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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3 Subject:10-426 forms for 1L PAD witnessed and non-witnessed MITIA"s on 6-1-24 Date:Sunday, June 2, 2024 10:19:54 AM Attachments:image001.png MIT KRU 1L PAD 06-01-24.xlsx MIT KRU 1L-2 and 18 SI TESTS 06-01-24.xlsx FYI, Please see the attached 10-426 froms for the witnessed and non witnessed MITIA’s on 1L PAD on 6-1-24. If you have any questions or concerns, please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58/$ 37' non witnessed MITIA Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990370 Type Inj N Tubing 600 600 600 600 Type Test P Packer TVD 4456 BBL Pump 1.5 IA 43 1800 1740 1730 Interval 4 Test psi 1500 BBL Return 1.5 OA 20 20 20 20 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2160560 Type Inj N Tubing 1100 1110 1110 1110 Type Test P Packer TVD 5859 BBL Pump 1.7 IA 250 1810 1720 1700 Interval 4 Test psi 1500 BBL Return 1.6 OA 525 545 545 545 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 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 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: 1L-03A 1L-18A Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1L Pad Arend / Casey 06/01/24 Form 10-426 (Revised 01/2017)2024-0601_MIT_KRU_1L-pad_2wells 9 9 9 9 9 9 9 9 999 9 -5HJJ 1L-03A TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1L-03A 50-029-21182-01 199037_1L-03A_HEX Plug_17Jul2022 199037_1L-03A_RBP_03Apr2022 199037_1L-03A_WFL_04Jan2023 1L-28 50-029-22951-00 199098_1L-28_LDL_29May2022 1Q-01 50-029-21247-00 184231_1Q-01_IPROF_09Jan2023 1Q-05 50-029-21233-00 184217_1Q-05_HEX Plug_18Jul2022 1R-07 50-029-21332-00 185072_1R-07_LeePPROF_14Jan2023 1R-19A 50-029-22185-01 191085_1R-19A_SBHPS CUT_18Jun2022 1R-36 50-029-23057-00 201227_1R-36_IPROFWFL_30Jun2023 1Y-19 50-029-22391-00 193107_1Y-19_PPROF_26Mar2022 1Y-32 50-029-21854-00 188093_1Y-32_PPROF_27May2023 2A-14 50-103-20040-00 185145_2A-14_LDL_23May2023 2A-19A 50-103-20197-01 201083_2A-19A_CHC_20Feb2023 5of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38351 T38352 T38353 T38354 T38355 T38356 T38357 T38358 T38359 T38360 T38361 2/29/2024 1L-03A 50-029-21182-01 199037_1L-03A_HEX Plug_17Jul2022 199037_1L-03A_RBP_03Apr2022 199037_1L-03A_WFL_04Jan2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:38:59 -09'00' Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field &Processed 7ͲJanͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-28_22079_KRU_1L-03A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 22079 KRU 1L-03A 50-029-21182-01 Caliper Survey w/ Log Data 28-Feb-23 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 By Samantha Carlisle at 7:49 am, Aug 31, 2022 5HJJ-DPHV% 2*& )URP %URRNV3KRHEH/ 2*& 6HQW :HGQHVGD\$XJXVW 30 7R 0RUDOHV7RQ\ &F 5HJJ-DPHV% 2*& 6XEMHFW 5( (6.58/%23(7HVW $WWDFKPHQWV 1DERUV(65HYLVHG[OV[ dŽŶLJ͕ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĂĚĚŝŶŐƚŽǁĞůůŶĂŵĞ<Zhϭ>ͲϬϯďĂƐĞĚŽŶWdηϭϵϵϬϯϳϬĂŶĚĐŚĂŶŐŝŶŐƚŚĞηϯZĂŵƐƚĞƐƚ ƌĞƐƵůƚƚŽ͞Ed͟ďĂƐĞĚŽŶƚŚĞƌĞŵĂƌŬƐ͘WůĞĂƐĞƵƉĚĂƚĞLJŽƵƌĐŽƉLJŽƌůĞƚŵĞŬŶŽǁŝĨLJŽƵĚŝƐĂŐƌĞĞ͘ dŚĂŶŬLJŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůLJƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗DŽƌĂůĞƐ͕dŽŶLJфdŽŶLJ͘DŽƌĂůĞƐΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂLJ͕:ƵůLJϯϭ͕ϮϬϮϮϯ͗ϯϴWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗E^<ZtKDфŶƐŬƌǁŽ͘ĐŵΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ZĞ͗ϳ ^<Zhϭ>ͲϬϯKW dĞƐƚ dŚŝƐŝƐƚŚĞĐŽƌƌĞĐƚƌĞƉŽƌƚ͘ dŚĂŶŬLJŽƵ &ƌŽŵ͗DŽƌĂůĞƐ͕dŽŶLJфdŽŶLJ͘DŽƌĂůĞƐΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂLJ͕:ƵůLJϯϭ͕ϮϬϮϮϯ͗ϭϴWD dŽ͗ũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖K'͘/ŶƐƉĞĐƚŽƌƐΛĂůĂƐŬĂ͘ŐŽǀфK'͘/ŶƐƉĞĐƚŽƌƐΛĂůĂƐŬĂ͘ŐŽǀх͖ ƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗E^<ZtKDфŶƐŬƌǁŽ͘ĐŵΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖,ĞŶƐŽŶ͕:ĂŵĞƐф:ŝŵ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх͖ŽnjďLJ͕<ĞůůLJ ф<ĞůůLJ͘ŽnjďLJΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ϳ ^<Zhϭ>ͲϬϯKW dĞƐƚ &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .58/$ 37' dŽŶLJDŽƌĂůĞƐ ϳ ^ZŝŐDĂŶĂŐĞƌ EKZ^>^<Z/>>/E'/E͘ KĨĨŝĐĞϵϬϳϲϳϬͲϲϭϯϮDŽďŝůϴϬϱϳϵϳͲϲϳϮϬ ƚŽŶLJ͘ŵŽƌĂůĞƐΛŶĂďŽƌƐ͘ĐŽŵ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:7ES DATE: 7/31/22 Rig Rep.: Rig Phone: 670-6132 Operator: Op. Phone:670-6130 Rep.: E-Mail Well Name: PTD #11990370 Sundry #322-389 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1633 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T 90 P Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2 7/8" x 5"NT H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8" Gate P Inside Reel valves 0NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2 1/16" Gate P Time/Pressure Test Result System Pressure (psi)3150 P CHOKE MANIFOLD:Pressure After Closure (psi)1650 P Quantity Test Result 200 psi Attained (sec)20 P No. Valves 16 P Full Pressure Attained (sec)104 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 5 @2020 psi P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.5 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 7-28-22 11:53AM Waived By Test Start Date/Time:7/30/2022 21:00:00 PM (date) (time)Witness Test Finish Date/Time:7/31/2022 1:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Annular tested 3 1/2" test joint. 4 1/2" & 3 1/2" test joint tested on UVPR. Note: lower pipe rams not tested on any size joint. Tony Morales / Paul Yearout ConocoPhillips Kevin Barr / Dale Rowell KRU 1L-03A Test Pressure (psi): nskrwo.cm@conocophillips.com Form 10-424 (Revised 02/2022) 2022-0731_BOP_Nabors7ES_KRU_1L-03A 9 9 9 9 9 999 9 9 9 9 9 9 -5HJJ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1L-03A KUPARUK RIV UNIT 1L-03A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 1L-03A 50-029-21182-01-00 199-037-0 W SPT 4456 1990370 1500 1240 1240 1240 1240 460 600 600 600 INITAL P Guy Cook 8/21/2022 MITIA post CTD initial test. Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 1L-03A Inspection Date: Tubing OA Packer Depth 620 2010 1960 1955IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220821062047 BBL Pumped:0.9 BBL Returned:0.9 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 MITIA post CTD initial test. James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 13:57:36 -08'00' ! " # $! % " & ' $ (" " ) *$ +, *# - # ./$ 0/ 1 $ $ " # # ! 2 ,2 3 $ 4* 56 $ 7 8&5 7 * 9*5 7 * :*5 7 + #* 9* + #* :* 9 5 7 59*7 ; <59*7 0404=$ " 6 "*6 < : < :9*5 7:*5 7 ' - " !< * > < +, *# # (+ * ) !< " /6 /$; * 6 .:# * ? ? ? 6@? ?"" #?/$; ! 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ProActive Diagnostic Services, Inc. WELL LOG TRANSM1 TAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Injection Profile 1J9037 31309 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MITT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) LeaKF OInt l" 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVED Attn: Diane Williams 130 West International Airport Road OCT 0 9 2019 Suite C n OGCC Anchorage, AK 99518 /"� l� Pdsa nchorageCa-Dmemorvlog.com 50-029-21182-01 Date : v" P PROACTIVE DIAGNOSTIC SERVICES, INC., 130W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEO-MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM https.,.readcasedholemyshampcintcomperconal/diene williams_readcasedhole comDocuments/D Drive/AchiveslMasteffemplatepiles/Templates/DistribmioMransmittalSheete;ConocoPhillips_Tmnsmicdoav WELL LOG TRANSMITTAL #9053886143 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Packer Setting Records: 1L -03A Run Date: 8/4/2019 19 90 37 3 120 4 September 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1L -03A Digital Data in LAS format, Digital Log file RECEIVED 1 CD Rom 50-029-21182-01 SEP 12 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@haHiburton.com Date: 9 I „ zo� Signed: SOF Tk • 0).." /7- s� THE STATE Alaska Oil and Gas ���?���� Of Conservation Commission=��___ LAS�; CommissionP 333 West Seventh Avenue =�"= GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Off,ALFax: 907.276.7542 www.aogcc.alaska.gov Jason Burke � � 0 2.51$Staff Wells Engineer so�0) ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-03A Permit to Drill Number: 199-037 Sundry Number: 317-538 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ea2C, Hollis S. French �� Chair J DATED this \ day of December, 2017. RBDPJis L,'—C: U 5 2017 r • WIRIVElit • STATE OF ALASKA 1010i 'qac .Pili , ALASKA OIL AND GAS CONSERVATION COMMISSION t 1.t 17 APPLICATION FOR SUNDRY APPROVALS r 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing LI Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Injection string installation0. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 199-037 3.Address: Stratigraphic ❑ Service 0 . 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21182-01 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 L-03A ` Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25659 • Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,979' ' •6,255' i 7912 , 6193 1812 / NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 62' 16" 93' 93' Surface 2,040' 9 5/8 2,071' 1,897' Production 6,034' 7" 6,063' 4,579' Liner 1,730' 4 1/2 7,572' 5,911' CTD Liner 1,014' 3.188 7,979' 6,255' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): 7775-7795,7813-7843,7835- 6080-6095,6110-6134,6128- 4.500" L-80 5,849' 7870 ' 6157 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=PARAGON 11 PACKER W BULLNOSE MD=5886 TVD=4477 PACKER=BAKER C-ZXP LINER TOP PACKER ' MD=5856 TVD=4456 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 • 14.Estimated Date for 12/15/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Di WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com Authorized Signature: Date: /// / Contact Phone: (907)265-6097 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/7 Plug Integrity ❑ BOP Test El Mechanical Integrity Test V Location Clearance �/j Other: Post Initial Injection MIT Req'd? Yes No 1=1RBDs�flS I (� ,v 0 0017 Spacing Exception Required? Yes Li No wr Subsequent Form Required: I D— 4 v '- l� Approved by: C422Cir COMMISSIONER APPROVED BY THE COMMISSION Date: (Z (4 It A 1 5- v/r/rS7_1112 ft,/� 1�"1��` lI `( � 07 ORIGINAL Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the daroyal. Attachments in Duplicate • • 0 0 b 0900 C6 a� 0 0. U iO ‘g i0 � 0 2 o V 0 O N cco M O U p Q V as N 0 co CH O Ln0- > H "- 0co 0 U 0) H O E w O O iO , W Z co i J co ; 1:- co', C Q 2 °' m N U © 1 o CI) N •C U ' Y I— O 3H U C 0 U a N Y Y .0 •CM-0 COCOo COos F.',, -:-J T C i ' i ,,,,, • • L 7 , L W MA c A el c ' a 2 o?oJ I t .i � N p V (Q N (D I OOL NOd NLN -o co C CO V n ii. iN 0 O L3 0 Q r v N Y N -,0 . *M f6 co MO gig r0 S D c, O dgt 2 ib-•N 0S j g Ua th a_ LL) a C12 dU N d I O ci -„, KUP • (Attributes 1 L-03A ConocoPhillipsj •„Ile&rI To Wellbore APIIUW I Fled Name Well Status Incl() MD I RS) Ad Btrn(TIKE) 500292118201 KUPARUK RIVER UNIT !NJ 54.98 2,500.00 7,979.0 ... Comment825(PPM Date Amdaxon End Date Ks<ad lit) Rig Release Date WNI(mat I OTA wAdvai zs z)nM I ,_SSSV.NIPPLE Last WO: 11/711999 34.80 9/21/1984 SGlemailc-Ad�ml Am6tat1011 Depth) End Date Annotation Last Mid By End Date Last Tag: 6.951.0 8/26120/0 Rev Reason TAG Imosbor 9/72010 Casing Strings String OD String ID set Depth Set Depth(TVD) String WI String i--- Casing Description (fry tin) Top MKS) Ire%) (IWB) Imam) Grade String Top Thrd ( (CONDUCTOR 16 15.062 0.0 93,0 93.0 62,58 H-40 WELDED SURFACE '----9 5/8 8.800 0.0 2,07)0 1.897.5 36.00 J-55 BTC CONDUCTOR, PRODUCTION 7 6.151 0.0 6,0)8.0 4,570.8 26.00 J-55 BTC 93 LINER TOP 412 3958 5943.0 7.572.0 5,910.8 12.60 L-00 'NSCT WINDOWA 412' 3.188 6.011.0 6.019.0 4,571.6 12.60 L-80 ' CTD LINER 33/16 2.800 6,965.0 7,979.0 620 L-80 TCI( NIPPLE.526 Tubing Strings rig OD smog ID Set Depn Set Depth(My string Wt String Tubing Descriseion (1N Ml Top IRKS) (EKB) (EKB) MUM Cade String Top Dad TUBING 412 3958 0.0 5.843.0 44467 12.60 L-80 BTC-MOD Other In Hole(All Jewelry:Tubing Run&Retrievable,Fish,etc.) SURFACE, Top Depth 1TVD) T Ind 2071 Top IRO) 1M) Top 1 Desonpdon Comment Run Date K3(IM 526 526.0 0.93 NIPPLE CAMCO DB NIPPLE 5/23/1999 3.875 I _5.797 4.414.0 45.05 SLEEVE-C BAKER CMU SLIDING SLEEVE 5/23/1999 3.812 5.857 4,456.5 45.12 PACKER BAKER C2 ZXP LINER TOP PACKER 523/1999 3.937 SLEEVE-C. 5,191 ' 6,965 5,367.9 30.71 DEPLOY DEPLOYMENT SLEEVE 5/23/1999 3.000 __ 7.911 6.192.1 26.42 COLLAR LANDING COLLAR ---- 523/1999 3.000 • � Perforations&Slots I Shot Top(TVD) 9511 150) Penn Dae Top(8MKS)KB)Bim KB) 1 ) (BErn E) ZoIain.. Tar 'type Coned 7.775 7.795 4082.1 6.096.3 A-5 1 L-07A 11/2611999 60 IPERF r HC,PJ.DP,60 deg phasing 7,813 7.843 6.109.9 6,133.9 A-4,1 L-03A ... 11/28/199960(P ERF 2'HC,PJ,DP,60 deg phasing ' 7.835 7.870 66..112/7 9 6.156.9 A-4.IL-03A 11/28/1999 6.0 IPERF THC,PJ,DP.60 deg phasing I'A�:KER_5857 Notes:General&Safety End Date Annotation11/5/1999 NOTE:WELL SIDETRACKED 8 WORKOVER 'ITODUCTION sale I WINDOW A. l E 919 I i'EPLOY,6,ae5fill '.(NEP TOP ',572 WERE, I 775.7,195 I W78e3ERE 181? I WERE. ]836-1871 I I ,:OILAR,1.5,1 __..._ CTD LINER, 1979 7 979 • • ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska 1L-03 Injection String Installation (TBD) Engineer: Jason Burke Wells Engineer 907-231-4568 1L-03 is an A-sand injection well that has multiple tubing leaks and has been off line since September 2010. In December of 2015 a paragon packer was set and the well passed a CMIT to 2500 psi. The goal of this job is to retrieve the paragon packer and clean out the tubing. Then a Weatherford WidePack straddle packer with 5800' of 1.5" CT will be set to return well to injection. i Objectives: Perform CMIT, fish packer, clean out the tubing and set 1.5" CT injection string and return to injection • Slick-line: Run CMIT testing tool and test to 2500 psi then fish Paragon packer • Coiled Tubing: Clean out well and set CT injection string 1. MIRU slick-line. (Min ID is 3.5" @ 5840' MD) 2. RIH with CMIT testing tool to Paragon Packer set at 5886' MD 3. Perform CMIT to 2500 psi (last passing was 12/27/15), POOH 4. MU packer retrieval tools and retrieve Paragon packer at 5866' MD 5. POOH, and RDMO slick-line 6. MIRU 1.5" CTU 7. MU following BHA: a. CT Connector b. DFCV c. 5 port wash nozzle 8. RIH pumping slick diesel. Perform FCO down to 6950' MD. Pump a gel sweep and a full well bore volume. Flag the pipe at 5866' MD. POOH 9. Begin prepping the Weatherford Widepack SLE straddle a. Ensure proper amount of shear screws have been installed in the setting piston and release piston. b. Apply Lubriplate grease to the Packer seal bore. c. Slide the Packer up over the ball seat until the threads in the Packer mandrel engage the threads on the release collect of the EHST. Make up the Packer to the EHST with 3.5 rounds of left hand until the Packer mandrel shoulders against the EHST mandrel—DO NOT OVER TIGHTEN November 3, 2017 1L-03 Well Work Procedure Page 1 of 5 • • ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska d. Thread the EHST setting sleeve down to engage the Packer setting sleeve. Tighten set screw in EHST setting sleeve to prevent back off. e. Ensure calculations for the downhole pressures required at the EHST have been completed before the run starts. 10. MU the following BHA a. CT Connector—External Dimple Connector b. Motor Head Assembly c. Crossover d. Ball Lock Circ Sub e. E-Hydraulic Setting Tool f. 3.66 Widepack SLE Packer 11. Open wellhead and run in hole at a maximum of 50ft/min and reduce the running speed to 10 ft/min passing thru restrictions. 12. Perform weight check every150 ft and record the weight. 13. Once CT reaches 50ft above the previous correlation flag depth(5866' MD),perform weight check and record weights. 14. Continue to run in hole until 5886' MD. 15. Pull out of hole until packer reaches 5866' MD and stop. 16. Launch 5/8" ball 17. Start pumping at 1.0 BPM and carefully until 5bbl below real volume, then slow to .5 BPM till ball lands and pressure increases 18. Pressure up in stages to 900psi at the EHST and stop pumping. DO NOT BLEED OFF THE PRESSURE. This pressure will set the packer slips. 19. Set down 15001bs to confirm the slips are set. 20. Pick up 10001bs over last known hanging weight and hold tension while pressuring up to 2350psi at the tool to fully set the packer. DO NOT BLEED OFF THE PRESSURE 21. Slack off on the coiled tubing to neutral weight before continuing to pressure up to 3350psi at the tool to release from the packer. You may RIH and set down 10001bs to confirm the packer is set at this time. 22. POOH to surface and break out BHA. 23. MU the following BHA a. CT Connector—External Dimple Connector b. Yo-Yo Valve c. 36 RS Anchor Assembly with Pump out plug November 3, 2017 1L-03 Well Work Procedure Page 2 of 5 • • • ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska Note: At this stage, the Pump out plug will create a closed system in the coiled tubing, a pressure of 1000psi,will burst the plug. Do not break circulation while running in hole 24. Stab on injector and pressure test the riser quick test sub as per SLB procedures. 25. Open well head and run in hole at 50 ft/min and reduce the running speed to 10 ft/min passing through restrictions. 26. Run in hole with coiled tubing string until complete length of coil needed to connect the two packers is achieved 27. Record all parameters such as WHP, CT hanging weight, run in hole weight and pick up weight. 28. Close in lower BOP pipe/slip rams and perform pull test and inflow test. 29. Upon successful inflow test of the lower pipe/slip rams, close in upper pipe/slip rams and inflow test same—this will ensure barriers from the well on the outside of the coiled tubing. 30. Open the coiled tubing at the back of the reel and inflow test the pump out Sub integrity. 31. Open the injector chains 32. Break the riser at the lower quick test and jack up to give the maximum working window. Note: during this process, the coiled tubing supervisor should monitor the weight indicator to ensure free movement of the injector head over the stationary coiled tubing. 33. Once maximum work window is achieved, close the injector chains to grip the coiled tubing again and attach the remote coiled tubing cutter to the coiled tubing as close to the top of the work window as possible and cut the coiled tubing. (Advised to give enough length to re-head the CTC in the event of a leak) Note: during this process, no personnel should be around the area where the coiled tubing is being cut. 34. Cut off the flat ends of the coiled tubing, using the manual tubing cutter, to get back a proper round shape for making up connectors. 35. Prepare the end of the coiled tubing protruding through the BOP's and install the External dimple preparation tool and dimple the Coil. 36. Drift Dimpled CT with 1.062" Drift ball rod. To ensure the Yo-Yo activation ball will Pass 37. Install External Dimple connector to the prepared Coil Tubing and Lock tight the Grub screws in Place. 38. Pressure test External Dimple Connector via test port between 0-rings to 500psi for 5 minutes and 5000psi for 10minutes. November 3, 2017 1L-03 Well Work Procedure Page 3 of 5 • S ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska 39. Run in with the coiled tubing until the end of the coiled tubing work string is visible out of the bottom 40. Make up coiled tubing end connector to the CT and pull test to 20,0001bs. 41. Make up the following BHA, up to the packer a. CT Connector- External b. Motorhead Assembly(MHA) c. Swivel d. Crossover e. Eclipse Hydraulic Setting Tool(EHST) f. Upper WidePakTM SLE packer (upper) Lower Section g. External Dimple Connector h. 1.5 Coiled Tubing 5830' 42. Skid injector back over well center and run in with the coiled tubing until the end of the packer is visible in the window. 43. RIH with CT and make up the packer to the External Dimple Connector. 44. Open the injector chains and Trolley down injector to stab the riser onto the well at the lower quick test sub. Note: during this process, coiled tubing supervisor should monitor the weight indicator to ensure free movement of the injector head over the stationary coiled tubing. 45. Once stabbed, close the injector chains and pressure test at the quick test sub. Note: No pressure test of stack can be performed at this stage. 46. Upon successful test, pick up on the coiled tubing to the weight equivalent to the hung pipe weight(-10,800 lbs) 47. Open the upper pipe/slip ram and monitor weight. 48. Open the lower pipe/slip ram and monitor weight 49. Once all weights and pressures are stable, run in hole. 50. Slowly RIH onto Lower Packer at 10 ft/min when CT is approximately 50 ft above lower packer. Note: The upper packer should be set at-36' MD 51. When CT tags Lower Packer, Slack off 2000 lbs at the tool and wait 10 mins 52. Pick up 20001bs max at the tool to ensure seal assembly is latched on and then return to neutral weight for setting the upper Widepak Packer. November 3, 2017 1L-03 Well Work Procedure Page 4 of 5 ID • ConocoPhillips Alaska, Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska Note: The seal assembly will be set to release at 5000 lb. Packer release will be set to release at 10000 lb. 53. Start pumping at 1.5 BPM until unit 5 bbls minus real volume, then slow pump to .5 BPM. 54. Pressure up in stages to 900 psi at the EHST and stop pumping. DO NOT BLEED OFF THE PRESSURE. This pressure will set the packer slips. 55. Set down 15001bs to confirm the slips are set. 56. Pick up 10001bs over last known hanging weight and hold tension while pressuring up to 2350psi at the tool to fully set the packer. DO NOT BLEED OFF THE PRESSURE 57. Slack off on the coiled tubing to neutral weight before continuing to pressure up to 3350 psi at the tool to release from the packer. You may RIH and set down 10001bs to confirm the packer is set at this time. 58. POOH to surface and break out BHA 59. Line up to rupture pump out plug at 4500 psi Recent Well Events 12/22/2015 RAN 2.23"CENT W/ 1.5" SAMPLE BAILER.S/D @ 7412'SLM,WORKED THRU.S/D @ 7445' SLM.UNABE TO GET ANY DEEPER.RECOVERED BAILER FULL OF FORMATION SAND. RAN 1.80" CENT WI 1.5" SAMPLE BAILER.S/D @ 7424'SLM,UNABLE TO GET ANY DEEPER.MADE 30 MINUTE STOP @ 7467'RKB BHP=2730 PSI/142.2 DEGF.MADE 15 MINUTE STOP @ 7357'RKB BHP=2672 PSI/142.2 DEGF.BAILER FULL OF FORMATION SAND. JOB IN PROGRESS.... 12/23/2015 RAN 3.44" CENT W/2'X 1 7/8" STEM W/2.50"GAUGE RING.S/D @ 5071'SLM.UNABLE TO GET ANY DEEPER. RAN 2.25"X 1 1/2" STEM W/2.37"GAUGE RING.S/D @ 5071'SLM.UNABEL TO GETANY DEEPER. RAN 1.80"CENT,3'X 1 1/2" STEM W/ 1.75"GAUGE RING.S/D @ 5071'SLM.UNABLE TO GET ANY DEEPER.LRS CAME ON LINE @ MINIUM RATE,TBG PRESSURE CAME UP TO 1750 PSI THEN PRSSURE FELL OFF INSTANTLY.RETAGGED @ 509 1'SLM,WORKED DOWN TO 5750'SLM.RAN 1.90"CENT W/2.5"BLB&2.25"GAUGE RING.S/D @ 5700'SLM,WORKED DOWN TO 6100'SLM.RAN 3.5" BLB W/2.50"GAUGE RING.DRIFTED DOWN TO 6100'SLM. RAN 4.5"BLB W/3.50"GAUGE RING.DRIFTED DOWN TO 6100'SLM. JOB IN PROGRESS... 12/24/2015 RAN 3.805" GAUGE RING W/4.5"BLB&3.70" GAUGE RING.BRUSH&FLUSHED DOWN TO 6050'SLM. SET 3.75" SOS PARAGON II PACKER(set#cpp45003)W/EQZ DEVICE(ser#cpeg45001)W/ JUNK DEBRIS EXTENSION @ 5886'RKB. WELL READY FOR CMIT&DRAWDOWN TEST. 12/27/2015 CMIT TO 2500 PSI-PASSED,BLED TBG AND IA DOWN TO 0 PSI JOB COMPLETE November 3, 2017 1L-03 Well Work Procedure Page 5 of 5 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. l C~c~' O3'TFile Number of Well History File PAGES TO DELETE RESCAN Ior items - Pages: ayscale, halftones, pictures, graphs, charts - Pages ~;~/~'~,~ [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds Other Complete COMMENTS: Scanned by: Beved~incent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 10:53 AM sLANNEr3 JAN 2 0 2011 To: NSK Well Integrity Proj Cc: 'NSK Problem Well Supv' Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 l CQ All, � I am continuing to review the December Monthly Injector report. I am through a total of 13 wells. I wanted to send this latest message due to what I have found or not found on 1 Q -02B. As I continue to work through the report, I plan to send interim messages as I get 7 - 10 new wells reviewed. Call or message with any questions. 13. 1Q-02B — Well name is 1 Q -02B. Well last injected 9/10. I do not show having received any specific notification /request in June, 2010 regarding this well. There is an email in the file from 4/20/10 reporting diagnostics accomplished to that time containing a statement that you intend to return the well to injection and remove it from the waiver report in May. 12. 1 L -05 — AA 2B.054 issued 10/22/2010. Well last injected 9/10 11. 1 L -03A — Well name is 1 L -03A. Permit to Drill # is 199 -037. MITIA failed 09/25/2010. Well last injected 9/10. 1 s . 1G-01 — AA 2B.035 issued 7/30/2008. 9. 1 F- A - Well name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have passed since. last injected 4 •07. AA 2B.018 was issued in October 2007, but no injection has occurred into the well. •oking at the pressure p • , it is shown that the IA pressure appears to have been bled off in October and - +ember. Was there well work co -.ucted, maybe plug setting? There is email traffic exchanged regarding " at if" for an OA pressure sensor. Su • have been installed on other wells, is that possible here? What ar- e plans for the well? 8. 1D-40A—Well name is 4 -40A. MITIA failed - 10/1/2009. Well last injected 9 7. 1D-119 — Single casing well. IA failed 7/16/2010. Well last injected 010. 6. 1 D -106 — Single casing well. MITIA fa' -d 7/16/2010. Well last i . -cted 6/2010. Comments on the sheet indicate you have located the deep leak. 5. 1C-133 — Single casing well. MITIA failed 5/21/ : 0. ell last injected 5/2010. 4. 1 C -10 — AA 2B.036 issued 8/25/2008. From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11: AM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhilli • Monthly Injector Report - Dec 2010 Martin, et al, I am conductin.. review of December's Monthly report. I have just gotten started and wanted to • -ss back the comments /. •stions I am developing. I also am .oing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. -ve only edite. e 1A -07, 1A -12 and 1B -02 in the attached spreadsheet. The edits are highlighted in yellow. Can t' : e 1/4/2011 • • 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. 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 • 0 ConocoPhillips Well 1L-03A Injection Data • Tbg Psi IA Psi • OA Psi I 4000 - 3500 - 3000 - y 2500 ••••• O. • a 2000 - • • • . ••• • • • • • • • • ••. • • 1500 - • • • • • • • 1000 - • • • • • • • 1 500 - • • • •• • •• • • • ~••• 0 09/10 10/10 11/10 12/10 01/11 Date `s J PTD# 199 -037 TxIA Communication, Failed MITIA Well last injected 09/10 09/25/10 - Failed MITIA 09/27/10 - LDL identified possible tubing leak at 1133' 11/27/10 - Caliper Survey indicates poor tubing condition • • ConocoPhillips Well 1 L -03A Injection Data \ • Water Injection *Gas Injection I 4000 3500 - 3000 - .° 2500 a a: 2000 1500 1000 500 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 Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 31- Dec -10 0 0 345 625 20 30- Dec -10 0 0 278 625 20 29- Dec -10 0 0 261 625 20 28- Dec -10 0 0 260 625 20 27- Dec -10 0 0 264 625 20 26- Dec -10 0 0 313 625 20 25- Dec -10 0 0 385 625 20 24- Dec -10 0 0 409 600 50 23- Dec -10 0 0 167 600 50 22- Dec -10 0 0 643 600 50 21- Dec -10 0 0 1109 650 25 20- Dec -10 0 0 855 650 25 19- Dec -10 0 0 462 650 25 18- Dec -10 0 0 389 650 25 17- Dec -10 0 0 411 650 25 16- Dec -10 0 0 555 650 25 15- Dec -10 0 0 559 650 25 14- Dec -10 0 0 527 650 25 13- Dec -10 0 0 815 650 25 12- Dec -10 0 0 505 650 25 11- Dec -10 0 0 180 650 25 10- Dec -10 0 0 34 650 25 9- Dec -10 0 0 35 650 25 8- Dec -10 0 0 31 650 25 7- Dec -10 0 0 23 650 25 6- Dec -10 0 0 28 650 25 5- Dec -10 0 0 39 650 25 • • 4- Dec -10 0 0 39 650 25 3- Dec -10 0 0 31 650 25 2- Dec -10 0 0 45 650 25 1- Dec -10 0 0 33 650 25 30- Nov -10 0 0 59 650 25 29- Nov -10 0 0 61 650 25 28- Nov -10 0 0 96 650 25 27- Nov -10 0 0 96 650 25 26- Nov -10 0 0 380 600 25 25- Nov -10 0 0 953 700 50 24- Nov -10 0 0 1375 700 50 23- Nov -10 0 0 2078 700 50 22- Nov -10 0 0 1855 700 50 21- Nov -10 0 0 1724 700 50 20- Nov -10 0 0 1833 700 50 19- Nov -10 0 0 1375 700 50 18- Nov -10 0 0 1937 700 50 17- Nov -10 0 0 1308 700 50 16- Nov -10 0 0 299 700 50 15- Nov -10 0 0 181 700 50 14- Nov -10 0 0 395 700 50 13- Nov -10 0 0 691 700 50 12- Nov -10 0 0 750 700 50 11- Nov -10 0 0 830 700 50 10- Nov -10 0 0 660 700 50 9- Nov -10 0 0 1066 700 50 8- Nov -10 0 0 1628 700 50 7- Nov -10 0 0 1466 700 50 6- Nov -10 0 0 1635 700 50 5- Nov -10 0 0 1941 700 50 4- Nov -10 0 0 1517 700 50 3- Nov -10 0 0 979 700 50 2- Nov -10 0 0 1155 700 50 1- Nov -10 0 0 1494 700 50 31- Oct -10 0 0 1881 700 50 30- Oct -10 0 0 2112 700 50 29- Oct -10 0 0 1806 700 50 28- Oct -10 0 0 847 750 50 27- Oct -10 0 0 1517 700 50 26- Oct -10 0 0 1638 750 50 25- Oct -10 0 0 1937 750 50 24- Oct -10 0 0 1869 750 50 23- Oct -10 0 0 1928 750 50 22- Oct -10 0 0 1929 750 50 21- Oct -10 0 0 1674 750 10 20- Oct -10 0 0 917 700 10 19- Oct -10 0 0 1954 800 50 18- Oct -10 0 0 1845 800 50 17- Oct -10 0 0 1847 800 50 16- Oct -10 0 0 1712 800 50 15- Oct -10 0 0 1740 750 50 14- Oct -10 0 0 1783 800 50 0 • 13- Oct -10 0 0 1873 800 50 12- Oct -10 0 0 1728 800 50 11- Oct -10 0 0 1837 800 50 10- Oct -10 0 0 2095 800 50 9- Oct -10 0 0 2230 800 50 8- Oct -10 0 0 2370 900 50 7- Oct -10 0 0 2349 900 50 6- Oct -10 0 0 2350 900 50 5- Oct -10 0 0 2352 900 50 4- Oct -10 0 0 2351 900 50 3- Oct -10 0 0 2348 900 50 2- Oct -10 0 0 2348 900 50 • • WELL LOG TRANSMITTAL PROACTIVE DIACINOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 27- Nov-10 1L-03A 1 Report / EDE 50 -029- 21182 -01 2) Caliper Report 28- Nov-10 2G-06 1 Report / EDE 50-029-21121-00 iii Q , - 006 Signed Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E -MAIL : Cdsanchorage (arF',emory?oq.cors'3 WEBSITE : www.memory oq.com C:\Documents and Settings \Diane Williams \Desktop \Transmit_Conoco.docx i • • i VS Memory Multi- Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1L-03A Log Date: November 27, 2010 Field: Kuparuk Log No.: Service # 7800985 State: Alaska I Run No.: 1 API No.: 50-029-21182-01 Pipet Desc.: 4.5 in. 12.6 Ib. L -80 BTC -Mod Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intv11.: 6,010 Ft. (MD) 1 Inspection Type : Pre -Patch Assessment COMMENTS: 1 This caliper data is tied into the Packer at 5,857 ft. (Drillers Depth). This log was run to assess the condition of the 4.5 in. tubing to determine the condition around a leak I recorded @ 1,133 ft, and to locate a proper setting position for the packer elements. The caliper recordings indicate the 4.5 inch tubing appears to be in fair to poor condition, with , probable holes, and multiple possible holes recorded in 9 of the joints logged, and wall penetrations over 20% wall I thickness recorded in all but 4 of the joints logged. The majority of the damage is recorded in the form of general corrosion. Heavy Deposits/ Deposits are recorded throughout the majority of the interval of tubing logged with a Minimum recorded ID 2.86 in. (5,389'). No significant areas of cross - sectional wall loss or I.D. restrictions are recorded. A graph illustrating minimum recorded diameters on a joint-by-joint basis is 1 included in this report. This summary report is interpretation of data provided by Halliburton Well Services. 1 MAXIMUM RECORDED WALL PENETRATIONS: Probable Hole ( 95 %) Jt. 42 @ 1,366 Ft. (MD) I Multiple Possible Holes ( 94%) Jt. 44 @ 1,436 Ft. (MD) Multiple Possible Holes (91 %) Jt. 40 @ 1,304 Ft. (MD) Multiple Possible Holes ( 91%) Jt. 38 @ 1,266 Ft. (MD) Possible Hole ( 89 %) Jt. 51 @ 1,650 Ft. (MD) 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 15 %) are recorded throughout the surface casing logged. 1 MAXIMUM RECORDED ID RESTRICTIONS: Heavy Deposits Minimum I.D. = 2.86 in. Jt. 169 @ 5,390 Ft. (MD) I Heavy Deposits Minimum I.D. = 2.89 in. Jt. 181.3 @ 5,803 Ft. (MD) Heavy Deposits Minimum I.D. = 2.92 in. Jt. 103 @ 3,301 Ft. (MD) Heavy Deposits Minimum I.D. = 2.95 in. Jt. 182.3 @ 5,862 Ft. (MD) 1 Heavy Deposits Minimum I.D. = 2.99 in. Jt. 138 @ 4,410 Ft. (MD) 1 Field Engineer: J. Corad Analyst: J. Thompson Witness: B. Boehme 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memoryiog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 lag -O3 (90 stL I • • Correlation of Recorded Damage to Borehole Profile I 111 Pipe 1 4.5 in (41.5' - 5997.3') Well: 1 L -03A Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: November 27, 2010 I ■ Approx. Tool Deviation ■ Approx. Borehole Profile I 1 (1111111= 62 I 1 25 827 I 50 1618 75 2411 p I ,.= c z s 1 00 3202 n o v D I 125 3991 150 , _ ... 4775 I 175 5566 I 411111111111111‘. I ,. 187 5997 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 187 I I - • • I Minimum Diameter Profile Well: 1 L -03A Survey Date: November 27, 2010 Field: Kuparuk Tool: UW MFC 24 Haliburton ' Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 3.958 inches I Minimum Measured Diameters (In.) 1.69 2.19 2.69 3.19 3.69 0.7 — 8 13 1 20 7 20 T� 25 �� 30 �� 35 40 45 ' S0 �� 55 60 65 70 75 80 1 ' 85 d 90 E 95 7 Z 100 , , c .O 105 10 — _— 115 Y -- -, r 120 _�i I 125 130 135 , I 140 �� 745 150 155 I 160 - -- 170 r -- 175 . -- — 180 E -_ - _ -_- 182 -- ______ —_ 784 I I I • • I PDS Report Overview VS Body Region Analysis I Well: 1L -03A Survey Date: November 27, 2010 Field: Kuparuk Tool Type: UW MFC 24 Haliburton Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 4.5 ins 12.6 ppf L -80 BTC -Mod Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 4.5 ins 12.6 ppf L -80 BTC -Mod 3.958 ins 4.5 ins 6.0 ins 6.0 ins I I Penetration(% wall) Damage Profile (% wall) 200 ■ Penetration body MEI Metal loss body 0 50 100 150 0 =� 100 - -�q I 50 0 to 20 to 40 to over 20% 40% 85% 85% 46 Number of joints analysed (total = 196) -° = =Al I 4 14 169 9 - == I Damage Configuration ( body) 96 ____ 150 �∎ - - - -�� I 100 31 __ = =_1 - !] 50 - 146 __ ° � I Isolated General Other Hole/ _ ° P itting Corrosion Corrosion Corrosion Daamage Pos. Hole = - Number of joints damaged (total = 193) 13 143 28 0 9 Bottom of Survey = 187 I I I I i • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L -80 BTC -Mod Well: 1L-03A Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in USA Survey Date: November 27, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 42 0.04 0.04 15 6 3.50 Pup Shallow Line of Pits. Deposits. ■ ■ 0.2 44 0.05 0.09 33 4 3.93 Pup Line of Pits. 0.3 52 0.05 0.05 18 7 3.96 Pup Shallow Line Corrosion. ■�1 1 62 0.04 0.11 41 8 3.85 Line Corrosion. Lt. Deposits. i■■ I 2 94 0.04 0.10 37 6 3.79 Line Corrosion. Lt. Deposits. I■■ 3 125 0.08 0.09 34 7 3.70 Line of Pits. Deposits. mow 4 157 0.05 0.12 45 9 3.73 Line Corrosion. Lt. Deposits. i■■ 5 189 0.04 0.11 39 9 3.79 Line of Pits. Lt. Deposits. ■■ 6 220 0.05 0.09 33 7 3.23 Line of Pits. Heavy Deposits. l■. I 7 252 0.07 0.10 37 8 3.65 Line Corrosion. Deposits. mile 8 284 0.04 0.12 43 8 3.69 Line Corrosion. Deposits. t■■ 9 315 0.09 0.11 39 10 3.76 Line Corrosion. Lt. Deposits. ■■ 10 347 0.05 0.12 45 8 3.20 Isolated Pitting. Heavy Deposits. i■■ I ll 379 0.05 0.10 37 9 3.48 Line of Pits. Deposits. no 411 0.04 0.11 42 8 3.11 Isolated Pitting. Heavy Deposits. mow 13 442 0.04 0.09 32 6 3.30 Isolated Pitting. Heavy Deposits. ■■■ 14 473 0.04 0.13 47 6 3.24 Corrosion. Heavy Deposits. o■ I 15 505 0.05 0.07 27 6 3.27 Line of Pits. Heavy Deposits. 15.1 536 0 0.01 4 0 3.92 Pup I 15.2 539 0 0 0 0 3.87 Camco DB Nipple 15.3 541 0 0.06 21 5 3.90 Pup Line of Pits. Lt. Deposits. ■■ 16 , 544 0.04 0.09 34 8 3.39 Line of Pits. Heavy Deposits. t■■ ' 17 576 0 0.10 35 6 3.04 Line Corrosion. Heavy Deposits. ow 18 606 0.06 0.12 45 10 3.05 Line Corrosion. Heavy Deposits. ■■ 19 638 0.05 0.13 48 9 3.57 Line Corrosion. Deposits. t■■ 20 669 0.05 0.12 45 10 3.02 Line Corrosion. Heavy Deposits. ■■ '' 21 701 0.07 0.11 41 7 3.88 Line Corrosion. Lt. Deposits. o■■ 22 732 0.04 0.15 57 9 3.62 Line Corrosion. Deposits. t■■ 23 764 0.06 0.16 59 10 3.85 Corrosion. Lt. Deposits. ■■ 24 796 0.10 0.19 72 11 3.89 Line Corrosion. Lt. Deposits. ■■ ' 25 827 0.05 0.15 57 7 3.77 Line Corrosion. Lt. Deposits. moo 858 0.07 0.18 68 10 3.92 Line Corrosion. ■■ 27 890 0.09 0.19 72 8 3.82 Line Corrosion. Lt. Deposits. woo 28 921 0.12 0.20 72 10 3.87 Line Corrosion. Lt. Deposits. ■■ 29 953 0.08 0.20 73 8 3.90 Corrosion. IM MO ■ 30 985 0.10 0.21 79 13 3.79 Corrosion. Lt. Deposits. ■w 31 1017 0.12 0.23 85 10 3.72 Possible Hole! Deposits. ■■ 32 1048 0.15 0.19 70 9 3.79 Line Corrosion. Lt. Deposits. ■■ 33 1080 0.18 0.21 77 11 3.60 Deposits. ■M I 34 , 1112 0.10 0.22 80 11 3.37 Line Corrosion. Heavy Deposits. ■■ 35 1143 0.16 0.22 82 13 3.77 Line Corrosion. Lt. Deposits. ■■ 36 1175 0.14 0.22 81 10 3.82 Line Corrosion. Lt. Deposits. ■■ 37 1207 0.18 0.21 79 15 3.83 Line Corrosion. Lt. Deposits. IN I 38 1238 0.10 0.25 91 11 3.83 Multiple Possible Holes! Lt. Deposits. ■■ 39 1270 0.16 0.22 82 13 3.33 Line Corrosion. Heavy Deposits. Iwo 40 1301 0.20 0.25 91 15 3.53 Multiple Possible Holes! Deposits. ■■ 41 1333 0.12 0.23 83 13 3.45 Corrosion. Heavy Deposits. ■■ I 42 1365 0.14 0.26 95 12 3.03 Probable Hole! Heavy Deposits. ■■ 43 1396 0.12 0.21 77 11 3.59 Corrosion. Deposits. ■■ 44 1428 0.18 0.26 94 11 3.39 Multiple Possible Holes! Heavy Deposits. I rat Metal Loss ion BoBody dy I Penet Page 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L-80 BTC -Mod Well: 1L-03A Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: November 27, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 45 1460 0.17 0.23 83 14 3.65 Corrosion. Deposits. 46 1492 0.10 0.23 84 12 3.41 Line Corrosion. Heave Deposits. IL- / 47 1523 0.06 0.24 89 14 3.38 Multiple Possible Holes! Heavy Deposits. 4 IL 8 1555 0.08 0.21 77 14 3.35 Corrosion. Heavy Deposits. 49 1586 0.14 0.21 79 11 3.54 Corrosion. Deposits. I 50 1618 0.15 0.23 83 11 3.49 Corrosion. Deposits. 51 1650 0.21 0.24 89 14 3.47 Possible Hole! Deposits. r''' l 1 NI 52 1682 0.14 0.22 81 12 3.43 Line Corrosion. Heavy Deposits. 53 1714 0.11 0.22 82 13 3.59 Corrosion. Deposits. I 54 1745 0.16 0.21 78 15 3.67 Corrosion. Deposits. 55 1777 0.15 0.22 80 15 3.51 Corrosion. Deposits. 56 1809 0.14 0.21 76 14 3.50 Corrosion. Deposits. w 57 1840 0.10 0.20 75 14 3.55 Corrosion. Deposits. I 58 1872 0.15 0.21 76 15 3.70 Corrosion. Deposits. 59 1904 0.17 0.20 75 14 3.32 Corrosion. Heavy Deposits. 60 1935 0.16 0.22 80 13 3.35 Corrosion. Heavy Deposits. 61 1967 0.11 0.20 73 16 3.51 Corrosion. Deposits. I 62 1999 0.15 0.19 68 13 3.70 Corrosion. Deposits. 63 2030 0.13 0.20 74 15 3.64 Corrosion. Deposits. 64 2062 0.12 0.21 78 16 3.58 Corrosion. Deposits. 65 2094 0.14 0.22 81 16 3.50 Corrosion. Deposits. 66 2125 0.13 0.18 67 14 3.45 Corrosion. Heavy Deposits. ■O■ 111 67 2157 0.11 0.19 68 15 3.38 Corrosion. Heavy Deposits. 2189 0.14 0.18 66 15 3.44 Corrosion. Heave Deposits. 69 2220 0.13 0.18 68 14 3.45 Corrosion. Heavy Deposits. 70 2252 0.14 0.20 74 15 3.40 Corrosion. Heavy Deposits. IL- I 71 2284 0.13 0.19 70 15 3.52 Corrosion. Deposits. 72 2315 0.08 0.15 55 14 3.55 Corrosion. Deposits. 73 2347 0.09 0.19 69 16 3.40 Corrosion. Heavy Deposits. L 74 2379 0.14 0.17 64 17 3.29 Corrosion. Heavy Deposits. k I 75 2411 0.13 0.18 66 16 3.41 Corrosion. Heavy Deposits. 76 2442 0.09 0.16 61 14 3.38 Corrosion. Heavy Deposits. 77 2474 0.09 0.16 57 14 3.42 Corrosion. Heavy Deposits. 78 2506 0.09 0.14 52 17 3.38 Corrosion. Heavy Deposits. -- 79 2537 0.09 0.16 60 14 3.45 Corrosion. Heavy Deposits. I 80 2569 0.08 0.16 57 14 3.36 Corrosion. Heavy Deposits. 81 2601 0.10 0.16 61 14 3.27 Corrosion. Heavy Deposits. 82 2632 0.11 0.17 64 17 3.37 Corrosion. Heavy Deposits. 83 2664 0.10 0.16 59 17 3.21 Corrosion. Heavy Deposits. I 84 2696 0.11 0.18 67 12 3.42 Corrosion. Heavy Deposits. 85 2727 0.18 0.17 62 15 3.33 Heavy Deposits. '= 86 2759 0.10 0.17 62 16 3.39 Corrosion. Heavy Deposits. 87 2791 0.10 0.16 59 13 3.28 Corrosion. Heave Deposits. - I 88 2822 0.08 0.16 58 15 3.40 Corrosion. Heavy Deposits. a 89 2854 0.11 0.1 63 12 3.19 Corrosion. Heavy Deposits. 90 2886 0.11 0.17 62 14 3.43 Corrosion. Heavy Deposits. 91 2917 0.10 0.1 65 13 3.21 Corrosion. Heavy Deposits. 4_ 92 2949 0.09 0.17 64 15 3.42 Corrosion. Heavy Deposits. I 93 2981 0.14 0.16 61 14 3.30 Corrosion. Heave Deposits. 94 3012 0.11 0.19 68 15 3.48 Corrosion. Deposits. I I 4 Penetration I Metal Loss Body Page 2 Penetra I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L -80 BTC Mod Well: 1L-03A Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in USA Survey Date: November 27, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 95 3044 0.09 0.21 76 16 3.26 Corrosion. Heavy Deposits. 96 3075 0.10 0.14 54 13 3.35 Corrosion. Heavy Deposits. 97 3107 0.10 0.18 67 15 3.36 Corrosion. Heaw Deposits. 98 3139 0.10 0.15 57 11 3.36 Corrosion. Heavy Deposits. i.- 99 3171 0.12 0.16 59 17 3.33 Corrosion. Heaw Deposits. I 100 3202 0.12 0.18 68 15 3.36 Corrosion. Heavy Deposits. r 101 3234 0.12 0.17 63 14 3.29 Corrosion. Heavy Deposits. 102 3266 0.13 0.16 60 15 3.43 Corrosion. Heavy Deposits. 103 3296 0.14 0.19 71 14 2.92 Corrosion. Heavy Deposits. I 104 3328 0.07 0.16 57 10 3.31 Line Corrosion. Heavy Deposits. 105 3359 0.10 0.18 67 13 3.29 Corrosion. Heavy Deposits. 106 3391 0.10 0.18 67 15 3.37 Corrosion. Heavy Deposits. t- 107 3423 0.12 0.17 63 15 3.28 Corrosion. Heave Deposits. L I 108 3455 0.07 0.13 47 12 3.45 Line Corrosion. Heavy Deposits. 109 3486 0.12 0.19 70 14 3.25 Corrosion. Heavy Deposits. 110 3517 0.17 0.19 69 13 3.30 Corrosion. Heavy Deposits. 111 3549 0.10 0.17 63 13 3.24 Corrosion. Heavy Deposits. I 112 3581 0.14 0.16 61 17 3.23 Corrosion. Heavy Deposits. 113 3612 0.12 0.17 62 14 3.14 Corrosion. Heave Deposits. 114 3644 0.12 0.16 58 15 3.15 Corrosion. Heavy Deposits. 115 3676 0.10 0.17 63 15 3.27 Corrosion. Heavy Deposits. 116 3708 0.12 0.20 73 15 3.35 Corrosion. Heavy Deposits. -'-- I 1 17 _ 3739 0.10 0.16 59 17 3.25 Corrosion. Heavy Deposits. 118 3771 0.11 0.18 67 14 3.40 Corrosion. Heavy Deposits. i ` 1 19 3803 0.12 0.17 62 12 3.39 Corrosion. Heave Deposits. L . 120 3834 0.12 0.18 65 13 3.35 Corrosion. Heavy Deposits. L I 121 3866 0.11 0.18 65 15 3.44 Corrosion. Heavy Deposits. >` 122 3897 0.11 0.14 52 18 3.33 Corrosion. Heavy Deposits. 123 3928 0.12 0.14 52 11 3.19 Corrosion. Heavy Deposits. L 124 3960 0.09 0.15 55 12 3.24 Corrosion. Heavy Deposits. - I 125 3991 0.12 0.13 48 12 3.25 Corrosion. Heavy Deposits. 126 4022 0.11 0.17 62 15 3.27 Corrosion. Heavy Deposits. 127 4053 0.12 0.13 49 14 3.32 Corrosion. Heavy Deposits. 128 4084 0.15 0.14 52 14 3.35 Corrosion. Heavy Deposits. 129 4116 0.09 0.15 55 15 3.38 Corrosion. Heavy Deposits. I 130 4147 0.09 0.13 47 13 3.12 Corrosion. Heavy Deposits. ' - 131 4179 0.10 0.15 56 11 3.13 Corrosion. Heave Deposits. 132 4210 0.11 0.14 52 12 3.41 Corrosion. Heavy Deposits. 133 4242 0.09 0.15 55 12 3.30 Corrosion. Heavy Deposits. I 134 4274 0.10 0.16 60 12 3.24 Corrosion. Heavy Deposits. 135 4306 0.11 0.15 56 12 3.40 Corrosion. Heavy Deposits. 136 4337 0.10 0.13 49 13 3.19 Corrosion. Heavy Deposits. 137 4368 0.08 0.15 55 11 3.29 Corrosion. Heaw Deposits. I 138 4400 0.09 0.15 55 12 2.99 Corrosion. Heaw Deposits. 139 4431 0.09 0.15 56 11 3.12 Corrosion. Heavy Deposits. 140 4463 0.08 0.15 57 12 3.27 Corrosion. Heavy Deposits. 141 4494 0.10 0.15 56 15 3.22 Corrosion. Heavy Deposits. 1-- 142 4526 0.10 0.14 51 11 3.38 Corrosion. Heavy Deposits.` I 143 4557 0.10 0.13 48 12 3.32 Corrosion. Heavy Deposits. 144 4589 0.09 0.17 62 11 3.36 Corrosion. Heavy Deposits. IL Penetration Body I Metal Loss Body Page 3 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L-80 BTC Mod Well: 1L-03A Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: November 27, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 145 4620 0.10 0.16 58 1 4 3.29 Corrosion. Heavy Deposits. 146 4651 0.12 0.14 52 11 3.49 Corrosion. Deposits. 147 4681 0.13 0.16 60 12 3.41 Corrosion. Heavy Deposits. 148 4712 0.10 0.15 56 10 3.26 Corrosion. Heavy Deposits. 149 4744 0.10 0.15 55 14 3.38 Corrosion. Heavy Deposits. I 150 4775 0.08 0.15 56 12 3.18 Corrosion. Heavy Deposits. 151 4807 0.12 0.16 59 14 3.37 Corrosion. Heavy Deposits. 152 4838 0.11 0.15 56 13 3.39 Corrosion. Heavy Deposits. 153 4869 0.10 0.17 62 14 3.31 Corrosion. Heavy Deposits. I 154 4901 0.09 0.17 63 13 3.44 Corrosion. Heaw Deposits. 155 4933 0.15 0.15 56 18 3.28 Corrosion. Heavy Deposits. 156 4965 0.10 0.17 63 10 3.40 Corrosion. Heavy Deposits. 157 4996 0.09 0.15 56 11 3.49 Corrosion. Deposits. L I 158 5027 0.13 0.15 55 1 3.35 Corrosion. Heavy Deposits. L 159 5058 0.08 0.16 59 10 3.48 Corrosion. Deposits. t 160 5090 0.14 0.18 65 13 3.38 Corrosion. Heavy Deposits. j 161 5122 0.09 0.16 58 11 3.21 Corrosion. Heavy Deposits. I 162 5154 0.1 0.16 61 12 3.42 Corrosion. Heavy Deposits. 163 5185 0.10 0.17 61 1 4 3.30 Corrosion. Heavy Deposits. 164 5217 0.10 0.15 57 13 3.33 Corrosion. Heavy Deposits. 165 5249 0.13 0.16 58 14 3.21 Corrosion. Heavy Deposits. -- r 166 5280 0.09 0.15 57 10 3.29 Corrosion. Heavy Deposits. I 167 5312 0.11 0.19 68 15 3.07 Corrosion. Heavy Deposits. 168 5344 0.12 0.17 64 11 3.21 Corrosion. Heavy Deposits. 169 5376 0.08 0.19 68 13 2.87 Corrosion. Heaw Deposits. rrr'' 170 5408 0.11 0.19 70 13 3.45 Corrosion. Heavy Deposits. >I rrr I 171 5439 0.13 0.18 67 13 3.41 Corrosion. Heavy Deposits. 5471 0.11 0.19 68 12 3.31 Corrosion. Heavy Deposits. L. 173 , 5503 0.11 0.18 67 13 3.26 Corrosion. Heavy Deposits. 4- 174 5534 0.15 0.20 74 15 3.05 Corrosion. Heavy Deposits. ' 175 5566 0.13 0.18 65 11 3.25 Corrosion. Heavy Deposits. 176 5598 0.15 0.19 70 14 3.21 Corrosion. Heavy Deposits. - IL IL 177 5629 0.12 0.19 72 17 3.10 Corrosion. Heavy Deposits. AL- 178 5660 0.18 0.20 72 12 3.18 Corrosion. Heavy Deposits. 11- i 179 5692 0.16 0.20 75 15 3.30 Corrosion. Heavy Deposits. - 11 I 180 5723 0.13 0.19 69 14 3.29 Corrosion. Heavy Deposits. 181 5754 0.13 0.18 65 9 3.12 Corrosion. Heavy Deposits. 181.1 5785 0 0.05 19 0 3.52 Pup Shallow Line of Pits. Deposits. 181.2 5793 0 i 0 0 0 3.55 Sliding Sleeve I 181.3 5797 0.06 0.11 39 9 2.89 Pup Corrosion. Heavy Deposits. 182 5805 0.15 0.18 67 14 3.15 Corrosion. Heavy Deposits. 182.1 5836 0.16 0.18 67 21 3.24 Pup Corrosion. Heavy Deposits. 182.2 5857 0 0 0 0 3.46 Packer I 182.3 5860 0.06 0.11 41 13 2.95 Pup Corrosion. Heavy Deposits. ` 183 5871 0.18 0.21 77 14 3.12 Corrosion. Heavy Deposits. 184 5904 0.13 0.22 80 13 3.45 Corrosion. Heavy Deposits. It_ a 185 5935 0.17 0.24 89 19 3.43 Multiple Possible Holes! Heavy Deposits. -- ,MI 186 5967 0.19 0.24 88 14 3.09 Possible Hole! Heavy Deposits. K.- I AM I 187 5997 0.14 0.20 74 13 3.09 Corrosion. Heavy Deposits. l' } ' 4 L Penetration Body Metal Loss Body I Page 4 I I I • • I 1:P____S. PDS Report Cross Sections I Well: 1 L -03A Survey Date: Tool Type: November 27, 2010 Field: Kuparuk UW MFC 24 Haliburton Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 4.5 ins 12.6 ppf L -80 BTC -Mod Analyst: J. Thompson I I Cross Section for Joint 42 at depth 1366.153 ft Tool speed = 50 Nominal ID = 3.958 I Nominal OD = 4.5 Remaining wall area = 92% Tool deviation = 25° I I I ,, I ■ �/ �' I Finger = 12 Penetration = 0.258 ins Probable Hole 0.25 = 95% Wall Pentration HIGH SIDE = UP 1 I I I I • r I PDS Report Cross Sections V I Well: 1L -03A Survey Date: November 27, 2010 Field: Kuparuk Tool Type: UW MFC 24 Haliburton Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 4.5 ins 12.6 ppf L -80 BTC -Mod Analyst: J. Thompson 1 I Cross Section for Joint 44 at depth 1436.833 ft Tool speed = 51 Nominal ID = 3.958 I Nominal OD = 4.5 — -- Remaining wall area = 93% /' ; Tool deviation = 29° j 1 I I _ - -- I I \ / I I Finger = 13 Penetration = 0.255 ins Multiple Holes 0.25 ins = 94% Wall Penetration HIGH SIDE = UP 1 I I I I • • I PDS Report Cross Sections I Well: 1L-03A Survey Date: November 27, 2010 Field: Kuparuk Tool Type: UW MFC 24 Haliburton Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 4.5 ins 12.6 ppf L -80 BTC -Mod Analyst: J. Thompson I I Cross Section for Joint 169 at depth 5389.963 ft Tool speed = 50 Nominal ID = 3.958 I Nominal OD = 4.5 -- -.� Remaining wall area = 93% Tool deviation = 45° I r I \ 101, I 1 / / \ l I I Minimum I.D. = 2.866 ins Heavy Deposits Min Id = 2.86 ins HIGH SIDE = UP I I I I • • 1 PDS Report Cross Sections VS. I Well: 1L-03A Survey Date: November 27, 2010 Field: Kuparuk Tool Type: UW MFC 24 Haliburton Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 4.5 ins 12.6 ppf L -80 BTC -Mod Analyst: J. Thompson I I Cross Section for Joint 181.3 at depth 5803.273 ft Tool speed = 51 Nominal ID = 3.958 I Nominal OD = 4.5 Remaining wall area = 96% % — Tool deviation = 44° I I I i r 1 1 N I \ IIPPr I Minimum I.D. = 2.893 ins Heavy Deposits Min ID = 2.89 ins HIGH SIDE = UP I I I I a KU P 1 L -03A ConocOPhillips $ ( Attributes ngle & nip TD W elibore API/UWI Field Name Well Status Intl (1 ND (ItKB) Ac[ Btrn (RKB) coneeeehillis 500292118201 KUPARUK RIVER UNIT INJ 54.98 2,500.00 7,979.0 Comment H2S (ppm) Date Annotatlon End Date KB-Grd (ft) Rig Release Date ' Well conga: -1L -0u, sNZ010]zs zz AM SSSV: NIPPLE Last WO: 11/7/1999 34.80 9/21/1984 schematic -Aaual Annotation Depth OMB) End Date Annotation Last Mod By End Date Last Tag: 6,951.0 8/26/2010 Rev Reason: TAG Imosbor 9/7/2010 Casing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description ON BM Top (RKB) (BB) BBB) Bbsmq Grade String Top Thni CONDUCTOR 16 15.062 0.0 93.0 93. 62.58 (1110 WELDED SURFACE 95/8 8.800 0.0 2,071.0 1,897.5 36.00 J-55 BTC CONDUCTOR. PRODUCTION 7 6.151 0.0 6,018.0 4,570.8 26.00 J-55 BTC 93 LINER TOP 4 1/2 3.958 5,843.0 7,572.0 41/2 3.188 6,011.0 6,019.0 5,910.8 12.60 L-80 NSCT I WINDOWA 4,571.6 12.60 L -80 CTD LINER 3 3/16 2.800 6,965.0 7,979.0 6.20 L -80 TCII Tubing Strings NIPPLE, 526 String OD String ID Set Depth Set Depth (TVD) String WI String Tubing Description ON (In) Top 91KB) (RKB) (fBB) (Sniff) Grade String Top T1rd TUBING 41/2 3.958 0.0 5.843.0 4,4467 1250 L-80 BTC -MOD I Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth SURFACE. (TVD) Top Ind 2,071 Top (IBB) VOW P) Description Comment Run Date ID On) 526 526.0 0.93 NIPPLE CAMCO DB NIPPLE 5/23/1999 3.875 I 5,797 4,414.0 45.05 SLEEVE -C BAKER CMU SLIDING SLEEVE 5/23/1999 3.812 5,857 4,456.5 45.12 PACKER BAKER C2 ZXP LINER TOP PACKER 5/23/1999 3.937 SLEEVE. 5,797 ,' ' 6,965 5,367.9 30.71 DEPLOY DEPLOYMENT SLEEVE 5/23/1999 3.000 7,911 6,192.1 26.42 COLLAR LANDING COLLAR 5/23/1999 3.000 Perforations & Slots Shot ----fi Top(TVD) Min(TVD) Dens Top (MB) Btrn(RKB) (MB) BIKB) zone Date (sn.. Type Comment 7,775 7,795 6,082.1 6,096.3 A -5, 1L-03A 11/26/1999 6.0 IPERF 2" HC, PJ, DP, 60 deg phasing 7,813 7,843 6,109.9 6,133.9 A-4, 1L-03A 11/28/1999 6.0 IPERF 2" HC, PJ, DP, 60 deg phasing I 7,835 7,870 6,127.9 6,156.9 A -4, 1L-03A 11/28/1999 6.0 IPERF 2" HC, PJ, DP, 60 deg phasing PACKER. 5,857 Notes: General & Safety ! End Date Amotatlon 11/5/1999 NOTE: WELL SIDETRACKED 8 WORKOVER I PRODUCTION. 6,018 I 'WINDOW A, 8,019 I DEPLOY. 6.965 I I/ LINER TOP, 7,572 I 7, PER :, ns7,7as 1 IPERF, 7.813-7,313 I PERF, 7,836 -7 071 I I COLLAR, 7,911 CTD LINER, 7,979 I TD D L -O3AL 7.979 I Page l of l • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Sunday, September 26, 2010 9:26 AM To: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: RE: KRU Injector 1L-03A (PTD 199 -037) Tom, is our intention complete 1 failed the diagnostic MITIA. The well was shut in 9/25/10. It s ou 1L-03A (PTD 99 037 ) a ed g p further diagnostics to locate the leak and repair if possible. The appropriate 10 -403 or AA will be submitted as required before repair or variance. - MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 JAN 2 0 2011 From: NSK Well Integrity Proj Sent: Thursday, September 23, 2010 11:39 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; Schwartz, Guy L (DOA); NSK Problem Well Supv Cc: NSK Well Integrity Proj Subject: KRU Injector 1L -03A (PTD 199 -037) Tom, KRU Injector 1L-03A (PTD 199 -037) was reported to have the IA equalize with the tubing shortly after bleeding the well down this morning. A diagnostic MITIA will be schedule this week. It is ConocoPhillips intent to leave the well online until the MITIA. If the MITIA passes we will likely request AA approval, if the MITIA fails we will shut in the well and complete further diagnostic to locate the leak. The well is added to the monthly injector report. A Schematic and TIO Plot are attached. Please let me know if this plan is not acceptable. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 « File: 1 L- 03A.pdf » « File: 1 L -03A schematic.pdf » 1/4/2011 Well Name 1L-03A Notes: Reported End Date 9/29/2010 Days 120 Start Date 6/1/2010 Annular Communication Surveillance 3000 - 140 - _ WHP — _ IAP _ OAP WHT - 120 2500 �� A- - - .1 v Iry vo v 100 2000 - - - Ala AA - _ __ 80 u. 0 1500 IL, ►` rI 'w C - 60 1000 _ - 40 500 - 20 0 , '1 • . ~...., 0 Jun -10 Jul -10 Aug -10 Sep -10 700, • •DGI ■MGI E �PWI _..."---__ —.ft. A _SWI L. - E _131-PD m 200 100 . 0 Jun -10 Jul -10 Aug -10 Sep -10 Date • • MEM®I~ANDUM State Df Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June l 1, 2008 TO: Jim Regg ~~~~ ~-I,l ~~r~ P.I. Supervisor (~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA [NC 1 L-03A FROM: Jeff Jones KUPARUK RIV UNIT 1L-03A Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~_i.~ Comm Well Name: KUPARUK RN UNIT 1L-03A API Well Number 50-029-2 1 1 82-0 1-00 Inspector Name• Jeff Jones Insp Num: mitJJ080606190656 Permit Number: 199-037-0 ~ Inspection Date: 6/1/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ tL-o3A Type Inj. ~ ~' ~ TVD aas6 IA ~~ - 67o j Islo ~ Isoo ~ Iaoo i - -- -- -- ~ P.T. j 19903~o TypeTest I sPT ~ Test psi I ~ ~ I soo ~ OA ~ zs ' ~s ~ zs ~ zs - - ------- Interval 4YRTST p~F P ~ Tubing~ 2400 2400 -1- -~---- 2400 ~ 2400 T Notes: 0.7 BBLS diesel pumped, no exceptions noted. ~~ta+Ji~~~ ,JUL ~ =~ 2Q~8 Wednesday,.lune 1 f, 2008 Page 1 of l STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~{L bt \h l04 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.a OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 1 L DATE: 06/14/04 OPERATOR REP: Brake 1 Rogers AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. well 1L-01 I Type Inj I N I TV.D. I 5762 J Tubing I 8°1 8°1 8°1 8°llnterval 4 P.T.D. 1841730 Type Test P Test psi 1500 Casing 240 1740 1720 1720 P/F P Notes: we" 1L-03A I Type Inj I S I T.V.D. I 44561 Tubing I 255°1 255°1 255°1 2550 lnterval 4 P.T.D. 1990370 Type Test P Test psi 1500 Casing. 450 1800 1760 1760 P/F P Notes: Well 11 L-05 I Type Inj I G I T.V.D. I 5826 I Tubing I 35401 35401 35401 354°I'nterval~ 4 P.T.D. 1841230 Type Test P Test psi 1500 Casing 700 1740 1710 1700 P/F P Notes: we" 1L-07 I Type Inj j S I T.V.D. I 57381 Tubing I 25501 25501 25501 2550 'nterva'l 4 P.T.D. 1841450 Type Test P Test psi 1500 Casing 560 1740 1740 1740 P/F P Notes: we1l11L-10 I Type Inj I S I T.V.D. I 5866 I Tubing I 17901 179°1 17901 179°1 Interval 4 P.T.D. 1900350 Type Test P Test psi 1500 Casing 1240 2500 2450 2450 P/F P Notes: well 1L-14 I Type Inj I G I T.V.D. I 57681 Tubing I 28°°1 28001 28001 2800 ,nterva'l 4 P.T.D. 1910100 Type Test P Test psi 1500 Casing 650 1700 1680 1680 P/F P Notes: well 1L-16 I Type Inj I N I T.V.D. I 5794 I Tubing 9°1 9°1 9°1 90 lnterval 4 P.T.D. 1841810 Type Test P Test psi 1500 Casing 125 1625 1620 1620 P/F P Notes: well 1L-17 I Type Inj I G I 1. V. D. I 5868 1 Tubing I 32601 3260 I 330°1 33001,nterva, 4 P.T.D. 1910430 Type Test P Test psi 1500 Casing 725 1725 1720 1720 P/F P Notes: well 1L-18 I Type Inj I s 1 T.V.D. I 5859 I Tubing I 18901 189°1 18901 1890 lnterval 4 P.T.D. 1910350 Type Test P Test psi 1500 Casing 470 2600 2550 2540 P/F P Notes: well 1L-21DPN Type Inj I ' P.T.D. 1910060 Type Test Notes: we1111L-22 I. Type Inj I P.T.D. 1901640 Type Test Notes: well 1 l-25 I Type Inj I P.T.D. 1910700 Type Test Notes: MIT Report Form Revised: 05/19/02 s I T.V.D. 1 5769 1 Tubing I 229°1 229°1 229°1 229°1 Interval 1 4 p Test psi 1500 Casing 60 1760 1760 1760 P/F P S I T.V.D. I 5909 I Tubing I 230°1 2300 I 23°°1 2300j Interval 4 P Test psi 1500 Casing 60 1760 1750 1750 P/F P N I TVD. I 58841 Tubing I 12501 125°1 12501 125011nterval 4 P Test psi 1500 Casing 410 1760 1720 1720 P/F P MIT KRU 1L 06-14-04.xls 6/15/2004 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990370 Well Name/No. KUPARUK RIV UNIT 1L-03A Operator PHILLIPS ALASKA INC. API No. 50-029-21182-01-00 MD 7979 TVD 6254 Completion Date 11/5/1999/'~ Completion Status IWINJ Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Interval Data Digital Digital~ Log Log Run OH / Dataset Type Media Format N~h~e Scale Media No Start Stop CH Received Number Comments ................................--/-"--ff .... ~8i~¢ ........................... ~- ....... FJ'N~,L ....... 5~0 ....7§74- .... iSH- ..... 5~-4)2-600 ..................... ~iL-(~;-) R SRVY RPT 6000 7571 OH 6/17/1999 SPERRY . . DGR/EWR4-TVD FINAL 4552 5881 OH 8/17/1999 DGR/CNP/SLD-TVD ' FINAL 4552 5881 OH 8/17/1999 /~.~ DGR/CNP/SLD-MD FINAL 6015 7570 OH 8/17/1999 ~'DGR/EWR4'MD FINAL 6015 7570 OH 8/17/1999 ~ ~5'RVY LSTNG 46 7979 OH 12/20/1999 BH 7502.. t.E PDC/SCMT 5 FINAL 5830 7874 CH 2/25/2000 11/26/99UIC ~" 0~.~'" 8/12/1999 09291 5988-7515 ~-'"' ~..---~'~ 2/25/2000 09450 5830-7874 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y 4~5 Daily History Received? Formation Tops Receuived? Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990370 Well Name/No. KUPARUK RIV UNIT 1L-03A Operator PHILL1PS ALASKA INC. AP1 No. 50-029-21182-01-00 MD 7979 TVD 6254 Completion Date 11/5/1999 Completion Status IWINJ Current Status 1WINJ UIC Y Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121189 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk 2/15/00 Well Job # Log Description Date BL Sepia CD 1.L-03A t~.~(~ 20001 PERF DEPTH CORREI_/SCMT/GR/CCL ~(I (._ 991126 I I I SIGNE ,v,,~(~ / DATE: FEB 2 5 2000 (~ Alaska Oil & Gas Coas. L;ommission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you?nch°rag6 Schlumberger NO. 121121 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 1 L-O3A 20011 SCMT 991126 1 1 L-28 20009 SCMT 991219 1 1R-01A 20013 SCMT 000108 1 2N-343 L~ I ~ 99350 EST .~.. (~ L~ 990827 I I 1 i~ i-i' t-IVFI) Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. FEB 04 2000 Anchorage 1/25/00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 10, 2000 Mr. Robert W. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1L-03A (Permit No. 199-37/399-063) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1L-03A. If there are any questions, please call 265-6120. Sincerely, :G. L. Alvord Kuparuk Engineering Supervisor AAI Drilling GLA/skad alaska 0/I & 6as Oons. Commission Anchorage .... RECF VED STATE OF ALASKA ALASKA OIL AND GAS OONSERVATION. ~O~1'¢155i~N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well ~Sk~ 0ii& 6~s Co.~. C0~i~, o~Service Well Anchorage Oil [] Gas [] Suspended [] Abandoned [] Service [] Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 199-37 / 399-063 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-21182-01 4. Location of well at surface 343' FSL, 144' FEL, Sec. 30, T11N, R10E, UM At Top Producing Interval 1694' FNL, 2482' FEL, Sec. 30, T11N, R10E At Total Depth 1710' FNL, 2329' FEL, SEC 30, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 31', Pad 81' feet 6. Lease Designation and Serial No. ADL 25659 ALK 2585 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1 L-03A 11. Field and Pool Kuparuk River Field Kuparuk River Pool 12. Date Spudded May 17, 1999 13. Date T.D. Reached 114. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore November 2, 1999 J November 5, 1999 N/A feetMSL 18. Plug Back Depth (MD + TVD) 119. Directional Survey 120. Depth where SSSV set 7912' MD/6193' TVD lYES [] No [] I N/A feetMD 16. No. of Completions 2 21. Thickness of Permafrost 1500' (approx,) 17. Total Depth (MD + TVD) 7979' MD / 6254' TVD 22. Type Electric or Other Logs Run CBT/GR/CCL, SCMT 23. CASING SIZE 16" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD WT. PER FT. 62.5# GRADE 24. Perforations o interval, size and number) H-40 TOP Surface BO'FI-OM 93' HOLE SIZE 24" CEMENTING RECORD 235 sx Cold Set II 9.625" 36# J-55 Surface 2071' 12-1/4" 72o sx AS III, 250 sx Class G 7" 26# J-55 Surface 8323' 8-1/2" 575 sx class G & 200 sx AS I 4.5" 12.6# L-80 5843' 7571' 6.125" 253 sx Class G 3-3/16" 6.2# L-80 6965' 7978' 4.125" 10 bbls 15.8 ppg Class G bridge plug @ 6032', cement retainer @ 7872' )eh to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD 7775'-7795' M D 6078'-6080' TVD 6 spf 7813'-7843' MD 6110'-6135' TVD 6 spf 7853.5'-7870.5' MD 6144'-6158' TVD 6 spf AMOUNT PULLED SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production 'Date of Test Flow Tubing Hours Tested Casing Pressure Method of Operation (Flowing, gas I Injector IProduotion for IOIL-13BL [Test Period > I Icaculated IOIL-BBL [24-Hour Rate > I lift, etc.) GAS-MCF GAS-MCF WATER-BBL WATER-BBL CHOKE SIZE IGAS-OIL RATIO I OIL GRAVITY - APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of Kuparuk D Base of Kuparuk D Top of Kuparuk A Base of Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7655' 7665' TRUE VERT. DEPTH 5984' 5992' 6068' 7760' 7910' 6191' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open o 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 Mark Chambers 265-1319 Signed ~ ~ ~ Title Drilling Enqineering Supervisor Date ~/ - Chip Alvord ~' INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVfiB Item 28: If no cores taken, indicate "none". Form 10-407 Date: 12/07/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iL-03A WELL_ID: AK0036 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:05/12/99 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21182-01 05/07/99 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD/TVD: 8241/6331 (8241) MOVING RIG SUPV:DEARL W. GLADDEN Move rig from 3A pad to iL pad. UPCOMING OPERATIONS:MIRU ON 1L-03 - APIWL: 0.0 05/08/99 (D2) MW: 9.9 VISC: 65 PV/YP: 16/32 APIWL: 5.0 TD/TVD: 8241/6331 ( 0) TEST BOPS SUPV:DEARL W. GLADDEN Finish rig move to iL pad. Accept rig $ 0600 hrs. 5/8/99. Rig up. PJSM. Pump LSND mud. UPCOMING OPERATIONS:TEST BOPS - PULL HANGER - CBU - L/D TBG 05/09/99 (D3) MW: 9.9 VISC: 44 PV/YP: 17/30 APIWL: 4.8 TD/TVD: 8241/6331 ( 0) P/U DCS & HWDP BACK IN DERRICK SUPV:DEARL W. GLADDEN N/D tree. N/U BOP and test BOPs. Pull tubing. UPCOMING OPERATIONS:TIH W/ BIT & SCRAPER - TOH - RUN E-LINE LOGS 05/10/99 (D4) MW: 9.9 VISC: 43 PV/YP: 9/17 APIWL: 3.0 TD/TVD: 8241/6331 ( 0) RUNNING E-LINE LOGS SUPV:DEARL W. GLADDEN Continue to pull tubing. P&A integrity test, EMW=12.5 ppg. UPCOMING OPERATIONS:LOG - SET BRIDGE PLUG - TIH TO RUN WHIP STOCK 05/11/99 (D5) MW: 9.9 VISC: 40 PV/YP: 13/15 APIWL: 3.0 TD/TVD: 8241/6331 ( 0) MILL OFF BAKER MASTER WHIPSTCK TOP ~ 6018' NORDIC DEPT SUPV:DONALD L. WESTER Run cement bond log CBT/GR/CCL log from 7450'-5450' Run Baker bridge plug and set $ 6032' RIH with Whipstock and set. UPCOMING OPERATIONS:COMTINE MILLING WINDOW TILL TOP MILL THORUGH WINDOW & BOTTOM MILL $ 6034'. FIT & TIRP FOR DRILLING ASSY. RECEIVED 2000 Naska Oil & Gas Cons. Commission Anchorage Date: 12/07/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/12/99 (D6) MW: 10.0 VISC: 46 PV/YP: 13/29 APIWL: 3.0 TD/TVD: 6018/4565 ( 0) SQUEEZE WINDOW W/ 23 BBLS BEHIND PIPE WITHOUT LOCK UP SUPV: DONALD L. WESTER~k] Start cutting out 7" casing w/Baker Windowmaster ~ 6018'. . Cut bottom of window 6030' Drill to 6042' FIT, EMW=12.9 ppg. Pump cement. Down squeeze cement through window. UPCOMING OPERATIONS:TAG & C/O CEMENT. FIT 05/13/99 (D7) MW: 10.0 VISC: 45 PV/YP: 14/25 APIWL: 3.2 TD/TVD: 6018/4565 ( 0) CIRCULATE R/U DOWELL PUMP SQUEEZE #2 26 BBL'S CMT SLU SUPV:DONALD L. WESTER Continue squeezing window 6018' MD. Spill drill. RIH w/clean out Baker window master mill assembly. Would not pass thru wear ring. Tag cement @ 5535' Clean out firm cement 5535' to 6042'. Cement hard thru window section 6018' to 6042' FIT, EMW=13.0 ppg. UPCOMING OPERATIONS:HOLD CEMENT SQUEEZE IN PLACE FOR 3 HRS. POOH RIH W/ MILLING ASSY C/0 CEMENT. 05/14/99 (D8) MW: 10.3 VISC: 42 PV/YP: 12/26 APIWL: 8.0 TD/TVD: 6042/4565 ( 24) CONTINUE TO CLEAN OUT CEMENT FROM WINDOW 6018'-6030' & SUPV:DONALD L. WESTER Pump cement. Down squeeze cement through window 6018' to 6042'. RIH w/window milling assembly. Clean out cement from 5677' to 6018' and clean out window from 6018' to 6025' UPCOMING OPERATIONS:POOH TEST BOP'S 05/15/99 (Dg) MW: 10.3 VISC: 43 PV/YP: 14/25 APIWL: 12.0 TD/TVD: 6042/4565 ( 0) COMPLETE TRIP OUT L/D MULE SHOE. M/U 6-1/8" RR BIT & S SUPV:DONALD L. WESTER Continue to clean out cement from 61.25" window from 6025' to 6042'. LOT, EMW=13.3 ppg. Pump cement and down squeeze. UPCOMING OPERATIONS:C/0 CMT TO 6040' W/ ROTARY ASSY. POOH FOR DRILLING ASSY. 05/16/99 (D10) MW: 10.0 VISC: 42 PV/YP: 14/29 APIWL: 16.0 TD/TVD: 6042/4565 ( 0) CONTINUE RIH TO 5992' ORIENT TOOL FACE TO 38 DG TO RIG SUPV:DONALD L. WESTER Clean out cement stringers 5753', hard ~ 5782' Continue to clean out to 6035' While pullint out set top drive down on tool joint. Damage to top drive gear box oil fill nipple & guard. Repair same. UPCOMING OPERATIONS:CLEAN UP WINDOW, LOT DRICTIONAL DRILL 6.125" HOLE RECEIVED ~ ,~',!i 1 1 2000 Alaska Oil & Gas Certs. Commiss~ Date: 12/07/99 ARCO ALASKA INC. WELL SI/MMARY REPORT Page: 3 05/17/99 (Dll) MW: 9.8 VISC: 49 PV/YP: 16/29 APIWL: 3.8 TD/TVD: 6042/4565 ( 0) CONTINUE RIH TO 6119' SLIDE AND DRILL AHEAD 6202' @ 06 SUPV:DONALD L. WESTER Continue RIH w/drilling BHA #4. Slide thru window 6018'-6030' to 6032' Slide and clean out from 6032' to 6042' Continue sliding and drill new 6.125" hole from 6042'-6080'. Perform LOT, EMW 13.5 ppg broke down to EMW 12.75 ppg. Continue directional drilling 6.125" hole from 6080'-6119'. Bit balled up or motor damaged. Unable to make it drill. Safety meeting. UPCOMING OPERATIONS:DRILL AHEAD 05/18/99 (D12) MW: 9.8 VISC: 42 PV/YP: 12/26 APIWL: 2.9 TD/TVD: 6697/5136 (655) DRLG & SLIDE @ 6870' SUPV:DONALD L. WESTER Drilling and slide from 6118' to 6697' MD. UPCOMING OPERATIONS:DRIL TO 100' ABOVE KUP - PEFORM LOT 05/19/99 (D13) MW: 9.8 VISC: 43 PV/YP: 13/27 TD/TVD: 7385/5742 ( 688) CIRCU & CONDITION FOR LOT SUPV:DEARL W. GLADDEN Drill 6.125" hole 6693' to 7385' UPCOMING OPERATIONS:TOH TO SHOE - PERFORM LOT APIWL: 3.0 05/20/99 (D14) MW: 10.0 VISC: 51 PV/YP: 14/31 APIWL: 3.2 TD/TVD: 7571/5910 (186) TIH W / 4 1/2" LINER SUPV:DEARL W. GLADDEN Drill 6.125" hole from 7385' to 7539'. Perform FIT test, 11.8 ppg EMW. Perform pad evacuation drill. Drill from 7539' to 7571' UPCOMING OPERATIONS:RUN LINER - CMT LINER - L/D DP - RUN 4 1/2" COMP STRING 05/21/99 (D15) MW: 9.8 VISC: 41 PV/YP: 13/19 APIWL: 3.2 TD/TVD: 7575/5910 ( 4) LOAD SHED WITH 4 1/2" TBG FOR COMPLETION SUPV:DEARL W. GLADDEN Run 4.5" liner. Cement liner. UPCOMING OPERATIONS:LOAD PIPE SHED W/ 4 1/2" TBG - RUN COMPLETION 05/22/99 (D16) MW: 9.8 VISC: 43 PV/YP: 13/19 TD/TVD: 7575/5910 ( 0) SPACE OUT TBG HANGER SUPV:DEARL W. GLADDEN Run 4.5" tubing. UPCOMING OPERATIONS:SPACE OUT - TEST TBG & CSG APIWL: 3.2 05/23/99 (D17) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD/TVD: 7575/5910 ( 0) MOVING RIG TO 3H PAD SUPV:DEARL W. GLADDEN Freeze protect well. ND BOPE and NU Tree. UPCOMING OPERATIONS: MOVE RIG TO 3H PAD APIWL: 0.0 RECEIVED 2000 05/24/99 (D18) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7575/5910 ( 0) SUPV:DEARL W. GLADDEN Test tree, test pull not holding. Remove and redress. Reinstall test plug and test tree to 500/5000 psi. OK. Move rig off of well. Rig released ~ 0300 hrs. 5/24/99. UPCOMING OPERATIONS: RECEIVED ~',;',:'J 11 2000 1L-03A DESCRIPTION OF WORK COMPLETED COILED TUBING EXTENSION DRILLING OPERATIONS SUMMARY Date Event Summary 10/30/1999: 10/31/1999: 11/01/1999: 11/02-/1999: 11/03/1999: 11/04/1999: 11/05/1999: 11/06/1999: Move CTU f/Prudhoe Bay to Kuparuk.. Begin RU. Accept rig 1730 hrs. Continued MIRU of CTU. NU BOPE. Performed rig maintenance. Continued MIRU of CTU. Performed rig maintenance. Performed rig maintenance. PT'd BOPE. RIH w/BHA & circulated warm Seawater while RIH. Tagged wiper plugs @ 7462' MD. Circulated well to 10 ppg mud. Milled through wiper dart, landing collar, float collar, & float shoe. Drilled FM to 7575' MD. Milled FM to 7580' MD & POOH w/BHA. RIH w~ Bi-Centered Bit & drilled ahead to 7588'. Performed LOT to EMW of 11.5 ppg. Drilled to 7730'. Drilled to TD @ 7979' MD. Conditioned 4-1/8" OH for liner & POOH. MU 3-3/16" 6.2# TCII liner. RIH & landed the 3-3/16" liner @ 7978' MD. TOL = 6965'. PBTD = 7912'. Dropped ball & pressured to 2500 psi to shear/release liner. Cemented liner in place by pumping 10 bbls of 15.8 ppg Class G Cement (LARC). Launched dart & plug bumped. Squeezed to 500 psi. Unstung f/liner & POOH. RIH w/nozzle & cleaned out to 7909'. POOH displacing wellbore to 10 ppg brine to 2500'. FP'd to surface w/Diesel. Left 500 psi on wellbore. Began RDMOL. Completed RDMOL. Rig released 1000 hrs. RECEIVED ,.').5 1 1 2000 Naska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, K1(1L-03A(W4-6)) WELL JOB SCOPE JOB NU'MBER 1L-03A DRILLING SUPPORT-CAPITAL 1115992130.10 DATE DAILY WORK UNIT NUMBER 11/28/99 PERFORATE 2158 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 YES YES SWS-KI RKBY GOBER FIELD AFC# CC# Signed ESTIMATE AK0036 230DS10LG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 150 PSI 100 PSI 0 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY PERFORATE 7813'-7843', 7853.5'-7870.5' W/2" POWER JET, HC, DP, 6 SPF, 60 DEG PHASING, .20" EH, 18.6" PENETRATION, 6.5 I GMS[Perf] I TIME LOG ENTRY 07:00 LEAVE KIC FOR 1L PAD 07:30 MIRU ELINE AND ARRANGE TRIPLEX AND SLOP TANK, CAP PRESSURE GAUGE READS 150 PSI 08:45 PT TO 3000 PSI, PRESSURE GAUGE ON WIRELINE VALVES IS FROZEN AT 3000 PSI AFTER SWAB IS OPEN CANNOT COMPARE TO CAP GAUGE 09:15 10:15 10:45 11:15 RIH WITH GUN 1 (20 FT) TIED IN, WAIT FOR SHOT APPROVAL SHOOT GUN 1 7823'-7843' W/ 2" POWER JET, HC, DP, 6 SPF, 60 DEG PHASING - POOH - ALL SHOTS FIRED - HEAT UP PRESSURE GAUGE FROM WIRELINE VALVES INSIDE WHALE, REPLACE ON WIRELINE VALVES, WHP 5O PSI RD GUN 1, RU GUN 2 (17 FT) 11:45 RIH GUN 2 12:15 CORRELATE 12:45 SHOOT GUN 2 7853.5'-7870.5' W/2" POWER JET, HC, DP, 6 SPF, 60 DEG PHASING - POOH - ALL SHOTS FIRED - WHP 200 PSI 13:30 RD GUN 2, RU GUN 3 (10 FT) 14:00 RIH GUN 3 14:30 TIE IN AT FLAG, PULL SHORT PASS, ON DEPTH WAIT FOR APPROVAL 14:45 SHOT GUN 3 7813'-7823' W/2" POWER JET, HC, DP, 6 SPF, 60 DEG PHASING - POOH - ALL SHOTS FIRED 15:30 RD GUN, RISER WAS BLED BEFORE GETTING WHP FROM WIRELINE VALVES. CAP TEST SHOWED WHP AT 100 PSI. 16:30 LEAVE LOCATION 17:00 PASS BY THE KIC EN ROUTE TO DEADHORSE FOR MAINTENANCE RECEIVED ,';',!'J ] 'i 2:000 Na~ O# & ~s Certs. Commi~tm ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, K1(1L-03A(W4-6)) WELL JOB SCOPE JOB NUMBER " 1L-03A DRILLING SUPPORT-CAPITAL 1115992130.10 DATE DAILY WORK UNIT NUMBER 11/26/99 SLIM CEMENT MAPPING TOOL / PERF 2158 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 NOI YES SWS-KIRKBY GOBER FIELD AFC# CC# Signed ESTIMATE AK0036 230DS10LG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSI 250 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY IRUN SCMT LOG 7850'-5950' - GOOD CMT ABOVE PERF ZONE - PERFORATE 7775'-7795' W/2" HC, POWER JET, DP, 6 SPF, 60 DEG PHASING - GUN DID NOT FIRE ON 2ND RUN[Perf] TIME LOG ENTRY 07:00 PICK UP LOGGING UNIT FROM KIC AND DRIVE TO LOCATION 08:00 MIRU ELINE UNIT AND SCMT LOGGING TOOL 09:45 RIH WITH SCMT 11:15 CORRELATE TO MWD GR - 1:240 SCALE DIFFICULT TO READ 11:45 LOG 300' REPEAT UP FROM 7830 FT 12:00 LOG MAIN PASS IN 3 3/16" LINER TO ABOVE DEPLOYMENT SLEEVE 12:45 CHANGED SCMT SETTINGS FOR 4.5" PIPE, DROPPED BELOW DEPLOYMENT SLEAVE AND LOGGED UP ABOVE THE WINDOW AT 6000 FT RKB 13:30 POOH WITH SCMT 14:15 RD SCMT AND BEGIN PREPARING 20 FT GUN 15:00 RIH WITH 20 FT 2" HC GUN 15:45 CORRELATE 16:45 PERF 7775-7795' W/2" HC, POWER JET, DP, 6 SPF, 60 DEG PHASING. POOH WITH GUN 1 - ALL SHOTS FIRED 17:15 RD GUN 1 AND PREPARE ANOTHER 20 FT GUN 17:35 RIH WITH 20 FT GUN 18:30 CORRELATE 18:40 STOP ON DEPTH. FIRST SHOT ATTEMPT INDICATES CURRENT LEAK BELOW GUN GR, ATTEMPT 5 MORE TIMES TO DISCHARGE ESIC, CURRENT LEAK IS EVIDENT AT SURFACE. POOH. 19:30 BUMP UP IN LUBRICATOR. RIG DOWN, DISARM GUN, POWER UP TRUCK, HOT CHECK FAILS, REMOVE ESIC, HOT CHECK FAILS, REMOVE TOOL SAVER, HOT CHECK PASSES. TOOL SAVER CHECKED FOR ELECTRICAL INSULATION - SHOWS LEAK. 21:00 LEAVE LOCATION WITH LOGGER FOR KIC 21:30 DROP OFF LOGGER RECEIVED 2000 Naska 0ti & Gas Cons. Commission An~hora~ Survey Calculations ~[UOHgS Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLAN Company: ARCO Rig: Na bors 3s J ob No: 108587 Well: PAD 1L-03A Field: Kuparuk AFE No: AK-0036 Calculation Method: Minimum Curvatur¢ Mag. Declination: i26.690] !.' ?::. AP1 No: 50-029-211.82-01 Vertical Sect. Plane: 83~000 :]'. !:: .! TRUE Grid Correction: 0:300::'.i] .i i.' ::. BIII Rep: CItUCK SEYLER Vertical Sect. Plane: ?:. 'i ':: :.: i:: 'i :::: :: GRID Total Correction: 26.391} Job Start Date: ######## Measured Depth frown: RKB Dip: ' 80~57 ::i' ::i :'iii i.: Job End Date: ######## True Vertical Depth: Sca Level RKB Height: !'.!6i00.i Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Vertical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Co,inherits (deg) (den) (dog) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°/I00f't) (from 0,0) (°/100ft) (°/100f't) ii::iii:7502.¢[6'. 'i "!!:: 21~i7.!: ~ : ~ I : ~ : :: :.:3ti ! !i 30.81 i: ?..573::1!i89i ::i i::'i3!9~1:96 :: .:[i~96.:~5i i'::::: :::iS952~492:::29.:: .:..: :57~502 78 ': :!83 .~ .... :37.30..0¢:: :. 0.00 -1988.83 0.00 0.00 Tie In ::ii' ::75i53i00 i'..:.::.'i:':.2~5.100 i".:.i':i: ~3i:: Ii!.~ 30.81 5777.75 3213.15 -2385.07 5952511.04 537513.66 201.25 -719.12 0.57 -1975.71 0.57' 0.00~ IN CSG ::!: :: :754i!~00: ::::' i:: :::':::25:~0: ~ ::'.:.::':]i: :, 4:~i.~20,..: 41.40 5812.08 3226.23 -2375.40 5952524.16 537523.27 214.37 -709.51 12.19 -1964.52 2.37 27.87 BItA # 2 1.8° HP MTR · ;..:..76,:2[~00i :i ::: 'i :';29:80 : i ii:! 5240' 52.10 5850.11 3239.77 -2360.67 5952537.79 537537.92 228.00 -694.86 14.71 -1948.25 9.07 24.88 177574'-7972' ::: !::i!76~9:00. i.:::?i:i i'35i4:0ii :i ..' i/ :: :57'80 57.50 5879.60 3250.49 -2345.19 5952548.59 537553.35 238.80 -679.43 18.02 -1931.57 16.00 15.43 Average DLS=19.07° i7769~i.00..:i':::: i3813i~::: .;]" i'52:80 62.50 5903.60 3259.37 -2329.56 5952557.55 537568.93 247.76 -663.85 13.90 -1914.98 9.67 16.67 :::::i:77/29:.:00: :::i.i: ::i3::75k~0.:'i:i:.i; ::::72::170 72.40 5927.31 3266.34 -2312.58 5952564.61 537585.88 254.82 -646.90 20.45 -1897.27 -3.00 33.00 .7759:i00: : 38'2:0 ': .... 82 ii9 81.89 5951.04 3270.31 -2294.67 5952568.67 537603.76 258.88 -629.02 19.56 -1879.02 2.67 31.63 .i:. ::':~820~00;: :: i: ':. :.:: :: :' 3T70 ::' :i ?:i ?l~01! ,::2~:i 101.49 5999.32 3269.06 -2257.59 5952567.61 537640.85 257.82 -591.93 19.72 -1842.36 -0.82 32.13 i:: ! ]i:!785:.4~00::] i:i]::::"13~20 :: ::: :? ~12 i79i 112.49 6026.87 3263.23 -2238.58 5952561.88 537659.89 252.09 -572.89 21.57 -1824.20 -10.29 32.35 'i.:'::' ::'78i86;00:":' :::" :':304501' .:'! :!i!20':2"91 119.99 6053.91 3255.64 -2223.26 5952554.38 537675.25 244.59 -557.53 17.04 -1809.93 -11.56 23.44 i!.:ii:7954..06:!ii.i:::.:12~4~561 .:':[ !:3'7i;49 137.19 6087.68 3244.99 -2209.62 5952543.79 537688.95 234.00 -543.83 26.31 -1797.68 -16.32 45.26 :::' '.7946~00: : 'i 20;90 i'i::..12~41129 143.99 6107.99 3238.46 -2204.27 5952537.29 537694.33 227.50 -538.45 19.47 -1793.17 -15.45 30.91 · :: i:.797:8i00: : (:' 1T00 i i ::"{52'00 151.70 6138.26 3229.69 -2198.74 5952528.55 537699.91 218.76 -532.87 14.46 -1788.75 -12.19 24.09 PROJECTED TO TD · · 2000 5500- 5400 ~ 5500 ,.+_ 5600 5700 5800 5goo 60O0 I 6100 6200 6300 Tie-in Point ARCO Alaska, Inc. Structure : Pad 1L Field : Kuparuk River Unit Well : 1L-OSA, 50-029-21182-01 Location : North Slope, Alaska <-- West (feet) 2440 2420 2400 2380 2360 2340 2320 2300 2280 2260 2240 2220 2200 2180 2160 2140 2120 I I II { I I I I t I I I I II I t II I I I I I I I I I I I I I 3340 · -in Point RECEIVED ORIGINAL ed to TD ~_l ,_-o~ ,~ .ia. I 1L-O3bhs -- Projected to TD 1999 Dote plotted ; 30-Nov-1999 Plot Reference is 1L-03~ Coordinates ora in feet roi'atonce 1L-03. True Vertical Depths are reference RK8 - MSL - 116 ft. Sri~ Potnis 267-6615 --- Baker Hughe~ IN~Q --- i i i i i i i i i i i i i % i i i i i i i 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 Vertical Secfion (feet) -> Azimuth 85.00 with reference 0.00 N, 0.00 E from 1L-05 332O 3300 ~ 3280 3260 3240 3220 3200 3180 316O ARCO Alaska, Inc. Pad IL 1L-03A 1L-03 Kuparuk River Unit North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 1L-03A Our ref : svy251 License : 50-029-21182-01 Date printed : 30-Nov-1999 Date created : 30-Nov-1999 Last revised : 30-Nov-1999 Field is centred on 487754.621,5948985.821,999.00000,N Structure is centred on 540062.684,5948968o898,999.00000,N Slot location is n70 16 20.831,w149 40 37.780 Slot Grid coordinates are N 5949310.950, E 539915.570 Slot local coordinates are 342.86 N 145.31 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED ARCO Alaska, Inc. Pad 1L,1L-03A Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 1L-03A Last revised : 30-Nov-1999 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing. 7502.46 24.71 31.11 5731.89 7553.00 25.00 31.11 5777.75 7591.00 25.90 41.70 5812.08 7634.00 29.80 52.40 5850.11 7669.00 35.40 57.80 5879.59 3194.96N 2396.05W 1.34 -1988.83 537502.78 5952492.79 3213.14N 2385.08W 0.57 -1975.71 537513.66 5952511.04 3226.22N 2375.40W 12.19 -1964.52 537523.26 5952524.17 3239.77N 2360.67W 14.71 -1948.25 537537.92 5952537.79 3250.49N 2345.19W 18.02 -1931.57 537553.34 5952548.59 7699.00 38.30 62.80 5903.60 7729.00 37.40 72.70 5927.31 7759.00 38.20 82.20 5951.04 7820.00 37.70 101.80 5999.32 7854.00 34.20 112.80 6026.87 3259.37N 2329.56W 13.90 -1914.98 537568.92 5952557.55 3266.34N 2312.58W 20.45 -1897.27 537585.87 5952564.61 3270.31N 2294.67W 19.58 -1879.02 537603.75 5952568.68 3269.05N 2257.59W 19.72 -1842.37 537640.83 5952567.61 3263.21N 2238.58W 21.57 -1824.21 537659.87 5952561.88 7886.00 30.50 120.30 6053.90 7924.00 24.30 137.50 6087.68 7946.00 20.90 144.30 6107.99 7979.00 20.90 144.30 6138.82 3255.62N 2223.27W 17.04 -1809.94 537675.22 5952554.37 3244.97N 2209.63W 26.31 -1797.69 537688.92 5952543.79 3238.44N 2204.28W 19.47 -1793.18 537694.31 5952537.29 3228.88N 2197.41W 0.00 -1787.52 537701.23 5952527.77 RECEIVED 1999 Nadm 011 & Gas Cons. Commissi Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 1L-03 and SSTVD from RKB - MSL = 116 ft. Bottom hole distance is 3905.67 on azimuth 325.76 degrees from wellhead. Vertical section is from wellhead on azimuth 83.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,1L-03A Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 1L-03A Last revised : 30-Nov-1999 Comments in wellpath MD SSTVD Rectangular Coords. Comment 7502.46 5731.89 3194.96N 2396.05W Tie-in Point 7979.00 6138.82 3228.88N 2197.41W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised ........................................................................................................... 1L-03bhs 537610.000,5952525.000,999.00 6012.00 3226.59N 2288.65W 29-Ju1-1999 RECEIVED 1999 Maslm 0tl & Bas Oons. Cz~m~ Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1L, Slot 1L-03 1L-O3A Job No. AKMM90117, Surveyed: 20 May, 1999 SURVEY REPORT 7 June, 1999 Your Ref: API-500292118201 Surface Coordinates: 5949310.95 N, 539915.57 E (70° 16' 20.8308" N, Kelly Bushing: 116.00ft above Mean Sea Level 149° 40' 37.7801" W) ORIGINAL RECEIVED "~N 1 7 1999 Alaska Oil & Gas Cons. Commission An~o~'age sper~r',~j-sun D: R:I L L I ,,N,Ei ~i; E,,R V I I: Ei,,$ Survey Ref: svy8592 A tlAl,l,lfll~'rON COMPANY Sperry-Sun Drilling Services Survey Report for 1L-O3A Your Ref: API-500292118201 Job No. AKMM90117, Surveyed: 20 May, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 6000.00 44.450 309.630 4441.98 4557.98 2532.91 N 2384.15 W 5951831.17 N 537518.02 E 6018.00 44.310 309.560 4454.85 4570.85 2540.93 N 2393.85 W 5951839.15 N 537508.28 E 6116.00 42.260 323.460 4526.35 4642.35 2589.32 N 2439.97 W 5951887.29 N 537461.90 E 6212.70 37.290 330.150 4600.68 4716.68 2640.91 N 2473.94 W 5951938.70 N 537427.65 E 6307.71 32.050 331.710 4678.79 4794.79 2688.10 N 2500.23 W 5951985.75 N 537401.11 E 6404.79 29.530 334.930 4762.19 4878.19 2732.46 N 2522.58 W 5952030.00 N 537378.53 E 6501.75 28.310 336.400 4847.05 4963.05 2775.18 N 2541.92 W 5952072.61 N 537358.97 E 6599.31 27.520 345.730 4933.30 5049.30 2818.24 N 2556.74 W 5952115.59 N 537343.92 E 6696.86 27.820 359.940 5019.79 5135.79 2862.90 N 2562.33 W 5952160.22 N 537338.10 E 6792.53 30.000 15.920 5103.66 5219.66 2908.29 N 2555.78 W 5952205.65 N 537344.40 E 6891.18 31.380 24.750 5188.54 5304.54 2955.36 N 2538.25 W 5952252.81 N 537361.68 E 6987.98 30.240 26.150 5271.68 5387.68 3000.13 N 2516.95 W 5952297.69 N 537382.74 E 7085.79 28.220 29.760 5357.03 5473.03 3042.32 N 2494.62 W 5952340.00 N 537404.85 E 7180.14 26.690 35.420 5440.77 5556.77 3078.96 N 2471.26 W 5952376.76 N 537428.02 E 7276.53 25.170 34.150 5527.45 5643.45 3113.57 N 2447.20 W 5952411.50 N 537451.89 E 7373.38 25.310 32.110 5615.06 5731.06 3148.15 N 2424.64 W 5952446.20 N 537474.27 E 7471.47 25.120 31.280 5703.80 5819.80 3183.71 N 2402.68 W 5952481.87 N 537496.04 E 7502.46 24.710 31.110 5731.91 5847.91 3194.87 N 2395.92 W 5952493.07 N 537502.74 E 7571.00 24.710 31.110 5794.17 5910.17 3219.40 N 2381.12 W 5952517.68 N 537517.41 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.077° (20-May-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 323.513° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7571.00ft., The Bottom Hole Displacement is 4004.28ft., in the Direction of 323.513° (True). Alaska State Plane Zone 4 Kuparuk 1 L Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.824 9.933 6.777 5.593 3.101 1.456 4.546 6.758 8.366 4.774 1.391 2.740 3.205 1.679 0.910 0.409 1.343 0.000 3454.15 3466.37 3532.7O 3594.38 3647.95 3696.91 3742.75 3786.19 3825.41 3858.01 3885.43 3908.77 3929.40 3944.97 3958.49 3972.88 3988.41 3993.36 4004.28 TIE ON SURVEY WINDOW POINT PROJECTED SURVEY Continued... 7 June, 1999 - 11:33 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1L-O3A Your Ref: API-500292118201 Job No. AKMM90117, Surveyed: 20 May, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1 L Comments Measured Depth (ft) 6000.00 6018.00 7571.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4557.98 2532.91 N 2384.15 W 4570.85 2540.93 N 2393.85 W 5910.17 3219.40 N 2381.12 W Comment TIE ON SURVEY WINDOW POINT PROJECTED SURVEY 7 June, 1999 - 11:33 - 3 - DrillQuest Re: Kuparuk 1L-03A CTD Drillout PTD 99-037_.. Subject: Re: Kuparuk 1L-03A CTD Drillout PTD 99-037 Date: Thu, 21 Oct 1999 11:14:00-0800 From: Blair Wondzell <blair wondzell~admin, state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Danny T Kara <DKARA~mail.aai.arco.com> CC: Bruce E Smith <BESMITH~mail.aai.arco.com>, Lamar L Gantt <LGANTT~mail.aai.arco.c0m> Dan, Thanks for the heads-up on the CTD rig moving in to complete the well 1L-03A started by Nordic 3. Yes, operations can proceed under PTD 99-037. If you have questions, please call me at 793-1226. Blair Wondzell Danny T Kara wrote: > Blair, > ARCO Coiled Tubing Drilling (CTD) will be moving to Kuparuk within two weeks to > finish the 1L-O3A sidetrack. Nordic 3 sidetracked from 1L-03 and top-set the > Kuparuk sands with 4-1/2" liner in May of this year, under drilling permit > number 99-37. Mark Chambers with ARCO Drilling communicated with you and Jack > Hartz on or around 8/23/99 about the intent to have CTD complete the drillout. > Mr. Chambers was told CTD operations can operate under the original drilling > permit and Sundry approval is not required. You requested notification a couple > of weeks prior to commencement of operations. > Plan forward is for CTD to over-balance drill out of the 4-1/2" liner and > through the Kuparuk reservoir with a 10 ppg fluid. A 3-3/16" liner will be > cemented in place. > In the event reservoir pressure is greater than expected, dynamically > overbalanced drilling techniques will be employed. This will include the use of > ~10 ppg drilling fluid in combination with annular friction losses and applied > surface pressure to maintain overbalanced reservoir conditions. A hydraulic > choke for regulating surface pressure will be installed between the BOPE choke > manifolding and the mud pits and will be independent of the BOPE choke. At > least two times hole volume of kill weight fluid will be on location as a > contingency. Frequent monitoring and rolling of the kill weight fluid will be > done to ensure proper weight distribution. > Unless otherwise directed, we'll assume CTD operations can move forward under > drilling permit #99-37. 1 would appreciate it if you could acknowledge receipt > of this notification, either by calling me or E-mail. > Thanks for your time. > > Dan Kara > ARCO CTD > 263-4837 > dkara~mail, arco. com 1 ofl 10/21/99 ll:14AM WELL LOG TRANSMITTAL / To: State of Alaska Alaska Oil and Gas Conservation Cotton. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 17, 1999 ciq. 1L-03A, AK-MM-90117 The technical data listed below is being submitted herewith. Please 'address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1L-03A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21182-01 2" x 5" TVD Resistivity & Ganuna Ray Logs: 50-029-21182-01 2"x 5"MD Neutron & Density Logs: 50-029-21182-01 2" x 5" TVD Neutron& Density Logs: 50-029-21182-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia Blueline Folded Sepia 1 Blueline 1 Folded Sepia i : , - -.. 5631 Silverado Way, Suite G , Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 I::t I I_1-- I IM (~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1L-03A, August 12, 1999 AK-MM-90117 1 LDWG formatted Disc with verification listing. APl#: 50-029-21182-01 PLEASE ACKNOWLEDGE RECElPT BY SIGNING AND RETURNING THE ATrACItED COPY OF ~ TRANSMITTAL LET'rER TO THE ATrENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 07-Jun-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1L-03A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,000.00' MD 6,018.00' MD 7,571.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns.---. ~, Raga rd s, ~~.~~ f~% REC -IVED JUN 1 7 1999 William T. Allen Survey Manager Alaska 0il & Gas Cons. Commission Anoh0rage Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 25, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1L-03 Sidetrack (Top Set) Dear Blair, Per our conversation concerning the 1L-03 Sidetrack, I have attached a schematic of the original planned completion and a schematic showing the final top set completion run on 5/21/99. Before drilling into the reservoir, A LOT was performed immediately above the top of the C4-Sand. Results from the LOT indicated the well bore would not hold pressures exceeding 11.8 ppg EMW. Since projected reservoir pressure requires a 12.1 ppg EMW, the decision was made to set a 4-1/2" intermediate liner above the Kuparuk prior to drilling into the reservoir. Nordic 3 ran the 4-1/2" completion, shown on 1L-03 (Top Set) Schematic, and moved off the well. Presently, 1L-03 is scheduled for drill out and completion with a CTD Rig. The plan forward is to have coil move over well, drill out the liner and Kuparuk sands to approximately 7,921' MD / 6,206' TVD and run a 3-3/16" cemented liner. This work is tentatively scheduled for late July. Please call me at 265-1319 if you have any questions. Mark Chambers Drilling Engineer ARCO Alaska, Inc. Attachments: Well Schematic 1L-03 (Top Set) Completion Well Schematic 1L-03 Proposed Completion 4-1/2" liner top @ +/-5868' MD Top of whipstock @ +/- 6018' MD KOP / bottom of window @ +/- 6030' MD 1L-03A (Top Set) Completion K. 4-1/2" 5M FMC Gen IV tubing hanger with 4-1/2" L-80 BTC ABMod pin down J. 4-1/2", 12.6#, L-80 BTC ABMod tubing to surface I. 4' Crossover Pup Joint w/4-1/2" BTC Box x 4-1/2" EUE 8rd Pin. H. 4-1/2" Camco 'DB' landing nipple - 3.875" ID No-Go profile w/4-1/2" EUE 8rd Box x Pin set at +/-500' MD G. 4' Crossover Pup Joint w/4-1/2" EUE 8rd Box x 4-1/2" BTC Pin. F. 4-1/2", 12.6#, L-80, BTC ABMod Tubing to 'DB' Landing Nipple. E. 8' Crossover Pup Joint w/4-1/2" BTC Box x 4-1/2" EUE 8rd Pin. D. 4-1/2" Baker 'CMU' sliding sleeve - 3.812" Camco 'DB' No-Go profile w/4-1/2" EUE 8rd Box x Pin ( Run sleeve in closed position ). C. 8' Crossover Pup Joint w/4-1/2" EUE 8rd Box x 4-1/2" BTC Pin. B. I joint - 4-1/2", 12.6#, L-80 BTC ABMod Tubing A. Baker 4-1/2" seal assembly w/10' of seals and special Iocator to locate in liner tie back sleeve w/4-1/2" NSCT Box up (4.75" OD seals). 2' crossover pup installed w/4-1/2" BTC Box x 4-1/2" NSCT Pin. ~ !!_~,' :. r. :.~ . Liner Top: , .' .,. - Baker 12' Tieback Extension with 4.75" ID. ' - Baker 4-1/2" x 7" 'ZXP' Liner Top Isolation Packer. - Baker 4-1/2" x 7" 'HMC' Hydraulic Liner Hanger with 4-1/2" NSC'I~i~)~.~ Bridge Plug at +/-6032' MD 4-1/2", 12.6#, L-80, NSCT Tubing to Liner Hanger. Baker 'TYPE I' Landing Collar w/4-1/2" NSCT Box x Pin. 1 Joint 4-1/2", 12.6#, L-80, NSCT Tubing. Baker Float Collar w/4-1/2" NSCT Box x Pin. 2 Joints 4-1/2", 12.6#, L-80, NSCT Tubing. Baker 'V' Set Float Shoe w/4-1/2" NSCT Box up. 4-1/2" L-80 NSCT liner @ +/-7571' MD / 5910' TVD. Abandoned A Sand 7", 26#, J-55 casing @ 8323' MD Nordic 3 top set the 4-1/2" Liner above the C-4 Sand. The wells group will drill out the liner and the Kuparuk Sands with the CTD Rig, They will then run and cement a 3-3/16" liner across the Kuparuk Sands to a projected depth of 7921' MD / 6206' 'I-VD, Projected Formation Tops K-1 Marker 5890' TVD C-4 Sand 5984' TVD TD 7921' MD / 6206' TVD MAC 5/2O/99 Liner top and Whipstock Depth's are based on Original RKB from the 7" Csg Detail. These depths need to be converted to Nordic RKB. 4-1/2" liner top @ +/-5835' MD Top of whipstock @ +/- 5985'. MD KOP / bottom of window @ +/- 5997' MD Window in 7" I'L-03A PropOsed ompletion K. 4-1/2, 5M FMC Gen Iv tubing hanger with 4-1/2' L-80 BTC ABMod pin down J. 4-1/2", 12.6#, L-80 BTC ABMod tubing to surface I. 4' Crossover Pup Joint w/4-1/2" BTc Box x 4-1/2" EUE 8rd Pin. H. 4-1/2" Camco 'DB' landing nipple - 3.875" ID No-Go profile w/4-1/2" EUE 8rd Box x Pin set at +/-500' MD G. 4' Crossover PUp Joint w/4-1/2" EUE 8rd Box x 4-1/2" BTC Pin. F. 4-1/2", 12.6#, L-80, BTC ABMod Tubing to 'DB' Landing Nipple. E. 8' Crossover Pup Joint w/4-1/2" BTC Box x 4-1/2' EUE 8rd Pin. D. 4-1/2" Baker 'CMU' sliding sleeve - 3.812" Camco 'DB' No-Go profile w/4-1/2" EUE 8rd Box x Pin ( Run sleeve in closed position ). C. 8' Crossover Pup Joint w/4-1/2" EUE 8rd Box x 4-1/2" BTC Pin. B. I joint - 4-1/2", 12.6#, L-80 BTC ABM0d Tubing A. Baker 4-1/2" seal assembly w/10' of seals and special Iocator to locate in liner tie back sleeve w/4-1/2" NSCT Box up (4.75" OD seals). 2' crossover pup inslalled w/4-1/2' BTC Box x 4-1/2" NSCT Pin. Liner Top: - Baker 12' Tieback Extension with 4.75" ID. - Baker 4-1/2" x 7" 'ZXP' Liner Top Isolation Packer. - Baker 4-1/2" x 7" 'HMC' Hydraulic Liner Hanger with 4-1/2" NSCT pin down. Bridge Plug at +/-6005' MD Abandoned A Sand 7", 26#, J-55 casing @ 8323' MD Fill C Sand Future Perfs 4-1/2", 12.6#, L-80, NSCT Tubing to Liner Hanger. 2' Crossover Pup Joint w/4-1/2" NSCT Box x 4-1/2" EUE 8rd Pin. 4-1/2" Camco 'DB' landing nipple with 3.75" ID No-Go profile w/EUE 8rd Box x Pin. 2' Crossover Pup Joint w/4-1/2" EUE 8rd Box x 4-1/2" NSCT Pin. 4-1/2", 12.6#, L-80,-NSCT Tubing to Camco 'DB' Nipple. 4-1/2" Halliburton Polish Nipple - 3.75" ID polish bore w/4-1/2" NSCT Pin x Pin 4-1/2', 12.6#, L-80, NSCT Tubing to Halliburton Polish Nipple. Baker 'TYPE I' Landing Collar w/4-1/2' NSCT Box x Pin. 1 Joint 4-1/2", 12.6#, L-80, NSCT Tubing. Baker Float Collar w/4-1/2" NSCT Box x Pin.. 2 Joints 4-1/2", 12.6#, L-80, NSCT Tubing. Baker 5/' Set Float Shoe w/4-1/2" NSCT Box up. A Sand 4-1/2" L-80 NSOT liner @ +/-7921' MD. BDN/MAC 4/12/99 TONY KNOWLE$, GOVERNOR ALAS~ OILAND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 30, 1999 Mr. Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0361 Kuparuk River Unit I L-03A ARCO Alaska, Inc. Permit No: 99-37 Sur. Loc. 343'FSL, 144'FEL, Sec. 30, T11N, R10E, UM Btmhole Loc. 1587'FNL, 2379'FEL, Sec. 30. T11N, R10E, UM Dear Mr. Alvord: Enclosed is thc approved application for permit to redrill thc above referenced well. The permit to redrill docs 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 thc MI test before operation, and of the BOPE test performed bcforc drilling below thc surface casing shoe. must be given so that a representative of the Commission may witness thc tests. Notice may be given by contacting the Commission petroleum field inspector on thc North Slope pager at 659-36O7. Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work: Drill [] Redrill [] I lb. Typeoiwelli" Explorato;~ [] Str~tigra~hicTestD Development Oil E] Re-entry [] Deepen []I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 31' Pad 81 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0361 ADL 25659 ALK 2585 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 343' FSL, 144' FEL, Sec. 30, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1643' FNL, 2421' FEL, Sec. 30, T11N, R10E, UM 1L-03A #U-630610 At total depth 9. Approximate spud date Amount 1587' FNL, 2379' FEL, Sec. 30, T11N, R10E, UM April 30, 1999 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) 1587' @ TD feetI 1L-04 1239' @ 7921' feet 2560 8323 ' MD / 6230 ' TV• 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 5996' MD Maximum hole angle 44 MaXimum surface 3094 psig At total depth C-VD) 3750 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantib/of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TV• (include sta,cje data) 6.125" 4.5" 12.6# L-80 NSCT 2091' 5830' 4436' 7921' 6206' 56 bbls Class G sidetrack - top of window @ 5984' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 8475 feet Plugs (measured) true vertical 6331 feet Effective Depth: measured 8241 feet Junk(measured)ORIGINAL true vertical 6176 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 93' 16" 235 sx CS II 93' 93' Surface 2071' 9.625" 720 sx ASlII, 250 sx Class G 2071' 1897' Production 8323' 7" 575 sx Class G & 200 sx AS I 8323' 6230' Liner Perforation depth: measured 7978'-7998', 8018'-8054', 8064'-8078' ... ' ¢. true vertical 5998'-6012', 6025'-6050', 6057'-6136' 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling programr~! Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Call Mark Chambers 265-131~. Signorinas.. ~ F-mi~ C/.//*~ ~t,*~ Title: DdllingEngineeringSuperv~sor Date Chip AIvord (/# Prp_n~r~cl hv .C;h~rnn AIl.~un-I')r~k~ Oommission Use Permit~u~ber J APl ,umber Approval date .,, Isee cover letter )'~/"" *-~ YI 50- O 2.. ~~ .'" ,Z,//"~;~',,~_. -- O / ~"~'",,,.~-~ ¢¢ Jfor other requirements Conditior~s of approval Samples required [] Yes ,,~ No Mud Icg required [] Yes /~ No Hydrogen sulfidemeasures '~ Yes [] No Directional surveyrequired ~ Yes [] No Required working pressure for BOPE [] 2M; [] 3M; [] 5M; [] lOM;r'l J~ "~ Other: by order of ORIGINAL SIGNED BY Commissioner the commission Date '''~ Approved by RohCr~ I~ ,-,, . ..... hds[enson ................... R~Jhmit in trinlicate Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail. These depths need to be converted to Nordic RKB. 4-1/2" liner top @ +/-5830' MD Top of whipstock @ +/- 5984' MD KOP / bottom of window @ +/- 5996' MD Window in 7" 1L-03A Proposed Completion G. 4-1/2" 5M FMC Gen IV tubing hanger with 4-1/2" L-80 BTC ABMod pin down F. 4-1/2", 12.6#, L-80 BTC ABMod tubing to surface E. 4-1/2" Camco 'DB' landing nipple with 3.875" ID No-Go profile set at +/-500' MD D. 4-1/2", 12.6#, L-80 ABMod tubing to 'DB' landing nipple C. 4-1/2" Baker 'CMU' sliding sleeve w/3.812" Camco 'DB' No-Go profile. Sleeve run in closed position B. 1 joint - 4-1/2", 12.6#, L-80 BTC ABMod tubing A. Baker 4-1/2" seal assembly w/10' of seals and special Iocator to locate in liner tie back sleeve Liner ToD: - Baker 12' Tieback Extension with 4.75" ID. - Baker 4-1/2" x 7" 'ZXP' Liner Top Isolation Packer. - Baker 4-1/2" x 7" 'HMC' Hydraulic Liner Hanger with 4-1/2" NSCT pin down. Bridge Plug at +/-6005' MD 4-1/2" Camco 'DB' landing nipple with 3.75" ID No-Go profile 4-1/2" Camco 'A' seating nipple with 3.75" ID polish bore Abandoned A Sand 7", 26#, J-55 casing @ 8323' MD C Sand Future 4-1/2" L-80 NSCT liner Perfs @ +/-7921' MD. A Sand BDN/MAC 4/12/99 EDRILL PLAN SUMMARY Well 1 L-03A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: INJECTOR 1643' FNL, 2421' FEL, SEC 30, T11 N, R10E, UM 1587' FNL, 2379' FEL, SEC 30, T11 N, R10E, UM 7,921' 6,206' Nordic Rig 3 4/3O/99 10 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate Yo Solids Milling Window in 7" casing 9.8 16-24 16-24 45-55 5-8 7-10 4-5 9.0-9.5 7-9 Kick off to weight up 9.8 16-24 16-24 45-55 5-8 7-10 4-5 9.0-9.5 7-9 Weight up to TD 12.4 26-36 22-32 50-68 8-10 10-13 3-4 9.0-9.5 15-17 Drilling Fluid System: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Casing/Tubing Program: Hole size Csg/'l'bg Liner 6-1/8" 4-1/2", 12.6#, L-80, NSCT Tubing 4-1/2", 12.6#, L-80, BTC AB Mod Length Top (MD/I'VD) Btm (MD/TVD) 2,038' 5,830' / 4,436' 7,921' / 6,206' 5,803' 27' / 27' 5,830' / 4,436' KRU 1L-03 A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK (P&A): 1. RU slickline unit. RIH gauge tubing and tag fill. Last tag was 8134' MD RKB on 11/25/89. Pressure test 7" casing to 3500 psi for 30 min (chart test). . . '4. 5. 6. 7. RU CTU. RIH and establish injection rate into perforations. Record breakdown pressure and rate. Note final injection rate and pressure. RIH with inflatable cement retainer on CTU and set retainer at +/-7887' MD RKB (middle of 15'x 3-1/2" pup joint in tubing tail below retrievable packer). Squeeze at least 16.5 bbls of 15.8 ppg Class G cement below retainer (9 bbl for the 3-1/2" and 7" volume below the retainer down to top of fill at 8134' MD RKB + 7.5 bbls into perfs). If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and circulate well clean immediately on top of inflatable retainer. Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. Bleed annulus pressure to 0 psi. Pressure test tubing above inflatable retainer to 2500 psi for 30 min (chad test). Slowly bleed tubing pressure to 0 psi. (monitor pressure for build-up). RU slickline unit. RIH and pull 1" DV from bottom GLM at 7821' MD RKB, leaving an open pocket. RU E-line unit. RIH and cut tubing at +/-7843' MD RKB. Remove well house and scaffolding. Prepare location for Nordic 3. WORKOVER RIG WORK: 1. MIRU Nordic 3. Lay hard-line to tree. 2. Verify well is dead. Load pits w/water. Circulate well to water. 3. Set BPV. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. 5. PU 7" Casing Scrapper on DP and run through Packer setting depth. 6. RU E-Line Unit. RIH and set Bridge Plug at +/- 6,005' MD. 7. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, Etc and RIH. Orient and set whipstock w/MWD. Shear off whipstock bolt and test wellbore to 3500 psi, testing packer and cement plug to ensure isolation from perforations. Circulate well to milling fluid, and mill window in 7" casing. POOH and LD milling assembly. RIH w/6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, perform FIT test, kick-off well, and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. Note: Mud should be weighted up +/- 200' MD above estimated top of Kuparuk. Run 4-1/2" liner to TD w/150' of overlap to top of milled window. 10. Cement liner. Set liner hanger and liner top packer. POOH w/DP. , o 11. Pressure test casing and linei ,ap to 3500 psi for 30 min (Chart Test for St~..~). 12. RIH w/completiOn assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 14. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 9 days Expected Case: 10 days Upper Limit: 15 days No problems milling window, drilling new hole, or running completion. Difficulties encountered milling window, or drilling new hole. MAC 4/1 O~99 For: NOEL] 45OO 4600 4700 480O 4900 5000 5100 5200 5500 5400 5500 5600 I V 5700 5800 5900 6000 6100 6200 6300 6400 T~e-ln Pt MAXIMUM ANGLE 44.45 DEG TARGET ANGLE 29.47 DEG Sfruafure: Pad 1l Well : 5A Reid : Kuparuk Rlver Unlf Looaflon: North Slope, a Point ...... TTe-ln Pt C50 EOC C30 (~K-2) C20 (HRZ Mid Point) BASE HRZ K- 1 Marker TOP C4 TOP B SHALE TOP TOP TOP A(4) / TARGET TO / 4 1/2 CS(:; PT PROFILE COMMENT DATA MD Inc Dir TVD North East V. Sect Deg/lOC 5996.05 44.45 ~09.63 4554.00 2533.01 -2~84.27 3440.71 O.OC 6670.65 26.82 1.61 5112.00 2844.87 -2567.22 $801.19 5.0C 6997.79 29.47 36.29 5402.38 2984.46 -2517.17 5887.27 5.0¢ 7199,51 29,47 36,29 5578,00 3064.45 -2458.45 3919.43 0.00 7550.44 29.47 56.29 5692.00 5116.36 -2420.33 5940.31 0.00 7464.85 29.47 36.29 5809.00 5169.65 -2581.21 5961.74 0.00 7536.04 29.47 36.29 5871.00 3197.89 -2560.47 5975.09 0.00 7644.00 29.47 56.29 5965.00 3240.70 -2329.04 3990.31 0.00 7652.04 29.47 56.29 5972.00 5245.88 -2526,70 599t.59 0.00 7759.54 29.47 36.29 6048.00 3278.50 -2501.29 4005.51 0.00 7750.82 29.47 36.29 6058.00 3285.05 -2297.94 4007.34 0.00 7779.54 29.47 56.29 6085.00 5294.44 -2289.5§ 4011.92 0.00 7920.81 29.47 56.29 6206.00 5550.45 -2248.46 4054.45 0.00 <- West (feet) 5400 3200 5000 2800 2600 2400 2200 2000 1800 I I I I I I I I I I I I I TO LOCATION: 1587' FNL, 2379' FEL SEC. 50, T11N, R10E ~.~ SEC. ~0, T11N, RIOE EOC ~ C~O ~e-ln Pt C20 (HRZ Mid Point) ~E HRZ ~ K-1 Ma~er TOP A(4) / TARGa m/. ,/~ cso PT 5600 3400 3200 5000 z 2800 0 2600 ~ -.I- 2400 ~ 22OO 2000 1800 395.g0 AZIMUTH 4018' (TO TARGET) eeePlane at Proposal*** i i i i i i i i i i i i i i i i i i i 3400 3500 3600 3700 3BOO 3900 4000 4100 4200 4500 4400 4500 VerticalSection (feet)-> Azimuth 525.20 with reference 0.00 N, 0.00 E from slot 44O0 4200 4000 5800 36OO 3400 3200 3OOO A 2800 I '"~ 2600 2400 0 Z 2200 2000 1800 1600 1400 1200 1000 800 600 ARCO Alaska, Inc. Sfruafure : Pad IL Well : 5A Field: Kupar~k River Unlf Loo~lon : North Slope, Alaska < West (feet) 3600 5400 5200 5000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 I I I I I I t I I I I I I I I I I I I I I I I I I I I I I I I 4200 4000 3800 5600 5200 000 5200 460C 5200 3000 2800 2600 62007~.] 8oo /6000 5600 ~' 5800 ,.%oo '..,.5400 /5400 ~00 ,~5200 ~ood~ 5ooo 4600 4400 [ ~~6°° 000 ] I i i i t i i i i I i i I i i i i ii i i i i i i i i i i i $600 3400 5200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 <- West (feel) 4400 4200 4000 3800 3600 3400 5200 3000 2800 /~ 2600 0z 2400 ~ --i- 2200 ~ 2000 1800 1600 1400 1200 1000 8O0 600 Creal~ed by:. A~drews For: NOEL] 320 33o 340 ARCO Alaska, Inc. Strualure: Pc~l 1L Well: 3A Field : Kuparuk R~ver Unlt Laaatlan: North Slope, Alaska TRUE NORTH 350 0 10 2O 5O 4O 510 5O 500 6O 290 7O 280 8O 270 9O 260 100 25O 110 240 120 230 130 220 210 2OO 190 180 170 160 150 140 Normal Plane Travelling Cylinder- Feet All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Pad 1L 3A slot #3A Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 3A Version #2a Our ref : prop3385 License : Date printed : 6-Apr-99 Date created : 5-Apr-99 Last revised : 6-Apr-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 40 33.55 Slot location is n70 16 20.832,w149 40 37.742 Slot Grid coordinates are N 5949311.121, E 539916.862 Slot local coordinates are 343.00 N 144.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1L,3A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A Depth Degrees Degrees Depth C 0 0 R D I N A T E 5996.03 6000.00 6100.00 6200.00 6300.00 44.45 309.63 4554.00 2533.01 N 2384 44.30 309.81 4556.84 2534.79 N 2386 40.56 314.75 4630.65 2580.06 N 2436 37.08 320.47 4708.58 2626.23 N 2478 33.91 327.14 4790.02 2672.94 N 2513 6400 6500 6600 6670 6700 .00 .00 .00 .63 .00 PROPOSAL LISTING Page 1 Your ref : 3A Version#2a Last revised : 6-Apr-99 6800.00 6900.00 6997.79 7000.00 7199.51 R Dogleg Vert S Deg/lOOft Sect 7330.44 7464.83 7500.00 7536.04 7644.00 .27 W 0.00 .41 W 5.00 .35 W 5.00 .66 W 5.00 .00 W 5.00 7652.04 7739.34 7750.82 7779.54 7920.81 31.16 334.92 4874.35 2719.83 N 2539.12 W 28.96 343.89 4960.94 2766.56 N 2556.82 W 27.43 353.98 5049.12 2812.75 N 2565.96 W 26.82 1.61 5112.00 2844.87 N 2567.22 W 26.69 4.86 5138.23 2858.07 N 2566.47 W 26.81 15.98 5227.58 2902.16 N 2558.35 W 27.78 26.69 5316.50 2944.69 N 2541.66 W 29.47 36.29 5402.38 2984.46 N 2517.17 W 29.47 36.29 5404.30 2985.34 N 2516.53 W 29.47 36.29 5578.00 3064.45 N 2458.45 W 29.47 36.29 5692.00 3116.36 N 2420.33 W 29.47 36.29 5809.00 3169.65 N 2381.21 W 29.47 36.29 5839.62 3183.60 N 2370.97 W 29.47 36.29 5871.00 3197.89 N 2360.47 W 29.47 36.29 5965.00 3240.70 N 2329.04 W 3243.88 N 2326.70 W 3278.50 N 2301.29 W 3283.05 N 2297.94 W 3294.44 N 2289.58 W 3350.45 N 2248.46 W 29.47 36.29 5972.00 29.47 36.29 6048.00 29.47 36.29 6058.00 29.47 36.29 6083.00 29.47 36.29 6206.00 3440.71 Tie-In Pt 3443.38 3509.06 3571.12 3629.08 5.00 3682.49 5.00 3730.96 5.00 3774.10 5.00 3801.19 C50 5.00 3811.61 5.00 3843.18 5.00 3868.58 5.00 3887.27 EOC 0.00 3887.62 0.00 3919.43 C30 (K-2) 0.00 3940.31 C20 (HRZ Mid Point) 0.00 3961.74 BASE HRZ 0.00 3967.35 0.00 3973.09 K-1 Marker 0.00 3990.31 TOP C4 0.00 3991.59 TOP B SHALE 0.00 4005.51 TOP A(6) 0.00 4007.34 TOP A(5) 0.00 4011.92 TOP A(4) 1L-O3B 4/1/99 0.00 4034.45 TD / 4 1/2" CSG PT All data is in feet unless otherwise stated. Coordinates from sl°t #3A and TVD from RKB (Nordic III) (112.00 Ft above mean sea level). Bottom hole distance is 4034.98 on azimuth 326.13 degrees from wellhead. Total Dogleg for wellpath is 50.09 degrees. Vertical section is from wellhead on azimuth 325.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,3A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 3A Version #2a Last revised : 6-Apr-99 Comments in wellpath MD TVD Rectangular Coords. Comment 5996.03 4554.00 2533.01 N 2384.27 W Tie-In Pt 6670.63 5112.00 2844.87 N 2567.22 W C50 6997.79 5402.38 2984.46 N 2517.17 W EOC 7199.51 5578.00 3064.45 N 2458.45 W C30 (K]2) 7330.44 5692.00 3116.36 N 2420.33 W C20 (HRZ Mid Point) 7464.83 5809.00 3169.65 N 2381.21 W BASE HRZ 7536.04 5871.00 3197.89 N 2360.47 W K-1 Marker 7644.00 5965.00 3240.70 N 2329.04 W TOP C4 7652.04 5972.00 3243.88 N 2326.70 W TOP B SHALE 7739.34 6048.00 3278.50 N 2301.29 W TOP A(6) 7750.82 6058~00 3283.05 N 2297.94 W TOP A(5) 7779.54 6083.00 3294.44 N 2289.58 W TOP A(4) 1L-O3B 4/1/99 7920.81 6206.00 3350.45 N 2248.46 W TD / 4 1/2" CSG PT Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 5996.03 4554.00 2533.01N 2384~27W 7920.81 6206.00 3350.45N 2248.46W 4.5" Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised TOP A(4) 1L-O3B 4/1/ 537610.000,5952593.000,0.0000 6083.00 3294.44N 2289.58W 25-Jan-99 ARCO Alaska. Inc. Pad 1L.3A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 44.45 309.63 44.30 309.81 40.56 314.75 37.08 320.47 O0 33.91 327.14 O0 31.16 334.92 O0 28.96 343.89 O0 27.43 353.98 63 26.82 1.61 O0 26.69 4.86 5996.03 6000.00 6100.00 6200.00 6300. 6400. 6500. 6600. 6670. 6700. 6800.00 26.81 6900.00 27.78 6997.79 29.47 7000.00 29.47 7199.51 29.47 4554.00 4556.84 4630.65 4708.58 4790.02 4874.35 4960.94 5049.12 5112.00 5138.23 15.98 5227.58 26.69 5316.50 36.29 5402.38 36.29 5404.30 36.29 5578.00 7330.44 29.47 36.29 5692.00 7464.83 '29.47 36.29 5809.00 7500.00 29.47 36.29 5839.62 7536.04 29.47 36.29 5871.00 7644.00 29.47 36.29 5965.00 7652.04 29.47 36.29 5972.00 7739.34 29.47 36.29 6048.00 7750.82 29.47 36.29 6058.00 7779.54 29.47 36.29 6083.00 7920.81 29.47 36.29 6206.00 RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : 3A Version #2a Last revised : 6-Apr-99 Dogleg Vert Deg/lOOft Sect 2876.01 N 2528.27 W 0.00 2877.79 N 2530.41 W 5.00 2923.06 N 2580.35 W 5.00 2969.23 N 2622.66 W 5.00 3015.94 N 2657.00 W 5.00 3062.83 N 2683.12 W 5.00 3109.56 N 2700.82 W 5.00 3155.75 N 2709.96 W 5.00 3187~87 N 2711.22 W 5.00 3201.07 N 2710.47 W 5.00 3245.16 N 2702.35 W 5.00 3287.69 N 2685.66 W 5.00 3327.46 N 2661.17 W 5.00 3328.34 N 2660.53 W 0.00 3407.45 N 2602.45 W 0.00 3459.36 N 2564.33 W 0.00 3512.65 N 2525.21 W 0.00 3526.60 N 2514.97 W 0.00 3540.89 N 2504.47 W 0.00 3583.70 N 2473.04 W 0.00 3586.88 N 2470.70 W 0.00 3621.50 N 2445.29 W 0.00 3626.05 N 2441.94 W 0.00 3637.44 N 2433.58 W 0.00 3693.45 N 2392.46 W 0.00 3440.71 Tie-In Pt 3443.38 3509.06 3571.12 3629.08 3682.49 3730.96 3774.10 3801.19 C50 3811.61 3843.18 3868.58 3887.27 EOC 3887.62 3919.43 C30 (K-2) 3940.31 C20 (HRZ Mid Point) 3961.74 BASE HRZ 3967.35 3973.09 K-1 Marker 3990.31 TOP C4 3991.59 TOP B SHALE 4005.51 TOP A(6) 4007.34 TOP A(5) 4011.92 TOP A(4) 1L-O3B 4/1/99 4034.45 TD / 4 1/2" CSG PT All data is in feet unless otherwise stated. Coordinates from NW Corner of SEC. 32. T11N, RIOE and TVD from RKB (Nordic III) (112.00 Ft above mean sea level). Bottom hole distance is 4034.98 on azimuth 326.13 degrees from wellhead. Total Dogleg for wellpath is 50.09 degrees. Vertical section is from wellhead on azimuth 325.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes 'INTEQ ARCO Alaska, Inc. Pad 1L, 3A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 3A Version #2a Last revised : 6-Apr-99 Comments in wellpath MD I~/D Rectangular Coords. Comment 5996.03 4554.00 2876.01N 2528.27 W Tie-In Pt 6670.63 5112.00 3187.87 N 2711.22 W C50 6997.79 5402.38 3327.46 N 2661.17 W EOC 7199.51 5578.00 3407.45 N 2602.45 W C30 (K-2) 7330.44 5692.00 3459.36 N 2564.33 W C20 (HRZ Mid Point) 7464.83 5809.00 3512.65 N 2525.21 W BASE HRZ 7536.04 5871.00 3540.89 N 2504.47 W K-1 Marker 7644.00 5965.00 3583.70 N 2473.04 W TOP C4 7652.04 5972.00 3586.88 N 2470.70 W TOP B SHALE 7739.34 6048.00 3621.50 N 2445.29 W TOP A(6) 7750.82 6058.00 3626.05 N 2441.94 W TOP A(5) 7779.54 6083.00 3637.44 N 2433.58 W TOP A(4) 1L-O3B 4/1/99 7920.81 6206.00 3693.45 N 2392.46 W TD / 4 1/2" CSG PT Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 5996.03 4554.00 2876.01N 2528.27W 7920.81 6206.00 3693.45N 2392.46W 4.5" Targets associated with this wellpath Target name GeograPhic LOcation T.V.D. Rectangular Coordinates Revised TOP A(4) 1L-O3B 4/1/ 537610.000,5952593.000,0.0000 6083.00 3637.44N 2433.58W 25-$an-99 ARCO Alaska, Inc. Pad 1L,3A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A Depth Degrees Degrees Depth C 0 0 R D 5996.03 44.45 309.63 4554.00 2533.01 N 6000.00 44.30 309.81 4556.84 2534.79 N 6100.00 40.56 314.75 4630.65 2580.06 N 6200.00 37.08 320.47 4708.58 2626.23 N 6300.00 33.91 327.14 4790.02 2672.94 N 6400.00 31.16 334.92 4874.35 2719.83 N 6500.00 28.96 343.89 4960.94 2766.56 N 6600.00 27.43 353.98 5049.12 2812.75 N 6670.63 26.82 1.61 5112.00 2844.87 N 6700.00 26.69 4.86 5138.23 2858.07 N 6800.00 26.81 15.98 5227.58 2902.16 N 6900.00 27.78 26.69 5316.50 2944.69 N 6997.79 29.47 36.29 5402.38 2984.46 N 7000.00 29.47 36.29 5404.30 2985.34 N 7199.51 29.47 36.29 5578.00 3064.45 N 7330.44 29.47 36.29 5692.00 3116.36 N 7464.83 29.47 36.29 5809.00 3169.65 N 7500.00 29.47 36.29 5839.62 3183.60 N 7536.04 29.47 36.29 5871.00 3197.89 N 7644.00 29.47 36.29 5965.00 3240.70 N 7652.04 29.47 36.29 5972.00 3243.88 N 7739.34 29.47 36.29 6048.00 3278.50 N 7750.82 29.47 36.29 6058.00 3283.05 N 7779.54 29.47 36.29 6083.00 3294.44 N 7920.81 29.47 36.29 6206.00 3350.45 N PROPOSAL LISTING Page 1 Your ref : 3A Version #2a Last revised : 6-Apr-99 N G U L A R Vert Ellipse Semi Axes Minor I N A T E S Sect Major Minor Vert. Azi. 2384.27 W 3440.71 76.35 23.93 21.44 316.92 2386.41W 3443.38 76.39 23.94 21.45 316.91 2436.35 W 3509.06 77.38 24.30 21.79 316.88 2478.66 W 3571.12 78.40 24.66 22.10 316.92 2513.00 W 3629.08 79.39 25.03 22.39 317.05 2539.12 W 3682.49 80.31 25.41 22.67 317.26 2556.82 W 3730.96 81.13 25.80 22.93 317.55 2565.96 W 3774.10 81.84 26.21 23.18 317.91 2567.22 W 3801.19 82.25 26.52 23.36 318.21 2566.47 W 3811.61 82.43 26.65 23.43 318.33 2558.35 W 3843.18 82.91 27.12 23.68 318.80 2541.66 W 3868.58 83.28 27.68 23.93 319.31 2517.17 W 3887.27 83.54 28.33 24.19 319.86 2516.53 W 3887.62 83.55 28.35 24.19 319.87 2458.45 W 3919.43 84.16 30.29 24.73 321.10 2420.33 W 3940.31 84.57 31.57 25.09 321.91 2381.21W 3961.74 84.98 32.88 25.45 322.74 2370.97 W 3967.35 85.09 33.22 25.55 322.95 2360.47 W 3973.09 85.22 33.67 25.65 323.21 2329.04. W 3990.31 85.62 35.00 25.94 323.98 2326.70 W 3991.59 85.65 35.10 25.96 324.04 2301.29 W 4005.51 85.97 36.19 26.20 324.66 2297.94 W 4007.34 86.02 36.33 26.24 324.74 2289.58 W 4011.92 86.12 36.68 26.31 324.95 2248.46 W 4034.45 86.70 38.56 26.70 326.05 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 5996 ARCO (H.A. Gyro) User specified 76.35 23.93 21.44 5996 7921 ARCO (H.A. Mag) User specified 86.70 38.56 26.70 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. All data is in feet unless otherwise stated. Coordinates from slot #3A and TVD from RKB (Nordic III) (112.00 Ft above mean sea level). Bottom hole distance is 4034.98 on azimuth 326.13 degrees from wellhead. Vertical section is from wellhead on azimuth 325.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L, 3A Kuparuk River Unit, North S1 ope, A1 aska PROPOSAL LISTING Page 2 Your ref : 3A Version #2a Last revised : 6-Apr-99 Comments in wellpath MD TVD Rectangular Coords. Comment 5996.03 4554.00 2533.01 N 2384.27 W Tie-In Pt 6670.63 5112.00 2844.87 N 2567.22 W C50 6997.79 5402.38 2984.46 N 2517.17 W EOC 7199,51 5578.00 3064.45 N 2458.45 W C30 (K-2) 7330.44 5692.00 3116.36 N 2420.33 W C20 (HRZ Mid Point) 7464.83 5809.00 3169.65 N 2381.21W BASE HRZ 7536.04 5871.00 3197.89 N 2360.47 W K-1 Marker 7644.00 5965.00 3240.70 N 2329.04 W TOP C4 7652.04 5972.00 3243.88 N 2326.70 W TOP B SHALE 7739.34 6048.00 3278.50 N 2301.29 W TOP A(6) 7750.82 6058.00 3283.05 N 2297.94 W TOP A(5) 7779.54 6083.00 3294.44 N 2289.58 W TOP A(4) 1L-O3B 4/1/99 7920.81 6206.00 3350.45 N 2248.46 W TD / 4 1/2" CSG PT Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 5996.03 4554.00 2533.01N 2384.27W 7920.81 6206.00 3350.45N 2248.46W 4.5" Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised TOP A(4) 1L-O3B 4/1/ 537610.000,5952593.000,0.0000 6083.00 3294.44N 2289.58W 25-Jan-99 ARCO Alaska, Inc. Pad 1L, 3A Kuparuk River Unit, North Slope, A1 aska Measured Inclin Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 5996.03 44.45 309.63 4554.00 2533.01N 6000.00 44~30 309.81 4556.84 2534.79N 6100.00 40.56 314.75 4630.65 2580.06N 6200.00 37.08 320.47 4708.58 2626.23N 6300.00 33.91 327.14 4790.02 2672.94N 6400.00 31.16 334.92 4874.35 2719.83N 6500.00 28.96 343.89 4960.94 2766.56N 6600.00 27.43 353.98 5049.12 2812.75N 6670.63 26.82 1.61 5112.00 2844.87N 6700.00 26.69 4.86 5138.23 2858.07N 6800.00 26.81 15.98 5227.58 2902.16N 6900.00 27.78 26.69 5316.50 2944.69N 6997.79 29.47 36.29 5402.38 2984.46N 7000.00 29.47 36.29 5404.30 2985.34N 7199.51 29.47 36.29 5578.00 3064.45N 7330.44 29.47 36.29 5692.00 3116.36N 7464.83 29.47 36.29 5809.00 3169.65N 7500.00 29.47 36.29 5839.62 3183.60N 7536.04 29.47 36.29 5871.00 3197.89N 7644.00 29.47 36.29 5965.00 3240.70N PROPOSAL LISTING Page 1 Your ref : 3A Version#2a Last revised : 6-Apr-99 U L A R Dogleg Vert G R I D C 0 0 R D S A T E S Deg/lOOft Sect Easting Northing 2384.27W 0.00 3440.71 537519.38 5951831.16 2386.41W 5.00 3443.38 537517.23 5951832.92 2436.35W 5.00 3509.06 537467.05 5951877.93 2478.66W 5.00 3571.12 537424.50 5951923.86 2513.00W 5.00 3629.08 537389.91 5951970.39 2539.12W 5.00 3682.49 537363.55 5952017.13 2556.82W 5.00 3730.96 537345.60 5952063.76 2565.96W 5.00 3774.10 537336.22 5952109.90 2567.22W 5.00 3801.19 537334.79 5952142.01 2566.47W 5.00 3811.61 537335.47 5952155.21 2558.35W 5.00 3843.18 537343.35 5952199.34 2541.66W 5.00 3868.58 537359.82 5952241.95 2517.17W 5.00 3887.27 537384.09 5952281.85 2516.53W 0.00 3887.62 537384.73 5952282.73 2458.45W 0.00 3919.43 537442.38 5952362.14 2420.33W 0.00 3940.31 537480.22 5952414.25 2381.21W 0.00 3961.74 537519.05 5952467.74 2370.97W 0.00 3967.35 537529.22 5952481.74 2360.47W 0.00 3973.09 537539.63 5952496.08 2329.04W 0.00 3990.31 537570.83 5952539.06 7652.04 29.47 36.29 5972.00 3243.88N 2326.70W 0.00 3991.59 537573.16 5952542.26 7739.34 29.47 36.29 6048.00 3278.50N 2301.29W 0.00 4005.51 537598.38 5952577.~00 7750.82 29.47 36.29 6058.00 3283.05N 2297.94W 0.00 4007.34 537601.70 5952581.57 7779.54 29.47 36.29 6083.00 3294.44N 2289.58W 0.00 4011.92 537610.00 5952593.00 7920.81 29.47 36.29 6206.00 3350.45N 2248.46W 0.00 4034.45 537650.83 5952649.23 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3A and TVD from RKB (Nordic III) (112.00 Ft above mean sea level). Bottom hole distance is 4034.98 on azimuth 326.13 degrees from wellhead. Total Dogleg for wellpath is 50.09 degrees. Vertical section is from wellhead on azimuth 325.20 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1L,3A Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 2 Your ref : 3A Version#2a Last revised : 6-Apr-99 Comments in wellpath MD TVD Rectangular Coords. Comment 5996.03 6670.63 6997.79 7199.51 7330.44 7464.83 7536 04 7644 O0 7652 04 7739 34 7750 82 7779 54 7920 81 4554.00 2533.01N 2384.27W Tie-In Pt 5112.00 2844.87N 2567.22W C50 5402.38 2984.46N 2517.17W EOC 5578.00 3064.45N 2458.45W C30 (K-2) 5692.00 3116.36N 2420.33W C20 (HRZ Mid Point) 5809.00 3169.65N 2381.21W BASE HRZ 5871.00 3197.89N 2360.47W K-1 Marker 5965.00 3240.70N 2329.04W TOP C4 5972.00 3243.88N 2326.70W TOP B SHALE 6048.00 3278.50N 2301.29W TOP A(6) 6058.00 3283.05N 2297.94W TOP A(5) 6083.00 3294.44N 2289.58W TOP A(4) 1L-O3B 4/1/99 6206.00 3350.45N 2248.46W TD / 4 1/2" CSG PT Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 5996.03 4554.00 2533.01N 2384.27W 7920.81 6206.00 3350.45N 2248.46W 4.5" Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised TOP A(4) 1L-O3B 4/1/ 537610.000,5952593.000.0.0000 6083.00 3294.44N 2289.58W 25-$an-99 ARCO Alaska, Inc. Pad 1L 3A slot#3A Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 3A Version #2a Our ref : prop3385 License : Date printed : 6-Apr-99 Date created : 5-Apr-99 Last revised : 6-Apr-99 Field is centred on n70 16 18'.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 40 33.55 Slot location is n70 16 20.832,w149 40 37.742 Slot Grid coordinates are N 5949311.121, E 539916.862 Slot local coordinates are 343.00 N 144.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PMSS <O-lO065'>,,26,Pad 1L PGMS <0-12532'>,,2A-C,Pad 1L PGMS <0-10345'>,,23,Pad 1L PGMS <O-9241'>,,24,Pad 1L PGMS <0-8700'>,,17,Pad 1L PGMS <0-7950'>,,13,Pad 1L PGMS <O-10176'>,,22,Pad 1L PGMS <O-12550'>,,21,Pad 1L PGMS <0-9353'>,,25,Pad 1L PGMS <O-7478'>,,1,PadlL PGMS <0-6469'>,,14,Pad 1L PGMS <0-7800'>, 18,Pad 1L PGMS <0-6721'> ,2,Pad 1L PGMS <0-7795'>.,5,Pad 1L PGMS <0-8470'> ,6,Pad 1L PGMS <0-9369'>, 11,Pad 1L PGMS <0-8103'>, 12,Pad 1L PGMS <0-6704'>, 15,Pad 1L PGMS <0-7830'>, 16,Pad 1L PGMS <0-8839'>, 19,Pad 1L PGMS <0-7668'> ,4,Pad 1L PGMS <0-6700'> ,7,Pad 1L PGMS <0-10125'> ,9,Pad 1L PGMS <0-7810'> ,8,Pad 1L PGMS <0-9100'>,,lO,Pad 1L PMSS <O-11500'>,,20,Pad 1L PMSS <0-4285'>,,3PB1,Pad 1L Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28-0ct-98 5762.2 5996.0 7572.0 1-Jul-91 5116.9 5996.0 7200.0 18-Feb-99 5191.7 5996.0 7700.0 18-Feb-99 5632.9 5996.0 5996.0 18-Feb-99 4926.2 5996.0 5996.0 18-Feb-99 4779.6 5996.0 5996.0 9-May-91 5576.0 5996.0 7128.0 20-Jun-91 5376.4 5996.0 7881.0 28-0ct-98 5594.7 5996.0 7905.0 9-May-91 2046.8 5996.0 5996.0 1-Jul-91 4740.7 5996.0 5996.0 1-~ul-91 5043.9 5996.0 7281.0 9-May-91 2679.5 7359.0 7359.0 9-May-91 3549.4 5996.0 7920.8 9-May-91 4635.4 5996.0 5996.0 9-May-91 5455.0 5996.0 7626.0 9-May-91 5152.1 5996.0 5996.0 9-May-91 4074.6 5996.0 5996.0 9-May-91 3898.5 5996.0 5996.0 9-May-91 5667.7 5996.0 7779.0 9-May-91 1239.1 7920.8 7920.8 9-May-91 4014.3 5996.0 5996.0 9-May-91 5009.9 5996.0 5996.0 9-May-91 4678.1 5996.0 5996.0 9-May-91 5069.0 5996.0 5996.0 12-May-91 5245.4 5996.0 5996.0 6-Apr-99 1715.7 5996.0 5996.0 7-1/16" 5OOO PSI BOP STACK 6 PIPE RAM. ~= I I 5 BLIND RAM~= MUD CROSS 4 3 PIPE RAM I I 1 11" - 3000 PSI CASING HEAD 2.11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16" - 5000 PSI DRLG SPOOL W/CHOKE & KILL UNES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL UNE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. SEC 31 SEC 32 . . ~' ~ NO SCA~ ~CINI~ MAP SCA~: 1"~ 2 ~ILES · ~1 ~C. ~C. PAD O.O. No. ,~ A.~.P.~ 'X' ~~DE ~ON~I~DE ~ ~ ~ I ~OCA~D ~7~IN P~O~AC~TD SEC. JO, ~ ~., ~.~0 E. F.~.~.F.E.~. I 5,949,190.90 539,916. 79 70~6'1&650' 149'~'3Z 765' 223' 1~' 81.8 2 5,949,250.87 539,916.27 ~ 70~6'20.2~" 149'40'~7. 769' 28~' 1~' 81.5 ~ 5,949,310,95 539,915.57 70~6'20.~31' 149'~'37. 780' 34~' 1~' ' 81.2 4 5,949,370.89 539,914.96 70~6'21.420' i 149'~'~7. 789' 40~' 1~' ' ~81.1 LOCA~D ~TY/N PRO~AC~D SEC. 29, ~11 t~., R. 10 E. F.S.L.~L. 5 5,949,374.47 5~,275.01 70~6'21.4~7" 149'~'27.305' ]~4' 216' 81.9 6 5,949,314.55 5~,275.61 70~6'20.847' 149'~'27.296 3~' 216' 82.0 7 5,949,254.59 5~,276.20 70~6'20.257' 149'~'2Z289' 284' 216' 82.2 8 5,949,194.52 5~,276. 79 70~6'19.667' I49'~'27.281" 224' 216' 82.4 9 5,949,224.81 5~,276.28 70~6'19.964" 149'~'27.291' 255' 216' 86.0 82.4 10 5,949,134.55 5~,277.45 70~6'19.077' 149'~'27.271' 164' 216' 86.0 82.4 ~ 20 ' 5,949,074.61 5~,27&08 70~6'1& ~7' 149'~'2Z262' 104' 216' 86.2 82.2 ~ , NO ~S 1. ~lS DRA~NG IN~UDES INF~MA~ ~ DRA~NGS NSK 6.112-d17 ~d dlB & N~ 9.05.112-dl ond d2. Z ~IS P~T R~EC~ CURR~T NUMB~ING S~M ~L~ NO ~R~Y CONDUCED ~IS DA ~ AND NO C~CA~ON AS TO ACCURACY ~ AS-BUILT L~A~S /S MADE BY ~iS P~ ~. CO,DINArS ~0~ ARE A.S.P. ZONE 4, N.A.D. 27. E~VA~S ~0~ ARE BRI~ PE~~M MEAN SEA 4. BASLE ~ L~A~S AND ~VA~ONS ARE D.S. 1--L MONUM~ P~ ~D AND ASS~IA~S. 5. CONDUCTUS ~E LOCA~D ~/N PRO~AC~D SEC'S. 29, 30, 31 ~ 32, ~11 N., R. 10 E., UMIAT MERIDIAN, AK. ~ ~ ~ I~ ~RCO D~. NO.: NSDK 1LO0 ~ ~ ~ CEA-D1~-6112D20 SHT 001 = ~ t ~ SUR ~YOR'S CER ~FICA ~ ~CO ~ka,~e. ~ , , . REGIS~REO AND U~D ~ PRAC~CE DRILL SI~ I-L ~JD SUR~NG IN ~E ST~ ~ ~SKA · ~.~ t~5 _,.'~ AND ~A T ~lS P~ T REPRE~ A ~LL CONDUCTOR '~;~~. _/~ SURLY DONE BY ME ~ UNDER MY DIRECT L OCA ~ON AS-BUlL ~ ~~~ ~9~ SUP~Z~ON AND ~A T A~ DIMEN~ONS fRE-P~ T) · .~.~- JA~U~ 25, ~. ~OU~U~Y · ~SOC. Rev. By Dete Description Do[e: 1~25/91 ~wg:N~ 6.112-d20 Well SEC. SEC. PAD O. G. No. ,y, A.S.P.~ 'X' LATITUDE LONGfTUD£ Uo,~ LOI,~ ELEV. ELEV. LOCATED ~IHIN PROTRAC~D SEC. 50, T. 11 L, R. 10 E. F.S.L.F.£.L. I 5,949,190.90 539,916. 79 70'16'19.650" 149'40'37. 763" 223' 144' 81.8 2 5,949,250.87 539,916.27 70'16'20.240" 149'40'37. 769" 283' 144' 81.5 3 5,949,310.95 539,915.57 70'16'20.851' 149'40'37. 780' 343' 144' 81.2 4 5,949,370.89 539,914.96 70'16'21.420" 149'40'37. 789" 403' 144' 81.1 LOCATED H47¥/N PROTRACi~ED SEC. 29, 7'.11 t~., R. 10 E. F.S.L.F-.kKL 5 5,949,374.47 540,275.01 70'16'21.437" 149'40'27.305" 404' 216' 81.9 6 5,949,314.55 540,275.61 70'16'20.847" 149'40'27.296 344' 216' 82.0 7 5,949,254.59 540,276.20 70'16'20.257" 149'40'27.289" 284' 216' 82.2 8 5,949,194.52 540,276. 79 70'16'19.667" I49'40'27.281" 224' 216' 82.4 9 5,949,224.81 540,276.28 70'16'19.964" 149'40'27.291" 255' 216' 86.0 82.4 10 5,949,134.53 540,277.45 70'16'19.077' 149'40'27.271" 164' 216' 86.0 82.4 20' 5,949,074.61 540,278.08 70'16'18.407" 149'40'27.262" 104' 216' 86.2 82.2 D~F]LE /1~1.D~ AAI PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776. ARCO Alaska, Inc. v ~-.~ ~.~..~.. 205088669 ~ PAY TO THE ORDER OF: The First Nati0n~i' Bank: o~ ch'icago-0710 Chicago;~ I II inois Payable ThroUgh Republic Bank Shelbyville, Kentucky MARCH 8, 1999 0997579 i:: ALASKA DEPT OF REVENUE ALASKA OIL & GAS:CONSERVATION COMMI , : 3001 PORCUPINE :DRIVE' ' ,~;~: fY:olD,AFTER 90 DAYS *** :: i ':~: .: , . ~ ~' ;: i' ~EXACTLY *********~*ilO0 DOLLARS AND O0 CENTS $***********100.00 TRACE NUMBER: 205088669 "' 8D 5OS.°.r-.r=~,' ,:O.°.~,~Oh 8r= WELL PERMIT CHECKLIST COMPANY ~ ~ C ~ WELL NAME l~'~/~ ~ I L- ¢,~f'-~ PROGRAM: exp __ dev redrll /~ serv X wellbore seg ann. disposal para req ~ FIELD & POOL INITCLASS ..~'~¢- 1- L/J'i/~J GEOLAREA ~(~ UNIT# ~-~'~'O/~O ON/OFFSHORE .... ADMINISTRATION A~,R DATE 1. Permit fee attached ....................... ~ 2. Lease number appropriate ................... ~a--N 3. Unique well name and number .................. (~ N 4. Well located in a defined pool .................. ~ N 5. Well located proper distance from drilling unit boundary .... ,~ N 6. Well located proper distance from other wells .......... '~ N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... (~ N 9. Operator only affected party ...................~ N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N ENGINEERING APPR DATE 14. Conductor string provided ................... (~7) 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 ........ Y 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 "~ ~ ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N N N GEOLOGY A, .1~_~ DATE ANNULAR DISPOSAL APPR DATE 30. 31. 32. 33. 34. 35. Permit can be issued w/o hydrogen sulfide measures.._~.~___,._-~ Y N Data presented on potential overpressu~r.e-~b~. ...... Y N Seismic analysis of shal~e,s ............. Y N . Seabed conditio~f off-shore) ............. Y N Contact n one for weekly progress reports [exploratory only] Y N With proper cementing records, this plan (A) will contain waste in a suitable ~ng zone; ....... (B) will not contaminate freshw,~; or cause drilling waste... Y N to surface; (C) will not impair mec~ical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOL.~..~: ENGINEERING: UIC/Ann/~- COMMISSION: RPC__~_ BEW~.~-~'(~'~. WM ~ DWJ ~"~'~- JDH ~ RNC co Comments/Instructions: c:\m soffice\wordian\diana\checklist Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX, No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Aug 10 13:12:48 1999 Reel Header Service name ............. LISTPE Date ..................... 99/08/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/08/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. qq . Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUN]D LEVEL: MWD RUN 2 AK-MM-90117 K. FERGUSON D. WESTER 1L-03A 500292118201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 10-AUG-99 MWD RUN 3 AK-MM-90117 R. KRELL D. GLA/DDIN 30 liN 10E 343 144 116.00 116.00 85.90 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 6030.0 6.125 7571.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA ttAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CNP) AND STABILIZED LITHO DENSITY (SLD) . 4. MO COMPENSATED THERMAL NEUTRON POROSITY DATA PRESENTED FROM MWD RUN 2. THE DATA WAS COLLECTED BEHIND CASING. 5. MWD DATA HAS BEEN DEPTH SHIFTED/CORRECTED USING THE 1L-03 OH-FDN WL-GR LOGGED ON 20 SEPTEMBER, 1984 BY SCHLUMBERGER. SPERRY-SUN MWD DATA IS THE PRIMARY DEPTH CONTROL (PDC) FOR WELL 1L-03A. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7570'MD, 5910'TVD. SROP = SMOOTHED tlATE OF PENETtlATION 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. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE' SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. EAIVIRONMENTAL PAR31METERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = MUD WEIGHT = MUD SALINITY = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = 6.125" 9.7 - 10.0 PPG. 16500 PPM CL- 13600 PPM CL- 1.oo G/CC 2.65 G/CC SAMDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP PEF DRHO RHOB FET RPD RPM RPS RPX FCNT NCNT NPHI $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH 5988 0 6014 5 6029 5 6029 5 6029 5 6029 5 6029 5 6029 5 6029 5 6029 5 6032 0 6032 0 6032 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 5988.0 5989.0 5992.5 5994.5 6011.0 6024.0 7569.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: GR 5987.5 5988 5 5993 0 5995 5 6011 5 6024 5 7570 0 STOP DEPTH 7515 0 7569 5 7493 5 7493 5 7493 5 7522 0 7522 0 7522 0 7522 0 7522 0 7478 0 7478 0 7478 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 6015.0 6123.0 3 6123.0 7570.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BAP~N 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF Min 5988 1.09 45 66 0 76 0 78 0 77 0 83 0 66 19 96 -26154.2 160.97 2.18 -0.17 1.17 Max 7569.5 481 86 492 15 11 24 11 37 10 36 10 45 123 41 51 62 29885.4 623.59 3.29 0.77 7.49 Mean Nsam 6778.75 3164 60.6645 3111 154.371 3055 2.42358 2986 2.47253 2986 2.44283 2986 2.4942 2986 3.50519 2986 36.7548 2893 19998 2893 268.697 2893 2.38071 2929 0.0692386 2929 3.46811 2929 First. Reading 5988 6014.5 5988 6029.5 6029.5 6029.5 6029.5 6029.5 6032 6032 6032 6029.5 6029.5 6029.5 Last Reading 7569.5 7569.5 7515 7522 7522 7522 7522 7522 7478 7478 7478 7493.5 7493.5 7493.5 First Reading For Entire File .......... 5988 Last Reading For Entire File ........... 7569.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5987 5 6068.5 ROP 6015 0 6123.0 PEF 6030 0 6047.0 DRHO 6030 0 6047.0 RHOB 6030 0 6047.0 FET 6030 0 6075.5 RPD 6030 0 6075.5 RPM 6030 0 6075.5 RPS 6030 0 6075.5 RPX 6030 0 6075.5 $ LOG HEADER DATA DATE LOGGED: 17-MAY-99 SOFTWARE SURFACE SOFTWARE VERSION: I3.23 DOWNHOLE SOFTWARE VERSION: 5.16/2.41/10.87/0.37/8.28 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6123.0 TOP LOG INTERVAL (FT) : 6015.0 BOTTOM LOG INTERVAL (FT) : 6123.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 46.0 MAXIMI/M ANGLE: 46.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P1310MGRV4 DGR DUAL GAMMA RAY P1310MGRV4 CTN COMP THERMAL NEUTRON P1310MGRV4 SLD $ STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER2kTURE (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 STAAIDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P1310MGRV4 6.130 6.1 LSND 10.00 42.0 10.5 16500 16.0 .240 .158 .210 .320 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 RHOB MWD 2 G/CC 4 1 68 32 9 DRHO MWD 2 G/CC 4 1 68 36 10 PEF MWD 2 BARN 4 1 68 40 11 102.5 Name Min DEPT 5987.5 GR 45.66 RPX 1.96 RPS 2.4 RPM 2.55 RPD 2.62 ROP 1.09 FET 2.85 RHOB 2.3 DRHO -0.01 PEF 2.6 Max 6123 138.31 3.88 4.27 4 09 4 29 202 96 123 41 2 53 0 16 6 84 Mean Nsam 6055.25 272 87.682 163 2.77587 92 2.835 92 2.83 92 2.90261 92 31.2094 217 38. 9902 92 2. 39314 35 0.0605714 35 4.98571 35 First Reading 5987.5 5987.5 6030 6030 6030 6030 6015 6030 6030 6030 6030 Last Reading 6123 6068.5 6075.5 6075.5 6075.5 6075.5 6123 6075.5 6047 6047 6047 First Reading For Entire File .......... 5987.5 Last Reading For Entire File ........... 6123 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE AIUMBER: 3 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 6032.5 NCNT 6032.5 NPHI 6032.5 PEF 6048.0 DI{HO 6048.0 STOP DEPTH 7478.5 7478.5 7478.5 7494.0 7494.0 RHOB 6048 0 GR 6069 5 FET 6076 5 RPD 6076 5 RPM 6076 5 RPS 6076 5 RPX 6076 5 ROP 6123 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REA_L-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 7494 0 7515 5 7522 5 7522 5 7522 5 7522 5 7522 5 7570 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 20 -MAY- 99 I3.23 5.16/2.41/10.87/0.37/8.28 MEMORY 7570.0 6123.0 7570.0 25.2 42.3 TOOL NUMBER P1310MGRV4 P1310MGRV4 P1310MGRV4 P1310MGRV4 6.130 6.1 LSND 9.80 43.0 9.5 17000 3.0 .230 .130 .180 .520 132.3 .6 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block Sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 ROP MWD 3 FT/H 4 1 68 FET MWD 3 HOUR 4 1 68 NPHI MWD 3 P.U. 4 1 68 FCNT MWD 3 CNTS 4 1 68 NCNT MWD 3 CNTS 4 1 68 RHOB MWD 3 G/CC 4 1 68 DRHO MWD 3 G/CC 4 1 68 PEF MWD 3 BA/~N 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min DEPT 6032.5 GR 60.32 RPX 0.76 RPS 0.78 RPM 0.77 RPD 0.83 ROP 1.27 FET 0.66 NPHI 19.96 FCNT 160.97 NCNT -26154.2 RHOB 2.18 DRHO -0.17 PEF 1.17 Max 7570 492 15 11 24 11 37 10 36 10 45 481 86 19 08 51 62 623 59 29885.4 3.29 0.77 7.49 Mean Nsam 6801.25 3076 158.074 2893 2.41227 2893 2.4609 2893 2.43041 2893 2.48113 2893 62.8731 2894 2.3759 2893 36.7548 2893 268.697 2893 19998 2893 2.38056 2893 0.0693363 2893 3.45003 2893 First Reading 6032 5 6069 5 6076 5 6076 5 6076 5 6076 5 6123 5 6076 5 6032 5 6032 5 6032 5 6048 6048 6048 Last Reading 7570 7515.5 7522.5 7522.5 7522.5 7522.5 7570 7522.5 7478.5 7478.5 7478.5 7494 7494 7494 First Reading For Entire File .......... 6032.5 Last Reading For Entire File ........... 7570 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/08/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/08/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
