduct formation tst to 12.5 ppg EMW, POOH. RIH w/Navi-Drl, drl & surv to 8½" hole to 6342'. 2497', 41.0~, S66.75E, 2330 TVD, 606 VS, 209S, 569E 2780', 42.1", S65.75E, 2541TVD, 794 VS, 286S, 742E 3155', 41.9", S65.75E, 2821TVD, 1042 VS, 390S, 969E 3565', 42.5", S63.75E, 3126 TVD, 1313 VS, 509S, 1215E 4071', 44.9°, S76.75E, 3485 TVD, 1669 VS, 620S, 1553E 4604', 43.?e, S77.75E, 3865 TVD, 2041VS, 704S, 1917E 5044', 43.3°, S75.75E, 4184 TVD, 2343 VS, 774S, 2212E 9-5/8" @ 3505' 7580', (1238'), Drlg ahead "'~t¥.. Wt. 9.9, PV 12, Y.P 7, PH 10.0, WL 5.6, Sol 12 '~' ,, , , Navi-Drl & surv 8½ hole to 7381 , drl to 7580 . ~.~, 5301', 43.3~, S75.75E, 4371 TVD, 2518 VS, 817S, 5612', 43.1:, S75.75E, 4598 TVD, 2731 VS, 870S, 2589E"t':: .6113', 42.6 , S74.75E, 4965 TVD, 3071 VS, 949S, 2921E '?'~- cz.. 6620 , 41.1 , S75.75E, 5343 TVD, 3408 VS, 1036S, 3247E 7250', 38.9~, S76.75E, 5825 TVD, 3813 VS, 1131S, 3647E "~;~ 7321', 38.8~, S76.75E, 5880 TVD, 3858 VS, 1141S, 3685E ii/ The above is correct Signature IDate Title I1-1-~ I Drillinz Superintendent ARCO Oil and Gas Company Daily Well History-Final RePort Inetructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Filial Rel~rt" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovera when an official teat is nol required upon completion, rel~ort completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting State cost center code Alaska IWell no. 3F-2 District ~County or Parish Alaska I North Slope Borough Field lLease or Unit Kuparuk River I ADL 25643 Auth. or W.O. fid. ~Title AFE AK0405 I Drill Doyon 9 API 50-029-21447 Operator I A.R.Co. W.I. Al{CO Alaska, Inc. 56.24% Spudded or W.O. begun ~Oate Spudded I 9/26/85 Iotal number of.wails (active or inactive) on thisI dst center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 0400 hrs. Date and depth as of 8:00 a.m. Old TD Released rig 10/02/85 lo/o3/85 Complete record for each day reported 9-5/8" @ 3505' 7864', (284'), RIH Wt. 10, PV 16, YP 10, PH 9.0, WL 5.8, Sol 12 Drl 8½" hole to 7864', short trip, CBU, POOH. RU Schl, log DIL/GR/SP/SFL f/7852'-3504', FDC/CNL f/7852'-7000' & 5600'-5,000', CAL f/7852'-3500', .rD Schl. RIH f/cond'g trip. 7" @ 7839' 7864' TD, 7750' TD, RR 9.9 ppg NaC1/NaBr Fin RIH, CBU, POOH, LD DP. RU & rn 181 jts, 7", 26#, J-55 BTC csg w/FS @ 7839', FC @ 7750'. Cmt w/450 sx Cl "G" w/.6% FDP-C344 & .25% HR-7. Displ w/brine, bump plug. CIP @ 0200 hfs, 10/3/85. Tst csg to 3000 psi. ND BOPE, NU tbg head, companion flange & 3" vlv. Tst pack-off. RR @ 0530 hrs, 10/3/85. Moving to DS 3F-3. New TD I PB depth Date IKind of rig 10/3/85 0530 hrs. Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test lime Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date ITitle //-/ For form preparation and ~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent RETURN TO: ARCO Alaska, Inc./'~'~ Post Office b~,x 100360 Anchorage, Alaska 99510-0360 Telephone 907' 276 1215 ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 10-31-85 TRANSMITTAL NO: 5423 ENGINEERING TRANSMITTED hEI~EWITH ARE THE FOLLOWING ITL~4S. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THI$ TRANSMITTAL. FINAL PRINTS/ SCHL/ OPEN HOLE ONE * OF EACH 3C-1~'-~5" DI~/SFL-GR 09-29-85 RUN ~ 1 3705-6844 ~... x,~2 DIL/SFL-GR 09-29-85 RUN #1 3705-6844 /% 5 DEN/NEU PORO 09-29-85 RUN ~ 1 3705-6818 ~x 2 DEN/NEU PORO 09-29-85 t{UN ~1 3705-6818 ~, ~ DEN/NEU' RAW 09-29-85 RUN 91 3705-6818 2' DEN/NEU RAW 09-29-85 RUN 91 3705-6818 · '~CYBERLOOK 09-29-85 RUN 91 6050-6795 3C-i ~"~5' DIL/SFL-GR 09-23-85 ~UN 91 2446-8308 "N32" DIL/SFL-GR 09-23-85 RUN 91 2466-8308 ~2". DEN/NEU-GR PORO 09-23-85 RUN 91 7390-~283 :5" DEN/NEU-GR PAW 09-23-85 RUN 81 7390-8283 "2" DEN/NhU-GR RAW 09-23-85 RUN 91 73~0-8283 "-CYBER.LOOK 09-23-85 RUN 91 7390-8300 3F-2 ~N'~5" DIL/SFL-GR 10-02-85 RUN 91 3502-7844 0-02-8S 02-7844 n~5" DEN/NEU PORO 10-02-85 RUN ~l 3502-7818 "~ ~2" D~N/N~U PORO 10-02-85 RUN ~1 3502-7818 ~" DEN/NEU ~ 10-02-85 RUN ~l 3502-7818 ~2" DEN/NEU RAW 10-02-85 RUN ~l 3502-7818 ~ CYBE~OOK 10-02-85 ~UN ~1 7200-7700 RECEIPT ACKNOWL~:DGED: DATE: DISTRIBUTION: BPAE DRILLING*BL W. PASHER STATE OF B. CURRIER L. JOHNSTON EXXON ~OHIO CHEVRON ~IOBIL PHILLIPS OIL UNION D & H*BL NSK CLEkK*BL J. RA~PIMELL*BL VAULT/ANO*FILM 0~ & 6ss F:nns. ALASKA*BL /SE ARCO Alaska. Inc. is a Subsidiary O! AtlanticRichfieldCompany ARCO Alaska, Inc. ~ Post Office [ .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3F Pad Wel 1 s 1-16 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUll/L22 Enclosure If RECEIVED OCT 2 Alaska Oi~ & Gas Cons. Commission Anchora~s ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany :/--~ AS BU' ', CONDUCTOR, I-e IN ,ECTION Z~ 1- Y=5, ~85,734.98 LAT=70°22 ' 20.0858,, X= 508,662.35 LONG=149°55' 46. 549'' 89 FNL, 162 FWL, 52 O.G., 56.1 PAD- 2- Y=5,985,745.10 LAT=70°22' 20. ~856'' X= 508,638.99 LONG=149°55' 47. 233'' 78 FNL, 139 FWL, 52 O.G., 56.3 PAD 3- Y=5,985,754.79 LAT=70o22 ' 20. 2812" X= 508,616.29 LONG=149°55' 47. 896'' 69 FNL, 116 FWL, 52 O.G. 56.3 PAD 4- Y=5,985,764.77 LAT=70°22 ' 20. 3796'' X= 508,593.66 LONG=149°55' 48. 558" 59 FNL, 93. FWL, 52 O.G. 56.2 PAD ~. ~ 5- Y=5,985,774.87 LAT=70°22'20.4792'' X= 508,570.43 LONG=149°55' 49. 237 ~ 49 FNL, 70 FWL, 52 O'.G. 56.2 PAD 6- Y=5,985,784.84 LAT=70°22'20.5776'' ~ X= 508,547' 58 LONG=149°55' 49' 906" NOTE, ' 39 FNL, 48 FWL, 52 O.G. 56.1 PAD I. COORDINATE, AREA.S.R, ZONE4. 7- Y=5,985,794'93 LAT=70°22,20'6771,' X= 508,524.44 LONG.149°55'50.582'' 2. SECTION LINE DISTANCE, ARETRUE. 28 FNL, 24 FWL, 52 0.G.,55.9 PAD 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8_ y=5,985,804.81 LAT=70o22,20.7744,, ON MONUMENTs 3F'MIDDLE &3F'EAMTPERL.H.D&ASSOC. X= 508,501.41 LONG=149°55,51.256,, 4' O'G' ELEVATIONS INTERPOLATED FROM S/C DWG'NO' 18 FNL, 1 FWL, 52 O.G.,55.9 PAD CED-RIXX-30$O RE~-V~_~. 9A,y~lgT~ CONDUCTOR, 9-1, IN SECTIQN I, o,'~' OF A~%~. - = ,~,~.~ ~.A~=7OO~'~.O~0r' ' ~C~..'"' .... 7':~;~ x= ~o~,~.~z ~.o.c=~°~,~.~,, M'.A% -' ---,/~--~ '.~[' ~' 12 FSL, 67 FEL, 51.20.G., 56.1 PAD f.~/49~~ ::~'~ 10- ¥=5 . 985 , 844. 70 L.~:70°22.21.z678,, ~... ~' ......, ,,. ,~...~... ~ , ' . ,~ ~ ~z~ '~/ = X= 508 410.73 LONG=149°55 53 908'' 21' FSL, 89 FEL, 51.20.G., 56.2 PAD ~j~..OwA~.~.'~-~"^- · .~ . 11- Y=5 985,855 14 LAT=70°22'21 2708" ~%%. az80,s .** .~_~ X= 508,387.41 LONG=149°55' 54. 590'' '~ ~.........-"i~; 3~ ~'s~ ~:~ ~'E~,, ~.~ o.0. ~.~ PAD - ~ .... ,~ ~ , , ~1~;~111~.~,~ 12- Y=5,985,865.19 LAT=70°22' 21.3699" · ~~" . X= 508,364.05 LONG=149°55' 55. 273" I' HEREBY'CERTIFY THAT I AM I"~OI~RLY I~(~ISTERED 42 FSL, 136 FEL, 51.10.G. 56.2 PAD AND.LICENSED TO PRACTICE LAND II)RYEYIM~'IN 13- Y=5,985,874.97 LAT=70°22'21.4663'' THE.STATE OF ALASKA, THAT THIi I'I. AT ,IFaE~ENTS x= 508,341.36 LONG=149°55' 55.937" A SURVEY MADE UNDER MY DIRECT ~#¥1~ION AND 52 FSL, 158 EEL, 51. ]. O.G., 56.3 PAD · THAT CONDUCTOR~ I TNI~I · AR~.CORII~CT AS O~ 14- Y=5,985 885 08 LAT=70°22'21 5660" SEPTEMBER 19,19&· ANO.COMD(N3TOIt~'~ THNU 1· ' ' ' ARE CORRECT A8 OF SEPTEII~ER ~·,1~. X= 508,318.27 LONG=lag°55' 56.612" 62 FSL, 181 FEL, 51.1 0.G.,56.3 PAD .T. ~[ ~_~ :38.3B 15- Y=5,985,894.96 LAT=70°22' 21.6635'' '~ ~ 2 X= 508,295.72 LONG=149°55' 57.271'' c;:¥.--,~ 72 FSL, 204 FEL, 51 O.G. 56.1 PAD · 30 ~). 2 q 25 1~]~5 16- Y:5,985,904.95 LAT:70°22 21.7610" x: ~o8,~7~.~ ~o.0:z~°~,~7.~3,, ~ ' g,~,, or~ . ~; ......... ~2 FSL~ 227 FEL.~ 51 O.G. 56 PAD ~'s DRILL SITE 3 F 6 < a · CONDUCTOR AS-BUILT . 1 LOCATIONI CONDUCTORS I THRU 8 LOCATED IN PROTRACTED --- SEC. Zg, T.I~N.,R.9 E., U, MER. Il'Il& D.t-: Oc,ober 11,1985 Se..: N.T.S. CONDUCTOR, 9 THRU 16 LOCATED IN PROTRACTED SEC. 19, T. IMN.,R.9E.,U. MER. m~,,~.~,,,,,,~ Drifted by: Sydney2 DWI. Ne. Nil( 85-26 i~ETUIIN TO: ARCO Alaska, Inc~.~ Post Offic~ ~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 10-10-85 TKANSMITT~L NO: 5393 Al{CO ALASKA, INC. KUPARUK OPL;RATIONS ENGINEERING I{ECOId)S ATO-1115U P.O. BOX 100360 ANCIiORAGE, AK 99510 T,,~,,,c~:',- .... ,,,.,, ilEREi.,'ITII iU ICi,,L)Jl.,t..I. ,~. I~I.;CEIPT AIiD KETU!{!,I ON OPI. iN IIOLE LIS TA['LS/ ,,./3J-6 u/" 10-02-U5 I%Ui,I -,~3 J-5/ 09-25- . 1 v- ~ 1'U- 24- -"3C-2~ 09-15- ~3C-1 - 09-23- '~3A- 4 ~' 09-21- '~2A- 13~' 07-16- Alii.: TIiE FOLLOWING ITEi:IS. PLLAUE ACIiI~t)WLEDGI] E SIGNED CoPY 0£" Tills TI{ANSI.~ITTAL. #1 ONL T~d'E 42U4.5-S649.5 4317.5-~ 679.0 16UU. 5-8522.0 3493.5-7~/65.5 3'-344.0-8654.0 355}3.0-7622.0 2450.0-8308.0 379}3.5-84;34.0 7643.5-8i6U. 0 PLUS LIST RI: F REF REF REF hEF I{EF RI"F REF ING . #70853 ~7OU4O ~70824 ~70825 ~70832 ~70830 {i 70645---REVISED RECEIPT ACKNO~LEDGUD: -_ DPAL. Dtil LI.,IilG B. CUI,tl,iiER L. JOII.~II3TON C!IEVROH ;. ~c,~'r L : - "~ ' -~. "'>~.¢ ~ DA'I'Ll , , ":7.,.~ ~. '" K.TULItI/VAULT ARCO AIn_~ka, In(: i~ a ~ubsidl,3ry OI Atlanl!¢Rii'hfieldComp~ny ARCO Alaska, Inc. Post Office L .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr.~ Chatterton: Enclosed are the September monthly reports for the 3A-2 3C-3 3J-4 WSP-6I (workover) L3-5 3A-3 3C-16 3J-5 L1-2 4-21 3A-4 3F-1 3J-6 L1-14 (workover) 4-30 3C-1 3F-2 1R-3 L2-13 4-32 3C-2 3J-3 1R-4 L2-26 9-24 following 9-29 11-8 11-9 11-11 15-7 16-17 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRUll/L62 Enclosures wells: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany --- STATE OF ALASKA ~-.. ALASKA C._ AND GAS CONSERVATION CO,...¢IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 79 ' FNL, 139' FWL, Sec.29, T12N, RgE, UM (Approx.) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93' RKB ADL 25643 ALK 2574 7. Permit No. 85-226 8. APl Number 50-- 029-21447 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3F-2 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of September , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well at 0400 hfs, 9/26/85. Drld 12-1/4" hole to 3520'. Ran, cmtd, & tstd 9-5/8" csg. Drilled 8-1/2" hole to 7864' TD (10-1-85). Ran logs· Ran, emtd & tstd 7" csg. PBTD=7750'. Secured well & RR ~ 0530 hfs, 10-3-85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set @ 110' Cmt detail not yet available 9-5/8" 36 0 #/ft, J-55, BTC csg w/shoe @ 3505' Cmtd w/980 sx PF "E" & 400 7" 26 O#/ft, J-55, BTC csg w/shoe @ 7839' Cmtd w/450 sx Class "G" , · · · sx PF "C". 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/GR/SP/SFL F/7852'-3504' FDC/CNL F/7852'-7000' & F/5600'-5000' Cal F/7852-3500' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report06n/l this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ......... DRH/MR44 Submit in duplicate September 17, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F- 2 ARCO Alaska, Inc. Permit No. 85-226 Sur. Loc. 79'FNL, 139'FWL, Sec. 29, T12N, RgE, UM. Btmhole Loc. I409'FNL, 1407'FEL, Sec. 29, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the comductor pipe. Very~ruly yo~, Lonnie C. Smith Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COM}{ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department.of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARco Alaska, Inc. /~-*~ Post Office Bo), ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3F-2 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3F-2, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on S~ptember 23, 1985. any questions, please call me at 263-4970. If you have Sincerely, _~~.,~~~'-]R.glonal Drlllln§ Engineer JBK/HRE/tw PD/L156 Enclosures RECEIVED s 'p z o Alaska O# ~ Gag Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~" ALASKA O,- AND GAS CONSERVATION CO~,,,vllSSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DR ILL [~]X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE ~ MULTIPLE ZONE~_, 9. Unit or lease name '~_~d~ f'~ ~'~ Kuparuk River 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 79' FNL, 139' FWL, 5ec,29, T12N, RgE, UN At top of prgposed producing interval 1273' f~[, 1466' FEL, Sec.29, T12N, RgE, UM At total depth 1409' FNL, 1047' FEL, Sec.29, T12N, RgE, UM 1 5. Elevation in feet (indicate KB, DF etc.) RKB 93', PAD 56' 6. Lease designation and serial no. ADL 25643 ALK 2574 10. Well number 3F-2 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 79' ~ surface feet 3F-1 well 25' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7945' MD, 6303' TVD feet 2560 09/23/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1000 feet. MAXIMUM HOLEANGLE 43 Ol(see2OAAC25.035(c) (2) 2665 .psig@ 80°F Surface 3060 psig@ 6000 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE I H°le I Casing i 24" 16" 12-1/4" 9-5/8" [8-1/2" 7" Weight 62.5# 36. O# 26. O# 22. Describe proposed program: CASING AND LINER Grade Coupling 1-55/HF-E~ 1-55/HF'EIrW BTC Length MD TOP TVD 80' 35' I 35' 3460' 35' I 35' I 7911' I 34' I 34' MD BOTTOM TVD 1151 115' 3495~ 3073' I 7945q 6303' I I (include stage data) + 200 cf 900 sx PF "E" & 400 sx PF "C" 325 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7945' MD (6303' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 1375/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2665 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F=2 will be 25' away from 3F-1 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23.1hereby ~J~2at the foregoing is true and correct to the best,~~/~ . of my knowledge SIGNED / ~ TITLE Regional Drilling Engr. DATE T h e spa c e ~l/~vv~, ~¢~C ~rn/~l~'ss~o n ~ e-- ' CONDITIONS OF APPROVAL Samples required I--lYES /~O Permit number Mud log required []YES ~ Directional Survey required [~f-ES ~NO APl number 50- oZ.? Approval date -~ 09/17/85 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE September 17, 19R5 by order of the Commission Form 10-401 (HRE) PD/PD156 Submit in triplicate - o~ 200 $~ cement ~mo~e~O" ~ck -ln~" ~d ~tn~, ~d uP°n ~ ~pon ~"'~ ~rct%C r~.~' ~ OerfOra~ .,~a and %es%~ _ ~d RECEIVED S E P 1 0 k985 Alaska Oil & Gas CoRs. Commission Anchorage ........ D"~: i000 ' 2000 3000 . 4000 5000 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage SCALE I PRO JE C T ! 13Id ;, ,1..00, _ 100 _ 200 . 300 _ 400 . 5'00 . NO~E' WEL:L P~ATHS 5XTEND ,!~¥~3ND rH!$ V /,,- ' N-O. .TH 1355 14414 2~ 23 227'8 t I 1 I ~02 51 KUPARUK R I VER UNIT '20" DIVERTER SCHEMATIC DE $CR ! PT [ ON i. 16- C(~TOR. 2. TAI~{O STARTER HEJO. 2. TAI~I<O SAVER 51J~. 4. TAI~I<O LOVER QUICK-C(~CT ASSY. S. TAI~I<O UPPER QUICK-Ci~CT ASSY. 6. 20" 2000 PS! DRILLING 5PO(3L W/I0" OUTLETS, 7. I0" HCR BALL VALVES W/lO" DIVERTER LINES° VALVES OPEN AUTOMATICALLY U~(DN CL(3~ 01: ANnUl. AR PREVENTER. 8. 20" 2000 PSI AI~IJLAR PREVENTER. 6 MAINTENANCE & OPERATION I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AIk~) VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AN~4ULAR PREVENTER AI~) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE AI~I~ULAR PREVENTER IN THE EVENT THAT AN I~IrLUX OF V~LL~ FLUID~ OR GAS IS DETECTED. IF NECES~Yo MANUALLY OVERRIDE AbI) CLOSE APPROPR]ATE VALVE TO ACHIEVE ~I~l) DIVERSIOt~ DO NOT SHUT IN V4EL.L UNL'~R ANY CIRCUMSTANCES- 7 6 DIAGRAM #1 ~// 13-5/8" 5000 PSI RSRRA 80P STA(~ I. 16' - ~ ~I T~ ST~I~ ~ 2. I1' - ~ ~[ ~[~ ~ 3. I1' - ~ ~I X 1~8'~~ ~I ~ ~ K~ LZ~ 7. 1~8' - ~ ~I -. ACCt.M.LATCR CApAqITY TEST I. C]-E:CX AI~ FILL AO3.M,,LATCR RF.,.RERVOIR TO LEVEL WITH HYI:::RN~IC FLUID. 2. ASSU~ THAT AC::C1.M.LATCR ~ IS ,:TK:X::IO PSI WITH 1500 PSI DO/e~TRF, Na CF' ~ i::F.(~LATCR. 3. C~ TIll, ~ CLC~I~ ALL UNITS ALL LIMITS ~E CLO~D WITH ~IN~ PU~P CFF. 4. RECCIqD ~ NAOC RE:PCRT, TIE. ACCEPTABLE LCIR(~ LIMIT IS 45 SE~ CLOSING T~lVE ~ 12DC) PSI REMAINING 5 4 > IVED o !985 Alaska Oil & Gas Cons. ¢ommissior, Anchorage 13-5/~" BCI3 ~TACK TEST I. FILL B(3:~ STAO( AI~ ~ MN~FCLD WITH ARCTIC DIF.~. 2. C3..[CX THAT ALL LCX3< ~ SCRLrYeS IN WELJJ-EAD ARE FULLY F~RACTED. ~F=AT TF. ST PLU~ IN ~ WITH RUtCql~ Jl' A~ ~ IN L~ LII~ VALVES AD~ TO ~ STACX, ALL OT~ 4. PRF~ UP TO 250~ FC~ I0 MIN. IN- a~.AS[ P~E~ TOt~~ HOlD FC~ I~) MIN. BLEED PR~SS~ TO 0 PSI. LI~E VALVES. CLOSE TCP PIPE ~ A~ H(~ VALVES CN KILL. A~D C~ 6.TEST TO 250 PSI ~AS IN STEP 4. ?. CCINTI~ TESTING ~F~o LII~o A~D CHCKES WITH A 250 PSI LOW A]~ _3000_~ PSI HIGH. TEST AS iN STEP 4. m3 N~T p~r~ T~.~T ANY CWa<Z THAT NOT A FLLL CLOSlN~ pOSITIVE SEAL CHC~E. CN_Y Fu~ricN TEST ~ THAT DO bDT FULLY CL__ngE_. 8. 01~ TC~ PIPE RAW4S ~ CLOSE BOTTCM PIPE RAMS. TEST BOTTOa PIPE RAMS TO 2.50 PSI A~ 3000 PSI. 9.CI~ BOTTCM PIPE RAMS, BA(]( OUT Rt~N~ JT I0. CLOSE BLIhD RAMS A~ TEST TO 250 PSI ~ 3000 PSI. MANIFOLD ~ LIhES ARE F1.M.L CF NCI~ING FLUID. ~-r ALL VALVES IN C~ILLINO PO~ITIGN. 12. TEST STAI~IPE VALVES° KFI/Yo KELLY COCKS° C~ILL PIPE SAFETY VALVE, AI~ INSIDE B43m TO 2.50 PSI 3000 PSI. 13. REC~ TEST II~C~TICN CN BLC~ PREV~ TEST FCI~o SIGN, AhD ~ TO C~ILLINO SI~ISCR. 14. PERF(~ COv~ B(]:~ TEST ~ NIPPLIN~ il: A~ WEE)(LY THEREAFTER FlJNCTI~Y CI~TE B(]~ DAILY. M~Y 15,, 19~5 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~/z~-'~:: ITEM APPROVE DATE (1) Fee ¥',/">~.- :;/ " ~'..1 ,~ ~ . . ~/~' .~. (2) Loc ., (2 thru 8) (3) Admin Y'.'- ~/~-'/[< (9 thru 12) (10 and 1 (13 thru ill)' (22 thrff' 26) i · YES Is the permit fee attached ...................... · .................... · 2. Is well to be located in a defined pool .......................... 3. Is well located proper distance from property line ............. 4. Is well located proper distance from other wells ............ :~.. 5. Is sufficient undedicated acreage available in thi; ;ool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. NO 27. Does operator have a bond in force .................................. Is a conservation order needed el~leeellleeeeeeleeeeeeeeee~eeeeeeeeee Is administrative approval needed ................................... Is the lease number appropriate ' Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ......... Will surface casing protect freSh water zones ...i.i~iiii..ii.ii. Will all casing give adequate safety in collapse, tension and burstl Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ................. ' ........... Is a diverter system required ....................................... ~ . Are necessary diagrams of diverter and BOP equipment attached ....... /~ Does. BOPE have sufficient pressure rating - Test to .~m~ psig .. ~ .... Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................ . .................. ~_ Additional requirements ............................................. ~ Additional Remarks: REMARKS Geology: Engineer in~: WVA ,- MTM HJH . JAL ("~,. ' rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , ~ , 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 APPENDIXl No special'effort has been made to chronologically . . organize this category of information, ********************** ~T$ TA~ UNIT ~J'Y PE CATE SIZE CODE 000 000 olg 065 000 000 004 065 000 000 OOB 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 OhO 000 003 065 !.INIT TY~C CATE SIZE CODE 000 000 001 065 T,, V r,' 0.1, 0. H O 7 V i¢; ? 1' F Z C.. A ? l r! ~,4 'L, ? 8 T 'L ~'! 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