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199-031
Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 6-Dec-20 0 1 2 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 7-Dec-20 0 1 3 1C-25 50-029-22941-00 906866139 Kuparuk River Packer Setting Record Field- Final 15-Dec-20 0 1 4 1H-108B 50-029-23608-02 906811421 Kuparuk River Water Flow Record Field- Final 12-Nov-20 0 1 5 1H-109 50-029-23595-00 906810847 Kuparuk River Injection Profile Field & Processed 14-Nov-20 0 1 6 1H-111 50-02923581-00 906831134 Kuparuk River Injection Profile Field & Processed 21-Nov-20 0 1 7 1H-115 50-029-23605-00 906832402 Kuparuk River Injection Profile Field & Processed 23-Nov-20 0 1 8 1H-117 50-029-23602-00 906810277 Kuparuk River Injection Profile Field & Processed 20-Nov-20 0 1 9 1J-118 50-029-23337-00 906798402 Kuparuk River Plug Setting Record Field- Final 1-Nov-20 0 1 10 1Y-19 50-029-22391-00 906849383 Kuparuk River Leak Detect Log Field- Final 7-Dec-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the 01/08/2021 01/11/2021 Abby Bell PTD: 1990310 E-Set: 34539 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Thursday, December 31, 2020 P.I. Supervisor] l� , 1 ZI�� SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1C-25 FROM: Lou Laubenstein KUPARUK RIV UNIT 1 C-25 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry LBP - NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IC -25 Insp Num: mitl,OL201230120540 Rel Insp Num: API Well Number 50-029-22941-00-00 Inspector Name: Lou Laubenstein Permit Number: 199-031-0 Inspection Date: 12/30/2020 Thursday, December 31, 2020 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well lc -2s 'Type J Type In -- !!TVD — 6213 Tubing 2597 2597 2597 +�-- 2597 {' - PTD 1 1990310 - a Test SPT SPT L TBSt pSll L553 j 1064 - 1810 1790 1785 a - � BBL Pumped: --,T 0.8 BBL Returned: 0.8 ~' QA 41010 -- 501 L 498 497 -- Interval - - - OTHER �pIF - - - Notes: MIT -IA post patch per Sundry # 320-496 Thursday, December 31, 2020 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-25 KUPARUK RIV UNIT 1C-25 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-25 50-029-22941-00-00 199-031-0 W SPT 6213 1990310 1553 2521 2528 2510 2504 294 414 409 404 4YRTST P Austin McLeod 5/15/2022 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 1C-25 Inspection Date: Tubing OA Packer Depth 875 1810 1775 1760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220515190316 BBL Pumped:1.2 BBL Returned:1.1 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. 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5HTXLUHGE\9DULDQFH , ,QFRQFOXVLYH , ,QGXVWULDO:DVWHZDWHU 2 2WKHU GHVFULEHLQQRWHV 1 1RW,QMHFWLQJ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 MMec h an i c al Int egr i t y Tes t MLPUHJJ#DODVNDJRY $2*&&,QVSHFWRUV#DODVNDJRY SKRHEHEURRNV#DODVNDJRY FKULVZDOODFH#DODVNDJRY 1RWHV 0,7,$SRVWSDWFKSHU6XQGU\ 1RWHV & 1RWHV 1RWHV 1RWHV &RQRFR3KLOOLSV$ODVND,QF .XSDUXN.58&3DG /RX/DXEHQVWHLQ 9DQ&DPS+HPEUHH )RUP 5HYLVHG 0,7.58&[OV[ 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: Stratigraphic Service 6.API Number: 7.If perforating:8.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10140'3337 psi N/A Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:11/22/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity & Compliance Specialist Jan Byrne / Dusty Freeborn n1617@conocophillips.com 9656 115'115' 9570' 115'16" 9.625" 7" 6473' Length TVD Burst 9452 MD 4554' 6306 6567' 6649'10039' PRESENT WELL CONDITION SUMMARY 6587'9410' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028242 199-031 P.O. Box 100630, Anchorage, Alaska 99508 50029229410000 ConocoPhillips Alaska, Inc. KRU 1C-25 Kuparuk River/Kuparuk River Oil Other: Tubing patch COMMISSION USE ONLY Authorized Name: N/A Tubing Grade:Tubing MD (ft): 6437'-6458', 6464'-6470', 6544'-6556' Perforation Depth TVD (ft):Tubing Size: 9788'-9824', 9834'-9844', 9967'- 9987' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7224 Baker 80-40 Seal Assembly N/A 9422' MD & 6216' TVD N/A Size Authorized Signature: 11/25/2020 3.5" Perforation Depth MD (ft): L-80 m n P 1 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:07 am, Nov 23, 2020 320-496 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-11-22 19:32:17 Foxit PhantomPDF Version: 10.0.0 Dusty Freeborn X X DLB 11/23/2020 N/A DLB DSR-11/23/2020VTL 11/25/20 ; ADL0025649 DLB 10-404 X Comm.Comm.Co 11/25/2020 dts 11/25/2020 JLC 11/25/2020 RBDMS HEW 11/25/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 22 November 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1C-25 (PTD 199-031) to set a retrievable tubing patch over the known tubing leak at 7227’ to regain tubing by inner annulus integrity. Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-11-22 19:31:24 Foxit PhantomPDF Version: 10.0.0 Dusty Freeborn KRU 1C-25 (PTD# 199-031) Description Summary of Proposal Well Work Justification & Objectives: A leak detect log was ran on 1C-25 which identified a tubing leak at 7227'. A tubing patch needs to be set to regain tubing and IA integrity. Steps: DSL. 1. Have jumper line hooked from IA to available flow line. 2. Set catcher on CA-2 plug at 9410'. 3. Pull dummy valve from station #6 (9392'). 4. Pump 275 bbls of 1% CRW CISW followed by 75 bbls of diesel down tubing taking returns up IA. U-tube to freeze protect T & IA. 5. Install dummy valve into station #6. If dummy valve set is questionable, pump down IA and run spinner to verify no flow into tubing. 6. Pull catcher from 9410'. 7. Drift for 20' patch. 8. Pull CA-2 plug from 9410'. 9. Set lower P2P mid-element at 7240' (~3' below collar at 7237'). 10. Set test tool in lower P2P and perform CMIT-TxIA to 3000 psi. Record initial, 15 min and 30 min pressures. A. If CMIT-TxIA passes, pull test tool and proceed to step 11. B. If CMIT-TxIA fails, trouble shoot failure mechanism. 11. Set anchor latch, spacer pipe and upper P2P mid-element at 7220' 12. Perform MIT-IA to 3000 psi. Record initial, 15 min and 30 min pressures. A. If MIT-IA passes, turn well over to operations to be BOI. DHD will schedule AOGCC witnessed test once IA is stable. B. If MIT-IA fails, trouble shoot failure mechanism. schedule AOGCC witnessed test once IA is stable. Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag:lmosbor 1C-25L1 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Leak Detect Log 11/14/2020 famaj 1C-25 Notes: General & Safety End Date 12/5/2006 Annotation NOTE: 1C-25L1 LINER STUCK @ ~10,500' TD, LINER TOP CHEMICAL CUT @ 9775' Wellbore 1C-25L1 End Date 12/5/2006 Annotation NOTE: MULTI-LATERAL WELL - 1C-25 & 1C-25L1 (BOTH C-SANDS) Wellbore 1C-25 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 35.0 115.0 115.0 62.58 H-40 WELDED 1C-25 SURFACE 9 5/8 8.70 34.6 6,567.3 4,553.8 40.00 L-80 BTC-MOD 1C-25 PRODUCTION 7 6.28 37.9 9,570.0 6,305.5 26.00 L-80 BTC-MOD 1C-25 LINER 3 1/2 2.99 9,416.5 10,138.0 6,647.6 9.30 L-80 EUE8rdMO D 1C-25 WINDOW 3 1/2 2.99 9,765.0 9,775.0 6,428.8 1C-25 LINER L1 2 3/8 2.00 9,775.0 10,487.3 6,461.4 4.70 L-80 STL 1C-25L1 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 3 1/2 2.99 30.0 9,452.3 6,234.6 9.30 L-80 EUE8rdMOD 1C-25 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 30.0 30.0 0.07 HANGER FMC GEN IV TUBING HANGER 3.500 1C-25 501.9 501.8 1.63 NIPPLE CAMCO 'DS' NIPPLE 2.875 1C-25 9,410.0 6,209.2 53.24 NIPPLE CAMCO 'D' NIPPLE NO GO PROFILE 2.750 1C-25 9,421.9 6,216.3 53.21 SEAL ASSY BAKER 80-40 CSG SEAL ASSEMBLY 3.000 1C-25 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 7,227.0 4,941.3 53.66 Tubing Leak Tubing leak at 7227' identified with LeakPoint tool. 11/14/2020 2.992 1C-25 9,410.0 6,209.2 53.24 2.75" CA-2 PLUG 2.75" CA-2 PLUG (29" OAL) 10/23/2020 0.000 1C-25 9,793.0 6,439.6 53.09 WHIPSTOCK BAKER GEN II MONOBORE FLOW-THRU WHIPSTOCK 11/12/2006 1C-25 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 34.6 34.6 0.09 HANGER 8.697 1C-25 35.0 35.0 0.09 CONDUCTOR 15.062 1C-25 36.6 36.6 0.09 SURFACE 8.697 1C-25 37.9 37.9 0.09 PRODUCTION 6.276 1C-25 1,002.9 994.2 16.45 PORT COLLAR 8.697 1C-25 1,005.9 997.2 16.53 SURFACE 8.697 1C-25 6,484.2 4,504.6 53.96 SURFACE 8.697 1C-25 9,416.5 6,213.1 53.22 PACKER BAKER ZXP LINER TOP PACKER 5.000 1C-25 9,430.3 6,221.4 53.18 HANGER BAKER HMC LINER HANGER 3.500 1C-25 9,437.0 6,225.4 53.15 SBE BAKER 80-40 SBE 3.500 1C-25 9,484.3 6,253.9 52.91 PRODUCTION 6.276 1C-25 9,765.0 6,422.7 53.01 WINDOW 2.992 1C-25 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 9,775.0 10,454.0 6,428.8 6,462.1 C-4, C-3, C-4, 1C -25L1 12/5/2006 40.0 SLOTS slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 1C-25L1 9,788.0 9,824.0 6,436.6 6,458.2 C-4, 1C-25 8/27/1999 4.0 IPERF 2.5 HC, DP, 180 deg. ph 1C-25 9,834.0 9,844.0 6,464.1 6,470.1 C-4, 1C-25 8/27/1999 10.0 IPERF 2.5 HC, DP, 180 deg. ph 1C-25 9,967.0 9,987.0 6,543.5 6,555.5 C-1, 1C-25 5/16/2006 6.0 APERF 2" 2006 PJ Omega Charges 1C-25 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 3,230.3 2,612.3 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 4/11/2007 1C-25 2 5,166.4 3,733.9 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 4/11/2007 1C-25 3 6,594.3 4,569.9 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 4/11/2007 1C-25 4 7,775.5 5,262.0 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 4/12/2007 1C-25 5 8,615.6 5,748.6 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 11/9/2006 1C-25 6 9,391.6 6,198.2 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/11/2006 1C-25 Stimulation Intervals Start Date Proppant Designed (lb) Proppant In Formation (lb) 11/9/2002 00:00 Frac Summary Stg # Start Date Top (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1 11/9/2002 9,788.0 9,844.0 Comment SSSV: NIPPLE 1C-25, 11/15/2020 8:52:46 AM Vertical schematic (actual) LINER; 9,416.5-10,138.0 APERF; 9,967.0-9,987.0 IPERF; 9,834.0-9,844.0 FRAC; 9,788.0 IPERF; 9,788.0-9,824.0 WHIPSTOCK; 9,793.0 LINER L1; 9,775.0- 10,487.3 SLOTS; 9,775.0-10,454.0 WINDOW; 9,765.0- 9,775.0 PRODUCTION; 37.9- 9,570.0 2.75" CA-2 PLUG; 9,410.0 GAS LIFT; 9,391.6 GAS LIFT; 8,615.6 GAS LIFT; 7,775.5 Tubing Leak; 7,227.0 GAS LIFT; 6,594.3 SURFACE; 34.6-6,567.3 GAS LIFT; 5,166.4 GAS LIFT; 3,230.3 NIPPLE; 501.9 CONDUCTOR; 35.0- 115.0 KUP INJ KB-Grd (ft) 39.16 Rig Release Date 4/28/1999 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 10,140.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294100 Wellbore Status INJ Max Angle & MD Incl (°) 56.41 MD (ftKB) 4,002.46 Legal Wellname 1C-25 Common Wellname1C-25 AK All Wellbores Schem K https://readcasedhole-my.sharepoint.com/personal/diane_williams_readcasedhole_com/Documents/D Drive/Achives/MasterTemplateFiles/Templates/Distribution/TransmittalSheets/ConocoPhillips_Transmit.docx Well Log Transmittal To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 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 : READ Cased Hole, Inc. Attn: Diane Williams 4141 B Street Suite 308 Anchorage, AK 99503 Diane.Williams@readcasedhole.com 1) Caliper Survey 14-Nov-20 1C-25 Upload 50-029-22941-00 2) Signed : ______________________________________ Date : ___________________ Print Name: ______________________________________ READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-ANCHORAGE@READCASEDHOLE.COM WEBSITE : WWW.READCASEDHOLE.COM Received by the AOGCC 11/19/2020 PTD: 1990310 E-Set: 34289 Abby Bell Abby Bell 11/23/2020 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Thursday, October 22, 2020 2:50 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: Kuparuk Injector 1C-25 (PTD# 199-031) reported of unexplainable IA pressure increase. Attachments: 1C-25.pdf; 1C-25 90 day TIO plot.pdf Chris- Kuparuk Injector 1C-25 (PTD# 199-031) was reported by operations with a sudden unexplainable IA pressure increase. The operator attempted to bleed the IA, however the IA continued to rebuild pressure after the bleeds were completed. To prevent the loss of the IA freeze protect, the IA bleeds were discontinued which caused the IA to exceeded the DNE of 2000 psi. Operations shut the well in and it appears the IA has stabilized with the tubing pressure around 2100 psi. The well is equipped with 7", 261b, L-80 which has an internal yield rating of 7240 psi. CPAI intends to secure the well with a down hole plug and initiate the first set of diagnostics to identify the pressure source of the recharging IA. Once the failure mechanism has been identified the proper paperwork for continued injection or repair will be submitted at that time. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Conoco-Ftops • MEMORANDA State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,May 16,2018 P.I.Supervisor I£LL Cit "*-1713 C`f3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-25 FROM: Austin McLeod KUPARUK RIV UNIT 1C-25 Petroleum Inspector Src: Inspector Reviewed Bye P.I.Supry ,I19 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IC-25 API Well Number 50-029-22941-00-00 Inspector Name: Austin McLeod Permit Number: 199-031-0 Inspection Date: 5/13/2018 Insp Num: mitSAM180514082055 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well , 1C-25 ;Type Inj w ';TVD t 6213 4Tubing 2377 2371 2375 2380 PTD 1990310 IType Test SPT Test psi 1553 IA 1140 1855 • 1825 ' 1820 BBL Pumped: I Os 0.8OA 352 435 432 ' 428 BBL Returned: Interval 4YRTST P/F P V Notes: MIT-IA SCANNED JUN 012018 Wednesday,May 16,2018 Page 1 of 1 • ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggc i I I I r(p DATE: Friday,January 08,2016 P.I.Supervisor ),,,e-�( I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-25 FROM: Jeff Jones KUPARUK RIV UNIT 1C-25 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Sae---- ' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-25 API Well Number 50-029-22941-00-00 Inspector Name: Jeff Jones Permit Number: 199-031-0 Inspection Date: 12/19/2015 Insp Num: mitJJ151221075142 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IC-25 Type Inj T W TVD 6213 Tubing 1760 - 1960 1760 1760 - r PTD 199031° ' Type Test SPT iTest psi 1553 IA 1100 2600 - 2540 2540 - Interval 4YRTST P/F P ✓ OA 480 650 660 660 - i Notes: I well inspected;no exceptions noted. SCANNEhl i Friday,January 08,2016 Page 1 of 1 • MEMORANDUM To: JimRegg `~ ~fZ,~~l~ ~~~~ P.1. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 C-25 KUPARUK RIV UNIT 1C-25 Sre: Inspector NnN-CnNFIDENTIAL Reviewed By: P.I. SuprvJgF? -- Comm Well Name: KUPARUK RIV UNIT 1C-25 API Well Number: 50-029-22941-00-00 Inspector Name: John Crisp Insp Num: mitJCr100524062043 Permit Number: 199-031-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Ic 2s Type InJ. c ~ TVD ~~ 6zI3 ~ ~IA I~ 873 -}-- --- --~~ -~ -- zzzo zl9o ~ ztso ' P.T.D~1990310~TypeTBSt~ Te$t pSl ~ 1553 ~ QA 325 49] i 488 i 484 p~F, P ~~ TUbin~ 3567 ~ Interval 4YRTST 3570 -3570 3568 _ _ Notes: 1.3 bbls pumped for test. ANSI 1500 flange installed on IA annulus valve. With the injection pressure at 3567 with the potential for thermal expansion having these low pressure flanges on the IA is not good industry practice. There are several ANSI 1500 flanges installed on West Sak IA's with no potential to exceed rated working pressure, the ANSI 1500 on gas injectors has potential to exceed working pressure. - 2e~~t~5~s ,~,~ ~~r ~ ~ ~~ZS~io - ~Gfti~-oQ Tuesday, May 25, 2010 Page 1 of 1 Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, June 25, 2010 2:17 PM ~~ ~~ZSllc K2~c ~ ~. - Zs l~(~~o3i To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: ANSI 1500 Flanges Inspectors have been finding ANSI 1500 flanges installed on the IA of some wells when out to witness MITs. The rated working pressure for these flanges is 3700psi. If I understand the situation correctly, the ANSI 1500 flange is installed on the IA and would either be directly exposed to test pressure approaching the rated working pressure, or could be exposed to excessive injection pressures in the case of TxIA communication (e.g., high injection pressures on gas injectors or via thermal expansion). During witnessed MITs in late May 2010, ANSI 1500 flaanges were found on West Sak gas injectors KRU 1 C-25 and 1C-27. In both occurances, CPAI was advised these are deficiencies. API defines the rated working pressure of equipment to be the maximum internal pressure that the equipment is designed to contain or control, and further notes that rated working pressure should not be confused with testing presssure (I read that to say it is inappropriate to justify operating equipment at pressure exceeding rated work pressure just because it was tested to the higher pressure). Exceeding the rated working pressure represents an inappropriate risk to field personnel attending to the wells. Inspectors have not been able to field verify if ANSI 1500 flanges have been hydrotested to proposed higher test pressure, and even if the flange was tested, we question how you would account for the history (exposure to extreme temps, harsh chemicals, corrosive fluids, etc.). We are interested in understanding CPAI's safe operating practices regarding ANSI 1500 flanges. We are also interested in reviewing any CPAI test policy that allows for the pressure rating of equipment to be exceeded. Other deficiencies noted during the KRU 1 C-pad inspections in late May: - Two instances of tree flange adapters made up to tubing spool without full engagement of the nuts on the studs (1 C-10, 1 C-15) - KRU 1 C-119 and 1 C-121 were noted to have mandrel hangers off seat from conductor casing; WAG injection lines were hanging from tree without support, placing the casings in a sideways bind. - KRU 1 C-174 was observed to have orifice meter wrapped in absorbent and an oily waste bag; use and condition of the orifice meter here needs to be explained. Please address these items. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 6/25/2010 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~ S~::~isor r:¿er1 S'/ ~ D 7 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-25 KUPARUK RIV UNIT 1C-25 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ÔBe- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IC-25 API Well Number: 50-029-22941-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070822053717 Permit Number: 199-031-0 Inspection Date: 8/21/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1C-25 Type Inj. w TVD 6213 ~ IA 720 3240 3200 3200 P.T. I~U.jJU TypeTest :srI Test psi 1553.25 OA 500 825 825 825 Interval INITAL /P/F P .../ Tubing 1500 1500 1500 1500 Notes: SCANNED SEP 1 0 2007 Wednesday, August 22, 2007 Page 1 of 1 1. Operations Performed: 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 94' / 8. Property Designation: %8 1..'fz- ,;/:, 1· 1.7. ø 7 ADL~LK 2292 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PRODUCTION LI C-SAND WINDOI l' Perforation depth: . . RECEIVED STATE OF ALASKA JUL 2 6 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Cammission Repair Well D Pull Tubing D Operat. ShutdownD ,¡ ProJt~ WAG ,/ Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development [2] Stratigraphic D Other Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D Service D 199-031 1 6. API Number: 50-029-22941-00 / 9. Well Name and Number: 1 C-25 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 10140' feet true vertical 6649' ./ feet measured 10039 feet true vertical 6587 feet Length Size MD 115' 16" 115' 6473' 9-5/8" 6567' 9656' 7" 9750' 722' 3-1/2" 10138' 2-7/8" 9796' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 4554' 6414' 6648' Measured depth: 9788'-9824'; 9834'-9844'; 9967-9987' true vertical depth: 6437'-6458'; 6464'-6470'; 6544'-6556' SCANNED AUG 0 3 2007 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9452' MD. Packers & SSSV (type & measured depth) PKR == Baker 7" x 5" ZXP L T PKR == 9416' SSSV== NIP SSSV== 502' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 712 237 8 931 295 Subsequent to operation 1805 979 75 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service [2] Daily Report of Well Operations _X 16. Well Status after proposed work: ouO GasO WAG [2] GlNJO WINJ 0 WDSPLO 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: 307-014 Contact Printed Nam/) Signature ~ RBDMS 8Fl AUG 0 1 2DD7 Title Phone 659-7535 Form 10-404 Revised 04/2004 ORIGINAL h . AÞ 7·Z-7.07 ~~h/~7 . . 1 C-25 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/23/07 Commenced WAG Injection . . RECEIVED APR 1 8 2007 Conoc~illips Alaska Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 16,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ~CA~NED APR 1 82007 Dear Mr. Maunder: ,\q~-Ö 31 5 \ &'" ð: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~Ä/~ M.J. Loveland ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 1 C-25 l~q~ItW . 9'4" 0.8 14" 4/14/2007 3.8 4/15/2007 1 C-119 ')Ã)1-139 25'6" 4.8 16" 4/14/2007 5.4 4/15/2007 1 C-121 201-080 11' 2.0 18" 4/8/2007 8.6 4/15/2007 1C-131 201-185 12' 1" 1.8 16" 418/2007 6.8 4/15/2007 1 C-135 201-220 11' 1.3 10" 418/2007 2.4 4/15/2007 1 C-172 203-095 10' 8" 1.5 18" 4/14/2007 6.6 4/15/2007 1 H-02 193-008 14' 6" 2.0 4/5/2007 3.3 4/15/2007 1 H-09 193-029 11" n/a 11" n/a 4.9 4/15/2007 1 H-17 192-130 20" n/a 20" n/a 7.5 4/15/2007 Kuparuk Field April 16,2007 . . SARAH PALIN, GOVERNOR A",A~1iA. OILAlÐ) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1C-25 Sundry Number: 307-014 SCANNED JAN 2 2 2007 Dear Mr. Christensen: 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, -0~-=' Dan T. Seamount Commissioner DATED this rt day of January, 2007 Encl. /C]D¡ -os 1 . ø k/f·,ø7 ~ RECEIVED STATE OF ALASKA l{\,\ ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 10 Z007 APPLICATION FOR SUNDRY APPROVAL . . 20 MC 25.280 Alaska Oil & Gas Cons. CommissIOn 1, Type of Request: Abandon 0 Suspend D Operational Shutdown D Perforate D Wa,ve, LJ Other [] Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Producer to Change approved program 0 D 0 Re-enter Suspended Well D Injector Pull Tubing Perforate New Pool Conversion 2, Operator Name: 4, Current Well Class: 5, Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory D 199-031 3: Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22941-00 ' 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 1 C-25 9. Property Designation: rtl>L. "2-1;/2--12,,41> /./þ.ø7 10. KB Elevation (ft): 11. Field/Pool(s): A~, ALK 2292 RKB 94' Kuparuk River Field / 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): 10140' 6649' - 10039' 6587' Casing Length Size MÐ TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 6473' 9-5/8" 6567' 4554' "- PRODUCTION 6414' :- 9656' 7" 9750' PRODUCTION LINER 722' 3-1/2" 10138' 6648' C-SAND WINDOW l' 2-7/8" 9796' 6441' . Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9788'-9824'; 9834'-9844'; 9967-9987' 6437'-6458'; 6464'-6470'; 6544'-6556' 3-1/2" ... L-80 9452' Packers and SSSV Type: Packers and SSSV MD (f!) PKR = Baker 7" x 5" ZXP L T PKR = 9416' SSSV= NIP SSSV= 502' 13. Attachments; Description Summary of Proposal [] 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch 0 Exploratory D Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 26, 2007 Oil D Gas 0 Plugged 0 Abandoned D 17. Verbal Approval: Date: [] . 0 0 WDSPL 0 WAG . GINJ WINJ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen / Bob Buchholz Printed NaVß Robert D. Chri9l:ensen . Title: production Engineering Technician Signature, F~ .cJ""'ç;} Phone 659-7535 Date I) II /~=¡- Commission Use Only , Sundry Number: 014- Conditions of approval: Notify Commission so that a representative may witness 301- Plug Integrity D BOP Test D Mechanical Integrity Test 'ÞZl Location Clearance D Other: RBDMS BFL JAN 2 2 2007 S"b",,"'"' Fom R'q"'''' ~ 'I Approved by: )-:\ J / APPROVED BY / /1 7 COMMISSIONER THE COMMISSION Date: Form 10~40j~læd OEft2006 VJR I GI N A I ~ . s~~~~ 1./ø~_(;>1 . . Ir ~ ? ( <;'\~ ~ !/t~\.,\\ . . 1 C-25 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to change the approved program for Kuparuk well 1 C-25 from Oil production to WAG EaR injection service. The conversion of well 1 C-25 will provide pressure support to off-set producer 1C-21 (568 BOPD and 598 FGOR) and is expected to allow 1C-21 to remain on-line full-time. 1C-25 was completed as a 3-1/2" Slimhole Oil producer on Apri/29, 1999. The targeted "C" sands were encountered between 9781' - 9989' md (6432' - 6557' tvd). A CTD "C" sand lateral (1C-25L 1) was completed on Dec. 05, 2006. The 1C-25 7" production casing Inner Annulus is isolated from the 3-1/2" tubing and 3-1/2" production casing utilizing a Baker 7" x 5" ZXP L T Packer at 9416' md (6213' tvd). A Baker GEN II Monobore Flow-thru Whipstock (1C-25L 1) is located a~d (6441' tvd). The 1 C-25L 1 lateral window is located at 9795' md (6441' tvd). A Cement Bond Log obtained on June 24, 2006 indicates good cement integrity from 9452' - 9792' md (6234' - 6439' tvd). The 9-5/8" Surface casing (6567' tvd /4554' tvd) was cemented with 790 sx AS III and 650 sx Class G. The 7" Production casing (9750' md / 6414' tvd) was cemented with 170 sx Class G. The 3-1/2" Production liner (10138' md /6648' tvd) was cemented with 260 sx Class G. Ò E ...J cô :?: ..:.:: 1L (I) .... r-- t1! ï:: r-- « ~ N (I) .... ('") ~ Q) ,.... OJ > a. ä: ...J :c Z c ..:.:: Z Q... º ëi5 ::J U. 0 të .... ('") If) () J:: t1! ('") C}J C Ü t::: C- o:> c: 0 ª CD Ü 0 9 z ..- ..- Ü J:: c: OJ 0 ::J ~ 0 :Q t1! .... () ã) 0 OJ ..9 u:: :?: Cement Bond Log SCMT-CB PBMS 24 June 2006 16833 FNL 13277 FWL at Surface Permanent Datum: Log Measured From: Drilling Measured From: API Serial No. 50-029-22941-00 24-Jun-2006 . 1 10034 ft 9954 ft 9948ft 9400 ft Seawater Depth Bottom Log Jf1ìerval Top Log Interval Casing Fluid Type Salinity Densit Fluid Level BIT/CASING/TUBING STRING. Bit Size From To Casing/Tubin Size Wei ht Grade From To Maximum Recorded Temperatures Logger On Bottom Time Unit Number Location Recorded B Witnessed B 8 Ibm/ al 8.000 in 3.500 in 9.3 Ibm/ft L-80 Oft 9452 ft MSL KB KB Section 12 24-Jun-2006 2128 Prudhoe Bay Hines Evan Reill Elev.: K.B. G.L. 60.2ft D.F. 94.2 ft Elev.: above Perm. Datum Township î1N Range 10E " ." . r-- .......... I-- Ir ..- r- - )') - - ~ ;;,. ~ J I-- ... I ,.. . lto ..... I - I I . f-- ) , ..- I-- --:: C ..~ ..... I> I-- ..... [( l- I L II W· II r-- '-- I, 97 ro II ~¡¡e.. ..... ¡;. I I' .t. ; · I ) , · -l ..... 1 , , - \ · \ :¡ ,.. /' ¡-- L-- I-- '.. ,- -:;; """ I '\.. , - , -- í' " - . , It - I-- I i-... . -, \ I ¡.;;:.;: I - ,..... .... ~... ;. .... ~ ro- It' '" , I',;'JI -, ......... '7 - 1- :-;:- - 'i\ L--- -. I-- ....- .- - . , ~1iJii- '. - - ~L --..... ..... -. ~ .- .- .- 98 ro ~ - ...... .. . . . ) ~-L :" I'-J 1./ '" <... - I..... 1""0 -- :-.;;: ... ...... -- ~ ( ....... ./ " / " - )' / ./ ..~.... ....;!!" IV . ~ '- - . .- .0 ~ .- .. -. .... .- 0- .. -' ¡-., / J r ~ , II - .. , "'" -- .. þ, . -.,. ConocoPhilJips Ala$ka~ Inc. TUBING (0-9452, OD:3.500, ID:2.992) SURFACE (0-6567, OD.9.625, Wt:40.00) 'RODUCTlON (0-9750, OD:7.000, Wt:26.00) Gas Lift MandrelNalve 3 (6594-6595, Gas Lift MandrelNalve 4 (7775-7776, NIP (9410-9411, OD:4.500) PACKER (9416-9417, OD:7.000) .::~:~., .,:~::. ~ ~ Whipstock ~ (9793-9798, ~ OD:4.000) Perf (9788-9824) FRAC (9788-9844) Perf (9834-9844) Perf - (9967-9987) - - - - Well Type: PROD Orig 4/28/1999 Completion: Annular Fluid: Last W /0: Reference LOQ: Ref LOQ Date: Last Tag: 9994 TD: 10140 ftKB Last TaQ Date: 10/12/2006 Max Hole AnQle: 56 deQ Cd! 4002 Øij$i6a$.biijóAAL;ÞQA$~Nß$.)· . Descrietion Size Top CONDUCTOR 16.000 0 SURFACE 9.625 0 PRODUCTION 7.000 0 PRODUCTION LINER 3.500 9416 C-SAND LINER TOP 2.375 9775 C-SAND WINDOW 3.000 9795 API: 500292294100 SSSV Type: Nipple Size 3.500 . KRU 1 C-25 Angle @ TS: 53 deg @ 9781 Angle @ TO: 52 deg @ 10140 Rev Reason: Add L T PKR Last Update: 1/8/2007 Bottom 115 6567 9750 10138 9796 9796 ........................ ........................ ........................ ........................ ........................ ........................ . . . . . . . . . . . . . . . . . . . . . . . . ....................... ..................... Thread WELDED BTC-MOD BTC-MOD EUE 8rd STL TVD 115 4554 6414 6648 6441 6441 Wt 62.58 40.00 26.00 9.30 4.70 0.00 Grade H-40 L-80 L-80 L-80 L-80 rhread EUE 8rd I 1 I Toe Bottom I TVD I Wt I Grade I o I 9452 1 6234 I 9.30 1 L-80 1 Interval TVD Zone 9788 - 9824 6437 - 6458 C-4 9834 - 9844 6464 - 6470 C-4 9967 - 9987 6544 - 6556 C-1 $tìfflMãtì¢)ßs:&Tteatments{··········· . Interval Date Type 9788 - 9844 I 11/9/2002 I FRAC Status Ft SPF 36 4 10 10 20 6 Date 8/27/1999 8/27/1999 5/16/2006 Type Comment IPERF 2.5 HC, DP, 180 deQ. ph IPERF 2.5 HC, DP, 180 deQ. ph APERF 2" 2006 PJ Omega CharQes I I Comment St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 1 3230 2612 CAMCO KBMM CAMCO GLV 1.0 BK 0.156 1392 12/8/2006 2 5166 3734 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1409 12/8/2006 3 6594 4570 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1390 12/8/2006 4 7775 5262 CAMCO KBMM CAMCO OV 1.0 BK 0.250 0 12/8/2006 5 8616 5749 CAMCO KBMM CAMCO DMY 1.0 BK 0,000 0 11/9/2006 6 9391 6198 CAMCO MMM CAMCO DMY 1,5 RK 0.000 0 1/11/2006 Deeth TVD Tyee Description ID 502 502 NIP CAMCO DS nipple 2.875 9410 6209 NIP CAMCO D nipple NO GO profile, ELMD @ 9413 ON SWS JEWELRY LOG 2.750 9/21/99 9416 6213 PACKER PRODUCTION LINER ZXP LINER TOP PACKER 1C-25 4.000 9422 6216 SEAL BAKER 80-40 casina seal assembly 3.000 9793 6440 Whipstock BAKER GEN If MONOBORE FLOW-THRU WHIPSTOCK- 0.000 Date Note 12/5/20061 NOTE: MULTI-LATERAL WELL - 1 C-25 & 1 C-25L1jC-SANDS)-1 C-24L1 DRLD 12/5/2006 x. ::::: . . ',,"> _.~ Casing Detail 3-1/2' Production liner WELL: 1C-25 DATE: 04/25/99 1 OF 1 PAGES ARCD Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EOUlPMENT RUN LENGTH DEPTH Pool 6 RT to LOS = 30.00' TOPS Top of liner Hanger @ 9416.49 Packer BAKER 7"x 5" ZXP lT PACKER 13.84 9416.49 Hanger BAKER 5" Butt HMC HANGER 6.68 9430.33 SBE BAKER 80·40 SBE 5" Butt Box X 3-112 EUE PIN 20.87 9437.01 PuP 3-1/2", 9.3#. 8 rd EUE Mod Pup 10.00 9457.88 Pup 3·112", 9.3#, 8 rd EUE Mod Pup 10.07 9467.88 Jts.4-21 3-1/2", 9.3#,8 rd EUE Mod Tubing (18 Jts.) 561.66 9477.95 Baker landing collar .89 10039.61 Jt.#3 3-112",9.3#,8 rd EUE Mod Tubing 62.76 10040.50 Gemeco Float Collar 1.16 10103.26 Jts. 1-2 3·1/2",9.3#, 8 rd EUE Mod Tubing 31.47 10104.42 Gemeco Float Shoe 2.11 10135.89 10138.00 21 Weatherford Spirolators Run Spirolators 1 per joint on its. # 1-21. Remarks: String Weights with Blocks: 185k Up, 125k Dn, 70k Blocks. Ran 21 joints of casing. Drifted casing with 2.867" plastic rabbit. Used Arctic Grade API Modified No lead thread compound on all connections. Casing is non·coated. Pool6 Df/7/ing Supervisor: Dave Burley / Rick Overstreet . . \<\ C\-G ~s \ dO~ '-lOO l-ŒCRANICAL INTEGRITY RE1?ORT -.... ?, .::. G 2. S :.. ::: ;'.::: ::: : OPER & FIELD ~~~~ -¡¿U NUMJ3ER \ \.. ';:) ç \L\. ) \O\:- --.J L - d S L'~ ¡ 5 ? U 0 G ,~, ;::: ' ÎÏ'\ CèSÜ~g: \ TD: MD TVD; ?BTD: !1D TVD Shoe: S~SO HD ()-\ \ ~, TVD¡ DV: MD ·IVu Shoe: lG \'~ß MD (. ~ ~ «; T~/1J ; ':-C? : HD --:~;'D -",sLL DATi-. _:':le::-: ~\(""':\ _ '.J D~" 2:: 3\1) P 2.CKe:!:" :":.ole S':'ze S \1) S~\ ~m <1~\l ~ TVD; ènò ~ \/'6 i PeI"£3 See ê.L S '1 ~ 'Îs -- " C\ ~ '<, \ I;--.. ~ '\ ~~n~cS.> LO . ~ \e:. \-\~ \. '\ ~ \' S. '\ c; (, - \D L-~Ss ~ :SC?.ÞJ.E C;..l.. INTEGRITY - P -'illI !l Annül~s Press Test: ~p 15 Gnn 30 IDln Couaents: ,/' Cemenc Volumes: ¡\..rut. 'î..iner , ~ L \ 5" ':. ~ ~ ~ \, \ <;. \to~~; Csg ; DV 0-\ ~ 'Z M.~ ~\ ~~CHÞ~IC;'~ INTEGRITY - PART 12 Cwt -';01 co cove:::- ?e:!:"': 5 ~ 30) c"4.). d ì b b'~ +r-J CLJ ~ <L (- ~ \-:\~ \> \ \oJ ~ ÇCO' -='-beorecical TOC ~~\ ""- \- \Nú<:::.C::\.\\..~\n..\-~ .ç.rn\V\ '\-~C2 \'; if'(r(' ~ Cement Bond Log (Yes '....j or No) \~S. In AOGCC File '\<ts ~ \lÇ;..~ (" (}~ ~~ ~\ I,~ J ~ eEL ~v2.1uation, zone èDove perfs ~<L \t::>~ \'~ <j ,,"OQ Production Log: 'Ivoe - - Evuluation CONCLUSIons: ? ar t t 1 : \J\ 1:: ,<, ., 0,'C..O.:~ ~1tv\ . .- p." 1\ S. '"()"""\ :J~_~ _ a.J... '- ;2: - , . . Review of Sundry Applications 307-014&015 ConocoPhillips Alaska, Inc. Wells Kuparuk River Unit 1C-25 & 1C-25L1 Kuparuk River Field, Kuparuk River Oil Pool AOGCC Permits 199-031 & 206-100 Requested Action: ConocoPhillips Alaska, Inc. (CP AI) proposes to convert an existing development wellbore and recently completed lateral to WAG injection. Recommendation: I recommend approval of CPA!' s proposed actions Discussion: CPAI proposes to convert welllC-25 and it's laterallC-25Ll from development oil status to WAG injection service. Both wellbores are completed in the Kuparuk 'C sand' and the conversion is intended to provide production support to other 'C sand development wells in the area. The original wellbore was completed and began production in September 1999 and the lateral was drilled and completed in December 2006. The pennit to drill application for the lateral indicated that the well was intended for conversion to a WAG injector upon its completion. To date the original wellbore has produced a total of 1.8 million barrels of oil and is still producing at over 500 barrels per day. There is no production data available for the lateral. In December 2004, the most recent available data, the bottomhole pressure was 1,750 psi at a depth of6,209' TVDSS. This is well below the original Kuparuk pressure of3,135 psi and the bubble point of2,600 psi. The pressure is also significantly less than that reported during 2005 for other 1 C producers, which ranged from 2,100 psi to almost 3,500 psi. The significant pressure difference between this well and the other producers on the pad indicates that the portion of the reservoir surrounding lC-25 and lC-25L is not receiving adequate pressure support. Therefore, converting this well to a WAG injector even though it is still capable of producing at a high rate should enhance ultimate recovery for this portion of the reservoir. .... , . . Conclusion: Converting these wells to WAG injection service should improve current operations in this portion of the pool. Therefore, it is prudent to authorize CP AI to perform their requested actions because of the future benefits that should be achieved. D.S. Roby ~ Reservoir Engineer January 11, 2007 RE: Direction Needed - Kuparuk 1 C-25 potential conversion to injection . . Tom - Attached is a Word document which contains my assessment of cement in we1l1C-25 as well as an evaluation of wells within one-quarter mile of the 1 C-25L 1 lateral. The only penetration within one-quarter mile of 1C-25L 1 is weIl1C-27. Also attached are cementing records for both 1C-25 and 1C-27. Please let me know if you need any more information to support our application to convert 1 C-25 to water injection. Gary Eller CPAI Wells Engineer -----Original Messagemn From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, January 11, 2007 11:16 AM To: Johnstone, Sam Cc: Eller, J Gary Subject: Re: Direction Needed - Kuparuk 1(-25 potential conversion to injection Sam and Gary, I am reviewing the sundries to convert these wells to injector. In my reply of April 24, I mentioned that there isn't much detailed cementing information available in our files and requested some more detailed info. I don't believe that I have received anything. I'd appreciate getting the necessary info so I can complete the assessment. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 4/24/2006 10:59 AM: Sam, I don't believe we have met. I don't see major problems with what you propose. When the sundry application is submitted for the conversion, after the production period, a request for the exception to the packer depth can be made at that time. Getting the bond log is an important step in the overall plan. I did a look at the file we have and there are no detailed cementing reports regarding the 7" intermediate/production casing or the liner. Having detailed operations reports is also part ofthe review. An assessment of any well within 1/4 mile of the trajectory of the lateral will also need to be done. If the fault isolation is as you say, then the only well of concern would likely be 1 C-21. I suggest that you contact Pat Riley in drilling for some "assistance" on these requirements. He recently submitted a permit package for an injection well and worked through these matters. Also, just a little nomenclature. We at the AOGCC do not consider a well constructed like 1 C-25' a monobore. In this case, the conventional construction involved using same-sized liner and tubing resulting in a mono diameter wellbore. The distinction may seem fine, however the monobore term has been applied to wells where the reservoir penetrating string is also the tubing string. 30-19 is one of the wells that comes to mind. Jerry Dethlefs or one of the other people at Problem Wells can provide further information on the distinction. Call or message with any questions. Nice reserve target. 100 1/19/2007 8:42 AM RE: Direction Needed - Kuparuk I C-25 potential conversion to injection . . Tom Maunder, PE AOGCC Johnstone, Sam wrote, On 4/24/200610:34 AM: Tom, We see an opportunity to increase pattern reserve recovery by converting Kuparuk 1 C-25 (C4-sand producer) to water and MI injection. Due to isolating faults, the 1 C-25/1 C-21 pattern does not receive and has not received water or MI injection support. The most recent measured reservoir pressure (PBU - December 2004) indicated that the 1C-25 area reservoir pressure is approximately 1750 psi. To maximize pattern recovery, we recommend drilling a 2000' Coiled Tubing Drilling horizontal sidetrack (kicking out of the existing perforations), producing the well 6 to 12 months, and then converting to water and MI injection service. By drilling the sidetrack and converting 1 C-25 to an injection well, it is estimated that approximately 1000 MBO additional Waterflood and EOR reserves will be recovered. The concern with the project is that the existing casing liner seal assembly (wellbore is a 3.5" monobore configuration) is located more than 200' MD above the top Kuparuk C4-sand perforation. (See the Table below.) Is it possible to receive an exception to this rule (20 MC 25.412 (b)) if verification of proper cement placement below the seal assembly and above the top perforation is established? We are currently looking at running a CBL to verify cement placement. Thanks for your help. Please let me know if you have any suggestions, Sam 1C-25 Depths Measured Depth, ft TVD, ft SSTVD,ft Seal Assem bly 9422 6216 6122 Top Kuparuk (D) 9743 6409 6315 Top Kuparuk (C4) 9781 6432 6338 Top Perf 9788 6437 6343 Sam Johnstone Office (907) 263-4617 Home (907) 746-5809 lC-27 cementing report Content-Description: lC-27 cementing report 06-03-99.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: lC-25 cementing report 04-26-99.pdf 1 C-25 cementing report 04-26-99.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f3 1/19/2007 8:42 AM RE: Direction Needed - Kuparuk 1C-25 pote.onverSion to injection . .. Cement Evaluation for Content-DescrIptIon: I· t· P ·t d nJec Ion elTI1l. oc application/msword base64 Cement Evaluation for Injection Permit. doc Content-Type: Content-Encoding: 30f3 1/19/20078:42 AM . . Well1C-25L1 D>âCo- \~U Assessment of Cement and Wells Within One-Quarter Mile Application to Convert to Water Injection January 12,2007 lC-25 Cement Evaluation \ ~~ -C) ~ \ ~ Well1C-25 is a Kuparuk C sand producer equipped with 3Y2" tubing and 3Y2" production liner. The 3Y2" liner spans the entire C sand from 9416' - 10,138' MD, 6213' - 6648' TVD. The L1lateral in well1C-25 was recently drilled and completed with 2%" slotted liner in the C Sand, while still leaving the original perforations open in the 1 C-25 wellbore. It is proposed that well 1 C-25 and the 1 C-25L1 lateral be converted to water injection. The only other well within one-quarter mile of the C sand of 1C-25 or 1C-25L1 is well1C-27 to the east. The 3Y2" liner across the Kuparuk C sand in well1C-25 was cemented in place on April 26, 1999. A total of33 bbl of 15.8 ppg cement were pumped, which compares to a gauge open hole volume of 13.9 bbl. The cement job proceeded smoothly without any problems. Full returns were maintained throughout the cementing operation, and the pipe was reciprocated until shortly before the plug was bumped. Gemoco "spirolator" centralizers were installed on every joint. After releasing from the liner hanger, 13 bbl of cement were circulated off the top of the liner. A SCMT log run on June 24,2006 shows excellent cement coverage over the entire 3Y2" liner. The 1C-25L1lateral exits the 3Y2" liner at 9793' MD (6440' TVD), which leaves a 223' cemented interval across the 3Y2" liner up to the 7" shoe at 9570' MD. 1 C-27 Cement Evaluation \ q <; - Q 4 ~ Well1C-27 is a horizontal producer in the Kuparuk C sand, although there are plans to convert it to water injection in 2007. It is completed with 7" production casing cemented to a depth of 10,787' MD (6403' TVD) with 4Y2" slotted liner installed in the horizontal section. There is approximately 490' of separation from well 1 C-25L1 at 6482' TVD in the C Sand. The 7" casing in well1C-27 was cemented in place on June 3, 1999 using 37.5 bbl of 15.8 ppg cement. The job proceeded smoothly without any problems. The calculated top of cement is reported as 9987' MD (6202' TVD), but no cement evaluation log was fUll. Full returns were maintained during the cement job, and the casing was reciprocated until shortly before the plug was bumped. Gemoco bow-spring centralizers were installed on every joint for the bottom 25 joints. The 7" casing was pressure tested to 3500 psi prior to drilling out, but for some unknown reason no LOT or FIT was conducted after drilling out the shoe. J. Gary Eller ConocoPhillips Wells Engineer PAl Daily Drilling . . Page 1 of2 Well lC-25 DATE 4/26/1999 DFS REPT NO. Sidetrack TMD TVD Network lC-25 6,649' 23 10,140' AK0023 O' D.P. BURLEY / Superviso RICK Proposed TMD OVERSTREET Rig Name Pool 6 Field Name Current Status Event Code 24 HR Forecast Last Surve 0' Pressure Test(s) Paily CO!,it Type I Date I TMD I TVD I MW I Press I Tot. ress EMW $0 KUPARUK RIVER UNIT CHANGING OVER Last Safety WITH CLEAN . SEAWATER. Meeting Cumulative Cost $0 11'1'1 ppgl psi 0.00 psí 0.00 ppg ODR Incident 1st 24 hrs. No 4/22/1999 I TMD: Last Casing Next Casing INC: Qp~rªtiºnSmSllnUnªrY From To Hours Phase Activity Subcode Time Trouble Start End Class Depth Depth Operation PJSM. Test lines to 4500 psi. Pumped 10 bbls Arco pre-flush, 30 bbls Arco 00:00 01:00 1.00 PROD CEMENT PLUG P 10,140' 10,140' spacer, 33 bbls of cement. Displaced w/23 bbls high vis pill & 47.1 bbls of mud. Bumped plug, press. to 3000 psi. Set 01:00 01:30 0.50 PROD WELCTL BOPE P 10,140' 10,140' hanger, increased to 4200 psi set packer. Press. to 1000 psi unsting from packer. Circulate hole clean. 7 BPM @ 3500 01:30 03:00 1.50 PROD CIRC P 10,140' 10,140' psi. Had 13 bbls. of cement returns at surface. 03:00 03:30 0.50 PROD CASE DEQT P 10,140' 10,140' est casing to 3000 for 10 min. 03:30 04:00 0.50 PROD P 10,140' 10,140' RD Baker cement manifold. - 04:00 04:30 0.50 PROD P 10,140' 10,140' Swivel leaking, changed out. Pumped 30 bbl high vise. pill. 04:30 06:30 2.00 PROD CIRC P 10,140' 10,140' Changed well over to seawater @ 6 BPM 2500 psi. 06:30 08:00 1.50 PROD P 10,140' 10,140' RU and laydown 35 jts. DP. Pumped additional 150 bbls seawater 08:00 09:00 1.00 PROD CIRC P 10,140' 10,140' to obtain clean returns at surface 8.5 BPM @ 2000 psi. POH laying down 120 jts DP. Stand 09:00 13:30 4.50 PROD TRIP P 10,140' 10,140' back 60 stands in derrick. LD running tools. RU HES slickline. Held PJSM. RIH 13:30 16:00 2.50 PROD P 10,140' 10,140' w/6.0" gauge ring to 9440' (wireline measurement) tagged top of liner - w/no problems. http://partners.conocophillipsalaska.com/ drilling/ cgi - b in/reports/daily .asp 1/11/2007 . ...... ,,,. ARCa Alaska, Inc. . Cementin Details Report Number: 23 Field: KRU Hole Diameter: 6.125 Angle thru KRU: 53 Report Date: 04126199 AFC No.: AK0023 LC Depth: 10039 1 Weatherford Spirolater per ¡oint Weight: 11.5 Gels before: 13/19 PV(prior cond): 29 Gels after: 11/14 Mix wtr temp: Mix wtr temp: 65 Shoe Depth: 10138 % washout: State type used, intervals covered and spacing PV(after cond): 27 YP(prior cond): 34 YP(after cond): 31 Total Volume Circulated: 500 Volume: 10 bbts Weight: 8.4 Volume: 30 bbls Weight: 13.5 No. of Sacks: Yield: Weight: No. of Sacks: 180 Yield: 1.2 Weight: 15.8 Additives: 0.1 gps D47, 3% D53, 0.75% D65, 0.1 gps D135. 2 gps D6DO, 0.1% DBOO. Rate(before lail at shoe): Rate(lail around shoe): 4bpm 4bpm Reciprocation speed: 20fpm Actual Displacement: 70.1 Calculated lop of cement: 9416' TOL, (Circulated out 13 bbls of cement above Hoer top after releasing from running tool. CP: Date:4-26-99 lime:0110hrs. SIr. WI. Up: 185 SIr. WI. Down: 125 Str. WI. in mud: Bumped plug: yes FlOats held: yes Remarks:Conditloned mud @ 3.5 bpm 1500 psi. Pumped 10 bbls of preflush, 30 bbls of spacer and 33 bbls of cemenl. Displaced with 23 bbls high vis pill and 47.1 bbls of mud, Saw 200 psi pump Increase 65 bbls into displacement (2.7 bbls late). ( drill pipe I liner wiper plug PU). Reciprocated pipe untllllast 20 bbls of displacement Set liner hanger with 3200 psi, packer with 4200 psi. Cement Company: DS Rig Contractor: POOL Approved By: D.BURLEY . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 AE : 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) 245-8951 1) 1 8L / EDE Disk 2) 3) 4) 5) 6) 7) Signed: ~,f1--- C' j.!lJ'~ tÁ 1 Print Name: 1 C - 25 12-Oct-06 Caliper Report "i'h.., ft\H~í!;;~) "~~rM.; ";~~~;~:~ " ¡. ?~ ' ì RECE\VEO Date : orT ,>, 4 2006 ~, ~\ . '. I r f"1,t,1 ,¡j (j J) r1, ;~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 WEBSITE: W'J\íW.i\lJ¡:¡fuJORYLOG.COM E-MAIL: ?DSÞ_NGHOP...~GE(Œj\.'1EMOR.'{L:,JG.GOM ¡qCj - 031 -+1: ILI/CJ3 D:IOO _ PDSANC-2006\Z _ W ordlDistributionlTransmíttaJ_ SheetslTransmít_ Original. doc 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. October 12, 2006 8058 2 3.5" 9.3 lb. L-80 EUE 8rd Tubing & Liner 1 C-25 Kuparuk Alaska 50-029-22941-00 9,280 Ft. (MD) 9,928 Ft. (MD) Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: Inspection Type : Co"osive & Mechanical Damage Inspection (Side Track) COMMENTS: This log is tied into the D Nipple wI No Go Profile @ 9,413' (ELMD). This log was run to assess the condition of the 3.5" tubing and liner interval with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing and liner interval is in good condition with respect to corrosive damage. No significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions are recorded in the interval logged. This is the second time a PDS caliper has been run in this well. the first of the liner interval. MAXIMUM RECORDED WALL PENETRATIONS: Perforations Perforations Perforations 9,814 Ft (MD) 9,786 Ft. (MD) 9,837 Ft. (MD) ( 100%) ( 90%) ( 83%) Jt. Jt Jt. 306 @ 305 @ 307 @ No significant wall penetrations (> 18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 9%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. RECEIVED OCT 2 4 2006 .-a Oil & Gas Cons. eommissioo Anchorage I Field Engineer: R. Richey Analyst: M. Tahtouh Witness: C. Fitzpatrick Df1 - O~3 ¡ 1* I '-{ Cf3 I I PDS Report Overview Body Region Analysis I Well: Field: Company: Country: 1C-25 Kuparuk ConocoPhillips Alaska, Ine. USA Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st Nom'!D 2.992 ins October 12, 2006 MFC 24 UW No. 211387 1.69 24 M. Tahtouh I Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread L-80 EUE 8rd Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins I Penetration ami Meta! loss ('Yo wall) Damage Profile ('Yo wall) I penetration body o 293 penetration body metal loss body 50 metal loss body 100 30 I 20 10 I GLM 6 o o to 1% 1 to 10% 10 to 20% 20 to 40 to over 40% 85% 85% I pene. loss 2 o I Damage Configuration ( body) I 10 I I o isolated pitting general line ring hole I pass corrosion corrosion corroSion ¡ble hole I I Bottom of Survey = 310 2 I I Analysis Overview page 2 I I I' I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABU Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf 1.-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 1 C-25 Kuparuk ConocoPhillips Alaska, Inc. USA October 12, 2006 Joint Jt. Depth P"i' Pen. Pen. I Metel Min. Damag e Profile No. (Ft.) Body 1.0. Comments (% wall) ( (Ins.) (Ins.) 0 50 100 293 9292 IJ 0.03 12 ) 2.92 !IiI 294 9322 IJ 0.03 13 >' 2.94 Shallow corrosion. !IiI 295 9352 IJ 0.03 11 7' 2.92 !IiI 295.1 9383 IJ 0.03 n >' 2.91 PUP Shallow nitting. !IiI 295.2 9394 IJ 0 0 NIA GI.M 6 (Latch @ 2:0m 295.3 9402 0 0.04 14 2.93 PUP Shallow corrosion. If 295.4 9412 I 0 0 2.73 o Nioole wi No Go Profile 295.5 9414 ({ 0.02 9 2.91 PUP 295.6 9424 IJ 0 0 3.00 SEAL ASSEMBLY 295.7 9438 ({ 0 0 I N/A PACKER 295.8 9460 0 0.03 11 1 2.82 PUP Shallow Dining. Lt. Denosits. It! 295.9 9470 0 0.04 11, q 2.91 PUP Shallow corrosion. Lt. Denosits. 296 9480 IJ 0.03 10 I 2.92 Lt. Deoosits. 1 st fulllemzth It. of Liner. 297 9511 I 0.03 10 2.92 298 9541 I 0.02 (1 2.93 299 9573 i 0.02 (1 2.92 300 9605 I 0.03 I ,- 2.93 Shallow Ditting. 301 9636 I 0.05 1 2.90 Shallow Dining. Lt. Denosits. 302 9668 0 0.04 1 I 2.93 Shallow corrosion. Lt. DeDosits. 303 9698 0 0.05 II 2.93 Shallow Ditting. Lt. Denosits. 304 9730 0 0.03 ]{ 2.94 305 9760 0 0.23 90 2.93 Perforation Interval. 306 9791 0 0.28 100 2.94 Perforation Interval. 307 9822 0.10 0.21 in 2.91 Perforation Interval. 308 9854 0 0.03 11 ¿¡ 2.95 Shallow Dining. 309 9886 0 0.04 14 4 2.92 Shallow Dining. 310 9917 0 0.04 17 4 2.93 Shallow corrosion. Lt. DeDosits. Body Metal Loss Body Page 1 I' I .r .. . . KRU 1 C-25 , , !tC~2S TUBING API: 500292294100 Well Type: PROD Angle @ TS: 53 deg @ 9781 (0-9452, SSSV Type: Nipple Orig Completion: 4/28/1999 Angle @ TO: 52 deg @ 10140 003500. Annular Fluid: Last W/O: Rev Reason: TAG FILL 10:2.992) Reference Log: Ref Log Date: Last Update: 1 0/2/2006 Last Tag: 9813 TD: 10140 ftKB ~ 10/112006 Max Hole Angle: 56 cleo @ 4002 I<...>AU DescriDtion Size Too Bottom TVD wt Grade Thread PRODUCTION 7.000 0 9570 6305 26.00 L-80 BTC-MOD CONDUCTOR 16.000 0 115 115 62.58 H-40 WELDED PRODUCTION SURFACE 9.625 0 6567 4554 40.00 L-80 BTC-MOD (0-9570, PRODUCTION LINER 3.500 9416 10138 6648 9.30 L-80 EUE 8rd 007000, >''''. Wt26 00) Size Top Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 9452 I 6234 I 9.30 I L-80 I EUE 8rd Interval TVD Zone Status Ft SPF Date Type Comment SURFACE -9824 6437 - 6458 C-4 36 4 8/27/1999 IPERF 2.5 HC. DP. 180 deg. ph (0-6567, - 9844 6464 - 6470 C-4 10 10 8/27/1999 IPERF 2.5 HC. DP. 180 deg. ph 009625, Wt40.00) 9967 - 9987 6544 - 6556 C-1 20 6 5/16/2006 APERF 2" 2006 PJ Omega Charges Interval Date I Type I Comment 9788 - 9844 11/9/2002 I FRAC I Gas Lift 'Gä:l.;m: MandreWalve St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run VI v 3 (6594-6595, Mfr Cmnt 005.390) 1 3230 2612 CAMCO KBMM CAMCO GLV 1.0 BK 0.125 1290 11/15/200 2 5166 3734 CAMCO KBMM CAMCO GLV 1.0 BK 0.156 1316 11/15/200 3 6594 4570 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1339 1/171200 4 7775 5262 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1327 11/15/200 Gas Lift 5 8616 5749 CAMCO KBMM CAMCO GLV 1.0 BK 0.250 1420 11/14/200 MandreWalve 6 9391 6198 CAMCO MMM CAMCO OV 1.5 RK 0.250 0 11/14/200 4 (7775-7776, vun:r p.u\.J ÒeCiI.liD....· F'tIOI\l 005.390) Depth TVD Type Description ID 502 502 NIP CAMCO DS nipple 2.875 9410 6209 NIP CAMCO D nipple NO GO profile. ELMO @ 9413 ON SWS JEWL LOG 2.730 9/21/99 Gas Lift 9422 6216 SEAL BAKER 80-40 casing seal assembly 3.000 MandreWaIve 5 (8616-8617, 005.390) Gas Lift MandreWalve 6 (9391·9392, 006.018) NIP (9410-9411, 004.500) Perf (9788-9824) FRAC ...). (9788-9844) ~ Perf (9834-9844) ~ Perf _.~ -. (9967·9987) - - -~ r- .... I-- I I 1 1 I I 1 1 1 I I 1 1 1 I 1 I . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 a Fax: (907) 245-8951 1) 1 BL / EDE Disk 2) 3) 4) 5) 6) 7) Signed: (1/ j )~ 1 C - 25 Caliper Report 27 -Sep-06 I CID¡~ Q3 I ~ ILl/53 G;:. ¡(: f-;" I~ ItH ~"ì OVinC \JU \ô1io-v r RECEIVED OCT 0 4 ZOOÖ 1,. ~ .~:..,.- Date : ¡\Iaska Oil & Gas Cons. Commission Anchorage (}l~'¿ev( Print Name: Q ~ r;",fj 11\ p PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: Eps/~J:.¡CHOfy\Gf@MEMORYLOG.COI\j WEBSITE: WWW.MEMORYLOG.c~M D:\OO ]DSANC-20()(í\Z _ WordlOistribution\Transmiltat Sheel.ITransmit_ Original.doc 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: ConocoPhitlips Alaska, Inc. September 27, 2006 7104 1 3.5" 9.3 lb. L-80 EUE 8rd Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log IntvI1.: 1 C-25 Kuparuk Alaska 50-029-22941-00 Surface 9,459 Ft. (MO) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the DS Nipple wI No Go Profile @ 9,410' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage and to determine future potential for whipstock placement. The caliper recordings indicate the 3.5" tubing is in good condition, with the exception of a ring of damage measuring 24% wall thickness in joint 67 (2,111'). The damage appears to be mechanical in nature. No other significant wall penetrations, areas of cross-sectional wall loss or I. D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: Ring of Damage 2,111 Ft. (MD) ( 24%) 67 @ Jt. No other significant wall penetrations (> 17%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 12%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. ~- ~+- I Field Engineer: Wm. McCrossan Witness: J. Brake I PDS,gJrnernOry¡og,cRECE IVE 0 Analyst: M. Lawrence OCT 0 4 2006 /0'1-0'3 I :µ 14163 4Jaska Oil & Gas Cons. Commissìon Anchorage I I I I I I I I I I I I I I I I I I I - Pipe 1 160 5031 0 ... ~ Q) ..0 .,.; E u... ::¡ c: z 200 6304 ..r:; -~ ã. Q) -2, 0 240 7580 Correlation of Recorded Damage to Borehole Profile 3.5 in (3.8' - 9457.0') Well: Field: Company: Country: Survey Date: 1C-25 Kuparuk ConocoPhillips Alaska, Inc. USA September 27, 2006 Approx. Tool Deviation Approx. Borehole Profile 120 40 80 280 295.8 o 50 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Su rvey = 295.8 26 1251 2499 3777 8884 9457 100 I I I I I I I I I I I I I I I I I I I - Well: Field: Company: Country: 1C-25 Kuparuk ConocoPhillips Alaska, Inc. USA Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread l-80 fUE 8rd Penetration and Metall.oss ('Yo wall) penetration body metal loss body 250 200 150 100 50 0 o to 1% 1 to 10% 10 to 20 to 40 to over 20% 40'/"o 85% 85% o o Damage Configuration ( body) 80 40 60 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole o PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.lD 2.992 ins September 27, 2006 MFC 24 No. 040665 1.69 24 M. Lawrence Nom. Upset 3.5 ins Upper len. 1.2 ins lower len. 1.2 ins Damage Profile (% wall) penetration body o o GlM 1 GlM2 GlM 3 GlM4 GlM 5 GlM 6 Bottom of Survey = 295.8 Analysis Overview page 2 metal loss body 50 100 I I I I I I I I I I I I I I I PDS REPORT JOINT ULATION SH Pipe: Body Wall: Upset Wall: Nominal !.D.: 3.5 in 9.3 ppf l-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-25 Kuparuk ConocoPhillips Alaska, Inc. USA September 27,2006 Joint Jt. Depth Pen Pen, Pen. inln';11 Min. Damage Profile No. (Ft.) Body !.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 .1 4 it om .l. Jl 2.89 PUP . .2 6 Jl 0.02 Jl Jl 2.94 PUP .., 17 Jl 0.02 9 2 2.89 PUP .J 1 26 º- 0.04 14 2 2.92 Shallow corrosion. 2 58 CJ 0.02 9 2 2.90 3 89 (J om II 2 2.91 4 121 U 0.02 I 2.90 5 152 (J 0.02 I 2.90 . 6 184 JJ 0.03 1 I 2.91 7 215 º- 0.03 º- .l. 2.92 8 246 Jl 0.03 .11 2 2.91 9 278 -º om I 2 2.93 10 309 0 0.02 1 2.90 11 341 CJ 0.03 2 2.89 12 372 CJ 0.02 2 2.91 13 403 [) 0.02 J 2.90 14 435 º- 0.02 -º 2.90 15 466 Q 0.02 ( -º 2.88 15.1 498 CJ 0 ( CJ 2.88 DS Nipple 16 499 Jl om 1 ! 2.90 111 17 531 () 0.02 ¡ 2.91 18 562 J 0.02 2 2.92 19 594 J om .l. 2.92 20 625 0.02 ¡ 2.91 21 657 l 0.ü2 1 2.92 1" ¡ 22 689 CJ om JQ Jl 2.93 23 720 Jl 0.04 15 I 2.89 Shallow pitting. 24 752 Jl om 1 I 2.90 25 781 (1 0.ü2 _f' 2 2.95 26 812 (1 om IQ _2 2.91 27 843 Jl om I Jl 2.91 ,. 28 875 if 0.02 Jl -º 2.93 '" 29 907 (1 0.03 /I 2 2.91 ,. 30 938 Jl 0.02 2 2.92 31 970 (1 0.02 ¡ 2.94 32 1001 (1 0.ü2 () 2.90 , 33 1033 .1) 0.02 Jl 2.91 34 1064 iJ 0.ü2 .¡ 2.90 . , 35 1096 J.I. 0.02 J. 2.91 36 1127 Jl om /I .l. 2.90 37 1156 º- 0.02 <) 2 2.91 38 1188 º- om 11 I 2.91 39 1219 () 0.ü2 13 () 2.90 iii 40 1251 () 0.03 1 3 2.92 pi 41 1282 J) om 1 .2 2.92 Sha!lowj2Ìtbo&. p 42 1313 J. 0.03 .1.. ! 2.90 Shallow J2ittif}g, 43 1344 º- 0.03 II I 2.91 44 1376 () 0.02 1 2 2.91 45 1407 CJ om I Jl 2.91 46 1439 iJ 0.02 _l 2.89 Body Metal Loss Body Page 1 _I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-25 Kuparuk ConocoPhillìps Alaska, Ine. USA Sepæmber 27, 2006 Joint Jt. Depth 1\-:;:; Pen. I)E)~ . !vielal Min. Damage Profile No. (Fl.) (;:::"1 Body ;5 !.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 47 1470 0 0.02 9 2 2.90 48 1502 ( om 10 2 2.90 II 49 1533 U om 12 2 2.91 50 1565 () om !3 I 2.91 Shallow corrosion. 51 1594 () 0.03 1 2 2.90 52 1625 .() 0.03 1 2 2.91 53 1657 () 0.02 6 2.91 54 1686 () om 13 ~¡ 2.91 Shallow oÎtúnQ. 55 1718 I. om II) I 2.92 II 56 1748 n 0.02 E) ~¡ 2.91 57 1779 n om 11 2 2.90 II!! 58 1809 n om ID 2 2.91 !III 59 1840 0 0.03 12 0 2.89 II!! 60 1871 0 om 1D 2 2.91 !III 61 1903 0 0.02 ( ¡ 2.90 III 62 1934 n 0.02 2 2.90 63 1966 0 0.03 11 I 2.91 64 1997 0 om 10 4 2.92 IJ 65 2029 () 0.02 if 2 2.90 66 2060 () 0.02 9 2 2.90 67 2092 () 0.06 24 12 2.90 Rim.! of Damaae. 68 2123 n 0.03 n .1 2.89 Shallow oitúm:¡:. 69 2155 n 0.02 9 2 2.90 70 2186 n om In 2 2.91 71 2218 () 0.03 3 I 2.90 Shallow oitúnQ. 72 2248 n 0.03 '3 2 2.91 Shallow corrosion. 73 2280 () 0.02 I 2.89 74 2311 () 0.03 J I 2.90 II!! 75 2343 () 0.02 2 2.89 II!! 76 2374 0 0.02 2 2.88 !II 77 2406 0 0.02 2 2.88 , 78 2437 () om 10 I 2.90 79 2468 ( om 12 2 2.89 80 2499 () 0.02 n I 2.89 II!! 81 2531 () 0.02 7 2 2.87 filii 82 2562 ( om () 2 2.89 !III 83 2594 ( om Ii 4 2.89 IIi 84 2625 ( 0.03 I 2 2.87 !III 85 2656 ( om 11 2 2.89 86 2688 0 0.03 13 I 2.89 Shallow corrosion. !! 87 2720 0 0.03 12 I 2.90 !III 88 2751 0 om 11 2 2.87 !III 89 2781 I 0.03 13 1 2.88 Shallow oitúmL Lt. Denosits. i 90 2812 0.02 9 2 2.87 III 91 2843 ( 0.03 10 3 2.88 !!II 92 2874 I 0.04 14 2 2.87 Shallow oitúm:¡:. ~ 93 2905 0 0.03 13 3 2.85 Shallow Ditún¡:¡;. Ll. Deposits. pi! 94 2937 U 0.04 14 2 2.85 Shallow corrosion. Lt. Deposits. !III 95 2967 () om 13 2 2.86 Shallow nitún2. ¡ill 96 2999 () om 12 2 2.87 Shallow oitúnQ. ¡ill Body Metal Loss Body Page 2 - I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nomina! ID.: 3.5 in 9.3 ppf l-80 EUE Brei 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-25 Kuparuk ConocoPhiUips Alaska, Inc. USA September 27, 2006 Joint JL Depth I\'n. Pen. 1'¡'le Me:d Min. Damage Profile No. (Ft.) 'I Body ID. Comments (%wall) (Ins.) (ins.) 0 50 100 97 3030 om JJ.. 1 2.B8 ShalloW.12itóQg, 98 3062 º- om li -2 2.88 Shallow.12itóQg, 99 3093 Jl 0.02 .2.. -2 2.89 100 3125 Jl om JJ.. -2 2.87 Shallow.J¿jtófJg, 101 3157 J) 0.03 10 2 2.88 102 3187 JJ 0.02 .9 ) 2,89 102.1 3218 J om 12 2.86 PUP Shallowpittifjg. 102.2 3228 JL 0 Jl NLA GlM 1 Jlatch @ 9:001 102.3 3235 Jl om 11 2.78 PUP Oval. 103 3245 Jl 0.04 11. ) 2.85 Shallow.J¿jtólJ&,. 104 3276 Jl 0.02 11 -2 2.88 105 3307 Jl 0.03 1 -2 2.88 ShallowjdjtóO&., 106 3339 0 0.03 .11 (] 2.88 107 3369 j! 0.02 13 1 2.86 108 3401 j) 0.03 I 2.88 Shallow corrosion. 109 3431 Jl 0.03 1 2.90 110 3463 Jl 0.03 1 2.89 111 3494 0.D2 I 'j 2.90 112 3525 Jl 0.04 J.2 -2 2.88 Shallow.1?itóQg, iiB 113 3557 Jl 0.02 .2.. 2.86 I'" 114 3588 0 0.02 9 2.85 iiB 115 3620 _0 0.03 1L ) 2.87 )0 116 3651 Jl 0.04 tl ) 2.88 Shallow.J¿jtóQ&.. 117 3683 Jl 0.03 ill. l 2.88 118 3714 Jl 0.02 JL -2 2.89 119 3746 -º- 0.03 JlL -2 2.90 120 3777 _I om 13 2.89 ShalloW..Qitóng. 121 3809 J) 0.03 I ¡ 2.89 122 3840 () om JJ.. 2.87 Shallow.J¿jtóog. 123 3872 ill. 0.D2 _2 2.89 124 3903 JL 0.03 JJ 2.86 125 3935 -º- om IQ.. 2 2.87 126 3966 Jl 0.03 1.1 -2 2.87 Shallow..QitóQg, 127 3997 ill. 0.03 22 Jl 2.91 128 4028 J 0.D2 ...9 J 2.90 129 4060 J 0.03 J) ¡ 2.86 W§!j 130 4091 J. 0.03 1 .1 2.87 Shallow.P.itóf)g. G 131 4123 J! om J -2 2.87 ShaHowj)itÓQg. 132 4154 0.D2 Jl -2 2.88 133 4186 Jl om l.l Jl 2.88 Shallow.Q1thlJ&,. Lt. Demsits. p 134 4217 0 om 1 ! 2.85 It. D~its. W§!j 135 4249 0 0.D2 9 2.86 )0 136 4280 J. om 1 2.85 Shallow.QitÓf)g. ¡ 137 4312 0.04 1 2.91 Shallow_pitóOg. 138 4343 .J 0.03 J 2.89 ShalloW..QitóQg, 139 4375 J 0.02 l 1 2.90 140 4406 om J 2 2 2.89 )0 141 4438 0 om 1 ì 2.90 W§!j 142 4469 JJ om _HL A 2.88 143 4501 l 0.03 11) 1 2.84 Body Metal loss Body Page 3 - I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal J.D.: 3.5 in 9.3 ppf L-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-25 Kuparuk ConocoPhillips Alaska, Ine. USA September 27,2006 Joint Jt. Depth Pen. Pen. Pen. "/Ie' 11 Min. Damage Profile No. (Ft.) -j Body I.D. Comments (%wall) Ins) (Ins.) (Ins.) 0 50 100 144 4532 ( 0.04 J6 I 2.87 Shallow pittim!. !III !ii 145 4564 0.03 10 2.87 pi! 146 4595 0.02 9 2.85 147 4627 .1) 0.03 11 2.88 pi! 148 4658 0 0.03 10 2.88 111 149 4690 0 0.02 ß 2.85 150 4719 0 0.02 9 I 2.87 151 4750 0 0.03 10 2.87 152 4782 0 0.02 7 2.89 153 4812 0 0.03 11 2.88 154 4843 .0 0.04 17 2.88 Shallow corrosion. Iii 155 4874 0 0.03 12 2.88 156 4905 (3 0.03 II 1 2.89 157 4937 0 0.03 )e) 2 2.89 158 4968 0 0.03 12 2.90 159 5000 0 0.03 (I I 2.87 160 5031 ..0 0.03 11 2 2.87 . 161 5063 0 0.03 -P 2 2.88 pi! 162 5094 0 0.03 I 2 2.82 Shallow Dittimc !III 163 5125 0 0.02 9 ) 2.84 iii 163.1 5156 0 0.02 n 2 2.90 PUP III 163.2 5166 0 0 0 0 N/A GLM 2 (Latch @ 12:30) 163.3 5172 0 0.03 10 2 2.89 PUP pi! 164 5182 0 0.04 14 2 2.90 Shallow pittiQg. III 165 5214 0 0.02 9 I 2.88 166 5244 C 0.03 ! 4 2.89 ShaJlowpitting. 167 5276 0 0.03 11 ') 2.87 168 5307 0 0.04 1 /\ 2.85 Shallow pitting. 169 5339 0 0.03 1 I 2.88 Shallow corrosion. 170 5370 0 0.03 I 1 2.86 171 5401 0 0.02 ¡ I 2.86 172 5432 0 0.02 ¡ 2 2.88 173 5464 0 0.04 } I 2.85 Shallow Ditting. 174 5495 0 0.04 I. /] 2.83 Shallow corrosion. Ii1I 175 5527 () 0.03 11 2 2.84 111 176 5558 0 0.03 10 2 2.86 111 177 5589 () 0.03 10 i 2.85 !III 178 5620 0 0.03 13 I 2.84 Shallow pitting. ~ 179 5650 () 0.04 13 I 2.88 Shallow corrosion. IIU 180 5682 0 0.03 11 3 2.87 111 181 5713 () 0.02 9 ~! 2.87 Fiii 182 5744 0 0.03 13 2 2.87 Shallow Ditling. 111 183 5776 U 0.03 II I 2.88 III' 184 5805 0 0.03 13 2 2.88 Shallow pitling. r'" 185 5837 () 0.02 9 ¡ 2.87 III ¡ 186 5867 () 0.03 L2 2 2.88 ShallowíJitling. Fiii 187 5898 () 0.04 15 ) 2.89 Shallow pitting. 11I11I 188 5929 () 0.03 II 2 2.89 III 189 5961 () 0.03 13 2 2.88 Shallow pitting. III~ 190 5992 () 0.03 /1 2 2.89 III Page 4 Body Met¡ Loss Body --- I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 WF 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-25 Kuparuk ConocoPhillips Alaska, Inc. USA September 27, 2006 Joint JI. Depth Pee. Pen. Pee. '\1e!al Min. Darn age Profile No. (Fl.) 'I Body /D. Comments (%wall) (IllS) (Ins.) (Ins.) 0 50 100 191 6023 0 0.02 (1 2.85 192 6054 0 0.03 1, 2.85 ~ 193 6086 0 0.04 1 2.85 Shallow oitfing. 194 6116 0 0.03 ¡ 2.83 Shallow oitfing. 195 6148 0 0.03 :' 2.85 196 6180 0 0.03 ¡ 1 2.87 197 6211 0 0.03 0 2.88 198 6243 0 0.02 2.88 199 6273 0 0.03 I 2.87 Shallow oittim;¡. Lt Denosits. 200 6304 0 0.03 H 2.85 201 6337 0 0.03 11 2.87 Shallow nitfing. 202 6368 0 0.03 1 (I 2.87 203 6400 0 0.03 11 :' 2.84 204 6431 0.03 10 2.85 205 6463 I 0.03 10 2.83 206 6494 I 0.03 13 2.85 Shallow oitfimr. 207 6524 ( 0.04 14 2.83 Shallow oitfing. 208 6555 0.03 13 2.87 Shallow oitfim¡¡. 208.1 6585 0 0.02 i1 1 2.91 PUP 208.2 6593 0 0 0 n N/A GLM 3 (Latch @ 1 :30\ 208.3 6601 0 0.03 II 0 2.88 PUP I 209 6611 I 0.03 10 I 2.86 II 210 6643 I 0.02 9 2 2.86 211 6674 ( 0.02 8 ] 2.85 212 6705 ( 0.03 ìl 2 2.84 213 6737 0 0.02 (1 2 2.87 214 6769 0 0.04 14 2 2.88 Shallow nitling. 215 6800 0 0.02 9 (, 2.85 216 6832 0 0.03 I :' 2.84 217 6863 0 0.03 I 2 2.85 Shallow oitlinQ. 218 6895 0 0.03 1 2.84 219 6926 ( 0.03 1 2.86 220 6957 0.03 11 2.79 221 6987 () 0.03 13 2.78 Shallow pitting. 222 7018 0 0.02 ì 2.83 223 7050 0 0.03 II I 2.83 224 7081 0 0.03 11 I 2.82 225 7113 0 0.03 ] 3 2 2.79 Shallow oitling. 226 7143 0 0.04 15 2 2.88 Shallow oitling. 227 7174 0 0.03 13 2 2.84 Shallow oitting. 228 7206 0 0.03 13 I 2,86 Shallow oitling. 229 7237 0 0.03 ì3 I 2.83 Shallow oitting. 230 7267 0 0.02 9 ) 2.84 231 7298 n 0.03 0 I 2.83 232 7329 () 0.03 12 I 2.85 Shallow nittimi!. pII1 233 7361 () 0.03 II 2 2.86 234 7391 0 0.02 9 ) 2.87 235 7422 0 0.02 9 ) 2.85 236 7454 0 0.03 11 I 2.87 237 7436 0 0.02 9 0 2.84 ¡III Penetration Body Metal Loss Body Page 5 I I I I I I I I I I I I I I I I I I I - PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D.; 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2,992 in Well: Field: Company; Country: Survey Date; 1C-25 Kuparuk ConocoPhillips Alaska, Inc. USA September 27,2006 Joint )1. Depth F'en. Pen. 1\:"11 ! "¡Ielal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 238 7517 0 0.03 10 I 2.83 239 7548 0 0.D2 9 I 2.84 240 7580 0 om I I 2.83 241 7611 0 0.D2 9 I 2.84 242 7642 0 0.D2 ß 1 2.83 243 7674 0 0.04 'j 2.84 Shallow corrosion. It. D~posits. 244 7705 ( om I 2.84 245 7737 0.02 2 2.86 1£1 245.1 7767 0.02 2 2.85 PUP 245.2 7777 ( 0 ( 0 N/A GlM 4 (latch @ 9:00) 245.3 7783 0 om 12 3 2.81 PUP Oval. 246 7793 0 0.03 11 I 2.82 247 7824 U 0.04 17 I 2.80 Shallow corrosion. 248 7856 0 0.03 10 I 2.81 249 7887 ( 0.D3 11 I 2.83 Lt. Deoosits. 250 7919 ( 0.D3 13 2 2.80 Shallow corrosion. 251 7950 0.04 1'; i 2.80 Shallow oittim:!:. 252 7981 U 0.02 9 . 2.86 I 253 8012 U om II I 2.84 254 8044 0 0.03 11 2 2.81 III 255 8076 0 0.03 11 2 2.79 1£1 256 8107 ( om I 2 2.80 ShaJlow corrosion. !II 257 813a ( 0.03 1 2 2.a2 Shallow oittim!. III 25a 8170 ( om 1 2 2.al 259 8202 0 om ¡ 2 2.83 260 8233 0 om 12 2 2.81 Shallow pitting. 261 8265 0 om 13 2 2.81 Shallow pitting. It. Deposits. 262 8296 0 om ] ¡ 2.81 Shallow pitting. It. D~posits. III 263 8327 ( 0.02 I 2.79 iii! 264 8359 ( 0.03 Q 2 2.79 Oval. III 265 8388 0 0.02 ! 2.82 Oval. 266 8419 ( 0.D2 9 I 2.84 267 8451 0 0.D3 11 2 2.85 268 8483 0 0.04 1b 2 2.82 Shallow pitting. 11I11 269 8514 0 0.03 13 J 2.83 Shallow corrosion. III 270 8545 0 0.D2 9 2 2.84 III 271 8576 0 0.03 10 I 2.85 iii! 271.1 8607 () 0.03 10 5 2.86 PUP 271.2 8616 0 0 0 0 N/A GlM 5 (latch @ 1:00) 271.3 8624 U om 11 2 2.86 PUP 272 8633 U 0.D2 9 I 2.87 273 a665 u 0.D3 11 I 2.82 Oval. 1£1 274 8697 0 om 11 1 2.80 275 8728 U 0.D3 10 2 2.81 276 8759 0 0.02 _9 2 2.81 277 8790 U 0.02 9 I 2.82 278 8821 U 0.03 II 2 2.83 279 8852 ( 0.02 9 2 2,82 Oval. III 280 8884 U 0.02 9 I 2.81 III 281 8915 U 0.03 II J 2.83 III Body Metll loss Body Page 6 I I I I I I I I I I I I I I I I I I I - PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf 1.-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-25 Kuparuk ConocoPhillips Alaska, Inc. USA September 27, 2006 Joint Jt. Depth I~ Pen. ~ \!\(.- ,I Min. Damage Profile No. (Ft.) '[ Body 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 282 8947 U 0.04 15 2 2.81 Shallow corrosion. 283 8978 U 0.04 14 2 2.76 Shallow oittin2. 284 9010 (¡- 0.D3 12 i 2.81 ¡ 285 9041 0 0.02 9 [ 2.79 Oval. 286 9072 0 0.02 g ") 2.79 Lt. Deposits. IIiI 287 9103 0 0.D3 12 ) 2.80 Shallow nittinQ. I t. Denosits. IIiI 288 9135 U 0.D3 11 2 2.79 Oval. 289 9166 U 0.02 ß . 2.83 . 290 9198 U 0.D3 11 3 2.83 291 9229 0 0.D3 \1 2 2.82 292 9259 0 0.D3 I) 2.80 Shallow pitting. ¡ 293 9291 I) 0.D3 I' 2.79 i 294 9321 0 0.D3 11 2.81 III! 295 9351 0 0.02 ! 2.82 Lt. Deposits. IIiI 295.1 9383 0 0.02 !) ) 2.83 PUP IIiI 295.2 9392 U 0 1 0 NIA GLM 6 (Latch @ 1 :301 295.3 9401 0 0.02 ß 5 2.88 PUP r 295.4 9409 0 0 0 2.75 D Nipole wi No Go Profile 295.5 9411 iT 0.02 :! 1 2.82 PUP 295.6 9422 U 0 J 0 3.00 Seal Assemblv 295.7 9453 0 0 ) 0 NIA Packer 295.8 9457 0 0 0 0 2.81 BpçrinniO\:! of 3.5" Production Liner Body MeJaI Loss Body Page 7 .. - - - - - Well: Field: Company: Country: Tubin : - - - 1C-25 Kuparuk Conocophillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 WE 8rd Cross Section for Joi Tool speed = 55 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 88 % Tool deviation = 59 0 67 at depth 2111.2 - - - - - - PDS epo rt ross S ons Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: September 27,2006 MFC 24 No. 040665 1,69 24 M. Lawrence ft Finger 3 Penetration = 0.061 ins Ring of Damage 0.06 ins 24% Wall Penetration HIGH SIDE = UP Cross Sections page 1 - -- - -- I . . KRU 1C-25 I 111;..25 API: 500292294100 Well TYpe: PROD A~EU@ TS: 53d~9781 TUBING SSSV Type: Nipple Orig 4/28/1999 Angle @ TO: 52 deg@ 10140 (0-9452, C olT!Qletíon: OD:3.500, ID:2.992) Annular Fluid: LastW/O: Rev Reason: RETRIEVED FISH ' RODUCTlON Reference LQR: Ref LQR Date: Last ~date: 6/27/2006 (0-9570. LasH ~ 9991 TO: 10140 ftKB OD:7.000, ~ 5/16/2006 Max Hole Ar:!!J.le: 56 d~ 4002 Wt:26.00) Desc~tion ~ Ttm... Bottom NO Wt Grade Thread PRODUCTION 7.000 0 9570 6305 26.00 L-80 BTC-MOD CONDUCTOR 16.000 0 115 115 62.58 H-40 WELDED SURFACE SURFACE 9.625 0 6567 4554 40.00 L-80 BTC-MOD (0-6567, PRODUCTION liNER 3.500 9416 10138 6648 9.30 L-80 EUE 8rd OD:9.625, W!:40.00) TUBING Size J T(jp J Bottom J NO I Wt J Grade J. Thread 3.500 J 0 J 9452 .J 6234 J 9.30 J L-BO J. EUE 8rd Interval NO lone Status Ft SPF Date !me Comment Gas Lift 9788 - 9824 6437 - 6458 C-4 36 4 8/27/1999 IPERF 2.5 HC, DP, 180 d~h MandrelNalve 2 9834 - 9844 6464 - 6470 C-4 10 10 8/27/1999 ¡PERF 2.5 HC, OP, 180 d~h (5166-5167, 9967 - 9987 R<¡.1L/ . R<¡<;R C-1 20 6 I),PI=P<= ')" 2006 PJ O~ Chaffies 1& Interval Date "[.me Comment 9788 - 9844 11/9/2002 FRAC G8I; Gas Lift St MD NO Man Man Type V Mfr V Type VOO Latch Port TRO Date VI" MandrelNalve 3 Mfr Run Cmnt (6594-6595, 1 3230 2612 CAMCO KBMM CAMCO GLV 1.0 BK 0.125 1290 1/15/200 2 5166 3734 CAMCO KBMM CAMeO GLV 1.0 BK 0.156 1316 1/15/200 3 6594 4570 eAMeo KBMM eAMeo GLV 1.0 BK 0.188 1339 1/17/200 4 7775 5262 eAMeo KBMM CAMCO GLV 1.0 BK 0.188 1327 1/15/200 5 8616 5749 CAMCO a CAMCO GLV 1.0 BK 0.250 1420 1/14/200 Gas Lift 6 9391 CAMeO OV 1.5 RK 0250 0 MandrelNa!ve 4 ~I, in, 'ek:J _ (7775-7776, D~th NO Tvpe Descrlmion ID 502 502 NIP CAMCO DS nipple 2.875 9410 6209 NIP CAMCO D nipple NO GO profile, ELMD @ 9413 ON SWS JEWL LOG 2.750 9/21/99 9422 6216 SEAL BAKER 80-40 casing seal assembly 3.000 Gas Lift MandrelNalve 5 (8616-8617, Gas Lift MandrelNalve 6 (9391-9392, NIP (9410-9411, OD:4.500) 'RODUC1lON LINER (9416-10138. OD:3.500, Wt:9.30) Perf (9788-9824) FRAC (9788-9844) Perf (9834-9844) \ ....l Perf -- - (9967-9987) --- = 1-'-' 1--" f-.- I I I I I I I I I I I I I I I I I - Sc~lIIDbepglP NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~.~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 "l'\..¡r, ~..A.r- .- J\in~ '. ''1¿;;';...i l~Cl - D3( Field: Kuparuk Well Job # Color Log Description BL CD Date /",,0 o 1 E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE 05/20106 1 1 E-1()5L 1 11213766 INJECTION PROFILE 06/20106 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y -07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17106 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 US IT 07/10106 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1 F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04106 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1D-10'1 N/A INJECTION PROFILE 06/27/06 1 2Z-1) 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 . 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12120/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e e Conoc6Phillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 31,2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 0 B 2006 Alaska Oil & Gas C on8. Commission Anchorage Subject: Report of Sundry Well Operations for 1 C-25 (APD # 199-031) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operation on the Kuparuk well 1 C-25. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, {,f' ! hi ...) ::~ V\ '.., ,-"í't" T..d'\~. ¡.' ¡j~ µ, J/(~5 M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e e RECEIVED JUN 0 B 2006 o REPORT OF SUNDRY WELL OPERATIONS Al8sk a ;1 & r,~. f'_ - 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other A~ v..... '-'UfIITllS I Orage Alter Casing 0 Pull Tubing 0 Perforate New Pool -0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. 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 0 199-031/ . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22941-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 94' 1 C-25 8. Property Designation: 10. Field/Pool(s): ADL 28242,' ALK 2292 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10140' feet true vertical 6649' feet Plugs (measured) Effective Depth measured 9991' feet Junk (measured) true vertical 6558' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 114' 114' SURFACE 6473' 9-5/8" 6567' 4554' PRODUCTION 9476' 7" 9570' 6305' PRODUCTION LI 722' 3-1/2" 10138' 6648' Perforation depth: Measured depth: 9788'-9824', 9834'-9844', 9967'-9987' true vertical depth: 6437'-6458', 6464'-6470', 6544'-6556' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9452' MD. Packers & SSSV (type & measured depth) no packer Cameo OS nipple @ 502' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft ,IUN 1 4 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 554 528 63 -- 243 Subsequent to operation 493 913 110 -. 236 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development D· Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OiIO' GasO WAG 0 GINJO WINJO 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 Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Lead ~¿: ,/I I 1/ Phone Date G 7 Ó Signature PreDared bv. haro'XiDf&:ake 263-4612 /' 8"~ ~ v .../ on Form 10-404 Revised 04/2004 ORIGINAL h-ù \ \v::.CL ...4..1 C"/~'Ó~ Submit Original Only d o/1K~ e 1C-25 Well Events Summary e DATE Summaryops 05/10/06 CLEANED FILL TO 10025' CTMD (PLUG BACK TD IS 10039') WITH DIESEL, GELLED DIESEL, NITROGEN AND GAS LIFT TO MAINTAIN 70% RETURNS. FORMATION SAND AND SCALE IN RETURNS. RETURNED WELL TO PRODUCTION. 05/14/06 DRIFT TBG WI 22' X 2.5" TO 10005' SLM. 05/16/06 PERFORATE C1INTERVAL: 9967' - 9987' WI 2" 2006 PJ OMEGA CHARGES- 6SPF. EHD= 0.22", PEN 21.8". DEPTH REF TO SS MWD ROP LOG DATED 25-APR-1999. TAGGED TD AT 9991 FT. DSO TO POP. e e KRU 1 C-25 TUBING 1 C-25 (Q..9452, API: 500292294100 Well Type: PROD Anqle @ TS: 53 deq @ 9781 OD:3.500, SSSV Type: NiDDle Orio ComDletion: 4/28/1999 Anole (â2 TD: 52 dea (â2 10140 ID:2.992) Annular Fluid: Last W/O: Rev Reason: DRIFT & TAG 'RODUCTION Reference Loa: Ref Loa Date: Last UDdate: 5/15/2006 (0·9570, OD:7.000, Last Taa: 10005 SLM TD: 10140 ftKB wt:26.00) Last Tag Date: 5/14/2006 Max Hole Angle: :::::::=002 Casing String - ALL CASINGS DescriDtion Size TOD Bottom TVD Wt Grade Thread PRODUCTION 7.000 0 9570 6305 26.00 L-80 BTC-MOD CONDUCTOR 16.000 0 115 115 62.58 H-40 WELDED SURFACE SURFACE 9.625 0 6567 4554 40.00 L-80 BTC-MOD (0-6567, PRODUCTION LINER 3.500 9416 10138 6648 9.30 L-80 EUE 8rd OD:9.625, Wt:40.00) Tubing String - TUBING Size 1 Top I Bottom I TVD 1 Wt I Grade 1 Thread 3.500 1 0 1 9452 I 6234 I 9.30 I L-80 1 EUE 8rd Perforations Summary Interval TVD I Zone I Status 1 Ft I SPF 1 Date Type Comment Gas Lift 9788 - 9824 I 6437 - 6458 I C-4 1 1 36 I 4 18/27/1999 IPERF 2.5 HC, DP, 180 dee. Dh MandreWawe 9834 - 9844 6464 - 6470 I C-4 1 1 10 1 10 18/27/1999 IPERF 2.5 HC, DP, 180 deg. ph 2 (5166-5167, Stimulations & Treatments OD:5.390) Interval Date TVDe Comment 9788 - 9844 11/9/2002 I FRAC Gas Lift MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Gas Lift Mfr Cmnt MandreWalve 1 3230 2612 CAMCO KBMM CAMCO GLV 1.0 BK 0.125 1290 11/15/200 3 (6594-6595, 2 5166 3734 CAMCO KBMM CAMCO GLV 1.0 BK 0.156 1316 11/15/200 OD:5.390) 3 6594 4570 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1339 11/17/200 4 7775 5262 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1327 11/15/200 5 8616 5749 CAMCO KBMM CAMCO GLV 1.0 BK 0.250 1420 11/14/200 6 9391 6198 CAMCO MMM CAMCO OV 1.5 RK 0.250 0 11/14/200 Other plugs, equip., etc.) . JEWELRY Gas Lift Depth TVD Type Description ID MandreWalve 502 502 NIP CAMCO DS niDDle 2.875 4 (7775-7776, 9410 6209 NIP CAMCO D nipple NO GO profile, ELMD @ 9413 ON SWS JEWL LOG 2.750 OD:5390) 9/21/99 9422 6216 SEAL BAKER 80-40 casing seal assembly 3.000 Gas Lift MandreWalve 5 (8616-8617, OD:5.390) Gas Lift MandreWalve 6 (9391·9392, OD:6.018) NIP (9410-9411, OD:4.500) - Perf , ~ -7- (9788-9824) {--- + FRAC -\;--- --\- (9788-9844) !- --J- Perf += ::3; (9834-9844) ~ =¢ -¡- --"- :j: Re: Direction Needed - Kuparuk lC-25 potential conversion to injection e e Sam, I don't believe we have met. I don't see major problems with what you propose. When the sundry application is submitted for the conversion, after the production period, a request for the exception to the packer depth can be made at that time. Getting the bond log is an important step in the overall plan. I did a look at the file we have and there are no detailed cementing reports regarding the 7" intermediate/production casing or the liner. Having detailed operations reports is also part of the review. An assessment of any well within 1/4 mile of the trajectory ofthe lateral will also need to be done. If the fault isolation is as you say, then the only well of concern would likely be 1 C-21. I suggest that you contact Pat Riley in drilling for some "assistance" on these requirements. He recently submitted a permit package for an injection well and worked through these matters. Also, just a little nomenclature. We at the AOGCC do not consider a well constructed like 1C-25 a monobore. In this case, the conventional construction involved using same-sized liner and tubing resulting in a mono diameter wellbore. The distinction may seem fine, however the monobore term has been applied to wells where the reservoir penetrating string is also the tubing string. 30-19 is one ofthe wells that comes to mind. Jerry Dethlefs or one of the other people at Problem Wells can provide further information on the distinction. Call or message with any questions. Nice reserve target. Tom Maunder, PE AOGCC Johnstone, Sam wrote, On 4/24/200610:34 AM: ¡¡;;:. c' ~ Î!l.jò.\¡:;n I} Dr:" 9 &:: 2006 ~'J\¡Jrul't~~¡-;;o;Ÿ t ijf J ~ f~' qJ Tom, We see an opportunity to increase pattern reserve recovery by converting Kuparuk 1 C-25 (C4-sand producer) to water and MI injection. Due to isolating faults, the 1 C-25/1 C-21 pattern does not receive and has not received water or MI injection support. The most recent measured reservoir pressure (PBU - December 2004) indicated that the 1 C-25 area reservoir pressure is approximately 1750 psi. To maximize pattern recovery, we recommend drilling a 2000' Coiled Tubing Drilling horizontal sidetrack (kicking out of the existing perforations), producing the well 6 to 12 months, and then converting to water and MI injection service. By drilling the sidetrack and converting 1 C-25 to an injection well, it is estimated that approximately 1000 MBO additional Waterflood and EOR reserves will be recovered. The concern with the project is that the existing casing liner seal assembly (well bore is a 3.5" monobore configuration) is located more than 200' MD above the top Kuparuk C4-sand perforation. (See the Table below.) Is it possible to receive an exception to this rule (20 MC 25.412 (b)) if verification of proper cement placement below the seal assembly and above the top perforation is established? We are currently looking at running a CBL to verify cement placement. Thanks for your help. Please let me know if you have any suggestions, Sam c- -..:-==-..::::".::...-.:~~~= __z~1 -- g~g,," r ~~r ~=~= 10[2 4/24/2006 1: 15 PM Re: Direction Needed - Kuparuk 1 C-25 potential conversion to injection e e 1 C -25 Depths Measured Depth, ft TVD, ft SSTVD, ft Seal Assem bly 9422 6216 6122 Top Kuparuk (D) 9743 6409 6315 Top Kuparuk (C4) 9781 6432 6338 Top Perf 9788 6437 6343 Sam Johnstone Office (907) 263-4617 Home (907) 746-5809 20[2 4/24/2006 1: 15 PM Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1 B-17 /q4 - 045" 1 E-36 /98-':;/.'? 3H-07 /B7-o7Q 3H-07" '" 2A-09 /ð!o-ffiJ 1A-10 IA/-II!)/) 2M-14 }q¿;)-I)/():2, 1 E-05 /9/)- [15R 2H-12 /f35-~'{¡)2 1 C-21 3G-18 /qO- /;)¿;;' 1 E-119 2U-13 leA-~4{¿; 1Y-09 /83-~ 1 E-1 05 2C-08 /B~ -oq5 2C-02 /R7:J-Ð93 1C-25 ¡QQ-C>31 2C-14 1134-;;(0 2C-10 /!!3~- Q/t 1A-18 ICJo- J5.~ 2C-01 IB!;- ()f;? 1 D-32 1)00-17 A 2C-12 184-~ 2C-15 184· ~6:2: 1J-154 1 E-1 04 Job # 11216283 11216282 11217023 11166757 11154126 11213710 11154127 11166747 11154128 11154131 11154129 11217025 11166753 11213128 11162832 11141255 11213129 11144074 11166759 11144067 11144070 11213709 11141252 11141260 11141254 N/A 11217024 j. ~...' # \ 1 ~ ß ~; ZGCCFEB 22. 2006 02/21/06 NO. 3691 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk e Date BL Color CD 02/18/06 1 02/18/06 1 02/11/06 1 01/20/06 1 02/09/06 1 02/08/06 1 02/10/06 1 12/25/05 1 02/11/06 1 02/14/06 1 02/12/06 1 02/13/06 1 01/14/06 1 02/06/06 1 01/28/06 1 e 01/28/06 1 02/07/06 1 02/02/06 1 01/25/06 1 01/26/06 1 01/29/06 1 02/07/06 1 01/25/06 1 02/02/06 1 01127/06 1 02/05/06 1 02/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to'(907) 561-8317. Thank you. ~~ ~,",'" ..'vil.>. .,..UIHIW:>SIOI, AjclXìf~e Log Description SBHP SURVEY SBHP SURVEY LDL STATIC SURVEY PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT/GHOST PRODUCTION PROFILE W/DEFT INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE MEMORY INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE GLS PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION LOG WITRACTOR INJECTION PROFILE ConoCOPhillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 27, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1C-25 (199-031) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1C-25. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader CPAI Drilling MM/skad 2002, RECEIVED DEC 1 1 2002 Alaska Oil. & Gas ~ns. Commission Anchomoe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _XX Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1691' FNL, 3950' FEL, Sec. 12, T11N, R10E, UM At top of productive interval 1490' FNL, 2025' FEL, Sec. 7, T11N, R11E, UM At effective depth At total depth 1491' FNL, 1740' FEL, Sec. 7, T11N, R11E, UM Perforate _ Other _ 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 562335, 5968546) (asp's 569457, 5968808) 6. Datum elevation (DF or KB feet) RKB 94 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 C-25 9. Permit number / approval number 199-031 / 10. APl number 50-029-22941 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 10140 feet Plugs (measured) 6649 feet Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURFACE 6473' PRODUCTION 9476' PRODUCTION LI 722' PRODUCTION LI Size 16" 9-5/8" 7" 3-1/2" 10001 feet Junk (measured) 6564 feet Cemented 9 cu yds High Early 796 sx ASIIIL, 653 sx Class G 180 sx Class G 180 sx Class G Measured Depth 115' 6567' 9570' 10138' True ve~icalDepth 115' 4554' 6305' 6648' Perforation depth: measured 9788' - 9804', 9804' - 9824', 9834'-9844' true vertical 6437' - 6446', 6446' - 6458', 6464' - 6470' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 9452' MD. Packers & SSSV (type & measured depth) No packer CAMCO DS @ 502' MD. RECEIVED DEC 1 1 2002 NasEa 0il & Gas Cons. C0mmissi0r, Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) 9788' - 9844' Treatment description including volumes used and final pressure pumped 137013# of 16/20 ceramic proppant 14. Prior to well operation Subsequent to operation OiI-Bbl 819 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 907 32 1491 1759 2O6 Casing Pressure Tubing Pressure 226 294 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Gas _ Suspended __ Service _Water Injector ... 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~. ~,,,W,t~ Michael Moone)/ Form 10-404 Rev 06/15/88 · "4 nl',,,IS BFL Title: Wells TeaCh Leader Questions? Call Mike Mooney 263-4574 Date Prepared by Sharon Al/sup-Drake 263-4612 II ~nno ~- LJL SUBMIT IN DUPLICATE Date Comment 1C-25 Event History 11/09/02 11/10/02 PUMPED FRACTURE TREATMENT WITH 137,013# OF 16/20 CERAMIC PROPPANT, USING 50# DELAYED X-LINK GEL. PLACED 134,781# PROP BEHIND PIPE WITH 10 PPA ON PERFS. FLUSH JOB WITH WATER/GEL AND 7 BBLS OF DIESEL. LEFT 2,232# PROP IN PIPE. [FRAC-REFRAC] POST FRAC CLEANOUT TO 10025' RKB USING 240 BBLS SLICK WATER AND 420 BBLS DIESEL ALONG WITH 500 SCFM NITROGEN THROUGHOUT THE JOB - WASHED GLM'S WHILE PULLING OUT OF HOLE. SHUT IN WELL FOR GL STRING [FCO] 11/13/02 11/14/02 11/15/O2 TAGGED FILL @ 10001' WLM. SET CATCHER SUB @ 9410' RKB. IN PROGRESS. [TAG] INSTALLED OV @ 9391' RKB, GLV @ 8616' RKB. LEFT OPEN GLM @ 7775' RKB. IN PROGRESS [GLV] COMPLETED GAS LIFT INSTALLATION. [GLV] Page I of I 11/25/2002 . Ms. Wendy Mahan AOGCC Second Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the second quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-19 33933 100 0 34033 Open, Freeze Protected 1C-25 34836 100 0 34936 Open, Freeze Protected 7- CD1-40 32777 100 0 32877 Open, Freeze Protected 1C-23 34470 100 0 34570 Open, Freeze Protected ~-' 1C-18 0 0 0 0 Open, Freeze Protected ? CD1-35 217 100 0 317 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Doug Chester Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files 199-031-0 KUPARUK RIV UNIT 1C-25 50- 029-22941-00 PHILLIPS ALASKA[NC Roll #1: Start: Stop Roll #2: Start Stop MD 10140 ~' TVD 06649v~Completion Dat.~"~5/27/99 Completed Status: 1-OIL Current: T Name Interval D 9333~ 1-4 SPERRY MPT/GR/EWR4/CNP/SLD L DGR/CNP/SLD-MDv// FINAL 9573-10140 L DGR/CNP/SLD-TVD///~INAL 6307-6648 L DGR/EWR4-MD .b/ FINAL 116-10140 L DGR/EWR4-TVD /x' R SRVY CALCO,,... R SRVY RPT d.,,/' FINAL 116-6648 BHI 0-10140. SPERRY 0-10140. Sent Received OH 9/23/99 9/28/99 OH 9/28/99 9/30/99 OH 9/28/99 9/30/99 OH 9/28/99 9/30/99 OH 9/28/99 9/30/99 OH 10/6/99 10/7/99 OH 5/4/99 5/6/99 T/C/D Wednesday, May 02, 2001 Page 1 of 1 ARCO Alaska, Inc. = Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 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, Third Quarter, 1999 Dear Ms. Mahan' Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Annttlar Injection during the third quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-25 I 520 100 0 620 34316 34936 CD1-40 I 20079 100 0 20179 12171 32350 CD1-01 I 4905 100 0 5005 0 5005 1C-23 . 24865 100 0 24965 9605 34570 0 ] 16719 CD1-23 16079 I 100 0 16179 I CD1-37 17173 100 0 17273 0 17273 CD1-39 i 3917 100 ~ 0 4017 ~ 0 4017 1D-12 ! 4305 [ 100 , 0 4405 ! 0 I 4405 Total Volumes into A/muli for which Injection Authorization E,,cpired during the quarter , Total Total h(1) Total h(3) Volume Well Name Volume Volume Total h(2) Volume ~ Injected 32640 Status of Annulus Open, Freeze Protected 1D-09 32540 i 100 0 2N-337A 30539 I 100 0 I 30639 Open, Freeze Protected 2N-313 32758 ' 100 0 Ii 32858 Open, Freeze Protected 2N-321A 27507 I 100 0 ] 27607 Open, Freeze Protected Please call me at 263-4603 should vou have any questions. Sincerely, Paul Mazzolini Drilling Team Leader 0il & Gas Cons. Commission ~ncn0ratla CC' Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two ARCO Alaska, Inc. -. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 6, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 C-25 (Permit No. 99-31) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 1C-25. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling ORIGINAL GCA/skad Naska 011 & ~88 Cons. O0mmissi0r, Anchorage STATE OF ALASKA ALASKA OIL AND GAS OONSERVATION OOMM~SSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~1 Gas BI Suspended r-1 Abandoned E~ Service 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-31 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22941 4. Location of well at surface i C,I'):'.~"~ ~-i't0~ '~ '~ 9. Unit or Lease Name 1693' FNL, 1327' FWL, Sec. 12, T11 N, R10E, UM : ...... ~ ;-, Kuparuk River Unit At Top Producing Interval; '-~-,/~,.~.~-.~: 1, ' 10. Well Number 1490' FNL, 2025' FEL, SEC 7, T11 N, R11 E, UM ¢V??'~ ~'~ '¢ !i~. 10-25 At Total Depth '.--~'~~-~ 11. Field and Pool 1494' FNL, 3170' FWL, SEC 7, T11 N, R11 E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Serial No. Kuparuk River Pool RKB 95 feet[ ADL 28242 ALK 2292 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. [15. Water Depth, if offshore 16. No. of Completions April 9, 1999 April 24, 1999 April 27, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10140' MD/6649' TVD 10039' MD/6587' TVD YES [~] I No N/A feet MD 1915' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FI-OM HOLE SIZE CEMENTING RECORD[ AMOUNT PULLED 16" 62.5# R-3 Surface 114' 24" 9 cu yds High Early 9.625" 29.7# L-80 Surface 6567' 12.25" 796 sx AS III L, 653 sx Class G 7" 26# L-80 Surface 9570' 8.5" 18o sx Class G 3.5" 9.3# L-80 9416' 10138' 6.125" 18o sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9452' 9416' 9788'-9804' MD 6437'-6446' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9804'-9824' MD 6446'-6458' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9834'-9844' MD 6464'-6470' TVD 4 spf 9788'-9824', 9834'-9844' 60M# in formation, 10 ppa on perfs, 1600# in wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 7, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/3/1999 12.0 Test Period > 460 65.5 43 176I 226 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 220 --- 24-Hour Rate > 920 131 86 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A ORIGINAL Anch0rag¢ =orm 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. $0. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 9781' 9989' 10140' 10140' TRUE VERT. DEPTH 6432' 6557' 6649' 6649' FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF A1-FACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Paul Mazzolini Drilling Team Leader Date Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Sh ut-in, Oth er-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 5/7/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-25 WELL_ID: AK0023 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:04/09/99 START COMP: RIG:POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22941-00 04/04/99 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD: 0' ( 0) PREP SUB BASE FOR MOVE TO lC PAD SUPV:DAVE BURLEY / SCOTT REYNOLDS Prep rig for move. UPCOMING OPERATIONS:MOVE RIG TO 1C-25 APIWL: 0.0 04/05/99 (D2) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 0' ( 0) MOVING RIG, BOTH MODULES @ CPF-2. SUPV:DAVE BURLEY / SCOTT REYNOLDS Move utility module to 2M pad. UPCOMING OPERATIONS:CONTINUE MOVING RIG TO lC PAD. 04/06/99 (D3) TD: 118' (118) SUPV:FRED HERBERT MW: 0.0 VISC: BEGIN MOVING TO lC PAD 0 PV/YP: 0/ 0 Continue to move rig. UPCOMING OPERATIONS:CONTINUE MOVE TO 1C-25 APIWL: 0.0 04/07/99 (D4) TD: 114'( 0) SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG UP DIVERTER LINE (STARTING HEAD TO HIGH ?) Move modules to lC pad. Rig up. UPCOMING OPERATIONS:RIG UP, P/U DP & TOOLS TEST DIVERTER 04/08/99 (D5) TD: 114'( 0) SUPV:FRED HERBERT MW: 10.0 VISC: 215 PV/YP: 55/64 PICK UP HWDP APIWL: 8.8 Continue to rig up. Nipple up diverter system. Electrical fire in truck shop, put out. Investigate casue. Rig accepted @ 0900 hrs. 4/8/99. Function test diverter. UPCOMING OPERATIONS:SPUD WELL, DRILL SURFACE 04/09/99 (D6) TD: 287' (173) SUPV:FRED HERBERT MW: 9.8 VISC: 287 PV/YP: 59/71 DRILLING AHEAD ~ 630 APIWL: 6.8 Hold pre-spud safety meeting. Drilling 12.25" hole from 114' to 287' High volume of gravel coming back. TIH bridge @ 220' Ream to bttm. UPCOMING OPERATIONS:DRILL AHEAD, SHORT TRIP Date: 5/7/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/10/99 (D7) TD: 2105'(1818) SUPV:FRED HERBERT MW: 10.2 VISC: 175 PV/YP: 31/47 WIPER TRIP APIWL: 6.9 Drilling 12.25" hole from 287' to 2105' UPCOMING OPERATIONS:DRILL AHEAD, BIT TRIP, DRILL TO TD 04/11/99 (D8) TD: 4153' (2048) SUPV:FRED HERBERT MW: 10.2 VISC: 80 PV/YP: 24/36 APIWL: 6.2 DRILLING AHEAD, DEPTH @ 0600 HRS, 4850' NOTE: MAX GAS UNIT Drilling 12.25" hole from 2105' to 2547' Pump hi density sweep around for wiper trip, pump slug. POOH to 1152' (swabbed from 2450' to 2175'). Drilling 12.25" hole from 2547' to 4153'. UPCOMING OPERATIONS:DRILL, TRIP FOR BIT , DRILL TO CASING POINT 04/12/99 (D9) TD: 5258'(1105) SUPV:FRED HERBERT MW: 10.3 VISC: 70 PV/YP: 24/32 DRILLING AHEAD, DEPTH 5480' APIWL: 6.2 Drilling 12.25" hole from 4153' to 5258' Pump hi density, hi vis sweep around for bit trip. Pump slug. TOH for bit, work pipe, swabbing. Tight 8 4120' Change bit. TIH. UPCOMING OPERATIONS:DRILL TO CASING POINT 04/13/99 (D10) MW: 10.2 VISC: 81 PV/YP: 25/30 APIWL: 6.2 TD: 6580'(1322) L/D BHA SUPV:FRED HERBERT & SCOTT REYNOLDS RIH. Tight from 4020' to 4050' and from 4480'-4510' CBU before drilling. Drill from 5258'-6580' Circulate. Notice large mud loss after picking pipe up 90' Mud was spotted coming out of cellar. Shut down pumps and sound spill alarm. Start spill clean up. UPCOMING OPERATIONS:CEMENT CONDUCTOR 04/14/99 (Dll) MW: 10.2 VISC: 71 PV/YP: 17/26 APIWL: 7.6 TD: 6580'( 0) CONTINUE TO RIH W/HO TO 6580' SUPV:FRED HERBERT & SCOTT REYNOLDS POOH (work thru tight spot from 700' to 600' Pump 20 bbl hi vis pill from 186' to 114' Pump cement. No cement returns to cellar however there were constant mud returns to cellar. Tag cement @ 110' Circulate out contaminated mud and drill cement from 110' to 135' Wash down to 190' to circulate out hi vis pill and contaminated mud. UPCOMING OPERATIONS:CIRC AND CONDITION MUD FOR RUNNING 9-5/8" CASING Date: 5/7/99 ARCO ALASKA INC. Page: 3 WELL SUMMARY REPORT 04/15/99 (D12) MW: 10.2 VISC: 75 PV/YP: 20/14 APIWL: 5.8 TD: 6580'( 0) CIRCULATING AND CONDITIONING MUD FOR CEMENT JOB SUPV:FRED HERBERT & SCOTT REYNOLDS Weight mud up to 10.2 before holeopen run. Circulate out thick mud. RIH. No fill. No tight spots to work thru. Pump hi vis hi den sweep. PJSM. Run 9-5/8" casing. UPCOMING OPERATIONS:CEMENT 9-5/8" SURFACE STRING 04/16/99 (D13) MW: 8.3 VISC: 0 PV/YP: 35/ 0 APIWL: 0.0 TD: 6580'( 0) TEST BOP'S SUPV:FRED HERBERT & SCOTT REYNOLDS Run 9-5/8" casing. Pump cement. NU BOPE. UPCOMING OPERATIONS:TIH, P/U DP. DRILL CEMENT, CIT, LOT. 04/17/99 (D14) MW: 8.8 VISC: 38 PV/YP: 9/10 APIWL: 9.5 TD: 6589' 9) DRILLING @ 6900' NOTE: RIG & CAMP ON HIGH LINE POWER FOR T SUPV:FRED HERBERT & SCOTT REYNOLDS NU 13-5/8" BOPE and test to 300/3000 psi. Clean out cement from 6216' to 6450' Solid cement @ 6365' Circ out cement cont. mud. Drilling cement. Float equip. Drilling 8.5" hole from 6580' to 6589' UPCOMING OPERATIONS:DRILL TO CASING POINT, SHORT TRIP AS NEEDED, OPEN HOLE LOT 04/18/99 D15) MW: 9.0 VISC: 41 PV/YP: 11/18 APIWL: 7.0 TD: 8444' 1855) DRILLING @ 8507' SUPV:FRED HERBERT & SCOTT REYNOLDS Drilling from 6589' to 6600'. Change over to LSND mud. Perform FIT to 15.9 ppg calculated. Drilling from 6600' to 8444' UPCOMING OPERATIONS:TD INTERMEDIATE HOLE, SHORT TRIP, RUN 7" CASING. 04/19/99 (D16) MW: 9.3 VISC: 45 PV/YP: 13/21 APIWL: 4.4 TD: 9573' (1129) WEIGHT UP TO 10.0 PPG SUPV:FRED HERBERT & SCOTT REYNOLDS Drilling from 8444' to 8465' Circulate hi vis/hi den sweep around. CBU. Drilling from 8465' to 9573'. CBU. Perform LOT to 12.3 ppg EMW. UPCOMING OPERATIONS:10 STAND SHORT TRIP, CBU 04/20/99 (D17) MW: 10.3 VISC: 44 PV/YP: 17/ 0 APIWL: 3.6 TD: 9573'( 0) MONITOR WELL AT SHOE, STATIC. SUPV:D.P. BURLEY / RICK OVERSTREET Perform LOT, 12.3 ppg EMW. Circ and cond mud, had 4100 units of gas @ BU. Increase mud weight to 10.3 ppg. Monitor well, static. UPCOMING OPERATIONS:FINISH POH. RUN 7" CASING. Date: 5/7/99 ARCO ALASKA INC. Page: 4 WELL SUMMARY REPORT 04/21/99 (D18) MW: 10.3 VISC: 45 PV/YP: 18/17 APIWL: 4.0 TD: 9573' ( 0) CEMENTING 7" CASING. SUPV:D.P. BURLEY / RICK OVERSTREET Run back in hole to 9573' No problem. Circulate bottoms up. Max 100 units gas. Increase mud weight to 10.3, monitor well, pumped dry job. PJSM. Run 7" casing. UPCOMING OPERATIONS:SET SLIPS ON CASING. NU. MAKE BHA #5, PICK UP 3-1/2" DRILL PIPE. 04/22/99 (D19) MW: 10.5 VISC: 45 PV/YP: 16/20 APIWL: 4.6 TD: 9573'( 0) PICKING UP 3-1/2" DRILL PIPE, RIH. SUPV:D.P. BURLEY / RICK OVERSTREET Finish running 7" casing. PJSM. Pump cement. NU BOP and test to 250/5000 psi. UPCOMING OPERATIONS:CONTINUE TO PICK UP 3-1/2" DP. TEST CASING, CLEAN OUT, L.O.T. 04/23/99 (D20) MW: 11.5 VISC: 62 PV/YP: 30/35 APIWL: 3.8 TD: 9573'( 0) DRILLING AHEAD @ 9680' SUPV:D.P. BURLEY / RICK OVERSTREET Clean out cement from 9440' to 9573' Drill from 9573' to 9576' UPCOMING OPERATIONS:TD PRODUCTION HOLE, SHORT TRIP. RUN 3-1/2" LINER. 04/24/99 (D21) MW: 11.5 VISC: 57 PV/YP: 29/34 APIWL: 4.2 TD:10140' ( 567) COMPLETE POOH W DRILL PIPE AND LD BHA. SUPV:D.P. BURLEY / RICK OVERSTREET Displace mud to 11.5. Drill from 9576' to 9593' FIT 16.4 EMW. Drill from 9593' to 10140' TD. UPCOMING OPERATIONS:RUN 3-1/2" LINER AND CEMENT. 04/25/99 (D22) MW: 11.5 VISC: 52 PV/YP: 26/16 APIWL: 5.0 TD:10140' ( 0) CHANGE WELL OVER TO SEAWATER. SUPV:D.P. BURLEY / RICK OVERSTREET PJSM. Ran 3.5" liner. UPCOMING OPERATIONS:LAY DOWN DRILL PIPE, RUN 3-1/2' COMPLETION. 04/26/99 (D23) MW: 8.6 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD:10140' ( 0) CHANGING OVER WITH CLEAN SEAWATER. SUPV:D.P. BURLEY / RICK OVERSTREET PJSM. Pump cement. Displaced high vis pill and mud. Run 3.5" completion. UPCOMING OPERATIONS:TEST TUBING AND CASING. FREEZE PROTECT AND LAND 3-1/2" COMPLETION. ND, INSTALL WELLHEAD EQUIPMENT. 04/27/99 (D24) TD:10140' ( 0) SUPV:D.P. BURLEY MW: 8.6 VISC: 28 PV/YP: 0/ 0 SLIP AND CUT DRILLING LINE. APIWL: 0.0 PJSM. Run 3.5" completion tubing. Freeze protect well. ND BOPE. UPCOMING OPERATIONS:INSTALL AND TEST TREE, MOVE RIG TO UPCOMING OPERATIONS:INSTALL AND TEST TREE, MOVE RIG TO 1C-23. 04/28/99 (D25) TD:10140' ( 0) SUPV:D.P. BURLEY MW: 8.6 VISC: 28 PV/YP: 0/ 0 RELEASED RIG @ 0900 HOURS. APIWL: 0.0 Install tree and test to 5000 psi. Released rig @ 0900 hrs 4/28/99. UPCOMING OPERATIONS: MOVE Date 09/03/99 Well Na 1C-25 Service Type ELECTRIC LINE Upcoming Desc of Work 2 1/2" HSD 4 SPF PERFORATE Supervisor KRALICK Complet r~ Accident C Idury F Spill P Summary F Job Num 0516991532,6 Unit 2128 Contractor Key Perso SWS-JOHNSON Successful I~ initial Tbg Press 1000 Initial Int Csg Press 700 Initial Out Csg Press 600 PERFORATED: 9788-9804 & 9834-9844 USING 2.5" HC DP 4 SPF AFC 999321 0 Prop 230DS10C Uploaded to Sen Final Tbg Press 1000 Final Int Csg Press 700 Final Out Csg Press 600 Date printed: 09/21/99 at: 09:18:09 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT ~' K1(1C-25(W4-6)) WELL JOB SCOPE JOB NUMBER '~' 1 C-25 DRILLING SUPPORT-CAPITAL 0516991532.6 DATE DAILY WORK UNIT NUMBER 09/02/99 2 1/2" HSD PERFORATE 2128 DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 2 NOI NO SWS-JOHNSON KRALICK FIELD AFC# CC# Signed ESTIMATE 999321 230DS10CG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 1000 PSI 600 PSI 700 PSII 500 PSII 500 PSI DAILY SUMMARY PERFORATED: 9804-9824, 4 SPF, HOLLOW CARRIER DP W/180 DEGREE PHASING TIME LOG ENTRY 08:00 ARRIVE LOC SWS UNIT 2128 09:30 HOLD SAFTEY MEETING 10:10 PRESSURE TEST BOP/RISER TO 3000# 10:20 RIH WITH HEAD/SWIVEL/PGGT/MPD/ESIC/20' GUN 11:15 TIE INTO SPERRY DGR/EWR4/ROP LOG DATED 4/25/99 11:40 RUN GR/CCL TIE IN/JEWELRY LOG - GUN STUCK AT 9975', TOOK 900# PULL OVER NORMAL TO GET FREE 12:20 BLEED WHP TO 20# 12:45 SHOOT 9804-9824, NO INDICATION OF GUN FIRING 12:50 POOH 13:55 GUN DID NOT FIRE - REMOVE GR AND RERUN GUN 14:40 RIH WITH HEAD/SWIVEL/MPD/ESIC/20' GUN 15:43 SHOT 9804-9824, WHP= 30# BEFORE AND 900# AFTER FIRING 17:00 AT SURFACE, ALL SHOTS FIRED, RIG DOWN 18:00 LEAVE EQUIP SPOTTED - FINISH PERFORATING IN AM ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~. WELL SERVICE REPORT '~' K1(1C-25(W4-6)) WELL JOB SCOPE JOB NUM'BER ' " 1C-25 FRACTURING. 0927991848.11 DATE DAILY WORK UNIT NUMBER 09/27/99 C SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-GALLEGOS ODELL FIELD AFC# CC# Signed ESTIMATE 999321 230DS10CG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1085 PSI 1100 PSI 1000 PSI 500 PSII 375 PSII 375 PSI DAILY SUMMARY IPUMPED C SAND FRACTURE TREATMENT, FLUSHED TO COMPLETION. 60M# IN FORMATION, 10 PPA ON PERFS. 1600# IN WELLBORE. [Frac-Refrac] TIME LOG ENTRY 09:00 DS ON LOCATION, RIG UP EQUIPMENT. SAFETY MEETING (SNOW, JOB REVIEW). PRIME UP PUMPS, SET TREE SAVER, PT LINES TO 9500 PSI, GOOD TEST. 12:25 PUMP BREAKDOWN, 145 BBLS 20# LINEAR GEL. SAW GOOD PRESSURE BREAK-BACK, PERFORM STEP- DOWN TEST, ISIP = 1716 PSI. FG = 0.7, XW FRIC = 620 PSI @ 20 BPM. 12:40 PUMP SCOUR STAGE, 75 BBL PAD, 40 BBL 1 PPA SCOUR, 137 BBL FLUSH. PERFORM SDT, ISlP = 1749 PSI, FG = .71, XS FRIC = 374 PSI. 13:00 PUMP DATAFRAC, 100 BBL 50# XL GEL, 87 BBL 20# LINEAR FLUSH. ISlP = 1980, CLOSURE TIME = 6.1 MINUTES, CLOSURE PRESSURE = 1730 PSI, FG =.7. GO WITH JOB AS DESIGNED. 14:00 PUMP PROPPANT STAGES, 60,600# IN 2-10 PPA STAGES. FLUID = 558 BBLS FLUSHED TO COMPLETION. 1690# PROPPANT IN WELLBORE, 10 PPA ON PERFS. 14:35 SHUT-DOWN, MONITOR PRESSURE. TOTAL FLUID PUMPED = 1153 BBLS. 15:00 RIG DOWN DS. ALL TREESAVER CUPS RECOVERED. 16:00 WELL SECURED. A.~chora~¢, SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-04464 Sidetrack No. Page 1 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. POOL- 6 Field KUPARUK RIVER UNIT Well Name & No. PAD 1C/25 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. WELL DATA Target-l-VD .............................. !FT) ........... TargetCoord, N/S ..................... SlotCoord. N/S ___-..1_6._9~3.0__0- ..... Grid Correction ...... _0_._00.0__ ........ Depths Measured From: RKB_~i MSLi.i.i SSI~i! Target Description Target Coord, EAN Slot Coord. E/W 1327.00 Magn, Declination 27.260 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: lOOft[~ 30m[~ lOm~ Vert. Sec. Azim, 88,16 Magn, to Map Corr, 27,260 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~-r) (DD) (DD) (FI') (ET) (F'T) (F'I-) (Per 100 FT) Drop (-) Left (-) 0,00 0,00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT ,' . '1 O-APR-99 MWD 206,12 0,51 306.29 206,12 206.12 -0.72 0.54 -0.74 0,25 0.25 9 1/2" M1C SET @ 1.4 AKO 1 O-APR-99 MWD 288,53 0,59 290,71 82.41 288.52 -1.40 0.91 -1.43 0.20 O. 10 1 O-APR-99 MWD 376.26 0.63 235.18 87,73 376.25 -2.22 0.79 -2.25 0,65 0.05 1 O-APR-99 MWD 466.81 0.99 82.28 90.55 466.80 -1.86 0.62 -1,88 1.74 0.40 ALL SLIDE 1 O-APR-99 MWD 557.89 2.64 90.12 91.08 557.83 1.02 0.72 0.99 1.83 1.81 65' lO-APR-99 MWD 649.49 5,96 73.45 91.60 649.16 7.73 2.07 7.66 3.84 3.62 -18.20 90' 1 O-APR-99 MWD 739,18 10,16 65.39 89.69 737,95 19.53 6.69 19.32 4.84 4.68 -8.99 65' lO-APR-99 MWD 822.94 12.73 65.88 83.76 820.03 34.88 13.54 34.47 3.07 3.07 0.59 65' lO-APR-99 MWD 916,76 14.40 68.68 93.82 911.23 55.45 22.01 54.77 1.9t 1.78 2.98 45' lO-APR-99 MWD 1006.50 16.54 72.59 89.74 997.72 78.28 29.89 77.36 2.65 2.38 4.36 50' 1 O-APR-99 MWD 1091.22 19,34 79.69 84.72 1078.32 103.78 36.01 102.67 4.19 3.3i 8.38 60' 1 O-APR-99 MWD 1186.39 21,09 84.47 95.17 1167.63 136.46 40.48 135.23 2.53 1.84 5.02 50' i" 1 O-APR-99 MWD 1279.07 22,37 86.59 92.68 1253,73 170.73 43.13 169.43 1.62 1.38 2.29 50' ,__ 1 o-APR-99 MWD 1372.83 25.00 87,12 93.76 1339.58 208.38 45.19 207.03 2.81 2.81 0.57 55' -- 1 O-APR-99 MWD 1465,17 27,44 88.74 92.34 1422.42 249.17 46.64 247.80 2,75 2.64 1.75 55' 1 O-APR-99 MWD 1557.25 28.72 89.43 92.08 1503.66 292.51 47.33 291.14 1.43 1.39 0.75 55' lO-APR-99 MWD 1648.63 31,34 89.07 91.38 1582.76 338.22 47.93 336.86 2.87 2.87 -0.39 65' 1 O-APR-99 MWD 1743.93 34.15 88.90 95.30 1662.91 389.76 48.85 388.39 2.95 2.95 -0.18 55' lO-APR-99 MWD 1836.04 36.61 87.03 92.11 1738.01 443.08 50.77 441.68 2.92 2.67 -2.03 55' , lO-APR-99 MWD 1930.02 39.22 87.87 93.98 1812.14 500.82 53.32 499.37 2.83 2.78 0.89 55' 1 O-APR-99 MWD 2025.19 42.83 85.27 95.17 1883.94 563.24 57.11 561.70 4.20 3.79 -2.73 55' 11-APR-99 MWD 2120.69 45.82 87.00 95.50 1952.25 629.92 61.58 628.27 3.38 3.13 1.81 45' 11-APR-99 MWD 2213,86 48,80 85.74 93.17 2015.42 698.36 65.93 696.60 3.35 3.20 -1.35 50' I · i B.A3f.F.R SURVEY CALCULATION AND' FIELD WORKSHEET Job No. 0451-04464 Sidetrack No. Page 2 of 5 -' [1:4 -'1:~;-~ Company ARCO ALASKA, INC. Rig Contractor & No, POOL -6 Field KUPARUK RIVER UNIT Well Name & No. PAD 1C/25 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD, WELL DATA Target 'I'VD ......................... .(_F_'O_ ................. Target Coord. N/S .................. Slot Coord. N/S ...... _-._1.6_9_3_,._0_0' .... Grid Correction ...... _0.0__0__0_ ............ Depths Measured From: RKB ~i MSL i_.i SS{__ Target Description ............................ Target Coord, ERV ................. Slot Coord, ERV 1327,00 Magn, Declination 27,260 Calculation Method MINIMUM CURVATURE Target Direction (DC}) Build\Walk\DL per: lOOft~ 30m~ lOm~ Vert, Sec, Azim, 88,16 Magn, to Map Corr, 27.260 Map North to: OTHER ,= SURVEY DATA I- survey survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FI') (F'l) (FT') (F'I) (Per lO0 FT) Drop (-) Left (-) 11 -APR-99 MWD 2307.00 52.38 87.18 93.14 2074.54 770,27 70,35 768,41 4.02 3.84 1.55 50' 11-APR-99 MWD 2400.98 53.07 86.33 93.98 2131.46 845.03 74.59 843.07 1.03 0.73 -0,90 15' .__ 11 -APR-99 MWD 2489.49 54.42 87,38 88.51 2183.80 916.38 78.50 914,34 1,80 1.53 1.1 9 20' 11 -APR-99 MWD 2587.98 54,04 85.28 98.49 2241.38 996.25 83.61 994.08 1.77 -0.39 -2.13 11 -APR-99 MWD 2682.51 53.62 85.80 94.53 2297,17 1072.48 89.54 1070,16 0.63 -0.44 0.55 -- 11-APR-99 MWD 2774.30 55.73 86.51 91.79 2350.24 1147.32 94.56 1144.87 2,38 2.30 0.77 35' 11 -APR-99 MWD 2868.17 55.20 87,34 93.87 2403,45 1224.63 98,71 1222.09 0.92 -0.56 0.88 11 -APR-99 MWD 2960.35 54.19 86.21 92.18 2456.73 1299.83 102,94 1297,19 1.48 - 1,10 -1.23 11 -APR-99 MWD 3057,12 55,41 87.87 96.77 2512.51 1378,88 107.01 1376.16 1,89 1.26 1.72 35' 11 -APR-99 MWD 3150,76 54.69 87.43 93.64 2566,15 1455.63 110.16 1452.84 0.86 -0.77 -0,47 11 -APR-99 MWD 3244.75 54.25 87,24 93.99 2620.77 1532.11 113.71 1529.25 0.50 -0,47 -0,20 11 -AP R-99 MWD 3337.59 53,57 87.42 92.84 2675.46 1607.13 117.21 1604.19 0.75 -0.73 O, 19 11 -APR-99 MWD 3432,03 52.94 88,28 94.44 2731.96 1682.80 120.05 1679.81 0.99 -0.67 0,91 11 -APR-99 MWD 3528,35 55,71 89.61 96,32 2788,13 1761.03 121,47 1758,03 3,09 2,88 1,38 40' ~" 11 -APR-99 MWD 3622,54 55,14 89,77 94,19 2841,58 1838,55 121,89 1835,59 0,62 -0,61 O, 17 11 -APR-99 MWD 3715,51 54,63 89,40 92.97 2895,06 1914,58 122,45 1911,63 0,64 -0,55 -0,40 11 -AP R-99 MWD 3812,82 54,10 89,68 97,31 2951,75 1993,64 123.08 1990.72 0,59 -0,54 0,29 11 -APR-99 MWD 3907,46 53.56 88,98 94,64 3007,61 2070.03 123,97 2067,11 0,83 -0,57 -0,74 11-APR-99 MWD 4002,47 56,41 89,15 95,01 3062,12 2147,82 125,24 2144,91 3,00 3.00 0,18 35' 11 -APR-99 MWD 4096,16 55,84 88,97 93,69 3114,34 2225,60 126,52 2222,68 0,63 -0,61 -0,19 12-APR-99 MWD 4189,15 55,19 89,12 92,99 3166,99 2302,24 127,79 2299,32 0,71 -0,70 0.16 12-APR-99 MWD 4274.92 54,67 90,04 85,77 3216,27 2372,41 128,31 2369,52 1,07 -0,61 1,07 12-APR-99 MWD 4374,84 53,74 89,32 99,92 3274,71 2453,43 128,76 2450,56 1,10 -0,93 -0,72 12-APR-99 MWD 4467,49 55,88 89,47 92.65 3328.10 2529,13 129,56 2526,27 2,31 2,31 0,16 35' i ~ I'- [1~ -'l =~! Company ARCO ALASKA, INC. Rig Contractor & No. POOL- 6 Field KUPARUK RIVER UNIT ! Well Name & No. PAD ........ 1C/25 Survey Section Name Definitive Survey.. BHI Rep. ROBBY BARNARD. WELL DATA Target TVD ................... _(_F_'T). ............ Target Coord. N/S ......................... Slot Coord. N/S ........ -_!_6_93_:...0_0 ......... Grid Correction ...... 0.._00.0_ ......... Depths Measured From: RKB ~Target Description Target Coord. E/W Slot Coord. E/W 1327.00 Magn. Declination 27.260 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10OftE~ 30m~ 10m~ Vert. Sec. Azim. 88.16 Magn. to Map Corr. 27.260 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'I) (DB) (OD) (FT) (F'F) (F-T) (FT) (Per 100 FT Drop (-) Left (-) -- 12-APR-99 MWD 4564.03 55.27 89.58 96.54 3382.68 2608,74 130,22 2605.90 0.64 -0.63 0.11 , 12-A PR-99 MWD 4657.99 55.12 89.56 93.96 3436,31 2685.86 130.80 2683,05 O. 16 -0.16 -0.02 -- 12-APR-99 MWD 4746.66 54,63 89.60 88.67 3487.33 2758.36 131.33 2755.57 0.55 -0.55 0.05 -- 12-APR-99 MWD 4842.94 54.03 89.25 96.28 3543.47 2836.56 132.11 2833.78 0.69 -0.62 -0.36 12-APR-99 MWD 4936.93 52.93 90.06 93.99 3599.40 2912.07 132.57 2909.31 1.36 -1,17 0,86 -- 12-APR-99 MWD 5026.13 54.81 89.19 89.20 3652.00 2984.08 133.05 2981.35 2.25 2.11 -0.98 40' 12-APR-99 MWD 5121.59 54.03 89,01 95,46 3707.54 3061.71 134.27 3058.98 0.83 -0.82 -0.19 12-APR-99 MWD 5217.24 53.36 89.87 95.65 3764,17 3138.77 135.02 3136.05 1.01 -0,70 0,90 13-APR-99 MWD 5311.56 56,00 89,06 94.32 3818.70 3215,70 135.75 3213.00 2.89 2,80 -0.86 35' NEW BIT MXCl 13-APR-99 MWD 5404,81 55.49 88.93 93,25 3871.19 3292.77 137.10 3290.07 0,56 -0.55 -0.14 13-APR-99 MWD 5499.16 55.08 88.90 94.35 3924.92 3370,32 138.57 3367.61 0.44 -0,43 -0.03 13-APR-99 MWD 5591.49 54.30 88,22 92.33 3978,28 3445.66 140.46 3442.93 1.04 -0.84 -0.74 13-APR-99 MWD 5686.89 53.85 88.10 95.40 4034.26 3522.91 142.94 3520.14 0.48 -0,47 -0.13 , 13-A PR-99 MWD 5780,86 53.50 88.06 93.97 4089.92 3598.62 145.48 3595.81 0.37 -0.37 -0.04 13-APR-99 MWD 5870,35 52.71 87.70 89.49 4143,65 3670.19 148.13 3667.32 0.94 -0.88 -0.40 13-APR-99 MWD 5965.45 54.52 88.59 95.10 4200.06 3746.75 150.60 3743.84 2,05 1.90 0.94 35' 13-A PR-99 MWD 6057,62 54.28 88.11 92.17 4253.71 3821.69 152.76 3818.75 0.50 -0.26 -0.52 13-APR-99 MWD 6147,96 53.61 87.68 90.34 4306.88 3894.72 155,44 3891.74 0.84 -0,74 -0,48 13-APR-99 MWD 6244.06 52.91 87.52 96.10 4364.37 3971.73 158.66 3968,68 0.74 -0.73 -0.17 13-APR-99 MWD 6338.39 55,02 88.00 94.33 4419.86 4048.00 161.64 4044.90 2,27 2,24 0.51 35' 13-APR-99 MWD 6431.52 54,36 88.23 93,13 4473.69 4124.00 164.14 4120,85 0.74 -0.71 0.25 13-APR-99 MWD 6525.16 53.65 87.60 93.64 4528.72 4199,76 166.89 4196,56 0,93 -0,76 -0.67 18-APR-99 MWD 6619.88 53.15 86.58 94.72 4585.20 4275.79 170,75 4272.51 1,01 -0.53 -1.08 18-APR-99 MWD 6712,90 52,59 87.87 93.02 4641.35 4349,94 174.34 4346,58 1.26 -0.60 1.39 ..... i SURVEY CALCULATION AND FIELD WORKSHEET ~ i Job No. 0451-04464 Sidetrack No. Page 4 of 5 ,~1 Company ARCO ALASKA, INC. Rig Contractor & No. POOL - 6 Field KUPARUK RIVER UNIT Well Name & No. PAD 1C/25 Survey Section Name Definitive Su_rveY BHI Rep. ROBBY BARNARD. WELL DATA Target'FVD ...................... (_F?_ .............Target Coord. N/S .................. Slot Coord. N/S -1693.00 Grid Correction ........ 0.000 Depths Measured From: RKB ~ MSL!,ii SSE Target Description .... Target Coord. E/W Slot Coord. E/W 1327.00 Magn. Declination 27.260 Calculation Method MINIMUM CURVATURE Target Direction (BD) Build\Walk\DL per: 100ft~ 30m~ lOmE~ Vert. Sec. Azim. 88.16 Magn. to Map Corr. 27.260 Map North to: OTHER I ' SURVEY DATA - _ Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type . (FT) (DD) (DD) (FT) (FI') (FT) (FT) (Per ~00 F-r)Drop (-) Left (-) 18-APR-99 MWD 6808.83 54,90 88.12 95.93 4698.07 4427.29 177.05 4423,88 2.42 2.41 0.26 30' ,,,' 18-APR-99 MWD 6901.49 ' 54.85 87.89 92.66 4751,39 4503,07 179.69 4499.62 0.21 -0.05 -0.25 18-APR-99 MWD 6997.01 54.59 88.20 95,52 4806.56 4581,05 182,35 4577.55 0.38 -0.27 0.32 18-AP R-99 MWD 7093.33 54.20 87.26 96.32 4862.63 4659.36 185,45 4655.80 0.89 -0.40 -0.98 18-APR-99 MWD 7184.26 53.85 87.45 90,93 4916.05 4732,94 188.84 4729.31 0.42 -0.38 0,21 18-APR-99 MWD 7277.81 53.43 88.65 93,55 4971.51 4808.27 191.41 4804,60 1.13 -0.45 1,28 18-AP R-99 MWD 7372.41 53.12 87.20 94,60 5028.08 4884.09 194.15 4880,37 1.27 -0.33 -1.53 -- 18-APR-99 MWD 7466.55 55,19 89.59 94.14 5083.21 4960.39 196.27 4956.64 3.01 2.20 2.54 35' 18-APR-99 MWD 7562.35 54.78 87.94 95,80 5138.18 5038.84 197.96 5035.08 1.47 -0.43 -1.72 18-APR-99 MWD 7655.03 54,64 88,41 92.68 5191.73 5114.49 200.37 5110.69 0.44 -0.15 0.51 18-AP R-99 MWD 7748.17 54,17 88,01 93.14 5245.94 5190.22 202.73 5186.39 0.61 -0.50 -0.43 18-APR-99 MWD 7843.09 53.95 89,56 94.92 5301.65 5267.06 204.36 5263.22 1.34 -0,23 1.63 18-APRL99 MWD 7935.87 53.58 87.95 92,78 5356.50 5341,89 205,99 5338.03 1.46 -0.40 -1.74 , ~., 18-APR-99 MWD 8028,99 56.11 89.68 93.12 5410.11 5418.01 207.54 5414,14 3.11 2.72 1.86 35' 18-APR-99 MWD 8123.05 55.89 89.76 94.06 5462.71 5495.96 207.92 5492.12 0.24 -0.23 0.09 18-APR-99 MWD 8216.81 55.32 91.31 93.76 5515.68 5573,26 207.20 5569.48 1,49 -0.61 1.65 18-APR-99 MWD 8310.00 54.86 90.24 93.19 5569,01 5649.60 206.17 5645,89 1.06 -0.49 -1.15 18-APR-99 MWD 8403,81 54.29 91.09 93.81 5623.39 5725,97 205.28 5722.33 0,96 -0.61 0.91 19-APR-99 MWD 8496.29 53.84 89.55 92,48 5677.66 5800.79 204,86 5797.20 1,43 -0.49 -1.67 19-APR-99 MWD 8590.42 53.14 89.69 94.13 5733,67 5876.42 205.36 5872,85 0,75 -0.74 O. 15 .. 19-APR-99 MWD 8685.34 55.51 90,10 94,92 5789.02 5953,49 205,50 5949.96 2.52 2.50 0.43 35' 19-APR-99 MWD 8778.03 55.53 89.27 92,69 5841,49 6029,87 205.92 6026.36 0.74 0.02 -0.90 19-APR-99 MWD 8870,34 55.18 91.24 92,31 5893.97 6105.75 205.59 6102.30 1.80 -0.38 2.13 19-APR-99 MWD 8964.79 55.06 88.54 94.45 5947,99 6183,19 205.73 6179.77 2.35 -0.13 -2,86 i [~~~; ~ SURVEY CALCU L~T~ON AN D F~ELD WOR KSH EET Job No, 0451.04464 Sidetrack NO.Rig - F~eld KUPARUK RIvERPage 5 of 5UNIT [~,"~1 Company ARCO ALASKA, INC. Contractor & No. POOL 6 Well Name & No. PAD 1C/25 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. WELL DATA Target TVD ...................... ._(_F~_ .................. Target Coord. N/S Slot Coord. N/S ..... -_1_69_3.__0_0 ...... Grid Correction 0.000 Depths Measured From: RKB ~-] MSL~] SSll Target Description ........................... Target Coord. E/W Slot Coord. E/VV 1327.00 Magn. Declination 27.260 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mE~ 10m~ Vert. Sec. Azim. 88.16 Magn. to Map Corr. 27.260 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'T) (F-T) (FT) (FT) (Per lO0 FT) Drop (-) Left (-) 19-APR-99 MWD 9057.84 54.57 89,45 93.05 6001.61 6259.23 207.07 6255.80 0,96 -0.53 0.98 ,., 19-AP R-99 MWD 9150.64 54.10 90,65 92,80 6055,72 6334,58 207.01 6331.19 1.17 -0.51 1.29 . 19-APR-99 MWD 9244.01 53.90 91,25 93.37 6110.60 6410.02 205.75 6406.72 0,56 -0.21 0.64 19-APR-99 MWD 9338.47 53.47 90.47 94.46 6166.54 6486.05 204.61 6482.82 0,81 -0.46 -0.83 19-APR-99 MWD 9430.55 53,18 90.64 92.08 6221.54 6559.84 203,90 6556.67 0.35 -0.31 0.18 19-APR-99 MWD 9510.00 52.78 90.17 79.45 6269.37 6623.22 203.45 6620.11 0.69 -0.50 -0.59 24-APR-99 MWD 9601.40 53.33 88.86 91.40 6324.31 6696.25 204.07 6693.15 1.29 0.60 -1.43 4 3/4"M1XL-AKO-1.2deg. 24-APR-99 MWD 9696.09 52.83 88.54 94.69 6381.19 6771.95 205.78 6768.83 0,59 -0.53 -0.34 24-APR-99 MWD 9793.67 53.09 90.02 97.58 6439.97 6849.82 206.76 6846.71 1.24 0.27 1.52 24-APR-99 MWD 9890.07 53.62 91.38 96.40 6497.51 6927.09 205.81 6924.05 1.26 0.55 1.41 , , 24-APR-99 MWD 9985.01 52.88 91.74 94.94 6554.32 7003.02 203.74 7000.09 0,84 -0.78 0.38 24-APR-99 MWD 10061.57 52.29 90.06 76.56 6600.84 7063.76 202.79 7060.89 1.91 -0.77 -2.19 24-APR-99 MWD 10140.00 52,29 90.06 78.43 6648.81 7125.77 202.72 7122.93 0.00 0.00 0,00 PROJ*BHC=7125.81 @ 88.37deg. .,, sl c ! .r -sLjr TM [:1 Ft I /l_l IM G S El FtL/I r- El 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 1C-25, AK-MM-90104 September 28, 1999 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1C-25: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22941-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22941-00 2" x 5" MD Neutron & Density Logs: 50-029-22941-00 2"x 5" TVD Neutron & Density Logs: 50-029-22941-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline RECEIVED 1999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 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 September 23, 1999 1C-25, AK-MM-90104 1 LDWG formatted Disc with verification.listing. API#: 50-029-22941-00 PLEASE ACKNOWLEDGE RECEIlYr BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMrI'rAL LETYER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchoraee Alaska 99518 1999 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company I-I I::! I I__1__ I I~1 G S E I::!~/I I-- E S 04-May-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1C-25 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,140.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C, Slot 1C-25 1C-25 Job No. AKMMg0104, Surveyed: 24 April, 1999 SURVEY REPORT 4 May, 1999 ORIGINAL Your Reh AP1-500292294100 Surface Coordinates: 5968546.47 N, 562335.47 E (70° 19' 28.5246" N, 149° 29' 40.3553" W) Kelly Bushing: 94.15ft above Mean Sea Level RECEIVED ['?~ AY 0 6 !999 Alaska Oil & Gas Cons. Com~ssion =l==r",r",~-==un Survey Ref: svy8541 Sperry-Sun Drilling Services Survey Report for 1C-25 Your Ref: API-500292294100 Job No. AKMM90104, Surveyed: 24 April, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 0.00 0.000 0.000 -94.15 0.00 206.12 0.510 306.290 111.97 206.12 288.53 0.590 290.710 194.37 288.52 376.26 0.630 235.180 282.10 376.25 466.81 0.990 82.280 372.65 466.80 557.89 2.640 90.120 463.68 557.83 649.49 5.960 73.450 555.01 649,16 739.18 10.160 65.390 643.80 737.95 822.94 12.730 65.880 725.88 820.03 916.76 14.400 68.680 817.08 911.23 1006.50 16.540 72.590 903.57 997.72 1091.22 19.340 79.690 984.17 1078.32 1186.39 21.090 84.470 1073.48 1167.63 1279.07 22.370 86.590 1159.58 1253.73 1372.83 25.000 87.120 1245.43 1339.58 1465.17 27.440 88.740 1328.27 1422.42 1557.25 28.720 89.430 1409.51 1503.66 1648.63 31.340 89.070 1488.61 1582.76 1743.93 34.150 88.900 1568.76 1662.91 1836.04 36.610 87.030 1643.86 1738.01 1930.02 39.220 87.870 1717.99 1812.14 2025.19 42.830 85.270 1789.78. 1883.93 2120.69 45.820 87.000 1858.10 1952.25 2213.86 48.800 85.740 1921.27 2015.42 2307.00 52.380 87.180 1980.39 2074.54 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5968546.47 N 562335.47 E 0.54 N 0.74W 5968547.01N 562334.73 E 0.91 N 1.43W 5968547.37 N 562334.03 E 0.79 N 2.25W 5968547.25 N 562333.21E 0.62 N 1,88W 5968547.07 N 562333.58 E 0.72 N 0;99 E 5968547.19 N 562336.46 E 2.07 N 7.66 E 5968548.60 N 562343.12 E 6.69 N 19.32 E 5968553.32 N 562354.74 E 13.54 N 34.47 E 5968560.29 N 562369.82 E 22.01N 54.77 E 5968568.93 N 562390.06 E 29.89 N 77.36 E 5968577.00 N 562412.58 E 36.01N 102.67 E 5968583.33 N 562437.84 E 40.48 N 135.23 E 5968588.07 N 562470.36 E 43.13 N 169.43 E 5968591.01 N 562504.54 E 45.19 N 207.04 E 5968593.38 N 562542.12 E 46.64 N 247.80 E 5968595.17 N 562582.87 E 47.33 N 291.14 E 5968596.21N 562626.20 E 47.93 N 336.86 E 5968597.20 N 562671.92 E 48.85 N 388.39 E 5968598.54 N 562723.44 E 50.77 N 441.68 E 5968600.90 N 562776.71 E 53.32 N 499.37 E 5968603.94 N 562834.38 E 57.11N 561.70 E 5968608.24 N 562896.68 E 61.58 N 628.27 E 5968613.27 N 562963.20 E 65.93 N 696.60 E 5968618.19 N 563031.50 E 70.35 N 768.41 E 5968623.20 N 563103.27 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.247 -0.72 0.205 -1.40 0.649 -2.22 1.742 -1.86 1.828 1,02 3.835 7.73 4.838 19.53 3.070 34.88 1.912 55.45 2.652 78.28 4.188 103.78 2.527 136.46 1.620 170.73 2.814 208.38 2.754 249.17 1,434 292.51 2.874 338.22 2.950 389.76 2.918 443.08 2.831 500.82 4.195 563.24 3.377 629.92 3.349 698.36 4.025 770.27 Continued... 4 May, 1999 - 10:09 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-25 Your Ref: API-500292294100 Job No. AKMM90104, Surveyed: 24 April, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 2400.98 2489.49 2587.98 2682.51 2774.30 2868.17 2960.35 3057.12 3150.76 3244.75 3337.59 3432.03 3528.35 3622.54 3715.51 3812.82 3907.46 4002.47 4096.16 4189.15 4274.92 4374.84 4467.49 4564.03 4657.99 53.070 54.420 54.040 53.620 55.730 55.200 54.190 55.410 54.690 54.250 53.570 52.940 55.710 55.140 54.630 54.100 53.560 56.410 55.840 55.190 54.670 53.740 55.880 55.270 55,120 Azim. 86.330 87.380 85.280 85.800 86.510 87.340 86.210 87.870 87.430 87.240 87.420 88.280 89.610 89.770 89.400 89.680 88.980 89.150 88.970 89.120 90.040 89.320 89.470 89.580 89.560 Sub-Sea Depth (ft) 2037.31 2089.65 2147.23 2203.02 2256.09 2309.30 2362.58 2418.36 2472.00 2526.62 2581.31 2637.81 2693.98 2747.43 2800.91 2857.60 2913.46 2967.97 3020.19 3072.84 3122.12 3180.56 3233.95 3288.53 3342.16 Vertical Depth (ft) 2131.46 2183.80 2241.38 2297.17 2350.24 2403.45 2456.73 2512.51 2566,15 2620.77 2675.46 2731.96 2788.13 2841.58 2895.06 2951.75 3007,61 3062.12 3114.34 3166.99 3216.27 3274.71 3328.10 3382.68 3436.31 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (fi) (ft) (ft) 74.59 N 843.07 E 5968628.06 N 563177.89 E 78.50 N 914.34 E 5968632.56 N 563249.12 E 83.61 N 994.08 E 5968638.33 N 563328.82 E 89.54 N 1070.16 E 5968644.90 N 563404.84 E 94.56 N 1144.87 E 5968650.54 N 563479.52 E 98.71N 1222.09 E 5968655.33 N 563556.70 E 102.94 N 1297.19 E 5968660.18 N 563631.76 E 107.01 N 1376.16 E 5968664.91 N 563710.69 E 110.16 N 1452.84 E 5968668.69 N 563787.35 E 113.71N 1529.25 E 5968672.88 N 563863.72 E 117.21N 1604.19 E 5968677.00 N 563938.63 E 120.05 N 1679.81 E 5968680.47 N 564014.23 E 121.47 N 1758.03 E 5968682.54 N 564092.43 E 121.89 N 1835.59 E 5968683.61 N 564169.98 E 122.44 N 1911.63 E 5968684.79 N 564246.02 E 123.08 N 1990.72 E 5968686.08 N 564325.10 E 123.97 N 2067.11 E 5968687.61 N 564401.48 E 125.24 N 2144.91 E 5968689.52 N 564479.26 E 126.52 N 2222.68 E 5968691.44 N 564557.03 E 127.79 N 2299.32 E 5968693.36 N 564633.65 E 128.31 N 2369.52 E 5968694.46 N 564703.84 E 128.76 N 2450.56 E 5968695.58 N 564784.88 E 129.56 N 2526.27 E 5968697.01 N 564860.58 E 130.22 N 2605.90 E 5968698.33 N 564940.20 E 130.80 N 2683.05 E 5968699.55 N 565017.34 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/~OOft) (ft) Comment 1.028 845.03 1.800 916.38 1.772 996.25 0.628 1072.48 2.384 1147.32 0.922 1224.63 1.484 1299.83 1.885 1378.88 0.860 1455.63 0.496 1532.11 0.749 1607.13 0.989 1682.80 3.087 1761.03 0.621 1838.55 0.638 1914.58 0.593 1993.64 0.826 2070.03 3.003 2147.82 0.629 2225.60 0.712 2302.24 1.067 2372.41 1.099 2453.43 2.314 2529.13 0.639 2608.74 0.161 2685.86 Continued... 4 May, 1999 - 10:09 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-25 Your Ref: A P1-500292294100 Job No. AKMM90104, Surveyed: 24 April, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 4746.66 4842.94 4936.93 5026.13 5121.59 5217.24 5311.56 5404.81 5499.16 5591.49 5686.89 5780.86 5870.35 5965.45 6057.62 6147,96 6244.06 6338.39 6431.52 6525.16 6619.88 6712.90 6808.83 6901.49 6997,01 54.630 54.030 52.930 54.810 54.030 53.360 56.000 55.490 55.080 54.300 53.850 53.500 52.710 54.520 54.280 53.610 52.910 55.020 54.360 53.650 53.150 52.590 54.900 54.850 54.590 Azim. 89.60O 89.250 90.060 89.190 89.010 89.870 89.060 88.930 88.900 88.220 88.100 88.060 87.700 88,590 88.110 87.680 87.520 88,000 88.230 87.600 86.580 87.870 88.120 87.890 88.200 Sub-Sea Depth (ft) 3393,18 3449.32 3505.25 3557.85 3613.39 367O.O2 3724.55 3777.04 3830.77 3884.13 3940.11 3995.77 4049.50 4105.91 4159.56 4212.73 4270.22 4325.71 4379.54 4434,57 4491.05 4547.20 4603.92 4657.24 4712.41 Vertical Depth (ft) 3487.33 3543.47 3599.40 3652.00 3707.54 3764.17 3818.70 3871.19 3924.92 3978.28 4034.26 4089.92 4143.65 4200.06 4253.71 4306.88 4364.37 4419.86 4473.69 4528.72 4585.20 4641.35 4698.07 4751.39 4806.56 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 131.33 N 2755.57 E 5968700.68 N 565089.85 E 132.11N 2833.78 E 5968702.12 N 565168.06 E 132.57 N 2909.31E 5968703.20 N 565243.58 E 133.05 N 2981,35 E 5968704.28 N 565315.61 E 134.27 N 3058.98 E 5968706.14 N 565393.23 E 135.02 N 3136.06 E 5968707.54 N 565470.30 E 135.75 N 3213.00 E 5968708.91N 565547.23 E 137.10 N 3290.07 E 5968710.90 N 565624.28 E 138.57 N 3367.61 E 5968713.01 N 565701.81 E 140.46 N 3442,93 E 5968715.53 N 565777.11E 142.94 N 3520.14 E 5968718.65 N 565854,30 E 145.48 N 3595.81 E 5968721.81 N 565929.94 E 148.13 N 3667.33 E 5968725.05 N 566001.44 E 150.60 N 3743.84 E 5968728.16 N 566077.93 E 152.75 N 3818,75 E 5968730.94 N 566152.82 E 155.44 N 3891,74 E 5968734.23 N 566225.78 E 158.66 N 3968.68 E 5968738.09 N 566302.70 E 161.64 N 4044.90 E 5968741.70 N 566378.89 E 164.14 N 4120.85 E 5968744.83 N 566454.82 E 166.89 N 4196,56 E 5968748.22 N 566530.50 E 170.75 N 4272,51 E 5968752.71 N 566606.41 E 174.34 N 4346.58 E 5968756.91N 566680.45 E 177.05 N 4423.88 E 5968760.26 N 566757.73 E 179.69 N 4499.62 E 5968763.53 N 566833.45 E 182.35 N 4577.56 E 5968766.83 N 566911.35 E Alaska State Plane Zone 4 Kuparuk lC Dogleg Vertical Rate Section (°/~00ft) (ft) Comment o.554 2758.36 0.690 2836.56 1.360 2912.07 2.250 2984.09 0.831 3061.71 1.008 3138.77 2.885 - 3215.71 0.559 3292.77 0.435 3370.32 1.037 3445.66 0.483 3522.91 0.374 3598.62 0.940 3670.19 2.047 3746.75 0.497 3821.69 0.836 3894.72 0.741 3971.73 2.274 4048.00 0.737 4124.00 0.933 4199.76 1.013 4275.79 1.259 4349.94 2.417 4427.29 0.210 4503,07 0,380 4581.05 Continued... 4 May, 1999 - 10:09 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-25 Your Ref: A PI-500292294100 Job No. AKMM90104, Surveyed: 24 April, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 7093.33 7184.26 7277.81 7372.41 7466.55 7562.35 7655.03 7748.17 7843.09 7935.87 8028.99 8123.05 8216.81 831o.o0 84o3.81 8496.29 8590.42 8685.34 8778.03 8870.34 8964.79 9057.85 9150.64 9244.Ol 9338.47 54.200 53.850 53.430 53.120 55.190 54.780 54.640 54.170 53.950 53.580 56.110 55.890 55,320 54.860 54.290 53.840 53.140 55.510 55.530 55,180 55.060 54.570 54.100 53.900 53.470 Azim. 87.260 87.450 88.650 87.200 89.590 87.940 88.41o 88.OLO 89.560 87.950 89.680 89.760 91.310 90.240 91.o9o 89.550 89.690 9O.lOO 89.270 91.240 88.540 89.450 90.650 91.250 90.470 Sub-Sea Depth (ft) 4768.48 4821.90 4877.36 4933.93 4989.06 5044.03 5097.58 5151.79 5207.50 5262.35 5315.96 5368.56 5421.53 5474.86 5529.24 5583.51 5639.52 5694.87 5747.34 5799.82 5853.84 5907.47 5961.57 6016.45 6072.39 Vertical Depth (ft) 4862.63 4916.05 4971.51 5028.08 5083.21 5138.18 5191.73 5245.94 5301.65 5356.50 5410.11 5462.71 5515.68 5569.01 5623.39 5677.66 5733.67 5789.02 5841.49 5893.97 5947.99 6001.62 6055.72 6110.60 6166.54 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 185.45 N 4655.81 E 5968770.58 N 566989.57 E 188.84 N 4729.31E 5968774.59 N 567063.05 E 191.41 N 4804.60 E 5968777.78 N 567138.32 E 194.15 N 4880.37 E 5968781.15 N 567214.06 E 196.27 N 4956.64 E 5968783.90 N 567290.31 E 197.96 N 5035.08 E 5968786.24 N 567368.73 E 200.37 N 5110.69 E 5968789.28 N 567444.32 E 202.73 N 5186.39 E 5968792.28 N 567520.00 E 204.36 N 5263.22 E 5968794.54 N 567596.81 E 205.98 N 5338.03 E 5968796.79 N 567671.61 E 207.54 N 5414.14 E 5968798.98N 567747.70 E 207.92 N 5492.12 E 5968800.01 N 567825.67 E 207.20 N 5569.48 E 5968799.93 N 567903.04 E 206.17 N 5645.89 E 5968799.53 N 567979.45 E 205.28 N 5722.33 E 5968799.28 N 568055.89 E 204.86 N 5797.20 E 5968799.48 N 568130.77 E 205.36 N 5872.86 E 5968800.61N 568206.42 E 205.50 N 5949.96 E 5968801.39 N 568283.52 E 205.92 N 6026.36 E 5968802.44 N 568359.91 E 205.59 N 6102.30 E 5968802.74 N 568435.85 E 205.73 N 6179.77 E 5968803.53 N 568513.32 E 207.07 N 6255.81E 5968805.50 N 568589.35 E 207.01 N 6331.20 E 5968806.06 N 568664.73 E 205.75 N 6406.72 E 5968805.44 N 568740.26 E 204.61N 6482.83 E 5968804.92 N 568816.37 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOft) (ft) Comment o.891 4659.36 0.420 4732.94 1.126 4808.27 1.271 4884.09 3.Oll 4960.39 1.474 5038.84 o.441 5114.49 o.614 519o.22 1.342 5267.07 1.455 5341.89 3.113 5418.Ol 0.244 5495.96 1.493 5573.26 1.o63 5649.60 0.956 5725.97 1.433 5800.79 0.753 5876.42 2.521 5953.49 0.738 6029.87 1.796 6105.75 2.348 6183.19 0.957 6259.24 1.166 6334.58 0.562 641o.03 0.806 6486.05 Continued... 4 May, 1999 o 10:09 - 5- DrillQuest Sperry-Sun Drilling Services Survey Report for lC-25 Your Ref: API-500292294100 Job No. AKMM90104, Surveyed: 24 April, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 9430.55 53.180 90.640 6127.39 6221.54 203.89 N 6556.67 E 5968804.82 N 568890.22 E 9510.00 52.780 90.170 6175.23 6269.38 203.45 N 6620.11 E 5968804.90 N 568953.66 E 9601.40 53.330 88.860 6230,16 6324.31 204.07 N 6693.15 E 5968806.13 N 569026.69 E 9696.09 52.830 88.540 6287.04 6381.19 205.78 N 6768.83 E 5968808.47 N 569102.36 E 9793.67 53.090 90.020 6345.82 6439.97 206.76 N 6846.71 E 5968810.10 N 569180.23 E 9890.07 53.620 91.380 6403,36 6497.51 205.81 N 6924.05 E 5968809.79 N 569257.57 E 9985.01 52.880 91.740 6460.17 6554.32 203.74 N 7000.09 E 5968808.35 N 569333.63 E 10061.57 52.290 90.060 6506.69 6600.84 202.78 N 7060.89 E 5968807.90 N 569394.43 E 10140.00 52.290 90.060 6554.66 6648.81 202.72 N 7122.93 E 5968808.35 N 569456.48 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.348 0.690 1.294 O.593 1.240 1.258 0.837 1.906 0.000 6559.84 6623.23 6696.25 6771.95 6849.82 6927.09 7003.02 7063.76 7125.77 PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 88.160° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10140.00ft., The Bottom Hole Displacement is 7125.82ft., in the Direction of 88.370° (True). Continued... 4 May, 1999 - 10:09 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-25 Your Ref: API-500292294100 Job No. AKMM90104, Surveyed: 24 April, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C Comments Measured Depth (ft) 10140.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6648.81 202.72 N 7122.93 E Comment PROJECTED SURVEY 4 May, 1999- 10:09 - 7- DrillQuest 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~ection during the second quaner of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-15 34380 100 0 32195 16795 48990 2L-313 3779 100 0 3879 8654 12533 CDI-19 33933 100 0 34033 0 34033 1C-25 34216 100 0 34316 0 34316 CD1-40 12071 100 0 12171 0 12171 1C-23 . 9505 100 0 9605 0 9605 Total Volumes into Amzuli for which hzjection Authorization Expired during the quarter ~ i Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus ID-10 I 35473 100 0 35573 Open, Freeze Protected 2N-323 32696 100 0 32796 Open, Freeze Protected 2N-343 17895 100 0 17995 I Open, Freeze Protected 2N-329 , 9 100 0 109I 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 Kupamk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other _X Annular InjeCtion 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1693' FNL, 1327' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1478' FNL, 1998' FEL, Sec. 7, T11N, R11E, UM At effective depth At total depth 1470' FNL, 1656' FEL, Sec. 7, T11N, R11E, UM 12. Present well condition summar Total depth: measu red 10242 true vertical 6693 5. Type of Well: Development __X Exploratory __ Stratigraphic _ Service __ feet Plugs (measured) feet 6. Datum elevation (DF or KB feet) RKB 95 feet 7. Unit or Property name KuparUk River Unit 8. Well number 1 C-25 9. Permit number / approval number 99-31 10. APl number 50-029-22941 11. Field / Pool Kuparuk River Field Effective depth: Casing Conductor Surface Production measu red 10242 true vertical 6693 Length Size 114' 16" 6567' 9.625" 7" feet Junk (measured) feet Cemented 9 cu yds High Early 796 sx AS IIIL, 653 sx Class G 180 sx Class G Measured Depth 114' 6567' 9570' TrueverticalDepth 114' 4550' 6304' Liner Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth N/A Packers & SSSV (type & measured depth) N/A ORIGINAL %'. BOP sketCh 13. Attachments Description summary of proposal__ Detailed operations program __ 14. Estimated date for commencing operation May 1, 1999 16. If proposal was verbally approved Oil __X Name of approver _~ Date approved Service__ 17. I-"~ereb"~'ced~~/~or~~~nycor~.~ct to the best of my knowledge. Signed Paul M~z~i~'''~ ~l~('~ Title: Drilling Team Leader \/ FOR COMMISSION USE ONLY Conditions of approval: Notify Con'dmission 15. Status of well classification as: Gas __ Suspended __ Questions? Call William Lloyd 265-6531 // so representative may witness I Approval no. Plug integrity_ BOP Test _ Location clearance I Mechanical Integrity Test__ Subsequent form required 10-.~i~(.~:~¢ p~~' ~.~ 'ORIGINAL SIGNED-BY A_R.p..r. oved by order of the Commission ~.J,,~,.~ · ¢jOg'"~Do~m!ssione r Casing Detail 9.625" Surface Casina WELL: 1C-25 ARCO Alaska, Inc. DATE: 04/16/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOPS Above RKB 9 5/8" Landing Joint (Jt. 169) 38:70 · -4.10 FMC GEN IV- Kuparuk.9 5/8'' Csg Hgr 1.96 34.60 jts144-168 9 5/8", 29.7#, L-80 BTC (25 jts) 966:32 36.56 TAM 7 5/8" Port Collar 3.05 1002.88 its. 3-143 9 5/8", 29.7#, L-80 BTC (141 its) 5476.82 1005.93 Gemeco Float Collar 1.50 6482.75 its 1-2 9 5/8", 29.7#; L-80 BTC (2 its) 81.34 6484.25 Gemeco Float Shoe 1.75 6565.59 Casing shoe @ 6567.34 T.D. @ 6580' leaving 12.66' of rathole 13 Gemeco Bow Spdng CENTRALIZERS Run centralizers in center of Jts. 1, 2 over stop collars and over casing collars on Jts. 3-12 and over collar of jt. 168 Run 1 ROTCO Rigid Straight Blade Centralizer in middle of joints 143 and 144 w/stop dngs Joint 169 will be used as the landing joint . · . Remarks: String Weights with Blocks: 295k Up, 180k Dn, 70k Blocks. Ran 168 oints of casing. Drifted casing with 8.679" plastic rabbit. Used 'Arctic Grade APl Modified No Lead thread compound on all connectionS. Casing is non-coated. Pool 6 Drilling Supervisor: Fred Herbert / Scoff Reynolds CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 1 C-25 Scoff Reynolds 7 5/8", 29.7 ppf, L-80, BTC Date: 4/18/99 Casing Size and Description: Casing Setting Depth: Mud Weight: 8.8 ppg Hole Depth: 4,573' TVD 6,567' TMD 4,561' TVD EMW = Leak-off Press. + MW 0.052 x TVD 1,700 psi + 8.8 ppg EMW LOT = (0.052 x 4,573') = 15.9 ppg Fluid Pumped = 3.6 bbl Pump output = 0.0846 bps 3'200psi I 3'100 ps1 i I I I I I I ~ i ~ I i I I I' I' I' I' I' T' I'f' 1'1' I't'l' I'~'~_ 2,g~ psi 2,~p¢1 It I I I 2,7~ psi i Il I I I I ~1 I t I I II I II I II I I I I I ,,,,''''' 1,7mpsm I I I I I I I 1,6~ psi I , I I I I 1,~ psi J ~ 1,4~ psi J 1,3ffi psi J 1,2~ psi i J i ~J I i I I I I I :~ ~"":' .......... ~Jl ~ ~ ~ ~ J ~ I ~ I I I ~ : LEAK-OFFTEST I/ I / J / / / / / / I / / ~pslI I J I I I I I J I II II J I I I I I I I J I J~ 7~ psi ~'~ LOT SHUT IN TIME ~ psi ~ CASING TEST SHUT IN TIME J / ~psl I I J I~ J I I J J I I I Jl 4~psl I ~ ~ TIME LINE I ~pslJ i~lllllJlll I II Ill Ill It Jill J lllll/ 0 ~sl ~ 0 4'6 8 1012141618 ~ 22 24 26 28 30 32 34 36 38 40 42 44 46 48 ~ 52 54 56 58 ~ 62 ~ ~ ~ 70 72 74 76 78 ~ 82 84 86 88 ~ ~ 94 sN STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE 0 stks ! 0 psi ........................... -i--i-t-k-i' .... ? .... i-ii~-i;i~i .... 8stks ! 400 psi ........................... _L~_.s._t.k_s__ .... :~ .... _s_ _o_ .o_ _ p. .s_ [ ..... 16stks i 700 psi 32stks i 1,300 psi 38stks i 1,520psi ..................... ~ .................... p .................... 40stks ! 1,600psi · 42stks i 1,670 psi i ............. , ...... i .... '~;~--gii;~ .... t-"0-6-~--~i'--i ~ .................... -I ..................... F .................... ..................... .~ ..................... }- .......................................... ~ CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... T ..... z-;~N; ..... ~ .... -~-i~ii ..... : 16stks i 800 psi .................... ~, .................... ~ .................... ., ! 20stks i 990 psi ..................... T .... ~-~-i~- .... F'T;¥~-6-~-~-i---' .................... T .... ~ii-~iii~- .... f"T;~i66--~-i-i'-'! i 32stks i 1,490ps~ i .................... .1- .................... t .................... ! 36stks i 1,650psi : .................... T .... ii:i-~iii~' .... ..... : .............. T--'-ii'iiii- .... .................... T .... i§'iii&' .... [--'Ei'6'6--~-ii---i " ............... --T .... ii'iiiii- .... ........ ~ ........ :'-T .... ii-iiiii- .... F'Eg6~"m~iT-q ................. :--T .... ii;i-~ii~; .... [---ii;ii66--/,-;i---i SHUT IN TIME i SHUT IN PRESSURE ............. -. ...... T .... " ............... ' ................ ']---I 0.0m~n : 3,000 pm : ............. : ...... ,-j- .................... ~ .................... .j 1.0mm : 2,990 psi i l SHUT IN TIME i SHUT IN PRESSURE ...... ~Tb-'rT1Tll~ .... T ........................ ..... ~)-.'6--r~]~ .... T ............... ~ .... f-'-:l-~)'~)"l~-~i ........................ 4.0 min -vi ........................................ 2,985 psi ~l i ..... i".-6--Big--,--i .................... T---i",-i'6'6'i~-ii 6.0 min. i 1,400 psi .................... ~ .................... .~. .................... ~ 9.0 min i 1,350 psi · .................... ~ .................... I' ................ ;--'~ 12.0 min ~ 1,300 ps~ 15.0 min i 1,270 psi i .... i-~:'6"r~i~;-':i ................... 7T---i;-i-i~'-miii'"i 22:0 min i 1,200 psi ..... ff~:'6"~i~7"i .................... T'-'i;'i-6-6-iiii"-' .... _2_?_:9__m__!n____i .................... i__b.2.Pp_.P_~i_ .... 7.0min i 2,965 psi ............. ~ ...... I- ..................................... 8.0m~n i , 2,965 psm ..... ~J:b-'~-',-~ .... T---; .... : ............... .... i:~i;6--~i;~:'-T ....... : .... : ....... F"Eiig6--~'i-f"i .... Tg:b'-~r'-T ....... : ............ [-"~;~'~-6'-~-;-i---i .... i~;6--6~ii;'"T .................... [i--i~;~-g6'-~'ii---i .................... '}' ............................ ' ............ 25.0min ~ i 2,960 psi 30.0min i i 2,960 psi 'NOTE: STROKES TURN T© MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO cLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION April 6, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99501-0360 Re: Kuparuk River Unit I C-25 ARCO Alaska, Inc. Permit No: 99-31 Sur Loc: 1693'FNL, 1327'FWL, Sec. 12, T11N, R10E, UM Btmhole Loc. 1470'FNL, 1656'FEL, Sec. 7, T11N, R11E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation v&ich are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site lC must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting. Ibc Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Consen'ation w/o encl. STATE OF ALASKA ,~,I-~AsKA OIL AND GAS CONSERVATION COMM'i~SIoN PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [] Redrill [] I lb. Type of well. Exploratory [] StratigraphicTest [] Development Oil [] Re-entry [] Deepen []I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 95 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28242 ALK 2292 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1693' FNL, 1327' FWL, Sec, 12, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1478' FNL, 1998' FEL, Sec. 7, T11N, R11E, UM lC-25 #U-630610 At total depth 9. Approximate spud date Amount 1470' FNL, 1656' FEL, Sec. 7, T11N, R11E, UM April 7, 1999 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1470' @ TD feetI 1 C-01 38.3' @ 800' feet 2560 10242 ' MD / 6693 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 500 MD Maximum hole angle 54 Maximum surface 2680 psig At total depth (TVD) 3400 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD -I-VD (include stage data) 20" 16" Weld 25' 95' 95' 120' 120' +/-CF200 12.25" 9.625" 40# L-80 BTC 6467' 95' 95' 6562' 4544' 790 sx AS III, 650 sx Class G 8.5" 7" 26# L-80 BTC-M 9402' 95' 95' 9497' 6316' 170 sx Class G 6.125" 3.5" 9.3~ L-80 EUE 895' 9347' 6229' 10242' 6693' 260 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production .i ", ?:,t :t~ ., Perforation depth: measured ,..,'i ?'. t'! ?' ~.~-i ORIGINAL Anchorage:'. 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Ddlling fluid program [] Time vs depth plot []Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Ca//William Lloyd 265-653~ Signed /~.~¢'~. ~ O'//~'~ Title: Dfilling TeamLeader Date .-~c.u: .~.'._%-z~:.'~ ~t-/~ ,,~_v-~ ~Lb Prer~ared bv Sharon AIIsu~-Drake Commission Use Only Permit Number I AP lnumber Appr0~?at~/' Ieee cover letter ?¢ "---~7I 50- 43 ~ ~'--- .~. ~_. ¢ ~,Z,/,/' i¢-" _- ¢¢ Ifor other requirements Conditions (~fapproval Samples required [] Yes [] No Mud Icg required [] Yes .~ No Hydrogen sulfide measures [] Yes [] No Directional survey required [~ Yes [] No Required working pressure for DOPE [] 2M; [] 3M; [] ~ [] 10M; [] [] Other: ORIGINAL SIGNED'BY by order of Robert N. Chdstenson Appr?ved by. ..... ....... Commissioner the commission Date c,~__ ~, _..- ,,~' Form 10-401 Rev. 12/1/85 · L I in triplicate ..... ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU :[C-25 Drillinq Fluid Pro Density PV YP Funnel Vis Initial Gel 10 Hinute Gel API Filtrate pH % Solids ~erties: Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 100- 120' Drill out to TD 9.5- 11.0 ppg 6-20 5-20 35-50 10-20 15-40 7-15 9.5-10 +10% 2-6 4-8 <6 through Kup 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (HASP) while drilling the production hole 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 pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. HASP = (2,300 ft)(0.70 - 0.11) = 2,680 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1C pad are expected to be ~3,400 psi (0.53 psi/E). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.6 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6,447'. Target (Kuparuk C4) ( 3400+ 150 )/( 0.052 *6447 )= 10.6. Well Proximity Risks: The nearest well to 1C-25 is lC-01. The wells are 38.3' from each other at a depth of 800' HD. Drillinq Area Risks: Drilling risks in the :LC-25 area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) ARCO Alaska, Inc.- .... Annular Pumpin0 Operations: ];ncidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permi[ted Class ];]; disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any ex~ended shut down (> 4 hr) in pumping operations. The :tC-25 surface/production casing annulus will be filled with diesel after seeing production casing and prior to the drilling rig moving off of the well. ;If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that :[C-25 be permiL~ed for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. 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 ¢olville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) · (0.052) ~< (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) ~< (0.052) * (4,544') + 1,500 psi Max Pressure = 4,335 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst · 9'-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi '7" 26 L-80 3 LTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 31/2'' 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. Drill and Case Plan for 1C-25 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. ]:nstail diverter lA function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 6562' MD/4544' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAIVi Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Make up 8 1/2" bit and BHA and R]:H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to intermediate casing point at +9600' MD/6316' TVD · Perform a second LOT and determine an acceptable kick tolerance · ]:f kick tolerance is acceptable, 8 1/2" hole will be drilled to TD · ]:f kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and R]:H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8' hole to TD at 10242' MD/6693' TVD · Condition hole and mud for casing 14. Run and cement 3 1/2" 9.3# L80 EUE Liner 15. IVlake a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 16. Run and land 3 1/2" tubing with gas lift completion 17. Nipple down BOP's. ]:nstall production tree and pressure test same. 18. Secure well, release rig ..._ · Completed 1¢-25 FMC Prudhoe Gen V 9-5/8 x 5¥2 x 31/2 1,91 5' MD / 1,795' TVD ::::::: 12-1/4" Hole ':':':' :.:.;.', :.:.:.: 9-5/8" PORT Collar .. · :.:-:.; Standard Grade, BTC -:.:-:. ::;::: 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 6,562' MD / 4,544' TVD 81/2" Hole 3W' 9.3 ppf L-80 8rd EUE tubing w/15' seal bore extension tied 7" 26 ppf L-80 BTC Intermediate. Csg. 9,497' MD / 6,316' TVD Baker 3.5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger. TOL@ 9347' MD/6229' TVD 6-1/8" Hole I I I J :.:.:. ':':'.' 2.87 :,:.:. · :-:-: nipl: ~ ::3 :.2.:. ::><3 X:::::::: CAi 'i :._ ...:1 ~:- -. '. -. -. -. '. '. '. -. -. '. .., CAMCO DS 31e for SCSSV 500' + MD 31~" x 1" pocket GLM Camco 3½"x 1-1/2" side pocket GLM 7,0 2.75" D nipple 3-1/2"Slimhole Completion 3/24/99 All Depths are RKB Pool Rig 6 1C-25 and set Casing FMC Prudhoe Gen IV 9-5/8 x 7 9-5/8 Mandrel Hanger Base of permafrost at 1,915' MD / 1,795' TVD 12-1/4" Top of West Sak at 5,469' MD / 3,906' TVD Base of West Sak 6,219' MD/.4,344' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 6,562' MD / 4,544' TVD 8-1/2" Hole Baker 3.5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger w/PBR @ 9347' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 3-1/2" Landing Collar, Float Collar and Float Shoe (1 jt. spacing between each) Completion Type 2 ,%* ,%-.. ,%-.- -.-.. 16" Conductor Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 1,001' MD / 1,000' TVD Mud Weight in Surface hole: 10.0 ppg by 1100' TVD i.'.'. B~ 10.2 ppg by 1900' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe ', '. ', Mud Weight in Production hole 9.1 to 10.0 ppg 7" 26 L-80 BTC Mod Csg i:!:!:! 9,497' MD / 6,316' TVD %, %, 3-1/2" 9.3#/ft L-80 EUE 3/24/99 ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS i 3" 5,000 psi WP OCT MANUAL GATE VALVE KILL LINE ~ 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator E~ BSA 13-5/8" 5,000 psi WP L x 11" 3,000 psi WP --~ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE ~/hvdraulic actuator CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL w! two 3" 5M psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ~.. ARCO Alaska, Inc. Diverter Schematic Pool #6 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. Pad 1C 25 slot#25 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 25 Version~S Our ref : prop3220 License : Date printed : 23-Mar-99 Date created : 30-Nov-98 Last revised : 23-Mar-99 Field is centred on n70 16 18.576,w150 5 56,536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 28.521,w149 29 40.392 Slot Grid coordinates are N 5968546.132, E 562334.230 Slot local coordinates are 1693.00 S 1327.00 E Projection type: alaska - Zone 4, Spheroid: clarke - 1866 Reference North is True North Object wellpath GMS <O-7780'>,,1,Pad 1C GMS <O-7615'>,,2,Pad 1C PMSS <0 - 8095'>,,18,Pad 1C PMSS <O-9390'>,,15,Pad 1C PMSS <0-10980'>,,14,Pad 1C PMSS <0 - 11918'>,,16,Pad lC GMS <O-7575'>,,4,Pad 1C PMSS <0-17089'>,,12,Pad 1C PMSS <0 - 10969'),,17,Pad 1C MSS <0-7000'>,,9GI,Pad 1C PGMS <0-9002'>,,lOGI,Pad 1C GMS <0-9600'>, 8,Pad 1C GMS <0-9784'>, 7,Pad 1C GMS <0-10243'> ,6,Pad 1C GMS <0-7753'>, 5,Pad 1C GMS <0-9700'>, 3,Pad 1C PMSS <0-8677'>, 13,Pad 1C Unknown Data,,WS1,Pad 1C PMSS <O-11300'>,,11,Pad 1C MMS <6948-7570'>,,WS~24,Pad 1C Closest approach with 3-D Minimum Distance method Last revised Distance 11-Mar-99 18-Dec-98 22-Feb-99 17-Dec-98 18-Mar-98 8-Jan-99 18-Dec-98 7-Jan-98 2-Dec-98 2-Jan-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 1-Dec-98 2-Nov-98 19-Mar-97 17-Dec-97 38 3 76 3 383 0 95 0 192 1 494 6 315 3 401 2 820 1 844 5 688 6 796 3 675 4 555 8 434.4 195.8 531.2 7740.1 832.5 4179.4 M.D. Diverging from M.D. 800.0 800.0 500.0 500.0 100.0 100.0 766.7 766.7 816.7 816.7 766.7 766.7 480.0 480.0 2680.0 2680.0 100.0 100.0 511.1 511.1 566.7 566.7 0.0 460.0 380.0 380.0 500.0 500.0 440.0 440.0 480.0 480.0 360.0 360.0 40.0 40.0 320.0 320.0 10242.0 10242.0 RCO Alaska, In C~t,d b~ ~.~ For: LLOYD :Structure : Pad lC Well : 2.5 Date plott~: 23-U-r-1999 I p- East (feet) 500 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 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 500 SURFACE LOCATION: ~ T~D~ LOCA~ON: TD LO~TION: ]695' ~L, ]5~7' ~L ~ ]478' FNL, ]998' FEL ]470' FNL, 1656' ~L 500 SEC. ~2, T1]N, R]OE SEC. 7, TllN, R~IE SEC. 7, 0 . RKB ELEVATION: g5' 500 1~.00 KOP ~9.00 Begin Build/Turn to Target 88. 1 6 AZIMUTH ,ooo k,4.62 6872' (TO TARGET) ~,20.40 *,*Plane of Proposal*** 26.27 DLS: 5.00 100 ft deg per 1500 ~32.19 8.15 ~2~.09Base pe~afrost Sonds ~Base Ugnu Sands : ,::-: ..... ~Top West Sok : :, ...., se Wes~ Sok 5000 >~: ~ U 5500 6000 54.gg DEG ~500 Top B Shale v TD - Casing PI 500 0 500 1000 15~ 2000 2500 5000 3~0 ~0 4~0 5000 5500 6000 6500 7000 7500 Vertical Section (feet) -> 2000 2500 .5000 3500 4OO0 4500 Azimuth 88.16 with reference 0.00 N, 0.00 E from slot #Z5 Created by finch For: LLOYD 1 Date plotted: 23-Mar-1999 I Plot Ref ...... is 2,5 Versron ~§. I Coardlnatee are ~n feet reference slot ~25. ITrue Vertical Depth .... i~.f~ ce.KB <:poo, 6).I I / ARCO Alaska, Inc. Sfrucfure: Pad 1C Well: 25 Field : Kuparuk River Unit Looatlon : North Slope, Alaska Point KOP Begin Build/Turn to 4a Base Permafrost EOC Top Ugnu Sands Base Ugnu Sands Top West Sak Base West Sak 9 5/8 Casing Pt Bose HRZ K- 1 Marker 7 Casing Pt Top Kup~aruk D TARGET - Top C4 Top C5 Top C2 Top C1 Top B Shale TD - Cosinq Pt PROFILE MD Inc 500.00 0.00 833.33 lo.a0 1915.19 41.56 2341.62 54.28 4529.85 54.28 5282.15 54.28 5468.84 54.28 6219.05 54.28 6561.61 54.28 9497.55 54.28 9596.69 54.28 9655.98 54.28 9755.98 54.28 9821.07 54.28 9875.88 54.28 9918.70 54.28 10009.48 54.28 10042.02 54.28 10242.02 54.28 COMMENT DATA Dir TVD North East V. Sect 0.00 500.00 0.00 0.00 0.00 65.00 851.64 12.26 26.50 26.68 86.84 1795.00 75.56 482.00 484.10 88.75 2080.20 85.04 797.61 799.92 88.75 5241.00 120.95 2411.58 2414.01 88.75 5797.00 158.15 5184.54 5187.15 88.73 3906.00 141.50 5535.88 3338.70 88.73 4344.00 155.04 3944.80 3947.74 88.75 4544.00 1 61.22 4222.84 4225.84 88.75 6258.00 214.22 6605.69 6609.1 6 88.75 651 6.00 21 6.01 6686.52 6689.81 88.75 6550.61 217.08 6754.45 6737.94 88.75 6409.00 218.89 6815.61 6819.15 88.75 6447.00 220.06 6868.44 6871.97 88.75 6479.00 221.05 6912.95 691 6.46 88.75 6504.00 221.82 6947.69 6951.25 88.75 6557.00 225.46 7021.57 7024.92 88.75 6576.00 224.05 7047.78 7051.54 88.75 6692.77 227.66 7210.12 7215.71 Deg/',.1 O0 / 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00~ 0.00 0.00 Creoted by finch For: LLOYD Dote plotted: 25-Mor-1999 Plot Reference ;e 25 Vere;on ~5. I Coordinotee ore in feet reference slot 1~25. [True Ver[~co, Depths orej~ce RKB (Pool 6).[ ARCO Alaska, Inc. Sfruofure: Pad 1C Well: 25 Field : Kuporuk River Unit Looaflon : Norlh Slope, Alosko 160 140 120 10o East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 .520 540 560 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1°~20'~0 ~ //' _---~'~ ~ 1100 .-- ~'2400 2300 800 / / / ~' 2~00 ~400 /~' ~' 2200 ~ 300 ~500 '500 ~2~00 ~ ~ ~' ~ ~ ~ 2200~ ~ _X / /~oo ~2oo~ ~ - ~ ~ 1600 /500 ~--'"" '-" 11 O0 800..~ -" 800,..- '"' '"' ~, ~soo 6ooe- '~ ~u... ~- \ ~ 500 ~ 20 I 19oo 6oo I ~ i 500 ~700 ~ 7O0 1600 ~o ~ ~ ~oo 2000 I 900 I,ooo 6o x \ ~ 1 ~oo lOO 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I [ I I I 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 520 540 360 East (feet) -> 8O 16O 140 ",, 120 1 O0 8O 6O 40 Z 0 20 :3- 0 20 40 80 lO0 Created by finch For: LLOYD Date plotted: 25-Mor-1999 Plot R~ference ~s 25 Version ~15, Coordinates ore in feet reference slot 1~25. ARCO Alaska, Inc. Sfruafure: Pad lC Well: 25 Field : Kuparuk River Unlt Looaflon : North Slope, Alaska 32O 280 240 2OO 16O 120 60 r 40 -i-- O Z 0 40 8O 120 160 200 Easf (feel) -> 240 280 520 560 400 440 480 520 560 600640 680 720 760 800 840 880 920 960 1000 1040 1080 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~~0o .~ ~ _ ~ ~ '.~°° ,....-e~ ~ - - ___ ~ .~~ - ~ ~ o o '"~ ~ o o ?_o .... .... .... .......................... I I I I I I I I I I I I I I I I I I I I I I ! I [ I I I I I I I I I I I I I I I I I I 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 East (feet) -> 32O ,' 280 24O 200 16O 120 I Z 0 80 ~ ---i- 0 40 80 120 160 2OO Created by finch For: Date plotted: 23-Mar-1999 Coord;notea ore ;n feet r~erence slot ARCO Alaska, Inc. Sfruofure: Pad lC Well: 25 Fleld: Kuporuk River Unit Loootlon : North Slope, Alosk¢ East (feet) -> 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2500 2400 900 2500 2600 2700 2800 2900 5000 5100 __ 800 7OO 600 2700 ~ ~ ~500 ~500 2700 2900 3100 3300 5500 3700 0 ~7:~~ 2100 -- ~ .... ~ 2500 ~ 2500 ~ -- ~ ~ 2700 ........... 5100 ~ 3300 7O0 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 310¢ East(feet) -> 500 400 I $00 H---- ~-~ 200 0 1 O0 Z 100 2OO 500 2100 2900 3100 ~9~- ~oo ......... ~~ ~oo - - - 400 90( 900 800 700 6OO 500 400 300 200 I Z 0 lOO ~ 1 O0 200 500 400 Created by finch FOT; LLOYD Dote plotted: 23-Mor-1999 Plot Reference ;e 25 Verelon ~15. I I Coord;notee ore in feet reference slot 1~25. /True Veer'col Depth .... [[~=f~ce RKB (Pool ARCO Alaska, Inc. Struofure : Pad 1C Well: 25 Field : Kuparuk River Unit Loootlon : North Slope, Alaska 1400 1200 1000 80O 6OO A I 400 200 200 400 6OO BOO 1000 1200 East (feet) -> 3000 3200 5400 3600 ,t800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 I I I I I I I I I I II II II II I I I I I I I I I I II I I I I II I I I I I I I 4500~.,~''~ 4100 ~ 330~ ~ ~ 4300 4100 ~-- ~-- ~ 3900 ~ ~ ~"~ ~ ~ 3700 ~ ~ ~'--~ 3500 ~ ~ --~ ~ ~ 4500 470~ 5900 4100 4300 4500 4700 4900 5100 5300 5500 5700 5900 6100 6500 6500 .[~ .--e --o 3500 5700 3900 ......... .._,__~ 4100 4300 ~,,--~ 4500 4700 4900 .... 5500 o 5100 5500 5700 5900 ~ '--e~ ~ ~ ~ ~ ~ ~ __ ,..,_e ~ ~~ 61 O0 I I I I I I I I ! I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 3000 5200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 East (feet) -> 1400 1200 1000 800 600 400 I Z o 200 ~_ 200 400 1200 1000 800 6OO Ct*eared by finch For: LLOYD I O-t, plotted: 25-ldor-1999 I Coo~fnat. om ~ feet ~f~ slot t25, IT~e Ve~tcol Depths em ~emn~ RKB (~ol 6~ 310 ~ 1300 '¢30 320 x IARCO Alaska, Inet'.1 Structure : Pad l C Well : 2,5 Field: Kuparuk River Unit Location : North Slope, AlaskaJ 340 TRUE NORTH 350 0 10 0 1900 3O 4O 5O 500 290 6O 280 80 270 + ~,5o, 9O 260 100 240 230~~ 220 210 200 190 Normal Plane Travelling Cylinder- Feet 140 110 ~100 ~3oo120 3500 13©~,oo ~ 3900 150 160 180 170 All depths shown (2re Measured depths on Reference Well ARCO Alaska, Inc. .._~ Post Office Box 10Cr,~'60 Anchorage, Alaska 99510-0360 March 24, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU 1C-25 Surface Location: ::L693' FNL ::[3:27' FWL Sec ::L2 T::L:I.N R:I. OE, UI~! Target Location: :~478' FNL, :1.998' FEL Sec. 7, T:L:LN, R:I.:I.E, UM Bottom Hole Location: :!.470' FNL, ::!.656' FEL Sec. 7, T:I.:LN, R:I.:I.E, UM Dear Commissioner Christenson, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1C pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 3 1/2" liner and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . 1) 2) 3) 4) 5) 6) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Robert Christenson Application for Permit to Drill - 1C-25 Page 2 10) Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned.The following are ARCO's designated contacts for reporting responsibilities to the Commission: z) 2) Completion Report Technologist (20 AAC 25.070) Geologic Data and Logs (20 AAC 25.071) Sharon AIIsup-Drake, Drilling 263-4612 Meg Kremer, Geologist 265-6460 The anticipated spud date for this well is April 7, 1999. If you have any questions or require further information, please contact Bill Lloyd at (907) 263-6531 or Chip Alvord at (907) 265~.~ ~ Williatn B.__Lloyd~ Senior Drilling Eng~'l~ r CC: Kuparuk 1C-18 Well File Ch ip Alvord ATO- 1200 MJ Loveland NSK6 ...... ARCO AlaSka, 'inc.""{>, ............ AAI PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: The First Nati~n~ilB~ink: of Chicago-0710 Chicago,. :,11 linois Payable ThrOugh Republic Bank Shelbyville, Kentucky 205088671 ~ 099?5?9 MARCH 8, 1999 ALASKA DEPT OF REVENUE :" ':::~ i::"':~'"': ~'":i ALASKA OIL & GAS.CONSERVATION COMMI ., ~ ":~::~:~: . :: i 3001 PORCUPINE ~DRIVE: :,.: ,.',~ ,~<. :iVOiD:AFTER 00 DAYS *** ::' : ':: '~; · ACTLY *******%?i',~ DOLL.s AND O0 :CENTs $%*~****** 100.00 TRACE NUMBER: 205088671 OC~Cl ? c; ? cf,' VVELL PERMIT CHECKLIST COMPANY..~,/"d.~c"b WELLNAME,,~/~_.,////C-2..~ PROG~M:exp~dev~ redrll__se~~wellboreseg ann. dis~salparareq FIELD & POOL ~~ ~ INIT C~SS ~ ~/~ ,~ ~:,? GEOL AR~ ~.~ ADMINIST~TION 1. Permit fee aEached ....................... ~ N 2. Lease number appropriate ................... Y N 3. Unique well name and number .................. Y N 4. Well located in a defined pool .................. Y N 5. Well located proper distance from drilling unit bounda~ .... ~ Y N 6. Well located proper distance from other wells ..........~ Y N 7. Sufficient acreage available in drilling unit ............ Y N 8. If deviated, is wellbore plat included ............... I Y N 9. Operator only affected pa~ ................... ' Y N 10. Operator has appropriate bond in force .............~ Y N 11. Permit can be issued without conse~ation order ........ J Y~ N ~r~R D~T~E/~ 12.~ Permit can be issued without administrative approval ......~ Y] N . 13. Can permit be approved before 15-day wait ........... ~ N ENGINEERING 14. Conductor string provided ................... ~ N 15. Sufiace casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & su~ csg ..... ~ N 17. CMT vol adequate to tie-in long string to sufi csg ........ Y N 18. CMT will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or rese~e pit ................. ~ N 21. If a re-drill, has a 10~03 for abandonment been approved... 22. Adequate we,bore separation proposed ............. ~ N 23. If dive,er required, does it meet regulations ..........~ N 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................~ N 26. BOPE press rating appropriate; test to ~~ psig. N APPR DATE Ch,k m,,ir, d RP-S3 (M y 84) ........ N 28. Work will occur without operation shutdown .........../~ N 29. Is presence of H2S gas probable ................. ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. R DATE 33. Seabed condition su~ey (if off-shore) ............. ~~ 34. Oontact name/phone for weekly progress repo~s [e~plo~ato~y o~] Y N ~NNUL~ ~ISPOS~L 35. With proper cementing records, this plan ~~. ~~[ (A) will contain waste in a suitable receiving zone; ....... /-- APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to sudace; &ee~o ~u~v~ ~s ~ ~S ~Tu~C 05~ 0~-~5 ~. ~ ~ ~ j31[ ~ ~ (C) will not impair mechanical integrity of the well used for disposal; ~ N (D) will not damage producing formation or impair recove~ Eom a ~ N pool; and (E) will not circumvent 20 ~C 25.252 or 20 ~C 25.412. ~ N GEOLOGY: ENGINEERING: UlC/Annular COMMISSION: Comments/Instructions: ' ~ JDH ~ ', I. - 0 Z 0 --I ITl >. c:\msoffice\wordian\diana\checklist 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 Sep 21 11:16:23 1999 Reel Header Service name ............. LISTPE Date ..................... 99/09/21 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 ..................... 99/09/21 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 KUPA~UK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-90104 A. PIEPER F. HERBERT 1C-25 500292294100 ARCO ALASKA, INC. RECEIVED ;Ep 2 8 1999 SPERRY-SUN DRILLING SERVICES 21-SEP-99 MWD RUN 2 AK-MM-90104 A. PIEPER F. HERBERT MWD RUN 3 AK-MM-90104 M. H31NIK F. HERBERT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MM-90104 M. HANIK D. BURLEY 12 liN 10E 1693 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1327 .00 94.10 60.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 116.0 12.250 9.625 6567.0 8.500 7.000 9568.0 6.125 10140.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA tLAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 3. MWD RUN 3 IS DIRECTIONAL WITH DGR AND PRESSURE WHILE DRILLING (PWD) . 4. MWD RUN 4 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO- DENSITY (SLD), AND PWD. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 05/13/99. MWD DATA IS PDC. 6. MWD RUNS 1 - 4 REPRESENT WELL 1C-25 WITH AN API# 50-029-22941-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10140'MD, 6648'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SRALLOW 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN PROCESSING POROSITY LOGS: HOLE SIZE: 6.125" MUD WEIGHT: 11.5 PPG FILTRATE SALINITY: 450-600 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM FLIUD DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE N-UMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 217.0 ROP 259.5 PEF 9550.0 FCNT 9550.0 NCNT 9550.0 NPHI 9550.0 FET 9550.0 RPD 9550.0 RPM 9550.0 RPS 9550.0 RPX 9550.0 DRHO 9560.0 RHOB 9560.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 10087 5 10140 0 10055 5 10039 0 10039 0 10039 0 10094 5 10094 5 10094 5 10094.5 10094.5 10055.5 10055.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 116.0 5258.0 2 5258.0 6580.0 3 6580.0 9573.0 4 9573.0 10140.0 MERGED MAIN PASS. $ 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 DEPT FT 4 1 68 GR MWD API 4 1 68 ROP MWD FT/H 4 1 68 RPD MWD OHMM 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 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 Nsam DEPT 217 10140 5178.5 19847 GR 20.51 554.64 101.874 19742 ROP 8.52 2350.82 162.215 19762 RPD 1.49 1837.19 25.7131 1090 RPX 1.53 495.4 5.57176 1090 RPS 1.58 1482.4 7.29558 1090 RPM 0.52 2000 37.2163 1090 FET 0.4651 105.346 5.74392 1090 NPHI 13.45 68.07 36.0109 979 FCNT 94.4 1008.1 332.459 979 NCNT 4564.4 37564.8 21525.8 979 RHOB 2.21 2.96 2.40404 992 DRHO -0.23 0.33 0.0576411 992 PEF 3.22 17.78 6.63214 1012 First Reading 217 217 259.5 9550 9550 9550 9550 9550 9550 9550 9550 9560 9560 9550 Last Reading 10140 10087.5 10140 10094.5 10094.5 10094.5 10094.5 10094.5 10039 10039 10039 10055.5 10055.5 10055.5 First Reading For Entire File .......... 217 Last Reading For Entire File ........... 10140 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 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 ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NL~MBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 217.0 5215.5 ROP 259.5 5257.0 $ LOG HEADER DATA DATE LOGGED: 12-APR-99 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: .5 MAXIMUM ANGLE: 56.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P1291CG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER' S CASING DEPTH (FT) : 12 . 3 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 10.20 INSITE 3.2. (UPGRADE 3) CIM 5.46 MEMORY 5258.0 116.0 5258.0 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 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 80.0 9.1 350 6.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 t GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 34.5 First Name Min Max Mean Nsam Reading DEPT 217 5257 2737 10081 217 GR 20.51 132.42 74.2245 9998 217 ROP 15.93 2350.82 190.617 9996 259.5 Last Reading 5257 5215.5 5257 First Reading For Entire File .......... 217 Last Reading For Entire File ........... 5257 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 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 ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE IqUMBER: 3 P_AW 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 GR 5216.5 ROP 5258.5 $ 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 $ 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) : STOP DEPTH 6539.0 6580.0 13-APR-99 INSITE 3.2. (UPGRADE 3) CIM 5.46 MEMORY 6580.0 5258.0 6580.0 52.7 56.0 TOOL NUMBER P1291CG8 12.250 12.3 SPUD 10.30 70.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE 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 9.2 350 6.2 .000 .000 .000 .000 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 38.4 First Name Min Max Mean Nsam Reading DEPT 5216.5 6580 5898.25 2728 5216.5 GR 55.29 147.6 97.502 2646 5216.5 ROP 16.92 846.69 165.322 2644 5258.5 Last Reading 6580 6539 6580 First Reading For Entire File .......... 5216.5 Last Reading For Entire File ........... 6580 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 R3kW 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 GR 6539.5 ROP 6580.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 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: STOP DEPTH 9528.5 9571.0 19-APR-99 INSITE 3.2. (UPGRADE 3) CIM 5.46 MEMORY 9573.0 6580.0 9573.0 52.6 56.1 TOOL NUMBER P1290HWG6 8.500 8.5 LSND 9.30 45.0 9.4 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: 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...0 150 4.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 52.1 First Name Min Max Mean Nsam Reading DEPT 6539.5 9571 8055.25 6064 6539.5 GR 37.14 554.64 150.269 5979 6539.5 ROP 18.61 1273.83 129.813 5982 6580.5 Last Reading 9571 9528.5 9571 First Reading For Entire File .......... 6539.5 Last Reading For Entire File ........... 9571 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR PEF FCNT NCNT NPHI FET RPD RPM RPS RPX DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9529 0 9550 0 9550 0 9550 0 9550 0 9550 0 9550 0 9550 0 9550 0 9550 0 9560 0 9560 0 9572 5 SURFACE SOFTWARE VERSION: DOWN-HOLE 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 STOP DEPTH 10087 5 10055 5 10039 0 10039 0 10039 0 10094 5 10094 5 10094 5 10094 5 10094 5 10055.5 10055.5 10140.0 24-APR-99 INSITE 3.2. (UPGRADE 3) CIM 5.46 MEMORY 10140.0 9573.0 10140.0 52.3 53.6 TOOL NUMBER P1281GR4 P1281GR4 CTN SLD $ COMP THERMAL NEUTRON 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 TEMPEP~ATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAi~DOFF (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 P1281GR4 P1281GR4 6.130 6.1 LSND 11.50 57.0 9.5 550 4.2 1.250 .845 1.600 2.800 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 RPX MWD 4 OHMM 4 1 68 12 4 RPS MWD 4 OHMM 4 1 68 16 5 RPM MWD 4 OHMM 4 1 68 20 6 RPD MWD 4 OHMM 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 NPHI MWD 4 PU-S 4 1 68 32 9 FCNT MWD 4 CNTS 4 1 68 36 10 NCNT MWD 4 CNTS 4 1 68 40 11 RHOB MWD 4 G/CM 4 1 68 44 12 52.2 DRHO MWD 4 G/CM 4 1 68 PEF MWD 4 BARN 4 1 68 48 13 52 14 Name Min Max Mean DEPT 9529 10140 9834.5 GR 38.85 212.07 100.691 ROP 8.52 450.88 76.1298 RPX 1.53 495.4 5.57176 RPS 1.58 1482.4 7.29558 RPM 0.52 2000 37.2163 RPD 1.49 1837.19 25.7131 FET 0.4651 105.346 5.74392 NPHI 13.45 68.07 36.0109 FCNT 94.4 1008.1 332.459 NCNT 4564.4 37564.8 21525.8 RHOB 2.21 2.96 2.40404 DRHO -0.23 0.33 0.0576411 PEF 3.22 17.78 6.63214 First Last Nsam Reading Reading 1223 9529 10140 1118 9529 10087.5 1136 9572.5 . 10140 1090 9550 10094.5 1090 9550 10094.5 1090 9550 10094.5 1090 9550 10094.5 1090 9550 10094.5 979 9550 10039 979 9550 10039 979 9550 10039 992 9560 10055.5 992 9560 10055.5 1012 9550 10055.5 First Reading For Entire File .......... 9529 Last Reading For Entire File ........... 10140 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/09/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/09/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
