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200-190
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 1D-40A 50029229690100 2001900 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-01-18_22206_KRU_1D-40A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22206 KRU 1D-40A 50-029-22969-01 Caliper Survey w/ Log Data 18-Jan-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 200-190 T40015 1/24/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.24 15:24:29 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 9, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-40A KUPARUK RIV UNIT 1D-40A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/09/2024 1D-40A 50-029-22969-01-00 200-190-0 W SPT 5977 2001900 1500 2218 2218 2218 2218 628 718 715 712 4YRTST P Adam Earl 2/25/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-40A Inspection Date: Tubing OA Packer Depth 970 1720 1680 1670IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240225145321 BBL Pumped:0.6 BBL Returned:0.6 Tuesday, April 9, 2024 Page 1 of 1 5HJJ-DPHV% 2*& )URP :HOO,QWHJULW\6SHFLDOLVW&3) &3) Q#FRQRFRSKLOOLSVFRP! 6HQW 0RQGD\-XO\ $0 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW .58'3DGQRQZLWQHVVHG0,7,$V $WWDFKPHQWV 0,7.58'3$'6,7(676[OV[ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001900 Type Inj N Tubing 580 585 585 585 Type Test P Packer TVD 5977 BBL Pump 2.1 IA 145 1800 1770 1770 Interval 4 Test psi 1500 BBL Return 2.1 OA 43 54 54 54 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001830 Type Inj N Tubing 150 160 160 160 Type Test P Packer TVD 3626 BBL Pump 0.3 IA 380 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 0.3 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1972400 Type Inj N Tubing 100 1800 1740 1730 Type Test P Packer TVD 3621 BBL Pump 1.7 IA 25 1800 1740 1730 Interval 4 Test psi 1500 BBL Return 1.6 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2000470 Type Inj N Tubing 500 505 505 505 Type Test P Packer TVD 3526 BBL Pump 0.8 IA 140 1800 1700 1690 Interval 4 Test psi 1500 BBL Return 0.5 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1D Pad Galle / Borge 07/14/22 Notes: Notes: 1D-40A 1D-101 1D-137 Notes:Single casing well 1D-106 Notes:Single casing well. Tubing plug at 4444' MD. Open Pocket at 4286' MD. CMIT T x IA. Notes:Single casing well STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0714_MIT_KRU_1D-pad_4wells 9 9 9 9 9 9 9 -5HJJ 1D-40A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 29,2013 TO: Jim Regg P.I.Supervisor ') �IZZ�I SUBJECT: Mechanical Integrity Tests g CONOCOPHILLIPS ALASKA INC ID-40A FROM: Lou Grimaldi KUPARUK RIV UNIT 1D-40A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Ye- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1D-40A API Well Number 50-029-22969-01-00 Inspector Name: Lou Grimaldi Permit Number: 200-190-0 Inspection Date: 5/28/2013 Insp Num: mitLG130528110505 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well', 1D-40A - Type Inj ' W TVD 5977 IA 360 2200 2173 ' 2171 • PTD Type Test', psi 2001900 � YP sPT Test ' 0,4 6sa H sss. 848 844 Interval INITAL P/F P Tubing 1406 • 1406 1405 1401 Notes: Initial MIT on recent workover.Crew well prepared for this good solid test. 1.9 bbl's diesel pumped, 1.5 bbl's returned, SCANNED FEB 2 p 2014 Wednesday,May 29,2013 Page 1 of 1 7 r, WELL LOG TRANSMITTAL MAY 1 0 2013 AOGCC To: Alaska Oil and Gas Conservation Comm. April 29, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Multi Finger Caliper(MFC): 1D-40A Run Date: 4/25/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 matthew.cook@halliburton.com 1D-40A Digital Data(LAS),Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22969-01 SCANNED MAR 13 2014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: Signed: kiteLf.,-_LII) STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well 17' Plug Perforations r Perforate r Other r Alter Casing r Rill Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: V' 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 200 -190 3. Address: 6. API Number: ✓ P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50 029 - 22969 - 01 7. Property Designation (Lease Number): ✓ 8. Well Name and Number: ✓ ADL 25661, 25650 1 D - 40A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): CCL Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: si Total Depth measured 11110 feet Plugs (measured) 10463 true vertical 6360 feet Junk (measured) none Effective Depth measured 11041 feet Packer (measured) 10385 true vertical 6323 feet (true vertical) 5978 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20 117 117 SURFACE 6944 9.625 6978 4257 PRODUCTION 10527 7 10559 6068 LINER 733 3.5 11110 6361 SCANNED JUL 0 2313 . E Perforation depth: Measured depth: 10904' - 10944' n • True Vertical Depth: 6250' -6271' '' 0 '1 ;.� a p ya Tubing (size, grade, MD, and TVD) 3.5, L -80, 10431 MD, 6001 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER ZXP LINER TOP PACKER @ 10385 MD and 5978 TVD NIPPLE - DS LANDING NIPPLE @ 498 MD and 498 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r' Service J' Stratigraphic r 16. Well Status after work: / Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR WIND r WAG 17 GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -031 Contact Jonathan Coberly a. 265 -1013 Email Jonathan .Coberlya,conocophillips.com Printed Name Jonathan Coberl. Title Wells Engineer Signature Pii"5� Phone: 265 -1013 Date 0 /Z0 /3 - Y� 2 RBDMS MAY - 9 201 Form 10 -404 Revised 10/2012 �// // 3 Subm rtg al Only �' : KUP 1D-40A ' CionocoPhillips u . a Well Attributes Max Angle & MD TD .,, Alaska Inc, v f Wellbore APVUWI Field Name Wellbore Status Ind ( °) MD (ftKB) Act Btm (ftKB) Conocot „hp• 500292296901 KUPARUK RIVER UNIT INJ 68.32 3288.42 12225.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date : - o 5mzo131rs61s PM SSSV: LOCKED OUT Last WO: 4/27/2013 I 40.60 9/2/2000 Well conr9 Schematic - Actual Annotation Depth (ftKB) End Date Annotation I ( Last Mod By End Date Last Tag: SLM 10,914.0 6/21/2010 Rev Reason: WORKOVER haggea 5/6/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.140 35.0 117.0 117.0 91.50 H - 40 WELDED - - Casing Description String 0... String ID ... Top (ftKB) 'Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 29 SURFACE 95/8 8.835 34.4 6,978.3 4,256.8 40.00 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.8 10,559.3 6,067.6 26.00 J - 55 BTC - MOD -- Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd LINER 31/2 2.992 10,377.5 11,110.0 6,360.7 9.30 L -80 SLHT Details 1 Top Depth (TVD) Top Ic! Nomi... T op (ftKB) (ftKB) (°) Rem Description Comment ID (in) 10,377.5 5,974.0 58.93 TIE BACK BAKER TIE BACK SLEEVE 5250 10,384.8 5,977.8 58.94 PACKER BAKER ZXP LINER TOP PACKER 4.875 10,392.4 5,981.7 58.96 HANGER BAKER FLEX LOCK LINER HANGER w/ RS NIPPLE 4.250 10,404.4 5,987.9 58.99 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 10,463.4 6,018.21 59.12INIPPLE !OTIS XN NIPPLE w/ 2.75" NO GO 2.750 CONDUCTOR, 117 Tubing. Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 3 1/2 2992 29.0 10,430.7 6,001.4 9.30 L -80 EUE 8rd Completion Details g Top Depth NIPPLE. 498 "1 (TVD) Top Inel Noml... 1 Top (ftKB) (MB) (1 Rem Description Comment ID ('n) 1 29.0 29.0 -0.21 HANGER FMC GEN V 11 "x 3.5 ", TYPE H PROFILE 2.992 4 98.0 498.0 0.61 NIPPLE DS LANDING NIPPLE 2.813 10,394.0 5,982.5 58.96 SEAL ASSY 80/40 GBH SEAL ASSEMBLY 2.960 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (RKB) (ftKB) (°) Description Comment Run Date ID (!n) 10,463.0 6,0180 59.12 PLUG 3.5" XXN PLUG (43" OAL) SET IN LINER NIPPLE 6/21/2010 0.000 SURFACE, • Perforations & Slots 348,978 - Shot MIR , ' . Top (TVD) Btm (TVD) Dens I Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 10,904.0 10,944.0 6,249.7 6,271.0 C -4, C -2, 1D-40A 4/11/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg phasing, random orientation MA 10 Notes: General & Safety End Date Annotation 12/4/2000 NOTE: WELL SIDETRACKED - Drilled out thru bottom of Production Casing Cement Plug 4/27/2001 NOTE: Pumped HPBD 2520 Ibs rock salt & 5562 Ibs 16/20 sand 11/27/2006 NOTE: WORKOVER 10/9/2009 NOTE: IDENTIFIED TUBING LEAK BETWEEN 8253' & 8722' WITH HOLEF)NDER 8/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/27/2013 NOTE: 3 1/2'WO Tubing String is Plastic Coated SEAL ASSY, 10,394 PLUG, 10,483 PRODUCTION, . ■ i 33- 10,559 Ma nd r el Details T o p p Port IPERF. N ... (TV Inc! Latch 10,90470,944 Valve N. T op (R KB) (R KB) (') Make Model ( in) Sery TYPe Type ( ) TRO (psi) Run Run Date Com... 1 10,338.9 5,954.0 58.84 Camco ' MMG 1 1/2 PROD DMY RKP 0.000 0.0 5/5/2013 I I [1 LINER. 10,377 - 11,110 TD (10-40A), 11,110 • • Conocahilhps Time Log & Summary Wel!view Web Reporting Report Well Name: 1 D - 40 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/20/2013 1:30:00 PM Rig Release: 4/27/2013 9:30:00 PM Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 04/20/2013 24 hr Summary Rig move from 1 C- to 1D pad. Arrive on location @ 06:00 hrs, P/U 11 "BOPE stack. Replace Rig tire, spot over well. * ** Rig Accept @ 13:30 hrs * ** Rig up hard line, pressure test. Take on fluids. 01:30 05:30 4.00 MIRU MOVE MOB P Rig move from 1 C pad to 1D pad. 05:30 12:30 7.00 MIRU WHDBO RURD P PJSM - crw change - Install 11" BOPE stack 12:30 19:30 7.00 MIRU MOVE EQRP X Damaged tire on Rig. Change out tire. Time will be recorded under rig move time. 19:30 20:30 1.00 MIRU WELLPF PRLO X Grease IA valve & fix broken needle valve on IA prior to moving rig over well. Fix tear in secondary containment. Report spill of 1 teaspoon of diesel on ground /rig mat. 20:30 21:30 1.00 MIRU MOVE MOB P Spot rig over well. 21:30 00:00 2.50 MIRU WELCTL RURD P * * ** Rig Accept * ** rig up hard lines, take on fluids. Rig accept time backed up to 13:30 hrs. 8 hours for tire change /spot rig over well charged to rig move. 8 hours for BOP swap and IA valve charged to the well. 34/21/2013 Pull BPV, Reverse circ 50 bbls, then switch to pump down tubing, pumped additional 370 bbls of 9.6# KWF. Flow check - good, set BPV, ND tree, NU BOP's, BOPE test 250/3500 psi. State test waived by Bob Noble. Performed full choke & kill drill during initial well kill. 00:00 02:00 2.00 MIRU WELCTLMPSP P Rig up lubricator and pull BPV. Pressure tubing 220 psi, IA 280 psi. 02:00 04:00 2.00 MIRU WELCTL CIRC P PJSM - Kill well - perform choke and kill drill. Kill tank volume 93 bbls of frozen fluid. Reverse first 50 bbls holding choke pressure to clean up diesel head. Stop pumping record SI pressures, SITP 220, SICP 280 psi. Start pumping the long way, follow well kill drill. 04:00 07:30 3.50 MIRU WELCTL CIRC P Stopped pumping 270 bbls of the 370 bbls of 9.6# brine pumped due to Kill tank space. SITP 0, IA -SICP 400 psi. OA 200 psi Vac truck pulling off fluid from kill tank. 07:30 09:00 1.50 MIRU WELCTL CIRC P Continue with well kill. 9.6 to surface. Page 1 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:30 0.50 MIRU WELCTL OTHR P No flow 30 mins. 09:30 10:00 0.50 MIRU WELCTL MPSP P install BPV and tested to 1000 psi down IA up tbg. good test. 10:00 13:30 3.50 MIRU WELCTL NUND P ND TREE. Kick out old tree and P/U new tree, hang in the cellar. 13:30 20:30 7.00 MIRU WELCTL NUND P NU BOPE. Tighten flanges, install VBR into top rams. 20:30 23:00 2.50 MIRU WHDBO BOPE P Shell test PJSM for BOP testing. Start testing 250/3000 psi. State test waived by Bob Noble. 23:00 00:00 1.00 MIRU WHDBO BOPE P Annular not holding, leak off. Re -Test plug against rams - good. Move test joint - re -test - no luck. 34/22/2013 Continue changing out the element then lower piston seals on the Annular. Removed the blanking plug and installed the landing joint, RILDS. Complete remaining BOPE test Annular and HCR 250/3500psi. 00:00 00:30 0.50 MIRU WHDBO BOPE P Annular not testing. 00:30 01:30 1.00 MIRU WHDBO BOPE X PJSM - Change out annular 01:30 11:30 10.00 MIRU WHDBO BOPE T Exceeded 12 hour BOPE test allocation. Load and strap 3.5" DP while changing out annular. 11:30 13:00 1.50 MIRU WHDBO BOPE T began linking out IA pulled test jt. pulled blanking plug installed landing jt re -test to 2550 psi no fluid past hanger fluid return to accumulator on open side. 13:00 18:00 5.00 MIRU WHDBO BOPE T continue to work on annular, changed out piston seals. 18:00 20:00 2.00 MIRU WHDBO PRTS T Set up to test with low test, notice fluid leaking out the IA - leaking by in the tree possible hanger seal or control line. Call out FMC - tighten in LDS, no change, decent leak off with a light drip out the IA valve. 20:00 21:00 1.00 MIRU WHDBO PRTS T Rig up a line to the IA, bring up pressure to 2100 psi. SI the IA, holding solid at 2100 psi. Pressure test against upper pipe rams to 3500 psi, inital test leaked off to 2800 psi. IA never changed. Bumped up to 3500 psi - hold for 5 minutes. Bleed down to zero. Open Upper rams and close annular. 21:00 22:00 1.00 MIRU WHDBO BOPE T Test Annular element - low test good. High test 3500 psi - holding. IA pressure staying constant at 2100 psi. Good test. Test HCR valve - 250/3500psi. - good test. 22:00 00:00 2.00 MIRU WHDBO BOPE T Rig up Riser and break down test joint & X- overs. 34/23/2013 POOH laying down 3.5" Completion string. Field went to Phase 3 conditions. Page 2 of 6 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 MIRU WELCTL MPSP P PJSM - Clean up rig floor & cellar. Rig up Dry rod and pull BPV, M/U Landing joint, BOLDS. 02:00 04:00 2.00 COMPZ RPCOM PULL P P/U on 3.5" completion string. Pulled smooth max. pull 107K. Hanger = 95K Seals = 107K String weight = 102K P/U 20 ft & circulate 2 X B/U @ 8 bpm, 900 psi 04:00 04:30 0.50 COMPZ RPCOM PULL P 30 minute No -flow - Good - 04:30 20:30 16.00 COMPZ RPCOM PULL P POOH with 329 jts of 3.5" 9.3# L -80 P/C de completion string.pitting on pin ends from 7200 -ft +/- ft and below exterior of tubing looks good. Recovered 79 SS Bands 20:30 00:00 3.50 COMPZ RPCOM OTHR T Suspend operations due to Phase 3 Conditions in the CPF 1 area 04/24/2013 Continue to standby for Phase 3 conditions. Install wear ring, PU, MU and RIH w/ BHA #1 (7" Csg Scraper assy) while PU 3 -1/2 DP from 233 -ft to 10,410 -ft. Reverse circulate 1 -1/2 DP volumes. Monitor well - static. POOH laying 3 1/2 DP to 9005 -ft. 00:00 09:00 9.00 COMPZ RPCOM OTHR T Waiting on Phase 3 weather to lift D pad released to Phase 2 @ 09:00 hrs by Jim D/S lead 09:00 11:00 2.00 COMPZ RPCOM OTHR P install wear ring in tubing spool, upload scraper and subs to floor 11:00 21:00 10.00 0 10,410 COMPZ RPCOM TRIP P make up 7" scraper assembly & rih picking up 3.5 D/P to 10,394 -ft. 148k up wt, 98k do wt. No -go scraper @ 10,384 -ft with mule shoe @ 10,410 -ft. PU to 10,405 -ft 21:00 21:45 0.75 10,405 10,405 COMPZ RPCOM CIRC P Reverse circulate 126 bbls @ 3 bpm @ 400 psi 21:45 22:15 0.50 10,405 10,405 COMPZ RPCOM OWFF P Monitor well for flow on trip tank - Static 22:15 00:00 1.75 10,405 9,005 COMPZ RPCOM PULD P POOH from 10,405 -ft to 9,005 -ft X4/25/2013 Con't to POOH laying down DP f/ 9,005 -ft to BHA. Lay down BHA. RU eline and run gyro and 40 ARM caliper. _ 00:00 04:00 4.00 9,005 3,136 COMPZ RPCOM PULD P Continue to POOH laying down 3 -1/2" DP from 9,005 -ft to 3,136 -ft 04:00 05:30 1.50 3,136 3,136 COMPZ RIGMNT SLPC P Slip and cut 84 -ft of 1 -1/8" drill line and service draw works. 05:30 09:00 3.50 3,136 COMPZ RPCOM PULD P continue to lay down D/P stood back drill collars. laid down BHA 1 09:00 11:00 2.00 COMPZ RPCOM NUND P Clear floor & NU dutch rizer for wire line log 11:00 18:00 7.00 COMPZ EVALWE ELOG P PJSM with HES. RU HES to run CCL. , GR, csg.caliper and GYRO log from 10,337 to surface. @ 15:30 hrs Gyro quit working @ 6600 ft. continued in the hole to run Caliper to 10,387 -ft. Wait for 40 ARM caliper to activate - Attempt to log out of the hole - had no movement. Page 3 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 23:00 5.00 COMPZ EVALWE ELOG T Pull 2,000 lbs tension against logging tools and wait for memory tools to disengage 40 ARM Caliper tool. @ 23:10 - 1 hr before ending time , tools came loose. 23:00 00:00 1.00 COMPZ EVALWE ELOG P Begin logging out of the hole 34/26/2013 Conitnue to log well w/ 40 ARM caliper, re -head. RIH w/ 40 Arm caliper w/ CCL and GR to 10,400 -ft and log out. RD E -line. RIH w/ 3 -1/2 plastic coated completion string to 10,434 -ft and SO 5k. Space out, found hanger pup not PC. Discuss w/ Town engr, send to Baker machine to be swapped out. 00:00 02:00 2.00 COMPZ EVALWE ELOG P Continue logging out of the hole - All tools recovered. Inspect equipment - found cable head shorted, check Gyro tools - Functioning 02:00 04:30 2.50 COMPZ EVALWE ELOG P Re head, PU and check tools 04:30 10:30 6.00 COMPZ EVALWE ELOG P RIH w/ 40 Arm caliper tool to 10,400 -ft, Log out of the hole. RD HES 10:30 11:30 1.00 COMPZ RPCOM NUND P ND Dutch riser and pull wear ring 11:30 21:30 10.00 0 10,437 COMPZ RPCOM PUTB P PU & RIH with production string to 10,437 -ft and No -Go w/ 5k SO. 105k upwtand75kdnwt. PUtoupwt plus 7 -ft and mark pipe. POOH to 10,341 -ft. 21:30 22:30 1.00 10,437 10,397 COMPZ RPCOM HOSO P PU and RIH w/ 4 pup jts = 24.71 -ft and jt# 336 to 10,396.8 -ft. Found pup joint on hanger was not Plastic coated. Call Town engr and discuss - ship to Baker machine to change out. Secure well. 22:30 00:00 1.50 10,397 10,397 COMPZ RPCOM HOSO T Ship hanger and plastic coated pup joint to Baker machine to be installed. 34/27/2013 Wait for hanger, RIH while circulating and locate top of SBE, Change hole over to CI sea water and land hanger. RILDS, PT IA and TBG. Shear out SOV. Install TWC and test barrier. ND BOPE, NU Tree. Test voids and Tree. FP. RDMO. 00:00 02:00 2.00 10,397 10,397 COMPZ RPCOM HOSO T Ship hanger and plastic coated pup joint to Baker machine to be installed. 02:00 03:30 1.50 10,397 10,397 COMPZ RPCOM HOSO P MU FMC Gen V 11" x 3 -1/2" Tubing Hanger, RIH w/ charge pump on and locate seals @ 22 -ft in. This calculated up gave showed to have 6 -ft of seals in SBE. POOH, lay down 25 -ft of pups and replace with 30 -ft jt. RIH w/ pump on @ .25 bpm and locate SBE @ 16 -ft in. Calculates to have 7 -ft space out when landed. 03:30 05:30 2.00 10,397 10,397 COMPZ RPCOM CIRC P Reverse circulate w/ 20 bbl high visc sweep, followed by 60 bbls of sea water, followed by 275 bbls of CI sea water and chase with 15 bbls of sea water. Pumping at 3.5 bpm @ 480 psi. Page 4 of 5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:30 1.00 10,397 10,431 COMPZ RPCOM OTHR P Drain BOP stack, Land hanger. RILDS. 06:30 08:30 2.00 10,431 COMPZ RPCOM PRTS P PT TBG to 3000 PSI 08:30 09:00 0.50 COMPZ RPCOM PRTS P pressure test IA to 3500 psi 09:00 09:30 0.50 COMPZ RPCOM OWFF P No flow well 30 rains. 09:30 10:00 0.50 COMPZ RPCOM PRTS P blew SOV @ 2300 psi 10:00 10:30 0.50 COMPZ RPCOM THGR P install BPV & test to 1000 psi good test 10:30 12:00 1.50 COMPZ RPCOM NUND P ND BOPE 12:00 15:30 3.50 COMPZ RPCOM NUND P NU tree 15:30 17:00 1.50 COMPZ RPCOM THGR P test tree 250 /5000 ps i pulled plug g 17:00 19:00 2.00 COMPZ RPCOM FRZP P PJSM RU LRS to freeze protect well with 73 BBLS of Diesel and let well equalize. RD Hoses. 19:00 20:00 1.00 COMPZ RPCOM MPSP P Install BPV, Dress and secure well. 0 PSI TBG, 0 PSI IA and 200 PSI OA 20:00 21:30 1.50 COMPZ MOVE MOB P Held PJSM, Prepare to move off 1 D-40A. Conduct walk around. Pull off well. Release Nordic rig 3 @ 21:30 hrs. Page 5 of 5 A w \ I �jj s THE STATE Alaska Oil and Gas -_ ALAS Conservation Commission GOVERNOR SEAN PARNELL ; 333 West Seventh Avenue p ;;' Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Jonathan Coberly SCANNED MAR 13 2013 Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 �� O _ G D Re: Kuparuk River Field, Kuparuk River Oil Pool, 1D-40A Sundry Number: 313 -031 Dear Mr. Coberly: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P4 n t/ Cathy P. oerster Chair DATED this 8 day of February, 2013. Encl. STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMMON t 1 JAN 2 4 2013 APPLICATION FOR SUNDRY APPROVALS e 20 AAC 25.280 AOGCC 1. Type of Request: Abandon r Plug for Redrill r- Perforate New Pool r Repair w ell Change Approved Program E Suspend r Rug Perforations r Perforate r Pull Tubing )✓ • Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r After casing r Other I — 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 200 - 190 3. Address: Stratigraphic r ° Service p- , 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22969 - 01 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WiII planned perforations require spacing exception? Yes r No t' 1D 9. Property Designation (Lease Number): 10. Field /Pool(s): �1� �otg ADL 25661, 25650 Kuparuk River Field / K k c,�44 Ri',/6,r r7, ' ( 0\, 11. PRESENT WELL CONDITION SUMMARY' Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 11110 6360 11041' 6323' 10463' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20 117' 117' SURFACE 6944 9.625 6978' 4257' PRODUCTION 10527 7 10559' 6068' LINER 733 3.5 11110' 6361' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 10904'- 10944' 6250' - 6271' 3.5 L -80 10451 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER ZXP LINER TOP PACKER MD =10385 TVD =5978 SSSV - CAMCO TRM-4E MD =2087 TVD =2028 • 12. Attachments: Description Summary of Proposal - 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r"" Exploratory r Stratigraphic l Development r Service 17 • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/4/2013 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG p Abandoned E Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly © 265 -1013 Email: Jonathan .Coberly(rDconocoohillios.com Printed Name Jonathan Cobe I Title: Wells Engineer Signature Phone: 265 -1013 Date //ZOgt / Commission Use Only Sundry Number :3) �v31 Conditions of approval: Notify Commission so that a representative may witness - Plug Integrity r BOP Test p' Mechanical Integrity Test r Location Clearance r° 1 2 _ RBDMS FEB01 Other: 0 U ► ��$ / C i J � ; O X 17 S L Spacing Exception Required? Yes ❑ No [+) Subsequent Form Required: /0 —1' ,/ APPROVED BY Q -I-6 Approved by: y- �- COMMISSIONER THE COMMISSION Date: r U 3 pproved application is valid for 12 months from the date of approval. O R / 012) �� �r 1 7 )� o� d Att � ' EN L a • • RECEIVED ConocoPhillips JAN 2 4 2013 Alaska P.O. BOX 100360 AOGCC ANCHORAGE, ALASKA 99510 -0360 January 18, 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 1D -40A (PTD 200 -190). The 1D -40A sidetrack was completed into the Kuparuk C -sand interval in 2000. The well is configured as a water injector that provides pressure support to producers 1D -42 and 1J -09. It has been shut in since 9/25/2009 due to a tubing leak and corroded injector header. The tubing leaks were identified during an MITIA failure on 9/26/2009 and a caliper log on 10/12/2009. A Holefinder log was conducted on 10/9/2009 that confirmed holes in the tubing from 8,253' RKB to 8,722' RKB. The internal tubing corrosion was determined to be too widely distributed to effectively patch. Since the tubing corroded in approximately 2 years, fusion bonded epoxy (FBE) internally coated 3 ' /2" tubing will be run. The last CMIT TxIA/drawdown test passed on 10/9/2009. This well has been identified as a candidate for an expense workover to repair the corroded tubing and to inspect the production casing for signs of 1D pad subsidence. The 3 ' /2" production tubing will be pulled, a caliper and gyro will be run on the casing, and new FBE internally coated 3 ' /2" tubing will be run. A recent SBHP of the Kuparuk C -sand interval on 7/12/2012 measured 2,293 psi at a depth of 5,824' TVP. This is equivalent to a 7.6 ppg equivalent mud weight. Seawater exceeds the reservoir pressure and will be used as KWF. The `XXN' plug currently set in the `XN' liner nipple at 10,463' RKB will isolate the reservoir from the KWF to minimize fluid loss. It will also mechanically isolate the reservoir pressure from the workover. If you have any questions or require any further information, please contact me at 265 -1013 or Jonathan.Coberly@conocophillips.com. Sincerely, I I OF FA 4 Jonathan Coberly Wells Engineer CPAI Drilling and Wells • • 1D -40A Rig Workover, P &R Tubing (PTD #: 200 -190) Current Status: Kuparuk well 1D -40A is a Kuparuk C -sand injector. The well is currently shut in since 9/25/2009 due to multiple tubing leaks. Scope of Work: Pull 3 ' /2" tubing, inspect the casing, and install new internally coated 3 'A" tubing. General Well info: MASP: 1,711 psi Reservoir pressure/TVD: Kuparuk C -Sand — 2,293 psi / 5,824' (7.6 ppg EMW) measured 7/12/2012 Wellhead type /pressure rating: FMC Gen V, 11" / 5M Nordic 3 BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: CMIT TxIA — passed 10/9/2009 CMIT TxIA — scheduled during pre -rig well work POT - T/PPPOT - T/POT- IC/PPPOT -IC — passed 1/4/2013 Well Type: Injector Estimated Start Date: February 20, 2013 Production Engineers: David Lagerlef / Dana Glessner Workover Engineer: Jonathan Coberly (265 -1013 / Jonathan.Coberly @conocophillips.com) Proposed Pre -Rig Work: Slickline 1. CMIT TxIA against `XXN' plug. 2. RU SL. RIH and lockout SSSV. POOH. 3. RIH and set catcher on `XXN' plug. POOH. 4. RIH and remove DV from GLM #2. Leave GLM #2 open. 5. RDMO SL. Other 6. Set BPV within 24 hours prior to rig arrival. Proposed Procedure: 1. MIRU. 2. Pull BPV. Reverse circulate KWF through open GLM. Monitor for 30 minutes. 3. Install two way check valve. Pressure up on IA to 1,000 psi to test two way check valve. ND tree. 4. NU and test BOPE to 250/3,500 psi. //v Yh /j 4 6 C 2 ¢ i-' vS ' k c,c, Cl V c e 5. RU lubricator and pull two way check valve. 6. MU landing joint. BOLDS. Pick up and reverse circulate well clean. 7. POOH laying down tubing. 8. Offload old tubing. Load new tubing. 9. RIH w/ casing scraper to liner tie back sleeve. Reverse circulate the well clean. POOH w/ scraper assembly. 10. RU E -line. Log with caliper and gyro from liner tie back sleeve to surface. RDMO E -Line. 11. RIH to just above the SBE with new FBE internally coated 3 ' /2" tubing injector completion. 12. Engage seal assembly until fully located. Space out to allow for future subsidence. Mark the pipe and POOH two joints. Space out with pup joints. 13. MU tubing hanger. Swap well over to CI seawater. Land the tubing hanger. RILDS. 14. PT tubing to 3,000 psi. PT casing to 3,500 psi with 2,500 psi on the tubing. Bleed pressure to 0 psi. • • 15. Shear SOV. 16. Install two way check. PT the IA to 1,000 psi to test two way check from below. 17. ND BOPE. NU tree. PT tree and tubing hanger packoffs 250/5,000 psi. 18. Remove two way check. Freeze protect with diesel to 2,000' TVD. Set BPV. 19. RDMO. Proposed Post -Rig Work: Slickline 1. Pull BPV. 2. RIH and pull the SOV from the GLM and replace w/ a DV. POOH. 3. RIH and pull catcher sub set on `XXN' plug. POOH. 4. RIH and pull `XXN' plug. POOH. RD SL. Other 5. Reset the well houses and flow lines. 6. Turn well over to Operations. • • ConocoPhillips Well: 1D-40A 2013 RWO PROPOSED COMPLETION API: 500292296901 Conductor Casing: PTD: 200-190 20 ", 91.5 #, H -40 to 117' RKB Proposed 3 Completion DS 1- Surface Casing: • Tubing, 3'/ ", 9.3 ppf, L -80, 8rd 9 -5/8 ", 40 #, L -80 to 6,978' RKB EUE -Mod (FBE Internally Coated) 4 , • 2.875" ID DS Nipple ( -500' MD) • 3 -1/2" x 1 -1/2" MMG GLM Production Casing: • 15" Locating Seal Assembly 7 ", 26 #, J -55 to 10,559' RKB Production Liner: 3.5 ", 9.3 #, L -80 from 10,378' RKB to 11,110' RKB Perforations: MD Zone 10,904' - 10,944' Kuparuk C — 2.875" ID DS Landing Nipple ( -500' MD) 4— 1 -1/2" CAMCO MMG GLM _ Tie Back Sleeve, ZXP Liner Top Packer, Liner Hanger 4orm• •• Baker 80 -40 SBE (4" ID) w/ 41.1.010 Locating Seal Assembly (3" ID) \/ x 4— Otis 'X' Nipple (2.813" ID) • Directional: Max Incline: 68.3° @ 3288' Max Dogleg: 7.2° @ 7066' ALA Fill at: 10,890' SLM Last Updated: 22- Jan -13 TD: 12,225' RKB Updated by: JRC ts KU P • 1 D -40A ConocoPhillips Well Attributes Max Angle & MD TD Alaska. [MC Wellbore APVUWI Field Name Well Status Inc! ( °) MD (MB) Act Btm (ftKB) COnccoar. 500292296901 KUPARUK RIVER UNIT INJ 68.32 3,288.42 12,225.0 Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date "' SSSV: TRDP Last WO: 12/3/2006 40.60 9/2/2000 Well Gonad' - 10 -40A, 5/30/2012 9:37:06 AM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 10,914.0 6/21/2010 Rev Reason: WELL REVIEW osborl 5/30/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd `NM :),,. CONDUCTOR 20 19.140 35.0 117.0 117.0 91.50 H WELDED woo 1 iz Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.835 34.4 6,978.3 4,256.8 40.00 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (MB) Set Depth (f.-. Set Depth (TVD) ... String Wt.. String ... String Top Thrd I ' PRODUCTION 7 6.276 32.8 10,559.3 6,067.6 26.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 10,377.5 11,110.0 6,360.7 9.30 L -80 SLHT I Liner Details Top Depth l (TVD) Top Inc! Nomi... Top (ftKB) (8KB) (°( Item Description Comment ID (in) 10,377.5 5,974.0 58.93 TIE BACK BAKER TIE BACK SLEEVE 5.250 10,384.8 5,977.8 58.94 PACKER BAKER ZXP LINER TOP PACKER 4.875 10,392.4 5,981.7 58.96 HANGER BAKER FLEX LOCK LINER HANGER w/ RS NIPPLE 4.250 10,404.4 5,987.9 58.99 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 CONDUCTOR, € ! 10,463.4 6,018.2 59.12 NIPPLE OTIS XN NIPPLE w/ 2.75" NO GO 2.750 35-117 - Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I TUBING 3 1/2 2.992 29.0 10,450.6 6,011.6 930 L - 80 8 rd EUE SAFETY VLV, i 0 i 1 2.067 Completion Details 19._ l- Top Depth y (TVD) Top Intl Nomi... { Top (ftKB( (ftKB) ( °) Rem Description Comment ID (In) 29.0 29.0 -0.21 HANGER FMC GEN V TUBING HAER 3.500 2,087.4 2,028.1 33.90 SAFETY VLV CAMCO TRM-4E SAFETY VALVE (Ser # HWS -86) 2.812 GAS LIFT, { 1 0,369.4 52:96022998.1891 ,969.8 58.91 NIPPLE OTIS X NIPPLE w /2.813" PROFILE NG 2.812 2.765 ! 10,408.3 5,989.9 59.00 LOCATOR BAKER NO GO LOCATOR 2.990 10,411.5 5,991.5 59.00 SEAL ASSY BAKER SEAL ASSEMBLY 3.000 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) - Top Depth (TVD) Top Intl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 10,463.0 6,018.0 59.12 PLUG 3.5" XXN PLUG (43" OAL) SET IN LINER NIPPLE 6/21/2010 0.000 SURFACE, ,J L Perforations & Slots 34-6,978 Shot Top (TVD) Btm (ND( Dena Top(ftKB) Btm (RKB) (ftKB) (ftKB) Zone Date (ah• -- Type Comment 10,904.0 10,944.0 6,249.7 6,271.0 C -4, C -2, 1D-40A 4/11/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg phasing, GAS LIFT, random orientation 10,321 Notes: General & Safety End Date Annotation I I 12/4/2000 NOTE: WELL SIDETRACKED - Drilled out thru bottom of Production Casing Cement Plug 4/27/2001 NOTE: Pumped HPBD 25201bs rock salt 8 5562 Ibs 16/20 sand - NIPPLE 10,369 - 10/9/2009 NOTE: IDENTIFIED TUBING LEAK BETWEEN 8253' & 8722 WITH HOLEFINDER 8/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 I LOCATOR, 10,406 SPACE OUT _ -_- , TUBING, 10,410 SEAL ASSY, 10,412 , PLUG, 10,463 Mandrel Details Top Depth Top Port PRODUCTION, (TVD) Intl OD Valve Latch Size TRO Run 33- 10,558 Stn Top (ftKB) (6103) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... IPERF, ■ 1 2,765.5 2,535.3 50.12 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 12/2/2006 10,904 2 10,320.9 5,944.6 58.80 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/17/2006 I LINER. 10,377- 11,110 TD (1D-40A), � 11,110 • • 10. 1G-01 — AA 2B.035 issued 7/30/2008. aoo "" t./ 9. 1 F -16A — Well name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have passed since. Well last injected 4/2007. AA 2B.018 was issued in October 2007, but no injection has occurred into the well. Looking at the pressure plot, it is shown that the IA pressure appears to have been bled off in October and November. Was there well work conducted, maybe plug setting? There is email traffic exchanged regarding "what if" for an OA pressure sensor. Such have been installed on other wells, is that possible here? What are the plans for the well? �- --� 8. 1D-40A — Well name is 1D-40A. MITIA failed -- 10/1/2009. Well last injected 9/09. 7. 1D-119 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. 6. 1D-106—Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. Comments on the sheet indicate you have located the deep leak. 5. 1C-133 — Single casing well. MITIA failed 5/21/2010. Well last injected 5/2010. 4. 1C-10 — AA 2B.036 issued 8/25/2008. From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM To: 'NSK Problem Well Supv' StNINED JAN 2. 0 201. Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A -07, 1A -12 and 1B-02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1 A -12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. From: NSK Problem Well Supv [ mailto :n1617 ©conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 • . The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. DOO ° " - VO From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907- 943 -1720 / 1999 Pager 907 - 659 -7000 #909 s • ConocoPhillips Well 1D-40A Injection Data • Tbg Psi • IA Psi • OA Psi I 4000 3500 3000 - 2500 N a 2000 - 1500- 1000 500 0 09/10 10/10 11/10 12/10 01/11 Date PTD: 200 -190 Failed MITIA 10/1/2009 Well last injected 9/09 0 0 ConocoPhillips Well 1D-40A Injection Data • Water Injection *Gas Injection L 4000 3500 3000 - 2 2500 - a d 2000 - 1500 - 1000 - 500 1 III 0 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 220 243 206 30- Dec -10 0 0 220 243 206 29- Dec -10 0 0 220 243 206 28- Dec -10 0 0 220 243 206 27- Dec -10 0 0 220 243 206 26- Dec -10 0 0 220 244 206 25- Dec -10 0 0 221 244 206 24- Dec -10 0 0 221 243 206 23- Dec -10 0 0 221 243 206 22- Dec -10 0 0 221 244 207 21- Dec -10 0 0 221 245 207 20- Dec -10 0 0 222 245 207 19- Dec -10 0 0 222 244 206 18- Dec -10 0 0 221 245 206 17- Dec -10 0 0 222 245 206 16- Dec -10 0 0 222 245 206 15- Dec -10 0 0 222 245 207 14- Dec -10 0 0 222 246 207 13- Dec -10 0 0 223 246 207 12- Dec -10 0 0 223 246 207 11- Dec -10 0 0 223 246 207 10- Dec -10 0 0 224 247 207 9- Dec -10 0 0 224 247 207 8- Dec -10 0 0 224 247 207 7- Dec -10 0 0 224 247 207 6- Dec -10 0 0 224 247 207 5- Dec -10 0 0 225 247 207 0 • 4- Dec -10 0 0 225 247 208 3- Dec -10 0 0 225 248 208 2- Dec -10 0 0 225 248 208 1- Dec -10 0 0 225 247 208 30- Nov -10 0 0 225 248 208 29- Nov -10 0 0 225 248 208 28- Nov -10 0 0 226 249 208 27- Nov -10 0 0 226 249 208 26- Nov -10 0 0 227 250 209 25- Nov -10 0 0 227 250 209 24- Nov -10 0 0 227 250 209 23- Nov -10 0 0 228 250 208 22- Nov -10 0 0 228 250 208 21- Nov -10 0 0 228 250 208 20- Nov -10 0 0 228 250 208 19- Nov -10 0 0 228 250 208 18- Nov -10 0 0 228 250 208 17- Nov -10 0 0 228 249 208 16- Nov -10 0 0 228 250 208 15- Nov -10 0 0 228 251 209 14- Nov -10 0 0 229 252 209 13- Nov -10 0 0 230 252 209 12- Nov -10 0 0 230 252 209 11- Nov -10 0 0 230 252 209 10- Nov -10 0 0 230 252 209 9- Nov -10 0 0 230 254 209 8- Nov -10 0 0 231 254 209 7- Nov -10 0 0 231 254 209 6- Nov -10 0 0 231 254 209 5- Nov -10 0 0 232 254 209 4- Nov -10 0 0 231 253 209 3- Nov -10 0 0 232 254 209 2- Nov -10 0 0 232 255 209 1- Nov -10 0 0 232 255 210 31- Oct -10 0 0 233 255 210 30- Oct -10 0 0 233 255 210 29- Oct -10 0 0 233 255 210 28- Oct -10 0 0 233 255 210 27- Oct -10 0 0 233 255 209 26- Oct -10 0 0 233 256 210 25- Oct -10 0 0 233 255 210 24- Oct -10 0 0 233 255 210 23- Oct -10 0 0 233 255 210 22- Oct -10 0 0 233 255 210 21- Oct -10 0 0 234 255 210 20- Oct -10 0 0 233 255 210 19- Oct -10 0 0 233 255 210 18- Oct -10 0 0 233 255 210 17- Oct -10 0 0 233 255 210 16- Oct -10 0 0 234 256 210 15- Oct -10 0 0 234 256 210 14- Oct -10 0 0 234 256 210 0 • 13- Oct -10 0 0 234 256 210 12- Oct -10 0 0 234 256 210 11- Oct -10 0 0 234 256 210 10- Oct -10 0 0 235 256 210 9- Oct -10 0 0 235 256 210 8- Oct -10 0 0 234 257 210 7- Oct -10 0 0 235 257 210 6- Oct -10 0 0 235 257 210 5- Oct -10 0 0 235 257 210 4- Oct -10 0 0 235 257 210 3- Oct -10 0 0 235 257 210 2- Oct -10 0 0 235 258 210 ~ Page 1 of 2 ~ Z ~((t --( 2 C~ Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~~„ ~~~ 6~~ ~ Sent: Thursday, October 01, 2009 10:54 AM ~~ To: Regg, James B(DOA); Schwartz, Guy L(DOA); Maunder, Thomas E(DOA) Cc: NSK Problem Well Supv Subject: 1 D-40a PTD # 200-190, notice of failed MITIA Attachments: 1 D-40A.pdf Jim, ,/ 1 D-40a WAG injector, PTD # 200-190, has failed an MITIA. ~ Current T/UO = 958/1081/16 psi. The well has been shut in and freeze protected. We have added it to the monthly report. We plan to troubleshoot the well with slick line and e-line as needed to determine the problem. Any future repair or Administrative Approvals will be handled in a separate notification. I've enclosed a 90 day TIO plot and schematic for your convenience. Please note the tubing pressure is represented in a 0 to 4000 psi scale and all other data is represented in a 0 to 3000 psi scale. Please let me know if you have any questions. Perry Klein, for Problem Wells Supervisor 907-659-7224 , ~4 r f i~tj~j ~~'~' .: ;. ~~~~ • -- ~ 11 /6/2009 KRU 1D-40A PTD 200-190 10/ 1 /2009 TIO Pressures 2 30 30 30 iu. s~y ` 3000 2700 2~os 2ioe i~o• isa~ izoe a~ ci 31 ~ ~ ~ ~ ~ ~ ~ ~ PLO'I STAR"I' TIME MINOR TIME PL.OT UIJItF:'IION PLOT END TIME 03-JUL-09 10:39 MAJOR TIME WEEE t02160:00:tiB HRS al'-f1CT-09 lA:S4 ~~~~~ ~~~~ . ercx rs~r. 29-S EP-09 16:25:2 6 T.IG HAHE DESCRIPTION ~ --:^iJ.11Ft lATEST ''~~~~ ~ PREV WELL DRILLSITE WELL SCRATCH 75 FLOW TUHIN6 PRESSURE 958_ ld 40 SCRATCH_75 FLOW NHING TEMP B1- ^~7~' WELL 7777777 ???7??? ENTHY "I"YPE OPERATOR ?7????? ~ OPERATOR VERIFIED SCRaTCH 75 INNER ANNIJLUS PRES 1081. ~ SYSTEM AUTO ENTRY SCRATCI~75 OUTER ANN[JLUS PRES 16. ~ BOTH • • ,C~ke : G-- 4vc:c:~ ; WELL NAMI: WLICRUID-40 ~ ~(U P C c~ ~Ilips ~ ~ ~ ~F~~~ w~~~.~' ~n~~~~. r--~ ;' ~~y~(~, WellboreAPl/UWI FIeldName ' S00292296900 KUPARUK RNER UNIT __.. ____ ___ ... . ~~-, . Comment H2S (ppm) Date ... '.:'ecan .t-' ~t8 : .SSSV:TRDP 10 7/1/2008 m8t~c, w~ ~~: r Annotation Depth (RKB) Entl Date Annotation Last Tag: 11,055.0 12/26/2006 Rev Reason: F ... _ - . ._.. _ t".~XRirria~tCirituC ~ ` , ` ~~ "'. ~~ t ai sssv, GAS SURFACE, GAS LIFT, 10,321 TIE 59E.1 spa~e NIPPLE. COLLAR, 11.~1 COLLAR, ii.ma SHOE.11.108 CONDUCTOR 20 19.140 0.0 717.0 Casing Description Strin... String 1... Top (kKB) SM Depth (R. SURFACE 9 5/8 8.697 0.0 6,978.0 Casing DescNption Strin... String 1... Top (ftKB) Set Depth (ft. PRODUCTION 7 6.059 0.0 10,559.0 Casing Descripdon Strin... String I... Top (ttKB) Set Depth (R. LINER ~ 31/2 2.992 10.377.0 11.710.0 31/2 ~ 2.992 ~~~3 ' - ~ , . ~~~.. i~ 3.5" x 11 # 1 D-40A 68.41 ~ 8,889.73 ~ 72,225.0 ]ate KB-Grd (R) Rig Release Date 12/32006 40.60 92Y1000 End Date F r 9/192008 si : a a ~ a; ° ,~: a ; ' ` ~ iM Depth (ND) (tt... String ... Strin... String Top Thr 117.0 91.50 H-40 WELDED Set Depth (ND) (tt... String... Strin._ String Top Thr 4,256.7 40.00 L-80 BTC MOD iM Depth (ND) (R.. String ... Strin... String Top Thr 6,067.4 26.00 J-55 BTC MOD ~et Depth (ND) (ft... String ... Strin._ String 7op Thr 6,360.7 9.30 L-80 SLHT - -` ~ _ ~i ~'..`;.Ii'~~~~~~~~~ ~ pth (ND) (ftKB) Strin g Wt..GStrin... String Top Thrd 6.011.6 9 .30 L-80 8 rd EUE Top Btm ~(ND) ~(ND) ~ I I ~en% I I I (ftKB) (ftKB~ (ttKB) I(ttKB) Typa Zone (sho... Date Comment 10,904.0 70,944.0 6,249.7 6,271.0 IPERF C-4, C-2, 1D-40A 4.0 4/11/2001 2.5" HC/DP, 60-120 deg phasing, random orientation Top (ND) Valve Latch Size 7R0 Run gt~ (RKB) (ftK8) Make Model OD Ilnl Type Type (in) (psi) LINER. 10.377.11.110 TD (iD-40H). 11.110 ~ ~~~ STATE OF ALASKA • ~A~ ~ ~ 2~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPEIQ'~ ~~~ ~°~'~' ~'°'Y'I"'SS`o" ~. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other _ ~ WINJ to WAG Alter Casin Pull Tubin g ^ g ^ Perforate New Pool ^ Conversion Waiver ^ Time Extension ^ 2/23/os Change Approved Program ^ Operat. Shutdown^ Pertorete ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: ~ ,; U3 ~"~ 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ 6cploratory^ ( 200-190 3. Address: Stratigraphic ^ , Service ~D ~ ~ v 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ~, ~ 50-029-22969-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 35' • 1 D-40A 8. Property Designation: 10. Field/Pool(s): ADL 25661 •/ 25650 Kuparuk River Field /Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 11110' feet true vertical 6360' feet Plugs (measured) 10463' Effective Depth measured 10420' feet Junk (measured) true vertical 5995' feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 117' 20" 117' 117' SURFACE 6943' 9-518" 6978' 4256' PRODUCTION 10524' 7" 10559' 6067' LINER 733' 3-1/2" 11110' 6360' Perforation depth: Measured depth: 10904' - 10944' ~~ •., ~~ _ true vertical depth: 6249' - 6270' Tubing (size, grade, and measured depth) 3.5", L-80, 10438' MD. Packers & SSSV (type & measured depth) Baker ZXP 10384' TRM-4E SCSSSV 2087 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-Mcf Water-Bbl Casin P s re Tubin Pressure Prior to well operation 2026 29ti 1755 Subsequent to operation 3223 672 2851 14. Attachments 15. Well Class after proposed work: a•v;• 4'c' " Copies of Logs and Surveys run _ Exploratory ^ 3 3 L 7 Development " Service ~~~ Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A Contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date ~ r ~ ~ , Q qr ~~ s •~. ~• .~ ~ lGi~~; ~ 2009 ~~'/z - Form 10-404 Revised 04/2004 ~ ~5ubmit Origin ~~~~ . . ConocJPhillips Alaska RECEIVED AUG 1 3 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 aDO - \9° Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ~~ ConocoPhillips Well Integrity Projects Supervisor ~ SCANNED AUG 1 41007 . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTO# cement oumoed cement date inhibitor sealant date ft bbls ft Qal 1 0-32 200-173 10" nla nla nla 6.8 8/8/2007 1 0-36 200-130 20" n/a n/a nla 4.2 8/8/2007 10-37 200-204 20" n/a n/a n/a 4.2 8/8/2007 1 0-38 200-077 24" nla n/a n/a 4.2 8/8/2007 1 0-39 200-216 27" n/a n/a n/a 7.6 8/8/2007 10-40 200-190 13" nla n/a n/a 3.4 8/812007 10-41 205-188 12" n/a n/a n/a 1.7 8/8/2007 10-42 200-164 16" n/a n/a n/a 3.4 8/8/2007 10-131 198-110 6" n/a n/a nla 2 8/8/2007 MEMORANDUM . State of Alaska . TO: Jim Regg 0 -?J I P.I. Supervisor T\ e.r1 VI e" D 7 Alaska Oil and Gas Conservation Commission DATE: Monday, January 29, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lD-40A KUPARllK RIV UNIT 1D-40A FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv':¡'Ffl- Comm Well Name: KUPARUK RIV UNIT 1D-40A Insp Num: mitCS070122151709 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-22969-01-00 Permit Number: 200-190-0 Inspector Name: Chuck Scheve Inspection Date: 1/21/2007 Packer Depth 5976 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1220 2500 2460 640 780 780 -"--..---'--'._----'- 2100 2100 2100 Wen P.T. Il!te.IYª' Notes Pretest pressure observed and found stable. SCANNED FEB 0 7 2007 Monday, January 29, 2007 Page I of I · . RECEIVED STATE OF ALASKA D ALASKA OIL AND GAS CONSERVATION COMMISSION EC 1 9 2006 REPORT OF SUNDRY WELL OPERA TIONS\/aska Oil & Gas Cons. 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other Anflilirage Alter Casing 0 Pull Tubing 0 Perforate New Pool LJ 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 0 200-190/306-357 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22969-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 35' 1 D-40A n 8. Property Designation: ADL 25661'/25650 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 11110' . feet true vertical 6360' feet measured 10420' feet true vertical 5995' feet Length Size MD 117' 20" 117' 6943' 9-5/8" 6978' 10524' 7" 1 0559' 733' 3-1/2" 11110' Plugs (measured) Junk (measured) 10463' TVD Burst Collapse 117' 4256' 6067' 6360' Measured depth: 10904'-10944' true vertical depth: 6249'-6270' c· "1 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10438' MD. Packers & SSSV (type & measured depth) Baker ZXP pkr @ 10384' TRM-4E SCSSSV 2087' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: OilO Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl na na Representative Daily Average Production or Injection Data Gas-Met Water-Bbl SI SI Tubin Pressure Casin Pressure Service 0 Daily Report of Well Operations _X Contact Printed Name Signature GINJO WINJ0 WDSPL 0 Jill Long @ 265-1102 Jill Long !~6 Title Phone Wells Group Engineer /"//0 10· J"" (}07 -Jr:..g ~II () z.. Date çV (j II \V -/1 II" Pre red b Sharon All -Drake 63-4612 Form 10-404 Revised 04/2004 OR\G\N kp¡ ";) \ AI} 1Z.·lf·D~ Su~ Original Only ¿'K I?/;y ø/" -- Conoc~hillips Time Log Summary WelMew Web Reporting Well Name: 1 D-4OA Job Type: RECOMPLETION 11/27/2006 00:00 18:00 18.00 MIRU MOVE MOB P RDMO. Move rig from 3Q-09 to 1 D Pad. 18.2 miles, pad to pad rig move, derrick up. Move over 1 D-40A & RU. Accept Rig @ 1800 hours, 11/27/06. 18:00 20:00 2.00 COMPZr RPCOI\ NUND P Pull BPV. Verity well is dead. Inspect tubinQ hanQer threads. Install BPV. 20:00 22:00 2.00 COMPZr RPCOI\ NUND P Set blanking plug. Determine blanking plug is too long for BOP stack configuration. Will not be able to test lower rams with blanking plug installed. 22:00 00:00 2.00 COMPZ~ RPCOI\ NUND T Pull blanking plug and BPV. Set TWC. 11/28/2006 00:00 02:00 2.00 COMPZ~ RPCOI\ NUND P ND Tree. 02:00 04:00 2.00 COMPZr RPCOI\ NUND P Begin to NU BOP's. 04:00 07:00 3.00 COMPZr RPCOI\ NUND P Studs are not long enough to engage all threads of nuts. Get longer studs and finish NU BOP's. 07:00 10:30 3.50 COMPZr WELCT BOPE P John Crisp, AOGCC, waved witnessing of the BOP test. Begin testing BOP's. Bottom pipe rams I passed. Blind rams passed. 10:30 14:30 4.00 COMPZr WELCT EQRP P Variable rams failed, changed out rams and passed test. 14:30 17:00 2.50 COMPZr WELCT EQRP T Annular preventer failed. Wait on new elastomer seals and change out. Passed test. Had 2.5 hrs of downtime on rig due to NU and testing BOP's took 10nQer than 12 hrs. 17:00 22:00 5.00 COMPZ~ WELCT BOPE P Finish testing BOPs. Load pipe shed with tubing and strap. 22:00 00:00 2.00 COMPZ~ WELCT OTHR P RU lubricator to pull TWC. 11/29/2006 00:00 03:00 3.00 COMPZr WELCT OTHR P Finished rigging up lubricator. Pulled two-way check valve. 03:00 04:00 1.00 COMPZr RPCOI\ PULD P Rig up landing joint. 04:00 05:00 1.00 COMPZ~ RPCOI\ PULD P Hold PJSM. Pull tubing hanger to floor, observe well for flow. Pull tubing free from seals. Up wt of 115K, block wt = 34K. 05:00 06:00 1.00 COMPZr RPCOI\ CIRC P Pump surface to surface volume of 9.6# brine. 06:00 07:30 1.50 COMPZr RPCOI\ PULD P RD tubing hanger, circulation lines, well out of balance, pump heavier fluid down tubing POH laying down tubing. 225 jts out at 15:15. 300 jts out at 16:10. All joints out at 17:30. No holes were apparent when pulling. Significant internal pitting was observed. Also, the pin ends showed metal loss up to 1/4 inch. External tubing appeared in ood condition. 17:30 20:00 2.50 COMPZ RPCOI\ OTHR P Finish loading tubing in pipe shed and stra in . 20:00 OO:ÒO 4.00 COMPZ RPCOI\ RCST P Held PJSM and began running 3-1/2" completion. Drift X nipple with 2.80". Drift tubin with 2.867". 11/30/2006 00:00 06:00 6.00 COMPZ RPCOI\ RCST P Continue to run 3-1/2" completion. 06:00 09:00 3.00 RPCOI\ RCST P RU Cameo spooler on floor to run control line from SSSV to surface while holdin 5000 si.. 09:00 14:00 5.00 COMPZ RPCOI\ RCST P Pump at 1 bpm while running tubing to locate top of seal bore, top of seal bore at 10,430 'rkb. Work pipe into seal bore for space out, bottom of seal assembl mule shoe at 10,446' rkb. 14:00 19:00 5.00 COMPZ RPCOI\ RCST P PU tubing for space out and unsuccessful in trying to run seals back into seal bore. PU to 10,400' rkb and circulate 35 bbl vise pill down tubing at 2 bpm. PU to 10,370' rkb and pump at 7 bpm. Still cannot sting into seal bore. 19:00 00:00 5.00 RPCOI\ SLKL X RU slickline to tag with pump bailer. 12/01/200600:00 01:00 1.00 0 0 RPCOI\ SLKL X Zero SL counter at rig floor. RIH with 2.5" pump bailer and tag at 10,420' rkb. Unable to get deeper. POOH. Pump bailer is full of frac proppant, sand, metal shavin s, and scale. 01:00 03:30 2.50 0 0 COMPZ RPCOI\ SLKL X RIH with SL 2.5" drive down bailer. Tag up at 10,420' rkb. Unable to drive deeper. POOH. Bailer full of frac proppant, sand, metal shavings and scale. 03:30 08:30 5.00 10,410 0 COMPZ RPCOI\ TRIP X Decide to make cleanout run. TOH standing back 3-1/2" tubing. Spool control line back on reel, recovered all bands. Inspect Seal Assembly at surface, seals look worn with grooves on mule shoe. Will replace with new seals before runnin com letion. 08:30 11:30 3.00 0 0 COMPZ RPCOI\ OTHR X MU BHA for cleanout run. 2-7/8" mule shoe, 3 jts of 2-7/8" 511 hydril, x-over to 3-1/2" EUE. Totallen th = 90.91'. 11:30 17:30 6.00 0 10,452 COMPZ RPCOI\ TRIP X TIH with 3-1/2" tubing and clean out BHA. Tag fill at 10,440' rkb, begin to reverse circulate and work down to 10,452' rkb. Seen increase in pressure, so PUH 2' and reverse circulated at 10 bpm. Pump 2 viscous gel sweeps, recovering scale, frac sand, and metal ieces at surface. 20:30 00:00 3.50 10,452 0 COMPZ RPCOI\ TRIP X TOH standing back 3-1/2" tubing. 12/02/200600:00 01:00 1.00 0 0 COMPZ RPCOI\ OTHR P Hold PJSM. Cut drill line 01:00 07:00 6.00 0 COMPZ RPCOI\ TRIP P TIH with 3-1/2" completion. Run control line from SCSSSV to surface. Set slips on line and mashed control line. Splice control line top of jt #312 (590' rkb) - double band above and below. Run total of 78 SS bands to hold control line. 07:00 10:00 3.00 COMPZ RPCOI\ HOSO P Locate seal bore l' up on jt #331 (10,430' rkb). Pressure up to 500 psi for 10 min. Fully land seals, then space out 2' with a full joint of tubing below tubin han er. 10:00 13:00 3.00 COMPZ RPCOI\ CIRC P Circulate 275 bbls of corrosion inhibited seawater down tubing, followed with 90 bbls of seawater. IA has corrosion inhibited seawater from surface to to of ZXP liner to acker. 13:00 14:00 1.00 COMPZ RPCOI\ HOSO P Land tubing hanger and RILDS. Up wt = 120K, down wt = 70K, block wt = 34K 14:00 16:00 2.00 COMPZ RPCOI\ DHEQ P Pressure test tubing to 2500 psi. Bleed tubing down to 1200 psi and pressure test IA to 2500 psi for 30 min. 16:00 17:00 1.00 COMPZ RPCOI\ OTHR P Bleed pressure off tubing and shear SOV 17:00 18:00 1.00 COMPZ RPCOI\ DHEQ P Bleed down both sides to 1500 psi. Close SCSSSV and test. Good test. Bleed ressure to 0 si. 18:00 21:00 3.00 RPCOI\ OTHR P Set TWC and ND BOPE. 21:00 23:00 2.00 RPCOI\ NU and test tree 12/03/2006 00:00 03:00 3.00 COMPZ RPCOI\ FRZP P Pump 90 bbls diesel down IA Shut down and let U-tube with tubing. Freeze protect depth of 2500' MD in tubin and IA 03:00 05:00 2.00 COMPZ RPCOI\ OTHR P Blow down lines. Set BPV. Release ri 0500 hours, 12/3/06. . . ConocoPhiUips Alaska, Inc. KRU 1 D-40A ~ Angle~ TUBING API: 500292296901 Well Type: INJ (0-10438, SSSV Type: NIPPLE Orig Completion: 12/2112000 Angle @ TD: 57 deo /fi) 11110 00:3.500. Annular Fluid: Last W/O: 12/3/2006 Rev Reason: WORKOVER 10:2.992) Reference Log: Ref Log Date: Last Update: 1217/2006 Last Tag: 10903' TD: 11110 ftKB Last Tag Date: 11/' Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 117 117 91.50 H-40 WELDED SURF CASING 9.625 0 6978 4256 40.00 L-80 BTC MOD PROD CASING 7.000 0 10559 6067 26.00 J-55 BTC MOD LINER 3.500 10377 11110 11110 9.30 L-80 SLHT ~TOP I Bottom I TVD I Wt 1 Grade I Thread I I 3.500 I I Interval I TVD Zone Status Ft SPF Date Type Comment ~ I C-4,C-2 I I 40 I 4 14/11/2001 IPERF~ St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 2766 2535 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1212/2006 y, 2 10321 5944 CAMCO KBMG SOV 1.0 BEK 0.000 0 1212/2006 i i Depth TVD Tvpe Description ID i 29 29 HANGER FMC GEN V TUBING HANGER 3.500 if 2087 2027 SCSSSV TRM-4E #HWS-86 SCSSSV 2.812 if 10369 5969 NIP OTIS 'X' NIPPLE w/2.813" PROFILE 2.813 A 10408 5989 LOCATOR BAKER LOCATOR w/EXTENSION 2.990 10412 5991 SEAL BAKER SEAL ASSEMBLY 3.000 Depth TVD Tvpe Description ID 10377 5973 TIE BACK BAKER TIE-BACK SLEEVE 5.250 10384 5976 PACKER BAKER ZXP LINER TOP PACKER 4.875 10392 5981 HANGER BAKER FLEX-LOCK HANGER 4.250 10404 5987 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 10463 6017 NIP OTIS 'XN' NO GO NIPPLE wlXXN PLUG 2.750 ii 10463 6017 PLUG XXN PLUG 0.000 Ail 11041 6322 COLLAR BAKER LANDING COLLAR 3.000 ¡y 11074 6340 COLLAR BAKER FLOAT COLLAR 3.000 1.1 ~ SHOE BAKER FLOAT SHOE 3.000 Date Note 4/27/20011 Pumped HPBD 2520 Ibs rock salt & 55621bs 16/20 sand ~ I- LOCATOR (10408-10412. 00:5.000) LINER - (10377-11110, - - 00:3.500, Wt:9.30) - - Perf - - (10904-10944) I I . . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jill Long Wells Group Engineer ConocoPhillips Alaska, Inc. 700 G Street Anchorage, Alaska 99501 Re: Kuparuk River Field, Kuparuk Oil Pool, Well Name ID-40A Sundry Number: 306-357 Dear Ms. Long: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 60f November, 2006 Encl. dõÙ -(ct () . . .~ ConocoPhillips Alaska '\lED v () ,¡, Z006 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3,2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡lh Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk We1l1D-40A (PTD# 200-190). Injecting well 1 D-40A was drilled in September 2000 and completed in April 2001. A tubing leak was diagnosed in September of 2005 and reported to the AOGCC. A caliper log ran in April 2006 confirmed that the tubing has considerable corrosion with multiple wall penetrations of up to 98%. .,/ In order to repair this well and return it to injection a rig workover must be completed. This well is a poor patch candidate because of the multiple locations with wall loss of 98%, pitting (as indicated by the caliper log), and the probability that additional leaks will develop if the current tubing string remains in the hole. The purpose of the proposed workover will be to pull the existing tubing string and replace it with /' a new one. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-1102. Sincerely, {~U JJr èh--nø- Jill~9 . 0 Wells Engineer CPAI Drilling and Wells b. ill s'/f> Cff 1I~~~Db. r STATE OF ALASKA A\ ALASKA OIL AND GAS CONSERVATION COMMISSION " ~ APPLICATION F~~~2~~~RY APPROVALAjç; 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0, Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0· Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-190 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22969-01 . 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 Requires? Yes 0 No 0 0 1 D-40A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661'/25650 RKB 35' Kuparuk River Field 1 Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11110' 0 6360' 10940' Casing Length Size MD TVD Burst Collapse CONDUCTOR 117' 20" 117' 117' SURF CASING 6943' 9-5/8" 6978' 4256' PROD CASING 10524' 7" 10559' 6067' LINER 733' 3-1/2" 11110' 6360' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10904'-10944' 6249'-6270' 3-1/2" L-80 10438' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ZXP pkr @ 10384' Camco 'DS' nipple @ 530' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat November 13, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 265-1102 Printed Name Jill Lona ððY. />hr;y¡ I Title: Wells Group Engineer Signature (~k i 1., Phone 265-1102 Date V tbmmission Use Onlv .... Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3D{p-357 Plug Integrity 0 BOP Test ~ Mechanical Integrity Test ~ Location Clearance 0 Other: ~~O~5\ ~\~~'-J\'M.... ~-\t:'">\- S.",,,,.,,, Fo"" R",.'œd 1."\'0 c-fJ ~ ' RBDMS SF!. Jj, 2005 -- I ~~MISSIONER APPROVED BY ¡f,.¡ '()P Approved by: THE COMMISSION Date: Form 10-403 Revised 06/2006 ~~V3tNAl '-- þUbaUPlicate /~ //0 7·~ . . Kuparuk 1D-40A General Workover Procedure Pre-RiQ Work 1. Set plug in nipple below seal assembly and pull valve in GLM 2. Load well with brine circulating through open GLM 3. Pressure test plug to 2,000 psi and freeze protect 4. Set BPV 5. Prepare location for arrival of Workover Rig General Workover Procedure 1. MIRU Workover Rig 2. NO tree,MU blanking plug, and pressure test BOPE. The last SBHP measurement was 3,396 psi on Aprill11, 2001, at 10,924' MO (6,259' TVO- also the mid-perf depth). Prior to rig arrival, a plug will be set in the Otis 'XN' Nipple at 11,108' MO and the well loaded with 9.6 ppg brine. Because of this, kill weight fluid should not be needed; however, in the event that the plug fails, the estimated mud weight needed at mid-perf would be 10.4 ppg. Assuming a 125 psi overbalance, the mud weight would need to be 10.8 ppg. The calculated maximum possible surface pressure assuming a full gas gradient (0.1 psi/ft) is 2,770 psi. 3. Pull tubing and run new tubing/new completion. Prior to setting the new completion, circulate out brine leaving corrosion inhibitor in the IA. ¡/ 4. NO BOPE, NU tree, and test tree 5. SetBPV \---\ \ \ ~~...:J\~' ~ ll/?:, 6. ROM 0 workover rig Post-RiQ Work: 1. Pull BPV 2. Set OV in mandrel 3. Pull plug from nipple 4. Tag fill 5. Return to injection . ConocóPhillips Well: 1 D-40A Field: Kuparuk . API: 500292296901 PTD: 200-190 2006 RWO PROPOSED COMPLETION ~. WELLHEAD Lift threads: 3W' 8rd EUE BPV: CIW H BPV Model: FMC Gen V CONDUCTOR 20",91.5 ppf, H-40 , welded SURFACE CASING 9%",40 ppf, L-80, BTC-MOO PRODUCTION CASING 7", 26 ppf, J-55, BTC-MOO TUBING 3W', 9.3 ppf, L-80, EUE-8rd Mod LINER 3W', 9.3 ppf, L-80, SLHT NIPPLE 3%" Otis 'XN' Nipple with 2.75 " 10 PERFS C-4, C-3, C-2 10,904'-10,944'MO 6,249'-6,270' TVO 4 spf, 4/11/01 A B B c NEW COMPLETION A: SCSSV: 3%" with 2.813" X profile 2,000' TVO= 2,055' MO B: Gas Lift Mandrels No. MO TVO 1 2,712 2,500 2 10,302 5,934 TYPE 1" KBMG 1" KBMG *Confirm set depth with Artificial Lift Coordinator prior to running. C: Nipple: 3%" with 2.813" X profile Place at least 1 full joint above seal assembly- approx. 10,354' MO D: Seal Assembly @ 10,400' MO Last Tag: 12/28/05 Tag Depth: 10,940' RKB Fill: 4' fill above btm perf TD: 11,110' RKB **Well has a history of schmoo** Last Updated: 3-Nov-06 Updated by: JWL e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /' Mechanical Integrity Test /:8' t- ~J I ~ ( ù':> :J. . Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Kuparuk / KRU/1D 09/04/05 Brian Murphy - LRS ). .... .~.. ............. ....,...~...>"... h." .ð. .... .~~~ ,',_, ,_ ", ':.. ..-;, ,,' ',.',-', "_'.;;';i;,'. .... ...-.... ....::. ~., .::':>" ; ',:"> 'fi ",-', ".. ..,;, ','- ,'. ,'ö.'è. .' . ,~, ". .. ' .. , ~.. Packer Depth Pretest Initial 15 Min. 30 Min. Well 1 D-40A 1 Type Inj. 1 N TVD 5,976' Tubing 7001 800 800 Interval I 0 P.T.D·12001900 I Type test I P Test psi 1500 Casing 8501 2,500 1,950 P/FI F Notes: Diagnostic MIT OA 01 01 0 Well also due for 4 year MIT Weill Type Inj. I TVD Tubing I I Interval P.T.D.I I Type test Test psi Casing I I P/FI Notes: OA I I Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I I Tubing Interval! P.T.D.I ! Type test I I Test psi! I Casing P/F! Notes: I OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psi! Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature.Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) ~J ')nn~ ~ANNE.u ND\Ú 0 10 LI,¡(J·J 2005-0904_MIT_KRU_1D-40Axls I D -40A (PTD 200 -190) suspect TxIA • Subject 1D-40A (PTD 200 -190) suspect TxIA 1 13t13 From: NSK Problem Well Supv <n1617 @conocophillips.com> 1:/%6 Date: Sat, 03 Sep 2005 05:37:08 -0800 To: James Regg <jim_regg @admin.state.ak.us>, Thomas Maunder <tom_maunder @admin.state.ak.us> CC: NSK Problem Well Supv <n1617 @conocophillips.com> Tom, Injection well 1D -40A (PTD 200 -190) had a pressure anomaly on the 7" IA last night. The IA pressure increased from 1300 psi to 2100 psi in a short time period. It was bled down and came back up to 2100 psi. Current T /I /0 = 2400/2150/550 TxIA communication is suspected. The 4 year MITIA is due this year. A MITIA is scheduled for this well Monday September 5, 2005. cy An eight week plot is attached. �` () �' E? As 2 ) Please let me know if you have any questions MJ Loveland wo_TaEno ',, . ��� ELL TRENDS�1 D %40 % PRODUCED WATER INJ g CURRENT VALUE CURRENT VALUE CURRENT VALUE CURRENT VALUE CHOKE 176. INJ RATE 1894.6 INJ PRES 2393.2 ORIF DP 49.42 - -- INJ TEMP 134.0 INJ VOL 431, IGV,OGV PRIORITY ' -- WH PRES 2393.2 ORIFICE MAX RATE -- 139. 3000 A 1. . 1 ' V'y ' 1A. Y WELL STATUS 3000.0 Vii 1 11 ' 01 ON 150.0 2700 ` h.1' ' ' 'ry� ` ,m 3000.0 h I INVERT OPEN/SI 3000.0 2400 01 EVENT AT 50.00 PICK TIME 3300, 2100 w 0 GENERAL PURPOSE 3000 ' �r lra/ " �/� V + IyAJr it EVENT AT ',UTOSCAI.r 1800 l ,, PICK TIME I CREATE WELL 1500 ,.. 1200 I. NOTE AT PICK TIME Iff iii ORIFICE e 400 ir FREEZE ����� PROTECTION 600 � 111, DEFEAT 0 0 300 �� � wir CREATE DEFEAT O.t' Illff NEXT WELL 0.00 , PREV WELL i).tOlil ER SCALE DESC PICK VALUE LATEST �- -- - -;,..6. • ® CHOKE 20 . 176. 13441,0 BRS 03 Will INJ PRES 2402.2 2393.2 ANNULAR COMMUNICATION PROBLEMS ■ M INJ TEMP 131.5 134.0 1 11) 70 eliersei miff Flags: ■ ® WH PRES 2402.2 2393.2 ZOOM TBG: • MI INJ RATE 1907.1 1894.6 INSTANT ® MINOR TIME IA: aim ORIF -DP 50.24 49.42 MINUTE mor PIN MIMI MAJOR TIM OA: IA &OA equalized Diagnostics planned N ® IA PRES 1308.9 2151.3 I+JIWILY = °ICE TIME :v' MR OOA/Tree: a OA PRES 550. 550.0 - 1 of 1 9/6/2005 9:56 AM PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY SSSV Type: NIPPLE Orig Completion: 12/21/00 Angle @ TD: 57 deg ~ 11110 Annular Fluid: - Last W/O: --- Rev Reason: HPBD by ImO Reference Log: __.___ Ref Log Dat~_____-==-. Last Update: 5/1/01 Last Tag: 11041 TD: 11110 ftKB ;;~~j~t~~;:~.~~1 Max Hole An~;I~:)~)~.)~~g @ 3288---- Description Size Top Bottom CONDUCTOR 20.000 0 117 SURF CASING 9.625 0 6978 PROD CASING 7.000 . .1 0 10559 LINER 3.500 10377 11110 ;'rLïbhjg·$trlrib:H··110$tN~r ';; :;...:;..;...'.:::.....: Size r Top \... Bottom [- TVD I Wt 3.500 0 10438 6004 9.30 t?ørlòt~tiO"$.$\;triJþ)ãl¥.{:· ... Interval TVD 10904 - 10944 6249 - 6270 NIP (530-531, OD :4.562) TUBING (0-10438, OD:3.500, ID:2.992) Gas Lift andrei/Dummy Valve 1 (10302-10303, OD:5.968) NIP (10354-10355, 00:4.520) PACKER (10384-10385, 00:5.938) LINER (10377-11110, 00:3.500, Wt:9.30) SEAL (10400·10401, 00:4.000) SBE (1 0404-1 0405, OD:5.938) NIP (10463-10464. 00:4.750) Perf (10904-10944) 'I .!.;" k~."""'./. r r ., 1.·.:.1 ~ ~\ ~ 1__ ) KRU 1 D-40A TVD Wt Grade Thread 117 91.50 H-40 WELDED ---4256--- 40.00 L-80 BTC MOD 6067 [_ 26.00 J-55 BTC MOD 11110 9.30 L-80 SLHT · ·············i~·~;·················~~~t~~';'1~1j:··:~~~·I'· 'D~te C-4,C-3,C-2 40 4 4/11/01 . .."., ,. ,. " " .,., . , , ." . .........:.. .......:.....:.::.:.:.. .... ;..Tf!:~:;· \.:]-::/ ::~::).u;:.:;):::;=: ::......; Gr~d~ .j'" . L-80 Thread EUE 8RD Type Comment IPERF 2.5" HC/DP, 60-120 deg phasin9,random orientation :..;":.::;"",,::::::.:=,::.:.::,.:: iGå$·:LlftNläüd jlslYaIVêij..··. .:..... St .. MD' 'WD Man Man Mfr Type 1 10302 5934 CAMCO MMG CAMCÕ .øtl1f1,,;.(pIÜg~;;~qµlp~;\êt~¡);H;JEW.~L:RX':····· . Depth TVD Type 530 530 NIP -10354 5961 NIP 10384 5976 PACKER 10400 5985- SEAL 10404 5987 SBE 10463 6017 VMfr DMY 1.5 V Type V OD Latch Port TRO o Date Run 3/8/01 Vlv Cmnt Description Camco 'OS' Nipple Camco 'OS' Nipple Baker ZXP Packer Baker 35' GBH-22 Seal Assembïÿ Baker 80-40 SBE Otis' XN' ---~--._._----- -.--.---..-------..------.--. RK 0.000 ...... ID 2.875 2.812 4.875 .,--..--.-- 3.000 - 4.875 ·__·~._________w -_.._._.._~._----_....__.- F:\LaserFiche\CvrPgs _ I nserts\M icrofi 1m _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE "tP"?;,rr.;.,'tr1l ) ') WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 21, 2002 RE: MWD Formation Evaluation Logs 1D-40A, AK-MM-00291 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, 6900 Arctic Blvd., Anchorage, AK 99518 1D-40A: Digital Log Images 1 CD Rom RECEIVED ~aska Oil & Gas Cons. Comm~or~ ioqD Permit to Drill 2001900 MD 11110,-~ TVD DATA SUBMITTAL COMPLIANCE REPORT 4118~2003 Well Name/No. KUPARUK RIV UNIT 1D-40A Operator CONOCOPHILLIPS ALASKA INC 6360 --- Completion Dar 4/11/2001 f Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22969-01-00 UIC Y REQUIRED INFORMATION Mud Log No Sample N_.9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt , ED ~ Ver LIS Verification Interval Log Log Run OH / Name Scale Media No Start Stop CH 1 6934 11073 Open (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments 4/26/2002 10794 '-~ C...o v-~,7 Ver LIS Verification R L Directional Survey MWD Directional Survey MWD Directional Survey Directional Survey ~ms~'u re Survey _Cement Bond Log 1 6942 11066 Open FINAL FINAL FINAL FINAL FINAL FINAL 10970 11730 CH 10208 11034 ch 12/28/2001 10510'-"'" 2/21/2001 MWD Dir Survey Paper Copy 2/21/2001 MWD Dir Survey Digital DataJ 2/21/2001 2/21/2001 5/1/2001 5/15/2001 Dir Survey Paper Copy Dir Survey Digital Data 10970-11730 BL, Sepia 10208-11034 Color Print Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Analysis R ~_n~.iv~.d ? Daily History Received? (~/N Formation Tops ~/_/_~'/N Comments: Permit to Drill 2001900 DATA SUBMITTAL COMPLIANCE REPORT 4118~2003 Well Name/No. KUPARUK RIV UNIT 1D-40A Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-22969-01-00 MD 11110 TVD 6360 Compliance Reviewed By: Completion Dat 4/11/2001 Completion Statu 1WINJ Current Status 1WINJ UIC Y Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska November 12, 2001 MWD Formation Evaluation Logs 1D-40A, AK-MM-00291 1 LDWG formatted Disc with verification listing. API#: 50-029-22969-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED DEC 2 8 2001 Alaska Oil & Gas Cons. Commissior~ Ancl~rage Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57tl ATTN: Sherrie NO. 1117 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Field: Kuparuk Color Sepia Print 1D-32 ~C~/7~ STATIC BHP 06/02/01 I 1 1D-40A ~ oO-F::IO 21147 SCMT 03/10/01 1 1R-29 I~i~L~'~'-/ 21205 USIT 04115101 1 . 5/8/2001 RECEIVED DATE: UAV 4 ~ 0/I/11 I-It'~! ! ~J LUUI Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-83~~'~.~ Cofl$. CommJssk)r- Anchorage 4/2512001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. T84 Company: Alaska Oil & Gas COns Corem Attn: Lisa Weepie 333 Wi 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print iD-40A Z_c~_-~O --' PRESSURE SURVEY 04111101. 1Y-22 J~,~-O'~C 'PROD PROFILE/GLS 04/10/01 ~3F-21 ~-~)O_~ 21146 SCMT 03105/01 SIGNE _ ~...,,~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above addreSs or fax to (907) 561-8317. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 May 11,2001 Commissioner Cammy Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1D-40A (200-190) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 1D-40A. If you have any questions regarding this matter, please contact me at 265-6434 or Todd Mushovic at 265-6974. Sincerel , J. Trantham Drilling Engineering Supervisor PAI Drilling JT/skad RECEIVED MAY 1 5 2001 Alaska Oil & Gas' Cons. Commission Anchorage f" STATE OF ALASKA i" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well ........ Produced Water Injector Oil D Gas D Suspended [~ Abandoned D Service 2. Name of Operator * r"~'~A'J'~"~r~'5 7. Permit Number Phillips Alaska, Inc. ¥~"-'-'-- 200-190 / 3. Address j.~. ~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 [..~.,~, ,',~ 50-029-22969-01 4. Location of well at sudace ~'";.. :'. '.:~' ~.'::' ¥':"°"~ ........... 9. Unit or Lease Name 537' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM (ASP: 560671,5959129) ~ ?.-.,-r? ) Kuparuk River Unit At Top Producing Interval ............ ':~.,~--z--, lO. Well Number 't 2140' FSL, 1044' FEL, Sec. 26, T11N, R10E, UM (ASP: 560117, 5951243) *'-; ¥'i!i~"?~;'i~':'._~.~...~i 1D-40A At Total Depth ~ .... ....... ~:'i 11. Field and Pool 1963' FSL, 1077' FEL, Sec. 26, T11 N, R10E, UM (ASP: 560085, 5951066) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool RKB 35' feetI ADL 25661/25650 ALK 471 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aban~. ,/ 115. Water Depth, if offshore 16. No. of Completions December 11,2000 December 18, 2000 Dj~c,~-'Z't'7~00 ',~'1' N/A feet USE 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11110'MD/6360'TVD 11041'MD/6323'TVD YES ~] No r"]'1 N/A feetMD 1511' 22. Type Electric or Other Logs Run GR/Res/Neu Dens, CBL/SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO'I-I'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 137' 30" 503 sx ASLite 9.625" 40# L-80 Surface 6978' 12.25" 818 sx AS III LW & 477 sx LiteCRETE 7" 26# J-55 Surface 10559' 8.5" 180 sx Class G 3.5" 9.3# L-80 10377' 11110' 6.125" 170 sx Class G cement plug @ 6778' 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" 10438' 10384' 10904'-10944' MD 6249'-6270' TVD 4 spf '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10904'-10944' HPBD - see attached summary 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A MAY 1 5 2001 Alaska 0il & Gas Cons, Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIG, INAL Submit In duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10897' 6245' Base Kuparuk C 10966' 6282' RECEIVED Top Kuparuk A 11110' 6360' Base Kuparuk A 11110' 6360' 1 5 001 Alaska 0il & Gas Cons. Commission Anchorage Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brockway 265-4135 Signed ~"',.", Title Ddllin,q En,qineer n,q Superv sor Date /~ Prepared by Sharon AIIsup-Drake INSTRUCTIONS General; This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1; Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 OR!G, II AL Date: 01/19/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lD-40A STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:12/04/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22969-01 12/04/00 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:ll127/6359 (11127) TESTING BOPE SUPV:G.R. WHITLOCK Inspect rig for rig move. Move rig from 1D-32 to 1D-40A. Spot rig. Accept rig @ 1930 hrs 12/4/00. Remove tree and start N/U BOPE. 12/05/00 (D2) MW: 10.3 VISC: 46 PV/YP: 13/15 APIWL: 8.8 TD/TVD:ll127/6359 ( 0) POOH FOR CUTTER SUPV:G.R. WHITLOCK N/U BOPE and test BOPE to 250/3000. POOH. RIH to 6150', CBU. 12/06/00 (D3) MW: 10.3 VISC: 49 PV/YP: 12/23 APIWL: 9.0 TD/TVD:ll127/6359 ( 0) CIRC SUPV:G.R. WHITLOCK ~RIH to 8071'. Circ and condition old mud. POOH to bha. RIH /w/casing cutter. Cut 7" casing @ 7197'. POOH. Hold safety meeting. R/U to pull 7" casing. 12/07/00 (D4) MW: 10.5 VISC: 46 PV/YP: 11/22 APIWL: 9.4 TD/TVD:ll127/6359 ( 0) CIRC PRIOR TO LAYING BALANCED PLUG SUPV:G.R. WHITLOCK R/U to pull 7" casing. Work 7" casing free while circulating. Circ and condition mud. R/U to run 2-7/8" tubing. RIH w/2-7/8" stinger. 12/08/00 (D5) TD/TVD:ll127/6359 ( SUPV:G.R. WHITLOCK MW: 10.4 VISC: 45 PV/YP: 11/21 0) L/D TUBING STINGER APIWL: 9.5 RIH to 8035'. CBU. Spot 300' viscous mud pill. POOH to 7710'. Circ and condition mud. Spot cement plug. POOH to 6760'. CBU. Monitor well. RIH tag cement @ 6910'. Safety meeting. 12/09/00 (D6) TD/TVD: 6978/4256 ( SUPV:G.R. WHITLOCK MW: 10.4 VISC: 42 PV/YP: 10/14 0) RIH W/ PACKER APIWL: 9.4 RIH. Tag cement @ 6909'. CBU. Test casing to 2500 psi. Drill cement from 6909' to 6950' Date: 01/19/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/10/00 (D7) MW: 10.4 VISC: 43 PV/YP: 11/13 APIWL: 9.5 TD/TVD: 6978/4256 0) M/U BHA SUPV:G.R. WHITLOCK Drill cement from 6950' to 6970'. CBU. POOH. RIH with p~cker and set @ 6940'. Test casing to 2500 psi. OK. POOH. Test BOPE to 250/3500 psi. Stand back for Phase 3 weather conditions. 12/11/00 (D8) MW: 9.1 VISC: 40 PV/YP: 8/13 TD/TVD: 7566/4550 ( 58~) DRILLING @ 8100' SUPV:G.R. WHITLOCK APIWL: 8.6 Wait on weather, Phase III conditions. Clean and perform rig maintenance. RIH. Tag @ 6970'. Drill cement .to 8988' ~Directional drill from 6988' to 7023'. Circ for LOT. Perform LOT to 13.3 ppg. Drill from 7023' to 7472' Displace hole w/new mud while drilling. Circ and condition mud. Drill from 7472' to 7566' 12/12/00 (D9) MW: 9.2 VISC: 42 PV/YP: 10/16 APIWL: 7.2 TD/TVD: 9165/5357 (1599) DRILLING AHEAD SUPV:HERBERT/THORNTON Drill from 7566' to 8881'. Pump sweep, circ for wiper trip. Monitor well, wipe hole from 8881' to 6912'. RIH to 8881' Pump sweep. Drill from 8881' to 9165' 12/13/00 (D10) MW: 9.8 VISC: 46 PV/YP: 19/18 APIWL: 4.6 TD/TVD: 9165/5357 ( 0) POOH TO RUN CASING SUPV:HERBERT/THORNTON Drill from 9165' to 10568'. Circ weighted sweep around, circ hole clean. Monitor well. Pump dry job, POOH to shoe. No problems. RIH, slow. 12/14/00 (Dll) MW: 9.9 VISC: 46 PV/YP: 19/16 APIWL: 4.4 TD/TVD:10568/6071 (1403) CIRC & COND FOR CEMENT JOB SUPV:HERBERT/THORNTON RIH. Circ, pump sweep, circ hole clean. Monitor well, POOH. Rig & run 7" casing to 9-5/8" shoe. Circ & cond mud. 12/15/00 (D12) MW: 9.9 VISC: 42 PV/YP: 17/14 APIWL: 5.4 TD/TVD:10568/6071 ( 0) SUPV:HERBERT/THORNTON Circ & cond mud w/casing @ 6970'. Run 7" casing to 10559' Circ & cond mud for cementing. Test cement lines. Set 7" pack-off and test to 5000 psi, OK. Test BOPE. 12/16/00 (D13) MW: 11.5 VISC: 61 PV/YP: 36/27 APIWL: 5.4 TD/TVD:10568/6071 ( 0) CHANGE OUT MUD SUPV:F. HERBERT/M. THORNTON PJSM. RIH to 2100'. POOH. Hold BOP drill. PJSM. Strip in hole w/5 stds. RIH P/U 4" DP. Rabbit same. BOP drill. PJSM. Strip in hole from 9800' to 10275'. POOH 5 stds. RIH w/5 stds. RIH. set 10 stds to drill with. Date: 01/19/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/17/00 (D14) MW: 11.5 VISC: 49 PV/YP: 24/19 APIWL: 4.6 TD/TVD:l1040/6323 ( 472) CIRC.& COND. MUD F/3.5"LINER SUPV:F. HERBERT/M. THORNTON -RIH tag @ 10475' Circ to test casing. Test casing to 3500 psi, OK. Drill float collar @ 10475', cement, shoe @ 10559', cement to 10568' Circ & change over to 11.5 ppg mud. Drill from 10568' to 10603' Circ & cond mud for LOT. Perform LOT to EMW of 14.4 ppg. Drill from 10603' to 10856' Wipe hole to shoe. Circ sweep to reduce ECD's. Drill from 10856' to 11040' 12/18/00 (D15) MW: 11.5 VISC: 55 PV/YP: 29/30 APIWL: 4.2 TD/TVD:lll10/6360 ( 70) RUN IN HOLE WITH LINER SUPV:F. HERBERT/M. THORNTON Drill from 11040' to 11110' TD. Pump sweep & circ hole clean. POOH to shoe. Pump out. RIH to bottom. No problems. Circ & cond for liner. Pump sweep. Monitor well. Pump out to shoe (precautionary). Monitor well. POOH to run liner. Monitor well @ 1340'. Rig up to run liner. PJSM. RIH w/liner slow. 12/19/00 (D16) MW: 11.5 VISC: 46 PV/YP: 20/28 APIWL: 5.6 TD/TVD:lll10/6360 ( 0) LAY DOWN 4" DP SUPV:F. HERBERT/M. THORNTON Run 3.5" liner. Circ and cond mud @ 10540'. Run 3.5" liner @ tag bottom @ 11110' Circ & cond mud for 3.5" cement job. Cement 3.5" liner. Circ out cement spacer & est. 4 bbls cement, condition mud. Monitor well. POOH. 12/20/00 (D17) MW: 11.5 VISC: 61 PV/YP: 33/27 APIWL: 5.8 TD/TVD:lll10/6360 ( 0) CHANGE HOLE OVER TO SEA WATER SUPV:F. HERBERT/M. THORNTON POOH. Rig up to run 3.5" completion string. Pick up 3.5" completion string. Circ bttms up @ 2500'. P/U 3.5" completion string. Circ bttms up @ 5000'. P/U 3.5" completion to 7500'. Circ out cement contaminated mud. 12/21/00 (D18) MW: 8.6 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:lll10/6360 ( 0) RIG RELASED F/ 1D-40A @24:00 HRS SUPV:F. HERBERT/M. THORNTON RIH w/seal assembly. Tag packer assembly w/seals @ 10377' Circ out thick mud for casing test. Test casing to 3500 psi. Displace mud w/seawater. Test tubing to 3000 psi. Test annulus to 3000 psi. Freeze protect with diesel. ND BOPE. NU tree and test to 250/5000 psi. Rig released from 1D-40 @ 00:00 hrs. 1D-40A Description of Work Completed Summary 4/11/01: PERFORATE 10904:10944' RKB W/2.5" HC/DP/4 SPF/60-120 PHASING (6 SPF 60 DEG GUN LOADED 4 SPF) RANDOM ORIENTATION - INITIAL SBHP SURVEY: 3396 PSI AND 156 DEG F @ 10924' RKB, 3300 PSI AND 146 DEG F @ 10500' RKB, AND 838 PSI IN LUBRICATOR [Perf, Pressure Data] 4/27/01: PUMP HPBD - PERFS BROKE BACK FROM 9200 PSI AT 27 BPM TO 8540 PSI AT 40 BPM - SAW GOOD BREAKBACK ON FIRST SET OF DIVERSION STAGES - PRESSURE INCREASED ON SAND SCOUR - PUMP SECOND SET OF DIVERSION STAGES - PRESSURED OUT WITH ROCK SALT ON PERFS - FLOW 90 BBLS OUT OF WELL - PUMP FINAL STAGE WITH 50 BBL SCOUR STAGE AND NO ROCK SALT - 'PLACED TOTAL OF 5562 LBS 16/20 SAND BEHIND PIPE - PUMPED TOTAL OF 2520 LBS ROCK SALT - .FINAL RATE 2.5 BPM AT 1870 PSI - FREEZE PROTECTED WELL WITH 20 BBLS DIESEL - READY FOR INJECTION [HPBD] Kuparuk River Unit Phillips Alaska Kuparuk 1D, Slot 1D-40 1D-40A Surveyed: ~8 December, 2000 S UR VEY REPORT 9 January, 2001 Your Ref: AP1500292296901 Surface Coordinates: 5959128.85 N, 560670.87 E (70° 17' 55.9141" N, Kelly Bushing: 104.45ft above Mean Sea Level 149° 30' 31.1998" VI/) DRILLING SERVICES Survey Reft svy9350 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 1D-40A Your Ref: AP1500292296901 Surveyed: f8 December, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6920.65 66.400 184.440 4128.39 4232.84 6978.00 66.260 184.220 4151.41 4255.86 6988.00 66.230 184.300 4155.44 4259.89 7066.12 60.660 184.630 4190.35 4294.80 7119.98 57.640 184.890 4217.97 4322.42 7212.26 58.210 187.850 4266.98 4371.43 7311.84 58.190 192.900 4319.48 4423.93 7400.37 59.600 193.620 4365.21 4469.66 7499.51 59.650 194.640 4415.34 4519.79 7592.77 59.890 193.350 4462.30 4566.75 7683.03 59.830 190.830 4507.63 4612.08 7781.34 59.300 190.560 4557.43 4661.88 7871.01 59.780 190.390 4602.88 4707.33 7964.56 60.390 192.750 4649.54 4753.99 8063.63 59.980 192.450 4698.80 4803.25 8155.79 59.550 191.410 4745.21 4849.66 8244.82 60.170 192.910 4789.91 4894.36 8343.66 59.700 192.810 4839.43 4943.88 8438.77 58.950 193.360 4887.95 4992.40 8531.72 60.000 194.040 4935.16 5039.61 8624.75 59.470 194.190 4982.05 5086.50 8717.62 60.410 191.990 5028.57 5133.02 8811.42 60.150 191.670 5075.07 5179.52 8908.07 60.230 191.360 5123.12 5227.57 8999.14 59.760 191.250 5168.66 5273.11 9094.63 59.400 190.280 5217.01 5321.46 9191.74 59.930 191.410 5266.06 5370.51 9285.42 59.750 192.880 5313.13 5417.58 9377.45 59.180 193.940 5359.89 5464.34 9469.14 59.090 192.520 5406.93 5511.38 Local Coordinates Northings Eastings (ft) (ft) 4523.05 S 56.14 E 4575.43 S 52.17 E 4584.56 S 51.49 E 4654.20 S 46.06 E 4700.27 S 42.22 E 4777.97 S 33.54 E 4861.17 S 18.31 E 4934.95 S 0.92 E 5017.89 S 19.96W 5096.08 S 39.44W Global Coordinates Northings Eastings (ft) (ft) 5954606.40 N 560763.52 E 5954553.99 N 560759.98 E 5954544.86 N 560759.37 E 5954475.18 N 560754.50 E 5954429.07 N 560751.04 E 5954351.31N 560742.99 E 5954267.98 N 560728.43 E 5954194.07 N 560711.63 E 5954110.96 N 560691.42 E 5954032.62 N 560672.57 E 5172.39 S 55.79W 5953956.17 N 560656.84 E 5255.68 S 71.52W 5953872.76 N 560641.78 E 5331.69 S 85.57W 5953796.64 N 560628.34 E 5411.12 S 101.84W 5953717.09 N 560612.72 E 5495.00 S 120.59W 5953633.05 N 560594.65 E 5572.91 S 137.05W 5953555.02 N 560578.81 E 5648.17 S 153.27W 5953479.63 N 560563.20 E 5731.56 S 172.31W 5953396.08 N 560544.84 E 5811.24 S 190.83W 5953316.26 N 560526.96 E 5889.03 S 209.79W 5953238.32 N 560508.63 E 5966.95 S 229.39W 5953160.24 N 560489.66 E 6045.24 S 247.58W 5953081.81 N 560472.10 E 6124.97 S 264.28W 5953001.95 N 560456.04 E 6207.14 S 281.03W 5952919.64 N 560439.97 E 6284.47 S 296.49W 5952842.19 N 560425.13 E 6365.37 S 311.87W 5952761.17 N 560410.40 E 6447.68 S 327.64W 5952678.73 N 560395.30 E 6526.86 S 344.68W 5952599.42 N 560378.90 E 6603.97 S 363.06W 5952522.16 N 560361.14 E 6680.58 S 381.07W 5952445.41N 560343.75 E Dogleg Rate (°/100ft) 0.43 0.79 7.14 5.62 2.79 4.31 1.74 0.89 1.22 2.42 0.59 0.56 2.28 O.49 1.08 1.61 0.48 0.93 1.29 0.59 2.29 0.41 0.29 0.53 0.95 1.14 1.37 1.17 1.33 Vertical Section 45O4.64 4557.16 4566.31 4636.16 4682.40 4760.54 4844.68 4919.60 5003.93 5083.40 5160.77 5245.03 5321.91 5402.37 5487.47 5566.43 5642.73 5727.37 5808.25 5887.29 5966.51 6045.99 6126.78 6210.02 6288.33 6370.18 6453.48 6533.76 6612.07 6689.86 Phillips Alaska Kuparuk 1D Comment TIE ON POINT SHOE OHST 9 January, 2001 - 16:42 Page 2 of 4 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 1D-40A Your Reft AP! 500292296901 Surveyed: f8 December, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 9563.99 58.470 192.540 5456.09 5560.54 6759.76 S 398.67 W 9660.35 59.840 191.890 5505.50 5609.95 6840.62 S 416.17 W 9754.79 59.960 191.170 5552.86 5657.31 6920.68 S 432.50 W 9844.01 59.410 191.490 5597.89 5702.34 6996.19 S 447.63 W 9941.48 58.890 190.700 5647.87 5752.32 7078.31 S 463.73 W 10033.88 60.220 191.530 5694.69 5799.14 7156.47 S 479.09 W 10126.84 60.070 189.620 5740.97 5845.42 7235.72 S 493.89 W 10219.54 59.570 188.890 5787.58 5892.03 7314.81 S 506.78 W 10315.38 58.870 190.000 5836.62 5941.07 7396.03 S 520.29 W 10410.37 59.000 192.390 5885.64 5990.09 7475.84 S 536.08 W 10498.35 59.200 193.430 5930.83 6035.28 7549.42 S 552.95W 10580.32 58.440 191.680 5973.27 6077.72 7617.87 S 568.20W 10675.38 58.500 190.510 6022.98 6127.43 7697.38 S 583.79W 10770.04 58,040 190.960 6072.76 6177.21 7776.48 S 598.79W 10866.42 57.620 190.350 6124.08 6228.53 7856.66 S 613.87W 10965.16 57.490 190.180 6177.05 6281.50 7938.65 S 628.72W 11026.53 57.200 191.170 6210.17 6314.62 7989.42 S 638.29W 11110.00 57.200 191.170 6255.38 6359.83 8058.26 S 651.88W Global Coordinates Northings Eastings (ft) (ft) 5952366.09 N 560326.79 E 5952285.09 N 560309.94 E 5952204.91 N 560294.26 E 5952129.27 N 560279.74 E 5952047.03 N 560264.30 E 5951968.75 N 560249.57 E 5951889.38 N 560235.41E 5951810.19 N 560223.16 E 5951728.86 N 560210.31E 5951648.93 N 560195.16 E 5951575.21 N 560178.89 E 5951506.64 N 560164.19 E 5951427.01N 560149.24 E 5951347.79 N 560134.89 E 5951267.49 N 560120.45 E 5951185.38 N 560106.26 E 5951134.53 N 560097.10 E 5951065.59 N 560084.07 E ..~_~_ All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1D-M WPs. Northings and Eastings are relative to 1D-M WPs. Magnetic Declination at Surface is 26.356° (06-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from and calculated along an Azimuth of 184.510° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11110.00ft., The Bottom Hole Displacement is 8084.58ft., in the Direction of 184.625° (True). Dogleg Rate (°/'lOOft) 0.65 1.54 0.67 0.69 0.88 1.63 1.79 0.87 1.23 2.16 1.04 2.05 1.05 0.63 0.69 0.20 1.44 0.00 Vertical Section 6770.18 6852.16 6933.25 7009.73 7092.86 7171.98 7252.15 7332.01 7414.04 7494.84 7569.53 7638.96 7719.45 7799.49 7880.60 7963.51 8014.88 8084.56 Phillips Alaska Kuparuk 1D Comment PROJECTED SURVEY 9 January, 2001 - 16:42 Page 3 of 4 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for ID-40A Your Ref: AP150029229690~ Surveyed: ~8 December, 2000 Kuparuk River Unit Phillips Alaska Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6920.65 4232.84 4523.05 S 56.14 E 6978.00 4255.86 4575.43 S 52.17 E 6988.00 4259.89 4584.56 S 51.49 E 11110.00 6359.83 8058.26 S 651.88W Comment TIE ON POINT SHOE OHST PROJECTED SURVEY Survey tool program for f D-40A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 11110.00 Vertical Depth (ft) 6359.83 Survey Tool Description AK-6 BP_IFR-AK (1 D-40A) 9 January, 2001 - 16:42 Page 4 of 4 DriilQuest 2.00.06 Kuparuk River Unit Phillips Alaska Kuparuk ~D, Slot ~D-40 ID-40A MWD Surveyed: ~8 December, 2000 S UR VEY REPORT 9 January, 2001 Your Ref: APl 500292296901 Surface Coordinates: 5959128.85 N, 560670.87 E (70° 17' 55.914~" N, Kelly Bushing: 104.45ft above Mean Sea Level ~49°30'3~.~998"W) DRILLING SERVICES Survey Reft svy9351 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 1D-40A MWD Your Reft AP1 500292296901 Surveyed: 18 December, 2000 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth fit) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 6920.65 66.400 184.440 4128.39 4232.84 6978.00 66.260 184.220 4151.41 4255.86 6988.00 66.230 184.300 4155.44 4259.89 7066.12 60.660 184.460 4190.35 4294.80 7119.98 57.640 184.660 4217.97 4322.42 7212.26 58.210 187.470 4266.98 4371.43 7311.84 58.190 192.650 4319.48 4423.93 7400.37 59.600 193.380 4365.21 4469.66 7499.51 59.650 194.420 4415.34 4519.79 7592.77 59.890 193.400 4462.30 4566.75 7683.03 59.830 191.820 4507.62 4612.07 7781.34 59.300 190.390 4557.42 4661.87 7871.01 59.780 190.190 4602.88 4707.33 7964.56 60.390 192.540 4649.54 4753.99 8063.63 59.970 192.230 4698.81 4803.26 8155.79 59.550 191.180 4745.22 4849.67 8244.82 60.170 192.700 4789.93 4894.38 8343.66 59.700 192.520 4839.44 4943.89 8438.77 58.950 192.980 4887.96 4992.41 8531.72 60.000 193.920 4935.18 5039.63 8624.75 59.470 194.160 4982.06 5086.51 8717.62 60.410 191.890 5028.59 5133.04 8811.42 60.150 191.580 5075.09 5179.54 8908.07 60.230 191.150 5123.14 5227.59 8999.14 59.760 191.050 5168.68 5273.13 9094.63 59.400 190.130 5217.03 5321.48 9191.74 59.930 191.310 5266.07 5370.52 9285.42 59.750 192.830 5313.14 5417.59 9377.45 59.180 193.890 5359.90 5464.35 9469.14 59.090 192.340 5406.94 5511.39 4523.05 S 56.14 E 4575.43 S 52.17 E 4584.56 S 51.49 E 4654.20 S 46.16 E 4700.29 S 42.49 E 4778.04S 34.22 E 4861.32 S 19.44 E 4935.17 S 2.37 E 5018.20 S 18.18W 5096.41S 37.55W 5954606.40 N 560763.52 E 5954553.99 N 560759.98 E 5954544.86 N 560759.37 E 5954475.17 N 560754.60 E 5954429.05 N 560751.30 E 5954351.25 N 560743.66 E 5954267.84 N 560729.56 E 5954193.86 N 560713.08 E 5954110.67 N 560693.21E 5954032.30 N 560674.47 E 5172.58 S 54.59W 5953956.00 N 560658.05 E 5255.75 S 70.91W 5953872.69 N 560642.39 E 5331.80 S 84.72W 5953796.53 N 560629.20 E 5411.29 S 100.70W 5953716.92 N 560613.86 E 5495.24 S 119.14W 5953632.82 N 560596.10 E 5573.20 S 135.29W 5953554.74 N 560580.58 E 5648.53 S 151.22W 5953479.29 N 560565.25 E 5732.01 S 169.90W 5953395.66 N 560547.25 E 5811.79 S 187.95W 5953315.73 N 560529.85 E 5889.66 S 206.58W 5953237.72 N 560511.85 E 5967.61 S 226.07W 5953159.61 N 560492.99 E 6045.91S 244.18W 5953081.16 N 560475.51E 6125.67 S 260.74W 5953001.27 N 560459.59 E 6207.89 S 277.27W 5952918.93 N 560443.73 E 6285.28 S 292.45W 5952841.42 N 560429.17 E 6366.22 S 307.59W 5952760.36 N 560414.69 E 6448.57 S 323.18W 5952677.89 N 560399.76 E 6527.77 S 340.11W 5952598.55 N 560383.47 E 6604.89 S 358.43W 5952521.28 N 560365.78 E 6681.54S 376.29W 5952444.49 N 560348.54 E Dogleg Rate (°/'lOOft) 0.43 0.79 7.13 5.62 2.65 4.42 1.74 0.91 0.98 1.52 1.37 0.57 2.27 0.50 1.08 1.63 0.50 0.89 1.43 0.61 2.35 0.40 0.39 0.52 0.91 1.18 1.42 1.17 1.45 Vertical Section 4504.64 4557.16 4566.31 4636.16 4682.40 4760.55 4844.74 4919.71 5004.O9 5083.58 5160.86 5245.O6 5321.96 5402.45 5487.60 5566.59 5642.93 5727.62 58O8.57 5887.67 5966.91 6O46.39 6127.21 6210.47 6288.81 6370.69 6454.01 6534.30 6612.62 6690.44 Phillips Alaska Kuparuk 1D Comment TIE ON POINT SHOE OHST 9 January, 2001 - ~6:42 Page 2 of 4 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 1D-40A MWD Your Reft AP1 500292296901 Surveyed: 18 December, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 9563.99 58.470 192.360 5456.10 5560.55 6760.78 S 393.63W 9660.35 59.840 191.690 5505.51 5609.96 6841.69 S 410.87W 9754.79 59.960 190.930 5552.87 5657.32 6921.81S 426.89W 9844.01 59.410 191.270 5597.91 5702.36 6997.39 S 441.72W 9941.48 58.890 190.560 5647.89 5752.34 7079.55 S 457.56W 10033.88 60.220 191.430 5694.71 5799.16 7157.74 S 472.76W 10126.84 60.070 189.570 5740.99 5845.44 7237.01S 487.45W 10219.54 59.570 188.760 5787.59 5892.04 7316.12 S 500.22W 10315.38 58.870 189.880 5836.64 5941.09 7397.37 S 513.55W 10410.37 59.000 192.340 5885.66 5990.11 7477.20 S 529.23W 10498.35 59.200 193.350 5930.84 6035.29 7550.81S 546.01W 10580.32 58.440 191.420 5973.28 6077.73 7619.30 S 561.05W 10675.38 58.500 190.590 6022.99 6127.44 7698.83 S 576.52W 10770.04 58.040 190.630 6072.78 6177.23 7777.97 S 591.35W 10866.42 57.620 190.160 6124.09 6228.54 7858.21 S 606.07W 10965.16 57.490 190.020 6177.06 6281.51 7940.25 S 620.67W 11026.53 57.200 191.290 6210.18 6314.63 7991.02 S 630.22W 11110.00 57.200 191.290 6255.40 6359.85 8059.83 S 643.95W Global Coordinates Northings Eastings (ft) (ft) 5952365.12 N 560331.83 E 5952284.07 N 560315.25 E 5952203.82 N 560299.88 E 5952128.13 N 560285.66 E 5952045.84 N 560270.48 E 5951967.52 N 560255.91E 5951888.14 N 560241.86 E 5951808.93 N 560229.73 E 5951727.57 N 560217.06 E 5951647.62 N 560202.03 E 5951573.88 N 560185.84 E 5951505.27 N 560171.35 E 5951425.62 N 560156.52 E 5951346.36 N 560142.34 E 5951266.00 N 560128.27 E 5951183.85 N 560114.33 E 5951133.00 N 560105.19 E 5951064.08 N 560092.01 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1D-M WPs. Northings and Eastings are relative to 1D-M WPs. Magnetic Declination at Surface is 26.356° (06-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from and calculated along an Azimuth of 184.510° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11110.00ft., The Bottom Hole Displacement is 8085.51ft., in the Direction of 184.568° (True). Dogleg Rate (°/~ OOft) 0.65 1.54 0.71 0.70 0.82 1.65 1.74 0.93 1.24 2.22 1.01 2.22 0.75 0.49 0.60 0.18 1.81 0.00 Vertical Section 6770.79 6852.81 6933.94 7010.45 7093.61 7172.75 7252.93 7332.80 7414.85 7495.67 7570.36 7639.82 7720.33 7800.38 7881.53 7964.47 8015.84 8085.51 Phillips Alaska Kuparuk 1D Comment PROJECTED SURVEY 9 January, 2001 - 16:42 Page 3 of 4 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 1D-40A MWD Your Ref: APl 500292296901 Surveyed: f8 December, 2000 Kuparuk River Unit Phillips Alaska Kuparuk 1D Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) Comment 6920.65 4232.84 4523.05 S 56.14 E TIE ON POINT 6978.00 4255.86 4575.43 S 52.17 E SHOE 6988.00 4259.89 4584.56 S 51.49 E OHST 11110.00 6359.85 8059.83 S 643.95 W PROJECTED SURVEY Survey tool program for 1D-40A MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 11110.00 6359.85 Survey Tool Description MWD Magnetic (1D-40A MWD) 9 January, 2001- ~6:42 Page 4 of 4 DrillQuest 2.00.06 Directional Survey Data Inclination Direction Latitude Measured Depth (feet) Vertical Depth (degrees) (degrees) (feet) (feet) 8921,50 66,40 6978,00 66,26 6988,00 66,23 7066,12 60,66 7119,98 57,64 7212.26 7311.84 7400.37 7499.51 7592.77 7683,03 7781,34 7871,01 7964.56 8063,63 8155,79 8244,82 8343.66 8438,77 8531,72 8624,75 8717,62 8811,42 8908,07 8999,14 9094,63 9191.74 9285,42 9377.45 9469,14 9563,99 9660,35 9754.79 9844,01 9941,48 10033,88 10126,84 10219,54 10315,38 10410,37 58,21 58,19 59,60 59,65 59.89 59,83 59,30 59,78 60,39 59,98 59.55 60.17 59.70 58.95 60.00 59,47 60,41 60,15 60,23 59,76 59,40 59,93 59,75 59,18 59,09 58,47 59,84. 59,96 59,41 58,89 60.22 60.07 59.57 58.87 '59.00 Departure (feet) Vertical Section (feet) 184,44 4233,25 4523,16 S 56,94 E 4504,68 184,22 4255,93 4574,76 S 53,03 E 4556,42 184.30 4259.96 4583.89 S 52.35 E 4565.58 184,63 4294,87 4653,53 $ 46,92 E 4635,43 184,89 4322,49 4699,60 S 43,08 E 4681.66 187.85 4371.50 4777.30 S 34.40 E 192.90 4424.00 4860.50 S 19,17 E 193.62 4469.73 4934.28 S 1,78 E 194.64 4519.86 5017.22 S 19.10W 193.35 4566.82 5095.41S 38.58W 4759,80 4843,95 4918,86 5003,19 5082.66 190.83 190.56 190.39 192.75 192.45 4612.15 5171.72 S 54.93W 5160.03 4661,94 5255.01S 70.66W 5244.30 4707.40 5331.02 S 84.71W 5321.17 4754.06 5410.45 S 100.98W 5401.63 4803.32 5494.33 S 119.73W 5486,74 191,41 192,91 192,81 193,36 194,04 194,19 191,99 191,67 191,36 191,25 190,28 191,41 192,88 193.94 192,52 4849,73 4894,43 4943,95 4992,47 5039,68 5086,57 5133,09 5179,59 5227,64 5273,18 5321,53 5370,58 5417,65 5464,41 5511,45 5572.23 S 5647.50 S 5730.89 S 5810.57 S 5888,36 S 5966.28 S 6044.56 S 6124.30 S 6206.47 S 6283,80 S 6364,70 S 6447,01S 6526,19 S 6603,30 S 6679,91S 136,19 W 152,41 W 171,45 W 189,97 W 208,94 W 228.53 W 246.73 W 263.43 W 280.17 W 295.63 W 311:01W 326.78W 343.82W 362.20W 380.21W 5565.69 5641,99 5726.63 5807.52 5886,55 5965,78 6045,25 6126,05 6209,28 6287,59 6369,45 6452.75 6533,02 6611,33' 6689,13 192.54 191,89 191.17 191.49 190.70 5560,61 5610,01 5657,38 5702,41 5752,39 6759.09 S 6839.95 S 6920.00 S' 6995.52 S 7077.64S 397.81W 415,31W 431,64W 446,77W 462,88W 6769.45 6851.43 6932.52 7008.99 7092.12 191,53 189,62 188,89 190,00 192,39 5799.21 5845.49 5892.09 5941.14 5990.16 7155.80 S 7235.05 S 7314.14 S 7395.36 S 7475.17 S 478,24W 493,03W 505,92W 519,43W 535,23W 7171.25 7251,41 7331.27 7413.30 7494.11 Dogleg (deg/100f) TIE-IN 0.43 0.79 7.14 5.62 2.79 4,31 1.74 0.89 1.22 2.42 0.59 0.56 2.28 0.49 1.08 1,61 0,48 .0.93 1,29 0,59 2,29 0.41 0,29 0,53 0,95 1.14 1,37 1.17 1.33 '0.65 1.54 0.67 0,69 0.88 1,63 1,79 0,87 1,23 2.16 Job No,: AK-MM-0029'I Well No,: 'ID-40A End of Well Report , Page 7 DirectionalSurvey Data Measured Depth (feet) 10498.35 10580.32 10675.38 10770,04 10866,42 1096516 11026.53 1111O,0O Inclination Direction Vertical Latitude Departure Depth (degrees) (degrees) (feet) (feet) (feet) Vertical Dogleg Section (feet) (deg/lO00 59.20 193.43 6035.34 7548,75 S 552.10W 58.44 191.68 6077.78 7617.20 S 567.34W 58.50 190.51 6127.50 7696.71 S 582.94W 58.04 190.96 6177.28 7775.81 S 597.93W 57.62 190.35 6228,60 7855.98 S 613.02W 57.49 190.18 6281.57 7937.98 S 627,87W 57.20 191.17 6314.68 7988.75 S 637.44W 57.20 191.17 6359.90 8057.58 S 651.03W 7568.79 1.04 7638.22 2.O5 7718.71 1.05 7798.75 0.63 7879.86 0.69 7962.77 0.20 8014.14 1.44 8O83.83 0.00 Job No.: AK-MM-00291 Well No.: ID-40A End of Well Report Page 8 MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 11, 2001 · SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips P.I. Supervisor/~t---'- ' 1D Pad ~('tc~''O~, 1 D-32, 1 D-39, 1 D-40A FROM: Chuck Scheve KRU Petroleum Inspector Kupamk NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well'I 1D-32 I Typelni. I S I' T.V.D. I 6276I~u~"~l ~o~o'1 ~°"°1 ~o~ol ~0~0 l ln'tervall' ~ ' P.T.D.I 200-173',Typetes'tI . P ITestpsil 1569 I CasingI 1850'I 2500..I 2450. ! .2450 Notes: 'WellI 1D-39 J mype,nJ.l''s' I ~.v.D. ! ~00 'l'Tu'bing J 2050 I ~o~o I' ~o~o I 2o~o I Interva, I'.', P.T.D.j 200'216,'~ype'testJ P jTestpsi.J .~550 J, Casi.ng.J 1250J 2500' J 2475 I 2475,1 P,,/F"I _P' Notes: w~.I._,,,jJ;;..'.~A '1Type Inj.I s'I Y.v.o. I5976 I TubingI ~oso 'i2050I2050I 2o5o"1 IntervalI' I'~ ,P'~~~~o~,',,,'::il'~p~testl P'I Test psiI 1494. I Casing I zso,, I 2s50, i 25oo I 2soo '1 ?~F Notes: we,I. I Type Inj. I I ~.V.D. I ITubin~l I' I I ' ' I' I Inte~Vall .P'T'D'I ' 'ITYpetestl" ITest psil '1 casing I I I" I "' I p/F Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 1D Pad in thc Kuparuk river field and witnessed the initial MIT on wells 1D-32, 1D-39 and 1D-40A. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: 3 Attachments: Number of Failures: Total Time during tests: 3 hours cc,: MIT report form 5/12/00 L.G. MIT KRU 1-D Pad 5-11-01 CS 5/18/01 08-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-40A MWD Dear Dear Sir/Madam: ~OO -'/~ Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,920.65' MD 6,978.00' MD 11,110.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ALASKA OIL AND GAS CONSERVATION COPlPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Tranthan Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River .I D-40A Phillips Alaska, Inc. Permit No: 200-190 Sur. Loc. 537'FNL, 421'FEL, Sec. 23, TI IN, R10E, UM Btmhole Loc. 1945'FSL, 1088'FEL, Sec. 26, TI 1N, RIOE, UM Dear Mr. Tranthan: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours)of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the COmmission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, J. M. Heusser Commissioner 'BY ORDER OF THE COMMISSION DATED this ~r~..., day of November, 2000 dlffEncloSures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill L.J Redrill ~ I lb. Type of well. Exploratory D Stratlgraphic Test D Development Oil Re-entry D Deepen r'~I Service [~] Development Gas ~ Single Zone r~ Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation OZ~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25661 ALK 471 ,~ Kuparuk River Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 537' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2122' FSL, 1050' FEL, Sec. 26, T11N, R10E, UM 1D-40A #U-630610 At total depth 9. Approximate spud date Amount 1945' FSL, 1088' FEL, Sec. 26, T11N, R10E, UM December 1, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) 2122 @ Targ~ feetI 1D-134 852' @ 6922' feet 2560 11127' MD/6359 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth: 6988 MD Maximum hole angle 59° Maximum surface 3374 psig At total depth (TVD) 4062 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantib/of Cement Hole Casin~l Wei~lht Grade Couplinc, I Len~h MD 'rVD MD TVD (include sta~le data) e,~"~/74' ~ ,~" 26# L-SO BTCM 10585' 35' 35' 10620' 6101' 170 sx Class G I~," ~?~" ~,.~'6.6~5" 9.3# L-80 LHT 657' 10470' 5628' 11127' 6359' 150 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 12225 feet Plugs (measured) 11610'-12225', 11137'-11610' true vertical 6376 feet Effective Depth: measured 11137 feet Junk (measured) true vertical 5957 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 102' 20" 503 sx ASLite 137' 137' Surface 6943' 9.625" 818 sx AS IIILW, 477 sx LiteCrete 6978' 4244' Production 11558' 7" 180 sx Class G 11561' 6082' RECEIVED .erforatlondepth: measured No Perforations 0 RIG iNA L NOV true vedical No Perforations Alaska 0il & Gas Cons. Commission Anchorage 20. Attachments Filing fee r~] Property Plat D BOP Sketch D Diverter Sketch ~;] Drilling program [~] Drilling fluid program r~ Time vs depth plot [~]Rofractlon analysis ~ Seabed report r~ 20 AAC 25.050 requirements 21. I hereby certif)' that the foregoing is true and correct to the best of my knowledg~ Questions? Call Todd Mushovic 265-697, Signed !ra~~ ( ¢"~.-4, ~~ Title: DrillingEngineeringSupervisor gatel ~ / Pre~ared bv Shar~)tl AIIsun-DrM~ u/' Commission Use Chi) Permit Number~ .-/?{~ I AP150.number~ 2.~::~._ P~/~'-~' 7'" ~) /]~ Apprqv.al date ,. ]See cover letter ' //"",~ ~'"~;~0 Ifor other requirements Conditions of approval Samples required ~] Yes [~ No Mud I~)g required E~ Yes F~ No Hydrogen sulfide measures [~1 Yes r-~ No Directional survey required [] Yes El No Required working pressure for BOPE [-']2M; D 3M; ~~ r'~ lOM;[~] r~ c,,~w,e.~.~(~,t~,,~,,/~_c)~,~,~ Other: O~GINAL SIGNED BY by order of Approved by J.M. Heusser Commissioner the commission Date ,, Form 10-401 Rev. 12/1/85 · Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE EBA INJECTOR KRU 1 D-40A General Procedure: 1. Move in / rig up Nabors Rig 16E. 2. Verify well is dead. Circulate out diesel w/10.5 ppg mud through tubing kill string. 3. Set BPV. ND tree. NU BOPE and test to 5000 psi. Record results. 4. Screw into landing joint. Pull tubing hanger to rig floor. POOH laying down tubing. 5. PU Baker Multi-String Hydraulic Cutter and RIH. Cut 7" 26.0# L-80 BTCM intermediate casing at +/- 7230' MD. POOH and lay down cutter. 6. POOH laying down 7" casing 7. TIH and spot cement plug across the 7" stub according to AOGCC regulations and up into the 9-5/8" casing to +/- 6700' MD. TOH. 8. TIH and tag cement. Pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 10. Directionally drill 8-1/2" hole to mid-point of the HRZ (10522' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Perform second LOT at mid-HRZ to evaluate long string option. If LOT is adequate to long string, drill to well total depth (11127' MD), run 7" 26.0# J-55 BTCM casing to surface and cement, and continue with step #17. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 11. If LOT is inadequate to long string, drill to 7" intermediate casing point (10620' MD). 12. Run 7" 26.0# L-80 BTCM casing to surface and cement. . Note: If significant hydrocarbon zones are present above the Kuparuk, sufficier,,l~e,_men~VO~ will be pumped for isolation in accordance with Rule 20 AAC 25.030 -'"reo/7~. 13. Nipple up B PE and test to 5000 psi. Record results. O, -,u~.~, - 14. Shut in BOP s and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 15. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 16. Drill 6-1/8" hole to well total depth (+/- 11127' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 17. Run open hole e-line or drill pipe conveyed logs as needed. 18. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/FlexIock hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 19. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 20. Run and land 3-1/2" tubing. TJM, 11/15/00, vl 21. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 22. Freeze protect well. Set BPV. Release rig and turn well over to production. 23. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLToJ or CBT) will be run to establish isOlation after the cleanout is completed, but prior to perforating. RECEIVED NOV ?. 0 ?OOO Alaska Oil & Gas Cons. Commission Anchorage TJM, 11/15/00, vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1 D-40A Drillin.q Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" Surface Casin[I 8.5-10.2 16-26 25-50 100-200* 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin[1 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 20-30 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Three possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1 D-40A well path. 1) MASP can be calculated using an expected leak-off of 13.8 ppg EMW (0.72 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2596 psi. The leak off EMW was chosen based on an open hole LOT on well, 1 D-40, taken to 13.8 ppg at 4256' TVD (0.72 psi/fi). MASP = (4256 ft)(0.72-0.11) = 2596 psi 2) 3) If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can be calculated based on a reservoir pressure of 3550 psi at 6359' TVD (0.56 psi/fi) and a gas gradient of 0.11 psi/ff. In this case, MASP would occur at 2862 psi. MASP = (6359 ft)(0.56 - 0.11) = 2862 psi Some prior EBA and GSA wells in this area have experienced gas charged sands in the D-shale as a result of historic Gas Storage Area injection. These sands are located above the Kuparuk reservoir and are expected to occur at +/- 6249' TVD along the proposed well path in the 1D-40A target area. There is a strong possibility that gas charging will be encountered in this well and if this occurs, MASP would be based on a 12.5 ppg equivalent pressure (0.65 psi/ft). Based on this pressure gradient and a gas gradient of 0.11 psi/fi, MASP would occur at 3374 psi. MASP = (6249 ft)(0.65 - 0.11) - 3374 psi Therefore, based on the possibility of a MASP greater than 3000 psi, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing. In the event that the well must be topset above the Kuparuk, the maximum anticipated pressure for the intermediate casing string would continue to be the pressure exerted by the gas charged D-shale sands at the surface and would remain at 3374 psi as calculated previously. Therefore, based on the possibility of a MASP greater than 3000 psi, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an intermediate string is needed. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based on the potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 13.0 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6359'. MW = [(6359 fi)(0.65)+150]/6359/.052 = 13.0 ppg In order to allow for a long string design, the minimum LOT in the Mid-HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 13.0 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 1D-40A, besides 1D-40, is 1D-134. As designed, the minimum distance between the two wells would be 852' at 6922' MD. Drilling Area Risks: Risks in the 1D-40A drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D-shale based upon those results. Annular Pumpin~ Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (>4 hr) in pumping operations. The 1D-40A surface/production casing annulus will be filled with diesel after setting 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. At the end of drilling operations, a request for 1D-40A to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1D pad, per regulation 20 AAC 25.080, will be submitted. 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 Colville 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 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 iNA 5,750 psi 4,888 psi 7" 26 L-80 3 BTC 5,410 psi 4,599 psi 7,240 psi 6,154 psi 3Y2"* 9.3 L-80 2 '8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi *ifneeded 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). RECEIVED NOV ?,. 0 Alaska Oil & Gas Cons. Commission Anchorage KRU 1D-40A Injec{' .r Proposed Completion Schematic Topset Base Case PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM OOMPANY 20" 91.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM ( 6978' MD / +/- 4244' TVD) Old Wellbore 1D-40 Top of 7" casing stub +/- 7200' MD Cement plug set inside and outside of casing according to AOGCC regulations TOC @ 11,137' MD For Cement Plug #2 7" 26.0# L-80 BTCM (+/- 11561' MD / 6082' TVD) //~, TOC @ 11,610' MD / For Cement Plug #1 TJM, 11/16/00, v2 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUESRD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUESRD tubing to landing nipple RECEIVED NOV 2 0 Alaska Oil & Gas Cons. Commission Anchorage 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/shear valve and latch (Max. OD 5.968" ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handlin pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly, set @ +/- 10470' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer w/HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Halliburton 'XN' nipple w/2.75" No-Go Profile, 3-1/2" SLHT box x pin 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe Intermediate csg. 7" 26.0# L-80 BTCM (+/- 10620' MD/ 6101' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+/- 11127' MD / 6359' TVD) 1D-40A Well Intermediate Cement loads and CemCADE* summary. Use 75 % excess. Drilled with 8 1/2" bit. 7", 29 #casing TMD 10620'. TOC@ 9820' (800' Shoe Tack). Volume Calcs: Pump 20 bbls Arco Preflush, 30 bbls MudPUSH XL Spacer @ 12.0ppg. Cement from 10620' MD to 9820' with Class G + adds @15.8 ppg Slurry Requirements: 15.8 ppg Class G 0.2%D46, 0.3%D65, 0.1%D800 - 1.17 ft3/sk (adjust retarder to give 3-4 hours thickening time) 7", 29# x 8 1/2" OH: (10620'-9820') x 0.1268 ft3/ft x 1.75 (75% excess) = Shoe Joints: (80') x 0.2086 ft3/ft = Total Volume = 194.2 ft3 / 1.17 ft3/sk = 177.5 ft3 16.7 ft3 BHST = 150F (estimated) CemCADE* Summary: 194.2 ft3. 166 sks - Round up to 170 sks Circulation: Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1100 psi. At 7 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 20 or under, Ty = 20 or under. Kevin Tanner can be reached at the following numbers regarding this job or any other assistance: 265- 6205(w), 336-0067(h), 230-6628(ce11). Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 30 bbls 12.0 ppg MudPUSH XL Spacer, 170 sks (35 bbls) Class G + adds. Displacement is approximately 392 bbls. {' 1D-40A Kuparuk Well, Liner Cement loads and CemCADE* summary. Use 60% excess. Drilled with 6 1/8" bit. 3 1/2", 9.3 #casing TMD 11127'. TOC@ 10270' (200' over top of liner top). Liner Top @ 10470' Previous casing 7", 29#, 10620' TMD. 4", 14# DP, 300' liner lap. Volume Calcs: Pump 20 bbls Arco Preflush, 20 bbls MudPUSH XL Spacer @ 13.0ppg. Cement from 11127' MD to 10270' with Class G + adds @ 15.8 ppg Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, D800, D047, D065, per lab testing - 3.5 to 4.5 hour thickening time, Yield = 1.2 ft3/sx 3 1/2", 9.3//x 6 1/8" OH: (11127'-10620') x 0.1378 ft3/ft x 1.60 (60% excess) = 111.8 ft3 3 1/2", 9.3# x 7", 29#: (300') x 0.1418 ft3/ft = 21.3 ft3 7", 294/: (200') x 0.2086 ft3/ft = 41.7 ft3 Shoe Joints: (80') x 0.0488 ft3/ft = 3.9 ftc3 Total Volume = 178.7 ft3. 178.7 ft3 / 1.2 ft3/sk = 149 sks - Round up to 150 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 20 bbls 13.0 ppg MudPUSH XL Spacer, 150 sks (32 bbls) Class G + adds. Displacement is approximately 118 bbls. Circulation: Circulation and cementing at or less than 3 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 2 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1700 psi. At 3 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 13.0 ppg (preferably lower), Pv = 20 or under, Ty = 20 or under. ~ r~s, FOR: MUSHOVI(~ oa,e p,o,t~: , ~-,o,,-2ooo Plot Ret .... i~ 40A V--ion ~2./ C~dTnate~ are in feet reference slot t40. / Phillips Alaska, Inc. Structure : Pad 1D Well : 40A Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 1200 go0 600 300 0 300 I I I I I I I I SIDETRACK POINT: 159' FSL, 572' FEL SEC. 25, T11N, RIOE Tie-in Survey 9-5/8 Casing Sidetrack Paint t ~,. Tie-ln Survey __ 9-5/8 Casing - 4200 ~ Sidetrack Polnt I TARG~ LO~ Begin 3 Deg Right Turn J 65.00 9 ~ Begin 3 Deg Right Turn I 2122' FSL, 1050' FELI CSn fK-ln~ I SEC. 25, T11N, RIOEI.... 4500 59J6 ~ C80 ~~ EOC m TD LO~TION: m EOC ~ ~ ] 1945' FSL, 1088' FEL m ~ ~ 184.51 AZIMUTH / ~,oo~ ~ ~ 79~5' (TO TARGET) ~// c5o ***Plane of Proposal*** C50 6600 To~, B Shole C30 J TD-Cosing Pt Top HRZ 6900~ C20 {HRZ Midpoint / , 7 Casing Pt/Base HRZ ' ' ' ' -- ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' K-1 4200 450O 480O 51~ 54~ 5700 6~ 6~ 6~0 6900 7200 7500 7800 8100 8400 Top Kuporuk D Target-Top C4 Vertical Section (feet) -> Top C3 Top C2 Azimuth 1B~.51 with reference 0.00 S, 0.00 E from slot ~40 Top C1 Top B Shole TD-Cosing Pt 3900 4200 ..,~. 4500 4800 5100 ~00 5700 0~ 6300 ~' ,.--~. 6600 6900 7200 7500 78OO B 1 O0 c~--t~d ~ ~,e FOR: MUSHOVI(~ Dote ploit~: 17-N~-2~0 l ~ot R~e~e ~ ~ V~n ~2. / ~r~ ore ~n f~ r~ ~ ~. / True V~oI ~pths ar~ ~e ~e[~J /' Phillips Alaska, Inc. Structure : Pad lO Well : 40A Field: Kuparuk River Unit Location: North Slope, Alaska Point Tie-in Survey 9-5/8 Csg. Shoe Sidetrack Point Begin 5 Deg Right Turn ca0 (K-lO) EOC C50 C40 (K-S) Top HRZ C30 (K-2) C20 (HRZ Midpoint) 7 Casing Pt/Base HR K-1 Top Kuparuk D Target-Top C4 Top C5 Top C2 Top C1 Top B Shale TD-Casing Pt PROFILE MD 6921.50 6978.OO 6988.00 7124.54 7387.03 7653.55 9153.88 9.617.71 1O195.52 10234.83 10521.77 10620.04 10765.47 10910.91 10916.81 10948.25 10960.04 10969.87 10979.70 11127.10 iRC 66.40 66.26 66.23 59.41 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 59.42 COMMENT Dir 184.44 184 22 1 84 50 1 84 50 192 01 192 01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 192.01 TVD 4255.25 4255.95 4259.96 4522.20 4456.00 4591.61 5355.00 5591.00 5885.00 5905.00 6051.00 6101.00 6175.00 6249.0O 6252.00 6268.00 6274.00 6279.00 6284.00 6559.00 DATA North -4523.1 6 -4574.76 -4583.89 -4704.75 -4927.97 -5152.59 -6415.70 -6806.25 -7292.79 -7325.89 -7567.50 -7650.24 -7772.70 -7895.16 -7900.1 3 -7926.60 -7956.55 -7944.81 -7955.08 -8077.20 East 56.94 53.03 52.35 45.27 8.86 -58.90 -307.72 -590.85 -494.56 -501.41 -552.82 -570.43 -596.49 -622.54 -623.60 -629.24 -651.55 - 653.11 -654.87 -661.28 V. Sect 4504.65 4556.40 4565.56 4686.76 4912.00 5159.47 642O .O2 6815.90 7509.07 7342.62 7587.55 7671.40 7795.53 7919.67 7924.70 7951.54 7961.60 7969.99 7978.58 8104.19 0.00 0.44 0.76 5.00 0.00 0.00 0.00 o.oO 0.00 0.o0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 c,.ot~d ~, ~... FOR: MUSOVIC Dot~ plotted: 16-No~-,2000 Phillips Alaska, Inc. Structure : Pad 1D Well : 40A Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 4000 .3600 .3200 2800 2400 2000 1600 1200 800 400 0 400 800 1200 1600 6400 6800 7200 I v 76oo 3600 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 4000 4400 /5900 500 4700 I, ~700 6000 5100 4900 5300 ~/ ' I i 5100 5500 ~ / 5700 ~ 5300 / / 5900 t / 5500 6100~ / / 5700 8000 6500 ~ 5900 8400 RECEIVED 8800 6100 NOV 2 0 ZOO0 9200 6500 Al~aOil&GasCons. Com~$sion 960o ^n~omoe ~oooo 4000 3600 3200 2800 2400 2000 ~6oo ~2oo 800 400 o 400 800 ~2oo ~6oo <- West (feet) 3600 4000 4400 4800 5200 5600 6OOO 6400 (./) 0 6800 7200 ,-,i.. I 7600 V 8000 84-00 8800 9200 9600 10000 10400 Phillips Alaska, nc. Structure : Pod 1D Well : 40 Field : Kuporuk River Unit Locofion : North Slope, Alosko TRUE NORTH 350 0 10 540 20 330 30 320 40 310 5O 3OO 60 290 7O 280 270 80 9O 260 100 250 110 240 120 230 220 ~soo 140 8600 210 8~50 200 160 190 180 170 All depths shown (]re Measured depths on Reference Well Normal Plane Travelling Cylinder - Feet 130 Phillips Alaska, Inc. Pad 1D 40A slot #40 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 40A Version#2 Our ref : prop4286 License : Date printed : 17-Nov-2000 Date created : lO-Nov-2000 Last revised : 17-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.035,w149 30 31,181 Slot Grid coordinates are N 5959129.177, E 560670.303 Slot local coordinates are 537.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Pad 1D,40A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 6921.50 66.40 184.44 4233.25 4523.16 S 56.94 E 6978.00 66.26 184.22 4255.93 4574.76 S 53.03 E 6988.00 66.23 184.30 4259.96 4583.89 S 52.35 E 7012.54 65.00 184.30 4270.09 4606.17 S 50.68 E 7112.54 60.00 184.30 4316.25 4694.59 S 44.03 E 7124.34 59.41 184.30 4322.20 4704.75 S 43.27 E 7200.00 59.36 186.93 4360.74 4769.55 S 36.90 E 7300.00 59.38 190.42 4411.70 4854.59 S 23.92 E 7345.69 59.42 192.01 4434.96 4893.16 S 16.27 E 7387.03 59.42 192.01 4456.00 4927.97 S 8.86 E PROPOSAL LISTING Page 1 Your ref : 40A Version#2 Last revised : 17-Nov-2000 Dogleg Vert Deg/lOOft Sect 0.00 4504.65 Tie-in Survey 0.44 4556.40 9-5/8" Csg. Shoe 0.76 4565.56 Sidetrack Point 5.00 4587.90 5.00 4676.57 5.00 4686.76 Begin 3 Deg Right Turn 3.00 4751.86 3.00 4837.66 3.00 4876.71 0.00 4912.00 C80 (K-lO) 7500.00 59.42 192.01 4513.48 5023.10 S 11.38 W 0.00 5008.42 7653.55 59.42 192.01 4591.61 5152.39 S 38.90 W 0.00 5139.47 EOC 8000.00 59.42 192.01 4767.89 5444.11 S 100.97 W 0.00 5435.17 8500.00 59.42 192.01 5022.29 5865.12 S 190.56 W 0.00 5861.93 9000.00 59.42 192.01 5276.70 6286.13 S 280.15 W 0.00 6288.68 9153.88 59.42 192.01 5355.00 6415.70 S 307.72 W 0.00 6420.02 C50 9500.00 59.42 192.01 5531.11 6707.14 S 369.74 W 0.00 6715.44 9617.71 59.42 192.01 5591.00 6806.25 S 390.83 W 0.00 6815.90 C40 (K-5) 10000.00 59.42 192.01 5785.52 7128.15 S 459.33 W 0.00 7142.20 10195.52 59.42 192.01 5885.00 7292.79 S 494.36 W 0.00 7309.07 Top HRZ 10234.83 59.42 192.01 5905.00 7325.89 S 501.41W 0.00 7342.62 C30 (K-2) 10500.00 59.42 192.01 6039.92 7549.17 S 548.92 W 0.00 7568.95 10521.77 59.42 192.01 6051.00 7567.50 S 552.82 W 0.00 7587.53 C20 (HRZ Midpoint) 10620.04 59.42 192.01 6101.00 7650.24 S 570.43 W 0.00 7671.40 7" Casing Pt/Base HRZ 10765.47 59.42 192.01 6175.00 7772.70 S 596.49 W 0.00 7795.53 K-1 10910.91 59.42 192.01 6249.00 7895.16 S 622.54 W 0.00 7919.67 Top Kuparuk D 10916.81 59.42 192.01 6252.00 7900.13 S 623.60 W 0.00 7924.70 40A Target lO-Nov-O0 10948.25 59.42 192.01 6268.00 7926.60 S 629.24 W 0.00 7951.54 Top C3 10960.04 59.42 192.01 6274.00 7936.53 S 631.35 W 0.00 7961.60 Top C2 10969.87 59.42 192.01 6279.00 7944.81S 633.11W 0.00 7969.99 Top C1 10979.70 59.42' 192.01 6284.00 7953.08 S 634.87 W 0.00 7978.38 Top B Shale 11000.00 59.42 192.01 6294.33 7970.18 S 638.51 W 0.00 7995.71 11127.10 59.42 192.01 6359.00 8077.20 S 661.28 W 0.00 8104.19 TD-Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 8104.22 on azimuth 184.68 degrees from wellhead. Total Dogleg for wellpath is 13.78 degrees. Vertical section is from wellhead on azimuth 184.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,40A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 40A Version#2 Last revised : 17-Nov-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 6921.50 4233.25 4523.16 S 56.94 E Tie-in Survey 6978.00 6988.00 7124.34 7387 03 7653 55 9153 88 9617 71 10195 52 10234 83 10521 77 10620 04 10765.47 10910.91 10916.81 10948.25 10960.04 10969.87 10979.70 11127.10 4255.93 4259.96 4322.20 4456.00 4591.61 5355.00 5591.00 5885.00 5905.00 6051.00 6101 O0 6175 O0 6249 O0 6252 O0 6268 O0 6274 O0 6279 O0 6284 O0 6359.00 4574.76 S 4583.89 S 4704.75 S 4927.97 S 5152.39 S 6415.70 S 6806.25 S 7292.79 S 7325.89 S 7567.50 S 7650.24 S 7772.70 S 7895.16 S 7900.13 S 7926.60 S 7936.53 S 7944.81S 7953.08 S 8077.20 S 53.03 E 52.35 E 43.27 E 8.86 E 38.90 W 307.72 W 390.83 W 494 36 W 501 41 W 552 82 W 570 43 W 596 49 W 622 54 W 623 60 W 629 24 W 631 35 W 633.11W 634.87 W 661.28 W 9-5/8" Csg. Shoe Sidetrack Point Begin 3 Deg Right Turn C80 (K- 10) EOC C50 C40 (K-5) Top HRZ C30 (K-2) C20 (HRZ Midpoint) 7" Casing Pt/Base HRZ K-1 Top Kuparuk D 40A Target 10-Nov-O0 Top C3 Top C2 Top C1 Top B Shale TD-Casing Pt Casing positions in string 'A' ~Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 4233.25 4523.16S 56.94E n/a 4233.25 4523.16S 56.94E 9-5/8" Casing n/a 4233.25 4523.16S 56.94E 10620.04 6101.00 7650.24S 570.43W 7" Casing n/a 4233.25 4523.16S 56.94E 11126.50 6358.70 8076.69S 661.17W 3 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 40A Target lO-Nov-O0 560111.000,5951225.000,2.0000 6252.00 7900.13S 623.60W lO-Nov-2000 Phillips Alaska. Inc. Pad 1D,40A Kuparuk River Unit,North Slope, A1 aska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 40A Version #2 Last revised : 17-Nov-2000 GRID COORD S GEOGRA Easting Northing C 0 0 R D I 6921.50 66.40 184.44 4233.25 4523.16S 56.94E 560764.00 5954607.06 n70 17 11.55 6978.00 66.26 184.22 4255.93 4574.76S 53.03E 560760.51 5954555.44 n70 17 11.04 6988.00 66.23 184.30 4259.96 4583.89S 52.35E 560759.91 5954546.30 n70 17 10.95 7012.54 65.00 184.30 4270.09 4606.17S 50.68E 560758.41 5954524.01 n70 17 10.73 7112.54 60.00 184.30 4316.25 4694.59S 44.03E 560752.49 5954435.54 n70 17 09.86 7124.34 59.41 184.30 4322.20 4704.75S 43.27E 560751.81 5954425.38 n70 17 09.76 7200.00 59.36 186.93 4360.74 4769.55S 36.90E 560745.96 5954360.54 n70 17 09.13 7300.00 59.38 190.42 4411.70 4854.59S 23.92E 560733.68 5954275.41 n70 17 08.29 7345.69 59.42 192.01 4434.96 4893.16S 16.27E 560726.34 5954236.78 n70 17 07.91 7387.03 59.42 192.01 4456.00 4927.97S 8.86E 560719.22 5954201.91 n70 17 07.57 7500.00 59.42 192.01 4513.48 5023.10S 11.38W 560699.75 5954106.64 n70 17 06.63 7653.55 59.42 192.01 4591.61 5152.39S 38.90W 560673.29 5953977.14 n70 17 05.36 8000.00 59.42 192.01 4767.89 5444.11S 100.97W 560613.60 5953684.95 n70 17 02.49 8500.00 59.42 192.01 5022.29 5865.12S 190.56W 560527.44 5953263.26 n70 16 58.35 9000.00 59.42 192.01 5276.70 6286.13S 280.15W 560441.29 5952841.58 n70 16 54.21 9153.88 59.42 192.01 5355.00 6415.70S 307.72W 560414.77 5952711.80 n70 16 52.94 9500.00 59.42 192.01 5531.11 6707.14S 369.74W 560355.13 5952419.89 n70 16 50.07 9617.71 59.42 192.01 5591.00 6806.25S 390.83W 560334.85 5952320.62 n70 16 49.09 10000.00 59.42 192.01 5785.52 7128.15S 459.33W 560268.98 5951998.21 n70 16 45.93 10195.52 59.42 192.01 5885.00 7292.79S 494.36W 560235.29 5951833.31 n70 16 44.31 10234.83 59.42 192.01 5905.00 7325.89S 501.41W 560228.51 5951800.16 n70 16 43.98 10500.00 59.42 192.01 6039.92 7549.17S 548.92W 560182.82 5951576.52 n70 16 41.79 10521.77 59.42 192.01 6051.00 7567.50S 552.82W 560179.07 5951558.16 n70 16 41.61 10620.04 59.42 192.01 6101.00 7650.24S 570.43W 560162.14 5951475.29 n70 16 40.79 10765.47 59.42 192.01 6175.00 7772.70S 596.49W 560137.08 5951352.63 n70 16 39.59 10910.91 59.42 192.01 6249.00 7895.16S 622.54W 560112.02 5951229.97 n70 16 38.39 10916.81 59.42 192.01 6252.00 7900.13S 623.60W 560111.00 5951225.00 n70 16 38.34 10948.25 59.42 192.01 6268.00 7926.60S 629.24W 560105.58 5951198.48 n70 16 38.08 10960.04 59.42 192.01 6274.00 7936.53S 631.35W 560103.55 5951188.54 n70 16 37.98 10969.87 59.42 192.01 6279.00 7944.81S 633.11W 560101.86 5951180.25 n70 16 37.90 10979.70 59.42 192.01 6284.00 7953.08S 634.87W 560100.16 5951171.96 n70 16 37.82 11000.00 59.42 192.01 6294.33 7970.18S 638.51W 560096.66 5951154.84 n70 16 37.65 11127.10 59.42 192.01 6359.00 8077.20S 661.28W 560074.76 5951047.65 n70 16 36.59 PHIC NATES w149 30 29.51 w149 30 29.63 w149 30 29.65 w149 30 29.70 w149 30 29.89 w149 30 29.91 w149 30 30.10 w149 30 30.48 w149 30 30.70 w149 30 30.91 w149 30 31.50 w149 30 32.31 w149 30 34.11 w149 30 36.72 w149 30 39.33 w149 30 40.13 w149 30 41.94 w149 30 42.55 w149 30 44.55 w149 30 45.57 w149 30 45.77 w149 30 47.15 w149 30 47.27 w149 30 47.78 w149 30 48.54 w149 30 49.30 w149 30 49.33 w149 30 49.49 w149 30 49.55 w149 30 49.60 w149 30 49.66 w149 30 49.76 w149 30 50.42 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 8104.22 on azimuth 184.68 degrees from wellhead. Total Dogleg for wellpath is 13.78 degrees. Vertical section is from wellhead on azimuth 184.51 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,40A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 40A Version#2 Last revised : 17-Nov-2000 Comments in wellpath MD la~D Rectangular Coords. Comment 6921.50 6978.00 6988.00 7124.34 7387.03 7653.55 9153.88 9617.71 10195 52 10234 83 10521 77 10620 04 10765 47 10910 91 10916 81 10948 25 10960 04 10969.87 10979.70 11127.10 4233.25 4255.93 4259.96 4322.20 4456.00 4591.61 5355.00 5591.00 5885.00 5905.00 6051.00 6101.00 6175.00 6249.00 6252.00 6268.00 6274.00 6279.00 6284.00 6359.00 4523 16S 4574 76S 4583 89S 4704 75S 4927 97S 5152 39S 6415 70S 6806 25S 7292.79S 7325.89S 7567.50S 7650.24S 7772.70S 7895.16S 7900.13S 7926.60S 7936.53S 7944.81S 7953.08S 8077.20S 56.94E 53.03E 52.35E 43.27E 8.86E 38.90W 307.72W 390.83W 494.36W 501.41W 552.82W 570.43W 596.49W 622 54W 623 60W 629 24W 631 35W 633 11W 634 87W 661 28W Ti e- i n Survey 9-5/8" Csg. Shoe Sidetrack Point Begin 3 Deg Right Turn C80 (K- 10) EOC C50 C40 (K-5) Top HRZ C30 (K-2) C20 (HRZ Midpoint) 7" Casing Pt/Base HRZ K-1 Top Kuparuk D 40A Target lO-Nov-O0 Top C3 Top C2 Top C1 Top B Shale TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 4233.25 4523.16S 56.94E n/a 4233.25 4523.16S 56.94E 9-5/8" Casing n/a 4233.25 4523.16S 56.94E 10620.04 6101.00 7650.24S 570.43W 7" Casing n/a 4233.25 4523.16S 56.94E 11126.50 6358.70 8076.69S 661.17W 3 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 40A Target lO-Nov-O0 560111.000,5951225.000,2.0000 6252.00 7900.13S 623.60W lO-Nov-2000 Phillips Alaska. Inc. Pad 1D,40A Kuparuk River Unit. North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth PROPOSAL LISTING Page 1 Your ref : 40A Version#2 Last revised : 17-Nov-2000 R E C T A N G U L A R Vert Ellipse Semi Axes Minor C 0 0 R D I N A T E S Sect Major Minor Vert. Azi. 6921.50 66.40 184.44 4233.25 4523.16 S 56.94 E 4504.65 62.62 40.36 50.16 1.65 6978.00 66.26 184.22 4255.93 4574.76 S 53.03 E 4556.40 63.90 40.42 50.24 1.66 6988.00 66.23 184.30 4259.96 4583.89 S 52.35 E 4565.56 64.13 40.44 50.25 1.66 7012.54 65.00 184.30 4270.09 4606.17 S 50.68 E 4587.90 64.69 40.47 50.29 1.67 7112.54 60.00 184.30 4316.25 4694.59 S 44.03 E 4676.57 66.91 40.60 50.45 1.71 7124.34 59.41 184.30 4322.20 4704.75 S 43.27 E 4686.76 67.18 40.61 50.47 1.71 7200.00 59.36 186.93 4360.74 4769.55 S 36.90 E 4751.86 68.90 40.71 50.60 1.84 7300.00 59.38 190.42 4411.70 4854.59 S 23.92 E 4837.66 71.23 40.85 50.77 2.19 7345.69 59.42 192.01 4434.96 4893.16 S 16.27 E 4876.71 72.32 40.92 50.86 2.37 7387.03 59.42 192.01 4456.00 4927.97 S 8.86 E 4912.00 73.33 40.98 50.94 2.53 7500.00 59.42 192.01 4513.48 5023.10 S 11.38 W 5008.42 76.09 41.14 51.17 2.97 7653.55 59.42 192.01 4591.61 5152.39 S 38.90 W 5139.47 80.12 41.41 51.53 3.47 8000.00 59.42 192.01 4767.89 5444.11 S 100.97 W 5435.17 89.22 42.00 52.36 4.59 8500.00 59.42 192.01 5022.29 5865.12 S 190.56 W 5861.93 103.31 43.01 53.82 5.79 9000.00 59.42 192.01 5276.70 6286.13 S 280.15 W 6288.68 118.03 44.14 55.55 6.68 9153.88 59.42 192.01 5355.00 6415.70 S 307.72 W 6420.02 122.69 44.52 56.16 6.89 9500.00 59.42 192.01 5531.11 6707.14 S 369.74 W 6715.44 133.17 45.38 57.51 7.36 9617.71 59.42 192.01 5591.00 6806.25 S 390.83 W 6815.90 136.81 45.69 58.02 7.49 10000.00 59.42 192.01 5785.52 7128.15 S 459.33 W 7142.20 148.60 46.72 59.69 7.90 10195.52 59.42 192.01 5885.00 7292.79 S 494.36 W 7309.07 154.72 47.27 60.61 8.07 10234.83 59.42 192.01 5905.00 7325.89 S 501.41 W 7342.62 155.95 47.39 60.80 8.10 10500.00 59.42 192.01 6039.92 7549.17 S 548.92 W 7568.95 164.25 48.14 62.05 8.33 10521.77 59.42 192.01 6051.00 7567.50 S 552.82 W 7587.53 164.93 48.21 62.16 8.34 10620.04 59.42 192.01 6101.00 7650.24 S 570.43 W 7671.40 168.04 48.50 62.65 8.41 10765.47 59.42 192.01 6175.00 7772.70 S 596.49 W 7795.53 172.63 48.94 63.39 8.52 10910.91 59.42 192.01 6249.00 7895.16 S 622.54 W 7919.67 177.22 49.38 64.12 8.62 10916.81 59.42 192.01 6252'.00 7900.13 S 623.60 W 7924.70 177.41 49.40 64.15 8.62 10948.25 59.42 192.01 6268.00 7926.60'S 629.24 W 7951.54 178.40 49.49 64.31 8.65 10960.04 59.42 192.01 6274.00 7936.53 S 631.35 W 7961.60 178.78 49.53 64.37 8.65 10969.87 59.42 192.01 6279.00 7944.81 S 633.11 W 7969.99 179.09 49.56 64.42 8.66 10979.70 59.42 192.01 6284.00 7953.08 S 634.87 W 7978.38 179.40 49.59 64.48 8.67 11000.00 59.42 192.01 6294.33 7970.18 S 638.51 W 7995.71 180.04 49.65 64.58 8.68 11127.10 59.42 192.01 6359.00 8077.20 S 661.28 W 8104.19 184.08 50.05 65.25 8.76 All data is in feet unless otherwise stated. Coordinates from slot #40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 8104.22 on azimuth i84.68 degrees from wellhead. Vertical section is from wellhead on azimuth 184.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,40A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 40A Version#2 Last revised : 17-Nov-2000 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6922 MWD + IFR (Alaska) - Corrected Dat User specified 62.62 40.36 50.16 6922 11127 ARCO (H,A. Mag) User specified 184.08 50.05 65.25 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 6921.50 6978.00 6988.00 7124.34 7387.03 7653.55 9153,88 9617.71 10195.52 10234.83 10521.77 10620.04 10765,47 10910.91 10916,81 10948,25 10960,04 10969.87 10979.70 11127.10 4233.25 4255.93 4259.96 4322.20 4456,00 4591,61 5355.00 5591.00 5885.00 5905.00 6051.00 6101.00 6175 O0 6249 O0 6252 O0 6268 O0 6274 O0 6279 O0 6284 O0 6359 O0 4523.16 S 56. 4574.76 S 53. 4583.89 S 52. 4704.75 S 43. 4927.97 S 8. 5152,39 S 38 6415,70 S 307 6806.25 S 390 7292.79 S 494 7325.89 S 501 7567.50 S 552 7650,24 S 570 7772.70 S 596 7895.16 S 622 7900,13 S 623 7926.60 S 629 7936,53 S 631 7944.81 S 633 7953,08 S 634 8077.20 S 661 94 E Tie-in Survey 03 E 9-5/8" Csg. Shoe 35 E Sidetrack Point 27 E Begin 3 Deg Right Turn 86 E C80 (K-lO) 90 W EOC 72 W C50 83 W C40 (K-5) 36 W Top HRZ 41W C30 (K-2) 82 W C20 (HRZ Midpoint) 43 W 7" Casing Pt/Base HRZ 49 W K-1 54 W Top Kuparuk D 60 W 40A Target lO-Nov-O0 24 W Top C3 35 W Top C2 11 W Top C1 87 W Top B Shale 28 W TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 4233.25 4523.16S 56.94E n/a 4233.25 4523.16S 56.94E 9-5/8" Casing n/a 4233.25 4523.16S 56.94E 10620.04 6101.00 7650.24S 570.43W 7" Casing n/a 4233.25 4523.16S 56.94E 11126.50 6358.70 8076.69S 661.17W 3 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D, Rectangular Coordinates Revised 40A Target lO-Nov-O0 560111.000,5951225.000,2.0000 6252.00 7900.13S 623.60W lO-Nov-2000 Phillips Alaska. Inc. Pad 1D 40A slot ~0 Kuparuk River Unit North Slope, Alaska 3-D M I N I MUM D I STANC E CLEARANCE INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ REPORT Your ref: 40A Version#2 Our ref : prop4286 License : Date printed : 16-Nov-2000 Date created : lO-Nov-2000 Last revised : 15-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.035,w149 30 31.181 Slot Grid coordinates are N 5959129.177, E 560670.303 Slot local coordinates are 537.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 1000 feet Proximities will incorpOrate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wel lpath PMSS IFR <O-16053'>,,34,Pad 1D PMSS <O-5015'>,,135,Pad 1D PMSS <O-5354'>,,102PB1,Pad 1D PMSS <5181-6454'>,,102PB2,Pad 1D PMSS <6143-6767'>,,102PB3,Pad 1D PMSS <6527-7378'>,,102,Pad 1D L1PMSS <4338-7400'> Sperry,,lO2L1,Pad 1D PMSS <0-1288'>,,138PB1,Pad 1D PMSS <0-6543'>,,138,Pad 1D 37 VersiOn O.i,,37,Pad 1D 41 VerSion#O.a,,41,Pad 1D PMSS IFR<O-11660'>,,36,Pad 1D PMSS IFR <O-14324'>,,38,Pad 1D Closest approach with 3-D Minimum Distance method Las~ revised Distance M.D. Diverging from M.D. 39 Version O.c,,39,Pad 1D 31-0ct-2000 PGMS <0-8850'> 28-May-81,,MP 1 17-ii-II,Pad 1D 23-Apr-1999 PMSS IFR <O-12044'>,,30,Pad 1D 2-0ct-2000 . '28 Version ~4, ,28,Pad 1D 2-0ct-2000 PGMS <0 ~-' 6400'>, ,WS-8, Pad ID 27-Apr-2000 PMSS <0 :'~ 7340'>,, 10, Pad 1D 28-Apr-1998 , 23-0ct-2000 )3618.0( 6921.5 8480.0 2-Jun-1998 )4362.6( 6921.5 6921.5 28-Jul-2000 )3011.3( 6~21.5 6921.5 27-Jul-2000 )2049.4( 6921.5 6921.5 27-Jul-2000 )1830.9( 6921.5 6921.5 28-Jul-2000 )1392.6( 6921.5 6921.5 27-Jul-2000 )1466.8( 6921.5 6921.5 18-May-2000 )5189.3( 6921.5 6921.5 18-May-2000 )2391.4( 6921.5 6921.5 26-0ct-2000 )3131.0( 6921.5 6921.5 10-0ct-2000 )2238.9( 6921.5 6921.5 2-0ct-2000 )2082.8( 6921.5 6921.5 2-0ct-2000 )943.4( 6921.5 6921.5 )2375.8( 6921.5 6921.5 )9428.2( 6921.5 6921.5 )3914.9( ~6921.5 6921.5 )5307.4( 6921.5 6921.5 )4341.0( 6921.5 6921.5 )3939.4( 6921.5 6921.5 PMSS <4674'-5639'>,,12~ ad 1D PMSS <0-5142'>..115,Pad 1D PMSS <0 - 6270'>.,114.Pad 1D PMSS <293 - 6866'>,.113,Pad 1D PMSS <294 - 8250'>,.112,Pad 1D PMSS <556-7024'>,,9,PadtD PMSS <0-8702'>..14.Pad 1D PMSS <O-9250'>,.12,Pad 1D PMSS<O-7045'>,,111,Pad 1D PMSS <O-4850'>..109.Pad 1D PMSS <0 - 7150'>.,108,Pad 1D PMSS <291 - 5795'>,.125,Pad 1D PMSS <0-5047'>.,124.Pad 1D PMSS <290.6245'>.,116.Pad 1D GSS <0-175'>,.116,Pad 1D PMSS <287-6055'>..123,Pad 1D GSS <0-173'>,.123,Pad 1D PMSS <0 - 5445'>..122,Pad 1D PMSS <0 - 6580'>,,128.Pad 1D PMSS <0 - 7432'>.,127,Pad 1D PMSS <0 - 6716'>,.126,Pad 1D PMSS <0-4530'>.,120,Pad 1D PGMS <0-8070'>.,3,Pad 1D PMSS <0.4515'>,,119,Pad 1D PMSS <0-5462'>,,129,Pad 1D PMSS <O-4778'>.,130.Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <467 - 5802'>.,132,Pad 1D PGMS <0-9783'>.,2,Pad 1D PMSS <381-6092'>,,105.Pad 1D PGMS <0-8930'>,,5,Pad 1D PMSS <0-4590'>,,118,Pad 1D 139 <PMSS 515 - 4838'>,,139,Pad 1D PGMS <O-8610'>,,6,Pad 1D PMSS <O-11234'>,,11,Pad 1D PMSS <O-4414'>,,121,Pad 1D MSS <3311-8200'>,,7,Pad 1D 136 PMSS <519 - 5680'>,,136,Pad 1D 16 Wp2 Sperry,,136,Pad 1D PMSS <O-5205'>,,117,Pad 1D 141PMSS <O-9550'>,,141,Pad 1D 141L1PMSS<5475'-9480'>,,141L1,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D PMSS<377 - 6224'>,.134,Pad 1D PMSS <5155'- 5905'>,,110A,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <O-3252'>,,133PB1,Pad 1D PMSS <O-5126'>,,106,Pad 1D PGMS <O-8365'>.,1,PadlD PGMS <O-7502'>,,4,Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PMSS IFR <O-12225'>.,40,Pad 1D 32 Version #5,,32,Pad 1D PMSS <0- ???'>,,32,Pad 1D 140 SperryF,140,Pad 1D PMSS <3682-7663'>,,140L1,Pad 1D PMSS <5493-8117'>,,140,Pad 1D PMSS IFR <548-4120'>,,140,Pad 1D PMSS <4168-6156'>,,140PB1,Pad 1D 42 Version #1.,42,Pad 1D PMSS (IFR) <0-8660'>,,42,Pad 1D 40 PMSS IFR<O-12225'>,.40,Pad 1D 24-Apr-2000 2-Jun-1998 2-Sep-1998 22-Sep-1998 21-Sep-1998 29-Apr-1998 6-0ct-1999 21-Jan-2000 3-Sep-1998 2-2un-1998 28-0ct-1998 19-Aug-1998 2-Jun-1998 17-Sep-1998 8-Sep-1998 13-Sep-1998 4-Sep-1998 29-Aug-1998 17-Aug-1998 6-~u1-1998 1-Ju1-1998 2-Jun-1998 13-Aug-1998 2-Jun-1998 2-Jun-1998 2-~un-1998 23-Ju1-1998 6-Aug-1998 4-Aug-1992 2-Jun-1998 13-Nov-1997 2-~un-1998 18-May-2000 13-Nov-1997 30-Dec-1999 2-Jun-1998 6-Nov-1997 5-Jun-2000 5-0ct-2000 2-Jun-1998 6-Sep-2000 26-Sep-2000 24-Apr-2000 3-Aug-1998 17-May-2000 2-Jun-1998 21-Sep-2000 2-Jun-1998 10-Dec-1997 4-Aug-1992 2-Jun-2000 2-0ct-2000 3-Nov-2000 16-Nov-2000 20-Sep-2000 13-Nov-2000 13-Nov-2000 13-Nov-2000 13-Nov-2000 22-Sep-2000 6-Nov-2000 15-Nov-2000 )4458.2( )5996.5( )5895.4( )6136.1( )6145.8( )5395.9( )5647.7( )5503.2( )6099.6( )6041.0( )6289.5( )4396.5( )4641.2( )5896.2( )6412.5( )5422.5( )6309.5( )5592.7( )3644 9( )3826 2( )4645 8( )5000 2( )5332 4( )5218 3( )3076.7( )3410.2( )2538.1( )1691.0( )6014.7( )6215.2( )4779,9( )5732.2( )2871.1( )2236.2( )4254.8( )4311.7( )2965.6( )3387.3( )5852.8( )5879.6( )3260.5( )3390.1( )6220.5( )762.9( )6220.5( )1986.5( )3469.3( )5892.7( )5801.5( )5605.8( )1386.2( )0.0( )4506.6( )4389.7( )5305.7( )5314.4( )5314.4( )5314.4( )5314.4( )1701.9( )1698.6( )0.0( 692ii 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 7920.0 6921,5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 7920.0 6921.5 9740.0 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 8200.0 6921.5 9300.0 6921.5 6921.5 7580.0 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921,5 6921.5 6921,5 6921,5 6921,5 6921,5 6921,5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 11060.0 6921.5 10960.0 7920.0 6921.5 6921.5 6921.5 6921.5 692i.5 6921.5 6921.5 6921.5 6921.5 7920.0 Phillips Alaska, Inc. Pad 1D,40A Kuparuk River Unit,North Slope, Alaska Last revised : 15-Nov-2000 Reference wellpath Object wellpath : PMSS IFR <0-14324'>,,38,Pad 1D Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 7000.0 4264.9 4594.8S 51.5E 7173.0 4265.6 4270.6S 1207.2E 74.3 1200.3 7100.0 4310.0 4683.7S 44.8E 7222.4 4281.6 4315.5S 1220.4E 72.6 1232.2 CLEARANCE LISTING Page 2 Your ref : 40A Version #2 Ellipse Sep'n )963.2( )991.8( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 184.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,40A Kuparuk River Unit,North Slope, Alaska Reference wellpath CLEARANCE LISTING Page 3 Your ref : 40A Version t~2 Last revised : 15-Nov-2000 Object wellpath : PMSS <377 - 6224'>,,134,Pad 1D M.D. T.V.D. Rect Coordinates M.D. T.V.D. 7000.0 4264.9 4594.8S 51.5E 6224.0 4235.1 7100.0 4310.0 4683.7S 44.8E 6224.0 4235.1 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 3726.4S 246.7W 341.0 918.6 )833.7( 3726.4S 246.7W 343.1 1003.5 )923.9( RECEIVED AJaska Oil & Gas Cons. Commission Anchorage All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 184.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska. Inc. Pad 1D.40A Kuparuk River Unit. North Slope. Alaska CLEARANCE LISTING Page 4 Your ref : 40A Version#2 Last revised : 15-Nov-2000 Reference wellpath Object wellpath : PMSS IFR <O-12225'>..40.Pad 1D M.D. T.V.D. Hori z Min' m Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 7000.0 4264.9 7100.0 4310.0 7200.0 4360.7 7300.0 4411.7 7400.0 4462.6 4594.8S 51.5E 7000.0 4264.8 4594.8S 51.6E 135.6 0.1 4683.7S 44.8E 7099.8 4305.3 4685.9S 45.3E 169.3 5.2 4769.6S 36.9E 7199.3 4346.4 4776.3S 40.OE 155.5 16.1 4854.6S 23.9E 7298.4 4387.3 4866.4S 33.7E 140.2 28.8 4938.9S 6.5E 7397.3 4427.5 4956.4S 25.5E 132.6 43.6 75O0.0 4513.5 7600.0 4564.4 7700.0 4615.2 7800.0 4666.1 7900.0 4717.0 5023.1S 11.4W 7496.0 4467.7 5046.0S 17.3E 128.6 58.7 5107.3S 29.3W 7593.5 4506.0 5135.4S 8.9E 126.3 75.2 5191.5S 47.2W 7692.4 4544.3 5226.2S 0.5E 126.0 92.3 5275.7S 65.1W 7792.4 4583.9 5317.5S 8.5W 126.4 108.3 5359.9S 83.1W 7891.1 4623.7 5407.3S 17.5W 125.9 123.5 8000.0 4767.9 8100.0 4818.8 8200.0 4869.6 8300.0 4920.5 8400.0 4971.4 5444.1S 101.0W 7989.1 4662.0 5497.0S 27.3W 125.7 139.4 5528.3S 118.9W 8088.7 4700.9 5588.2S 37.4W 126.3 155.3 5612.5S 136.8W 8186.0 4739.2 5677.2S 47.0W 125.7 171.1 5696.7S 154.7W 8281.8 4775.9 5765.2S 55.5W 124.6 188.3 5780.9S 172.6W 8380.2 4813.7 5855.8S 62.9W 124.3 206.3 8500.0 5022.3 8600.0 5073.2 8700.0 5124.1 8800.0 5174.9 8900.0 5225.8 5865.1S 190.6W 8480.3 4852.9 5947.6S 69.5W 124.3 223.9 5949.3S 208.5W 8579.2 4892.4 6038.0S 76.2W 123.9 240.9 6033.5S 226.4W 8679.3 4932.8 6129.4S 82.6W 123.7 257.8 6117.7S 244.3W 8773.1 4970.6 6215.0S 88.7W 122.0 274.7 6201.9S 262.2W 8865.6 5005.9 6300.3S 94.2W 120.4 293.7 9000.0 5276.7 9100.0 5327.6 9200.0 5378.5 9300.0 5429.3 9400.0 5480.2 6286.1S 280.2W 8962.8 5041.8 6390.5S 99.7W 120.0 314.1 6370.3S 298.1W 9062.8 5079.2 6483.1S 105.1W 120.3 334.1 6454.5S 316.0W 9164.0 5118.0 6576.4S 110.6W 120.7 353.4 6538.7S 333.9W 9266.9 5158.4 6670.8S 116.4W 121.3 371.7 6622.9S 351.8W 9369.9 5199.9 6764.9S 122.7W 121.8 388.9 9500.0 5531.1 9600.0 5582.0 9700.0 5632.9 9800.0 5683.8 9900.0 5734.6 6707.1S 369.7W 9469.8 5241.0 6855.7S 129.0W 121.7 405.3 6791.3S 387.7W 9569.2 5282.4 6945.9S 135.0W 121.5 421.3 6875.5S 405.6W 9662.8 5320.3 7031.3S 141.3W 120.5 438.0 6959.7S 423.5W 9760.5 5358.9 7120.8S 148.1W 120.3 455.3 7044.0S 441.4W 9861.5 5399.0 7213.2S 155.3W 120.6 472.4 10000.0 5785.5 10100.0 5836.4 10200.0 5887.3 10300.0 5938.2 10400.0 5989.0 7128.2S 459.3W 9962.6 5439.8 7305.4S 162.7W 120.9 488.8 7212.4S 477.2W 10062.8 5480.9 7396.6S 168.9W 120.9 505.3 7296.6S 495.2W 10160.2 5521.4 7484.9S 175.0W 120.5 521.4 7380.8S 513.1W 10259.6 5562.1 7575.4S 181.8W 120.4 537.7 7465.0S 531.0W 10353.6 5600.3 7661.0S 188.5W 119.8 554.0 10500.0 6039.9 10600.0 6090.8 10700.0 6141.7 10800.0 6192.6 10900.0 6243.4 7549.2S 548.9W 10449.3 5638.3 7748.6S 195.0W 119.4 571.2 7633.45 566.8W 10547.6 5677.5 7838.5S 201.2W 119.3 588.7 7717.6S 584.8W 10647.3 5717.7 7929.6S 207.0W 119.3 606.2 7801.8S 602.7W 10752.7 5760.7 8025.6S 213.4W 119.9 623.0 7886.0S 620.6W 10856.2 5803.4 8119.6S 220.9W 120.3 638.7 11000.0 6294.3 11100.0 6345.2 7970.2S 638.5W 10952.0 5843.6 8206.3S 227.1W 119.9 654.4 8054.4S 656.4W 11053.4 588611 8298.1S 233.3W 119.9 670.2 Ellipse Sep'n )0.0( )0.0( )0.0( )0.0( )0.0( )0.0( )0.0( )0.0( )0.0( )0.0( )7.0(. )18.3( )31.2( )46.3( )61.0( )75.1( )89.0( )102.4( )117.1( )134.1( )151.6( )168.4( )184.1( )198.8(. )212.4( )225.5( )238.1( )252.2( )266.7( )280.6( )293,8( )306.9( )319.7( )332.8( )346.3( )360.7( )375.1( )389.1( )402.2( )414'.4( )4'26.8( )439.0( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~40 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 184.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc, Pad 1D, 40A Kuparuk River Unit,North Slope, Alaska Reference wellpath M,D, T,V,D, 7000.0 4264.9 7100.0 4310,0 7200,0 4360.7 7300,0 4411,7 7400.0 4462,6 75OO.0 4513.5 7600,0 4564,4 7700.0 4615,2 7800,0 4666,1 7900,0 4717.0 8000,0 4767,9 8100,0 4818,8 8200,0 4869.6 8300,0 4920,5 8400,0 4971,4 8500,0 5022,3 8600,0 5073,2 8700,0 5124,1 8800,0 5174,9 8900,0 5225,8 9000,0 5276,7 9100,0 5327,6 9200,0 5378,5 9300,0 5429,3 9400,0 5480,2 9500,0 5531,1 9600,0 5582,0 9700,0 5632,9 9800,0 5683,8 9900,0 5734,6 10000,0 5785,5 10100,0 5836,4 10200,0 5887,3 10300,0 5938,2 '10400,0 5989,0 10500,0 6039,9 10600,0 6090,8 10700,0 6141,7 10800,0 6192,6 10900.0 6243,4 CLEARANCE LISTING Page 5 Your ref : 40A Version#2 Last revised : 15-Nov-2000 11000,0 6294,3 11100,0 6345,2 Object wellpath : 40 PMSS IFR<O-12225'>,,40,Pad 1D Rect Coordinates M,D. T.V.D. 4594,8S 4683,7S 4769,6S 4854,6S 4938,9S 51,5E 7000.0 4264,8 44,8E 7099,8 4305,3 36,9E 7199.3 4346,4 23.9E 7298,4 4387,3 6.5E 7397,3 4427,5 5023,1S 5107,3S 5191,5S 5275,7S 5359.9S 11.4W 7496,0 4467,7 29,3W 7593.5 4506,0 47,2W 7692,4 4544,3 65,1W 7792,4 4583,9 83.1W 7891,1 4623,7 5444,1S 5528,3S 5612,5S 5696,7S 5780,9S lOl,OW 7989,1 4662,0 118,9W 8088,7 4700,9 136,8W 8186,0 4739,2 154.7W 8281,8 4775,9 172,6W 8380,2 4813,7 5865,1S 5949,3S 6033,5S 6117,7S 6201,9S 190,6W 8480,3 4852,9 208,5W 8579,2 4892,4 226,4W 8679,3 4932,8 244,3W 8773,1 4970,6 262,2W 8865,6 5005,9 6286,1S 280,2W 8962,8 5041,8 6390,5S 6370,3S 298,1W 9062,8 5079,2 6483,1S 6454,5S 316,0W 9164,0 5118,0 6576,4S 6538,7S 333,9W 9266,9 5158,4 6670,8S 6622,9S 351,8W 9369,9 5199,9 6764,9S 6707,1S 369,7W 9469,8 5241,0 6855,7S 6791,3S 387,7W 9569,2 5282,4 6945,9S 6875,5S 405,6W 9662,8 5320,3 7031,3S 6959,7S 423,5W 9760,5 5358,9 7120,8S 7044,0S 441,4W 9861,5 5399,0 7213,2S 7128,2S 459,3W 9962,6 5439,8 7305,4S 7212,4S 477,2W 10062,8 5480,9 7396,6S 7296,6S 495,2W 10160,2 5521,4 7484,9S 7380,8S 513,1W 10259,6 5562,1 7575,4S 7465,0S 531,0W 10353,6 5600,3 7661,0S 7549,2S 548,9W 10449,3 5638,3 7748,6S 7633,45 566,8W 10547,6 5677,5 7838,5S 7717,6S 584,8W 10647,3 5717,7 7929,6S 7801,8S 602,7W 10752,7 5760,7 8025,6S 7886,0S 620,6W 10856,2 5803,4 8119,6S 7970,2S 638,5W 10952,0 5843.,6 8206,3S 8054,4S 656,4W 11053,4 5886,1 8298,1S Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 4594,8S 51,6E 135,6 0,1 )0.0( 4685,9S 45,3E 169,3 5,2 )0,0( 4776,3S 40,OE 155,5 16,1 )0,0( 4866,4S 33.7E 140,2 28,8 )0,0( 4956,4S 25,5E 132,6 43,6 )0,0( 5046,0S 17,3E 128,6 58,7 )0,0( 5135,4S 8,9E 126,3 75,2 )0,0( 5226,2S 0.5E 126.0 92,3 )0,0( 5317,5S 8,5W 126,4 108,3 )0,0( 5407,3S 17,5W 125,9 123,5 )0,0( 5497,0S 27,3W 125,7 139,4 )7,0( 5588,2S 37,4W 126,3 155,3 )18,3( 5677,2S 47,0W 125,7 171,1 )31,2( 5765,2S 55,5W 124,6 188,3 )46,3( 5855,8S 62,9W 124,3 206.3 )61,0( 5947,6S 69,5W 124,3 223,9 )75,1( 6038,0S 76,2W 123,9 240,9 )89,0( 6129,4S 82,6W 123,7 257,8 )102,4( 6215,0S 88,7W 122,0 274,7 )117,1( 6300,3S 94,2W 120,4 293,7 )134,1( 99,7W 120,0 314,1 )151,6( 105,1W 120,3 334,1 )168,4( 110,6W 120,7 353,4 )184,1( 116,4W 121,3 371,7 )198,8( 122,7W 121,8 388,9 )212,4( 129,0W 121,7 405,3 )225,5( 135,0W 121,5 421,3 )238,1( 141,3W 120,5 438,0 )252,2( 148,1W 120,3 455,3 )266,7( 155,3W 120,6 472,4 )280,6( 162,7W 120,9 488,8 )293,8( 168,9W 120,9 505,3 )306,9( 175,0W 120,5 521,4 )319,7( 181,8W 120,4 537,7 )332,8( 188,5W 119,8 554,0 )346,3( 195,0W 119,4 571,2 )360,7( 201,2W 119,3 588,7 )375,1( . 207,0W 119,3 606,2 )389,1( 213,4W 119,9 623,0 )402,2( 220,9W 120,3 638,7 )414,4( 227,1W 119,9 654,4 )426,8( 233,3W 119,9 670,2 )439,0( All data is in feet unless otherwise stated, Casing dimensions are not included, Coordinates from slot ~40 and TVD from RKB(Nabors 16E) (106,00 Ft above mean sea level), Vertical section is from wellhead on azimuth 184,51 degrees, Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ Phillips Alaska. Inc. Pad 1D 40A slot ~0 Kuparuk River Unit North Slope, A1 aska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 40A Version#2 Our ref : prop4286 License : Date printed : 16-Nov-2000 Date created: lO-Nov-2000 Last revised : 15-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.035,w149 30 31.181 Slot Grid coordinates are N 5959129.177, E 560670.303 Slot local coordinates are 537.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS IFR <0-16053'>~,34,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <0-5354'>,.102PB1,Pad 1D PMSS <5181-6454'>,,102PB2,Pad 1D PMSS <6143-6767'>,,102PB3,Pad 1D PMSS <6527-7378'>,,102,Pad 1D L1PMSS <4338-7400'> Sperry,,lO2L1,Pad 1D PMSS <0-1288'>,,138PB1,Pad 1D PMSS <O-6543'>,,138,Pad 1D 37 Version O.i,,37,Pad 1D 41 Version~.a,,41,Pad 1D PMSS IFR <0-11660'>,,36,Pad 1D PMSS IFR <O-14324'>,.38,Pad 1D 39 Version O.c,,39,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. 23-0ct-2000 3794.8 6921.5 2-Jun-1998 4515.1 6921.5 28-Jul-2000 3169.1 6921.5 27-Jul-2000 2237.0 6921.5 27-Jul-2000 2034.5 .6921.5 28-Jul-2000 1621.0 6921.5 27-Jul-2000 1700.1 6921.5 l~-May-2000 5216.8 6921.5 18-May-2000 2672.7 6921.5 26-0ct-2000 3284.3 6921.5 10-0ct-2000 2499.7 6921.5 2-0ct-2000 2221.3 6921.5 2-0ct-2000 1175.7 6921.5 31-0ct-2000 2529.6 6921.5 Diverging from M.D. 6921.5 6921.5 6921.5 692i.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 PGMS <0-8850'> 28-May-81,,MP i 17-II-ii,Pad 1D 23-Apr-1999 PMSS IFR <O-12044'>,,30,Pad 1D 28 Version~/q,,28,Pad 1D PGMS <0 - 6400'>,,WS-8,Pad 1D PMSS <0 -7340'>,,lO,Pad 1D PMSS <4674'-5639'>,,125A,Pad 1D PMSS<O-5142'>,.l15,Pad 1D PMSS <0 - 6270'>,,114,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D PMSS <294 - 8250'>.,112,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0-8702'>,,14,Pad 1D PMSS <0-9250'>,,12,Pad 1D , 2-0ct-2000 2-0ct-2000 27-Apr-2000 28-Apr-1998 24-Apr-2000 2-Jun-1998 2-Sep-1998 22-Sep-1998 21-Sep-1998 29-Apr-1998 6-0ct-1999 21-Jan-2000 9772.9 6921.5 4084.7 6921.5 5362.8 6921.5 4399.5 6921.5 4075.6 6921.5 4706.0 6921.5 6040.5 6921.5 5927.5 6921.5 6169.5 6921.5 6178.1 6921.5 5435.5 6921.5 5686.6 6921.5 5616.6 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921,5 6921.5 6921.5 PMSS<0-7045'>,,111,I' 1D PMSS <0-4850'> ,109,~'~d 1D PMSS <0 ' 7150'>.,108,Pad 1D PMSS <291 - 5795'>,.125,Pad 1D PMSS <O-5047'>,,124,Pad 1D PMSS <290-6245'>..116.Pad 1D GSS <O.175'>,,116.Pad 1D PMSS <287-6055'>.,123,Pad 1D GSS <0-173'>,,123.Pad 1D PMSS <0 - 5445'>..122,Pad 1D PMSS <0 - 6580'>,,128.Pad 1D PMSS <0 - 7432'>.,127,Pad 1D PMSS <0 - 6716'>,.126.Pad 1D PMSS <0,4530'>.,120,Pad 1D PGMS <0-8070'>,.3.Pad 1D PMSS <0.4515'>,.119,Pad 1D PMSS <O-5462'>.,129,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <467 - 5802'>.,132,Pad 1D PGMS <O.9783'>,,2.Pad 1D PMSS <381-6092'>,,105.Pad 1D PGMS <O-8930'>,,5,Pad 1D PMSS <0,4590'>,.liS,Pad 1D 139 <GSS 0 - 475'>.,139.Pad 1D 139 <PMSS 515 - 4838'>.,139,Pad 1D PGMS <O-8610'>,,6,Pad 1D PMSS <0-11234'>,,11.Pad 1D PMSS <0,4414'>,,121,Pad 1D MSS <3311-8200'>,,7,Pad 1D 136 PMSS <519 - 5680'>,,136,Pad 1D 16 Wp2 Sperry,,136,Pad 1D PMSS <O-5205'>,,117,Pad 1D 141GSS <0 - 671'>,,141,Pad 1D 141 PMSS <0-9550'>,,141,Pad 1D 141L1PMSS<5475'-9480'>,,141L1,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS<245-5962'>DepthShifted,,110,Pad 1D PMSS <5155'- 5905'>,,110A,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <0-3252'>,.133PB1,Pad 1D PMSS <O-5126'>,,106,Pad 1D PGMS <0-8365'>.,1,Pad 1D PGMS <O.7502'>,,4,Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PMSS IFR <O-12225'>,,40,Pad 1D 32 Version #5,,32,Pad 1D PMSS <0- ???'>,,32,Pad 1D 140 Sperry,,140,Pad 1D PMSS <3682-7663'>,,140L1,Pad 1D PMSS <5493-8117'>,,140,Pad 1D PMSS IFR <548-4120'>,,140,Pad 1D PMSS <4168-6156'>,,140PB1,Pad 1D 42 Version #1,,42,Pad 1D PMSS (IFR) <O-8660'>,,42,Pad 1D 40 PMSS IFR<O-12225'>,,40,Pad 1D 3-Sep-1998 2-Jun-1998 28-0ct-1998 19-Aug-1998 2-Jun-1998 17-Sep-1998 8-Sep-1998 13-Sep-1998 4-Sep-1998 29-Aug-1998 17-Aug-1998 6-Ju1-1998 1-Ju1-1998 2-Jun-1998 13-Aug-1998 2-Jun-1998 2-Jun-1998 2-Jun-1998 23-Ju1-1998 6-Aug-1998 4-Aug-1992 2-Jun-1998 13-Nov-1997 2-Jun-1998 18-May-2000 18-May-2000 13-Nov-1997 30-Dec-1999 2-Jun-1998 6-Nov-1997 5-Jun-2000 5-0ct-2000 2-Jun-1998 lO-Aug-2000 6-Sep-2000 26-Sep-2000 24-Apr-2000 3-Aug-1998 17-May-2000 17-May-2000 2-Jun-1998 21-Sep-2000 2-Jun-1998 10-Dec-1997 4-Aug-1992 2-Jun-2000 2-0ct-2000 3-Novo2000 16-Nov-2000 20-Sep-2000 13-Nov-2000 13-Nov-2000 13-Nov-2000 13-Nov-2000 22-Sep-2000 6-Nov-2000 15-Nov-2000 6129.3 6072.8 6316.6 4662.0 4814.4 5946.8 6435.6 5594.6 6332.7 5676.0 3953.5 4110.8 4880.2 5083.6 5402.6 5290.5 3294.3 3519.2 2818.5 1878.5 6051.0 6244.7 4860.2 5763.2 5782.9 2959.7 2357:1 4430.8 4370.6 3130.2 3624.2 5893.9 5924.7 6200.1 3449.5 3509.3 6248.6 852.6 6248.6 6248.6 2051.3 3502.3 5925.0 5839.0 5646.5 1494.4 0.0 4721.8 4716.0 5351.7 5360.8 5360.8 5360.8 5360.8 1821.9 1818.4 0.0 692~ 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921,5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 11060.0 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 6921.5 creot.~ ~ ~ FOR: BROCKWAY Dote plotted: 24-Jul-2000 P~O( Referenc! il 40 Vision #1 . Coordinates are in feet ~e~e sl~ ~40 . Tree Ve~cal ~tht a~ rerer~ce R~(Nabom IS[) PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska RE E!VED 60 40 2O 20 40 6O 80 1 O0 12O 140 16O 18O 200 22O 140 120 100 80 60 240 26O 280 140 18OO 1200 30O 800 go0 1900 1000 ,/' ,./1600 / 900 // .,"~ 7oo / 1000 / / 1800 ,t 1201 1000 110C 1100 East (feet) -> 40 20 0 20 40 60 80 100 /'1'400 1400 1200 ,4%oo / 1100 120 100 80 60 40 20 -, 900 goo ~ 300 14oo 15db'-. lOOO 6O0 5OO O0 (~.5oo "~ 120o 500 "\,~ 1300 1600 ~, 1400 '\ '~ 15O0 1100 1600 1~00 2100 ~1,700 m,u,,a 07; & Ga~ Cons. c~mmi$$ion Anchorage 120 140 160 180 6O 40 1700 ',~ 1200 1700 1300 1800 ',,~ 1300 ', 1800 1400 20 20. 40 60 8O 1 O0 120 140 0 I v 16O 1200 1300 1300 i1800 22O0 ~ ~ 1900 16~140 0 20 40 60 East (feet) -> 80 100 120 140 160 ,180 200 240 260 280 180 c~,~ ~ ~,,e FOR: BROCK~AY Dote plotted: 25-Jul-2000 Caardlnot~ are ;n feet ~e~e 31~ ~40 . T~e Ve~c~ ~t~e are re~erence 200 60 120 PHILLIPS Alaska, Inc. Structure : Pad 1D Well: 40 Field : Kuparuk River Unit Location : North Slope, Alaska 8O East (feet) -> 40 0 40 80 120 160 200 240 · . 280 REC. AUG 0 2 AWs~a 0,, & Gas ~mmi~sJ0n 320 360 400 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 21 O0 / ; / I ; ! , ! ! / ./2300 ! ! I I I / I 2300 1500 2500 1900 1100 150 27OO 21 O0 1300 3oq ~ 1900 700 210C i ia0 ! ~ 2300 1~00 2900 200 160 120 80 40 0 40 80 120 2500 160 200 ,,,\, 1700 \ \ \'\'\\\ 1900 1700 2700 1900 700 '\ 240 280 320 2900 360 2100 1~00 400 200 240 280 320 360 400 440 480 520 560 600 640 680 72O 760 800 840 East (feet) -> . C~.oted ~ ,~,,e FOR: BROCKWAY Date plotted: 25.-Jul-2000 P~at Ref~enca ;I 40 Vemion ~1 . Coordinates are ;n f~t ~e~e ~ ~40 . Tree Ve~cal ~tha am reference R~(Nabor, 16E) 500 400 300 200 100 PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 0 1 O0 200 .300 4(; 500 600 ._ Anchorage 700 800 900 1000 700 2100 ! 800 / : , ! 900 I ! / 2900 1000 I / ; 230( ! / 1100 1200 1300 ! ! 1400 1500 1600 1700 3100 2500 1700 1900 2700 2300 ~ 2500 ' i ~, 3300 '", i \ \ \ 2500 ~ ~ 3700 xan~ ~' 2900 ~ 370( 27OD 3100 1800 2900 1900 12 3100 lO0 2000 [13100 2100 [ 13300 Il 2200 113500 2300 ~.~.j ~_~3700 ~ i i i I i i i i i i i i i i i i 500 400 300 200 1 O0 0 1 O0 200 300 400 East (feet) ->' I I i i i 500 600 700 2300 3300 ., i 800 900 1000 700 800 go0 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 P 'HILLIP S Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 1800 1200 1000 800 600 East (feet) -> 400 200 0 20C 400 600 1000 1200 /~sska Oi~ & Gas'* ' "' ' ' 1400 1600 1800 1800 2000 2200 2400 2600 2800 3000 ~ 3200 -I-- ~'~ 3400 I (- / 5100 ~ ,' 0 3600 I V 38oo 4000 4200 4400 4600 4800 5000 5200 / / 3900 2500 ,, I ~' 41 oo ! I ; I ? ¢300 ! ~.9oo / , ? 4500 / 4700 ! ! / 49O0 2100 2300 2500, 2700 2900 3100 3300 3500 3700 3900 4100 3100 3100 350C 2000 2900 4300 3300 3500 3700 3900 4100 j330C i 3500 I 1 3700 ! 13900 3100 3300 3500 3700 3900 4100 41 O0 I I I I I I I I I I I I L7 I I I I I I I I 1200 1000 800 600 400 200 0 200 400 600 800 4300 2900 2200 3700 ',,~ 3500 '\ 37( 3900 \ 2400 O0 26OO 2800 5100 5300 3000 5500 5700 3200 3400 4100 ] (1) ,,, 3600 .~_ 6500 4000 .4200 4400 4600 4800 5OOO I 41 O0 '\ 6700 3800 V ',. 4300 \ '.,. ~ ¢500 ' ,ioo' ,g oo ' ,go ' ,ioo c~,=<~ ~ ~=,e FOR: Dote plotted: P~ot Ref~ence il Coord~ot~ a~ ~n f~t ~e~e T~e Vm~c~ ~thl ~ reference 2800 2400 2000 1600 1200 3600 4000 4400 4800 5200 5600 6000 ~'~ 6400 ~-~ 6800 0 7200 I V 7600 8000 8400 8800 9200 9600 10000 ~'5500 /5700 ! 5900 / ¢ 61oo 6300 PHILLIPS Alaska, Inc. Structure : Pad 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 800 400 0 400 800 1200 1600 2000 4100 4300 4500 4 4700 14900 5100 5300 5500 670O 4300~ ~00 4500 4300 ,~ 4700 '~,, 4900 4500 ,,, 4700 490O 5100 \, ~ 53oo ~ 55oo 5700 5100 5300 .~s~,a 0~', ¢~ Ga~ Cons. ~Yh~{{~i~ ~¢horage 2400 2800 .3200 3600 3600 \"'\, 4000 '\ 4100 \, ,, . 4400 4800 5200 5600 k5900 6100 '\ ~63oo ~ 6500 6000 6400 .0 6800 7200 I 7600 V 57OO 5500 8000 5900 61oo i6300 57OO 5900 6100 84oo 8800 9200 9600 10000 1O4O0 2800 2400 2000 1600 1200 800 400 0 400 800 Easf (feet) -> 1200 1600 2000 2400 2800 5200 10400 3600 c~.t,~ ~ ~,,e FOR: BROCKWAY Dote plotted : 25-Jul-2000 Coord~notes ora ~n fee[ ~e~ce sl~ ~40 . Tee Ve~[col ~thl ere reference R~(Nabors 16E). ~ 700__.~ 500 © 33O PHILLIPS Alaska, Inc. Structure : Pod 1D Well : 40 Field : Kuparuk River Unit Location : North Slope, Alaska 340 TRUE NORTH 350 0 10 2O 900 1100 290 7O 28O 8O 270 -F soo 9O 260 1 O0 ,250 1500 0 1700 2~0 200 190 1300 3900 4300 170 160 150 900 150 2O 10 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY November 17, 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 1D-40A Surface Location: 537' FNL, 421' FEL, Sec 23, T11N, R10E, UM Target Location: 2122' FSL, 1050' FEL Sec. 26, T11N, R10E, UM Bottom Hole Location: 1945' FSL, 1088' FEL Sec, 26, Tl lN, FI10E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. submits this Application for Permit to Drill the development well KRU 1D- 40A Nabors Rig 16e will sidetrack 1D-40 and complete this well as an injector. Please utilize. documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1D, or hauled to an approved Prudhoe or GKA Class II disposal well. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Bill Raatz, Geologist 263-4952 (20 AAC 25.071) If you have questions or require additional information, please contact Todd Mushovic at 265- 6974 or me at 265-6434 in our Anchorage office. Sincerely, ,lames Trantham Drilling Engineering Supervisor Attachments cc: KRU 1D-40AWell File RECEIVED N.O¥ 2, 0 ?000 Gas ConS. Commission Anchorage Ame~c~n ~Frxpre§.s ® . Cas~! ~vance DATE Draft 191 ORDER OF~ 'f" -- -- // ~/ I~u~ b~ I~ P~nt 5y~ In~ Engkw~, ~b~o NOT VALID FOR AMOUNT OVER $1~ Payable at No~ B~k of Gnma Junc~o. - Dow~ow., N~%~DELIA BROWN '~'~.E,,,~7,:.V,,.~+aV"UJ.d.~ ,. . , . ': &O E. &DDL, O0~: ~, 5 ,,,O ;, ? 5DDDL, ~,q,'O &q ~ FIELD & POOL ~/'~'~/~:)~) INI'i~ CLASS ~~v//~r.~ /O..~/~..l' GEOL AREA -- ADMINISTRATION APPR DATE ,~Ix Ii. 1. Permit fee attached. 2. Lease number approl:;ri~t' .e~i~i~i '.~-"~i,':~/'.c'i-?~. ( i i 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ....... : .,. ....... 26. BOPE press rating appropriate; test to _~r,,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... dev~redrll ¢ serv vx wellbore seg ann. disposal para req~ UNIT# ~.2////_~ ~ ON/OFF SHORE N Y N Y..N N GEOLOGY APPR DATE l i, ANNULAR DISPOSAL35. 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Se is m ic analysis of shallow gas zones ............. p ~ ~ N 33. Seabed condition suwey (if off-shore) ........... ~ T~ 34. Contact name/phone for weekly progress repods [exp,~~ only] With proper cementing records, this plan APPR DATE (A) will contain waste in a suitable receiving zonei ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N Y N Y N GEOL~I3h': ENGINEERING: UIC/Annular COMMISSION: JMH ~ ~ Commentsllnstructions: O Z O c:\msoffice\wordian\diana\checklist (rev. 11/01//00) 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 simp!ify finding information, informati;3n 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 SRevision: 3 $ LisLib SRevision: 4 $ Mon Nov 12 13:45:05 2001 ld-40a.tapx Reel Header Service name ............. LISTPE Date ..................... 01/11/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. RECEIVED ,~ ,,,, Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/11/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Corament Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWD RUN 2 AK-MM-00291 P. SMITH F. HERBERT 1D-40A 500292296901 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 12-NOV-01 MWD RUN 3 AK-MM-00291 P. SMITH F. HERBERT 23 Tll Ri0 537 421 104.45 70.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 6978.0 2ND STRING 6.125 7.000 10559.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) UNLESS OTHERWISE NOTED. Page 1 ld-40a.tapx 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED., 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER- MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 5. MWD RUN 3 COMPRISED DIRECTIONAL, DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). THERE WAS NO SLIDING ON RUN 3 WITH THE DENSITY SENSOR OUT OF THE CASING (ERGO, NO SLDSLIDE). 6. DEPTH SHIFTING/CORRECTION IS WAIVED PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 1/30/01. 7. MWD RUNS 2 & 3 REPRESENT WELL 1D-40Ai WITH API# 50-029-22969-01. THIS WELL REACHED A TOTAL DEPTH OF ll,l10'MD/6359.90'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 11.5 PPG MUD SALINITY: 550-1400 PPM CHLORIDES FORMATION WATER SALINITY: 13,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY Page 2 PBU TOOL CODE RPX RPS RPM RPD GR FET ROP NCNT FCNT NPHI PEF RHOB DRHO $ # BASELINE CURVE FOR SHIFTS: START DEPTH 6934 0 6934 0 6934 0 6934 0 6942 0 6978 5 6978 5 10497 5 10497 5 10497 5 10512.5 10549.0 10549.0 CURVE SHIFT DATA (MEASURED DEPTH) ld-40a.tapx STOP DEPTH 11073 11073 11073 11073 11066 11073 11109 11038 11038 11038 11053 11053 11053 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 2 6934.0 MWD 3 10497.5 $ REMARKS: 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 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10568.0 11109.5 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD 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 Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS Min 6934 2 62 30 15 0 92 0 94 1 O1 0 43 0 14 15 54 130 41 15805.4 Max 11109.5 1222.27 481.48 1549.26 1773.52 2000 2000 88.81 49.71 862.54 36668.9 Mean Nsam 9021.75 8352 135.499 8263 140.537 8249 4.11287 8279 4.71248 8279 17.1138 8279 27.5657 8279 1.71069 8190 38.051 1082 264.855 1082 20898.3 1082 Page 3 First Reading 6934 6978.5 6942 6934 6934 6934 6934 6978.5 10497.5 10497.5 10497.5 Last Reading 11109.5 11109.5 11066 11073 11073 11073 11073 11073 11038 11038 11038 RHOB MWD G/CM 2.01 3.14 DRHO MWD G/CM -0.52 0.52 PEF MWD BARN 3.78 17.69 ld-40a.tapx 2.4626 1009 0.0989098 1009 7.55377 1082 First Reading For Entire File .......... 6934 Last Reading For Entire File ........... 11109.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 10549 10549 10512.5 11053 11053 11053 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6934.0 10524 0 RPS 6934.0 10524 0 RPD 6934.0 10524 0 RPM 6934.0 10524 0 GR 6942.0 10531 5 FET 6978.5 10524 0 ROP 6978.5 10568 0 $ LOG HEADER DATA DATE LOGGED: 13-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10568.0 TOP LOG INTERVAL (FT) : 6978.0 BOTTOM LOG INTERVAL (FT): 10568.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 57.6 MAXIMUM ANGLE: 66.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1757HWRG6 PBO1757HWRG6 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 Page 4 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHM_M) 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 Depth Units ....................... Datum Specification Block sub-type...0 ld-40a.tapx LSND 9.80 46.0 9.5 600 4.6 2.600 1.390 2.400 1.450 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 68.0 132.8 68.0 68.0 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 6934 2.62 30 15 0 92 0 94 1 01 0 43 0 14 Max 10568 1222.27 481.48 1549.26 1773.52 1865.01 2000 6.68 First Reading For Entire File .......... 6934 Last Reading For Entire File ........... 10568 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Mean 8751 145.285 142.607 3.62202 3.94551 4.47211 22.7676 0.695571 Nsam 7269 7180 7180 7181 7181 7181 7181 7092 First Reading 6934 6978.5 6942 6934 6934 6934 6934 6978.5 Last Reading 10568 10568 10531.5 10524 10524 10524 10524 10524 Page 5 ld-40a.tapx Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RPD RPX RPM FET RPS GR RHOB DRHO ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 10497.5 10497 5 10497 5 10512 5 10524 5 10524 5 10524 5 10524 5 10524 5 10532 0 10549 0 10549 0 10568 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11038 0 11038 0 11038 0 11053 0 11073 0 11073 0 11073 0 11073 0 11073 0 11066 0 11053.0 11053.0 11109.5 18-DEC-00 Insite 4.15 Memory 11110.0 10568.0 11110.0 57.2 58.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1760GR4/1756 EWR4 ELECTROMAG. RESIS. 4 PBO1760GR4/1756 SLD STABILIZED LITHO DEN PBO1760GR4/1756 CTN COMP THERMAL NEUTRON PBO1760GR4/1756 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.50 MUD VISCOSITY (S): 49.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1300 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 1.900 66.0 .990 132.3 1.400 66.0 Page 6 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 Depth Units ....................... Datum Specification Block sub-type...0 ld-40a.tapx 1.100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 OHMM 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 66.0 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 OHMM NPHI MWD030 PU-S FCNT MWD030 CNTS NCNT MWD030 CNTS RHOB MWD030 G/CM DRHO MWD030 G/CM PEF MWD030 BARN Min 10497.5 5 14 41 94 1 81 1 86 1 97 1 98 0.35 15.54 130.41 15805.4 2.01 -0.52 3.78 Max Mean Nsam 11109.5 10803.5 1225 133.6 70.621 1083 277.45 126.633 1069 1273.01 7.32309 1098 1524.32 9.72851 1098 2000 99.7911 1098 1875.15 59.1668 1098 88.81 8.26733 1098 49.71 38.051 1082 862.54 264.855 1082 36668.9 20898.3 1082 3.14 2.4626 1009 0.52 0.0989098 1009 17.69 7.55377 1082 First Reading For Entire File .......... 10497.5 Last Reading For Entire File ........... 11109.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Page 7 First Reading 10497.5 10568.5 10532 10524.5 10524.5 10524.5 10524.5 10524.5 10497.5 10497.5 10497.5 10549 10549 10512.5 Last Reading 11109.5 11109.5 11066 11073 11073 11073 11073 11073 11038 11038 11038 11053 11053 11053 ld-40a.tapx Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/11/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/11/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 8
