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198-049
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 18, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-10 KUPARUK RIV UNIT 1D-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 1D-10 50-029-22870-00-00 198-049-0 W SPT 6180 1980490 1545 1750 1751 1751 1754 465 688 674 668 4YRTST P Austin McLeod 7/13/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-10 Inspection Date: Tubing OA Packer Depth 760 2500 2385 2370IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220714083450 BBL Pumped:1.6 BBL Returned:1.4 Thursday, August 18, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:09:05 -08'00' IO RECEIVED ConocoPhillips APR 0 6 2016 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 4, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SOWS APR 0 8 2016 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. No cement was pumped. The corrosion inhibitor/sealant was pumped March 25, 2016 & March 28, 2016. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, 00/*/ __/2;. MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • S ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 4/4/2016 1D-10, 2N-302, 2N-331, 2N-335, 2N-243&2X-1 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-10 50029228700000 1980490 11" NA 11" NA 4.00 3/25/2016 2N-302 50103203800000 2011150 10" NA 10" NA 5.90 3/25/2016 2N-331 50103202650000 1981170 20" _ NA 20" NA 10.00 3/28/2016 2N-335 50103202740000 1982040 23" NA 23" NA 15.50 3/28/2016 2N-343 50103202600000 1980920 26" NA 26" NA 15.50 3/25/2016 2X-01 50029209630000 1830840 25" NA 25" NA 9.00 3/25/2016 Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, March 07, 2016 8:47 AM To: Wallace, Chris D (DOA); Regg, James B (DOA); Brooks, Phoebe L tDOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; Senden, R. Tyler Subject: Recent non witnessed MITIA performed in KRU Attachments: MIT KRU 1D-10 non witnessed 03-06-16.xls Attached is a copy of the MITIA performed on 1D-10 (PTD 198-049). The test was done as a stipulation in Sundry#314- 439 that the well would be retested once it had been WAG'd to gas injection. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 SCANNED SEP 2 3 2016 AWELLSTEAM conoaPhaps 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggt6alaska.gov• AOGCC.Inspectors(rtalaska.00v. phoebe.brooks(W.alaska.gov chris.wallacet talaska.gov keie 7j 1(0 OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/1 D Pad DATE: 03/06/16 OPERATOR REP: Duffy/Sumrall AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-10 Type Inj. G - TVD -6,180' Tubing 3,431 3,431 3,428 3,428Interval 0 P.T.D. 1980490 - Type test P Test psi 1545 Casing 466 2,500 2,400 2,390 P/F P 'r Notes: Non Witnessed MITIA while on gas injection OA 580 822 809 799 Test was completed per Sundry#314-439 stipulation that would be retested once the well was on gas injection. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing . P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing. P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 1D-10 non witnessed 03-06-16.xIs Kea Pm t 9to4cic Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, February 26, 2016 4:11 PM \7a, . Ij To: Regg,James B (DOA) Cc: NSK Fieldwide Operations Supt Subject: 1D AOGCC inspector deficiency reports response Attachments: 1D Deficiencies reports 02-26-16.pdf Jim—enclosed is ConocoPhillips response to the deficiencies noted by the AOGCC inspector during the 2/22/16 SVS testing on 1D pad. Please let me know if any further action is needed. Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) s`AINED SEP 2 32016 K AA t0-10 • • 1)-N) (Ct(,Q4cie conocoPhillips Alaska AOGCC EXCEPTION REPORT Location: 1D Pad Date: 02/22/16 AOGCC Inspector: Guy Cook Instructions:All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered Into the'Action Taken'section below. Note-Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: 10-02- Possible SSV bonnet seal leak. Choke stem leak, packing needs to be tightened or replaced. This 1D-10.-Choke stem leak, packing needs tightened or replaced. 1D-110-Choke stem leak, packing needs tightened or replaced. 1D-141 -SSV barrel leaking hydraulic fluid from plug Action Taken to Correct Problem: Date: 02/26/16 Initials: JRH 1D-02 choke has been inspected and rebuilt Date: 02/26/16 Initials: JRH 1D-10 choke has been inspected and rebuilt 1D-110 choke was visualy inspected. No apparent leaks. Snoop Date: 02/26/16 Initials: JRH tested the stem and actuated, then used snoop again. No leaks 1 D-141 SSV barrerl was serviced by the valve crew. No longer Date: 02/26/16 Initials: JRH leaking. Date: Initials: Date: Initials: Return completed form to Prod. Engr.Specialist: n1139(a conocoohillios.com Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist G.C. CPF1&2 Ops Supt CPF3 Ops&DOT Pipelines Supt NSK Fieldwide Operations Supt • • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: // L4724 - /1)—J0 Date: 2/2. 114::. d� PTD: / Fife /i la Operator: 44.0 Jp,(,, i1 i -. Type Inspection: sus Operator Rep: , 4. � Inspector: G�i (4514._ Position: � , Op. Phone: to J q— 72-2-9 Correct by(date): 2/ �9 I I Op. Email: / Follow Up Req'd: I Detailed Description of Deficiencies Date Corrected /„CQ1C • /rL Vie_ ..P / Operator Rep Signatures: AOGCC Inspector *After signing,a copy of this f is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification (Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 04/2015 STATE OF ALASKA - ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing E Operations shutdown E Performed: Suspend r Perforate r Casing r AlterCi9 r Change Approved Program r Plug for Redrill E Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Conductor Ext N.T. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory I- 198-049 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic (` Service 50-029-22870-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025650 KRU 1D-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7340 feet Plugs(measured) None true vertical 6633 feet Junk(measured) None Effective Depth measured 7245 feet Packer(measured) 6810 true vertical 6547 feet (true vertical) 6157 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 0 0 SURFACE 4737 12 4778 4351 0 0 PRODUCTION 6988 10 7027 6350 0 0 LINER 518 6.062 7339 6632 0 0 Perforation depth: Measured depth: 7148-7228 ti %.,; `' S') ` True Vertical Depth: 6459-6531 RECEIVED FEB 12 2010 Tubing(size,grade,MD,and TVD) 4.5, L-80,6813 MD, 6160 TVD AOGCC Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER LOCATOR SEAL ASSEMBLY STABBED INTO EXISTING PBR, SEALS SPACED OUT 1.4'FROM FULLY ENGAGED 8/14/2007 @ 6810 MD AND 6157 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service E Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL E Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ E WAG F GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-657 Contact MJ Loveland Email n1878conocophillips.com Printed Name MJ Loveland, Title WI Project Supervisor Signature Phone:659-7043 Date 2/11/16 i —...„t4:1_,..t.._______ 1/1-1 2/161i, Form 10-404 Revised 5/2015r Z/� RBDMS LL- F 1 2 2016 Submit Original Only • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 FEB 12 2016 AOGCC February 11, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1D-10, PTD 198-049, Sundry 315-657 conductor extension. Please contact MJ Loveland at 659-7043 if you have any questions. Sincerely, „AAA.i. g-(A) Roger Winter ConocoPhillips Well Integrity Field Supervisor • w 1D-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/06/16 Prep&weld 11"extension on conductor made with 16"x .375 wall pipe. • OF 7'4, I%7,cs. THE STATE AlaskaOil andGas - ofConservation Commission ALAsKA 333 West Seventh Avenue Alaska 99501-3572 GOVERNOR BILL WALKER Anchorage, Main: 907.279.1433 �FALAS' Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland WI Project Supervisor 0'q ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-10 Sundry Number: 315-657 Dear Ms. Loveland: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 23Acklay of October, 2015 Encl. RBDMS her 2 6 2015 STATE OF ALASKA •KA OIL AND GAS CONSERVATION COMADION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations r Fracture Stimulate E Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Conductor Ext F• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. ' Exploratory r Development r 198-049 • 3.Address: 6.API Number: Stratigraphic r Service F-• P.O. Box 100360,Anchorage,Alaska 99510 50-029-22870-00 ' 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Wit planned perforations require spacing exception? Yes r No 1' ✓ KRU 1D-10 RECENED 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025650 , Kuparuk River Field/Kuparuk River Oil Pool . OCT2 1 2015 11. PRESENT WELL CONDITION SUMMARY /,, / 4 ) /!S' Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): °'1O GCC 7340 ' 6633 ' 7245' - 6547' . None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' 0 0 SURFACE 4737 12 4778' 4351' 0 0 PRODUCTION 6988 10 7027' 6350' 0 0 LINER 518 6.062 7339' 6632' 0 0 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7148-7228 • 6459-6531 4.5 L-80 6813 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) . SEAL ASSY-BAKER LOCATOR SEAL ASSEMBLY STABBED INTO MD=6810 TVD=6157 NO SSSV 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r Development r Service F14.Estimated Date for Commencing Operation 11/2/2015 15. Well Status after proposed work: WINJ r WDSPL r Suspended .1— OIL r 16.Verbal Approval: Date: GAS E WAG F ' GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the est of my knowledge. Contact: MJ Loveland Email: n1878@conocophillips.com Printed Name MJ Lov la Title: WI Project Supervisor Signature / Phone:659-7043 Date 10/19/15 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315-451 Plug Integrity E BOP Test E Mechanical Integrity Test E Location Clearance r Other: Spacing Exception Required? Yes ❑ No 4l Subsequent Form Required: / — 4 U 1-/- Approved I APPROVED BY A roved b :�, , OMMIS IONER THE COMMISSION Date/0-23-/< pp y j• : c• .p• i a io i v td for 1�m�1onths from thre�date of approval. Submit Form and Form 10-403 Revised 5/2015 � ' . AAD ioIv../ Attachments in Duplicate V TL 6c`Z3/`5 ,w eO/y�5' R�3DM fCT 2 6 2015 • • • RECEIVED ConocoPhillips OCT 2 1 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 19, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1D-10, PTD 198-049 conductor extension. Please contact MJ Loveland at 659-7043 if you have any questions. Sincerely, MJ Lovela ConocoPhillips Well Integrity Projects Supervisor S II PV ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska, Inc. Kuparuk Well 1D-10 (PTD 198-049) SUNDRY NOTICE 10-403 APPROVAL REQUEST October 19, 2015 This application for Sundry approval for Kuparuk well 1D-10 is to extend the(conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 8". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP INJ ID 1D-10 r.' • ConocoPhillips 1 Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) e,..,„4hnipe 500292287000 KUPARUK RIVER UNIT INJ 28.57 2,117.68 7,340.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-10,11/11/20149.41.57 AM SSSV:NIPPLE Last WO: 8/15/2007 42.21 4/12/1998 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,144.0 11/9/2014 Rev Reason:TAG,PULLED CATCHER,PLUG lehallf 11/11/2014 HANGER;36.4- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread -, CONDUCTOR 16 15.063 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(EKE) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 41.0 4,777.8 4,351.4 40.00 L-80 BTC Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L.:Grade Grade Top Thread t. . , PRODUCTION 7 6276 38.6 7,027.0 6,3499 2600 L-80 MOD BTC li ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth IRKS) Set Depth(ND)...WtlLen II...Grade Top Thread LINER 41/2 3.958 6,821.2 7,338.8 6,632.3 12.60 L-80 NSCT 7Liner Details .. .. e /alb Nominal ID Top(kK0) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 6,821.2 6,166.7 27.50 PBR BAKER PBR 4.750 f- 6,836.1 6,179.9 27.44 PACKER 'BAKER ZXP LINER TOP PACKER 3.875 '"A-~A CONDUcroa;at.S-t2tt 6,842.9 6,186.0 27.42 HANGER BAKER HMC LINER HANGER 3.937 7,062.1 6,381.4 26.15 NIPPLE -CAMCO DB-6 NO GO NIPPLE 3.750 NIPPLE;477.9 ar"" Tubing Strings a Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO I 3 1/21 2.9921 36.41 6,827.31 6,172.21 9.301 L-80 I EUE8RDMOD Completion Details ( Nominal ID Top(ftKB) Top(ND)(f(KB) Top Incl 7) Item Des Com (in) Wiz36.4 36.4 0.00 HANGER 4.5"NSCT TUBING HANGER 4.500 . 477.9_ 477.7 4.73 NIPPLE CAMCO DS NIPPLE 2.875 6,775.8 6,126.5 27.66 NIPPLE CAMCO DS NIPPLE 2.813 6,809.7 6,156.5 27.54 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY STABBED INTO 2.992 EXISTING PBR,SEALS SPACED OUT 1.4'FROM FULLY ENGAGED 8/14/2007 Perforations&Slots snot Den Top(ND) Btm(TVD) (shotsff SURFACE;41.0-4.777.8 A Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,148.0 7,214.0 6,458.8 6,518.5 C-4,C-3,1D- 1/27/2007 6.0 RPERF 2-7/8"HSD PJ Omega 10 Guns,60 deg.phase 7,175.0 7,195.0 6,483.2 6,501.3 C-4,C-3,10- 5/18/1998 4.0 IPERF 27/8 HC,DP 10 GAS LIFT;6,725.4 7,220.0 7,228.0 6,524.0 6,531.3 C-3,C-2,1D- 1/27/2007 6.0 APERF 2-7/8"HSD PJ Omega _ - 10 Guns,60 deg.phase Mandrel Inserts St ° ati NIPPLE;6,775.8 ..ir on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 6.725.4 6.081.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/8/2014 Notes:General&Safety End Date Annotation p 8/3/2006 'NOTE:WORKOVER U. SEAL ASSY;6,809.7 8/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 I Z.J 10/8/2014 NOTE:Repaired Production Casing Leak at 6320'with Seal-Tite. 0 PRODUCTION;38.6-7.027.0- RPERF;7,148.0-7,214.0, IPERF;7,175.0.7.195.0 APERF;7.220.0-7,228.0 LINER;6,821.2-7,338.8 .~ Pages NOT Scanned in this Well History File fI XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /9Y:" - 6'-/9 File Number of Well History File PAGES TO DELETE Complete RESCAN 0 Color items - Pages: 0 Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: 0 0 Other - Pages: DIGITAL DATA 0 Diskettes, No. 0 Other, Noffype OVERSIZED 0 Logs of various kinds 0 Other COMMENTS: Scanned by: Beverly Mildred o"aretha eLowell Dat~: -;2/;;;..(ß Isl /I.J- 0 TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl • • cilWa WELL LOG TRANSMITTAL PRO ivE i A i SERVICES, /�Cil DI � INC. 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 544MAILV MAR 0 3 2O11 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 3O- Jan -11 1A-26 1 Report / EDE 50-029-22115-00 2) Caliper Report O5 -MR -11 1D-10 1 Report / EDE 50-029- 22870-00 � qlr — o e lg ao HO- - i& e g0 ?3 (1'6- FEE 1 2°11 Signed : Date Print Name: MOM rYt CGIS. "t SS1 ti PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E-MAIL : pdsanchora®eimemorvloa.com WEBSITE : WWW.memorvioci.com C:\Documents and Settings\Diane Williams \Desktop \Transmit_Conoco.docx I . • Multi- Finger Caliper � Lo Results Summary 9 Company: ConocoPhillips Alaska, Inc. Well: 1D-10 Log Date: February 5, 2011 Field: Kuparuk Log No.: SO# 10258371 ZX70 State: Alaska I Run No: 2 API No.: 50- 029 - 22870 -00 Pipet Desc.: 3.5" 9.3 lb. L -80 Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 6,810 Ft. (MD) I Pipe2 Desc.: 4.5" 12.6 lb. L -80 Pipe2 Use: Liner Top Log Intvl: 6,810 Ft. (MD) Bot. Log Intvl: 6,895 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection I COMMENTS : This caliper data is correlated to the Tubing Tally Record. I This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing appears to be in good to fair condition, with a maximum I recorded wall penetration of 27% in joint 202 (6,402'). Recorded damage appears as a line of pits and isolated pitting. There are no areas of cross - sectional wall loss recorded throughout the 3.5" logged. The caliper recordings indicate light deposits from 2,650' to 6,895' (end of log), restricting the I.D. to 2.68" and 2.75" in joints 192 (6,071') and 159 (5,052') respectively. A graph illustrating minimum recorded I diameters on a joint by joint basis is included in this report. The caliper recordings indicate the two joints of 4.5" liner logged appear to be in fair condition, with wall penetrations of 29% and 24% recorded in joints 215 (6,871') and 216 (6,893') respectively. Recorded I damage appears as a line of pits. No significant areas of cross- sectional wall loss or I.D. restrictions are recorded throughout the liner logged. The body region analysis and joint tabulation sheets for the 3.5" tubing and 4.5" liner are combined. I This is the second time a caliper has been run in this well and the first time the 3.5" tubing and 4.5" liner have been logged. This summary report is interpretation of data provided by Halliburton Well Services. 1 3.5" TUBING & 4.5" LINER- MAXIMUM RECORDED WALL PENETRATIONS : Line of Pits ( 29 %) Jt. 215 @ 6,871 Ft. (MD) I Line of Pits ( 27 %) Jt. 202 @ 6,402 Ft. (MD) Line of Pits (24 %) Jt. 216 @ 6,893 Ft. (MD) Isolated Pitting ( 22 %) Jt. 208 @ 6,563 Ft. (MD) Isolated Pitting ( 22 %) Jt. 192 @ 6,063 Ft. (MD) 1 3.5" TUBING & 4.5" LINER - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the tubing and liner logged. I 3.5" TUBING & 4.5" LINER - MAXIMUM RECORDED ID RESTRICTIONS : Deposits Minimum I.D. = 2.68 ins Jt. 192 @ 6,071 Ft. (MD) Deposits Minimum I.D. = 2.75 ins Jt. 159 @ 5,052 Ft. (MD) I No other significant I.D. restrictions are recorded throughout the tubing and liner logged. I I Field Engineer: D. Schwarzenberger Analyst: C. Lucasan Witness: J. Condio ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS@imemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 I 1 , 1 - 0 4{ 61 9 I • • Correlation of Recorded Damage to Borehole Profile I Pipe 1 3.5 in (39.3' - 6810.2') Well: 1D-10 Pipe 2 4.5 in (6810.2' - 6877.7') Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 5, 2011 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 41 d — I I 25 = 825 I 50 1608 I 75 2391 III i p I 45 1 00 4 3174 -- Z s I . 0 125 3959 Q I 150 4743 I 175 5527 I 200 6309 GLM 1 _A I 216 6878 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 216 I I I I • • I Minimum Diameter Profile I Well: 1 D -10 Survey Date: February 5, 2011 Field: Kuparuk Tool: UW MFC 24 No. 10000428 HAL I C ompany: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches 1 Minimum Measured Diameters (In.) 1.69 1.94 2.19 2.44 2.69 2.94 I 0.1 i 3 10 1= I 16 I T. 23 30 I 37 44 s � 51 I 58 65 I 72 s_ 79 M. 86 I= 93 I WM 100 = 107 IS Z .. 114 -_ 121 mu 128 = 135 I 142 149 l= 156 i = I 163 170 I_ 177 1 184 -1--4- 191 I ye 198 205 212 214 I l i l I I I I II • ' PDS Report Overview S Body Region Analysis I Well: 1D-10 Survey Date: February 5, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 2.992 ins 3.5 ins 6.0 ins 6.0 ins I 4.5 ins 12.6 ppf L -80 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration(% wall) Damage Profile (% wall) I 250 Penetration body Metal loss body 0 50 100 200 0 1 150 100 1 50 0 46 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 223) I 212 11 0 0 96 1 Damage Configuration ( body) 80 iiii I 60 1.--- 146 40 1 20 _ I Isolated General Line Other Hole/ 1 96_ Pitting Corrosion Corrosion Damage Pos. Hole GLM 1 I Number of joints damaged (total = 80) 64 0 16 0 0 Bottom of Survey = 216 I I 1 I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips, Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: February 5, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile 0 I No. (Ft.) Upset Body % Loss I.D. Comments (/o wall) (Ins.) (Ins.) `)/0 (Ins.) 0 50 100 0.1 39 0 0 0 O 2.92 Pup Lt. Deposits. 1 41 0 0.03 10 4 2.97 1.1 73 0 0.02 6 2 2.93 Pup Lt. Deposits. 1.2 82 0 0.02 7 2 2.93 Pup 1.3 90 0 0.02 7 3 2.93 Pup Lt. Deposits. I 1.4 100 0 0.03 12 0 2.93 Pup • 2 102 0 0.03 10 1 2.96 ■ 3 134 0 0.03 11 2 2.95 • 4 165 0 0.02 9 2 2.97 I 5 196 0 0.02 8 2 2.96 6 228 0 0.02 8 2 2.95 7 258 0 0.02 9 2 2.93 8 290 0 0.03 10 2 2.96 ■ I 9 321 0 0.02 9 3 2.97 0 352 0 0.03 11 3 2.96 0.1 384 0 0 0 0 2.87 Camco DS Nipple I ! 11 386 0 0.02 8 2 2.96 12 417 0 0.02 8 2 2.97 I 13 448 0 0.02 9 2 2.93 14 480 0 0.02 9 2 2.95 15 511 0 0.03 10 2 2.95 16 543 0 0.02 9 1 2.96 17 574 0 0.03 13 3 2.95 Shallow Pitting. 18 605 0 0.02 9 2 2.94 19 637 0 0.02 7 2 2.95 3 20 668 0 0.02 9 3 2.95 I 21 699 0 0.02 6 2 2.97 22 731 0 0.03 11 4 2.96 • 23 762 0 0.03 12 3 2.98 • 24 793 0 0.02 6 2 2.97 I 25 825 0 0.02 8 3 2.97 26 856 0 0.03 12 3 2.97 • 27 887 0 0.02 9 2 2.98 7 28 919 0 0.02 7 1 2.96 29 950 0 0.03 10 2 2.97 I 30 981 0 0.01 6 2 2.97 31 1013 0 0.04 15 6 2.96 Shallow Apparent Wear. • 32 1044 0 0.03 12 4 2.96 Shallow Apparent Wear. • 33 1075 0 0.02 9 1 2.96 • I 34 1107 0 0.03 11 2 2.96 • 35 1138 0 0.02 9 1 2.97 • 36 1169 0 0.03 10 2 2.96 ■ 37 1200 0 0.03 12 3 2.96 • I 38 1232 0 0.03 11 2 2.96 ■ 39 1263 0 0.03 11 2 2.96 • 40 1294 0 0.03 12 2 2.96 N 41 1326 0 0.02 9 2 2.96 42 1357 0 0.03 10 4 2.96 ■ I 43 1389 0 0.03 11 2 2.97 44 1420 0 0.02 9 2 2.97 ti I Metal Loss on Body I Page 1 Penetra I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 Well: 1D-10 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips, Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Iris.) (Ins.) % (Ins.) 0 50 100 45 1451 0 0.03 12 3 2.97 • 46 1483 0 0.03 10 2 2.97 ••1 47 1514 0 0.03 13 4 2.96 Shallow Pitting. • 48 1546 0 0.03 11 4 2.96 • I 49 1577 0 0.03 10 2 2.97 50 1608 0 0.02 9 2 2.96 51 1639 0 0.03 11 2 2.97 • 52 1670 0 0.03 13 4 2.94 Shallow Pitting. ■ 53 1702 0 0.02 9 3 2.97 I 54 1733 55 1764 0 0.02 7 2 2.97 0 0.02 9 2 2.98 • 56 1796 0 0.02 9 2 , 2.97 is 57 1827 0 0.02 9 2 2.96 ■ I 58 1858 0 0.03 12 4 2.95 59 1890 0 0.02 9 3 2.95 60 1920 0 0.02 9 2 2.95 ■ 61 1952 0 0.03 11 2 2.96 I 62 1983 0 0.02 9 2 2.94 63 2014 0 0.03 10 3 2.96 • 64 2046 0 0.03 13 5 2.97 Shallow Pitting. • 65 2077 0 0.04 15 3 2.96 Shallow Apparent Wear. • 66 2108 0 0.03 12 2 2.97 • I 67 2140 0 0.04 17 4 2.97 Shallow Apparent Wear. • 68 2171 0 0.03 13 3 2.96 Shallow Apparent Wear. ■ 69 2203 0 0.02 9 2 2.96 IN 70 2234 0 0.03 11 4 2.95 • I 71 2265 0 0.02 9 2 2.95 IN 2297 0 0.03 11 3 2.98 • ■ 73 2328 0 0.03 10 1 2.96 ■ 74 2359 0 0.03 13 4 2.95 Shallow Apparent Wear. ■ I 75 2391 0.03 11 3 2.96 76 2422 0 0.02 9 1 2.98 77 2453 0 0.03 13 4 2.95 Shallow Apparent Wear. • 78 2484 0 0.03 10 2 2.96 ■ 79 2515 0 0.03 12 4 2.96 Shallow Apparent Wear. • I 80 2547 0 0.02 9 2 2.96 ■ 81 2579 0 0.03 11 1 2.96 ■ 82 2610 0.03 0.03 13 3 2.93 Shallow Apparent Wear.. Lt. Deposits. • 83 2641 0 0.03 10 2 2.94 • I 84 2673 0 0.03 11 3 2.92 Lt. Deposits. ■ 85 2704 0 0.03 10 2 2.97 86 2736 0 0.02 9 2 2.95 87 2767 0 0.02 9 2 2.96 I 3 88 2799 89 2829 0 0.02 7 2 2.96 0 0.02 8 2 2.96 90 2860 0 0.03 11 1 2.95 ■ 91 2891 0 0.03 11 3 2.94 • I 92 2923 0 0.02 9 3 2.92 Lt. Deposits. 93 2954 0 0.02 9 2 2.94 94 2985 0 0.02 9 1 2.95 Penetration Body I Metal Loss Body Page 2 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips, Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: February 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 95 3017 0 0.03 10 2 2.93 96 3049 0 0.02 9 2 2.94 97 3080 0 0.03 11 2 2.94 98 3111 0 0.02 9 2 2.94 99 3143 0 0.02 9 2 2.97 I 100 3174 0 0.02 7 2 2.92 Lt. Deposits. 101 3205 0.10 0.02 9 2 2.91 Lt. Deposits. 102 3237 0 0.02 8 2 2.94 103 3269 0 0.03 11 3 2.93 Lt. Deposits. • I 104 3300 0.03 0.04 17 5 2.93 Shallow Apparent Wear. Lt. Deposits. ■ 105 3331 0 0.03 10 1 2.95 • 106 3363 0 0.03 11 3 2.93 Lt. Deposits. • 107 3394 0 0.03 12 3 2.94 • I 108 3425 0 0.03 11 4 2.94 • 109 3457 0 0.03 11 2 2.92 Lt. Deposits. • ■ 110 3488 0 0.04 14 6 2.90 Shallow Apparent Wear. Lt. Deposits. ■ 111 3519 0 0.03 13 4 2.92 Shallow Apparent Wear. Lt. Deposits. • 112 3551 0 0.03 12 4 2.93 Lt. Deposits. • I 113 3582 0.17 0.03 10 2 2.91 Lt. Deposits. • 114 3614 0 0.03 10 3 2.92 Lt. Deposits. ■ 115 3645 0 0.03 11 2 2.93 ■ 116 3677 0 0.03 10 2 2.96 ■ I 117 3708 0 0.03 10 2 2.94 ■ 118 3740 0 0.03 11 2 2.94 ■ 119 3771 0 0.03 13 4 2.93 Shallow Apparent Wear. • 120 3803 0 0.02 9 2 2.95 • I 121 3834 0 0.03 11 2 2.92 Lt. Deposits. • 122 3865 0.03 0.04 14 4 2.91 Shallow Apparent Wear. Lt. Deposits. ii 123 3897 0 0.03 10 2 2.93 Lt. Deposits. • 124 3928 0 0.03 13 3 2.92 Shallow Apparent Wear. Lt. Deposits. • I 125 3959 0 0.04 14 2 2.93 Shallow Line of Pits. Lt. Deposits. IN 3991 0 0.03 11 2 2.94 • ■ 127 4022 0 0.02 9 2 2.94 • 128 4053 0 0.03 10 2 2.93 Lt. Deposits. on 129 4085 0 0.03 11 3 2.94 • I 130 4116 0 0.03 13 4 2.92 Shallow Apparent Wear. Lt. Deposits. • 131 4148 0 0.03 12 3 2.92 Lt. Deposits. ■ 132 4179 0 0.02 9 2 2.91 Lt. Deposits. • 133 4211 0 0.03 11 4 2.91 Lt. Deposits. ■ I 134 4242 0 0.02 9 2 2.93 Lt. Deposits. • 135 4273 0 0.03 11 2 2.92 Lt. Deposits. • ■ 136 4305 U 0.03 11 3 2.91 Lt. Deposits. ■ 137 4336 0 0.04 14 2 2.92 Shallow Pitting. Lt. Deposits. IN I 138 4367 0 0.03 11 4 2.90 Lt. Deposits. ■ 139 4399 0 0.03 11 2 2.91 Lt. Deposits. • ■ 140 4430 0 0.03 11 2 2.92 Lt. Deposits. • 141 4461 0 0.03 10 2 2.92 Lt. Deposits. ■ I 142 4492 0 0.03 11 2 2.93 Lt. Deposits. 143 4523 0 0.02 9 2 2.90 Lt. Deposits. 144 4555 1) 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. rat I Metal Loss ion Body Page 3 Penet I I I • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -10 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips, Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: February 5, 2011 1 Joint Jt. Depth Pen. Pen. Pen. Me(,il Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 145 4586 0 0.03 11 3 2.93 Lt. Deposits. 21 146 4617 0 0.03 10 2 2.88 Lt. Deposits. ■ 147 4649 0 0.04 16 3 2.91 Shallow Pitting. Lt. Deposits. • 148 4680 0 0.03 11 2 2.91 Lt. Deposits. • 149 4712 0 0.03 13 2 2.88 Shallow Pitting. Lt. Deposits. lo ' 150 4743 0 0.02 9 3 2.91 Lt. Deposits. • 151 4775 0 0.03 10 2 2.91 Lt. Deposits. ■ 152 4806 0 0.04 18 5 2.85 Shallow Pitting. Lt. Deposits. ■ 153 4838 () 0.03 13 2 2.88 Shallow Pitting. Lt. Deposits. ■ I 154 4869 0 0.03 13 2 2.86 Shallow Pitting. Lt. Deposits. • 155 4900 0 0.03 11 4 2.89 Lt. Deposits. • ■ 156 4931 0 0.04 17 2 2.91 Shallow Pitting. Lt. Deposits. • 157 4962 0.03 0.03 12 3 2.88 Shallow Pitting. Lt. Deposits. • 158 4993 0 0.06 22 5 2.86 Line of Pits. Lt. Deposits. ■ 159 5025 0 0.04 17 2 2.75 Shallow Line of Pits. Deposits. ■ 160 5055 0.03 0.05 19 3 2.89 Shallow Line of Pits. Lt. Deposits. • 161 5086 0.03 0.03 13 5 2.87 Shallow Line of Pits. Lt. Deposits. ■ I 162 5118 0 0.03 11 2 2.87 Lt. Deposits. • 163 5150 0 0.04 16 2 2.91 Shallow Pitting. Lt. Deposits. • ■ 164 5181 0 0.05 21 4 2.86 Isolated Pitting. Lt Deposits. • 165 5212 0 0.03 11 2 2.89 Lt. Deposits. • 166 5244 0 0.03 11 1 2.92 Lt. Deposits. ■ I 167 5275 0 0.02 9 2 2.92 Lt. Deposits. • 168 5306 0 0.04 16 3 2.83 Shallow Line of Pits. Lt. Deposits. ■ 169 5338 0.04 0.04 14 5 2.88 Shallow Pitting. Lt. Deposits. • 170 5369 0 0.05 18 4 2.85 Shallow Line of Pits. Lt. Deposits. ■ I 171 5401 0 0.05 18 3 2.91 Shallow Pitting. Lt. Deposits. • 172 5432 0 0.03 11 2 2.91 Lt. Deposits. • ■ 173 5464 0 0.04 16 2 2.90 Shallow Line of Pits. Lt. Deposits. • 174 5495 0 0.05 21 4 2.87 Line of Pits. Lt. Deposits. • I 175 5527 0.03 0.05 21 3 2.88 Isolated Pitting. Lt. Deposits. • 176 5558 0 0.04 15 2 2.92 Shallow Pitting. Lt. Deposits. • 177 5589 0 0.04 17 2 2.88 Shallow Line of Pits. Lt. Deposits. • 178 5620 0 0.03 10 4 2.89 Lt. Deposits. ■ 5653 0 0.05 20 2 2.92 Shallow Pitting. Lt. Deposits. • I 179 180 5684 0 0.03 12 3 2.91 Shallow Pitting. Lt. Deposits. • 181 5714 0 0.05 18 4 2.88 Shallow Pitting. Lt. Deposits. ■ 182 5746 0 0.04 14 3 2.89 Shallow Line of Pits. Lt. Deposits. • 183 5776 0 0.04 18 5 2.81 Shallow Pitting. Lt. Deposits. II ' 184 5808 0 0.05 18 4 2.87 Shallow Line of Pits. Lt. Deposits. • 185 5840 0.03 0.03 13 3 2.88 Shallow Pitting. Lt. Deposits. • 186 5869 () 0.04 14 3 2.88 Shallow Pitting. Lt. Deposits. ■ 187 5902 (1 0.03 13 3 2.92 Shallow Pitting. Lt. Deposits. ■ I 188 5932 0 0.03 11 2 2.79 Deposits. • 189 5964 0 0.04 14 2 2.90 Shallow Pitting. Lt. Deposits. • 190 5995 (U34 0.04 14 2 2.85 Shallow Pitting. Lt. Deposits. • 191 6027 0 0.05 18 4 2.87 Shallow Pitting. Lt. Deposits. ■ 192 6057 0.15 0.06 22 4 2.68 Isolated Pitting. Deposits. ■ 111 193 6090 0 0.03 10 2 2.90 Lt. Deposits. • 194 6121 0.03 0.03 13 4 2.86 Shallow Line of Pits. Lt. Deposits. rat I Metal Loss ion Body I Page 4 Penet I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips, Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: February 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( wall) (Ins.) (Ins.) To (Ins.) 0 50 100 I 195 6151 0 0.05 18 3 2.89 Shallow Pitting. Lt. Deposits. • 196 6184 0.03 0.04 16 3 2.81 Shallow Pitting. Lt. Deposits. • 197 6215 0 0.04 15 4 2.86 Shallow Pitting. Lt. Deposits. ■ 198 6247 0 0.04 17 4 2.81 Shallow Line of Pits. Deposits. ■ 199 6278 0 0.03 11 3 2.87 Lt. Deposits. ■ I 200 6309 0 0.04 17 4 2.86 Shallow Pitting. Lt. Deposits. ■ 201 6340 0 0.04 15 2 2.84 Shallow Pitting. Lt. Deposits. ■ 202 6373 0 0.07 27 4 2.86 Line of Pits. Lt. Deposits. ■ 203 6404 0 0.05 19 3 2.77 Shallow Pitting. Deposits. • 1 204 6435 0.04 0.04 18 4 2.83 Shallow Line of Pits. Lt. Deposits. ■ 205 6467 0 0.03 13 3 2.85 Shallow Pitting. Lt. Deposits. ■ 206 6498 0 0.05 18 2 2.81 Shallow Line of Pits. Lt. Deposits. ■ 207 6528 0 0.05 20 3 2.86 Line of Pits. Lt. Deposits. • 208 6560 0.04 0.06 22 4 2.88 Isolated Pitting. Lt. Deposits. • 209 6591 0 0.04 14 4 2.82 Shallow Pitting. Lt. Deposits. • 210 6624 0.03 0.04 15 4 2.87 Shallow Line of Pits. Lt. Deposits. ■ 211 6654 0 0.04 17 6 2.83 Shallow Line of Pits. Lt. Deposits. ■ I 212 6686 0 0.04 17 4 2.80 Shallow Pitting. Deposits. • 212.1 6718 0 0.04 14 2 2.85 Pup Shallow Pitting. Lt. Deposits. 212.2 6728 0 0 0 0 2.81 GLM 1 (Latch @ 1:30) I 212.3 6736 0 0.03 11 4 2.79 Pup Deposits. • 213 6747 0 0.03 11 2 2.88 Lt. Deposits. 1 213.1 6778 214 6780 0 0 0 0 2.76 Camco DS Nipple 0 0.04 15 4 2.83 Shallow Line of Pits. Lt. Deposits. 214.1 6810 0 0 0 0 2.87 Baker Locator / Seal Assembly 214.2 6817 0 0 0 0 3.56 Baker PBR I 214.3 6833 0 0 0 0 3.68 Baker ZXP Liner Top Packer 214.4 6840 0 0 0 0 3.77 Baker HMC Hanger 215 6847 0 0.08 29 5 3.81 Top of 4.5" Liner. Line of Pits. Lt. Deposits. • 216 6878 0 0.07 24 3 3.88 Line of Pits. Lt. Deposits. I 'Penetration Body Metal Loss Body I I I I Page 5 I I I • • I P PDS Report Cross Sections (......_.. S,, I Well: 1 D -10 Survey Date: February 5, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 4.5 ins 12.6 ppf L -80 Analyst: C. Lucasan I I Cross Section for Joint 215 at depth 6871.107 ft Tool speed = 59 Nominal ID = 3.958 1 Nominal OD = 4.5 Remaining wall area = 96% i i Tool deviation = 27° ■ \ N 1 — ) 1 1 . . / 1 1 Finger = 16 Penetration = 0.079 ins Line of Pits 0.08 ins = 29% Wall Penetration HIGH SIDE = UP I I I I I I • • I PDS Report Cross Sections +P 11. Well: 1D-10 Survey Date: February 5, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan I I Cross Section for Joint 202 at depth 6402.127 ft Tool speed = 63 Nominal ID = 2.992 I Nominal OD = 3.5 __ Remaining wall area = 97% /�— Tool deviation = 25° I I / ' N 1 I \ ( --____ I I 7 1 I '1www""'....- ' Finger = 14 Penetration = 0.069 ins Line of Pits 0.07 ins = 27% Wall Penetration HIGH SIDE = UP I I I I I I 0 • I PDS Report Cross Sections S I Well: 1D -10 Survey Date: Tool Type: February 5, 2011 Field: Kuparuk UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan I I Cross Section for Joint 192 at depth 6070.567 ft Tool speed = 64 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 99% Tool deviation = 26° / 1 1 i\ r 1 I 1 / i Minimum I.D. = 2.676 ins Deposits Minimum I.D. = 2.68 ins HIGH SIDE = UP 1 I I I • 0 I PDS Report Cross Sections I Well: 1D-10 Survey Date: February 5, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan I II Cross Section for Joint 159 at depth 5052.007 ft Tool speed = 63 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 99% Tool deviation = 28° 411111e ''`,. / \ I \\.. I Minimum I.D. = 2.754 ins Deposits Minimum I.D. = 2.75 ins HIGH SIDE = UP I I I I I • KRU 1D-10 ° ConocoPhillips Alaska, Inc. I C. 'ix HNIi•- 1D -10 API: 500292287000 Well Type: INJ Angle @ TS: 25 deq @ 7147 TUBING SSSV Type: NIPPLE Orig 4/12/1998 Angle @ TD: 24 deg @ 7340 (45 -6821, OD:3.500, Completion: I I -477 Annular Fluid: Last W /O: 8/15/2007 Rev Reason: TAG SURFACE Reference Log: Ref Log Date: Last Update: 10/2/2007 (0-.778, Last Tag: 7206 SLM TD: 7340 ftKB uvtao.00j Last Tag Date:, 9/29/2007 Max Hole Angle: 29 deq @ 2118 Casing String - ALL STRINGS I Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H -40 Welded SURFACE 9.625 0 4778 4352 40.00 L -80 BTC 'RODUCTION PRODUCTION 7.000 0 7027 6350 26.00 L -80 Mod BTC I (0 -7027, I LINER 4.500 6821 7339 6632 12.60 L -80 NSCT 00:7.000, T String - TUBING wt26.00) Size Top Bottom TVD Wt Grade Thread 4.500 0 45 45 12. L -80 NSCT 3.500 45 6821 6167 9.30 L -80 8rdEUE I Perforations Summary Interval TVD Zone Status Ft SPF D ate Type Comment NIP 7148 7175 6460 6484 C -4 27 6 1/27/2007 RPERF 2 -7/8" HSD PJ Omega (6773 4.550) Guns, 60 deg. phase I OD:4.550) 7175 - 7195 6484 - 6502 C -4,C -3 20 10 1/27/2007 RPERF 2 -7/8" HSD PJ Omega Guns, 60 deg. phase 7195 - 7214 6502 - 6519 C -3 19 6 1/27/2007 RPERF 2 -7/8" HSD PJ Omega Guns, 60 deg. phase xo 7220 - 7228 6525 - 6532 C -3,C -2 8 6 1/27/2007 APERF 2 -7/8" HSD PJ Omeg (6806 -6807, Guns, 60 deq. phase I OD:4.550) SEAL Gas Lift Mandrels/Valves (6807 - 6815, St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv 00:4.750) Cmnt - 1 6723 6080 CAMCO MMG DMY 1.5 RK 0.000 0 8/23/2007 I Other (plugs equip., etc.) - COMPLETION Depth TVD Type Description ID 34 34 HANGER 4.5" NSCT TUBING HANGER 3.883 PBR 37 37 XO NSCT 4.5" x 3.5" CROSSOVER 2.992 (6813 -6822, 00:4.500) 476 476 NIP CAMCO 'DS' NIPPLE 2.875 I 6773 6124 NIP CAMCO 'DS NIPPLE 2.813 6806 6154 XO 3.5" x 4.5" CROSSOVER 2.992 6807 6154 SEAL BAKER LOCATOR /SEAL ASSEMBY STABBED INTO EXISTING PBR, 2.992 SEALS SPACED OUT 1.4' FROM FULLY ENGAGED 8/14/2007 6813 6160 PBR Baker PBR 8/7/2006 3.813 I LINER 6836 6180 LINER PKR Baker ZXP LINER TOP PACKER 3.953 (6821 -7339, 6843 6186 LINER Baker HMC 3.938 00:4.500, wtlzso) HANGER 7062 6382 NIP CAMCO NO GO NIPPLE 3.750 7336 6630 SHOE Baker FLOAT SHOE 3.953 LINER HANGER (6843-6844, I OD:5.875) I • I NIP (7062 -7063, OD:4.500) El Pert (7148 -7214) I Pert - (7175 -7195) I i I ~J MEMORANDUM To: Jim Regg P.I. Supervisor ~G ~(Z~CLt~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 D-10 KUPARUKRIV UNIT 1D-]0 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~.~~ Comm Well Name: KUPARUK RIV UNIT 1D-10 Insp Num: mitRCN100718153342 Rel Insp Num: API Well Number: 50-029-22870-00-00 Permit Number: 198-049-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-10 ~ Type Inj. N TVD 6180 ' IA 34 2806 "' 2714 2690 P.T.D 1980490 ~ TypeTest SPT Test psi 2806 QA 513 847 827 816 InterVal4YRTST p~ P ~ Tubing 2050 2075 2075 2075 Notes: ~u1 ~ ~1, P e y ~~~ -~S'~" l ~fS~s; Thursday, July 22, 2010 Page 1 of 1 • . ~ ~ ~ Robert Christensen Production Engineering Specialist. ~,/ Greater Kuparuk Unit , NSK-69 ~ ~ „~ LG~~ PO Box 196105 ConocoPh ~ I I ~ ps ~~ ~ v ~ Anchorage, AK 99519-6105 Phone: (907) 659-7535 - A~BSI(i~ alb ~ ~, ~5 i',~1 , +..~°11iiiS~i~~c: 659-7314 F1l~Ct;~~ vt~u November 13, 2008 / ~ q ~~ Tom Maunder, P.E. Senior Petroleum Engineer State ofth laska, Oil & Gas Conservation Commission E,•.~-~ , ~~~V ~~~~ 33 W. 7 Ave. Ste. 100 ~'~'~" Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has begun Gas Injection is association with the Kuparuk River Oil Pool 1 D FOR Expansion. Enclosed .you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for Wells 1 D-O5, 1 D-06, 1 D-10, 1 D-11, 1 D-11 L 1, and 1 D-11 L2. This report records the commencement ofwater-alternating-gas injection service. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, ""-----_ Robert D. Christensen Attachments • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIQNS- 1. 0 erations Pertormed: Abandon p ^ ^ Repair Well ^ Plug Perforations ^ a 1 D EORX Stimulate • Oti~er WINJ Alter Casin g ^ Pull Tubin Pertorate New Pool g ^ ^ Waiver ^ ~~ ^ Time Extension WAGIN Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhllllps Alaska, InC. Development ^ Exploratory ^ 198-049 • 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22870-00 7. KB Elevation (tt): 9. Well Name and Number: RKB 112' 1 D-10 8. Property Designation: 10. Field/Pool(s): ADL 25650,•ALK 468 Kuparuk River Field /Kuparuk Oil Pool • 11. Present Well Condition Summary: Total Depth measured 7340' ~ feet true vertical 6633' feet Plugs (measured) Effective Depth measured 7319' feet Junk (measured) true vertical 6614' feet Casing Length Size MD ND Burst Collapse CONDUCTOR 121' 16" 121' 121' SURFACE 4778' 9-5/8" 4778' 4352' PRODUCTION 7027' 7" 7027' 6350' LINER 518' 4-1/2" 7339' 6632' Perforation depth: Measured depth: 7148'-7214'; 7220'-7228' true vertical depth: 6460'-6519'; 6525'-6532' Tubing (size, grade, and measured depth) 4-1/2" x 3-1/2", L-80, 6821' MD. •--~^ Packers &SSSV (type & measured depth) Packers =Baker ZXP Packer = 6836' ' °`~' , ~~~ ~~ ~ ~~~ ~~ SSSV =Nipple SSSV = 476 12. Stimulation or cement squeeze summary: ~~~ Intervals treated (measured) '~"''~` ta~ O Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 3025 ~ 1550 2462 Subsequent to operation 1255 - 166 1694 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAG^~ ~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Bob Christensen/Vacant ' Printed Nam o D. Chr t sen Title Production Engineering Technician Signature ~~~--- Phone: 659-7535 Date Ct ~ ,~ a /ID ~~~~ ~ r '~``~ ~ ~ ~ Et ~ ~ ~~ Submit Origjnal Only Form 10-404 Revised 04/2084 ~ I ~ f ~ ~~~~ p i ~ 1 D-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/03/08 Commenced 1D EORX WAGIN Injection 10/26/07 Initial state witnessed MIT-IA post RWO (passed ). T/I/0= 1250/1040/520. Pressured up IA with 1.5 bbls diesel. T/I/0=1250/2520/690. 15 min T/I/0= 1250/2455/680. 30 min T/I/0=1250/2430/660. Bled IA. Final T/I/0= 1250/1090/480. . • KRU 1 D-10 ConocoPhillips Alaska, Inc. 1 D-10 API: 500292287000 Well T e: INJ An le TS: 25 de 7147 ruewc SSSV Type: NIPPLE Orig 4/12/1998 _ _ ___ _ Angle @ TD: 24 deg @ 7340 (as~azl, oD:3.5o0, Com letion: ID:z.ss2) Annular Fluid: _ _ Last W/O: 8/15/2007 Rev Reason: TAG SURFACE ~ ~ Reference Lo Ref Lo Date: Last U ate: 10/2/2007 (o-477a, Last Ta :7206 SLM _ TD: 7340 ftKB OD:9.625, wc:ao.oo) -- - Last Ta Date: 9/29/2007 in Strin -ALL STR C _ Max Hole An le: 29 de INGS - 2118 g g as Description Size To Bottom TVD _ Wt Grade_ Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded SURFACE 9.625 0 4778 _ _ 4352 40.00 _ L-80 BTC ~ROOUCnoN _ P_R_ODUCTIO_N_ _ __ 7.000 _ __ 0 7027 _ _6350 26.00 L-80 Mod BTC (0-7027, LINER 4.500 6821 7339 6632 12.60 L-80 NSCT oD:7.oo0, Tubin Strin -TUBING " wczs.oo> ~ Size Tom -- - -- -- Bottom TVD - -- Wt Grade Thread - 4.500 0 45 45 12.60 L-80 NSCT _ 3.500 45 6821 6167 9.30 L-80 8rdEUE Perf_ orations Summa Interval TVD Zone Status Ft SPF - Date T e Comment NIP - - -- --~- -- - 7148 - 7175 6460 - 6484 C-4 27 6 1/27/2007 RPERF 2-7/8" HSD PJ Omega (8773b77a, OD:4.550) Guns, 60 de hase 7175 - 7195 6484 - 6502 C-4,C-3 20 10 1/27/2007 RPERF 2-7/8" HSD PJ Omega Guns 60 de hase 7195 - 7214 6502 - 6519 C-3 19 6 1/27/2007 RPERF 2-7/8" HSD PJ Omega Guns 60 de hase xo 7220 - 7228 6525 - 6532 C-3 C-2 8 6 1/27/2007 APERF 2-7/8" HSD PJ Omega (s6os~eo7, , Guns 60 de . hase OD:4.550) , SEAL Gas Lift Mandrels/Valve -- - - s._____ _- - - - (6807~815, St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv OD:4.750) Cmnt _ _ 1 6723 6080 CAMCO MMG DMY 1.5 RK 0.000 0 8/23/2007 pe~_ _TV~ equp., et Type c.) - COM_ P_ LETION I Des_c -- _rlption _ _ ___ ID 34 34 HA NGER ' 4.5" NSCT TUBING HANGER 3.883 (sal3~azz _ 37 37 XO NSCT 4.5" x 3.5"CROSSOVER 2.992 OD:4.500) 476 476 NIP CAMCO 'DS' NIPPLE 2.875 6773 6124 NIP CAMCO'DS NIPPLE 2.813 6806 6154 XO 3.5" x 4.5" CROSSOVER 2.992 6807 6154 SEAL BAKER LOCATOR/SEAL ASSEMBY STABBED INTO EXISTING PBR, 2.992 SEALS SPACED OUT 1.4' FROM FULLY ENGAGED 8/14/2007 _ 6813 6160 PBR Baker PBR 8/7/2006 3.813 LINER 6836 6180 LINER PKR Baker ZXP LINER TOP PACKER 3.953 (6821-733s, 6843 6186 LINER Baker HMC 3.938 oD:a.SOO, wr.lzso) ~ HANGER 7062 6382 NIP CAMCO NO GO NIPPLE 3.750 7336 6630 SHOE Baker FLOAT SHOE 3.953 LINER HANGER 6843 6844 ( - , OD:5.875) NIP (7062-7063, OD:4.500) Perf (7148-7214) Perf (71757195) MEMORANDUM TO: Jim Regg P.I. Supervisor ~~ ~ ~~~~ ~d FROyt: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Comm~sswn DATE: Monday, November 05, 2007 SUBJECT: Mechanical integrity Tests CONOCOPHILL[PS ALASKA INC 1 D-10 KLPARUK RIV UNIT ID-l0 5rc: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv y~[~;?-!' Comm Well Name: KUPARUK RN UNIT ID-10 API Well Number: ~0-029-22870-00-00 Inspector Name: Bob Noble Insp Num: mitRCN071028042234 Permit Number: 198-049-0 Inspection Date: 10i26l2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~' 1D-1o ~TypeInj. ; w ; TVD 6I8o IA Io4o ', 2szo-~ 24ss za3o , I 1980490 ' SPT P.T. ~ TypeTest ~~ ~~ Test psi 1545 "r QA~ 620 690 ~ j i _ 680 I 660 _ ~ Interval n`~T~- P/F P _ =~ Tubing ~ 1260_.., 1250_ ! I26o j 12so Notes: ~~~ N~i~I ~ ~~~~ •w _: ,,:.~ Y ...-.. _......... ,..,.__,:w.. _.... 4~~.0~9 Monday, November O5, 2007 Page l of 1 a ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 14, 2007 • RECEIVED O C T I ~ 2007 Alaska Oil & Gas Cons. Cow Anchorage Mr. Tom Maunder / ~ ~q Alaska Oil & Gas Commission ~C~ 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 ~~1~~~~ Nov o ~ Zaa7 Dear Mr. Maunder: -Enclosed please find a~spreadsheet with a list of ~wvells ~fram-the Kti~~ruk field (KRfiJ). ° Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor,. engineered to prevent water from entering the annular space. As per previous agreement with he AOGCC, this .letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on August 21 & September 28, 2007 and the corrosion inhibitor/sealant was pumped on. September 28 & 29, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and. volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~ .~.~. Perry Kl --___ ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Data ~ nr~ w t~nn~ Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 L-28 199-098 15' 6" 2 4" 8/29/2007 1 9/28/2007 1 C-102 201-161 29' 8 24" 9/21 /2009 11.5 9/29/2007 1 D-10 198-049 sf n/a sf n/a 4 9/29/2007 . . RECEIVED SEP 0 5 Z007 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION Gas Cons. Cnmmissióf\ Other Anclîi1rage Time Extension D D Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41','Pad 71' 8. Property Designation: ADL 25650,' ALK 468 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: Stimulate D Waiver D Plug Perforations D , Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D Exploratory Service D o Re-enter Suspended Well 5. Permit to Drill Number: 198-049 1 . 6. API Number: 50-029-22870-00 ,,' 9. Well Name and Number: 10-1 0 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool ' measured 7340' / feet true vertical 6633.... feet measured 7319' feet true vertical 6614' feet Length Size MD 80' 16" 121' 4737' 9-518" 4778' 6986' 7" 7027' 518' 4-1/2" 7339' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4352' 6350' 6632' ~ .'.............'" -'9 U ..'............. of·._,. Measured depth: 7148'-7214', 7220'-7228' true vertical depth: 6460'-6519',6525'-6532' 5CÞ1NNED SEP 272007 Tubing (size, grade, and measured depth) 4-1/2" x 3-1/2", L-80, 45' x 6821' MD. Packers & SSSV (type & measured depth) Baker lXP liner top packer @ 6836' Cameo nipple @ 476' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na na SI Subsequent to operation na na Si 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD Gas D WAG D GINJ 0 WINJ 0 ," WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ifC.O. Exempt: ~~O~- \, Form 10-404 Revised 04/2004 0 R I Contact Printed Name Signature Jill Long @265-1102 Jill L0l"!.g Wells Group Engineer O '7 Date t..--- Pre are SEP 2 [j 2007 .¡ \.. ft" '\'J>'\ Title Phone o I NA~DMSBFl Sharon AlIsu Drake 263-4612 ~ .,.$"'.07 ~su?(~al Only · ~ ConocoPhillips We/Mew Web Reporting Time Log Summary 16:00 18:00 2.00 MIRU RIGMN RURD Preparing to pull BPV check for ressure. 18:00 19:00 1.00 MIRU RIGMN SFTY Pre-spud meet with rig crew. 19:00 00:00 5.00 MIRU WELCT NUND NU BOP system. 08/13/2007 00:00 00:30 0.50 MIRU WELCT NUND Continue nipple up BOP. CAli AOGCC John Crisp waived witness of test 0020 Au ust 13, 2007. 00:30 02:30 2.00 MIRU WELCT NUND Continue Rig up of BOP. 02:30 08:00 5.50 MIRU WELCT BOPE Begin BOP test. 08:00 09:00 1.00 PROD1 EVALFI RURD Check BPV for pressure. Pull BPV. Screw in landin ·oint. 09:00 09:30 0.50 PROD1 RPCO OWFF Watch well for flow. 09:30 11:30 2.00 PROD1 RPCOII. CIRC Pull hanger to floor. Up WT = 86K. No problems. Load hole with 9.6 PPG Brine. Begin reverse circulation X 2 hole volumes. 11:30 12:30 1.00 PROD1 WELCT OWFF Monitor well after reverse circulating 2.5 X hole volume. Losses = O. 9.6 in - 9.6 out. 12:30 00:00 11.50 PROD1 RPCOII. TRIP Finished pulling completion at midnight. Pull 4.5" 12.6 PPF L-80 tubing. All NSCT is to be normed prior to leaving. Begin preparations to strap 3.5" completion. Pre-job safety meet & Pre-tower. Current joint = 204 OOH Hole stable no losses. 08/14/2007 00:00 01:30 1.50 PROD1 RPCOII. PULD P Empty pipe shed of used 4.5" tubing. 01:30 05:30 4.00 PROD1 RPCOII. PULD P Loading pipe shed, strap pipe, and change out handling equipment for 3.5" tubin . 05:30 13:30 8.00 PROD1 RPCO RCST P Added new redressed seal assb. and began running the 3.5" completion per rocedures 13:30 15:30 2.00 PROD1 RPCOII. RCST P Ran completion per procedure - stung in to the top of the PBR with seal assb. 6813' MD 08/14/2007 15:30 16:30 1.00 PROD1 RPCOII. DHEQ P Pressured up to 500 psi on annulus - good - slacked off 10' to locator sub on seals 16:30 18:30 2.00 PROD1 RPCOII. CIRC P Pull out of seals and circulate 240 bbls inhibited 9.6# brine w/1 % by volume Baker Petrolite CRW-132 18:30 19:30 1.00 PROD1 RPCOII. DHEQ P Sting back in and engage seals and pressure test IA to 500 psi - Space out l' off bottom 19:30 22:00 2.50 PROD1 RPCOII. HOSO P Add pup joints for space out. Land tubing and RILDS. Space out l' off bottom 22:00 00:00 2.00 PROD1 RPCOII. DHEQ P Rig up char! recorder to tubing and IA - drop ball and rod - pressure test tubing to 2500 psi for 15 min. with the annulus 0 en. Test ood 08/15/200700:00 01:00 1.00 PROD1 RPCOII. DHEQ P Bled off tbg. pressure to 1750 psi - pressure up IA to 2500 psi for 30 min. Bled tbg pressure to zero to shear the SOY. 01:00 06:00 5.00 PROD1 RPCOII. NUND P Set two way check. Strip BOP's off well re are to install roduction tree. 06:00 10:00 4.00 PROD1 RPCO NUND P Install tree - pull two way check and install BPV - Pressure test tree to 5000 si - ood 10:00 00:00 14.00 PROD1 MOVE DMOB P 10:00am Rig Released - begin moving equipment via floats and wait on Peak trucks from Deadhorse. Peak trucks arrived at 1830. Leave location for 1 R @ 2200. On location at 1 R pad 0000 Au 16,2007 API/UWI 5002922870 Ground Elevation (It) 69.39 Surface Legal Location 11N 10E 23 'Original KB Elevation (It) 111.60 s s S Yes Yes I Yes Field Name KUPARUK RIVER UNIT KB-Ground Distance (It) 42.21 . , - , " .. .. , ..' - , License No. StateiProvince Alaska KB-Casing Flange Distance (It) - 41/2 41/2 36.42 L-801 ' '1(\(\1 L-80 1.00 '> <1' 9.3 3 1/2 9.30 L-80 9.98 3 1/2 9.30 L~80 9.94 31/2 9.30 L-80 8.15 3 1/2 ' 9.30 L-80 2.10 3 1/2 9.30 L-80 31.34 3 1/2 9.30 L-80 31.32 3 1/2 9.30 L-80 31.34 3 1/2 9.30 L-80 I '11 '1<; 31/2 9.30L-80 31.34 Well Configuration Type 'KB- Tubing Hanger Distance (It) 0.0 6,82 .... 36.4 39.416,787.... No No U I I I DISTANCE for "RKB" .5" NSCT tubing hanger 4.5" NSCT X 3.5" Cross over 3.5" 9.3# coÜar 1- 3.5" 9.3# L-80 8rnd EUE (pup joint) .5" 9.3# L-80 8rnd EUE (pup joint) " 3- 3.5" 9.3# L-80 8rnd EUE (pup joint) #; L-80 8rnd EUE (pup joint) Yes 214 3.5" 9.3# L-80 8rnd EUE 213 3.5" 9.3# L-80 Yes 212 3.5" 9.3# L-80 8rnd EUE 211 3.5" 9.3# L-80 8rnd EUE 210 3.5" 9.3# L-80 8rnd EUE 209 3~5u 9::.g1fL..~80:,-:árnd El..JE - s 208 3.5" 9.3# L-80 8rnd EUE 207 3.5" 9.3# L-80 8rnd EUE s 206 3.5" 9.3# L-80 8rnd EUE .3# L~80 8rnd EUE ' 204 3.5" 9.3# L-80 8rnd EUE 203 3.5" 9.3#'[-80 '8rnd EUE es 202 3.5" 9.3# L-80 8rnd EUE es 2.875" Cameo DS Nipple es 201 3.5" 9.3# L-80 8rnd EUE 00 3.5" 9.3# L-80 8rnd EUE es 199 3.5" 9.3# L-80 8rnd EUE es 198 3.5" 9.3# L-80 8rnd EUE Yes 197 3.5" 9.3# L-80 8rnd EUE Yes 1963:5"9.3# L~80 8rnd EUE Yes 195 3.5" 9.3# L-80 8rnd EUE 1194 3.5" 9.3# L-80 8rnd EUE 193 3.5" 9.3# L-80 8rnd EUE 192 3.5" 9.3# L-80 8rnd EUE " 191 is" 9.3# L-808md EUE es 190 3.5" 9.3# L-80 8rnd EUE es 189 3.5" 9.3# L-80 8rnd EUE UE Yes 187 3.5" 9.3# L-80 8rnd EUE Yes 186 3.5" 9.3# L.:sO 8rnd EUE Yes 185 3.5" 9.3# L-80 8rnd EUE Yes 184 3.5" 9.3# L-80 8md EUE Yes 183 3.5" 9.3# L-80 8rnd EUE # L-80 8md EUE 9.3# L-80 8rnd EUE # L-80 8rnd EUE 179 3.5" 9.3# L-80 8rnd EUE 178 3.5" 9:3# L-80 8rnd EUE 177 3.5" 9.3# L-80 8rnd EUE 5" 9.3# L-80 8rnd EUE 75 3.5" 9.3# L-80 8rnd EUE # L-80 8rnd EUE 173 3.5" 9.3# L-80 8rnd EUE 2 3.5" 9.3# L-80 8rnd EUE 171 3.5" 9.3# L-80 8rnd EUE 170 3.5" 9.3# L-80 8rnd EUE 169 3.5" 9.3# L-80 8rnd EUE L-80 8rnd EUE s 167 3.5" 9.3# L-80 8rnd EUE 41.2 6,786.... No 61.1 6,766.... No 69.3 6,7 71.4 6,755.... No 102.7 6,7 134.0 6,693.... No 165.4 6,661.... No 196.7 6,630.... No 1,106.3 5,721.... 1,137.7 5,689.... 1,168.0 5,659.... No N No 1\1 3 1/2 9.30 L-80 3 1/2 9.30 L-80 ' 3 1/2 9.30 L-80 3 1/2 9.30 3 1/2 9.30 L-80 3 1/2 9.30 L-8 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/21 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 31/2 9.30 L-80 31/21 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 I 3 1ï2 9.30 L-80 3 1/2 9.30 L.80 3 1/2 9.30 L-80 3 1/2 9.30 L-80 .. 3 1/2 9.30 L-80 3 1/2 9.30 L-80 " 3 1/2 9.30 L-Bo 3 1/2 9.30 L-80 3 1/2 9.30 L-80 31/2 9.30 L-80 31.33 1,230.7 5,596.... No 31/2 9.30 L-80 ,31.36 1,262.1 3 1/2 9.30 L-80 31.35 1,293.4 5,533.... No 3 1/2 9.30 L-80 3 1/2 9.30 L-80 31.34 1,356.1 5,471.... No I 3 1/2 9.30 L-80 31.3 31/2 9.30 L-80 31.36 1,418.8 5,408.... No 31/21 9.30 L-80 31.35 1,450.1 3 1/2 9.30 L-80 31.34 1,481.5 5,345.... No If! 31/21 -3f35t"1,512.8 5,314.... N 31/2 9.30 L-80 ~1,5442 5,283.... No kJ 9.30 L-80 31.36 1,575.5 5,251.... No " n 165 3.5" 9.3# L-80 8rnd EUE 1 31/21 9.30 L-80 30.291 1,606.9 5,220.... No I 31.41 258.4 6,568.... 31.33 289.8 6,537.... 31.36 321.1 6,506.... '31.34 352.5 6,474.... 31.33 383.8 6,443.... No 31.42 44~ No 1.57 477.9 31.34 479.5 6,347.... 31.32 510.8 6,316.... 31.34 542.1 6,285.... 31.29 573.5 6,253.... 31.33 604.8 6,222.... No 1 31.32 636.1 6,191.... No I 31.32 667.4 6,159.... No I 31.38 698.7 6,128.... No 31.35 730.1 6,097.... No 31.34 761.5 6,065.... "No 31.33 792.8 6,034.... No 31.34 824.1 6,003.... No 31.38 855.5 5,971.... No , "~~: 31.34 886.9 5,940.... No 31.42 918.2 5,909.... No 3f30 9 31.33 980.915,846.... 31.32 1,012.215,815.... 31.33 1,043.615,783.... ,3 31.41 30.35 31.36 III II II No No I No 1:1 II f¡j . n r:J I Ii II No No No ===r1 No No No 1.1 II! I [i r:! APIIUWI Surface Legal Location Field Name License No. State/Province Well Configuration Type 5002922870 11N 10E 23 KUPARUK RIVER UNIT Alaska Ground Elevation (It) Original KB Elevation (It) KB-Ground Distance (It) iKB-CaSing Flange Distance (It) [KB-Tubing Hanger Distance (It) 69.39 111.60 42.21 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.37 1,637.2 5,190.... No 162 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-801 31.30 1,699.9 5,127.... No I III! .5'~ 9:3#L~80Bmd E .5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.35 1,762.5 5,064:..·1 No I Ii] 3112' -::9.30 L" s 158 3.5" 9.3# L-BO Brnd EUE 31/2 9.30 L-BO 31.35 1,825.2 5,002.... No I I 3.5" 9.3# L-BO Brnd EUE 31/2 9.30IL-BO 30.65 1,887.914,939....1 No 1 II~ 154 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.32 1,949.91 4,B77....1 No I !I Le80 8rnd EUE ) ii /I' IIIIIii ~'1lZ I/ii/9.3 s 152 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.34 2,012.5[4,B14·..·1 No 1 I es 151 3,5" 9.3# L-~O 8rndEUEii ii'icIIIIi c,= 3112' ~9.3 iCi ii es 150 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.34 2,075.2 4,752....[ No I es 7149 3.5" 9.3# baa 8rnd EUE ICi'i: >i 31/2 i'i 9.3 es 148 3.5" 9.3# L-80 Brnd EUE 31/2 9.30 L-80 31.34 2,137.9 4,689....[ No I .3# L-80 8rnd EUE ii ,.........··C··ii···CCC >i - 0CC3 11%- 9 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 I L-80 I 31.35 2,200.61 4,626....1 No I E"iCC iii "Ii" CiYi/CI iC :51/2 ii 9.3 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.47 2,263.3 4,564.... . No I 3.5" 9.3#L-80 8rnd EUE ii"'i> "CiC' .C C 31/2 9.30 L-80 CCC 31.38 2,294.7 4,532..:.') es 142 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.40 2,326.1 4,501.... No I eg'> 141 3.5"9.3# L"80 8rndEUE ./ ii » 31/2 ~9.3ã L-80 II> 31.43 2,3575 ex' I>CNQ.. '/iC .iiCC<i> 4,469..:. es 140 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 30.67 2,388.9 4,438.... No IIIj eSi ·'/139 3.5" 9.3# L-80 8rnd EUE 'iii i/ iii II i, c) 31/2 9.30 L-BO 31,41 2,41 es 138 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-BO 31.22 2,451.0 4,376.... No ~I 137 3.5" 9.3# L-80 8rnd EUE > CiC cC'S' c-cTà 1/2 ~30 L-80 31.49 2,4B2.2 4,345:.:, No /i Ciii Yes 136 3.5" 9.3# L-80 Brnd EUE 3 1/2 9.30 L-BO 31.40 2,513.7 4,313.... No I ~es= 135 3.5" 9.3# L-808rnd EUE .,/ CC··CIi.>ii. CT 31/2 ~,. L-BO ..= 2,545.1 4,282:':';. IIiiNo ii '.Y> I»' 9.30 Ci 31.41 Yes 134 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-BO 31.40 2,576.5 4,250.... No I si 133 3.5" 9.3# L-80 8rnd EUEIii ii >i C iC c-cT3 1/2' ~e9.3Q L-BO 31.44 2,607.9 4,219..:, No li< es 132 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-BO 31.33 2,639.4 4,187.... No I I131 3.5" 9.3# L-80 8rnd El.JE >iCi>i ..II./ii ii 3 172' 9.30 L-BO 7= . 00= 4,156.;:: «N es i.i <> <i'31.42 2,670} Yes 130 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 2,702.1 4,125.... No I Yes C'S' 3:5'i 9.3#1.':-80 8rnd EUE .. Cc-cT 3 1/2p> 129 «"i< iI <i 9.30 L-80 > 31.37 2,73 Yes 128 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.40 2,764.9 4,062.... No 11 # L-80 8rnd EUE à 1/2 k7 Iil-BO 30.25 ~2,i96?3 bF . NO<ili> I >IIil ,) ,'«. iC i>iiii <ii..ii9.3O 4,031.... es 126 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.40 2,826.5 4,000.... No II~ es <ii125 3.5"9.3# L-8Q8md EUE i < /i i,/"C» 31/2b7 9.30 L-80 iiI» 31,.43 "2Jf57.9 3,969.... >yNo Yes 124 3.5" 9.3# L-BO 8rnd EUE 31/2 9.30 L-80 31.41 2,8B9.4 3,937.... No I Yes 71Q3' 3"~5" 9.3# L-808rnd EUE.i i.>.·'.' -= b731/2 '===-9.30 L-80 Ci 31 ~4Z "2;92013 3,906 iI« <i .iY Yes 122 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.49 2,952.2 3,875.... No I s -121 3.5" 9.3# L-BO 8rnd..EUE ii C<.> , i .C¡= !TšT3 1 12' ,. 9.30 1il-80 31,42 2,9B3,7 3,84 s 120 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-BO 31.49 3,015.1 3,812.... No I IC 9.30 L-80 Ci·.,.31:,42 3,046:6 3,78 # L-80 8rnd EUE I 31/2 9.30 L-80 31.50 3,078.0 3,749.... No [Ii) 116 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.40 3,140.9 3,686.... No I .5"9.3# L-80 iiiC< i,.I iIi I<iii.i.ii "i> .IIi·ii> 3 flzÞ' 9.3"â 1::86 2i ",31:39 3.172:3 3 i> 1 11413.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.38 3,203.7 3,623.... No [I þ\pI·Þi<i<I'I·:Ii//<IiiiIIIiI 1/ 31/2. 9c3{) IÍ~ ÞiCI31A3 3,235.1 3, I 11213.5" 9.3# L-80 Brnd EUE 31/2 9.30 L-BO 31.38 3,266.5 3,560.... No l~ iC <CiiICi<»ICI< ·.'.i 31/2 9.30 L-80 :.1 31:47 3,297·9 3, [ 11013.5" 9.3# L-BO Brnd EUE 31/2 9.30 L-80 31.42 3,329.4 3,497....~ No [III .<Ii<..I:< .<CiiI? '>i'" 113-1/2 be 9.30 L-80 31,39 3,36Q.8 3, i<' Ci es 108 3.5" 9.3# L-BO Brnd EUE 31/2 9.30 L-80 31.41 3,392.2 3,435.... ~I =. 3.5"9.3# L~808rndEUE "'i, 1>,3 1/2'i> 9,.30 1:~BO .~= 1··3,423.6 eSI/ 107 ,i 31.40 3,403..". es 106 3.5" 9.3# L-80 Brnd EUE 31/2 9.30 L-80 31.41 3,455.0 3,372.... No API/UWI Surface Legal Location Field Name License No. StateiProvince Well Configuration Type 5002922870 11N 10E 23 KUPARUK RIVER UNIT Alaska Ground Elevation (It) 'Original KB Elevation (It) KB-Ground Distance (It) i KB-Casing Flange Distance (It) KB-Tubing Hanger Distance (It) 69.39 111.60 42.21 105 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.39 3,486.4 3,340.... No - 103 3.5" 9.3# L-80 8md EUE I 31/2 9.30IL-80 I 31.38 3,549.2 3,278.... No I 101 3.5" 9.3# L-80 8md EUE I 31/2[ 9.30 I L-80 31.47 3,612.0 3,215.... No I 99 3.5" 9.3# L-80 8md EUE I 31/2 9.30 I L-80 31.41 3,674.9 3,152.... No rnl md EUE:CCC,' Yes 97 3.5" 9.3# L-80 8md EUE 31/2 9.30 I L-80 I 31.40 3,737.7 3,089.... No I 'CC 5 3.5" 9.3# L-80 8md EUE 31/2 9.3OIL-80 31.41 3,800.6 3,026.... No I !gr··9. es 93 3.5" 9.3# L-80 8md EUE 31!2 9.3. 31.38 3,863.3 2,963.... No I _%C ~92 1]';9.3# L~BO 8rndE!.JE := 31/2 es .. :,...:':.:. Ci:... es 91 3.5" 9.3# L-BO 8md EUE 31/2 9.30 L-80 31.07 3,926.1 2,901.... No I 8rnd,EUE.: ·cc= 31/2 =, 9.30 Le80 ... 89 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.39 3,988.5 2,838.... No I :: 88 3.5" 9.3# 1..-80 8rnd EUE "i' .: : ': =31/2 ..9.30 t='BO' I'i 31,3814,01 es 87 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.41 4,051.3 2,776.... No II 136 '3.š" 9.3# L-80 8rnd EUE iiC i, - es :i 'f es 85 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.39 4,114.2 2,713.... No I .5" 9.3# L-80 8rnd EUE .... :i .i ,i31/2 ))9.30 L-80 31.41 4,14 Yes 83 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.43 4,177.0 2,650.... No I Yes 82 3.5" 9.3# I..~80 8rnd EUE iC 3 172 ~9.30 ~ 31.38 4,20 Yes 81 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 4,239.8 2,587.... No I Yes 80 3.5" 9.3# L-BO 8mdEUEi: .. 31/2 .i~ L-80~ 3,1.40 4,27 i: i: Yes 79 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.36 4,302.6 2,524.... No i: 78 3.5"9.3# Le80 BmdEUEC'i )9.30 ~ 'c;31.44 4,333.9 2,493..;. 6,~.. J.-s.---;:;~0i "i 3 1/2 No Yes 77 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.37 4,365.4 2,461.... No :7 :,76 ~ 9.3# 1..-80 8rnd EUE i. i "ii .'i' .-,= L-80"" =' 31.44 cr..,. , 2,430.:.. iJ'N Yes .. 31/2 iC 9.30 C. 4,396.7 Yes 75 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 30.40 4,428.2 2,399.... ~~~i~i..;~1 ~ 74 '3:'5" 9.3# L-80 8rnd EUE C..,...i. ..=.~--=.-, =3 172' ~'9.3Ò ìiIao 31.41 4,45B.6 ,,= es 'i ....:..... 2,368.... Yes 73 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.39 4,490.0 2,337.... No II Yes 72 ~:3# L-80 8rôd EUE ii' .. ii 3 112 10; 9.30 ~ i,'·31.43 14,521.4 2,305..;, Yes 71 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-BO 31.42 4,552.8 2,274.... No IJII Yes ,,'70 3.5" 9.3# L-80 8rnd EUE . 7==- 31/2 , 9.30 L-BO ,.. 31 .42 4,5 f: i··,' "C'i Yes 69 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.41 4,615.6 2,211.... No I ~-- .. 68 3.5" 9.3# l.-80 .8md EUE :ii - .= 3'W =: 9'3(f L-80 .. 31.42 4,647.112,1 es - 67 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-BO 31.43 4,678.5 2,148.... No I es es 66 3.5" 9.3# L-80 8rnd EUE :: ,,' 31/2 9.30 L-BÓ" 0ii31..3 es 65 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-BO 31.43 4,741.3 2,086.... No -- :·.64 3.5" 9.3# L-80 8md EmE '" 3112' L-80 :ij 31.48 þ--,~- 2,054:... ..No .,ii··.·,iiii··..·. es : :, 9.30 4,772.7: es 63 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.19 4,804.2 2,023.... No ~ -62 =...~-- .'·"".i -- =-a 1/2 =: 1,9~ ~ es 3.5" 9.3# L-80 8rnd EUE ,.. ,i' .., 9.30 es 61 3.5" 9.3# L-80 8md EUE 31/2 9.30 I L-80 I 31.14 4,866.8 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 I, 31.10 4,929.1 1,898.... No I 7 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.19 4,991.1 1,836.... No I 6 3.5" 9;3# L.-80 8mdEUE . -, ..... .,31/2 ,.,SUO 4-80 '·';JJ'91.2 ," .., Yes 55 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.33 5,053.6 1,773.... No 11 .5" 9.3# Le80 8mdSblg.ii'ii.. ,::":i' :..'::' .. i' 7T77',9]O L-åtYbc 31.4ª ~' J,7 31/2 5,084.9 53 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.36 5,116.4 1,710.... No ~. i 3.5" 9.3# 1..-80 8rnd EUE ¡"..: ,," ::, :. 31/2 " ,9.30 L-80 I":: "8' fÌÈf 5,141':7 ~,67 51 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.43 5,179.1 1,648.... No :: 50 3.5"9.3#L~80 8rôd EUE.. ::: - :. :: es 49 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.41 5,242.0 1,585.... No III .48 3.5·~ 9,3# L-8Q8mdEUE : ":. ':.. := 3 1'72' es :.: . i. .ii es 47 3.5" 9.3# L-80 8md EUE 31/2 9.30 L-80 31.41 5,304.8 1,522.... No Ij~ - -, APliUWI Surface Legal Location Field Name License No. State/Province Well Configuration Type 5002922870 11N 10E 23 KUPARUK RIVER UNIT Alaska Ground Elevation (ft) ¡Original KB Elevation (ft) I KB-Ground Distance (ft) I KB-Casing Flange Distance (ft) KB-Tubing Hanger Distance (ft) 69.39 111.60 42.21 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 5,336.2 1,491.... No 3.5" 9. 4 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 5,399.0 1,428.... No n 42 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 5,461.8 1,365.... No n 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.44 5,524.5 1,302.... No f1 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.43 5,587.3 1,239.... No f~ 36 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.40 5,650.2 1,177.... No ~, E es 34 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.45 5,712.0 1,115.... No ! es 33 3.5" 9.3# L-80 8rnd EU es 32 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 5,774.9 1,052.... No I~ s 31 "3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-8 s 30 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 30.14 5,837.6 989.68 No ~ UE 31/2 9.30 L-80 31.41 5,867.8 959.5 28 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.42 5,899.2 928.13 No I~ 27 3.5" 9:3# L-80 8rnd EUE , -- .~ '31/2 9.30 L-80 31.47 5, 26 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-8-0 31.38 5,962.1 865.24 No 1:4 25 "3.'5" 9.3# L-80 8rnd EUE 31/2 9~30 L-80 31.40 5,9 Yes 24 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.31 6,024.8 802.46 No ¡~ Yes I 23 3.5" 9.3# L-80 8rnd EUE 3'172 -. 9.30 Yes 22 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.40 6,087.6 739.69 No I 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.38 6,119.0 708. 20 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.40 6,150.4 676.91 No [I 19 3.5" 9.3# L-80 8rnd EUE .- f---- 31/2 ~-- 9.30 L-80 31M -6,181.8 645.51 No es 18 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.46 6,213.2 614.10 No I Yes- --17 31/2 ' -- 3.5" 9.3# L-80 8rnd EUE 9.30 L-80 31.44 6,244. Yes 16 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.42 6,276.1 551.20 No r Yes 15 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 6,307.5 519.78 ' No Yes 14 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.50 6,338.9 488.39 No 13 3,5" 9.3# L-80 8rnd EUE 3 1/2 ~ 9.30 L-80 31.40 6,370.4 456.89 No ---~- es es 12 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 6,401.8 425.49 No .5" 9.3# L-80 8rnd EUE .. 31/2 9.30 L-80 31.48 6,433.2 Yes 10 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.17 6,464.7 362.621 No ~ I~ Yes 9 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.41 6,4 Yes 8 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.42 6,527.3 300.04 No ti .- ..~ -- 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.47 6,558.7 268.62 N 6 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.39 6,590.2 237.15 No ~1 - 31/2 1-----9~30 Do 31.42 3.5" 9.3# L-80 8rnd EUE 6,621.5 205.76 4 3.5" 9.3# L-80 8rnd EUE 31/2 9.30 L-80 31.38 6,653.0 174.34 No WI 3.5" 9.3# L-80 8rnd EUE . , 31/2 , 9.30 L-80 31.40 6 5- 3.5" 9.35-# L-80 8rnd EUE (pup joint) 31/2 9.30 L-80 9.60 6,715.7 111.56 No IJ [6- 3.5" 9.3# L-80 8rnd EUE (pup joint) 31/2 9.30 L-80 10.09 6,734.2 93.07 No l [2.813" Camco DS Nipple 31/2 9.30 L-80 0.97 6,775.8 51.53 No [4.5" 1ST X 3.5" 9.3# L-80 8rd EUE crossover 4 1/~~_ L-80 1.42 6,808.2 19.08 No ~ 41/21 ' L-80 I 17.66/ 6,80 . . ConocoPhmips Alaska, Inc. KRU 1 D-1 0 API: 500292287000 Well Type: INJ Angle @ TS: 25 deg @ 7147 TUBING SSSV Type: NIPPLE Orig 4/12/1938 Angle @ TO: 24 deg @ 7340 (450$821, 00:3.500. Completion: 10:2,992) Annular Fluid: Last W/O: 8/15/2007 Rev Reason: WORKOVER SURFACE . Reference Log: Ref Loa Date: Last Update: 8116/2007 (0-4778. Last Tao: 7319' TO: 7340 ftKB 00:9,625. _Date: 1/24/2007 MaxHoleAnole: 29dill2118 wt:40.oo) DescriDtlon Size TOD Bottom TVD WI Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded SURFACE 9.625 0 4778 4352 40.00 L-80 BTC PRODUCTION 7.000 0 7027 6350 26.00 L-80 Mod BTC LINER 4.500 6821 7339 6632 12.60 L-80 NSCT 'ROOUCTION (0-7027, l 00:7000, Size Too Bottom I TVD , WI I Grade I Thread Wt:26.00) 4.500 I 0 1 45 I 45 I 12.60 I L-80 I NSCT 3.500 I . I 6821 I 6167 " 9.30 I L-80 I 8rdEUE I il:"J.'" Interval Zone Status Ft Date rvoe Comment XO 7148-7175 6460 - 6484 C-4 27 6 1/27/2007 RPERF 2-7/8" HSD PJ Omega (68060$807, Guns, 60 deo. phase 00:4.550) 7175-7195 6484 - 6502 C-4,C-3 20 10 1/27/2007 RPERF 2-718" HSD PJ Omega SEAL Guns, 60 deo. phase (68070$815, 7195 - 7214 6502 - 6519 C-3 19 6 1/27/2007 RPERF 2-718" HSD PJ Omega 00:4.750) Guns, 60 dea. phase 7220 - 7228 6525 - 6532 C-3,C-2 8 6 1127/2007 APERF 2-7/8" HSD PJ Omega Guns, 60 deo. phase 111 PBR $I I MD TVD I Man Mfr Man Type I V Mfr I V Type I V 00 I Latch I Port I TRO I Date Run I C~t (6813-6822, 1 1 1 6723 60801 L;ANlL;U I MMG 1 I ill 1.5 I RKP I I 0 18/14/20071 I 00:4.500) DeDth TVD TVDe 10 34 34 HANGER 4.5" NSCT TUBING HANGER 3.883 37 37 XO NSCT 4.5" x 3.5" CROSSOVER 2.992 476 476 NIP 2.875" CAMCO 'OS' NIPPLE 2.875 6773 6124 NIP 2.813" CAMCO 'OS NIPPLE RHC PLUG w/BALL & ROD 2.813 LINER 6806 6154 XO 3.5" x 4.5" CROSSOVER 2.992 (6821-7339. 6807 6154 SEAL BAKER LOCATOR/SEAL ASSEMBY STABBED INTO EXISTING PBR, 2.992 00:4,500, SEALS SPACED OUT 1.4' FROM FULLY ENGAGED 8/14/2007 Wt:12.60) 6813 6160 PBR Baker PBR 8/7/2006 3.813 6836 6180 LINER PKR Baker ZXP LINER TOP PACKER 3.953 6843 6186 LINER Baker HMC 3.938 HANGER 6955 6286 PLUG BAKER IBP (39' OAL x 2.5" max 00) SET 7/5/2007 [MID ELEMENT = 0.000 LINER 1[11 69551, -5' CALCIUM CARBONATE DUMP BAILED ONTO PLUG 7/11/2007 HANGER 7062 6382 NIP CAMCO NO GO NIPPLE 3.750 (6843-6844. 7336 6630 SHOE Baker FLOAT SHOE 3.953 00:5,875) PLUG (69550$968, V 00:4,500) NIP (7062-7063, I I 00:4,500) Perf _"_n_ (7148-7214) __m_" .-.- - c--- Perf = r= (7175-7195) - c--- = r= = 1== = ~ . ~V~VŒ illJ~ ~~~~[K(fÆ . AIfA~1iA OIL Al'WD GAS CONSERVATION COMMISSION I Jill Long Wells Group Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 D-l 0 Sundry Number: 307 -191 $GANNED JUN 1 5 2007 qs~o¥1 \í\ Dear Ms. Long: 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. When providing 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. Sincerely, DATED this /~ay of June, 2007 Encl. 1. Type of Request: Abandon D D D b~~E:~~~ aq¡-Ik-. R~CEIVoEO···.··7D ALASKA OILAND GAS CONSERVATION COMMISSION ...JUN 0 8 Z APPLICATION FOR SUNDRY APPRQta'sRølDil & GåS Cons. Commissîon 20 MC 25.280 Am:hgrage D Time Extension D Re-enter Suspended Well D . Alter casing Repair well Suspend D o o Operational Shutdown Plug Perforations D D D Stimulate Perforate D D Waiver Other D Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Pull Tubing Perforate New Pool 4. Current Well Class: Development D Stratigraphic D Exploratory D Service 0 5. Permit to Drill Number: 198-049 . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22870-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes D No 0 10-10 '" 9. Property De,signation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650, ALK 468 RKB 41', Pad 71' , Kuparuk River Field 1 Kuparuk Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7340' ~ 6633' 7319' 6614' Casing Length Size MD TVD Burst Collapse CONDUCTOR SURFACE PRODUCTION LINER 7" 121' 121' 4778' 4352' 7027' 6350' 7339' 6632' 80' 4737' 6986' 518' 16" 9-5/8" 4-1/2" Perforation Depth MD (ft): 7148'-7214',7220'-7228' Packers and SSSV Type: Baker ZXP liner top packer @ Cameo 4.5" nipple @ 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 15. Estimated Date for Commencing Operations: 17. Verbal Approval: Commission Representative: Perforation Depth TVD (ft): 6460'-6519', 6525'-6532' Tubing Size: 4-1/2" Tubing Grade: L-80 Tubing MD (ft): 6832' July 1, 2007 Date: Packers and SSSV MD (ft) 6836' 512' 14. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: Oil D Gas D WAG D GINJ D Service 0 / Plugged D WINJ 0 / Abandoned D WDSPL D 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact: Jill Long @ 265-1102 Title: Wells Group Engineer Phone 265-6958 Date tJ/klo7 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test !l Mechanical Integrity Test ~ Location Clearance D Other: 7> aoo ~ \ ~a \' ~c:; ~ Subsequent Form Required: 40 Approved by: Form 10-403 Revised 06/2006 ,.. ( ) Submit in Duplicate 6'¡f4;/ /1:> (,.·/~-7 . Conoc;Phillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RêCê/l/êD JUN 0 8 Alaska a"' 200? I &Ga sCans. C . Anchorage DI111l1188io¡ June 7, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 D-1 0 (PTD# 198-049). .- Injecting we1l1D-10 was drilled in April 1998 as a 4.5" single injector. The well failed an MITIA in April 2007 and has since been shut-in. (NOTE: The well passed a Combo MIT on April 28, 2007.) A caliper log indicated multiple joints with greater than 70% wall penetration and so the well was put on the rig workover list for replacement of the 4-1/2" injectiontubing. The purpose of the proposed workover will be to pull all of the existing 4-1/2" tubing string and replace it with a new 3-1/2" tubing string.' Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-1102. Sincerely, /7t: fðr I". ' c....-' , ' t , Jill '. Long Wells Engineer CPAI Drilling and Wells tI>~ · Kuparuk 1D-10 . General Workover Procedure Pre-Riq Work 1. Test packoffs and LDS 2. Drift tubing as far as possible 3. Set IBP in liner below seal assembly at -6,950' 4. Perform positive and negative pressure test on the plug 5. Dump bail 3-5' of calcium carbonate on top of IBP 6. Open the sliding sleeve at 6,768' MD 7. Load the well with 9.6 ppg brine thru the sliding sleeve 8. Freeze protect if necessary 9. Set CIW 4" H BPV 10. Prepare location for arrival of Work over Rig General Workover Procedure 1. Verify Sundry approval acquired 2. MIRU Nabors 3S 3. ND tree. MU blanking plug 4. NU and pressure test BOPE to 250/3,000 psi 5. The last SBHP measurement was 3,412 psi on May 31, 2007, at 7,185' MD (6,492' TVD) which is mid-perf depth. Prior to rig arrival, a plug will be set in the liner below the seal assembly and the well loaded with 9.6 ppg brine. Because of this, kill weight fluid should not be needed; however, in the event that the plug fails, the estimated brine weight needed at mid-perf would be 10.1 ppg. Assuming a 125 psi overbalance, the brine weight would need to be 10.5 ppg. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 2,763 psi.) 6. Pull 4-1/2" tubing and run new 3-1/2" tubing 7. Prior to setting new completion circulate in corrosion inhibited seawater. 8. Set new completion 9. Set BPV and ND BOPE 10. NU tree, pull BPV, set tree test plug, and test tree 11 . Remove tree test pi ug 12. Set BPV and RDMO workover rig Post-Riq Work 1. Pull BPV 2. Open sliding sleeve. 3. Freeze protect diesel down to 2,500' TVD. 4. Close sliding sleeve. Bail calcium carbonate and pulllBP 5. Return to injection , . . . .. _...~ .---- . Conoc~illips Well: 1D-10 Field: Kuparuk . API: 50-029-22870-00 PTD: 198-049 2007 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 4%" NSCT BPV: 4" CIW H BPV Model: FMC Gen V Slimhole CONDUCTOR 16",62.58 ppf, H-40, welded SURFACE CASING 9%", 40 ppf, L-80, BTC PRODUCTION CASING 7", 26 ppf, L-80, BTC-MOD TUBING Current Situation: 0'- 4,670' MD: 4~", 12.6 ppf, L-80, NSTC 4,670'-6,800' MD: 4%", 12.6 ppf, L-80, IBT Proposed: 3%", 12.6 ppf, L-80, NSTC LINER 4-%", 12.6 ppf, L-80, NSCT PERFS C-4: 7,148'-7,175' C-4, C-3: 7,175'-7,195' C-3: 7,195'-7,214' C-3, C-2: 7,220'-7,228' A B NEW COMPLETION A: Nipple: 3%" with 2.813" X profile 500' TVD= 500' MD B: Sliding Sleeve: 3%" CMU with 2.813" DS profile Place 1 full joint above seals C: Seal Assembly @ 6,813' MD Last Updated: 7 -Jun-07 Updated by: JWL . . WELL LOG TRANSMIITAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1 Report / EDE 1) 2) 3) 4) 5) 6) 7) 10 - 10 Caliper Report 27-Apr-07 S~MÄ{ 0'7 2007 U:'c.- lCì'Ý-~ ;rJ. 7 5()7) {j RECEIVED Print Name: II r I /'\ I. t. l '. l' N"'---· - 0)1 rfB~ ('f £? {1~,ô¡f[1 Iii [teL--- Date : 1'\Iaska Oil & Gas Cons. CommIssion Anchorage MAY 0 3 Z007 Signed: PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.C:OM WEBSITE : WWW.MEMORYLOG.COM D:lMaster _cOPY- 00 ]DSANC-2OxxIZ _ Wonl\Distribution\TmnsmìttaC Sheets\Transmit _ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No,: Pipe1 Desc,: Pipe1 Use: ConocoPhillips Alaska, Inc. April 27, 2007 8589 1 4,5" 12.6 lb. L-80 Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log Intvl1,: 1D-10 Kuparuk Alaska 50-029-22870-00 Suñace 5,980 Ft. (MD) Inspection Type: COMMENTS: Co"osive & Mechanical Damage Inspection This caliper data is tied into the "DB" Nipple @ 504' (Driller's Depth). This log was run to assess the condition of the 4.5" tubing with respect to internal corrosive and mechanical damages, The recordings indicate the 4.5" tubing is in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 82% in joint 150 at 4,575', Penetrations ranging 20% to 82% are recorded in 38 of the 199 joints logged. The damage appears in the forms of isolated pitting, lines of corrosion, and general corrosion. As illustrated in the Body Corrosion Profile the deeper penetrations are recorded in the interval between 3,940' and 4,612', The recordings indicate a cross over to a buttress type connection below pup joint 151.1 at -4,612'. No significant areas of cross-sectional wall loss or 10 restrictions are recorded, Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report, The caliper ñngers temporarily closed at 5,182' and 5,070: resulting in a partial coverage for joints 165 and 168, MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Corrosion Isolated Pitting Line Pitting Corrosion ( 8?>ÆJ) ( 81%) ( 73%) ( 71%) ( 59%) Jt. Jt. Jt. Jt. Jt. 150 @ 149 @ 130 @ 140 @ 151 @ 4,575 Ft. (MD) 4,521 Ft. (MD) 3,949 Ft. (MD) 4,262 Ft. (MD) 4,579 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 7%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant LD. restrictions are recorded, I Field Engineer: K. Miller Analyst: M. Tahtouh Witness: C, Fitzpatrick I Inc, I P,O. Box 1369, Stafford,TX 7ì497 DECEIVED Fax (281) 565-1369 E-mail: PDSC!j:¡memorylog,C.Q Phon::: (907) 659-2307 Fax: (907) 659-2314 ProActive Diagnostic Phone: (281) or (888) 565-9085 Prudhoe Bay Field Office MAY 0 3 Z007 U'~ c. 10, ~- G'Lfì1 * ISõ5'{) ~0i1& Gas Cons. CommiSSion Anchorage I I I Well: Field: Company: 10-10 Kuparuk ConocoPhillips Alaska, Ine. USA I Grade & Thread L-80 Nom.OD 4.5 ins Weight 12.6 f I I Penetration and Metal loss (% penetration body melalloss body 200 I 150 I o o to 1% 1 to 10% 10 to 20 10 40 10 over 20% 40% 85% 85% I o o I I Damage ( body ) 60 I 40 I 20 o I isolated pitting genera! line rìng hole poss corrosion corrosion corrosïon ¡hie I o I I Repo Region ew alysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: April 27, 2007 MFC 40 No. 30807 2.75 40 M. Tahtouh Nom.ID 3.958 ins Nom. Upset 4.5 ins Upper len. 6.0 ins Lower len, 6.0 ins Damage Profile (0/0 wall) penetration body o o metal loss body 50 100 147 47 97 Bottom of Survey 194.1 Analysis Overview page 2 I I I Correlation of Damage Borehole Profile I Pipe 1 4.5 in (21.6' - 5981.2') Well: Field: Company: Country: Survey Date: 1O-JO Kuparuk ConocoPhillips Alaska, Ine. USA April 27, 2007 I I I Approx, Tool Deviation Approx. Borehole Profile I 25 24 I 777 I 50 1524 I 75 2280 I Q¡ JOO 3062 ..D ...; E u... :¡ £ Z .~ 125 3796 ..2, 150 4548 I 175 5368 I I I 194.1 o 50 5981 100 I Damage Profile (% / Tool Deviation I I Bottom of Survey = 194.1 I I I PDS JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4,5 in 12,6 ppf L-80 0.2 71 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: 10-10 Kuparuk ConocoPhìllips Alaska, Inc. USA April 27, 2007 I I Joint Jt Depth Pc: Pen. Per I,Vlela( Min. Damag e Profile No. Body !.D. Comments wall) (I (Ins.) (Ins,) ° 50 100 .1 22 r 0.01 4 ¡ 3,92 PUP 1 24 r 0.00 ¡ 2 3.93 1.1 55 r 0.ü1 ( 3,91 PUP 2 65 r 0.01 2 3.92 3 95 () 0.ü1 ) 3.94 4 125 () 0,01 J 3,94 5 155 i1 0.00 ~¡ 3.94 6 186 () 0.01 ) 3.91 7 217 () 0.ü1 I 2 3.92 8 252 () 0,00 ( 3,89 9 291 () 0.01 ¡ 3.93 10 321 () 0.ü1 ( 3.90 11 349 () 0.04 II 3.88 Shallow nittioo. Lt Denosits, 12 380 () 0.01 3.92 13 410 Iì 0.00 3.93 14 439 Iì 0,01 3.92 15 468 () 0,03 J1 3.90 15.1 498 0 0.ü1 ) 3.89 PUP 15.2 504 (! 0 Iì 3.81 DB-6 NIPPLE 15.3 506 () 0.ü1 ) 3.90 PUP 16 511 0 0.02 ¡ 3.88 17 542 0 0.03 11' 1 3.90 Shallow niWoo. 18 570 0.01 2 3.93 19 600 0.03 2 3.93 20 630 0.01 7 3.92 21 659 0.01 1 3.94 22 688 0.02 ( ) 3.92 23 718 0 0.01 ) 3,93 24 747 () 0.ü1 1 3.93 25 777 () 0.01 ) 3.94 26 807 0 0.ü1 1 3.94 27 836 0 0.03 f¡ ( 3.94 28 865 Iì o ()1 I 2 3.93 29 895 () 0.ü1 4 3.92 30 924 () 0.00 I 3.93 31 954 C! 0.01 I 3.88 32 982 () 0.01 'I 3.91 33 1012 0 (¡f)) P 3,88 34 1043 0.01 3.93 35 1072 O,04e 4 3.92 Shallow oitô¡w. \ì 36 1103 0,0';1 I 3.94 Shallow niWno, 37 1133 0.011 3 3.93 38 1162 ¡ 0.ü1 4 ) 3,93 39 1192 0 0.03 !I ) 3.93 40 1223 0 0.01 4 I 3,92 41 1252 () 0.ü1 2 3,93 42 1283 () 0,01 I 3.93 43 1313 () 0.03 1 2 3.94 Shallow níttino. 44 1343 () 0,03 1 ) 3,93 45 1373 () 0.03 2 3.94 I I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I I REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0,271 in 3.958 in Well: Field: Company: Country: Survey Date: 10-10 Kuparuk ConocoPhillips Alaska, Inc. USA April 27, 2007 I Joint Jt. Depth Pe Pen. Pel . tvleial Min. Damage Profile No. (Ft.) Body I.D. Comments (%wa II) ( (Ins,) (Ins.) 0 50 100 46 1403 ') 0,01 i 3.91 47 1434 0 0.01 3,94 48 1464 U 0.02 ( 3.93 49 1494 0 0.03 ¡ 3.94 50 1524 0 0.01 3.91 51 1555 0 0.01 I 3,88 52 1585 OiJS ~4 1 m Shallow nittilW in unset. 53 1616 0 , 54 1647 0 ) 55 1677 0 giti ' I 3.89 56 1706 !I !IS ) 3.93 Shallow nittino. 57 1736 0 0,0 ) 3,92 58 1766 U 0.09 1 3.85 Isolated niUino. 59 1796 ( 0.06 " ) 3.90 Isolated niuino. 60 1824 i 0.02 ) 3.93 61 =1854 i 0.01 ; ±±~~ 62 1884 0.ü1 63 1914 n 0.02 I 3.89 64 1945 0 0.ü1 1 3,93 ~ 65 1975 0 0.ü1 ) 3.94 66 2005 0 0.06 I)) ) 3.93 Isolated niUinp". 67 2035 o )(, 0.ü1 4 ) 3.95 Pitting in un<:et. 68 2065 i 0,01 1 I 3.93 69 2094 I 0.02 () ) 3.93 70 2124 i 0.01 ) 3.93 71 2154 0 0.ü2 3.94 72 2185 0 0.02 3.94 73 2217 0 0.02 3.93 74 2249 0 0.01 3.93 75 2280 0 0.01 " 'i 3.92 76 2312 0 0.02 ) 3.94 77 2344 I 0.01 3 3.93 78 2376 i 0.01 3.90 ¡ 79 2408 ( 0.04 1 3.88 Shallow níttino. 80 2441 ( 0.04 1 1 3.93 Shallow nittino. 81 2473 ( 0.03 11 3.94 Shallow nittir1º, 82 2504 ( 0.00 3.93 83 2535 í 0.ü1 '\ 3.92 84 2566 ( 0.02 ) 3.93 85 2597 ( 0.01 \ 3.93 ~ 86 2629 ( 0,03 H I 3,89 Shallow niUinp". 87 2658 0.06 ) ) 3,91 Isolated nittirw, 88 2689 0.02 ( ) 3.92 89 2721 0.03 10 ! 3.94 90 2752 0.03 1 ) 3,93 Shallow nittina. 91 2782 I) \7 0.03 It 3.93 Pitting' in unset. 92 2813 ( 0.05 ¡ 3.91 Line shallow corrosion. [II 93 2844 ( 0,01 3.83 U. Denosits 1M 94 2876 0 0.Q3 1 3.88 Shallow nittìnp", 95 2908 OW, 0.09 1) 3.90 Isolated nittinQ. I I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I I PDS REPORT NT TABU ONSH I Pipe: Body Wall: Upset Wall: NominaIID.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: field: 10-10 ConocoPhillips Alaska, Ine. USA April 27, 2007 Country: Survey Date: I Joint Jt Depth Pell. Pen. Pen. ,\/Iplal Min. Damage P rofile No. (~;::(;\ Body ID. Comments (%wall) (Ins.) (Ins.) ° 50 100 96 2939 0 0.07 2 6 3.91 Isolated DittimL 97 2970 0 0.05 2 3.93 Line shallow corrosion, 98 3001 0 0.08 1 3.93 Isolated oittim~, 99 3031 0 I 0,08 3,85 Isolated oittim~, Lt Denosits. 100 3062 0 0.06 3,91 Isolated pitting. 101 3092 0 0.01 3,88 ~3124 \ 0.02 9 3.93 103 3155 . 0.02 ¡.j 3.93 104 3185 n I') . 0.03 'I, ') 3.87 Shallow oitting: in uoset. I 105 3216 0.05 ¡ 2 3.90 Shallow oittinR 106 3245 \ 0.05 1 2 ±f87 Shallow Dittim~:. 107 3274 \ 0,05 :p: 1 93 Shallow oittim~. 108 3300 no" 0.02 2 3.93 Shallow pitting in unset. I 109 3328 n 0.01 4 2 3.94 I 110 3356 ( 0.02 ;7 I 3.89 I 111 3385 ( 0.01 3.92 112 3413 ( 0.10 ') 3.90 I pitting:. 113 3442 0.05 If! 3,93 Line shallow corrosion. 114 3472 0 0,01 3.93 115 3502 0 0.ü2 ;7 3.87 Lt. Deposits. 116 3532 n 0,06 20 3,93 Isolated pittim'1.. 117 3561 0,10 36 I 3, Isolated pittim~. 118 3591 0.06 22 2 3. Isolated oitting. 119 3621 0,03 2 3.88 Shallow pitting. 120 3649 0.06 2 3.91 Isolated pittinll. 121 3678 0.09 3 3.92 Isolated oittim~. 122 3707 ( 0.03 I 3.93 123 3736 0 0.04 ¡ 3.93 Shallow pitting. 124 3766 I 0.01 I 3.92 125 3796 ( 0.ü3 1 4 3.90 126 3827 ( 0.07 2 2 3.92 Isolated oitting:. 127 3857 0.01 2 3.93 128 3887 0.05 1 / 3.90 Line shallow corrosion. 129 3917 \) 0.02 3.91 130 3947 0 0.20 3 3.92 Isolated pitting. 131 3977 0 0,14 .)\ 3.89 Isolated pitting. 132 4008 C 0.10 36 3.91 Isolated oitting, 133 4038 O. \6 0.04 2 3.90 Shallow pitting. 134 4068 0.09 3.89 Isolated oittim!. 135 4097 0,07 3.94 Line of oits. 136 4128 ( 0.05 3.94 line of shallow nits. 137 4157 0 0.05 3,88 Line of shallow nits, Lt. DeoosÎts. 138 4188 0 0.04 3.92 line of shallow nits. 139 4217 0 0.09 33 3.91 Isolated pitting. Lt. Deoosits. 140 4248 o J'i 0.19 3,94 Line of nits. 141 4279 ( 0.07 3,93 line of nits. 142 4309 ) 0.06 3.92 Line of oits. 143 4339 ) 0.07 3.92 Isolated pitting. 144 4370 0 0.06 3.97 line of oits, 145 4401 0 0.08 3.89 Line of pits. I I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I REPORT INTTABU ONS I Pipe: Body Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: 10-10 Kuparuk ConocoPhillips Alaska, Inc. USA April 27, 2007 I I I Joint Jt. Depth Pell Pen. Pen. !'/le!al Min. Damag e Profile No. (Ft.) Body 1.0. Comments (% wall) (Ins (Ins.) (Ins.) 0 50 100 146 4431 0.06 ) J 3.93 Isolated nittina, 147 4461 0.15 c) I /\ 3.92 Isolated nittino. 148 n Ih (j Od 3.92 Line of shallow nits. 149 4519 ( 0.22 3.91 Corrosion. 150 4548 ~ 3.86 Isolated nittino, 151 4578 3.91 Corrosion. 151.1 4607 3.88 PUP CROSS OVER TO BUTTRESS C 152 4612 n 0,05 I ) 3.91 Line shallow corrosion. 153 4643 II 0.Q3 1 /\ 3.90 Line shallow corrosion. 154 4673 II 0.04 1 3.87 Line shallow corrosion. Lt. Denosits, 155 4703 (I 0.04 I 3.91 Line shallow corrosion. 156 4734 (I 0,05 i1 3.88 Line cDrrosion, 157 4764 ( 0.03 ·1 3.87 Line shallow corrosion. 158 4795 0 0,05 :> 3.91 Line shallow corrosion. 159 4827 II 0,06 it ,88 Line corrosion. Lt. Denosits. 160 4860 II 0.04 :> 3.91 Line shallow corrosion, 161 4894 II 0,05 /\ ') corrosion. Lt. Denosi ts. 162 4928 0 0.03 3.87 Line shallow corrosion. 163 4962 0 0.04 3.86 Line shallow corrosion. U. Denosits. 164 4996 0 0.04 3.91 Line shallow corrosion, 165 5030 0 0,03 3.91 Line shallow corrosion. Denosits, 166 5079 0 0.03 ¡') :> 3,86 Line shallow corrosion. 167 5114 0 0.03 "Ie:¡ :> 3.90 Line shallow corrosion. 168 5148 0,03 (, 3,90 Line shallow corrosion. Denosits. 169 5186 0.05 3.87 Line shallow corrosion. 170 5216 ( 0.04 3.92 Line shallow corrosion. 171 5246 ( 0,06 3.86 Line corrosion. U, Denosits. 172 5277 0 0,03 3.87 Line shallow corrosion. Lt. Denosits, 173 5307 0 0,05 3,89 Line corrosion. 174 5337 0 0,03 1'1 3,89 Lt. Denosits. 175 5368 II 0.05 j 3.90 Line shallow corrosion. 176 5398 0 0.05 1 2 3.87 Line of shallow ois. Lt. Denosits. 177 5429 0 0.04 1 ) 3.86 Line of shallow ois. It. Denosits. 178 5459 0 0.Q3 1 2 3.90 Lt. Denosits. 179 5490 0 0.04 I " 3.89 Line shallow corrosion, 180 5521 0 0.04 f I 3.87 Line shallow corrosion, U. Denosits. 181 5550 ì 0,04 11 4 3,87 Line shallow corrosion. Lt. Denosits. 182 5582 ( 0.ü1 it ;; 3.89 Lt. Denosits, 183 5612 ( 0.03 1J 2 3.88 Line shallow corrosion. U. Denosi ts. 184 5642 ì 0.05 ~ I 3,88 Line shallow corrosion. 185 5674 0 0,04 I 3.93 Line shallow corrosion, 186 5705 0 0.04 2 3.89 ! Line shallow corrosion, 187 5736 0 0,06 1 3.92 Line corrosion, 188 5766 0 0.06 '1 3.86 Line corrosion. 189 5797 0 ~ I 3.86 Line corrosion, 190 5828 :> 3.87 line cDrrosion. 191 5859 0.06 ) 3,90 Line corrosion. 192 5891 I 0,06 ¡ 3.92 line corrosion. 193 5921 I 0.02 1 3.90 194 5952 0 0.04 4 J 3.90 line shallow corrosion. Denosi ts, I I I I I I I I I I I I Body Metal Loss Body Page 4 I I I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I Joint Jt. Depth No. (Ft) 194.1 5981 I I I I I I I I I I I I I I I REPORT JOINT TABULATION SH 4.5in 12.6ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: END OF LOG Page 5 10-10 Kuparuk ConocoPhillips Alaska, Inc. USA 27, 2007 Comments Damage Profile o 50 100 Body Metal Loss Body .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. .. s s 10-10 Kuparuk ConocoPhillips Alaska, Inc USA 4.5 ins 12.6 f L-80 April 27, 2007 MFC 40 No. 30807 ;U5 40 M. Tahtouh Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Cross Section ft Tool 69 Nominal ID 0= 3.958 Nominal OD 4.500 Remaining wall area 96 % Tool deviation 0= 29 0 Finger 6 Penetration 0= 0.222 ins Isolated Pitting 0,22 ins 82% Wall Penetration HIGH SIDE 0= UP Cross Sections page 1 .. ns .. .. .. .. - .. .. .. Well: Field: Company: Country: Tubin : Tool speed = 68 Nominal 10 = 3.958 Nominal 00 = 4.500 Remaining wall area = 94 % Tool deviation = 24 0 .. .. .. .. .. .. .. .. .. .. S rt ss Sections 10-10 Kuparuk ConocoPhillips Alaska, Inc USA 4.5 ins 12.6 f L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: April 27, 2007 MFC 40 No. 30807 :U5 40 M. Tahtouh Joint 149 13 ft Finger 17 Penetration = 0.22 ins Corrosion 0.22 ins 81% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .. .. .. .. I I I NIPO (504-005, OD:4.500) TUBING (0-6821, OD:4.500, ID:3.953) I I PBR (6821-6822, ODA.500) I LINER PKR (6835-6837, 00:6.168) LINER (6821-7339, OD:4.500, Wt:12.60) I I LINER HANGER (6843-6844, OD:5.875) 'RODUCTION (0-7027, 00:7.000. Wt:26.00) I I I Perl (7175-7195) I I I I I SHOE (7335-7339, ODA.500) I I I KRU 1D-10 Rev Reason: Set PLUG Last U date: Sm2oo5 6843 6186 1062 6382 7062 6382 1336 6630 ID 3.813 3.813 3.813 3.953 3.938 3.150 0,000 3.953 SHOE NO GO NIPPLE DB? PLUG w/2S'14" PLUG BODY, P-PRONG 42.75" w/1 3/8" set 8/612005 Baker FLOAT SHOE I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. April 27, 2007 8589 1 4.5" 12.6 lb. L-80 Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log IntvI1.: 1D-10 Kuparuk Alaska 50-029-22870-00 Suñace 5,980 Ft. (MD) Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This caliper data is tied into "DB" Nipple @ 504' (Driller's Depth). This log was run to assess the condition of the 4.5" tubing with respect to internal corrosive and mechanical damages. The recordings indicate the 4.5" tubing is in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 82% in joint 150 at 4,575'. Penetrations ranging 20% to 82% are recorded in 38 of the 199 joints logged. The damage appears in the forms of isolated pitting, lines of corrosion, and general corrosion. As illustrated in the Body Corrosion Profile the deeper penetrations are recorded in the interval between 3,940' and 4,612'. The recordings indicate a cross over to a buttress type connection below pup joint 151.1 at -4,612'. No significant areas of cross-sectional wall loss or ID restrictions are recorded. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. Intermittent tool malfunctions caused the caliper to open later than programmed and to temporarily close at 5,182' and 5,070', resulting in a loss of coverage from 7,064' to 5,980' and partial coverage forjoints 165 and 168. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Corrosion Isolated Pitting Line Pitting Corrosion ( 82%) ( 81%) ( 73%) ( 71%) ( 59%) Jt. Jt. Jt. Jt. Jt. 150 @ 149 @ 130 @ 140 @ 151 @ 4,575 Ft. (MD) 4,521 Ft. (MD) 3,949 Ft. (MD) 4,262 Ft. (MD) 4,579 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 7%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: sCANNED JUL 2 0 2007 No significant J.D. restrictions are recorded. I Field Engineer: K. Miller Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 U:ï:C---ICJf" -Dt.¡~ :tt; I~QirÒ I I I Well: Field: 10-10 Kuparuk ConocoPhiUíps Alaska, Ine. USA I Country: Tubing: Nom.OD 4.5 ins Weight 12.6 f Grade & Thread l-80 I I Penetr¡¡tioo and Metal loss (0/0 wali) penetration body metal loss body I 200 150 100 50 0 o to 1% 10 to 20 to 40 to over 20% 40% 85'''10 85"1" 1 to 10% I o o pene. loss ( body ) 60 40 I 20 I o isolated general line ring hole I poss pitting corrosion corrosion corrosion ¡ble hole I o I I PDS Report Overview Body Region Analysis Survey Date: Too! Type: Tool Size: No. of Fingers: Anal st: Nom.ID 3.958 ins April 27, 2007 MFC 40 No. 30807 2.75 40 M. T ahtouh Nom. Upset 4.5 ins Upper len. 6.0 ins lower len. 6.0 ins Damage Profile (% wall) penetration metal loss body 50 100 147 Bottom of Survey = 194.1 Analysis Overview page 2 I I I Correlation of to Borehole Profile I Pipe 1 4.5 in (21.6' - 5981.2') Well; Field: Company: Country; Date: 10-10 Kuparuk ConocoPhillips Alaska, ¡ne. USA April 27, 2007 I I I Tool Deviation Approx. Borehole Profile I 25 24 I 777 I 50 1524 I 75 2280 I ..... 100 3062 ()) ...a ...:; E u.. :;:¡ .!S z .... 3796 c: 125 :5 150 I 175 5368 I I 194.1 o 50 5981 100 I Damage Profile ('Yo wall) I Too! Deviation (degrees) I I Bottom of Survey = 194.1 I I I I I JOINT TABULATION Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf 1.·80 0.271 in 0.271 in 3.958 in Well: Field: 10-10 Kuparuk ConocoPhimps Alaska, Ine. USA April 27, 2007 Survey I I I I I I joint Jt. Depth PerL Pen. Pen. !yiela! Min. -çr Profile No. (Ft.) \:;::¡~I LD. Comments wall) (ins.) (Ins.) 0 50 100 .1 27 -ft II 3.92 PUP I 1 74 0.00 3.93 1.1 55 () 1 I 3.91 PUP 2 65 1 i ~~ 3 q<; i 125 3.94 tF: 3.94 ~ 0.01 .91 7 0.D1 .92 8 252 fWD 9 91 0.01 ! 10 1 0.01 11 j () 0.04 n ShallowoiUint!. ! t Dpl1OSÎts. 12 .. 13 L 3.93 14 439 I 3.92 15 468 I 0.03 11 15 î 498 I 0.01 PUP 15.2 504 0 o I 3.81 DR.6 NIP?! F 153 SOh 0 0.01 3.90 PUP 16 511 0.02 tl 3.88 17 542 0.03 I 3.90 Shallow nittinQ. 18 570 11 111 11 2 3.93 19 600 It 9t+ 3.93 20 h<!) 392 21 659 I. 3.94 22 688 ( 3.92 23 718 t 3.93 24 747 0.01 1.<)1 25 777 0.01 ~ 3.94 26 807 0.01 3.94 27 836 0.03 3.94 28 865 0.111 3.93 29 895 ) =! .'5 3.92 30 924 I. 3.93 31 954 t 3.88 32 982 ( it 3.91 33 1012 ¡ ¡ 3.88 34 1043 1.93 35 1072 0.04 13 3.92 ittir12. 36 1103 005 Hi 3.94 ç¡.."l!ow DittinQ. 37 1133 0.01 3.93 38 11h2 0.01 ! <.<13 39 1192 0.03 '0 I 3.93 40 1223 I 0.01 3.92 41 1252 0.01 3.93 42 1283 =1 ~.o~ 3.93 43 1313 nl 3.94 Shallow "¡tûng, 44 1343 101 3.9'1 45 1373 ¡ 0.03 9 I 3.94 I I Page 1 Pipe: Body Wan: Upset Wall: NominaII.D.: I Joint Jt. Depth No. (Ft.) I 1403 1434 L 1 1 51 15 52 1585 53 1616 54 1647 5" 1677 =E56 1706 57 1 716 1766 59 1796 60 1824 61 1 854 62 1 RR.1 63 191.1 64 1945 65 1975 66 2005 67 2035 68 2065 69 2094 70 2124 71 2154 72 2185 73 2217 74 2249 75 2280 76 2312 77 2344 78 2376 79 2408 80 2441 81 2473 82 2504 83 2535 84 2566 85 2597 862629 87 88 2689 89 2721 90 2752 91 2782 ~~ -+-m~ 94 +1ff6 95 I 2908 46 47 48 49 ""ro I I I Pen p~n ¡ "e<, r'f'" Mjn Ijpsel Body 1.0. (Ins.) (Ins.) o 3.91 D 0.01 3 3.94 1 : 1 3: I 11 3 o )'i 0,021 3.94 ShaHow nittinQ in unseL n ,,~; dª Sh.,~w nitti- ¡ ~:) 3.92 0.091 ~ '. ¡ 0.06 1 2 ~ed nittin"'-. I 0.02 :¡ 3.93 ill . .~. ~:~~ 1:93 3.94 0.06 3.93 Isolated nittiOQ. O)() 0.01 3.95 Pittinlr in unseL ..ML.!--. 3.93 ~ 3.93 0.01 3.93 0.02l 3.94 0.02 ? 3.94 0.02 I:) 3.93 =t!= 3.93 3.92 3.94 ¡ Q01 3Æ I 0.Q1 I 3.90 1 3.88 3.93 3.94 ~93 ~92 3.Q'1 3.en 3.RQ Shallow nittio<>. 3.91 Isolated nittin"'-. 3.92 3.94 3.93 Shallnw nittinQ. 3.93 PittinlZ in uoset. 3.91 3.83 3.88 3.90 JOINT TABU 4.5 in 12.6 ppf 1.-80 0.271 in 0.271 in 3.958 in Well: field: Company: Country: Survey Date: II o II o II o ) Shallow nittino-. Shallow nittín<>. Shallow niUin\!. 13 0.17 0.02 0.01 O'031,~ 0.05 1 [1 0.01 ¡ 0.03 1 0.091 ¡ t denn"it, S ittínp". ittinQ. o )S Page 2 ONSH 10-·10 Kuparuk ConocoPhimps Alaska, Inc. USA April 27, 2007 Comments nome ("/" wa!!) o 50 100 W I I pi iIiIIII i I JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal ID.: 4.5 in 12.6 ppf L-BO 0.271 in 0.271 in 3.958 in Well: field: Cornpany: Country: Survey Date: 10-10 Kuparuk ConocoPhillips Alaska, ¡fie. USA April 27, 2007 I Joint Jt Depth Pen, Pen. PerL i lnletal Min. i. Profile No. (Ft.) Body 1.0. Comments (OJ,, wall) (Ins) (Ins.) (Ins.) o 50 100 96 2939 ) 0.07 )¿! 6 3.91 Isolated nittinQ. 97 2970 ì 0.05 111 2 3.93 line shallow corrosion. 98 \ ~ '1.93 !solater! nittil1<T. 99 3031 3.85 Isolated nittil1<T. Lt. Denosits. 100 3062 3.91 Isolated nittina. 101 3092 3.88 102 3174 0.02 I '.93 ~'1r:;5 3185 n_ . ¡nu~t 105 3216 3.90 Shallow ninina. 106 3245 3.87 Shallo\A! nittin<T. 107 3274 3.93 Shallow nittil1º. 108 3300 (¡ or:; O.tV i.93 Shallow."ii,ti'lo in u""et. 109 3328 0.01 3.94 110 0.02 3.89 111 3385 0.D1 3.92 112 3411 0.10 3.90 Isolated nittino-. 113 3442 0.05 1 3.93 Line shallow corro'-'ion. 114 3472 0.01 3.93 115 3502 0 m~ 3.87 Lt. Denosits. 116 3532 0 3.93 knbtÞc! ninin¡:r. 117 3561 0 3.94 knlatÞrl niU:ìn¡:r. 118 3591 \ 3.93 isolated "iuina. 119 3621 0.03 2 2 3.88 Shallow "iWnO'. 120 '1649 0.06 3.91 Isolaterl ninino. 121 3678 0.09 3.92 Isolated ninirn.>. 122 3707 m 3.93 123 3736 \ 3.93 Shallow nittin¡:r. 124 3766 \ 0.D1 3.92 125 3796 i 0.03 ¡ '" 3.90 126 3827 i 0.07 :)i)T~?- 3.92 Isolated "ittino. 127 3857 \ 0.D1 3.93 128 38f!711i fI fI'> iqfl 129 3917 0:02 3.91 130 3947 0.20 3.92 Isolated niWne. 131 3977 0 0.14 3.89 Isolated nittinq. 132 4008 ) 0.10 1.91 !solated njtlin"'. 133 4038 () 06 0.04 1, 3.90 Shallow "itlino. 134 4068 ~~ 1.89 Isolated "iWno. 135 4097 3.94 Line of nits. 136 4128 0.05 3.94 Line of shallow nits. 137 4157 n 0.05 3.88 line of its. Lt. Denosits. 138 41RR Ii 0.04 3.92 Line of shallow nits. 139 4217 0 0.09 3.91 Isolated nitlinº. U. Deoosits. 140 42411 nO') 0.19 , 3.94 line of "its. 141 4279 0 0.07 3.93 line of nits. 142 4309 ( ~ 3.92 line of nits. 143 4339 ( 3.92 Isolated nittinO". 144 4370 I 0.06 3.92 line of nits. 145 4401 I 0.08 3.89 line of nits. I I I Body Loss Body Page 3 I I Pipe: Body Wall: Upset Wail: Nominal I.D.: I I Joint Jt. Depth No. (Ft) I I I I I I 5079 5114 5148 5186 5216 5246 5277 5'07 5337 5368 5398 <;4JQ 5459 5490 5521 5550 5582 5612 5642 5674 5705 5736 5766 5797 5828 5859 5921 5952 4,5 in 12.6 ppf 1.-80 0271 in 0.271 in 3.958 in JOINT TABULATION SH Well: Field: Company: Country: Survey Date: 10-10 Kuparuk ConocoPhillips Alaska, Inc. USA April 27, 2007 Pen. Pen. F'en. I !\v~eíal Body ::":,~I ~: ~ loJ,} ) 0.03 I ¡i 0.04 I 1d 1 Min. LO. Ons.) 3 3.93 Isolated nittir\<'. 3.92 isolated nittino. 3.92 Une of shallow nits. 3.91 Corro,,¡nn 3.86 iso!ato..i"'iWno. 3.91 Corrosion. 3.88 PUP CROSS OVER TO BUTIRESS CO 3.91± cnrrosiùn. 3.90 Une slv,lIow mrrosion. 3.fJ7 Line shallow corrosion. I.t. Denosits. 3.91 Line shallow corrosion. 3.88 Une oorro"ion. 3.87 Line I ii:i. I line ,""'ow 'O<l';on~" 3.91 3.82 shallow oorrosion. Lt. DPI'>osits. 3.87 Line shallow corrosion. 3.86 ,,= ""liow oono.on. I... [)P~.~. 3.91 i Line shallow corrosion. c¡ 3.91 Line shallow corr"'si...n. Denosits. 2 3.86 Line shallow corrosion. :? 3.90 Line shallow mrrosion. 6 3.90 Line shallow oorrosion. Dennsits. 3.87 I ine shallow corrosion. ii. Line shallow Line Lt. n",nosits. Line shallow corrosion. Lt. DPnosits. 3.89 Line oorrosion. 1.89 Lt. Denosits. 3.90 Line shallow 3.87 Line of shallow nis. Lt. Deno<;it<: 3.86 Line of shalir-.w "is it. D"''''''''¡tc 0.031 n 3.90 Lt Denosits. 0.04 ~ c¡ .: 3.89 Line shallow corrosion. 0.041 SEt! Line shallow corrosion. Lt. Deoosits. o 04 1 7 oorrosinn. Lt. f)pnosits. 0.01 Lt Denosits. 0.03 3.88 Line shallow corrosion. Lt. Denosits. 0.05 3.88 Une shallow corrosion. 0.04 II 3.93 !. ne shallow corrosion. 0.04 3.89 L ne shallow corrosion. 0.06 3.92 I np corrosion. 0.06 =;=. I np oorrosÎon. 0.05 : Line oorrosion o '- ---' . . line corrosion. o '-~ 3.90 Line o '- 3.92 Line oorrosion. o '- I 3.90 0.04 14i I 3.90 Line shallow corrosion. Denosits. ¡ ¡ ¡ I ¡ () o ( o. O. 0.04 0.03 0.03 i 0.06 0.03 o o 146 4431 147 4461 148 4489 149 4519 150 4548 =t$:~b~ 4612 1 4643 1 ')4 4671 155 4703 156 4734 1 "'7 4764 158 4795 159 4827 160 4860 161 4894 162 4928 163 4962 1 64 4996 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 191 192 193 194 o 0.05 ( I I o o Comments 1 1 17 ¡H Page 4 Damage Profil.e (%,wal!) o 100 JOI Pipe: Body Wall: UpsetWal!: Nominal I.D.: 4.5 in 12.6 ppf L-80 0271 in 0271 in 3.958 in Weil: Field: Company: Country: Survey Date: Joint Jt. Depth No. (Ft) 194.1 5981 END OF LOG I I I I I I I I I I I PageS I I LATION SH 10-10 Kuparuk ConocoPhi!lips Alaska, Ine. USA April 27, 2007 Comments PDS Repo ro Sections Well: 1 D--10 Field: Kuparuk Company: Alaska, Inc. Country: USA Tubin: 4.51n5 12.6 f L-80 Survey Date: Too! Type: Tool Size: No. of Fingers: Anal sf: April 27, 2007 MFC 40 No. 3000 7 2.75 40 M. Tahtouh ft Tool '" 69 Nominal 10 '" 3.958 Nominal 00 =' 4.500 Remaining wall area'" 96 % Tool ~ation 29" 6 PenetratÎún '" 0.222 ins Isolated Pitting 0.22 ins 82"1" Waf! Penetration HIGH SIDE"" UP Cross Sections page 1 - - Well: Field: Company: Country: Tubin : 10-10 Kuparuk ConocoPhilIips Alaska, Inc. USA 4.5 ins 12.6 f L-80 for Joint 149 at depth Tool '" 68 Nominal 10 '" 3.958 Nomina! OD '" 4.500 Remaining wall area'" 94 % Tool deviation'" 24 0 - - - - - - - PDS Report Cross S ons Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: April 27, 2007 MFC 40 No. 30807 2.75 40 M. Tahtouh 0.813 ft Finger 17 Penetration'" 0.22 ins Corrosion 0.22 ins'" 81% Wall Penetration HIGH SIDE'" UP Cross Sections page 2 I I I I I I I I KRU 1 D-10 NIPO (504-505, OD:4.500) TUBING (0-6821, OD:4.500. ID:3.953) PBR (6821-6822, 00:4.500) LINER PKR (6836-6837, 00:6.156) LINER (6821-7:339. 00:4.500. Wt:12.60) UNER HANGER (6843-6844, 00:5.875) 'RODUCTlON (0.-7027, OD:7.000, Wt:26.00) Perf (7176-7195) SHOE (7336-7339. 00:4.5(0) lD-1O PTD # 198-049 . . Jim, 10-10, PTO # 198-049, produced water injector, failed a MITIA today. Initial notice of suspect communication was 4/2/07. T/I/O is 2000/1920/720 psi. Pack off testing performed today indicates that the leak is down hole. / Immediate action will be to set a TIP to identify the leak source, tubing or packer, run an E-line leak detect log, and caliper the tubing to investigate patch options. The well has been added to the Monthly Failed MIT report. Would you like a copy of the MITIA results in state format? ./' ~Ut5iW 41,i\ŒI Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com SCAj~ APR 1 7 2007 «1 0-1 O.pdt» Content-Description: ID-lO.pdf ID-l O.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 4/10/2007 1:13 PM lD-lO PTD # 198-049 T X IA communicatio. Jim, 10-10 PTO # 198-049, produced water injector, begin showing signs of T X IA communication early this morning. ,// T/I/O = pre bleed was 1994/2132/650. The IA was bled to 991 psi but recharged rapidly to 2120 psi. I've enclosed two pressure plots. The event is hard to see in our typical 90 day plot. The one day plot is a Better visual representation of the pressure event. This well was worked over in August 2006, to replace corroded tubing, and had a witnessed passing / MITIA 8/22/06. Immediate action will be to troubleshoot the source of the pressure communication with OHO and slick line. Let me know if you have any questions. Sincerely, 6t7A~ APR 05 2007 Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244. Pager (907) 659-7000 x909 n1617@conocophillips.com «10-10 1 day pressure plot.gif» «10-10 90 day TIO.gif» «10-1 O.pdf» ID-IO 1 day pressure Content-Description: ID-IO 1 day pressure plot.gif Content-Type: image/ gif Content-Encoding: base64 ./ ID-IO 90 day TIO.gif Content-Description: ID-IO 90 day TIO.gif ./ Iof2 4/2/2007 II :56 AM ID-IO PTD # 198-049 T X IA communicatio. Content-Type: Content-Encoding: . image/ gif base64 Content-Description: ID-IO.pdf ID-IO.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 /' 4/2/2007 II :56 AM D-lO pressure 1 267x78 1 I of I 4/2/2007 AM 10-10 90 AM . . KRU 1 D-1 0 API: 500292287000 Well Type: INJ Angle @ TS: 25 dea (Q) 7147 TUBING SSSV Type: NIPPLE Orig 4/12/1998 Angle @ TD: 24 deg @ 7340 (0-4672, 00:4.500, Completion: 10:3.953) Annular Fluid: Last W/O: 8/7/2006 Rev Reason: TAG FILL, PERF Reference Loa: Ref Log Date: Last Update: 1/29/2007 SURFACE Last Taa: 7319' TD: 7340 ftKB (0-4778, Last Taa Date: 1/24/2007 Max Hole Angle: 29 deg @ 2118 00:9.625, Wt:40.00) Descriotion Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded SURFACE 9.625 0 4778 4352 40.00 L-80 BTC TUBING PRODUCTION 7.000 0 7027 6350 26.00 L-80 Mod BTC (4672-6832, LINER 4.500 6821 7339 6632 12.60 L-80 NSCT 00:4.500, 103.953) Size TOD I Bottom I TVD I Wt I Grade I Thread 4.500 I 0 I 4672 I 4258 I 12.60 I L-80 I NSCT I "ROOUCTION 4.500 I 4672 I 6832 I 6177 I 12.60 I L-80 I IBT-MOD I (0-7027, 00:7.000, Wt:26.OO) Interval TVD Zone Status Ft SPF Date Type Comment SLEEVE-C 7148- 7175 6460 - 6484 C-4 27 6 1/27/2007 RPERF 2-7/8" HSD PJ Omega (6768-6769, Guns, 60 dee:¡. phase 00:5.490) 7175- 7195 6484 - 6502 C-4,C-3 20 10 1/27/2007 RPERF 2-7/8" HSD PJ Omega SEAL Guns, 60 dee:¡. phase (6813-6831, 00:4.870) 7195 - 7214 6502 - 6519 C-3 19 6 1/27/2007 RPERF 2-7/8" HSD PJ Omega Guns, 60 dea. phase 7220 - 7228 6525 - 6532 C-3,C-2 8 6 1/27/2007 APERF 2-7/8" HSD PJ Omega PBR Guns . ohase (6821-6822, 00:4.500) DeDth TVD Tvpe Description ID LINER 36 36 HANGER FMC GEN 5 TUBING HANGER 8/7/2006 4.500 (6821-7339, 512 512 NIP CAMCO 4.5" DB-6 Nipple 81712006 3.875 00:4.500, Wt:12.60) 6768 6120 SLEEVE-C Baker CMU SlidinQ Sleeve w/3.813" RUN IN CLOSED 8/7/2006 3.813 6813 6160 SEAL BAKER LOCATORISEAL ASSEMBY STABBED INTO EXISTING PBR, 3.890 SEALS SPACED OUT 1.4' FROM FULLY ENGAGED 8/7/2006 6821 6167 PBR Baker PBR 3.813 6836 6180 LINER PKR Baker ZXP LINER TOP PACKER 3.953 6843 6186 LINER Baker HMC 3.938 LINER PKR HANGER (6836-6837, 00:6.156) 7062 6382 NIP CAMCO NO GO NIPPLE 3.750 7336 6630 SHOE Baker FLOAT SHOE 3.953 LINER Pro~~ - L Jf:J::> I z,<o il \ ~p-=' 7 ZAop';;.! HANGER (6843-6844, I 00:5.875) CÐ(¡ l.t p'X ~ 54(Of""l "5cP .:. 'bt 3 Z fS'ì -) Zq, ~ ~ M3A-tP .. NIP (7062-7063, 00:4.500) Perf ----- --- (7148-7214) - - ~---- ------ m.. mmm Perf ..... == (7175-7195) -- --~ ~ = = ----~- --- = = . . RECEIVED STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION 0 2 2007 REPORT OF SUNDRY WELL OPERA 1iðN91 & Gas Cons,' 1. Operations Performed: Abandon 0 RepairWell 0 Plug Perforations 0 Stimulate 0 Grage 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 198-0491 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22870-00 - 7. KB Elevation (ft): 9. Well Name and Number: ( RKB 41', Pad 71' 10-10 8. Property Designatipn: ADL 25650, ALK 468 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool - Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 7340' feet true vertical 6633' feet measured 7319' feet true vertical 6614' feet Length Size MD 80' 16" 121' 4737' 9-5/8" 4778' 6986' 7" 7027' 518' 4-1/2" 7339' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4352' 6350' 6632' Measured depth: 7148'-7214',7220'-7228' true vertical depth: 6460'-6519',6525'-6532' SCANNED FEB () 7 2007 Tubing (size, grade, and measured depth) 4-112" , L-80, 6832' MD. Packers & SSSV (type & measured depth) Baker ZXP liner top packer @ 6836' Cameo 4.5" nipple @ 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure na na SI na na 2332 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ 0 WDSPLO Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Printed Name Signature Title Phone Wells Group Engineer Date ~,...{ -0 -7- Pre ared b Sharon AIIsu -Drake 263-4612 1r?{ ç- ~ '¡. ~.Ð7 ~NP~nIY .~ . 1D-10 Well Events Summary . DATE Summaryops 1/24/07 TAG 3.75" D NIPPLE @ 7062' RKB.TAGGED @ 7319' RKB WITH 2.5" DUMMY GUNS,3.25" CENT AND SAMPLE BAILER (OAL=24') EST 124' RATHOLE.NO PROBLEMS DRIFTING 1/27/07 PERFORATED 7148'-7214' & 7220'-7228' 6 SPF USING 2 7/8" HSD POWERJET v OMEGA GUNS TAGGED BOTTOM AT 7236' Well stayed on injection during program. 350 BPD. . Handed over to production to bring back up post perf. . . ConocoPhillips Alaska, Inc. KRU 10-10 ~ API: 500292287000 Well Tvoe: INJ Anale @ TS: 25 dea @ 7147 TUBING SSSV Type: NIPPLE Orig 4/12/1993 Angle @ TD: 24 deg @ 7340 (0-4672, OD:4.5oo, Comoletion: ID:3.953) Annular Fluid: Last W/O: 81712000 Rev Reason: TAG FILL, PERF Reference Loa: Ref Loa Date: Last Uodate: 1/29/20CJl SURFACE Last Taa: 7319' TD: 7340 ftKB (0-4778, LastTaa Date: 1/24/20CJl Max Hole Anale: 29dea@2118 00:9.625, Wt:40.00) Descriotion Size Too Bottom TVD WI Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded SURFACE 9.625 0 4778 4352 40,00 L-80 BTC TUBING PRODUCTION 7.000 0 7027 6350 26.00 L-80 Mod BTC (4672-6832, LINER 4,500 6821 7339 6632 12.60 L-80 NSCT 00:4.500, 10:3.953) I Size I Top I Bottom I TVO I WI I Grade Thread I 4.500 I 0 I 4672 I 4258 I 12.60 I L-80 I NSCT I 'ROOUCTION I 4.500 I 4672 I 6832 I 6177 [ 12.60 [ L-80 I IBT-MOD I (0-7027, 00:7.000, Wt:26.00) Interval TVD Zone Status Ft 'SPF Date Type Comment SLEEVE-C 7148-7175 6460 - 6484 C-4 / 27 6 1/27/20CJl RPERF 2-7/8" HSD PJ Omega (6768-6769, Guns, 60 dea. chase 00:5.490) 7175-7195 6484 - 6502 C-4,C-3 20 10 1/27/20CJl RPERF 2-7/8" HSD PJ Omega SEAL Guns, 60 dea. chase (6813-6831. 00:4.870) 7195-7214 6502- 6519 C-3 19 6 1/27/20CJl RPERF 2-7/8" HSD PJ Omega Guns, 60 dea. ohase 7220 - 7228 6525 - 6532 C-3,C-2 I 8 6 1/27/20CJl APERF 2-7/8" HSD PJ Omega PBR Gun . ohase (6821-6822, 00:4.500) Deoth TVO Tvoe Oescriotion ID LINER 36 36 HANGER FMC GEN 5 TUBING HANGER 8/7/2006 4.500 (6821-7339, 512 512 NIP CAMCO 4,5" DB-6 Nioole 8/7/2006 3.875 00:4.500, Wt:12.60) 6768 6120 SLEEVE-C BakerCMU Slidina Sleevew/3.813" RUN IN CLOSED 8m2006 3.813 6813 6160 SEAL BAKER LOCATOR/SEAL ASSEMBY STABBED INTO EXISTING PBR, 3.890 SEALS SPACED OUT 1,4' FROM FULLY ENGAGED 8/7/2006 6821 6167 PBR Baker PBR 3.813 6836 6180 LINER PKR Baker ZXP LINER TOP PACKER 3.953 6843 6186 LINER Baker HMC 3.938 LINER PKR HANGER (6836-6837, 7062 6382 NIP CAMCO NO GO NIPPLE 3.750 00:6.156) 7336 6630 SHOE Baker FLOAT SHOE 3.953 LINER HANGER (6843-6844, 00:5.875) NIP (7062-7063, 00:4.500) Perf - f-- (7146-7214) - f--- - f-- - f--- Perf =- ~ (7175-7195) = F= = F= - ~ = r= . . RECEIVED A .L 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other CJ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 198-049 "I 305-193 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22870-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' 10-10 ' 8. Property Designation: 10. Field/Pool(s): ADL 25650:ALK 468 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7340' feet true vertical 6633' . feet Plugs (measured) Effective Depth measured 7176' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 4737' 9-5/8" 4778' 4352' PRODUCTION 6986' 7" 7027' 6350' LINER 518' 4-1/2" 7339' 6632' Perforation depth: Measured depth: 7175'-7195' o ZN\r. . ~NEn ~EP 0 Q \Jut) true vertical depth: 6484'-6502' ~ r.) '" . Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6832' MD. Packers & SSSV (type & measured depth) Baker ZXP liner pkr @ 6836' Cameo nipple @ 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft SfP 0 6 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation na na SI Subsequent to operation na na 2440 . 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0. Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ0 . WDSPL 0 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: . Contact Howard Gober @ 263-4220 Printed Name -Æard Gober Title Wells Group Engineer ß!~l/o~ Signature ~- Phone Date ___ -v PreDared bv Sharon AlIsuD-Drake 263-4612 , SEP Os 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska 0., & G REPORT OF SUNDRY WELL OPERATIONS' as Cons. Commission STATE OF ALASKA Form 10-404 Revised 04/2004 OR\G\NAL ktl-? ",4b 9· S'.~ S~~p: . 10-10 Well Events Summary . 8/3/2006 Activi lowered derrick, preped rig for move. I Disconnect and move pipe shed and pit module away from carrier. RU trucks to 'Camp, Shop and generator and moved to new location 1D pad. Moved carrier off of well. Cleaned up herculite, berming material and remainder of pad. Moved derrick, pipe shed and pit module from 3Q pad to 1D pad. ,=·_,____,_"'~~.....'~'__WNN=~_'__'''=_=__''''''~-_'''''m'' "-NN=_=·___·",,,"V.'.WN._ 8/4/2006 Move rig from 3Q pad to 1D. Spot rig over well. Raise derrick. Connect pipe shed and pit module. SU containment under rig. Accepted 'W"'W'W<'~^'^ ",,,~~.--v= W~,=",NN_'''-''' ig up head pin and reverse circulated dies ut ta flow back tanks. Switched back to pi " Qd".c.lrcul.at:ed.uotJL.b.aJªJ1ced."~......"..."...,,~w.~ nland tubing hanger. Pulled Baker Seal i ssy. loose @ 180K. Pulled hanger to rig I LD"In...P.iQe..s.b..ed..ÍOcred.r.ess.."m.... ....J OH standing back goad 4 1/2" NSCT I I;¡jOQ..Qut:sIde.º[t!.tbinQ.JO..Q.Ks...LiKe.ÐeY'l~.-I OH standing back 76 stands NSCT. Then ¡ y down 2000' bad pipe (NSCT) to be ~~~~¿~gð~·~rh 4:~éomPletion."1 13:00 14:00 I ¡ ¡ 1 TPRODi1RPcÓM.. I P i í I "'«'''' <~"""w____.o»».=w__' 1. 5 PROD 11 RPCOM i PU lD , P' I unction test BOPE. Pressure test ra nnular ta 250/3000 psi. Test witnes UCk.Scb.e.v.e."LAQGCC1"....... ..~......,.. RD test equipment. MU TIW valve in landing "to Pull test plug. Pull BPV. MU landing jt in hanger. BOLDS. Pull tubing up to lOOk and '.'''=N.- w,,~~,___~=W"_'__'?=W' 8/5/2006 J ,,_,_·WWMVN._ W~=·_______,,+"·,"k____~W,'" -, i RPCOM I PUlD I P ........j~.........,~w~.'"'. PROD1iRPCOMi PUlD I P 8/5/2006 14: 8/6/2006 ,,=ww'___"'m·,','.w"~,.m"h "'_m';=wv___,_^~, I 8/6/2006 I 3:0 r' 87672ÓÓ6w~r.i4:·ÔO I "".W..._...N..'N"'W.__._L, 17:00 í 3 J IPROD1 i I ULD I CSTT" RPCOM í Hosot P I P locate PBR. Rig up pump, establish circulation. lower seal assy down until pressure increase to prove we are inside PBR with seals. Shut down pump. Space out l' off bottom. NU tubing hanger, land tubing hanger with 1 full jt below hanger and space _L!,t.......o_'__,ta~"_,hQ!Q.\"'_I__,,,t'"(::'..t,_,Jt.w 'W^ wwww '___"m=w_____~ RIlDS. RU chart recorder to tubing & IA. With the annulus open, PT tubing to 2500 psi for 15 min. Bleed off tubing pressure to 500 psi. Halding the tubing pressure at 500 psi PT IA to 2500 psi for 30 min. Bleed tubing and IA pressures to zero. Install 2-way check BOP stack. NU tree. r' 8/6/2006 I 17:00 P 8/6/2006 r~-'" 8/7/2006 tree. Test pack-offs and tree to 5000 p ean wellhead and cellar. Release rig @ ..rs.81712SJQ6.................~.... e rig at 0500 hrs on 08/07/06 8/7/20 . ConocoPhillips Alaska, Inc. 1)-10 TUBING (0-4672, 00:4.500, 10:3.953) SURFACE (0-4778, 00:9.625, Wt:40.00) . KRU API: 500292287000 SSSV Type: NIPPLE Rev Reason: TAG FILL Last U ate: 8/18/2006 TUBING (4672-6832, 00:4.500, 10:3.953) 'ROOUCTION (0-7027, 00:7.000, Interval Wt:26.00) SLEEVE-C 7175 - 7195 (6768-6769, 00:5:490) De th TVD SEAL 36 36 (6813-6831, 512 512 00:4.870) 6768 6120 6813 6160 PBR 6821 6167 (6821-6822, 00:4.500) 6836 6180 LINER 6843 6186 (6821-7339, 00:4.500, 7062 6382 Wt:12.60) 7336 6630 LINER PKR (6836-6837, 00:6.156) LINER HANGER (6843-6844, 00:5.875) NIP (7062-7063, 00:4.500) Perf (7175-7195) TVD 6484 - 6502 T e Descri tion ID HANGER FMC GEN 5 TUBING HANGER 8/7/2006 4.500 NIP CAMCO 4.5" DB-6 Ni Ie 8/7/2006 3.875 SLEEVE-C Baker CMU Slidin Sleeve w/3.813" RUN IN CLOSED 8/7/2006 3.813 SEAL BAKER LOCATOR/SEAL ASSEMBY STABBED NTO EXISTING PBR. 3.890 SEALS SPACED OUT 1.4' FROM FULLY ENGAGED 8/7/2006 PBR Baker PBR 3.813 LINER PKR Baker ZXP LINER TOP PACKER 3.953 LINER Baker HMC 3.938 HANGER NIP CAMCO NO GO NIPPLE 3.750 SHOE Baker FLOAT SHOE 3.953 MEMORANDUM . State of Alaska .. Alaska Oil and Gas Conservation CommissP TO: Jim ReggK&i.!Cf 'B(3ù(Oç., P.I. Supervisor I DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC !D-1O KUPARUK RIV UNIT !D-1O ~ ~",Q f\ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 10-10 API Well Number 50-029-22870-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060824143501 Permit Number: 198-049-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-1O Type Inj. w TVD 6180 IA 915 2720 2650 2630 P.T. 1980490 TypeTest SPT Test psi 1545 OA 700 850 850 800 Interval WRKOVR P/F P Tubing 1900 1900 1900 1900 Notes Post rig W/O; tubing replaced. 1 well house inspected; no exceptions noted. / SCANNED SEP 0 8200B Wednesday, August 30, 2006 Page I of I Re: Sundry 305-193 for lD-10 Still Open? Not a problem Gary. Just needed to ask the questions. Good luck. Nice to see repairs being done. Tom Eller, J Gary wrote, On 5/2/2006 3:46 PM: Tom -I gave you some bad info on the static BHP on 10-10 (I was looking at the wrong well folder). In fact, we have not measured static BHP at 10-10 since the sundry application was submitted in 2005. Regardless, my statement that "Well conditions are still within the scope of the original sundry approval" remains accurate. As indicated on the proposed procedure, the well has been secured with a slickline plug which will remain in place for the duration of the workover. I apologize for the confusion. Gary Eller CPAI Wells Engineer -----Original Message----- From: Eller, J Gary Sent: Tuesday, May 02,20063:33 PM To: 'Thomas Maunder' Subject: RE: Sundry 305-193 for 10-10 Still Open? j'- t¿!~h\~i~·Y;' ~~íT~1:~w'-..... ...,....,- ,.i;... ....'" Tom - Well conditions are still within the scope of the original sundry approval. Static BHP was measured in February 2006 in 10-10 and found to be about 150 psi lower than it was when the sundry was submitted in 2005. The proposed well configuration has only nominally changed from what was presented in the 2005 sundry application. We are planning to perform the workover using Nabors 3S. Thanks for the quick response. Gary Eller CPAI Wells Engineer -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, May 02,20063:19 PM To: Eller, J Gary Subject: Re: Sundry 305-193 for 10-10 Still Open? Hi Gary, The sundry is still valid. Are the conditions described in the sundry application still valid? If the well conditions have changed, you can send the changed information via email. Call or message with any questions. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 5/2/2006 2:49 PM: 10f2 Tom - Sundry approval #305-193 was issued on 7/18/05 for pulling tubing and repairing of injection well 1 0-1 O. We anticipate performing this work in June 2006. Is that sundry , approval still valid? ~ ~<Ç.. '\ V~~ò «-cÞ~ 6/12/2006 12:02 PM ~ lC"':1J I , ~ I~' ~,~~ -~11~, /8" \, I ¡ ¡ i ' !! ¡, \ I I I I )~ Iii \ I [ I . II ~ . I It' QV U¡i \ W l-=n I,l-n»" [' r,=.:J,' ,I "'6 I I 'I I !,'!I,I!J:,:' Iii ¡ i \0:!.) ¡ I ) ß/ '~' il¡ ,1~,... ,r::;') in'~:'l.'i\\\\ " ì. ~ I! . ;1, p...J, I )") ; '1' ;' ¡\ 1, ! il Ii 1\ \\ \>,"" : ; /.\ i /\\ \, 1-.:1\""1 '","""1~'\:"U'~'(¡Ü\ 'j'-'! \\ I I 1 ,¡-~" f\''"]J' ! 'i' '" 1M.!1 i" U L..:::DU \\', ~ \'1,,/ ;; ',~U 'Ù ) ALASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Group Engineer Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 L f{~.-Dl{tf Re: Kuparuk 1 D-l 0 Sundry Number: 305-193 SC¡~NNED JUL 2 0 2005 Dear Mr. Peirce: 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 0 holiday or weekend. A person may not appeal a Commission decision to Super" r J unless rehearing has been requested. DATED this/8 day of July, 2005 Enc!. ) ConocJP'hillips Alaska ') P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED JUL I 5 2005 Alaska Oil & Gas Cons. Commission Anchorage ........ July 14, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 0-1 O. The purpose of the proposed 10-10 workover will be to replace leaking 4.5" tubing. 10-10 has two confirmed tubing leaks, and a third leak is suspected. Attached is a proposed general workover procedure. If you have any questions or require any further information, please contact me at 265-6471. Sincerely, t~~~' ,... ( '1f ,- John Peirce Wells Engineering Tech CPAI Drilling and Wells 41' i: l~¡Î\jAL .. '''u''- ~ i ) ) "RECEIVED /L ALASKA OIL AND ~~;~g~S~~;':;;ON ~J,is~;~ ~ JUL 1 5 2005 '\( r 5 APPLICATION FOR SUNDRY APPROIfa\llaOil & Gas Cons. Commission 20 MC 25.280 Anchorage Operation Shutdown D Perforate 0 Waiver 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Perforate New Pool D 1. Type of Request: Abandon 0 o o Suspend 0 o o Alter casing Repair well Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41', Pad 71' Other 0 Re-enter Suspended Well o ---- 5. Permit to Dri~ber: 198-049 6. API Number: V 50-029-22870-00 9. Well Name and Number: 1 D-1 0 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 8. Property Designation: ADL 25650, ALK 468 11. Total depth MD (ft): 7340' 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6633' 7188' Length Size Casing CONDUCTOR SU RF ACE PRODUCTION LINER 16" 121' 4666' 6915' 518' 9-518" 7" 4-1/2" Perforation Depth TVD (ft): 6484'-6502' Perforation Depth MD (ft): 7175'-7195' Packers and SSSV Type: Baker ZXP pkr @ no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for August 15,2005 Date: MD TVD Burst Collapse 121' 121' 4778' 4352' 7027' 6350' 7339' 6632' Tubing Size: 4-1/2" Packers and SSSV MD (ft) 6836' no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ D Contact: Title: Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name John Peirce Signaturet~, t/í~~- ~~ Ij~ Plug Integrity 0 BOP Test ~ Tubing Grade: L-80 Tubing MD (ft): 6821' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 John Peirce @ 265-6471 Wells Group Eng. Tech. Date 7-/4-D~ Sundry Number: ~5:-1C¡3 Mechanical Integrity Test ~ Location Clearance 0 \ ~",~..)\0 \:oil" <:'0 ~~~ 0-<:' "'- \\c..S.\'<:~ <0 ') Other: \t,~ \ ~~~~~~ RBDMS BFL .JUl 1 9 2005 COMMISSIONER APPROVED BY THE COMMISSION ORIGINAL Date: 11&5 Submit in Duplicate ') Kuparuk 1D-10 General Workover Procedure RECEIVED JUL 16 2005 Alaska Oil & Ga. Cons. Commission Anchorage Pre-Rig Work 1.) Set a plug in the No-Go Nipple at 7062' RKB. PT plug to 2500 psi. 2.) Set D&D Hole Finder at 4790' RKB and PT tubing to check for any additional tubing leaks that may exist above 4790' RKB. 3.) Circulate the well to 9.6 ppg Brine through confirmed tubing leaks at 4811' and 5905' RKB. 4.) Bleed tubing down to zero psi and check for flow. 5.) Prep location for Workover Rig. 6.) Set BPV within 24 hours of rig arrival on location. General Workover Procedure 1.) 2.) 3.) MIRU Workover Rig. Verify that the well is dead. ND tree. NU 11" 5M BOPE. Pull BPV. Test BOPE to 250/3000 psi (MASP = 2740 psi). Unland tubing hanger. Cut the tubing in the middle of first full joint above the PBR if tubing does not pull free from PBR. POOH with 4.5" tubing. Run new 4.5" completion and stab into PBR, else overshot the tubing stub and set a stacker packer if a tubing cut was required. Space out and la'Rhanger. , Pressure test tubing and inner annulus. "\('C~~ \Þ\ ~~,>~\Q'"~~ - ~() ~\'" ) Install2-way check valve, ND BOPS, NU tree, test tree & packoff. ~Tr1 RDMO workover rig. ">/ ,- ,~ 4.) 5.) 6.) 7.) 8.) Post-Rig Work 1.) Pull2-way check valve. 2.) RU Slickline. Shift Sliding Sleeve open. 3.) Circulate out 9.6 ppg ~ Brine through Sliding Sleeve w/corrosion inhibited Brine and FP well w/Diesel. 4.) RU Slickline. Shift Sliding Sleeve closed. 5.) Retrieve ball and rod and RHC plug, if needed, following stacker packer set. 6.) Retrieve plug from No-Go Nipple at 7062' RKB. 7.) Reset the well house and return well to injection. Schlumberger NO. 3313 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Company: Field: Well Job # Log Description Date BL 190" /b 7 1 A-25 10942816 PRODUCTION PROFILE/DEFT 12/25/04 1 1'W..~D-10 10942818 LDL & MUL TIFINGER CALIPER 12/27/04 1 :20 fo#~f( 1 E-112 10715441 MPSP PRODUCTION PROFILE 11/12/04 1 jOI.../?/1C-119 10942819 INJECTION PROFILE 12/28/04 1 ~ 4....1.'2. .., 1 E-1 04 10942821 PERF RECORD W/SBHP 12/30104 1 ~- /2." 2T -12A 10922519 PRODUCTION PROFILE/DEFT 01/03/05 1 104"Z2..1.1E-104 10942821 SCMT 12/29/04 2-() '/-2.' ( 1 E-1 02 10942815 USIT 12/24/04 SIGNED: 7, f. .. ~ _..'" ~on¡; . {¡)aMM.~ SCANNEu l.\pR 1 ö L 'YU DATE: Please sign and return one copy of this 'transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1/19/05 lq~c. Ó'rr Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk ~ Color CD 1 1 ~ 1-(9- 05 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRU /1 D 12/14/04 Vance Yoakum Waived Packer Depth We1l1D-10 Type Inj. N TVD 6,180' Tubing P.T.D. 1980490 Type test P Test psi 1545 Casing Notes: diagnostic Combo MIT T-IA completed with TTP Pretest Initial 15 Min. 30 Min. 900 2,500 2,495 2,495 Interval 850 2,275 2,275 2,275 P/F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test SCANNED DEC 2 12004 2004-1214_CMIT _KRU_1 D-1 O.xls ,(t>~ \~ 0 P INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) Re: ID-I0 (PTD 1980490) Sustained IA Pres: ) ) Subject: Re: 1D-10 (PTD 1980490) Sustained IA Pressure From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Mon, 01 Nov 200409:30:12 -0900 To: NSK Problem Well Supv <n1617@conocophillips.com> CC: jim _regg@admin.state.ak.us MJ, It is appropriate to keep the well in service while you are conducting your diagnostic tests. keep us informed of the determination. Tom Maunder, PE AOGCC Please NSK Problem Well Supv wrote: Tom, We completed a pre witnessed MITIA today on 10-10 with the purpose of ensuring it was ready to go when John Crisp witnessed the scheduled MIT Monday morning. That Pre MIT failed. Since he is coming over to witness another injector MITIA in the morning anyhow! I notify him of the failure today, and if he chooses, we can re MIT 10-10 so he can witness the failed test. I'll send the MIT form to you tomorrow with either our failed MIT test or one witnessed by John Crisp, whichever is appropriate. In the mean time, ConocoPhillips requests approval to leave the well online until a Combo MIT (and subsequent leak detection log and patching plan) can be arranged. The TTP plug should be set in the next few days to a week. Please let me know íf leaving the well online is acceptable. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Saturday, October 30, 2004 10:47 AM To: NSK Problem Well Supv Cc: Jim Regg; AOGCC North Slope Office Subject: Re: 1D-10 (PTD 1980490) Sustained IA Pressure MJ, Thanks for the report. Please remember that injection wells must be treated differently than production wells. The sustained casing pressure rules are for production wells. In the case of an injection well, this appears to be an integrity loss. Your trouble shooting plan is appropriate. Please make contact an inspector for the option to witness the MITIA. Tom Maunder, PE AOGCC SCANNED NOV 0 3 2004 1 of ') 11/1/20049:31 AM Re: ID-I0 (PTD 1980490) Sustained IA Pres ) ) NSK Problem Well Supv wrote: Tom Injection well 1 D-10 (PTO 1980490) was reported this morning as having IA pressure while on PWI above 2000 psi. When operations bleeds it off, it tracks back again with in a few hours. Our diagnostic plans are to: Pressure test the Tubing Packoffs Tighten the LDS MITIA Repair plans will depend on the results of the diagnostics. Please let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 ? of? 11/1/2004 9:31 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor(~'~ DATE: July 11, 2002 Chair ,~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips Alaska Lv---/ 1 D Pad P.I. Supervisor 1D-10,1D-119,1D-120,1D-130 FROM: John Crisp Kuparuk River Field Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. we,,J 10-10 J Type,nj.I S I T.V.~. I~0 I Tu~,,~I~0 11864 1186~ I 1.~I lntervall 4 P.T.D.J 1980490 ITypetestJ P JTestpsiI 1545 J CasingJ 0 I 1822 1,1789 J 1783 J P/F I __P Notes: Rosemount Digital Gauge:observed for test. 1 1/2 bbls. Pumped for test pressure. We,,I ~D-~ ITy,e,~j.J S I T.V.D. I~ )Tub,ng)~850i ~o i~0 I,nterva, I 4 P.T.D.I 1972220ITypetestl, P I TestpsiJ 1500 JCasingJ 0 I 1725 I 1700 I 1690 I P/F I P Notes: 2 bbls. Pumped for test pressure. Well'I 1D-120 I Typelnj. J N I T.V.D. I 3590 J TubingI 920 I 920 I 890 I 890 I lntervalJ 4 P.T.D.I 1972210JTypetestI P I TestpsiJ 1500 I CasingI 0 I 1800 I 1750 I 1750I P/F } _P Notes: 1 1/2 bbls. Pumped for test pressure. WellJ 1D-130 I Typelnj. I S ! T.V.D. I~ }Tubing I 900 [ 1000 I 1000 11000 I lntervall 4 ,P.T.D.I 1971830 ITypetestl P }TestpsiJ 1500 I Casingl ,175 I 1865 I 1825 I lS25 I P/Fl?- Notes: 1 bbl. pumped for test pressure. WellI I Type Inj. P.T.D. I I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING 4 MIT'S Witnessed, no failures. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 4 Attachments: Number of Failures: 0 -- Total Time during tests: 3 hrs. cc: SCANNED AUG 0 1 2002 MIT report form 5/12/00 L.G. MIT PAl 1D 07-11-02jc.xls 7/24/2002 Well' ComPliance Report File on Left side of folder 198-049-0 KUPAI~K ~ WIT. ' iD2i0 50~ 029222870200 ~0 MD 07340. TVD _0_6_63_3_ ~.C~mpletion Date: -'4/12/98 Completed Status: 1WINJ Current: T Name Interval Sent Received T/C/D C 9155 SCHLUM DSI OH 5/6/99 5/19/99 D 8298 ~ SPERRY MPT/GR/EWR4/CNP/SLD OH 4/29/98 4/30/98 L CBL ~--'F-1NAL 6750-7234 ~ft~/q~ CH 5 7/9/98 7/13/98 L DGR/CNP/SLD-MD .-FI'~AL 4793-7340 OH 5/6/98 5/6/98 L DGR/CNP/SLD-TVD ~ 4365-6628 OH 5/6/98 5/6/98 L DGR/EWR4-MD ~..1~L 4793-7340 OH 5/6/98 5/6/98 L DGR/EWR4-TVD .F~rNAL 4365-6628 OH 5/6/98 5/6/98 L DSIREPROCESSED ~[~"~L 7027-7300 CH 5/6/99 5/19/99 C R SRVY RPT --t-~ER'RY 0-7340. OH 6/2/98 6/19/98 Daily Well Ops 3/.))/~°O-- )"-//d°/¥~ Are Dry. Ditch Samples Required? yes no And Received? yes no Was the well cored? yes no Analysis Description Received? yes no Sample Set # Comments: Monday, May 01,2000 Page 1 of i ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the second quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the second quarter of 1999. Annular b,jection during tile seco~id quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume I Volume Quarter Total Total 1C-15 34380 100 ] 0 32195 16795 48990 2L-313 3779 100 I 0 3879 8654 12533 CDI-19 33933 100 , [ 0 34033 0 34033 . 1C-25 34216 100 ] 0 I 34316 0 34316 . CDI-40 12071 100 , 0' I 12171 0 12171 1 C-23 9505 100 ! 0 9605 0 I 9605 Total Volumes into Amudi for which h~jection Authorization Expired during the quarter ' Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected I Status of Annulus 1D-10 35473 100 0 35573 { Open, Freeze Protected 2N-323 32696 100 0 32796 Open, Freeze Protected 2N-343 17895 100 i 0 17995 Open, Freeze Protected 2N-329 9 100 I 0 109 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Ms. Wendy Mahan AOGCC Second Quarter 1999 Annular Injection Report Page Two CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11326 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/9/98 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1 A- 20 PRODUCTION PROFILE 980531 I 1 1D-10 * CBT 980518 I 1 1 D-124 FLOWING TEMP/PRESS 980524 I 1 1 D- 130 ~ \ ~ - INJECTION PROFILE 980423 I 1 1 D- 133 FLOWING TEMP/PRESS 980524 I 1 1 E-23 ~\ ~ L,.~ - INJECTION PROFILE 980523 I 1 2 A- 17 PRODUCTION PROFILE 980522 I 1 2A- 19 PRODUCTION PROFILE 98051 0 I 1 2 D- 14 (..~\ ( WATER INJECTION PROFILE 980531 I 1 2 D- 16 t..k [ ~ .... WATER INJECTION PROFILE 980530 1 1 2F-02 [ ~.~ (.~ .~ WATER INJECTION PROFILE 980528 I 1 2F-03 ~,~ C --.WATER INJECTION PROFILE 980529 I 1 2 M-23 TEMPERATURE SURVEY 980507 I 1 , 3 C- 04 PRODUCTION PROFILE 980505 I 1 3C-04 GAS LIFT SURVEY 980505 I 1 3F-06 GAS LIFT SURVEY 98051 2 I 1 3 F- 06 PRODUCTION PROFILE 980512 I 1 3 F- 14 PRODUCTION PROFILE 98051 4 1 1 3K-27 GAS LIFT SURVEY 980504 I 1 1D-09 ', CBT 98051 7 1 I q'q-'a~ h ~,3, Iq o '4- Please sign and return one copy of this transmittal to Sherrie at the above address, lhank you. DATE: 5~6~99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12557 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia Color CD-R Print 1D-10 ~ ~'~- 98193 REPROCESSEDDSl 980410 1 1 1 1D-111 CBL 990415 1 1 1D-114 CBL 990421 1 1 1 D-132 WFL W/RST 990416 1 1 2B-02 PROD. PROFILE 990423 1 1 3N-18 PROD. PROFILE 990425 1 i 3G-25X 99200 USIT 980107 1 3H-11 99201 USIT 990428 1 SlGNED.(~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ~aska Oil & Gas Cons. Commi~ioi~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: iD-10 (Permit No. 98-49) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU iD-10. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Team Leader Kuparuk Drill Site Development GCA/skad MAY 22 1998 4taska Oil .& 8as Cons..G~,,'~imis Anch'0ra!3~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [~ ABANDONED [~-~SERVICE [~] Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-0049 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22870 4 Location of well at surface 9 Unit or Lease Name At Top Producing Interval ~i~ i ~llllj~l~i~i'. 10 Well Number At1693' FNL, 2104' FWL, Sec. 24, T11N, R10E, UMTotal Depth i i";~.;.l .;_~;'~ ' j ~! 1 D-1 0 111 Field and Pool 1716' FNL, 2180' FWL, Sec. 24, T11N, R10E, UM ",-, .... -.~ ..... ~" KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. Kuparuk River Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 114 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 31 -Mar-98 09-Apr-98 12-Apr-98 NA feet MSL 1 7340' MD & 6633' TVD 7245' MD & 6547' 'I-VD YES __ NO __ N/A feet MD 1465' APPROX 22 Type Electric or Other Logs Run Dipole Sonic/GR, CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECC)RD 16" 62.511 H-40 SURF. 121' 24" 9 cubic yards High Eady 9.625' 4011 Lo80 SURF. 4778' 12.25' 595 sx ASIII, 576 sx Class G, 60 sx AS I 7' 26.011 L-80 SURF. 7027' 8.5' 170 sx Class G 4.5' 12.611 L-80 6821' 7339' 6.125' 89 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5' 6832' 6836' 7175'-7195' MD 6484'-6502' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Injector Date of Test Hours Tested PRODUCTION FO OIL-BBL GASoMCF WATER-BBI CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVITY-APl (corr) 3ress. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORI¢I L N/A Form 10-407 z[~r~'~ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase~ Top of Kuparuk C 7147' 6459' Base of Kuparuk C 7238' 6541' Total pump volumes for this event: Category 1. 13713 Category 2. 100 Category 3. 0 Total: 13813 Total to Date: 13813 Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of D. aily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. PrepareU by N,~me/Number Sl~aron AIIsup-Drake/263-4612 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 Date: 5/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-10 WELL_ID: AK9133 TYPE: AFC: AK9133 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/31/98 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22870-00 03/27/98 (D1) TD: 121' (121) SUPV:GRW 03/28/98 (D2) TD: 121'( SUPV:GRW 0) 03/29/98 (D3) TD: 121'( SUPV:GRW 0) o3/3o/98 (D4) TD: 121'( SUPV:GRW 0) 03/31/98 (D5) TD: 1268' (1147) SUPV:DEB 04/01/98 (D6) TD: 4270' (3002) SUPV: DEB 04/02/98 (D7) TD: 4793'(523) SUPV:DEB MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Prep rig modules for move. Start moving rig. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Continue moving rig from 2T pad. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Move to iR exit road. Move utility module to iD pad. Move drilling module. Lost left track engine on #2 Lampson on drill module. Remove ~2 Lampson and exchange w/#4 Lampson from utility module. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 P/U DRILLPIPE Change out ~2 Lampson w/#4 Lampson and repair air leaks. Move drill module to pad and position over hole. Accept rig @ 1800 hrs. 3/30/98. N/U diverter stack. MW: 9.2 VISC: 278 PV/YP: 36/52 APIWL: 5.8 WIPER TRIP TO DC'S ~ 2012' Function test diverter system. Spud at 121' and drill to 1268' MD. MW: 9.6 VISC: 331 PV/YP: 37/55 APIWL: 6.4 DRILLING AT 4750' Drill from 1268' to 2012' MD. Circulate hole clean. Pump slug. CBU, no gas. Drill to 4270' MD. MW: 9.7 VISC: 286 PV/YP: 32/52 APIWL: 6.8 MU CASING HANGER & LANDING JT Drill from 4270' to 4793' Circulate lo-visc sweep around and circulate hole clean. Pump slug. RIH with hole opener. 04/03/98 (D8) TD: 4793' ( SUPV: DEB 04/04/98 (D9) TD: 4793'( SUPV:DEB 0) 0) 04/05/98 (D10) TD: 6935' (2142) SUPV:DEB 04/06/98 (Dll) TD: 7037' (102) SUPV:DEB 04/07/98 (D12) TD: 7057' ( 20) SUPV:DEB 04/08/98 (D13) TD: 7285' (228) SUPV:DEB Run 9-5/8" surface casing. MW: 10.1 VISC: 101 PV/YP: 31/35 TESTING BOPE APIWL: 7.0 Run 9-5/8" surface casing. Pump first and second stage cement jobs. ND cement head and NU BOPE. MW: 8.6 VISC: 35 PV/YP: 4/ 4 TEST FORMATION @ 4843' APIWL: 15.8 Test BOPE. Clean out cement from 2128' to 2133'. Drill out plug & stage collar from 2133' to 2136' Wash down to 2206' Clean out cement to 4634' Test casing to 3000 psi for 30 minutes. Clean out cement to plug at 4653' Drill out shut-off plug and baffle plate at 4653' Clean out cement to 4690' MW: 9.5 VISC: 48 PV/YP: 13/25 DRILLED TO 7037' APIW-L: 6.8 Finish drilling out cement & floats. Shoe at 4778' MD. Clean out rathole. Drill 20' of new hole to 4813' MD. Test formation. Drill 30' more hole to 4843' MD. Re-test formation. Leaked off at 14.7+ ppg EMW. Drill to 6935'MD. MW: 9.7 VISC: 61 PV/YP: 25/22 SET WEAR BUSHING APIWL: 6.2 Drill to 7037' MD. Test formation, leaked-off at 13.2 ppg EMW LOT. Run 7" intermediate casing. Cement 7" casing. MW: 10.4 VISC: 54 PV/YP: 27/23 CIRC AT 7077' MD APIWL: 6.0 Finish displacing cement with mud. Bumped plug. Floats held. Set 7" packoff and test to 5000 psi, OK. Test casing to 3500 psi, OK. Clean out cement and drill out float collar; drill out shoe at 7027'. Clean out rathole to 7037' Drill 20' of new hole to 7057' MD. MW: 12.6 VISC: 62 PV/YP: 34/32 TD AT 7340' MD APIWL: 3.6 Test formation, no leak off, 16.0 ppg EMW. Drill 20' more new hole to 7077' MD. Re-test formation to 1346 psi, no leak off, 16.0+ ppg EMW. Drill to 7110'. Got gas cut mud up from drilling break at 7090' to 7095' Drill to 7157' MD. Drilled into top of 'C' sand at 7151' MD. CBU. Got boiling gas cut mud. Weight up to 12.3 ppg. Drill to 7168' Started getting boiling gas cut mud. Weight up to 12.5 ppg. Drill to 7285' Had gas cut on bottoms up and weig~..~.~~~ .... ~2~ ppg while drilling..~~'i %~~_-) MAY 22 1998 {DJ{ A _ons, Date: 5/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/09/98 (D14) TD: 7340'( 55) SUPV:DEB MW: 13.9 VISC: 62 PV/YP: 37/30 RU SWS E-LINE. APIWL: 4.0 Drill from 7285' - 7340' MD, 6633' TVD. (2.28 ADT) . Gas cut for 32 Bbls to 11.7 ppg minimum; no bollng. Pump slug. POH slow to 4525' Monitor well - static. 04/10/98 (D15) TD: 7340'( 0) SUPV:DEB MW: 13.9 VISC: 64 PV/YP: 41/30 RUN 4.5" LINER IN HOLE ON DP. APIWL: 4.2 Monitor well at 2600' and 11268' PJSM on removing RA sources. Circ. No gas cut on bottoms up. Record slow pump rates. Hole fill 1/2 Bbl over calculated. PJSM on running liner. Checking floats at midnight. 04/11/98 (D16) TD: 7340' ( 0) SUPV:DEB MW: 13.9 VISC: 61 PV/YP: 35/30 RUN 4.5" COMPLETION STRING APIWL: 4.2 Reciprocate pipe & circ to condition mud & hole for cementing. Test casing, liner and liner packer to 3500 psi for 5 min., no loss, OK. Broke out and Bakerlocked both sides of center coupling. (Old LJ had dinged pin.) RU to run completion. 04/12/98 (D17) TD: 7340'( 0) SUPV:DEB MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED MOVE TO 1D-09 APIWL: 0.0 RU to run completion. PJSM. NU FMC tubing head adapter and WKM master valve. Test hanger to 5000 psi; OK. LD 3.5" DP. 04/13/98 (D18) TD: 7340' ( 0) SUPV:DEB MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED, MOVED TO 1D-09 APIWL: 0.0 Finish LD 3.5" DP. Release rig 8 0400 hrs. 4/13/98. Moving to 1D-09. End of WellSummary for Well:AK9133 Prepared by: S. ALLSUP-DRAKE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~, K1(1D-10(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-10 FILL: TAG, CLEANOUT, BAIL 0511981717.4 DATE DAILY WORK UNIT NUMBER 05/18/98 RUN CBT LOG/PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES SWS-JOHNSON SCHWENDERMAN Signed Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 800 PSI 0 PSI 0 PSII 500 PSI 500 PSI DAILY SUMMARY RAN CBT LOG AND PERFORATE "C3" SANDS TIME 09:00 11:00 13:00 15:00 17:00 18:00 19:00 LOG ENTRY MIRU TGSM TOOL HANDLING. MU CBT TOOL ASSEM (CENT/CBS/CENT/CBC/CENT/FLEJT/GR/TOG/CAL Y) TL=49'. RIH TIE IN LOG W/SCHLUMBERGER DIPOLE SONIC/GR DATED 4/10/98. TAGGED DOWN AT 7242' RKB. LOGGED F/7234' TO 6750' RKB LOG SHOWED GOOD CEMENT BOND. POH. AT SURFACE BREAK DOWN CBT TOOL. CHANGED E-LINE FROM LARGE TO SMALL SPOOL MU PERFORATING ASSEMBLY 2-7/8" HC, DP 4 SPF 60-120 DEG PHASING (20' GUN/CCL) RIH. TIE IN W/ SCHLUMBERGER DIPOLE SONIC 4/40/98 AND CBT LOG FROM ABOVE.TAGGED DOWN AT 7242 RKB. APPLY 700 PSI TO TUBING TO OBTAIN 500 PSI UNDERBALANCE. PERFORATED F/7175' TO 7195'. POH. AT SURFACE RD ALL SHOTS FIRED. RETURN WELL TO PRODUCTION. I I ARCO ALASKA, INC. KUPARUK RIVER UNIT PARKER 245 DS 1D-10 50-029-22870-00 AK-MM-80176 SPERRY-SUN DRILLING SERVICES 09-APRIL-1998 MAGUTM VALUES: DECLINATION = 27.68 DIP ANGLE = 80.62 TOTAL FIELD STRENGTH = 57,279 DATE OF MAGNECTIC DATA = 30-MARCH-1998 MEASURED ANGLE DEPTH DEG 0.00 0.00 121.00 0.00 191.55 0.57 282.55 1.31 371.83 2.48 463.05 4.25 554.65 7.22 644.11 10.80 733.80 13.06 823.70 15.43 914.28 19.45 1005.51 23.90 1095.27 25.53 1188.61 25.44 1375.99 25.78 1564.85 26.26 1750.13 27.83 1931.52 28.35 2117.68 28.57 2305.60 27.58 2584.60 27.74 2863.55 27.94 3141.72 27.51 3419.28 26.82 3702.26 26.35 3978.37 25.22 4166.29 25.96 4350.85 26.82 4539.02 26.22 4712.62 27.83 5017.13 28.34 5296.64 28.14 5576.40 27.50 5854.41 26.49 6134.54 27.32 DIRECTION DEG 0.00 0.00 201.93 168.60 133.74 118.98 105.74 102.79 105.93 109.25 108.46 109.02 112.73 115.04 118.74 115.66 112.88 113.23 109.06 109.62 112.03 112.72 112.21 111.89 112.07 111.84 113.10 112.91 113.05 112.95 112.60 112.66 113.17 114.03 112.04 VERTICAL LATITUDE DEPARTURE VERTICAL DOG DEPTH FEET FEET SECTION LEG 0.00 0.00 0.00 0.00 0.00 121.00 0.00 0.00 0.00 0.00 191.55 0.33 S 0.13 W 0.00 0.81 282.54 1.77 S 0.09 W 0.58 0.98 371.77 4.10 S 1.50 E 2.94 1.78 462.83 7.10 S 5.89 E 8.13 2.14 553.96 10.31 S 14.40 E 17.22 3.53 642.31 13.69 S 27.99 E 31.08 4.03 730.05 18.33 S 45.93 E 49.45 2.62 817.19 25.07 S 66.99 E 71.50 2.79 903.58 33.82 S 92.68 E 98.59 4.45 988.34 44.66 S 124.58 E 132.22 4.88 1069.88 58.06 S 159.61 E 169.72 2.51 1154.14 74.31 S 196.33 E 209.86 1.07 1323.12 110.94 S 268.52 E 290.54 0.87 1492.85 148.79 S 342.20 E 373.04 0.76 1657.87 183.35 S 419.00 E 457.20 1.09 1817.89 216.80 S 497.58 E 542.60 0.30 1981.57 248.78 S 580.28 E 631.25 1.07 2147.38 278.06 S 663.73 E 719.58 0.55 2394.50 324.10 S 784.76 E 849.04 0.41 2641.17 373.69 S 9'05.22 E 979.31 0.14 2887.40 423.15 S 1024.81 E 1108.72 0.18 3134.34 470.72 S 1142.26 E 1235.44 0.25 3387.40 518.12 S 1259.70 E 1362.08 0.17 3636.02 563.03 S 1371.09 E 1482.18 0.41 3805.50 594.06 S 1446.09 E 1563.34 0.49 3970.83 626.12 S 1521.60 E 1645.37 0.47 4139.20 658.92 S 1598.95 E 1729.38 0.32 4293.84 689.74 S 1671.56 E 1808.25 0.93 4562.49 745.23 S 1803.74 E 1951.59 0.18 4808.73 796.12 S 1925.81 E 2083.84 0.07 5056.15 846.95 S 2046.07 E 2214.39 0.24 5303.87 897.45 S 2161.71 E 2340.54 0.39 5553.68 947.02 S 2278.36 E 2467.27 0.44 ORIGINAL Page 2 ARCO ALASKA, INC. KUPARUK RIVER UNIT PARKER 245 DS 1D-10 50-029-22870-00 AK-MM-80176 SPERRY-SUN DRILLING SERVICES 09-APRIL-1998 MAGUTM VALUES: DECLINATION = 27.68 DIP ANGLE = 80.62 TOTAL FIELD STRENGTH = 57,279 DATE OF MAGNECTIC DATA = 30-MARCH-1998 MEASURED ANGLE DIRECTION DEPTH DEG DEG 6415.29 25.46 6692.50 27.96 6970.87 26.96 7283.80 24.17 7340.00 24.17 VERTICAL DEPTH LATITUDE FEET 112.90 5805.17 994.68 S 109.17 6052.79 1039.22 S 108.37 6299.80 1080.53 S 106.43 6582.07 1121.02 S 106.43 6633.34 1127.52 S DEPARTURE VERTICAL DOG FEET SECTION LEG 2393.68 E 2592.05 0.68 2509.97 E 2716.55 1.09 2631.50 E 2844.69 0.38 2760.30 E 2979.25 0.93 2782.37 E 3002.15 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET THE VERTICAL SECTION WAS COMPUTED ALONG 112.14- (TRUE) BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 3002.15 FEET, IN THE DIRECTION OF 112.06- (TRUE) Kuparuk Unit Kuparuk 1D 1D.10 S UR VEY REPORT May, ~998 Your Reft API-500292287000 Last Survey 08-April-98 Job# AKMMSO176 KBE- 1~1.60' Sl:3~r~r',~j-sLJr~ DRILLING ¢~ E RV I I"' E 5 ORIGINAL Survey Ref: svy4 Sperry-Sun Drilling Services Survey Report for 1D-lO Your Ref: A PI-50029228 7000 Kuparuk Unit Measured Depth (ft) Incl. 0.00 121.00 191.55 282.55 371.83 463.05 554.65 644.11 733,80 823.70 914.28 1005.51 1095.27 1188.61 1375.99 1564.85 1750.13 1931.52 2117.68 2305.60 2584,6O 2863.55 3141.72 3419.28 37O2.26 3978.37 4166.29 435O.85 4539 .O2 4712.62 0.000 0.000 0.570 1.310 2.480 4.250 7.220 10.800 13.060 15.430 19.450 23.900 25.530 25.440 25.780 26.260 27.83O 28.350 28.570 27.580 27,740 27.940 27.510 26.82O 26.350 25.220 25.960 26.820 26.220 27.830 0.000 0.000 201.930 168,600 133.74O 118.980 1 O5.74O 102.790 105.930 109.250 108.460 109.020 112.730 115.040 118.740 115.660 112.880 113.230 109.060 109.620 112.030 112.720 112.210 111.890 112.070 111.840 113.100 112.910 113.050 112.950 Sub-Sea Depth (ft) -111.60 9.40 79.95 17O.94 260.17 351.23 442.36 530.71 618.45 705.59 791.98 876.74 958.28 1042.54 1211.52 1381.25 1546.27 1706.29 1869.97 2035.78 2282.90 2529.57 2775.80 3O22.74 3275.80 3524.42 3693.90 3859.23 4027.60 4182.24 Vertical Depth (ft) Local Coordinates Global Coordinates Dogleg Vertical. Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 0.00 0.00 N 0.00 E 5959108.97 N 560490.70 E 0.00 121.00 0.00 N 0.00 E 5959108.97 N 560490.70 E 0.000 0.00 191.55 0.33 S 0.13W 5959108.64 N 560490.57 E 0.808 0.00 282.54 1.77 S 0.09VV 5959107,20 N 560490.62 E 0.979 0.58 371.77 4.10 S 1.50 E 5959104.88 N 560492,24 E 1.783 2.93 462.83 7.10 S 5.89 E 5959101.91N 560496.64 E 2.145 8.12 553,96 10.31S 14.40 E 5959098.78 N 560505.18 E 3.529 17.22 642.31 13.69 S 27.99 E 5959095.50 N 560518.80 E 4.034 31.08 730,05 18.33 S 45.93 E 5959091.01N 560536.77 E 2.621 49.45 817.19 25.07 S 66.99 E 5959084.44 N 560557.89 E 2.787 71.50 903.58 33.82 S 92.68 E 5959075.90 N 560583.65 E 4.446 98.60 988.34 44.66 S 124.58 E 5959065.32 N 560615.63 E 4,883 132.23 1069.88 58.06 S 159.61E 5959052,20 N 560650.77 E 2.506 169.73 1154.14 74.31S 196.33 E 5959036,24 N 560687.62 E 1.069 209.87 1323.12 110.94 S 268.52 E 5959000.19 N 560760.11E 0.872 290.53 1492.85 148.79 S 342.20 E 5958962.94 N 560834.08 E 0.759 373.03 1657.87 183.35 S 419.00 E 5958929.00 N 560911.16 E 1.088 457.19 1817.89 216.80 S 497.58 E 5958896,18 N 560990.01 E 0.301 542.58 1981.57 248.78 S 580.28 E 5958864.87 N 561072.97 E 1.074 631.23 2147.38 278.06 S 663.73 E 5958836.26 N 561156.65 E 0.545 719.57 2394.50 324.10 S 784.76 E 5958791.20 N 561278.05 E 0,405 849.04 2641.17 373.69 S 905.22 E 5958742.58 N 561398.90 E 0.136 979.30 2887.40 423.15 S 1024.81 E 5958694.09 N 561518.88 E 0.177 1108.71 3134.34 470.72 S 1142.26 E 5958647.46 N 561636.71 E 0.254 1235.43 3387.40 518.12 S 1259.70 E 5958601.01 N 561754.53 E 0.169 1362.07 3636.02 563.03 S 1371.09 E 5958557.00 N 561866.28 E 0.411 1482.17 3805.50 594.06 S 1446.09 E 5958526.57 N 561941.52 E 0.489 1563.34 3970.83 626.12 S 1521.60 E 5958495.12 N 562017.29 E 0.468 1645.36 4139.20 658.92 S 1598.95 E 5958462.94 N 562094.90 E 0.321 1729.37 4293.84 689.74 S 1671.56 E 5958432.71 N 562167.75 E 0.928 1808.23 Comment Kuparuk 1 D Con~nued... 14 May, 1998 - 9:41 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-lO Your Ref: API-500292287000 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 5017.13 28.340 112.600, 4450.89 4562.49 745.23 S 1803.74 E 5958378.28 N 562300.38 E 0,176 1951.58 5296.64 28.140 112.660 4697.13 4808.73 796.12 S 1925.81 E 5958328.38 N 562422.85 E 0.072 2083.83 5576.40 27.500 113.170 4944.55 5056.15 846.95 S 2046.07 E 5958278.52 N 562543.52 E 0.244 2214,37 5854.41 26.490 114.030 5192.27 5303.87 897.45 S 2161.71E 5958228.95 N 562659.56 E 0,389 2340,51 6134.54 27.320 112.040 5442.08 5553.68 947.02 S 2278.36 E 5958180.32 N 562776.61 E 0,437 2467,24 6415.29 25.460 112.900 5693.57 5805.17 994.68 S 2393.68 E 5958133.59 N 562892.31 E 0,676 2592.02 6692.50 27.960 109.170 5941.19 6052.79 1039.22 S 2509.97 E 5958089.99 N 563008.96 E 1.085 2716.53 6970.87 26,960 108.370 6188.20 6299.80 1080.53 S 2631.50 E 5958049.66 N 563130.81 E 0.383 2844.68 7283.80 24.170 106.430 6470.47 6582.07 1121.02 S 2760.30 E 5958010.21N 563259.93 E 0.931 2979.25 7340.00 24.170 106.430 6521.74 6633.34 1127.52 S 2782.37 E 5958003.88 N 563282.06 E 0.000 3002.15 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Referance. Northings and Eastings are relative to Well Referance. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 112.060° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7340.00ft., The Bottom Hole Displacement is 3002.15ft., in the Direction of 112.060° (True). Comment Projected Survey Kuparuk 1 D 14 May, 1998 - 9:41 - 3 - DrillQuest ri I::t I I_1_ I I~ G S E I:tVI r" E S 02-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-10 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 7,340.OO' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) o_ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSi~ffI~AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-10, AK-~MM-80176 May 6, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' .Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 ID-10: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22870-00 2" x 5" TVD ResistiviW & Gamma Ray Logs: 50-029-22870-00 2" x 5" MD Neutron & Density, Logs: 50-029-22870-00 2" x 5" TVD Neutron & Density Logs: 50-029-22870-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia l Blueline 1 Folded Sepia 1 Blueline 1 Fold.ed Sepia~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. I:! Ft I I,..I,- I N G SEE RtUI (~ EE S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs April 29, 1998 AK-MM-80176 1 LDWG formatted Disc with verification listing. API#: 50-029-22870-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service At-tn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: f/~O//~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 9, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 D- 10 Dear Mr. Commissioner: Enclosed please find a LOT plot, cementing detail and the casing detail sheets for Kuparuk Well 1D-10. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. Please note that logging and remedial work were performed on 1D-10 to fulfill the requirement of bringing cement to surface. These operations are detailed in the summary sheets, and a copy of the bond log is enclosed. If there are any questions, please call 263-4290. Sincerely, G. Alvord Drilling Engineer Kuparuk Drill Site Development GCA/skad RECEIVED .~aska 0ii & Gas Cons. 60rnmissi0~ Anchorage cc: Blair Wondzell -_ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 9, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 D- 10 Dear Mr. Commissioner: Enclosed please find a LOT plot, cementing detail and the casing detail sheets for Kuparuk Well ID-10. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. Please note that logging and remedial work were performed on 1 D-10 to fulfill the requirement of bringing cement to surface. These operations are detailed in the summary sheets, and a copy of the bond log is enclosed. If there are any questions, please call 263-4290. Sincerely, G. Alvord Drilling Engineer Kuparuk Drill Site Development GCA/skad cc: Blair Wondzell File 0¢-07-~8 22:15 P.01 Calculations Chat tSheet nun'~m o~ _ 5"O0 Anchorage,~ ARCO ~)5-04-98 15:55 P.04 . ........~ CalCulations Chal IShset numOer / o~ t" Alaska Oi~ a Gas Cons. Date: 4/9/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-10 WELL_ID: AK9133 TYPE: AFC: AK9133 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/31/98 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22870-00 03/27/98 (D1) TD: 121' (121) SUPV: GRW MW: 0.0 VISC: 0 PV/YP: 0/ 0 MOVING RIG Prep rig modules for move. Start moving rig. APIWL: 0.0 03/28/98 (D2) TD: 121'( SUPV:GRW 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 MOVING RIG Continue moving rig from 2T pad. APIWL: 0.0 03/29/98 (D3) TD: 121'( SUPV:GRW 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Move to iR exit road. Move utility module to iD pad. Move drilling module. Lost left track engine on ~2 Lampson on drill module. Remove ~2 Lampson and exchange w/~4 Lampson from utility module. 03/30/98 (D4) TD: 121' ( SUPV: GRW 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 P/U DRILLPIPE Change out ~2 Lampson w/~4 Lampson and repair air leaks. Move drill module to pad and position over hole. Accept rig @ 1800 hrs. 3/30/98. N/U diverter stack. 03/31/98 (D5) TD: 1268' (1147) SUPV:DEB MW: 9.2 VISC: 278 PV/YP: 36/52 APIWL: 5.8 WIPER TRIP TO DC'S @ 2012' Function test diverter system. Spud at 121' and drill to 1268' MD. 04/01/98 (D6) TD: 4270'(3002) SUPV:DEB MW: 9.6 VISC: 331 PV/YP: 37/55 APIWL: 6.4 DRILLING AT 4750' Drill from 1268' to 2012' MD. Circulate hole clean. Pump slug. CBU, no gas. Drill to 4270' MD. 04/02/98 (D7) TD: 4793' (523) SUPV:DEB MW: 9.7 VISC: 286 PV/YP: 32/52 APIWL: 6.8 MU CASING HANGER & LANDING JT Drill from 4270' to 4793' Circulate lo-visc sweep around and circulate hole clean. Pump slug. RIH with hole opener. Run 9-5/8" surface casing. 04/03/98 (D8) TD: 4793 ' ( SUPV: DEB 04/04/98 (D9) TD: 4793' ( SUPV: DEB 0) 0) MW: 10.1 VISC: 101 PV/YP: 31/35 APIWL: 7.0 TESTING BOPE Run 9-5/8" surface casing. Pump first and second stage cement jobs. ND cement head and NU BOPE. MW: 8.6 VISC: 35 PV/YP: 4/ 4 APIWL: 15.8 TEST FORMATION @ 4843' Test BOPE. Clean out cement from 2128' to 2133' Drill out plug & stage collar from 2133' to 2136' Wash down to 2206' Clean out cement to 4634' Test casing to 3000 psi for 30 minutes. Clean out cement to plug at 4653' Drill out shut-off plug and baffle plate at 4653' Clean out cement to 4690' 04/05/98 (D10) TD: 6935' (2142) SUPV: DEB MW: 9.5 VISC: 48 PV/YP: 13/25 APIWL: 6.8 DRILLED TO 7037' Finish drilling out cement & floats. Shoe at 4778' MD. Clean out rathole. Drill 20' of new hole to 4813' MD. Test formation. Drill 30' more hole to 4843' MD. Re-test formation. Leaked off at 14.7+ ppg EMW. Drill to 6935'MD. 04/06/98 (Dll) TD: 7037' (102) SUPV:DEB MW: 9.7 VISC: 61 PV/YP: 25/22 APIWL: 6.2 SET WEAR BUSHING Drill to 7037' MD. Test formation, leaked-off at 13.2 ppg EMW LOT. Run 7" intermediate casing. Cement 7" casing. 04/07/98 (D12) TD: 7057'( 20) SUPV:DEB MW: 10.4 VISC: 54 PV/YP: 27/23 APIWL: 6.0 CIRC AT 7077' MD Finish displacing cement with mud. Bumped plug. Floats held. Set 7" packoff and test to 5000 psi, OK. Test casing to 3500 psi, OK. Clean out cement and drill out float collar; drill out shoe at 7027' Clean out rathole to 7037' Drill 20' of new hole to 7057' MD. 04/08/98 (D13) TD: 7285'(228) SUPV: DEB MW: 12.6 VISC: 62 PV/YP: 34/32 APIWL: 3.6 TD AT 7340' MD Test formation, no leak off, 16.0 ppg EMW. Drill 20' more new hole to 7077' MD. Re-test formation to 1346 psi, no leak off, 16.0+ ppg EMW. Drill to 7110'. Got gas cut mud up from drilling break at 7090' to 7095' Drill to 7157' MD. Drilled into top of 'C' sand at 7151' MD. CBU. Got boiling gas cut mud. Weight up to 12.3 ppg. Drill to 7168' Started getting boiling gas cut mud. Weight up to 12.5 ppg. Drill to 7285' Had gas cut on bottoms up and weighted up to 12.8 ppg while drilling. End of WellSummary for Well:AK9133 . . 9.~/8" Suffaae Casin~ ARCO Alaska, Inc, SubsidJa~ of Atlantic Richfie~ Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 53 Jts Joint Joint 'A' 85 Jt$ -- 1 Jt _ 2 J£S ! __ RKB to Landing Ring - Parker Rig #245 FMC Fluted Mandrel Casi%l H=noe,r, & 47#, NT-80SS, N$CC x BTC pup I;}-5/8", 40#, L-80, BTC Casino )-5/8", ,40#, L-a0, BTC Casing - Baker Locked Gemoco '764' Stage Cementing Tool ,9-5/8", 40#, L-BO, BTC Casino - Baker Locked 0-5/8"~ 40~, L-80, BTC Casin~l Gemoco Insert Shut-Off Baffle 9-518", 40~, L-80. BTC Casin~ Gemoco Float Collar 9-5f8", 40~, L-80, BTC Casing Oemoco Float ghoe [,I lilt III IIII ! III I II I WELL: 1D-10 KRU DATE: 4/3198 I OF I PAGES LENGTH DEPTH TOPS 41.00 1.73 41.00 2051.59 42,73 39.23 2094,32 2.86 2133.55 39.86 2136.41 2477.44 2176.27 4653.71 43.20 4653.71 1.45 4696.91 77.70 4698.36 1.70 4776,06 Bottom of Shoe ----->> TD = 4793' MD (-15' Rathole Baker Lock thru insert Shut-Off Baffle. plus Stage Collar to Joints 'A' & 'B' 4777.76 Install In=er~ 3hut-Off Baffle in Connection on Top of Jt ~, Run Stage Collar & Baker Locked Jt$ 'A' & 'B' on To/3 of Jr #68 RUn FMC Hang~r an Top of Joint #'12f ~0 Bow SpHn~7 Centralizers'." ,One on each of first 13joints (first. two on stop rfnE~_~ Then one on every 3rd joint to surface, Plus one on a stop ring on Baker Locked Jts 'A' & 'B' ,Leave OUT 4 Joints: #122 thru #125. -'Remarks: String Weights with Blocks: 25014# Up, 180K# Dh, 76K# Blocks. Ran 1Z3ioints of casing. Drifted casing with 8,§79" plastic rabbit. Calipered pup on hanger to be sure it passed an 8-1/2" bit. Used Arctic Grade 'APl Modified No Lead thread coml3ound on all connections (National = BOL 2000). ,, __ Torcjued to the base of the triangle stamp, ARCO Alaska Inc. C' ~enting Details Well#: 1D-10 Field: Kupa'ruk River Unit ._~, Date: 413198 Casing Size Hole Diameter KOP & Angle! Shoe Depth Baffle Depth' I Stage Tool Depth 9-5/8" !2-114" 300' - 27' 4778' 4654' 2134' Centralizers $~ate type used, in,err,Is covered ancl,~pacin~7 50 Gemoc. o Bow Spring Centralizers: One on each of first t3 )oints,. first 2, on stop rings in middle of float joints; One on couplin~ of' every third joint to surface, with one on stop ring in -~iddle ofjoinl; on each stele of Gemoco sta~le collar. , M~d Weight PV(prior cond) PV(afler cond) IYP(prior cond) YP(after 10 0 32 31 I 52 35 Gels before ' Gels after Total Volume Circulated 21J58 ,, J 12/36 . Stage 1:1408 ~bls / Sta~le 2:1013 19bls . Spacer Type Volume Weight Water 50 BOls 130 Bbls 8.34 ppg 'Lead 'Type IMix water tamp No. of sect's Weight Yield Cement AS III LW! -75* F 145 sx / 450 s× 10.5 ppg ,, 4.42 cfs, Additives: Class G ~' 3,5%' D44 · 0.6% D46 + 30% D53 + 1,5% D79 · ,50% D124 ',. 1.5% $1 Tat' Type ' IMix water tamP I No. of sacks! Weight J Yie,d Cement Class G & AS 1 ~75~ F , 576 sx / 60 sx 15.8 ppgf15.7 ppg 1.i6 cf~0.93 cfs A-~ditives: stacJe ~I: Class G * 0.2% D46 + 0.3¥~ D65 + 0.55% D156 + 1.0% $1 Stage 2: Arctic Set 1 , Displacement Rate(before tail at shoe) iRate(tail around shoe) Str. Wt. Up 8.2 I~PM 8.0 BPM 250K# [Reciprocation length Reciprocation speed Str. Wt. Down ~ 15' ~20 FP,M 180K~ (76K~ Blocks) 'J'heoretical Displacement Actual Displacement Str. Wt. in mud 3528 Bbls/ 161.8 Bbls 352.8 BOls ! 162.2 BOls 162K# , C---alculated lop of Cement I CIP BumPecl plug JFloats held Cemented to Surface~ 1700 hfs, 413 Yes] , Yes Remarks: Include whether full returns were oblained, reciprocation thr, oughout operation and arty other pertinent information. Sta~le #1' Prime & test lines to 3500 psi. Pum[3 50 BO! water spacer, 8 BPM, 25(~ psi.. Mix & pumpr 114 B01s, 1--45 sx, 10.5.ppg AS III LW Lead Cement, 8.2 BPM, 280.psi. Load & drop b),pass !~I~t. Mix & pump 110 BOls, , 5;28 sx, 15.8 PP~I Class~ Tail C~m~nt (with 1% CaCl &,additives), 7.4 BPM, 280 psi'to tO0 psi. Load & dro_p ~hut-off plug. Chase pluc) with' 10 Bbis, 48 sx, 15.8 pp~ Tail. slurry & 25 Bbls wash-up water, 8 BPM. 50.psi. S--witch to ri~ pump & displace with mud, 8 BPM, I00 psi to 900 psi, slowed to 5 BP,M last 20 Bbls. Bumped iplu~! at 318 BOls mud. Bumped up to 1400 psi .& helot 2 minutes, OK. Floats held, Fu.I! returns. Reciprocated pipeI Ltntil ~11 Lead Cement had rounded the shoe. Pipe 9~)~ sticky as Taii sfa ,rted around the shoe, so landed .. _han~ler, then. 1st Sta_.qe CII~ @ 1, 130 hrs, 413198. Stage ~2: Opened Gemoco Sta~e Tool at2;134' with 23~0 Psi. Circulated out wa[er spacer, .cement, &'cement contaminated mud. Circulated hole clean above stage collar with some difficulb/d,"ue to contaminated mud packinc. I 0~f in small flutes in han~ler..Worked han~ler beck & forth in bowl to clear plugging & maintain circul,ation. Reconditioned mud & pu'mped 2nd sta~e. Pump 30 BOls water sjpacer, 6 'BPM, 80 psi. Mix & pump 10.'5 ppg AS III LW Lea~l Cement until ~l, etting good. 10.5 ppg retUrns, 6._BPM, 50.psi ,to 210 psi. Contaminated 8.8 ppg .. (water) returns at 263 Bbls pump, ed, contaminated cement at 305 BOls, 10.4 PP~I cement at, 348 Bbis. 10.5 ppg ~ement ai 354 B01s i--450 sx), Had to work han._[ter in bowl to maintain, return~ as thick / cor~taminated stuff came out, ~o problem once clean cement returned shortly thereafter. Switch to Tail, mix & pump 10 BOls, 60 sx, AS I Tail Cement, 4 B~M, 220 psi. Drop closing plug & chase wi~h 25 l~bls wash-up wa[e.r., 5.5 BPM, 200 psi. Switch to rig pump & displace with mud, 5.9 BPM, 200 psi to 450, psi. Bumped PlUg at 137 BOls mud. J='ressured -~p & sta~e tool closed at '1300 psi. Held ~000 psi for 2 minutes, OK. Floats held. Full returns. Relande.,d _ ha.nger, OK. GOOd ~0.5~- PP.9 cement returns to surface, 2nd Sta~e CiP (~I 1700 hrs, 413/98. , C--ement Company J Rig Contractor JSignature Dowell ! Parker Ri9 ~245 J Don E. Breede_n ~ -- TONY KNOWLE$, GOVERNOR ALASKA OIL ~AND GAS CONSERVATION COMMISSION ,3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 13. 1 Mike Zanghi Drill Site Develop. Supv. ARCO Alaska. Inc. PO Box 1()0360 Anchorage. ,AK 99510-()36() Rc: KupamkRivcrUnit 1D-l() ARCO Alaska. Inc. Permit No 98-49 Sur. Loc.: 588'FNL. 6()I'FEL. Sec. 23. T1 IN. RI()E. UM Btmholc Loc: 1684'FNL. 2171'FWL. Sec. 24. T1 IN. RI()E. UM Dear Mr. Zanvhi. Enclosed is thc approved application for pcnnil to drill thc above referenced xv¢ll. This approval includes annular disposal of drilling was]cs and is contingent on obtaining a well ccmcnlcd surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records. FIT data. and any CQLs arc to be submitted to thc Commission prior to thc start of disposal operations. The permit to drill docs not exempt you from obtaining additional permits required by law from other govermncntal agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Bloxvout prevention equipment (BOPE') must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours} of the BOPE test performed bcforc drilling bcloxv the surface casing shoc must be given so that a rcprcscnlativc of tile Comrnission may witness thc test. No]icc may be given by conlacting tile Commission petroleum field inspector on thc Noah Slope pager at 659-3607. Robert Christcnson. PE Commissioner BY ORDER OF THE COMMISSION dlf enclosures Department of Fish & (;amc. l iabltat Section we encl. l)cpartment of l(nvironlllCnl Conscn'ation w o encl. - STATE OF ALASKA ,~¢ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41'; PAD 7]' feet Kuparuk River Field 3. Address 6. Property Design.~ation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 AD]_. 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 588' FNL, 601' FEL, Sec. 23, T1 iN, R10E Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1649' FNL, 2085' FWL, Sec. 24, T11N, R10E 1D-10 #U-630610 At total depth 9. Approximate spud date Amount 1684' FNL, 2171' FWL, Sec. 24, T11N, R10E 03/21/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 7315' MD 3109' @ TD feet 32' @ 300' feet 2560 6612' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 27.08° Maximum su,aoe 3?53 psig At total depth (TVD) 4628 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD .! TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 40.0# L-80 BTC 4722' 41' 41' 4763' 4340' 785 Sx Arcticset III & 495 Sx Class G & 60 Sx ASl 8.5" 7" 26.0# L-80 BTC MOB 6992' 41' 41' 7033' 6361' 96 Sx Class G Top @ 500' above shoe 6.125" 4.5" 12.6# L-80 NSCT 482' 6833' 6184' 7315' 6612' 66 Sx Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. ?,, ~ %¢ Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet [¥2' :'"'"" 'd ~ 1998 Effective depth: measured feet Junk (measured) true vertical feet ~a~'~-~.i~ 0ii & 6as casing Length Size Cemented Measured depth -A~oh0~'vertical depth Structural Conductor Surface Intermediate Production Perforatio:i;;;th: measured ORI61NAL true vertical 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that.4the foregoing is true and correct to the best of my knowledge Signe%d~J¢~/// ~¢//~,~_.¢ ~,~/,/~,/-// Title Drill Site Develop. Supv. Date ,~/~' ~ Commission Use Only Permit Number~o~ G~), 00~ ~ IAPl number50- O~,~ -~,~, P'~O tAppr°val date ,'"'~ I~,~'~('~ Iseec°verletterf°rother requirements Conditions of approval Samples required Yes (~ Mud I~l reqt~red Yes Hydrogen sulfide measures ~ No Directional survey required ~ No Required working pressure for BOPE ~ 2M 3M (5M) 10M 15M Other: <~~ 9/ ~,..~~e~)':'''''~ ~/~~ by order of Approved by ~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 ilin triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - INJECTOR KRU 1D-10 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 12.25" hole to 9-5/8" surface casing point (+/4763') according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (+/- 7033') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 9. NU and test BOPE to 5000 psi. Test casing to 3500 psi. 10. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 11. Drill 6.125" hole to well total depth (+/- 7315') according to directional plan, running LWD logging equipment as needed. 12. Rig up and rig E-line logs 13. Run and cement 4-1/2" NSCT liner with Baker liner-top packer and hanger. Hydraulically set packer _+200' inside intermediate casing shoe to provide appropriate liner lap. 14. Pressure test liner to 3500 psi. 15. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 16. ND BOPE and install production tree. 17. Shut in and secure well. 18. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. 1D-10 TAB,03/05/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 1D-10 Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~ 8.8-10.0 35-70 25-50 150-250* 10-25 10-30 8-15 8-10 4-6% Drill out to 7" interm, casin~ 8.8-9.0 4-8 5-8 35-40 2-4 4-8 8-15 9.5-10 4-7% Drill out to TD 12.0-13.0 15-25 5-8 50-65 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillin_cl Fluid System' Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressu re of..~2,560 .psi. MASP: (4340 ft)(0.70 - 0.11) = 2560 psi Maximum anticipated surface pressure is calculated using an intermediate casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of psi. Therefore, ARCO Alaska, Inc. will do a one-time test of the BOP equipment to 5000 psi, retesting only roke'r~ flanges or after 7 day limit. ' "' ~ ~ MASP = (6361 ft)(0.70 - 0.11) = 3753 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1D pad are expected to be 4000 psi (0.62 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.4 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6407'. Well Proximity Risks: The nearest existing well to 1D-10 is 1 D-135. As designed, the minimum distance between the two wells would be 32' at 300' MD. Drillinq Area Risks' Risks in the 1D-10 drilling area running gravels, lost circulation and high pressures in the Kuparuk formation. These are addressed by using a high viscosity spud mud and by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of 12.4 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-10 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1D-10 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set ___200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the A©GCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.4 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.4 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure: 4298 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ~ 1 D-10 TAB, 3/05/1998, v. 1 400 4OO 800 1200 1600 2000 2400 2800 5200 3600 4O00 I V 4400 4800 5200 5600 6000 6400 ct.or.. ~ ,~.oh For: BROCKWAY] Date p4ott~d : l l-geb-§fl Plot R~ferenc~ is IO True V~tlc~l Depths ore reference EsLRKS(Porker~245). 6800 ARCO Alaska, Inc. Structure : Pad 1D Well: 10 Field : Kuporuk River Unit Location : North Slope, Alaska East (feet) -> 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 t I I I I I I I I I I I I I I I I I I I I I I I I I I I I 200 EST. SURFACE LOCATION: TARGET LOCATION: ] L i' 558' FNL, 601' FEL 1649' FNL, 208,5' FWL SEC. 2.5, T11N, RIOE SEC. 24, TllN, RiOE ~- 0 TARGET TVD=6451 EST. RKB ELEVATION: 112' _ _-'----..~8ose Permofrost~ TMD=7112 DEP=2899 ~- 200 SOUTH I091 0 KOP TVD=300 TMD=300 DEP=0 ~ EAST 2686 3.00 ~ -+- 400 6.00 ~ 3.00 DLS: 3.00 deg per 100 ft 12.00 ,5.00 ~ West Sak Sands ~. WS 10 600 8.0O C100 ~/8, Casing Pt VC8~n S TARGTET C_e ~-~ gC TD~ -~LJ~J / [- i 200 1.00 27.00 EOC TVD= 11 69 TMD= 1 20.3 DEP=209 B/ PERMAFROST TVD=1812 TMD=1924 DEP=538 1 12.1 AZIMUTH a899' (TO TARGET) 80o I V i ooo T/ W SAK SNDS TVD=3679 TMD=4021 DEP=1492 WSIO TVD=414-0 TMD=4559 DEP=1728 C100 '~'X~ 8 9 5/ " CSG PT TVD=4340 TMD=4763 DEP=1830 C80 '~AMP SS TVD=4545 TMD=4-994 DEP=1935 TARGET ANGLE 27.08 DEG ~4o B/ HRZ TVD=6255 TMD=6892 DEP--2799 K-1 MARKER TVB=6522 TMD=6989 DEP=28~5 \%'~ .......... 7" CSG PT TVD=6561 TMD=7055 DEP=2865 ¢%_ 'I'At~,U~T -- 't'/U¢ TYD=6431 TMD=?lt2 DBP=g899 T/ O TVD=6407 TM~5 T C3 TVD=6460 TMD=7144 DEP=2914 T/ C, 1 TVD=6524 TMD=7216 DEP=2947 T/_ B TVD=6552 TMD=7225 DEP=2951 TD - CSG PT TVD=6612 TMD=7315 DEP=2992 i I i I [ [ i i i ii i iI i i I i I 0 400 800 1200 1600 2000 2400 2800 .3200 .3600 Vertical Section (feet) -> Azimuth 112.10 with reference 0.00 N, 0.00 E from slot #10 Creotcd by finch For: BROCKWAY Dote plotted : 11 -Feb-98 Plo[ Reference is 10 Verslon ~2 ARCO Alaska, Inc. Siructure : Pod 10 Well : 10 Field : Kuporuk River Unif Locoi)on : North Slope. Alosko Eos' (feel) -> 120 80 40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 560 600 640 B80 720 760 i i I i i i I i i i i i i i i i i i i i i I i i i i i i i i i i i i I i i 160 1.500 900 1000 1600 120 1100 9OO 1'700 8O 1000 16O 120 11 O0 1800 40 BO0 1100 ~ 4O 0 120 I v ~6o 200 240 280 1000 1300 500(~.. iQ0 1900 700 800 300 1400 500, 1400 1500 300 1000 1600 2000 "'""--., 1200 2100 1700 1800 .... '--~ 1300 '""--. 1400 '--.. 1500 1600 2200 1700 23O0 1900 2000 .... --. 1600 '---. 1700 2100 2200 "--.. 1800 '"'--...1.900 ""'--. 2000 ""'"-... 2100 '""--.. 2200 40 Dr) 0 --4-- 80 2300 ,--(-,, 120 I 16o v 200 240 28O 320 320 360 2400 1800 360 I "'W ....... T"-'-- ~ ..... W ..... F ...... f' I I .... 1 ....... T ....... '1 ...... F ........ T 1 I T-'----IT ..... F T---'"'~---'~-"-'~ I i I I I r ..... '7 .... T-'---q- I I I .... 7 ........ T ....... T"'--'~ 120 80 40 0 40 80 120 160 200 240 280 320 560 400 440 480 520 560 600 640 680 720 760 Easf (feel) -> For: BROCKWAY Dote plaited : 11-Feb-fiB Plot Reference is 10 Version VerUcol Oeptha o~ [o[.EKB(Porker~245). 200 10o lOO 200 300 -4-- Q~ 400 --~ 500 0 6O0 I 7O0 800 900 lO00 11oo 1200 ARCO Alaska, Inc. Structure : Pad lO Well : 10 Field : Kuparuk River Unit Location : Nor'ih Slope, Alaska East (feet) -> 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 I I I I I I I I I I I I I I I I I I I I ! I I I I I I I I I II I I II I I II I I I ~0 2400 '----~.~ 2500 % 2600 2700 ~__..2800 -...2500 500 '"'--..~700 '""--.. 2900 .... -.. 31 O0 -.. 3300 -~ 5500 0 2~-~~.3000 ----------...~00 3200 ~3300 ""--'~'~.~..~3400 "--------~500 --'"-----~600 700 "'"----...~800 ~900 '"~'---~000 2900 3000 5100 "~"'----~100 '----~.---.__~ 3300 ~ 500 '------........._~.~5900 4100 -- 3700 ~'"'"'--~ 3900 '--~ 4100 '""'- 4300 '"'"'--~ 4500 '"--. 4700 '"-.. 4900 . '"---..5100 .. 5300 .... 5500 '"" .... . 5700 -.... '"-.. 5900 --~ 61 O0 "--~ 6300 .... ~ 6500 200 lOO lOO 2OO 500 0 400 C 50O 60O 700 8OO 9O0 1000 1100 I [ ~ ..... 1 ..... %---'1 .... I ~---% 1 .......... T ........ T ...... %'--~-f ..... I I I i I ] T----3-'--~--T ....... [ [ I I 1 I r ...... ¥ ..... ff i I I I f r --T'--' II I [---- 12 0 0 700 800 900 1000 1100 1200 1300 14-00 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 East (feet) -> I v ARCO Alaska, Inc. Pad 1D 10 slot #10 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 10 Version Our ref = prop2?59 License ~ Date printed : 11-Feb-98 Date created : 10-Feb-98 Last revised : 11-Feb-98 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on n?0 18 1.316,w149 30 18.908 Slot location is nT0 17 55.828,w149 30 36.428 Slot Grid coordinates are N 5959106.717, E 560490.497 Slot local coordinates are 558.00 S 601.00 W Projection ty~e: alaska - Zone 4, Spheroids Clarke - 1866 Reference North is True North Report is lim/ted to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8610 >,,6,Pad 1D PGMS <0-8930 >,,5,Pad 1D PGMS <0-7502 >,,4,Pad 1D PGMS <0-8070 ),,3,Pad 1D PGMS <0-9783 >,,2,Pad 1D P~MS <0-8365 >,,1,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <381-6092'>,,CT,Pad 1D PMSS <0-5126'>,,D6,Pad 1D PMSS <0-4850'>,,D4,Pad 1D PMSS <0-5047'>,,G3,Pad 1D PMSS <0-5205'>,,ET,Pad 1D PMSS <0-5142'>,,E3,Pad 1D PMSS <O-4590'>,,ES,Pad 1D PMSS <0-4515'>,,F4,Pad 1D PMSS <0-4530'>,,F6,Pad 1D PMSS <O-4414'>,,G5,Pad 1D PMSS <O-5462'>,,J3,Pad 1D PMSS <0-4778'>,,H4,Pad 1D PMSS <O-5015'>,,G?,Pad 1D PMSS <1957-5265'>,,JS,Pad 1D TOTCO Survey,,WS-8,Ped 1D WS 1D-126/J1 Vets. #3,,J1,Pad 1D WS 1D-125/H2 Vets, #3,,H2,Pad 1D WS 1D-123/G1 Vets. #3,,Gl,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 13-Nov-9? 194.2 325.0 2240.0 13-Nov-97 314.5 300.0 2060.0 4-Aug-92 434.8 300.0 300.0 4-Aug-92 555.0 20.0 325.0 4-Aug-92 674.9 300.0 300.0 1~-Dec-97 795.0 300.0 300.0 6-Nov-9? 75.0 300.0 300.0 2?-Jan-98 691.5 300.0 300.0 19-Jan-98 662.0 120.0 120.0 12-Jan-98 617.0 100.0 100.0 6-Jan-98 287.0 100.0 100.0 7-Jan-98 467.0 120.0 120.0 30-Dec-9? 497.0 180.0 180.0 22-Dec-97 451.7 300.0 300.0 16-Dec-97 407.0 100.0 100.0 19-Dec-97 392.0 100.0 100.0 8-Dec-9? 3??.0 100.0 100.0 1-Dec-9? 167.0 120.0 120.0 9-Nov-9? 152.0 120.0 120.0 13-Nov-9? 32.0 300.0 2360.0 24-Nov-9? 107.0 120.0 120.0 10-Feb-98 39.9 575.0 575.0 26-Jan-98 255.0 300.0 4800.0 26-Jan-98 2?0.0 300.0 4960.0 26-Jan-98 345.0 280.0 4960.0 WS 1D-122/F2 WS 1D-116/E1 WS 1D- 114/D2 WS 1D- 113/C1 WM 1D- llg./A1 WS 1D- 111/B2 WS 1D- 110/C3 WS 1D- 108/A3 WS 1D- 10~/A7 WS 1D- 103/B6 WS 1D- 102/A5 WS 1D- 101/C5 Vets. ,F2,Pad 1D Vets. #~;,E1,Pad 1D Vets. #3,,D2,Pad 1D Vets. #3,,C1,Pad 1D Vets. #3,~A1,Pad 1D vers #3,,B2,Pad 1D Vets #3,,C3,Pad 1D Vets #3,,A3,Pad 1D Vets #3,,A?,Pad 1D Vets #3,,B6,Pad 1D Vets #3,,AS,Pad 1D Vets #3,,CS,Pad 1D 26-Jan-98 26 -Jan- 98 26-Jan-98 22-Jan-98 22 -Jan- 98 22-Jan-98 22 -Jan- 98 22-Jan-98 21-Jan-98 21-Jan-98 21-Jan-98 21- Jan- 98 360 480 510 525 540 585 600 630 '705 '720 735 '750 300.0 260.0 300.0 260.0 300.0 300.0 300.0 280.0 300.0 300.0 300.0 5520.0 7301.6 260.0 300.0 260.0 300.0 300.0 5620.0 280.0 300.0 300.0 5380.0 Rood ~//-I C,P,F. 1 ,,~, / ~?""""'~"--'~,~"h.._.- 9 LANE D.S. 1-D \ '%.) "h SAK~I ~r- _--~-"" ,o~ 2 ~ L4~ (~ THIS ,o~.~ .~ ~ 5- ~ su/~vE~""""~,~ ~ 14._~ 3 \ ~ 6 ,~ '- VICINITY MAP 1~7 ~ SCALE: I" = I MILE 9 ~.I 119 Lu 120~I · 121 (D 124 g -- 1.30 ~ 1,35 e lO LEGEND SEE SHEET # 2 FOR NOTES AND LOCATION INFORMATION o EXlSTINO CONDUCTORS ~ LOU!NSBURY · NEW CONDUCTOR LOCATION ~'/',1,~_ & A$$OCIAT]~$. INC. AREA · 1D MODULE XX UNIT · D1 ~ DRILL SITE 1-9 ARCO Alaska, Inc. ~r WELL CONDUCTORS 9 & 10 AS-STAKED LK6104D12 2/27/98 NSK 6.104-d12 1 OF 2 0 REVI DATE BY CK APP . DESCRIPTION B',. i CK APP DESCRIPTION ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN P'l/ (.;~__________.~ (.( '~0 L ~'/'~' S~ ' SEA LEVEL ALL DISTANCES SHOWN ARE TRUE "~9 ~'F"LARE~' (") '~ '¥2 (,r" ]'-'-'~ 2. BASIS OF ~OCATIONS AND ELEVATIONS ARE D.;. 1-D MONUMENTS PER LHD AND ASSOCIATES. ,3. CONDUCTORS ARE LOCATED ~ITHIN PROTRACTED SECTION 5. DRILL SITE 1-D GRID NORTH IS ROTATED 00' 0" 05" ×, ~ /,:~_~__ ~ SA~- ~'-7'~ mST FROM A.S.P. ZONE 4 GRID NORTH. ~'-~ OF CONDUCTORS ,t/1 THROUGH ,//8. 21 VICINITY MAP SCALE: 1" = I MILE Sec. 25, T. 11 N., R. IO E. SEC. SEC. PAD O. G. WelI A.S.P.s LA TITUDE LONGITUDE LINE LINE No. 'Y' 'X' O/'S O/'S ELEV. ELEV. F.N.L.F.E.L. 9 5,959,528.9 560,490.7 70' 17' 59.98" 149' .30' ,:76.52" 156' 598' 70.4' 66.0' 10 5,959,109.0 560,490.8 70' 17' 55.85" 149' ,,~0' 36.42" 556' 601' 70.5' 69.4' LOUNSBURY & ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS AREA: 1D MODULE: XX UNIT: D1 ~, DRILL SITE 1-g ARCO Alaska, Inc. WELL CONDUCTORS 9 & 10 AS-STAKED LK6104D12 2/27/98 NSK 6.104-d12 2 OF 2 0 , 6 , > 13 5/8" 5000 PSi BOP STACK ACCUMULATOR CAPACITY 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 BOP STACK TEST 4 > 1. 16' - 2000 PS! STARTING HEAD P_ 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI VARIABLE PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSl DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PS1 ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE UNES. 7. TESTTO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WiTH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TESTTO 5000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12_ TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH · KUPARUK RIVER.s=.., ,IT. 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER --AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES· . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WF_LLRORE FLUIDS OR GAS I$ DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC?.5.035(b) 1. 16'CONDUCTOR. 2. SLIP~DN WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20' - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINF_ THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PS! ANNULAR PREVENTER. 0KI= 1 · WELL PERMIT CHECKLIST COMPANY f~r I~(.,, 0 WELL NAME FIELD&POOL /-~ °1, O|~O INIT CLASS D~/ '~~ I~ i /-..- ADMINISTRATION .,R DATE '~ [~) -- '~ C) PROGRAM: exp FI dev,~ redrll [] serv [] wellbore seg ~- ann. disposal para req~ GEOL AREA. I~ ¢/0 UNIT# I I I (,¢ ~ ON/OFF SHORE 0 v'L REMARKS 1. Permitfeeattached ..................... (~ .2. Lease number appropriate ................... 3. Unique well name and number .................. (~ N 4. Well located in a defined pool ................. (~ N 5. Well located proper distance from drilling unit boundary .... C~ N 6. Well located proper distance from other wells .......... (~ N 7. Sufficient acreage available in drilling unit ......... (~ N 8. If deviated, is wellbore plat included ........... ~ N 9. Operator only affected party ............... ~ N 10. Operator has appropriate bond in force ............ C,~ N 11 Permit can be issued without conservation order ....... '~ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N ENGINEERING DATE DATE 14. 15. 16. 17. 18. 19. 20. 21 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................. (~ N Surface casing protects all known USDWs ........... ,~,, _ . CMT vol adequate to tie-in long string to surf csg ........ ('~~ ~'~'~ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... (..~N Adequate tankage or reserve pit ................. (,~N · If a re-drill, has a 10-403 for abandonment been approved... Y N Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate .... (~¢) N ' ~__~?.4,-~ '" ' ..... ROPEs, do they meet regulation .... ~ .... ,,, ....... ¢ ~, ,,,~_/ad'¢,_-"~'¢_ _;_ ~ ._~,t~-¢-'~~.¢~¢~_ _._"~6_~_..__~..~.~ ROPE press rating appropriate; test to -'~'~,/~--(::r'~:~sig. 2 .... -' /' "- Choke manifold complies w/API RP-53 (May 84) ..... '... Work will occur without operation shutdown ........... )N .,,,, ! Is presence of H2S gas probable ................. (. N 30. Permit can be issued w/o hydrogen sulfide measures. . . ~.~.~--N"'"'"- 31. Data presented on potential overpressure zones~./ Y N 32. Seismic analysis of shallo.wgasz~ ........ .Y..N 33. Seabed conditi~hore) ............. ~ .N 34. contac one for we,eklyprogress reports ....... Y N lexploratory only] GEOLOGY: ENGINEERING: COMMISSION: ......... /. JDH__ RNC~ ~,,~ ~ co Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Apr 28 12:11:46 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-80176 S. BURKHARDT D. BREEDEN iD-10 500292287000 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 28-APR-98 MWD RUN 3 AK-MM- 80176 M. GABEL D. BREEDEN 23 liN 10E 588 601 .00 111.60 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 12.250 9.625 4776.0 3RD STRING 8.500 7.000 7027.0 PRODUCTION STRING 6.125 7340.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 4. MWD RUN 3 IS DIRECTIONAL, DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), STABILIZED LITHO DENSITY (SLD), AND COMPENSATED NEUTRON POROSITY (CNP). 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7340'MD, 6633'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED CONVENTIONAL BULK DENSITY (COMPENSATED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL FACTORS USED IN PROCESSING NEUTRON DATA: HOLE SIZE: 6.125" MUD WEIGHT: 12.00 TO 12.8 LBS/GAL. MUD FILTRATE SALINITY: 700 PPM CL. FORMATION WATER SALINITY: 11,500 PPM CL. MATRIX: SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR ROP FCNT NCNT NPHI PEF FET RPD RPM RPS RPX DRHO RHOB $ START 4750 4792 6943 6943 6943 0 6966 0 7O0O 5 7000 5 7000.5 7000.5 7000.5 7025.5 7025.5 DEPTH .0 .5 0 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4750 0 7028 5 7030 0 7030 5 7035 0 7045 0 7046.5 7068.5 7085.5 7086.0 7102.0 7144 5 7148 0 7150 5 7163 0 7164 5 7166 5 7178 0 7185.5 7228.5 7238 0 7243 5 7247 5 7251 5 7258 5 7339 0 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: GR 4752. 7031. 7032 7032 7037 7045 7046 7069 7087 7088 7104 7147 7150 7152 7164 7165 7167 7180 7187 7231 7238 7244 7248 7252 7259 7340 STOP DEPTH 7300.0 7339.0 7248.0 7248.0 7248.0 7264.0 7307.0 7307.0 7307.0 7307.0 7307.0 7264.0 7264.0 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 4793.0 7037.0 3 7037.0 7340.4 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 DRHO MWD G/CC 4 1 68 RHOB MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 4750 7339 6044.5 ROP 5.271 655.017 194.718 GR 33.5923 508.392 133.394 RPX 1.2091 2000 11.3823 RPS 1.1603 2000 14.8191 RPM 0.4301 2000 115.928 RPD 0.8605 2000 118.989 FET 0.6731 51.8065 7.72285 NPHI 17.54 81.46 36.0426 NCNT 690.596 1580.02 1083.58 FCNT 3.328 25.048 11.7962 DRHO -0.169 0.4348 0.0575957 RHOB 1.7923 3.0885 2.39482 PEF 3.8236 19.2314 9.36635 Nsam 5179 5094 5101 614 614 614 614 614 611 611 611 478 478 597 First Reading 4750 4792.5 4750 7000.5 7000.5 700O.5 7000.5 7000.5 6943 6943 6943 7025.5 7025.5 6966 Last Reading 7339 7339 7300 7307 7307 7307 7307 7307 7248 7248 7248 7264 7264 7264 First Reading For Entire File .......... 4750 Last Reading For Entire File ........... 7339 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4752 . 5 6992 . 0 ROP 4795 . 0 7034.5 $ LOG HEADER DATA DATE LOGGED: 06-APR- 98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 7037.0 TOP LOG INTERVAL (FT) : 4793.0 BOTTOM LOG INTERVAL (FT) : 7037.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 25.5 MAXIMUM ANGLE: 28.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER P0988CG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 182.70 48.0 10.3 700 6.8 .000 .000 .000 .000 50.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4752.5 7034.5 5893.5 4565 4752.5 GR 42.5018 508.392 140.094 4480 4752.5 ROP 11.9404 655.017 216.529 4480 4795 Last Reading 7034.5 6992 7034.5 First Reading For Entire File .......... 4752.5 Last Reading For Entire File ........... 7034.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 6945.5 NCNT 6945.5 NPHI 6945.5 PEF 6968.5 GR 6996.0 FET 7003.0 RPD ~7003.0 RPM 7003.0 RPS 7003.0 RPX 7003.0 DRHO 7028.0 RHOB 7028.0 ROP 7037.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: STOP DEPTH 7249.0 7249.0 7249.0 7265.0 7301.0 7308.0 7308.0 7308.0 7308.0 7308.0 7265.0 7265.0 7340.0 08-APR- 98 ISC 5.06 CIM 5.46 MEMORY 7340.4 7037.0 7340.4 24.2 24.2 TOOL NUMBER P0959SP4 P0959SP4 P0959SP4 P0959SP4 6.130 6.1 LSND 200.00 54.0 8.9 7OO 6.0 2.600 1.800 49.2 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.300 2.700 .4 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHFiM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 NPHI MWD 3 P.U. 4 1 68 RHOB MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 ROP MWD 3 FT/H 4 1 68 DRHO MWD 3 G/CC 4 1 68 NCNT MWD 3 CNTS 4 1 68 FCNT MWD 3 CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPX RPS RPM RPD FET NPHI RHOB PEF ROP DRHO NCNT FCNT Min 6945.5 33 5923 1 2091 1 1603 0 4301 0 8605 0 6731 17.54 1.7923 3.8236 5.271 -0.169 690.596 3.328 Max Mean Nsam 7340 7142.75 790 162.755 85.3298 611 2000 11.4231 611 2000 14.8797 611 2000 116.484 611 2000 119.56 611 51.8065 7.64317 611 81.46 36.0903 608 3.0885 2.39712 475 19.2314 9.31931 594 217.57 34.8057 607 0.4348 0.0591022 475 1580.02 1082.58 608 25.048 11.7805 608 First Reading 6945.5 6996 7003 7003 7003 7003 7003 6945.5 7028 6968.5 7037 7028 6945.5 6945.5 Last Reading 7340 7301 7308 7308 7308 7308 7308 7249 7265 7265 7340 7265 7249 7249 First Reading For Entire File .......... 6945.5 Last Reading For Entire File ........... 7340 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Apr 28 12:11:46 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-80176 S. BURKHARDT D. BREEDEN iD-10 500292287000 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 28-APR-98 MWD RUN 3 AK-MM-80176 M. GABEL D. BREEDEN 23 liN 10E 588 601 .00 111.60 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 12.250 9.625 4776.0 3RD STRING 8.500 7.000 7027.0 PRODUCTION STRING 6.125 7340.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR). 4. MWD RUN 3 IS DIRECTIONAL, DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), STABILIZED LITHO DENSITY (SLD), AND COMPENSATED NEUTRON POROSITY (CNP). 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7340'MD, 6633'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED CONVENTIONAL BULK DENSITY (COMPENSATED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL FACTORS USED IN PROCESSING NEUTRON DATA: HOLE SIZE: 6.125" MUD WEIGHT: 12.00 TO 12.8 LBS/GAL. MUD FILTRATE SALINITY: 700 PPM CL. FORMATION WATER SALINITY: 11,500 PPM CL. MATRIX: SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR ROP FCNT NCNT NPHI PEF FET RPD RPM RPS RPX DRHO RHOB $ START 4750. 4792. 6943. 6943 0 6943 0 6966 0 7000 5 70OO 5 70OO 5 7O0O 5 7OOO 5 7025.5 7025.5 DEPTH 0 5 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 4750.0 4752. 7028.5 7031 7030.0 7032 7030.5 7032 7035.0 7037 7045.0 7045 7046.5 7046 7068.5 7069 7085.5 7087 7086.0 7088 7102.0 7104 7144.5 7147 7148.0 7150 7150.5 7152 7163.0 7164 7164.5 7165 7166.5 7167 7178.0 7180 7185.5 7187 7228.5 7231 7238.0 7238 7243.5 7244 7247.5 7248 7251.5 7252 7258.5 7259 7339.0 7340 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 $ REMARKS: MERGED MAIN PASS. $ STOP DEPTH 7300.0 7339.0 7248.0 7248.0 7248.0 7264.0 7307.0 7307.0 7307.0 7307.0 7307.0 7264.0 7264.0 Data Format Specification Record EQUIVALENT UNSHIFTED DEPTH Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGE TOP MERGE BASE 4793.0 7037.0 7037.0 7340.4 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHNiM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 DRHO MWD G/CC 4 1 68 RHOB MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 4750 7339 6044.5 ROP 5.271 655.017 194.718 GR 33.5923 508.392 133.394 RPX 1.2091 2000 11.3823 RPS 1.1603 2000 14.8191 RPM 0.4301 2000 115.928 RPD 0.8605 2000 118.989 FET 0.6731 51.8065 7.72285 NPHI 17.54 81.46 36.0426 NCNT 690.596 1580.02 1083.58 FCNT 3.328 25.048 11.7962 DRHO -0.169 0.4348 0.0575957 RHOB 1.7923 3.0885 2.39482 PEF 3.8236 19.2314 9.36635 Nsam 5179 5094 5101 614 614 614 614 614 611 611 611 478 478 597 First Reading 4750 4792.5 4750 7000.5 7000.5 7000.5 70O0.5 70O0.5 6943 6943 6943 7025.5 7025.5 6966 Last Reading 7339 7339 7300 7307 7307 7307 7307 7307 7248 7248 7248 7264 7264 7264 First Reading For Entire File .......... 4750 Last Reading For Entire File ........... 7339 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Next File' Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4752 . 5 6992 . 0 ROP 4795 . 0 7034.5 $ LOG HEADER DATA DATE LOGGED: 06-APR- 98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7037.0 TOP LOG INTERVAL (FT) : 4793.0 BOTTOM LOG INTERVAL (FT): 7037.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.5 MAXIMUM ANGLE: 28.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER P0988CG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 182.70 48.0 10.3 7OO 6.8 .000 .000 .000 .000 50.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4752.5 7034.5 5893.5 4565 4752.5 GR 42.5018 508.392 140.094 4480 4752.5 ROP 11.9404 655.017 216.529 4480 4795 Last Reading 7034.5 6992 7034.5 First Reading For Entire File .......... 4752.5 Last Reading For Entire File ........... 7034.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT NCNT NPHI PEF GR FET RPD RPM RPS RPX DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 6945 5 6945 5 6945 5 6968 5 6996 0 7003 0 7003 0 7003 0 7003 0 7003 0 7028 0 7028 0 7037 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7249.0 7249.0 7249.0 7265.0 7301.0 7308.0 7308.0 7308.0 7308.0 7308.0 7265.0 7265.0 7340.0 08-APR-98 ISC 5.06 CIM 5.46 MEMORY 7340.4 7037.0 7340.4 24.2 24.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ TOOL NUMBER P0959SP4 P0959SP4 P0959SP4 P0959SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.130 6.1 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: LSND 200.00 54.0 8.9 7O0 6.0 2.600 1.800 49.2 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.300 2.700 .4 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 NPHI MWD 3 P.U. 4 1 68 RHOB MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 ROP MWD 3 FT/H 4 1 68 DRHO MWD 3 G/CC 4 1 68 NCNT MWD 3 CNTS 4 1 68 FCNT MWD 3 CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 6945.5 7340 7142.75 GR 33.5923 162.755 85.3298 RPX 1.2091 2000 11.4231 RPS 1.1603 2000 14.8797 RPM 0.4301 2000 116.484 RPD 0.8605 2000 119.56 FET 0.6731 51.8065 7.64317 NPHI 17.54 81.46 36.0903 RHOB 1.7923 3.0885 2.39712 PEF 3.8236 19.2314 9.31931 ROP 5.271 217.57 34.8057 DRHO -0.169 0.4348 0.0591022 NCNT 690.596 1580.02 1082.58 FCNT 3.328 25.048 11.7805 First Last Nsam Reading Reading 790 6945.5 7340 611 6996 7301 611 7003 7308 611 7003 7308 611 7003 7308 611 7003 7308 611 7003 7308 608 6945.5 7249 475 7028 7265 594 6968.5 7265 607 7037 7340 475 7028 7265 608 6945.5 7249 608 6945.5 7249 First Reading For Entire File .......... 6945.5 Last Reading For Entire File ........... 7340 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/04/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
