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Home My WebLink About204-231 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 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 1D-34 50-029-22975-00 200143_1D-34_CHC_02Aug2022 1D-36 50-029-22973-00 200130_1D-36_RBP_19Jul2023 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 _1E-12L1 50-029-20736-60 210004_1E-12_JetCutter_12Jun2022 210004_1E-12_MechCutter_06Jun2022 210004_1E-12_SBHPS-RBP-LDL_03Jun2022 2of 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 T38317 T38318 T38321 T38322 T38323 T38324 T38325 T38326 T38327 T38328 2/29/2024 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:18:42 -09'00' 1 Regg, James B (OGC) From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Thursday, March 9, 2023 11:22 AM To:Regg, James B (OGC) Cc:CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael; Abbas, Sayeed; Krysinski, Marina L Subject:LPP/SSV Returned to Service on CPAI Well 1E-102 on 03.01.23 Good Morning Jim, The low pressure pilot (LPP) on well 1E 102 (PTD#204 231,204 232)was returned to service and removed from the Facility Defeated Safety Device Logon 03/01/2023 as the well has been shut in for the foreseeable future due to continued suspected communication with an offset producer. The LPP had been defeated on 06/16/2022 after a significant injection pressure reduction (due to well communication with an offset producer)could not satisfy the LPP. This notification is in accordance with Administrative Approval No. CO 406B.001. Please let me know if you have any questions. Thank you, Will Parker Production Engineer GKA (CPF1 West Sak) ConocoPhillips |Alaska, Inc Office: 907.265.6239 (x7234)|Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Monday, June 20, 2022 5:45 AM To:Jim Regg <jim.regg@alaska.gov> Cc:CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com> Subject:Defeated LPP/SSV on CPAI Well 1E 102 on 6/16/2022 Jim, The low pressure pilot (LPP) on well 1E 102 (PTD#204 231,204 232)was defeated on 6/16/2022, after the well lost its well head injection pressure due to communication with offset producer. The well is currently injecting at a rate of 750 BWPD and wellhead injection pressure of 5 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log. The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." 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. 2 Please let me know if you have any questions. Thank you, Toon Toon Changklungdee WestSak Production Engineer Office: (907) 659 7234 / (907) 265 1375 Cell: (303) 564 7586 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-102 KUPARUK RIV U WSAK 1E-102 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 1E-102 50-029-23236-00-00 204-231-0 W SPT 3653 2042310 1500 14 14 14 14 194 205 205 203 4YRTST P Lou Laubenstein 6/26/2022 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 U WSAK 1E-102 Inspection Date: Tubing OA Packer Depth 1380 2200 2160 2160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220626140148 BBL Pumped:1.5 BBL Returned:1.5 Thursday, July 21, 2022 Page 1 of 1          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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI Well 1E-102 on 6/16/2022 Date:Monday, June 20, 2022 9:01:11 AM KRU 1E-102 (PTD 2042310) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, June 20, 2022 5:45 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1E-102 on 6/16/2022 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD# 204-231, 204-232) was defeated on 6/16/2022, after the well lost its well head injection pressure due to communication with offset producer. The well is currently injecting at a rate of 750 BWPD and wellhead injection pressure of 5 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee WestSak Production Engineer kr�uC )----1(D2 Regg, James B (CED) P7h ZZ47-310 From: NSK West Sak Prod Engr <n1638@conocophillips.com> �, I /d�� Sent: Tuesday, June 23, 2020 8:30 PM rl To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv, CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; NSK Optimization Engr Subject: LPP/SSV Returned to Service on CPAI Well 1 E-102 on 6/22/2020 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD# 204-231, 204-232) was returned to service and removed from the "Facility Defeated Safety Device Log" last night on 6/22/2020, after the well was shut in following a MBE diagnostic wellwork completion. The LPP had been defeated on 6/8/2020 when the well was brought back on injection for diagnostic wellwork. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW7XHVGD\-XQH$0 7R5HJJ-DPHV%2*& 6XEMHFW):>(;7(51$/@5(.58(3DGQRQZLWQHVVHG0,7,$V WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗tĞůů/ŶƚĞŐƌŝƚǇ^ƉĞĐŝĂůŝƐƚW&ϭΘW&ϯфŶϭϲϭϳΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂǇ͕:ƵŶĞϭϰ͕ϮϬϮϮϭϬ͗ϮϭD dŽ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁Z͗<ZhϭͲWĂĚŶŽŶǁŝƚŶĞƐƐĞĚD/d/Ɛ WŚŽĞďĞ͕ zĞƐƚŚĞĐŽƌƌĞĐƚĚĂƚĞŝƐϲͬϭͬϮϮ͘/ĐŽƌƌĞĐƚĞĚŽƵƌĐŽƉǇ͘dŚĂŶŬƐĨŽƌĐĂƚĐŚŝŶŐƚŚĂƚ͊ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &ƌŽŵ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗DŽŶĚĂǇ͕:ƵŶĞϭϯ͕ϮϬϮϮϭϭ͗ϭϭD dŽ͗tĞůů/ŶƚĞŐƌŝƚǇ^ƉĞĐŝĂůŝƐƚW&ϭΘW&ϯфŶϭϲϭϳΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗<ZhϭͲWĂĚŶŽŶǁŝƚŶĞƐƐĞĚD/d/Ɛ CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. .58( 37' ĐŽƌƌĞĐƚĚĂƚĞŝƐϲͬϭͬϮϮ͘ :ĂŶ͕ tŝůůǇŽƵǀĞƌŝĨǇƚŚĞĚĂƚĞŽĨƚĞƐƚŝŶŐ͍dŚĞĨŝůĞŶĂŵŝŶŐĐŽŶǀĞŶƚŝŽŶŝŶĐůƵĚĞĚϲͬϭͬϮϮ͕ďƵƚƚŚĞƌĞƉŽƌƚĚĂƚĞŝŶĐůƵĚĞĚϲͬϮͬϮϮ;/͛ŵ ĂƐƐƵŵŝŶŐŝƚƐŚŽƵůĚďĞϲͬϭͿ͍ 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. &ƌŽŵ͗tĞůů/ŶƚĞŐƌŝƚǇ^ƉĞĐŝĂůŝƐƚW&ϭΘW&ϯфŶϭϲϭϳΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕:ƵŶĞϮ͕ϮϬϮϮϭ͗ϮϴWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ> ;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗<ZhϭͲWĂĚŶŽŶǁŝƚŶĞƐƐĞĚD/d/Ɛ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1800390 Type Inj N Tubing 450 525 525 525 Type Test P Packer TVD 5941 BBL Pump 3.3 IA 290 3180 3050 3030 Interval V Test psi 3000 BBL Return 3.3 OA 105 300 245 215 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1820780 Type Inj N Tubing 1050 1150 1150 1150 Type Test P Packer TVD 6090 BBL Pump 1.5 IA 484 2000 1900 1885 Interval 4 Test psi 1523 BBL Return 1.4 OA 180 300 300 300 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821100 Type Inj N Tubing 1550 1650 1650 1650 Type Test P Packer TVD 6019 BBL Pump 1.3 IA 860 2500 2450 2440 Interval 4 Test psi 1505 BBL Return 1.3 OA 200 320 320 320 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1830170 Type Inj N Tubing 950 950 950 950 Type Test P Packer TVD 5970 BBL Pump 1.1 IA 500 1800 1750 1730 Interval 4 Test psi 1500 BBL Return 1.2 OA 320 410 420 420 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821700 Type Inj N Tubing 1500 1500 1500 1500 Type Test P Packer TVD 5940 BBL Pump 1.7 IA 560 2400 2290 2275 Interval 4 Test psi 1500 BBL Return 1.7 OA 40 40 40 40 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2042310 Type Inj N Tubing 50 50 50 50 Type Test P Packer TVD 3655 BBL Pump 1.2 IA 247 1800 1740 1730 Interval 4 Test psi 1500 BBL Return 1.2 OA 158 160 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2050060 Type Inj N Tubing 300 350 350 350 Type Test P Packer TVD 3512 BBL Pump 3.1 IA 234 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 2.3 OA 138 140 138 138 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040310 Type Inj N Tubing 275 425 425 425 Type Test P Packer TVD 3024 BBL Pump 0.6 IA 245 1800 1710 1700 Interval 4 Test psi 1500 BBL Return 0.5 OA 145 190 152 146 Result P 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 1E-105 1E-119 Notes: 1E-19 1E-25 1E-102 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanicall Integrityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 1E-16 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1E Pad N/A Arend / Richwine 06/02/22 Notes:MITIA to MAIP per AIO 2C.076 Notes: Notes: Notes: 1E-01 1E-13 Form 10-426 (Revised 01/2017)2022-0601_MIT_KRU_1E-pad_8wells 9 9 9 9 9 9 -5HJJ 1E-102 last I E do z Pit Z�MZ31 C) Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, June 8, 20204:21 PM j��y �(9(�2� To: Regg, James B (CED) ff�� Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; NSK Optimization Engr Subject: Defeated LPP/SSV on CPAI Well 1 E-102 on 6/8/2020 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD# 204-231, 204-232) was defeated today, 6/8/2020, after the well was brought back on injection for diagnostic wellwork. The well is currently injecting at a rate of 1500 BWPD and wellhead injection pressure of -8 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Toon Changklungdee/ Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 wcq ► t -toZ Prb Ze4 z310 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, March 22, 2019 3:07 PM3'II To: Regg, James B (DOA) ft Cc: CPF1 Ops Supv; CPF1 DS Lead Techs; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt; Autry, Sydney, Braun, Michael (Alaska); Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI Well 1E-102 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD #204-231, 204-232) was returned to service and removed from the "Facility Defeated Safety Device Log" on 3/21/2019, after the well was shut-in at the completion of our facility testing. The LPP had been defeated on 3/15/2018 when the well was returned to service. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 KU IE-leiZ (� za�zsio Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophiIli ps.com> Sent: Thursday, May 7, 2020 7:13 AM I 5/7/Zzrzo To: Regg, James B (CED) / Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Autry, Sydney, Mowrey, Andrew F; Braun, Michael (Alaska); NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI Well 1 E-102 on 5/6/2020 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD# 204-231, 204-232) was returned to service and removed from the "Facility Defeated Safety Device Log" last night on 5/6/2020, after the well was shut in following a diagnostic injection period. The LPP had been defeated on 4/23/2020 when the well was returned to injection after an extended shut-in period. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 K,c A t I E —I cr� PA'� ZD47-310 Regg, James B (DOA) From: NSK West Salk Prod Engr <nl638@conocophilIips.com> '61 61 y Sent: Friday, March 15, 2019 7:54 PM To: Regg, James B (DOA) Cc: CPF1 Ops Supv; CPF1 DS Lead Techs; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1 &2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1E-102 on 3/15/2019 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD# 204-231, 204-232) was defeated today on 3/15/2019 after the well was returned to injection. The well is currently injecting at a wellhead injection pressure of -12 psi and rate of 610 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Stephanie Thomson for Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 • • atit I E-/Oz- Prb Regg, James B (DOA) Z 4Zsi 0 From: NSK West Sak Prod Engr <n1638@conocophillips.com> I Sent: Monday,June 11, 2018 3:24 PM �i 6,(01$(6 CPF1Ops Supv; NSK Well Integrity Supv CPF1 and NSK To: Regg, James B (DOA); p , g y p 2; Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney; Sudan, Hari Hara; Braun, Michael (Alaska); Fox, Pete B Subject: Defeated LPP/SSV on CPAI well 1E-102 on 6/11/2018 Jim, The low pressure pilot (LPP) on well 1E-102(PTD#204-231,204-232)was defeated today, 6/11/2018, after the well was returned to injection to further evaluate the presence/strength of an MBE to offset producer 1E-121 The well is currently injecting at a wellhead injection pressure of 0 psi and rate of 780 BWPD.The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Courtney Gallo /Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. SCANNED JUN 2 1 LULU Office: (907) 659-7234 Pager: (907) 659-7000 #497 1 • kgs Le - 1,02_ • l 264 Z3 j a Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> i'r 71/6 Sent: Saturday, May 12, 2018 5:19 AM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK Optimization Engr Subject: LPP/SSV Returned to Service on CPAI Well 1E-102 Jim, The low pressure pilot (LPP) on well E-102 (PTD#204-23 204-232)was returned to service and removed from the "Facility Defeated Safety Device Log" today, 5/12/2018, after the well was shut-in at the completion of wellwork. The LPP had been defeated on 5/5/2018 when the well was returned to service to perform wellwork.This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. 1n18 Office: (907) 659-7234 SCOW" �� Pager: (907) 659-7000 #497 i S • 1<RtAE-162- PM ze42-310 tvPMze42-310 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, May 5, 2018 7:55 AM To: Regg, James B (DOA) �1 G(.711 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK Optimization Engr Subject: LPP/SSV Defeated on CPAI Well 1E-102 Jim, Today we returned well 1E-102 (PTD#204-231,204-232), a WestSak produced water injector, to service. We are ramping the injection up to 1500bwpd but the well is takin at zero wellhead pressure, so the low pressure pilot (LPP/SSV) had to be defeated. The intent is to run an injection profile on coiled tubing next week for reservoir surveillance purposes. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Michael Braun for Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. SCANNED j 4 ,, Office: (907) 659-7234 Pager: (907) 659-7000 #497 i • ! 1<i&A I E- 107- P1-6 ze)etZ-3fv Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, November 15, 2017 4:19 AM 1 L /( 1 I(7 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI well 1E-102 - 11/15/2017 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD#204-231, 204-232)was returned to service and removed from the "Facility Defeated Safety Device Log"today, 11/15/2017, after the well was shut-in. The LPP had been defeated on 11/13/2017 after the wellhead injection pressure fell below the LPP setpoint of 500 psi during wellwork. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SEWS 1 • • kA. Ii✓- 1cZ Pri) 2-DEz3i0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> 11 Sent: Monday, November 13, 2017 5:40 PM clc� '4it7 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1 E-102 on 11/13/2017 Jim, The low pressure pilot (LPP) on well 1E-102 (PTD#204-231, 204-232)was defeated today, 11/13/2017, after wellhead pressure fell to below 500 psi during wellwork.The well is currently injecting at a wellhead injection pressure of 438 psi and rate of 757 BWPD.The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 Fri) 7-64 Regg, James B (DOA) Zit0 From: NSK West Sak Prod Engr <n1638@conocophillips.com> / Sent: Thursday, September 15, 2016 1:35 PM ,� l 6 f, , To: Regg,James B (DOA) ` Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Braden,John C; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on well 1E-102 Jim, The low pressure pilot(LPP) on well 1E-102 (PTD#204-231, 204-232)was returned to service and removed from the safety defeat log today, 9/15/2016, after the well was shut-in. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, ED JUN 2 7 2017 David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • (mac..k It--r v-a W 7.D4z-3io Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, July 22, 2016 12:46 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI well 1E-102 Jim, The low pressure pilot(LPP) on well 1 E-102 (PTD#204-231, 204-232)was defeated today, 7/22/16, after the well was brought online on water injection following a long shut-in period. The well is currently injecting 890 BWPD at 40 psig wellhead pressure. The LPP and surface safety valve (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The AOGCC will be notified when the well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers SCANNED SAN 1 1 2 017 ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com • 1.621kiE-to y_ P 2o4Z3t0 Regg, James B (DOA) From: Haakinson, David <David.Haakinson@conocophillips.com> Sent: Wednesday, April 06, 2016 8:35 AM 1`Ceifq 16" To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M Subject: LPP/SSV on well 1E-102 returned to service Jim, The low pressure pilot (LPP) on well 1E-102 (PTD#204-231-0, 204-232-0)was returned to service and removed from the safety defeat log today, 4/6/16, after the well was shut in for reservoir communication diagnostics. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, David Haakinson / Tyler Hall West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497SCANNEp SEP 2 1 21116 n1638@conocophillips.com (7m 24 231 0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> 3 1��iv Sent: Sunday, March 06, 2016 5:03 AM 1`6:e/l( To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M Subject: Defeated LPP/SSV on well 1E-102 Jim, The low pressure pilot(LPP) on well 1 E-102 (PTD#204-231-0, 204-232-0)was defeated last night, 3/6/16, when the well was brought online on water injection after a long term shut-in period. The well is currently stabilizing at a wellhead injection pressure of 170 psi, and is expected to build over the coming weeks. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Tyler Hall West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED SEP. 2 3 2016 n1638@conocophillips.com STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well riqRe-enter Susp Well r Other:Crystal Seal MBE 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-231 3.Address: 6.API Number: Stratigraphic r Service P' P. 0. Box 100360,Anchorage,Alaska 99510 50-029-23236-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25648 KRU 1 E-102 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 14360 feet Plugs(measured) none true vertical 3650 feet Junk(measured) none Effective Depth measured 14332 feet Packer(measured) 6112,5947 true vertical 3650 feet (true vertical) 3655,3615 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 SURFACE 3156 10.75 3186 2412 INTERMEDIATE 6472 7.625 6499 3710 B-SAND LINER 8221 4.5 14332 3651 Perforation depth: Measured depth: slots from 6507-14295, perfs 9465-9475 0 C T 1 5 2015 True Vertical Depth: slots 3711-3652, perfs 3737-3737 AOGCC Tubing(size,grade,MD,and TVD) 4.5, L-80, 5981 MD, 3616 TVD Packers&SSSV(type,MD,and TVD) PACKER-HRD ZXP LINER TOP PACKER @ 6112 MD, 3655 TVD PACKER-BAKER ZXP LINER TOP PACKER @ 5947 MD, 3615 TVD NIPPLE-CAMCO'DB-6' NIPPLE w13.875'NO GO PROFILE @ 511 MD and 509 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 296 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG ' GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-389 Contact John Peirce Cad 265-6471 Email John.W.Peirce a(�conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature 04. Phone:265-6471 Date /Oil si s. r r ,070(44 Form 10-404 Revised 5/2015 ARBDMS OCT 212Q6 Submit Original Only 1 ElIF Crystal Seal Treatment • DATE , SUMMARY 4/19/2015 Pumped 5 bbls meth down F/L, followed by 35 bbls diesel down Tbg. Job complete. 5/11/2015 BRUSH N FLUSH CMU @ 5905' RKB; DRIFT TO CMU WITH 3.84"DRIFT; SET 5/16" CHOKE ON 3.81" DB LOCK @ CMU 5905' RKB, JOB COMPLETE. 5/23/2015 PULLED 5/16" CHOKE AND SET 3.81" DB LOCK w/ 1/4" CHOKE @ 5905' RKB. COMPLETE. 7/19/2015 B&C CTU#1: RETREIVE DOWNHOLE CHOKE ON DB LOCK FROM SLIDING SLEEVE AT 5905'WITH BAKER G-FORCE JARS. PULL P PRONG FROM DB PLUG AT 6059'WITH JARS. IN PROGRESS. 7/20/2015 B&C CTU#1: RETREIVE DB PLUG FROM 3.56" DB NIPPLE AT 6059'WITH BAKER G-FORCE JARS. INSTALL NEW STYLE (2.75" ID)TYPE 1 ISO-SLEEVE ACROSS D LEM AT 6006'WITH BAKER SI-DI HIPP TRIPPER. PERFORM WEEKLY BOP TEST. READY FOR ELINE TRACTOR PERF. 8/6/2015 UNABLE TO TRACTOR PAST 8890'. DECISION MADE TO RDMO AND MOVE OVER TO 1E-105 TO BEGIN PERFORATION JOB. 8/8/2015 PUMP 40 BBL DIESEL DOWN TBG JOB COMPLETE 8/14/2015 B&C CTU#1: PERFORM DEPTH DETERMINATION LOG IN B LATERAL WITH PDS MEMORY UTILIZING A PUMP THROUGH TOOL CARRIER. DRY TAG AT 10679' CTMD (PERF DEPTH FROM 9460'-9470'). LOG PERF INTERVAL AND PAINT TIE IN FLAGS AT 9451'AND 9551' CTMD. IN PROGRESS. 8/19/2015 B&C CTU #1: PERFORM WEEKLY BOP TEST ON BACK DECK. PERFORATE MBE INTERVAL IN B LATERAL FROM 9465'-9470' RKB WITH SLB 2-IN POWERFLOW HSD GUNS (2006FP-6SPF, EHD 0.45", 4.5" PEN). DEPTH CORRECTED TO TAG FROM LAST MEMORY LOG, REFERENCED TO IPROF DATED 23-JUN-06. WELL LEFT FREEZE PROTECTED AND SHUT IN. READY FOR CRYSTAL SEAL. 9/18/2015 PUMPED 219BBL SEAWATER DWN TBG FOLLOWED BY 42BBL DSL TO ESTABLISH INJECTION RATES (JOB COMPLETE) 9/19/2015 Pumped MBE treatment per design. Pumped 217 bbls 3% KCL w/ 1925#of 124 mesh Crystal Seal. Treatment displaced into suspected MBE w/ 100 SW and 40 bbls diesel. Note: Do not bring well back on injection or offset producer 1E-121 on prod until minimum tomorrow, 9/20, afternoon. 9/27/2015 Injectivity Test, pump 40 bbls dsl down tbg @1 bbl/min @ 900 psi,job complete r' E KUP INJ 1E-102 . ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska.I(1C. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cmncoThilhpy 500292323600 WEST SAK INJ 93.36 12518.09 14,360.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1E-102,8/25/2015 7:43.15 AM SSSV:NIPPLE Last WO: 31.31 1/7/2005 Vertical schem t (actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PERFORATIONS hipshkf 8/25/2015 HANGER',22.7 "ig1 li la ' Casing Strings " - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K-55 WELDED 'f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)ND)...-Wt/Len(I...Grade Top Thread ��u. �� SURFACE 103/4 9.794 30.1 3,186.0 2,411.8 45.50 L-80 BTC •, 1 casing Description OD(in) ID(in) Top(ftKB) -Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 27.2 6,498.8 3,709.8 29.70 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)ND)...Wt/Len(I...Grade Top Thread D-SAND WINDOW 75/8 6.000 6,005.0 6,015.0 3,6321 Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)... Wt/Len(I...Grade Top Thread D-SAND LINER LEM 41/2 3.958 5,946.9 6,154.1 3,663.9 12.60 L-80 IBT ^Liner Details CONDUCTOR;31.0-108.0 L Nominal ID Top(ftKB) Top)TVD)(ftKB) Top Incl I°) Item Des Corn 8n) NIPPLE;511.3 11 V 5,946.9 3,615.0 75.76 PACKER BAKER ZXP LINER TOP PACKER 5.500 5,966.7 3,619.9 75.58 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,986.0 3,624.7 75.41 XO BUSHING XO BUSHING 4.500 111 5,994.0 3,626.8 75.33 HANGER LEM ABOVE HOOK HANGER 4.500 GAS LIFT;3.156.9 si 6,004.3 3,629.4 75.30 HANGER LEM HOOK HANGER 3.958 li6,059.7 3,643.0 76.26 NIPPLE CAMCO'DB'NIPPLE W/3.562"PROFILE 3.562 f 6,150.9' 3,663.3 78.11 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 SURFACE;30.1-3186.0 •♦ l Casing Description 000n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread B-SAND LINER 1 41/21 3.958 6,111.6) 14,332.31 3,650.71 12.601 L-80 I DWC Liner Details GAS LIFT;5,453.1 Nominal ID Top(ftKB) Top(ND))ftKB) Top Incl(°) Item Des Corn (in) • 6,111.6 3,654.9 77.24 PACKER HRD ZXP LINER TOP PACKER 5.500 • • 6,130.6 3,659.0 77.66 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 • SLEEVE-C;6905.4 6,133.4 3,659.6 77.72 HANGER FLEX-LOCK LINER HANGER 5.500 6,144.1 3,661.9 77.96 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 • 6,163.4 3,665.8 78.38 XO BUSHING XO BUSHING 4.500 4 K 14298.0 3,651.8 91.73 BUSHING DRILLABLE PACKOFF BUSHING 3.958 LOCATOR;5,952.8 :/.■y Tubing Strings 4 5 1 Tubingtion p Descri String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt Ib/ft Grade To Connection SEAL ASSY;5.9545 se �„�,% TUBING 1 41/21 3.9581 22.61 5,981.11 3.623.5 ( 12.601 L-S0 I IBTM kyriX� Completion Details SHOE;5,980.1 ke, Nominal lD Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 3� 22.6 22.6 0.07 HANGER VETCO GRAY TUBING HANGER 4.500 v2 v- 511.3 508.8 12.60 NIPPLE CAMCO'DB-6'NIPPLE w13.875"NO GO PROFILE 3.875 5,905.4 3,604.9 76.14 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO 3.81'DB'2/ 3.810 5/16"CHOKE(CLOSED 1/17/2005) g - 5,952.8 3,616.4 75.71 LOCATOR BAKER LOCATOR - 3.875 5,954.5 3,616.9 75.69 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 DSAND WINDOW;6,005.0- 6,015.0 ,005.0- 5,980.1 3,623.3 75.46 SHOE 3.000 SLEEVE;6,0006.01' ■IfLIpt. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ,.' ' 'ji1 Top(ND) Top Incl Top)ftKB) (ttKB) (°) Des Com Run Date ID(in) 6,006.0 3,629.8 75.33 SLEEVE NEW STYLE TYPE 1 ISO SLEEVE ACROSS THE D 7/20/2015 2.750 LATERAL Perforations&Slots Shot Den Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,507.0 14,295.0 3,710.6 3,651.9 WS B,1E-102 12/25/2004 32.0 SLOTS Alternating solid 1 _ jt/slotted 2 jts pipe,2.5" x.125"slots,4 circum. rows/ft,3"centers,18 deg.orient 111 9,465.0 9,470.0 3,736.2 3,736.1 WS B,1E-102 8/19/2015 6.0 APERF 2"Powerflow HSD guns (2006FP-6 SPF,60 DEG,EHD 0.45",4.5" I I PEN) iII I'; 9,470.0 9,475.0 3,736.1' 3,736.0 WS B,1E-102 9/23/2012 6.0 IPERF 5"GUN,BH CHARGES, I pumped 15008 crystal seal D-SAND LINER LEM;5,946.9- -7-1-7T:I Cement ,946.9- Cement Squeezes 61541 I Top(ND) Btm(ND) It Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 1 9,470.0 9,475.0 3,736.1 3,736.0 GEL SQZ 9/23/2012 ' , 9,470.0 9,475.0 3,736.1 3,736.0 GEL SQZ 8/9/2013 Profile Modification-Pumped 1600 LBS of 4 MM I Product in 228 BBLS of 2%KCL Solution • Mandrel Inserts st INTERMEDIATE;27.25,498 B ati ' SLOTS;6,064.0-14,278.0 on Top(ND) Valve Latch Port Size TRO Run D-SAND LINER;6,004.3- N Top(ftKB) (ORB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 14,378.2 APERF;9,4650.9,470A 1 3,156.9 2,400.1 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 3/14/2005 IPERF;9,470.0-9,475.02 5,453.1 3,474.5 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 3/23/2005 SLOTS,6,507.0-14,295.0 Notes:General&Safety End Date Annotation 1/6/2005 NOTE:B-SAND LINER LEM IS OPEN,NO ISO SLEEVE,NO DIVERTER 1/6/2005 NOTE:MULTI-LATERAL B-SAND 8 D-SAND WELL 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 - 5/13/2010 NOTE:LDL SHOWS D-SAND LEAK @"8900'RKB 9/3/2011 NOTE: PROFILE MODIFICATION-PUMPED 2530 LBS(4MM)ACROSS PERFS @ 8880-8885'D'MBE B-SAND LINER;6,111.6- 14,332.3 f ;, KUP INJ • 1E-102 w . Conoco`Phillips �, Alaska.Inc. ci.m...}tdH[a •,• 1E-102,8/25/2015 7:43:16 AM Vertical schematic(actual) HANGER,227 . H INotes:General&Safety ` -t lef End Date Annotation 9/23/2012 NOTE: PROFILE MODIFICATION-PUMPED 1500 LBS CRYSTAL SEAL IN B-LATERAL @a MBE 9470 11 1 8/9/2013 NOTE: PROFILE MODIFICATION-PUMPED 1600 LBS(4MM)CRYSTAL SEAL IN MBE @ 9470 1 CONDUCTOR;31.0-108 0--4 NIPPLE;511.3 I GAS LIFT;3,156.9 ViaIF .. d { SURFACE;30.1-3,186.0 GAS LIFT;5,453.1 SLEEVE-C;5.9050 1 f v LOCATOR;5,952.8 41:: :fib :A. SEAL ASSY;5.9545 1 �_ tV SHOE;5,980.1 :111V v, YaV V, V. v v, v, -' v,. v ,i x D-SAND WINDOW,6,005.0- l 6,015. I SLEEVE;6,00fi.0 0� II rt. I li It D-SAND LINER LEM;5,946.9- .A) 6.154.1 II- -II I' I I I I INTERMEDIATE;27.2-6,498.8 SLOTS;6,064.0-14,278.0 D-SAND LINER;6.004.3- 14,318.2 APERF;9,465.09,470.0 IPERF;9,470.0-9,475.0 r SLOTS;6,507.0.14,295.0 B-SAND LINER;6,111.6- 14,332.3 • • WELL LOG TRANSMITTAL PROACTIVE DIAC{NOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 DATA LOGGED Anchorage, Alaska 99501420101 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. E.C, Attn: Robert A. Richey 130 West International Airport Road AUG 2 0 Suite C Anchorage, AK 99518 . :�, ,• ;/'• Fax: (907) 245-8952 sI NE® SEP 0 3 2015 1) Coil Flag 13-Aug-15 1E-105 L1 CD 205-c70-1 50-029-23243-60 ? 0-k. 5 2) Jewelry Log 14-Aug-15 1E-102 CD 2-pd-k-2:5 \ 50-029-23236-00 2-:Co\2-kCo Signed : 12'24ZL)< I��E;,k; Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D'\Achives\MasterTemplate Files\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx ti � OF T� � w\�� s� THE STATE Alaska Oil and Gas � ofJT `iSJ(TA Conservation Commission 17 ,_ '= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ".� Main 907 279 1433 OF ALAS' Fax 907 276 7542 2Q1www.aogcc alaska gov satitiED .la L 0 U John Peirce •— a3I Sr. Wells Engineer p2 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-102 Sundry Number: 315-389 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster �, Chair DATED this day of June, 2015 Encl. STATE OF ALASKA luN 22 lel' A, ,KA OIL AND GAS CONSERVATION COM. 3ION S 6 ' uL11S APPLICATION FOR SUNDRY APPROVALS - -, 20 AAC 25.280 1.Type of Request. Abandon r Plug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE . I✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc Exploratory r Developrrent r 204-231 - 3.Address: 6.API Number: Stratigraphic r Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-23236-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p' ✓ KRU 1E-102 ` 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 25651,25648 • Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured): 14360 • 3650 - 14332'- 3650' • 6060' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108' 108' SURFACE 3156 10.75 3186' 2412' INTERMEDIATE 6472 7.625 6499' 3710' B-SAND LINER 8221 4.5 14332' 3651' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): ` slots from 6507-14295, perfs 9470-9475 slots 3711-3652,perfs 3737-3737 4.5 L-80 5981 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER ZXP LINER TOP PACKER MD=5947 TVD=3615 ' PACKER-HRD ZXP LINER TOP PACKER MD=6112 TVD=3655 ' NIPPLE-CAMCO'DB-6'NIPPLE w/3.875"NO GO PROFILE MD=511 TVD=509 ' 12.Attachments. Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic E Development r Service 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 7/13/2015 OIL r VVINJ r WDSPL r Suspended r 16.Verbal Approval. Date: GAS r WAG r.: ' GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirceconocophillips.com Printed Name John PeirceTitle: Sr. Wells Engineer Signature fLio...7f,;, ... Phone:265-6471 Date 6/19/1 Commission Use Only Sundry Number S -54) Conditions of approval: Notify Commission so that a representative may witness ✓✓✓✓✓✓ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /c — 4.0 APPROVED BY / Approved by: '917)2-1-.°4--- 1 ' COMMISSIONER THE COMMISSION Date: tP 30— ( 5 J Approved application Is valid for 12 m n tr f1/��t date of approval. submit Form and Form 10-403 Revised 5/2015 Ifri_LII 0 R O aAt. t a hments in Duplicate RBDMJUN 3 0 7015 • KUP INJ 1E-102 • > ConocoPhillips ® Well Attributes Max Angle&MD TD Alaska,Inc. .,..-,:v} Wellbore API/UWI Aeld Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CnnoccRu0ipe 500292323600 WESTSAK INJ 93.36 12,518.09 14,360.0 ",. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date tE-102,528/20151.59.42PM SSSV:NIPPLE Last WO: 31.31 1/7/2005 Vertical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:CHANGED CHOKE lehallf 5/28/2015 HANGER;22.7 7 r Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread CONDUCTOR 20 19.124 31.0 1080 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread �a • SURFACE 103/4 9.794 30.1 3,186.0 2,411.8 45.50 L-80 BTC '' . lit J. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread INTERMEDIATE 75/8 6.875 27.2 6,498.8 3,709.8 29.70 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread D-SAND WINDOW 7 5/8 6.000 6,005.0 6,015.0 3,632.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-SAND LINER LEM 4 1/2 3.958 5,946.9 6,154.1 3,663.9 12.60 L-80 IBT .,,..Liner Details CONDUCTOR,31.0-108.0 . . Nominal 10 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE,511.3 5,946.9 3,615.0 75.76-PACKER BAKER ZXP LINER TOP PACKER 5.500 5,966.7 3,619.9 75.58 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 1 s 5,986.0 3,624.7 75.41 XO BUSHING XO BUSHING - 4.500 _ 5,994.0 3,626.8 75.33 HANGER LEM ABOVE HOOK HANGER 4.500 li 6,004.3 3,629.4 75.30 HANGER LEM HOOK HANGER 3.958 GAS LIFT;3,156.9 6,059.7 3,643.0 76.26 NIPPLE CAMCO'DB'NIPPLE W/3.562"PROFILE 3.562 6,150.9 3,663.3 78.11 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 Casing Description IOD(in) IID(in) Top(ftKB) (Set Depth(ftKB) I Set Depth(ND)...I Wt/Len(I...I Grade I Top Thread SURFACE;30.1-3,186.0 13-SAND LINER 41/2 3.958 611161 143323 36507 1260 L-80 DWC Liner Details Nominal ID GAS LIFT;5,453.1 t Top(ftKB) Top(ND)(ftKB) Top!nett.) Item Des Com (in) 6,111.6 3,654.9 77.24 PACKER HRD ZXP LINER TOP PACKER 5.500 6,130.6 3,659.0 77.66 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 6,133.4 3,659.6 77.72 HANGER FLEX-LOCK LINER HANGER 5.500 CHOKE;5,905.4 1 , SLEEVE-C;5,905.4 6,144.1 3,661.9 77.96 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 6,163.4 3,665.8 78.38 XO BUSHING XO BUSHING 4.500 14,298.0 3,651.8 91.73 BUSHING DRILLABLE PACKOFF BUSHING 3.958 Tubing Strings Tubing Description (String Ma...l ID(in) (Top(ftKB) (Set Depth(ft..l Set Depth(ND)I...'Wt(IWft) 'Grade IMP Connection LOCATOR;5,952.8 ;o ll. TUBING 41/2 3.958 22.6 5,981.1 3,623.5 12.60 L-80 IBTM `-a Completion Details SEAL ASSY;5,954 5 ?ftii Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.6 226 007 HANGER VETCO GRAY TUBING HANGER 4.500 ' SHOE;5,980.1 , t., SII ti® 511.3 508.8 12.60 NIPPLE CAMCO'DB-6'NIPPLE w/3.875"NO GO PROFILE 3.875 5,905.4 3,604.9 76.14 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO 3.81'DB'2/ 3.810 V 5/16"CHOKE(CLOSED 1/172005) v 5,952.8 3,616.4 75.71 LOCATOR BAKER LOCATOR 3.875 5,954.5 3,616.9 75.69 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 x 5,980.1 3,623.3 75.46 SHOE 3.000 Other In Hole Top(ND(Wi)relineTop Ind retrievable plugs,valves,pumps,fish,etc.) 0-SAND WINDOW,8,005.0. 8,015.0 II Top(ftKB) (ftKB) r) Des Com Run Date ID(in) 5,905.4 3,604.9 76.14 CHOKE 3.81"DB LOCK W/1/4"CHOKE OAL 2'10" 5/23/2015 0.250 6,059.7 3,643.0 76.26 PLUG 3.562"DB PLUG 12/4/2013 0.000 Perforations&Slots Shot Dens Top 1TVD) Btm(ND) (shots/t Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PLUG,6,059.7 y 6,507.0 14,295.0 3,710.6 3,651.9 WS B,1E-102 12/25/2004 32.0 SLOTS Alternating solid 1 �l jt/slotted 2 jts pipe,2.5" x.125"slots,4 circum. rows/ft,3"centers,18 deg.orient " 9,470.0 9,475.0 3,736.1 3,736.0 WS B,1E-102 9/23/2012 6.0 IPERF 5"GUN,BH CHARGES, pumped 1500#crystal . - seal Cement Squeezes I ITop(ND) (ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 9,470.0 9,475.0 3,736.1 3,736.0 GEL SQZ 9/23/2012 9,470.0 9,475.0 3,736.1 3,736.0 GEL SQZ 8/9/2013 Profile Modification-Pumped 1600 LBS of 4 MM D-SAND LINER LEM;5.946.9- = Product in 228 BBLS Of 2%KCL Solution 6,154.1 Mandrel Inserts -i t i on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com r 3,156.9 2,4001 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 3/14/2005 --.r 2 5,453.1 3,474.5 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 3/23/2005 INTERMEDIATE;27.2.6,498.8 -ter SLOTS,6,064.0-14,278.0Notes:General&Safety D-SAND LINER;6,004.3-'" 14.318.2 End Date Annotation IPERF;9.470.0.9,475.01/6/2005 NOTE:B-SAND LINER LEM IS OPEN,NO ISO SLEEVE,NO DIVERTER SLOTS;6,507.0-14,295.0-- 1/6/2005 NOTE:MULTI-LATERAL B-SAND 8 D-SAND WELL 1/29/2009 NOTE:View Schematic w/Alaska Schemetic9.0 5/13/2010 NOTE:LDL SHOWS D-SAND LEAK @-8900'RKB 9/3/2011 NOTE: PROFILE MODIFICATION-PUMPED 2530 LBS(4MM)ACROSS PERFS @ 8880-8885'D'MBE 9/23/2012 NOTE: PROFILE MODIFICATION-PUMPED 1500 LBS CRYSTAL SEAL IN B-LATERAL @MBE 9470 ® 8/9/2013 NOTE: PROFILE MODIFICATION-PUMPED 1600 LBS(4MM)CRYSTAL SEAL IN MBE @ 9470 13-SAND LINER;8,111.6-__I I 14,332.3 1E-102 to 1E-121 B Sand MBE Fulibore Crystal Seal Treatment A Matrix Bypass Event (MBE) occurred 6-6-06 in 1 E-102 B Lat to offset producer 1E-121. A 6-26-06 (PROF found an MBE at -9480' MD half way down 1E-102 lateral. Another MBE occurred in Dec. 2009 in 1E-102L1 D lateral to 1E-121L1 producer. A 9-3-11 Crystal Seal treatment successfully sealed the D MBE, and this MBE continues to behave sealed. A 9-23-12 Crystal Seal treatment was pumped to seal the B MBE, but this treatment broke down after -3 months. An 8/9/13 Crystal Seal retreatment was pumped to seal the B MBE, but the retreatment only held -1 month. Both B MBE treatments only resulted in small volumes of Crystal Seal entering this `tight' acting MBE feature. Of 9 West Sak MBE's treated to date with Crystal Seal, 1E-102 B MBE has been the most difficult to fill with Crystal Seal. Thus, It is proposed that a high rate fullbore Crystal Seal job be pumped to help open the MBE near wellbore to enable it to take larger volumes of Crystal Seal. The 2 CT jobs treating this B MBE resulted in only 1500 lbs & 1600 lbs of Crystal Seal away at 1.5 - 2 bpm prior to screen outs. These jobs are by far the smallest volume jobs pumped to an MBE. Successful jobs average -2400 lbs Crystal Seal prior to Flush. It is proposed that Crystal Seal slurry be fullbore pumped at -4 bpm (target) down tubing to the B MBE, per the proposed procedure: Coil Tubing: 1) RIH & pull 3.562" DB Plug at 6059' RKB (set 12/4/13 for B MBE isolation & `D only PWI' service). 2) RIH & set an Iso-Sleeve in the D LEM at 6006' RKB. E-line: 3) RIH with 5' perf gun on tractor to shoot 6 spf, 60 deg ph large hole add perfs at 9460 - 9465' RKB. This adds more perfs in 5.5" slotted liner near the B MBE at -9480' RKB. Fire gun. POOH. RD. Note, 5' of Perfs were shot 9/23/12 at 9470 - 9475' RKB. Adding more perfs may better help enable more 4 mm Crystal Seal particles to pass through the slotted liner(with 2.5"x 0.125"slots) Pumping: 4) Pump SRIT with Seawater down tubing to B MBE (Vol to MBE -144 bbls). Select steady treatment rate (target +/- 4 bpm) to be held constant during treatment through Flush to monitor MBE response to treatment and observe Crystal Seal screen out development during slurry pumping. Use 2% KCL for making Crystal Seal slurry (or Seawater) and pump slurry down 4.5" tubing as follows: a) 2% KCL Water w/0.10 ppg Crystal Seal, or go to Flush (step d) if screen out develops. b) 2% KCL Water w/0.15 ppg Crystal Seal, or go to Flush if screen out develops. c) 2% KCL Water w/0.20 - 0.25 ppg Crystal Seal, or go to Flush if screen out develops. d) When screen out occurs, pump Flush (targeting 107 bbls Seawater, followed by 37 bbls Diesel FP) to displace all Crystal Seal from well to B MBE. RD. Wait 6 hours before returning 1E-102 to PWI. Coil Tubing: 5) RIH with jet swirl nozzle and tag top of Crystal Seal in well, then jet through Crystal Seal to deep as possible in the B Lat to shear/ mechanically break Crystal Seal remaining in the liner. POOH w/CT. 6) RIH with IPROF BHA to memory log down and up passes in the B Lateral. Wait 2 hours. Log cool back pass. POOH with CT. RD CTU. Return 1E-102 to PWI. Evaluate when to pull the D Iso-Sly. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 03,2015 TO: Jim Regg P.I.Supervisor S e.1 6/4(/' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-102 FROM: Jeff Jones KUPARUK RIV U WSAK 1E-102 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry z:j — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1E-102 API Well Number 50-029-23236-00-00 Inspector Name: Jeff Jones Permit Number: 204-231-0 Inspection Date: 5/2/2015 Insp Num: mitJJ150505154339 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-102 Type Inj J W TVD 1 3653 - Tubingi o o o o PTD J 2042310 ,Type Test SPT Test psi 1500 - IA 1720 2600 - 2560 . 2560 Interval I4YRTST P/F P . OA 176 176 176 176 Notes: Tubing is on a vacuum.0.9 BBLS diesel pumped. 1 well inspected;no exceptions noted ,- SCANNED Jut_ 13 2015 Wednesday,June 03,2015 Page 1 of 1 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 0 4 - 623 l Well History File Identifier Organizing (done) "Two-sided 1111111111111I 11111 o Rescan Needed 111111111111111I11I REj-CAN ¥ Color Items: o Greyscale Items: D~TAL DATA ).15 Diskettes, No. It> o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: l" o Other:: Y\1P Is~lllllllllIl~ 11111 ~f 151 BY: ~ Date: ~ 7D7 Project Proofing BY: ~ Date:~ 7 07 \.-1) x 30 = J 50 Date <;)./7/ D 7 + 0 = TOTAL PAGES 160 (Count does not include cover sheet) IA/t P 151 I I , Scanning Preparation BY: c: Marj~ J BY: Production Scanning Stage 1 Page Count from Scanned File: J 57 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES C Maria J Date: d-J 7/07 If NO in stage 1, page(s) discrepancies were found: 1111111111111111111 NO Stage 1 YES 151 ¥Y\ 11 NO BY: Maria Date: 151 1II111I111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc kizu (E- 1 az Pr-6 204 z;310 Regg, James B (DOA) From: NSK West Sak Prod Engr[n1638 @conocophillips.com] Sent: Sunday, October 13, 2013 5:36 PM Keit tLI LkIi; To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Optimization Engr; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr; Jensen, Marc D Subject: LPP/SSV Returned to service on 1E-102, 1E-105, and 1J-105 10/13/13 Jim, The low pressure pilots(LPP)on the following injectors were returned to service on Oct 13, 2013 when the well head injection pressures exceeded 500 psi: • 1E-102(PTD#204-231 204-232) • 1 - 15 ' 205-006,2pd`-ea14205-008) • 1J-105(PTD#207-027,207-028 and 207-029) This note is in reference to"Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Amanda Patterson/Scott Stanley West Sak Production Engineers SCANNED DEC 2 32013 ConocoPhillips Alaska, Inc. (907)659-7234 Pager 497 1 • �wPti O ��j, :s THE STATE Alaska Oil and Gas ° A LAS servation Commission w�. GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 Off, ALAS�� Main: 907.279.1433 Fax: 907.276.7542 John Peirce SCWAV Wells Engineer �3 ConocoPhillips Alaska, Inc. P.O. Box 100360 a 0 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -102 Sundry Number: 313 -222 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P45/ Cathy P oerster Chair DATED this Ay of May, 2013. Encl. . STATE OF ALASKA III /STS / e *KA OIL AND GAS CONSERVATION COMMISSION • / MAY 01 3 APPLICATION FOR SUNDRY APPROVALS ` ..� S - 20 AAC 25.280 AOGCC 1. Type of Request: Abandon F- Plug for Redrill F'"'" Perforate New Pool j"" Repair w ell jµ'" Change Approved Program r Suspend r Rug P E Perforate f Pull Tubing r Time Extension E Operational Shutdow n r Re -enter Susp. Well E Stimulate F"'" Alter casing _ Other:Crystal Seal MBE V a 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development )" Exploratory F 204 - 231 N 3. Address: Stratigraphic ) Service f;; 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23236 - 00 ' 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes F No )i 1E 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25651, 25648* Kuparuk River Field / West Sak Oil Pool " 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14360 3650 , 14332' 3651'c none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108' 108' SURFACE 3156 10.75 3186' 2412' INTERMEDIATE 6472 7.625 6499' 3709' B -SAND LINER 8221 4.5 14332' 3651' Perforation Depth MD (ft): a Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slots 6507 perfs 9470' - 9475' slots 3710' 3652', perfs 3737' - 3737' 4.5 L - 5981 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER ZXP LINER TOP PACKER 5947 MD, 3614 TVD PACKER - HRD ZXP LINER TOP PACKER 6112' MD, 3653' TVD 2 NIPPLE - CAMCO'DB -6' NIPPLE 511' MD, 509' TVD, 12. Attachments: Description Summary of Proposal IV + 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch r Exploratory E Stratigraphic ) Development E Service IV to 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil I — Gas F WDSPL 1 Suspended F 16. Verbal Approval: Date: WINJ f° GINJ F WAG IV Abandoned E Commission Representative: GSTOR E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Email: John.W.Peircena cop.com Printed Name John Peirce Title: Wells Engineer Signature te fift. I f .. er.. Phone: 265 -6471 Date ; Jth3 Commission Use Only Sundry Number: 3-- 222 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity E BOP Test )'— Mechanical Integrity Test F- Location Clearance f RBDMS MAY 10 ,dVA Other: Spacing Exception Required? Yes ❑ No [✓( Subsequent Form Required: 1 G — 1 U 4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: $ 10 - / 3 a lication is valid for 12 months trom the date of approval. p pp Form 10 -403 (Revised 0/2012) /�L 1- Submit Form and Attachments in Duplicate � �� ORIGINAL 5 /if:5- /j • 1E-102 to 1E-121 `B' MBE Crystal Seal Retreatment A Matrix Bypass Event (MBE) occurred on 6 -6 -06 in 1E-102 in the B sand lateral. A 6 -26 -06 IPROF saw the B MBE at 9480' RKB behind the 4.5" slotted liner. Almost all PWI was exiting the slotted liner at this MBE. A 9 -23 -12 Crystal Seal treatment sealed the B MBE, but the treatment broke down within 3 months that resulted in SI of PWI to 1E-102 on 12 -8 -12. A 3 -27 -13 (PROF in 1E-102 confirmed the B MBE at —9480' RKB Crystal Sealed 9 -23 -12 was once again open taking all PWI. The 1E-102L1 D MBE was isolated with an Iso -SIv on 9 -18 -12 (for the 9 -23 -12 B MBE Crystal Seal treatment), and the D Iso - Sleeve remains set, so 1E-102 is currently configured to perform a B MBE retreatment with Crystal Seal. It is proposed that 1E-102 B MBE will be resealed with Crystal Seal pumped down coil tubing. No well work needs to be done to prepare for 1E-102 for a retreatment. Large hole perforations already exist in 1E-102 across the B MBE, which were shot prior to pumping the initial B MBE treatment. A post - Crystal Seal IPROF will likely be run in 1 E -102 to verify success of the job. Coil Tubing Procedure: RIH with either a large down port or side port nozzle on 2 "coil tubing. Park nozzle across the large hole perforation interval at 9470 - 9475' RKB in the 4.5" slotted liner just above the MBE at 9480' RKB. Pump a Crystal Seal retreatment as follows: a) Seawater down coil. Determine a steady treatment rate (likely between 1.5 - 2 bpm) to be held constant during the treatment through Flush (step f) to monitor MBE response to treatment and to note a CrystalSeal screenout during slurry pumping. Swap from Seawater to 2% KCI, b) 2% KCI Water with 0.05 ppg Crystal Seal (we will use 4 mm mesh for all stages b through e) down coil. Each stage volume is TBD during pumping based on the treating pressure response seen during stage. When called, continue pumping, c) 2% KCI Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if we see screen out. d) 2% KCI Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCI Water w /0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out is seen, open CT x Tbg annulus to return tank, and pump 1 CT volume Seawater Flush to displace Crystal Seal slurry from coil to well while POOH. If screen out has not been seen prior to Flush, leave CT x Tbg annulus SI and pump 1 full CT volume of Seawater Flush to displace remaining Crystal Seal Slurry from coil to liner while POOH to D LEM, then swap to 53 bbls of Diesel FP down coil, followed by 1 CT volume of Diesel ( -40 bbls) to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let Crystal Seal become fully swollen and seal off the MBE before returning 1 E -102 to PWI for treatment evaluation. Coil tubing will be used to perform a post - CrystalSeal treatment tag, a possible Crystal Seal cleanout, and a memory IPROF depending on post -job PWI and offset producer responses. a KUP 1 E -102 Conoc /$ Well Attributes Max Angle & MD TD Alaska. kk: Wellbore API/UWI Field Name Well Status Inc! ( °) MD (RKB) Act Btm (RKB) pyyps 500292323600 WESTSAK INJ 93.36 12,518.09 14,360.0 " Comment H2S (ppm) Date Annotation End Date KB - Grd (R) Rig Release Date SSSV: NIPPLE Last WO: 31.31 1/7/2005 Well Conf4' - 1 E-102, 102620125022890 achemat - Actual Annotation Depth (RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: WELL REVIEW /UPDATE PERFS osborl 10/26/2012 Casing Strings HANGER, 28 ` - Casing Descri Strin 0... Strin ID ... Top (RKB) Set Depth (f... Set De pth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K - 55 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd _ SURFACE 103/4 9.794 30.1 3,186.0 2,415.7 45.50 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 75/8 6.875 27.2 6,498.8 3,708.8 29.70 L - 80 BTC - M r • Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D - SAND WINDOW 75/8 6.000 6,005.0 6,015.0 3,630.6 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D -SAND LINER LEM 4 1/2 3.958 5,946.9 6,154.1 3,663.5 12.60 L -80 IBT Liner Details Top Depth (TV)) Top Inc! Nomi... CONDUCTOR, Top (RKB) (ftKB) ( °) item Description Comment ID (in) 3f - foe 5,946.9 3,613.9 74.30 PACKER BAKER ZXP LINER TOP PACKER 5.500 NIPPLE, 511 1 1, 5,966.7 3,619.4 74.64 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,986.0 3,624.6 74.98 X0 BUSHING XO BUSHING 4.500 5,994.0 3,626.7 75.12 HANGER LEM ABOVE HOOK HANGER 4.500 i 6,004.3 3,627.5 74.89 HANGER LEM HOOK HANGER 3.958 6,059.7 3,642.7 76.11 NIPPLE CAMCO 'DB' NIPPLE W/3.562" PROFILE 3.562 GAS LIFT, p 6,150.9 3,662.8 77.71 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 3.157 I ' Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd B -SAND LINER 41/2 3.958 6,111.6 14,332.3 3,650.7 12.60 L -80 DWC L. Liner Details SURFACE, Top Depth 30 -3,186 (TVD) Top 10cl Nomi... Top (ftKB) (RKB) (1 Rem Description Comment ID (in) 6,111.6 3,652.7 76.42 PACKER HRD ZXP LINER TOP PACKER 5.500 GAS LIFT, - 5,453 6,130.6 3,657.8 77.04 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 IIIIII 6,133.4 3,658.5 77.14 HANGER FLEX -LOCK LINER HANGER 5.500 all 6,144.1 3,661.1 77.48 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 SLEEVE - C. I 6,163.4 3,665.6 78.11 XOBUSHING XOBUSHING 4.500 5,905 14,298.01 3,651.9 91.94 BUSHING DRILLABLE PACKOFF BUSHING 3.958 MI Tubing Strings Al\ Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LOCATOR, '1 TUBING 4 1/2 3.958 22.6 5,981.1 3,623.3 12.60 _ L -80 IBTM s.9s3 Completion Details 1 1 Top Depth SEAL ASSY, (TVD) TO lncl Nomi... 5,954 Top (ftKB) (RKB) (1 Rem Description Comment ID (in) 22.6 22.6 - 0.41 HANGER VETCO GRAY TUBING HANGER 4.500 SHOE, 5,980 511.3 508.9 13.11 NIPPLE CAMCO'DB -6' NIPPLE w /3.875" NO GO PROFILE 3.875 5,905.4 3,604.9 76.14 SLEEVE -C BAKER CMU SLIDING SLEEVE w /CAMCO 3.81 'DB' PROFILE 1810 (CLOSED 1/17/2005) 5,952.8 3,615.5 74.40 LOCATOR BAKER LOCATOR 3.875 5,954.5 3,616.0 74.43 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 5,980.1 3,623.1 74.88 SHOE 3.000 D -SAND Perforations & Slots WINDOW, Shot 6,0058,015 Top (TVD) Btm (TVD) Dens Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (oh.. Type Comment 6,507.0 14,295.0 3,710.1 3,652.0 WS B, 1E -102 12/25/2004 32.0 SLOTS Alternating solid 1 jt/slotted 2jts pipe, 2.5" 0.125" slots, 4 circum. rows/ft, 3" centers, 18 deg. orient 9,470.0 9,475.0 3,736.9 3,736.7 WS B, 1E -102 9/23/2012 6.0 IPERF 5" GUN, BH CHARGES, pumped 15008 crystal seal Notes: General & Safety End Date Annotation 1/6/2005 NOTE: B-SAND LINER LEM IS OPEN, NO ISO SLEEVE, NO DIVERTER 1/6/2005 NOTE: MULTI - LATERAL B-SAND & D -SAND WELL 1/29/2009 NOTE: View Schematic w/ Alaska Schematic9.0 5/13/2010 NOTE: LDL SHOWS D -SAND LEAK @ - 8900' RKB D -SAND LINER LEM, 5,9475.154 NTERMEDIATE, 278,499 IPERF, 9.470-9.475 SLOTS, 6,064 - 14,278 SLOTS, 6,507-14.295 DAAND LINER, 6,004 - 14,318 Mandrel Details Top Depth Top Pon (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (RKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 13 1 3,156.9 2,406 68.97 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 3/14/2005 6,112.14332 \ 2 5,453.1 3,474.5 65.42 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 3/23/2005 TD (1E -102), - 14,360 STATE OF ALASKA ' ALlik OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Ferforations r Perforate r Other r Crystal Seal MBE Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Rogram r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 204 - 231 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service - 50 029 - 23236 - 00 — ®® 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25648 — s 1E 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .- none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14360 feet Plugs (measured) 6060 true vertical 3650 feet Junk (measured) None Effective Depth measured 14332 feet Packer (measured) 6112 true vertical 3651 feet (true vertical) 3653 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 SURFACE 3156 10.75 3186 2412 INTERMEDIATE 6472 7.625 6499 3709 B -SAND LINER 8221 4.5 14332 3651 a k k, f :•t` ;., emu: Perforation depth: Measured depth: slots 6507'- 14295', perfs 9470' -9475' SCANNED JAN 2 8 2013 True Vertical Depth: slots 3710'- 3652', perfs 3737' -3737' Tubing (size, grade, MD, and TVD) 4.5, L -80, 5981 MD, 3623 TVD Packers & SSSV (type, MD, and TVD) _ PACKER - HRD ZXP LINER TOP PACKER @ 6112 Mb and 3653 TVD.-. SSSV - CAMCO 'DB -6' NIPPLE @ 511 MD and 509 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): see attached summary Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation na 0 SI Subsequent to operation na 0 1618 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service F.: Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r° Daily Report of Well Operations XXX GSTOR r WINJ r WAG J;r GINJ r SUSP r° SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -160 Contact John Peirce (a7 265 -6471 Email John .W.Peirce @conocophillips.com Printed Name John Peirce Title Wells Engineer Signature 7 fj .e. — Phone: 265 -6471 Date 612 4 OCT lv.Lg • !L FIREWL:: CT2920 Form 10 -404 Revised 12/2012 / 0V ubmit Original Only 1 E -102 Well Work Summary DATE SUMMARY 7/16/12 RIH WITH 2.25" JSN, TAGGED LATERAL DIVERTER AT 6015' CTMD, I BLE TO MAKE IT DOWN, POOH, RIH WITH 2.5" JSN USING PIPE STRAIGHTENER, DID NOT ENCOUNTER CRYSTAL SEAL IN D LATERAL, CT HIT LOCKUP AT 12,695' CTMD, F/P TBG, READY FOR S /L, JOB IN PROGRESS 9/12/12 LOCATED TBG TAIL @ 5967'SLM - 5980' RKB. TAGGED @ 6040' RKB. IN PROGRESS. 9/13/12 BRUSHED DB PROFILE @ 5905' RKB. SET 3.812" DB LOCK & 5/16" CHOKE IN CMU @ 5905' RKB. COMPLETE. 9/16/12 PULLED 5/16" CHOKE ON 3.812" DB LOCK FROM 5905' RKB; MISSING PACKING PIECES AND SPRING FROM DB LOCK. BRUSHED TUBING TO 5905' RKB. READY FOR CTU / CRYSTAL SEAL. 9/17/12 PULLED DIVERTER FROM 6006' KB AND PRONG FROM PLUG AT 6060' KB. WELL FREEZE PROTECTED. JOB IN PROGRESS. 9/18/12 PERFORMED WEEKLY BOP TEST. PULLED PLUG FROM 6060' MD. SET TYPE 1 ISO SLEEVE AT 6014' CTMD (6006' MD). JOB IN PROGRESS. 9/19/12 PERFORMED FLUFF AND STUFF TO 13,002.1' CTMD USING SEAWATER AND SAFE LUBE. FREEZE CT G TO 2000' TVD. WELL READY FOR CRYSTAL SEAL. JOB IN PROGRESS. /23/12 PERFORATED LINER FROM 9475' TO 947 CTMD. PUMPED 1500 UNDS OF CRYSTAL SEAL TO T' B- LATERAL. APPROXIMATELY 800 POUNDS PLACED INTO LINER PRIOR TO STACKING OUT WEIGHT. TOP OF CRYSTAL SEAL OUT OF COIL AT 7000'. WELL FREEZE PROTECTED. JOB COMPLETE. 1.-- • KUP • 1 E -102 COnOCoPhillip5 0. Well Attributes Max Angle & MD TD I nc. Welibore AP W WI Field Name Well Status Incl ( °) MD (RKB) Act Btm (ftKB) 500292323600 WEST SAK INJ 93.36 12,518.09 - 14,360.0 "`-° Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well Cones: -1E-102 10/26/2012 9 :02 :28 AM SSSV: NIPPLE Last WO: 31.31 1/7/2005 Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: WELL REVIEW /UPDATE PERFS osborl 10/26/2012 Casing Strings HANGER, 23 = , ` Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ' ° ' CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K - 55 WELDED z: Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd `" SURFACE 103/4 9.794 30.1 3,186.0 2,415.7 45.50 L -80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd INTERMEDIATE 75/8 6.875 27.2 6,498.8 3,708.8 29.70 L -80 BTC -M Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D- SANDWINDOW 75/8 6.000 6,005.0 6,015.0 3,630.6 Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D -SAND LINER LEM 4 1/2 3.958 5,9469 6,154.1 3,663.5 12.60 L -80 IBT Liner Details Top Depth (TVD) Top Inc! Nonni... CONDUCTOR, Top (RKB) (RKB) (°) Item Description Comment ID (!n) 3t -toe __ 5,946.9 3,613.9 74.30 PACKER BAKER ZXP LINER TOP PACKER 5.500 NIPPLE, 511 5,966.7 3,619.4 74.64 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,986.0 3,624.6 74.98 XO BUSHING XO BUSHING 4.500 5,994.0 3,626.7 75.12 HANGER LEM ABOVE HOOK HANGER 4.500 6,004.3 3,627.5 74.89 HANGER LEM HOOK HANGER 1958 6,059.7 3,642.7 76.11 NIPPLE CAMCO 'DB' NIPPLE W/3.562" PROFILE 3.562 GAS LIFT, 6,150.9 3,662.8 77.71 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 3.157 Casing Description String 0... String ID ... Top (RIO) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B -SAND LINER 4 1/2 3.958 6,111.6 14,332.3 3,650.7 12.60 L -80 DWC Liner Details Top Depth AL [ 30-3,166 (TVD) Top Incl Nonni... Top (ftKB) (ttKB) (1 Rem Description Comment ID (in) 6,111.6 3,652.7 76.42 PACKER HRD ZXP LINER TOP PACKER 5.500 GAS LIFT, 5,453 6,130.6 3,657.8 77.04 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 - 6,133.4 3,658.5 77.14 HANGER FLEX -LOCK LINER HANGER 5.500 NIP 6,144.1 3,661.1 77.48 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 IF SLEEVE -C. 6,163.4 3,665.6 78.11 XO BUSHING XO BUSHING 4.500 5,905 AIR 14,298.0 3,651.9 91.94 BUSHING DRILLABLE PACKOFF BUSHING 3.958 MP Tubing Strings i . ':._. • Tubing Description String 0... String ID ... Top (R6B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LOCATOR, TUBING 41/2 I 3.958 I 22.6 I 5,981.1 I 3,623.3 12.60 L -80 IBTM 5,953 ` e Completion Details m Top Depth Nonni... SEAL ASSY, (TVD) Top Inc! 5,954 W, Top (RKB) (RKB) r) Item Description Comment ID (in) 1 t 22.6 22.6 -0.41 HANGER VETCO GRAY TUBING HANGER 4.500 SHOE, 5,980 II 511.3 508.9 13.11 NIPPLE CAMCO'DB -6' NIPPLE w/3.875" NO GO PROFILE 3.875 .- 5,905.4 3,604.9 76.14 SLEEVE -C BAKER CMU SLIDING SLEEVE w /CAMCO 181 'DB' PROFILE 3.810 (CLOSED 1/17/2005) 5,952.8 3,615.5 74.40 LOCATOR BAKER LOCATOR 3.875 5,954.5 3,616.0 74.43 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 ■t 5,980.1 3,623.1 74.88 SHOE 3.000 D-SAND Perforations & Slots WINDOW, Shot 6,005 -6,015 11 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (RKB) (RKB) Zone Date (sh... Type Comment N 6,507.0 14,295.0 3,710.1 3,652.0 WS B, 1E -102 12/25/2004 32.0 SLOTS Altemating solid 1 ft/slotted 2jts pipe, 2.5" x .125" slots, 4 circum. rows/ft, 3" centers, 18 deg. orient 9,470.0 9,475.0 3,736.9 3,736.7 WS B, 1E -102 9/23/2012 6.0 IPERF 5" GUN, BH CHARGES, pumped 1500# crystal seal Notes: General & Safety ■ End Date Annotation 'I 1/6/2005 1/6/2005 NOTE: B -SAND LINER LEM IS OPEN, NO ISO SLEEVE, NO DIVERTER NOTE: MULTI - LATERAL B-SAND & D -SAND WELL 1/29/2009 NOTE: View Schematic w/ Alaska Schematic9.0 5/13/2010 NOTE: LDL SHOWS D -SAND LEAK @ - 8900' RKB L 4: so 0 -591413 LINER LEM, 5,9476,754 IIlit y NTERMEDIATE, 27-6,499 IPERF, 9.4709,475 SLOTS, 6.064 - 14.278 SLOTS. 6,507-74,295 DLSAND LINER, 6,004 - 14,4,378 18 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (RKB) (RKB) (°) Make Model (in) Sery Type Type (,n) (psi) Run Date Corn... e -SAND 1 3,156.9 2,406.3 68.97 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 3/14/2005 6,11214332 2 5,453.1 3,474.5 65.42 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 3/23/2005 TO (7E -102 14,360 Z4)4 L3,' O Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] Sent: Wednesday, October 24, 2012 4:58 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E-102, 10/23/12 Jim, The low pressure pilot (LPP) on injector 1E -102 (PTD# 204 -231, 204 -232) was defeated on Oct. 23, 2012 when the well was returned to injection service after being shut in on Oct. 22 to evaluate a breakthrough event. Current wellhead pressure is 4 psi at an iJection rate of 896 BWPD. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 Cell: (281) 796 -5044 SCANNED APR 0 9 2013 • • KU ► E o--2_ ?- 4z3 o Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] '1,e-e) Sent: Monday, October 22, 2012 5:35 PM t` 10( 'I To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: 1E-114 AND 1E-102 removed from Safety Defeat Log: 10/22/12 Jim, West Sak injectors 1E-114 (204 -171, 204 -172, and 204 -173) and 1E-102 204 -23204 -232) have been shut -in and removed from the safety defeat log due to breakthrough events in bo wells. 1E-114 was shut in on Oct 18, 2012 and 1E- 102 was shut in on Oct 22, 2012. The AOGCC will be notified when the injectors return to service. Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 APR �� Cell: (281) 796 -5044 SCANNED A 1 • P iTh6 ZotI 2 Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] Sent: Wednesday, October 17, 2012 3:52 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E-114 AND 1E-102: 10/17/12 Jim, The low pressure pilots (LPPs) on both injectors 1E -114 (204 -171, 204 -172 L1, and 204 -173 L2) and 1E -102 (PTD# 204- 231,204 -232) were defeated on Oct. 17, 2012 when the wells were returned to injection service after being shut in for MBE remediation. Current wellhead pressures and injection rates are as follows: 1E -114 Wellhead Pressure: 3 psi Injection rate: 1220 BWPD 1E-102 ✓ SCANNED APR 0 9 2013, Wellhead Pressure: 256 psi Injection rate: 1021 BWPD The LPPs and SSVs have been tagged and their status is recorded in the "Facility. Defeated Safety Device Log." The AOGCC will be notified when the injection pressure of each well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 Cell: (281) 796 -5044 1 Regg, James B (DOA) 0025 i© From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] / Sent: Thursday, September 13, 2012 4:55 PM '\ '� lll` c/ /4 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Short, Suzanne C; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E-102: Sept 13, 2012 Jim, The low pressure pilot (LPP) on West Sak injector 1E -102 (PTD# 204 - 231,204 -232) was defeated on 9/13/2012 when the well was brought online in water injection service. The well was shut in on 6/23/12 due to over - injecting, and a new downhole choke has been installed. Current wellhead injection pressure is 106 psi and injection rate is 1430 bwpd. The AOGCC will be notified when the injection pressure has increased and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any questions. Thanks, Amanda Patterson West Sak Production Engineer , ConocoPhillips Alaska, Inc. SCANNED 1' Office: (907) 265 -6782 Cell: (281) 796 -5044 1 • • • riD w '1- lj 1 1 --- SEAN PARNELL, GOVERNOR "iC, u Lrid , , i,, k Li --- ' 11 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. � P.O. Box 100360 — 4' 3 I Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -102 Sundry Number: 312 -160 Dear Mr. Peirce: 4iiiiiMED AP `Z , ZOIZ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holida 43 weekend. Sincer orman om • sioner DATED this 7, day of April, 2012. Encl. • STATE OF ALASKA RECEIVED A OIL AND GAS CONSERVATION COMMI N AP FOR SUNDRY APPR VALS APR 2 0 2012 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Chanetb"Gm r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension E Operational Shutdown r Re -enter Susp. Well r Stimulate Al ter casing 9 r Other:Crystal Seal MBE p • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 -231 . 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23236 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1E - 102 ` 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25651, 25648 • Kuparuk River Field / West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14360 3650 14332' 3651' 6060' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108' 106' SURFACE 3156 10.75 3186' 2412' INTERMEDIATE 6472 7.625 6499' 3709' B -SAND LINER 8221 4.5 14332' 3651' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6507' 14295' (slotted liner), 8880' - 8885' 3710' - 3652' (liner), 3735' - 3735' 4.5 L - 80 5981 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - HRD ZXP LINER TOP PACKER MD= 6112 TVD= 3653 NIPPLE - CAMCO 'DB -6' NIPPLE W/3.875" NO GO PROFILE MD= 511 TVD= 509 12. Attachments: Description Summary of Proposal F.,-• 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service ` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/26/2012 Oil r Gas r• WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG F. . Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature „ Phone: 265 -6471 Date zW 1 2 Commission Use Only (CO Sundry Number: 312 -1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r• BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: 0 /, APPROVED BY Approved by: � MI SSIONER THE COMMISSION Date: Z� 1z 1 m 10 -403 Revised 1/2010 {� r n' � � CRP 1 S S ubmit in Duplicate - ®NIS A PR 2 6 20 L /� R l7 I V �, 17� 1 "Z-=,� �� U' • • 1E-102 to 1E-121 MBE Treatment An (PROF on 6 -6 -06 found a Matrix Bypass Event (MBE) in 1E-102 in the B sand lateral at 9480' RKB behind 4.5" slotted liner. Most PWI appears to exiting the slotted liner at this MBE. Per the proposed procedure, this MBE will be sealed with Crystal Seal. Halliburton Crystal Seal product is intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. Crystal Seal is a dehydrated crosslinked synthetic swellable polymer gel available in various granular mesh sizes. Crystal Seal can swell to 400 times original size by absorbing water. Due to swellability of Crystal Seal, it can be used to fill highly conductive large voids or channels (MBE's) that dominate reception of injection fluids in a welibore. Procedure: Coil Tubing 1) Pull Diverter from the D LEM at 6006' MD. 2) Pull DB Plug from 3.562" DB Nipple at 6060' MD to enable access to 1E -102 B sand lateral. 3) Set !so-Sleeve with 2.75" min ID across the D LEM at 6006' MD to isolate the D sand lateral. 4) RIH with nozzle to perform a B lateral Fluff & Stuff cleanout of the slotted liner to 9600' CTMD to ensure that the B lateral will be free of any fill obstructions above the MBE at 9480' RKB before attempting CTC perforating and Crystal Seal pumping. 5) RIH with BHA on 2 "coil tubing consisting from bottom to top of 2" OD x 5' OAL TCP Perf Gun, a 2 -1/8" OD closed Circ -Sub, and hydraulic disconnect. Park perf gun to fire 6 spf large hole charges at 9470 - 9475' RKB in the 4.5" slotted liner above the MBE at 9480' RKB. Drop a ball to fire the perf gun, then spot the Circ -Sub over the pert interval. Drop ball #2 to shift Circ -Sub open, then pump Crystal Seal through the Circ -Sub and the perfs to seal the MBE. Pump: a) Seawater down coil. Hold a steady rate between 1 - 2 bpm during treatment through step f Flush to monitor treating pressure at a stable rate. Swap from Seawater to 2% KCI and pump, b) 2% KCI Water with 0.05 ppg Crystal Seal (we use 4 mm mesh for stages b through e) down coil. Each stage volume is TBD during pumping based on treating pressure rise during stage. c) 2% KCI Water w /0.10 ppg Crystal Seal down CT, or go to Flush (step f) if we see screen out. d) 2% KCI Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCI Water w /0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out is seen, open CT x Tbg annulus to return tank, and pump 1 CT volume Seawater Flush to displace Crystal Seal slurry from coil to well while POOH. If screen out is not been seen prior to Flush, leave CT x Tbg annulus SI and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to MBE while POOH to D LEM, then swap to 53 bbls of Diesel FP down coil, followed by 1 CT volume of Diesel ( -40 bbls) to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait 6 hours before return 1E-102 to PWI for evaluation. 4. KU P 1 E- 102 • COnot o Ph Alaska, illip5 0-4 Well Attributes Max Angle & MD TD InG Wellbore API/UWI Field Name Well Status Inci(1 MD (RKB) Act Btm (ftKB) ConociaPha' lips 500292323600 WEST SAK INJ 93.36 12,518.09 14,360.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date - SSSV: NIPPLE Last WO: 31.31 1/7/2005 I Well Conk': -1 E-102, 12/12/2011 8:48:59 AM 3chemaric -ADuet Annotation Depth (RKB) End Date Annotation Last Mod ... End Date • Last Tag: Rev Reason: SET DB LOCK ninam 12/12/2011 Casing Strings HANGER, 23 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd o CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K WELDED • z . : Casing Description String 0... String ID ... Top (5KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 30.1 3,186.0 2,415.7 45.50 L -80 BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd INTERMEDIATE 75/8 6.875 27.2 6,498.8 3,708.8 29.70 L -80 BTC -M iiimmomems. r Casing Description String 0... String ID ... Top (RKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd D -SAND WINDOW 75/8 6.000 6,005.0 6,015.0 3,630.6 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D- SANDLEM 41/2 3.958 5,946.9 6,154.1 3,663.5 12.60 L -80 IBT Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd B -SAND LINER 4 1/2 3.958 6,111.6 14,332.3 3,650.7 12.60 L -80 DWC CONDUC70R,_� Liner Details 31 -108 Top Depth - (TVD) Top Intl Nomi... NIPPLE, 511 I Top (RKB) (RKB) r Item Description Comment ID (in) ` - -- 6,111.6 3,652.7 76.42 PACKER HRD ZXP LINER TOP PACKER 5.500 6,130.6 3,657.8 77.04 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 6,133.4 3,658.5 77.14 HANGER FLEX -LOCK LINER HANGER 5.500 6,144.1 3,661.1 77.48 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 GAS LIFT, semi* 6,163.4 3,665.6 78.11 XO BUSHING XO BUSHING 4.500 3,157 14,298.0 3,651.9 91.94 BUSHING DRILLABLE PACKOFF BUSHING 3.958 s -_ Tubing Strings SURFACE, Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... Siring ... String Top Thrtl 30 -3,186 A TUBING I 41/2 3.958 I 22 5 3623.3 12.60 I L -80 I BTM Completion Details GAS LIFT, 4 Top Depth 5.453 (TVD) Top Inol Nomi... Top (RKB) (RKB) ( °) Item Description Comment ID (in) 22.6 22.6 -0.41 HANGER VETCO GRAY TUBING HANGER 4.500 SLEEVE -C, 5 511.3 508.9 13.11 NIPPLE CAMCO 'DB-6 NIPPLE w/3.875" NO GO PROFILE 3.875 PROFILE, 4.. ar 5.905 5,905.4 3,604.9 76.14 SLEEVE -C BAKER CMU SLIDING SLEEVE w/CAMCO 3.81 'DB' PROFILE 3.810 IMI (CLOSED 1/17/2005) a 5,952.8 3,615.5 74.40 LOCATOR BAKER LOCATOR 3.875 LOCATOR, 5,954.5 3,616.0 74.43 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 5,953 t t- 5,9801 3,623.1 74.88 SHOE 3.000 SEAL ASSY, Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 5,954 / T Depth (TVD) TO Intl SHOE, 5,980 Top (RKB) (RKB) (°) Description Comment Run Date ID (In) / 5,905 3,604.9 76.14 PROFILE 3.81" DB LOCK & 5/16" CHOKE 12/11/2011 0.313 6,004 3,627.4 74.88 DIVERTER NEW TYPE 1 DIVERTER IN D SAND LEM 9/3/2011 3.668 6,060 3,642.8 76.11 PLUG SET DB Plug [body 28.5" OAL] 8 P -Prong [43" OAL] (1 3/8" 10/25/2006 neck) ISOLATING B -SAND Perforations & Slots H Shot Top (ND) Btm (TVD) Dens DIVERTER, Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (ah °• Type Comment fi.00a 6 ,507 14,295 3,710.1 3,652.0 WS B, 1E -102 12/25/2004 32.0 SLOTS Alternating solid 1 j6slotted 2 jts pipe, D -SAND 2.5" x .125" slots, 4 circum. rows/ft, 3" WINDOW, centers, 18 deg. orient 6,005-6,015 WINDO 11 ll N 8,880 8,885 3,734.6 3,734.8 8/31/2011 6.0 IPERF 60 DEG PHASING w/ 0.6" HOLES Notes: General & Safety End Date Annotation 1/6/2005 NOTE: B -SAND LINER LEM IS OPEN, NO ISO SLEEVE, NO DIVERTER 1/6/2005 NOTE: MULTI - LATERAL B -SAND & D-SAND WELL 1/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PLUG, 6,060 5/13/2010 NOTE: LDL SHOWS D -SAND LEAK @ - 8900' RKB A. ....., Rt. 1 le D -SAND LEM, 5,947.6,154 .. Br F Mandrel Details NTERMEDIATE, Top Depth Top Port 276,499 _ (TVD) Intl OD Valve Latch Size TRO Run 8,8806,885 1 .909 RKB) ( °) Make Model On) Sery Type Type (in) (psi) Run Date Cont... s OTS5 Stn Top (MB) ( . - 1 3,156.9 2,406.3 68.97 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 3/14/2005 , 6,064-14,278 SLOTS, 2 5,453.1 3,474.5 65.42 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 3/23/2005 6,507 - 14,295 D -SAND LINER, 6,004-14,318' B -SAND LINER, 6,112 - 14,332 TO(1E -102), • 14,360 Ili • • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 ©conocophillips.comj Sent: Tuesday, December 20, 2011 6 :38 AM To: Maunder, Thomas E (DOA) Subject: LPP /SSV Returned to Service on 1E-102: 12- Dec -2011 Tom and Jim, The low pressure pilot (LPP) on the well listed below was retumed to service on 12/12/2011 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure and injection rate are also listed below. This pilot had been defeated on 09/16/2011 in accordance with "Administrative Approval No. CO 406B.001." The injection pressure has increased on the following well so as to remain above 500 psi and the LPP /SSV function has been returned to normal. Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1E-102 (PTD# 204 -231 04 -232) 671 2469 Please let me know if you have any questions. Thank you. Daniel Bearden /David Lagerlef CPF1 Production Engineers - ; t 4 n1269 @conocophillips.com - `,>. °;:.. 907 -659 -7493 pager 907-659-7000 #765 From: Gauer, Tenn L Sent: Friday, September 16, 2011 4:55 PM To: CPF1 Prod Engr; 'Maunder, Thomas E (DOA) ' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E -102: 16 -Sept -2011 Tom, The low pressure pilot (LPP) on 1E-102 (PTD# 204- 231,204 -232) was defeated on 09/16/2011 when the injector was returned to service after being shut in since August 31, 2011. As of 1650 hrs on 09/16/2011, wellhead injection pressure is 158 psi; injection rate is 2100 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi or the B -sand has been isolated again and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 12/20/2011 STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well E Plug Perforations C` Stimulate f'" Other MBE Sealing Alter Casing r Pull Tubing ` Perforate New Pool r Waiver F lime Extension r D Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. . Development r Exploratory f k. 204 - 231 3. Address: 6. API Number: Stratigraphic r Service 1 P. O. Box 100360, Anchorage, Alaska 99510 • 50 - 029 - 23236 - — 00 7. Property Designation Number): 8. Well Name and Number: ADL 25651 & 25648 ` 1E 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 14360 feet Plugs (measured) 6060' true vertical 3650 feet Junk (measured) None Effective Depth measured 14332 feet Packer (measured) 6112 true vertical 3651 feet (true vertucal) 3653 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108' SURFACE 3156 10.75 3186 2412' INTERMEDIATE 6472 7.625 6499 3709' B -SAND LINER 8221 4.5 14332 3651 `2 J (E ` i �' 'p� i3�y �� : L" r_� C. U ' ' ' �' �nr. g s q- _ { Js ~' , � �C � ., C R VE Perforation depth: Measured depth: 6507- 14295' (slotted liner) SEP 2 8 2flf1 True Vertical Depth: 3710' -3652' (slotted liner), 3735-3735' Alaska Oil & Gas Cons. Commies• io Anchorage Tubing (size, grade, MD, and TVD) 4.5, L -80, 5981 MD, 3623 TVD Packers & SSSV (type, MD, and TVD) PACKER - HRD ZXP LINER TOP PACKER @ 6112 MD and 3653 TVD NIPPLE - CAMCO 'DB -6' @ 511 MD and 509 TVD 11. Stimulation or cement squeeze summary: / /� .� r Y Intervals treated (measured): b l�ls.� f r"t'K' Treatment descriptions including volumes used and final pressure: 9.27. /t see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 9701 Subsequent to operation 520 13. Attachments 14. Well Class after work: • Copies of Logs and Surveys run Exploratory r Development r Service 17 Stratigraphic °" 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX 0, r GSTOR WINJ E WAG Fi GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -179 Contact John Peirce Ca. 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date el r 7 / 1 / Zi .c e` gs„.__, i,„ Form 10 -404 Revised 10/2010 MOMS SEP 2 8 Submit Original Only 1E-102 and 1E-102L1 Well Work Summary DATE SUMMARY 8/26/11 PERFORMED PRES/TEMP GRADI SURVEY WHILE RIH WITH WELL ON I CTION AT 620 BWPD, 735 PSI. STOP AT 6000' ELMD TO MEASURE FBHP FOR 30 MIN, 1015 PSI, 68 DEGREES. SHUT -IN WELL AND MEASURED PRESSURE FALL -OFF FOR 3 HOURS AT 6000' ELMD. MEASURED GRADIENT SURVEY WHILE POOH WITH WELL SHUT -IN. SAW FLUID /GAS INTERFACE AT 5848' ELMD. CAPACITANCE CURVE WS ERRATIC ON THE RIH PASS DUE TO GAS PRESENT IN THE FLUID COLUMN. 8/31/11 PERFORATED D SAND LAT SLOTTED LINER @ 8880 TO 8885' CTMD, PERF INTERVAL PROVIDED 6 SPF AT 60 DEG PHASING, HOLE DIA ARE APPROX 0.6 ", ATTEMPTED TO PUMP CRYSTAL SEAL, ENCOUNTERED DIFFICULTIES GETTING BALL ON SEAT WITH PERF GUN AND CIRC SUB, RESTART TOMORROW DUE TO TIME OF DAY, WH FP, IN PROGRESS, 9/1/11 FAILED ATTEMPT TO PUMP CRYSTAL SEAL, UNABLE TO PASS THRU THE TYPE 1 DIVERTER IN THE D LAT LEM, PULL DIVERTER NO APPARENT PROBLEMS W/ DIVERTER, IN PROGRESS, 9/2/11 FAILED ATTEMPT TO SET DIVERTER IN THE D LEM LAT, JETTED TUBING W/ SIDE JET NOZZLE ACROSS THE HOOK HANGER AND THE D LEM WINDOW, BACK TOMORROW, IN PROGRESS, 9/3/11 SET NEW TYPE 1 DIVERTER INTHE D SAND LEM @ 6004 MD, PUMP CRYSTAL SEAL, 2530 LBS OF 4MM PRODUCT WAS PUMPED IN 306 BBL OF 2% KCL SOLUTION ACROSS PERFS @ 8880- 8885 CTMD IN THE D SAND LAT. WH FP, JOB COMPLETE ,y • KU P • 1E 102 Co� [Welttrutes l Aib Max Angle & MD TD t . S � llborn APUUWI I Field Name Well Status Inc! ( °) MD (ftK6) Act Btm (ftKB) rFr I 500292323600 WEST SAK IN.! 9336 I 12,518.09 14,360.0 ~ 1 SSSV: Comment H2S (ppm) Date I 0n 'End Dafe KB (11) Rig Release Dale NIPPLE !Last 03 W 31.31 31 1!7!2005 ,.-,.. -- t o °""`"' -"'- ShcOrdellc �v _ An Annotation 'Depth ( E n d Date Annotation Lest Mod ... End Dat Last Tag: - L / Rev Reason: ADD PERFS & DIVERTER ninam 9/7/2011 C St rings HANGER, 23 - Casin g Description String O . String ID . Top (ftKB) Set Depth (f Set Depth (TVD) .. String Wt . String String Top Thrd w " COND 310 108.0 8 90 WELDED Casing oesc nption String 20 0... String 19 ID 124 ... Top (ftl( Set Depth (L.. Set Dept .0 (N ... String 4 0 WI... String K - 55 . Stdng Top Thrd " SURFACE 103/4 9.794 30.1 3,186.0 2,415.7 45.50 L-80 BTC Casing Description String 0... String ID ... Top (HIM) Sat Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 75/8 6.875 27.2 6,498.8 3,708.8 29.70 L - 80 BTC - M - B) T Thrd : ' Casing Description P String O... String ID... Top (RIM) Set Depth (f... Set Depth (TVD) I ... String WI... String �� String W D -SAND WINDOW 75/8 6.000 6,005.0 6,015.0 3,630.6 �.- C sing Description String 0... String ID ... Top (81103) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd i D - SAND LEM 41/2 3.958 5,946.9 6,154.1 3,663.5 12.60 L - 80 IBT Casing Description String 0... String ID ._ Top (ftKB) Set Depth (f... _ Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 , B - SAND LINER 41/2 3.958 6,111.6 14,332.3 3 650 7 12.60 L80 , DWC CONDUCTOR_ Liner Details 31 -106 Top Depth ,' (TVD) ) Top Inc] NIPPLE, 511 Rani_ Top (ftKB) ( I C) Item Description Comment (in) I 6,111.6 3,652.7 76.42 PACKER HRD ZXP LINER TOP PACKER 5.500 6,130.6 3,657.8 77.04 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 6,133.4 3,658.5 77.14 HANGER FLEX -LOCK LINER HANGER 5.500 6,144.1 3,661.1 77.48 SBE 1907 CASING SEAL BORE EXTENSION 4.750 GAS LIFT, - 6,163.4 3,665.6 78.11 XO BUSHING XO BUSHING 4.500 3,157 3,651.9 91 94 BUSHING DRILLABLE PACKOFF BUSHING 3.958 74.298 -0 __1.. _ __. _.. l Tubing Strings Tubing Description String 0... String ID... Top (ftKB) Set Depth (t.. . Set Depth (TVD) I String Wt... String .. String Top Thrd Su 36 - 3,186 TUBING 41/2 3.958 226 I 5,981.1 3,623.3 I 12.60 L-80 IBTM ! Completion Details _ GAS LIFT, V - Top Depth 5,453 (IVO) Top Intl N mi... Toy(nt(B) iftKS1 PI Item Description c ommnnt D(in) 22.6 22.6 -0.41 HANGER VETCO GRAY TUBING HANGER 4.500 511.3 508.9 13.11 NIPPLE CAMCO'DB -6' NIPPLE w/3 8 /5" NO GO PROFILE 3.875 5,905 5,905.4 3,604.9 76 -14 SLEEVE -C BAKER CMU SLIDING SLEEVE w /CAMCO 3.81 'DB' PROFILE 3.810 i (CLOSED 1/17/2005) 5,952.8 3,615.5 74.40 LOCATOR BAKER LOCATOR 3.875 LOCATOR, 3.616.0 74.43 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 5 980 11 5.953 Other In Hole (Wireline e retrievable _ SHOE 3.000 sEALASSV, - { plugs, valves, pumps, fish, etc.) 5,954 , ' Top Depth (TVD) Top Inc! SHOE, 5,980 Top (ue) (ftKB) ( °) Description Comment Run Date ID (in) ■ 6,004 3,627.4 74.88 DIVERTER NEW TYPE 1 DIVERTER IN D SAND LEM 9/3/2011 3.668 6,060 3,642.8 76.11 PLUG SET DB Plug [body 28.5" CAL) & P -Prong [43" OAL] (1 3/8" 10/25/2006 neck) ISOLATING B -SAND I a rte' -e:: 7+ f . "-- 4 Y 1 -' 24 Shot Top (TVD) Btm (TVD) Dens I 1 Top (ftKB) Mtn (fg(B) (ftKB) (ftKB) Zone Date (sh... Type Comment DIVERTER, 6,507 14,295 3,710.1 3,652.0 WS B, 1E -102 12/25/2004 32.0 SLOTS Alternating solid 1)1/slotted 2 jts pipe, 6,004 2.5" x .125" slots, 4 ctrcum. rows/ft, 3" centers, 18 deg. orient DSAND WINDOW. -- . `- -- 6,665 - 6,915 I l 8,880 8,885 3,734.6 3,7348 8/31/2011 6.0 IPERF 60 DEG PHASING w/ 0.6" HOLES t� (,/ • Ens General y Annotation _. _... NOTE E i } Notes: General & Safety 1/6/2005 NOTE: BSAND LINER LEM IS OPEN, NO ISO SLEEVE, NO DIVERTER ■■ 1/6/2005 NOTE: MULTI- LATERAL BSAND & D-SAND WELL 10 Q I f'j 1/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 R 5/13/2010 NOTE: LDL SHOWS DSAND LEAK @ ` 8900' RKB (G t / A (r - (O � ) /I Y ' il P LUG, 6,060 f ! �r 1 `' f o?_L_f ' •• " DSAND LEM, 5,947 -6,154 n - Mandrel Details ,,,, a x NTERMEDIATE, ` 6' Top Depth Top I Port 27-6,409 ' "rt ' : (TVD) Inc! OD Valve Lath I S1ce TRO Run 8,8805,885 I ! Stn Top (t1K6� SLOTS, (ftKB) 1) Make Model (in) Sens Type TYP ( ) (Ps) Run Date Can... ' a 1 3,156.9 2,406.3 68.97 CAMCO KBG 1 GAS LIFT BK - 5 0.000 0.0 3/14/2005 " 6,064-14,278 '"' ; Szo I - LINER, • - ,�� GAS LIFT OMY BK -5 0.000 0.0 3/23/2005 6,507 _ k 2 5,453.1 3,474.5 65.42 CAM KBG - 2 1 D -SAND 6,004- 14,318 BSNND LINER, - 6,112- 14,332 \ I TD (1E-102), • 14,360 2 «755 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 20, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey : 1E -102 Run Date: 9/16/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -102 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23236 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23236 -00 StANNED MAY 1 6 LU1Z PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 1 i 1$ `' Signed: )41444 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 16, 2011 5:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: FW: LPP /SSV defeated on 1 E -102: 16- Sept -2011 Tom and Jim, Please see information below. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 ti pager 659 -7000 765 From: Gauer, Jenn L Sent: Friday, September 16, 2011 4:55 PM To: CPF1 Prod Engr; 'Maunder, Thomas E (DOA)' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E -102: 16- Sept -2011 Tom, The low pressure pilot (LPP) on 1 E -102 (PTD# 204 - 231204 -232) was defeated on 09/16/2011 when the injector was returned to service after being shut in since August 31, 2011. As of 1650 hrs on 09/16/2011, wellhead injection pressure is 158 psi; injection rate is 2100 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi or the B -sand has been isolated again and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. f ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 9/19/2011 • • 2D4 23( WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 7, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 1E -102 Run Date: 8/26/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -102 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23236 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23236 -00 St-ANNEDMAY 1 6 U12 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: I 9/1 Signed: s - • • • S 113A [E Lit[LAs-A ® SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. a0 , - " P.O. Box 100360 sL 2 all Anchorage, AK 99510 .41 *Fr Re: Kuparuk River Field, West Sak Oil Pool, 1E-102 Sundry Number: 311 -179 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair s DATED this % day of June, 2011. Encl. STATE OF ALASKA Cff ALAS AND GAS CONSERVATION COMMISSI� 1 i.I+ . APPLI T ION FOR SUNDRY APPROVALS lV 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Ftug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r ` Other: MBE Sealing iv ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 -231 3. Address: Stratigraphic r Service 2. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23236 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: ,. Spacing Exception Required? Yes r No 17 1E -102 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651 & 25648 • Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14360 - 3650 • 14332' 3651' 6060' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108' 108' SURFACE 3156 10.75 3186' 2412' INTERMEDIATE 6472 7 -5/8" 6499' 3709' B -SAND LINER 8221 4.5" 14332' 3651' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 6507'- 14295' 3710' -3652' 4.5 L - 5981 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - HRD ZXP LINER TOP PACKER MD= 6112 TVD= 3653 NIPPLE - CAMCO 'DB -6' MD= 511 TVD= 509 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG I✓ Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature 7474 l/.-- • ,� -s-r-c___ Phone: 265 -6471 Date Sf 2 Sif Commission Use Only Sundry Number: 6l'- po Conditions of approval: Notify Commission so that a representative may witness Plug Integrity f ' BOP Test r Mechanical Integrity Test r Location Clearance r CE!VED IlA`X ''r ii ?f1' Other: Als5tta Oil Si (i8, CM*. CWitat sSIOP Subsequent Form Required: /6 — t/ p 41 1 .. ilr.1)'; !'8i)tt k) . , APPROVED BY 61/2 � t l Approved by: COMMISSIONER THE COMMISSION Date: Form 10 -403 @IAS1c1UN 0 2 2 Q `40 L Submit in Dupiicate /// • , �i • Sealing 1E-102L1 to 1E-121L1 MBE i" A matrix bypass event (MBE) occurred May 2010 in 1E-102L1 (D lateral) during Viscosity Reducing Injection (VRI) with breakthrough to 1E-121L1 producer. A diverter was set in the D LEM at 5994' RKB and a 5 -13 -10 IPROF in 1E-102L1 found an MBE at 8900' RKB. 1E-102 has been shut -in since May 2010 due to MBE's in both the B and D laterals. Halliburton CrystalSeal is intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through the formation to offset producers. CrystalSeal is a water swellable dehydrated crosslinked synthetic gel polymer available in various granular mesh sizes. CrystalSeal swells to 400 times initial size in presence of water by hydrating and absorbing water. Due to swellability of CrystalSeal it is often used to fill highly conductive large voids or channels (MBE's) that readily accept very high rates of injection. Procedure: Slickline: 1) Pull DV's from GLM's at 3156' & 5453' MD; set memory T & P gauges in each of the GLM's. Coil Tubing: 2) RIH with perf gun & shoot 10' of big hole perforations in 4.5" slotted liner at 8900 - 8910' RKB to enable CrystalSeal entry past the slotted liner to the MBE. POOH with perf gun. 3) RIH w /Active -Coil until nozzle is across perf interval at 8900 - 8910' MD, then pump 40 bbls 2% KCI Pad down coil at initial rate of 0.7 bpm. Work rate to max rate allowable while taking any returns from the CT x Tbg annulus, followed by 5 bbls 2% KCI with 0.1 ppg CrystalSeal (4 mm size) at max rate allowable while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.25 ppg CrystalSeal (4 mm size) at max rate allowable while taking returns from CT x Tbg, ✓ followed by 20 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) at max allowable rate while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) while ramping rate down to 0.7 bpm and taking returns from CT x Tbg, followed by shut -in of CT x Tubing annulus, followed by 60 bbls (target) 2% KCI with 0.4 ppg CrystalSeal (4 mm size) down coil at steady target rate of 0.7 bpm to stay below frac gradient while squeezing slurry to MBE and monitoring treating pressure at nozzle. Cycle nozzle up and down over perf interval to mitigate screen out, and to N help remove any bridging buildups of CrystalSeal across perf interval. If screen out (pressure spike) is seen during pumping, stop mixing slurry and open CT x Tbg annulus to take returns to surface to halt the squeeze, followed by a swap to displacement to push remaining CrystalSeal in coil to liner. If pumping proceeds OK to target of 60 bbls, open CT x Tbg at completion of this stage and take returns, if any, to surface to halt the squeeze on the MBE, then swap to pumping displacement of 50 bbls 2% KCI down coil at 0.5 bpm to push all CrystalSeal from the coil to the liner while POOH with nozzle to D LEM at 6006' MD, followed by POOH with coil pumping 45 bbls of Diesel for FP, followed by 1 CT volume of Diesel to fully displace all 45 bbls of Diesel FP into the tubing. RD CTU. Wait at least 6 hours to let the CrystalSeal fully hydrate before returning 1 E -102L1 to PWI to evaluate effectiveness of treatment in sealing the MBE. Return 1 E -102L1 to PWI slowly in step rate fashion (ie: 0.25 bpm, 0.4 bpm, 0.6 bpm) to observe post- treatment PWI rate vs. WHIP, and to evaluate if injectivity has changed as a result of treatment. t • KUP • 1E -102 I C onoc�lSi o ii Well Attributes Max Angle & MD TD • _ ANI°640k1G 7 Wellbore APUUWI F Id Name Well Status Inc! -) MD (ftKB) Act Btm (8103) tAnoecYhtt8p5 500292323600 WEST SAK I INJ i 93 36 12,518.09 14,360.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date SSSV N IPPLE Last WO 31.31 1/7/2005 _.._..._.. �k+ t£ 4,. caPI9. ..,}....{1,i1R2#?,?,'2P.1x v. I ^Amuai .. Annotation ( Depth (ftKB) End Date Annotab Last Mod ... End Date Last Tag: Rev Reason' D -SAND LEAK Imosbor 5/15/2010 Casing Strings HANGER, 23 3 ^" Casing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd I I y Casing CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K WELDED a '' ': � g Descri ption S 0... String ID ... Top (Nn) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 1 03/4 9.794 30.1 3,186.0 2,415.7 45.50 L BTC a Casing Description S 0... String ID... Top (ftKB) Set Depth (T... Set Depth (TVD) ... String Wt... String ... String Top Thrd 7 INTERMEDIATE 75/8 6.875 27.2 6,498.8 3,708.8 29.70 L-80 BTC -M .__ Casing Description String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (ND) ... String WI... String ... String Top Thrd DSAND WINDOW 75/8 6.000 6,005.0 6,015.0 3,630.6 Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd 0 - SAND LEM 4 1/2 3.958 5,946.9 6,154.1 3,663.5 12.60 1 IBT .- -- - -- - - _-_ _�- r : Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String lop Thrd ...�" B LINER 41/2 3.958 6,111 6 14,332.3 3,650.7 12.60 L DWC . . -_. .acv diner Details CONDUCTOR, Top Depth -- 31 -108 (ND) Top Inc! N NIPPLE, 511 ' Top (9NCB) (ftKB) ( °) Hem Description Comment ID (in) 6,111.6 3,652.7 76.42 PACKER HRD ZXP LINER TOP PACKER 5.500 ,_ -.. 6,130.6 3,657.8 77.04 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 6,133.4 3,658.5 77.14 HANGER FLEX -LOCK LINER HANGER 5.500 6,144.1 3,661.1 77.48 SBE 190 -47 CASING SEAL BORE EXTENSION 4.750 6,163.4 3,665.6 78.11 XO BUSHING XO BUSHING . 4.500 GAS LIFT, 1 1 42980 3,651.9 91 94 PACKOFF BUSHING 1 3.958 I Tubing Strings Tubing Description 'String 0 String ID ... Top (ftKB) I Set Depth (1... Set Depth (ND) . String Wt... String .. String Top Thrd SURFACE, TUBING 41/2 3958 226 5,981.1 3,623.3 1260 L -80 I IBTM 303186 Completion Details Top Depth GAS LIFT, (ND) Top Intl Nomi... 5,453 Top (ftKB) (ftKB) ("1 Item Description Comment 10 (in) Sr 22.6 22.6 -0.41 HANGER VETCO GRAY TUBING HANGER 4.500 ig 511.3 508.9 13.11 NIPPLE CAMCO 'DB-6' NIPPLE w/3.875" NO GO PROFILE 3.875 5,905.4 3,604.9 76.14 SLEEVE -C BAKER CMU SLIDING SLEEVE w /CAMCO 3.81 'DB' PROFILE 3.810 SLEEVE 5,905 (CLOSED 1/17/2005) 5,952.8 3,615.5 74.40 LOCATOR BAKER LOCATOR 3.875 - ._ l 5,954.5 3,616.0 74.43 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 it Ilt 5,980.1 3,623.1 74.88 SHOE 3.000 S.�f3 'LTM, ..,r ` , ": e� '� ---11, Other In Hole (Wlreline retrievable plugs, valves, pumps, fish, etc) a��,�._- Top Depth SEAL ASSY, v_ (ND) Top Inc' 5.954 ------ (((��' Top (ftKB) (ftKB) ( '') Description Comment Run Date ID (in) , SHOE, 5s8o - - - - -- 5,994 3,626.7 75.12 DIVERTER BAKER TYPE 1 DIVERTER IN D-SAND LEM 3/31/2010 3.688 - - - - ' F 6,060 3,642.8 76.11 PLUG SET DB Plug [body 28.5" OAL] & P-Prong [43" OAL] (1 3/8" 10/25/2006 r --- neck) ISOLATING B -SAND Perforations & Slots Shot DIVERTER, F 6,507 14,295 Top 3, 0 at 3,652 0 0 WS B, 1E -102 1225/2004 Dens 5, Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh - -- Type Comment DIVERTER, _ s .____ _.. s ss4 _ - - - a , N 32.0 Slots Alternating solid 1)VSlottetl 2 its pipe, 2.5" x .125" slots 4 circum. rows/ t, 3" centers, 18 deg orient D - SAND - .. -J. _. _..... _..�._. - - -_- __ WINDOW, Notes: General & Safety 6,0056 „ End Date Annotation I - -- i i ' 1/6/2005 NOTE B -SAND LINER LEM IS OPEN, NO ISO SLEEVE, NO DIVERTER 1/6/2005 NOTE: MULTI - LATERAL B -SAND & D-SAND WELL 1/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 5/13/2010 NOTE: LDL SHOWS D -SAND LEAK @ "8900' RKB PLUG, 6,060 we /: D -SAND LEM. 5,947 - 6,154 a n. Mandrel Details 'Top Depth Top P80 we .. (TVD) Intl OD Valve Latch Site TRO Run , , Stn Top (ftKB) (ftKB) ('1 Make Model (in) Sore Type TYpe ON (Psi) Run Date Con... NTERMEDIATE, , 1 3,156.9 2,406.3 68.97 CAMCO� KBG - 2 1 GAS LIFT DMY BK - 5 0.000 0.0 3/14/2005 27 27e Slots, r II m 2 5,453.1 3,474.5 65.42 CAMCO' KBG 1 GAS LIFT DMY BK - 5 0.000 0.0 3/23/2005 6,064 - 14,278 78 do '- -" Slots, ' ? � 6,507 - 14,295 . DANND LINER, 6,006 - 14,318 _ ' 13-SAND LINER,- h. TD (1E-102L " 14,360 • • Page 1 of 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] P j~ ~~ ~Z3 ~ Sent: Sunday, June 27, 2010 8:14 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay ~~~ ~~~1 i ~ Cc: NSK Problem Well Supv Subject: KRU 1 E MIT's Attachments: KRU 1 E pad 062610.x1s Please find the attached 4 Year MITIA for 1 E-102. Let me know if you have any ques ions about t e data: Also for your information we have 2 more long term SI wells (1 E-19 & 1 E-30) on the pad that require MIT's this month. Pending discussions from town this week, we may choose to carry them on the monthly injector report in lieu of the MIT pe'r Guidance bulletin 10-002. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~...~, 6/28/2010 I...J Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~~~"`Z ` (, ~ 2'0 ~ t c FIELD /UNIT /PAD: Kuparuk /KRU / 1 E DATE: 06/26/10 OPERATOR REP: Ives/Mouser - ASRC AOGCC REP: Waived by Bob Noble STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer Depth Pretest Initial 15 Min. 30 Min. Well 1E-102 Type Inj. N TVD 3,616 Tubing 1,100 1,100 1,100 1,100 Interval 4 P.T.D. 2042310 ~ T pe test P Test psi 1500 Casing 875 2,00 1,980 1,97 P/F P Notes: OA 160 165 165 165 Well Type Inj. TVD Tubin Interval P.T.D. Type test P Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test P Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1E pad 062610.x1s Page 1 of 1 Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Monday, May 24, 2010 4:41 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; Pierson, Chris R Subject: FW: LPP/SSV No Longer Defeated On 1 E-102, 13-May-2010 Correction of previous email subject line. Correct well is 1E-102, not 1J-102. I apologize for the error. Please let me know if there are any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 Pr~iE ~j ~~_~a~°-~ a ~ ..: From: Pierson, Chris R Sent: Monday, May 24, 2010 4:38 PM To: CPFi Prod Engr; "Maunder, Thomas E'; "Regg, James B' Cc: CPFl DS Lead Techs; CPFl Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF18~2 Ops Supt; Pierson, Chris R Subject: LPP/S5V No Longer Defeated On 1J-102, 13-May-2010 Tom/] i m, The low pressure pilot (LPP) on 1E-102 (204-231 and 204-232) is no longer defeated, as the well was shut-in at 19:50 hrs on May 13, 2010. Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 7/2/2010 • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr (n1269@conocophillips.com] Sent: Sunday, May 09, 2010 7:24 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Pierson, Chris R Subject: LPP/SSV defeated on 1 E-102 - 5-09-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 1 E-102 (204-231 and 204-232) was defeated on 5/09/2010 when the well was returned to injection service after being shut since 12/29/09. Downhole surveillance is planned for 5/10/10 and the well will be shut-in 5/11/10 pending the next step in the wellwork plan for this well. Current wellhead pressure (as of 19:15 5/09/10) is 0 psi; injection rate is 686 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. C0 406B.001." Please let me know if you have any questions. Daniel Bearden CPF1 Production Engineer ConocoPhillips Alaska, Inc. 659-7493 _ c ~ ~ .~,.~ {J~ ~ z . ~'1 i . ~"~ ~+="ti. .~4- .. 5/10/2010 Maunder, Thomas E {DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 06, 2010 3:32 PM To: Pierson, Chris R Page 1 of x Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FW: MBE event in West Sak VRWAG project (1 E-102 PTD 204-232) ~ ~ ~~ Chris, Just got in the 403 sundry to convert to water Injection for 1 E-102. This will effectively ban further Mt injection into 1 E-102 until the MBE event(s) has been diagnosed and fixed. As part of the sundry follow-up for the 10-404 please submit the diagnostics results as soon as they are finished. We are keenly interested in what the results may be concerning the nature and type of the MBE. Regards, P.S. could you please forward this to Mellisa Gangl , I don't have her email. Guy Schwartz Petroleum Engineer AOGCC rt ~~~i~. j~~~ ", r ~~a~-e ~~,. 793-1226 (office) -:,,f~r:~ ~ '~~ 444-3433 (cell) rom: Schwartz, Guy L (DOA) t: Monday, January 04, 2010 3:34 PM To: y, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject. E: MBE event in West Sak VRWAG project I hope it is the p leaking in 1 E-102 ... don't think it is likely though as it is a standard DB plug set in a nipple. They don't usually st" start leaking and if they do it would have to be a huge leak in order to restart an MBE in the lower B lateral. ~f it truly is a D lateral MBE... (very rare .. think there is only one other I know of) it doesn't bode well for VR G. Will be interesting to follow the diagnostics on this one........ Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Roby, David S (DOA) \ Sent: Monday, January 04, 2010 2:53 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Regg, James B (DOA) Subject: RE: MBE event in West Sak VRWAG project E (DOA); Schwartz, Guy L (DOA); I just heard more from CPAI on this event. The MBE occurred between the 1 E-1 injection well and the 1 E-121 producer on the 29th. They noticed pressure falling off on the injector and shortly the after the offset producer began producing at higher GOR. They did shut this well in as soon as the noticed a pro m and they also shut in the other well that was injecting gas, the 1 E-117, as part of this project despite the fact that re was no indication of any problems with it or its offset producer. Samples taken from the 1 E-121 well sh MI from the 1 E-102 well. 1 E-121 remains on production with a decreasing GOR. There has not been any indi tion of any sort of containment failure. 7/29/2010 Maunder, Thomas E (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, January 04, 2010 3:34 PM Page 1 of 2 To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: RE: MBE event in West Sak VRWAG project hope it is the plug leaking in 1 E-102 ... don't think it is likely though as it is a standard DB plug set in a nipple. They don't usually "just" start leaking and if they do it would have to be a huge leak in order to restart an MBE in the lower B lateral. So if it truly is a D lateral MBE... (very rare .. think there is only one other I know of) it doesn't bode well for VRWAG. Will be interesting to follow the diagnostics on this one........ Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Roby, David S (DOA) Sent: Monday, January 04, 2010 2:53 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) a0y-'~3 ~Oy"~~~ Subject: RE: MBE event in West Sak VRWAG project I just heard more from CPAI on this event. The MBE occurred between the 1 E-102 injection well and the 1 E-121 ~~ producer on the 29th. They noticed pressure falling off on the injector and shortly there after the offset producer began producing at higher GOR. They did shut this well in as soon as the noticed a problem and they also shut in !~~ the other well that was in~ectin as, the 1 E-117, as part of this project despite the fact that there was no ~~ mica ion o any pro ems wit it or its o et producer. Samples taken from the 1 E-121 well show MI from the 1 E-102 well. 1 E-121 remains on production with a decreasing GOR. There has not been any indication of any sort of containment failure. The 1 E-102 and 1 E-117 both remain shut in. CPAI plans to return the 1 E-117 to gas injection service when they have completed gas analyses from its offset producer to ensure there has been no MI breakthrough in that well. The plan proposed plan forward for the 1 E-102 is to convert it back to produced water injection service so that ~v~l ~} ~. they can run logging tools to diagnose the problem. The well had a previous MBE in the lower lateral, the B-sand, which was isolated in October 2006 by installing a plug in the mother bore to shut off injection into this lateral. They need to determine whether this plug is leaking, which would be the easier fix, or if an MBE has occurred in the upper lateral, the D-sand. They will be sending in a 403 to convert the well to water injection and describe in more detail what diagnostic work they plan to do. They also said that they would not have expected a new MBE to occur so quickly, so they are leaning towards a leaking plug that allowed gas to flow through the existing MBE or an MBE was forming in the D-sand while the well was on water injection and would have still occurred even if the well was not converted to gas injection. Dave Roby (907)793-1232 From: Roby, David S (DOA) Sent: Monday, January 04, 2010 1:08 PM To: Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: MBE event in West Sak VRWAG project 7/29/2010 Page 2 of 2 i I just got a call from Scott Redman with CPAI about a MBE occurring in one of the wells they are injecting gas in as a part of the West Sak VRWAG pilot project. The well was on gas injection for approximately one month prior to the MBE event occurring and is a well that previously had a MBE event when on water injection. At this time they don't know if it is a new MBE channel or if the plug isolating the previous one has failed. They will most likely be switching this well back to water injection so that they can perform diagnostics and determine whether the MBE is a new one or the old one reopened and how to shut it off. I believe he said, but can't remember for certain, that the well was shut in when the MBE was detected. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 7/29/2010 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 07, 2009 7:50 AM To: Dave Roby; Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: FW: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1 E-102 & 1J-170L1 Attachments: Picture (Metafile); Picture (Metafile) Dave, et al, Here is some information regarding a call I got yesterday on MBE events and isolations in these segments. Have the sundries to convert been approved? Tom From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Tuesday, October 06, 2009 5:28 PM To: Maunder, Thomas E (DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1E-102 & 1J-170L1 Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11/15/09), I have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining to zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-170L1 that were not included in the 10-403 submittals. Well 1 E-102 MBE to offset Producer 1 E-121 Date Well 1 E-102 PTD# 204-231 10/25/2006 BRUSH DB NIPPLE @ 6060' RKB. SET 3.562 DBP PLUG @ 6060' RKB. SET P-PRONG INSIDE DB PLUG BODY @ 6060' RKB (13/8 FISH NECK-43" OAL ). (( B-SAND IS ISOLATED )). JOB COMPLETE. Well 1J-170L1 MBE to offset Producer 1J-166 Date Well 1J-170L1 PTD# 206-063 8/10/2008 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET. Please provide direction as to what is needed to move the process forward. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. Tubing, Special Drift to +l- 500' MD 511' MD, 508' TVD, 12.5° - 3.875" DB Nipple 3156' MD, 2399' TVD, 66.3° -GLM, Camco 1" KBG-2 5453' MD, 3474' TVD, 65.4° -GLM, Camco 1" KBG-2 5905' MD, 3604' TVD, 76.1 ° - CMU Sliding Sleeve, wl 3.81" DB Nipple 10-3/4" 40.5/45.5# Casing Shoe, set @ 3186' MD, 2412' TVD Tubing String 4-112" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 5947' MD - 5-112" X 7-5/8" ZXP Liner Top Packer 5967' MD -Casing Sealbore Receptacle 4.75" ID, 6.25" OD, 20' Length 6004' MD - 4-112" X 7-518" Model 'B' HOOK Hanger Seal Bores 3.688" ID 6029 MD - Liner Swivel, 4-1/2" 6060' MD - 3.562' DB Nipple 4-1/2" 12.6# Tubing 3.833" Drift 3.958" ID / 5-112" X 7-518" ZXP 1 Liner Top Packer / ~ with Hold Downs ~\ 5-1/2" X 7-S18" Flex Lock Liner Hanger / Packe Liner Hanger Assembly at slag' MD -Casing 6111.60' MD Sealbore Receptacle " \ ~ 5 0 '~\CC(J~ ~,.1 3-112" Bent Joint - 3-112" Guide Shoe `~``ii1~= 3-1/2" Casing Shoe, 12.6#, L-80 IBTM Set @ 1431 ' MD, 3614' TVD 14281' MD - Pack-off Bushing ~~.,~-. ~~,~,`C~~` GSe~~ ii~~3- 6151' MD -Seal 'B' Sand Lateral ~~ I Assembly 4.75" Seal OD 4-1/2" 12.6#, L-80, D 3.875" ID Slotted Liner e ~ 4-1/2" Eccentric f i Guide Shoe 4.75" ID, 6.25" OD CONFIDENTIAL 2o'Length 7-5/8"Casing Shoe, Set at @ 6499' MD, 3709' TVD Baker Hughes 2DDl. This document may not be reprotlucetl or tllstrlbu[etl, in whole or In part, In any form or by any means electronic or mechanical, Including photocopying. recortling, or by any Intormaaon storage and retrieval system now known or hereafter Invented, without written permission from Baker Hughes Inc. 2001 West Sak ]S/8" Dual Lateral Completion -Infector li ' 5954' MD -Seal Assembly, w/ spacer, 4.75" Seal OD 3.875" ID, 26' long r ConocoPhillips West Sak 7-5/8" Injector 1 E-102 Dual Lateral Completion ~~ Baker Oil Tools FINAL As Completed 5987' MD -Tubing Swivel, 4-1/2" 'D' Sand Lateral 5994' MD -Lateral Entry Module (LEM) D-sand Window @ 6006' MD, a-1 n^ 12.6#, L-8o, Dwc, . ;~ 75° InC Slotted Liner Equipment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.68" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +I- 3.89" Diverter and Sleeve Length: +1-18.5' 4-1/2" Casing Shoe, 12.6#, L-80 IBTM Set @ 14332' MD 14298' MD -Pack-off Bushing J ~ ~ • • ConocoPh ~ I I ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~ :~~~~~~~ ~ ~~ FEB~~?n~~ . , „~.:~.,:;a~~:;e~ _ €'° 4 '~, ~• „ :• ~ ~,$~~a~ ~ ~i~.~c~els ~~';: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. West Sa.k injection well 1E-102 (20_ 4-231), 1E-102L1 (204-032) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any ques~iens. Sincerely, v~'~ ~ ~-,,~{, ~~+ ~~~~~~ ~a ~ ~ 3 200~ ~. MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~ , _ ; ~~~~~~ Y C~.i ~E~ ~ 7 zoos 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiyer '~ `;' ~/ Alter casing ^ Repair well ^ Plug PerForations ^ ~1pCI10t Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: 5. Per to D' Number: ConocoPhillips Alaska, Inc. oeveiopment ^ ~pioratory ^ 4- '' 3. Address: Stratigraphic ~ Service ~ 6. I umber: P. O. Box 100360, Anchora e, Alaska 99510 5~9- 9-23236-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name d ber: where ownership or landownership changes: i E ti R i S d? ^~ I~~ ng xcep on re pac equ Y@S NO ~ - ' 9. Property Designation: 10. KB Elevation (ft): 1 ie ool(s): ADK 25651 & 25648' RKB 94' `~ k River Field / West Sak Oil Pool • 12. PRESENT WEL N ITI U MARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ):,~ lugs ( easured): Junk (measured): 14360' • 3650' ~ Casing Length Size M ND Burst Collapse CONDUCTOR 108' 20" 10 ' 108' SURFACE 3092' 10-3/4" 86' 2415' INTERMEDIATE 6404' 7-5/8" 6498' 3709' LI NER g221' 4-1 /2" 4332' 3651' Liner 208' 4-1/ " 54 3664' F.. Perforation Depth MD (ft): Perf r ti D h N (: ~ Tubing Size: Tubing Grade: Tubing MD (ft): 6507-14295 3 1- \ 4-1/2" L-80 5981' Packers and SSSV Type: Packers an SSSV MD (ft) Baker SBE Seal Assembly & ZXP liner top Pac 5947' & 6112' no SSSV - Camco DB-6 Nipple 511' 13. Attachments: Description Summary of Pr osal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^' ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: ~~ c> / LS ~' Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG 0• GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certiy that the for going is true and correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ oveland Per d~lll Title: Well Integrity Project Supervisor Signature ,~?;~ ~~~ /~ Phone 659-7043 Date ~.:~~~3~~, ~ Commission Use Onl Sundry Number: Conditions of proval: Notify Commission so that a representative may witness ' ,.- ~Q . Plug Inte ty ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: M J ! h. ~l t~o h n-arT ~. PP/'o veN ~~- G c ~~ / ti~~ ~ . .. . a Subsequent Form Required: APPROVED BY Approved by: CO SI R TH COM I SION Date: Form 10-403 Revised 06/2006 ! ~ ~ + ~ ~ ~t ~ ~ ~ v~ Submit in Duplicate . . r _ , '~ ~. ~~/~e•~ .is ~ x .,~. ~i' ~ • ConocoPhillips Alaska, Inc. West Sak Well 1 E-102 (PTD 204-231), 1 E-102L1 (PTD 204-232) Sundry Notice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in / West Sak Injection Well 1 E-102 (PTD 204-232) and gain approval to do so. This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of VRWAG to West Sak for a potential future project to expand EOR on a broader scale. See attached pattern map. Well History: 1 E-102 was completed in February 2005 as a pre produced injector and placed in water only injection service in April 2005. ~ The well was driiied with a 20" conductor to 108'. The surface hole was drilled with a 13 '/Z" bit and cased with 10 3/" casing to a TD of 3186'. The casing was cemented in place with 423.5 bbl of lead cement and 95 bbl of tail cement. Full returns were attained with 125.2 bbl cement of 10.7 ppg cement to surface. The floats checked ok. The intermediate hole was drilled with a 9 7/8" bit and cased to 6498' with 7 5/8" casing. The casing was cemented in place with 128.5 bbl DeepCrete cement with full returns. The calculated top of cement is confirmed at 3634' by a USIT log. The USIT log also shows good bond through and above the West Sak and Ugnu intervals. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. lnject VRWAG cycles into 9 E-102 2. Injection well 1 E-102 will be operated and maintained in compliance with 20 AAC 25 and Area Injection Order 2B. 3. All West Sak wells with in '/4 mile of 1 E-102 will be completed (or recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oil and gas samples from the offset West Sak producers. 5. All Kuparuk wells with in'/4 mile will have OA pressure indicating transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. ~ ~s- , r ` ~~ r•- ~ ~,. ~L ." ~ ~ .,,Q..- ~ ~ 1' I ' ''+ ' ] ~' ~ ~ ~`_5 . ~ ' y .~_.~! , ~ ~ ( f ~ S ~ ~ F ~ _ ' _' -_ r ' ~. ~ 1 E-102 ~_ ~ ~~: _- -- ~ ~ .__~ ~ ,~ ~.~ ~ ~ _ , ; _ ~ ~ -. '~-`~ . _`~ , .y~ ~ a ,~ y _. ~ r, ~ :. ~ - . a~ I! '~ ~ ~` r ~ ~ i ~ ,~ -.,~ ~ , ~. . : ~ 2009 WSAK EOR , ~~ ._~'' : ~~ .~' ~ ' 1 ~ ~ ~ ~ • Pattern Targets ' ~ - _~_ ~ ' ._~~ .= ; _" ~,a _ t _ .. . ~ . ~ _-~.:. ~ . _.~ ~_ _ ,, . . ,~ ., ~ ~ ~ ~ ~ ~ . ~~- ~ . , . . - : ~' _ `~, :. ~ _ ~ '~ - - f~- ,± ~#~:~~- ~ ~- 1 J-122 1 J-170 ~ p _ ~: . ~- ~ , , r~- f f ~ ~ ± ~ ~ - ~ ~ , I L 5 ' ~ j a I w I ' ( w~ ~ ~ ' ' -9 ~ ~ • ~ ' ~ ~~ ' ~ ~ .; ~ ~ ~ . '+ ~ . '~ . I ~ ~ ' ~ } + ~ . • __~ F ~ . y J ~ _ ~ ~ ~ r , ~ ~ ~' ;, . ~ - = - + ~ ' ~ ~ - r , ~ • , ' , = ~ ~ . , ~ ~ ~ _ ~ - i~ ~ - ~ i : ~ r _ ~ ec~a s~,x~,sd v~+t 117 ~ ~ 1 E ~- - i ~ ~ ~ --- „~ N~ .~, - ~• ~ ' _ -,~-,~ ~.,~,~,~, ~. ~ 4 _ a ;~ ~ ~ ~ ~ - C~Char KRU ~'tifall I f ~ a 3~ + ~ ~ YV'~' hta~vr .`ie~aMny Faults ~ t ' l ' 1 ,~ - . ti~1S Far~~S t ~ ~ r ' ~ ~ ~~ ~~~ ~e C+~ PnpCUGer P d ~ ~ ~ ~ ~ ~ ~ .~ I no ~ uoer SI Producer , I .~~ • P i/W A ` I j +~ ~ Y_d~ '~ c • ~10 . ~ ~ ' ~, . . .. tE- 1F4 rn= BufMBr ~ ~` 4 l Rv~+v /J4 m~ Bufrsr ~ ~ ~ /'. N Rovv 114 rn~ BufMt ~ ~ L 2S O.g ' . t,$ - ~ ' ' _ ~Q Row 7!4 m~ BuKet ~f7IF9itE• BOl1~'-48ry' yy°' PR B ~--_: :~: ::. r.~~Nes , aund~ry ~ ~ Bottom interval 6300'-6457' Mid interval 4270'-4470' •Interval between 6457' and 3271' logged •343' of cumulative good cement bond •Impedance highly varied around circumference of hole •Top of cement @3634' MD -reported at 3743' MD 1 E-102 Cement Log Tops UG C 4,419 UG B 4,973 UG A 5,140 K13 5,560 WS D 6,009 FEET FEET }H.GR_MWD_S_ 1 42`JO "LtiUl 4300 4350 285~ 4400 4450 290~ 4500 4550 295~ 4600 4650 30Q( 4700 4750 305( 4800 4850 31 Qi 4900 4950 315( 5000 5fl50 320( 5100 5150 3255 5200 5250 330( 53D0 5350 5400 335I 5450 5500 34Q( 555~ 5600 565D 345t 5700 5750 5800 5850 3501 5900 5950 6000 6050 355( ?~- 6100 ~-- 615D ~ 6200 ~-- 6250 ~- 6300 6350 3sai 6400 6450 6500 I ~~ ~ ~ ~ ~ ~ Schwartz, Guy L (DOA From: Maunder, Thomas E (DOA) Sent: Wednesday, October 07, 2009 7:50 AM To:. Roby, David S(DpA); Schwartz, Guy L(DpA); Davies, Stephen F{DOA) Subject: FW: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1 E-102 & 1 J-17~L1 Attachmen~: Picture (Metafife~; Picture (Metafile) Dave, et al, Here is some information regarding a call I got yesterday on MBE events and isolations in these segments. Have the sundries to convert been approved? Tom From: NSK Prod Engr Specialist [mailto:n1139Ca~conocophillips.com] Sent: Tuesday, October 06, 2009 5:28 PM To: Maunder, Thomas E (DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1E-102 & 11-170L1 Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11/15/09), I have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining to zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-170L1 that were not included in the 10-403 submittals. Well 1 E-102 MBE to offset Producer 1 E-121 Date We111 E-102 PTD# 204-231 10/25/2006 BRUSH DB NIPPLE @ 6060' RKB. SET 3.562 DBP PLUG @ 6060' RKB. SET P-PRONG INSIDE DB PLUG BODY @ 6060' RKB ( 1 3/8 FISH NECK-43" OAL ). (( &SAND IS . ISOLATED ) . JOB COMPLETE. VlOeli 1J-170L1 MBE to offset Producer 1J-166 Date Well 1J-170L1 PTD# 206-063 8/10/2008 PULL BSAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE S ET. Please provide direction as to what is needed to move the process forward. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 j924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. ~ ~~~1 ~~1 ~~~~9~~~~`~ ~~J~~~~ ~ ~ ~ ~~~~~rn ~thi~ ~/~ ~I~ rad~u~ ~~~~ tt~~ • ~ ~~~ ~ ~~~ ~d~a~ent capture p~oducer~ ar~ ~urr~ntly ~r ~r~ll ~~ ~~r~~~~ ~~~~ t~ L cornpletion~ ~ith pa~k~r~ ~~~~r~ !/RI ~t~~t ~~ ~~~~~n~e~ ~~~~ 4~~~ectors hav~ prir~ary cern~~~ ~~vew~~~ tl~~ V~l~~~ ~~~ ~~d U~~u ~~rrnati~n~ ~~d h~v~ ~it~l~ ri~k ~~ ~~~in~ pr~~~~r~ ~~ ~~~~~~ ~ ~r II p n trat~ons ~nrithi~ u~rt~r il~ r~di~~ Nli ~~~~ i~~re annular r~~~ure~ ~~1C~~3 \~11;; ~C?~ !l11e1! Integrity Review with AOGCC . January :'~, :~Oi)4 5 -- ~~~-~ b ~~-~+r~~~F~h I I I i ~s ~..,~~~~~' 1 Em10~ Pattern =iG~ ~~ ve~ • 1 E-121, 1 B-101, 1 B-07, and 1 B-08 all fall within '/4 mile ofi 1 E~-102 ~1 E~102-343' of cumulative good cement b~nd ~ ~ 1 E-121 to be converted to a GL Completion 1 St qtr 09 0 1 B-101-Shut in jet pump well with packer ~nd surface casing ~ 1 B-07,1 B-08- OA's to be monitored •On downthrown side of sealing fault from a oil colurr~n charge perspective 0 1 B-07,1 ~-08 have no cement acro~s th~ West Sak and lJgnu Intervals ~ 2U0~ V1I5 ~~~ VVell Integrity Review with AOGCC Januar/ 21, 2009 13 ConocoPhillips 1 E-102 Inj~ctor Cement Details ~~~ ~ .~.~. ~n ~ ,~ ~r~~~ ~ ~ 14 January 21, 2009 2009 WS EOR Well integrity Review with AOGCC - _.- - -7 -r ~ ---~ -r - ~a -~ _--7~ - .. ir~~~~ ! r~ 4*~•.. ~ - 're ~ 1 .' _ ~ •,~+i~ ~?~ ~#~- . ~:f,~~ =, DEPT ~ ~ FeFr !+ t ~ -tR i ~ ~ /~i.. ~,I i ~'r.--~4'A;C7--- ~ ~ ~ &~ !}~ ~~s... ~~ry~ 1 ~O V ~~ p~ ~SC~ ~+, '~?~' )~ I~ ] : GA ;r y~, I ~ ' ~ ~ZJD ~~ ~ .,~ .~~~~,~~ - ~ ~634j ~ ~` ~ 4300 " ~„'. •' i -~,~-.~~. . ~ 4350 ~ ~~` ~j~y ~_ _ . ~,-,. 4400 ~,~~ ~" ~ ~i ~~ ,~".~.~..+:~,:-,.+~.~~- ~~ ~: ~_ . ° ,~ ,~' ' 4450 ~~ ~°' .~-s~,~,,~.;~,,.~.~~,-.~~~µ, 45~~ ~ ~~ ~ "x- ~t a~, ~ ' ~ ~ _ ,,~ ; = -_ 45~0 " ~ :n „~~ ~ ~ ~~. n ~,, n w 'r 4600 ^~;:.. : ~ i ~~.' ~ ~~. ~ r~.:,.. ~~.: ' ~ ~ r '" 4650 ~ ~ ~ ~ -"'~ ~~ ~, ~, ° ~ 4~00 ~~ ~~: ~~~~~ ~`~ ~-,~~~a'~~~-~~ .y ~~.':! __ ~~~n ~', .~~ ~ , ~,, ~ ~. , ;~ . ~ ~ .;„ ~. ~ ~ tt ~_'~ , ._ . " ~ ' ~ • .,; ~ ~ ~,, r~~ ~' +R~B ~ '' `n4- ~..,, ~a: ~a „ ~.:T~~ .A~;-s7 :u ,a ~ a ~f ~- ; ,'~.. r~"~`°i?.~'- , ~ ~ .,~ ^ry ~' ~ .~.fc».,, I ~~x , ~? + t~ y~ _ ~ ~.} ,~~~S ~ 1:~~ x` • Y~i ~j ~~y~^~aM'! ~~ r3~.d~~ I~-~. ~'~ ~~ _ tl ~ ~. .^!.ir ~ .. ~~~.~.~ ~ Yn. ~~'-~ y E~~~ ~-:~ _~ J h ~~b`^ a1 i.~t • f'!"'~.},1'3~~ ~~ "~ ~.h4(~ `~ 1l.. w.~v ~Ty~. R- -~~alr'~- .1~~'y '}~ ~R'Llis~.~. ',~~ ~ ~. ~I~" y~T'+•• irI' ~ ~ f ~ _ ,: ~9x. ~°°~,"'~+,:. .,,~~ d ~ : ~-u:~ ~', -,. ~ ° ~a,~, .eI Yu ~ R'~ ~.7+P6^^~7f~:.~`E's -~"w,;y~)~.p " . ~ a . ~ ~.~ . _., ^~ "~ i~ r "7i" tt ~ ~'~ ^ ', E ,~~,: ,... ~x. -~. 5~: ~ T o ~~ ~ . ~ ~ .." ~ ~~ ~ Q - i ' ~ ~I.w ~ ^~ L -.- ~ . 3 ~ ~~'~ ~Y ~ ~1 ~t~ ~,~r`_.- ~~ ~' ~ ..y ~ .' f .~ ~ ~ ~ ~ ~a.i' 4 1 ~ ~ ~ ~ 4 `~ ' i 'q`^r"w} ~ . yS 1n . F~'} 'h~.' !9 , t if~. E f }..~ { M ~ NA y 4^ #'~" - Y' vi y3 ~~, ~ ~ '' .d+ ,~ ~ € ;~;~ sy`~'7k " ~ -.5:.. ti+~~ ~d "~ ~n~ ~ • ,. . ~ ,~ ~ ~~ , "~ ~~~ ".,. ,~ s~= : ~SY"C .+w <+* ~ '.' ~ k ~ i4+Mb 3$ ~' 2+~ y ~^AA"Y.~F'1FA ~ g ^ ~*~ ~-' { ~ xY`~ c ~ n, ~;'" V f~ > ~ z ~"' ~+` "M" ~ ~ - ~ ~ „~. ,~ d~. ~S r'~ :: „. ;~ ".~ : -~.~ ~ ~~ ~ °"~ ~ '~-v ,m.- ~~ *~ ~ ~ ~ ~ "~ ~ ~ r ~y t . ~ a: ~ ~ ~":~. , R "t~a'r ~~.~., ~.>.« . ~~~.~` Battiom interval 6300'-6457' Mid interval 4270'-4470' ~Interval between 6457' and 3271' logged 0343' of cumulative good cement bond •Ir~~pe~ance highly varied around circumference of hole •7op of c~ment @3634' MD -reported at 3743' MD 1 E-1 ~2 C~nnent Log y ~lJ V V - a~ " -'~~~ ;;~y .~ i ~ _ 5350 , '"x .,'~ `s - 5400 ' ... r ~ 3 - i r -~, "r ~ ~' n ~ = 5450 "~'~. ~ `r~,'~ _"" ¢ 5500I ' ., 4 d ,~S °b ~~ -~~ ~J~~ . ~ ° '~ ~ 5600 ~ ~,:'.~ ~ u~. ti { 565(J ~`'ya M_ ~~,_ _.. ~ f 5700 r~. J7~J~ Top interval 3600'-3730 5e~o 5$SO 5900 Tops UG C 4,4'19 UG B 4,973 UG A 5,140 K13 5,560 WS D 6,~09 59~0 I ~~~ I6500 15 ~~ 31 31 13600 s I ~I ~ :. ! Q ~~~~-~~P'h~ll~~~ ~u rnary ~ 4 attern~ being targ~ted fior 2009 - ~ E-102,1 E-11791 J~17091 J-122 ~ No wells of concern within 1/~ rnil~ r~diu~ ~ff~~tt~n~ these • ~~411 adjac~nt capture produ~ers are currer~tly or ~nrill b~ w~rk~d over to GL cort~pletion~ ~rith pa~k~rs before i/RI ~t~rt up ~ommences - All 4 injectors have prirnary c~r~ent c~v~ring th~ V'V~~t ~~k and lJgnu formations and h~ve little ri~k of s~eing pre~~~re ~t surfiace ~ ~ Kuparuk well penetrati~ns within quarter rr~ile radius ~nrill ha~r~ nnonitored annular pressures . 2009 WS EOR Well Integrity Review with AOGCC January 21, 2009 bp ~ ~~~ y. ~ ~~ 5 ,~~„~, ~~~c~~~~'hillr~s M ti ~i ~~ i t~ 1 ~~1 ~~ ~attern ~ 1 E-121, 1 B-101, 1 B-07, and 1 B-08 all fall within '/4 mile of 1~~-102 ~1 E~102-343' of cumulative good cement bond ~. , ~~ ~ '~~ ~ ~ 1 E-121 to be converted to a GL Cornpletion 1 St qtr 09 ~ 1 B-101 ~Shut in jet pump well with pack~r ~nd surfac~ casing 0 1 B-07,1 ~-08- OA's to be monitored ~On downthrown side of sealing fault from a oil column charge perspective _... ~, ,, , ~; F Q'"' I ~ i r ~ 1 ~ 1 E3-07,1 ~-08 have no cement acro~s th~ We~t S~k and lJgnu I nterval~ , ~ 7.h~)~3 V1r'~ ~~R Well Integrity Review with AOGCC 1J Januar,r 21, 2009 bp ~~`'s . ~~4~ ~c~r~~-~~Ph i I I i pS . . 1 E-102 In~ector Cement Details ~~~ ~ ~~.,~. ~~ r$z~ ~. • s 14 January 21, 2009 2009 WS EOR Well Integrity Review with AOGCC < Tt~ 1 ~` ~'~ ~' ~ '~: .F.~ ~.. ~ rY :,~~ ~ . ~ 2~ .~ °'.~ ~ ,~ A ., -~ . ~---~ ~l~r,:"_T" M ~ ~.~ ~. ~_~_ I R~- ~ = w~ ~ w~rwr:~w ~~ - „ ~...,. I FEEf I FEET ., 6 :_ ~~~}~ ~ 43(]0 E. - t r..13 . ' 4350 285D ~ . ~'~' ~ 4400 __ _ _ .~ 4450 2900 - -...- , _ . : ' -W - '"µ ' "~ 4500 -.-_~..~,r-~..;.-,~-~~.: - - z~5o ~ 7„ ~ ~, . `.~" ~* . -~._ 4550 ~_ ~ a - _ '. t ~ . ~ 4600 ' ' ` ..-r ~ ~ r 4650 3QQ0 ~ a.'"° ,~ -t Nr ' `' ~ ~- 4700 ' „} ~ ~ * ~ , 3050 ~ .. . a ~~; ~s` ~ T ~ ~ - 4750 l Y i ~' • . -~"`' ~ ~~ ~ . ~~. ~ • --~, ~1800 W Y ~~~ ~ ~"' }7' ~ ~ ~ 4850 3160 ~ ~' ., , a ~ . . . ~ _ - - -, r" _ ~ -~ m " ~ 4900 ^+ti ~ ~:-. ' ~~. . . -; ~geo 3150 , ~ :'+ ~°~!` °L , i ~ 5000 ; ..~ hF~ i. ;N ~ ~"_ : ir r.: 5D50 3200 ~ ~,~~~"~ ~ ~ '~__ 5100 ~ ~ - '~ ~ ~ ~ ~ ~"' '.~'.~ • ~ A "~" ~ f , _ 515~ 3250 -. ~ p.,~:,:~.. ;, ~; ~, ~'';. ~ r „~,-~ '" `,~ 3 57Q0 y r 6" ~~. T, '; '~ i C* 3' ~~' '': -~~- ~3 1* ~ 5250 ! " ~~-;.,~-+-a ~9~ .,~ - r ~ ; s=:_ 53Q0 3300 ~ ,, r: ~'~ .:. K~ y .^~ . . " r ~.,~, " - ~ ys^'~' . ` ~ -~~~y ~~- ~ 5350 _ =..~ ` :.~ ~`» .,.~~ ` ~ ~~~ ~- ~ _ 54Q0 3350 -. ~ ~ , ` ~ , " E . ~' _ .s ;~n ~ ° 5450 ? ` ~-~ '~' ~ . ~.~.~ ~--,`- ~ ^s,F r ~~~~ . -~ " _ t 55U0 3400 y~~~ ~ ~? ~*~- '~ .; ~;,~_ ~`-'''`~ `~„~- {Ef 5550 ~ ~ i` ~~,C~ ~:~-" ,~_ ..y~ 4x 9. ,,.. '-~ ~~: `f~ r . ~ F 5~0~ ~ M ; ` 7 '~ "ti '+2 w.. ~p' '~~ T. ~~ .j i x _. ~ ~~'s ~-.^.. ~ :e a ^~~Y~,1~-rs. ~~~ ~~- Bc~ttt~m inte~val 6300'-6457' Niid interval 4270'-4470' ~Ir~t~rv~l between 6457' and 3271' logged ~3~3' ef ~~mulative ~ood cement bond ~I~7~~~dan~~ hi~hly varied around circumference of hole ~~op of ~~ment ~a 3634' IVID -reported at 3743' MD ~ ~-~ ~~ ~~f`~l~l~l~ ~0~ ~.;~r.,+~...-..-..,. 565Q 3450 ~ `~4 " ~ ~ ' fy -~ 5700 ° .~. . : _ _- - _ 5750 Top interval 3600'-3730 5ar~o ~ Tops UG C 4,419 UG B 4,973 UG A 5,14p K13 5,560 WS D 6,009 95 5$50 ~500 59p0 ~ 59~0 sooo _ ~~ 6fl$D 3550 6100 6150 6200 • ~ 6250 630p 6350 3~4D 6400 =L= 6450 ~J ~ 6500 ~ I ~ - • ~ Page 1 of 2 Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, October 17, 2009 9:42 AM To: Schwartz, Guy L(DOA); Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Prod Engr Specialist; NSK Well Integrity Proj Subject: FW: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1 E-102 & 1J-970L1 Attachments: 1E-102 Schematic.pdf; 1J-170 schematic.pdf Guy, Per our discussion, ConocoPhillips requests the withdrawal of Sundry Applications for VRWAG on the B laterals of the following wells: 1 E-102 (PTD 204-231) ~ 1J-170L1 (PTD 206-063) Sundry Applications for the remaining laterals on each well are still requested. 1 E-102L1 (PTD 204-232) - D Sand Lateral 1 J-170 (PTD 206-062) - A Sand Lateral 1 J-170L2 (PTD 206-064) - D Sand Lateral The B sand laterals will remain isolated with sleeves during any VRWAG injection periods. Conceptual schematics are attached to show the approximate location of each iateral. Please let me know if you have any questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: N5K Prod Engr Specialist Sent: Tuesday, October 06, 20Q9 5:28 PM To: Thomas Maunder Cc: Hollar, Erit Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & addiGonal 10-403 information for wells 1E-102 & 1J-llOLi Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11l15/09), I have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining ta zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-17QL1 that were not included in the 10-403 submittals. Well 1E-102 MBE to offset Producer 1E-121. 10/20I2009 ~_ `~. ~ ~ Page 2 of 2 Date Vltell 1E-102 PTD# 204-231 10r1~t~006 BRUSH DB NIPPLE a~ 6060' RKB. SET 3.562 DBP PLU G@ 6Q60' RKB. SET P-PRON G INSIDE DB PLUG BODY a~ 6060' RKB ~ 1 33Ji8 FISH NECK d3" OAl ). ~( B-S~4ND IS ISOtATED . J~B COMPLETE Well 1J-170L1 MBE to offset Producer 1J-166 Date Weil 1J-170L1 PTD# 206-Q63 8/10~2008 PULL B-SAND DIVERTER AND SEf E~~IND ISOLATION SLEE~JE AT 6818'. JAR~ RAN ON FIRST RUN, NOT NEEDED. HiPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET . Please provide direction as to what is needed to move the process forward. Bob Christensen / Darreil Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Rrea Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. 10/20/2009 • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA,. 99510-0360 April 16, 2008, Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue Suite 100 Anchorage, AK 99501 ~ APR ~ ~ 2008 Dear Mr. Maunder:. • RECEIVED APR 2 2 2008 a ai g cap cons. Commi~io~ . a~ ~~,3 "I 1 ~, - 16 2- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosioninhibitor/sealant was pumped on 3/29/2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klein . ConocoPhillips Well Integrity Projects Supervisor • • Y ConocoPhillips Alaska Inc. Sur•F~ce Casing'by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Dt a e 3/29/2008 Well Name PTD # Initial top of Vol. of cement Final top of Cement top off Corrosion Corrosion inhibitor/ cement um ed cemerit date inhibitor sealant date 1 E-34 197-166 ft 9" bbls NA ft 9" al 1 E-102 204-231 14" NA 14" NA NA 7 3/29/2008 1 E-114 204-171 24" NA 24" NA 8 3/29/2008 1 E-126 204-122 25" NA 25" NA 16 3/29/2008 1 E-166 204-153 20" NA 20" NA 14 3/29/2008 12 3/29/2008 • • " ~:~A nnicROFi~n~ED 03/01 /2008 DO NOT PLACE y..: _.:~.;~ ~` ..:~, , ANY NEW MATERIAL UNDER THIS PAGE F:\L,aserFiche\CvrPgs_Inserts~Microfilm Ma~er.c~oc LPPISSV reenabled on 1E-10 • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com~ Sent: Sunday, February 17, 2008 10:10 AM To: Maunder, Thomas E {DOA); Regg, James B {DOA) Cc: CPF1 Prod Supt; CPF1 DS Lead Techs; NSK West Sak prod Engr Subject: LPP/SSV reenabled on 1 E-102 Page 1 of 2 Tom 1 Jim, ~~ The LPP/SSV function on 1E-'It12 PTD#204-231 204232) was returned to normal on 13-Feb-2008. The well is now injecting 1225 bwpd at 589 psi wellhead pressure. Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt !Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: {907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com ~~~~~~E, FEB l 9 200 From: NSK West Sak Prod Engr Sent: Saturday, January 12, 2ot~ 7:W AM To: 'Maunder, Thomas E (tom.maunder@alaska.gov)'; 'Regg, lames B (jim.regg@ataska.gov)' Cc: CPFi Prod Supt; CPFi DS Ledd Techs; Pierson, Chris R; Selisker, Gary R; NSK West Sak Prod Engr Subject: LPP/SSY Defeated ~ 1E-102 Tom /Jim, Water injector 1E-102 (PTD# 204-231,204-232) was shut in from 5-Dec-07 to 11-Jan-0$ to collect surface pressure fall-off data (SPFO). When the well was retumed to injection, wellhead injection pressure was too tow to have the low pressure pilot (LPP) enabled. The well is currently injecting 647 bwpd at 330 psi wellhead injection pressure. The LPP for this wets has been defeated because of low wellhead injection pressure. The LPP and Surface Safety Valve {SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is retumed to normal, in accordance with "Administrative Approval No. CO 4068A01." Please let me know if you have any questions. Regards, Hai Hunt 2/1'7/2008 LPP/SSV Defeated on 1~102~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.comj Sent: Saturday, January 12, 2008 7:06 AM Ta: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 Prod Supt; CPF1 DS Lead Techs; Pierson, Chris R; Selisker, Gary R; NSK West Sak Prod Engr Subject: LPP/SSV Defeated on 1 E-102 Tom /Jim, Water injector 1 E-102 (PTD# 204-231,204-232} was shut in from 5-Dec-C?7 to 11-Jan-OS to collect surface pressure fall-off data (BFPO}. When the well was retumed to injection, wellhead injection pressure was too low to have the low pressure pilot (LPP} enabled. The weft is currently injecting 647 bwpd at 330 psi wellhead injection pressure. The LPP for this well has been defeated because of low wellhead injection pressure. The LPP and Surface Safety Valve (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to at~ve 500 psi and the LPP/SSV function is retumed to normal, in acxordance with "Administrative Approval No. CO 406.001." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Holtar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907} 659-7061 Fax: (907} 658-7749 Email: n1638@CanocoPhiltips.com ~' ~~ ~~' JAN ~ ~ 2i 1/14/2008 7rtb DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 ) J,.t- /hi:-).M Y API N'R. ~O-029-~236-00-00 ~ Permit to Drill 2042310 MD 14360 Well Name/No. KUPARUK RIV U WSAK 1E-102 Operator CONOCOPHILLlPS ALASKA INC TVD 3650 Completion Date 1/7/2005 Completion Status 1-01 L Current Status 1WINJ ~___~~_"_."'_U·__._____~ --_._----,~-,-- ------,._-,--~---,- -..--"'---"--',.-.---- ------,._-----~----~,---- REQUIRED INFORMATION Samples No -----'---.-"'-.---..--.--.., Mud Log No Directional Survey Yes ..--..-.---- _._'--'---,--~._--- ------- (data taken from Logs Portion of Master Well Data Maint e Interval OH/ Start Stop CH Received Comments 12603 14630 Open 2/3/2005 IIFR 12603 14630 Open 2/3/2005 MWD (non sag) 0 8048 Open 2/3/2005 IIFR PB 1 0 8048 Open 2/3/2005 MWD PB 1 (non sag) 6670 12901 Open 2/3/2005 IIFR PB 2 6670 12901 Open 2/3/2005 MWD PB 2 (non sag) 3350 6460 Case 1/19/2005 USIT/CEMENT EVALUATING LOG 3160 12839 Open 1/27/2005 GRlEWR4/ABI/ROP/PWDI GEO PILOT PB-2 3160 12839 Open 1/27/2005 GR/EWR4/ABIIROP/PWDI GEO PILOT-PB 2 3160 7986 Open 1/27/2005 GRlEWR4/ABI/ROP/PWDI . GEO PILOT PB-1 3160 7986 Open 1/27/2005 GRlEWR4/ABI/ROP/PWDI GEO PILOT PB-1 3160 14298 Open 1/27/2005 GRlEWR4/ABIIROP/PQDI GEO PILOT 3160 14298 Open 1/27/2005 GR/EWR4/ABI/ROP/PQD/ GEO PILOT 5400 13000 Case 7/14/2005 04 Jul 2005 108 14360 Open 2/22/2006 ROP DGR EWR plus Graphics / PB 1 108-8048 ROP DGR EWR plus Graphics 1 PB 2 108-12901 ROP DGR EWR plus Graphics ------.------"--'.---.----.'-.-- -"_._._,--,-----,,'--_._--,-,~_._- DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Log/ Data Digital Type Med/Frmt ~--- D Asc I~ D Asc UD D Asc ~ D Asc ~D D Asc JD D Asc ~ ¡y6 \ßÞt £ ~t D Lis D Lis ~ Lis \.3pt ¡~ fiD C Lis Electr Dataset Number Name Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Cement Evaluation 12964 I nd uction/Resistivity 12964 LIS Verification 12963 I nd uction/Resistivity 12963 LIS Verification 12962 I nd uction/Resistivity 12962 LIS Verification Injection Profile 13701 Induction/Resistivity Log Log Run Scale Media No 5 Col 5 Blu DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2042310 Well Name/No. KUPARUK RIV U WSAK 1E-102 API No. 50-029-23236-00-00 Operator CONOCOPHILLlPS ALASKA INC MD 14360 TVD 3650 Completion Date 1/7/2005 F----~_~=~~_..I~jectio~ro~~__~______-=- Well Cores/Samples Information: Completion Status Current Status 1WINJ UIC Y 1-01L .-.-. .~.~- 5 Blu 5700 9522 Open 7/25/2006 Injection Profile wI Well Tee Tractor 23-Jun-2006 -- ---_._._--_..._~---_._- -. -----~.- ....----....-- __ __.____n_......._._____._ Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? ye Chips Received? ~ Daily History Received? lDN CJN Formation Tops Analysis Received? ~. ._-_._----._._.._-~-- ------------_._--------_.-~- -~--,-~--"..._-~---,.~---_._..... Comments: -~- þ---:, Date:__>.~~.~ -5= Compliance Reviewed By: . . LPP Defeated On West Sak Injectors at DSlE . . Subject: LPP Defeated On West Sak Injectors at DS 1 E From: NSK West Sak Prod Engr <n1638@conocophillips.com> Date: Sun, 14 Jan 2007 13:26:44 -0900 To: "Tom Maunder:" <tom_maunder@admin.state.ak.us>, "Jim Regg:" <jim_regg@admin.state.ak.us> CC: CPF1 DS Lead Techs <nl140@conocophillips.com>, CPFl Prod Supt <nl132@çonocophillips.com> Tom / Jim, The Low Pressure Pilots for 1 E-102, 1 E-105, 1 E-112, and 1 E-114 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: r::;¡. ~) 1E-102 822 BWPD, 541 PSI~O~ -d-~ \ 1E-1051006 BWPD, 660 PSI dO S--OO ' 1E-1121937 BWPD, 597 PSI ~()4 - G'\ , 1E-114 945 BWPD, 562 PSI dO'-\. _ \ ~ \ This email is in accordance with Administrative Approval No. CO 406B.001. ~ Regards, Hai Hai Hunt / Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com SCANNW JUN 1 4 2007 ..' ....- lofl 6/12/2007 1 :33 PM . . WELL LOG TRANS MITT AL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th A venue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: lE-102_Ll_Ll PB1_PB1_PB2, lE-104, lE-121_Ll. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 UIC-- 904 -;)31/ U 'J:.C- Gó4-d3'J lE-102_Ll_Ll PB1_PBl PB2: IL/4Coó IL/L../fgr Digital Log Images: 1 CD Rom 50-029-23236-00, 60, 72, 70, 71 lE-104: U Ic..eol...{-88'f I:b L/L/5"7 Digital Log Images: 1 CD Rom 50-029-23234-00 lE-121_ Ll: ao"l-dt./fo il 14LIS-~ c90(.{ - d~1- oM I L{ 45"9 Digital Log Images: I 1 CD Rom 50-029-23238-00, 60 þ LPP Defeated On West Sak Injectors at DSlE ~- . Tom I Jim, The Low Pressure Pilots for 1 E-1 02, 1 E-1 05, 1 E-112, and 1 E-114 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: .~ 1E-102 822 BWPD, 541 PSI :)04 - JS \ 1E-105 1006 BWPD, 660 PSI 1 E-112 1937 BWPD, 597 PSI 1E-114 945 BWPD, 562 PSI This email is in accordance with Administrative Approval No. CO 406B.001. Regards, Hai Hai Hunt I Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Emaìl: n1638@ConocoPhillips.com 1 of 1 1/16/2007 11:07 AM West Sak Injector lE-102 : Notification of Defeated Low Pressure Pi... . . Tom 1 Jim, \ ~ dO 4~d-~ \ This email is to notify the AOGCC that the (West Sak Injector) 1E-102 Low Pressure Pilot (LPP) is defeated as of 10/28/06. This is in accordance with "Administrative Approval No. CO 4068.001." The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log." 1 E-1 02 was brought online at 10:57 on October 28, 2006. Current injection rate is -1700 bwpd; injection pressure at the wellhead is 4psig. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Regards, Hai Hunt Hai Hunt 1 Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 1 of 1 11/2/20063:33 PM 07/24/06 Scblulllbe.glP NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 dei/-dol Û~T~ Anchorage, AK 99501 Field: Kuparuk . Well Job# Log Description Date BL Color CD 1E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-1{)5L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 NIA PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 rW 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 ,/ 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-01 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213178 INJECTION PROFILE 01/17/06 1 2K-14 11213177 PRODUCTION PROFILE W/DEFT 01/16/06 1 1 C-20 11213175 FBHP SURVEY 07/14/06 1 1J-156 11216308 US IT 01/10/06 1 . 2K-06 11213173 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1 F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-11 11249923 PRODUCTION PROFILE/DEFT 01/04/06 1 1 H-04' 11320991 INJECTION PROFILE 07/03/06 1 1 D-1 0'1 N/A INJECTION PROFILE 06/27/06 1 2Z-13- 11249930 LDL 07/11/06 1 1D-106 NIA INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg \( / 11¡~ . P.I. Supervisor . ,i'fry b : It; 1+" DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lE-I02 KUPARUK RIV U WSAK lE-102 Ô"'1>\ ~Q~~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.1. S u pry -..Jl$ ¡2..... Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 1E-102 API Well Number 50-029-23236-00-00 Insp Num: mitCS060605141430 Permit Number: 204-231-0 Rei Insp Num Inspector Name: Chuck Scheve Inspection Date: 6/4/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- Well lE-I02 ¡Type Inj. w TVD 3615 IA 290 2290 2290 2290 i ~--- P.T. 2042310 ¡TypeTest SPT i Test psi 1500 OA 230 230 230 230 ! Interval 4YRTST PIF p Tubing I 625 625 625 -~ 625 Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integriy Wednesday, June 07, 2006 Page I of I . . WELL LOG TRANSMITTAL c?û4-- G'61 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1310) RE: MWD FOnTIation Evaluation Logs 1 E-1 02 + PB 1 + PB2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 lE-l02 + PBl + PB2: LAS Data & Digital Log hnages: 50-029-23236-00, 70, 71 1 CD Rom ~ ø\0 Scblumbepgep NO. 3429 Schlumberger -DCS 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 2G-02 ¡ 1S '{-j ). , 11047334 BHP SURVEY 06/30/05 1 , 2G-13 ¡g4-i).<{ 11047336 BHP SURVEY 07/01/05 1 J. 2G-11 If'..,-in 11047337 BHP SURVEY 07/01/05 1 Ii 1Y-14)3~~ on 11022907 LEAK DETECTION LOG 06/30/05 1 \/3H-19187 . (J) 11022907 PRODUCTION PROFILE 06/28/05 1 V. 1J-Ò3 ~c."í - C).. 'f 11022893 PRODUCTION PROFILE 06/17/05 1 ."} 1L-09 ¡'iO" v jI{ 11022895 PROD PROFILE W/DEFT 06/19/05 1 '/,3S-10Jo).-Bl 11001235 PROD PROFILE WIDEFT 06/14/05 1 J 3F-04 /J:i . .2..lS 11022891 INJECTION PROFILE 06/15/05 1 1Y-26A ¡$3'11~ 11022892 PROD PROFILE WIDEFT 06/16/05 1 .; 1E-112;2(i.f -MI 11047339 INJECTION PROFILE Ui<.. 07/03/05 1 j 1E-102 )..(;'1#J.J/ 11047340 INJECTION PROFILE VtC 07/04/05 1 SIGNED: v1LJ tJ~ c.......-- ~DATE: 1J4 I ¡f\ II . i C) \.ø Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color '"\ ¡ !J. '·à".~-· CD :¿~ J-" 07108/05 . . West Sak lE-102--PTD 204-231 . . All, While looking at some of the production/injection records, I ran across this well. Planned as an injector, it was preproduced as a number of these "new injectors" are. At the end of March, it was converted to injection with the status noted as "WAGIN". With very few exceptions (in the IC EOR Pilot), only water injection is presently authorized in the West Sak. Please pass this on to your associates responsible for submitting the 404s/407s for the West Sak wells. I have asked Steve McMains to change the well status to "IWINJ" with the same effective date. Thanks in advance for your assistance. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 8/23/2005 2:28 PM MJ£MORANDUM State of Alaska TO: Jim Regg P.I. Supervisor D· <-,é't[1 4{-¿1/0tf Alaska Oil and Gas Conservation comm.· . DATE: Wednesday, April 13, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-I 02 KUPARUK RIV U WSAK 1E-102 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ 1Ð2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK lE-102 Insp Num: mitCS050407l64451 ReI Insp Num: API Well Number: 50-029-23236-00-00 Permit Number: 204-231-0 Inspector Name: Chuck Scheve Inspection Date: 4/7/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I IE-I 02 IType Inj. I P i TVD Well i 3605 I IA 1000 1980 1960 1955 i P.T. I 2042310 ITypeTest I SPT ! Test psi 901.25 lOA 240 240 240 240 I ! Interval INITAL P/F P Tubing 50 50 50 50 Notes: Well demonstrated good mechanical integrity. Injection pressure very low. Wednesday, April 13, 2005 Page 1 of 1 REceIVED . STATE OF ALASKA a APR z ALASKA OIL AND GAS CONSERVATION COMMISŠ- 1 I 005 REPORT OF SUNDRY WELL OPERATIONS\Iaska Oil & Gas Cons, Commission 2. Operator Name: ConocoPhil/ips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 94' 8. Property Designation: ADL 25651 & 25648 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE INTERMEDIATE SLOTTED B-SAI\ Perforation depth: 5. Permit to Drill Number: 204-231 6. API Number: 50-029-23236-00 9. Well Name and Number: 1 E-1 02 10. FieldlPool(s): Kuparuk River Field I West Sak Oil Pool .. . measured 14360' feet true vertical 3650' feet measured 14332' feet true vertical 6276' feet Length Size MD 108' 20" 108' 3092' 10-3/4" 3186' 6404' 7-5/8" 6498' 8221' 4-1/2" 14332' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2412' 3709' 3651' Measured depth: 6507' - 14295' true vertical depth: 3710' - 3558' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5981' MD. Packers & SSSV (type & measured depth) no packer sssv= 511' N/A guD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact @659-7535 ,s:n ../ Title .......,J Y\. Phone RBDMS BFl APR 1 1 2~ ~~ I G I {\j A L E"gl""':::,~ Ter~s-- Form 10-404 Revised 04/2004 Submit Original Only . 1E-102 . DESCRIPTION OF WORK COMPLETEP SUMMARY Date Event Summary 3/30/200sICommenced WAG EOR Injection e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleekenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West Sak 1 KRU 1 1 E 04/07105 Rogers - AES Chuck Scheve well1E-1021 Type Inj I P.T.D. 2042310 Type Test Notes: Initial MIT S P Packer Depth Pretest Initial 15 Min. 30 Min. I TVD. I 3615 I Tubing I 501 501 501 501 Interval I I Test psi 1500 Casing 1000 1980 1960 1955 P/F P well I Type Inj I I TVD. I I Tubing I Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: weill I Type Inj I I T.V.D. I I Tubing I Ilnterval P.T.D. Type Test Test psi 1500 Casing P/F Notes: weill I Type Inj I I TVD. I I Tubing I Ilnterval P.T.D. Type Test T est psi 1500 Casing P/F Notes: weill I Type Inj I I TVD. I I Tubing I I Interval I P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0= other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1 E-102 04-07-05.xls 4/11/2005 IE-I02 (204-231) - e Subject: lE-102 (204-231) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 30 Mar 2005 16:02:21 -0900 To: Gary Targac <Gary.Targac@conocophillips.com> Gary, I have reviewed the information on the subject well and the primary cementing operation appears to have provided the necessary isolation to allow you to being water injection into the subject well. Please have Problem Wells coordinate the MIT on the well when thermal effects have stabilized. Please contact me with any questions. Tom Maunder, PE AOGCC 1 of 1 3/30/2005 4:03 PM e e è}04-è)S \ MECHANICAL I1ITEGRITY REPORT' '.. --G "'~~~I'-"'" :..~" r,,':'~':'r...':'~: OPER & FIELD t:~ ~ -r \(. R ~ WELL NUMBER 'Vt: - \(') ~. ::?UD DA!:::: ~t:.LL DATA TD: Jill. TVD¡ ?BTD: HI> TVD Cas ing: ,l.;( K Shoe: ì,LtC;') HD ~~()~ TVD i DV: ~~. HI> ~.~ "Tvu _:..:>e-r-: Shoe: HD TVD; :CP: HD :VD _;'.10 ~::g : 4l{~\( P acker 5~'-\~HD ::ole Size ~~( ¥ ana TVD¡ See at "ì> \o~ \ ~ "'-.tL,-~ <... ~ \ ;". to Pe-r-£s +O\' vJ\~\I..) Q. CôOOS- :-::EC?.Þ.lECl-..L INTEGRITY - PART /1 Annulus Press Test: :? 15 uan j 30 min Cor:ur:rrents: --- ;Œ:CRÞ_1\TICÞ.L INTEGRITY - PART f 2 e. ;);~ç. ..... '~,\~\,,> Cement Volumes:' Þ-..mt. Liner \.,j~ esg~c::.,,; DV ~~ Cüit 701 to cover perfs ,ç \ S'f: C;.... }~C'\EJ'-.\ ~ (c-,..~\" -\cf>~'\~ P \...:>~ SòC)- Q. ?IJ "'to '£ S . Iheore tical Toe ...\.","~A"t(·4.. \ \C) c. ~ ~~" '(~. 4'400 \<x..w~· ",OC ~<àÇ{) Dvx·~J.. S y \. \'0 lèT4-0~ Cement Bond Log (Yes or No) '-..:{'t? ; In AOGCC Fire .~~~ CBL Evaluation, zona abova parfs ~~""Ç'<" ':fà~~iê vJ\~ ~t<")'C~"'N:~\ \ b..*' ~ ~ · Proåuc.tion Log: Tn>e j Evaluation ., CONCLUSIONS: , ?art: ;1: ? ar:: : Z : \A~ h \:::V=-4~$~ 3/~"ðÇ Re: Variance for lE-102 (PTD 2042310) e . Subject: Re: Variance for lE-102 (PTD 2042310) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 29 Mar 2005 10:57:49 -0900 To: NSK Problem Well Supv <nI617@conocophillips.com> Brad, This is similar to the request for 2 other wells. Your request is appropriate. The well cannot flow and avoiding unnecessary pilot trips will prevent valve damage. Keep us advised. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, We are requesting a temporary variance from Conservation Order #4068, Rule 6, section b which requires SSVs for water injection well 1 E-1 02. A temporary variance to operate 1 E-1 02 water injection well with a defeated SSV pilot and without a 24 hr man watch for a maximum of 30 days is requested. This will be the initial injection for 1 E-1 02 and once an established tubing pressure of 300 psi has been reached the SSV pilot will be placed back in working service. Thanks, Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 1 of 1 3/29/2005 10:58 AM . ConocóP'hillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 February 2, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 R FE8 0 8 Alaska Subject: Well Completion Reports for 1 E-1 02, 1 E-1 02L 1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk wells 1 E-1 02 and 1 E-1 02L 1. Both these wells are injectors but we will pre-produce them for a short time. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~,~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad AL .; STATE OF ALASKA . ALA Oil AND GAS CONSERVATION COM ~~ION WELL COMPLETION OR RECOMPLETION REPORT ANPu~q~ 1 a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 Suspended U WAG 0 1 b. Well ClirsS:' 20MC 25.105 20MC 25.11 0 ~eJelo~~ent <(2J ~¡ofi] WlNJ 0 WDSPL 0 No. of Completions_ Other _XXX Pre-produced injector ',' 'SerVice' ,D,,~::~~tigraPhiCTesO 2. Operator Name: 12. Permit to btiA·NUmbé,,:'" GINJ 0 ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 491' FSL, 223' FEL, Sec. 16, T11N, R10E, UM At Top Productive Horizon: Total Depth: 411' FNL, 1499' FWL, Sec. 15, T11N, R10E, UM 2073' FSL, 2377' FEL, Sec. 3, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301 < y- TPI: x- 551984 y- Total Depth: x- 553319 / y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GRlRes 22. CASING SIZE wr. PER FT. 62.5# 45.5# I 40.5" 29.7# 12.6# 12.6# GRADE H-40 L-80 L-80 L-80 L-80 20" x 34" 10.75" 7-518 " 4.5" 4.5" 5960081 < 5964470 5972243 ' Zone- 4 Zone- 4 Zone-4 c: ';\i.;(.l ;~_";_, 5. Date Comp., Susp., ; or Aband.: January 7, 2005 204-231 I 6. Date spu~ ed: I ,..,..,.." .u.~~' , 13. API Number: ¿':"LòA.1> -....../ , ._ emberi5, 2004 . ," .I¿,f?) 50-029-23236-00 7. Date TD Reached: 14. Well Name and Number: December 23, 2004 8. KB Elevation (ft): 28' RKB 9. Plug Back Depth (MD + lVD): 14332' MD I 3651' TVD 10. Total Depth (MD + lVD): , 14360' MD I 3650' TVD / 11. Depth where SSSV set: nipple @ 511' 19. Water Depth, if Offshore: NIA CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD TOP BOTTOM TOP BOTTOM 28' 1 08' 28' 108' 28' 3186' 28' 2412' 28' 6499' 28' 3709' 6100' 14332' 3652' 3651' 5946' 6154' 3615' 3664' 23. Perforations open to Production (MD + lVD of Top and Bottom Interval, Size and Number; if none, state "none"): PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) pre-produced injector - shared production with 1 E-1 02L 1 Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 241 133 0 48 bean OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 1401 846 not available CORE DATA slots in liner from 6507'-14295' MD 26. Date First Production January 28, 2005 Date of Test Hours Tested 1/31/2005 Flow Tubing press. 369 psi 27. 4 hours Casing Pressure not t;lvailable Test Period --> Calculated 24-Hour Rate -> TUBING RECORD DEPTH SET (MD) 5981' constrictor pkrs @ 6659' & 6839' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 24. SIZE 4.5" 25. nla feet MSL HOLE SIZE 42" 13.5" 9-7/8" 6.75" Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS BFL fEI:l 1 '7 2005 Form 10-407 Revised 12/2003 NONE CONTINUED ON REVE~SE , L. / 1 E-1 02 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25651 & 25648 17. Land Use Permit: ALK 469 & 466 20. Th ickness of Permafrost: 1660' MD CEMENTING RECORD AMOUNT PULLED 375 sx AS I 548 sx AS Lite, 216 sx DeepCrete 319 sx DeepCrete slotted liner LEM assembly PACKER SET 5947',6112' IGAS-OIL RATIO 604 ,1"---,_ J fX)~piifiõ¡-'l : ,DJ.\Tf ; ! j¡7u")t:;"'¡ '~r ,_lEU "AI) ., ,. "..,.,.."'>._"",.,c1....,......... r J:::: ,.J't ..../ GEOLOGIC MARKERS . 29. . FORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-1 02 West Sak B West Sak Base 6458' 14360' 3705' 3650' NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name Ral}dv Thomas Signature ~ ~ l...ó-- Title: '----phone Kuparuk Drillina Team Leader 2.f::, S- ~-9 J. ò Date 2...('(05 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 02 1E-102 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 1/712005 Spud Date: 1216/2004 End: 11712005 Group: 12/5/2004 06:00 - 08:00 2.00 MOVE DMOB MOVE Blow Down steam, water and glycol lines and disconnect lines between complex's 08:00 - 09:00 1.00 MOVE MOVE MOVE Stage complex's down the pad, moved boilers, motors, pumps, pits and pipe sheds 09:00 - 12:30 3.50 MOVE OTHR MOVE Cleared out snow around well, leveled pad and set in matting boards, set on starting head, diverter and lines, tested slip on flange on starting head, unable to prep before rig move due to rig blocking 1E-102 12:30 - 17:00 4.50 MOVE POSN MOVE Moved sub base off 1 E-1 04 and spotted over well, set in rig complex's 17:00 - 19:00 2.00 MOVE RURD MOVE RU and connected service loops to rig complex's, air, water and steam, bermed around rig and rock washer, completed rig acceptance check list and ACCEPTED RIG at 16:00 Hrs 12/5/04, rig on highline at 17:00 hrs 19:00 - 22:00 3.00 WELCTL NUND SURFAC NU, starting head, 21 1/4" 2M diverter and 16" line, installed riser and began mixing spud mud in pits 22:00 - 00:00 2.00 DRILL OTHR SURFAC Load pipe shed with 75 jts of 5" DP, 29 jts of 5" HWDP, jars and strapped, installed mousehole preparing to PU and stand back DP 12/6/2004 00:00 - 00:15 0.25 DRILL SFTY SURFAC Held PJSMon PU and standing back 5" DP 00:15 - 05:00 4.75 DRILL PULD SURFAC PU and stood back 25 stds of 5" DP and 10 stds 5" HWDP and jars 05:00 - 06:00 1.00 DRILL OTHR SURFAC Leveled sub base 06:00 - 06:30 0.50 WELCTL BOPE SURFAC Function tested diverter and performed accumulator test, Note: Chuck Scheve with AOGCC waived witnessing of test 06:30 - 07:00 0.50 DRILL PULD SURFAC PU and stood back 1-std of 73/4" NM Flex Dc's 07:00 - 08:00 1.00 DRILL CIRC SURFAC Flooded conductor checking for leaks, had slight leak on starting head, sealed leak and checked ok 08:00 - 10:30 2.50 DRILL PULD SURFAC MU 13 1/2" BHA #1 with 1.8 deg bend motor, MU MWD and oriented RIH t0108' / 10:30 - 12:15 1.75 DRILL DRLG SURFAC Spud well and drill 13 1/2" hole from 1 08' to 163', ART 1.2 Hrs, hit hard spot below conductor 12:15 - 12:45 0.50 DRILL TRIP SURFAC POOH and stood back 1 std HWDP and RIH with NM Flex Dc's 12:45 - 13:15 0.50 DRILL SURV SURFAC Ran gyro survey at 163', No good 13:15 - 14:00 0.75 DRILL SURV SURFAC Break eire, Rerun gyro survey at 163' 14:00 - 15:00 1.00 DRILL DRLG SURFAC Drilled 13 1/2" hole from 163' to 252', ART .2 hrs, AST .8 hrs 15:00 - 15:30 0.50 DRILL SURV SURFAC Ran gyro survey at 252' 15:30 - 16:45 1.25 DRILL DRLG SURFAC Drilled from 252' to 344', ART.1 hr, AST 1hr 16:45 ~1-7:15- -- -O.-!;o-iJRttt - StJRV- - -stJRrA-e- --Ranwro-~'t4',No90m:l- ----- 17:15 - 17:30 0.25 DRILL SURV SURFAC Rerun gyro survey at 344' 17:30 - 20:30 3.00 DRILL DRLG SURFAC Drilled from 344' to 621', ART 2 hrs, AST .6 hrs 20:30 - 21 :00 0.50 DRILL SURV SURFAC Ran gyro at 621', No good. 21 :00 - 21 :45 0.75 DRILL SURV SURFAC Rerun gyro survey at 621', Had 1 mis-run, Got survey on 2nd attempt. 21 :45 - 00:00 2.25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 621' to 804' MD/794' TVD, ART .7 hrs, AST .4 hrs, 5-15Kwob, 30 rpm's, 107 spm, 453 gpm, off btm pressure 900 psi, on btm pressure 1,000 psi, off btm torque 1 K ft-Ibs, on btm 3K ft-Ibs, st up wt 71 K, dn wt 84K 12m2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 804' to 1704' MDI 1554' TVD, ART 3.1 hrs, AST 6.1 hrs, 10-40K wob, 40 rpm's, 107-130 spm, 453-550 9pm, off btm pressure 1100 psi, on btm pressure 1,700 psi, off btm torque 2-5K ft-Ibs, on btm 2-6K ft-Ibs, st up wt 86-96K, dn wt 84-86K, rot wt 86-93K 12:00 - 23:15 11.25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 1704' to 3196' MD/2416' TVD, ART 5.72 hrs, AST 1.89 hrs, 5-25K wob, 40-60 rpm's, 130-166 spm, 550-702 gpm, off btm pressure 1800-2500 psi, on btm pressure 1,780-2650 psi, off btm torque 2-8K ft-Ibs, on btm 5-8K ft-Ibs, st up wt 98-125K, dn wt 85-90K, rot wt 94-1 02K Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 02 1 E-1 02 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 12/6/2004 End: 11712005 Group: 12/6/2004 11712005 Shut down pumps survey @ TD. Circ and condition mud and hole fl 10 3/4" csg. Had max 1050 units of gas 10 minutes into circ. Circ out all gas cut mud. Lowest wt was 7.8ppg. MW 9.2ppg, vis 180, fI temp 55 deg. Monitor well wI pumps off fl 10 min. OK. Proceed to circ bottoms up. Note: Max of 87 units when circ bottoms up. Circ bottoms up @ 700 gpm, rot @ 60rpm. Max gas 87 units. MW @ 9.2 ppg.vis 180 Backream out of hole wI 60 rpm, 700 gpm 2500 psi. Shakers loaded up while @1740', slow down pulling rate. UD 13 1/2" ghost reamer and (12) 5" HWDP. POOH (6) stands(includes jars)-- 5" HWDP UD Sperry BHA, download MWD. Clean rig floor. Rig up to run 103/4" casing. PJSM on running 103/4" surface casing. Run 1 0 3/4" casing. Weatherford Model 303 float shoe, 2 joints 45.5ppf L-80, BTC,Weatherford model 402 FC, (1) joint 45.5ppf L-80 BTC casing, first three joints baker locked, pump thru and check float equipment,then (1) joint 40.5ppf L-80 BTC casing. 4.50 CASE RUNC SURFAC PJSM, Continue running 103/4" 40.5ppf L-80 BTC casing to 790', break circ wI Franks fillup tool, run 40.5ppf L-80 BTC csg to 2011', break circ, run 40.5ppf L-80 BTC csg to 2985', run last 4 jts of csg (45.5ppf L-80 BTe) to 3153', break circ @ 2.5 bpm, 250 psi. 0.25 CASE RUNC SURFAC PUlMU Vetco/Gray hanger and landing joint. Run in hole to land @ 3186'. Ran total of 79 joints. The first 3 joints in hole and last 4 joints in hole were 45.5 ppf L-80 BTC, the rest were 40.5 ppf L-80 BTC. Ran total of 15 centalizers and 1 stop ring. PU wt 145-150k, SO wt 80k. 1.25 CEMENT CIRC SURFAC CBU wI Frank's fillup tool, stage rate up fl 3bpm wI 250psi to 4 bpm wI 300psi, then 5bpm @ 350 psi. Circ one bottoms up, 252 bbls. PU wt 165k, SO wt 96K 0.50 CEMENT PULD SURFAC UD Franks fillup tool. Blow down top drive. MU Dowell cement head. 1.00 CEMENTCIRC SURFAC Continue to circ and condition mud fl cement job. Circ @ 5bpm wI 350 psi. Stage up to 6bpm w/390 psi. PU wt 165k, SO wt 96K, Block 35K. 0.75 CEMENTCIRC SURFAC PJSM on cement job wI Dowell, rig crew and vac truck drivers w/ cõh1inTIetÓ eirC-andtòhdìffonmÜd.Cìfc@ô WrilWT:3IDþsT.-Tofalòf 2 1/2 bottoms up (579 bbls) (3 hours) mud circulated prior to cement job. Mud prior to conditioning was 9.2 ppg, 164 vis, 25 PV and 42 YP. After conditioning mud 9.0 ppg, 45 vis, 12PV, and 13 YP. 2.00 CEMENT PUMP SURFAC Dowell pump 10 bbls CW100(8.3 ppg) @ 4bpm 160 psi, test lines to 3500 psi. follow wI 40 bbls CW 100(8.3 ppg) @ 5.5 bpm 300 psi, follow wI 42 bbls MudPush wI red dye(10.3 ppg) @ 4 bpm 160 psi, Drop bottom plug. Dowell pump 435 bbls AS Lite(10.7 ppg) @ 6-7 bpm 420 psi- 550 psi, follow wI 95 bbls DeepCrete tail cement(12 ppg) @ 4-5 bpm 330-550 psi, Drop top plug. Note:Reciprocated casing until 84 bbls lead cement around shoe, then landed on hanger wI 75K SO wt. Blocks were 35K of this wt. 0.75 CEMENTDISP SURFAC Dowell displace wI 20 bbls fresh water @ 6 bpm then turn over to rig.Rig displace cement wI 9 ppg mud @ 7 bpm(initial presss 400 psi,final press 600 psi) till 1 0 bbls prior to bump plug, then slow to 3 bpm 350 psi. Bump plug @ calculated displacement, increased pressure to 1000 psi. CIP @ 2300 hrs 12/8/2004. Had full returns on cement job. Dye in spacer to surface after rig displaced 36 bbls, had 125.2 bbls good 10.7 ppg cement returns to surface 12/7/2004 12:00 - 23:15 11.25 DRILL DRLG SURFAC 23:15 - 23:45 0.50 DRILL CIRC SURFAC 23:45 - 00:00 0.25 DRILL OBSV SURFAC 12/8/2004 00:00 - 00:30 0.50 DRILL CIRC SURFAC 00:30 - 04:30 4.00 DRILL REAM SURFAC 04:30 - 05:45 1.25 DRILL PULD SURFAC 05:45 - 06:30 0.75 DRILL TRIP SURFAC 06:30 - 09:15 2.75 DRILL PULD SURFAC 09:15 -10:30 1.25 CASE RURD SURFAC 10:30 - 11 :00 0.50 CASE SFTY SURFAC 11 :00 -12:00 1.00 CASE RUNC SURFAC 12:00 - 16:30 16:30 -16:45 16:45 - 18:00 18:00 - 18:30 18:30 -19:30 19:30 - 20:15 20:15 - 22:15 22:15 - 23:00 Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1E-102 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 1/7/2005 Spud Date: 12/6/2004 End: 11712005 Group: 1218/2004 23:00 - 23:15 0.25 CEMENTOTHR SURFAC Check floats. OK. 23:15 - 00:00 0.75 CASE DEQT SURFAC RU to test casing. Pressure test 10 3/4" casing to 3000 psi wI 9.0 ppg mud. Hold test fl 30 min. , chart test. 12/9/2004 00:00 - 00:30 0.50 CASE DEQT SURFAC Continue pressure test 10 3/4" casing to 3000 psi wI 9.0 ppg mud. Hold test fl 30 min. , chart test. 00:30 - 01 :00 0.50 CASE RURD SURFAC Check float equipment. OK. UD Dowell cement head.Break Dowell crossover fl landing joint. Needed to use rig tongs to break. 01 :00 - 01 :30 0.50 CASE RURD SURFAC Break Dowell crossover fl landing joint. Needed to use rig tongs to break. UD same. 01:30 - 03:15 1.75 CASE RURD SURFAC UD 10 3/4" landing joint. RID casing equipment. Change out casing bales to drilling bales fl top drive. 03:15 - 03:30 0.25 WELCTL SFTY SURFAC PJSM wI rig crew and crane operator on N/D diverter and NU Vetco/Gray wellhead. 03:30 - 07:30 4.00 WELCTL NUND SURFAC N/D Diverter system. Using crane to remove pieces from behind rig, and installing wellhead equipment in cellar. 07:30 - 08:45 1.25 WELCTL NUND SURFAC NU VetclGray tubing spool, orient and test to 5000 psi fl 10 min. Rig Floor to Upper LDS 22.65'(Tubing Hanger) Rig floor to Lower LDS 26.49'(7 5/8" packoff) Rig floor to tubing hanger load shoulder 25.32' Rig floor to 7 5/8" hanger load shoulder 27.23' 08:45 - 11 :00 2.25 WELCTL NUND SURFAC NU 13 5/8" BOP stack, connect choke and kill lines, install double valves on annulus. 11 :00 - 13:45 2.75 DRILL OTHR SURFAC Break off and change out saver sub on top drive from 4 1/2" IF to 4" XT 39. Change stabbing guide and grabber heads. 13:45 - 17:45 4.00 WELCTL BOPE SURFAC RU and test BOPE. Test all rams and valves and annular to 250 psi low, then 3500 psi high. Accumulator test. Witness of test waived by AOGCC inspector John Crisp. 17:45 - 18:30 0.75 WELCTL BOPE SURFAC Rig down test equipment. Blow down choke manifold. 18:30 -19:00 0.50 DRILL OTHR SURFAC Set wear bushing. 19:00-21:30 2.50 DRILL PULD SURFAC RU, rabbit Weatherford 4" S-135 XT39 dp wI 2" rabbit, MU mule shoe, PU & RIH 60 joints 4" XT39 dp. Torque 20,000 fIIlb. 21 :30 - 22:00 0.50 DRILL CIRC SURFAC Circ to clear any debris fl dp. Circ a dp volume @ 9bpm wI 700 psi. 22:00 - 23:00 1.00 DRILL TRIP SURFAC POOH wI Weatherford 4" XT 39 dp, stand back in derrick. 23:00 - 00:00 1.00 DRILL PULD SURFAC RU, rabbit Weatherford 4" S-135 XT39 dp wI 2" rabbit, MU mule shoe, PU & RIH 17 joints 4" XT39 dp. Torque 20,000 fIIlb. ... 1271 072004 -00:00 -02:00-- 2.00 DRILL - -PUW- -SURFAC PJSM,RU, rabtiiIWeatfiefforâ4"-S::135XT39âp WI2"-rabtiit, MUIl1Ule shoe, PU & RIH 43 joints 4" XT39 dp. Torque 20,000 fIIlb. 02:00 - 03:00 1.00 DRILL TRIP SURFAC POOH wI Weatherford 4" XT 39 dp, stand back in derrick. Total of 40 stands in derrick. 03:00 - 04:30 1.50 DRILL PULD SURFAC PJSM. PUlMU BHA # 2 fl 9 7/8" hole. 04:30 - 05:30 1.00 DRILL OTHR SURFAC Sperry Sun plug into and upload MWD 05:30 - 06:00 0.50 DRILL PULD SURFAC PUlMU 3 non mag flex drill collars, one stand 5" HWDP. 06:00 - 07:00 1.00 DRILL OTHR SURFAC Change elevators to 4", PU x-a fl 41/2" IF to XT39 and 10' pup joint, Screw into and test MWD. OK. Blow down top drive, break 10' pup and x-o, change elevators back to 5". 07:00 - 08:30 1.50 DRILL TRIP SURFAC RIH wI rest of 5" HWDP(5 more stands), follow wI 25 stands 5" dp. RIH to 3052. Break circ. PU wt 11 Ok, SO wt 71 k. 08:30 - 11 :30 3.00 CEMENT DSHO SURFAC Change elevators to 4", PU 1 stand 4" DP, break circ. PU wt 110k, SO wt 71k. Drill FC @ 3100', cement, FS @ 3186', clean out to 3186' and 20' new hole to 3216'. Note: Casing was tested to 3000 psi after bumping plugs on cement job,12/9/04 11:30 -12:00 0.50 DRILL CIRC SURFAC Pump 25 bbl Hi-Vis sweep surf to surf prior to performing LOT @ 3216'. 12:00 - 13:30 1.50 DRILL LOT SURFAC RU & perform LOT 13.6ppg wI 9.2 ppg 551psi @ 3216' MDI 2423'TVD Printed: 1/12/2005 3:52:55 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1E-102 ROT - DRilLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 1/7/2005 Spud Date: 1216/2004 End: 1/712005 Group: 12/10/2004 13:30 - 23:00 9.50 DRILL DRLG INTRM1 Drilled 9 7/S" hole per directional plan from 3216' to 4,356' MD/2,953' TVD, (1140') ART 6.12 hrs, 4-10K wob, 75-S0 rpm's, 100-150 spm, 420-634 gpm, off btm pressure 1050-1900 psi, on btm 1100-2000 psi, off btm torque 3-5K ft-Ibs, on btm 4-6K ft-Ibs, rot wt 90-97K, up wt 97-105K, dn wt S3-S5K, 9.0 ppg MW, 65 vis Note: Intervals of hard drilling: 3312' to 3342'(30') took 45 minutes & 344S' to 34S2'(34') took 1S minutes 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Pull 1 stand off bottom, stand back. Pump weighted hi vis sweep(11 ppg, 150 vis), circ sweep out of hole. Saw 10% increase in cuttings when sweep back to surf. Max ECD 10ppg throughout drilled interval while backreaming prior to connections. While drilling ECD were 9.5 to 9.7 ppg 12/11/2004 00:00 - 02:15 2.25 DRILL REAM INTRM1 PJSM. Backream out of hole f/4173' to 3239'. Trip due to failure of Sperry Sun GeoPilot. 02:15 - 04:15 2.00 DRILL TRIP INTRM1 Pull 2 stands on elevator. Check fl swabbing, OK. Pump dry job, POOH fl 3052' to 25' 04: 15 - 05:00 0.75 DRILL OTHR INTRM1 Clean and service Sperry Sun GeoPilot. Break bit, download MWD. 05:00 - 06:00 1.00 DRILL PULD INTRM1 UD Sperry Sun tools and Security/DBS 9 7/S" PDC bit. 06:00 - 06:45 0.75 DRILL PULD INTRM1 MU BHA # 3. Sperry Sun GeoPilot, Security/DBS 9 7/S" PDC bit, flex collars and MWD. 06:45 - 07: 15 0.50 DRILL OTHR INTRM1 Sperry Sun plug into and upload MWD. 07:15 - 07:45 0.50 DRILL TRIP INTRM1 RIH to 717'. 07:45 - OS:15 0.50 DRILL OTHR INTRM1 Shallow test MWD tools @ 717'. Blow down top drive. 08:15 - 09:45 1.50 DRILL TRIP INTRM1 RIH to 3050' Fill pipe, RIH to 4263'. MU top drive. Fill pipe. 09:45 - 10:00 0.25 DRILL REAM INTRM1 Washlream fl 4263' to 4356'. 10:00 - 12:00 2.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 4356' to 4,550' MD (194') MDI 3050' TVD, ART 1 hrs, 5-10K wob, 120 rpm's, 121 spm, 512 gpm, off btm pressure 1300 psi, on btm 1475 psi, off btm torque 5K ft-Ibs, on btm 5K ft-Ibs. rot wt 96K, up wt 107K, dn wt 84K, 9.1 ppg MW. 65 vis 12:00 - 12:30 0.50 DRILL CIRC INTRM1 Circulate bottoms up. 12:30 - 13:30 1.00 DRILL REAM INTRM1 PJSM. Backream out of hole fl 4455' to 4176'. Trip due to failure of Sperry Sun GeoPilot. POOH 5 stands to 3700' 13:30 - 13:45 0.25 DRILL CIRC INTRM1 Monitor well, OK. Pump dry job. Blow down top drive. 13:45 -15:00 1.25 DRILL TRIP INTRM1 POOH fl 3700' to 78'. 15:DD~-16:00 1.OouDRTlL - OTHR-INTRM1 .. DòWhlöádSperry SÜnMWD. UDBHAl#~. 16:00 - 17:30 1.50 DRILL PULD INTRM1 PUlMU BHA #4. SperryDrill 7" Motor(1.5 deg bend) and 9 7/S" Hughes MX-CX1( 1-12, 3-20's) (TFA 1.031). 17:30 - 1S:00 0.50 DRILL OTHR INTRM1 Sperry Sun up load MWD. 1S:00 - 18:30 0.50 DRILL TRIP INTRM1 RIH to 735'. 18:30 - 1S:45 0.25 DRILL OTHR INTRM1 Shallow test MWD tools. Blow down top drive. 18:45 -19:45 1.00 DRILL TRIP INTRM1 RIH to 3058'. 19:45 - 20:00 0.25 DRILL CIRC INTRM1 Fill pipe. Blow down top drive. 20:00 - 20:30 0.50 DRILL TRIP INTRM1 RIH to 4455. 20:30 - 21 :00 0.50 DRILL REAM INTRM1 Fill pipe, wash fl 4455' to 4550'. 21 :00 - 00:00 3.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 4550' to 4880' MD (330') MDI 3213' TVD, ART.7 hrs, AST 1.3 hrs, 5-15K wob, 100 rpm's, 130-140 spm, 549-592 gpm. off btm pressure 2100 psi, on btm 2300 psi, off btm torque 6-7K ft-Ibs, on btm 5K ft-Ibs, rot wt 96K, up wt 111 K, dn wt 86K, 9.1 ppg MW, 70 vis 12/12/2004 00:00 - 20:00 20.00 DRILL DRLG INTRM1 Drilled 9 7/S" hole per directional plan from 4880' to 6511' MD (1631') MDI 3711.4' TVD, ART 8.52 hrs, AST 4.73 hrs, 5-20K wob, 100 rpm's, 140 spm, 592 gpm. offbtm pressure 2100-2450 psi, on btm 2300-2600 psi, off btm torque 6-10K ft-Ibs. on btm 6-10K ft-Ibs, rot wt 96-98K, up Printed: 1/1212005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1E-102 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 12/6/2004 End: 11712005 Group: 12/6/2004 11712005 12112/2004 12/13/2004 wt 111-124K, dn wt 86-82K, 9.1 ppg MW, 70 vis Circ hi vis weighted sweep to surface. 11 ppg wI 150vis. No increase in cuttings Backream out of hole wI ghost reamer fl bit depth of 6418' to 4086'. Backream wI 100 rpm and 592 gpm, pulling @ 45ft/min. Backream out of hole wI ghost reamer fl 4086' to 3932'(Ghost reamer to 3197'). Backream wI 100 rpm and 592 gpm, pulling @ 45ft/min. Pull 2 stands, check hole fl swabbing, OK. Pull out of hole to 3152'. Circ 30 bbl hi vis weighted sweep to surface. 11 ppg wI 150vis. Circ @ 592 gpm wI 1700 psi, recip and rotate. 15% increase in cuttings returns. Pump 40 bbls EM 1- 920 pill, spot in hole fl 1500' to 1000'. Wt 9.1 ppg. vis 80. Stand back last stand of 4" dp. Blow down top drive. Monitor well, PJSM, RU to POOH UD dp. POOH, UD 5" dp (25 stands=75 jts), 5" HWDP(17), UD jars. UD BHA # 4 (9 7/8"). Download MWD. Pull Vetco/Gay wear bushing. Clean rig floor. PJSM. Ru to run 7 5/8", 29.7 ppf, L-80, BTC-M casing. PJSM on running 7 5/8", 29.7 ppf, L-80, BTC-M casing. Run 7 5/8" casing. Weatherford Model 303 float shoe, 2 joints 29.7ppf, L-80, BTC-M,Weatherford model 402 FC, (5) joints 29.7 ppf L-80 BTC-M casing, first three joints baker locked, pump thru and check float equipment. Ran total of 7 jts to 326' 9.25 CASE RUNC INTRM1 PJSM. Continue running 7 5/8", 29.7ppf, L-80, BTC-M (3) joints, then (1) 20' pump jt,continue running. Note joint # 11 has no centralizer, plannned to be window joint. Centralizers placed 10' fl shoe jt, 10' from box and 10' from pin on jt # 2, then every 30' till jt # 60 in hole. Total of 60 tandem centralizers over stops and 19 bowspring on collars. Run to jt 148', then 10' pup, one more joint (total of 149 joints + 10' and 20' pup jt), then Vetco gray hanger and landing joint. Land casing WI shoe @ 6498'. Broke circ @ 1740', circ @ 3120' (shoe of 103/4" @ 3186'), break circ @ 4120', 4980' circ@ 2bpm wI 350 psi (80 bbls), 5410', 5930'. 0.25 CASE CIRC INTRM1 Circ wI Frank's tool @ 2 bpm 400 psi fl 10 min, recip pipe. PU wt 165K, SO wt 87K. 0.50 CEMENT CIRC INTRM1 Change out Frank's circ tool. Install Dowell's cement head. 2.00 CEMENTCIRC INTRM1 Continue circ casing wI recip pipe. Circ @ 3 bpm stage up to 4 bpm, then 5 bpm after one bottoms up, and then 6 bpm. Go to 6 bpm after 402 bbls pumped wI 475 psi. 9.3-9.4 ppg, reducing wt to 9.1 ppg wI centrifuge and water. Total of 524 bbls pumped so far. ( 5200 strokes) 0.75 CEMENTCIRC INTRM1 Continue circ casing wI recip pipe. Circ @ 6 bpmwl 475 psi. 9.3-9.4 ppg, reducing wt to 9.1 ppg wI centrifuge and water. Total of 795 bbls pumped so far.(7900 strokes) PU wt 177K , SO wt 91 K. 00:00 - 20:00 20.00 DRILL DRLG INTRM1 20:00 - 21 :00 1.00 DRILL CIRC INTRM1 21 :00 - 00:00 3.00 DRILL REAM INTRM1 00:00 - 00:30 0.50 DRILL REAM INTRM1 00:30 - 01:15 0.75 DRILL TRIP INTRM1 01 :15 - 02:00 0.75 DRILL CIRC INTRM1 02:00 - 02:30 0.50 DRILL CIRC INTRM1 02:30 - 02:45 0.25 DRILL TRIP INTRM1 02:45 - 03: 15 0.50 DRILL PULD INTRM1 03:15 - 06:15 3.00 DRILL PULD INTRM1 06:15 - 08:30 2.25 DRILL PULD INTRM1 08:30 - 09:00 0.50 WELCTL OTHR INTRM1 09:00 - 10:30 1.50 CASE RURD INTRM1 10:30 - 11 :00 0.50 CASE SFTY INTRM1 11:00 -12:00 1.00 CASE RUNC INTRM1 12:00 - 21:15 21:15 - 21:30 21 :30 - 22:00 22:00 - 00:00 12/14/2004 00:00 - 00:45 0.25 CEMENT SFTY INTRM1 PJSM on cement job while continue to circ casing & recip pipe. Circ @ 6 bpmwl 475 psi. 9.3-9.4 ppg, reducing wt to 9.1 ppg wI centrifuge and water. 0.50 CEMENTCIRC INTRM1 Continue circ casing wI recip pipe. Circ @ 6 bpmwl 475 psi. 9.3-9.4 ppg, reducing wt to 9.1 ppg wI centrifuge and water. Total of 1039 bbls pumped.(10320 strokes) PU wt 177K, SO wt 91 K. 1.25 CEMENT PUMP INTRM1 Dowell pump 10 bbls CW100, test lines to 3500 psi, pump 30 bbls CW 00:45 - 01 :00 01 :00 - 01 :30 01 :30 - 02:45 Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-102 1E-102 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 12/6/2004 End: 1/712005 Group: 12/6/2004 11712005 1.25 CEMENT PUMP INTRM1 100@ 4.4 bpm wI 225 psi for total of 40 bbls(8.3 ppg), pump 22.5 mud push(10.5 ppg) @ 4.8 bpm w/270 psi, shutdown, drop bottom plug, mix and pump 128.5 bbls DeepCrete cement(12.5ppg) @ 4-5.5 bpm wI 320-85 psi, drop top plug, washup lines w/4 bbls water to pits. 0.75 CEMENTDISP INTRM1 Rig displace wI 9.1 ppg, 150 vis, Oil base mud @ 7 bpm (initial250 psi, final 820 psi) pump 279 bbls , then slow pumps to 3 bpm wI 500-600 psi, bump plug w/11 00 psi @ calculated displacement 294.4 bbls. (2937 strokes). Recip casing until last 51.75 bbls pumped ( 72.65 bbls cement around shoe). Landed wI PU wt 185K, SO wt 70K, Blocks 35K of this. CIP 0330 hrs 12/14/2004. Full returns. Hold pressure 5 min. Bleed off, check floats, OK. RU, Pressure test 7 5/8" casing to 3000 psi fl 30 min. Chart test. OK. Bleed back 3.4 bbls. RID Dowell cement head, casing equipment, UD landing joint, change out bales, clean rig floor. RU/PU 1 jt 4" HWDP. Set Vetco Gray 7 5/8" packoff, test to 5000 psi fl 15 min. Install Vetco gray wear bushing. Perform injectivity test on 10 3/4" x 7 5/8" annulus. 9.1 ppg fluid between 7 5/8" x 10 3/4", shoe @ 3186'MD (2412'TVD) Note: After test, while working on PU DP.Flush wI 150 bbls water. Broke down @ 930 psi wI 9.1 ppg @ 1.25 bpm , then pump @ 2.5 bpm pumping 900 psi. Final shut in 730 psi. Little Red Freeze protected wI 85 bbls diesel @ 2bpm wI 1200 psi. Rabbit wI 1.91 ", PU/RIH wI 4" HWDP( Weatherford S-135 XT 39). 3 stands HWDP + 5 stands of hybrid (1 hwdp + 2 4 3/4" DC) in hole @ noon. Continue rabbit wI 1.91", PU/RIH wI 4" hybrid ( 1hwdp + 2 4 3/4" DC's). 10 more stands of hybrid. Drill collar torque 20000 ftllb POOH wI 15 stands of hybrid (1 hwdp + 2 43/4" DC), then 3 stands of 4" HWDP (Weatherford). Stand back in derrick. Torq on HWDP 22,000 ftllb. Rabbit Weatherford 4" S-135 XT39 dp wI 2" rabbit, PU & RIH 150 joints 4"$-135 XT39 dp~ Torqae20;000 ftllb. PU 60 LoTads to rig floor. Length 3.27', FN 1.28' (4 7/8" OD) (ID 2 9/16") POOH wI dp. Install LoTads above singles, LoTads drifted to 2.00". 45 stands out @ midnight. 5 stands left to pull and install. POOH wI dp. Install LoTads above singles, LoTads drifted to 2.00". Pull 5 stands and install LoTads. Clear rig floor, prep to PU 6 3/4" BHA, PU Sperry tools to rig floor. PJSM. Change elevators to 3 1/2". PU/MU 6 314" BHA (BHA # 5) Adjust motor to 1.5 deg, orient, MU Hycolog DSX 146 PDC RR bit, MU MWD, PWD. Upload MWD tools. Finish PU/MU BHA. 3 NM flex DC, change elevators to 4", MU x-a, 3 HWDP, jar, 2 HWDP to 365'. Test MWD tools. Rabbit dp to 2". PU 129 joints 4" dp f/ pipe shed. Torque to 20,000 ftllb. RIH to 4382'. Continue trip in hole wI Weatherford 4", S-135, XT 39 dp from derrick. Run 21 stands to 6344'. 12/14/2004 01 :30 - 02:45 02:45 - 03:30 03:30 - 03:45 0.25 CEMENTOTHR INTRM1 03:45 - 04:45 1.00 CASE DEQT INTRM1 04:45 - 07:30 2.75 CASE RURD INTRM1 07:30 - 08:30 1.00 WELCTL OTHR INTRM1 08:30 - 09:00 0.50 WELCTL OTHR INTRM1 09:00 - 09:30 0.50 DRILL LOT INTRM1 09:30 - 12:00 2.50 DRILL PULD INTRM1 12:00 - 13:30 1.50 DRILL PULD INTRM1 13:30 - 14:30 1.00 DRILL TRIP INTRM1 14:30 - 18:30 4.00 DRILL PULD INTRM1 18:30 - 19:30 1.00 DRILL PULD INTRM1 19:30 - 00:00 4.50 DRILL TRIP INTRM1 12/15/2004 00:00 - 00:30 0.50 DRILL TRIP INTRM1 00:30 - 01 :00 0.50 DRILL OTHR INTRM1 01 :00 - 03:30 2.50 DRILL PULD INTRM1 03:30 - 04:00 0.50 DRILL OTHR INTRM1 04:00 - 05:15 1.25 DRILL PULD INTRM1 05:15 - 05:30 0.25 DRILL OTHR INTRM1 05:30 - 09:30 4.00 DRILL PULD INTRM1 09:30 - 10:30 1.00 DRILL TRIP INTRM1 Printed: 1/1212005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 02 1 E-1 02 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 12/6/2004 End: 1/712005 Group: 1216/2004 11712005 12115/2004 10:30 - 12:00 1.50 RIGMNT RSRV INTRM1 12:00 - 14:00 2.00 CEMENT DSHO INTRM1 14:00 - 15:00 1.00 DRILL CIRC INTRM1 15:00 - 16:00 1.00 DRILL LOT INTRM1 16:00 - 00:00 8.00 DRILL DRLG PROD 12/16/2004 00:00 - 04:00 4.00 DRILL DRLG PROD 04:00 - 08:30 4.50 DRILL DRLG PROD 08:30 - 10:00 1.50 DRILL CIRC PROD 10:00 - 12:00 2.00 DRILL DRLG PROD 12:00 - 15:30 3.50 DRILL DRLG PROD 15:30 - 16:00 16:00 - 18:00 0.50 DRILL WIPR PROD 2.00 DRILL DRLG PROD 18:00 - 19:30 1.50 DRILL OTHR PROD 19:30 - 22:00 2.50 DRILL OTHR PROD 22:00 - 00:00 2.00 DRILL OTHR PROD 12/17/2004 00:00 - 02:15 2.25 DRILL OTHR PROD 02:15 - 05:00 2.75 DRILL DRLG PROD PJSM,Slip & cut 75' (1 114") drilling line. MU top drive, tag float collar @ 6409', drill float collar, cement, FS, clean out to 6511', drill 20' new hole to 6531'. Circ hole clean fl LOT. Perform LOT. 14 ppg EWM wI?? ppg mud wt . Drilled 6 3/4" hole per directional plan from 6531' to 6677' (146')MD 13715' TVD, ART 3.5 hrs, AST 2.4 hrs, 2-15K wob, 80-100 rpm's, 74 spm, 313 gpm, offbtm pressure 3050-3100 psi, on btm 3200 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 105K, dn wt 73K, 9.1 ppg MW, 88 vis Drilled 6 3/4" hole per directional planl geologist from 6677' to 6990' (313')MD 13713.76' TVD, (89.5 deg) ART 2.31 hrs, AST .27 hrs, 2-10 K wob, 90-95 rpm's, 74 spm, 313 gpm, off btm pressure 3050-3100 psi, on btm 3100-3215 psi, off btm torque 6K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 106-111 K, dn wt 73-65 K, 9.0 ppg MW, 93 vis Drilled 6 3/4" hole per directional planl geologist from 6990' to 7414' (424')MD 13723' TVD, (90.55 deg) ART 1.75 hrs, AST .72 hrs, 2-5K wob, 95-100 rpm's, 74 spm, 313 gpm, off btm pressure 3100-3250 psi, on btm 3200-3500 psi, off btm torque 6K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 111-137K, dn wt 65-50K, 9.0 ppg MW, 93 vis Note: Later evaluation determined that we came out of top of West Sak"ß" sand @ 6990' MOl 3713.76' TVD wI drilling @ 89.5 deg. Stop drilling. PU of bottom, reciprocate and work pipe. Uncertainty of geological formations. Confirm wI drilling team in town. Drilled 6 3/4" hole per directional planl geologist from 7414' to 7582' (168')MD 13718.11' TVD, (92.3 deg) ART .72 hrs, AST .26 hrs, 2-4K wob, 100 rpm's, 75 spm, 317 gpm, off btm pressure 3250 psi, on btm 3325-3475 psi, off btm torque 6K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 137K, dn wt 45-50K, 9.0 ppg MW, 93 vis Drilled 6 3/4" hole per directional planl geologist from 7582' to 7855' (273')MD 13704.25' TVD, (93.15 deg) ART 1.23 hrs, AST .64 hrs, 2-4K wob, 100 rpm's, 75 spm, 317 gpm, off btm pressure 3250 psi, on btm 3325-3475 psi, off btm torque 6K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 137K, dn wt 45-50K, 9.0 ppg MW, 93 vis Short trip: Pump out ofh01eft7855,utu 7462'. RIH ft7462' to 7855'. Drilled 6 3/4" hole per directional planl geologist from 7855' to 8048' (168')MD 13683' TVD, (97.6 deg) ART .93 hrs, AST .26 hrs, 2-4K wob, 100 rpm's, 75 spm, 317 gpm, off btm pressure 3250 psi, on btm 3325-3475 psi, off btm torque 6K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 137K, dn wt 45-50K, 9.0 ppg MW, 93 vis Pump out of hole fl 8048' to 6717'. (1331') 6717' MD = 3717' TVD @ 90.79 deg Leave 1331' of 6 3/4" OH. Low side OH sidetrack @ 6717'. Point motor down to exit hole, work trough fl 6717' to 6757' (40'). 6717' MD = 3717' TVD @ 90.79 deg. Time drill fl 6757' to 6760' (3') TVD = 3714' estimated, @ ??? deg. (3 min per inch) :exit fl original 6 3/4" wellbore. 3 min per inch. AST 2 hrs. 67 spm 283 gpm, 2530 psi., mtr rpm=218 rpm. 9.2 ppg mw Time drill fl 6760' to 6767' (7') 3724'TVD ,(6760'-6763' 2 min inch, 6763'- 6767' 1min inch= 5'/hr) :exit @ 6757' floriginal 63/4" wellbore. AST 2.18 hrs. 67 spm 283 gpm, 2530 psi., mtr rpm=218 rpm. 9.2 ppg mw, wob 2k Time drill (slide)f/6767' to 6788' (11') 3717'TVD ,( 6767'-6774' 10'/hr, 6774'-6787' 30'/hr) :exit @ 6757' floriginal 63/4" wellbore. AST 2.3 Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 02 1 E-1 02 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 1/712005 Spud Date: 12/6/2004 End: 11712005 Group: 12117/2004 02: 15 - 05:00 2.75 DRILL DRLG PROD hrs. 67 spm 283 gpm, 2530 psi., mtr rpm=218 rpm. 9.2 ppg mw, wob 2k 05:00 - 10:00 5.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 6788' to 6990' (202')MD 13724.5' TVD, ART 2.96 hrs, AST .41 hrs, 3-5K wob, 100 rpm's, 74 spm, 313 gpm, off btm pressure 2950-3000 psi, on btm 3000-3100 psi, off btm torque 5K ft-Ibs, on btm 5K ft-Ibs, rot WI 85K, up WI 105K, dn WI 71K, 9.0 ppg MW, 88 vis 10:00 - 12:00 2.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 6990' to 7150' (160')MD 13730' TVD, ART 1.34 hrs, AST .14 hrs, 2-15K wob, 80-100 rpm's, 74 spm, 313 gpm, off btm pressure 3050-3100 psi, on btm 3200 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot WI 85K, up wt 105K, dn wt 73K, 9.0 ppg MW, 86 vis 12:00 - 00:00 12.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 7150' to 8065' (915')MD 13736' TVD, 90.44 deg, ART 7.07 hrs, AST 1.13 hrs, 2-15K wob, 80-100 rpm's, 74 spm, 313 gpm, off btm pressure 3050-3100 psi, on btm 3200 psi, off btm torque 6-8K ft-Ibs, on btm 5-6K ft-Ibs, rot WI 85K, up WI 105-110K, dn WI 73-69 K, 9.0 ppg MW, 84 vis Max gas approx 450 units, slow drilling background gas @ 66 units Max ECD 10.7 ppg. 12/18/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 8065' to 8605'(540')MD 13732' TVD, 90 deg, ART 7.88 hrs, AST 1.49 hrs, 2-12K wob, 100 rpm's, 73 spm, 309 gpm, off btm pressure 3100 psi, on btm 3150 psi, off btm torque 6-7K ft-Ibs, on btm 6K ft-Ibs, rot WI 85K, up WI 110-115K, dn WI 69-64 K, 9.0 ppg MW, 86 vis 12:00 - 00:00 12.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 8605' to 9378'(773')MD 13738.76' TVD, ART 7.46 hrs, AST .88 hrs, 2-15K wob, 100 rpm's, 73 spm, 309 gpm, off btm pressure 3050-3100 psi, on btm 3150-3200 psi, off btm torque 7.5-8K ft-Ibs, on btm 6-7K ft-Ibs, rot WI 86K, up WI 115-120K, dn WI 64-63 K, 9.0 ppg MW, 85 vis, Max gas 526 units. Max ECD 11.2 ppg, most of the time ECD 10.8-10.9 ppg. 12/19/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 9378' to 1 0055'(677')MD 13734' TVD, 88.9 deg, ART 6.13 hrs, AST 2.0 hrs, 2-12K wob, 100 rpm's, 73 spm, 309 gpm, off btm pressure 3150-3200 psi, on btm 3300-3400 psi, off btm torque 7.5-8K ft-Ibs, on btm 7-7.5K ft~lb$, rolwt 86K,· up \Nt 118c120K, dnwtô3=60 K,9.0-ppg MW,85 Vis max gas 518 units. Max ECD's 11.18 while drilling I 12.07 on connection 12:00 - 00:00 12.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 10055' to 10635'(580')MD 13731' TVD, 90.53 deg, ART 7.72 hrs, AST .66 hrs, 2-10K wob, 100 rpm's, 73 spm, 309 gpm, off btm pressure 3200-3250 psi, on btm 3300-3450 psi, off btm torque 8-9 K ft-Ibs, on btm 7.5-8 K ft-Ibs, rot wt 86K, up wt 118-124K, dn WI 60-57 K, 9.0 ppg MW, 84 vis max gas 421 units. Max ECD's 11.44 while drilling I 12.0 on connection. 12/20/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 10635' to 11350'(715')MD /3717.4' TVD, 91.6 deg, ART 7.9 hrs, AST .87 hrs, 2-10K wob, 100 rpm's, 73 spm, 309 gpm, mtr rpm 237,off btm pressure 3250-3400 psi, on btm 3450-3500 psi, off btm torque 8-9 K ft-Ibs, on btm 7.5-8 K ft-Ibs, rot WI 85K, up WI 123 K, dn wt 55 K, 9.0 ppg MW, 84 vis max gas 351 units. Max ECD's wI drilling 11.45 ppg 12:00 - 16:45 4.75 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 11350' to 11506'(156')MD 13713' TVD, 91.9 deg, ART 2.95 hrs, AST .47 hrs, 2-10K wob, 100 rpm's, 73 spm, 309 gpm, mtr rpm 237, off btm pressure 13350-3400 psi, on btm 3550 psi, off btm torque 9 K ft-Ibs, on btm 8 K Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 02 1 E-1 02 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 1/7/2005 Spud Date: 12/6/2004 End: 11712005 Group: 12/20/2004 12:00 - 16:45 4.75 DRILL DRLG PROD ft-Ibs, rot wt 85K, up wt 125K, dn wt 55 K, 9.0 ppg MW, 84 vis max gas 307 units. Max ECD's wI drilling 11.46 ppg Note: trouble sliding, running out of weight. 16:45 - 18:15 1.50 DRILL WIPR PROD Pump out of hole 10 stands fl 11506' to 10540' wI 233 gpm & 2000 psi. Note: Ran out of weight to slide with. POOH 10 stands 4" dp wI LoTads, install 3 stands of 4" dp and then 7 stands Hybrid (1 HWDP on top and 2 4 3/4" DC's on bottom). 18:15 - 19:00 0.75 DRILL WIPR PROD RIH wI 3 stands HWDP, then 7 stands Hybrid (DC's and HWDP), wash 56' to bottom, no fill. PU wt 142 k, SO wt 64 K, Rot wt 102 k Note: Max ECD's after RIH 11/6 ppg. 19:00 - 00:00 5.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional planl geologist from 11506' to 11762'(256')MD /3705' TVD, 91.1 deg, ART 1.68 hrs, AST .65 hrs, 2-5K wob, 100 rpm's, 67 spm, 283 gpm, mtr rpm 218, off btm pressure 3300-3400 psi, on btm 3500 psi, off btm torque 9-10 K ft-Ibs, on btm 9 K ft-Ibs, rot wt 101-104K, up wt 143-146 K, dn wt 57-65 K, 9.0 ppg MW, 84 vis max gas 71?? units. Max ECD's wI drilling 11.49 ppg 12/21/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral from 11,762' to 12,656' MDI 3,681' TVD (894'), ART 5.6 hrs, AST 1 hr, 1-10K wob, 100 rpm's, 80 spm, 285 gpm, off btm pressure 3,600 psi, on btm 3,875 psi, off btm torque 10.5K ft-Ibs, on btm 10K ft-Ibs, rot wt 109K, up wt 156K, dn wt 65K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 200 units, max gas 380 units 12:00 - 15:45 3.75 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral from 12,656' to 12,901' MDI 3,667' TVD (245'), ART 1.4 hrs, AST .75 hrs, 2-15K wob, 100 rpm's, 80 spm, 285 gpm, off btm pressure 3,800 psi, on btm 4,000 psi, off btm torque 12K ft-Ibs, on btm 1 OK ft-Ibs, rot wt 106K, up wt 165K, dn wt 57K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 100 units, max gas 370 units 15:45 - 16:45 1.00 DRILL CIRC PROD Circ hole while evaluating logs for geology, determined we drilled out top of zone and decision was made to open hole sidetrack well at 12,600' 16:45 - 17:00 0.25 DRILL OBSV PROD Monitored well-static 17:00 - 17:30 0.50 DRILL REAM PROD Backreamed out of hole from 12,901' to 12,600', 100 rpm's, 250 gpm at 3,150 psi 17:30 -19:15 1.75 DRILL OTHR PROD Orientedtotowsidearrd Trencheâ6J/4" hole foroþen hole sidetrack from 12,600' to 12,630' MD, 275 gpm at 3,500 psi 19:15 - 00:00 4.75 DRILL OTHR PROD Time drilled for sidetrack from 12,630' to 12,634' MDI 3,684' TVD, ART 3.5 hrs, attempted to slide and was unable to get weight to bit without stacking out, rotated while time drilling at 100 rpm's, 270 gpm, 3,500 psi, rot wt 105K, up wt 135K, dn wt 70K, on btm torque 9K ft-Ibs, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 50 units 12/22/2004 00:00 - 07:30 7.50 DRILL DRLG PROD Time Drilled and sidetracked well from 12,634' drilling 6 3/4" hole to original hole depth of 12,901' MD, Time drilled while rotating from 12,634' to 12,639', then control drilled sliding from 12,639' to 12,660', then drilled ahead to 12,901', ART 3.6 hrs, AST 1.5 hrs, 0-4K wob, 100 rpm's, 80 spm, 285 gpm, off btm pressure 3,850 psi, on btm 3,975 psi, off btm torque 9K ft-Ibs, on btm 9K ft-Ibs, rot wt 107K, up wt 158K, dn wt 68K, ave BGG 50 units, max gas 225 units 07:30 - 12:00 4.50 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral from 12,901' to 13,281' MDI 3,678' TVD (380'), ART 2.1 hrs, AST .4 hrs, 0-4K wob, 100 rpm's, 80 spm, 285 gpm, off btm pressure 3,800 psi, on btm 3,900 psi, off btm torque 1 OK ft-Ibs, on btm 9.5K ft-Ibs, rot wt 106K, up wt 156K, dn wt 70K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 175 Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1E-102 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 11712005 Spud Date: 1216/2004 End: 117/2005 Group: 12122/2004 07:30 - 12:00 4.50 DRILL DRLG PROD units, max gas 325 units 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral from 13,281' to 13,976' MDI 3,660' TVD (695'), ART 6.1 hrs, AsT .5 hrs, 3-13K wob, 100 rpm's, 75-80 spm, 275-285 gpm, off btm pressure 3,700 psi, on btm 3,850 psi, off btm torque 11.5K ft-Ibs, on btm 11 K ft-Ibs, rot wt 100K, up wt 153K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.8 ppg, ave BGG 150 units, max gas 330 units 12/23/2004 00:00 - 06:00 6.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral from 13,976' to 14,360' MD/3,650'TVD (T.D.) (384'), ART 3.0 hrs, AST .6 hrs, 1-5K -" wob, 100 rpm's, 80 spm, 285 gpm, off btm pressure 3,950 psi, on btm 4,100 psi, off btm torque 12.5K ft-Ibs, on btm 12K ft-Ibs, rot wt 100K, up wt 160K, dn wt 42K, 9.0 ppg MOBM, ave ECD 11.9, max ECD 12.2 ppg while drilling, ave BGG 100 units, max gas 240 units, pumped weighted hi vis sweep (2# over WNV) at 14,106', had no increase in cuttings back from sweep, max ECD while circ out sweep 12.35 ppg . 06:00 - 06: 15 0.25 DRILL CIRC PROD Circ hole to clear BHA 06:15 - 06:30 0.25 DRILL OBSV PROD Monitored well-static 06:30 - 17:15 10.75 DRILL REAM PROD Backreamed out of hole from 14,360' to 6,437' (7 5/8" Shoe at 6,499'), backreamed out at drilling rate, 285 gpm at 100 rpm's, initial circ pressure 3,950 psi, final pressure 2,500 psi, no problems backreaming out 17:15 - 18:30 1.25 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean, had 10% increase in cuttings back from sweep and circ add btms up and was clean at shakers, circ at 285 gpm at 2,450 psi and 100 rpm's, st wt up 103K, dn wt 77K 18:30 - 18:45 0.25 DRILL OBSV PROD Monitored well at shoe-static 18:45 - 22:30 3.75 DRILL TRIP PROD Pumped dry job and POOH from 6,437' to BHA at 365', calc fill 34 bbls, actual fill 38 bbls 22:30 - 00:00 1.50 DRILL PULD PROD Stood back HWDP and jars, LD NM flex DC's, flushed thru MWD and motor and downloaded MWD 12/24/2004 00:00 - 01 :15 1.25 DRILL PULD PROD Fin LD BHA #5, LD MWD and motor 01:15-01:30 0.25 DRILL PULD PROD Pulled wear bushing 01 :30 - 05:45 4.25 WELCTL BOPE PROD RU and tested BOPE, tested rams, valves and manifold to 250 psi low and 3,500 psi high, tested annular to 250 psi and 2,800 psi, NOTE: Jeff . JOnes with AOGCC wáìVea witneSsìng oftes( 05:45 - 06:00 0.25 DRILL PULD PROD Installed wear bushing 06:00 - 07:15 1.25 LOG RURD PROD Held PJSM and RU Schlumberger (SWS) wireline and scheaves 07:15-08:15 1.00 LOG PULD PROD MU USIT logging tools with Welltec tractor tool 08:15 - 09:30 1.25 LOG ELOG PROD RIH with logging tools to 2,900' and tool failed 09:30 - 10:00 0.50 LOG ELOG PROD POOH from 2,900' with USIT logging tool 10:00 -12:15 2.25 LOG DEQT PROD Trouble shoot problem with tool, checking connections on tool and tool began working 12:15 - 12:30 0.25 LOG ELOG PROD RIH with US IT logging tool to 2,900' 12:30 - 13:30 1.00 LOG ELOG PROD Cont RIH with logging tools from 2,900', tools stopped at 5,850' 13:30 - 14:30 1.00 LOG ELOG PROD RIH using Welltec tractor tool from 5,850' to 6,460' 14:30 -16:15 1.75 LOG ELOG PROD Ran US IT bond log from 6,460' to 3,350' then POOH with logging tools, had good bond up to top of cement at 3,650' 16:15 -17:15 1.00 LOG RURD PROD LD logging tools and RD SWS wireline 17:15-18:45 1.50 DRILL PULD PROD PU and RIH with 15 jts of 4" HWDP, POOH and stood back same in derrick 18:45 -19:15 0.50 CASE RURD CMPL TN RU Doyon's 4 1/2" liner running equipment 19:15 - 19:30 0.25 CASE SFTY CMPL TN Held PJSM with rig crew, tong operator and Baker service hand on running of 4 1/2" liner Printed: 1/1212005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 02 1 E-1 02 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 117/2005 Spud Date: 12/6/2004 End: 117/2005 Group: 12124/2004 19:30 - 00:00 4.50 CASE PULR CMPL TN PU and RIH with 41/2",12.6#, L-80 DWC Liner to 4,886' (151Jts total, 2 jts slotted 1 ~t blank) 12/25/2004 00:00 - 03:15 3.25 CASE PULR CMPL TN Fin PU and RIH with 4 1/2" liner per well program from 4,886' to 8,164', ran 4 1/2" ROT silver bullet guide shoe with no float, ran 259 its, (8,158') of41/2" 12.6#, L-80, DWC liner, ran 97 its (2,998') of blank liner and 162 its (5,160') of slotted liner, ran 255 - 4 1/2" x 6 1/2" spiralglide centralizers 1 on jt #1 then 1/it #3 thru # 256, ran 2 restrictor packers placed on blank liner from 6,840' to 6,690' . 03: 15 - 04:00 0.75 CASE PULR CMPL TN MU Baker 190-47 seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 8,220', st wt up 90K, dn wt 65K, MU 1 std of DP and RIH to 8,282' and rotated liner at 10 rpm's with 3K ft-Ibs torque 04:00 - 09:45 5.75 CASE RUNL CMPL TN RIH with liner on 4" DP to 14,332' with no problems, ran liner with 40 stds of 4" DP w/Lo-Tads, 8 stds HWDP, 15 stds Hybrid push pipe and 2 stds DP w/Lo-tads, st wt up 148K, dn wt 81 K, rotated liner at 10,071' at 10 rpm's and 4K ft-Ibs torque, rot wt 86K, up wt 102K, dn wt wIno rotation 62K, dn wt wlrotation 73K, rotated liner at 12,646', up wt 118K, dn wt 68K, 10 rpm's at 4.5K ft-Ibs torque, then rotated liner at 14,285', at 10 rpm's pipe would not rotate, pipe would rotate slow while working down at 6.5K ft-Ibs torque 09:45 - 10:15 0.50 CASE OTHR CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 2.5 bpm at 700 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, slacked off 40K, cont to set packer, pressured up to 3,000 psi and set ZXP packer, no problems setting hangerlpacker, set "B" sand liner with TOL @ 6,111' MDI 3,655' TVD and shoe at 14,332' MDI 3,651' TVD 10:15 - 10:30 0.25 CASE DEQT CMPL TN Tested ZXP packer to 1,000 psi for 5 min & checked ok 10:30-10:45 0.25 CASE RUNL CMPL TN Pressured up to 4,100 psi and released from liner running tool, PU and verified running tool was released. Set back down wI 15 on dogs to verify set "OK". 10:45 - 11 :00 0.25 DRILL OBSV CMPL TN Monitored well-static 11 :00 - 14:30 3.50 DRILL TRIP CMPL TN Pumped dry job, POOH and LD running tool, cleared rig floor 14:30 - 15:30 1.00 RIGMNT RSRV CMPL TN Slip and cut 71' of drilling line 15:30 - 17:30 2.00 RIGMNT RSRV CMPL TN Changed out XT-39 saver sub on top drive, serviced top drive and drawwOrks 17:30 - 21 :00 3.50 WINDOWPULD PROD2 MU Baker 7 5/8" whipstock assembly BHA #6 and RIH to 1,027', MU milling assembly and LD same, PU seal assembly, locator sub, unloader sub, then PU 2 it of 3 1/2" HWDP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 9 stds of hybrid push pipe to 1,027' 21 :00 - 21 :30 0.50 WINDOV\lOTHR PROD2 Shallow tested MWD at 1,027', circ at 275 gpm 850 psi 21 :30 - 00:00 2.50 WINDOWTRIP PROD2 RIH with whipstock assembly from 1,027' to 3,249' 12/26/2004 00:00 - 01 :30 1.50 WINDOWTRIP PROD2 RIH with whipstock assembly from 3,249' to 5,476' 01:30 - 02:15 0.75 WINDOV\lOTHR PROD2 Made MADD, pass from 5,476' to 5,521' (5,308' to 5,353' sensor depth) and correlated MWD to K-13 02:15 - 02:30 0.25 WINDOWTRIP PROD2 RIH with whipstock assembly from 5,521' to 6,050', st wt up 107K, dn wt 80K, RIH with whipstock milling assembly with 9 stds of hybrid push 102:30 - 03:15 pipe, 50 stds of 4" DP W/Lo-tads and 2 stds of slick 4" DP 0.75 WINDOWSETW PROD2 Oriented whipstock 1 deg right of high side and RIH, tagged TOL at 6,111', set whipstock and sheared off from same, top of whipstock at 6,005' 03:15 - 09:00 5.75 WINDOWSTWP PROD2 Milled window in 7 5/8" casing for "D" sand lateral, top of window at 6,006', btm of window at 6,018', drilled 6 3/4" hole to 6,034' MDI 3,636' Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1E-102 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 12/6/2004 End: 11712005 Group: 1216/2004 1/7/2005 TVO (28') 1-8K wob, 90-120 rpm's, 275 gpm, 2,000 psi, torque 3-7K ft-Ibs, rot wt 90K, up wt 108K, dn wt 80K Pumped hi vis sweep and circ hole clean while working mills thru window, circ at 275 gpm, 2,000 psi Monitored well-static, pumped dry job, Phase 3 in effect POOH from 6,034' to 107', stood back 9 stds hybrid pushpipe LD MWD and milling assembly, upper mill in gauge Flushed out BOP stack after milling window with stack washer MU 6 3/4" Sperry Sun Slickbore BHA #7, 4 3/4" motor with 1.22 deg bend, MWD and PWD, oriented and uploaded MWD, RIH to 364' Shallow tested MWD at 275 gpm at 1,800 psi Re-installed "D" rings on top drive service loop due to high wind RIH with BHA #7 from 364' to 5,876' Oriented BHA and RIH thru window, washed to btm at 6,034', no problems going thru window Drilled 6 3/4" hole from 6,034' to 6,045' MD/3,640' TVD (11') AST .4 hrs, 2-5K wob, 300 gpm, 3,100 psi, st wt up 100K, dn wt 75K Phase 3 still in effect Oirectionally drilled 6 3/4" hole in "D" sand lateral from 6,045' to 6,760' MDI 3,661' TVD (715'), ART 2.4 hrs, AST 6.35 hrs, 2-10K wob, 100 rpm's, 73 spm, 310 gpm, off btm pressure 3,050 psi, on btm 3,200 psi, off btm torque 5K ft-Ibs, on btm 5K ft-Ibs, rot wt 86K, up wt 105K, dn wt 72K, 9.0 ppg MOBM, ave ECD 10.5 ppg, ave BGG 100 units, max gas 375 units, Phase 3 Lifted at 05:00 hrs 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "0" sand lateral from 6,760' to 7,648' MDI 3,668' TVD (888'), ART 4.5 hrs, AST 3 hrs, 2-10K wob, 100 rpm's, 73 spm, 310 gpm, off btm pressure 3,200 psi, on btm 3,300 psi, off btm torque 6.5K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 86K, up wt 116K, dn wt 69K, 9.0 ppg MOBM, ave ECD 10.7 ppg, ave BGG 25 units, max gas 115 units 0.50 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral from 7,648' to 7,717' MDI 3,665' TVD (69'), ART -0- hrs, AST .5 hrs, 2-10K wob, 100 rpm's, 73 spm, 310 gpm, off btm pressure 3,200 psi, on btm 3,300 psi, off btm torque 6.5K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 86K, up wt 116K, dn wt 69K, 9.0pþg MOBM, ave ECD 10.7 ppg, avè BGG25 units Circ hole evaluating logs, determined we drilled out of the top of "D" sand, decision made to do open hole side track at 7,500' Pumped out of hole from 7,717' to 7,465' Oriented to lows ide and Trenched 6 3/4" hole for open hole sidetrack from 7,465' to 7,500' MD, (35') 310 gpm at 3,300 psi Time Drilled and sidetracked well from 7,500' drilling 6 3/4" hole to original hole depth of 7,717' MD, Time drilled sliding from 7,500' to 7,510', then directionally drilled ahead to 7,717', ART 5.1 hrs, AST 5.9 hrs, 2-11 K wob, 100 rpm's, 73 spm, 310 gpm, off btm pressure 3,100 psi, on btm 3,200 psi, off btm torque 6.5K ft-Ibs, on btm 6K ft-Ibs, rot wt 88K, up wt 109K, dn wt 72K, ave BGG 20 units 9.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 7,717' to 8,264' MDI 3,683' TVD (577'), ART 4.7 hrs, AST 1.8 hrs, 2-11 K wob, 100 rpm's, 73 spm, 310 gpm, off btm pressure 3,175 psi, on btm 3,275 psi, off btm torque 7.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 87K, up wt 113K, dn wt 69K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 20 units, max gas 100 units, drilling thru numerous calcite stringers 12/26/2004 03:15 - 09:00 5.75 WINDOWSlWP PROD2 09:00 - 10:00 1.00 WINOOWCIRC PROD2 10:00 - 10:15 0.25 WINDOV\lOTHR PROD2 10:15 - 13:30 3.25 WINDOWTRIP PROD2 13:30-15:15 1.75 WINDOWPULO PROD2 15:15 - 16:15 1.00 WINDOV\lOTHR PROD2 16:15 - 19:00 2.75 DRILL PULD PROD2 19:00 - 19:15 0.25 ORILL DEQT PROD2 19:15-19:45 0.50 RIGMNT RSRV PROD2 19:45 - 22:45 3.00 DRILL DRLG PROD2 22:45 - 23: 15 0.50 DRILL REAM PROD2 23:15 - 00:00 0.75 DRILL DRLG PROD2 12/27/2004 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 00:00 12/28/2004 00:00 - 00:30 00:30 - 01 :00 0.50 DRILL CIRC PROD2 01 :00 - 01 :30 0.50 DRILL TRIP PROD2 01 :30 - 03:00 1.50 DRILL OTHR PROD2 03:00 - 15:00 12.00 DRILL DRLG PROD2 15:00 - 00:00 Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1E-102 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 1/712005 Spud Date: 1216/2004 End: 11712005 Group: 12129/2004 00:00 - 12:00 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 8,264' to 8,749' MDI 3,677' TVD (455'), ART 4.08 hrs, AST 4.76 hrs, 2-11 K wob, 100 rpm's, 73 spm, 310 gpm, off btm pressure 3,175 psi, on btm 3,300 psi, off btm torque 7.5K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 113K, dn wt 67K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 20 units, drilling thru numerous calcite stringers 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 8,749' to 9,262' MDI 3,688' TVD (513'), ART 6.71 hrs, AST 1.93 hrs, 2-11 K wob, 100 rpm's, 73 spm, 310 gpm, off btm pressure 3,250 psi, on btm 3,350 psi, off btm torque 8K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 87K, up wt 117K, dn wt 68K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 20 units, max gas 140 units, cant to drill thru calcite stringers 12/30/2004 00:00 - 12:00 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 9,262' to 1 0,300' MDI 3,683' TVD (1,038'), ART 5.83 hrs, AST 2.0 hrs, 2-11 K wob, 100 rpm's, #1 mud pump, 73 spm, 310 gpm, off btm pressure 3,500 psi, on btm 3,600 psi, off btm torque 9K ft-Ibs, on btm 8K ft-Ibs, rot wt 85K, up wt 125K, dn wt 59K, 9.0 ppg MOBM, ave ECD 11.4 ppg, from 9,262' to 9,850', ave BGG 20 units, from 9,850' ave bgg was 200 units, max gas 520 units, dropped angle and got below the majority of the calcite stringers, cont to drill thru fewer and smaller stringers 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 1 0,300' to 11,390' MDI 3,667' TVD (1,090'), ART 5.2 hrs, AST 1.8 hrs, 3-11 K wob, 100 rpm's, #2 mud pump, 85 spm, 300 gpm, off btm pressure 3,475 psi, on btm 3,550 psi, off btm torque 1 OK ft-Ibs, on btm 9K ft-Ibs, rot wt 85K, up wt 130K, dn wt 55K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave bgg 200 units, max gas 500 units, cant to drill thru fewer and smaller calcite stringers 12/31/2004 00:00 - 11 :00 11.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 11,390' to 12,140' MDI 3,645' TVD (750'), ART 3.2 hrs, AST 3.55 hrs, 3-10K wob, 100 rpm's, #2 mud pump, 85 spm, 300 gpm, off btm pressure 3,525 psi, on btm 3,625 psi, off btm torque 11 K ft-Ibs, on btm 9.5K ft-Ibs, rot wt 91 K, up wt 140K, dn wt 53K, 9.0 ppg MOBM, ave ECD 11.3 ppg, ave bgg 200 units, max gas 516 units, while attempting lóslide was unable to get weight dówllló bit 11 :00 - 12:45 1.75 DRILL CIRC PROD2 Pumped weighted hi vis sweep and circ out of hole, circ at 300 gpm, 3,600 psi and 100 rpm's with 10k ft-Ibs torque, had very little increase in cuttings back from sweep, monitored well-static 12:45 - 20:30 7.75 DRILL REAM PROD2 Backreamed out of hole from 12,140' to 5,969' (Window @ 6,006') POOH to re-arrange HWDP and pushpipe, backreamed out from 12,140' to 6,342' at 100 rpm's, 40-45'/min, 300 gpm at 3,600 psi, pumped out of hole from 6,342' to 6,062' then POOH thru window to 5,969', no problems thru window or backreaming out of hole 20:30-21:15 0.75 DRILL CIRC PROD2 Pumped weighted hi vis sweep and circ out of hole at window, circ at 300 gpm, 3,000 psi and 40 rpm's with 4K ft-Ibs torque, had no increase in cuttings back from sweep and clean at shakers 21 :15 - 22:00 0.75 RIGMNT RSRV PROD2 Serviced top drive and drawworks, inspected saver sub and ck ok 22:00 - 23:00 1.00 RIGMNT RSRV PROD2 Slip and cut 38' of drlg line 23:00 - 23: 15 0.25 DRILL TRIP PROD2 Oriented BHA and ran thru window at 6,006' with no problems, RIH to 6,059' 23: 15 - 00:00 0.75 DRILL TRIP PROD2 RIH with 6 3/4" BHA #7 from 6,059' to 7,558' 1/1/2005 00:00 - 02:30 2.50 DRILL TRIP PROD2 RIH with 6 3/4" BHA #7 from 7,558' to 12,075', washed 65' to btm to 12,140' with no problems Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-102 1 E-1 02 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 1/7/2005 Spud Date: 12/6/2004 End: 1/712005 Group: 1/1/2005 02:30 - 12:00 9.50 DRILL DRLG PROD2 Oirectionally drilled 6 3/4" hole in "0" sand lateral per geology from 2,140' to 12,923' MDI 3,620' TVD (783'), ART 4.65 hrs, AST 1.13 hrs, 2-1 OK wob, 100 rpm's, #2 mud pump, 80 spm, 285 gpm, off btm pressure 3,950 psi, on btm 4,100 psi, off btm torque 12K ft-Ibs, on btm 11 K ft-Ibs, rot wt 11 OK, up wt 168K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.6 ppg, ave bgg 20 units, max gas 180 units 12:00 - 23:15 11.25 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 12,923' to 13,282' MDI 3,621' TVD (359'), ART 8.1 hrs, AST.4 hrs, 3-15K wob, 100 rpm's, #2 mud pump, 78 spm, 278 gpm, off btm pressure 3,875 psi, on btm 4,150 psi, off btm torque 13K ft-Ibs, on btm 12K ft-Ibs, rot wt 109K, up wt 174K, dn wt 50K, 9.0 ppg MOBM, ave ECO 11.4 ppg, ave bgg 20 units, max gas 50 units, began drilling calcite stringers at approx 12,900', while attempting to slide at 13,282' was unable to get weight down to bit 23: 15 - 00:00 0.75 DRILL REAM PROD2 Began backreaming out of hole 28 stds to move push pipe and HWDP up hole, backreamed out of hole 5 stds from 13,282' to 12,801' at 100 rpm's, 250 gpm, 3,200 psi 1/2/2005 00:00 - 02:45 2.75 DRILL REAM PROD2 Fin Backreaming out of hole from 12,800' to 10,715' (25 stds total), backreamed out at 100 rpm's, 250 gpm at 3,200 psi 02:45 - 05: 15 2.50 DRILL TRIP PROD2 RIH from 10,715' to 13,244', washed 38' to btm to 13,282', tagged up at 12,400' and washed thru, (area of slide), no other problems, RIH slow due to 40K down weight, RIH with 13 stds of 4" DP with lo-tads and 15 stds of hybrid pushpipe, to drill ahead with HWDP 05:15 -12:00 6.75 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 13,282' to 13,530' MDI 3,612' TVD (248'), ART 2.52 hrs, AST 1.34 hrs, 2-14K wob, 100 rpm's, #2 mud pump, 78 spm, 278 gpm, off btm pressure 3,900 psi, on btm 4,000 psi, off btm torque 12K ft-Ibs, on btm 11K ft-Ibs, rot wt 110K, up wt 164K, dn wt 56K, 9.0 ppg MOBM, ave ECO 11.6 ppg, ave bgg 20 units, max gas 80 units 12:00 - 00:00 12.00 DRILL ORLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral per geology from 13,530' to 14,248' MDI 3,606' TVD (718'), ART 8.3 hrs, AST 1.0 hrs, 2-15K wob, 100 rpm's, #2 mud pump, 78 spm, 278 gpm, off btm pressure 3,900 psi, on btm 4,150 psi, off btm torque 13K ft-Ibs, on btm 12K ft-Ibs, rot wt 111 K, up wt 178K, dn wt 47K, 9.0 ppg MOBM, ave ECD 11.6þpg, ave bgg 30 units, max gas 180 units, pumped weighted hi vis sweep at 14,168' with 5% increase in cuttings back from sweep 1/3/2005 00:00 - 01 :00 1.00 DRILL ORLG PROD2 Drilled 6 3/4" hole from 14,248' to 14,358' MD/3,616' TVD (T.D.) (110'), ART .33 hrs, AST -0- hrs, 2-15K wob, 100 rpm's, #2 mud pump, 78 spm, 278 gpm, off btm pressure 3,900 psi, on btm 4,150 psi, off btm torque 13.5K ft-Ibs, on btm 12.5K ft-Ibs, rot wt 111 K, up wt 182K, dn wt 45K, 9.0 ppg MOBM, ave ECD 11.6 ppg, ave bgg 30 units, max gas 200 units, 01:00- 01:15 0.25 DRILL CIRC PROD2 Circ hole to clear BHA and survey 01:15 - 01:30 0.25 DRILL OBSV PROD2 Monitored well-static 01 :30 - 10:45 9.25 DRILL REAM PROD2 Backreamed out of hole from 14,358' to 5,969', pulled thru window at 6,006', no problems backreaming or pulling thru window, backreamed out at 100 rpm's, 275 gpm, initial circ pressure 3,800 psi, final pressure 3,100 psi 10:45 - 12:45 2.00 DRILL CIRC PROD2 Pumped weighted hi vis sweep above window and circ hole clean, had no increase in cuttings back from sweep, circ a total of 2X btms up and clean at shakers, circ at 300 gpm, 2,600 psi, 100 rpm's, st wt up 103K, dn wt 75K 12:45 - 13:30 0.75 RIGMNT RGRP PROD2 Changed out swivel packing on top drive Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1E-102 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 117/2005 Spud Date: 1216/2004 End: 11712005 Group: 1/3/2005 13:30 - 18:30 5.00 DRILL TRIP PROD2 RIH thru window at 6,006' and cant RIH to 13,696', pipe floating in hole from 11,875' 18:30 - 19:30 1.00 DRILL REAM PROD2 Washed and reamed from 13,696' to btm at 14,358' (662'), washed to btm due to no down wt 19:30 - 21:30 2.00 DRILL CIRC PROD2 Pumped weighted hi vis sweep and circ out of hole, no increase in cuttings back from sweep and no gas on btms up, circ hole at 275 gpm, 3,900 psi, 100 rpm's with 12.5K ft-Ibs torque, rot wt 11 OK, up wt 185K, dn wt 35K 21 :30 - 23:00 1.50 DRILL CIRC PROD2 Displaced out 9.0 ppg MOBM with 8.95 ppg SFMOBM, circ at 275 gpm at 3,800 psi 23:00 - 23: 15 0.25 DRILL OBSV PROD2 Monitored well-static 23: 15 - 00:00 0.75 DRILL TRIP PROD2 POOH on elevators from 14,358' to 13,787' 1/4/2005 00:00 - 04:45 4.75 DRILL TRIP PROD2 Continue POOH on elevators from 13787' to 5969'. No problems pulling thru window. 04:45 - 08:15 3.50 DRILL TRIP PROD2 Monitor well, continue POOH on elevators from 5969' to 364'. 08:15 - 09:15 1.00 DRILL TRIP PROD2 UD BHA, 5 jts HWDP, jars, x-o, 3 jts NMDC, float sub. 09:15 -10:00 0.75 DRILL OTHR PROD2 Plug in, download MWD. 10:00 - 10:30 0.50 DRILL OTHR PROD2 Drain mtr, break bit, UD MWD and motor. 10:30 - 12:00 1.50 WINDOV\IPULD CMPL T2 Clear rig floor, MU BHA, RIH to 519'. 12:00 - 14:15 2.25 WINDOWTRIP CMPL T2 Trip in hole fl 519' to 5970'. PU = 130k, SO= 95k 14:15-15:00 0.75 WINDO\lllOTHR CMPL T2 Wash slot, latch whipstock. PU to 160k, slack off to 150k. PU to 21 Ok. Weight dropped off to 135k. Pick up 55'. Slot was located @ 6006'. 15:00 - 15:45 0.75 WINDO\I\ICIRC CMPL T2 CBU 83 spml 1900 psi. Monitor well. Static. 15:45 - 19:00 3.25 WINDOWTRIP CMPL T2 POOH wI Baker whipstock. UD jars and fishing tools. 19:00 - 21 :00 2.00 WINDOV\IPULD CMPL T2 Rack back 4 stands Hybrid dp, UD whipstock and fishing BHA. 21 :00 - 21 :30 0.50 CMPL TN RURD CMPL T2 Clean floor, RU f/ 4 1/2" liner. 21 :30 - 00:00 2.50 CMPL TN RUNT CMPL T2 PJSM on running 4 1/2" liner. Run 4 1/2" liner to 2023' (65 joints in hole). Ran Baker 31/2" guide shoe, 1jt 3 1/2", 9.3 ppf, L-80, IBT (bent joint), x-a, 4 1/2" 12.6 ppf, IBT pup joint, Drillable pack-off bushing, 4 1/2" 12.6 ppf, IBT pin x DWC box pup joint, then repeating pattern of 2jts 41/2" 12.6 ppf, L-80, DWC slotted, then 1 blank. 1/5/2005 00:00 - 03:00 3.00 CMPL TN RUNT CMPL T2 Continue runnning 4 1/2" liner to 6141' (197 joints in hole). Ran 41/2" 12.6 ppf, IBT pin x DWC box pup joint, then repeating pattern of 2jts 4 1/2" 12.6 ppf, L-80, DWC slotted, then 1 blank. 03:00 - 04:30 1.50 CMPLTN RUNT CMPL T2 Attempt to go throLigh WindoW @ 6006'. Tagged lower @6141' shoe depth. Pull 5 jts rotate and attemt again. On third attempt made it trhough window. 04:30 - 06:30 2.00 CMPL TN RUNT CMPL T2 Continue running 4 1/2" 12.6 ppf, L-80 DWC tubing alternating most wI 2 slots and one blank. 06:30 - 07:00 0.50 CMPL TN RUNT CMPL T2 MU Baker liner hook hanger. PU wt 85k, SO wt 63k. 07:00 - 12:45 5.75 CMPLTN TRIP CMPL T2 RIH wI 41/2" liner on 4" dp fl derrick. Run 41 stands dp wI Lo-Tads, 15 stands Hybrid (2 jts 4 3/4" DC + 1 jt 4"HWDP), 7 stands 4" HWDP. Ran to 6004' depth of hook hanger. PU wt 150k, SO wt 75k. Orient hanger 9 times, hook and unhook hanger 13 times. Found lowest hooked point wI bottom of window @ 6020.97' (top of hook @ 6004.27') (2.97' low). Slacked off 40k. Drop ball, pump @ 2bpm 2000psi. Seat ball and pressure to 3000 psi. Bleed pressure to zero. PU 20', break circ. Positive check fl release, PU wt 130K 12:45 - 13:30 0.75 CMPL TN CIRC CMPL T2 CBU @ 80 spm wI 1700 psi. Monitor well, OK. 13:30 - 14:00 0.50 CMPL TN TRIP CMPL T2 Pull 5 stands, monitor fill. Blow down top drive. 14:00 - 15:00 1.00 RIGMNT RSRV CMPL T2 Slip and cut 71' drilling line. 15:00-17:15 2.25 CMPL TN TRIP CMPL T2 POOH DP wI liner running tools. 17:15 - 18:00 0.75 CMPLTN TRIP CMPL T2 UD Baker liner running tools, clear and clean rig floor. Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-102 1 E-102 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 12/6/2004 11712005 Spud Date: 1216/2004 End: 11712005 Group: 1/5/2005 18:00 - 20:15 2.25 CMPL TN PULD CMPL T2 PJSM, RU/MU 41/2" LEM. Assembly consisting of Baker seal assembly, 1jt 41/2" 12.6ppf L-80 IBT tubing, (2) 41/2" 12.6 ppf IBT pups, (1) jt 41/2" 12.6 ppf IBT tubing, 4 1/2" "DB" nipple wI 3.562" ID, (1) jt 41/2" IBT tubing, Baker Lateral Entry Module, 41/2" pup, 4 1/2" casing swivel, x-a bushing, Baker 109-47 casing seal bore recept 4.75" ID, 5 1/2" Hydril563 collar, Baker 75/8" x 5 1/2" ZXP liner top packer, setting tool, running tool, x-a. 20: 15 - 23:00 2.75 CMPL TN TRIP CMPL T2 RIH w/4 1/2" LEM on 4" DP. Seals to 6154'. 23:00 - 00:00 1.00 CMPL TN CIRC CMPL T2 Drop ball. Pump ball to seat wI 2 bpm and 250 psi. Press to 2800 psi, bleed to zero. Rig up to test annulus to 1000 psi. 1/6/2005 00:00 - 01 :30 1.50 CMPL TN DEQT CMPL T2 Attempt to test 7 5/8" x 4" dp annulus after setting zxp packer. Press to 3100 psi on dp, shut in DP. Attempt to pressure up annulus. Attempt several times. No luck. 01 :30 - 01 :45 0.25 CMPL TN PCKR CMPL T2 Pressure dp to 4200, release running tool fl LEM, bleed off pressure, PU 6', then set down 50K on packer wI dog sub, repeat same, PU 6', rotate @ 15rpm wI slack off to 55K. Saw indication of pkr set. 01 :45 - 02:00 0.25 CMPL TN DEQT CMPL T2 Test liner top packer annulus to 1000 psi fl 10 min. Chart test. OK. Bleed off pressure. 02:00 - 02:30 0.50 CMPL TN CIRC CMPL T2 PU 30'. circulate bottoms up @ 80 spm wI 1700 psi. 02:30 - 05:15 2.75 CMPL TN TRIP CMPL T2 Blow down top drive. POOH wI LEM running tools and 4" DP. 05:15 - 05:45 0.50 CMPL TN PULD CMPL T2 UD Baker running tools. Clean rig floor. 05:45 - 06:15 0.50 WELCTL OTHR CMPL T2 Pull Vetco/Gray wear bushing. 06: 15 - 06:45 0.50 CMPL TN RURD CMPL T2 RU to run 4 1/2" completion. 06:45 - 07:00 0.25 CMPL TN SFTY CMPL T2 PJSM on running 4 1/2" completion assembly. 07:00 - 13:30 6.50 CMPL TN RUNT CMPL T2 Run 4 1/2" completion. Ran Baker 4.75" SBE seal assembly, Baker ., locator (5.50" OD), 4 1/2" 12.6 ppf L-80 IBT tubing pup joint, 1 jt 41/2" tubing, 4 1/2" pup joint, Baker CMU wI 3.81" profile (open), pup joint, 14 joints 41/2", pup joint, 41/2" Cameo GLM (KBG-2 wI 1" dummy, BK latch), pup joint, 73 joints 4 1/2" IBT tubing, pup joint, 4 1/2" Cameo GLM (KBG-2 wI 1" dummy, BK latch), pup joint, 85 joints 41/2" IBT tubing, Cameo 41/2" DB nipple wI 3.875" NO-GO profile, 14 joints 4 1/2" IBT tubing, space out pups (7.82" bottom, 7.80" top), 1 joint 41/2" IBT tubing, Vetco Gray hanger wI 3.38" pup. Tubing above DB nipple drifted to 3.91". Hanger drifted to 3.885", then Cameo toöl ran through it (3.875"). Torqued pipe tö 3100 ft/lb. 13:30 - 14:15 0.75 CMPLTN SOHO CMPL T2 Space out, MU hanger wI TWC, MU landing joint. 14:15-15:00 0.75 CMPLTN SOHO CMPL T2 Land hanger, RILDS, test upper and lower seals to 5000 psi fl 10 min. OK. PU wt 83k, SO wt 65K, blocks 35K. 15:00 - 15:30 0.50 CMPL TN RURD CMPL T2 Rig down Doyon casing tools. 15:30 - 16:45 1.25 WELCTL NUND CMPL T2 Nipple down BOPE. 16:45 - 18:45 2.00 WELCTL NUND CMPL T2 NU Vetco Gray 5000 psi tree. Attempt to test tree, change out TWC, test tree to 250 psi and 5000 psi. Test packoff to 5000 psi. Pull TWC. 18:45 - 20:15 1.50 CMPL TN FRZP CMPL T2 Displace OBM wI diesel wI Little Red Services. Test lines to 3500 psi. Pump 250 bbls diesel down annulus, taking returns fl tubing 5 bpm wI 800 psi initial, final 550 psi. Close well in. RU mousehole and floor fl U d dp. Started UD dp f/ derrick using mouse hole while displacing. 20:15 - 00:00 3.75 DRILL PULD CMPL T2 Continue UD Weatherford 4" dp fl derrick. Transfering mud fl pits to upright storage tanks. Cleaning pits. Layed down 52 stands. 107 stands left to go. 1m2005 00:00 - 06:30 6.50 DRILL PULD CMPL T2 Continue UD Weatherford 4" dp fl derrick. Transfering mud fl pits to upright storage tanks.Cleaning pits. Layed down 57 stands. 06:30 - 07:30 1.00 WELCTL OTHR CMPL T2 Set BPV in well wI lubricator. Pressure on tubing 400 PSI. ./ 07:30 - 09:00 1.50 DRILL PULD CMPL T2 UD 18 stands of Weatherford 4" dp wI Weatherford Lo-Tads. Printed: 1/12/2005 3:52:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-102 1 E-1 02 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 12/6/2004 Rig Release: 117/2005 Rig Number: Spud Date: 1216/2004 End: 11712005 Group: 1nt2005 09:00 - 10:00 1.00 WELCTL NUND CMPL T2 10:00 - 19:15 9.25 RIGMNT RGRP CMPL T2 19:15 - 22:15 3.00 DRILL PULD CMPL T2 22:15 - 00:00 1.75 DRILL OTHR CMPL T2 Install accuator valve on tree. Repair Varco Iron roughneck. Replace upper and lower torque arm bodies. UD 32 stands of Weatherford 4" dp wI Weatherford Lo-Tads. Clear rig floor of lo-tads. Clear dp fl pipe shed. Remove double valve on tbg annulus(2 1/16", install companion flange. Off high line @ 2330 hrs 1nt2005. Prep fl move to 1E-121. Rig released fl 1 E-1 02 fl 2640' move around to other side of pad to well 1E-121 @ midnight 1/7/05 Printed: 1/12/2005 3:52:55 PM ._..__._._---~----~ DEFINITIVE Halliburton Sperry-Sun Western North Slope ConocoPhillips 1E-102 . Job No. AKMW3431828, Surveyed: 23 December, 2004 Survey Report 18 January, 2005 Your Ref: API 500292323600 Surface Coordinates: 5960080.61 N, 550300.70 E (70018' 06.1456" N, 149035' 33.3062" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 94.40ft above Mean Sea Level . Cl\ru='f'""l""'y-sul"1 DRILL.ING SeRViCes A Halliburton Company Survey Ref: svy2098 . .: .: . - II: - 'a - .. .' .'1 .. - ~ IJ Halliburton Sperry-Sun Survey Report for 1E-102 Your Ref: API 500292323600 Job No. AKMW3431828, Surveyed: 23 December, 2004 ConocoPhillips Alaska, Inc. ConocoPhillips Western North Slope Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12603.53 92.950 6.870 3592.14 3686.54 10398.55 N 2886.13 E 5970498.25 N 553117.15 E 10789.61 Tie On Point 12630.00 93.170 7.260 3590.72 3685.12 10424.78 N 2889.38 E 5970524.50 N 553120.23 E 1.690 10815.83 Window Point 12710.45 88.880 8.250 3589.29 3683.69 10504.47 N 2900.23 E 5970604.26 N 553130.54 E 5.473 10895.71 12807.88 90.300 8.380 3589.98 3684.38 10600.87 N 2914.32 E 5970700.75 N 553143.99 E 1 .464 10992.58 12905.10 90.170 6.720 3589.58 3683.98 10697.24 N 2927.09 E 5970797.21 N 553156.11 E 1.713 11089.10 . 13001.86 90.510 5.620 3589.01 3683.41 10793.44 N 2937.49 E 5970893.47 N 553165.87 E 1.190 11184.87 13097.77 90.470 7.590 3588.19 3682.59 10888.70 N 2948.52 E 5970988.81 N 553176.26 E 2.054 11279.88 13191.75 91.420 7.250 3586.64 3681.04 10981.88 N 2960.66 E 5971082.06 N 553187.77 E 1.074 11373.15 13288.72 91.210 9.180 3584.41 3678.81 11077.83 N 2974.51 E 5971178.10 N 553200.98 E 2.002 11469.53 13385.37 91.160 8.430 3582.42 3676.82 11173.32 N 2989.30 E 5971273.69 N 553215.13 E 0.778 11565.69 13481.65 91.190 7.750 3580.44 3674.84 11268.62 N 3002.85 E 5971369.08 N 553228.04 E 0.707 11661.37 13578.46 91.420 7.070 3578.24 3672.64 11364.59 N 3015.33 E 5971465.13 N 553239.88 E 0.741 11757.44 13675.50 91.920 7.490 3575.41 3669.81 11460.81 N 3027.62 E 5971561.43 N 553251.53 E 0.673 11853.69 13771.77 92.520 6.340 3571.68 3666.08 11556.30 N 3039.20 E 5971657.00 N 553262.47 E 1.347 11949.06 13864.70 91.590 6.430 3568.35 3662.75 11648.60 N 3049.53 E 5971749.36 N 553272.18 E 1.005 12041.02 13968.68 92.680 7.030 3564.47 3658.87 11751.79 N 3061.71 E 5971852.63 N 553283.67 E 1.196 12144.00 14065.54 90.880 6.610 3561.46 3655.86 11847.91 N 3073.20 E 5971948.83 N 553294.52 E 1.908 12239.96 14162.41 90.670 5.480 3560.15 3654.55 11944.23 N 3083.40 E 5972045.22 N 553304.07 E 1.186 12335.79 14259.09 91 .340 4.430 3558.46 3652.86 12040.53 N 3091.75 E 5972141.57 N 553311.78 E 1.288 12431.15 14318.30 91.940 4.160 3556.76 3651.16 12099.55 N 3096.19 E 5972200.62 N 553315.82 E 1.111 12489.41 - 14360.00 91.940 4.160 3555.35 3649.75 - 12141.12 N 3099.21 E - 5972242.21 N 553318.56 E - 0.000 12530.43 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. - . Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 14.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14360.00ft., The Bottom Hole Displacement is 12530.44ft., in the Direction of 14.320° (True). 18 January, 2005 - 16:06 Page 20f3 DrillQuest 3.03.06.008 - - - - ConocoPhillips Alaska, Inc. Western North Slope Comments Measured Depth (ft) 12603.53 12630.00 14360.00 - - --........ Halliburton Sperry-Sun Survey Report for 1E-102 Your Ref: API 500292323600 Job No. AKMW3431828, Surveyed: 23 December, 2004 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) 3686.54 3685.12 3649.75 Comment 10398.55 N 10424.78 N 12141.12 N 2886.13 E 2889.38 E 3099.21 E Tie On Point Window Point Projected Survey Survey tool )roQram for 1E-102 0.00 262.00 18 January, 2005 -16:06 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 262.00 261.92 14360.00 261.92 CB-GYRO-SS (1E-102PB1) 3649.75 MWD+SAG (1E-102PB1) Page 3 of 3 ... ConocoPhillips . . DrillQuest 3.03.06.008 - .- - -- - .- _. - - - Halliburton Sperry-Sun Western North Slope ConocoPhillips 1E-102PB1 Job No. AKMW3431828, Surveyed: 16 December, 2004 Survey Report 18 January, 2005 Your Ref: API 500292323670 Surface Coordinates: 5960080.61 N, 550300.70 E (70· 18' 06.1456- N, 149· 35' 33.3062- W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 94.40ft above Mean Sea Level Bpe!ï'ï'Y-SUI'1 DRILLING SeRVIt:es A Halliburton Company DEFINITIVE . . Survey Ref: svy2104 .. .- -- .- .. ~ ~ -. -. -. -- - - Halliburton Sperry-Sun Survey Report for 1E-102PB1 Your Ref: API 500292323670 Job No. AKMW3431828, Surveyed: 16 December, 2004 ConocoPhillips Alaska, Inc. ConocoPhil//ps Western North Slope Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -94.40 0.00 0.00 N 0.00 E 5960080.61 N 550300.70 E 0.00 CB-GYRO-SS 78.00 0.250 289.000 -16.40 78.00 0.06N 0.16W 5960080.66 N 550300.54 E 0.321 0.01 170.00 1.350 7.000 75.59 169.99 1.20 N 0.22W 5960081.80 N 550300.47 E 1.436 1.10 262.00 3.100 20.000 167.52 261.92 4.61 N 0.76 E 5960085.23 N 550301.43 E 1.968 4.66 MWD+SAG 292.80 3.120 19.660 198.27 292.67 6.18 N 1.33 E 5960086.80 N 550301.99 E 0.088 6.32 386.66 6.480 27.020 291.79 386.19 13.31 N 4.60 E 5960093.95 N 550305.21 E 3.632 14.03 . 480.60 12.050 28.750 384.47 478.87 26.64 N 11.73 E 5960107.33 N 550312.25 E 5.936 28.72 534.00 13.000 30.000 436.60 531.00 36.73 N 17.41 E 5960117.45 N 550317.87 E 1.850 39.90 662.23 12.390 29.390 561.69 656.09 61.20 N 31.37 E 5960142.02 N 550331.66 E 0.487 67.08 755.02 13.990 29.650 652.03 746.43 79.63 N 41.81 E 5960160.51 N 550341.98 E 1.726 87.52 l 846.36 17 .370 31.150 739.96 834.36 100.90 N 54.33 E 5960181.87 N 550354.35 E 3.727 111.24 936.02 18.520 27.680 825.26 919.66 124.96 N 67.87 E 5960206.02 N 550367.73 E 1.751 137.91 1031.97 21.120 25.560 915.52 1009.92 154.06 N 82.41 E 5960235.21 N 550382.07 E 2.811 169.71 1130.86 25.900 26.920 1006.17 1100.57 189.41 N 99.88 E 5960270.68 N 550399.31 E 4.864 208.30 1222.91 28.290 25.600 1088.12 1182.52 227.01 N 118.41 E 5960308.41 N 550417.59 E 2.677 249.32 1316.64 31.290 23.260 1169.45 1263.85 269.41 N 137.63 E 5960350.94 N 550436.52 E 3.432 295.17 1407.98 36.310 24.330 1245.33 1339.73 315.88 N 158.15 E 5960397.54 N 550456.73 E 5.534 345.28 1498.13 42.670 25.850 1314.87 1409.27 367.75 N 182.49 E 5960449.57 N 550480.72 E 7.135 401.58 1593.41 45.460 23.960 1383.33 1477.73 427.85 N 210.37 E 5960509.86 N 550508.20 E 3.237 466.72 1685.39 48.810 22.650 1445.89 1540.29 489.76 N 237.01 E 5960571.95 N 550534.43 E 3.789 533.32 1777.64 52.490 20.880 1504.38 1598.78 556.01 N 263.43 E 5960638.37 N 550560.40 E 4.256 604.05 1870.42 51.830 21.500 1561.30 1655.70 624.32 N 289.91 E 5960706.86 N 550586.43 E 0.886 676.81 1959.50 51.080 20.970 1616.80 1711.20 689.26 N 315.15E 5960771.97 N 550611.23 E 0.962 745.98 2054.91 50.320 22.080 1677.24 1771.64 757.94 N 342.23 E 5960840.83 N 550637.85 E 1.202 819.24 . 2153.04 51.890 20.580 1738.85 1833.25 829.09 N 370.00 E 5960912.15 N 550665.14 E 1.994 895.05 2244.74 51.110 21.300 1795.94 1890.34 896.11 N 395.65 E 5960979.35 N 550690.34 E 1.049 966.35 2337.66 50.950 20.780 1854.37 1948.77 963.54 N 421.58 E 5961046.95 N 550715.82 E 0.468 1 038.11 2430.55 50.820 21.050 1912.98 2007.38 1030.86 N 447.31 E 5961114.44 N 550741.10 E 0.265 1109.71 2523.48 51.000 20.530 1971.57 2065.97 1098.29 N 472.91 E 5961182.04 N 550766.25 E 0.476 1181.39 2615.46 52.150 20.180 2028.74 2123.14 1165.85 N 497.98 E 5961249.77 N 550790.86 E 1.285 1253.06 2709.87 56.020 21.990 2084.11 2178.51 1237.16 N 525.50 E 5961321.26 N 550817.91 E 4.383 1328.98 2802.04 57.210 23.390 2134.83 2229.23 1308.16 N 555.20 E 5961392.46 N 550847.13 E 1.810 1405.13 2894.87 59.860 24.440 2183.28 2277.68 1380.53 N 587.30 E 5961465.04 N 550878.74 E 3.013 1483.21 2987.40 59.470 23.480 2230.01 2324.41 1453.51 N 619.73 E 5961538.23 N 550910.69 E 0.990 1561.96 3081.34 64.190 22.850 2274.35 2368.75 1529.63 N 652.29 E 5961614.57 N 550942.74 E 5.059 1643.79 18 January, 2005 - 16:02 Page 2 of5 Dril/Quest 3.03.06.008 .- - - - - - - - - -. -. -' - _1 - _1 -' ~ -: Halliburton Sperry-Sun Survey Report for 1E-102PB1 Your Ref: API 500292323670 Job No. AKMW3431828, Surveyed: 16 December, 2004 ConocoPhillips Alaska, Inc. ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 3144.72 66.370 21.290 2300.85 2395.25 1582.98 N 673.91 E 5961668.06 N 550964.00 E 4.102 1700.84 3298.50 66.200 21.820 2362.70 2457.10 1713.92 N 725.64 E 5961799.35 N 551014.85 E 0.334 1840.54 3393.67 64.340 23.520 2402.52 2496.92 1793.68 N 758.94 E 5961879.33 N 551047.62 E 2.540 1926.07 3488.03 63.620 24.080 2443.91 2538.31 1871.27 N 793.16 E 5961957.15 N 551081.32 E 0.931 2009.73 3581.63 63.210 26.500 2485.80 2580.20 1946.94 N 828.91 E 5962033.06 N 551116.56E 2.353 2091.92 3674.41 62.720 26.880 2527.98 2622.38 2020.78 N 866.03 E 5962107.14 N 551153.18 E 0.642 2172.67 . 3767.26 62.180 27.980 2570.92 2665.32 2093.85 N 903.95 E 5962180.46 N 551190.61 E 1.201 2252.87 3861.92 61.740 28.900 2615.42 2709.82 2167.31 N 943.74 E 5962254.19 N 551229.91 E 0.976 2333.92 3955.79 61.340 29.980 2660.15 2754.55 2239.18 N 984.30 E 5962326.33 N 551269.99 E 1.098 2413.62 4047.65 61.190 31.010 2704.32 2798.72 2308.58 N 1025.17 E 5962396.00 N 551310.40 E 0.997 2491.01 , 4141.56 60.540 32.830 2750.04 2844.44 2378.21 N 1068.54 E 5962465.92 N 551353.29 E 1.829 2569.22 4234.33 60.260 33.850 2795.87 2890.27 2445.59 N 1112.87 E 5962533.60 N 551397.17 E 1.003 2645.52 4327.80 59.980 34.200 2842.43 2936.83 2512.76 N 1158.22 E 5962601.07 N 551442.07 E 0.442 2721.86 4418.94 59.470 34.520 2888.38 2982.78 2577.74 N 1202.64 E 5962666.34 N 551486.06 E 0.636 2795.84 4511.36 58.720 34.370 2935.85 3030.25 2643.13 N 1247.49 E 5962732.03 N 551530.47 E 0.823 2870.33 4601.59 60.640 31.240 2981.41 3075.81 2708.59 N 1289.66 E 5962797.78 N 551572.20 E 3.673 2944.22 4693.38 60.480 26.370 3026.54 3120.94 2778.61 N 1328.16 E 5962868.05 N 551610.23 E 4.623 3021.61 4787.18 61.730 20.390 3071.90 3166.30 2853.95 N 1360.71 E 5962943.60 N 551642.27 E 5.738 3102.68 4881.13 60.960 16.620 3116.96 3211.36 2932.10 N 1386.88 E 5963021.93 N 551667.92 E 3.615 3184.89 4977.00 63.940 13.240 3161.31 3255.71 3014.21 N 1408.74 E 5963104.19 N 551689.22 E 4.408 3269.86 5068.24 63.100 9.710 3202.00 3296.40 3094.23 N 1424.99 E 5963184.31 N 551704.94 E 3.583 3351.40 5161.89 61.440 9.310 3245.58 3339.98 3175.98 N 1438.69 E 5963266.15 N 551718.09 E 1.812 3433.99 . 5254.89 60.880 8.650 3290.44 3384.84 3256.45 N 1451.40E 5963346.70 N 551730.27 E 0.865 3515.09 5348.28 63.020 8.920 3334.35 3428.75 3337.89 N 1463.99 E 5963428.23 N 551742.31 E 2.306 3597.11 5443.84 64.960 11.160 3376.26 3470.66 3422.45 N 1478.97 E 5963512.88 N 551756.73 E 2.926 3682.73 5534.77 69.530 12.310 3411.42 3505.82 3504.52 N 1496.04 E 5963595.07 N 551773.24 E 5.159 3766.47 5628.05 74.200 13.560 3440.45 3534.85 3590.89 N 1515.89E 5963681.57 N 551792.51 E 5.166 3855.06 5724.20 74.120 13.050 3466.69 3561.09 3680.90 N 1537.18 E 5963771.72 N 551813.20 E 0.517 3947.54 5815.41 76.880 14.120 3489.53 3583.93 3766.73 N 1557.92 E 5963857.68 N 551833.37 E 3.232 4035.83 5908.60 76.110 14.170 3511.29 3605.69 3854.59 N 1580.06 E 5963945.69 N 551854.92 E 0.828 4126.44 6002.08 75.260 13.060 3534.40 3628.80 3942.62 N 1601.39 E 5964033.86 N 551875.66 E 1 .466 4217.01 6095.00 76.880 14.100 3556.77 3651.17 4030.28 N 1622.56 E 5964121.67 N 551896.25 E 2.054 4307.18 6188.38 78.930 14.350 3576.34 3670.74 4118.79 N 1645.00 E 5964210.32 N 551918.09 E 2.211 4398.48 6282.10 81.990 14.640 3591.87 3686.27 4208.26 N 1668.13 E 5964299.94 N 551940.62 E 3.279 4490.89 6374.12 84.630 14.960 3602.59 3696.99 4296.61 N 1691.48 E 5964388.45 N 551963.37 E 2.890 4582.28 18 January, 2005 - 16:02 Page 3 of5 DrillQuest 3.03.06.008 - - . . . - .. - . II. II. .. .' . . . . . - Halliburton Sperry-Sun Survey Report for 1E-102PB1 Your Ref: AP/ 500292323670 Job No. AKMW3431828, Surveyed: 16 December, 2004 ConocoPhillips Alaska, Inc. ConocoPhillips Western North Slope Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 6470.23 83.720 13.880 3612.34 3706.74 4389.21 N 1715.29 E 5964481.20 N 551986.56 E 1.465 4677.89 6530.69 84.550 14.860 3618.52 3712.92 4447.47 N 1730.21 E 5964539.56 N 552001.10 E 2.118 4738.03 6576.46 87.340 15.320 3621.76 3716.16 4491.55 N 1742.10 E 5964583.72 N 552012.69 E 6.178 4783.68 6670.00 90.790 13.960 3623.28 3717.68 4582.02 N 1765.73 E 5964674.35 N 552035.72 E 3.964 4877.19 6763.43 90.790 12.280 3621.99 3716.39 4673.00 N 1786.94 E 5964765.47 N 552056.31 E 1.798 4970.58 . 6856.68 91.960 10.850 3619.76 3714.16 4764.33 N 1805.63 E 5964856.92 N 552074.39 E 1.981 5063.69 6950.20 89.110 12.980 3618.88 3713.28 4855.81 N 1824.93 E 5964948.53 N 552093.08 E 3.804 5157.10 7045.72 89.940 15.130 3619.68 3714.08 4948.46 N 1848.13E 5965041 .34 N 552115.66 E 2.413 5252.61 7137.18 87.210 17.430 3621.95 3716.35 5036.22 N 1873.75 E 5965129.26 N 552140.69 E 3.902 5343.98 7232.96 88.570 14.280 3625.48 3719.88 5128.28 N 1899.90 E 59652;21.4~ N . 552166.22 E 3.580 5439.65 7324.81 88.750 14.350 3627.63 3722.03 5217.25 N 1922.60 E 5965310.61 N 552188.33 E 0.210 5531.47 7370.90 89.370 13.880 3628.38 3722.78 5261.94 N 1933.84 E 5965355.38 N 552199.27 E 1.688 5577.56 7417.41 90.550 13.820 3628.41 3722.81 5307.10 N 1944.97 E 5965400.61 N 552210.10 E 2.540 5624.06 7511.36 92.040 14.770 3626.29 3720.69 5398.11 N 1968.16E 5965491.78 N 552232.68 E 1.881 5717.98 7597.87 92.140 14.950 3623.14 3717.54 5481.67 N 1990.33 E 5965575.49 N 552254.29 E 0.238 5804.43 7691.22 92.940 13.430 3619.00 3713.40 5572.08 N 2013.19 E 5965666.05 N 552276.55 E 1.839 5897.69 7791.58 93.380 13.060 3613.47 3707.87 5669.63 N 2036.15 E 5965763.74 N 552298.85 E 0.572 5997.87 7882.26 93.020 11.910 3608.40 3702.80 5758.02 N 2055.73 E 5965852.26 N 552317.83 E 1.327 6088.36 7982.28 97.600 12.630 3599.15 3693.55 5855.31 N 2076.88 E 5965949.69 N 552338.34 E 4.635 6187.86 8048.00 97.600 12.630 3590.46 3684.86 5918.88 N 2091.13 E 5966013.35 N 552352.16 E 0.000 6252.97 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 14.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8048.00ft., The Bottom Hole Displacement is 6277.41ft., in the Direction of 19.458° (True). 18 January, 2005 - 16:02 Page 4 of 5 DrillQuest 3.03.06.008 - - - - ConocoPhillips Alaska, Inc. Western North Slope Comments Measured Depth (ft) 8048.00 3684.86 - - -------..... Halliburton Sperry-Sun Survey Report for 1E-102PB1 Your Ref: API 500292323670 Job No. AKMW3431828, Surveyed: 16 December, 2004 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5918.88 N 2091 .13 E Projected Survey Survey too/ørogram for 1E-102PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 262.00 18 January, 2005 -16:02 0.00 261.92 . To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 262.00 8048.00 261.92 CB-GYRO-SS 3684.86 MWD+SAG Page 50f5 - -- ConocoPhillips . . DrillQuest 3.03.06.008 ....--------------- DEFINITIVE Halliburton Sperry-Sun Western North Slope ConocoPhillips 1E-102PB2 . Job No. AKMW3431828, Surveyed: 21 December, 2004 Survey Report 18 January, 2005 Your Ref: API 500292323671 Suñace Coordinates: 5960080.61 N, 550300.70 E (70018' 06.14568 N, 149035' 33.306r W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 94.40ft above Mean Sea Level . !5pt!!!............y-SUF1 CRIL.L.ING SeRVIC:~S A Halliburton Company Survey Ref: svy2089 -. . . . '.".'t""t- _a__&- .-, , .., ",- Halliburton Sperry-Sun Survey Report for 1E-102PB2 Your Ref: AP/ 500292323671 Job No. AKMW3431828, Surveyed: 21 December, 2004 ConocoPhillips Alaska, Inc. ConocoPhillips Western North Slope Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 6670.00 90.790 13.960 3623.28 3717.68 4582.02 N 1765.73 E 5964674.35 N 552035.72 E 4877.19 Tie On Point 6757.00 90.790 12.400 3622.08 3716.48 4666.72 N 1785.57 E 5964759.18 N 552054.99 E 1.793 4964.16 Window Point 6829.43 85.670 13.520 3624.32 3718.72 4737.25 N 1801.80 E 5964829.81 N 552070.74 E 7.236 5036.51 6857.16 87.950 14.230 3625.86 3720.26 4764.12 N 1808.44 E 5964856.73 N 552077.20 E 8.610 5064.19 . 6906.56 87.820 13.140 3627.69 3722.09 4812.09 N 1820.11 E 5964904.77 N 552088.56 E 2.221 5113.55 6949.47 88.500 13.240 3629.06 3723.46 4853.84 N 1829.90 E 5964946.60 N 552098.07 E 1.602 5156.43 7044.04 88.000 11.790 3631.95 3726.35 4946.12 N 1850.38 E 5965039.01 N 552117.93 E 1.621 5250.90 7090.32 87.690 11.370 3633.69 3728.09 4991.43 N 1859.67 E 5965084.37 N 552126.91 E 1.127 5297.09 7135.61 88.270 11.310 . 3635.29 3729.69 5035.80 N 1868.57 E 59651;28.81 N . 552135.51 E 1.287 5342.29 7229.83 91.220 11.440 3635.71 3730.11 5128.16 N 1887.15 E 5965221.29 N 552153.47 E 3.134 5436.37 7323.76 89.370 13.290 3635.22 3729.62 5219.90 N 1907.26 E 5965313.17 N 552172.97 E 2.785 5530.23 7358.93 89.110 13.070 3635.69 3730.09 5254.15 N 1915.28 E 5965347.46 N 552180.76 E 0.968 5565.39 7416.14 88.490 14.010 3636.89 3731.29 5309.75 N 1928.67 E 5965403.15 N 552193.78 E 1.968 5622.58 7509.65 88.500 14.300 3639.34 3733.74 5400.39 N 1951.53E 5965493.95 N 552216.03 E 0.310 5716.05 7602.75 88.250 13.240 3641.99 3736.39 5490.78 N 1973.68 E 5965584.48 N 552237.58 E 1.169 5809.11 7697.91 90.390 15.110 3643.11 3737.51 5583.02 N 1996.98 E 5965676.88 N 552260.26 E 2.986 5904.25 7793.34 89.990 14.310 3642.80 3737.20 5675.33 N 2021.21 E 5965769.34 N 552283.87 E 0.937 5999.68 7884.82 89.990 12.760 3642.81 3737.21 5764.26 N 2042.62 E 5965858.42 N 552304.69 E 1.694 6091.15 7981.51 90.430 14.150 3642.46 3736.86 5858.29 N 2065.12 E 5965952.60 N 552326.55 E 1.508 6187.82 8081.03 90.440 15.120 3641.70 3736.10 5954.58 N 2090.26 E 5966049.05 N 552351.05 E 0.975 6287.33 8176.18 90.160 15.360 3641.21 3735.61 6046.38 N 2115.27 E 5966141.02 N 552375.45 E 0.388 6382.47 . 8272.69 91.410 14.500 3639.88 3734.28 6139.62 N 2140.13E 5966234.42 N 552399.68 E 1.572 6478.97 8370.01 90.660 15.400 3638.13 3732.53 6233.63 N 2165.24 E 5966.328.60 N 552424.16 E 1.204 6576.27 8455.90 90.910 15.480 3636.95 3731.35 6316.42 N 2188.10E 5966411 .53 N 552446.47 E 0.306 6662.13 8560.57 89.180 15.100 3636.87 3731.27 6417.38 N 2215.70 E 5966512.68 N 552473.39 E 1.692 6766.79 8657.01 90.110 14.330 3637.46 3731.86 6510.65 N 2240.20 E 5966606.11 N 552497.26 E 1.252 6863.22 8753.70 88.680 14.060 3638.49 3732.89 6604.38 N 2263.91 E 5966700.00 N 552520.34 E 1.505 6959.90 8851.11 89.000 12.620 3640.46 3734.86 6699.14 N 2286.38 E 5966794.91 N 552542.18 E 1.514 7057.27 8946.90 89.200 11 .400 3641.96 3736.36 6792.82 N 2306.30 E 5966888.72 N 552561.48 E 1.290 7152.97 9044.01 90.180 13.100 3642.49 3736.89 6887.71 N 2326.91 E 5966983.75 N 552581.45 E 2.021 7250.00 9141.37 89.590 13.210 3642.68 3737.08 6982.52 N 2349.07 E 5967078.70 N 552602.97 E 0.616 7347.34 9237.42 89.590 12.850 3643.37 3737.77 7076.09 N 2370.72 E 5967172.41 N 552624.00 E 0.375 7443.36 9336.94 90.060 11.900 3643.67 3738.07 7173.30 N 2392.05 E 5967269.76 N 552644.67 E 1.065 7542.81 9433.92 91.290 13.580 3642.53 3736.93 7267.88 N 2413.43 E 5967364.48 N 552665.42 E 2.147 7639.74 9530.20 91.340 12.600 3640.32 3734.72 7361.63 N 2435.23 E 5967458.38 N 552686.59 E 1.019 7735.97 18 January, 2005 -16:03 Page 20f4 DrillQuest 3.03.06.008 .' . . . ..-~ . -..- Halliburton Sperry-Sun Survey Report for 1E·102PB2 Your Ref: AP/ 500292323671 Job No. AKMW3431828, Surveyed: 21 December, 2004 ConocoPhillips Alaska, Inc. ConocoPhi/lips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9626.74 90.170 12.980 3639.05 3733.45 7455.77 N 2456.60 E 5967552.65 N 552707.33 E 1.274 7832.46 9723.23 90.300 14.050 3638.65 3733.05 7549.58 N 2479.15 E 5967646.62 N 552729.25 E 1.117 7928.94 9820.48 90.790 14.010 3637.73 3732.13 7643.93 N 2502.73 E 5967741.12 N 552752.20 E 0.506 8026.18 9917.61 89.550 12.350 3637.44 3731.84 7738.49 N 2524.87 E 5967835.83 N 552773.71 E 2.133 8123.28 . 10014.28 88.810 9.810 3638.82 3733.22 7833.34 N 2543.45 E 5967930.80 N 552791.65 E 2.736 8219.77 10108.23 88.960 9.160 3640.65 3735.05 7925.99 N 2558.92 E 5968023.55 N 552806.51 E 0.710 8313.36 10206.34 90.250 8.300 3641.33 3735.73 8022.96 N 2573.82 E 5968120.62 N 552820.75 E 1.580 8410.98 10302.86 90.250 8.360 3640.91 3735.31 8118.46 N 2587.80 E 5968216.21 N 552834.09 E 0.062 8506.96 10397.37 91.410 8.500 . 3639.54 3733.94 8211.94 N 2601.65 E 59683Q9.78 N . 552847.32 E 1.236 8600.95 10495.04 90.230 8.200 3638.14 3732.54 8308.56 N 2615.83 E 5968406.49 N 552860.85 E 1.247 8698.06 10589.95 90.530 7.250 3637.51 3731.91 8402.60 N 2628.59 E 5968500.62 N 552872.98 E 1.050 8792.32 10691.57 92.200 8.560 3635.09 3729.49 8503.22 N 2642.56 E 5968601.33 N 552886.28 E 2.088 8893.26 10786.83 91.800 8.280 3631.77 3726.17 8597.40 N 2656.50 E 5968695.60 N 552899.59 E 0.512 8987.94 10882.62 89.940 8.090 3630.31 3724.71 8692.20 N 2670.14 E 5968790.49 N 552912.59 E 1.952 9083.15 10981.88 90.170 6.260 3630.22 3724.62 8790.68 N 2682.53 E 5968889.05 N 552924.32 E 1.858 9181.62 11078.64 91.110 5.850 3629.14 3723.54 8886.89 N 2692.74 E 5968985.33 N 552933.89 E 1.060 9277.35 11175.38 91.070 5.370 3627.30 3721.70 8983.15 N 2702.20 E 5969081.65 N 552942.70 E 0.498 9372.94 11272.10 91.470 5.600 3625.15 3719.55 9079.40 N 2711.44 E 5969177.96 N 552951.29 E 0.477 9468.46 11366.13 91.730 6.390 3622.53 3716.93 9172.88 N 2721.25 E 5969271.50 N 552960.49 E 0.884 9561.45 11461.09 91.780 6.690 3619.62 3714.02 9267.18 N 2732.07 E 5969365.87 N 552970.66 E 0.320 9655.47 11496.13 92.030 6.740 3618.45 3712.85 9301.96 N 2736.16 E 5969400.68 N 552974.53 E 0.728 9690.18 . 11587.31 91.650 7.690 3615.53 3709.93 9392.37 N 2747.61 E 5969491.16 N 552985.37 E 1.122 9780.59 11677.08 91.590 7.080 3612.99 3707.39 9481.36 N 2759.14 E 5969580.23 N 552996.30 E 0.683 9869.65 11769.26 91.030 8.960 3610.88 3705.28 9572.61 N 2772.00 E 5969671.56 N 553008.55 E 2.128 9961.23 11860.60 90.950 9.370 3609.30 3703.70 9662.77 N 2786.54 E 5969761.82 N 553022.49 E 0.457 10052.18 11952.50 89.630 8.390 3608.84 3703.24 9753.56 N 2800.73 E 5969852.70 N 553036.07 E 1.789 10143.65 12042.98 89.750 7.720 3609.33 3703.73 9843.15 N 2813.41 E 5969942.37 N 553048.15 E 0.752 10233.57 12131.21 90.110 6.900 3609.43 3703.83 9930.66 N 2824.63 E 5970029.96 N 553058.79 E 1.015 10321.13 12228.00 91.040 7.860 3608.46 3702.86 10026.64 N 2837.06 E 5970126.02 N 553070.58 E 1.381 10417.18 12324.96 92.160 8.530 3605.76 3700.16 10122.57 N 2850.88 E 5970222.04 N 553083.75 E 1.346 10513.54 12421.22 92.530 6.900 3601.82 3696.22 10217.88 N 2863.79 E 5970317.43 N 553096.02 E 1.735 10609.06 12518.09 93.360 7.210 3596.84 3691.24 10313.89 N 2875.67 E 5970413.52 N 553107.26 E 0.914 10705.01 12603.53 92.950 6.870 3592.14 3686.54 10398.55 N 2886.13 E 5970498.25 N 553117.15 E 0.623 10789.61 12708.85 93.840 8.430 3585.90 3680.30 10502.75 N 2900.12 E 5970602.54 N 553130.45E 1.703 10894.02 12804.95 94.160 9.530 3579.20 3673.60 10597.44 N 2915.09 E 5970697.32 N 553144.78 E 1.189 10989.45 18 January, 2005·16:03 Page 3 of 4· Dri/lQuest 3.03.06.008 ~'- - - - - - - -~ -, - ~ Halliburton Sperry-Sun Survey Report for 1E-102PB2 Your Ref: API 500292323671 Job No. AKMW3431828, Surveyed: 21 December, 2004 ConocoPhil/ips Alaska, Inc. Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12858.09 95.020 10.060 3574.94 3669.34 10649.63 N 2924.10 E 5970749.58 N 553153.44 E 12901.00 95.020 10.060 3571.19 3665.59 10691.72N 2931.56 E 5970791.72 N 553160.62 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 14.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12901.000., The Bottom Hole Displacement is 11Q86.34ft., in the Direction of 15.333° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6670.00 6757.00 12901.00 3717.68 3716.48 3665.59 4582.02 N 4666.72 N 10691.72 N 1765.73 E 1785.57 E 2931.56 E Tie On Point Window Point Projected Survey Survey too/prOf/ram for 1E-102PB2 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 262.00 0.00 262.00 261.92 12901.00 261.92 CB-GYRO-SS (1E-102PB1) 3665.59 MWD+SAG (1E-102PB1) 18 January, 2005 -16:03 Page 4 of4 ConocoPhillips Dogleg Vertical Rate Section Comment (O/100ft) 1.899 11042.25 0.000 11084.87 Projected Survey . . DrillQuest 3.03.06.008 ---,.-----... . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 1 E-102 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,603.53' MD 12,630.00' MD 14,360.00' MD (if applicable) 01-Feb-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 3l;J,) (\ G \ III / If/ Signed ~ ¿)¡JJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ f0Y-À:S / . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1E-102 (nonSag) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,603.53' MD 12,630.00' MD 14,360.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ."~ )~~) «''\ Y- Signed I Ii .~~ o/;Itj ( Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 01-Feb-05 ,:{ (J L/--2]'/ . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-102 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,048.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date J ~À G ~r- t· 1 (/JJ c/ I 11 Signed ~. . Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 01-Feb-05 ~OY-2~ l . . 01-Feb-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-1 02 PB1 (nonSag) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,048.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date J l7 j} ;z.C)(jf Signed ',Ll 6/LJ I Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) ~(jtf- )31 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 1 E-102 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,670.00' MD 6,757.00' MD 12,901.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date .~ F-~;. ()~ r Signed ¡;)J I ~ ()/JvJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 01-Feb-05 ~cs vl-)) f . . 01-Feb-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-1 02 PB2 (non Sag) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,670.00' MD 6,757.00' MD 12,901.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Jç::~\--~ ~ g Signed /J! t1 0/1 1 ~... L ij/Jv-dl Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) ~Ol/-2J( . . 2-tJ '-1- 23/ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 20, 2005 RE: MWD Formation Evaluation Logs 1E-102 PB1, AK-MW-3431828 1 LDWG formatted Disc with verification listing. API#: 50-029-23236-70 PLEASE ACKNOWLEDGE RECEIYf BY SIGNING AND RETURNING A COPY OF THE TRANSMITIAL LETTER TO THE ATTENTION OF: Sperry -Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~f~ e?!k~ . . ~or -23 I WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 20, 2005 RE: MWD Formation Evaluation Logs lE-102 PB2, AK-MW-3431828 1 LDWG formatted Disc with verification listing. API#: 50-029-23236-71 IJLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMIITAL LEITER TO THE A TfENTION OF: Sperry -Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: if? ¡., ç sign4Jf~ Schlumbergep NO. 3313 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1/19/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: . Well Job # Log Description Date BL /'io-I&:'7 1A-25 10942816 PRODUCTION PROFILE/DEFT 12/25/04 1 I ~-f)l{Cf1D-10 10942818 LDL & MUL TIFINGER CALIPER 12/27/04 1 2O'I..tfrf 1E-112 10715441 MPSP PRODUCTION PROFILE 11/12/04 1 JOI.../:!!11C-119 10942819 INJECTION PROFILE 12/28/04 1 :1.04-1..2. ~ 1E-104 10942821 PERF RECORD W/SBHP 12/30/04 1 fjh-/Z"i' 2T-12A 10922519 PRODUCTION PROFILEIDEFT 01/03/05 1 ,%04_¡:z..1 1E-104 10942821 SCMT 12/29/04 2-"'/-2.) 11E-102 10942815 USIT 12/24/04 . SIGNED: .!J~~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD 1 1 1-(9- tJ5 , . ~~~~E [ffi} ~~!Æ~~~ . }t I,ASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-102 ConocoPhillips Alaska, Inc. Permit No: 204-231 Surface Location: 4789' FNL, 223' FEL, SEe. 16, TIIN, RI0E, UM Bottomhole Location: 3207' FNL, 2359' FEL, SEC. 3, TIIN, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincere ø anie] T. Seamount, Jr. Commission DA TED thi1i- day of month, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. conoc~hillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com r- ~,.., ~ ~\ November lOth, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 k~f{~";'· Re: Applications for Permit to Drill, West Sak Injector, lE-I02,lE-I02 Ll Dear Commissioners: , ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for a pre-produced onshore injection well, a dual lateral horizontal well in the West Sak "B" and "D" sands. The main bore of the well will be designated lE-102, and the lateral bore ofthe well will be designated lE-I02Ll. / Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date oflE-102 is December 10,2004. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, ~-'-~ Randy Thomas Greater Kuparuk Area Drilling Team Leader OR\G\NAL . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . J,IJ It<( 1a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: RedrillU 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 4789' FNL, 223' FEL, Sec. 16, T11 N, R10E, UM Top of Productive Horizon: 974' FNL, 3924' FEL, Sec. 15, T11 N, R10E, UM Total Depth: 3207' FNL, 2359' FEL, Sec. 3, T11 N, R10E, UM / 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301' y- 5960081 16. Deviated wells: Kickoff depth: 400 It. Maximum Hole Angle: 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling 42" 20" x 34" 94# K-55 Welded 13.5" 10.75" 45.5# L-80 BTC 9-7/8" 7-5/8" 29.7# L-80 BTCM 6.75" 4.5" 12.6# L-80 IBTM 19 Total Depth MD (It): PERMIT TO DRILL 20 AAC 25.005 ExploratoryU Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-102 6. Proposed Depth: 12. Field/Pool(s): MD: 14377' / TVD: 3703' . Kuparuk River Field 7. Property Designation: / ADL 25651 & 25648 8. Land Use Permit: West Sak Pool 13. Approximate Spud Date: 12/10/2004 ALK 469 & 466 9. Acres in Property: 2560 14. Distance to Nearest Property: 6636' 10. KB Elevation 15. Distance to Nearest Zone- 4 Well within Pool: 1E-19 ,20' @ 450' (Height above GL): 28 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) 90° Downhole: 1582 psig Surface: 1160 psig Setting Depth Quantity of Cement Top Bottom c. f. or sacks Length MD TVD MD TVD (including stage data) 80' 28' 28' 108' 80' 260 cf ArcticCrete 3179' 28' 28' 3179' 2409' 535 sx ASLite, 212 sx DeepCrete 6600' 28' 28' 6500' 3696' 336 sx DeepCrete 7877' 6500' 3696' 14377' 3703' slotted liner PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (It): Length Size 20. Attachments: Filing Fee 0 Property Plat 0 BOP Sketch ~ Diverter Sketch 0 21. Verbal Approval: Commission Representative: (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD " , . "!.c J ) ::'004 ·'~7.. ,.... ..... ...":>Þ='I.~~~ perfOration Depth TVD (It): Drilling Program 0 Timev. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: ~.'/'-""":f' Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas '~. ' \ \ \.ç~ Commission Use Only Permit to Drill. ..._11, . I API Number: I Permit Approval I ~ i I see cover letter Number. .,.L.{./"T'- 23 I 50- 62.'7-2..3.2:3 G ÖÖ Date: / II g' L¡ for other requirements Conditions of approval: Samples required 0 Yes ~NO Mud log required 0 Yes ~ No Hydrogen sulfide measures 0 Yes "~ No Directional survey required ~ Yes 0 No Other: 3(JeJC) r' ~\>-\:~"S> \.-"o...c:.,. \> \o...~",~d, .'6\)\? -\esA\ K.~N Ct. \ 1- \ L.\~ 'f ~/ \-\ \ W c..1t.~r...:\ ~V'-',\~ \~, "I~\~\-\~"t)~~\-\o,,~ ,,, o.c-CC~ "'" I ~\a do\'), Original Signed By BY ORDER OF I I ~ ~/ I Approved by: nAN $I=~UNT THE COMMISSION Date:, I / 0 ¡v l Signature Form 10-401 Revised 12/2003 Contact Mike Greener @ 263-4820 Title Kuparuk Drilling Team Leader Phone 26 S 6. ~ ">0 Date 'II (( i (0« PreDared bv Sharon Al/suD-Drake Submit in Duplicate · .Plication for Permit to Drill, Well 1 E-1 02 Revision No.O Saved: 10-Nov-04 Permit It - West Sak Well #1 E-1 02 Application for Permit to Drill Document M 0):0: ï m i z E! W~II I/QI\l1i! Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ......... ....... ....... .............. ............. ...... ....... .... ... .... ....... .... .......... ..... 2 2. Location Summary....... ............. ........ ....... .................................................................... 2 Requirements of 20 AAC 25.005(c){2) ... ........ ........ ... ........ ..................... ......... ................... .......... ....... 2 Requirements of 20 AAC 25.050(b) ......... ....... .............. ...... .............. ..... ....... .... ............... ......... .... ...... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c){3) ... ....... ........ ............. ........ .......... ............ ...... ....... ..... ......... ........ 3 4. Drilli ng Hazards Information ............... ........... .......................... ........ .................. ........ 3 Requirements of 20 AAC 25.005 (c){ 4) . ...... ....... ...... ....... ........ ..... ....... ....... ..... ............. ...... ........ ......... 3 5. Procedure for Conducting Formation Integrity Tests.............................................4 Requirements of 20 AA C 25.005 (c){5) ..... ........................... ............ ....... ............. ...... ....... ..... ........ ..... 4 6. Casing and Cementing Program................................................................................4 Requirements of 20 AAC 25.005(c){6) ..... ....... ...... ..... ... ............ ...... .............. ..... ............. ..... ............... 4 7. Diverter System Information ......................................................................................4 Requirements of 20 AAC 25. 005(c){7) ................................................................................................4 8. D ri II i ng Flu id Prog ram................................................................................................. 4 Requirements of 20 AAC 25.005(c){B) ......... ............ ........ .......... ......... ....... ........... ............. .... ............. 4 Surface Hole Mud Program (extended bentonite)...... ........ ........ .... ........ ...... ............ ........... ......... ........ 5 Intermediate Hole Mud Program (extended bentonite) ........................................................................5 Lateral Mud Program (MI FloPro NT) ......... ...... .............. ............. ...... .......................... ...... ..... ............. 5 9. Abnormally Pressured Formation Information ........................................................ 5 Requirements of 20 AAC 25.005 (c){9) .... ...... ........ ................................. ...... .... .............. ..... ............... 5 10. Seismic Analysis .... ............................. ....... ............................................................. ..... 5 Requirements of 20 AAC 25.005 (c){10) .............................................................................................5 11. Seabed Condition Analysis...... ................. ....... .......................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................. ........ ........ .... ....... ........ ..... ....... ...... ...... ........ ......... 6 1E-102 PERMIT /T.doc Page 10f8 Printed: 10-Nov-04 · .PliCatiOn for Permit to Drill, Well 1 E-1 02 Revision No.O Saved: 10-Nov-04 12. Evidence of Bonding ........................ ....... .................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ..... .............. ....... ........ .... ....... ........ ........... ....... ..... ......... ........ 6 13. Proposed Dri lIing Program ...... ................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) .............................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................ 7 Requirements of 20 AAC 25.005 (c)(14) ........ ...... .......... .... ....... ............ ........ .... ....... ....... ...... ......... ..... 7 15. Attach me nts.................................................................................................................. 8 Attachment 1 Directional Plan (14 pages) ......... ..... ............. ........ ..... ...... ............. ...... ............... ..... ...... 8 Attachment 2 Drilling Hazards Summary (1 page).. ....... ................... ...... ............ ........ ...... .............. ..... 8 Attachment 3 Cement Loads and CemCADE Summary (2 pagse) .....................................................8 Attachment 4 Well Schematic (1 pages).... ...... ....... ...... ............... ..... ..... ............. ........ ............. ....... .... 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-102. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 51960,081 Eastings: 550,301 ¡" 4,7891 FNL, 223' FEL, Section 16, TllN, R10E I RKB Elevation I 94.11 AMSL Pad Elevation 66.11 AMSL Location at Top of Productive Interval (West Sak "8" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,964,496 Eastings: 551,992 974' FNL, 3,924' FEL, Section 15, TllN, RlOE Measured Depth/ RKB: Total Vertical Depth RKB: Total Vertical Depth 55: 6,500 3,696 3,602 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,972,243 Eastings: 5531338 3,207' FNL, 2,3591 FEL, Section 3, TllN, RlOE Measured Depth RKB: 14,377 Total Vertical Depth/ RKB: 3,703 Total Vertical Depth 55: 3,609 <' f) ~., t ~ .~. ~ t~ 'i~< ~\""1.J 1E-102 PERMIT IT. doc Page 2 of 8 Printed: 10-Nov-04 · .Plication for Permit to Drill, Well 1 E-1 02 Revision No.O Saved: 10-Nov-04 and (D) other information required by 20 MC 25. 050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate~ the application for a Permit to Drill (Form 10-401) must (1) include a pla~ drawn to a suitable scale, showing the path ofthe proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed we/~· Please see Attachment 1: Directional Plan .,. and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mai~· or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (3) a diagram and description of the blowout prevention equipment (80PE) as required by 20 MC 25.035, 20 AAC 25.036, or 20 MC 25.037, as applicable; An API 13-5/811 x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-102. For all operations the stack will be equipped with 3-1/211 to 61' variable bore rams in the uppermost ram cavity, blind rams in the middle cavityl and 7-5/81' rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 31000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to - running the intermediate string of 7-5/811 casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 31000 psi on a 7-5/811 00. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dr/II must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine i~ and maximum potential surface pressure based on a methane gradien~' The expected reservoir pressures in the West Sak sands in the 1E-102 area vary from 0.43 to 0.45 psi/ft, or 8.3 to 8.6 ppg EMW (equivalent mud weight). ./ The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand formation is 1,160 psi, calculated thusly: MPSP =(3,516 ft)(0.45 - 0.11 psi/ft) =1,160 psi " (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and r, J k' . ð '\ ~ í !'..... 1E-102 PERM/T /T.doc Page 3 of 8 Printed: 10-Nov-04 · .Plication for Permit to Drill, We1l1E-102 Revision No.O Saved: 10-Nov-04 (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: lE-102 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. OJO(f); lE-102 will be completed with 7-5/8" casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConcocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; I Casing and Cementing Program See also Attachment 3: Cement Summary Ho/e Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD 00 (in) (in) t (/b/ft) Grade Connection (fl) (fl) (fl) Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 80 / 80 Cemented to surface with 260 cf ArcticCRETE 10-3/4 13-1/2 45.5 L-80 BTC 3,179 28 / 28 2,179/1,847 Cemented to Surface with special 2,179/ 1,847 3,179/ 2,409 535 sx AS Lite Lead, drift 212 sx DeepCRETE Tail 7-5/8 9-7/8 29.7 L-80 BTCM 6600 28 / 28 6,500/ 3,696 Cement Top planned @ 3,743' MD / 2,672' WD. Cemented w/ 336 sx DeepCRETE 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 71877 6,500/ 3,696 14,377/31703 Slotted- no cement slotted Lateral (lE-102) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 81434 5,938/3,619 14,372 /3,641 Slotted- no cement slotted Lateral (lE-102 Ll) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lE-I02. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: r) t r'\, ~ 1\' ,A I H \0" 'M~ 1E-102 PERMIT /T.doc Page 4 of 8 Printed: 10-Nov-04 · Suñace Hole Mud Program (extended bentonite) Spud to Base of Permafrost Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (1b/1 00 sf) pH API Filtrate (cc / 30 min)) Initial Value 8.9 150 50-70 20-45 8.5-9.0 NC-8.0 *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4" Casing Shoe to 7-5/8" Casing Point Initial Value Density (ppg) 9.0-9.1 Funnel Viscosity 45-60 (seconds) Plastic Viscostiy 12-18 (lb1100 sf) Yield Point 26- 35 (cP) API Filtrate 4-6 (cc I 30 min)) Chlorides (mgll) <500 pH 9.0-9.5 MBT <20.0 Final Value 9.2 250 50-70 20-45 8.5-9.0 NC-8.0 epPlication for Permit to Drill, Well 1 E-102 Revision No.O Saved: 10-Nov-04 Base of Permafrost to 10-3/4" Casing Point Initial Value Final Value 9.5 200 30-50 15-20 8.5-9.0 5.0-7.0 9.6 300 30-50 15-20 8.5-9.0 5.0-7.0 ,/ Lateral Mud Program (MI VersaPro Mineral Oil Base) BID sand laterals Density (ppg) Plastic Viscostiy (lb1100 sf) Yield Point (cP) Value 9.0 15-25 18-28 HTHP Fluid loss (m1130 min @ 200psi & 1500 Oil I Water Ratio Electrical Stability <4.0 70 / 30 >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. ,/ 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflection analysis as required by 20 AAC 25. 061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. ~ t,,, 1E-102 PERMIT IT. doc Page 5 of 8 Printed: 10-Nov-04 · epPlication for Permit to Drill, Well 1 E-102 Revision No.O Saved: 10-Nov-04 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offShore platform, mobile bottom-founded structure, jack-up ria or floating drilling vesse~ an analysis of seabed conditions as required by 20 AAC 25.061(b)/ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25. 025 {Bonding}have been met,· Evidence of bonding for ConocoPhillips Alaskal Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified In the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 20'l x 34lT insulated conductor to +/- 1081 RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4lT Annular with 1611 diverter line and function test. 3. Spud and directionally drill 13-1/2lT hole to casing point at +/- 3,180' MD / 2,4091TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 1O-3/4'l, 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8lT x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. 6. PU 9-7/8lT bit and 6-1/4lT drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8lT casing point at 6,500 MD / 3,6961 TVDl the prognosed top of the B sand. 9. Run 7-5/8lTl 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 41300 MD /3088 TVD if Ugnu formation is not oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand if Ugnu is oil bearing.)) and pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8lT packoff and test to 5000 psi. 11. Flush 10-3/4lT x 7-5/8'l annulus with water, followed by diesel. 12. PU 6-3/4lT PDC Bit and 4-3/4lT drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar / 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4lT lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4'l hole to TD at +/- 14,377' MD / 3,703' TVD as per directional plan. 1\ ~ f-~ ' .{ \ ,~~ 1E-102 PERMIT IT.doc Page 6 of 8 Printed: 10-Nov-04 · epPliCatiOn for Permit to Drill, Well 1 E-1 02 Revision No.O Saved: 10-Nov-04 15. POOH, back reaming out of lateral. POOH. 16. Run USIT log for cement bond. 17. PU and run 4-1/2" slotted liner. 18. Land liner, set liner hanger @ +1- 5,800' MD 1 3,590'. POOH. Note: Remaining operations are covered under the 1E-102L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 5,938' MD 1 3,620' TVD, the top v of the D sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 14,372' MD 13,6411 TVD, as per directional plan. 23. POOH, back reaming out of lateral. POOH. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2'l slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation 1 re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 29. POOH, laying down drill pipe as required. 30. PU injection as required and RIH to depth. Land tubing. Set BPV. 31. Nipple down BOPE, nipple up tree and test. Pull BPV. 32. Freeze protect well with diesel by pumping into 4-1/2'l x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 33. Set BPV and move rig off. 34. Rig up wire line unit. Pull BPV. 35. Set gas lift valves in mandrels. Operate well on gas lift for +1- 180 days. Shut well in. 36. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids v into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substancesl and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ~hl·AI ( r\\ , " "" ~., . t;1 t ~.t; , ~ 1E-102 PERMIT IT. doc Page 7 of 8 Printed: 10-Nov-04 · epPlication for Permit to Drill, Well 1 E-1 02 Revision No.O Saved: 10-Nov-04 ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Doyon 141 West Sak 2004 3ksi BOP Configuration (1 page) Attachment 2 Directional Plan (18 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Cement Loads and CemCADE Summary (2 pages) Attachment 5 Well Schematic (1 page) ()f~~ I ~.Il\ L t. ;' ~ Ð .. 1E-102 PERMIT IT.doc Page 8 of 8 Printed: 10-Nov-04 . . ~ z z ~ ~ cL Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular __________ To be tested to 250 psi and 1,500 psi at initial ..------- installation and every 14 days thereafter. ~ 5 13-5 Double Ram Upper Rams: 3-W' to 6" variables To be tested to 250 psi and 3,000 psi at initial ~ ? installation and every 14 days thereafter. C ~ ? Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ..--- To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. ~ ? ~ 13-5 Single Ram ..J L Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly ~ y ConocoPhillips Alaska Doyon 141 West Sak 3 ksi BOP Configuration OO~li{Àff- - 0 RIG I ~,' :A 13-5 BOP 3K diagram.vsd Sheet 1 of 1 prepared by Steve McKeever 8/1112004 . . ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E-1 02 BLat eonocÓPhillips Plan: Plan 1 E-102 B Lat(wp05) Standard Planning Report 08 November, 2004 tìR¡lhl V~~tJä I iln- Kuparuk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Elliptical Conic Error Surface: Rules Based Warning Method: Trav. Cylinder North -....-- 12500 11250 1 oooo---~~-- 8750 7500 0 0 l{) ~ + 6250-- £' 0 z >.. . 5000 :;:: ::; 0 (f) 3750 2500 1250-=::.-::c _ 0--";"';;' I I I ¡ I -6250 WA!';t(-)/Fn!';t(+) (;?i'iOO ft/in) SECTION DETAILS I I Uli Engineering Error System: Calculation Method: Scan Method: Error Surface: Warning Method: Kuparuk Minimum Curvature ISCWSA Trav. Cylinder North Elliptical Conic Rules Based - 28 0 400 0 -"'-- 1500 I I 7-5/8" Gsg pt ... Begin 6-3/4" hole: 6500ft, 3696ft -- Continue Dk , ¡ , , , , I, , , , ¡ , , , , ¡ , , , , I, , , , ¡ , J 'J 'J 5250 6000 6750 7500 8250 9000 10500 11250 12750 5250 4500 . Co~illips Database: Company: Project: Site: Well: Wellbore: Design: Project Map System: Geo Datum: Map Zone: Site Site Position: From: Position Uncertainty: Well Well Position +N/-S +E/-W Position Uncertainty Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 11/10/200410:53:46AM EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-102 Plan 1E-102 BLat Plan 1E-102 Blat (wp05) . SPERRY_SUN HES Planning Report Well Plan 1E-102 1E-102 @ 94.1000 (28' above WRP) 1E-102 @ 94.1000 (28' above WRP) True Minimum Curvature Kuparuk River Unit, North Slope Alaska, United States US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 Kuparuk 1 E Pad Map O.ooOft --- Plan 1E-102 O.OOOft O.Oooft O.ooOft Plan 1E-102 BLat Model Name BGGM2004 Plan 1E-102 Blat (wp05) Northing: Easting: Slot Radius: System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,959,760.240ft 549,889.51 Oft 0" Latitude: Longitude: Grid Convergence: ~-~-~ 5,960,081.000 ft 550,301.000 ft /" ft Northing: Easting: Wellhead Elevation: Sample Date Phase: Depth From (1VD) (ft) 28.000 ~-- Latitude: Longitude: Ground Level: 70° 18' 03.021" N 149° 35' 45.358" W 0.38 ° ~~ 70° 18' 06.149" N 149° 35' 33.297" W O.OOOft ~--~ Declination (0) 111812004 24.54 80.74 PLAN Tie On Depth: 28.000 57,577 +N/-S (ft) 0.000 14.404 0.000 Page 2of9 r~) f~' n i.-] \ì \. ...;.¡;.or ¡ L COMPASS 2003.11 Build 41 . C~illips SPERRY_SUN HES Planning Report . River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E-102 BLat Plan 1E-102 Blat (wp05) 28.000 0.000 0.000 28.000 0.000 0.000 0.00 0.00 0.00 0.00 400.000 0.000 0.000 400.000 0.000 0.000 0.00 0.00 0.00 0.00 733.333 10.000 30.000 731.644 25.128 14.508 3.00 3.00 0.00 30.00 985.191 20.000 25.000 974.620 83.250 43.719 4.00 3.97 -1.99 350.19 1,605.659 51.000 22.720 1,473.633 409.822 185.152 5.00 5.00 -0.37 356.56 2,649.999 51.000 22.720 2,130.857 1,158.448 498.617 0.00 0.00 0.00 0.00 3,021.665 62.150 22.720 2,335.265 1,444.123 618.234 3.00 3.00 0.00 0.00 5,407.745 62.150 22.720 3,449.942 3,390.126 1,433.063 0.00 0.00 0.00 0.00 5,838.452 77.500 14.350 3,598.277 3,772.333 1,559.669 4.00 3.56 -1.94 331.33 6,128.452 77.500 14.350 3,661.044 4,046.625 1,629.840 0.00 0.00 0.00 0.00 6,426.202 89.410 14.350 3,694.922 4,332.690 1,703.023 4.00 4.00 0.00 0.00 6,426.591 89.425 14.354 3,694.926 4,333.067 1,703.119 4.00 3.89 0.91 13.17 8,919.663 89.425 14.354 3,719.937 6,748.194 2,321.132 0.00 0.00 0.00 0.00 8,942.372 89.755 13.507 3,720.100 6,770.235 2,326.599 4.00 1.45 -3.73 -68.741E-102WSBTgt2 8,967.300 89.639 14.497 3,720.232 6,794.421 2,332.630 4.00 -0.46 3.97 96.65 9,429.134 89.639 14.497 3,723.141 7,241.541 2,448.241 0.00 0.00 0.00 0.00 9,643.078 90.383 8.122 3,723.100 7,451.221 2,490.177 3.00 0.35 -2.98 -83.35 1 E-102 WS B Tgt 3 9,644.290 90.393 8.157 3,723.092 7,452.420 2,490.348 3.00 0.82 2.88 74.04 13,437.921 90.393 8.157 3,697.087 11,207.581 3,028.610 0.00 0.00 0.00 0.00 13,535.025 89.592 5.356 3,697.100 11,304.001 3,040.033 3.00 -0.82 -2.88 -105.95 1E-102WS B Tgt4 / 14,377.298 89.592 5.356 3,703.100 ( 12,142.575 3,118.656 0.00 0.00 0.00 0.00 1E-102WS B Tgt 5 .~- 11/10/2004 10:53:46AM Page 3 0'9 COMPASS 2003.11 Build 41 Jl _I' }-~ .. ;11) V~~ . eonocÓÁ,illips . SPERRY_SUN HES Planning Report Single User Db Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1E-102 B La! Plan 1 E-102 B La! 28.000 0.000 0.000 28.000 0.000 0.000 0.000 0.00 0.00 0.00 SHL - 47891'1 FNL & 2231'1 FEL, Sec16-T11N-R10E 100.000 0.000 0.000 100.000 0.000 0.000 0.000 0.00 0.00 0.00 199.999 0.000 0.000 199.999 0.000 0.000 0.000 0.00 0.00 0.00 400.000 0.000 0.000 400.000 0.000 0.000 0.000 0.00 0.00 0.00 Begin Dir@3.00 : 400.0101'1,400.0101'1 500.000 3.000 30.000 499.954 2.267 1.309 2.521 3.00 3.00 0.00 600.000 6.000 30.000 599.635 9.061 5.231 10.077 3.00 3.00 0.00 700.000 9.000 30.000 698.768 20.363 11.757 22.648 3.00 3.00 0.00 733.333 10.000 30.000 731.644 25.128 14.508 27.947 3.00 3.00 0.00 Continue Dir@4.00 : 733.4001'1, 731.7091'1 800.000 12.636 27923 797.008 36.585 20.817 40.614 4.00 3.95 -3.12 900.000 16.608 26.031 893.751 59.100 32.216 65.256 4.00 3.97 -1.89 985.191 20.000 25.000 974.620 83.250 43.719 91.509 4.00 3.98 -1.21 Continue Dir@ 5.00 : 985.2001'1, 974.6281'1 1,000.000 20.739 24.875 988.500 87.924 45892 96.576 5.00 4.99 -0.85 1,100.000 25.732 24.208 1,080.363 123.810 62.252 135.4û3 5.00 4.99 -0.67 1,200.000 30.727 23.746 1,168.441 167.021 81.453 182.003 5.00 5.00 -0.46 1,300.000 35.724 23.400 1,252.066 217.230 103.351 236.111 5.00 5.00 -0.34 1,400.000 4û.721 23.134 1,330.602 274.055 127.777 297.226 5.00 5.00 -0.27 1,500.000 45.719 22.915 1,403.452 337.063 154.547 364.912 5.00 5.00 -0.22 1,600.000 50.717 22.730 1,470.061 405.774 183.457 438.655 5.00 5.00 -0.18 1,605.659 51.000 22.720 1 ,473.633 409.822 185.152 442.998 5.00 5.00 -0.17 End Dir, Start Sail@51.00: 1605.7001'1, 1473.6591'1 1,660.428 51.000 22.720 1,508.100 449.083 201.591 485.114 0.00 0.00 0.00 Permafrost 1,700.000 51.000 22.720 1,533.003 477.449 213.469 515.544 0.00 0.00 0.00 1 ,800.000 51.000 22.720 1,595.936 549.134 243.485 592.441 0.00 0.00 0.00 1 ,900.000 51.000 22.720 1,658.868 620.818 273.500 669.339 0.00 0.00 0.00 1,994.121 51.000 22.720 1,718.100 688.288 301.751 741.716 0.00 0.00 0.00 T3 2,000.000 51.000 22.720 1 ,721.800 692.502 303.516 746.236 0.00 0.00 0.00 2,100.000 51.000 22.720 1,784.732 764.186 333.531 823.134 0.00 0.00 0.00 2,200.000 51.000 22.720 1,847.664 835.870 363.547 900.001 0.00 0.00 0.00 2,300.000 51.000 22.720 1,910.596 907.555 393.562 976.929 0.00 0.00 0.00 2,400.000 51.000 22.720 1,973.528 979.239 423.578 1,053.826 0.00 0.00 0.00 2,458.114 51.000 22.720 2,010.100 1,020.897 441.021 1,098.514 0.00 0.00 0.00 K15 2,500.000 51.000 22.720 2,036.460 1,050.923 453.594 1,130.724 0.00 0.00 0.00 2,600.000 51.000 22.720 2,099.392 1,122.607 483.609 1,207.621 0.00 0.00 0.00 2,649.999 51.000 22.720 2,130.857 1,158.448 498.617 1,246.069 0.00 0.00 0.00 Begin Dir @ 3.00 : 2650.0001'1,2130.8581'1 2,700.000 52.500 22.720 2,161.812 1,194.667 513.782 1 ,284.922 3.00 3.00 0.00 2,800.000 55.500 22.720 2,220.583 1,269.283 545.025 1,364.964 3.00 3.00 0.00 2,900.000 58.500 22.720 2,275.041 1,346.633 577.413 1,447.940 3.00 3.00 0.00 3,000.000 61.500 22.720 2,325.005 1 ,426.507 610.858 1,533.622 3.00 3.00 0.00 3,021.665 62.150 22.720 2,335.265 1,444.123 618.234 1 ,552.520 3.00 3.00 0.00 End Dir, Start Sail @ 62.15: 3021.6701'1, 2335.2671'1 3,100.000 62.150 22.720 2,371.860 1,508.010 644.985 1 ,621 .053 0.00 0.00 0.00 3,177.576 62.150 22.720 2,4û8.100 1 ,571 .278 671.476 1,688.923 0.00 0.00 0.00 T3+675 -~- 11/10I2oo410:53:46AM Page 4 of9 COMPASS 2003.11 Build 41 · e eonocJ'Pt,illips SPERRY_ SUN HES Planning Report 2003.11 Single User Db AI¡¡ska Inc. (Kuparuk) above WRP) Kuparuk River Unit above WRP) Kuparuk 1 E Pad Plan 1E-102 1E-102 BLat 1 E-102 BLat (wp05) 3,179.503 62.150 22.720 2,409.000 1 ,572.850 672.134 1,690.608 0.00 0.00 0.00 10-3/4" Csg Pt... Drill out 9-7/8" Hole: 3180ft, 2409ft 3,179.717 62.150 22.720 2,409.100 1,573.024 672.207 1,690.795 0.00 0.00 0.00 103/4" 3,200.000 62.150 22.720 2,418.575 1 ,589.566 679.134 1 ,708.541 0.00 0.00 0.00 3,300.000 62.150 22.720 2,465.291 1,671.123 713.283 1 ,796.028 0.00 0.00 0.00 3,400.000 62.150 22.720 2,512.007 1,752.679 747.432 1,883.516 0.00 0.00 0.00 3,500.000 62.150 22.720 2,558.723 1 ,834.236 781.582 1,971.004 0.00 0.00 0.00 3,600.000 62.150 22.720 2,605.439 1,915.792 815.731 2,058.492 0.00 0.00 0.00 3,700.000 62.150 22.720 2,652.155 1,997.349 849.880 2,145.979 0.00 0.00 0.00 3,800.000 62.150 22.720 2,698.870 2,078.905 884.029 2,233.467 0.00 0.00 0.00 3,900.000 62.150 22.720 2,745.586 2,160.462 918.179 2,320.955 0.00 0.00 0.00 4,000.000 62.150 22.720 2,792.302 2,242.018 952.328 2,408.443 0.00 0.00 0.00 4,100.000 62.150 22.720 2,839.018 2,323574 986.477 2,495.930 0.00 0.00 0.00 4,200.000 62.150 22.720 2,885.734 2,405.131 1,020.627 2,583.418 0.00 0.00 0.00 4,243.596 62.150 22.720 2,906.100 2,440.686 1,035.514 2,621.559 0.00 0.00 0.00 Ugnu C 4,300.000 62.150 22.720 2,932.450 2,486.687 1,054.776 2,670.906 0.00 0.00 0.00 4,400.000 62.150 22.720 2,979.165 2,568.244 1,088.925 2,758.394 0.00 0.00 0.00 4,500.000 62.150 22.720 3,025.881 2,649.800 1,123.074 2,845.881 0.00 0.00 0.00 4,600.000 62.150 22.720 3,072.597 2,731.357 1,157.224 2,933.369 0.00 0.00 0.00 4,700.000 62.150 22.720 3,119.313 2,812.913 1,191.373 3,020.857 0.00 0.00 0.00 4,800.000 62.150 22.720 3,166.029 2,894.470 1 ,225.522 3,108.345 0.00 0.00 0.00 4,870.792 62.150 22.720 3,199.100 2,952.205 1,249.697 3,170.279 0.00 0.00 0.00 Ugnu B 4,900.000 62.150 22.720 3,212.745 2,976.026 1,259.671 3,195.833 0.00 0.00 0.00 4,990.666 62.150 22.720 3,255.100 3,049.970 1,290.633 3,275.154 0.00 0.00 0.00 Ugnu A 5,000.000 62.150 22.720 3,259.461 3,057.583 1 ,293.821 3,283.320 0.00 0.00 0.00 5,100.000 62.150 22.720 3,306.176 3,139.139 1,327.970 3,370.808 0.00 0.00 0.00 5,200.000 62.150 22.720 3,352.892 3,220.696 1,362.119 3,458.296 0.00 0.00 0.00 5,300.000 62.150 22.720 3,399.608 3,302.252 1,396.268 3,545.784 0.00 0.00 0.00 5,400.000 62.150 22.720 3,446.324 3,383.809 1,430.418 3,633.271 0.00 0.00 0.00 5,407.745 62.150 22.720 3,449.942 3,390.126 1,433.063 3,640.048 0.00 0.00 0.00 Begin Dir @4.00 : 5407.750ft,3449.944ft 5,408.083 62.162 22.713 3,450.100 3,390.401 1,433.178 3,640.343 4.00 3.51 -2.17 K13 5,500.000 65.400 20.774 3,490.706 3,466.986 1,463.701 3,722.114 4.00 3.52 -2.11 5,600.000 68.951 18.775 3,529.492 3,553.709 1 ,494.857 3,813.861 4.00 3.55 -2.00 5,700.000 72.524 16.870 3,562.478 3,643.567 1,523.728 3,908.076 4.00 3.57 -1.91 5,800.000 76.115 15.039 3,589.501 3,736.121 1,550.173 4,004.299 4.00 3.59 -1.83 5,838.452 77.500 14.350 3,598.277 3,772.333 1,559.669 4,041.735 4.00 3.60 -1.79 End Dir, Start Sail@ 77.50: 5838.460ft, 3598.278ft 5,900.000 77.500 14.350 3,611.598 3,830.547 1,574.561 4,101.824 0.00 0.00 0.00 5,934.661 77.500 14.350 3,619.100 3,863.331 1 ,582.948 4,135.663 0.00 0.00 0.00 D 6,000.000 77.500 14.350 3,633.242 3,925.131 1,598.758 4,199.454 0.00 0.00 0.00 6,100.000 77.500 14.350 3,654.886 4,019.714 1,622.955 4,297.083 0.00 0.00 0.00 6,128.452 77.500 14.350 3,661.044 4,046.625 1,629.840 4,324.861 0.00 0.00 0.00 6,147.780 78.273 14.350 3,665.100 4,064.933 1,634.523 4,343.758 4.00 4.00 0.00 C 6,200.000 80.361 14.350 3,674.779 4,114.644 1,647.241 4,395.070 4.00 4.00 0.00 6,300.000 84.361 14.350 3,688.068 4,210.645 1,671.800 4,494.163 4.00 4.00 0.00 6,310.926 84.799 14.350 3,689.100 4,221 .183 1,674.496 4,505.040 4.01 4.01 0.00 1E-102 WS B (Heel) 6,335.260 85.772 14.350 3,691.100 4,244.678 1,680.507 4,529.292 4.00 4.00 0.00 B ---~~~ 11/10/200410:53:46AM Page 5 of9 COMPASS 2003.11 Build 41 OR ","" ~ . . eol'tOCÓPhillips SPERRY_ SUN HES Planning Report Db Inc. (Kuparuk) Unit 1E Pad Plan 1 E-102 BLat 1 E-102 BLat (wp05) 6,400.000 88.361 14350 3,694.412 4,307.310 1,696.530 4,593.941 4_00 4.00 ·0.00 6,426.202 89.410 14.350 3,694.922 4,332.690 1,703.023 4,620.138 4.00 4.00 0.00 6,426.591 89.425 14.354 3,694.926 4,333.067 1,703_119 4,620.527 4.00 3.89 0.91 6,500.000 89.425 14.354 3,695.662 4,404.180 1,721.317 4,693_932 0.00 0.00 0.00 7-5/S" Csg Pt... Begin 6-3/4" hole: 6500ft, 3696ft-- Continue Dir (974 ft FNL, 3924 ftFEL; Sec15-T11N-R10E. -75/8 6,600.000 89.425 14.354 3,696.665 4,501.054 1,746.106 4,793.927 0.00 0.00 0.00 6,700.000 89.425 14.354 3,697.669 4,597.928 1,770.895 4,893.922 0.00 0.00 0.00 6,800.000 89.425 14.354 3,698.672 4,694.801 1,795.684 4,993_917 0.00 0.00 0.00 6,900.000 89.425 14_354 3,699.675 4,791.675 1,820.473 5,093.912 0.00 0.00 0.00 7,000.000 89.425 14.354 3,700.678 4,888_548 1,845.263 5,193.907 0.00 0.00 0.00 7,100.000 89.425 14_354 3,701.682 4,985.422 1,870.052 5,293.902 0.00 0_00 0.00 7,200.000 89.425 14.354 3,702.685 5,082.295 1,894.841 5,393.896 0.00 0.00 0.00 7,300.000 89.425 14.354 3,703.688 5,179_169 1,919.630 5,493.891 0.00 0.00 0.00 7,400.000 89.425 14_354 3,704.691 5,276.043 1,944.419 5,593.886 0.00 0.00 0.00 7,500.000 89.425 14.354 3,705.695 5,372.916 1 ,969.209 5,693.881 0.00 0.00 0.00 7,600.000 89.425 14_354 3,706.698 5,469.790 1,993.998 5,793.876 0.00 0.00 0.00 7,700.000 89.425 14.354 3,707.701 5,566.663 2,018.787 5,893.871 0.00 0.00 0.00 7,800.000 89.425 14.354 3,708.704 5,663.537 2,043.576 5,993.866 0_00 0.00 0.00 7,900.000 89.425 14.354 3,709.708 5,760.410 2,068.365 6,093.861 0.00 0.00 0.00 8,000.000 89.425 14.354 3,710.711 5,857.284 2,093.155 6,193.856 0.00 0.00 0.00 8,100.000 89.425 14_354 3,711.714 5,954.158 2,117.944 6,293.851 0.00 0.00 0.00 8,200.000 89.425 14_354 3,712.717 6,051.031 2,142.733 6,393.846 0_00 0.00 0.00 8,300.000 89.425 14.354 3,713_721 6,147.905 2,167_522 6,493.841 0_00 0_00 0.00 8,400.000 89.425 14.354 3,714.724 6,244778 2,192.311 6,593.836 0.00 0.00 0.00 8,500.000 89.425 14.354 3,715.727 6,341.652 2,217.101 6,693.831 0.00 0.00 0.00 8,600.000 89.425 14.354 3,716.730 6,438_525 2,241.890 6,793.825 0.00 0.00 0.00 8,700.000 89.425 14.354 3,717.734 6,535.399 2,266.679 6,893.820 0_00 0.00 0.00 8,800.000 89.425 14.354 3,718.737 6,632.273 2,291.468 6,993.815 0.00 0.00 0.00 8,900.000 89.425 14.354 3,719.740 6,729_146 2,316.258 7,093.810 0.00 0.00 0.00 8,919.663 89.425 14.354 3,719.937 6,748.194 2,321.132 7,113.472 0.00 0.00 0_00 8,942_372 89.755 13.507 3,720.100 6,770.235 2,326.599 7,136.180 4.00 1.45 -3.73 1E-102 WS B Tgt 2 8,967.300 89.639 14.497 3,720.232 6,794.421 2,332.630 7,161.106 4.00 -0.46 3.97 9,000.000 89.639 14.497 3,720.438 6,826.079 2,340.816 7,193.806 0.00 0.00 0.00 9,100.000 89.639 14.497 3,721.068 6,922.893 2,365.849 7,293.804 0.00 0.00 0.00 9,200.000 89.639 14.497 3,721.698 7,019.707 2,390.882 7,393.801 0.00 0.00 0.00 9,300.000 89.639 14.497 3,722_327 7,116.521 2,415_915 7,493.799 0.00 0.00 0.00 9,400.000 89.639 14.497 3,722.957 7,213.335 2,440_948 7,593.797 0_00 0.00 0.00 9,429.134 89.639 14.497 3,723.141 7,241541 2,448.241 7,622.930 0.00 0.00 0.00 9,500.000 89.885 12.387 3,723.435 7,310.461 2,464.713 7,693.782 3.00 0.35 -2.98 9,600.000 90.233 9.407 3,723.332 7,408.647 2,483.613 7,793.583 3.00 0.35 -298 9,643.078 90.383 8.122 3,723.100 7,451.221 2,490.177 7,836.451 3.00 0.35 -2.98 1E-102 WS B Tgt 3 9,644.290 90.393 8.157 3,723.092 7,452.420 2,490 _348 7,837_655 3.00 0.82 2_88 9,700.000 90.393 8.157 3,722.710 7,507.566 2,498.253 7,893.033 0.00 0.00 0.00 9,800.000 90.393 8.157 3,722.024 7,606.552 2,512.441 7,992.437 0.00 0_00 0.00 9,900.000 90.393 8.157 3,721.339 7,705.538 2,526.630 8,091.841 0.00 0.00 0.00 10,000.000 90.393 8.157 3,720.653 7,804.524 2,540.818 8,191.245 0.00 0.00 0.00 10,100.000 90.393 8.157 3,719.968 7,903509 2,555.007 8,290.649 0.00 0.00 0.00 10,200.000 90.393 8.157 3,719.282 8,002.495 2,569.196 8,390.053 0_00 0.00 0.00 10,300.000 90.393 8.157 3,718.597 8,101.481 2,583.384 8,489.457 0.00 0.00 0_00 10,400.000 90.393 8.157 3,717.912 8,200.467 2,597.573 8,588.860 0.00 0.00 0.00 10,500.000 90.393 8.157 3,717.226 8,299.453 2,611.761 8,688.264 0.00 0.00 0.00 10,600.000 90_393 8.157 3,716.541 8,398.439 2,625_950 8,787.668 0.00 0.00 0.00 10,700.000 90.393 8.157 3,715.855 8,497.425 2,640.138 8,887.072 0.00 0.00 0.00 10,800.000 90.393 8.157 3,715.170 8,596.411 2,654_327 8,986.476 0.00 0.00 0.00 10,900.000 90.393 8.157 3,714.484 8,695.397 2,688.516 9,085.880 0.00 0_00 0.00 11,000.000 90.393 8.157 3,713.799 8,794.383 2,682.704 9,185.283 0.00 0.00 0.00 11/10/2004 10:53:46AM Page 6 of9 COMPASS 2003.11 Build 41 OR' . e ~illips SPERRY _ SUN HES Planning Report EDM 2003.11 Single U$er Db ConocoPhillips Alaska Inc. (Kuparuk) River Unit 1E Pad Plan 1E-102 Plan 1E-102 BLat Plan 1E-102BLat(wp05) 11,100.000 90.393 8.157 3,713.113 8,893.369 2,696.893 ---~~~ 0.00 0.00 0.00 9,284.687 11,200.000 90.393 8.157 3,712.428 8,992.355 2,711.081 9,384.091 0.00 0.00 0.00 11,300.000 90.393 8.157 3,711.742 9,091.341 2,725.270 9,483.495 0.00 0.00 0.00 11,400.000 90.393 8.157 3,711.057 9,190.327 2,739.458 9,582.899 0.00 0.00 0.00 11,500.000 90.393 8.157 3,710.371 9,289.313 2,753.647 9,682.303 0.00 0.00 0.00 11,600.000 90.393 8.157 3,709.686 9,388.298 2,767.835 9,781.706 0.00 0.00 0.00 11,700.000 90.393 8.157 3,709.000 9,487.284 2,782.024 9,881.110 0.00 0.00 0.00 11,800.000 90.393 8.157 3,708.315 9,586.270 2,796.213 9,980.514 0.00 0.00 0.00 11,900.000 90.393 8.157 3,707.629 9,685.256 2,810.401 10,079.918 0.00 0.00 0.00 12,000.000 90.393 8.157 3,706.944 9,784.242 2,824.590 10,179.322 0.00 0.00 0.00 12,100.000 90.393 8.157 3,706.258 9,883.228 2,838.778 10,278.726 0.00 0.00 0.00 12,200.000 90.393 8.157 3,705.573 9,982.214 2,852.967 10,378.130 0.00 0.00 0.00 12,300.000 90.393 8.157 3,704.887 10,081.200 2,867.155 10,477.533 0.00 0.00 0.00 12,400.000 90.393 8.157 3,704.202 10,180.186 2,881 .344 10,576.937 0.00 0.00 0.00 12,500.000 90.393 8.157 3,703.516 10,279.172 2,895.532 10,676.341 0.00 0.00 0.00 12,600.000 90.393 8.157 3,702.831 10,378.158 2,909.721 10,775.745 0.00 0.00 0.00 12,700.000 90.393 8.157 3,702.145 10,477.144 2,923.910 10,875.149 0.00 0.00 0.00 12,800.000 90.393 8.157 3,701.460 10,576.130 2,938.098 10,974.553 0.00 0.00 0.00 12,900.000 90.393 8.157 3,700.774 10,675.116 2,952.287 11,073.956 0.00 0.00 0.00 13,000.000 90.393 8.157 3,700.089 10,774.102 2,966.475 11,173.360 0.00 0.00 0.00 13,100.000 90.393 8.157 3,699.403 10,873.087 2,980.664 11,272.764 0.00 0.00 0.00 13,200.000 90.393 8.157 3,698.718 10,972.073 2,994.852 11,372.168 0.00 0.00 0.00 13,300.000 90.393 8.157 3,698.032 11,071.059 3,009.041 11,471 .572 0.00 0.00 0.00 13,400.000 90.393 8.157 3,697.347 11,170.045 3,023.230 11,570.976 0.00 0.00 0.00 13,437.921 90.393 8.157 3,697.087 11,207.581 3,028.610 11,608.670 000 0.00 0.00 13,500.000 89.881 6.368 3,696.939 11,269.160 3,036.457 11,670.265 3.00 -0.82 -2.88 13,535.025 89.592 5.356 3,697.100 11,304.001 3,040.033 11,704.901 3.00 -0.83 -2.89 1 E-102 WS B Tgt 4 13,600.000 89.592 5.356 3,697.563 11,368.691 3,046.099 11,769.065 0.00 0.00 0.00 13,700.000 89.592 5.356 3,698.275 11,468.251 3,055.433 11,867.819 0.00 0.00 0.00 13,800.000 89.592 5.356 3,698.988 11,567.812 3,064.768 11,966.572 0.00 0.00 0.00 13,900.000 89.592 5.356 3,699.700 11,667.373 3,074.102 12,065.325 0.00 0.00 0.00 14,000.000 89.592 5.356 3,700.412 11,766.934 3,083.437 12,164.078 0.00 0.00 0.00 14,100.000 89.592 5.356 3,701.125 11,866.495 3,092.772 12,262.831 0.00 0.00 0.00 14,200.000 89.592 5.356 3,701.837 11,966.055 3,102.106 12,361 .584 0.00 0.00 0.00 14,300.000 89.592 5.356 3,702.549 12,065.616 3,111.441 12,460.338 0.00 0.00 0.00 14,377.298 89.592 5.356 3,703.100 12,142.575 3,118.656 12,536.672 0.00 0.00 0.00 Targèt (Toe) : 14377.290ft, 3703.100ft, (3207ft FNL, 2359ft FEL, Sec3-T11N-R10E - 6 3/4" Open Hole· 1E-102 WSB TgtS -~- 11/10/200410:53:46AM Page 70f9 COMPASS 2003.11 Build 41 O R'¡ , ¡ . ~ . Co~illips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E-102 BLat Plan 1 E-102 B Lat (wpOS) Well Plan 1E-102 1E-102 @ 94.1000 (28' above WRP) 1 E-102 @ 94.1000 (28' above WRP) True Minimum Curvature Targets Target Name - hitlmiss target - Shape 1E-102WS B Tgt5 0.00 0.00 3,703.100 12,142.575 3,118.656 5,972,243.000 553,338.000 70" 20' 05.564" N 149" 34' 02.224" W - plan - Point 1E-102WS B (Heel) 0.00 0.00 3,689.100 3,866.858 1,584.074 5,963,958.000 551,859.000 70" 18' 44.178" N 149" 34' 47.089" W - plan - Point 1E-102WS B Tgt2 0.00 0.00 3,720.100 6,770.235 2,326.599 5,966,866.000 552,582.000 70" 19' 12.731" N 149" 34' 25.403" W - plan hits target - Point 1E-102WS B Tgt3 0.00 0.00 3,723.100 7,451.221 2,490.177 5,967,548.000 552,741.000 70" 19' 19.428" N 149" 34' 20.623" W - plan hits target - Point 1E-102WSBTgt4 0.00 0.00 3,697.100 11,304.001 3,040.033 5,971,404.000 553,265.000 70" 19'57.317" N 149" 34' 04.530" W - plan hits target - Point Measured Vert"tcal Depth Depth (ft) (ft) 3,179.717 2,409.100 103/4" 1 0-314 13-1/2 6,500.000 3,695.662 75/8 7-5/8 9-7/8 14,377.290 3,703.100 63/4" Open Hole 6-314 6-3/4 Fonnations Measured Vertical Depth Depth (ft) (ft) 1,660.428 1,508.100 Permafrost 0.00 1,994.121 1,718.100 T3 0.00 2,458.114 2,010.100 K15 0.00 3,177.576 2,408.100 T3+675 0.00 4,243.596 2,906.100 Ugnu C 0.00 4,870.792 3,199.100 Ugnu B 0.00 4,990.666 3,255.100 Ugnu A 0.00 5,408.083 3,450.100 K13 0.00 5,934.661 3,619.100 D 0.00 6,147.780 3,665.100 C 0.00 6,335.260 3,691.100 B 0.00 --~~-~---~ OR Page 8 of 9 I""'> i F'_~ 1,,_ t"'d -- ~-- . COMPASS 2003.11 Bui/d41 11/10/2004 10:53:46AM . eonocÓPhillips . SPERRY_SUN HES Planning Report 28.000 400.010 733.400 985.200 1,605.700 2,650.000 3,021.670 3,179.503 5,407.750 5,838.460 6,500.000 14,377.280 11/101200410:53:46AM 28.000 400.010 731.709 974.628 1,473.659 2,130.858 2,335.267 2,409.000 3,449.944 3,598.278 3,695.662 3,703.100 0.000 0.000 25.138 83.253 409.851 1,158.449 1,444.127 1,572.850 3,390.129 3,772.340 4,404.180 12,142.557 -~~~~ 0.000 0.000 14.513 43.720 185.164 498.617 618.235 672.134 1,433.064 1,559.671 1,721.317 3,118.655 Page 9 of9 O R I ¡I''''d ~d ~ I·] f, nJ <t,$Y U f; ti SHL -- 4789ft FNL & 223ft FEL, Sec16-T11 N-R10E Begin Dir @ 3.00 : 400.01 Oft,400.01 Oft Continue Dir @ 4.00: 733.4OOft, 731.709ft Continue Dir @ 5.00 : 985.2OOft, 974.628ft End Dir, Start Sail @ 51.00: 1605.700ft, 1473.659ft Begin Dir @ 3.00 : 2650.000ft,2130.858ft End Dir, Start Sail @ 62.15: 3021.67Oft, 2335.267ft 10-3/4" Csg pt ... Drill out 9-7/8" Hole: 318Oft, 2409ft Begin Dir @ 4.00 : 5407.75Oft,3449.944ft End Dir, Start Sail @ 77.50: 5838.46Oft, 3598.2700 7-518" Csg pt ... Begin 6-3/4" hole: 65OOft, 3696ft -- Continue Dir (974 ft FNL, 3~ Target (Toe): 14377.29Oft, 3703.10Oft, (3207ft FNL, 2359ft FEL, Sec3-T11N-R" COMPASS 2003.11 Build 41 WEtkOEfßJts: Plafl1E-1ù2 Ground Ls\lel: Ö,OC<J NorthIng Etistjng Urtmoo. ù:mgllude 59600{1.000 &50301.000 70'1f1'6.t49N 149"3$'3$.'ði7W "OC<J Engineering Kuparuk ANTI-COLLISION SETTINGS Calculation Method: MinimumCurvature Error System ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Sased Interpolation Method: to 14377 II H."'" Ite$>. ,.... ....1.au...ns Depth Range From: Reference: From Colour To MD 28- 300 300 500 500 750 1000 1250 1250 1500 1500 2000 2000 2500 2500 3000 90 3000 3500 270 3500 4000 4000 4500 270 90 4500 5000 5000 5500 5500 6500 6500 7000 7000 8000 8000 9000 9000 10000 10000 11000 11000 12000 12000 13000 13000 14000 14000 15000 15000 - 16000 180 Travelling Cylinder AzimutlI (TFO+AZI) [0] vs Centre to Centre Separation [50 Win] Centre Separation [10 Win] . . Halliburton Sperry-Sun Anticollision Report ~ .. -!I-an OfUI..LlfII/iI SIII'tVIC&S 11. >nrJi.tIa'¡¡!'(6;(:ö\1Ii',"''''.- NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 It Depth Range: 28.00 to 14377.37 It Maximum Radius: 1634.94 It Reference: Error Model: Scan Method: Error Surface: Plan: Plan: 1E-102 & NOT PLANNED PRO~RAf\ ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points 2979.18 5883.01 14377.37 2315.00 3608.00 3703.10 10.750 7. 625 4.500 12.250 9.875 6.750 103/4" 7-5/8" 41/2" Plan: Plan: 1E-102 Date Composed: Version: Tied-to: 11/8/2004 7 From Well Ref. Point Principal: Yes Summary Kuparuk 18 Pad 1B-06 1 B-06 V1 9100.08 5525.00 1385.05 202.09 1182.96 Pass: Major Risk Kuparu k 18 Pad 1B-07 1B-07 V1 10091.43 5200.00 486.73 192.30 294.43 Pass: Major Risk Kuparuk 18 Pad 18-08 1B-08 V1 11098.60 4950.00 415.29 183.02 232.28 Pass: Major Risk Kuparuk 1 B Pad 1 B-08A 18-0SA V1 11099.52 4950.00 415.47 182.86 232.61 Pass: Major Risk Kuparuk 1 B Pad 1B-101 18-101 V1 11181.90 4850.00 915.94 140.87 775.06 Pass: Major Risk Kuparuk 1 B Pad 18-101 18-101L1 V1 11181.90 4850.00 915.94 140.87 775.06 Pass: Major Risk Kuparuk 1 B Pad 1B-102 18-102 V1 11897.16 4700.00 1111.08 136.55 974.53 Pass: Major Risk Kuparuk 1B Pad 1B-11 1B-11 V1 14374.59 5975.00 1456.28 324.04 1132.24 Pass: Major Risk Kuparu k 18 Pad 1B-12 1B-12 V1 12607.39 4950.00 708.08 216.21 491.87 Pass: Major Risk Kuparuk 18 Pad WSW-02 WSW-02 V1 12355.91 4018.00 1309.96 224.12 1085.84 Pass: Major Risk Kuparuk 1 E Pad 1E-05 1 E-05 V1 1516.63 1625.00 294.79 26.70 268.09 Pass: Major Risk Kuparuk 1 E Pad 1E-07 1E-07V1 2606.25 2600.00 178.32 43.17 135.15 Pass: Major Risk Kuparuk 1 E Pad 1 E-123 1E-123 V2 1902.93 1900.00 114.21 37.64 76.57 Pass: Major Risk Kuparuk 1 E Pad 1E-123 1E-123L1 V2 1902.93 1900.00 114.21 37.64 76.57 Pass: Major Risk Kuparu k 1 E Pad 1E-123 1E-123PB1 V1 1902.93 1900.00 114.21 37.64 76.57 Pass: Major Risk Kuparuk 1 E Pad 1 E-126 1E-126 V1 1411.98 1525.00 63.49 32.30 31.20 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1 E-126L1 V1 1411.98 1525.00 63.49 32.30 31.20 Pass: Major Risk Kuparuk 1 E Pad 1 E-126 1E-126l2 V1 1411.98 1525.00 63.49 32.45 31.04 Pass: Major Risk Kuparuk 1 E Pad 1E-18 1E-18 V1 765.80 775.00 22.80 13.78 9.02 Pass: Major Risk Kuparuk 1 E Pad 1 E-19 1E-19 V1 438.05 450.00 19.95 7.69 12.27 Pass: Major Risk Kuparuk 1 E Pad 1E-20 1 E-20 V1 437.02 450.00 81.75 7.88 73.88 Pass: Major Risk Kuparu k 1 E Pad 1E-21 1 E-21 V1 436.08 450.00 140.97 7.46 133.51 Pass: Major Risk Kuparu k 1 E Pad 1E-22 1 E-22 V1 412.26 425.00 202.26 7.84 194.42 Pass: Major Risk Kuparuk 1 E Pad Plan: 1E-104 Plan 1E-104 VO Plan: P 546.04 550.00 57.98 10.06 47.92 Pass: Major Risk OR~ . . .. ... .~ _II- ConocUrIJl IPS ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-1 02 Plan 1 E-1 02 BLat Plan: Plan 1 E-1 02 BLat (wp05) Standard Planning Report - Geographic 08 November, 2004 ORIGI~JAL . Co~illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1E-102 BLat Plan 1 E-1 02 BLat (wp05) Well Plan 1E-102 1E·102 @ 94.1ooft (28' above WRP) 1E-102 @ 94.100ft (28' above WRP) True Minimum Curvature Project Map System: Geo Datum: Map Zone: Kuparuk River Unit, North Slope Alaska, United States US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Kuparuk 1 E Pad Site Position: From: Map Position Uncertainty: 0.000 ft Northing: Easting: Slot Radius: 5,959,760.240ft 549,889.51 Oft 0" Latitude: Longitude: Grid Convergence: 70° 18' 03.021" N 149° 35' 45.358" W 0.38 ° Well Plan 1 E-102 Well Position +N/-S +EI-W Position Uncertainty O.OOOft O.ooOft 0.000 ft Northing: Easting: Wellhead Elevation: 5,960,081.000 ft 550,301.000 ft ft Latitude: Longitude: Ground Level: 70° 18' 06.149" N 149° 35' 33.297" W 0.000 ft Wellbore Plan 1E-102 BLat BGGM2004 11/8/2004 24.54 80.74 57,577 Design Audit Notes: Version: Plan 1 E-102 BLat (wp05) Phase: PLAN Tie On Depth: 28.000 0.000 14.404 111812004 2:42:18PM Page 2 019 Of" ~ .f ~- t"'\ ~- t; \\ COMPASS 2003.11 Build 41 . eonoOO'Â1i11ips . SPERRY_SUN HES Planning Report - Geographic 28.000 0.000 0.000 28.000 0.000 0.000 0.00 0.00 0.00 0.00 400.000 0.000 0.000 400.000 0.000 0.000 0.00 0.00 0.00 0.00 733.333 10.000 30.000 731.644 25.128 14.508 3.00 3.00 0.00 30.00 985.191 20.000 25.000 974.620 83.250 43.719 4.00 3.97 -1.99 350.19 1,605.659 51.000 22.720 1,473.633 409.822 185.152 5.00 5.00 -0.37 356.56 2,649.999 51.000 22.720 2,130.857 1,158.448 498.617 0.00 0.00 0.00 0.00 3,021.665 62.150 22.720 2,335.265 1,444.123 618.234 3.00 3.00 0.00 0.00 5,407.745 62.150 22.720 3,449.942 3,390.126 1 ,433.063 0.00 0.00 0.00 0.00 5,838.452 77.500 14.350 3,598.277 3,772.333 1,559.669 4.00 3.56 -1.94 331.33 6,128.452 77.500 14.350 3,661.044 4,046.625 1 ,629.840 0.00 0.00 0.00 0.00 6,426.202 89.410 14.350 3,694.922 4,332.690 1,703.023 4.00 4.00 0.00 0.00 6,426.591 89.425 14.354 3,694.926 4,333.067 1,703.119 4.00 3.89 0.91 13.17 8,919.663 89.425 14.354 3,719.937 6,748.194 2,321 .132 0.00 0.00 0.00 0.00 8,942.372 89.755 13.507 3,720.100 6,770.235 2,326.599 4.00 1.45 -3.73 -68.741E-102WSBTgt2 8,967.300 89.639 14.497 3,720.232 6,794.421 2,332.630 4.00 -0.46 3.97 96.65 9,429.134 89.639 14.497 3,723.141 7,241.541 2,448.241 0.00 0.00 0.00 0.00 9,643.078 90.383 8.122 3,723.100 7,451.221 2,490.177 3.00 0.35 -2.98 -83.35 1 E-1 02 WS B Tgt 3 9,644.290 90.393 8.157 3,723.092 7,452.420 2,490.348 3.00 0.82 2.88 74.04 13,437.921 90.393 8.157 3,697.087 11,207.581 3,028.610 0.00 0.00 0.00 0.00 13,535.025 89.592 5.356 3,697.100 11,304.001 3,040.033 3.00 -0.82 -2.88 -105.95 1 E-1 02 WS B Tgt 4 14,377.298 89.592 5.356 3,703.100 12,142.575 3,118.656 0.00 0.00 0.00 0.00 1 E-1 02 WS B Tgt 5 11/8/2004 2:42:18PM Page 3 of9 COMPASS 2003.11 Build 41 1"\ ~ . Co~illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-102 Plan 1 E-102 BLat Plan 1 E-1 02 BLat (wp05) Well Plan 1 E-1 02 1E·102 @ 94.1ooft (28' above WRP) 1E-102 @ 94.100ft (28' above WRP) True Minimum Curvature 28.000 0.000 0.000 28.000 0.000 0.000 5,960,081.000 550,301.000 70° 18' 06.149" N 149° 35' 33.297" W SHL -- 478911 FNL & 223ft FEL, Sec16-T11N-R10E 1 00.000 0.000 0.000 100.000 0.000 0.000 5,960,081.000 550,301.000 70° 18' 06.149" N 149° 35' 33.297" W 199.999 0.000 0.000 199.999 0.000 0.000 5,960,081.000 550,301.000 70° 18' 06.149" N 149° 35' 33.297" W 400.000 0.000 0.000 400.000 0.000 0.000 5,960,081.000 550,301.000 70° 18' 06.149" N 149° 35' 33.297" W 13egin Dir@ 3.00: 400.010ft,400.010ft 500.000 3.000 30.000 499.954 2.267 1.309 5,960,083.275 550,302.293 70° 18' 06.172" N 149° 35' 33.259" W 600.000 6.000 30.000 599.635 9.061 5.231 5,960,090.095 550,306.170 70° 18' 06.239" N 149° 35' 33.145" W 700.000 9.000 30.000 698.768 20.363 11.757 5,960,101.440 550,312.619 70° 18' 06.350" N 149° 35' 32.955" W 733.333 10.000 30.000 731.644 25.128 14.508 5,960,106.222 550,315.338 70° 18' 06.397" N 149° 35' 32.874" W Continue Dir @ 4.00 : 733.400ft,731.709ft 800.000 12.636 27.923 797.008 36.585 20.817 5,960,117.720 550,321.570 70° 18' 06.509" N 149° 35' 32.690" W 900.000 16.608 26.031 893.751 59.100 32.216 5,960,140.309 550,332.816 70° 18' 06.731" N 149° 35' 32.358" W 985.191 20.000 25.000 974.620 83.250 43.719 5,960,164.533 550,344.156 70° 18' 06.968" N 149° 35' 32.023" W Continue Dir@5.00: 985.200ft, 974.628ft 1,000.000 20.739 24.875 988.503 87.924 45.892 5,960,169.221 550,346.298 70° 18' 07.014" N 149° 35' 31.959" W 1,100.000 25.732 24.208 1,080.363 123.810 62.252 5,960,205.211 550,362.415 70° 18' 07.367" N 149° 35' 31.482" W 1,200.000 30.727 23.746 1,168.441 167.021 81 .453 5,960,248.547 550,381.325 70° 18' 07.792:' N 149° 35' 30.923" W 1,300.000 35.724 23.403 1,252.066 217.230 103.351 5,960,298.896 550,402.884 70° 18' 08.286" N 149° 35' 30.284" W 1,400.000 40.721 23.134 1,330.602 274.055 127.777 5,960,355.878 550,426.927 70° 18' 08.845" N 149° 35' 29.572" W 1,500.000 45.719 22.915 1,403.452 337.063 154.547 5,960,419.057 550,453.272 70° 18' 09.464" N 149° 35' 28.791" W 1,600.000 50.717 22.730 1,470.061 405.774 183.457 5,960,487.953 550,481.718 70° 18'10.140" N 149° 35' 27.948" W 1,605.659 51.000 22.720 1,473.633 409.822 185.152 5,960,492.012 550,483.387 70° 18'10.180" N 149° 35' 27.899" W End Dir,Start Sail @51.00: 1605.700ft, 1473.659ft 1,660.428 51.000 22.720 1,508.100 449.083 201.591 5,960,531.378 550,499.561 70° 18' 10.566" N 149° 35' 27.420" W Pennafrost 1,700.000 51.000 22.720 1 ,533.003 477.449 213.469 5,960,559.821 550,511.248 70° 18' 10.845" N 149° 35' 27.073" W 1,800.000 51.000 22.720 1 ,595.936 549.134 243.485 5,960,631.698 550,540.780 70° 18' 11 .550" N 149° 35' 26.198" W 1,900.000 51.000 22.720 1 ,658.868 620.818 273.500 5,960,703.574 550,570.312 70° 18' 12.255" N 149° 35' 25.323" W 1 ,994.121 51.000 22.720 1,718.100 688.288 301.751 5,960,771.226 550,598.108 70° 18'12.919" N 149° 35' 24.499" W T3 2,000.000 51.000 22.720 1 ,721 .800 692.502 303.516 5,960,775.451 550,599.844 70° 18' 12.960" N 149° 35' 24.447" W 2,100.000 51.000 22.720 1,784.732 764.186 333.531 5,960,847.328 550,629.376 70° 18' 13.665" N 149° 35' 23.572" W 2,200.000 51.000 22.720 1,847.664 835.870 363.547 5,960,919.204 550,658.908 70° 18' 14.370" N 149° 35' 22.697" W 2,300.000 51.000 22.720 1,910.596 907.555 393.562 5,960,991.081 550,688.440 70° 18' 15.075" N 149° 35' 21.822" W 2,400.000 51.000 22.720 1,973.528 979.239 423.578 5,961,062.957 550,717.972 70° 18'15.780" N 149° 35' 20.946" W 2,458.114 51.000 22.720 2,010.100 1 ,020.897 441.021 5,961 ,104.728 550,735.135 70° 18'16.190" N 149° 35' 20.437" W K15 2,500.000 51.000 22.720 2,036.460 1,050.923 453.594 5,961,134.834 550,747.504 70° 18' 16.485" N 149° 35' 20.071" W 2,600.000 51.000 22.720 2,099.392 1 ,122.607 483.609 5,961,206.710 550,777.036 70° 18'17.190" N 149° 35'19.195" W 2,649.999 51.000 22.720 2,130.857 1,158.448 498.617 5,961,242.648 550,791.802 70° 18' 17.543" N 149° 35'18.758" W Begin Dir @ 3.00 : 2650.000ft,2130.858ft 2,700.000 52.500 22.720 2,161.812 1,194.667 513.782 5,961,278.964 550,806.723 70° 18'17.899" N 149° 35' 18.315" W 2,800.000 55.500 22.720 2,220.583 1,269.283 545.025 5,961,353.780 550,837.463 70° 18'18.633" N 149° 35' 17.404" W 2,900.000 58.500 22.720 2,275.041 1,346.633 577.413 5,961,431.338 550,869.330 70° 18' 19.393" N 149° 35' 16.460" W 3,000.000 61.500 22.720 2,325.035 1,426.507 610.858 5,961,511.425 550,902.235 70° 18' 20.179" N 149° 35' 15.484" W 3,021.665 62.150 22.720 2,335.265 1,444.123 618.234 5,961,529.089 550,909.493 70° 18' 20.352" N 149° 35' 15.269" W End Dir, Start Sail @ 62.15: 3021.670ft, 2335.267ft 3,100.000 62.150 22.720 2,371.860 1,508.010 644.985 5,961,593.147 550,935.813 70° 18' 20.980" N 149° 35'14.489" W 3,177.576 62.150 22.720 2,408.100 1 ,571.278 671 .476 5,961,656.585 550,961.878 70° 18' 21.603" N 149° 35'13.716" W T3+675 3,179.503 62.150 22.720 2,409.000 1 ,572.850 672.134 5,961,658.161 550,962.525 70° 18' 21.618" N 149° 35'13.697" W 10-3/4" Csg pt... Drill out 9-718" Hole: 2979.177ft, 2315.000ft 3,179.717 62.150 22.720 2,409.100 1 ,573.024 672.207 5,961,658.336 550,962.597 70° 18' 21 .620" N 149° 35'13.695" W 10 3/4" 3,200.000 62.150 22.720 2,418.575 1,589.566 679.134 5,961,674.922 550,969.412 70° 18' 21.782" N 149° 35'13.493" W 11/8/2004 2:42:18PM Page 4 of9 COMPASS 2003.11 Build 41 nR~r'~Ì\¡f\~ ~~J f ~\\ i~ ~~~:-, li B \1 ¡}-\ f·~·~ . eonc>cÓPhillips SPERRY_SUN HES Planning Report - Geographic . EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E-102 Blat Plan 1 E-1 02 BLat (wp05) Well Plan 1E-102 1E·102 @ 94.100ft (28' above WRP) 1E-102 @94.100ft (28' above WRP) True Minimum Curvature 3,300.000 62.150 22.720 2,465.291 1,671.123 713.283 5,961,756.698 551,003.011 70° 18' 22.584" N 149° 35' 12.497" W 3,400.000 62.150 22.720 2,512.007 1,752.679 747.432 5,961,838.473 551,036.610 70° 18' 23.387" N 149° 35'11.501" W 3,500.000 62.150 22.720 2,558.723 1,834.236 781.582 5,961,920.248 551,070.210 70° 18' 24.189" N 149° 35' 10.504" W 3,600.000 62.150 22.720 2,605.439 1,915.792 815.731 5,962,002.024 551,103.809 70° 18' 24.991" N 149° 35' 09.508" W 3,700.000 62.150 22.720 2,652.155 1,997.349 849.880 5,962,083.799 551,137.408 70° 18' 25.793" N 149° 35' 08.512" W 3,800.000 62.150 22.720 2,698.870 2,078.905 884.029 5,962,165.574 551,171.007 70° 18' 26.595" N 149° 35' 07.516" W 3,900.000 62.150 22.720 2,745.586 2,160.462 918.179 5,962,247.350 551,204.607 70° 18' 27.397" N 149° 35' 06.520" W 4,000.000 62.150 22.720 2,792.302 2,242.018 952.328 5,962,329.125 551,238.206 70° 18' 28.199" N 149° 35' 05.524" W 4,100.000 62.150 22.720 2,839.018 2,323.574 986.477 5,962,410.900 551,271.805 70° 18' 29.001" N 149° 35' 04.527" W 4,200.000 62.150 22.720 2,885.734 2,405.131 1,020.627 5,962,492.676 551,305.404 70° 18' 29.803" N 149° 35' 03.531" W 4,243.596 62.150 22.720 2,906.100 2,440.686 1,035.514 5,962,528.326 551,320.052 70° 18' 30.153" N 149° 35' 03.097" W Ugn\l C 4,300.000 62.150 22.720 2,932.450 2,486.687 1,054.776 5,962,574.451 551,339.004 70° 18' 30.605" N 149° 35' 02.535" W 4,400.000 62.150 22.720 2,979.165 2,568.244 1,088.925 5,962,656.226 551,372.603 70° 18' 31.407" N 149° 35' 01.538" W 4,500.000 62.150 22.720 3,025.881 2,649.800 1,123.074 5,962,738.002 551,406.202 70° 18' 32.209" N 149° 35' 00.542" W 4,600.000 62.150 22.720 3,072.597 2,731.357 1,157.224 5,962,819.777 551,439.801 70° 18' 33.011" N 149° 34' 59.546" W 4,700.000 62.150 22.720 3,119.313 2,812.913 1,191.373 5,962,901.552 551,473.401 70° 18' 33.813" N 149° 34' 58.549" W 4,800.000 62.150 22.720 3,166.029 2,894.470 1 ,225.522 5,962,983.328 551,507.000 70° 18' 34.615" N 149° 34' 57.553" W 4,870.792 62.150 22.720 3,199.100 2,952.205 1,249.697 5,963,041.218 551,530.785 70° 18' 35.183" N 149° 34' 56.848" W Ugnu B 4,900.000 62.150 22.720 3,212.745 2,976.026 1,259.671 5,963,065.103 551,540.599 70° 18' 35.417" N 149° 34' 56.557" W 4,990.666 62.150 22.720 3,255.100 3,049.970 1,290.633 5,963,139.245 551,571.062 70° 18' 36.145" N 149° 34' 55.653" W Ugnu A 5,000.000 62.150 22.720 3,259.461 3,057.583 1 ,293.821 5,963,146.878 551,574.198 70° 18' 36.219" N 149° 34' 55.560" W 5,100.000 62.150 22.720 3,306.176 3,139.139 1,327.970 5,963,228.654 551,607.797 70° 18' 37.021" N 149° 34' 54.564" W 5,200.000 62.150 22.720 3,352.892 3,220.696 1,362.119 5,963,310.429 551,641.397 70° 18' 37.824" N 149° 34' 53.567" W 5,300.000 62.150 22.720 3,399.608 3,302.252 1 ,396.268 5,963,392.204 551,674.996 70° 18' 38.626" N 149° 34' 52.571" W 5,400.000 62.150 22.720 3,446.324 3,383.809 1,430.418 5,963,473.979 551,708.595 70° 18' 39.428" N 149° 34' 51.574" W 5,407.745 62.150 22.720 3,449.942 3,390.126 1,433.063 5,963,480.313 551,711.198 70° 18' 39.490" N 149° 34' 51.497" W Begin Dir @4.00: 5407.750ft,3449.944ft 5,408.083 62.162 22.713 3,450.100 3,390.401 1,433.178 5,963,480.590 551,711.311 70° 18' 39.492" N 149° 34' 51.494" W K13 5,500.000 65.400 20.774 3,490.706 3,466.986 1 ,463.701 5,963,557.370 551,741.318 70° 18' 40.246" N 149° 34' 50.603" W 5,600.000 68.951 18.775 3,529.492 3,553.709 1,494.857 5,963,644.291 551,771.889 70° 18' 41.098" N 149° 34' 49.694" W 5,700.000 72.524 16.870 3,562.478 3,643.567 1,523.728 5,963,734.331 551,800.155 70° 18' 41.982" N 149° 34' 48.851" W 5,800.000 76.115 15.039 3,589.501 3,736.121 1 ,550.173 5,963,827.051 551,825.978 70° 18' 42.892" N 149° 34' 48.079" W 5,838.452 77.500 14.350 3,598.277 3,772.333 1,559.669 5,963,863.322 551,835.230 70° 18' 43.248" N 149° 34' 47.802" W End Dir, Start Sail @77.50:5838.46Oft, 359B.278ft 5,900.000 77.500 14.350 3,611.598 3,830.547 1,574.561 5,963,921.630 551,849.731 70° 18' 43.821" N 149° 34' 47.367" W 5,934.661 77.500 14.350 3,619.100 3,863.331 1 ,582.948 5,963,954.465 551,857.897 70° 18' 44.143" N 149° 34' 47.122" W D 6,000.000 77.500 14.350 3,633.242 3,925.131 1,598.758 5,964,016.364 551,873.292 70° 18' 44.751" N 149° 34' 46.661" W 6,003.964 77.500 14.350 3,634.100 3,928.880 1,599.717 5,964,020.119 551,874.226 70° 18' 44.788" N 149° 34' 46.633" W 1E-102 WS D (Heel) -1E-102 WS D Tgt 4 6,036.306 77.500 14.350 3,641.100 3,959.470 1,607.543 5,964,050.758 551,881.846 70° 18' 45.089" N 149° 34' 46.404" W 1E-102 WS D Tgt 5 6,100.000 77.500 14.350 3,654.886 4,019.714 1,622.955 5,964,111.098 551,896.853 70° 18' 45.681" N 149° 34' 45.954" W 6,128.452 77.500 14.350 3,661 .044 4,046.625 1,629.840 5,964,138.052 551,903.556 70° 18' 45.946" N 149° 34' 45.753" W 6,128.710 77.510 14.350 3,661.1 00 4,046.870 1,629.902 5,964,138.297 551,903.617 70° 18' 45.948" N 149° 34' 45.751" W 1E-102 WS DTgt 2 6,147.780 78.273 14.350 3,665.100 4,064.933 1,634.523 5,964,156.389 551,908.117 70° 18' 46.126" N 149° 34' 45.616" W C - 1E-102 WS D Tgt 3 6,200.000 80.361 14.350 3,674.779 4,114.644 1,647.241 5,964,206.179 551,920.500 70° 18' 46.615" N 149° 34' 45.245" W 6,300.000 84.361 14.350 3,688.068 4,210.645 1,671.800 5,964,302.333 551,944.414 70° 18' 47.559" N 149° 34' 44.528" W 6,310.926 84.799 14.350 3,689.100 4,221.183 1,674.496 5,964,312.887 551,947.039 70° 18' 47.663" N 149° 34' 44.449" W 1E-102 WS B IHeel) 111812004 2:42:18PM Page 5 019 COMPASS 2003.11 Build 41 n (1il"'<'C;~ .~, " ~o. Ii i , ¡'I J\ ~ 1\. Ii 'U ot't~1 ~\¡i;r~L . Cor1ocÓÁ1illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-102 Plan 1E·102 BLat Plan 1 E-1 02 BLat (wp05) 6,335.260 85.772 14.350 3,691.100 4,244.678 1,680.507 5,964,336.420 551,952.892 70° 18' 47.894" N 149° 34' 44.274" W B 6,400.000 88.361 14.350 3,694.412 4,307.310 1,696.530 5,964,399.152 551,968.494 70° 18' 48.510" N 149° 34' 43.806" W 6,426.202 89.410 14.350 3,694.922 4,332.690 1,703.023 5,964,424.572 551,974.816 70° 18' 48.759" N 149° 34' 43.616" W 6,426.591 89.425 14.354 3,694.926 4,333.067 1,703.119 5,964,424.950 551,974.910 70° 18' 48.763" N 149° 34' 43.614" W 6,500.000 89.425 14.354 3,695.662 4,404.180 1,721.317 5,964,496.177 551,992.629 70° 18' 49.462" N 149° 34' 43.082" W 7--5/8" Csg Pt ... Begin 6-3/4" hole: 6500ft, 3696ft -- Continue Dir - 7 5/8 6,600.000 89.425 14.354 3,696.665 4,501 .054 1,746.106 5,964,593.205 552,016.767 70° 18' 50.415" N 149° 34' 42.358" W 6,700.000 89.425 14.354 3,697.669 4,597.928 1,770.895 5,964,690.232 552,040.904 70° 18' 51.368" N 149° 34' 41 .635" W 6,800.000 89.425 14.354 3,698.672 4,694.801 1,795.684 5,964,787.260 552,065.042 70° 18' 52.320" N 149° 34' 40.911" W 6,900.000 89.425 14.354 3,699.675 4,791 .675 1,820.473 5,964,884.288 552,089.180 70° 18' 53.273" N 149° 34' 40.187" W 7,000.000 89.425 14.354 3,700.678 4,888.548 1 ,845.263 5,964,981.316 552,113.318 70° 18' 54.226" N 149° 34' 39.463" W 7,100.000 89.425 14.354 3,701.682 4,985.422 1,870.052 5,965,078.344 552,137.455 70° 18' 55.178" N 149° 34' 38.739" W 7,200.000 89.425 14.354 3,702.685 5,082.295 1,894.841 5,965,175.372 552,161 .593 70° 18' 56.131" N 149° 34' 38.015" W 7,300.000 89.425 14.354 3,703.688 5,179.169 1,919.630 5,965,272.400 552,185.731 70° 18' 57.084" N 149° 34' 37.291" W 7,400.000 89.425 14.354 3,704.691 5,276.043 1,944.419 5,965,369.428 552,209.869 70° 18' 58.036" N 149° 34' 36.567" W 7,500.000 89.425 14.354 3,705.695 5,372.916 1 ,969.209 5,965,466.456 552,234.006 70° 18' 58.989" N 149° 34' 35.843" W 7,600.000 89.425 14.354 3,706.698 5,469.790 1 ,993.998 5,965,563.484 552,258.144 70° 18' 59.942" N 149° 34' 35.119" W 7,700.000 89.425 14.354 3,707.701 5,566.663 2,018.787 5,965,660.512 552,282.282 70° 19' 00.894" N 149° 34' 34.395" W 7,800.000 89.425 14.354 3,708.704 5,663.537 2,043.576 5,965,757.540 552,306.420 70° 19' 01.847' N 149° 34' 33.671" W 7,900.000 89.425 14.354 3,709.708 5,760.410 2,068.365 5,965,854.568 552,330.558 70° 19' 02.800" N 149° 34' 32.947' W 8,000.000 89.425 14.354 3,710.711 5,857.284 2,093.155 5,965,951.596 552,354.695 70° 19' 03.753" N 149° 34' 32.223" W 8,1 00.000 89.425 14.354 3,711.714 5,954.158 2,117.944 5,966,048.623 552,378.833 70° 19' 04.705" N 149° 34' 31 .499" W 8,200.000 89.425 14.354 3,712.717 6,051.031 2,142.733 5,966,145.651 552,402.971 70° 19' 05.658" N 149° 34' 30.775" W 8,300.000 89.425 14.354 3,713.721 6,147.905 2,167.522 5,966,242.679 552,427.109 70° 19' 06.611" N 149° 34' 30.051" W 8,400.000 89.425 14.354 3,714.724 6,244.778 2,192.311 5,966,339.707 552,451.246 70° 19' 07.563" N 149° 34' 29.326" W 8,500.000 89.425 14.354 3,715.727 6,341.652 2,217.101 5,966,436.735 552,475.384 70° 19' 08.516" N 149° 34' 28.602" W 8,600.000 89.425 14.354 3,716.730 6,438.525 2,241.890 5,966,533.763 552,499.522 70° 19' 09.469" N 149° 34' 27.878" W 8,700.000 89.425 14.354 3,717.734 6,535.399 2,266.679 5,966,630.791 552,523.660 70° 19' 10.421" N 149° 34' 27.154" W 8,800.000 89.425 14.354 3,718.737 6,632.273 2,291.468 5,966,727.819 552,547.797 70° 19' 11.374" N 149° 34' 26.430" W 8,900.000 89.425 14.354 3,719.740 6,729.146 2,316.258 5,966,824.847 552,571.935 70° 19' 12.327" N 149° 34' 25.705" W 8,919.663 89.425 14.354 3,719.937 6,748.194 2,321.132 5,966,843.925 552,576.681 70° 19' 12.514" N 149° 34' 25.563" W 8,942.372 89.755 13.507 3,720.100 6,770.235 2,326.599 5,966,866.000 552,582.000 70° 19' 12.731" N 149° 34' 25.403" W 1E-102 WS B Tgt 2 8,967.300 89.639 14.497 3,720.232 6,794.421 2,332.630 5,966,890.224 552,587.869 70° 19' 12.968" N 149° 34' 25.227" W 9,000.000 89.639 14.497 3,720.438 6,826.079 2,340.816 5,966,921.933 552,595.842 70° 19' 13.280" N 149° 34' 24.988" W 9,100.000 89.639 14.497 3,721.068 6,922.893 2,365.849 5,967,018.903 552,620.224 70° 19' 14.232" N 149° 34' 24.256" W 9,200.000 89.639 14.497 3,721.698 7,019.707 2,390.882 5,967,115.873 552,644.606 70° 19 15.184" N 149° 34' 23.525" W 9,300.000 89.639 14.497 3,722.327 7,116.521 2,415.915 5,967,212.843 552,668.988 70° 19' 16.136" N 149° 34' 22.794" W 9,400.000 89.639 14.497 3,722.957 7,213.335 2,440.948 5,967,309.813 552,693.370 70° 19' 17.088" N 149° 34' 22.062" W 9,429.134 89.639 14.497 3,723.141 7,241.541 2,448.241 5,967,338.064 552,700.473 70° 19' 17.366" N 149° 34' 21.849" W 9,500.000 89.885 12.387 3,723.435 7,310.461 2,464.713 5,967,407.087 552,716.482 70° 1 g 18.043" N 149° 34' 21.368" W 9,600.000 90.233 9.407 3,723.332 7,408.647 2,483.613 5,967,505.387 552,734.722 70° W 19.009" N 149° 34' 20.815" W 9,643.078 90.383 8.122 3,723.100 7,451.221 2,490.177 5,967,548.000 552,741.000 70° 19' 19.428" N 149° 34' 20.623" W 1Ec102 WSBTgt 3 9,644.290 90.393 8.157 3,723.092 7,452.420 2,490.348 5,967,549.200 552,741.163 70° 19' 19.439" N 149° 34' 20.618" W 9,700.000 90.393 8.157 3,722.710 7,507.566 2,498.253 5,967,604.392 552,748.698 70° 19' 19.982" N 149° 34' 20.387' W 9,800.000 90.393 8.157 3,722.024 7,606.552 2,512.441 5,967,703.461 552,762.222 70° 19' 20.955" N 149° 34' 19.972" W 9,900.000 90.393 8.157 3,721.339 7,705.538 2,526.630 5,967,802.530 552,775.746 70° 19' 21.929" N 149° 34' 19.557" W 10,000.000 90.393 8.157 3,720.653 7,804.524 2,540.818 5,967,901.599 552,789.271 70° 19' 22.902" N 149° 34' 19.142" W 10,100.000 90.393 8.157 3,719.968 7,903.509 2,555.007 5,968,000.668 552,802.795 70° 19' 23.876" N 149° 34'18.727" W 10,200.000 90.393 8.157 3,719.282 8,002.495 2,569.196 5,968,099.737 552,816.319 70° 19' 24.849" N 149° 34' 18.312" W 10,300.000 90.393 8.157 3,718.597 8,101.481 2,583.384 5,968,198.806 552,829.843 70° 19' 25.823" N 149° 34' 17.896" W 10,400.000 90.393 8.157 3,717.912 8,200.467 2,597.573 5,968,297.875 552,843.368 70° 19' 26.796" N 149° 34' 17.481" W 10,500.000 90.393 8.157 3,717.226 8,299.453 2,611.761 5,968,396.944 552,856.892 70° 19' 27.769" N 149° 34' 17.066" W 10,600.000 90.393 8.157 3,716.541 8,398.439 2,625.950 5,968,496.014 552,870.416 70° 19' 28.743" N 149° 34' 16.651" W 10,700.000 90.393 8.157 3,715.855 8,497.425 2,640.138 5,968,595.083 552,883.940 70° 19' 29.716" N 149° 34' 16.236" W 10,800.000 90.393 8.157 3,715.170 8,596.411 2,654.327 5,968,694.152 552,897.465 70° 19' 30.690" N 149° 34' 15.821" W 11Æ/2004 2:42:18PM Page 60f9 COMPASS 2003.11 Build 41 f'\ f" it \ I ^ ~ ; ,,(' ~ ! '<.1,°\ - ~. ) ~ ^i, .: t) ~u ~ '":iP':' ~, ". -, . eonocciPt,illips SPERRY_SUN HES Planning Report - Geographic . EDM 2003.11 Single User Db ConocoPhUlips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E·102 BLat Plan 1 E-1 02 BLat (wp05) Well Plan 1E-102 1 E-102 @ 94.100ft (28' above WRP) 1E-102 @ 94.100ft (28' above WRP) True Minimum Curvature 10,900.000 90.393 11,000.000 90.393 11,100.000 90.393 11,200.000 90.393 11,300.000 90.393 11,400.000 90.393 11,500.000 90.393 11,600.000 90.393 11,700.000 90.393 11,800.000 90.393 11,900.000 90.393 12,000.000 90.393 12,100.000 90.393 12,200.000 90.393 12,300.000 90.393 12,400.000 90.393 12,500.000 90.393 12,600.000 90.393 12,700.000 90.393 12,800.000 90.393 12,900.000 90.393 13,000.000 90.393 13,100.000 90.393 13,200.000 90.393 13,300.000 90.393 13,400.000 90.393 13,437.921 90.393 13,500.000 89.881 13,535.025 89.592 1E-102 WS B Tgt 4 13,600.000 89.592 5.356 3,697.563 11,368.691 3,046.099 5,971,468.722 553,270.631 70° 19' 57.953" N 13,700.000 89.592 5.356 3,698.275 11,468.251 3,055.433 5,971,568.334 553,279.298 70° 19' 58.933" N 13,800.000 89.592 5.356 3,698.988 11,567.812 3,064.768 5,971,667.945 553,287.965 70° 19' 59.912" N 13,900.000 89.592 5.356 3,699.700 11,667.373 3,074.102 5,971,767.557 553,296.632 70° 20' 00.891" N 14,000.000 89.592 5.356 3,700.412 11,766.934 3,083.437 5,971,867.168 553,305.299 70°20'01.870" N 14,100.000 89.592 5.356 3,701.125 11,866.495 3,092.772 5,971,966.779 553,313.967 70° 20' 02.849" N 14,200.000 89.592 5.356 3,701.837 11 ,966.055 3,102.106 5,972,066.391 553,322.634 70° 20' 03.828" N 14,300.000 89.592 5.356 3,702.549 12,065.616 3,111.441 5,972,166.002 553,331.301 70° 20' 04.807" N 14,377.298 89.592 5.356 3,703.100 12,142.575 3,118.656 5,972,243.000 553,338.000 70° 20' 05.564" N Target (Toe) : 14377.290ft, 3703.100ft, (3207ftFNL, 2359ft FEL, Sec3-T11N-R10E - 6 3/4" Open Hole -1E-102 WS BIgt 5 111812004 2:42:18PM 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 8.157 6.368 5.356 3,714.484 8,695.397 3,713.799 8,794.383 3,713.113 8,893.369 3,712.428 8,992.355 3,711.742 9,091.341 3,711.057 9,190.327 3,710.371 9,289.313 3,709.686 9,388.298 3,709.000 9,487.284 3,708.315 9,586.270 3,707.629 9,685.256 3,706.944 9,784.242 3,706.258 9,883.228 3,705.573 9,982.214 3,704.887 10,081.200 3,704.202 10,180.186 3,703.516 10,279.172 3,702.831 10,378.158 3,702.145 10,477.144 3,701.460 10,576.130 3,700.774 10,675.116 3,700.089 10,774.102 3,699.403 10,873.087 3,698.718 10,972.073 3,698.032 11 ,071.059 3,697.347 11,170.045 3,697.087 11,207.581 3,696.939 11,269.160 3,697.100 11,304.001 2,668.516 2,682.704 2,696.893 2,711.081 2,725.270 2,739.458 2,753.647 2,767.835 2,782.024 2,796.213 2,810.401 2,824.590 2,838.778 2,852.967 2,867.155 2,881.344 2,895.532 2,909.721 2,923.910 2,938.098 2,952.287 2,966.475 2,980.664 2,994.852 3,009.041 3,023.230 3,028.610 3,036.457 3,040.033 5,968,793.221 5,968,892.290 5,968,991.359 5,969,090.428 5,969,189.497 5,969,288.566 5,969,387.635 5,969,486.704 5,969,585.773 5,969,684.843 5,969,783.912 5,969,882.981 5,969,982.050 5,970,081.119 5,970,180.188 5,970,279.257 5,970,378.326 5,970,477.395 5,970,576.464 5,970,675.533 5,970,774.602 5,970,873.671 5,970,972.741 5,971,071.810 5,971,170.879 5,971,269.948 5,971,307.515 5,971,369.139 5,971,404.000 Page 70f9 552,910.989 552,924.513 552,938.037 552,951.562 552,965.086 552,978.610 552,992.134 553,005.658 553,019.183 553,032.707 553,046.231 553,059.755 553,073.280 553,086.804 553,100.328 553,113.852 553,127.377 553,140.901 553,154.425 553,167.949 553,181.474 553,194.998 553,208.522 553,222.046 553,235.571 553,249.095 553,254.223 553,261.657 553,265.000 70° 19' 31.663" N 70° 19' 32.637" N 70° 19' 33.610" N 70° 19' 34.584" N 70° 19' 35.557" N 70° 19' 36.531" N 70° 19' 37.504" N 70° 19' 38.478" N 70° 19' 39.451" N 70° 19' 40.425" N 70° 19' 41.398" N 70° 19' 42.371" N 70° 19' 43.345" N 70° 19' 44.318" N 70° 19' 45.292" N 70° 19' 46.265" N 70° 19' 47.239" N 70° 19' 48.212" N 70° 19' 49.186" N 70° 19' 50.159" N 70° 19' 51.133" N 70° 19' 52.106" N 70° 19' 53.080" N 70° 19' 54.053" N 70° 19' 55.026" N 70° 19' 56.000" N 70° 19' 56.369" N 70° 19' 56.975" N 70° 19' 57.317" N 149° 34'15.406" W 149° 34' 14.990" W 149° 34' 14.575" W 149° 34'14.160" W 149° 34'13.745" W 149° 34' 13.329" W 149° 34' 12.914" W 149° 34' 12.499" W 149° 34'12.084" W 149° 34' 11.668" W 149° 34' 11.253" W 149° 34'10.838" W 149° 34' 10.423" W 149° 34' 10.007" W 149° 34' 09.592" W 149° 34' 09.177" W 149° 34' 08.761" W 149° 34' 08.346" W 149° 34' 07.930" W 149° 34' 07.515" W 149° 34' 07.100" W 149° 34' 06.684" W 149° 34' 06.269" W 149° 34' 05.853" W 149° 34' 05.438" W 149° 34' 05.023" W 149° 34' 04.865" W 149° 34' 04.635" W 149° 34' 04.530" W 149° 34' 04.352" W 149° 34' 04.079" W 149° 34' 03.805" W 149° 34' 03.531" W 149° 34' 03.257" W 149° 34' 02.984" W 149° 34' 02.710" W 149° 34' 02.436" W 149° 34' 02.224" W COMPASS 2003.11 Build 41 . eonocciPt,illips SPERRY_SUN HES Planning Report - Geographic . EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan1E-102 Plan 1E-102 BLat Plan 1 E-1 02 BLat (wp05) Well Plan 1E-102 1E-102 @ 94.100ft (28' above WRP) 1 £-1 02 @ 94.100ft (28' above WRP) True Minimum Curvature 1 E-1 02 WS D Tgt 3 0.00 0.00 3,665.100 7,451.221 2,490.177 5,967,548.000 - plan misses by 3492.720ft at 6147.780ft MD (3665.100 TVD, 4064.933 N, 1634.523 E) - Point 552,741.000 70° 19'19.428" N 149° 34' 20.623" W 1E-102 WS D (Heel) 0.00 0.003,634.100 3,866.858 1,584.074 5,963,958.000 - plan misses by 63.964ft at 6003.964ft MD (3634.100 TVD. 3928.880 N, 1599.717 E) - Point 1E-102WSDTgt2 0.00 0.003,661.100 6,770.235 2,326.599 5,966,866.000 - plan misses by 2811.068ft at 6128.71 Oft MD (3661.100 TVD, 4046.870 N, 1629.902 E) - Point 1 E-102 WS B Tgt 5 0.00 0.003,703.100 12,142.575 3,118.656 5,972,243.000 - plan misses by 1816.005ft at 12560.727ft MD (3703.100 TVD, 10339.283 N. 2904.149 E) - Point 1E-102 WS B (Heel) 0.00 0.003,689.100 3,866.858 1,584.074 5,963,958.000 - plan misses by 365.680ft at 6310.926ft MD (3689.100 TVD, 4221.183 N, 1674.496 E) - Point 551,859.000 70° 18' 44.178" N 149° 34' 47.089" W 552,582.000 70° 19'12.731" N 149° 34' 25.403" W 553,338.000 70° 20' 05.564" N 149° 34' 02.224" W 551,859.000 70° 18' 44.178" N 149° 34' 47.089" W 1E-102WSBTgt2 - plan hits target - Point 0.00 0.00 3,720.100 6,770.235 2,326.599 5,966,866.000 552,582.000 70° 19' 12.731" N 149° 34' 25.403" W 1 E-102 WS B Tgt 3 - plan hits target - Point 1 E-1 02 WS D Tgt 4 0.00 0.00 3,634.100 11,304.001 3,040.033 5,971,404.000 553,265.000 70° 19' 57.317" N 149° 34' 04.530" W - plan misses by 7514.447ft at6003.964ft MD (3634.100 TVD, 3928.880 N, 1599.717 E) - Point 0.00 0.003,723.100 7,451.221 2,490.177 5,967,548.000 552,741.000 70019'19.428"N 149°34'20.623"W 1 E-102 WS D Tgt 5 0.00 0.003,641.100 12,142.575 3,118.656 5,972,243.000 553,338.000 70° 20' 05.564" N 149° 34' 02.224" W - plan misses by 8321.458ft at 6036.306ft MD (3641.100 TVD, 3959.470 N, 1607.543 E) - Point 1E-102WS B Tgt4 - plan hits target - Point 0.00 0.00 3,697.100 11,304.001 3,040.033 5,971,404.000 553,265.000 70° 19' 57.317" N 149° 34' 04.530" W 3,179.717 6,500.000 14,377.290 103/4" 75/8 6 3/4" Open Hole 10-3/4 7-5/8 6-3/4 13-1/2 9-7/8 6-314 111812004 2:42:18PM Page 8of9 COMPASS 2003.11 Build 41 nnf fj ~m.,....'··' ~- . ~. >y < 0.' 'f i ~.) ~ \ : . Conoa~p¡.lÎllips (fI) 1,660.428 1,994.121 2,458.114 3,177.576 4,243.596 4,870.792 4,990.666 5,408.083 5,934.661 6,147.780 6,335.260 . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-102 Plan 1E-102 BLat Plan 1E·102 BLat (wp05) Permafrost T3 K15 T3+675 Ugnu C Ugnu B Ugnu A K13 o C B Well Plan 1 E-1 02 1E-102 @ 94. 1 OOft (28' above WRP) 1E-102 @ 94.100ft (28' above WRP) True Minimum Curvature 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 28.000 400.010 733.400 985.200 1,605.700 2,650.000 3,021.670 3,179.503 5,407.750 5,838.460 6,500.000 14,377.290 11/8/2004 2:42:18PM lo +Nl (It) 0.000 0.000 25.138 83.253 409.851 1,158.449 1,444.127 1 ,572.850 3,390.129 3,772.340 4,404.180 12,142.567 Page 9 of9 f'\í~ r·( " SHL -- 4789ft FNL & 223ft FEL, Sec16-T11 N-R1 OE Begin Dir @ 3.00 : 400.01 Oft,400.01 Oft Continue Dir @ 4.00 : 733.400ft, 731.709ft Continue Dir @ 5.00: 985.2ooft, 974.628ft End Dir, Start Sail @ 51.00: 1605.7ooft, 1473.659ft Begin Dir @ 3.00 : 2650.000ft,2130.858ft End Dir, Start Sail @ 62.15: 3021.670ft, 2335.267ft 10-314" Csg PI ... Drill out 9-718" Hole: 2979.177ft, 2315.00Oft Begin Dir @ 4.00 : 5407.75Oft,3449.944ft End Dir, Start Sail @ 77.50: 5838.460ft, 3598.278ft 7-5/8" Csg pt ... Begin 6-3/4" hole: 650Oft, 3696ft -- Continue Dir Target (Toe): 14377.290ft, 3703.100ft, (3207ft FNL, 2359ft FEL, Sec3-T COMPASS 2003.11 Build 41 . . , i~·II· Conocurlll . IPS ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-1 02 Plan 1 E-1 02 D Lat Plan: Plan 1E-102 D Lat (wp05) Standard Planning Report - Geographic 08 November, 2004 n ;, ~; V' . Co~illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhiUips Alaska Inc_ (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-102 Plan 1E·102 D Lat Plan 1 E-102 D Lat (wp05) Well Plan 1E-102 1E-102 @ 94.100ft (28' above WRP) 1 E-102 @94.100ft(28' aboveWRP) True _ Minimum Curvature Project Map System: Geo Datum: Map Zone: Kuparuk River Unit, North Slope Alaska, United States US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 1 E Pad Site Position: From: Map Position Uncertainty: 0.000 ft Northing: Easting: Slot Radius: 5,959,760.240ft 549,889.51 Oft 0" Latitude: Longitude: Grid Convergence: 70° 18' 03.021" N 149° 35' 45.358" W 0.38 ° Well Plan 1 E-102 Well Position +N/-S +E/-W Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5,960,081.000 ft 550,301.000 ft ft Latitude: Longitude: Ground Level: 70° 18' 06.149" N 149° 35' 33.297" W 0.000 ft Wellbore Plan1E-102 D Lat BGGM2004 11/8/2004 24.54 80.74 57,577 Design Audit Notes: Version: Plan 1 E-102 D Lat (wp05) Phase: PLAN Tie On Depth: 5,938.520 Depth From (lVO) - (ft) 28.000 0.000 14.404 5,938.520 77-500 14.350 3,619.935 3,866.982 1 ,583.882 0.00 0.00 0.00 0.00 5,950.520 79.408 14.346 3,622.337 3,878.372 1,586.796 15_90 15.90 -0.03 359.88 5,968.520 79-408 14.346 3,625_645 3,895.514 1 ,591-180 0.00 0_00 0.00 0.00 6,170.040 89-484 14_346 3,645.124 4,089.583 1,640.813 5.00 5.00 0.00 0.00 6,253.387 91.984 14_300 3,644.056 4,170.327 1,661 -429 3.00 3.00 -0.06 358.95 6,355.947 91.984 14.300 3,640.506 4,269.649 1,686.746 0.00 0.00 0.00 0.00 6,439.295 89.484 14_346 3,639.438 4,350.393 1,707.362 3.00 -3.00 0.06 178.95 8,937.295 89.484 14.346 3,661.935 6,770.400 2,326.284 0.00 0.00 0.00 0.00 8,944-412 89_612 14.517 3,661_991 6,777.292 2,328.057 3.00 1_80 2.40 53.08 9,422.926 89.612 14.517 3,665.229 7,240.519 2,448.000 0.00 0.00 0.00 0.00 9,637.922 90-456 8.122 3,665-100 7,451.221 2,490.177 3.00 0_39 -2.97 -82-49 1 E-1 02 WS D Tgt 3 9,639.169 90.468 8.158 3,665.090 7,452.456 2,490.353 3_00 0.96 2.84 71.37 13,431.363 90-468 8.158 3,634.093 11,206.152 3,028.440 0.00 0.00 0.00 0.00 13,529.907 89.524 5.356 3,634.100 11,304.001 3,040.033 3.00 -0.96 -2.84 -108.631E-102WSDTgt4 14,372.188 89-524 5.356 3,641-100 12,142.575 3,118.656 0.00 0.00 0.00 0.00 1 E-1 02 WS D Tgt 5 11/812004 2:41:32PM () ~ F ,,~) pa~ 20f7 ~:1 ~': r (,:) t [ COMPASS 2003.11 Build 41 . Co~illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E·102 D lat Plan 1 E-102 D lat (wp05) Well Plan 1E-102 1E·102 @ 94.100ft (28' above WRP) 1£-102 @ 94.100ft (28' above WRP) True Minimum Curvature 0.000 0.000 0.000 0.000 0.000 0.000 5,960,081.000 550,301.000 70° 18' 06.149" N 149° 35' 33.297" W 8-75/8 1 00.000 0.000 0.000 100.000 0.000 0.000 5,960,081.000 550,301.000 70° 18' 06.149" N 149° 35' 33.297" W 400.000 0.000 0.000 400.000 0.000 0.000 5,960,081.000 550,301.000 70° 18' 06.149" N 149° 35' 33.297" W 500.000 3.000 30.000 499.954 2.267 1.309 5,960,083.275 550,302.293 70° 18' 06.172" N 149° 35' 33.259" W 600.000 6.000 30.000 599.635 9.061 5.231 5,960,090.095 550,306.170 70° 18' 06.239" N 149° 35' 33.145" W 700.000 9.000 30.000 698.768 20.364 11.757 5,960,101.440 550,312.619 70° 18' 06.350" N 149° 35' 32.955" W 800.000 12.636 27.923 797.008 36.586 20.818 5,960,117.721 550,321.570 70° 18' 06.509" N 149° 35' 32.690" W 900.000 16.608 26.031 893.751 59.101 32.216 5,960,140.310 550,332.817 70° 18' 06.731" N 149° 35' 32.358" W 1 ,000.000 20.739 24.875 988.502 87.926 45.893 5,960,169.222 550,346.299 70° 18' 07.014" N 149° 35' 31.959" W 1,100.000 25.732 24.208 1,080.363 123.811 62.252 5,960,205.213 550,362.416 70° 18' 07.367" N 149° 35' 31.482" W 1 ,200.000 30.727 23.746 1,168.441 167.022 81.454 5,960,248.548 550,381.326 70° 18' 07.792" N 149° 35' 30.923" W 1,300.000 35.724 23.403 1 ,252.066 217.231 103.351 5,960,298.897 550,402.884 70° 18' 08.286" N 149° 35' 30.284" W 1,400.000 40.721 23.134 1 ,330.602 274.056 127.778 5,960,355.879 550,426.928 70° 18' 08.845" N 149° 35' 29.572" W 1,500.000 45.719 22.915 1,403.452 337.064 154.548 5,960,419.058 550,453.273 70° 18' 09.464" N 149° 35' 28.791" W 1 ,600.000 50.717 22.730 1,470.060 405.775 183.458 5,960,487.954 550,481.720 70° 18'10.140" N 149° 35' 27.948" W 1,660.428 51.000 22.720 1,508.100 449.084 201.592 5,960,531.379 550,499.562 70° 18' 10.566" N 149° 35' 27.420" W Permafrost 1,700.000 51.000 22.720 1,533.003 477.451 213.470 5,960,559.822 550,511.249 70° 18' 10.845" N 149° 35' 27.073" W 1,800.000 51.000 22.720 1,595.935 549.135 243.486 5,960,631.699 550,540.781 70° 18' 11.550" N 149° 35' 26.198" W 1,900.000 51.000 22.720 1,658.867 620.819 273.501 5,960,703.576 550,570.313 70° 18' 12.255" N 149° 35' 25.323" W 1,994.121 51.000 22.720 1,718.099 688.289 301.752 5,960,771.227 550,598.109 70° 18'12.919" N 149° 35' 24.499" W T3 2,000.000 51.000 22.720 1,721.799 692.503 303.517 5,960,775.452 550,599.845 70° 18' 12.960" N 149° 35' 24.447" W 2,100.000 51.000 22.720 1,784.731 764.187 333.532 5,960,847.329 550,629.377 70° 18' 13.665" N 149° 35' 23.572" W 2,200.000 51.000 22.720 1,847.663 835.872 363.548 5,960,919.205 550,658.909 70° 18' 14.370" N 149° 35' 22.697" W 2,300.000 51.000 22.720 1,910.595 907.556 393.564 5,960,991.082 550,688.441 70° 18' 15.075" N 149° 35' 21.822" W 2,400.000 51.000 22.720 1,973.527 979.240 423.579 5,961,062.958 550,717.973 70° 18' 15.780" N 149° 35' 20.946" W 2,458.114 51.000 22.720 2,010.100 1,020.899 441.022 5,961,104.729 550,735.136 70° 18'16.190" N 149° 35' 20.437" W K15 2,500.000 51.000 22.720 2,036.459 1 ,050.924 453.595 5,961 ,134.835 550,747.505 70° 18' 16.485" N 149° 35' 20.071" W 2,600.000 51.000 22.720 2,099.391 1 ,122.608 483.610 5,961,206.712 550,777.038 70° 18'17.190" N 149° 35'19.195" W 2,700.000 52.500 22.720 2,161.811 1,194.668 513.783 5,961,278.965 550,806.725 70° 18' 17.899" N 149° 35' 18.315" W 2,800.000 55.500 22.720 2,220.582 1 ,269.284 545.026 5,961,353.781 550,837.464 70° 18' 18.633" N 149° 35'17.404" W 2,900.000 58.500 22.720 2,275.040 1 ,346.635 577.414 5,961,431.339 550,869.331 70° 18' 19.393" N 149° 35' 16.460" W 3,000.000 61.500 22.720 2,325.034 1 ,426.508 610.859 5,961,511.427 550,902.237 70° 18' 20.179" N 149° 35' 15.484" W 3,100.000 62.150 22.720 2,371 .858 1 ,508.012 644.986 5,961 ,593.149 550,935.814 70° 18' 20.980" N 149° 35' 14.489" W 3,177.576 62.150 22.720 2,408.098 1 ,571 .280 671.478 5,961,656.587 550,961.879 70° 18' 21.603" N 149° 35'13.716" W T3+675 3,179.720 62.150 22.720 2,409.100 1,573.028 672.210 5,961,658.340 550,962.599 70° 18' 21.620" N 149° 35'13.695" W 10 3/4" 3,200.000 62.150 22.720 2,418.574 1,589.568 679.135 5,961,674.924 550,969.413 70° 18' 21.782" N 149° 35' 13.493" W 3,300.000 62.150 22.720 2,465.290 1,671.124 713.284 5,961,756.699 551,003.013 70° 18' 22.584" N 149° 35' 12.497" W 3,400.000 62.150 22.720 2,512.006 1 ,752.681 747.434 5,961 ,838.475 551,036.612 70° 18' 23.387" N 149° 35'11.501" W 3,500.000 62.150 22.720 2,558.721 1 ,834.237 781.583 5,961 ,920.250 551,070.211 70° 18' 24.189" N 149° 35' 10.504" W 3,600.000 62.150 22.720 2,605.437 1 ,915.794 815.732 5,962,002.025 551,103.810 70° 18' 24.991" N 149° 35' 09.508" W 3,700.000 62.150 22.720 2,652.153 1,997.350 849.882 5,962,083.801 551,137.410 70° 18' 25.793" N 149° 35' 08.512" W 3,800.000 62.150 22.720 2,698.869 2,078.907 884.031 5,962,165.576 551,171.009 70° 18' 26.595" N 149° 35' 07.516" W 3,900.000 62.150 22.720 2,745.585 2,160.463 918.180 5,962,247.351 551,204.608 70° 18' 27.397" N 149° 35' 06.520" W 4,000.000 62.150 22.720 2,792.301 2,242.020 952.329 5,962,329.127 551,238.207 70° 18' 28.199" N 149° 35' 05.524" W 4,100.000 62.150 22.720 2,839.016 2,323.576 986.479 5,962,410.902 551,271.806 70° 18' 29.001" N 149° 35' 04.527" W 4,200.000 62.150 22.720 2,885.732 2,405.133 1,020.628 5,962,492.677 551,305.406 70° 18' 29.803" N 149° 35' 03.531" W 4,243.596 62.150 22.720 2,906.099 2,440.688 1,035.516 5,962,528.328 551,320.054 70° 18' 30.153" N 149° 35' 03.097" W Ugnu C 4,300.000 62.150 22.720 2,932.448 2,486.689 1,054.777 5,962,574.453 551,339.005 70° 18' 30.605" N 149° 35' 02.535" W 4,400.000 62.150 22.720 2,979.164 2,568.246 1,088.926 5,962,656.228 551,372.604 70° 18' 31.407" N 149° 35' 01 .538" W 4,500.000 62.150 22.720 3,025.880 2,649.802 1 ,123.076 5,962,738.003 551,406.203 70° 18' 32.209" N 149° 35' 00.542" W 11/812004 2:41:32PM Page 30f7 COMPASS 2003.11 Build 41 . eonocÓPhillips SPERRY_SUN HES Planning Report - Geographic . EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan1E-102 Plan 1E·102 D Lat Plan 1 E-1 02 D Lat (wp05) Well Plan 1E-102 1E·102 @ 94.1ooft (28' above WRP) 1E-102 @ 94.1ooft (28' above WRP) True Minimum Curvature 4,600.000 62.150 22.720 3,072.596 2,731.359 1,157.225 5,962,819.779 551,439.803 70° 18' 33.011" N 149° 34' 59.546" W 4,700.000 62.150 22.720 3,119.312 2,812.915 1,191.374 5,962,901.554 551,473.402 70° 18' 33.813" N 149° 34' 58.549" W 4,800.000 62.150 22.720 3,166.027 2,894.472 1 ,225.523 5,962,983.329 551,507.001 70° 18' 34.615" N 149° 34' 57.553" W 4,870.792 62.150 22.720 3,199.098 2,952.207 1,249.698 5,963,041.220 551,530.787 70° 18' 35.183" N 149° 34' 56.848" W Ugnu B 4,900.000 62.150 22.720 3,212.743 2,976.028 1,259.673 5,963,065.105 551,540.600 70° 18' 35.417" N 149° 34' 56.557" W 4,990.666 62.150 22.720 3,255.099 3,049.972 1,290.635 5,963,139.247 551,571.063 70° 18' 36.145" N 149° 34' 55.653" W Ugnu A 5,000.000 62.150 22.720 3,259.459 3,057.584 1 ,293.822 5,963,146.880 551,574.200 70° 18' 36.219" N 149° 34' 55.560" W 5,1 00.000 62.150 22.720 3,306.175 3,139.141 1,327.971 5,963,228.655 551,607.799 70° 18' 37.021" N 149° 34' 54.564" W 5,200.000 62.150 22.720 3,352.891 3,220.697 1 ,362.121 5,963,310.431 551,641.398 70° 18' 37.824" N 149° 34' 53.567" W 5,300.000 62.150 22.720 3,399.607 3,302.254 1,396.270 5,963,392.206 551,674.997 70° 18' 38.626" N 149° 34' 52.571" W 5,400.000 62.150 22.720 3,446.322 3,383.810 1,430.419 5,963,473.981 551,708.597 70° 18' 39.428" N 149° 34' 51.574" W 5,408.083 62.162 22.713 3,450.098 3,390.403 1,433.179 5,963,480.591 551,711.312 70° 18' 39.492" N 149° 34' 51.494" W K13 5,500.000 65.400 20.774 3,490.705 3,466.988 1,463.702 5,963,557.372 551,741.319 70° 18' 40.246" N 149° 34' 50.603" W 5,600.000 68.951 18.775 3,529.492 3,553.711 1,494.858 5,963,644.293 551,771.890 70° 18' 41.098" N 149° 34' 49.694" W 5,700.000 72.524 16.870 3,562.477 3,643.568 1,523.728 5,963,734.333 551,800.156 70° 18' 41.982" N 149° 34' 48.851" W 5,800.000 76.115 15.039 3,589.501 3,736.123 1 ,550.173 5,963,827.053 551,825.978 70° 18' 42.892" N 149° 34' 48.079" W 5,900.000 77.500 14.350 3,611 .598 3,830.549 1,574.562 5,963,921.631 551,849.731 70° 18' 43.821" N 149° 34' 47.367" W 5,934.661 77.500 14.350 3,619.100 3,863.332 1 ,582.949 5,963,954.467 551,857.898 70° 18' 44.143" N 149° 34' 47.122" W D 5,938.520 77.500 14.350 3,619.935 3,866.982 1 ,583.882 5,963,958.123 551,858.807 70° 18' 44.179" N 149° 34' 47.095" W KOP Whipstok Start DLS 15.90 5,950.520 79.408 14.346 3,622.337 3,878.372 1,586.796 5,963,969.531 551,861.644 70° 18' 44.291" N 149° 34' 47.010" W End Dir, Start Sail @ 79.408: 5950.520ft, 3622.337ft 5,968.520 79.408 14.346 3,625.645 3,895.514 1,591.180 5,963,986.700 551,865.913 70° 18' 44.460" N 149° 34' 46.882" W Begin Dir @ 5.00: 5968.530ft,3625.647ft 6,000.000 80.981 14.346 3,631.006 3,925.566 1,598.866 5,964,016.799 551,873.396 70° 18' 44.755" N 149° 34' 46.657" W 6,020.946 82.029 14.346 3,634.100 3,945.636 1,603.999 5,964,036.902 551,878.394 70° 18' 44.953" N 149° 34' 46.508" W 1E-102WS D (Heel) 6,100.000 85.981 14.346 3,642.354 4,021.791 1,623.475 5,964,113.178 551,897.359 70° 18' 45.702" N 149° 34' 45.939" W 6,170.040 89.484 14.346 3,645.124 4,089.583 1,640.813 5,964,181.078 551,914.241 70° 18' 46.368" N 149° 34' 45.433" W Start DLS3.00 TFO 358.95 6,200.000 90.382 14.329 3,645.159 4,118.610 1,648.232 5,964,210.151 551,921.465 70° 18' 46.654" N 149° 34' 45.216" W 6,253.387 91.984 14.300 3,644.056 4,170.327 1,661.429 5,964,261.950 551,934.314 70° 18' 47.162" N 149° 34' 44.831" W Start Hold for 102.560ft 6,300.000 91.984 14.300 3,642.443 4,215.468 1,672.936 5,964,307.163 551,945.517 70° 18' 47.606" N 149° 34' 44.495" W 6,355.947 91.984 14.300 3,640.506 4,269.649 1,686.746 5,964,361.430 551,958.963 70° 18' 48.139" N 149° 34' 44.092" W Start DLS 3.00 TFO 178.95 6,400.000 90.663 14.324 3,639.488 4,312.322 1,697.633 5,964,404.171 551,969.563 70° 18' 48.559" N 149° 34' 43.774" W 6,439.295 89.484 14.346 3,639.438 4,350.393 1,707.362 5,964,442.302 551,979.036 70° 18' 48.933" N 149° 34' 43.490" W End Dir, Start Sail @ 89.484: 6439.300ft, 3639.438ft 6,500.000 89.484 14.346 3,639.985 4,409.203 1,722.403 5,964,501.206 551,993.681 70° 18' 49.512" N 149° 34' 43.051" W 6,600.000 89.484 14.346 3,640.885 4,506.081 1,747.179 5,964,598.238 552,017.807 70° 18' 50.464" N 149° 34' 42.327" W 6,700.000 89.484 14.346 3,641.786 4,602.958 1,771.956 5,964,695.270 552,041.932 70018'51.417"N 149° 34' 41.604" W 6,800.000 89.484 14.346 3,642.687 4,699.836 1,796.733 5,964,792.302 552,066.057 70° 18' 52.370" N 149° 34' 40.880" W 6,900.000 89.484 14.346 3,643.587 4,796.714 1,821.510 5,964,889.334 552,090.182 70° 18' 53.323" N 149° 34' 40.157" W 7,000.000 89.484 14.346 3,644.488 4,893.592 1,846.286 5,964,986.366 552,114.307 70° 18' 54.275" N 149° 34' 39.433" W 7,100.000 89.484 14.346 3,645.388 4,990.470 1,871.063 5,965,083.398 552,138.433 70° 18' 55.228" N 149° 34' 38.710" W 7,200.000 89.484 14.346 3,646.289 5,087.347 1 ,895.840 5,965,180.430 552,162.558 70° 18' 56.181" N 149° 34' 37.986" W 7,300.000 89.484 14.346 3,647.189 5,184.225 1,920.616 5,965,277.462 552,186.683 70° 18' 57.133" N 149° 34' 37.262" W 7,400.000 89.484 14.346 3,648.090 5,281.103 1 ,945.393 5,965,374.494 552,210.808 70° 18' 58.086" N 149° 34' 36.539" W 7,500.000 89.484 14.346 3,648.991 5,377.981 1,970.170 5,965,471.526 552,234.933 70° 18' 59.039" N 149° 34' 35.815" W 7,600.000 89.484 14.346 3,649.891 5,474.858 1,994.946 5,965,568.558 552,259.059 70° 18' 59.992" N 149° 34' 35.091" W 7,700.000 89.484 14.346 3,650.792 5,571.736 2,019.723 5,965,665.590 552,283.184 70° 19' 00.944" N 149° 34' 34.368" W 11/8/2004 2:41:32PM COMPASS 2003.11 Build 41 ~ \' ~ ~ t . ' . ConocÓÁ,illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhHlips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan1E-102 Plan 1E·102 D Lat Plan 1 E-1 02 D Lat (wp05) Well Plan 1 E-1 02 1E-102 @ 94.100f! (28' above WRP) 1 E-1 02 @ 94.1 00f! (28' above WRP) True Minimum Curvature 7,800.000 89.484 14.346 3,651.692 5,668.614 2,044.500 5,965,762.622 552,307.309 70° 19' 01 .897" N 149° 34' 33.644" W 7,900.000 89.484 14.346 3,652.593 5,765.492 2,069.276 5,965,859.655 552,331,434 70° 19' 02.850" N 149° 34' 32.920" W 8,000.000 89.484 14.346 3,653,494 5,862.370 2,094.053 5,965,956.687 552,355.560 70° 19' 03.803" N 149° 34' 32.197" W 8,100.000 89.484 14.346 3,654.394 5,959.247 2,118.830 5,966,053.719 552,379.685 70° 19' 04.755" N 149° 34' 31,473" W 8,200.000 89.484 14.346 3,655.295 6,056.125 2,143.606 5,966,150.751 552,403.810 70° 19' 05.708" N 149° 34' 30.749" W 8,300.000 89.484 14.346 3,656.195 6,153.003 2,168.383 5,966,247.783 552,427.935 70° 19' 06.661" N 149° 34' 30.025" W 8,400.000 89.484 14.346 3,657.096 6,249.881 2,193.160 5,966,344.815 552,452.060 70° 19' 07.613" N 149° 34' 29.302" W 8,500.000 89.484 14.346 3,657.996 6,346.758 2,217.937 5,966,441.847 552,476.186 70° 19' 08.566" N 149° 34' 28.578" W 8,600.000 89.484 14.346 3,658.897 6,443.636 2,242.713 5,966,538.879 552,500.311 70° 19' 09.519" N 149° 34' 27.854" W 8,700.000 89.484 14.346 3,659.798 6,540.514 2,267.490 5,966,635.911 552,524.436 70° 19' 10.472" N 149° 34' 27.130" W 8,800.000 89.484 14.346 3,660.698 6,637.392 2,292.267 5,966,732.943 552,548.561 70° 19'11,424" N 149° 34' 26,406" W 8,844.623 89.484 14.346 3,661.100 6,680.622 2,303.323 5,966,776.242 552,559.327 70° 19'11.849" N 149° 34' 26.083" W 1E-102 WS DTgt 2 8,900.000 89.484 14.346 3,661 .599 6,734.270 2,317.043 5,966,829.975 552,572.686 70° 19' 12.377" N 149° 34' 25.682" W 8,937.295 89.484 14.346 3,661.935 6,770.400 2,326.284 5,966,866.163 552,581.684 70° 19'12.732" N 149° 34' 25,412" W Target (2) GeoSteer, 8931.295ft, 3661.935ft, 8,944,412 89.612 14.517 3,661.991 6,777.292 2,328.057 5,966,873.066 552,583,411 70° 19' 12.800" N 149° 34' 25.361" W 9,000.000 89.612 14.517 3,662.367 6,831.104 2,341.991 5,966,926.965 552,596.983 70° 19' 13.329" N 149° 34' 24.954" W 9,100.000 89.612 14.517 3,663.044 6,927.910 2,367.056 5,967,023.927 552,621.397 70° 19' 14.281" N 149° 34' 24.221" W 9,200.000 89.612 14.517 3,663.720 7,024.715 2,392.122 5,967,120.888 552,645.812 70° 19' 15.233" N 149° 34' 23,489" W 9,300.000 89.612 14.517 3,664.397 7,121.520 2,417.188 5,967,217.850 552,670.227 70° 19'16.185" N 149° 34' 22.756" W 9,400.000 89.612 14.517 3,665.074 7,218.325 2,442.253 5,967,314.811 552,694.641 70° 19'17.137" N 149° 34' 22.024" W 9,403.876 89.612 14.517 3,665.100 7,222.077 2,443.225 5,967,318.569 552,695.588 70° 19'17.174" N 149° 34' 21 .996" W C 9,422.926 89.612 14.517 3,665.229 7,240.519 2,448.000 5,967,337.040 552,700.239 70° 19' 17.355" N 149° 34' 21.856" W 9,500.000 89.915 12.225 3,665.547 7,315.498 2,465.822 5,967,412.130 552,717.556 70° 19' 18.093" N 149° 34' 21.335" W 9,600.000 90.307 9.251 3,665.353 7,413.736 2,484.450 5,967,510.481 552,735.525 70° 19' 19.059" N 149° 34' 20.791" W 9,637.922 90.456 8.122 3,665.100 7,451.221 2,490.177 5,967,548.000 552,741.000 70° 19'19,428" N 149° 34' 20.623" W 1E-102 WSDTgt 3 9,639.169 90.468 8.158 3,665.090 7,452.456 2,490.353 5,967,549.236 552,741.168 70° 19'19,440" N 149° 34' 20.618" W 9,700.000 90.468 8.158 3,664.593 7,512.669 2,498.985 5,967,609.500 552,749.396 70° 19' 20.032" N 149° 34' 20.365" W 9,800.000 90.468 8.158 3,663.775 7,611.654 2,513.174 5,967,708.568 552,762.921 70° 19' 21 .005" N 149° 34' 19.950" W 9,900.000 90.468 8.158 3,662.958 7,710.639 2,527.364 5,967,807.636 552,776.446 70° 19' 21.979" N 149° 34' 19.535" W 10,000.000 90.468 8.158 3,662.141 7,809.624 2,541.553 5,967,906.704 552,789.971 70° 19' 22.952" N 149° 34'19.120" W 10,100.000 90.468 8.158 3,661 .323 7,908.609 2,555.742 5,968,005.772 552,803,496 70° 19' 23.926" N 149° 34'18.705" W 10,200.000 90.468 8.158 3,660.506 8,007.594 2,569.932 5,968,104.840 552,817.021 70° 19' 24.899" N 149° 34' 18.290" W 10,300.000 90.468 8.158 3,659.688 8,106.578 2,584.121 5,968,203.908 552,830.546 70° 19' 25.873" N 149° 34'17.875" W 10,400.000 90.468 8.158 3,658.871 8,205.563 2,598.310 5,968,302.976 552,844.071 70° 19' 26.846" N 149° 34'17.460" W 10,500.000 90.468 8.158 3,658.054 8,304.548 2,612.500 5,968,402.044 552,857.596 70° 19' 27.820" N 149° 34'17.045" W 10,600.000 90.468 8.158 3,657.236 8,403.533 2,626.689 5,968,501.112 552,871.121 70° 19' 28.793" N 149° 34' 16.629" W 10,700.000 90.468 8.158 3,656,419 8,502.518 2,640.878 5,968,600.180 552,884.646 70° 19' 29.766" N 149° 34' 16.214" W 10,800.000 90.468 8.158 3,655.602 8,601 .502 2,655.068 5,968,699.248 552,898.171 70° 19' 30.740" N 149° 34'15.799" W 10,900.000 90.468 8.158 3,654.784 8,700.487 2,669.257 5,968,798.316 552,911.696 70° 19' 31.713" N 149° 34' 15.384" W 11 ,000.000 90.468 8.158 3,653.967 8,799,472 2,683,446 5,968,897.384 552,925.221 70° 19' 32.687" N 149° 34'14.969" W 11,100.000 90.468 8.158 3,653.149 8,898.457 2,697.635 5,968,996.451 552,938.746 70° 19' 33.660" N 149° 34'14.553" W 11,200.000 90.468 8.158 3,652.332 8,997.442 2,711.825 5,969,095.519 552,952.271 70° 19' 34.634" N 149° 34'14.138" W 11,300.000 90.468 8.158 3,651.515 9,096,427 2,726.014 5,969,194.587 552,965.796 70° 19' 35.607" N 149° 34' 13.723" W 11,400.000 90.468 8.158 3,650.697 9,195,411 2,740.203 5,969,293.655 552,979.321 70° 19' 36.581" N 149° 34' 13.308" W 11 ,500.000 90.468 8.158 3,649.880 9,294.396 2,754.393 5,969,392.723 552,992.846 70° 19' 37.554" N 149° 34' 12.892" W 11,600.000 90.468 8.158 3,649.062 9,393.381 2,768.582 5,969,491.791 553,006.371 70° 19' 38.528" N 149° 34' 12.477" W 11,700.000 90.468 8.158 3,648.245 9,492.366 2,782.771 5,969,590.859 553,019.896 70° 19' 39.501" N 149° 34'12.062" W 11,800.000 90.468 8.158 3,647,428 9,591.351 2,796.961 5,969,689.927 553,033.421 70° 19' 40,474" N 149° 34' 11.647" W 11,900.000 90.468 8.158 3,646.610 9,690.336 2,811.150 5,969,788.995 553,046.946 70° 19' 41.448" N 149° 34' 11.231" W 12,000.000 90.468 8.158 3,645.793 9,789.320 2,825.339 5,969,888.063 553,060,471 70° 19' 42,421" N 149° 34'10.816" W 12,100.000 90.468 8.158 3,644.976 9,888.305 2,839.529 5,969,987.131 553,073.996 70° 19' 43.395" N 149° 34'10,401" W 12,200.000 90.468 8.158 3,644.158 9,987.290 2,853.718 5,970,086.199 553,087.521 70° 19' 44.368" N 149° 34' 09.985" W 12,300.000 90.468 8.158 3,643.341 10,086.275 2,867.907 5,970,185.267 553,101.046 70° 19' 45.342" N 149° 34' 09.570" W 12.400.000 90.468 8.158 3,642.523 10,185.260 2,882.097 5,970,284.335 553,114.571 70° 19' 46.315" N 149° 34' 09.154" W 111812004 2:41:32PM Page 5 of 7 COMPASS 2003.11 Build 41 Hd :i f; ~ . eonocJPt,illips . SPERRY_SUN HES Planning Report - Geographic Database: Company: Project: Site: . Well: Wellbore: Design: EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E·102 D lat Plan 1 E-102 D lat (wp05) Well Plan 1 E-1 02 1 E·102 @ 94.1ooft (28' above WRP) 1E-102 @ 94.1ooft (28' above WRP) True Minimum Curvature 12,500.000 90.468 8.158 3,641.706 10,284.244 2,896.286 5,970,383.403 553,128.096 70° 19' 47.289" N 149° 34' 08.739" W 12,600.000 90.468 8.158 3,640.889 10,383.229 2,910.475 5,970,482.471 553,141.621 70° 19' 48.262" N 149° 34' 08.324" W 12,700.000 90.468 8.158 3,640.071 10,482.214 2,924.665 5,970,581.539 553,155.146 70° 19' 49.236" N 149° 34' 07.908" W 12,800.000 90.468 8.158 3,639.254 10,581.199 2,938.854 5,970,680.607 553,168.671 70° 19' 50.209" N 149° 34' 07.493" W 12,900.000 90.468 8.158 3,638.437 10,680.184 2,953.043 5,970,779.675 553,182.196 70° 19' 51.182" N 149° 34' 07.078" W 13,000.000 90.468 8.158 3,637.619 10,779.169 2,967.233 5,970,878.743 553,195.721 70° 19' 52.156" N 149° 34' 06.662" W 13,100.000 90.468 8.158 3,636.802 10,878.153 2,981.422 5,970,977.811 553,209.246 70° 19' 53.129" N 149° 34' 06.247" W 13,200.000 90.468 8.158 3,635.984 10,977.138 2,995.611 5,971,076.879 553,222.771 70° 19' 54.103" N 149° 34' 05.831" W 13,300.000 90.468 8.158 3,635.167 11,076.123 3,009.801 5,971,175.947 553,236.296 70° 19' 55.076" N 149° 34' 05.416" W 13,400.000 90.468 8.158 3,634.350 11 ,175.108 3,023.990 5,971,275.015 553,249.821 70° 19' 56.050" N 149° 34' 05.000" W 13,431.363 90.468 8.158 3,634.093 11 ,206.152 3,028.440 5,971,306.085 553,254.063 70° 19' 56.355" N 149° 34' 04.870" W 13,500.000 89.811 6.208 3,633.926 11,274.247 3,037.021 5,971,374.229 553,262.187 70° 19' 57.025" N 149° 34' 04.619" W 13,529.907 89.524 5.356 3,634.100 11,304.001 3,040.033 5,971,404.000 553,265.000 70° 19' 57.317" N 149° 34' 04.530" W 1E-102 WS D Tgt 4 13,600.000 89.524 5.356 3,634.683 11,373.786 3,046.576 5,971,473.820 553,271.075 70° 19' 58.004" N 149° 34' 04.338" W 13,700.000 89.524 5.356 3,635.514 11,473.346 3,055.911 5,971,573.431 553,279.742 70° 19' 58.983" N 149° 34' 04.065" W 13,800.000 89.524 5.356 3,636.345 11 ,572.905 3,065.245 5,971,673.041 553,288.409 70° 19' 59.962" N 149° 34' 03.791" W 13,900.000 89.524 5.356 3,637.176 11,672.465 3,074.580 5,971,772.652 553,297.076 70° 20' 00.941" N 149° 34' 03.517" W 14,000.000 89.524 5.356 3,638.007 11 ,772.025 3,083.914 5,971,872.262 553,305.743 70° 20' 01.920" N 149° 34' 03.243" W 14,100.000 89.524 5.356 3,638.838 11,871.585 3,093.249 5,971,971.873 553,314.410 70° 20' 02.899" N 149° 34' 02.970" W 14,200.000 89.524 5.356 3,639.669 11,971.145 3,1 02.583 5,972,071.483 553,323.077 70° 20' 03.878" N 149° 34' 02.696" W 14,300.000 89.524 5.356 3,640.500 12,070.705 3,111 .918 5,972,171.094 553,331.744 70° 20' 04.857" N 149° 34' 02.422" W 14,372.188 89.524 5.356 3,641.100 12,142.575 3,118.656 5,972,243.000 553,338.000 70° 20' 05.564" N 149° 34' 02.224" W TD at 14372.188 -1E-102 WSD Tgt5 Targets 1E-102WS D Tgt3 - plan hits target - Point 0.00 0.00 3,665.100 7,451.221 2,490.177 5,967,548.000 552,741.000 70° 19' 19.428" N 149° 34' 20.623" W 1 E-102 WS D (Heel) 0.00 0.003,634.100 3,866.858 1,584.074 5,963,958.000 551,859.000 70° 18' 44.178" N 149° 34' 47.089" W - plan misses by 81.258ft at 6020.946ft MD (3634.100 TVD, 3945.636 N, 1603.999 E) - Point 1 E-102 WS DTgt 2 0.00 0.00 3,661.100 6,770.235 2,326.599 5,966,866.000 552,582.000 70° 19' 12.731" N 149° 34' 25.403" W - plan misses by 92.587ft at 8844.623ft MD (3661.100 TVD, 6680.622 N, 2303.323 E) - Point 1E-102WSDTgt4 - plan hits target - Point 1E-102 WS D Tgt 5 0.00 0.003,641.100 12,142.575 3,118.656 5,972,243.000 553,338.000 70° 20' 05.564" N 149° 34' 02.224" W - plan misses by 1797.468ft at 12574.144ft MD (3641.100 TVD, 10357.635 N, 2906.807 E) - Point 0.00 0.00 3,634.100 11,304.001 3,040.033 5,971,404.000 553,265.000 70° 19' 57.317" N 149° 34' 04.530" W 11/8/2004 2:41:32PM Page 6 of 7 COMPASS 2003.11 Build 41 . ~illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhiUips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E·102 D Lat Plan 1 E-102 D Lat (wp05) Well Plan 1E-102 1E-102 @ 94.100ft (28' aboveWRP) 1 E-1 02 @ 94.1 OOft (28' above WRP) True Minimum Curvature Casing Points 103/4" 7 5/8 1 0-3/4 7-5/8 13-1/2 9-718 Permafrost T3 K15 T3+675 Ugnu C Ugnu B Ugnu A K13 D C B 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical· Depth (ft) 3,619.935 3,622.337 3,625.647 3,645.124 3,644.056 3,640.506 3,639.438 3,661 .935 3,641.100 KOP Whipstok start DLS 15.90 End Dir, Start Sail @ 79.408: 5950.520ft, 3622.337ft Begin Dir @ 5.00 : 5968.530ft,3625.647ft Start DLS 3.00 TFO 358.95 Start Hold for 1 02. 560ft Start DLS 3.00 TFO 178.95 End Dir, Start Sail @ 89.484: 6439.300ft, 3639.438ft Target (2) GeoSteer, 8937.295ft, 3661.935ft, TD at 14372.188 11/8/2004 2:41:32PM Page 7 of? COMPASS 2003.11 Build 41 . . Standard Planning Report ..... i~·II· Conocurlll .. Ips ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-1 02 Plan 1 E-1 02 D Lat Plan: Plan 1E-102 D Lat (wp05) 08 November, 2004 . Co~illips SPERRY_SUN HES Planning Report . Database: Company: Project: Site: Well: Wellbore: Design: EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit KUparuk 1 E Pad Plan 1E-102 Plan 1E·102 D Lat Plan 1 E-102 D lat (wp05) Well Plan 1E-102 1 E-102 @ 94.1ooft (28' above WRP) 1E-102 @ 94.1ooft (28' above WRP) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 1 E Pad Site Position: From: Map Position Uncertainty: 0.000 ft Northing: Easting: Slot Radius: 5,959,760.24Oft 549,889.51 Oft 0" Latitude: Longitude: Grid Convergence: 70° 18' 03.021" N 149° 35' 45.358" W 0.38 ° Well Plan 1 E-102 Well Position +N/-S +E/-W Position Uncertainty O.OOOft O.ooOft 0.000 ft Northing: Easting: Wellhead Elevation: 5,960,081.000 ft 550,301.000 ft ft Latitude: Longitude: Ground Level: 70° 18' 06.149" N 149° 35' 33.297" W 0.000 ft Wellbore Plan 1E-102 D lat BGGM2oo4 11/8/2004 24.54 80.74 57,577 Design Audit Notes: Version: Plan 1 E-102 D lat (wp05) Phase: PLAN Tie On Depth: 5,938.520 0.000 14.404 5,938.520 77.500 14.350 3,619.935 3,866.982 1,583.882 0.00 0.00 0.00 0.00 5,950.520 79.408 14.346 3,622.337 3,878.372 1,586.796 15.90 15.90 -0.03 359.88 5,968.520 79.408 14.346 3,625.645 3,895.514 1,591.180 0.00 0.00 0.00 0.00 6,170.040 89.484 14.346 3,645.124 4,089.583 1,640.813 5.00 5.00 0.00 0.00 6,253.387 91.984 14.300 3,644.056 4,170.327 1 ,661 .429 3.00 3.00 -0.06 358.95 6,355.947 91 .984 14.300 3,640.506 4,269.649 1,686.746 0.00 0.00 0.00 0.00 6,439.295 89.484 14.346 3,639.438 4,350.393 1,707.362 3.00 -3.00 0.06 178.95 8,937.295 89.484 14.346 3,661.935 6,770.400 2,326.284 0.00 0.00 0.00 0.00 8,944.412 89.612 14.517 3,661.991 6,777.292 2,328.057 3.00 1.80 2.40 53.08 9,422.926 89.612 14.517 3,665.229 7,240.519 2,448.000 0.00 0.00 0.00 0.00 9,637.922 90.456 8.122 3,665.100 7,451.221 2,490.177 3.00 0.39 -2.97 -82.49 1 E-1 02 WS D Tgt 3 9,639.169 90.468 8.158 3,665.090 7,452.456 2,490.353 3.00 0.96 2.84 71.37 13,431.363 90.468 8.158 3,634.093 11,206.152 3,028.440 0.00 0.00 0.00 0.00 13,529.907 89.524 5.356 3,634.100 11,304.001 3,040.033 3.00 -0.96 -2.84 -108.631E-102WSDTgt4 14,372.188 89.524 5.356 3,641.100 12,142.575 3,118.656 0.00 0.00 0.00 0.00 1 E-1 02 WS D Tgt 5 11/1012004 10:56:28AM Page 2 of6 COMPASS 2003.11 BuHd 41 -......... ~ ~ V . CortocÓÁ,illips SPERRY_SUN HES Planning Report . EDM 2003.11 Single User Db ConocoPhiUips Ala$ka Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1E·102 D Lat Plan 1 E-102 D Lat (wp05) Database: Company: Project: Site: Well: Wellbore: Design: Well Plan 1 E-1 02 1E·102 @ 94.100ft (28' above WRP) 1 E-1 02 @ 94.1 OOft (28' above WRP) True Minimum Curvature +N!.S tit) 5,938.520 77.500 14.350 3,619.935 3,866.982 1 ,583.882 4,139.433 0.00 0.00 0.00 KOP Whipstok Start OLS 15.90; 0 Lðt Prod. Begin (921 ft FNL & 3911 ft FEL,Sec15-T11N-R10E 5,950.520 79.408 14.346 3,622.337 3,878.372 1,586.796 4,151.189 15.90 15.90 -0.03 End Oir, Start Sail @ 79.408: 5950.520ft, 3622.337ft 5,968.520 79.408 14.346 3,625.645 3,895.514 1,591.180 4,168.882 0.00 0.00 0.00 Begin Dir @ 5.00 : 5968.530ft,3625.647ft 6,000.000 80.981 14.346 3,631.006 3,925.566 1 ,598.866 4,1 99.902 5.00 5.00 0.00 6,020.946 82.029 14.346 3,634.100 3,945.636 1,603.999 4,220.618 5.01 5.01 0.00 1E-102 WS 0 (Heel) 6,1 00.000 85.981 14.346 3,642.354 4,021.791 1,623.475 4,299.224 5.00 5.00 0.00 6,170.040 89.484 14.346 3,645.124 4,089.583 1,640.813 4,369.198 5.00 5.00 0.00 Start OLS 3.00 TFO 358.95 6,200.000 90.382 14.329 3,645.159 4,118.610 1,648.232 4,399.158 3.00 3.00 -0.06 6,253.387 91.984 14.300 3,644.056 4,170.327 1,661.429 4,452.532 3.00 3.00 -0.06 Start Hold for102.560ft 6,300.000 91.984 14.300 3,642.443 4,215.468 1,672.936 4,499.116 0.00 0.00 0.00 6,355.947 91.984 14.300 3,640.506 4,269.649 1,686.746 4,555.030 0.00 0.00 0.00 Start.OLS 3.00TFO 178.95 6,400.000 90.663 14.324 3,639.488 4,312.322 1,697.633 4,599.070 3.00 -3.00 0.06 6,439.295 89.484 14.346 3,639.438 4,350.393 1,707.362 4,638.364 3.00 -3.00 0.06 End OiT, Start Sail @ 89.484: 6439.300ft, 3639.438ft 6,500.000 89.484 14.346 3,639.985 4,409.203 1,722.403 4,699.067 0.00 0.00 0.00 6,600.000 89.484 14.346 3,640.885 4,506.081 1,747.179 4,799.063 0.00 0.00 0.00 6,700.000 89.484 14.346 3,641.786 4,602.958 1,771.956 4,899.058 0.00 0.00 0.00 6,800.000 89.484 14.346 3,642.687 4,699.836 1,796.733 4,999.054 0.00 0.00 0.00 6,900.000 89.484 14.346 3,643.587 4,796.714 1,821.510 5,099.050 0.00 0.00 0.00 7,000.000 89.484 14.346 3,644.488 4,893.592 1 ,846.286 5,199.046 0.00 0.00 0.00 7,100.000 89.484 14.346 3,645.388 4,990.470 1,871.063 5,299.042 0.00 0.00 0.00 7,200.000 89.484 14.346 3,646.289 5,087.347 1,895.840 5,399.038 0.00 0.00 0.00 7,300.000 89.484 14.346 3,647.189 5,184.225 1,920.616 5,499.034 0.00 0.00 0.00 7,400.000 89.484 14.346 3,648.090 5,281.103 1 ,945.393 5,599.030 0.00 0.00 0.00 7,500.000 89.484 14.346 3,648.991 5,377.981 1,970.170 5,699.026 0.00 0.00 0.00 7,600.000 89.484 14.346 3,649.891 5,474.858 1,994.946 5,799.022 0.00 0.00 0.00 7,700.000 89.484 14.346 3,650.792 5,571.736 2,019.723 5,899.017 0.00 0.00 0.00 7,800.000 89.484 14.346 3,651.692 5,668.614 2,044.500 5,999.013 0.00 0.00 0.00 7,900.000 89.484 14.346 3,652.593 5,765.492 2,069.276 6,099.009 0.00 0.00 0.00 8,000.000 89.484 14.346 3,653.494 5,862.370 2,094.053 6,199.005 0.00 0.00 0.00 8,100.000 89.484 14.346 3,654.394 5,959.247 2,118.830 6,299.001 0.00 0.00 0.00 8,200.000 89.484 14.346 3,655.295 6,056.125 2,143.606 6,398.997 0.00 0.00 0.00 8,300.000 89.484 14.346 3,656.195 6,153.003 2,168.383 6,498.993 0.00 0.00 0.00 8,400.000 89.484 14.346 3,657.096 6,249.881 2,193.160 6,598.989 0.00 0.00 0.00 8,500.000 89.484 14.346 3,657.996 6,346.758 2,217.937 6,698.985 0.00 0.00 0.00 8,600.000 89.484 14.346 3,658.897 6,443.636 2,242.713 6,798.980 0.00 0.00 0.00 8,700.000 89.484 14.346 3,659.798 6,540.514 2,267.490 6,898.976 0.00 0.00 0.00 8,800.000 89.484 14.346 3,660.698 6,637.392 2,292.267 6,998.972 0.00 0.00 0.00 8,844.623 89.484 14.346 3,661.100 6,680.622 2,303.323 7,043.593 0.00 0.00 0.00 1E-102 WS OTgt 2 8,900.000 89.484 14.346 3,661.599 6,734.270 2,317.043 7,098.968 0.00 0.00 0.00 8,937.295 89.484 14.346 3,661.935 6,770.400 2,326.284 7,136.261 0.00 0.00 0.00 Target (2) GeóSteer; 8937.295ft, 3661.935ft, 8,944.412 89.612 14.517 3,661.991 6,777.292 2,328.057 7,143.378 3.00 1.80 2.40 11/10/2004 10:56:28AM -~ln i f!-aQ~3)Çf~ COMPASS 2003.11 BuUd 41 .~~ ,J . ~ _,"." :~ ó. '\ '. [" ~\, ~ ~.) J16 '''fl. U " .< . eonocc:iPhillips . SPERRY_SUN HES Planning Report 9,000.000 89.612 14.517 3,662.367 6,831.1 04 2,341.991 7,198.965 0.00 0.00 0.00 9,100.000 89.612 14.517 3,663.044 6,927.910 2,367.056 7,298.963 0.00 0.00 0.00 9,200.000 89.612 14.517 3,663.720 7,024.715 2,392.122 7,398.960 0.00 0.00 0.00 9,300.000 89.612 14.517 3,664.397 7,121.520 2,417.188 7,498.958 0.00 0.00 0.00 9,400.000 89.612 14.517 3,665.074 7,218.325 2,442.253 7,598.955 0.00 0.00 0.00 9,403.876 89.612 14.517 3,665.100 7,222.077 2,443.225 7,602.831 0.00 0.00 0.00 C 9,422.926 89.612 14.517 3,665.229 7,240.519 2,448.000 7,621.880 9,500.000 89.915 12.225 3,665.547 7,315.498 2,465.822 7,698.936 3.00 0.39 -2.97 9,600.000 90.307 9.251 3,665.353 7,413.736 2,484.450 7,798.720 3.00 0.39 -2.97 9,637.922 90.456 8.122 3,665.100 7,451.221 2,490.177 7,836.451 3.00 0.39 -2.98 'E-102 W$ DTgt 3 9,639.169 90.468 8.158 3,665.090 7,452.456 2,490.353 9,700.000 90.468 8.158 3,664.593 7,512.669 2,498.985 7,898.159 0.00 0.00 0.00 9,800.000 90.468 8.158 3,663.775 7,611.654 2,513.174 7,997.562 0.00 0.00 0.00 9,900.000 90.468 8.158 3,662.958 7,710.639 2,527.364 8,096.965 0.00 0.00 0.00 10,000.000 90.468 8.158 3,662.141 7,809.624 2,541.553 8,196.368 0.00 0.00 0.00 10,100.000 90.468 8.158 3,661.323 7,908.609 2,555.742 8,295.771 0.00 0.00 0.00 10,200.000 90.468 8.158 3,660.506 8,007.594 2,569.932 8,395.174 0.00 0.00 0.00 10,300.000 90.468 8.158 3,659.688 8,106.578 2,584.121 8,494.577 0.00 0.00 0.00 10,400.000 90.468 8.158 3,658.871 8,205.563 2,598.310 8,593.980 0.00 0.00 0.00 10,500.000 90.468 8.158 3,658.054 8,304.548 2,612.500 8,693.383 0.00 0.00 0.00 10,600.000 90.468 8.158 3,657.236 8,403.533 2,626.689 8,792.785 0.00 0.00 0.00 10,700.000 90.468 8.158 3,656.419 8,502.518 2,640.878 8,892.188 0.00 0.00 0.00 10,800.000 90.468 8.158 3,655.602 8,601.502 2,655.068 8,991.591 0.00 0.00 0.00 10,900.000 90.468 8.158 3,654.784 8,700.487 2,669.257 9,090.994 0.00 0.00 0.00 11,000.000 90.468 8.158 3,653.967 8,799.472 2,683.446 9,190.397 0.00 0.00 0.00 11,100.000 90.468 8.158 3,653.149 8,898.457 2,697.635 9,289.800 0.00 0.00 0.00 11,200.000 90.468 8.158 3,652.332 8,997.442 2,711.825 9,389.203 0.00 0.00 0.00 11,300.000 90.468 8.158 3,651.515 9,096.427 2,726.014 9,488.606 0.00 0.00 0.00 11,400.000 90.468 8.158 3,650.697 9,195.411 2,740.203 9,588.009 0.00 0.00 0.00 11,500.000 90.468 8.158 3,649.880 9,294.396 2,754.393 9,687.412 0.00 0.00 0.00 11,600.000 90.468 8.158 3,649.062 9,393.381 2,768.582 9,786.815 0.00 0.00 0.00 11,700.000 90.468 8.158 3,648.245 9,492.366 2,782.771 9,886.218 0.00 0.00 0.00 11,800.000 90.468 8.158 3,647.428 9,591.351 2,796.961 9,985.621 0.00 0.00 0.00 11,900.000 90.468 8.158 3,646.610 9,690.336 2,811.150 10,085.024 0.00 0.00 0.00 12,000.000 90.468 8.158 3,645.793 9,789.320 2,825.339 10,184.427 0.00 0.00 0.00 12,100.000 90.468 8.158 3,644.976 9,888.305 2,839.529 10,283.830 0.00 0.00 0.00 12,200.000 90.468 8.158 3,644.158 9,987.290 2,853.718 10,383.233 0.00 0.00 0.00 12,300.000 90.468 8.158 3,643.341 10,086.275 2,867.907 10,482.636 0.00 0.00 0.00 12,400.000 90.468 8.158 3,642.523 10,185.260 2,882.097 10,582.039 0.00 0.00 0.00 12,500.000 90.468 8.158 3,641.706 10,284.244 2,896.286 10,681.442 0.00 0.00 0.00 12,600.000 90.468 8.158 3,640.889 10,383.229 2,910.475 10,780.845 0.00 0.00 0.00 12,700.000 90.468 8.158 3,640.071 10,482.214 2,924.665 10,880.248 0.00 0.00 0.00 12,800.000 90.468 8.158 3,639.254 10,581.199 2,938.854 10,979.651 0.00 0.00 0.00 12,900.000 90.468 8.158 3,638.437 10,680.184 2,953.043 11,079.053 0.00 0.00 0.00 13,000.000 90.468 8.158 3,637.619 10,779.169 2,967.233 11,178.456 0.00 0.00 0.00 13,100.000 90.468 8.158 3,636.802 10,878.153 2,981 .422 11,277.859 0.00 0.00 0.00 13,200.000 90.468 8.158 3,635.984 10,977.138 2,995.611 11,377.262 0.00 0.00 0.00 13,300.000 90.468 8.158 3,635.167 11,076.123 3,009.801 11,476.665 0.00 0.00 0.00 13,400.000 90.468 8.158 3,634.350 11,175.108 3,023.990 11 ,576.068 0.00 0.00 0.00 13,431.363 90.468 8.158 3,634.093 11,206.152 3,028.440 11,607.244 0.00 0.00 0.00 13,500.000 89.811 6.208 3,633.926 11,274.247 3,037.021 11,675.333 3.00 -0.96 -2.84 13,529.907 89.524 5.356 3,634.100 11,304.001 3,040.033 11,704.901 3.01 -0.96 -2.85 1E-102 WSD Tgt 4 13,600.000 89.524 5.356 3,634.683 11,373.786 3,046.576 11,774.119 0.00 13,700.000 89.524 5.356 3,635.514 11,473.346 3,055.911 11,872.871 0.00 0.00 0.00 13,800.000 89.524 5.356 3,636.345 11 ,572.905 3,065.245 11,971.624 0.00 0.00 0.00 11/10/2004 10:56:28AM Page 4 of6 COMPASS 2003.11 Build 41 ()R I . eonocóPhillips SPERRY_SUN HES Planning Report . EDM2003.11 Single User Db ConocoPhillipsAlaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-102 Plan 1 E·102 D Lat Plan 1 E-1 02 D Lat (wp05) 13,900.000 89.524 5.356 3,637.176 11,672.465 3,074.580 12,070.376 0.00 14,000.000 89.524 5.356 3,638.007 11,772.025 3,083.914 12,169.128 0.00 14,100.000 89.524 5.356 3,638.838 11,871.585 3,093.249 12,267.880 0.00 14,200.000 89.524 5.356 3,639.669 11,971.145 3,102.583 12,366.633 0.00 14,300.000 89.524 5.356 3,640.500 12,070.705 3,111.918 12,465.385 0.00 14,372.188 89.524 5.356 3,641.10012,142.575 3,118.65612,536.672 0.00 TargetD Lat (Toe), 14372.188ft, 3641.100ft, (3207ft FNL, 2358f1 FEL, Sec3-T11N-R10E -1E-102 WS DTgt5 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1 E-102 WS D Tgt 3 - plan hits target - Point 1 E-102 WS D (Heel) - plan - Point 1 E-102 WS DTgt 2 - plan - Point 1 E-102 WS D Tgt 4 - plan hits target - Point 0.00 0.003,665.100 7,451.221 2,490.177 5,967,548.000 552,741.000 70019'19.428"N 149°34'20.623"W 0.00 0.00 3,634.100 3,866.858 1,584.074 5,963,958.000 551,859.000 70° 18' 44.178" N 149° 34' 47.089" W 0.00 0.00 3,661.100 6,770.235 2,326.599 5,966,866.000 552,582.000 70° 19' 12.731" N 149° 34' 25.403" W 0.00 0.00 3,634.100 11,304.001 3,040.033 5,971,404.000 553,265.000 70° 19' 57.317" N 149° 34' 04.530" W 1E-102WSDTgt5 - plan - Point 0.00 0.003,641.100 12,142.575 3,118.656 5,972,243.000 553,338.000 70°20'05.564" N 149°34'02.224"W 103/4" 7 5/8 1 0-3/4 7-5/8 13-1/2 9-718 Permafrost T3 K15 T3+675 Ugnu C Ugnu B Ugnu A K13 D C B 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11/1012004 10:56:28AM Page 5 of6 COMPASS 2003.11 Build 41 . eonocciPt,illips SPERRY_SUN HES Planning Report . 5,938.530 5,950.520 5,968.530 6,170.040 6,253.387 6,355.947 6,439.300 8,937.295 14,372.180 3,619.937 3,622_337 3,625.647 3,645.124 3,644.056 3,640.506 3,639.438 3,661.935 3,641.100 3,866.992 3,878.372 3,895.523 4,089.583 4,170.327 4,269.649 4,350.398 6,770.400 12,142.567 11/10/2oo410:56:28AM 1,583_885 1,586.796 1,591.182 1,640_813 1 ,661 .429 1,686.746 1,707.363 2,326.284 3,118.656 KOP Whipstok Start DLS 15.90; D Lat Prod. Begin (921 ft FNL & 3911 ft End Dir, Start Sail @ 79.408: 5950.520ft, 3622.337ft Begin Dir @ 5.00 : 5968.530ft,3625.647ft Start DLS 3.00 TFO 358.95 Start Hold for 102.560ft Start DLS 3_00 TFO 178.95 End Dir, Start Sail @ 89.484: 6439.300ft, 3639.438ft Target (2) GeoSteer, 8937.295ft, 3661.935ft, Target D Lat (Toe), 14372.188ft, 3641 .1 DOft, (3207ft FNL, 2358ft FEL, Se Page 60f6 COMPASS 2003.11 Build 41 n t.. : 1E-1. Drillina Hazar~ Summary (SEE WELL PLAN AND ATIACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole /10-3/4" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Hole swabbing on trips Risk Level Low Moderate / Low Moderate Mitigation strategy Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casina Interval Hazard Running Sands and Gravels Gas Hydrates Stuck Pipe Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Low Low ./ Low Low .j Low Moderate Mitigation Strategy Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight BOP training and drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low ,I Low Low Moderate Mitigation Strategy Stripping drills, shut-in drills, increased mud weight. Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Reduced pump rates, mud rheology, LCM Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1E-102 Drilling Hazards Summary. doc prepared by Steve McKeever 10/1/20043:48 PM Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 11/9/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 108' MD < Base of Permafrost at 1,660' MO (1,508' TVO) < Top of Tail at 2,179' MO -~ j ~ ~ ~ 1 < 103/4",45.5# casing in 131/2" OH TO at 3,179' MO (2,409' TVD) Mark of Schlumberger Schl.blPgllP Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,179' MD. Lead Slurry Minimum pump time: 220 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3fsk 3 1.3644 ft fft x (108') x 1.00 (no excess) = 3 0.3637 ft fft x (1660' - 108') x 3.50 (250% excess) = 0.3637 ft3fft x (2179' - 1660') x 1.35 (35% excess) = 147.4 ft3 + 1975.6 ft3+ 254.8 ft3 = 2377.8 ft3f4.45 ft3fsk = Round up to 540 sks 147.4 ft3 1975.6 ft3 254.8 ft3 2377.8 ft3 534.3 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 160 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3fsk 0.3637 ft3fft x (3179' - 2179') x 1.35 (35% excess) = 0.5400 ft3fft x 80' (Shoe Joint) = 491.0 ft3 + 43.2 ft3 = 534.2 ft31 2.52 ft3fsk = Round up to 220 sks 491.0 ft3 43.2 ft3 534.2 ft3 211.9 sks BHST = 48°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°Ff100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) ON100 5.0 10.0 2.0 2.0 Pause 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Pause 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 423.5 60.5 93.8 DeepCRETE 5.0 95.1 19.0 112.8 Pause 0.0 0.0 5.0 117.8 Water 5.0 20.0 4.0 121.8 Pause 0.0 0.0 5.0 126.8 Mud 7.0 263.0 37.6 164.4 Mud 3.0 15.0 5.0 169.4 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, Ty < 15. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-21, Ty? 20-25 Centralizers: Recommend 1 f" ,f". 0 ;, :t :::_..,,/' t~ I'...· .....,. '. \..,~:- ~ '\ t: SchlulbePl8P Preliminary Job Design based on limited input data, For estimate purposes only, Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 11/9/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C Sand - (2757' MD annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3fft 3 0.2148ft fftx 2757' x 1.25 (25% excess) = 0.2578 ft3fft x 80' JShoe Joint) = 740.3 ft3 + 20.6 ft = 760.9 ft3f 2.26 ft3fsk = Round up to 340 sks 740.3ft3 20.6 ft3 760.9 ft3 336.7 sks Previous Csg. < 103/4", 45.5# casing at 3,179' MD BHST = 82°F, Estimated BHCT = 71°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 Pressure test lines 0.0 0.0 10.0 CW100 5.0 30.0 6.0 Drop bottom plug 0.0 0.0 5.0 MUDPUSH II 6.0 40.0 6.7 DeepCRETE 6.0 135.5 22.6 [ < Top of Tail at Drop top plug 0.0 0.0 5.0 3,743' MD Mud 7.0 279.8 40.0 ,\ Slow & bump plug 3.0 15.0 5.0 ~ ~, ~ µ MUD REMOVAL < 75/8",29.7# casing in 9 7/8" OH Recommended Mud Properties: 9.0 ppg, Pv < 15, Ty < 15. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 19-22, Ty = 22-29 TD at 6,500' MD (3,696' TVD) Centralizers: Recommend 1 Tandem Rise per joint from shoe track to K13 @ 5400' MD r) r'~ ; " t" ~ ~. ~ I", "'''' ,", i 6' ;j o n ~~ ~ £= ~"C 6JV) ,~M" ,;m,..,\ '..... ,F r:IJ' "'11>'" (J~2:' ¡; w'¡.,. C) (J,o .... n lZt.·s ~:::ro· o C);:;¡ :~::E ~~ .... IJ1 .... <:> N ~ c '" ~ "." ~.g H Q)Q. ~~ î~ ~<;I." ~gG1 ~~~ ~~~ Insulated Conductor Casing, 20", 94#, K55 X34",o.312"WT@\ - +1- 80' MD r Wellhead 1 Tubing Head 1 Tree, 13-51 r 8" x 4-W', 5,000 ksi Tubing String: 4-1/2", 12.6 #, L- SO, IBT,AB Modlifed with Special ~ Clearance Couplings (4.920" ~ OD) l ~ ~ (1) 3.S75" DB nipple set@ 500' 10-3/4",45.5#, L-SO, Special Drift, BTC \ set @ +1- 3,179' MD 12,409' TVD @62 degrees TD 13-1/2" hole ~ ----~ (1) Gas Lift Mandrels, CAMCO 4-1t1i::2" x 1" Model KBG-2, one (1) set at <72 deg, one ,. 81:!~400' TVD. (1) Sliding Sleeve, with 3.81: j"'~ìpple, one (1) joint / above packer. ----.. D Sand Liner, 4-'1.",12.6#, LSO, 102L1"D"Sand~j~do\V@+I- R3 IBTM Yzslotted and Yz ~ 5,93S' MD 13,620"1Ir\fP. 77 degree/ bl;nk, (0:125" x 2.S" slots, 32 ¥ per foot, S.9% open area) f§~~~$ ~-~ ,,~ ~::;::.=-: ~== ----.. Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. ----- ----- ----- ----- Tublng,4-Yz" IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.S62" "DB" nipple. ----- ----- ----- 7-S/S", 29.7#, L-SO, BTCM /" Casing set @ +1- 6,500' MD I ~ 3,696' TVD. Set @ S9 degrees TD 9-7/S" hole \ B Sand Liner, 4-Yz", 12.6#, LSO, R3, ~ IBTM, Yz slotted and Yz blank (0.125" x 2.5" slots, 32 per foot, 5.9% open area) _,. 1E-102 As Built: ASP NAD 27 Eoslings: 550,301 ASP NAD 27 Northings: 5.960.081 Pad Elevation: 66.1' AMSL Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 94.1' AMSL . 1E-102L1: . 6-0/." D sand lateral TD @] 14,372' MD /3,641' TVD ----- ~~¡ ----- ~§ ~ ---....- 1E-102: J 6-0/." "B" Sand lateral TD @ 14,377' MD / 3,703' TVD KRU 1E...102 Proposed 1..WINJ West Sak B Sand 2032310 SFD 11/15/2004 ......., 4,000 . .'. SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 1078 / f I 2f201- DATE 12IY().J3v-1.þ~ý 62-14/311 ~~'œ"{~' ~r 1l1G-òF !lU/s:r,q IA 06c~ I, $ ¡IXI. .cß__. -- 6Jt4L- W ~ cÞ( ¿[,S ~ ~ OC/-COLLARS fÐ ~~M'" .11IIII-" CHASE Chose Manhattan Bonk USA, N.A. VaJ]l'd UP...T. O. 00 Dollars . · 200 Whit. Clay C.nte, D... Now..' DE 19'" ./¡,ïi.. . ..." .. I /) 'Î) ( !¿;;/CJ¿ 'U-/A-..- 't9· !h£óv" I~E~O? ¡. ¡. 0 0 ¡. ~ ~ I: 2 ¡. 8 ~ 7 ¡. 11 0 7 11 ¡; b ~~~~ 78 ---------- ~t........_'"'_oI!'~ ,... ___","__ _....". ~.._æJIaft; 1<-........--- ._.,~-,..g.:::Jè~~'-;I;¡,.. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME \ E - \(J )- PTD# ZLJcj-¿3! Development V Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new weJlboresegment of existing weD, . Permit No, .' API No. Production. sbould continue to be reported as a function' of tbe original API number. stated above. HOLE )n accordance with 20 AAC 25.005(f), aU records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and Jogs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fun compJiance witb 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:Jception. _ (Company Name) assumes tbe liability of any protest to the spacing .exception that may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater 1han 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample inter:vals through target zones. Field & Pool KUPARUK RIVER. WEST SAK OIL -490150 Well Name: KUPARUK RIV U WSAK 1E-102 PTD#: 204231 0 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType SER I PEND GeoArea 890 Unit 11160 1 Permittee Qttache~t . . . . . . . . . . . Yes. . . . 2 LeQs.e.ntJmberappropriat.e. . . . Yes. . . . . . . . 3 .U.niqtJe well.n.ame.and oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WeJlJocatßdin.a.ctefioe.dp.ool ....... ...... Yes. .KRUWestSa!<OjIP.ool.goYerned.byCo!1!~eJVation.Qrçler.No,4Q6B ........ 5 WeJlJocatßd proper .distance. from driJling uoitb.otJodary . . Yes. . WelJ is more thQn. 500 feet trom ao extemaJ pr.ope.rty lioe.. . . . . . . . . . . . . . . 6 WellJocatßd pr.operdistance from otber welJs. . . . . . . . . . Yes. f'Jo restriction!; QS.to welJ !;p<lCiog in COA06B . . . . . . . . . 7 .S.utfjcieotacreQge.ayQiI<lble indrilliog unit. . . . . . . . . Yes.. . . . . . . . . . . . 8 Jfdeviated. js. weJlbore platioclu.ded . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . .. ....... 9 .Oper.ator ooly Qffeçted party . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . 10 .Operator has.appr.opriate.b.ond inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Pß(IT)it. C<an be issueçl witbout conserva.tioo orçler . . . . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 12 Pß(IT)it.C<an be issueçlwitbout Qdmioistratille.apprpvaJ. . . Yßs. . . . . . . . . . . . . . . . . . . . . . SFD 11/16/2004 13 Can permit be approved before 15-day wait Yes 14 Well Jocated withio area alld.strata .atJthorized by.lojecti.oo Ordßr # (PutlO# inc.or:nmeots).(for. Yßs. . . . ,ð.rea Injectio.n.Qrder Np.. 2B. . . . . . . . . . . . . 15 All welJs.within .1 14. mite.area.of reyiew idßotified (Fpr !;ervjc.e.w.ell OOly). . . . . . . . . . . . . . . .Yes . . . . . . . KRU :11;-:18..1 B:06. 1.~-07, :1 B-08..1 B:OB,ð...1.B~1.0:1.. 1.BAO:11". 1.. :1 6-.102 .1 6-.12..1.B~1.1. . . . . . . . . . . . . . . . . . 16 Pre-pr.odu.ced injector; ~ur<ltion.of pre-pro~ucti.oo IßS!; thQIl3 mOlltbs (for service well only) . . .Yes . .. .. M.. Greeller. .CPAI..1 :1 1:16/2Q04: plao is .to pre-proçluce .the. weJlJr.om .30 to. 90 d.ay!;.. . . . . 17 ACMPFïlldjng.ofConsistency.h.as bee.ni!;stJed.for.tbis protect . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . Administration Appr TEM 18 19 20 21 22 23 24 25 26 27 Date 28 11/18/2004 29 30 31 32 33 34 Engineering ~~~ Geology 35 36 Date 37 11116/2004 38 39 Appr SFD Geologic Commissioner: o -rC; Program SER On/Off Shore On Well bore seg Annular Disposal ~ - - - - - .C.onductor strillg.provided . . . . . . . . . . . . . . . . . . . . Yes . . . . . . . SJJrfQceca!;iog.prote~t!; alLknown. USDWs . . . . . .NA. ..... ,ð.11 aq.uifel1> exer:npt.ed.40CFR 147.:102. (b).(3). .CMTv.otadeQu.ate.to çirc.utate on cood.uctor.& surfC$g . . . . . . . . . Yes. CMT vat adeQu.ate.to tie-in Jong .string to surf C!;g. . . . . . . No . . . . . . . M hydr.ocarbons pl<lOl1edto be ~overed.. . . .CMTwill coyeraJl !<oo.w.n.pro.ductiye borilOIlS. . . . . . . . . No. . .. .. Slotte.dJiner .completion pl<lOl1ed.. ............ .C.asing designs Qdequa.te f.or C..T, B&permafr.ost . . . . . . . Yes. . . . . . . . . . . . . . . . . .Adequ<lt.etallkage.o.rre.serve pit . . . . . . Yes. . . . . Rig is. e.qtJippe.d.with steel.pjts. . No reservepjtplanoe.d. All waste to.an .apprOlled .anl1ulu.sor Class It well. Jfa.re-drill, has a 1.0-403 for <lbandOllment beeo approved. . . . . . . . . . NA . . . . . . . . A~equ<lte.wellbore!;epQratio.npropose~. . . . . . . . . . . . . . . . . . . . . .. ......... Yes. . . . . . .l?r.oJ5imityan<llysis perfprme.d. Close approaçhe.sidentified.. Tra\{eJiogc;ytil1derplotjn.cl.uded~ .Gyrospo!;sible. Jfdiverter req.uiJed, does itmeet. reguJa.tions. . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . Drilliog fluid. program s~hematic.& eq.uipJistadequate . . . . . . . .Yes. . . . . . . BHfJ expected betwe.en B.3.- ß..6.EMW.. Plaon.ed MW 9.0- 9.1 ppg tor inlermediateand We.sl Sa.k. . .BOPEs.dp.they meet.reguJa.tioo . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . BOPE.PJessra.tiog appropriate;.testto(pu.t psig in.comr:nents) . . Yes. . . . . M.t\SfJ çalculated.at1.160 psj. 30DO psi.BOP.test pr.oPosed. . . . . . . . . . . . . . . . Choke manifold çompJies.w/API.R!>-53 (May 84). . . . . . . . . Yes . . . . .. . . . . . . . . .. . . . .. . . . . . . . Work will OCCJJr without.operatjon .sbutdown ....... . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Jspresence.ofH2SgQs.prob.able.... ................ No.. . H2Sisnotknown.ioWestSak. Ri.giseq.uipped.wilh.sensprs.andalarms........... ...... Meçba.nicaLc.oodjtionptwellswithin,ð.ORverifiect <ForservicewelJ onJ y)..... yes...... . f'JoKuparu!<welJsioAOR.. :1b-:10ta.nd.16-.102sa.tisfactorilycemeoted...... ........... Pßrmit. cao be issued wlo hydrogen. s.ulfide measures. ............ . . .YßS . . . . . . . KRU :1 D-Pad al1d.1.C~fJa.d.West $Qk. weJls :1 mjle toe<lstmeasured.le!;s.tban.5 ppm H2S. io 2004, .D.atapreseoted on. pote.ntialpveJpressure .zOl1es. . . . . . . . . . . . . . . . . . . . . . . . . . .Yes . . . . . . I;xpectect rßservoir pre.ssuJe is .8.3 - .8.6.ppg EMW; wilLbß.drilled w.itb 9.5.- 9.6 ppg r:ntJd.. . . . Seisr:nic.analysjs of sbaJlow gaszpoes. . . . . . . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Seabedconditipo survey (if off-sh.ore) . . . . . . . . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Contact l1amelphol1eJor.weekly prOgre!;Sreports [explorat.oryonly] . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ........... - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: J I ) )t?11 Engineering Commissioner: Public Commissioner Date .-/~ ~ ~ ~ Date Oñginal Signed By John K. Norman D D . . . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation. infomlation 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 Dr~ing Services LIS Scan Utility . C:<ot- 23. f $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 19 16:10:42 2005 fJJ-1~7-- Reel Header Service name..... ........LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name... ... . UNKNOWN Comments..... ........... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name.. ... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA lE-102 500292323600 ConocoPhillips Alaskal Inc. Sperry-Sun Drilling Services 19-JAN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003431828 P. ORTH M. THORNTON MWD RUN 3 MW0003431828 J. MARTIN M. THORNTON MWD RUN 4 MW0003431828 J. MARTIN M. THORNTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003431828 E. QUAM M. THORNTON MWD RUN 6 MW0003431828 E. QUAM D. GLADDEN MWD RUN 7 MW0003431828 E. QUAM D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 491 223 94.40 66.40 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 9.875 6.750 . SIZE (IN) DEPTH (FT) 10.750 3186.0 7.625 6498.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE lE-102 PB2 WELLBORE AT 12630'MD / 3685'TVDl BY MEANS OF AN OPEN-HOLE SIDETRACK. 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2 - 7 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUNS 2 & 3 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA (GP). RUNS 5 - 7 INCLUDED AT-BIT INCLINATION (ABI) . 6. EWR4 MEMORY WAS FULL AT 14090'MD / 3655'TVD. REAL-TIME SESP AND SEDP DATA ONLY ARE PRESENTED FROM THIS DEPTH TO TD. 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1 - 7 REPRESENT WELL lE-102 WITH API#:50-029-23236-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14360'MD / 3650'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record . . FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3160.0 3170.0 3170.0 3170.0 3170.0 3170.0 3196.5 STOP DEPTH 14298.0 14305.0 14305.0 14090.0 14305.0 14090.0 14359.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3160.0 4360.0 MWD 3 4360.0 4550.0 MWD 4 4550.0 6511.0 MWD 5 6511.0 6756.5 MWD 6 6757.0 12630.0 MWD 7 12630.5 14359.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type. ........... ......0 Data Specification Block Type.. ...0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value....... .............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3160 14359.5 8759.75 22400 3160 14359.5 ROP MWD FT/H 0.01 524.62 153.77 22327 3196.5 14359.5 GR MWD API 26.64 116.73 63.8309 22277 3160 14298 RPX MWD OHMM 1. 61 1693.54 41.1394 21841 3170 14090 RPS MWD OHMM 3.66 2000 39.6753 22271 3170 14305 RPM MWD OHMM 2.27 2000 43.708 21841 3170 14090 RPD MWD FET MWD O.~ 0.14 OHMM HOUR 2000 69.6 . 53.5424 22271 3170 1.43274 22271 3170 14305 14305 First Reading For Entire File......... .3160 Last Reading For Entire File.......... .14359.5 File Trailer Service name......... ... .STSLIB.OOl Service Sub Level Name... Version Number.. ...... ...1.0.0 Date of Generation...... .05/01/19 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.... ...05/01/19 Maximum Physical Record..65535 File Type.... ........... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 3160.0 3170.0 3170.0 3170.0 3170.0 3170.0 3196.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 4322.5 4314.5 4314.5 4314.5 4314.5 4314.5 4360.0 10-DEC-04 Insite 66.37 Memory 4360.0 3196.0 4360.0 60.0 66.2 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 TOOL NUMBER 053519 127479 # . 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): # 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 .1IN Max frames per record...... ...... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 9.875 3186.0 LSND 9.00 68.0 9.0 250 6.5 4.000 65.0 2.920 91.4 5.000 65.0 6.000 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD020 FT/H MWD020 API MWD020 OHMM MWD020 OHMM MWD020 OHMM MWD020 OHMM MWD020 HOUR Max 4360 387.01 115.73 24.69 1738.13 2000 2000 62.83 Min 3160 0.04 26.64 1.61 3.66 2.27 0.6 0.14 First Reading For Entire File........ ..3160 Last Reading For Entire File....... ....4360 Mean 3760 234.166 61.263 11.0027 12.8442 13.8348 24.9174 1. 9136 Nsam 2401 2328 2326 2290 2290 2290 2290 2290 First Reading 3160 3196.5 3160 3170 3170 3170 3170 3170 Last Reading 4360 4360 4322.5 4314.5 4314.5 4314.5 4314.5 4314.5 . File Trailer Service name.... ...... ...STSLIB.002 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/19 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.... ...05/01/19 Maximum Physical Record..65535 File Type... .......... ...LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 4315.0 4315.0 4315.0 4315.0 4315.0 4323.0 4360.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 4507.5 4507.5 4507.5 4507.5 4507.5 4515.0 4550.0 ll-DEC-04 Insite 66.37 Memory 4550.0 4360.0 4550.0 58.7 59.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 053519 127479 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: 9.875 3186.0 LSND . 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): # REMARKS: $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type.....O Logging Direction..... .... .... ... . Down Optical log depth units. ......... .Feet Data Reference Point.. ... ........ . Undefined Frame Spacing..... .... ...... ..... .60 .1IN Max frames per record. ..... ...... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 9.10 68.0 9.0 250 6.5 4.000 65.0 3.570 73.7 5.000 65.0 6.000 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4315 4550 4432.5 471 4315 4550 ROP MWD030 FT/H 38.35 355.16 234.381 380 4360.5 4550 GR MWD030 API 35.81 112.25 69.8084 385 4323 4515 RPX MWD030 OHMM 5.12 16.9 8.74433 386 4315 4507.5 RPS MWD030 OHMM 5.18 16.49 8.78655 386 4315 4507.5 RPM MWD030 OHMM 5.24 16.34 8.86837 386 4315 4507.5 RPD MWD030 OHMM 5.57 17.7 9.505 386 4315 4507.5 FET MWD030 HOUR 0.17 11. 9 3.11259 386 4315 4507.5 First Reading For Entire File......... .4315 Last Reading For Entire File.......... .4550 File Trailer Service name..... ....... .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Next . Type. . . . . . . . . . . . . . . . LO File Name.... ...... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record..65535 File Type.......... ..... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS FET RPD RPM GR ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 4508.0 4508.0 4508.0 4508.0 4508.0 4515.5 4550.5 STOP DEPTH 6456.5 6456.5 6456.5 6456.5 6456.5 6464.5 6511.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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): 12-DEC-04 Insite 66.37 Memory 6511.0 4550.0 6511.0 60.5 84.6 TOOL NUMBER 053519 127479 9.875 3186.0 LSND 9.10 68.0 9.0 300 5.4 4.000 65.0 MUD MUD MUD . AT MAX CIRCULATING FILTRATE AT MT: CAKE AT MT: TERMPERATURE: 2.550 5.000 6.000 . 105.8 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type. ....0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value.......... ......... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 4508 6511 5509.5 4007 4508 6511 ROP MWD040 FT/H 1. 57 524.62 173.12 3922 4550.5 6511 GR MWD040 API 29.44 116.73 75.3221 3899 4515.5 6464.5 RPX MWD040 OHMM 5.33 80.12 11.471 3898 4508 6456.5 RPS MWD040 OHMM 5.39 104.34 12.202 3898 4508 6456.5 RPM MWD040 OHMM 5.61 113.86 12.7678 3898 4508 6456.5 RPD MWD040 OHMM 6.16 156.81 14.5542 3898 4508 6456.5 FET MWD040 HOUR 0.18 9.74 0.842178 3898 4508 6456.5 First Reading For Entire File...... ... .4508 Last Reading For Entire File....... ....6511 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation..... ..05/01/19 Maximum Physical Record..65535 File Type.. ..... ....... ..LO Next File Name.. ....... ..STSLIB.005 Physical EOF . File Header Service name......... ... .STSLIB.005 Service Sub Level Name... Version Number... ..... ...1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type....... ........ .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR Rap $ 5 . header data for each bit run in separate files. 5 .5000 START DEPTH 6457.0 6457.0 6457.0 6457.0 6457.0 6465.0 6511.5 STOP DEPTH 6756.5 6756.5 6756.5 6756.5 6756.5 6756.5 6756.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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: 16-DEC-04 Insite 66.37 Memory 6757.0 6511.0 6757.0 84.6 97.6 TOOL NUMBER 135134 73764 6.750 6498.0 Oil Based 9.00 88.0 3.7 44000 3.0 .000 .000 .000 .000 .0 111.0 .0 .0 . HOLE CORRECTION (IN): . # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........... ... ....0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.... ...... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value.......... .......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6457 6756.5 6606.75 600 6457 6756.5 ROP MWD050 FT/H 0.18 404.42 121.188 491 6511.5 6756.5 GR MWD050 API 27.98 78.31 53.5844 584 6465 6756.5 RPX MWD050 OHMM 5.73 1693.54 76.7275 600 6457 6756.5 RPS MWD050 OHMM 9.05 1699 68.664 600 6457 6756.5 RPM MWD050 OHMM 14.66 2000 201.28 600 6457 6756.5 RPD MWD050 OHMM 1.17 2000 251.615 600 6457 6756.5 FET MWD050 HOUR 0.3 69.6 14.5459 600 6457 6756.5 First Reading For Entire File...... ....6457 Last Reading For Entire File..... ..... .6756.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/01/19 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... .~SLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX GR RPS RPM RPD FET ROP $ 6 . header data for each bit run in separate files. 6 .5000 START DEPTH 6757.0 6757.0 6757.0 6757.0 6757.0 6757.0 6757.0 STOP DEPTH 12630.0 12630.0 12630.0 12630.0 12630.0 12630.0 12630.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): # REMARKS: $ 21-DEC-04 Insite 66.37 Memory 12630.0 6757.0 12630.0 85.7 95.0 TOOL NUMBER 135134 73764 6.750 6498.0 Oil Based 9.00 82.0 .0 39000 .0 .000 .000 .000 .000 .0 118.0 .0 .0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction..... ........ ... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing...... .............. .60 .1IN Max frames per record. ........... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6757 12630 9693.5 11747 6757 12630 ROP MWD060 FT/H 0.01 393.62 134.133 11747 6757 12630 GR MWD060 API 29.57 105.57 59.9979 11747 6757 12630 RPX MWD060 OHMM 6.94 1627.29 59.477 11747 6757 12630 RPS MWD060 OHMM 7.93 2000 56.3595 11747 6757 12630 RPM MWD060 OHMM 7.96 2000 57.22 11747 6757 12630 RPD MWD060 OHMM 7.19 2000 69.1688 11747 6757 12630 FET MWD060 HOUR 0.31 30.23 0.96948 11747 6757 12630 First Reading For Entire File......... .6757 Last Reading For Entire File......... ..12630 File Trailer Service name.......... ...STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/01/19 Maximum Physical Record. .65535 File Type.......... ..... .LO Next File Name.. ....... ..STSLIB.007 Physical EOF File Header Service name..... ........STSLIB.007 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation..... ..05/01/19 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. . BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 7 .5000 START DEPTH 12630.5 12630.5 12630.5 12630.5 12630.5 12630.5 12630.5 STOP DEPTH 14305.0 14090.0 14305.0 14090.0 14298.0 14359.5 14305.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point.. .......... ..Undefined . 23-DEC-04 Insite 66.37 Memory 14360.0 12630.0 14360.0 88.9 92.7 TOOL NUMBER 135134 73764 6.750 6498.0 oil Based 9.00 81. 0 .0 38000 2.6 .000 .000 .000 .000 .0 123.8 .0 .0 . . Frame Spaclng...... .............. .60 .1IN Max frames per record............ . Undefined Absent value..... ..... ....... .... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12630.5 14359.5 13495 3459 12630.5 14359.5 ROP MWD070 FT/H 0.07 445.72 140.18 3459 12630.5 14359.5 GR MWD070 API 37.41 98.06 66.7915 3336 12630.5 14298 RPX MWD070 OHMM 10.3 148.82 27.5784 2920 12630.5 14090 RPS MWD070 OHMM 10.92 87.31 29.8467 3350 12630.5 14305 RPM MWD070 OHMM 10.53 107.1 26.309 2920 12630.5 14090 RPD MWD070 OHMM 11.98 1865.5 33.2792 3350 12630.5 14305 FET MWD070 HOUR 0.31 17.66 0.873475 3350 12630.5 14305 First Reading For Entire File......... .12630.5 Last Reading For Entire File.......... .14359.5 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ ... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF .. . . Physical EOF End Of LIS File Sperry-Sun Dr~ng Services LIS Scan Utility . apçt-~3 ( $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 19 14:47:52 2005 ~. '-"'" ) ) 2i~) Reel Header Service name... ........ ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number. .... .01 Previous Reel Name.... ...UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin.................. .STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-102 PB1 500292323670 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 19-JAN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003431828 P. ORTH M. THORNTON MWD RUN 3 MW0003431828 J. MARTIN M. THORNTON MWD RUN 4 MW0003431828 J. MARTIN M. THORNTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003431828 E. QUAM M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 491 223 94.40 66.40 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S' (IN) 9.875 6.750 . SIZE (IN) DEPTH (FT) 10.750 3186.0 7.625 6498.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 - 5 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUNS 2 & 3 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA (GP). RUN 5 INCLUDED AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 5 REPRESENT WELL 1E-102 PB1 WITH API#:50-029-23236-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8048'MD / 3685'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record..65535 File Type............... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE 1 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH GR FET RPD RPM RPS RPX ROP $ 3160.' 3170.0 3170.0 3170.0 3170.0 3170.0 3196.5 . 7986.0 7993.0 7993.0 7993.0 7993.0 7993.0 8048.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 2 3 4 5 MERGE TOP 3160.0 4360.0 4550.0 6511.0 MERGE BASE 4360.0 4550.0 6511.0 8048.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type...... .......... ..0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point........... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value....... ........ .......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3160 8048 5604 9777 3160 8048 ROP MWD FT/H 0.04 524.62 186.673 9704 3196.5 8048 GR MWD API 26.64 126.56 74.3359 9653 3160 7986 RPX MWD OHMM 1. 61 1693.54 17.946 9647 3170 7993 RPS MWD OHMM 3.66 1738.13 17.9004 9647 3170 7993 RPM MWD OHMM 2.27 2000 27.0148 9647 3170 7993 RPD MWD OHMM 0.6 2000 34.5738 9647 3170 7993 FET MWD HOUR 0.14 69.6 2.00489 9647 3170 7993 First Reading For Entire File...... ... .3160 Last Reading For Entire File........ ...8048 File Trailer Service name............ .STSLIB.001 . Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. ..... .05/01/19 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...... .05/01/19 Maximum Physical Record. .65535 File Type.... ......... ...LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 3160.0 3170.0 3170.0 3170.0 3170.0 3170.0 3196.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 4322.5 4314.5 4314.5 4314.5 4314.5 4314.5 4360.0 10-DEC-04 Insite 66.37 Memory 4360.0 3196.0 4360.0 60.0 66.2 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 053519 127479 # 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: 9.875 3186.0 LSND 9.00 68.0 9.0 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: . . 250 6.5 4.000 2.920 5.000 6.000 65.0 91.4 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... .... ..... ..0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 RPX MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPM MWD020 OHMM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 FET MWD020 HOUR 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3160 4360 3760 2401 3160 4360 GR MWD020 API 26.64 115.73 61.263 2326 3160 4322.5 RPX MWD020 OHMM 1. 61 24.69 11.0027 2290 3170 4314.5 RPS MWD020 OHMM 3.66 1738.13 12.8442 2290 3170 4314.5 RPM MWD020 OHMM 2.27 2000 13.8348 2290 3170 4314.5 RPD MWD020 OHMM 0.6 2000 24.9174 2290 3170 4314.5 FET MWD020 HOUR 0.14 62.83 1.9136 2290 3170 4314.5 ROP MWD020 FT/H 0.04 387.01 234.166 2328 3196.5 4360 First Reading For Entire File......... .3160 Last Reading For Entire File.......... .4360 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .05/01/19 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...... .05/01/19 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS FET RPX RPD GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 4315.0 4315.0 4315.0 4315.0 4315.0 4323.0 4360.5 STOP DEPTH 4507.5 4507.5 4507.5 4507.5 4507.5 4515.0 4550.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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: 11-DEC-04 Insite 6511 Memory 4550.0 4360.0 4550.0 58.7 59.5 TOOL NUMBER 053519 127479 9.875 3186.0 LSND 9.10 68.0 9.0 250 6.5 4.000 3.570 5.000 6.000 65.0 73.7 65.0 65.0 # . . NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............ .....Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value............... .... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4315 4550 4432.5 471 4315 4550 ROP MWD030 FT/H 38.35 355.16 234.381 380 4360.5 4550 GR MWD030 API 35.81 112.25 69.8084 385 4323 4515 RPX MWD030 OHMM 5.12 16.9 8.74433 386 4315 4507.5 RPS MWD030 OHMM 5.18 16.49 8.78655 386 4315 4507.5 RPM MWD030 OHMM 5.24 16.34 8.86837 386 4315 4507.5 RPD MWD030 OHMM 5.57 17.7 9.505 386 4315 4507.5 FET MWD030 HOUR 0.17 11.9 3.11259 386 4315 4507.5 First Reading For Entire File......... .4315 Last Reading For Entire File.......... .4550 File Trailer Service name.......... ...STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.... ...05/01/19 Maximum Physical Record. .65535 File Type............... .LO Next File Name.. ...... ...STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... version Number......... .~o.o Date of Generation..... ..05/01/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.. .... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM FET RPD GR ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 4508.0 4508.0 4508.0 4508.0 4508.0 4515.5 4550.5 STOP DEPTH 6456.5 6456.5 6456.5 6456.5 6456.5 6464.5 6511.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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): 12-DEC-04 Insite 6511 Memory 6511.0 4550.0 6511. 0 60.5 84.6 TOOL NUMBER 053519 127479 9.875 3186.0 LSND 9.10 68.0 9.0 300 5.4 4.000 2.550 5.000 6.000 65.0 105.8 65.0 65.0 EWR FREQUENCY (HZ): . . # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction... ........ ......Down Optical log depth units..... ......Feet Data Reference Point.... ..........Undefined Frame Spacing.... ...... ...... .....60 .1IN Max frames per record.. ........ ...Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4508 6511 5509.5 4007 4508 6511 ROP MWD040 FT/H 1.57 524.62 173.12 3922 4550.5 6511 GR MWD040 API 29.44 116.73 75.3221 3899 4515.5 6464.5 RPX MWD040 OHMM 5.33 80.12 11.471 3898 4508 6456.5 RPS MWD040 OHMM 5.39 104.34 12.202 3898 4508 6456.5 RPM MWD040 OHMM 5.61 113.86 12.7678 3898 4508 6456.5 RPD MWD040 OHMM 6.16 156.81 14.5542 3898 4508 6456.5 FET MWD040 HOUR 0.18 9.74 0.842178 3898 4508 6456.5 First Reading For Entire File...... ... .4508 Last Reading For Entire File.......... .6511 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type............. ...LO Next File Name........ ...STSLIB.005 Physical EOF File Header Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ . 5 . header data for each bit run in separate files. 5 .5000 START DEPTH 6457.0 6457.0 6457.0 6457.0 6457.0 6465.0 6511.5 STOP DEPTH 7993.0 7993.0 7993.0 7993.0 7993.0 7986.0 8048.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 16-DEC-04 Insite 6511 Memory 8048.0 6511.0 8048.0 84.6 97.6 TOOL NUMBER 135134 73764 6.750 6498.0 Oil Based 9.00 88.0 3.7 44000 3.0 .000 111.000 .000 .000 .0 .0 .0 .0 Of' , 1 k4IÞ Data Specl lcatlon B oc Type... ..0 Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6457 8048 7252.5 3183 6457 8048 ROP MWD050 FT/H 0.18 404.42 162.101 3074 6511.5 8048 GR MWD050 API 27.98 126.56 83.6376 3043 6465 7986 RPX MWD050 OHMM 4.64 1693.54 32.4893 3073 6457 7993 RPS MWD050 OHMM 5.21 1699 30.0414 3073 6457 7993 RPM MWD050 OHMM 5.67 2000 57.188 3073 6457 7993 RPD MWD050 OHMM 1.17 2000 70.3129 3073 6457 7993 FET MWD050 HOUR 0.3 69.6 3.40865 3073 6457 7993 First Reading For Entire File...... ." .6457 Last Reading For Entire File....... ... .8048 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .05/01/19 Maximum Physical Record. .65535 File Type... .... ........ .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .... . UNKNOWN Continuation Number..... .01 Next Tape Name... ... .... .UNKNOWN Comments... ..... ....... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services . . Physical EOF Physical EOF End Of LIS File Sperry-Sun Dri~ng Services LIS Scan Utility . Ol..t:>tf- ó?3 ( ~ l:Lq\o~ . $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 19 15:08:48 2005 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ... ....... ...UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ..... . UNKNOWN Continuation Number..... .01 Previous Tape Name.... ...UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-102 PB2 500292323671 ConocoPhillips Alaska, Inc. Sperry-SunDrilling Services 19-JAN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003431828 P. ORTH M. THORNTON MWD RUN 3 MW0003431828 J. MARTIN M. THORNTON MWD RUN 4 MW0003431828 J. MARTIN M. THORNTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003431828 E. QUAM M. THORNTON MWD RUN 6 MW0003431828 E. QUAM D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATIoN (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 491 223 MSL 0) 94.40 66.40 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 9.875 6.750 SIZE (IN) DEPTH (FT) 10.750 3186.0 7.625 6498.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE 1E-102 PB1 WELLBORE AT 6757'MD / 3716'TVD, BY MEANS OF AN OPEN-HOLE SIDETRACK. 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2 - 6 COMPRISED DIRECTIONAL¡ DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4)¡ AND PRESSURE WHILE DRILLING (PWD). RUNS 2 & 3 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA (GP). RUNS 5 & 6 INCLUDED AT-BIT INCLINATION (ABI) . 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 6 REPRESENT WELL 1E-102 PB2 WITH API#:50-029-23236-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12901'MD / 3666'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name... ....... ...STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ... .05/01/19 Maximum Physical Record..65535 File Type..... . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ cliPpe~rvesi .5000 START DEPTH 3160.0 3170.0 3170.0 3170.0 3170.0 3170.0 3196.5 all bit runs merged. . STOP DEPTH 12839.0 12846.0 12846.0 12846.0 12846.0 12846.0 12901.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 2 3 4 5 6 MERGED MAIN PASS. $ MERGE TOP 3160.0 4360.0 4550.0 6511.0 6757.0 MERGE BASE 4360.0 4550.0 6511.0 6756.5 12901.0 # Data Format Specification Record Data Record Type...... .......... ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing....... ....... ...... .60 .1IN Max frames per record. ..... .......Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3160 12901 8030.5 19483 3160 12901 ROP MWD FT/H 0.01 524.62 155.375 19410 3196.5 12901 GR MWD API 26.64 123.63 63.5238 19359 3160 12839 RPX MWD OHMM 1. 61 1693.54 42.9896 19353 3170 12846 RPS MWD OHMM 3.66 2000 41. 2172 19353 3170 12846 RPM MWD OHMM 2.27 2000 46.1387 19353 3170 12846 RPD MWD OHMM 0.6 2000 56.8749 19353 3170 12846 FET MWD HOUR 0.14 69.6 1.51877 19353 3170 12846 , d' "1. Flrst Rea lng For Entlre Fl e......... .3160 Last Reading For Entire File.... ...... .12901 . File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/19 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. ..... .05/01/19 Maximum Physical Record. .65535 File Type........ ........LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 3160.0 3170.0 3170.0 3170.0 3170.0 3170.0 3196.5 STOP DEPTH 4322.5 4314.5 4314.5 4314.5 4314.5 4314.5 4360.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10-DEC-04 Insite 66.37 Memory 4360.0 3196.0 4360.0 60.0 66.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 053519 127479 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 3186.0 # . 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): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ... ........ .... . Down Optical log depth units.. ..... ....Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value............... .... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . LSND 9.00 68.0 9.0 250 6.5 4.000 2.920 5.000 6.000 65.0 91.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3160 4360 3760 2401 3160 4360 ROP MWD020 FT/H 0.04 387.01 234.166 2328 3196.5 4360 GR MWD020 API 26.64 115.73 61. 263 2326 3160 4322.5 RPX MWD020 OHMM 1. 61 24.69 11.0027 2290 3170 4314.5 RPS MWD020 OHMM 3.66 1738.13 12.8442 2290 3170 4314.5 RPM MWD020 OHMM 2.27 2000 13.8348 2290 3170 4314.5 RPD MWD020 OHMM 0.6 2000 24.9174 2290 3170 4314.5 FET MWD020 HOUR 0.14 62.83 1. 9136 2290 3170 4314.5 First Reading For Entire File........ ..3160 Last Reading For Entire File.......... .4360 File Trailer Service name...... ...... .STSLIB.002 Service Sub Level Name. . . . Version Number.......... .1.0.0 Date of Generation.... ...05/01/19 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...... .05/01/19 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPX FET RPD GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 4315.0 4315.0 4315.0 4315.0 4315.0 4323.0 4360.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 4507.5 4507.5 4507.5 4507.5 4507.5 4515.0 4550.0 11-DEC-04 Insite 66.37 Memory 4550.0 4360.0 4550.0 58.7 59.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 053519 127479 # 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): 9.875 3186.0 LSND 9.10 68.0 9.0 250 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: . . 6.5 4.000 65.0 3.570 73.7 5.000 65.0 6.000 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ....... ...0 Data Specification Block Type. ....0 Logging Direction..... .,. .........Down Optical log depth units..... .... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. ................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4315 4550 4432.5 471 4315 4550 ROP MWD030 FT/H 38.35 355.16 234.381 380 4360.5 4550 GR MWD030 API 35.81 112.25 69.8084 385 4323 4515 RPX MWD030 OHMM 5.12 16.9 8.74433 386 4315 4507.5 RPS MWD030 OHMM 5.18 16.49 8.78655 386 4315 4507.5 RPM MWD030 OHMM 5.24 16.34 8.86837 386 4315 4507.5 RPD MWD030 OHMM 5.57 17.7 9.505 386 4315 4507.5 FET MWD030 HOUR 0.17 11.9 3.11259 386 4315 4507.5 First Reading For Entire File......... .4315 Last Reading For Entire File.......... .4550 File Trailer Service name..... ...... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.004 . Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 4508.0 4508.0 4508.0 4508.0 4508.0 4515.5 4550.5 STOP DEPTH 6456.5 6456.5 6456.5 6456.5 6456.5 6464.5 6511.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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: # 12-DEC-04 Insite 66.37 Memory 6511.0 4550.0 6511.0 60.5 84.6 TOOL NUMBER 053519 127479 9.875 3186.0 LSND 9.10 68.0 9.0 300 5.4 4.000 2.550 5.000 6.000 65.0 105.8 65.0 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION . . (IN) : # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ........ ..0 Data Specification Block Type. ....0 Logging Direction..... ..... ... ... . Down Optical log depth units...... .... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4508 6511 5509.5 4007 4508 6511 ROP MWD040 FT/H 1. 57 524.62 173.12 3922 4550.5 6511 GR MWD040 API 29.44 116.73 75.3221 3899 4515.5 6464.5 RPX MWD040 OHMM 5.33 80.12 11.471 3898 4508 6456.5 RPS MWD040 OHMM 5.39 104.34 12.202 3898 4508 6456.5 RPM MWD040 OHMM 5.61 113.86 12.7678 3898 4508 6456.5 RPD MWD040 OHMM 6.16 156.81 14.5542 3898 4508 6456.5 FET MWD040 HOUR 0.18 9.74 0.842178 3898 4508 6456.5 First Reading For Entire File......... .4508 Last Reading For Entire File.......... .6511 File Trailer Service name.......... ...STSLIB.004 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record. .65535 File Type.. ............. .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.... ........ .STSLIB.005 Service Sub Level Name... Version Number. ...... ....1.0.0 Date of Generation...... ~01/19 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPD FET RPX GR Rap $ 5 . header data for each bit run in separate files. 5 .5000 START DEPTH 6457.0 6457.0 6457.0 6457.0 6457.0 6465.0 6511.5 STOP DEPTH 6756.5 6756.5 6756.5 6756.5 6756.5 6756.5 6756.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): 16-DEC-04 Insite 66.37 Memory 6757.0 6511.0 6757.0 84.6 97.6 TOOL NUMBER 135134 73764 6.750 6498.0 Oil Based 9.00 88.0 3.7 44000 3.0 .000 .000 .000 .000 .0 111.0 .0 .0 # . . REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction........ ....... ..Down Optical log depth units.......... .Feet Data Reference Point.. ...... ..... . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6457 6756.5 6606.75 600 6457 6756.5 ROP MWD050 FT/H 0.18 404.42 121.188 491 6511. 5 6756.5 GR MWD050 API 27.98 78.31 53.5844 584 6465 6756.5 RPX MWD050 OHMM 5.73 1693.54 76.7275 600 6457 6756.5 RPS MWD050 OHMM 9.05 1699 68.664 600 6457 6756.5 RPM MWD050 OHMM 14.66 2000 201.28 600 6457 6756.5 RPD MWD050 OHMM 1.17 2000 251.615 600 6457 6756.5 FET MWD050 HOUR 0.3 69.6 14.5459 600 6457 6756.5 First Reading For Entire File......... .6457 Last Reading For Entire File...... .... .6756.5 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name. . . Version Number.. ........ .1.0.0 Date of Generation...... .05/01/19 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name......... ....STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .05/01/19 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER . FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 6 . header data for each bit run in separate files. 6 .5000 START DEPTH 6757.0 6757.0 6757.0 6757.0 6757.0 6757.0 6757.0 STOP DEPTH 12846.0 12846.0 12846.0 12846.0 12839.0 12901. 0 12846.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O 21-DEC-04 Insite 66.37 Memory 12901. 0 6757.0 12901. 0 85.7 95.0 TOOL NUMBER 135134 73764 6.750 6498.0 Oil Based 9.00 82.0 .0 39000 .0 .000 .000 .000 .000 .0 118.0 .0 .0 . Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ..... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record. ..... ...... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6757 12901 9829 12289 6757 12901 ROP MWD060 FT/H 0.01 393.62 133.708 12289 6757 12901 GR MWD060 API 29.57 123.63 60.4529 12165 6757 12839 RPX MWD060 OHMM 5.24 1627.29 58.5151 12179 6757 12846 RPS MWD060 OHMM 5.74 2000 55.5144 12179 6757 12846 RPM MWD060 OHMM 5.8 2000 56.4316 12179 6757 12846 RPD MWD060 OHMM 6.73 2000 68.3364 12179 6757 12846 FET MWD060 HOUR 0.31 30.23 0.968778 12179 6757 12846 First Reading For Entire File......... .6757 Last Reading For Entire File.......... .12901 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/01/19 Maximum Physical Record..65535 File Type............... .LO Next File Name......... ..STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ..... .......UNKNOWN Continuation Number..... .01 Next Tape Name... ........UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name..... ..... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments...... ......... ..STS LIS Writing Library. Scientific Technical Services . . Physical EOF Physical EOF End Of LIS File