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205-006
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-11-18_22137_KRU_1E-105_InjectionProfile.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22137 KRU 1E-105 50-029-23243-00 Injection Profile 18-Nov-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 205-006 T38145 11/22/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.22 12:45:15 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-105 KUPARUK RIV U WSAK 1E-105 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/29/2022 1E-105 50-029-23243-00-00 205-006-0 W SPT 3512 2050060 1500 262 263 263 263 156 157 157 157 4YRTST P Adam Earl 11/13/2022 MIT IA 30 MinPretest Initial 15 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-105 Inspection Date: Tubing OA Packer Depth 1040 1800 1765 1760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE221114154752 BBL Pumped:1.6 BBL Returned:1.5 Thursday, December 29, 2022 Page 1 of 1 5HJJ-DPHV% 2*& )URP %URRNV3KRHEH/ 2*& 6HQW 7XHVGD\-XQH $0 7R 5HJJ-DPHV% 2*& 6XEMHFW ): >(;7(51$/@5( .58(3DGQRQZLWQHVVHG0,7,$V WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůLJƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). 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Do not click links or open attachments unless you recognize the sender and know the content is safe. .58( 37' ĐŽƌƌĞĐƚĚĂƚĞŝƐϲͬϭͬϮϮ͘ :ĂŶ͕ tŝůůLJŽƵǀĞƌŝĨLJƚŚĞĚĂƚĞŽĨƚĞƐƚŝŶŐ͍dŚĞĨŝůĞŶĂŵŝŶŐĐŽŶǀĞŶƚŝŽŶŝŶĐůƵĚĞĚϲͬϭͬϮϮ͕ďƵƚƚŚĞƌĞƉŽƌƚĚĂƚĞŝŶĐůƵĚĞĚϲͬϮͬϮϮ;/͛ŵ ĂƐƐƵŵŝŶŐŝƚƐŚŽƵůĚďĞϲͬϭͿ͍ dŚĂŶŬLJŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůLJƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗tĞůů/ŶƚĞŐƌŝƚLJ^ƉĞĐŝĂůŝƐƚW&ϭΘW&ϯфŶϭϲϭϳΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂLJ͕:ƵŶĞϮ͕ϮϬϮϮϭ͗ϮϴWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ> ;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗<Zhϭ ͲWĂĚŶŽŶǁŝƚŶĞƐƐĞĚD/d/Ɛ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭ ͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 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-105 1 Carlisle, Samantha J (OGC) From:Regg, James B (OGC) Sent:Thursday, February 17, 2022 11:59 AM To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on CPAI Well 1E-105 on 2/16/2022 KRU 1E‐105 (PTD 2050060) 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: Wednesday, February 16, 2022 8:26 PM 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> Subject: LPP/SSV Returned to Service on CPAI Well 1E‐105 on 2/16/2022 Jim, The low pressure pilot (LPP) on well 1E‐105 (PTD# 205‐006, #205‐007, #205‐008) was returned to service and removed from the “Facility Defeated Safety Device Log” on 2/16/2022, after the well was shut in. The LPP had been defeated on 1/20/2022 after a significant injection rate reduction and injection pressure 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, Toon Toon Changklungdee WestSak Production Engineer Office: (907) 659‐7234 / (907) 265‐1375 Cell: (303) 564‐7586 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. 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-105 on 1/20/2022 Date:Thursday, January 20, 2022 5:18:32 PM 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: Thursday, January 20, 2022 3:44 PM 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> Subject: Defeated LPP/SSV on CPAI Well 1E-105 on 1/20/2022 Jim, The low pressure pilot (LPP) on well 1E-105 (PTD# 205-006, #205-007, #205-008) was defeated today, 1/20/2022 after a significant injection rate reduction and injection pressure could not satisfy the LPP. The well is currently injecting at a wellhead pressure of 102 psi and a rate of 730 BWPD. The LPP and surface safety valves (SSV) will be tagged and their status 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 k�PUA I C-1011;_ Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, July 22, 2021 2:34 PM To: Regg, James B (CED) 7[ Z ZI Z,Zf Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska); CPF1 Prod Engr; Thomson, Stephanie Subject: LPP/SSV Returned to Service on CPAI Well 1 E-105 on 7/22/2021 Jim, The low pressure pilot (LPP) on well 1E-105 (PTD# 205-006, #205-007, #205-008) was returned to service and removed from the "Facility Defeated Safety Device Log" on 7/22/2021, as the injection pressure increased above the LPP setpoint from sustained injection in the pattern. The well is currently injecting 1000 BWPD at 160 psi wellhead pressure. The LPP had been defeated on 5/12/2021 when the well was returned to injection after an extended shut-in period. 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 WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 KP -t& tE- IoS (Irt 705'0v.0 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> fj 5/1 3I ?ffL( Sent: Wednesday, May 12, 2021 2:25 PM To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska) Subject: Defeated LPP/SSV on CPAI Well 1 E-105 on 5/12/2021 Jim, The low pressure pilot (LPP) on well 1E-105 (PTD# 205-006, #205-007, #205-008) was defeated today, 5/12/2021, when the well was returned to injection after an extended shut-in period. The well is currently injecting at a wellhead pressure of 19 psi and a rate of 850 BWPD. The LPP and surface safety valves (SSV) will be taped and their status 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 4068.001." / Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Kelly Lyons CPF1 / WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1C-150 50-029-23496-00 906922998 West Sak Multi Finger Caliper Field & Processed 17-Jan-21 0 1 2 1C-150 50-029-23496-00 906922998 West Sak Injection Profile with TMD3D Field & Processed 17-Jan-21 0 1 3 1D-125A 50-029-22904-01 906903184 West Sak Plug Setting Record Field- Final 4-Jan-21 0 1 4 1D-142 50-029-23529-00 906921246 West Sak Multi Finger Caliper Field & Processed 15-Jan-21 0 1 5 1D-142 50-029-23529-00 906921246 West Sak Injection Profile with TMD3D Field & Processed 16-Jan-21 0 1 6 1E-105 50-029-23243-00 906936637 West Sak Injection Profile Field & Processed 25-Jan-21 0 1 7 1E-117 50-029-23251-00 906931006 West Sak Injection Profile Field & Processed 21-Jan-21 0 1 8 1J-118 50-029-23337-00 906941926 West Sak Packer Setting Record Field- Final 26-Jan-21 0 1 9 1J-122 50-029-23359-00 906955932 West Sak Injection Profile with TMD3D Field & Processed 6-Feb-21 0 1 10 1J-127 50-029-23306-00 906953848 West Sak Injection Profile with TMD3D Field & Processed 2-Feb-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2050060 E-Set: 34721 f b 00�'cxyo Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, October 3, 2020 2:12 PMQ�`� i 0l To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Mowrey, Andrew F Subject: LPP/SSV Returned to Service on Well 1 E-105 on 10/3/2020 Jim, The low pressure pilot (LPP) on well 1E-105 (PTD# 205-006, #205-007, #205-008) was returned to service and removed from the "Facility Defeated Safety Device Log" Saturday, 10/3/2020, as the injection pressure increased above the LPP setpoint. The well is currently injecting 2584 BWPD at 264 psi wellhead pressure. The LPP had been defeated on 9/3/2020. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Devin Kozak WSPE Fill -In ConocoPhillips Alaska, Inc. Cell: 254-203-3564 1 0 l4t-10 Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Thursday, September 3, 2020 7:42 AM --] � To: Regg, James B (CED) l`E 1r3(/ Zou' Cc: Autry, Sydney; Braun, Michael (Alaska); Mowrey, Andrew F; CPF1 Ops Supv; CPF1&2 Ops Supt; CPF1 DS Lead Techs Subject: Defeated LPP/SSV on CPAI Well 1 E-105 on 9/3/2020 Jim, 11 The low pressure pilot (LPP) on well 1E-105 (PTD# 205-006, #205-007, #205-008) was defeated today, 9/3/2020, when the well was returned to injection after an extended shut-in period. The well is currently injecting at a wellhead pressure of 10 psi and a rate of 1300 BWPD. The LPP and surface safety valves (SSV) will be tagged and their status 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 / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Marina's Cell: (907) 399-7791 Pager: (907) 659-7000 4497 l<R�A I E- I ()t PTS Z057004,0 Regg, James B (DOA) From: Changklungdee, Toon <Toon.Changklungdee@conocophillips.com> Sent: Sunday, March 31, 2019 3:31 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; NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI Well 1 E-105 Jim, The low pressure pilot (LPP) on well 1E-105 (PTD# 205-006) was returnqd to s@4:%iG@ and removed from the "Facility Defeated Safety Device Log" today 3/31/2019, after wellhead injection pressure built up above the LPP setpoint. The well is currently injecting 1100 BWPD at an injection pressure of 145 psi.. 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 Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> ��� ��� Sent: Saturday, March 16, 2019 5:00 AM Ili 5I f elt To: Regg, James B (DOA) I, P 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-105 on 3/15/2019 Jim, i The low pressure pilot (LPP) on well 1E-105 (PTD# 205-006) was defeated last night on 3/15/2019 after the well was returned to injection. The well is currently injecting at a wellhead pressure o psi and a rate of 613 BWPD. The LPP and surface safety valves (SSV) will be tagged and their status 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 20 5006 WELL LOG 2 9 1 8 9 T NSM/T TA L PROAcTiVE DiAgNosric SERVICES, INC. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 SCANNED Anchorage, Alaska 99501 (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: Y 1 RECEIVEProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road MAR 2 9 2018 Suite C Anchorage, AK 99518 AOGCC Fax: (907) 245-8952 1) Injection Profile 10-Mar-18 1E-105 Color Log/CD 50-029-23243-00 2) •c� t I Signed : Date : gDftiS Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.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\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • . 205006 RECElVED2 9 1 2 2 WELL LOG MAR 0 2 2018 TRANSMITTAL AOGCC PROACTIVE DiACINOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (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. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED 1) Injection Profile 17-Jan-18 1E-105 Color Log/CD 50-029-23243-00 2) Signed : /� 1 Date : Print Name: 1v\C 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(WMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\Conocophil lips_Transmit,docx • • e . ---(OS ft 2osoo(,o Regg, James B (DOA) From: Regg, James B (DOA) iz.1I Sent: Tuesday,January 2, 2018 9:28 AM 1 '' ( To: 'NSK West Sak Prod Engr' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: RE: LPP/SSV Returned to Service on CPAI Well 1E-105 - 12/31/2017 Correct PTD#is 2050060 Jim Regg Supervisor, Inspections AOGCC CANNA 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent:Sunday, December 31, 2017 6:36 AM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>; CPF1&2 Ops Supt<n2073@conocophillips.com>; Autry,Sydney <Sydney.Autry@conocophillips.com>;Targac, Gary<Gary.Targac@conocophillips.com>; Fox, Pete B <Pete.B.Fox@conocophillips.com>; Sudan, Hari Hara <Hari.H.Sudan@conocophillips.com> Subject: LPP/SSV Returned to Service on CPAI Well 1E-105 - 12/31/2017 Jim, The low pressure pilot (LPP) on well 1E-105 (PTD#J04- 2Z)was returned to service and removed from the "Facility Defeated Safety Device Log" today, 12/31/20 `/,after the well was shut-in. The LPP had been defeated on 12/12/2017 when wellhead pressure fell below the LPP setpoint of 100 psi. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski /Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 1 (..( )E-LOS S � Zocc o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, December 12, 2017 7:23 PM ! Z 1`5I t 7 To: NSK West Sak Prod Engr; 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; Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1E-105 on 12/12/2017 Jim, SOO‘;O The low pressure pilot (LPP) on well 1E-105 (PTD#2 2)will be defeated today, 12/12/2017, due to declining wellhead pressure following recent wellwork to improve injection efficiency.The well is currently injecting at a wellhead pressure of 124 psi and a rate of 1160 BWPD.The LPP and surface safety valves (SSV) will be tagged and their status 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. Evan Reilly on behalf of Marina Krysinski /Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. 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Q 0 0) M M C) O 0) C) M , 0) 01 vi p N N O O N N N N O N N .1":Q) O O O O o O O O 0 0 0 0 0 0 0 0 0 0 0 000 C N N N N N U) in M) N to In a 0U C Cin C F crl N U _>ct, 01 +U enw Y CC c c al LU E 01 -, ,O A= �- 0) 01 '"r Q 0 N N r., to N r O O r f0 4., 4J 4-, N 01 E Z_ 4_, .0 m Z r - M M 0 0 - N - N C' +' E 01 F- 4 = N 2 f\ J LL 6 Y 2 2 W6 ii N 2 LL E rp a C ....... a < Q N J M N N M M N (e) Z 01 f9 U C CU a3 0 CA a 3 Q N a` a Q tat( /06-- PM 20 5-606 0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, May 9, 2017 3:21 PMfFet 6. 51511 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;Jensen, Marc D; Sullivan, Michael; Krysinski, Marina L; Targac, Gary; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1E-105 on 05/09/2017 Jim, ✓ The low pressure pilot (LPP) on well 1E-105 (PTD# 2050060, 2050070, 2050080)) was defeated today, 5/09/2017, after the well was put on water injection service following and extended shut-in period. The well is currently injecting at a wellhead injection pressure of-7 psi and rate of 410 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. Best Regards, Scott Stanley / Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SNE c.F• 3. 5 2.x)1- ' 1 110 1112-(-t (E-- /o5 2-050aco Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> q6(tSent: Wednesday,June 7, 2017 4:59 PM ?e 1 1 To: Regg,James B (DOA) C Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Sullivan, Michael; Krysinski, Marina L; Targac, Gary; Effiong, Michael; Stanley, Scott M Subject: LPP/SSV Returned to Service on CPAI well 1E-105 - 06/07/2017 Jim, The low pressure pilot(LPP) on well 1E-105 (PTD#205-006-0, 205-007-0, 205-008-0)was returned to service and removed from the safety defeat log on 06/07/2017, after the wellrwas shut-in. The LPP had originally been defeated on 05/09/2017. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 Email: n1638conocophillips.com SC.WED JUL17 201 STATE OF ALASKA ALA IL AND GAS CONSERVATION COMMISSION. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE GEL JOB 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory El 205-006 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-23243-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-105 ADL 25661,ADL 25660 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 13,539 feet Plugs measured 7578 feet true vertical 3,624 feet Junk measured None feet Effective Depth measured 8,209 feet Packer measured 7190, 7462, 7619 feet true vertical 3,6g9 feet true vertical 3512, 3572,3601 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 139 feet 20 " 170'MD 170 SURFACE 3,875 feet 13 3/8" 3,905'MD 2286 INTERMEDIATE 8,265 feet 9 5/8" 8,290'MD 3713 A-SAND LINER 5,900 feet 51/2" 13,519'MD 3624 RECEIVED MAY 1 9 2017 Perforation Depth Measured depth 8312-13455 feet ``'' True Vertical depth 3717-3625 feet , O Tubing(size,grade,measured and true vertical depth) 4.5" L-80 7,229'MD 3,521'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 7,190'MD 3,512'TVD PACKER=HRD ZXP Liner Top Packer 7,462'MD 3,572'TVD PACKER=HRD ZXP Liner Top Packer 7,619'MD 3,601'TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED JUN 1 3201y, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequent to operation: - - 447 - 3 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Servi4] Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR El WINJ 0 WAG ❑ GINJ 0 SUSP❑ SPLUGO 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: 317-078 Contact Name:John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@conocophillips.com Authorized Title: Sr.Wells Engineer �f f /IS ./ Contact Phone: (907)265-6471 Authorized Signature: w ..C. ' --- Date: j1 C7(17 Form 10-404 Revised 4/2017 4Zr G/�// RBDMS U,-41A1 9 2417 Submit Original Only • • • IE- 105 DTTMS.JOBTYP SUMMARYOPS 2/13/17 MECH ZONE RIH AND RETRIEVE TYPE-1 ISO-SLEEVE AT 7500' CTMD, RIH AND SET TYPE-1 DIVERTER IN B LEM AT 7520', RIH AND SET TYPE-2 ISO-SLEEVE ACROSS D LEM AT 7234'. ***JOB COMPLETE*** 4/24/17 NRWO PERFORM PASSING MIT-IA, RIH WITH 3.5" NOZZLE, TAG ISO SLEEVE AT 7234' CTMD, FLAG PIPE, JOB IN PROGRESS. 4/25/17 NRWO RIH WITH SLB 2.0" POWERFLOW PERF GUNS, 6 SPF, 60 DEG PHASE, CORRECT DEPTH AT FLAG, FIRE GUNS FROM TOP SHOT AT 9945' RKB TO BOTTOM SHOT AT 9950' RKB, PUMP 40 BBLS DIESEL F/P WHILE POOH, READY FOR OPS TO BOL AT 1000 BWPD, JOB IN PROGRESS. 5/1/17 NRWO RIH TO 8740' RKB, PUMP 4190 LBS OF REFORMED PARTICLE POLYMER GEL (RPPG) INTO THE B LATERAL MBE, AVERAGE CONCENTRATION OF .68 PPG, FOLLOW WITH 220 LBS OF MI POLYSWELL WITH AVERAGE CONCENTRATION OF .24 PPG, F/P TBG WHILE POOH, READY FOR FCO IN 48 HRS, JOB IN PROGRESS. 5/4/17 NRWO RIH WITH XRV, DJN. FLUFF-N-STUFFED DOWN TO LOCK UP AT 13224.6' CTMD, LRS a KUP 1E-105 'ConocoPhillips 4 Well Attribuiel Max Angle D TD Alaska.Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) COMCOPhl9ips 500292324300 WEST SAK INJ 96.20 8,942.81 13,539.0 ... Comment H2S(ppm) Date i Annotation End Dare K8-Grd(ft) Rig Release Date 1E-105 5/16/201710.21.14 AM SSSV:NIPPLE Last WO: 30.59 6/20/2005 Vertical achernalc(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. 13,018.0 6/21/2006 Rev Reason:PULL ISO-SLEEVE's,SET ISO- pproven 4/5/2017 HANGER,226 J SLEEVE,SET TYPE 1 DIVERTER f �,n Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;31.0-1700 CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K-55 WELDED NIPPLE;503.2 Casing Description OD(in) 113(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 13 3/8 12415 30.0 3,905.3 2,285.7 68.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND(... Wt/Len(I...Grade Top Thread I • `` INTERMEDIATE 95/8 8.835 25.1 8,290.0 3,713.1 40.00 L-80 BTCM SURFACE;30.03,905.3 H L Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread GAS LIFT;4,217.0 A-SAND LINER 5 1/2 4.950 7,619.1 13,519.0 3,624.1 15.50 L-80 BTCM GAS LIFT;6,712.9 Liner Details SLEEVE;7,163.9 r Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) t 7,619.1 3,601.2 79.40 PACKER HRD ZXP LINER TOP PACKER 4.970 LOCATOR;7,211.1 i. 7,637.6 3,604.6 79.61 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875 SEAL ASSY;7,211.6 1 7,640.4 3,605.1 79.64 HANGER FLEX-LOCK LINER HANGER 4.853 7,649.4 3,606.7 79.74 SBE CASING SEAL BORE EXTENSION 4.750 L t Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 51 1 D-SAND LINER LEM 4 1/2 3.958 7,190.5 7,492.5 3,577.2 12.60 L-80 IBTM ISO SLEEVE;7,258.0 '7 4 ) Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,190.5 3,511.7 76.12 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 7,213.4 3,5172 76.09 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 AMi,.,. 7,232.6 3,521.8 76.06 XO BUSHING CROSSOVER BUSHING 3.940 D-SAND LINER LEM;7,190.6- 7,4925 _ � 7,240.3 3,523.7 76.05 HANGER LEM ABOVE HOOK HANGER 3.980 7,254.4 3,527.1 76.03 HANGER LEM INSIDE HOOK HANGER 3.688 B-SAND LINER;7,523.0- 13,509.9 ,1, rr# 7,489.2 3,576.6 79.49 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 B-SAND LINER LEM;7,461.5- �.I L a 1; 7,661.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4 1/21 3.9581 22.61 7,229.21 3,521.0 12.601 L-80 I/BTM PLUG;7,578.0 Completion Details Nominal ID Mt ? Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) � 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 5032 502.8 4.42 NIPPLE CAMCO'DB-6'NIPPLE w/NO GO 3.875"PROFILE 3.875 I I 7,163.9 3,505.3 76.00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE 3.810 INTERMEDIATE,25.1-8,290.0 (CLOSED 6/27/05) 7,211.1 3,516.7 76.09 LOCATOR BAKER LOCATOR 3.880 • 7,211.8 3,516.8 76.09 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 SLOTS;8,312.0-8,774.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) - Top(TVD) Top Incl Top(ftKB) (ftKB( 0) Des Com Run Date ID(in) 7,578.0 3,593.5 78.94 PLUG A SAND DB PLUG W/PRONG 7/24/2015 0.000 • Perforations&Slots Shot Dens SLOTS;9,030.0-9,498.0-. - Top(ND) Btm(ND) (shots/ Top(ftKB) Btle(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,312.0 8,774.0 3,716.9 3,726.6 WS A2,1 E- 5/18/2005 0.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 9,030.0 9,498.0 3,702.2 3,694.9 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots SLOTS;9,710.010,473.0 2.5 x.125 holes,4 rows/ft 9,710.0 10,473.0 3,703.6 3,685.1 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 . rows/ft 10,731.0 11,114.0 3,669.7 3,658.2 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted SLOTS;10,731.011.114.0 liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 11,584.0 12,090.0 3,665.2 3,659.9 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/sloned liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft SLOTS;11,584.0-12,090.0-44 12,348.0 12,603.0 3,649.4 3,631.0 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted ` liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 12,902.0 13.455.0 3,624.7 3,624.7 WS A3,WS 5/18/2005 40.0 SLOTS Slotted Liner,alternating SLOTS;12,348.012,603.0 A2,1E-105 joints of blank/slotted liner for all A-Sand slots 2.5x.125 holes,4 rows/ft - Mandrel Inserts St ah SLOTS;12,902.013,455.0 i on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Motlel OD(in) Sew Type Type (in) (psi) Run Date Com 1 4,217.0 2,399.1 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 1R A-SAND LINER;7,619.1- 13,518.01 KUP 1E-105 •eConocoPhillips 3 Alaska,Inc. t• canocnMlaltps ••- 1E105,5/16/2017.10.21.16 AM... Vertoal iithetnbatiktoo) .... HANGER,22.6 I&'' ni • .„..• Mandrel Inserts at CONDUCTOR;31.0-1700 ti NIPPLE,503.2 _ N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 2 6,712.9 3,383.2 CAMCO KBBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 SURFACE;30.0-3,9115.3 Notes:General&Safety GAS LIFT;4,217.0 End Date Annotation GAS LIFT;6,712.9 - 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92”ID @ 7578' SLEEVE;7,163.9 � 6/18/2006 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;7,211.1 • _ f..• 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' SEAL ASSY;7,211.6 9/4/2011 NOTE PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 111 ISO SLEEVE;7,258.0 17 10- 11•111f 41{ D-BAND LINER LEM;7,180.8- 7,492.5 B-SAND LINER;7,523.0- 13,509.9 B-SAND LINER LEM;7,461.5- ' 3�; 7,661.8 PLUG;7,578.0 900 .6. INTERMEDIATE,25.15,290.0 SLOTS;8,312.08,774.0 SLOTS,9,030.0-9,498.0 SLOTS;9,710.0-10,473.0 SLOTS;10,731.0-11,114.0 SLOTS;11,584.0-12,090.0 SLOTS;12,348.0-12,803.0 SLOTS;12,902.0-13,455.0 A-SAND LINER;7,819.1-_ 13,519.0 - - l KUP 1E-105L1 e conocoPhillips 4 Well Attrib Max AngID TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status 'no!C) MD(ftKB) Act Btm(ftKB) Lorrom traps 500292324360 WEST SAK INJ 98.07 8,166,01 13,529.0 • .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-105L1,5/18/20178.50.21 AM SSSV:NIPPLE Last WO: 30.59 6/20/2005 Voted schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 13,018.0 6/21/2006 Rev Reason:PERFORATIONS hipshkf 8/20/2015 HANGER;22.6 iil nk Casing strings Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread �'IICaning � B-SAND LINER I 51/21 4.9501 7,523.01 13,509.91 3,479.41 15.50IL-80 I BTCM Liner Details CONDUCTOR 31.0170.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;503.2 ��,. - 7,523.0 3,582.9 79.07 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 3 7,550.3 3,587.5 81.44 XO BUSHING XO BUSHING 5.500 u( Casing Description IOD(in) (ID(in) ITop(ftKB) I Set Depth(ftKB) Set Depth(ND).,.IWt/Len(I.,,I Grade Top Thread B-SAND LINER LEM 41/2 3.958 7,461 5 7,661.8 3,598.5 12.60 L-80 IBTM Liner Details SURFACE;30.0-8,905.3 ! ` Nominal ID Top(ftKB) Top(TVD)(ftKB) Top toot CI Item Des Com (in) GAS LIFT;4,217.0 � 7,461.5 3,571.6 79.84 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 1.1 GAS LIFT;6,712.9 a; 7,480.2 3,574.9 79.60 XO CROSSOVER 4.950 liam 7,481.9 3,575.2 79.58 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 SLEEVE;7,163.9 -1 i11 7,501.3 3,578.8 79.34 XO BUSHING XO BUSHING 3.940 t.. r 7,502.7 3,579.0 79.32 SWIVEL CASING SWIVEL 3.960 Mt LOCATOR;7,211.1 r•• •r 7,509.1 3,580.2 79.24 HANGER LEM ABOVE HOOK HANGER 3.980 ,-.;`. I 7,523.3 3,582.9 79.07 HANGER LEM INSIDE HOOK HANGER 3.688 SEAL ASSY;7,211.8 :;__ 7,578.0 3,591.0 83.95 NIPPLE CAMCO'DB'NIPPLE w/3.563"PROFILE 3.958 INit 7,658.6 3,598.2 84.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Iij 11Top(ND) Top Incl lop(ftKB) (ftKB) (°) Das Com I Run Date ID(in) ISO SLEEVE,7,258.0 11 II, 7,541.0 3,586.0 80.60 DIVERTER TYPE 1-B-LAT DIVERTER 2/23/2017 0.000 11 it Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,622.0 7,750.1 3,594.9 3,606.3 WS B,1E- 5/29/2005 40.0 SLOTS Slotted Liner,alternating wnz, 105L1 joints of blank/slotted ',a• ' liner for all B-Sand slots Ell 2.5 x.125 holes,4 .q.IMP rows/ft D-SAND LINER LEM;7,1908- 8,140.0 1 1 3,597.3 3,566.4 WS B,1E- 5/29/2005 40.0 1SLOTS 7,492,5 1 - 1 9,029.0 11 •01 SLOTS 1 8,745.0 8,750.0 9/4/2011 •0 PERE 60 DEG PHASING w/ 1111 I'EE 0.43"HOLES INTERMEDIATE;25.1-0,290.0 i gf r: 8,750.0 8,755.0 3,555.4 3,5552 WS B,1E- 8/27/2006 6.0 RPERF 2.5"HSD Guns-.26"ENT DIVERTER;7,541.0 i-----) 105L1 hole,60 deg phase 1.1i1 ��II � 8,945.0 8,950.0 3,549.1 3,549.1 WS B,1E- 8/20/2015 6.0 APERF 2"Powerflow HSD guns 105L1 (2006 FP,6 SPF,60 1010 Deg,EDH 0.45",4.5" PEN 9,328.0 9,623.0 3,543.4 3,531,7 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 I 9,926.0 10,385.0 3,525.4 3,517.2 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 10,644.0 11,023.0 3,513.7 3,516.6 WS B,1E- 5/29/2005 40.0 SLOTS 0-SAND LINER LEM;7,481.5 105L1 7,661.8 1 11,669.0 11,881.0 3,529.9 3,510.5 WS B,1E- 5/29/2005 40.0 SLOTS SLOTS;7,822.07,750.750.1 105L1 12,269.0 12,437.0 3,502.6 3,502.4 WS B,1E- 5/29/2005 40.0 SLOTS SLOTS;8,140.0-8,472.0 105L1 12,738.0 13,249.0 3,491.4 3,477.5 WS B,1E- 5/29/2005 40.0 SLOTS 105L1 GEL SQZ,8,745.0 ftKB (PERF;8,745.0-8,750.01 v 1 Cement Squeezes RPERF;8,750.08,755.0 Top(ND) Btm(ND) SLOTS;8,733.05,029.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) DesStart Date Com APERF;8,995.08,950.0 -. 8,745.0 8,750.0 3,555.5 3,555.4 GEL SQZ 19/4/2011 Notes:General&Safety End Date Annotation 6/18/2005 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) SLOTS;9,328.0-9,623.0 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' 1/29/2009 NOTE:View Schematic w/Alaska Schematic9 0 SLOTS;9,926.0-10,385.0 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 SLOTS;10,644.0-11,0200 ' SLOTS;11,889.0-11,881.0 SLOTS;12,269.012,437.0 SLOTS;12,738.013,249.0 B-SAND LINER;7,523.0 13,509.9' • • • �o 7.44, 9 THE STATE Alaska Oil and Gas -s�i �, tgALA S KA Conservation Commission 333 West Seventh Avenue .11_1111-111111�'� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r, Main: 907.279.1433 up)", L Sgt Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce SCANNED M. r r` wJ" Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-105 Permit to Drill Number: 205-006 Sundry Number: 317-078 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, Daniel T. Seamount, Jr. Commissioner J DATED this?_3 day of February, 2017. RBDMS tit/FEB 2 7 2017 ECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 15 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A0000 1.Type of Request: Abandon fl Plug Perforations E Fracture Stimulate fl Repair Well Operations Shutdown E Suspend E Perforate E Other Stimulate rPull Tubing Change Approved Program Plug for Red rill 1 Perforate New Pool 1 Re-enter Susp Well 1' Alter Casing 1 Other: MBE GEL JOB F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development E 205-006 • 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service ]✓ 50-029-23243-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes n No r`! KRU 1E-105 '" 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 • Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,539'• 3,624', 8209 , 3699 • 1400 7578 NONE Casing Length Size MD TVD Burst Collapse Conductor 139' 20" 170' 170' Surface 3,875' 13 3/8 3,905' 2,286' Intermediate 8,265' 9 5/8 8,290' 3,713' Liner 5,900' 4 1/2 13,519' 3,624' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted Liner 8312-13455 3717-3625 4.500" L-80 7,229' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=PACKER ZXP LINER TOP PACKER MD=7815 ND=5822 PACKER=PACKER ZXP LINER TOP PACKER SSSV: NONE MD=8130 ND=6095 N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic ® Development E Service F • 14.Estimated Date for 3/14/2017 15.Well Status after proposed work: Commencing Operations: OIL E WINJ F• WDSPL E Suspended I- 16.Verbal Approval: Date: GAS E WAG E GSTOR E SPLUG r-- Commission Commission Representative: GINJ E Op Shutdown E Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Pierce @ 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr.Wells Engineer % ,ts 2/14/LI Signature one 265-6471 Date / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test D Location Clearance ❑ f 2-.11_31t-4 Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes ❑ No i/ Subsequent Form Required: !0. _ 0 4{' RBDMS L, L- FE3 2 7 2017 THERO '/,Z 2 7 1`- Approved by: COMMISSIONER THE COMMISSION ION Dates/ p 1 M^7 . / r Submit Form and ��12�IS'/p/��H� f ,,(� Rrce 4ItttA4Iid for 12 months from the date of approval. Attachments in Duplicate z1Ik KUP 1 E-105 Con©coPhil(ips Well Attribut Max Angle ID TD Alaskainc. Wellbore API/UWI Field Name Wellbore Status ncI(°) MD(ftKB) Act Btm(ftKB) C«7oci tettips 500292324300 WEST SAK INJ 96.20 8,942.81 13,539.0 �.. ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-105,2/1320178:51,58AM SSSV:NIPPLE I Last WO: 30.59 6/20/2005 - Veda sCilernaac(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .�,�` Last Tag: 13,018.0 6/21/2006 Rev Reason:PULL ISO-SLEEVE's,SET ISO- pproven 2/1/2017 HANGER,22.6 tae,n � - SLEEVE . •: All Casing Strings !VII_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len .Len(I Grade Top Thread CONDUCTOR;31.0-170.0 '-CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K-55 WELDED NIPPLE;503.2 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I_Grade Top Thread SURFACE 133/8 12.415 30.0 3,905.3 2,285.7 68.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 25.1 8,290.0 3,713.1 40.00 L-80 BTCM L SURFACE;30.03,905.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread GAS LIFT;4,217.0 A-SAND LINER 51/2 4.950 7,619.1 13,519.0 3,624.1 15.50 L-80 BTCM GAS UFT;6,712.9 Liner Details SLEEVE;7,183.9 i Nominal ID Mal Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com lin) a•• 7,619.1 3,601.2. 79.40 PACKER HRD ZXP LINER TOP PACKER 4.970 LOCATOR;7,211.1 Ic• 7,637.6 3,604.6 79.61 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875' SEAL ASSY;7,211.8 7,640.4 3,605.1 79.64 HANGER FLEX-LOCK LINER HANGER 4.853 7,649.4 3,606.7 79.74 SBE CASING SEAL BORE EXTENSION 4.750 Utt Casing Description OD(In) ID tint TopKe Set Depth ftKB Set Depth g (ft ) p ( ) p (TVD)...Wt/Len(L..Grade Top Thread �i D-SAND LINER LEM 41/2 3.958 7,190.5 7,492.5 3,577.2 12.60 L-80 BTM Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,190.5 3,511.7 76.12 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 7e 7,213.4 3,517.2 76.09 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 0-SAND LINER LEM;7,190.6- 7,492.5 AM 7,232.6 3,521.8 76.06 XO BUSHING CROSSOVER BUSHING 3.940 7,240.3 3,523.7 76.05 HANGER 'LEM ABOVE HOOK HANGER 3.980 B-SAND LINER;7,523.0- 13,509.9Y3 rr 7,254.4 3,527.1' 76.03 HANGER 'LEM INSIDE HOOK HANGER 3.688 e-SAND LINER LEM;7,481.5- ';t 51: 7,489.2 3,576.6 79.49 SEAL ASSY 'BAKER SEAL ASSEMBLY 3.880 7,861.8 ISO SLEEVE;7,541.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 22.6 7229.2 3,521.0 12.60 L-80 IBTM PLUG;7,578.0 ',zi Completion Details 1!_ -t, Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) `1�1" 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 503.2 502.8 4.42 NIPPLE CAMCO'DB-6'NIPPLE w/NO GO 3.875"PROFILE 3.875 I I 7,163.9 3,505.3 76.00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE 3.810 INTERMEDIATE;25.1-8,290.0 (CLOSED 6/27/05) 7,211.1 3,516.7 76.09 LOCATOR BAKER LOCATOR 3.880 7,211.8 3,516.8 76.09 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 SLOTS;8,312.0-8,774.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(MO) (ftKB) (°) Des Com Run Date ID(in) 7,541.0 3,586.3 78.85 ISO SLEEVE TYPE-1 B-LAT ISO SLEEVE(LATCHED) 1/30/2017 2.750 7,578.0 3,593.5. 78.94 PLUG A SAND DB PLUG W/PRONG 7/24/2015 0.000 Perforations&Slots SLOTS;9,030.0-9,496.0 -, Shot Den s Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com - - 8,312.0 8774.0 3,716.9 3,726.6 WS A2,1E- 5/18/2005 0.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots - 2.5x.125 holes,4 rows/ft J 9,030.0 9,498.0 3,702.2 3,694.9 WS A2,1E- 5/18/2005 40.0 SLOTS 'Slotted Liner,alternating SLOTS,9,710.0-10,473 0 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 9,710.0 10,473.0 3,703.6 3,685.1 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft SLOTS;10,731.0-11,114.0 10,731.0 11,114.0 3,669.7 3,658.2 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 - - rows/ft 11,584.0 12,090.0 3,665.2 3,659.9 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating - - 105 joints of blank/slotted liner for all A-Sand slots -e - 2.5 x.125 holes,4 SLOTS;11,584.0-12,090.0 rows/ft ,� 12,348.0 12,603.0 3,649.4 3,631.0 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted - liner for all A-Sand slots - - 2.5 x.125 holes,4 rows/ft SLOTS;12,348.0-12,603.0 12,902.0 13,455.0 3,624.7 3,624.7 WS A3,WS 5/18/2005 40.0 SLOTS Slotted Liner,alternating A2,1E-105 joints of blank/slotted -v - liner for all A-Sand slots 2.5 x.125 holes,4 -" - rows/ft Mandrel Inserts SLOTS;t2,002.0-13,455.0------.' - St MI J - N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 4,217.0 2,399.1 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 19 A-SAND LINER;7,13619.1- ,519.01 •Con©c°Phillips • � 1 E-105 Alaska.(no. CanucoPt fillips ••• 1E-105,2/13/20178:51:59 AM Verticil>solpmaSc.(actual) HANGER,226--4 . • ,,._. Mandrel Inserts IIIst CONDUCTOR;31.0-170.0 ati NIPPLE;503.2 N Top(TVD) Valve Latch Port Size TRO Run I Top(ftKB) (11KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 2 6,712.9 3,383.2 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 1R SURFACE;30.0-3,905.3 k I Notes:General&Safety GAS LIFT;4,217.0 iE' End Date Annotation Mil GAS LIFT;6,712.9 F ir 6/18/2006 NOTE.B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' aga SLEEVE;7,163.9 ` ' 6/18/2006 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) .• ^• 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;7,211.1 ,.• 9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' SEAL ASSY;7,211.8 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 VI lis! °rr J9 II CI M Y�F D-SAND LINER LEM;7,190.6- 7,492.5 ,190.&7,492.5 I. B-SAND LINER;7,523.0- 13,509.9 1a g B-SAND LINER LEM;7,461.5- k J 7. 7,661.8 ISO SLEEVE;7,541.03 r PLUG;7,578.0 1 W I I INTERMEDIATE,25 1-8,290.0 SLOTS;8,312.08,774.0 SLOTS;5,030.0-9,496.0 • SLOTS;9,710.0-10473.0 SLOTS;10,731.611,114.0 SLOTS;11,584.0-12,090.0 SLOTS;12,348.0-12,603.0 -, SLOTS;12,902.0-13,455,0 =I I- A-SAND LINER,7,619.1- I I 13,519.01 1 l e • Proposal for 1 E-105L1 to 1E-126L1 B Sand MBE Treatment with RPPG 1E-105 tri-lateral injector was drilled & completed in 2005 with laterals in West Sak A, B, & D sands. 1E-105L1 B lateral has 5.5", L-80 slotted liner. Three MBE's have occurred in 1E-105L1. The first happened 12/28/05 from 1E-105 to 1E-126 producer. A 6/20/06 IPROF found a B MBE in 105L1 at 8750' RKB taking all PWI. On 9/4/11, a Crystal Seal job in 105L1 sealed this MBE. The treatment lasted —2 years, then rising WC% at 1E-126 indicated another MBE from 1E-105. An (PROF 1/28/14 in 105L1 showed a new MBE at 8950 - 9150' RKB area. This MBE was sealed by another Crystal Seal job 9/23/15, and lasted —1 year, until WC% again spiked at 1E-126. A new IPROF ran 1/29/17, found a new MBE in 1E-105L1 at 9950' RKB, but saw no evidence that the two earlier MBE's treated were taking any fluid. On 1/30 & 1/31/17, the D Iso-Sly was pulled and the B Diverter was replaced with an Iso-Sly to isolate the B MBE and configure 1 E-105 for injection to D sand only until we are ready to seal the B MBE. The A lateral was isolated by a Plug set in the DB Nipple at 7578' RKB on 7/24/15, and this plug is still set. The following procedure is proposed to seal off the new B MBE at 9950' RKB with RPPG (aka: Reformed Polymer Particle Gel) to return 1E-105L1 to PWI service. RPPG is a newly developed synthetic dehydrated crystalline particle polymer gel product that hydrates and swells in water. RPPG is like Crystal Seal in appearance and swellability. However, unlike Crystal Seal, RPPG has a delayed crosslinking feature that tightly bonds individual swollen particle polymer grains together into an amalgamated mass of gel after placement to the MBE. This crosslinking feature should give RPPG MBE treatments much better resilience to disaggregation and breakdown vs. Crystal Seal when the treatment in the MBE is being subjected to drawdown pressure from flowing the producer. Unlike all previous Crystal Seal MBE treatments that we have performed to date in West Sak MBE's, we also propose that we inject the initial 37 to 50 bbls of gel slurry at maximum concentration from CT to the MBE while drawdown is being applied on the MBE by flowing the 1E-126 offset producer. Coil Tubing Procedure: 1) RIH to pull the Iso-Sly set across the B LEM at 7524' RKB. 2) RIH to set a Diverter in the B LEM at 7524' RKB. 3) RIH to set a Iso-Sly across the D LEM at 7258' RKB. RD CTU. 4) RIH to shoot 5' of 'big hole' perforations at 9945 - 9950' RKB across the new B MBE located at 9950' RKB, per 1/29/17 IPROF. 5) Put both 1E-126 producer and 1E-105 injector BOL 12 - 24 hrs before CTU RU on 1E-105. Have 1 E-126 flowing to 1 E test separator. This will reestablish flow through the B MBE between the wells. RU CTU with 2" CT on 1E-105. RIH with a down port nozzle on CT. Park nozzle at 9940' RKB just above the open MBE in 1E-105L1. Blend Seawater from transports with 1 - 4 mm mesh RPPG at 0.30 - 0.35 ppg slurry concentration `on-the-fly' in a mixing van and then pump it down CT at a steady established rate of 1.7 - 2.2 bpm while producing 1 E-126 and injecting 1000 BPD PWI down CT x Tbg to keep CT back side flushed of any RPPG slurry. Pump the first 37 to 50 bbls of slurry out of the nozzle parked at MBE at —9940. After —37 bbls of slurry exits the nozzle, shut-in 1E-126 (to avoid any significant placement of RPPG into the producer), while continuing slurry pumping to 1E-105L1 and starting POOH at 40 fpm. Continue pumping steady # S rate and slurry concentration until nozzle is POOH and parked at `safety' above all liner slots at 7620' RKB. POOH to safety mitigates development of very heavy PU weight that often develops while pumping heavy gel concentrations into slotted liners with crossflow. Continue pumping slurry at steady rate and 0.30 - 035 ppg concentration until WHIP reaches -800 psi, then SI all 1E-105 injection to CT x Tbg annulus, and swap from RPPG slurry to pumping to 10 bbls of Seawater spacer down CT, followed by -34 bbls Diesel FP followed by 1 CT volume of CT Diesel FP. When Diesel starts going down CT, start POOH from safety while maintaining steady rate down CT. RD CTU. Wait 2 days for RPPG particles fully crosslink in MBE before returning 1E-105L1 to PWI. If step 5 is executed as planned, 1E-126 producer will be allowed to flow back to the plant with low odds that it creates a plant upset due to gel production. 6) RIH with jet swirl nozzle and tag top of RPPG in well, then jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner. POOH w/CT. PU & RIH with 2.5" OD CT Tractor with nozzle to jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner at deeper depths to open more lateral to PWI. POOH w/CT Tractor. Place 1 E-105L1 on PWI to evaluate the results of the MBE treatment. 7) RIH with IPROF BHA. Memory log down & up passes to verify all the MBE's are sealed off. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1E-105L1 to PWI service. Leave 1E-105L1 on `B sand only' injection long enough to evaluate that the B MBE's remain sealed. When deemed appropriate, proceed to steps 8 -10 to normal up well. 8) RIH to pull the Iso-Sly across the D LEM at 7258' RKB to open the D lateral to injection. 9) RIH to pull the Diverter in the B LEM at 7524' RKB and leave B lateral open to injection. 10) RIH to pull the Plug from the DB Nipple at 7578' RKB to open the a lateral to injection. Return 1E-105 to PWI service to all 3 laterals. te,ga i a • tZ6S-1 ?Go Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �C,� 7 Sent: Wednesday, February 01, 2017 7:42 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt Subject: LPP/SSV Returned to Service on CPAI well 1E-105 - 02.01.2017 Jim, The low pressure pilot(LPP) on well E- 05 # 5-006- 205-007-0, 205-008-0)was returned to service and removed from the safety defeat log o 02/01/2017. The well is currently injecting at approx. 13130 BWPD at a wellhead injection pressure of 568 psi after completion of wellwork and troubleshooting operations. The LPP had originally been defeated on 01/28/2016. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 SCANNED 7 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497APR 0 66 20/ Email: n1638conocophillips.com 1 at 1E- 105 • • ftr 7?SUcx0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, January 28, 2017 9:39 AM �� 1� 17 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt Subject: Defeated LPP/SSV on CPAI well 1E-105 - 01.28.2017 Jim, The low pressure pilot(LPP) on well E-105 PTD#205-006-0 205-007-0, 205-008-0)was defeated today, 01/28/2017, when the well was brought online on water injection a er a long term shut-in period. The well is currently injecting at approx. 1500 BWPD at a wellhead injection pressure of 85 psi. Wellwork and troubleshooting operations are currently ongoing on the injector. 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/or 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. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 Email: n1638conocophillips.com • qtk It—i Z-i-;Co60 Regg, James B (DOA) From: Haakinson, David <David.Haakinson@conocophillips.com> Sent: Sunday, April 24, 2016 11:02 AM .le�t 4-(z Mike To: NSK West Sak Prod Engr; 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; Sullivan, Michael; Hall, Tyler A Subject: Return to service of LPP/SSV on well 1E-105 Jim, The low pressure pilot (LPP) on well 1 E-105 (PTD# 205-006-0, 205-007-0, 205-008-0)was returned to service today, 4/24/16, with a pilot setting of 100 psig . The well is currently stabilizing at a wellhead injection pressure of 210 psig and rate at 1100 BWPD. The well has been removed from the "Facility Defeated Safety Device Log." This notification is 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 6 2016 n1638@conocophillips.com 1 f( l t G- • • rT 7.05Oavo Regg, James B (DOA) From: Haakinson, David <David.Haakinson@conocophillips.com> 3 I , Sent: Monday, March 07, 2016 4:58 AM 1 e(i/ 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; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on well 1E-105 Jim, The low pressure pilot(LPP) on well 1E-105 (PTD# 205-006-0, 205-007-0, 205-008-0) was defeated today, 3/7/16, 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 470 psi and rate at 800 BWPD. The injection pressure 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 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 #497 SCANNED SEP 2 32016 n1638@conocophillips.com 1 STATE OF ALASKA ALISA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend Perforate r Other Stimulate p Alter Casing r Change Approved Program " Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE Treatment (y 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205-006 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-23243-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25660 KRU 1E-105 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 13539 feet Plugs(measured) none true vertical 3624 feet Junk(measured) none Effective Depth measured 8209 feet Packer(measured) 7191,7619 true vertical 3699 feet (true vertical) 3512,3601 Casing Length Size MD TVD Burst Collapse Conductor 77' 20" 108' 108' Surface 3875' 13.375" 3905' 2285 Intermediate 8265' 9.625" 8290' 3713 Liner 5900 5.5" 13510 3624' RECEIVED Perforation depth: Measured depth: slotted liner 8312-13455O0 2015 True Vertical Depth: 3717-3625DEL 1 3 LUI5 AOGCC Tubing(size,grade,MD,and ND) 4.5, L-80, 7229 MD,3521 TVD Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 7191 MD,3512 TVD PACKER-ZXP LINER TOP PACKER @ 7619 MD,3601 TVD NIPPLE-CAMCO'DB-6' NIPPLE @ 503 MD, 503 ND 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-BbI Gas-Mcf Water-BbI Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development r Service F Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WIND WAG r GINJ r SUSP r SPLUG 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: 315-361 Contact John Peirce a,265-6471 Email John.W.Peirceconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date r 1-0(1311S /414. VT L-- 10/14l115- AC Form 10-404 Revised 5/2015 i /C74 )---� )--- RBDMS Or,T 14s jiit Original Only 1 E-105 Crystal Seal Treatment • • DATE SUMMARY 5/24/2015 PULLED 5/16" CHOKE ON DB LOCK @ 503' RKB. BRUSHED AND FLUSHED TBG TO 7164' RKB. SET 1/4"CHOKE ON 3.81" DB LOCK @ 7164' RKB. COMPLETE. 7/13/2015 GAUGED TBG TO 3.86"TO 503' RKB; 3.79"TO CMU @ 7164' RKB. PULLED CHOKE @ 7164' RKB. READY FOR CTU. 7/14/2015 Pumped 25 bbls diesel down Tbg. Job complete. 7/21/2015 B&C CTU #1: RETREIVE TYPE 1 ISO-SLEEVE FROM B LEM AT 7524'WITH BAKER G- FORCE JARS. WHILE GOING TO WELL FOR SECOND RUN, UNABLE TO COME UP ON TROLLEY WINCH. MECHANIC CALLED OUT, WILL RESTART IN THE MORNING. 7/24/2015 B&C CTU#1: SET A SAND ISOLATION PLUG & PRONG IN DB NIPPLE AT 7578'WITH BAKER SI-DI HIPP TRIPPER, TWO RUNS. SET TYPE 1 DIVERTER IN B LEM AT 7524'. WILL RETURN IN THE MORNING TO SET A TYPE 2 ISO SLEEVE ACROSS D LEM. 7/25/2015 B&C CTU#1: SET A TYPE 2 ISO SLEEVE ACROSS D LEM AT 7258'WITH BAKER SI-DI HIPP TRIPPER. READY FOR ELINE TRACTOR PERF. 8/7/2015 UNABLE TO TRACTOR PAST 8225'. MADE MULTIPLE ATTEMPS AND TRIED TO USE A PUMP ASSIST BUT WERE UNABLE. DECISION MADE TO RDMO AND GO TO NEXT JOB 8/13/2015 B&C CTU#1: PERFORM DEPTH DETERMINATION LOG IN B LATERAL WITH PDS MEMORY UTILIZING A PUMP THROUGH TOOL CARRIER. DRY TAG AT 11226' CTMD (PERF DEPTH FROM 8945'-8950'). LOG PERF INTERVAL AND PAINT TIE IN FLAGS AT 8900'AND 9000' CTMD. WILL RETURN THE MORNING TO PERFORATE. 8/20/2015 B&C CTU #1: PERFORATE MBE INTERVAL IN B LATERAL FROM 8945'-8950' 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 6-MAR- 06. WELL LEFT FREEZE PROTECTED AND SHUT IN. READY FOR CRYSTAL SEAL. 9/22/2015 INJECTIVITY TEST. PUMPED 20BBLS DIESEL @ 1BPM DOWN THE TUBING @ 200PSI. JOB COMPLETE. 9/23/2015 Perform MBE treatment with 2,805 lbs (51 sacks) of 4 millimeter CrystalSeal per design. Well freeze protected and to be left shut- in. ***Job in Progress with more steps in Procedure to follow.*** 9/27/2015 Injectivity test,pump 20 bbls dsl down tbg at 1 bbl/min @ 625 psi,job complete F KUP INJ 0 1E-105 .- • Conocoryhillips gl 4 Well Attributes Max Angle&MD TD Alaska.Inc. WellboreAPIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cyhithp, 500292324300 WEST SAK INJ 96.20 8,942.81 13,539.0 °.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-105,825/20157:53:58 AM SSSV:NIPPLE Last WO: 30.59 6/20/2005 Vertical schematic(actual) ..... .. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,22.6 I Last Tag: 13,018.0 6/212006 Rev Reason:PERFORATIONS hipshkf 8/20/2015 " Casing Strings ,�-ti7. 1. PI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR;31.0-170.0 CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K-55 WELDED NIPPLE;503.2 = Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...'Grade Top Thread SURFACE 133/8 12.415 30.0 3,905.3 2,285.7 68.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(L..Grade Top Thread SURFACE;30.03,905.3 INTERMEDIATE 9 5/8 8.835 25.1 8,290.0 3,713.1 40.00 L-80 BTCM GAS LIFT;4,217.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread GAS LIFT;6,712.9 ' I A-SAND LINER 512 4.950 7,619.1 13,519.0 3,624.1 15.50 L-80 BTCM SLEEVE;7,163.9 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) LOCATOR;7,211.1 7,619.1 3,601.2 79.40 PACKER HRD ZXP LINER TOP PACKER 4.970 SEAL ASSY;7,211.8 t � 7,637.6 3,604.6 79.61 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875 7,640.4 3,605.1 79.64 HANGER FLEX-LOCK LINER HANGER 4.853 Ill 7,649.4 3,606.7 79.74 SBE CASING SEAL BORE EXTENSION 4.750 ISO SLEEVE;7258.0 I E Cri Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread D-SAND LINER LEM 41/2 3.958 7,190.5 7,492.5 3,577.2 12.60 L-80 IBTM Liner Details p-i. Nominal ID Ind(° Top(ftKB) Top(ND)(ftKB) Top In ) Item Des Com (in) 7,190.5 3,511.7 76.12 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 7,213.4 3,517.2 76.09 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 D-SAND LINER LEM;7.190.6- -....- 7.492.5 ITO 7,232.6 3,521.8 76.06 XO BUSHING CROSSOVER BUSHING 3.940 B-SAND LINER;7,523.0. 7,240.3 3,523.7 76.051 HANGER LEM ABOVE HOOK HANGER 3.980 13,509.8 7,254.4 3,527.1 76.03 HANGER LEM INSIDE HOOK HANGER 3.688 B-SAND LINER LEM;7,461.5- 7,661.8 7,489.2 3,576.6 79.49 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 DIVERTER;7.524.0 " Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 22.6 7,229.2 3,521.0 12.60 L-80 IBTM PLUG;7,578.0 1 Completion Details 1!4µ7r �•.. Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 503.2 502.8 4.42 NIPPLE CAMCO'DB-6'NIPPLE w/NO GO 3.875"PROFILE 3.875 I 7,163.9 3,505.3 76.00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE 3.810 INTERMEDIATE;25.1-8.290.0 (CLOSED 6/27/05) 7,211.1 3,516.7 76.09 LOCATOR BAKER LOCATOR 3.880 7,211.8 3,516.8 76.09 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 SLOTS;8,312.0.8,774.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 7,258.0 3,528.0 76.03 ISO SLEEVE D-LAT ISO SLEEVE 7/25/2015 2.750 7,524.0 3,583.0 79.06 DIVERTER B-LAT DIVERTER 7/24/2015 0.000 7,578.0 3,593.5 78.94 PLUG A SAND DB PLUG W/PRONG 7/24/2015 0.000 SLOTS;9,030.0-9.498.0 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shotstt Top(ftKB) Blot(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,312.0 8,774.0 3,716.9 3,726.6 WS A2,1E- 5/18/2005 0.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft SLOTS;9,710.0-10,473.0 9,030.0 9,498.0 3,702.2 3,694.9 WS A2,1E- 5/182005 ' 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5x.125 holes,4 rows/ft 9,710.0 10,473.0 3,703.6 3,685.1 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 SLOTS;10731.0.11,114.0 rows/ft 10,731.0 11,114.0 3,669.7 3,658.2 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 11,584.0 12,090.0 3,665.2 3,659.9 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted SLOTS;11,584.0-12090.0 liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 12,348.0 12,603.0 3,649.4 3,631.0 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted liner for all A-Sand slots SLOTS;12,348.0.12,603.0 2.5 x.125 holes,4 rows/ft 12,902.0 13,455.0 3,624.7 3,624.7 WS A3,WS 5/182005 40.0 SLOTS Slotted Liner,alternating A2,1E-105 joints of blank/slotted liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft SLOTS;12902.0-13.455g - A-SAND LINER;7,619.1- 13,519.0 f KUP INJ11. 1E-105 ConocoPhillips 2 Alaska,Inc. C anco lotk9$ --• 1E-105.8/25/20157:54:00 AM Vertical schematic(actual) HANGER;22.6 i-"„"�_ r� M^ • Mandrel Inserts CONDUCTOR;31.0-170.0 ati NIPPLE;503.2on Top(TVD) Valve Latch Port Size TRO Run = I N Top(ftKB) (ttKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 4,217.0 2,399.1 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 SURFACE;30.0-3,905.3 1R GAS LIFT;4,217.0 2 6,712.9 3,383.2 CAMCO KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 GAS LIFT;6,712.9 1R SLEEVE;7,163.9 Notes:General&Safety End Date Annotation LOCATOR;7.211.1 _• ,. 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'DB'NIPPLE w/3.92"ID @ 7578' � 6/18/2006 NOTE:TRI LATERAL WELL:A-SAND(1E-105),B-SAND(1E-105L1),D-SAND(1E-105L2) SEAL ASSY;7,211.8 y 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 111 nwitiw9/11/2010 NOTE:MBE repair w/9 bbls of 1G1-2289E,105 degree meltpoint wax @ 8750' 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 ISO SLEEVE;7,258.0 I 4 D-SAND LINER LEM;7.190.6- 7,492.5 B-SAND LINER;7,523.0- 13,509.9i p'C B-SAND LINER LEM;7,461.5461.5- 7,661.8 DIVERTER;7.524.0 PLUG;7,578.0 .1),11 rare 1 I INTERMEDIATE;25.1-8,290.0 SLOTS;8,312.0.8,774.0 SLOTS;9,030.09.498.0 SLOTS;9,710.0-10,473.0 SLOTS;10,731.0-11.114.0 SLOTS;11,584.0-12,090.0 SLOTS;12,348.0-12,603.0 SLOTS;12,902.0.13,455.0 A-SAND LINER;7,619,1- 13,519.0 O � ��F 7 THE STATE Alaska Oil and Gas • ., Co T ' Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALASFax• 907.276.7542 1`I www.aogcc.alaska.gov S`ANaE© JUL 0 72 �J John Peirce Sr. Wells Engineer a05-00 -4, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-105 Sundry Number: 315-361 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, Daniel T. Seamount, Jr. / Commissioner DATED this/(/day of June, 2015 Encl. RECEIVED STATE OF ALASKA • AL. ..,KA OIL AND GAS CONSERVATION COM_ BION JUN 12 2015 lA0 APPLICATION FOR SUNDRY APPROVALS AAC 20 AOGCC 1.Type of Request: Abandon r Rug 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 Rug for Redrill r Perforate New Pool r Repair Well Re-enter Sus Well GE r p r Other:Crystal Sea#Stment[7. 2.Operator Name: 4 Current Well Class. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory r Development r 205-006 ' 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23243-00• 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 r J KRU 1E-105 • 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL 25651,25660 • 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): 13539 . 3624 . 8209' - 3699' - none none Casing Length Size MD TVD Burst Collapse Conductor 77' 20" 108' 108' Surface 3875' 13 375" 3905' 2285' Intermediate 8265' 9.625" 8290' 3713' Liner 5900' 5.5" 13519' 3624' Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade. Tubing MD(ft). slotted liner 8312-13455 • 3717-3625 4.5 L-80 7229 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=7191 TVD=3512 • PACKER-HRD ZXP LINER TOP PACKER MD=7619 TVD=3601 NIPPLE-CAMCO'DB-6'NIPPLE MD=503 TVD=503 • 12.Attachments: Description Surrrnary of Proposal ry 13 Well Class after proposed work. Detailed Operations Program r BOP Sketch r" Exploratory r Stratigraphic r Development r Service P• 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work. 7/8/2015 OIL r WINJ r- WDSPL r Suspended F- 16.Verbal Approval: Date. GAS r WAG r GSTOR r SPLUG [— Commission 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.Peirce(c�conocophillips corn Printed Name John Peirce Title. Sr. Wells Engineer Signature •• Phone:265-6471 Date 6/f 1 ii S Commission Use Only Sundry Number. Conditions of approval. Notify Commission so that a representative may witness 31S—3le Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [I Subsequent Form Required: Al 4 c 4- / APPROVED BY //C Approved by: y COMMISSIONER THE COMMISSION Date: //‘` [/.7.7., (o/1,57/S Ar roved ap Ilcatlon l valid for 12 months from the date of approval. Submit Form and Form 10-403 Revised 5/2015 R I I N ► L CIIli,),s Attachments in Duplicate le27%� RBDMS��t JUN 2 5 2015 , ) KUP INJ 1E-105 ConocoPhillips 8 Well Attributes Max Angle&MD TD - Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl C) MD(11:1(B) Act Btm(MB) ypy 500292324300 WEST SAK INJ 9620 8,942.81 13,539.0 --- Comment H2S(ppm) Date Annotation End Date KBGrd(ft) Rig Release Date 1E-105.309/201425133 PM SSSV:NIPPLE Last WO: 30.59 6/20/2005 Vertical achemabc(actual) Annotation Depth(568) End Date Annotation Last Mod By End Date HANGER;22.6- •- Last Tag. 13,018.0 6/21/2006 Rev Reason:SET CHOKE lehallf 3/4/2014 " """"roR;31.a C Casing De Strings �� A� Casing Description OD(In) ID(in) Top(RKB) Set Depth(TIKES) get Depth(ND)...Wt/Len(I...Grade Top Thread CONDUC O w wt7w0 r'CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K-55 WELDED CHOKE;5030 Casing Description OD(in) ID(In) Top(5613) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread NIPPLE:5022 - SURFACE 133/8 12.415 30.0 3.905.3 2.285.7 68.00 L-90 BTC I I Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TA))...WULen(1...Grade Top Thread SURFACE;30.03.905.3 INTERMEDIATE 95/8 8.835 25.1 8.290.0 3.713.1 40.00 L-80 BTCM GAS LIFT;4,217.0 Casing Description0D(in) ID On) Top(RKB) Set Depth(RKB) Set Depth END)...Wt/Len 0...Grade Top Thread A-SAND LINER 5 1/2 4.950 7,619.1 13.519.0 3,624.1 15.50 L-80 BTCM GAS LIFT;6,712.9 Liner Details SLEEVE;7,1639 Nominal ID Top(RKB) Top(TVD)(RKB) Top Incl C) Item Des Com (In) LOCATOR;72/1.7 ,u.�a. 7,619.1 3.6012 79.40 PACKER HRD ZXP LINER TOP PACKER 4.970 % 7.637.6 3,604.6' 79.61 NIPPLE RS'PACKOFF SEAL NIPPLE 4.875 SEAL ASSY;7211.8 7,640.4 3,605.1 79,64 HANGER FLEX-LOCK LINER HANGER 4,853 7.649.4 3.606.7 79.74 SBE CASING SEAL BORE EXTENSION 4.750 1 Casing Description 00(in) ID(In) 1Top(RKB) Set Depth(RKB) Set Depth(NO)...WVLen(I...Grade Top Thread D-SAND LINER LEM 4 1/2 3.958 7,190.5 7.492.5 3,577.2 12.60 L-80 IBTM Liner Details Nominal ID Top(MB) Top(TVD)(R)(B) Top Incl CI Item Des Com (in) ,1- 7.190.5 3,511.7 76.12 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 •1t 7.213.4' 3.517.2 76.09 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 DSAND LINER LEM;7.190.6- 7,492_5 .190.7.4925 IMF 7,232.6 3,521.8 76.06 XO BUSHING CROSSOVER BUSHING 3.940 eswD LINER;7.523.3 7.240.3 3,523.7 76.05 HANGER LEM ABOVE HOOK HANGER 3.980 13.5099 7,254.4 3,527.1 76.03 HANGER LEM INSIDE HOOK HANGER 3.688 BSAND LINER LEM;7,461.5 7,661.8 7,489.2- 3,576.6 79.49 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 SLEEVE-C;7.5240 qR tWY Tubing Strings 7Tubing Description String Ma...ID(In) Top(RKB) Set Depth(R..Set Depth(ND)I...Wt(Ib/R) Grade Top Connection TUBING 41/2 3.958 22.6 7,229.2 3.521.0 12.60 L-80 IBTM Completion Details Nominal ID Top(RKB) Top(ND)(RKB) Top Incl C) Item Des Corn (In) 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 5032 502.8 4.42 NIPPLE CAMCO'DB-6'NIPPLE w/NO GO 3.875"PROFILE 3.875 INTERMEDIATE;25.1$290.0 7,163.9 3,505.3 76,00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE 3.810 (CLOSED 6/27/05) i_ 72111 3,516.7 76.09 LOCATOR BAKER LOCATOR 3.880 SLOTS;8.31208.774.0 e"- 7,211.8 3.516.8 76.09 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl - Top(RKB) (RKB) C) Des Corn Run Date ID(in) -f 503.0 502.7 4.42 CHOKE "5/16"CHOKE ON 3.875 DB LOCK 2/25/2014 7,524.0 3.583.0 79.06 SLEEVE-C SET E-LEM ISO SLEEVE(19'OAL) 2/1/2014 r SLOTS;9030.0-9.498.0 _ Perforations&Slots ` Shot Den Top(IVO) Btm(ND) (shots/1 Top IRK131 Bun(MOB) (RKB) (568) Zone Date t) Type Com 8.312.0 8,174.0 3.716.9 3.726.6 WS A2,1E- 5/18/2005 0.0 SLOTS Slotted Liner,alternating "J 105 joints of blank/slotted 1 Hoer for all A-Sand slots • 2.5 x.125 holes,4 rows/ft 9.030.0 9.498.0 3,702.2 3,694.9 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating SLOTS;9210.310,4730 105 joints of blank/slotted J _ liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft r 9,710.0 10473.0 3,703.6 3,685.1 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating ` 105 joints of blank/slotted C liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft SLOTS;10,731.611.114.0 _ 11,114.0 3.669.7 3,658.2 WS A2,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted 0.- liner for all A-Sand slots 2.5 x.125 holes,4 rows/ft 11.581.0 12.090.0 3,665.2 3.659.9 WS A3,1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted - ` liner for all A-Sand slots SLOTS,11554.0-12,090.0 2.5 x.125 holes,4 ` rows/ft - - a_ 12.348.0 12,603.0 3,649.4 3.631.0 WS A3.1E- 5/18/2005 40.0 SLOTS Slotted Liner,alternating 105 joints of blank/slotted -. _ liner for all A-Sand slots 2.5 x.125 holes,4 SLOTS;12,348.0-12.603.0 i rows/ft 12.902.0 13,455.0 3,624.7 3,624.7 WS A3.WS 5/18/2005 40.0 SLOTS Slotted Liner,alternating A2.1E-105 joints of blank/slotted .- liner for all A-Sand slots -, r- 2.5 x.125 holes,4 - a_ rows/ft Mandrel Inserts SLOTS;12.902313.455.0 Sr ah on Top(ND) Valve Latch Port Size TRO Run N Top(6613) (PILED Make Model 013(in) Sere Type Type (in) (psi) Run Date Corn '.• 1 4.217 0 2.399.1 CAMCO KBG-2- 1 GAS LIFT DMV BK 0.000 0.0 8/8/2010 -+ � 18 A-SAND LINER;7,6191- 13,519.01 KUP INJ 1E-105 ConocoPhillips l4 • Alaska. Loroctirhotups ••• 1E-105,3!4!2014251:34 PM VerOcal schematc(actual) HANGER;22.6... �•�` �1 Aid St ad nserts els^CONDUCTOR;31 0-1700 ati CHOKE;503.0 on Top(TVD) Valve Latch Port Size TRO Run NIPPLE.503.2 "' N Top(MOB) (SKS) Make Model OD(In) Sery Type Type (In) (pal) Run Date Com I I I 2 6,712.9 3,383.2 CAMCO KBG-2- 1 GAS LIFT DMY 'BK 0.000 0.0 8/8/2010 118 SURFACE;30.03,905.3 GAs LIFT;4,2,20 �; Notes:General&Safety GAS LIFT,6.7129 End Date Annota0 on 6/18/2006 NOTE:B-SAND LEM CONTAINS CAMCO'D8'NIPPLE w/3.92"ID @ 7578' SLEEVE;7,1639r 6/18/2006 NOTE:TRI LATERAL WELL:A-SAND(1E-105).B-SAND(1E-105L1),D-SAND(1E-105L2) LOCATOR;7211.1 r, 1/29/2009 NOTE:View Schematic w/Alaska Schematic9.0 IA!1111 9/11/2010 'NOTE:MBE repair w/9 Obis of 1G1-2289E,105 degree meltpoint wax @ 8750' SEAL ASSY;7,211.8 9/4/2011 NOTE:PROFILE MODIFICATION-PUMPED 2310 LBS(4MM)CRYSTAL SEAL IN B LATERAL MBE@8750 I I I M_ 1�6 DSAND LINER LEM;7,190.6- .55 9i B-SAND LINER,7,523.0- 13,509.9 EI-SAND UNER LEM;7,461.5.1 I I 7,661.8 SLEEVE-C;7,524.0 �— INTERMEDIATE,25.1-8.290.0 I I SLOTS,e.312o-en4o r SLOTS;9,030.0-94980 SLOTS;9,710.0.10,473.0 SLOTS;10,731.0.11,114,0 SLOTS;11,584.0.12.090.0 SLOTS;12.348.0-12,603.0 • SLOTS;12,9020.13,455.0 A-SAND LINER;7,619.1- 13,519,01 Treatment Proposal for 1E-105L1 to 1E-126L1 B Sand MBE's 1E-105 tri-lateral injector was drilled & completed in 2005 with laterals in West Sak A, B, & D sands. 1E-105L1 B Sand lateral has 5.5", L-80 slotted liner. Two MBE's occurred in 1E-105L1. The first occurred 12/28/05 from 1E-105 to 1E-126 producer. A 6/20/06 (PROF found a B MBE in 105L1 at 8750' RKB taking all PWI at 2711 BWPD. On 9/4/11, a Crystal Seal job pumped in 105L1 to seal this MBE. The treatment lasted -2 years before rising WC% at 1E-126 indicated another MBE occurred from 1E-105. An IPROF 1/28/14 in 1E-105L1 shows the B MBE at 8750' RKB again taking some PWI, plus a new MBE now at 8950 - 9150' RKB area. 1E-105 lost PWI May 2014 due to 1E PWI line SI for repairs, then PWI resumed April 2015 to 1E-105L2 only (105L1 is Iso-Slv'd off due to B MBE's). A job procedure is now proposed to seal off the B MBE's to return 1E-105L1 lateral to PWI service: Slickline: 1) A 0.25" choke was set on 5/24/15 on a 3.81" DB Lock at 7164' RKB in a Camco Sliding Sleeve. RIH & pull this choke to enable CT access to 1 E-105L1 B Sand lateral. RD SL. Coil Tubing: 2) RIH to pull the Iso-Sly set across the B LEM at 7524' RKB. 3) RIH to set a Diverter in the B LEM at 7524' RKB. 4) RIH to set a Iso-Sly across the D LEM at 7258' RKB. RD CTU. E-line: 5) RIH with 5' pert gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 8945 - 8950' RKB. This perfs 5.5" slotted liner at the lower new MBE at -8950' to allow CrystalSeal entry through slotted liner to the MBE. Fire gun. POOH. RD. Perfs were shot in 2011 at the upper MBE at-8750'RKB. Coil Tubing: 6) RIH with a large down port nozzle on CT. Park nozzle at 8700' RKB above both MBE's, and then pump a Step Rate Injection Test (SRIT) followed by a Crystal Seal treatment as follows: a) Pump SRIT with Seawater down CT to MBE's. Select a steady treatment rate (likely to be in the 1.5 - 2 bpm range) to be held constant during the treatment (steps b through e) to Flush (step f) to monitor MBE response to treatment and to watch Crystal Seal screenout develop during the slurry pumping. Use 2% KCL for making Crystal Seal slurry (or Seawater of adequate salinity), then pump: b) 2% KCL Water with 0.05 ppg Crystal Seal (using 4 mm mesh all stages b through e) down CT. Each stage volume TBD during pumping based on treating pressure seen during stage. Then pump, c) 2% KCL Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if screen out develops. d) 2% KCL Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCL Water w/0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. • Once Crystal Seal concentrations > 0.10 ppg starts exiting the nozzle, begin POOH with nozzle continuously at 5 - 10 fpm while pumping away all the remaining slurry to be pumped until the nozzle reaches a safe parking point just above the B LEM (7524' RKB). This practice is used now to help mitigate development of very sudden heavy PU weights that have been experienced during previous Crystal Seal treatments where the nozzle stayed parked at the MBE while pumping away all the Crystal Seal stages with only periodic weight checks. Continuously POOH allows for continuous monitoring of PU weight development to provide early warning re: rising PU weight issues. Once the nozzle reaches final parking location at the B LEM, Crystal Seal stacking behind CT cannot occur, since only CT x Tbg dead leg exists above the B LEM and pumping of at least 0.3 bpm will be kept down the CT backside. f) If screen out occurs, pump 1 CT volume Seawater Flush to displace Crystal Seal from CT to well while POOH and pumping 0.5 bpm 2% KCL down CT backside to mitigate Crystal Seal stacking behind CT (that can lead to excessive PU weight). Even if screen out is not seen prior to Flush, keep a minimum of 0.3 bpm of 2% KCL down the CT backside at all times to help keep Crystal Seal flushed away from CT backside to mitigate elevated PU weights. Pump 1 full CT volume of 2% KCL to displace remaining Crystal Seal Slurry from CT to liner while POOH, then swap to Diesel FP down CT, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let the Crystal Seal particles fully hydrate and swell in the MBE's before returning 1E-105L1 to PWI. 7) RIH with jet swirl nozzle and tag top of Crystal Seal in well, then jet down through Crystal Seal to as deep as possible to shear & mechanically break all Crystal Seal remaining in the liner. POOH w/CT. Place 1E-105L1 on PWI to evaluate the results of the MBE treatment. 8) RIH with (PROF BHA. Memory log down & up passes to verify if the MBE's are sealed off or still taking PWI. Wait 2 hours, then log a cool back pass. POOH with CT. RD CTU. Return 1E-105L1 to PWI service. Leave 1E-105L1 on PWI to 'B sand only' for a few months to ensure that the B MBE's continue to appear to be sealed off. Depending on surveillance, evaluate retreatment options for the MBE's, if needed. If several months have passed without obvious indications of treatment failure, proceed to normal up the well to resume unobstructed PWI to the A sand and D sand laterals as follows: Coil Tubing: 9) RIH to pull the Iso-Sly across the D LEM at 7258' RKB. 10) RIH to pull the Diverter in the B LEM at 7524' RKB. Return 1 E-105 to PWI service to all 3 laterals. · . 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 bescanned during a special rescan activity or are viewable by direct inspection of the file. fÁQ5. - Q Q &2 Well History File Identifier Organizing (done) 0wo-sided 1111111111I11111111 o Rescan Needed 111111111111111I11I R~CAN \Jlf Color Items: o Greyscale Items: D~ITAL DATA .~ Diskettes, No. fc, o Other, NofType: 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: Date 7/30/07 o Other:: BY: ~ 151 mf 11111111111111 "III VVî~ Project Proofing BY: ~ Date 1/3D/D7 :5 x 30 = /50 Date 7 /3D / CJ 7 151 Scanning Preparation BY: ~adU + J 7 = TOTAL PAGES 110 7 (Count does not include cover sheet;" Ail 151 T Vir Production Scanning Stage 1 Page Count from Scanned File: I b ~ (Count does include cover sheet) Page Count Matches Number in sca;ï.ing Preparation: VYES BY G;> Date7/3D!D7 Stage 1 If NO in stage 1, page(s) discrepancies were found: 11111111111111 "III NO 151 W1 P YES NO BY: Maria Date: 151 11111111111I11 "III Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "III BY: Maria Date: 151 Comments about this file: Quality Checked III 11111I11I111111I 10/6/2005 Well History File Cover Page.doc • • t &- 1oS 06-6060 Regg, James B (DOA) From: NSK West Sak Prod Engr[n1638 @conocophillips.com] Sent: Sunday, October 13, 2013 5:36 PM 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 P D#204-231 204-232 1 -105 ' ' ' -I I s -007 205-008 1J-105 (PTD#207-027, 207-028 and 207-029) This note is in reference to"Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Amanda Patterson/Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. (907) 659-7234 Pager 497 SCANNED Oil( 2 3 2 Cx ,y • I - 0; Regg, James B (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] ���r Sent: Friday, August 03, 2012 10:38 AM �813/12. To: Regg, James B (DOA) Cc: NSK West Sak Prod Engr; Patterson, Amanda; CPF1 Prod Engr; CPF1 Ops Supv; CPF1 DS Lead Techs; CPF1 &2 Ops Supt; NSK Prod Engr & Optimization Supv; NSK Problem Well Supv; NSK Prod Engr Specialist; Seitz, Brian Subject: LPP /SSV returned to service on 1E-105, 6/19/12 Jim, The low pressure pilot (LPP) on tri- lateral injector E -105 (205 -006, ' 05 -007 L1, and 205 -008 L2) was returned to service on 06/19/12 after the wel was s I -. _ • ing well work to choke the injector downhoTe. The well work was completed on 07/21/12 and the well was put on injection 08/01/12 with the LPP /SSV in service. The current injection pressure is 925 psi and the injection rate is 1800 bwpd. This pilot was defeated on 06/18/12 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. thanks, Dana Glessner /David Lagerlef ConocoPhillips Alaska, Inc WAY Kuparuk CPF1 Production Engineer SCANNE office (907) 659 -7493 Dana .GlessnerCaconocophillips.com 'rod Engr , June 18, 2012 7:49 PM 3mes B' Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; Gauer, Jenn L; Jensen, Marc D; Hutcherson, Mark R PP /SSV defeated on 1E -105 : June 18, 2012 Jim, The low pressure pilot (LPP) on tri- lateral injector 1E -105 (205 -006, 205 -007 L1, and 205 -008 L2) was defeated on 06/18/12. Current wellhead pressure is 400 psi at an injection rate of 1100 bwpd. Troubleshooting is underway to determine why the injection pressure dropped today. 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 4068.001." Please let me know if you have any questions. David Lagerlef CPF1 Production Engineer n1269(cilconocophillips.com 659 -7493 pager 659 -7000 765 1 Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638 @conocophillips.com] Sent: Wednesday, December 14, 2011 8:28 AM To: Hutcherson, Mark R; CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA); Jensen, Marc D Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt Subject: LPP /SSV Returned to service on 1E-105 : Dec 12, 2011 Tom and Jim, • The low pressure pilot (LPP) on the well listed below was returned 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 10/18/2011 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-105 (205 -006, 205 -007, 205 -008) 648 1987 Please let me know if you have any questions. Thank you. /iii !- 1i7nCY ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.659.3901 Mobile - 303.248.6641 '"t.�l_ ; • From: Hutcherson, Mark R Sent: Tuesday, October 18, 2011 3:12 PM To: Gauer, Jenn L; CPF1 Prod Engr; "Maunder, Thomas E; "Regg, James B' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt Subject: RE: LPP /SSV defeated on 1E -105: Sept 23, 2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1E -105 (205 -006, 205 -007 L1, and 205 -008 L2) was defeated on 10/18/11. This occurred due to an SSV shut -in just after the LPP had been enabled earlier in the day. Current wellhead pressure (as of 15:20 hrs 10/18/11) is 499 psi at an injection rate of 1495 bwpd. It is anticipated the pressure will continue to build above 500 psi in the near future. 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. qatelsowea Senior Drillsite Petroleum Engineer NSOD KRU West Sak Field ConocoPhillips Alaska, Inc. Office: 907- 265 -1034 Cell: 832 - 794 -3862 12/14/2011 Page 1 of 1 • • •• • Maunder, Thomas E (DOA) , . From: Hutcherson, Mark R [Mark.R .Hutcherson @conocophillips.com] Sent: Tuesday, October 18, 2011 12:27 PM To: Gauer, Jenn L; CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt Subject: LPP /SSV Returned to Service on 1E-105 : Oct 18, 2011 Tom and Jim, The low pressure pilot (LPP) on the well listed below was returned to service on 10/18/2011 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 9/23/2011 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) 1 E -105 (205 -006, 205 -007, 205 -008) 538 1478 Please let me know if you have any questions. Thank you. ;/gtaferesa Senior Drillsite Petroleum Engineer NSOD KRU West Sak Field ConocoPhillips Alaska, Inc. h l, h I Office: 907-265-1034 ? 6 t- � Cell: 832 - 794 -3862 From: Gauer, Jenn L Sent: Friday, September 23, 2011 2:10 PM To: Gauer, Jenn L; CPF1 Prod Engr; "Maunder, Thomas E'; "Regg, James B' 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 Subject: LPP /SSV defeated on 1E -105 : Sept 23, 2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1E -105 (205 -006, 205 -007 L1, and 205 -008 L2) was defeated on 9/23/2011when the well was returned to injection service after being shut since 9/4/2011. Current wellhead pressure (as of 1410 09/23/11) is 188 psi at an injection rate of 487 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. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 10/18/2011 Page 1 of 1 Maunder, Thomas E (DOA) From: Hutcherson, Mark R [Mark.R .Hutcherson @conocophillips.com] Sent: Tuesday, October 18, 2011 3:12 PM To: Gauer, Jenn L; CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt Subject: RE: LPP /SSV defeated on 1E-105 : Sept 23, 2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1E -105 (205 -006, 205 -007 L1, and 205 -008 L2) was defeated on 10/18/11. This occurred due to an SSV shut -in just after the LPP had been enabled earlier in the day. Current wellhead pressure (as of 15:20 hrs 10/18/11) is 499 psi at an injection rate of 1495 bwpd. It is anticipated the pressure will continue to build above 500 psi in the near future. 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. Wad liar Senior Drillsite Petroleum Engineer NSOD KRU West Sak Field ConocoPhillips Alaska, Inc. Office: 907 - 265 -1034 Cell: 832 - 794 -3862 'YCIVISO4fil) (t 6 201; 10/19/2011 STATE OF ALASKA ALASKA•AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell r Rug Perforations r Stimulate r Other r MBE Sealing Pull Tubing Perforate New Pool Waiver Treatment Alter Casing r 9 � r � Time Extension �°-` Change Approved Program r Operat. Shutdow n 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 r ` 205 -006 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 - 50 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25660 • 1E -105 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 13539 feet Plugs (measured) None true vertical 3624 feet Junk (measured) None Effective Depth measured 8209' feet Packer (measured) 7191, 7619 true vertical 3699 feet (true vertucal) 3510, 3601 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108 108' SURFACE 3875 13.375 3905 2285 INTERMEDIATE 8265 9.625 8290 3712' A -SAND LINER 5900 5.5 13519 3624 RECE1VEL Perforation depth: Measured depth: slotted liner 8312'- 13454' r �? t :1GP ©�tl True Vertical Depth: 3716' � masi:a tJii & Gas c commission Tubing (size, grade, MD, and TVD) 4.5, L -80, 7229 MD, 3521 TVD 7iChOTKI0 Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PACKER @ 7191' MD and 3510' TVD PACKER - HRD ZXP LINER TOP PACKER @ 7619' MD and 3601' TVD NIPPLE - CAMCO 'DB -6' @ 503 MD and 503 TVD 1 1 . Stimulation or cement squeeze summary: f xi/4v 0 L 4 � c t A T , m . Ex — 'l. LF Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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 560 Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service' f Stratigraphic r 15. Well Status after work: Oil r Gas E WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ P' WAG GI NJ j"' f"` SUSP r SPLUG fa 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 -200 Contact John Peirce Ca 265 -6471 Printed Name John Peirce Title Wells Engineer hereby ce tt , ti Phone: 265 -6471 Date c -f z , r i L R DMS SEP W Form 10-404 Revised 10/2010 7•Z- - tr Submit Original Only `e f�7/i 1 E -105 and 1 E -105L1 Well Work Summary DATE SUMMARY 9!4/11 PERF FROM 8745' - 8750 CTMD !NI/PE B SANDS LATERAL, PERF INTERVAL PROVIDED 6 SPF @ 60 PHASING W/ 0.43" HOLES, PUMP CRYSTAL SEAL, 2310 LBS OF 4 MM PRODUCT WAS PUMPED IN A 2% KCL SOLUTION ACROSS THE PERFS IN THE B SAND LATERAL. WH FP, COMPLETE KUP , 1 E -105 Conocop ilfi . Well Attributes Max Angle & MD TO 7dti1Sf(A, f' Wellborn APUUWI Fi Id Name Well Status Ind 1 MD (ftKB) Act Btm (ftKB) ^ ,..,,,,,,,,, ., 500292324300 ( WEST SAK INJ 96.20 8,942.81 13 539.0 Comment H25 (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV NIPPLE Last WO 30.59 6/20/2005 _ - -_ _ "____ gdwdaue. Attk,et_„ Annotation Depth(BKB) End Date [Annotation Lest Mod ... [End Date Last Tag: 13,018.0 6/21/2006 Rev Reason: ADD PERFS nlnam 9/7/2011 HANGER 23- 'n' "° Casing Strings _. _,. , [Casing Description String 0... String ID .. Top (ftKB) Set Depth (f.. Set Depth (1300) ... String Wt... String Stnng Top Thrd : .' '� ° CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K WELDED CONDUCTOR, 1 I Casing Description String 0... String ID ... Top (ftt(B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 31 - 170 SURFACE 133/8 12.415 30.0 3,905.3 2,285.6 68.00 L BTC NIPPLE, 503 Casing Description String 0... String ID... Top (NKB) Set Depth (1.. Set Depth (TVD) ... String Wt... Siring ... String Top Thrd l' INTERMEDIATE 9 518 8.835 25.1 8,290 0 3,710.6 40.00 L BTCM SURFACE, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f_. Set Depth (TVD) .. String Wt... String ... String Top Thrd ' 38 - 3.905 ASAND LINER 5 1/2 4.950 7,619.1 13,519 0 3,624.1 15.50 L BTCM GAS LIFT, 4,217 - I Liner Details Top Depth' SLEEVE, 7,164 (TVD) Top Inc! Nomi... LOCATOR, Top (ftKBI (ftKB) (") Item Description Comment ID (in) 7,211 SEAL A 7,619.1 3,601.2 79.53 PACKER HRD ZXP LINER TOP PACKER 4.970 ,212 �' D SAND LINER _ 7 212 7,637 6 3,604.6 79.66 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.875 LEM._ � . =i 7,191 ` " 7,640.4 3,605.1 79.68 HANGER FLEX -LOCK LINER HANGER 4.853 4l 8 -SAND LINER LEM, + 7649.4 3,606.7 79.75 SBE CASING SEAL BORE EXTENSION 4.750 7,462-7,662 IATE, Casing Des ription - Wt. 6-SANO [String 0... Str g ID . f (ftKB) Set Depth (f... Set Depth (TVO) ... Str ng .. String ... String Top Thrd 25 - 8,290 DSAND LINER LEM 41/2 1 3958 L _ 7,1906 l 7,4925 I 35773 f 1260 l L80 IBTM 6,312 -8,774 grief Details I IPERF, 6,745 -8,759 Top Depth SLOTS, (7300) Top Inc! N i... 9,0309,498 Top (NKB) (ftKB) ( ") Rem Description Comment ID (In) SLOTS. _ - 9,710 - 10,473 7,190.6 3,510.0 74.79 PACKER ZXP LINER TOP PACKER w /HRD PROFILE 7 500 7,213.5 3,516.3 75.14 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 10584 - 120060 7,232.6 3,521.4 75.43 XO BUSHING CROSSOVER BUSHING 3.940 SLOTS._ 12318 - 12603 ti,. 7,240.3 3,523.4 75.55 HANGER LEM ABOVE BOOK HANGER 3.980 7,254.4 3,527.0 75.76 HANGER LEM INSIDE HOOK HANGER 3.688 SL 3455 T55 12,90 BSAND LINER, �, 7,489.2 3, 576.7 79.49 SE _.__ _ AL ASSY BAKER SEAL ASSEMBLY 3.880 7,523- 13,510 i Tubing Strings II� II Tubing Description String 0.. String ID Top (ftKB) Set Depth (f... Set Depth (TVD) . IStr ng Wt... String .. tring S Top Thrd - TUBING 41/2 3958 I __ 22.6 I 7,229.2 3,5205 j 12.60 L80 1 IBTM .. ,._ _ Completion Details Top Depth (7300) Top Incl Nontt... . I Top(ftKB) Mat) r) Item Description Comment ID(in) -- 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 I ,, ,,, , 503.2 502.8 4.42 NIPPLE CAMCO 'DB-6' NIPPLE w/NO GO 3.875" PROFILE 3.875 7,163.9 3,505.3 76.00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE (CLOSED 6/27/05) 3.810 _ __ - 7,211.1 3,515.7 75.10 LOCATOR BAKER LOCATOR 3.880 s^-^ a 7,211.8 3,515.9 75.11 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 Perforations & Slots Shot Top (7300) Bhn (PM) Dens Top (ftKB) 8477 (ftKB) {ftKB) (ftKB) Zone Date (sh..• Type - Comment 8,312 8,774 3,715.6 3,726.5 WS A2, 1E -105 5/18/2005 0.0 SLOTS Slotted Liner, alternating joints of blank/slotted linerfor all A-Sand slots 2.5 x .125 holes, 4 rows/ft .�.r 8,745 8,750 3,728.5 3,728.2 9/412011 6.0 IPERF 60 DEG PHASING w/ 0.43" HOLES ,---•-•• ,---•-•• N r " J 1 -t- ' alternating - ,. 9,030 9,498 3,702.2 3,695.0 WS A2, 1E- 105 5/18/2005 40.0 SLOTS Slotted Liner, alteating joints of I `-' I - blank/slotted linerfor all A -Sand slots N 0 .T- � � u.. 1 2.5 x .125 holes, 4 rows/ft 9,710 10,473 3,703.6 3,685.0 WS A2, 1E- 105 5/18/2005 40.0 SLOTS Slotted Liner, alternating joints of S ' `" blank /slotted linerfor all A-Sand slots F ''1 v f U 2.5 x .125 holes, 4 rows/ft l i 10,731 11,114 3,669.9 3, 658.2 WS A2, 1E -105 5/18/2005 40.0 SLOTS Slotted Liner, alternating joints of ����� I blank/slotted liner for all A-Sand slots 2.5 x .125 holes, 4 rows/ft i 11,584 12,090 3,663.2 3,660.0 WS A3, 1E -105 5/18/1005 40.0 SLOTS Slated Uner, alternating joints of i blank/slotted liner for all A-Sand slots 1 1 : :" 2.5 x .125 holes, 4 rows/ft i 12,348 12,603 3,649.3 3,631.7 WS A3, 1E- 105 5/18/2005 40.0 SLOTS Slotted Liner, alternating joints of l blank/slotte linerfor all A-Sand slots 2.5 x .125 holes, 4 rowslft p 12,902 13,455 3,623.9 3,624.7 WS A3, WS A2, 5/18/2005 40.0 SLOTS Slotted Liner, alternating joints of E 1E -105 blank/slotted linerfor all A-Sand slots .: -� 2.5 x .125 holes, 4 rows/ft Notes: General & Safety _. :r _H r '`.� 44 1 � End Date Annotation 6/18/2006 I NO T5: TRI LATERAL WELL: A -SAND (1E -105), B -SAND (1E- 105L1), DSAND (1E- 10512) ti� 6/18/2006 NOTE B SAND LEM CONTAINS CAMCO'DB' NIPPLE w/3.92" ID @ 7578' i I I I 1 1::: „ = Mandrel Details _ T op Depth Top o (TVD) Ind OD ( 1 Valve Latch SPizrt e TRO Run = Stn Top (ftKB) (ftKB) 1") Make Model (in) Sery Type,.., Type (in) (psi) Run Dale Com... • l 1 4,217.1 2,399.5 68.74 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 2 6,712.9 3,383.2 68.69 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 1 I t i L HM ASAND 9 LINER, 7,619 - 13,518 TD (1E- 105), 1 �::.- 13,539 • KU P . 1 E -105 Conocophimps - KB -Grd (ft) Rig Release Data • • _._. • _., - .- ...._ 30.59 6/20/2005 RANGER, 23 — -- ° Notes: General & Safety End Data Annotation 129/2009 NOTE VIEW SCHEMATIC w /Alaska Schemat c9 OREV CONDUCTOR, � I 9/11/2010 NOTE: MBE repairw /9 bbls of 1G7 2289E, 105 degree meltpoint wax @ 8750' 31 -170 .. NIPPLE, 503 - -- ze -. - — SURFACE, 30 -3,905 GAS LIFT, \ GAS 4,217 LIFT, :,fir -• - 6,1 SLEEVE, LOCAT O R, LOTR, '.ate: ],211 SEAL A ,212 .. 4 ],21R D -SAND LINER illW` LEM, - t 7,191 -7,493 B-SAND LINER LEM, 7,462-7.662 VTERME MEDI -8,290 2S- SOTS, 8,312-8,774 PER I' - PERF, _ 8,745-8,750 SLOTS, 9,030-9,498 0 OTT. SLOTS, 9,710-10,473 SLOTS, 10,731- SLOTS. 11,584-12,090 SLOTS, SLOTS, 12,348-12,603 SLOT SLOTS, 12,902-13,455 B-SAND BSAND LINER, 7,523- 13,510 • jl t I l 1 IL 1 1 1 f M _ I d 1 i A-SAND ^^^- LINER, 7,619 - 13,519 TD (1E -105), 1 F 13,539 Page 1 of 1 • Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Friday, September 23, 2011 2:10 PM To: Gauer, Jenn L; CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (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 Subject: LPP /SSV defeated on 1E-105 : Sept 23, 2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1E -105 (205 - 006, 205 -007 L1, and 205 -008 L2) was defeated on 9/23/2011when the well was returned to injection service after being shut since 9/4/2011. Current wellhead pressure (as of 1410 09/23/11) is 188 psi at an injection rate of 487 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. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile 303.248.6641 • `' ,' (} t- 9/23/2011 • • Neiv . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 V\ 1E0 June 27, 2011 ' ca,05 c „ Commissioner Dan Seamount / � ` Alaska Oil and Gas Commission d1 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, ( " cj'-- - ( c/----Y/ MJ L veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD II Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -03 50029206150000 1810880 I 16" I_ N/A 23" I N/A I 1.7 6/20/2011 1A-04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B-03 50029205880000 1810560 SF N/A 23" N/A 5 6/21/2011 1B-04 50029205950000 1810650 18" N/A 18" N/A I 2.5 6/21/2011 1B -05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6/21/2011 1B-07 50029206160000 1810890 72" 1.00 22" 5/9/2011 2.5 6/21/2011 1B -08A 50029206350100 1971120 _ 18'8" N/A 29" N/A 4.5 6/21/2011 1B-09 50029206550000 1811340 SF N/A 23" N/A 5 6/20/2011 1B -10 50029206560000 i 1811350 SF N/A 23" N/A 6 6/21/2011 1B-12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/21/2011 1B -101 50029231730000 2031330 3" _ N/A 22" N/A 1.7 6/21/2011 1B-102 50029231670000 2031220 11'2" 0.60 36" 5/9/2011 1.7 6/21/2011 1E -05 50029204790000 1800580 _ 19" N/A 19" N/A 1.7 6/19/2011 1E -22 50029208840000 1822140 14" 1.75 17" 3/21/2011 1.7 6/19/2011 1 E -23 50029208580000 1821840 58' 10.75 2'5" 5/23/2011 3.4 6/19/2011 1E -30 50029208140000 1821390 15'5" 1.75 16" 3/21/2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 1841810 _ 14'9" 2.00 35" 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 1951210 7'8" 1.00 12" 5/9/2011 5 6/18/2011 1Y -02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 r t Ii J L D mn 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 O o ConocoPhillips Alaska, Inc. ' �Q S P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E-105 Sundry Number: 311 -200 Dear Mr. Peirce: ifi jut Q"1 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 DATED this day of June, 2011. Encl. STATE OF ALASKA '4 .I‘ RECEIVED ALASKA" AND GAS CONSERVATION COMMISSIO . 1 APPLICATION FOR SUNDRY APPROVALS iu ► A 'I $ 201i 20 AAC 25.280 1. Type of Request: Abandon J Flug for Redrill r Perforate New Pool r Repair well r + + ": .tn�' { 1 $$IOfl Suspend r Rug Perforations r Perforate r Pull Tubing r Asgtarion r Operational Shutdown r Re -enter Susp. Well E Stimulate r Alter casing r Other: MBE Sealing Treatment P • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205 - 006 ' 3. Address: Stratgraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23243 - 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 2- • 1E -105 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25651, 25660 + 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): 13539 3624 ' 8209' 3699' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20 108' 108' SURFACE 3875 13.375 3905' 2285' INTERMEDIATE 8265 9.625 8290' 3712' A -SAND LINER 5900 5.5" 13519' 3624' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 8312' 13454' 3716' - 3625' 4.5 L - 7229 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) ZXP LINER TOP PACKER W /HRD PROFILE MD= 7191 TVD= 3510 HRD ZXP LINER TOP PACKER MD= 7619 TVD= 3601 CAMCO 'DB -6' NIPPLE MD =503 TVD =503 12. Attachments: Description Summary of R 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory j " Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/10/2011 Oil r Gas 1" WDSPL fl Suspended r 16. Verbal Approval: Date: WINJ 17 GINJ r WAG r 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 1 Signature ,r' /ii/ < :. Phone: 265 -6471 Date 6„ / 711 Commission Use Only Sundry Number:51 `— j W f) 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 Li APPROVED BY �� COMMISSIONER THE COMMON Date: C // 666 4 Approved bye/ , F I / � ,• 1 G - -1( or J U N 1 . 4 � 1, , Q R I G I N A L Submit Duplic 1113DMS .rt‘44 • • 1E-105L1 to 1E-126L1 MBE Treatment A matrix bypass event (MBE) occurred Dec. 2005 in 1E-105L1 with breakthrough to 1E-126L1 producer. A 6/20/06 IPROF in 105L1 found a heel MBE at 8750' RKB taking all PWI. 1E-105 currently has an Iso -Sly set over 1E-105L2 (D lat) and Diverter set in the 1E-105L1 (B tat) LEM. Halliburton CrystalSeal is intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is a water swellable dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal swells to 400 times original size by hydrating and absorbing water. Due to swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate acceptance of injection. Procedure: Coil Tubing: 1) Pull old style 2.50" min ID Iso - Sleeve from the 1E-105L2 (D lateral) LEM at 7258' MD. 2) Run 2.75" OD pert gun to shoot 10' of big hole perfs in 5.5" slotted liner at 8740 - 8750' RKB ✓ in 1 E -105L1 to enable CrystalSeal entry through slotted liner to the MBE. POOH with perf gun. 3) Set a 'new style' 2.75" min ID Iso - Sleeve across 1E-105L2 before Crystal Seal job. 1E-126 ✓ producer will be shut -in to limit drawdown on the MBE during the 1E-105L1 CrystalSeal job. 4) RIH w /Active -Coil until large side port only (`wax nozzle') is at the perf interval at 8740 - 8750' MD, then pump 40 bbls 2% KCI Pad down coil at initial rate of 0.7 bpm. Work rate to max allowable rate just below frac gradient 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 allowable rate while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.25 ppg CrystalSeal (4 mm size) ✓ at max allowable rate 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 0 60 bbls (target) 2% KCI with 0.4 ppg CrystalSeal (4 mm size) down coil at steady max allowable rate to stay just below frac gradient while squeezing slurry to MBE and monitoring treating pressure at nozzle. Cycle the nozzle occasionally over the perf interval to mitigate screen out, and to remove bridging of CrystalSeal across the perforated 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 from coil to liner. If pumping proceeds OK to target of 60 bbls, open CT x Tbq 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 B LEM at 7524' MD, followed by POOH with coil pumping xx bbls Diesel for FP, followed by 1 more CT volume of Diesel to fully displace all Diesel FP into the tubing. RD CTU. Wait at least 6 hours to let the CrystalSeal fully hydrate before returning 1E-105L1 to PWI to ✓ evaluate effectiveness of treatment in sealing the MBE. Return 1 E -105L1 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 how injectivity has changed as a result of the treatment. • -11,-. = KU P • 1 E -105 CSC ! it i , , A . Wsli Attribjotes -_ Max Angle & MD TO Et :,S`a°40, Inc 4 ,y Wellbore API/UWI Field Name Well Status Inc! () MD (ft108) Act Btm (ftKB) tsx+anMttdksz: 500292324300 WEST SAK INJ 96.20 8,942.81 13,5390 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "" SSSV: NIPPLE I Last WO _ _ 3059 _ 6/20/2005 - „F,,*--71k4A9ig, - - $ PM - >- A notation Depth (ftKB) End Date Annotation Last Mod By End Date rhem`sl aJ Last Tag: [Depth 1 6/21/2006 Rev Reason: MBE Repair w /Melted WAX � 10/2/2010 HANGER, 23 "" - " ` "*. Casing Strings _. Casing Description String 0... String ID . Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String . String Top Thrd ' "" " """ CONDUCTOR 20 19.124 31.0 170.0 170.0 94.00 K WELDED CONDUCTOR, I Casing Deserption String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth MD) ... String Wt... String ... String Top Thad 31 - 170 SURFACE 13 3/8 12.415 30.0 3,905.3 2,285.6 68.00 L BTC NIPPLE, 503 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thad INTERMEDIATE 9 5/8 8.835 25.1 8,290.0 3,710.6 40.00 L-80 BTCM - -_ __. ; I L Casing Description String O._ String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... String g .. String Top Thrd SURFACE, A-SAND LINER 5 1/2 4.950 7,619.1 13,519.0 3,624.1 15.50 L-80 BTCM 30-3 Liner Details GAS LIFT. " , 4,217 Top Depth - GAS LIFT, - (TVD) Top Intl Nomi... 6,713 - - _MR Top (ft(B) ( (") Item Description Comment ID (in) SLEEVE, 7,164 7,619.1 3,601.2 79.53 PACKER HRD ZXP LINER TOP PACKER 4.970 LOCATOR, - 7,211 - . -ma s ■ 7,637.6 3,604.6 79.66 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.875 SEAL ASSY, .. + 7.212 7,640.4 3,605.1 79.68 HANGER FLEX - LOCK LINER HANGER 4.853 D - SAND LINER - - - LEM, 7,649.4 3,606.7 79.75 SBE CASING SEAL BORE EXTENSION 4.750 7,1917,493 B- SAND LINER ICasing Description IStr ng O... String ID ... Top (HKB) Set Depth (f.. Set Depth (ND) . String W.. String ... String Top Thrd LEM, D -SAND LINER LLM 412 395 71906 [- _74925 l. D 3577.3 I t. 1260 L80 , IBTM 7,462 - 7,662 .._ NTERMEDIATE, Liner Details 25 -6.280 I Slat Top Depth' 8,312-8,774 - (ND) Top Inc! Nomi... 9,030-9,498 Do Top (ftKB) (ftKB) (°) Item Description _ Comment ID (in) y1 7,190.6 3,510.0 74.79 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 7.500 9,710 10,473 - - Slot, _ 7,213.5 3,516.3 75.14 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 10731 - 11.114 -- '-- - - 6101, I . r y 7,232.6 3,521.4 75.43 XO BUSHING CROSSOVER BUSHING 3.940 11,584 12,090 - - -- -- _. Slot - 7,240.3 3,523.4 75.55 HANGER LEM ABOVE HOOK HANGER 3.980 12,348. 12.603 Slot, _ 7, 254.4 3,527.0 75.76 HANGER LEM INSIDE HOOK HANGER 3.688 12.902 - 13.455 BSAND 7,489.2 3,576.7 79.49 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 LINER, i " - - 7,523 - 13.510 i ' ' Tubing Strings ( Tubing Description String 0... Strmg ID . Top (ftKB) Set Depth (1... Set Depth (ND) . String Wt... String String Top Thrd TUBING 41/2 1_ 3958 L ,._ 226 [ 7,2292 1 3,5205 I 12.60 I L-80 � ._. IBTM -. -_ e .e Completion Details _ _ _ _ Top Depth . - - (TVD) Top Inel Top (ftKB) (f e) Item Description Comment ID (in) L 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER _ 4.500 --- 503.2 502.8 4.42 NIPPLE CAMCO -6 NIPPLE w /NO GO 3.875" PROFILE 3.875 7,163.9 3,505.3 76.00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE (CLOSED 6/27/05) 3.810 d' . 1 7,211.1 3,515.7 75.10 LOCATOR BAKER LOCATOR 3.880 I i " - " 7,211.8 3,515.9 75.11 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 1 7 8a Perforations Slots Shot .M. Top (TVD) 8tm (11/0) Dens Top (ftKB) Btrn (81(8) (ftKB) (ftKB)_ Zone Date (5h..3 Comment f. 8,312.0 8,774.0 3,715.6 3,726.5 WS A2, 1E- 105 5/18/2005 0.0 Slot Slotted Liner, alternating joints of w blank/slotted liner for all A-Sand slots 1 2.5 x .125 holes, 4 rows/ft ..,..i; 9,030.0 9,498.0 3,702.2 3,695.0 WS A2, 1E- 105 5/18/2005 40.0 Slot Slotted Liner, alternating joints of t' I p blank/slotted liner for all A-Sand slots - • 9 2.5 x .125 holes, 4 rows/ft 9,710.0 10,473.0 3,703.6 3,685.0 WS A2, 1E-105 5/18/2005 40.0 Slot Slotted Liner, alternating joints of M 1 blank /slotted liner for all A-Sand slots '_ 1 i 2.5 x .125 holes, 4 rows/ft I ;. 1 I. _ 10,731.0 11,114.0 3,669.9 3,658.2 WS A2, 1E- 105 5/18/2005 40.0 Slot Slotted Liner, alternating joints of " ° blank /slotted liner for all A-Sand slots 2.5 x .125 holes, 4 rows/ft I I 1 ";t4 11,584.0 12,090.0 3,663.2 3,660.0 WS A3, 1E-105 5/18/2005 40.0 Slot Slotted Liner, alternating joints of II I 1.. ^+ 1 21 blank/slotted liner for all ASand slots 2.5x.125 holes, 4 rows/ft i 1 12,348.0 12,603.0 3,649.3 3,631.7 WS A3, 1E- 105 5/18/2005 40.0 Slot Slotted Liner, alternating joints of 1 I 1 blank/slotted liner for all A -Sand slots 1 ! 2.5 x .125 holes, 4 rows/ft ______� i 1 12,902.0 13,455.0 3,623.9 3,624.7 WS A3, WS A2, 5/18/2005 40.0 Slot Slotted Liner, alternating joints of _ - -- _ 1 1 1E -105 blank/slotted liner for all A-Sand slots d . 2.5 x .125 holes, 4 rows/ft I f Notes: General & Satety End Date Annotation 6/18/2006 NOTE: TRI LATERAL WELL A -SAND (1E -105), B -SAND (1E- 105L1), D -SAND (1E- 105L2) ^. _ - - _ - 6/18/2006 NOTE: B-SAND LEM CONTAINS CAMCO'DB' NIPPLE w/3.92" ID @ 7578' I M 1/29/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV 9/112010 NOTE: MBE repair w/9 bbls of 1G1-2289E, 105 degree me)tpoint wax @ 8750' + l 1 i. 0 . Mandrel Details 1 Top Depth Top I Port I e;„ (TVD) Intl OD Valve Latch Size TRO Run 1 - Stn Top(ftKB) (ftKB) ( °) Mae Model (in) Sere Type Type (in) (psi) Ron Date Corn... A -SAND '# 1 4,217.1 2,399.5 68.74 CAMCO KBG 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 LINER, 7619 2 6,712.9 3,383.2 68.69 CAMCO KBG 1 GAS LIFT DMY BK 0.000 0.0 8/8/2010 TO (1E-105), 13,539 , . ... Wellhead / Tu d/ Tree, 13-5/8" x 446', 5,000 ksi • ,.., Insulated Conductor fl Casing, 20", 94#, K55 x Tubing Suing: 4-1/2", 12.6 #, L-80, IBTM .------- == ',•: I 1 (1) 3.875" DB nipple set @500 ...rt !AR (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG- 2, one (1) set at 67 deg, 4,217' MD, 2,415' D. aor 13-3/8", 688, L-80, BTC, R3 (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG- ® 71.86 degrees TD 16" hole 2, one (I) set at 68 deg, 6,712' MD, 3,380' TVD. (1) Sliding Sleeve, with 3.812" nipple, one (1) joint above SlitirlAtigrt•Vii ------÷ 'IiII:. packer. 7,164' MD, 3,508' TVD a 105 L2 "D" Sand Window ® 7,258' MD / 3,52T TVD A 1 Lateral Entry Module #2 (LEVI), • 1 111111...' '''...,:'......, Baker, with seal bore and ZXP 76 degrees '93" Liner, 5-1/2", 15.56, L80, BTCM, R3 packer above. 'I.'.;'' 73 slotted and 71 blank, 01125" x 2.5" slots open area) , 32 per foot, 59% ope, X : o 1 EC? packer 16 constrictors ® 12,655'02,405', 11,860', 11,480', 11,400', 11,090', 1-• ,.." 0 ""' 0 Fil M 300' MD / 3,536' TVD 10 : ..3. long, 78.5 degrees 10,848', 10,630', 10,150', 9,790', 9,305', 9,110', 8,601', 8,400', 8,000% 7,420' ;•■• i V •.•itiiiiiiiittAiWaiig 1 11, • 1- 'i I"- 2-- Fi = lo s „ a 7-. 7.--. CA AV 10 rat th7 -.. WS" "a8P WO <V NW •S/ 'itS" NW N IIV Lateral Entry Module #1 (LEM), 7 () Baker, with seal bore and ZXP .' packer above. g. 105 LI "B" Sand Window ' "B"Lined, 5-1/2", 15.56, L80, BTCM, R3 ,..et ;'''''''',:*'• ' ® 7,524 MD / 3,583' TVD 65 jta Slotted, 63 jta blank, (0.125" x 2.5" slots, 32 per foot, 5.9% open 4 A / 79 degrees area), 18 constrictors @13,260', 12,710', 12,450', 12,245', 11,890', 11,641', iii* . 11,045', 10,641', 10,400', 9,910', 9,650', 9,300,9,050', 8,700', 8,500', • ir..S., • 8,134', 7,793% 7,610' -,•:•:•:::• .:,:•:•:•:::::,.:::•:•:•:•:•:•:•:•:•:•:,.......:,...... -4. ., ,..,-. Tubing, 4-lc" IBTM, from LEM to "111110 slotted a e ,1 A2 Sand Liner, 5-%", 15.54, L80, A2 Liner, with seal stein and .;:"....-',I" r".-----; urcm, R3 said % blank, CAMCO 3.562. "DB" nipple. .;:t'::•`:::?. 4--- corufrictors for Isolation ., , Seal bore and ZXP packer for A2 .... "a liner , o'.. .... *.• .1‘. ` t. ..•1 '`, ..itt, SY"; .1 +/- 90' below "B" window ..,.. ft,..."..":•;,,,ii•-e-.. .....1-'"':':::' .. 1 r 9-5/8", 40N, L-80, BTCM, R3 Csg __r .,-...'it".•;.:..., , -5,s.., "....."'" .:.,...:-...z ' / 4 9 - ® 8,295' MD l 3,713' TVD , - ...:_- ....r :14- ' KA ... @81.54 degrees TD 12-1/4" hole OF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERQATION CO1101ISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John W. Peirce Wells Engineer ConocoPhillips Alaska, Inc.? P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -105 Sundry Number: 310 -371 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 DATED this ti day of November, 2010. Encl. STATE OF ALASKA (_ r1 O ALASKJOL AND GAS CONSERVATION COMMISSI• A- (� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill Perforate New Pool Repair well Change Approved Program ) Suspend Rug Perforations Perforate" Pull Tubing r ', Time Extension Operational Shutdow n Re -enter Susp. Well r Stimulate Alter casin Other: Wax Treatment ]rr ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' Exploratory "" 205 - 006 3. Address: 6. API Number: Stratigraphic r Service rVe P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23243 -Ot7 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 1E -105 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651,•25660 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): 13539 3624 8209' 3699' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 108 20 108' SURFACE 3875 13.375 3905' 2285' INTERMEDIATE 8265 9.625 8290' 3712' A -SAND LINER 5900 5.5 13519' 3624' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slots in liner from 8312'- 13455' 3716' -3625' 4.5 L -80 7229 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) NIPPLE - CAMCO'DB -6' NIPPLE W /NO GO 3.875" PROFILE MD= 503 TVD= 503 PACKER - ZXP LINER TOP PACKER MD= 7619' TVD =3601' 12. Attachments: Description Summary of Proposal rv 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory r Development Service 1 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/15/2010 Oil F Gas WDSPL r Suspended" 16. Verbal Approval: Date: WINJ r GINJ WAG Abandoned Commission Representative: GSTOR r SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John W . ' Peirce Title: Wells Engineer Signature (w Phone: 265 -6471 Date 11 Commission nl Sundry Number: VVV �, D —�j� Conditions of approval: Notify Commission so that a representative may witness ✓✓ Plug Integrity BOP Test Mechanical Integrity Test Location Clearance r 4 �d Other: j lc.. �I► 2010 �,�•, . x `1it � ��� FOR$ Subsequent Form Required: Q — YQY • �Q "� Sion IChf.3 0 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I Form 10- 403�t�I /`f O RIGINAL Submit in Duplicat 10//a • 1 E -105 Seal B Sand MBE with Wax Proposal / Objective: 1E-105L1 is a B sand lateral with 5.5" slotted liner. A Matrix Bypass Event (MBE) occurred in 1051-1 in 2005 to 1 E -126 offset producer. A 6/20/06 [PROF in 1051-1 detected an MBE at 8750' MD near the heel of 1051-1. A Crete job was attempted on 9/4/06 to seal the MBE, but it failed. 1 E -1051_1 MBE isolation was attempted 9/11/10 with molten wax pumped down coil. This initial wax job failed to seal the MBE. The wax pumped to the MBE was probably too hot to solidify in the MBE before it flowed to 1 E -126 which was on production to exert drawdown on the MBE. Active -Coil will be used to reattempt sealing the 1E -1051-1 MBE using 105 - 115 F melt point wax heated to 180 ° F at surface. A total of 20 bbls of wax will be pumped down coil to the MBE at 8750' MD. For this attempt, the offset 1 E -126 producer will be shut -in and the wax will be placed in the MBE with the wax temperature in phase change range (melting point range) to help limit the wax solidification time in the MBE. Procedure: 1) Preheat 1 E -105 for wax job by pumping 180 F Seawater down tubing at 1 bpm for —72 hrs. 2) RIH with Active -Coil to MBE at 8750' RKB and pump 20 bbls of molten wax down coil to the MBE. Displace wax out of coil with hot Seawater at 0.5 - 1.5 bpm to the MBE, followed by shutdown. Monitor temperature cool down at MBE. POOH with CT. RD. 3) Wait on wax 5 - 7 days to harden and cure. 4) Return 1 E -1051-1 to injection to test wax job and determine if wax plug has sealed the MBE. Determine the future well work plans for 1 E -105 andl E -126 following evaluation of the wax job. r KU P 1 E-105 Coca lfips w le I naaX aJ1�e s� MD TD Wellboro APUUWI Fieltl Name Well Status Incl ( °) IMD (ftKB) Act Bum (ftKB) Ala" ft. 500292324300 W ES T SAK INJ �. 9620 _ L 8,942.81 13,539.0 C ment H2S (PPm) Date An otaf oo _ End Date KS-Grd (ft) Rig Release Date wan c 6 SSSV NIPPLE _ '� _ Last WO I 30.59 6/ 5 A k ,, 1 PM A otation� Depth (ftKB) End Date An "t.".. Last Mod By En Date .Last Tags 1$018 0 6/21/2006 Re Reaso M RepgiL WAX __ �____Imosbor _T_1012/2010 nANCER,23 - -- Cas S trin s Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Turd Fin. OR 20 19.124 31.0 170.0 170.0 9400 K -55 WELDE CONDUCTOR, ' dption String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt String String Top Thrd ... ... ... CTOR, 13318 12.415 30.0 3,905.3 2,2 68.00 L-80 BTC NIPPLE, 503 ription String 0 String ID ... Top (ftKB) Set Depth (t Set Depij (ND) String Wt String ... String Top Thrd IAT 9 5/8 8.835 25.1 8,290.0 3,710.6 40.00 L BTCM ription String 0... String ID ... Top (ftKB) Set Depth (L.. Ssl Dspth (TVD) .. String Wt... Str g .. String Top Thrd SURFACE, ER 5 112 4.950 7,619.1 13,519.0 3,6241 15.50 L - BTCM 3a3.99s Liner Details GAS LIFT, ' Pt Top De h x • AS 6,217 LIFT,_ (ND) Top loci Nomi... 6,713 r7,6637 (ftKB) ( °) Item - De s"I on Comment ID(in) SLEEVE,7,164 3,601.2 79.53 PACKER HRD ZXP LINER TOP PACKER 4.970 LOCATOR, 7,211 3,604.6 79.66 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.875 SEAL ASSY, 7,212 - 3,605.1 79.68 HANGER FLEX -LOCK LINER HANGER 4.853 D - SANDUNER LEM, = 3,6067 79.75 SBE CASING SEAL BORE EXTENSION 4.750 7,191 .93 . _ B - SAND LNER s ription String O Strng ID ... ITOp (ftKB) ISet Depth (i...ISet Depth (ND) .. Str ng Wt... Str ng ... String Top Thrd LEM, D SAND LINER LEM 4 112 3 958 7,190 6 7,492,5 3 12.60 L 80 IBTM l,a.7,fi62 TERMEDIATE, Liner Details 25 -8,290 - - - --- - -- -- - slot, Top Depth 8,312 -8,774 (ND) Top Ind Slat, To B (ftKB) (°) Itam DeacriP Comment ID (I. 9,030 -9,498 S' 73 7,190.6 3,510.0 74.79 PACKER ZXP LINER TOP PACKER w /HRD PROFILE 7.500 o 9,710 - 10.4 - - Sim, _ 7,213.5 3576.3 75.14 SBR 190 CASING SEAL BORE BORE RECEPTACLE 4.750 10.731 - 11.114 _ - .. __. -- Slot, 7,232.6 3,521.4 75.43 XO BUSHING CROSSOVER BUSHING 3.940 11584 12,090 _. ---._ - . _.. Sla, -- -- - 7,240.3 3,523.4 75.55 HANGER LEM ABOVE HOOK HANGER 3.980 12,348 - 12,603 - __ -_.. _ _. _. __- ___ Slot, 7,254.4 3,527.0 75.76 HANGER LEM INSIDE HOOK HANGER 3.688 12,902 - 13,455 _ - I - _ --. __. ._ BAND 7,489.2 3,576.7 79.49 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 LINER, 7,523 - 13,510 Tubina Strin s Tubing Description String 0... String ID ... Top (ftKB) Set Depth if Set Depth (ND) ... String Wt... String ... String Top Turd TUBING 41/2 3.958 22.6 7,229.2 3,520.5 12.60 L -80 IBTM Completion Details Top Depth (ND) Top Incl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) y 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 __-_._ L - -- -- 503.2 502.8 4.42 NIPPLE CAMCO'DB-6' NIPPLE w /NO GO 3.875" PROFILE 3.875 - 7,163.9 3,505.31 76.00 SLEEVE CMU SLIDING SLEEVE WCAMCO 3.81 DS PROFILE (CLOSED 6/27105) 3.810 k - -.: 7,211.1 3,515.7 75.10 LOCATOR BAKER LOCATOR 3.880 I '= 7,211.8 3,515.9 75.11 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 1 [ - Perforations S Slots Shot Top (TVD), St. (ND) Dons i i.. To ftKB Btm ft( Kg] (ftKB) (ftKB) _tone _Data (sh -• _ T e _ Comment ! 8,312.0 8,774.0 3,715.6 3,726.5 WS A2, 1 E- 105 5118/2005 0.0 Slot Slotted Liner, alternating joints of - blank/slotted liner for all ASand slots 2.5 x .125 holes, 4 rowsift 9,030.0 9,498.0 3,702.2 3,695 0 WS A2, 1 E -105 5118/2005 40.0 Slot Slotted Liner, alternating joints of blankslotted liner for all ASand slots 2.5 x .125 holes, 4 rows/ft !� 9,710.0 10,473.0 3,703.6 3,685.0 WS A2, 1 E -105 51182005 40.0 Slot Slotted Liner, alternating joints of -._ -� blank /slotted liner for all ASand slots l l.. 2.5 x. 125 holes, 4 rows/ft 1 10,731.0 11,114.0 3,669.9 3,6582 WSA2, 1E -105 5/18/2005 40.0 Slot Slotted Liner, alternating joints of blanWslotted liner for all A -Sand slots 2.5 x .125 holes, 4 rows/ft i f 11,584.0 12,090_ .0 3,663.2 3,660.0 WS A3, 1 E -105 5/18/2005 40.0 Slot Slotted Liner, alternating joints of blank/slotted liner for all ASand slots f z 2.5 x. 125 holes, 4 rows/ft 12,348.0 12,603.0 3,649.3 3,631.7 WS A3, 1E -105 5518/2005 40.0 Slot Slotted Liner, alternating joints of blank/slotted liner for all ASand slots 2.5 x .125 holes, 4 rows/ft l - 12,902.0 13,455.0 3,623.9 3,624.7 WS A3, WS A2, 5/18/2005 40.0 Slot Liner alternating joints of ( 1E -105 ]1 liner for all ASand slots 2.5 z 125 holes 4 rows /ft N ik-General 8 Safety _ End Date Annotat 6/18/2006 NOTE TRI LATERAL WELL A SAND (1E-1 05) B SAND (1E 1051-1), D -SAND (1E- 10512) 6/1 /2006 - NOTE BSAND LEW CONTAINS CAM CO 'DB' NIPPLE w/3.92" ID - @7578 - -- _ 1/292009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV 9/112010 NOTE: MBE repair w/9 bbls of 1G7- 2289E, 105 degree rneltpoint wax @ 8750' i - Ma_ ndrel Details y Top Depth Top Port (TVD) Inc] OD Valve Latoh Site -0 Run Stn To (fNCB) (ftKB) (7 Make Model (i ^) Sere TYPe TyPe (i ^) (Psi) Run Data Cam... ASAND 1 4,217.1 - 2.399.5 68.74 CAMCO KBG -2 -1 R 1 GAS LIFT M BK 0.000 0.0 8/8/2010 LINER, 2 6,712.9 3.383.2 68.69 CAMCO KBC -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 8182010 7,619 -t 3,519 _ TD(1E -105), 13,539 Re: 1 E -1 05L1 injector wax job of the MBE. 9 -07 -10 through 9- 10 -10: We injected 180F Seawater full -bore down the 4.5" tubing at 1 bpm for -96 hours to pre -warm 1 E -1051-1 for the wax job. This started on 9- 07 -10. Active -Coil started rig up on 1 E -105 on 9 -10 -10 while we continued 24 hr 180F water pumping into the well. 9 -11 -10 Wax Job: We started with a clean empty wax tank hard lined to a manifold that allowed drawing fluid from the wax tank through a pump to route it to coil. First we loaded 5 bbls of Seawater from a transport to the wax tank and then had a steam unit begin circulating steam through heater coils in the wax tank to bring this water up to 180F. This 5 bbls was 'starter fluid' to melt solid wax blocks we'd be dropping in this 35 bbl tank. Wax and water don't mix and don't form any lasting emulsion, so with water on the bottom of the tank we'd have our molten wax of lower density floating on this hot water. Since hot water would was the only fluid pumped ahead of the wax that we were going to pump into 1 E -105, the last 5 barrels of water down coil ahead of the wax would be the first 5 barrels of fluid to be drawn from the bottom of the wax tank once we got swapped over to drawing fluid from the wax tank. This water would be followed by molten wax, and then we'd swap back over to pumping 180F water to displace wax with 1 full coil volume out of the nozzle to the MBE. Using hot water for melting wax cubes worked well on this job. We started unpacking wax from 50 lb boxes and loading it to the wax tank. It was good idea we decided to start this work early, because it proved to be difficult and slow going loading the wax to the tank. This work was ongoing as coil was making preparations to RIH. While still pumping 1 bpm 180F water down the tubing, we stabbed dry 1.75" OD Active -Coil on the well and prepared to liquid pack coil with hot water. This required shutting down pumping of hot water into the well for a short while, so we could swap to pumping -1.5 coil volumes (39.2 bbls = 1 CT volume) of 180F water at 1.5 bpm through coil to our returns tank. This took -40 minutes. As soon as coil was loaded with hot fluid, we started RIH with coil at -100 fpm while swapping to pumping 180F water down the CT x Tbg to keep the well warm, since the CTU doesn't take well to pumping down coil with such a hot fluid while RIH (creates excessive elastomer wear concerns on the unit while moving pipe with hot fluid circulating through coil, plus the elastomers on the unit are only rated to 180F). When coil got the nozzle parked at the MBE at 8750' RKB, we swapped back over to 180F pumping going down coil at 1.5 bpm. Since we were only using one pump we were always either down pumping down the CT x Tbg annulus or the CT, but never both at the same time. When coil parked nozzle at the MBE we were still unpacking and loading wax to the wax tank, so coil just continued circulating 180F water at 1.5 bpm while parked at the MBE until we finished wax loading to the tank. After 6 hours we had unpacked and loaded 9 bbls of wax (105F - 108F melt point) to the wax tank and melted it to 180F - 200F. The initial plan was to put a few more barrels of wax in the tank, but it was getting late and everyone was beat from the work unwrapping the wax. We decided to just declare it a 9 bbl wax job at that point. 53 Ibs of wax hardener additive was added to the tank (2% by weight to wax). Lab testing showed that this hardener would significantly help us improve the final hardness of the low MID wax when it hardens in the MBE. While we were working at 1 E -105, we had also begun producing offset 1 E -126 on the day of the wax job to pre -warm the MBE. 1 E -126 was flowed with minimal GL to tanks to put some drawdown on the MBE from 1 E -105. This would draw hot fluids through the MBE. We had a 44 AAMI OLD N0 0 6 2 0) 0 choke hand at 1 E -126 for the day to monitor tanks and we ran transports to empty tanks since the plant would not allow 126 to flow to the plant due to plant upset potential. About mid - afternoon we were finally ready to pump the wax down coil. BHT at the nozzle was reading -116F which was plenty BHT for our 105F - 108F melt point wax. We decided to proceed pumping the job. We opened up the valve to allow flow from the wax tank through hard line to the pump to get the wax loaded to coil. The first barrel or two came out of the tank at a good rate, but then we suddenly had decreasing ability to draw fluid from the wax tank. Fortunately we were able to maintain at least a steady slow rate of drainage (0.2 - 0.4 bpm) from the wax tank and we had to be patient for a while to empty the contents of the tank. During this time BHT creeped down to 111 F due to the low rate we had going down the well. We didn't realize it at the time, but post job observations during equipment demob would later reveal that we had some plastic shreds in the wax tank that apparently got sucked down the tank drain line causing a partial blockage of flow in the hardline between the wax tank and our pump. We were just lucky we didn't totally plug off. Looks like in spite of our best efforts to keep plastic wrap (wax was shipped to us in plastic) out of our wax, we still had some small shreds of plastic in those 120 wax cubes we tossed in our tank. Once we got all 9 bbls of wax in the coil, we were able to swap from pulling fluid from the wax tank hardline and resume pumping 180F water down the coil to displace the wax down coil at 1.5 bpm. As we regained our pump rate, we saw BHT at the nozzle rebuild to 115F. With the first barrel of wax at the nozzle we had our hand at 1 E -126 shut -in GL on the producer. With wax exiting the nozzle and only 3 bbls of wax left in the coil, we had 1 E -126 shut -in. We over displaced the wax from coil by 1 bbl, then shutdown all pumping down coil. I'll assume all the wax should have traveled down the MBE (takes 100% of PWI on our (PROF). We were now waiting for the wax to cool and solidify in the channel (reservoir temp -75F). We kept CT parked at the MBE to monitor cool down for about 30 minutes and saw temp drop to about 109F during this time, then we started POOH. We slowly POOH while replacing voidage to avoid any swab effects on our wax placement. Later coil was blow down with N2 and we rigged down the unit. We started demob and broke down hardline. We found a nice plastic (wax packing) debris wad plugging the line from the wax tank and also observed a few plastic shreds left floating in the bottom of the empty wax tank. Overall the job went real well except for the plastic junk issue in our draw line. Had we placed clean wax in the tank with no plastic we'd have had a very smooth job pumping the wax. We've learned some good lessons for the next job. 1 E -1 14L1 wax job is to be done next; 9/30/10. Distributed Temp Survey DTS was not run because the DTS box was still out for repairs. We P Y( ) P should have DTS on the next job. We will leave 1E-105 shut -in a week to let the wax cure and build shear strength. The sample in my office is already showing that it's becoming quite hard. If the wax made it into the MBE and stayed in the MBE, we could have a pretty strong plug in place. We'll see how it turns out. Best way to know for sure is maybe consider doing another IPROF across the MBE. Plan forward is to steam clean the wax tank and order wax in buckets to avoid plastic in wax issues. Now we know that we can at least pump wax through the coil. We'll send a 10 -404 in a couple weeks when we get the well back on cold Seawater injection (should help keep the wax harder). John Peirce, 9 -14 -10 Page 1 of 1 Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Thursday, July 15, 2010 4:37 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: LPPISSV defeated on 1 E-105 - 07-15-2010 Tom /Jim, The low pressure pilot (LPP) on tri-lateral injector 1E-105 (205-006, 205-007 L1, and 205-008 L2) was defeated on 7/15/2010 when the well was returned to injection service after being shut since 06/16/10. Current wellhead pressure (as of 16:20 07/15/10) is 200 psi at an injection rate of 495 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 4066.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Office: 265-6112 (659-7493 this week) Cell: 240-5056 7/16/2010 ~ ~-~ l C - I ~`~ Regg, James B (DOA) ~ ~~-~° From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, June 26, 2010 9:59 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: KRU 4 Yr and Variance MIT's Attachments: KRU 1 G-01 062510.x1s; KRU 2D-04 062510.x1s; KRU 1 E pad 062510.x1s ~.~1 J_. ~ _J ~, ~.. KRU 1G-O1 KRU 2D-04 KRU lE pad 062510.x1s (21 KB) 062510.x1s (21 KB) 062510.x1s (21 KB) Attached please find the State Witnessed Variance required MIT~s for 2D-04 and 1G-O1 and State waived 4 year MIT~s on DS1E. Let me know if you have any questions about the data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 >;'ll~r r'~6 1 1 FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~~~ ~(2~~+a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Kuparuk /KRU / 1 E 06/25/10 Ives/Mouser - ASRC Waived by Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 1 E-21 Type Inj. W TVD 5,943' Tubing 2,000 2,000 2,000 2,000 Interval 4 P.T.D. 1830020 Type test P Test psi 1500 Casing 1,620 3,000 2,960 2,960 P/F P Notes: OA 80 80 80 80 Well 1 E-22 Type In'. N TVD 5,955' Tubing 2,250 2,250 2,250 2,250 Interval 4 P.T.D. 1822140 Type test P Test psi 1500 Casin 740 2,920 2,880 2,850 P/F P Notes: OA 490 520 520 520 Well 1 E-104 Type In'. W TVD 3,351' Tubing 900 900 900 900 Interval 4 P.T.D. 2042270 Type test P Test psi 1500 Casing 61 2,000 1,980 1,960 P/F P Notes: 45 Min T/I/O = 900/1960/200 OA 190 200 200 200 Well 1 E-105 - Type Inj. N TVD 3,515' Tubing 200 200 200 200 Interval 4 P.T.D. 2050060 Type test P Test psi 1500 ~ Casing 100 2,000' 1,940 1,920 P/F P ' Notes: OA 100 140 140 140 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 062510.x1s ~_~ Maunder, Thomas E (DOA) Page 1 of 1 From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Thursday, June 17, 2010 3:09 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 No Longer Defeated On 1 E-105, 16-June-2010 Tom/Jim, The low pressure pilot (LPP) on 1E-105 (205-006, 205-007 L1, and 205-008 L2) is no longer defeated, as the well was shut-in at 19:58 hrs on June 16, 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 _W-: u 6/17/2010 Page 1 of 1 n U ~J Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com) Sent: Wednesday, June 16, 2010 8:08 AM 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-105 - 06-15-2010 Tom /Jim, The low pressure pilot (LPP) on tri-lateral injector'FE-1,~8_ , 205-007 L1, and 205-008 L2) was defeated on 6/15/2010 when the well was retumed to injection service after being shut since 06/08/10. Wellwork commenced on the well 6/8/10 and is scheduled to continue through 06/17/10. Current wellhead pressure (as of 07:49 06/16/10) is 9 psi at an injection rate of 1,477 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 LPPISSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 c ~, . ~_ ~ ' `~ ... ~~~~ 6/16/2010 • • ~~Q~~ 00 ~ a[~Q~Q3Q /,E,~.~~,.~o.~.~, John Peirce Wells Engineer ~ a~~ ConocoPhillips Alaska, Inc. ~.~ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1 E-105 Sundry Number: 310-112 y~ -~ Dear Mr. Peirce: ~~ ;,{3;,~6Stl.:~,t~.• ~~ ~ ~ ~~; 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ~ ~ day of April, 2010. Encl. ~4', ~~`~ STATE OF ALASKA ~~~ ALAS~IL AND GAS CONSERVATION COMMISS~~~ APPLICATION FOR SUNDRY APPROVALS qpR t) R ~1Q ~ 20 AAC 25.280 ti~ 4•/µ~O a x r e n-a 1. Type of Request: Abandon "" Rug for Redrill ~ Perforate New Pool epair we~g ~~ 8rm ~"' Suspend ] Rug Perforations Perforate J-' Pull Tubing ~`°" Time Extension ~'"" qn Operational Shutdown j°` Re-enter Susp. Well ~ Stimulate After casin 9 ~ ~ ~pabr Other: Matnx bypass Event ~, 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r"'"` Exploratory ~""' 205-006 • 3. Address: Stratgraphic ~ Service ~`', 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23243-00 ' 7. If pertorating, 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 ~ N o ~ 1E-105 9. Property Designation: 10. Field/Pool(s): ADL 25651, 25660 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective ~eptn Mo (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13539 3624 8209' 3699' Casing Length Size MD ND Burst Collapse CONDUCTOR 108 20 108' 108' SURFACE 3875 13.375 3905' 2285' INTERMEDIATE 8265 9.625 8290' 3712' A-SAND LINER 5900 5.5 13519' 3624' Perforation Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slots in liner from 8312'-13455' 3716'-3625' 4.5 L-80 7229 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NIPPLE - CAMCO 'DB-6' NIPPLE W/NO GO 3.875" PROFILE MD= 503 ND= 503 HRD ZXP liner top pakcer MD= 7619 ND=3601 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory ~ Development ~ Service - 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/10/2010 Oil "` Gas ~"'' WDSPL ~ Suspended "'" 16. Verbal Approval: Date: WINJ ~' GINJ "` WAG ~' Abandoned ~"`" Commission Representative: GSTOR SPLUG '~`'. 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 ~~ r Phone: 265-6471 Date ~• ~ r~Q - C mmi i n nl Sundry Number: 31 ~ _. ~r Conditions of approval: Notify Commission so that a representative may witness 1 Plug Integrity BOP Test Mechanical Integrity Test "" Location Clearance Other: Subsequent Form Required: l d . yo y APPROVED BY ER ~/~~+. ~ o D O Approved by: COMMISSION THE COMMISSION ate: U AApppp ~~~~~~~ +~ ~~ ~ g~r~ Form 1 c~~1~~2040= ~ /~ y Submit in Duplicate. ,-<<~ -~ ~RIGII~IAL. •9`~ =-~~-~ 1 E-105L1 Proposal to Wax Fill the B Sand MBE Proposal 8- Objective: 1 E-105L1 is a B sand lateral with 5.5" slotted liner. A matrix bypass event (MBE) occurred in 105L1 in 2005 to 1E-126 offset producer. A 1/28/06 (PROF of 1/28/06 in 105 showed all PWI entering the B sand. A 6/20/06 IPROF in 105L1 saw a robust MBE at 8750' MD near the heel of 105L1. A Crete job was attempted on 9/4/06 to seal the MBE, but the job failed. On 10/7/06 an Iso-Slv was set in the B LEM. 1E-105 has since been on just `D & A only' PWI. (PROF data• shows 1 E-105 A sand lateral does not take any appreciable PWI. The Iso-Slv will be pulled from the 105 B LEM and replaced with a diverter, then an Iso-Slv will be set to isolate the D sand. In 1 E-126, the Iso-Slv will be pulled from the B LEM to allow inflow from the MBE, then an Iso-Slv will be set in the D LEM. A Step Rate Infectivity Test (BRIT) will then be pumped in 105L1 to determine fluid temperature pumped through an Active-Coil (I-Coil) nozzle at MBE depth vs. various pump rates. This will provide a temperature vs. rate plot at the nozzle to determine pump rates needed for placing liquid wax into the MBE. An Active-Coil job will be performed to seal the 105L1 MBE using 125 F melting point wax heated to 180°F at surface. Hot wax will be pumped down coil to the MBE at 8750' MD as liquid and will be displaced by warm diesel to the MBE, followed by shutdown to let the wax solidify in the MBE to West Sak reservoir temperature (~72 F). Work Sequence: 1 E-105 Injector Work 1 E-126 Producer Work CT Pull 'B' Iso-Sleeve CT Set'B' Diverter CT Set 'D' Iso-Sleeve halt X-Flow Pull 'B' Iso-Sleeve o en MBE Set 'D' Iso-Sleeve halt X-Flow Pump BRIT using Active-Coil with Distributed Temperature Survey (DTS), with 180°F Seawater pumped in 1 coil volume stages at various rates ranging from 1.5 bpm to 0.5 bpm. Verify an open MBE with DTS across trunk of MBE, and by WHIP vs. In' Rate indicators. Pump Wax Job using Active-Coil with Distributed Temperature Survey (DTS). Pump 100 bbls 180°F Seawater at 1.5 bpm to ensure open 8~ preheated MBE, followed by 10 bbls 180°F Wax at 1.5 bpm, followed by 1 Coil volume of warm Diesel displacement at 1.5 bpm gradually slowed to decreasing rates to put the tail of the wax slug into the MBE just a few degrees above cloud point, followed by shutdown to let wax solidify in MBE. Wait on Wax 4 da s to `cure'. Return to `B' sand onl PWI Flow as `B' sand onl to evaluate Wax Job Pull 'D' Iso-Sleeve Pull D lso-Sleeve Restore PWI to A, B, and D laterals Restore roduction from A, B, and D laterals ~...__.~ ~ KUP ,. Ct)YIOCI~I~'i!I{IBS ~` Well Attributes -- _ ,~ j I~ Wellbore APVU WI 1Field Name Well 1 / 500292324300 WESI SAK INJ 1 IC ent ~H2S (ppm) Date SSSV: NIPPLE 40 9/1/2009 WeA,C flg 1E 10§ 217 2W ___ Schema(i- Attu I A tattoo L 357 lag_ -Depth (HKB) End Data Annotalion ~~ 13,018.0 ~ 6/21/2006 Rev Reason: ^FIANGER^23 ~ ~^~ ~jnn Stnnnc GAS LIFT. 4,217 GAS LIFT. 6.713 SLEEVE. ],164 LOCATOR. 7.211 SEAL ASSV, ] 212 D-snrvD Prod/Inj TYPO 1 E-105 8MD jTD KB) Act Btm (ftK8) 942 81 13,539.0 'd (ft) Rig Release Dat 30.59 620/2005 I End Date 2/1/2009 Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 'CONDUCTOR 20 19.124 0.0 170.0 170.0 94.00 K-55 WELDED Casing Description String O._ String ID ... ' Top (ftK8) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE ~ 13 3/8 12.415 30.0 3,905.3 2,285.6 68.00 L-80 BTC _ Casing Description String 0... String ID ... Top (ftK8) Set Depth (t... Set Depth (ND) ... String W1... String ... String Top Thrd INTERMEDIATE 9 5/8 8.835 25.1 8,290.0 3,710.6 40.00 L-80 BTCM Casing Description String 0... String ID ... Top (ftK8) Set Depth (i... Set Depth (ND) ... String WI... String ... String Top Thrd D-SAND WINDOW 95/8 8.000 7,258.0 7,275.3 3,532.1 Casing Description String 0... String ID ... Top (HKB) Set Depth (f... set Depth (ND) ...'..String WL.. (String ... String Top Thrd B-SAND WINDOW 95/8 8.000 7,524.0 7,534.0 3,585.0 -- (Casing Description String 0... 'String ID ... Top (HKB) Set Depth (f... Set Depth (ND) .. String Wt... Str ng .. String Top Thrd 1 A-SAND LINEt2 S 1/2 ~ 4950 BTCM 7,619.1 13,519.0 3,624.1 1550 L 80 I Liner Details -~- . - (NDI '. TOP lncl (HKB) Top (HKB( ~ (°) Item Desttipti on Comment ID (in) 7,619.1' _ 3,601.2 79.53 PACKER HRD 2XP LINER TOP PACKER 4.970 7,63261 3,604.6 79.66 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.875 7,640.411 3,605.1 79.68 HANGER FLEX-LOCK LINER HANGER 4.853 ' 7,6424 6.7 79.75 SBE 'CASING SEAL BORE EXTENSION 4.750 Str- s Tubin~ - - _ - T bing Des option String 0... String ID ... Top (ftK8) Set D pth (f... Set Depth (ND) .. St ng Wt... Str ng String Top Thrd i ~ 7 ~ IUBING (BIM 1260 L-80.. 412 3.958 22.6 _i 7229.2 I 3,520.5 Completion Det Top Depth ails _ _ (NDI lop Intl Top (ftK8) (HKB) (°) Item Description Comment ID (in) 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 503.2 502.8 4.42 NIPPLE CAMCO'DBfi' NIPPLE w/NO GO 3.875" PROFILE 3.875 7,163.9 3,505.3 76 00 SLEEVE CMU SLIDING SLEEVE wCAMCO 3.81 DB PROFILE (CLOSED 6!27/05) 3.810 7.211.1 3,515.7 75.10 'LOCATOR iBAKER LOCATOR 3.880'. 7,211 A i 51 S 9 75.11 S EAL ASSY BAKER SBE S EAL ASSEMBLY 3.8801 ',Perfora tions _ _. - __ snot ToP(N D) Btm (TVD) ' Dens ' Top (ftK8) Bfm (HKB) (ftK8) (ftK8) Zone Date (sh-~ Type ~' Comment _ 8,312.0 8,774.0 3,715 .6 3,726.5 WS A2, tE-105 5/1812005 0 0 Slot Slotted Liner, alternating joints of hlank/slotted liner for all A-Sand slots 2.5 x .125 holes, 4 rows/ft 9,030.0 9,498.0 3,702 .2 3,696.O1 WS A2, 1E-105 5!18/2005 40.0 Slot 9,710.0 10,473.0 3,703 .6 3685.0 WS A2, 1E-105 5/18/2005 40.0 Slot 10,731.0 ' 11,114.0 3,669 .9 3,658.2 WS A2, 1E-105 5/182005 40.0 Slot 11,584.0 12,090.0 3,663 .2 3,660.0 WS A3, 1E-105 5/18/2005 40.0 Slot 12,348.0 12,6030 3,649 .3 3.631.7 WS A3, 1E-105 5/18/2005 400 1 Slot 12.902.0 13,455.0 ' 3,623 .9 3,624.7 WS A3, WS A2, 5718/2005 ', 40.O I~SIOt 1 E-105 (Notes: General & Safety ~ "?"°`'~£ _-. _ __ End Date Annotation 1/2912009 NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 (NOTE: TRI LATERAL WELL' A-SAND (1E-105), B-SAND (1E-105L1), D-SAND (1E-105L2) Mandrel Details : _ : _ _.. TOP Depth ToP - - -..: _. . Port ( (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftK6)~ (ftK8) (°) Make Model (inI Serv Type Type lin) (psi) Run Date Comm... 1 4,217.111 2,399.5 68.74 CAMCO KBG-2-1 R 1 Gas Lift DMY SBK-2C 0 0.016/18/2005 2 G,712.9 3,384.0 71.51 CAMCO KBG-2-1R 1 Gas Llft (DMY SBK-2C 0 006/182005 I A-SAND ±!!!' LINER, 7,619-13,515 TD (1 E-105). ~~~ 13,535 2T ' ~.., Schlumberger -DCS 2525 Gambell Street, Suite 400 ., _~~ Anchorage, AK 99503-2838 ~~~ ~,;~~ ~J'• ~ ~ ~~ ATTN: Beth Well Job # Log Description NO.5063 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 02/09/09 1 L-13 11978475 PRODUCTION PROFILE ~ - L $- 08/16/08 1 1 2A-26 AZJZ-00010 USIT ~- t~ 01/16/09 1 1 iD-141A ANHY-00041 FLOWING BHP -Q 01/21/09 1 1 3K-15 B04C-00004 INJECTION PROFILE ~' j 01/21!09 1 1 1E-105 AZED-00019 INJECTION PROFILE 01/23/09 1 1 1 E-119 AYS4-00023 INJECTION PROFILE v 01/23/09 1 1 3J-01 AYS4-00024 INJECTION PROFILE . -r = 01!24/09 1 1 2V-06 AZED-00022 INJECTION PROFILE /$ - 1 01/26/09 1 1 2K-22 AZED-00024 LDL J~-v J 01/28/09 1 1 2L-301 AZED-00025 SBHP SURVEY -' 01/29/09 1 1 1 R-03A ANHY-00045 INJECTION PROFILE T "~- s- ~ 02/09/09 1 1 2B-11 AZED-00028 INJECTION PROFILE e 02/01/09 1 1 2F-16 AZED-00029 INJECTION PROFILE U 02/02!09 1 1 3J-05 AZED-00030 INJECTION PROFILE 02!03/09 1 1 3G-07A AYS4-00033 PRODUCTION PROFILE j S 02/04/09 1 1 1 D-03 ANHY-00042 LDL °~ - - 02/05/09 1 1 gg Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. lI ~g~ • • ten" MICROFILMED 03/01/2008 DO NOT PLACE ,' ~.~; ~-' _. ANY NEW MATERIAL UNDER THIS PAGE F:\L.aserFicl~\CWrPgs_Insertsll~Iicrofilm Mazker.cbc i q J",~ DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050060 Well Name/No. KUPARUK RIV U WSAK 1E-105 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23243-00-00 MD 13539 TVD 3624 Completion Date 6/19/2005 Completion Status 1-01L Current Status 1WINJ ~ - -----= -~ REQUIRED INFORMATION Mud Log No Samples No Directional su~ Yes ~ .~..~~ - DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: - Log/ Electr Data Digital Dataset Log Log Run Interval OH/ ~d/Frmt Number Name Scale Media No Start Stop CH Received Comments -~~-~~ ~~._- og Cement Evaluation 5 Col 1 4792 8160 Case 5/23/2005 USITICORROSION ANDOG 1 CEENT EVALUATION LOG ~ D Asc Directional Survey 11264 13539 Open 7/29/2005 IIFR D Asc Directional Survey 11264 13539 Open 7/29/2005 MWD I" D Asc Directional Survey 0 4395 Open 7/29/2005 IIFR PB1 I ~D D Asc Directional Survey 0 4395 Open 7/29/2005 MWD PB1 I ~ D Asc Directional Survey 4022 12208 Open 7/29/2005 IIFR PB2 D Asc Directional Survey 4022 12208 Open 7/29/2005 MWD PB2 ~ Temperature 5 Blu 4000 7240 Case 9/28/2005 Temerature Survey & RST- .;4' WFL 18 Sep 2005 Temperature 5 Blu 5500 7260 Case 10/17/2005 TEMPERATURE SURVEY I MAXTRAC~PRESS~EMP 2 Sep 2005 . ~ Injection Profile OTH Blu 0 7229 Case 1/6/2006 INJECTION PROFILE PRESS~EMP/SPIN .e6 D Lis 13425 Induction/Resistivity 3862 13501 Open 1/31/2006 GR/EWR4/ABIICNP/SLD/R OP/ACAUPWD/GEOPILOT Rpt 13425 LIS Verification 3862 13501 Open 1/31/2006 GRlEWR4/ ABIICN P/SLD/R OP/ACAUPWD/GEOPILOT 1..E6 D Lis 13426 Induction/Resistivity 3862 12170 Open 1/31/2006 GRlEWR4/ABIICNP/SLD/R OP/ACAUPWD/GEOPILOT I PB2 Replaced by DSN Rpt 13426 LIS Verification 3862 12170 Open 1/31/2006 13440 I GR/EWR4/ABIICNP/SLD/R . OP/ACALlPWD/GEOPILOT PB2 Replaced by DSN 13440 DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050060 Well Name/No. KUPARUK RIV U WSAK 1E-105 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23243-00-00 MD 13539 TVD 3624 Completion Date 6/19/2005 Completion Status 1-01L Current Status 1WINJ UIC Y A Injection Profile 5 Blu 7140 7626 Case 2/22/2006 MEMORY INJECTION PROFILE MEMORY LEE CCUGR/PRESSfTEMP 4 D Lis 13440 Induction/Resistivity 3862 12170 Open GRlEWR4/ABIICNP/SLD/R OP/ACAUPWD/GEOPILOT PB2 Replaces DSN 13426 , Rpt 13440 LIS Verification 3862 12170 Open Replaced DSN 13 /ED C Lis If )4032 Induction/Resistivity 3862 13493 Open 4/17/2007 LIS Veri, GR, FET, ROP, e FCNT, NCNT, DRHO, RHOB w/Graphics CGM, EMF, PDF /ED C Lis 15035 Induction/Resistivity 3862 12170 Open 4/17/2007 PB2 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? """"H-N-.. Daily History Received? @/N (!)N Formation Tops Analysis Received? ~ Comments: e Compliance Reviewed By: ~ j Date: J~ J~~ ~7 To: - "'ELL LOG TRA1~SMITT AL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: IE-l05, Ll, L2 & PB2, . April 16, 2007 AK-MW -3677560 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 IE-105, Ll, L2 & PB2: LIS & Digital Log Images: 50-029-23243-00,60,61, 71. c. R EfVE l\PD, 1, 1 "no',-' rd J' J Lu' J i~ r:'t"l,~ ~<>"i,"', ""'.. t',~""mJ~_ _!! '.. '"""," ,w,"", ~""""__3! À"''''''rmra lIiY¡"",..,~ u Xl!.:;) o-s-- Có~ #' )f)D3d 7f ls-033 u:r e... 9-05- 00+ u:r. c.-- e 6-:'- - 00 ð" tJ= IS-Do C-{ H ~ /5035 1 CD Rom LPP Defeated On West Sak Injectors at DSIE . . Tom / Jim, The Low Pressure Pilots for 1 E-102, 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 ~ 1E-1051006 BWPD, 660 PSI fJ-OS-OCì.(ò 1E-1121937 BWPD, 597 PSI 1E-114 945 BWPD, 562 PSI This email is in accordance with Administrative Approval No. CO 4068.001. Regards, Hai Hal Hunt / 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 1/16/2007 11:07 AM MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -:/ ! hCr1' b(?fDG DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-105 KIJPARUK RIV U WSAK IE-I05 úo0 ðwo6" FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ -ìl~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK IE-105 API Well Number 50-029-23243-00-00 Insp Num: mitCS060605102447 Permit Number: 205-006-0 ReI Insp Num Inspector Name: Chuck Scheve Inspection Date: 6/4/2006 Packer Well 1E-I05 ¡Type Inj. I N i TVD P. T. 2050060 iTypeTest I SPT Test p-si Interval 4YRTST PIF P Notes Well shut in for reservoir management. Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 3512 IA 250 2310 2250 2250 1500 OA 130 140 140 140 Tubing 860 860 860 860 Wednesday, June 07, 2006 Page 1 of 1 02/21/06 Schlumberger NO. 3691 ¡. ,- ~ "1 . ~ Þ Schlumberger -DCS 2525 Gambell Street, Suite 400 Com pany: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 FEB 22 2006 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 ~..." ,j"ìI~. "ulìumì1S1û¡' Anchorage, AK 99501 A!JclYJrage Field: Kuparuk . Well Job # Log Description Date BL Color CD 1 B-17 /q4 - 045" 11216283 SBHP SURVEY 02/18/06 1 1 E-36 198-';;13 11216282 SBHP SURVEY 02/18/06 1 3H-07 /~7-07q 11217023 LDL 02/11/06 1 3H-07 " /f 11166757 STATIC SURVEY 01/20/06 1 2A-09 (ð~-m 11154126 PRODUCTION PROFILE 02/09/06 1 1A-10 IB/-/ÚJO 11213710 INJECTION PROFILE 02/08/06 1 2M-14 /9,;)- 010:1; 11154127 INJECTION PROFILE 02/10/06 1 1 E-05 I Pfr D5R 11166747 PRODUCTION PROFILE WIDEFT 12/25/05 1 2H-12 IB5-:Jw'), 11154128 PRODUCTION PROFILE WIDEFT 02/11/06 1 1 C-21 11154131 PRODUCTION PROFILE W/DEFT/GHOST 02/14/06 1 3G-18 Iqt)- / é)&) 11154129 PRODUCTION PROFILE WIDEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 /B4-;Jf{p 11166753 PRODUCTION PROFILE 01/14/06 1 1Y-09 /83- Chi< 11213128 INJECTION PROFILE 02/06/06 1 . 1 E-1 05 [}OS -DD{P 11162832 MEMORY INJECTION PROFILE 01/28/06 1 2C-08 /B3-oq~ 11141255 INJECTION PROFILE 01/28/06 1 2C-02 IB!J- 093 11213129 INJECTION PROFILE 02/07/06 1 1 C-25 / qq -C>3! 11144074 GLS 02/02/06 1 JC-14 /84 - dlO 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 18.f-~/t 11144067 PRODUCTION PROFILE 01/26/06 1 _1A-18 190- 153 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 /B~-CJ8? 11213709 INJECTION PROFILE 02/07/06 1 1D-32 !)()()-I7A 11141252 LEAK DETECTION LOG 01/25/06 1 2C-12 181-X;{o 11141260 PRODUCTION PROFILE 02/02/06 1 2C-15 /84 - :;63 11141254 PRODUCTION PROFILE 01/27/06 1 1J-154 N/A PRODUCTION LOG W/TRACTOR 02/05/06 1 1 E-1 04 11217024 INJECTION PROFILE 02/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to·(907) 561-8317. Thank you. ~~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West ih Avenue, Suite 100 Anchorage, Alaska December 27,2005 RE: MWD Formation Evaluation Logs {ð 440 ó20S-00Co IE-105 PB2, AK-MW-3677560 1 LDWG formatted Disc with verification listing. API#: 50-029-23243-71 fwr~ t '\ '-\,Îv~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: '/~, O'ø Signcdi::~H~O~ J Note: This data replaces any previous data for welllE-lOS PB2. Schlumberger \l~~ J~í] 1) \1@))~ --~" Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 3644 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Field: Well Job# Log Description Date BL 10-02 11166733 INJECTION PROFILE 11/30/05 1 1E-07 11154107 PROD PROFILE WIDEFT 01/01/06 1 1E-105 ,MQ,000 11141240 INJECTION PROFILE 12/30/05 1 1 G-12 11144060 PROD PROFILE W/DEFT 12/28/05 1 1 L-28 11141239 PROD PROFILE WIDEFT 12/29/05 1 38-08 11154108 PRODUCTION PROFILE 01/02/06 1 38-02 11154109 INJECTION PROFILE 01/03/06 1 Kuparuk Color CD SIGNED/!FUcú;æ~ld) ;:,~~, i~·9Dit6) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 01/05/06 . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska November 14,2005 RE: MWD Formation Evaluation Logs I ð 4;)~ /JD6 --000 lE-105, AK-MW-3677560 1 LDWG formatted Disc with verification listing. API#: 50-029-23243-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: 19/'1/ D5 ~'I Signe&~-ð) . . WELL LOG TRANSMITTAL To: State of Alaska . Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West ih Avenue, Suite 100 Anchorage, Alaska November 14, 2005 RE: MWD Formation Evaluation Logs 13 4-~ ;)05- DQ(¡; 1E-105 PB2, AK-MW-3677560 1 LDWG formatted Disc with verification listing. API#: 50-029-23243-71 ""- uf&.J- ~ \ >vt<-\ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: lJr/ï IDE) Sign"tY~ëJ ) Scblumbepgep NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Anchorage, AK 99503-2838 A TTN: Beth Field: Well Job# Log Description Date BL 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09/04/05 1 2V-08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10/02/05 1 1 E-1 05 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: J/.Ja/LJ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD / 7 (') If- .1vtt r Î--và ).... - ~ ~ ~ 10/07/05 . . ~:l~ e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address:, P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 94' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE INTERMEDIATE PROD. CASING Perforation depth: 5. Permit to Drill Number: , .?~/3057n~;l 6. API Number: 50-029-23243-00 9. Well Name and Number: 1 E-1 05 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool measured 13539' feet true vertical 3624' feet measured 8209 feet true vertical 3699 feet Length Size MD 170' 20" 170' 3811' 13-3/8" 3905' 8196' 9-5/8" 8290' 5900' 5.5" 13519' Plugs (measured) Junk (measured) rvD -' Burst Collapse 170' 2285' 3712' 3624' Measured depth: 8312'-13454' true vertical depth: 3717'-3625' RBDMS BFl SEP 1 5 1005 Tubing (size, grade, and measured depth) 4-112" , L-80, 7229' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 503' Form 10-404 Revised 04/2004 Submit Original Only e 1 E-1 OS DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 9/6/200S Commenced WINJ ~ t:;"? mi '\'\. c-;::3 rb .q . , ! I..' j \, I' ¡ I , " ; J,\!i ! ,..,,\ ¡! !iI...\1 [I Lb" ., U:. Îffnil ¡ i ,. u 'u ~ . I.'ñì Ib ,,(ii, A '. i.,,~ , f'F:\,^@," iUIU~', ¡Ig\:: ¡g\n)') \::::!..J iU U ~ U u-...:::::..; ~ I fÀ\ ,Jj \ ¡¡ , lrl.... / l / J J / ¡ FRANK H. MURKOWSKI, GOVERNOR AI",ASHA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert D. Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska ~G-f)Ð& Re: Kuparuk 1E-105 Sundry Number: 305-252 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a oliday or weekend. A person may not appeal a Commission decisio 0 uperior Court unless rehearing has been requested. J n . Chairman DATED thisé day of September, 2005 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~ ION APPLICATION FOR SUNDRY APP :~OVAL 20 MC 25.280 Qp~r<ltion S~II,II~W~ "I:l' plio/a !"j¡,rlorililon3 0 o ". -. ":'~...." ,", ,~..,.. """HII¡;: " ''','':11 11. I,' .1., I " ". '" .... . "" . .". "''',' 1;:<i¡¡yp~ oti~\ilqU ?òt ",' · '.AÞ;¡¡r~~.n ",' 0 .,' ":'" "'Å~r~~¡'¡¡¡ d,', :0: , '~ha~9~~gþf~j/llapfP9~~m;; .' 2. Operator Name: ._ " c::?nocoPhillips Alaska, Inc. 3. Address: " " '..",. "..- . :~~~þ"nd "....,,'l I ' ,I'.""" ~pÎÎlli¡'wøu, 0""·'" o '0 . .' . , , , Pull Tubilil~" P. O. Box toº~(30! Anc~()r.age, Alaska 99510 7. KB Elevation (it): RKB 94' s. Property Dðsignation; 5UP ilt:!.k.liiv~r Unit 11. Total depthMD iff): 13539' , .",.Ca~!!1U " ."..··u·_,_, ..... ..... Total Depth TVD (ft): E:ffeclive OePlh MO (ftr 3624' 8209 Length Size . ""'---'", -,,,.- CONDUCTOR SURFACE INTERMEDIATE LINER A-SAND 170' 3811' 8196' 5900' .. . ,....,.. 20" 13-3/8" . "..- /.... ......I ,~\ 9-518" 5~1/2" Perforation Depth TVD (ft): 3717'-3.6:25' /. n4IL ./ U~·~()~ ~{( ...:::.g .~=:...g;i'- ::::~~ ,", I.-I :R~n~r ¡;¡U$JiI~I1~~å:~/ .'. 0 5. Permit to Drill tliüinber:- 9. W~ II Name and Number: ~-105 10. F !lld/Pool($): Kupa IJk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUIIIMARY Effective Depth TVD (ft): Plugs (I :easured): . Junk'(measured): 3699 MD PétfOIõlW New Pool r···¡:· ëÙàérifWell' ëïas$: D~eIQPml;!f1t .... 0 S1ratJ9rap~ic 0 . e iplor~p iY c:::r ·SsrvItIO· Perforation Depth MD (ft): 8312'w1$454' Packers and SSSV"fype; ZXP Liner top pkr w/HRD sssv- NIP 1i;);.ti~èiïm'Mtš:-·'-De¡;Cript¡O"$ümm¡¡¡Ì'y of Proposal . 0 Q.etailed Opera(ior¡s Program' . 0 BOP ~~etch 0 14,Estjroäted Þ~t~ for Comm~ :1cing~peratiQn$~ ......,.. . 08.129/05 ·.is.·VërÞåì APï>i6'Ýal:··,n".""'''''' . '''D~t~tÕW261Ô5' .. Comi')'\i~!òiQI'1;Rf;lpr~~II!I:)~~t;\I !J: Tom MaUr'lder 17. ~~reby:¢ertÎtY"tti~rthe::flil~~oin915 tr~e aPld correÇt tö the best of my knowledge. Prir~d Narn~. .,~.9.Þ,~,r.!:~þ,~:;,~~ta~$,E1J~ . ~jgnat~.~~~:.~:...:._.._.. ~-:_. ..... '.' ...m_.. ... ...... ~~m~ sslon Use Only ._ ..un ~ ._ 170' 3905' 8290' 13519' 'ND 170 ¡~28S " J712 . .... ~ p" I .' ...,_ :'e~4 .. ..... --.- . Tubing ilta: " ..1/2" Packers and SSSV MD (ft) PKR = 7161': 7462'; 7619' SSsV= 503' 13. W~II Cla~s after proposed work Exploratory 0 ~\. itlopment 0 . . . " I.~ "...nl-,.,.r~l~i II I. .11" A 15. Well Status after proposedwor . Oil 0 Gas [] WAG 0 QINJ :J ·'Nfl-H"ldC. . &_ _41_. Cont¡ ;;1:; T,itle: Phon 659-7224 COnditions of approval: Notify Commission $0 that a reprè6èntatlve mijY witne5~ .205.,Q06 6. API Number: .. 50-029-23243·00 '- Burst """:'" . ....~.,'\. . Collapse ,'" ....~,~.:. . ",'.urn. ., "r~¡, I. ".A..IM,... ¡ "rr. ,,,n"\'''' rubiog Grijde: L-80 Tubing MD (ft): 7229' . ."1'1"\.,,.. Serv.ice ø PI1.I9ged 0 WINJ [2] Abandoned 0 WDSPL 0 .' . ',., .....,. N/J t.ovelanc:J/Ma~18 McConnEl.! Problem W!!II.' .$u':¡erv¡50r Qate:lI 0/ D$'" Isundry Number: ... . ..... ........ 3'0 S- ~ d. s-?-- Plug Integrity 0 BOF> Test 0 MechaniCÇlllntegrlty Test ~ Locatiol Clearance 0 0"", r~1t:&.1:> "Id íJtXtt \."'-WO~ '-J f þ,,\.G d-~, ~\t\ê.Ð t-J L ~ 10 39'\td APPRO ,'ED 6Y ~ lJS ..,.,.,.A_.......'...,_[.!..H~c. C.!JJMIS. SION I D8t';.: .. " /\ · . (l'C~ - J -~ ì ,," I' ~UPI¡Cijte Þl£L6S9L06 a~:60 S00l/80/60 COMMISSIONER dno~9 Sll3M >JSN · -. /1£-\ ". ~\ li!'''{' ,~,,\ .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 94' 11. Total depth MD (ft): Total Depth TVD (ft): Junk 13539' 3624' Casing Length Size CONDUCTOR 170' 20" SURFACE 3811' 13-3/8" INTERMEDIATE 8196' 9-5/8" LINER A-SAND 5900' 5-1/2" Packers and SSSV Type: ZXP Liner top packer w/HRD SSSV= NIP <-.,< ckers and SSSV MD (ft) :JI Pkr=7161', 7462',7619' o SSSV= 503' Commission Use Only ission so that a representative may witness ISUndry Number: ". . _ _._ ~C)~·_~:S d.... BOP Te 0 Mechanical Integrity Test ~ O.......()\Xl\Q~~,,'> '\ "'<.J-~<3:J:=J "VI Location Clearance 0 ~\O ~ ß, W~Th\<...O~L-'{ ~\)\-\ ()n,r'1\'Al J¡"\ ! LJ U\I .. . ORDER OF COMMISSIONER THE COMMISSION Date: Approved by: Form 10-403 Revised~ INSTRUCTIONS ON REVERSE Submit in Duplicate ,. . 1 E-1 05 DESCRIPTION SUMMARY OF PROPSAL ¥ ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Well 1 E-1 05. This well was pre-produced for a 30 day period. Well 1 E-1 05 is the multi-lateral wellbore which will provide pressure support for the West Sak A sand. The 13-3/8" Surface casing (3905' tvd / 2286' tvd) was cemented with 798 sx AS Lite followed by 219 sx DeepCrete. The 9-5/8" Intermediate casing (8290' md /3713' tvd) was cemented with 650 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 7" x 9-5/8" Liner Top Packer w/HRD located @ 7191' md /3512' tvd. The D sand lateral injection tubing/casing annulus is isolated via a lower ZXP 7" x 9-5/8" Liner Top Packer w/HRD located @ 7462' md /3572' tvd. The B sand lateral injection tubing/casing annulus is isolated via a lower ZXP 7" x 9-5/8" Liner Top Packerw/HRD located @ 7619' md /3601' tvd. The top of West Sak D sand is located at 7260'md / 3528' tvd. The top of West Sak B sand is located at 7516'md /3582' tvd. The top of West Sak A sand is located at 7688' md /3613' tvd. An MITrA was pèrformed on 08/20/05; MITIA 3000 psi, 30 minutes, Passed IE-I OS FINAL: . ~~~i~~::i~::i ;~9~';jd PadElevation: 66.1' AMSL Doyon Rig 141 Rig Floor (RF) @\J' Elevation: 94.1' AMSL Wellhead I Tub jug Head I Tree, 13-5/8" x r 4-V,". 5.000 ksi _ ~ Tubing String: 4-1/2", 12.6#,L-80,IBTM ~·l 3.875" DB nipple set@ 500' ... +--- y- Insulated Conductor Casing, 20", 94#, K55 x 34",0.312" wr @ +/- 80' MD g j o B g' ,,- ~'-6' ~. fÀ (I) Gas Lift Mandrel, CAMCO 4-112" x I" ModeIKBG- 2, one (I) set at 67 deg, 4,217' MD, 2,415' TVD. .. ". ~ 13-3/8",68#, L-80, BTC, R3 @ 3,905' MD /2.285' TVD @ 71.86 degrees TD 16" hole 'th ~ 812" nipple, one (I) Sliding Sleev;; ;~ 08' TVD packer. 7,164' M , ~, ~ " Sand Window ~ 105 L2 "D /3527' TVD ...- @ 7,258' MD , Ir 76 degrees ECPpacker /3536'TVI 7100' MD , r @,- 785 degrees 23 66' long, ~~~ª! ]~~~! . (1) Gas Lift Mandrel, CAMCO 4-112" x I" Model KBG- 2, one (1) set at 68 deg. 6.712' MD. 3,380' TVD. (I) joint ~1~i,I~~r'~~II~ IE-105 L2: 8-112" D sand lateral 13,530' MD /3,396' TVD 7 Angle 98.63 degrees ':) TD "D" Liner, 5-112". 15.5#, LSO, BTCM, R3 73 slotted and 71 blank, (0.125" x 2.5" slots, 32 per foo~ 5.9% open area), 16 constrictors @ 12,655', 12,405', 11,860', 11,480'. 11,400', 11,090', 10.841f.10,630', 10,150',9,790',9,305',9,110',8,601'.8,400',8,000', 7,420' above Lateral Entry Module #2 (LEM), Baker, with seal bore and ZXP packer above. ::;¡ !! '" ""J" ¡.;:." ~t"'§ !t~¡¡ ,., -. ......= = .. =' :: ~ ::;¡ d::!. ,., - ~ ... o '" 1§"~Eõ1' ,.~ ~ '<it'\"$I ""'" ""'" W \"$I 1fi;öEõ'? \21 '@I 1~dr If»' \"$I ~~~!;' W If»' I'.'>. ===~ ~ !N~MW~~f~Wß@ 7.4~~:MP@~~~')'@ #iI : IE-I05 LI: 8-1/2" «8" sand lateral TD 13,529' MD/3,479' TVD 1 Angle 98 07 degrees 0___ I'.'>. ~ ~ po ~~~~~ ~~~ ':'§§ ~ '<it' '<it'W W W 1E-105: 8-112 A2 sand lateral 13,539' MD /3,623' TVD 1 Angle 94.7 degrees ~' ~~ ."~.::;: :-. .....;:,~ :--.~~;:~ "B"Liner, 5-112",15.5#, L80, BTCM, R3 65 jts 'lotted, 63 jts blank, (0.125" x 2.5" slots. 32 per foot. 5.9% open area), 18 constrictors @ 13,260', 12.710', 12.450',12,245',11.890',11,641' 11.045',10,641'.10.400'.9.910'.9.650',9.300', 9.050', 8,700', 8,500', 8,134',7,780',7,610' ~~~t 1:;:;1 '<it' A2 Sahd Liner, 5·Yz", 15.5#, LSD, STCM, Ry.'/z slotted and Yz blank, constrictors for Χolation ~~~~f W W 1~~~f If»' W ~g!! 0---~ r ~ ØI W W 105 Ll «B" Sand Window @ 7,524 MD /3,583' TVD 79 degrees Lateral Entry Module # I (LEM). Baker, with seal bore and ZXP packer above. Tubing, 4·W! IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. 9-5/8",40#. L-80. BTCM, R3 Csg @ 8.295' MD /3,713' TVD @81.54 degrees TD 12-1/4" hole ~ Seal bore and ZXP packer for A21iner +/- 90' below "'B" window t¥MMMM~k#.~ 7;~)~~riW(~;~~~;ryp ~~ ~~ ,,~ 8'!:: §I~~ ¡;; " ~ :: tdt~~ · , KRU ConocoPhillip$ AI8skat Inc. ruBING (0-7229, 00:4.500, 10:3.985) HANGER (7648-7649, 00:9.625) Perf (8349-13454 ) I ¡ LI.·.· .................<: !¡I I" , ¡ II.'. ........., J ;:~::i) ..1111,:::'" I, ~ ..Tf1 ¡ ]...:::::....':\::,..' ~ :I~: ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ r~ ~ ~ ~ ~ I ~¡~¡¡¡¡¡~ .:.:.:.:.:.:.:.:.;.;.:.:. f:':':':': :::::::::::::::::::::=:: ".. ". ~ ~ ., I ¡;,¡r.... .,,,,J\ ~~_Þ...." ~¡¡¡¡¡¡¡¡~¡¡¡jj¡j¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡~¡ Type: PROD Orig Completion: Annular Fluid: Last W /0: Reference Log: 28' RKB Ref Log Date: Last Tag: TD: 13539 ftKB Last Ta9 Date: Max Hole Angle: 96 deQ @ 8943 Casil1~l..$tr'Îl1g..-.COMMØN..STRINQ$ Description Size CONDUCTOR 20.000 SURFACE 13.375 INTERMEDIATE 9.625 LINER A-SAND 5.500 Top o o o 7619 Bottom 170 3905 8290 13519 1 E-1 05 Angle @ TS: deg @ Angle @ TO: 91 deg @ 13539 Rev Reason: GLV design Last Update: 7/11/2005 TVD 170 2286 3713 3624 Wt 94.00 68.00 40.00 15.50 Grade K-55 L-80 L-80 L-80 TVD 3521 1 nterval 8349 - 13454 3722 - 3625 Thread WELDED BTC BTCM BTCM Thread IBTM Status Ft SPF Date Type Comment 5105 40 6/18/2005 IPERF Slotted Liner, alternating joints of blank/slotted liner for all A-Sand perfs 2.5 x .125 holes, 4 rows/ft St MD TVD Man Man Type V Mfr V Type V OD Latch Mfr 4217 2399 CAMCO KBG-2-1R GLV 2 6713 3383 CAMCO KBG-2-1R OV Othør{Þll@ii,eqUip.,ètc.)·COMMONJEWELRY Depth TVD Type Description 23 23 HANGER VETCO GRAY MCA TOP CONNECTION HANGER 503 503 NIP CAMCO 'DB-6' LANDING NIPPLE 7164 3505 SLEEVE-C BAKER CMU 'DB-6' SLIDING SLEEVE - CLOSED 6/27/05 7211 3517 SEAL BAKER SBE SEAL ASSEMBLY/GBH-22 LOCATOR Other.{Þlug$,..equip.......èt¢.)......D-SANO.I.EM Depth TVD Type 7191 3512 PACKER 7213 3517 SBR 7240 3524 D-SAND LEM 7489 3577 SEAL BAKER SEAL ASSEMBLY Other..~pIÚgs,..eqUiÞ....·.·ètc.)......ß..SAND..I...EM Depth TVD Type 7462 3572 PACKER 7482 3575 SBR 7509 3580 B-SAND LEM 7578 3593 NIP CAMCO 'DB' NIPPLE 7659 3608 SEAL BAKER SEAL ASSEMBLY Othef1Þlug$,eqüìp.,etc.)"A-SANDI...INERJEWELRY Depth TVD Type Description 7619 3601 PACKER HRD ZXP LINER TOP PACKER 7637 3604 NIP 'RS' PACKOFF SEAL NIPPLE 7648 3606 HANGER FLEXLOCK LINER HANGER 7649 3607 SBR CASING SEAL BORE RECEPTACLE 1.0 1.0 Description ZXP 7" LINER TOP PACKER w/HRD PROFILE 190-47 CASING SEAL BORE RECEPTACLE D-SAND LEM w/HOOK HANGERS Description ZXP LINER TOP PACKER w/HRD PROFILE 190-47 CASING SEAL BORE RECEPTACLE B-SAND LEM w/HOOK HANGERS BK BK Port TRO Date Run 0.188 1495 6/29/2005 0.313 0 6/29/2005 Date Note 6/18/2005 8.5" OPEN HOLE BEHIND SLOTTED LINERS 6/18/2005 TREE: VETCOGRAY/Horz/4-1/16"5M TREE CAP CONNECTION: 9" OTIS 6/18/2005 TRI LATERAL WELL w/A-SAND (1E-105), B-SAND (1E-105L1), D-SAND (1E-105L2) LEGS Vlv Cmnt ID 4.500 3.875 3.810 3.880 ID 7.500 4.750 3.688 ì 3.880 ID 7.500 4.750 3.688 3.563 3.880 ID 7.000 7.000 7.000 4.750 . ~ -- -- é)-OS -(X:)(Q òOs-aaì '.)05-00.£$/ \L Q. \.) - \J.:)~'7-\-~\- MECHANICAL INTEGRITY REPORT' '... :_IG RELEJ..S:::: . 'W"ELL NUMBER "c..? ~ 'C \£- \C)S - \OÇL 1- - \0 S-L.:1- ) . I. '-~UD ..,,~_. " .: :- 1J ...... .:.:.. : . OPER & FIELD Cas iDg: ~51« 1Ì:>: \")5\\ . liD.. 3(Q)q TVD j :?BTD: MD TVD Shoe: <6ð-tD èID ~~ \ J TVD i DV: \-J~ MD \..:1N. -!\¡l) :,.. !;..LL DATA _:..:>e= : Shoe: fill TVD; ~".., .:..uI' : HD :'TD ¡ _, \, '.l :-:Joi:-:g: ,r~ Packe:!:" ~\Io\' till TVD; See ë. i: \ d d<1 ~ole Size ana \}..î\~~~ L 1.Q. '"\ S ~~ Perfs to L) c: '\\ '\ \ O~~""' \-.0 \ ~ Ss-š \ dl - ,~~ S'i " :-::SC?.AIEC;'~ INTEGRITY - PART 11 Annulus Press Test: IE IS min ; 30 min COrm::lents: ...- :-ŒCRÞ_1\ìICÞ.2, INTEGRITY - PART /2 , .. JS~ \a~\<-> Cement: Volumes:- Þ-..mt. Liner Csg <0 'S<J':>'"t i DV .\.\J~ 'N\ ~'t;~ (' t \ ~ Ci:ü.i: 701 to cov~ perfs ,;)'S"-' ~'1- <.:>...;)~"f\(\i'~ ~tC...::Jt.\ ......, ~\ ~a\.>.J <.. \..:~\ -'<t roo t c:. Š \)1 ("\ ~ ~ , Iheoretical TOC ~ ~O<I.~ 'f.. ~ '-l <0$50 o...Lc...O~\."'~\o\Ct \0., "Q( 50s),=-) '--\S'7c ~ S . Cement Bo~d Lo~gor No) 'S1(~-oS~~\\\AOGCC File 'lfCS.., . _. . ~~ G.~,"":\;C> ~(~\~-Z0~~ t\~~\t{ CBL =..valuat~on, ::.one ë.DOVe perfs '\'\ \"'\. \; \ -, ". .ù......"',\: \.....-. '"":", ( . \... - "';). . "'...» \ . '- t,\It.S\t4\.., ~\'-"" ~\ =ï "-'U ( ~~~, Prociuction Log: Type Evaluation , ¡ I I CONCLUSIONS: '. ? ar tn, C. Pil.'t <ü ~"C.Q:x: ~ \1~\"- ~\- S jxsù'-;;. \N; \N::~~ \.\ \\ rt..~ · ?ar~ :2: M"L'v-:>\~\<.L\'i" ~~ ~\\\~~~~u:.~~~ .' ~CÐ"~\\~ '\sÐ\~'С~ YD?]/VJ _ . ~., , '( '1{" -0 ":; \E....\OS' i)05..,QC(o - \\)5 '-1- JOs-a(J~ - \05 L~ l1-0S-~<6 C\f\.'l ~ÐL-':;¡""~('..~ ~'l~\\()"~ '"' -\-k ~~. v~ ~ súCS <> o..~~ \ """ \ t:-l a S-. ~<t ~ \. ç~\. \.(¿ iTQ 9J'11 ~('rv s- RE: West Sak lE-I05 on injection with defea.p " Tom, There has been no injection into this well prior to today. Thanks, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, September 06, 2005 4:21 PM To: NSK West Sak Prod Engr Subject: Re: West Sak 1E-105 on injection with defeated LPP Thanks Pete. Had there been any injection into the well?? Since this is a baseline, likely not. I will look forward to seeing the follow-up. Tom Maunder, PE AOGCC NSK West Sak Prod Engr wrote, On 9/6/20053:58 PM: Tom, This email is to notify the AOGCC that 1E-105, a West Sak pre-produced injector, has been placed on injection 9/6/05. Per your request a base line temperature log has be run and is attached and a second temperature log is planned in 1-2 weeks to confirm isolation. «1E-105 Combined Press_Temp .zip» This email is also notifying the AOGCC that the LPP was defeated in accordance with AOGCC Rule Amendment No. C0406B.001 dated 6/14/05. The LPP has been tagged and recorded in the facility safety defeat log. The well is injecting 1600 bwpd at 300 psi. Thanks, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 9/7/2005 8:32 AM RE: 10-403 Sundry Applications; WelllE-1.5Ll, 105L2 ~ Tom, I'll put it on our schedule. Thank you! MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, August 26, 200S 3:1S PM To: Spenceley, Neil Cc: NSK Problem Well Supv Subject: Re: 10-403 Sundry Applications; Well 1E-10S, 10SL1, 10SL2 Neil, I got the report and that is the information I needed. The well appears to have been pressure tested satisfactorily. MJ, After the temperatures get equilibrated, please contact the Inspectors for a witnessed MIT. Tom Maunder, PE AOGCC Spenceley, Neil wrote, On 8/2612005 2:38 PM: Tom, I just faxed you a drillíng report detailing a test of the top ZXP packer and a service report detailing an MITIA on the well. Let me know if you need anything else. Thanks. Neil -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, August 26, 200S 1:S3 PM To: Spenceley, Neil Cc: NSK Prod Engr Tech; Redman, R.Scott; Hunt, Hai L; Schwartz, Guy L Subject: Re: 10-403 Sundry Applications; Well 1E-10S, 10SL1, 10SL2 Neil, I have received the faxed cementing information. On the pressure test information, what I need is the testing done at the end of the well when the tubing was run and packer set. That 10f3 9/7/2005 8:32 AM RE: 10-403 Sundry Applications; wellIE-I.5Ll, 105L2 ... would have occurred on the end of "L2". Based on the information in the operations report and my review of the USIT log, I concur with the plans you have proposed. I will look for the hard copies of the sundries. Please be aware that I will be out of the office next week. If that doesn't present a problem, I will address the sundries when I return. Please advise if this is acceptable. Tom Maunder, PE AOGCC Spenceley, Neil wrote, On 8/2612005 10:39 AM: Tom, As per our discussion today mine and Guy Schwartz's opinion of the US IT log is that we have good cement from 7006'-7022' with excellent cement from 7008'-7015', As a result it is likely that there is good isolation between the West Sak 0 sand and the UGNU. In order to confirm this our recommendation is as follows; ,- 1. Run a baseline temperature log prior to injection 2. Place the well in water injection service 3. Run a temperature log and RST log 1-2 weeks following injection to confirm isolation or identify any channeling that may exist Guy Schwartz is tracking down the 407 completion report, the cement report for the 9 5/8" casing and the pressure test information. Please give me a call at 263-4906 if you have any questions. Thanks. Neil -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Friday, August 26, 2005 9:51 AM To: NSK Prod Engr Tech Cc: Redman, R.Scott; Spenceley, Neil; Hunt, Hai L Subject: Re: 10-403 Sundry Applications; Well lE-l05, 105L1, 10SL2 Thanks Bob. I have included my message back to MJ yesterday. Did it get forwarded to Neil or Hai?? Tom Maunder -----Original Message----- From: Thomas Maunder rmailto:tom maunder(á}admin.state.ak.usl Sent: Thursday, August 25, 20053:20 PM To: NSK Problem Well Supv Subject: IE-114, et al MJ, I have pulled the file on IE-I05. I don't have the 407 in my hands yet. I do have the 20f3 9/7/2005 8:32 AM RE: 10-403 Sundry Applications; WelllE-l.5L1, 105L2 .. USIT. If you all are sending in some information, I need the 9-5/8 cementing information and the pressure tests conducted when the packer was set. Also, if Neil or Hai could look at the USIT and let me know their thoughts on the "fluid channel" around where the L2 junction was planned. Thanks, Tom Maunder, PE AOGCC NSK Prod Engr Tech wrote, On 8/26/2005 9:45 AM: Here are the sundry applications (10-403) and schematics for Wsak 1 E-1 05, 1 05L 1, and 105L2. «1 E-1 05%20FINAL %20Schematic.pdf» «1E-10510-403 08-25-05.xls» «1E-105 Schematic.pdf» «1 E-1 05L 1 10-403 08-25-05.xls» «1 E-1 05L 1 Schematic.pdf» «1E-105L210-403 08-25-05.xls» «1E-105L2 Schematic.pdf» Hardcopies are in the mail. Bob Christensen Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) 300 9/7/2005 8:32 AM 8UG-26-2005 12:13 . KUPARUK ... Cono~illips Date A"_j ;µ, ;'0_0 ~. From Name &{.:...~ ..700 G. ~~et. Anchorage, _Alaska 995,~) To NaIM ._7ö~ ~(2.CÑ\.Je.r RecelvlnQ location (BvlldlngIRoom/CI1y) Sublect C~.,H~ reo.,..J.,. ,. .. . ~ ¿'~ ' .,. Page Phone Number 907 265 1300 P.01/07 it~~ Cl:ll~t:.:-....> 'I. .. fIT' j "'D- F~vef~(~j ctr~R_ 4.... ~- "'*,iI< ...........~... . --"i~~_~ .. ,..')tJ of 7 ~(_>-~/?Ob Fa;iNumber (907) Z6S-ttS8 ' ...1*0. 111<1 Phone Number . Fax Numt:>èf ,..iI ~?6 -7Çc..l..{ fi,,... JIE-PO> ,.. ..Il' ',' Note$I'-':1stntçtl.~ns -r . . i1~ I ,-'- - .--- _ . Aift,,.¿) ...... j/. _e~...).~ ~,h yø~~ ÇJ~ c.. /."~1 J;òr... _ . . Æ':/ ..e-- Confidentiality statement This facsimile transmissIon contain$ Information from ConocoFhllljps and Is confidential or privileged. The loforrnatl.on Is Intended to be for the use of tM Individual or entity named above. If you are not the Intend~d recipient, be. awan;~ that any dlsc!c)sure, copying, distribution or use of the contents of thlslnfoJTJ'tatlon Is prohiblted./fYou have receIved this . trSO$mlssfoh In error, pleasE! nòtitYu$ immèdlataly pytelephonaat the number above. Thank you. .... . . . "..:..." ".... " ...." 4-1 '/91 PA, 9-02 - --'-'---'-'''~-'~'''-'.' _..,._,~...._.__._~....,_.. . Form 1811;13-$ 9-0~ . ... -.-.. - ,,- .......-..... . .."........, ,,, _.__.,u._ .·n ,...,.,._.....,_, 8UG-26-2005 12:14 . KUPRRUK ~I . .' .. " . . . . '" '" . . ..' .' ' . . . ,. ConocoPhiHips Alaska Cementing. Report Legal Well Name:1E-105P81 Common Well Name; 1 E-1 05PS 1 Event Name: ROT - DRILLING "'r"\....._."...... , Primary 12.250 (in) 8.290 (ft) 5/11/2005 Intermediate Casing/L.i 9.625 (in.) HOle Si¡¡:e: TMD Set Date Set Csg Type: Csg Size: Report #: Start 2 4/25/2005 .........-...'.. .". . Cèment JobType: . PrimarY . $( uaezeCasinçj Hole Size: TMD Set: Date Set CS9 Type: SQ TMD: SQ Date: Cmtd. Csg; Cementer: Chrstina Coyle SQue~¡¡:~_.Qp.~h Hole Hote Size: SQ TMD: (ft) sa Date; sa Type: Cmtd. Csg: Intermediate Casing/L.i Cmtd. Csg: Cement Co: Dowell Schlumberger Rot Time Start : Ree Time Start:01 :00 Time End: Time End: oa:~o RPM; SPM; Init Torque: (ft-Ibf) Strok~ Length: 8.0 (ft) Avg Torque: (fI.-lbf) Drag Up: 275 (Ibs) Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Ciro Prior To Cementing: 4.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 500 (psi) 907 265 1300 P.02/07 Page 1 of 3 Spud Date: 4/29/2005 Report Date: 5/11/2005 End: 6/20/2005 . ..... . -- ..,.,.,," Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd, Csg: Pipe Movement Reciprocating . . . Pipe Movement .. . . . ..$tag~NO: 1 off Start Mix Cmt: 06:00 Start Slurry Displ: 06:05 Start Displ: 07;20 End Pumping: 08:42 Ënd Pump Date: 5/11/2005 Top PlUg: Y Bottom Plug: Y Type: Non-D¡sp. LS Density: 9.2 (ppg) Vise: 48 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Other Slurry Data Fluid Type: CW 100 Slurry Interval; 4.318.00 (ft)To: Water Sourœ: Test Data Thickening Time: Free Water: (%) Fluid Loss; (ce) Fluid Loss Pressure: (OF) DiSp Avg Rate; Disp Max Rate: Bump Plug; Press Prior: Press Bumped: Press Held: Float Held: 8,00 (bbllmin) 8.00 (bbl/min) y 700 (psi) 1,200 (psi) 3 (min) y MaJl Torqve: (ft-Ibf) Drag Down: 45 (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After; N Mixing Method: Fly Density Meas By; Micromotio ......n...". PVIYP: 14 (cp)/15 (lb/100ft") Gels 10 see: 9 (lb/l00ft2) Gels 10 min: 14 (lb/100ff) Bottom Hole Static Temperature: (OF) Density: 9.0 (ppg) Volume; 621,00 (bbl) lIIIudData .....' , .... . .. . Stage No: 1 Slurry No: 1· of3 Description: CW100 3,600.00 (ft) Cmt Vol: (bbl) Slurry Vol; (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) - Density; 8.30 (ppg) Water Vol; (bbr) Class: Yield; (ft'/sk) Other Vol; 0 Time Compressive Strength 1: Compressive Strength 2: Pl,lrpose; Chemical Was Mix Water; (gal) Foam Job; N Tømp (OF) ("F) Pressure (psi) (psi) .,. . Priri!Qd: 812612005 10:59:41;1 AM h1UG-26-2005 12: 14 -- 4... KUPRRUK , ' . .... .. ConocoPhiHips Alaska' ",' .. .. , .. '," .. . ,: . .' .. . ,. '·Cementing Report, Legal Well Name: 1 E-1 OSP B 1 Common Well Name: 1E-105PB1 Event Name: ROT - DRILLING Slurry Data Fluid Type: Mud Push II Slurry Interval: 5.035,00 (ftJro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (CC) Fluid Loss Pressure: ("F) Slurry Data Fluid Type: TAIL Slurry Interval: 8,290.00 (ft¡To: Water Source: D pit Test Data Thickening Time: Free Water: (%) Fluid I..oss: (ee) Fluid Loss Pressure: (OF) , Trade Nj1¡me D186 D-46 B160 D167 Report. #: Start: 2 4/25/2005 , ' , , ' 'Stage No: '1 Slurry No: 2 of 3 ' - ' Description: MUDPUSH II Class: 4,318.00 (ft) Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft~/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: " ' , , , . , Stage .NO: 1 $Iurry No~ 3, of 3 Description: DeepCrete 5,035.00 (ft) Cmt Vol: 260.5 (bbl) Slurry VoIß50 (sk) 907 265 1300 P.03/07 , Page 2 of 3 Spud Date: 4/29/2005 Report Date: 5/11/2005 End; 6/20/2005 Temp (OF) ("F) Class: Density; 12.40 (ppg) Yield: 2,26 (ft"/sk) Water Vol: 118.2 (bbl) Other Vol: () Temperature: ("F) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: , . . .' , , , . . , .. , , , .'. . .. .' . S~ge No: 1 Slurry No: 3 of 3 - Addìtives·' · Type ACCELERATOR DEFOAMER LOw Temp Dis FL.UID LOSS Concentration ,., Units 0.60 %BWQC 0.60 %SWOC 0.30 %eWOC Temp (OF) (OF) .,-- Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 7.64 (gal) Foam Job: N Pressure (psi) (psi) UQuìdÇonc. Units 0.20 G P S Prin19d: 6/2612005 1 O.s!MS AM 8UG-26-2005 12:14 . KUPRRUK , 907 265 1300 P.04/07 . . . . . . çOnocoPhillips Alaska' Cementing Report .. . ,. . , . . Page 3 of 3 Legal Well Name: 1E-105PB1 Common Well Name: 1E-105PB1 Event Name: ROT - DRILLING Report #: Start: 2 4/25/2005 Spud Date: 4/29/2005 Report Date: 5/11/2005 End: 6/20/2005 Casing Test· Test Press: (psi) For: (min) Cement Found between Shoe and COllar; . Shoe Tëst Liner Top Test ........"...... Pressure: (ppge) Tool; Open Hole: (ft) Hr5 Before Test: Liner Lap; Pos Test: (ppge) Neg Test: (ppge) Hr5 Before Test Cement Found on TOOl; Tool; Tool: . .. .. Log/Survey Evaluation ,', '. ' . . . Interpretation SummarY . --',""...,.,. CBL Run; Under Pressure; (psi) Bond Quality; Cet Run: Bond Quality: Temp Survey; Hrs Prior to Log: Cement Top; (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required; Number of Remedial Squeezes: Remarks Circ and cond mud for cementing, circ at 7 bpm at 500 psi, 5t wt up 255K. dn 82K, initial MW out, 9.2+ ppg, 69 vis, PV 15, YP 30, Conditioned mud to final MW of 9.2 ppg. 48 vis, 15 YP and 14 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while eire. Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3.500 psi. Then pumped 30 add. bbls of CW 100, Pumped 38 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 260.5 bbfs, (650 sxs) of DeepCrete Cmt at 12.4 PPg, 2.26 yield with additives, ave 3.7 bpm at 450 PSi, Reciprocated pipe with fUll returns, shut down, Washed up and dropped top plug. Rig displaced cement with 9.0 ppg OBM. Bumped plug on calc displacement after pumping 621 bbls OBM (96% pump eft.) ave 8 bpm while displacing cmt, Max pressure 1230 psi, Slowed pump rate to 3 bpm (700 psi) with 20 bbls left to pump and bumped plug to 1200 psi, ck floats and held CIP at 08:42 hrs, Reciprocated pipe until 190 bbls amt was around shoe when hole began getting tight and stopped reciprocating. Stopped reciprocating with csg with Shoe @ 8,290', Float Collar @ 8,208'. Calc TOe @ 5,035', Had full returns thru out job. Ptint/!d: B1:¡¡612005 10:59:46 AM ¡:;)UG-26-2005 12: 14 . KUPRRUK ... .' . ..' . , , , .' "" . .. '" ... , CÖrJocoPhillîps AIt:iSka · . . " .. " . "" , .. ... . CømentingRØport .' Legal Well Name: 1E-106PB1 Common Well Name: 1E-105PB1 Event Name: ROT - DRILLING Pril!l;;!.!Y Hole Size: 16.000 (in) TMD Set: 3,905 (ft) Date Set: 5/4/2005 Csg Type: Surface Casing Csg Size: 13.375 (in.) Cmtd. Csg; OPEN HOLE. Cement Co: Dowell Schlumberger ..-,........,. Rot Time Start: : Rec Time Start : Time End: Time End: Type: Cement Casing Volume Excess %: 250.00 Meas. From: 291 Time Circ Prior To Cementing: 5.50 Mud Circ Rate: 400 (gpm) Mud Circ Press: 450 (p$i) Report #; Start: 1 4/25/2005 . ,. . .. , ",. , , ' . "" . '. . .., . , ' , ., CemenfJobType: Primal)'., ' ._..squeeze Casing Hole Siz:e; TMD Set: Date Set: Csg Type: sa TMD: SQ Date: Cmtd. Csg: Cementer: Jerry Culpepper SClü~~¢Operi Hole ' Hole Size: SO TMD: (ft) sa Date: SQ Type: Crntd. Csg: 907 265 1300 P.05/07 Page 1 of 3 - , Spud Date: 4/29/2005 Report Date: 5/4/2005 End: 6/20/2005 Plug HOle Size: Top Set: (ft) aTM set: (ft) Plug Date: Plug Type: Drilled Out Cmtd. CS9: Pipe Movement: Stuck prior cmt .._......~ ... . Pipe Niovemel1t , RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) . Stage, No: 1, on Start Mix Cmt: 12:40 Start Slurry Displ: : Start Displ: 14:59 End Pumping: 16:26 End Pump Date; 5/412005 Top Plug; Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump F'lug: F'ress Prior: Press Bumped: Press Held: Float Held: 7.00 (bblfmin) 7.00 (bbl/min) y 720 (p$i) 1 ,300 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: 100 % Total Mud Lost (bbl) Cmt Vol to Surf: 291.00 (bbl) Ann Flow After: N Mixing Method: Den$íty Meas By: micro "r":" Type: Spud Mud Density: 9.5 (PP9) Vise: 156 (slqt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PVfYP: 32 (cp)/56 (lb/10OftZ) Gels 10 $ElC: 23 (Ib/100ft") Gels 10 min: 37 (lb/100ftZ) Bottom Hole Static Temperature: (OF) Density: 9.4 (ppg) Volume: 549.00 (bbl) Slurry Data Fluid Type: CW100 Slurry Interval: (it) To: (ft) Water Source: Test Data Thickening Time: Free Water: ('Yo) Fluid Loss: (CO) Fluid LO$S Pressure: (OF) '... MudData e'~I" . . .. , . .' "," " , " . . stage No: 1 Slurry No: 10f 4 Description: Cmt Vol; (bbl) Slurry Vol: (sk) Temperature: (o¡:) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol; (bbl) Class: Yield: (ft~/sk) Other Vol: () Time Compressive Strength 1: Compre$$ive Strength 2: .. Purpose: Chemical Was Mix Water: (gal) Foam Job: N Temp (OF) (OF) PreS$I,IJ'e (p$i) (psi) Printed: BI2aI2005 11:00:00 AM RUG-26-2005 12: 14 - ,. KUPARUK . , . . . , ' " ' , COi1óçoPhiHips Âlaska , Cemen~ing Report' Legal Well Name: 1 E-1 05PB1 Common Well Name: 1E-105PB1 Event Name: ROT - DRILLING Slurry Data Fluid Type: MUDPUSH Slurry Interval: (ft) To: (ft) Water Source; Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Report #: Start: 1 4/25/2005 'Stag~ No: fSlurry No:2of4 Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density; 10.50 (ppg) Yield; (ft"/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol; () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Str~m9th 1: Compressive Strengtl'i 2: . . . . ,.., " . . .... . , " Stage No:1 Slurry ¡\Jo: 3 of 4 .'_..... \~,_.... Slurry Data Fluid Type; LEAD Description: ASLite Slurry Interval: (ft) To; 3.105.00 (ft) Cmt Vol: 604.0 (bbl) Water Source: Rig Water Tanks Slurry Vol;762 (sk) Test Oata Thickening Time; 6.00 Fl'Eie Water; (%) Fluid Loss: (CO) Fluid Loss Pressure: (OF) Trade Name ' S1 D-124 0-65 D-53 D-46 D·79 907 265 1300 P.06/07 Page 2of3 Spud Date: 4/29/2005 Report Date: 5/4/2005 End: 6/20/2005 Temp (OF) (OF) Class: Density: 10.70 (ppg) Yield: 4.45 (ft"lsk) Water Vol: 376.0 (bbl) Other Vol; () Temperature: (OF) Temperature: ('F) Temperature; (OF) Time Compressive Strength 1: Compressive Strength 2: .. . . , . . .' . . .. . Stage No: 1 Slurry Nò:3 ()f 4 ~ AØdith,es .-...... Type...·... ACCELERATOR FILLITE DISP¡;;RSANT GYPSUM DEFOAMER. EXTENDER Conœntl]Jion Units.. . 1.50 %BWQC 50.00 %BWOC 0.5<1 %BWOC 30.00 %BWOC 0.60 %BWOC 1.50 %BWOC . ," . . .. . . , , , .' " ~~ge No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: DeepCrete Slurry Interval: :3,105,00 (ft To: 3,905.00 (ft) Cmt Vol: 93.0 (bbl) Water Source; Rig Water Tanks SlurI)' Vol:212 (sk) Test Data Thickening Time: 4.56 Free Water: (%) Fluid Loss: (co) Fluid LosS Pressure: (OF) Temp (OF) (OF) Purpose: SPACER Mix Water; (gal) FO$m JOb: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 20,72 (gal) Foam Job: N Pressure (psi) (psi) liQUid Co.~9. r Class; Density: 12.00 (ppg) Yield: 2.48 (ft3/Sk) Water Vol: 41.7 (bbl) Other Vol: () Temperature: (OF) TemperatlJre: (OF) Temperature: ("F) Time Compressive Strength 1; Compressive Strength 2: Temp ('F) (OF) Units . Purpose: TAIL Mix Water: 8.27 (gal) Foam JOb; N Pressure (psi) (psi) Printod; 1¡!/26/2005 11 :00:00 AM ~UG-26-2005 12:14 . KUPRRUK ~ 907 265 1300 P.07/07 " .' . . .... .. . . . " .., " ' , ' GonocoPhillipsA.laska , , 'Cementing Report Page 3 of 3 .... Legal Well Name: 1 E-1 05PB1 Common Well Name: 1E~105P81 Event Name: ROT - DRILLING Report #: Start: 1 4/25/2005 Spud Date: 4/29/2005 Report Date: 5/4/2005 End: 6/20/2005 , ' ,,' , ' . . . " . .' . ., .' , . , " , stage 1'016: 1 Slurry No: 4 914 - Additives' .... -..,,". . Ir.aç e Name ' Type ACCELERATOR DEFOAMER DISPERSANT 'Concentration Units 0.15 %8WOC 0.60 %BWOe 0.17 %BWOC Liquid Conc. ,Units 0.25 G P S D·186 D46 B 160 - '., ,$boeTest..' I Pressure: 14.10 (ppge) Tool; N Open Hole: (ft) Hrs Before Test Liner Top Test ' Casing Te5t Test Press: 3,000 (psi) For: 30 (min) Cement FOund between Shoe and CoJl,ar: Y liner Lap: Pas Test: (ppge) Nag Test (ppge) Hrs Before Test: I Cement Foundo.~. Tool: N ToOl: N Tool: N . ' " ' Log/SurVey Evaluation Interpretation SUmmary m.... .,,~ .~-". ..... CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOe Sufficient: N JOb Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: , Remarks "... Cont to circ and cond mud for cementing, circ at 7 bpm at 420 psi, csg stuck @ 3905', initial MW out, 9.7 ppg, 156 vis, PV 3.2, YP 56. Conditioned mud to final MW out of 9.4 ppg. 56 vis. 15 YP and 20 PV. Held PJSM with Dowell, APC \/<lC truck drivers and rig crew on cementing c:sg Wl'lile circ. Dowell pumped 5 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 45 add. bbls of CW 100, Pumped 50 bbls of MudPush at 10.5 ppg, Dropped bim pll,lg then pumped 696 bblS, (798 sxs) of Articset lite cmt at 10.7 ppg. 4.45 yield with additives, ave 7.1 bpm at 220 psi, Follow wIth 97 bbls ( 219 sxs)of DeepCRETE @ 12.0 PPQ . 2.52 yield with additives, ave 7.1 bpm @ 1044 psi, dropped btm plug. Pump 20 water. Rig displaced cement with 9.4 ppg LSND mud, PR 7 bpm, 1140 psi, reduced Rate to 3 bpm @ 5300 stks, PP 720 Bumped plug 63 stks early ,displacement after pumping 550 bbls . Slowed pump rate to 3 bpm with 3 bbls left to pump and bumped plug to 1,300 psi, ck floats and held CIP at 16:35hrs, Reciprocated pipe until 73.0 bbfs cmt was around shoe when hole began getting tight and stopped reciprocating w/ Shoe @ S,157', Float Collar@ 8.026', Calc TOC @ 4.786', Had full returns thru out job. Printed: 6126/2005 11:00:00 AM TOTRL P.07 AUG-27-200S 14:43 41111ÞL1PS RK INC -. 907 263 4486 P.01 ConocÓPhillips Fax Cover Date . Av-;} ~/~.C?O> Page of dÿ þ. Ftom . .. _., Name &d....~ 100 G. Street. Anohorage, Alaska 995Ql ....&. -~ _, - --- \.... I Phone Number ~6 ~_- LI <t C?~ Fax NumbØC' _ . J~~?t265.lIS8 . 'To Name ~""" . ð~cJAJ V-. .".. . Receiving looatÎon (BulfdlngfRoomIClly) Phone Number .....,.. .. Fax Number (X 7 6.':" 7~(..(J... Subject .. C~.,h'J_c_.rep."~ f¡r-.. J€~ÞOC No_te~llnstructlons -r . ~... .' -'. . ... .- -/. /J/A.ck) .--¡J. .·-(;~~'f1 . ~",þ f'dq &1- ~ 1...4J. ;..nr... .u· . n' Æ-~ I... :- , ....... .. ,-r" -,. . .- .,L hq,r<- ..~¿)It '/"'ïØ."'j ß(-t d"'Wi~) PT oF... ~~d~s. ~~t!.;.f-4._:kf' Z'XI'? Wa..s? _ : ..~e+. A 1$0 _ð. ~~~1-'¡fuFkr......~) /VUTJA." ..-- ·-M:! ~ ~ Confidentiality Statement This facsimile transmission contains Information from COl1ocoPhlJlfps and [$ confidential or privileged. Tl1e InformatIon Is intended to be for the use of the Individual or entity named above. If you are not the Intended recipIent. be aware that any disclosure, copying, distribution or use of the oontentsOfthfs Information Is prohibited. If you h.aire received this transmIssIon In error, please notify us immediately by telephone at the number above. Thank you.· . n, . ."'1".... 4w1191 PAt 9...02 Form 1816$..s 9·Q2 ~l~' '~. ~þ t'f;, <ð , ~~ <1J1~.\..· . Q". ~)' ,,. ,\" ;\;~) RUG-26-200S 14:43 4IIFtlÞL1PS RK INC -. 907 263 4486 P.02 Well Sidetrack ¢ .m ~ .".,. -- ConocoPhillips Alaska _ Daily Dril~ªJ!; Re{>or! Network 24 Hrs TMD TVD Prog -, r- Conoc~iUips 10058687 13,.~?O' 3,396' DFS 54 REPT NO. DATE 1 E-105 lE-10SL2 0' 55 -. 6/18/2005 Supervisor Thornton/ Proposed TMD WilS9!l J Lowe 13,614' Pressure Test(s) Rig Name Doyon 141 Qitily Cost $359,270 Type I Date I TMD I TVD I MW I Press I Tot. press I EMW LOT 15/13/200518315'13718'18.9 ppgl650 $9,646,869 psi I 2,368.97 psi 1 12.27 pp~ ... Field Name West 5ç¡k Cumulative Cost Current Status LD DP F/ Derrick While Working on Bridge Crç¡ne Last Safety Meeting 6/18/2005 BOP Tst (Last I Next) 6/11/2005 I 6/25/2005 Event Code 24HR Forecast Rig Accept: 4/26/200S@ 12:00 ~..i.g Relea~~:~4/25/2005 @ 01:30 LD DP F/Derrlck, Move Stack & NU Tree, C/O Hole to Diesel ODR Incident 1st 24 hrs? No Last Survey 6/14/2005 13,530 1$3.62 Last Casing 9.625 (in) @ 7258 Next Casing TMD: INC: Azim: 90.68 o (in) @ 0 . .. . . ,. - -. ..... ........ --.- ..-.. Operations Summary. ... __..... From To Hours Phase Activity Subcode ~::: Trouble ~~:~ D~~~h -.........-... ...........-..... ..,....... POOH with hook hanger 6,328' 70' assembly running tool from 6,328' to 70' POOH LD running tool and 0' çleç¡red rig floor, calc fill on trip out 6S bbls, actual fill 73 bbls 0' RÜ'DoŸon's tubing handling equipment .... .._._.... 0' Held PJSM with rig crew on running of LËM MU "D" sand LEM assembly 312' with ZXP paçker ç¡nd RIH to 312' R.IH with LEM from 312' to 312' 7,250' 7,250' to above hook hanger, st wt UP i73K, dn wt 103K Operation 00:0002:00 2-00 CMPLT3 CASE RUNL P 02:0003:00 1.00 CMPLT3 CASE OTHR P 70' 03:0003:30 0.50 CMPLT3 CMPLTN RURD p 0' 03:3003:45 0.25 CMPLT3 CMPLTN SFTY P 0' .- ,j.. ._, -- .--.. - -...- ",,,- 03;4505:00 1.25 CMPLT3 CMPLTN PULD p 0' 05;0010:00 5.00 CMPLT3 CMPLTN TRIP P 10:0010:15 0.25 CMPLT3 CMPLTN TRIP p 7,250' Oriented LEM and located hook hç¡nger at 7,254' ç¡nd landed same with ZXP packer 7 191' top Clt 7/191' Clnd end of seClls , at 7,493', snapped in & out of hanger 1 time to verify on depth and latching into hook hanger, Rehook and pull test http://partners.conocophillipsalaska.comJdrilling! cgi -bin/reports/daily .asp?wellname= 1 E%... 8/26/2005 8UG-26,-2005 14:44 4111ÞL1PS RK INC ... 907 263 4486 P.03 12:1512:30 0.25 CMPLT3 CMPLTN ,_.u 10K over to verify possitive hook, Set down 30K wt. on h99k assembly. Dropped 1 3/4" phenolic ball and pumped down to seat, pumped down at 4 bprrl at , 350 psi, pressured up to 7,191' 7,191 2,500 psi to set packer, then pressured up to 3,900 psi to release from setting tool, 110 'probl.~ms setting paçker Tested ZXP paCker and 7,191' 7,191' annulus to 1,000 psi for 5 min, good test - ... ~PU out of ZXP packer and set back down with dog sub to 7,191' 7,191' verify packer setting depth and clrc btms up, circ at 285 .9pm at 675 psi 7,191' 7,191' Monitored well-static 7,191' 45' POOH with LEM running tool from 7,191' to 45' -.... . . O' POOH LDLE.[\' .r.-':I~nin9 tool 0' Pulled wear ~.l.Is~~~g 0' RU Doyon's tbg handling equipment and held PJSM Ran 4 1/2" 12.6#, L-80 IBTM tbg with completion assembly 0' 7217' to 7,217', RIH and tagged no- , go at 7,217' tbg measurement, ran a total of 230 jts, 7,106' of 4 1/2" tbg Spaced out completion string, MU Vetco Gray tbg hanger and landed tbg at 7.229', RILDS, landed tbg with open CMU sliding sleeve at 7,164', 7,217' 7,229' btm GLM at 6,713', upper GLM at 4,217' and DB-6 nipple at 504', st wt up 95K, down wt 57K, tested hanger seals to 5,000 psi for 15 min, 900d test¡ inst~lle_~!~S. RD Doyon's tbg handling p 7,229' 7/229' equipment and landing jt, .. ~........__, de¡;¡red rig floor 24 Fin POOH &. LD Hook Hênger Running Tool, MU "D" Lat LEM Assembly &. RIH, Set Same with Top of Hr. ZXP Pkr @ 7,191' &. Tested to 1,000 Psi, POOH &. LD Running Tool, MU 41/2" Completion &. RIH, Sum: Spaced Out &. Landed TbQ. Ha_n~_er!...I3:D Handling Tools CIRC P 10:1511:00 0.75 CMPLT3 CMPLTN 11;0011:15 0.25 CMPLT3 CMPLTN DEQT P 11:1512:15 1.00 CMPLT3 CMPLTN CIRC p OBSV P 12:3015:00 2.50 CMPLT3 CMPLTN TRIP P 15:0015:45 0.75 CMPLT3 CMPLTN 15:4516:00 0.25 CMPLT3 CMPLTN PULD PULL P P 45' 0' 16:0016:30 0.50 CMPLT3 CMPLTN RURD p 0' 16:3022:00 5.50 CMPLT3 CMPLTN RUNT p 22:0023:00 1.00 CMPLT3 CMPLTN RUNT p 23:0000:00 1.00 CMPLT3 ÇMPLTN RURD . .-....'" ".. ...,.- . Mud Data Mud D 't Chk 10:sec;; / 10 WL/HTHP MBT PH Flowline Dril~ing Company Type ens I y TMD FV PV/YPmin /30 min Gels Temp Solids M"I SolidsFree 9.15 13,530' 75 22/7 5/8/10 o L ,",:,6.. 0 0 0 3.1 M-I Solids.~~~e 9.1 13,530' 73 21/6 4/7/8 0/4.4 0 0 0 .... 2.9 .. .._ A_ Bit/ Run Size Manuf. Serial Type No. Bits Jets 1-6 Depth TFA Date In I~O·D-L-B-G-O-R In Start 0.000 http://partners.conocophillipsalaska.com/drilling/cgi-bin/reports/daily .asp ?wellname= 1 E%... 8/26/2005 RUG-26-2005 14:44 ~LIPS RK INC fe 907 263 4486 P.04 8/12. I 4.69 I Baker I Mill I MS I 0-0-0-0-0-0 I In2 1?648' 16/1/200~. O-Qu n. - ~ ~ http://partners.conocophillîpsalaska.comJ drilling/cgi -bin/reports/daily .asp?wellname= 1 E%... 8/26/2005 4111JL1PS AK INC , 907 263 4486 P.05 . . 8UG-2~-2005 14:44 Well Service Report ...... I Well I¡Job ~cope .. ..._._-- -. IlJ~b NJ)mber ... I 11:Ë~105 IID~LLING SUPPORT~Ç~PITAL 110624051113:13 I Date IIDailyWork . ... .~~:_m .JfUnit NUlnber I 1~8f20f200511~~~~ SU:PORT:CAPITAL: SET DL,~Ÿ/ MITIA / PULLII~LINE 765 I Day .IIO~eration Cõmplêtc IISucces~.~u~. IIKeyï~erson _1I~'!.Pervisö¡,·__.J I 0 II .... F~lsem II False . '11 ~~~.-SPAULDING IIFiTZPATRIÇ~__1 IFieÏd AFC# Ilcc# IID~iIY Cost I AccumÇ_~st'-'-'I Signed I WEST SAKII 1005868~_.--' ... I 8593 _J 168266.32 limo ?...__ I .- Init Tbg Press IIFi...~1 T~g ~ress Init I~~·~r Ann IIFinal Inner An.n. ..IIJ_~_¡t Õütéi-Ánn IIFinal Outer ~JJn I I ..m_. 1000 II 800 JC .-. 1000 II 100011_ _ .~_-.": II 0 I Daily Summary ¡Time u.__ O.~OO 08:00 09:00 13:36 14:10 .....,..... 15:47 ---. 16:45 17:54 19:39 ...... - . LOADED CSG WITH 240 BBL INHIBITED SW & DSL. SET DV @ 6713' RKB. MITIA 3000 PSI 30 MIN, GOOD. PULLED 4-1/2" CATCHER. ATTEMPTED PULL WRP, NO SUCCESS, POOR TOOL ACTION. [MIT] IILo.gEl!try __m.. I I WEEKL Y SAFETY MEETING TILL 7:30, HEAD TO OFFICE-T()PÏCK UP PAPE. R I .WORK, HEAD TO LOCATION VIA V-PAD . ... ...... MIRU# 6961 765 TGSM, INSPECTED LOACTION , LRS ON WAY .125" 1.875, RS,QC,5,QC,KJ,5,QC,KJ,LSS,QC.. HANG IN RACK FOR LRS TO PPUMP FLUIDS BEFORE STABING ON .. .., ............._,- - - .--. LRS ARRIVED HOOKINü" Ui>G"ET WITH PAD OP , RAN JUMPER TO NEXT ! WELL LRS PUMPING 100 BBLS DIESEL, 240 BBLS WATER, 125BBLS DIESEL I¡FINISHED PÜMPING FLUÏDES , GREASE CREW STILL NOT HERE , I ATTEMPTING TO BLEED CAP .. .. ,.,."...........-.- ,- - ........ .."...-..- RIH W/4 1/2" OK-I, 1" DMY, TO STA# 2 @ 6711' WLM, LOCATE START TAPPING HA VB LRS PT TO 2000# HOLDING IA @ 500# , SHEAR OFF POOH, HAVE LRS BLEED TUBING TO 500# . ... .... --..-- . .,."......-... , - SWAP TOOLS AND START MIT IA TO 3000# I LOST ONLY 75 LBS AFTER 1ST IMIN, 2ND LOST 50# ( GOOD) ONLY LOST 125# TOTAL ON IA TUBING ST~~X.~D @ 775# , HAVE LRS BLEED LA J?~S~ TO 1 000# RIH WI 41/2" GS TO 2800' TO 3000' WLM, WORKED PAST TO 6730' WLM, LATCH AND PULL C-SUB , CATCHER SUB HAD 1 HARD RUBBER FINGER FROM WRP SETTING RIH W/4 1/2" GS AND 4 1/2" WETHERFORD WRP PULLING TOOL 29" OAL TO 6736' WLM, TAP DOWN NOT HITTING HARD NO BINDS TAP MORE, UNABLE TO KNOCK EQUILIZING SLEEVE OFF SEAT, DUE TO POOR ACTION POOH IrOOH wiioOLS , CALL CWG, SAID DUE TO rÍMi: AND PRIORITY JOB IN ÄM http://anc402/wsr/content/atdbworklog.asp?ID= 1 E 1058202005084641 &Field=KRU 8/26/2005 ,AUG-46-2005 14:44 4111ÞLLIPS AK INC , 907 263 4486 P.06 20:30 Ilro RD AND WILLCOME BAC!<- TO AFTER .c.._ _ I IIPJSM. -~ RDMO TO YARD... HEAD TO 0.. FFICE TO DOWN LOAD, TELL PAD. OP I TO~EA VE SHUT ~ . . n. ._. ... IIENDËDTICKET '.. J 21:00 .. . rS~rvice ëompa~y - Sen'ice HALLIBURTON SERVICES - SLIÇKLINE !LITTLE RED SERVIC~S - PUM~.~G .___m IPHÏLÙPS F;LUIDS - DIESEL Reco~erable ITota~_~Jeld Esti~ate IIDaily Cost ....IIAccum Total ....JI ····4,475.5011...._- II 3?105.0olf"oo .. mIl 1,012.5011" If 8,593.0011 _.. .. I ?I ?I ?I ?I I¡:~~~.~~x. __ 11;~5 138L8 DIE8E~ 2~~B~LS INHIBITED SE~_::V A TER· . II http://anc402/wsr/content/atdbworklog.asp?ID=1 E 1058202005084641 &Field-- KRU 8/26/2005 TOTRL P.06 e . Randy Thomas Kuparuk Drilling Team Leader Drìllíng & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 21,2005 RECEIVED JUL 2 3 2007 Commissioner Sfate of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Maska ,,\~ Gas Cons, Commission Anchorage Subject: Well Completion Reports for 1 E-1 OS, 1 E-1 05L 1 and 1 E-1 05L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells1E-105, 1E-105L 1, 1 E-105L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Si~ M.re.'~i . ..... . ¿JI/l{~ J/R 7i/ÒfflQS R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad () ~ l <t .1 ...1 ~ f. ...: wi' b j... I\. "'1 ~ ~J .\..ð-t) r ~l"lhe...'.¡I tel',:? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION \K3 Ü¡¡ & Gas Cons. CommÎssìoft WELL COMPLETION OR RECOMPLETION REPORT AND LrQGge Oil 0 Gas U Plugged 0 Abandoned 0 Suspended 0 WAG 0 20AAC 25.105 20AAC 25.110 1a. Well Status: GINJ 0 2. Operator Name: o WDSPL 0 WINJ ConocoPhillips Alaska, Inc. 3. Address: e e No. of Completions _ Other ~XX Pre-produced Injector 5. Date Comp., Susp., or Aband.: June 20, 2005 6. Date Spudded: April 29, 2005 7. Date TD Reached: May 16, 2005 8. KB Elevation (ft): 28' RKB 9. Plug Back Depth (MD + ND): 8209' MD / 3699' TVD 10. Total Depth (MD + ND): 13539' MD /3624' TVD P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): purface: 391' FSL, 224' FEL, Sec. 16, T11 N, R10E, UM At Top Productive Horizon: Total Depth: 1385' FNL, 325' FEL, Sec. 22, T11N, R10E, UM 1338' FNL, 345' FEL, Sec. 27~ T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550300 y- TPI: x- 555495 y- Total Depth: x- 555519 y- 18. Directional Survey: Yes [2] NoU 21. Logs Run: GRlRes 22. CASING SIZE WT. PER FT. 62.58# 68# 40# 15.5# GRADE H-40 L-80 L-80 L-80 20" 13.375" 9.625" 5.5" 5959981 5958241 5953009 Zone- 4 Zone- 4 Zone- 4 11. Depth where SSSV set: n/a 19. Water Depth, if Offshore: N/A feet MSL CASING, LINER AND CEMENTING RECORD SETIING DEPTH MD SETTING DEPTH ND TOP BOTTOM TOP BOTTOM 28' 108' . 28' 108' 28' 3905' 28' 2285' 28' 8290' 28' 3712' 7619' 13519' 3595' 3624' 23. Perforations open to Production (MD + ND of Top and Bottom Interval, Size and Number; if none, state "none"): slots in liner from 8312'-13454' MD 40 slotslft 26. Date First Production July 12, 2005 Date of Test Hours Tested 7/13/2005 Flow Tubing press. 464 psi 27. 14 hours Casing Pressure 1204 24. SIZE 4.5" F<ECt::IVt:J)' JUL 2 3 Z007 1 b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 205-006 13. API Number: 50-029-23243-00 14. Well Name and Number: 1 E-1 05 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ALK 25651/25660 17. Land Use Permit: ADL 469/470 20. Thickness of Permafrost: 4195' MD HOLE SIZE 30" AMOUNT PULLED CEMENTING RECORD 16" 225 sx AS I xx sx AS Lite, xx sx DeepCrete 650 sx DeepCrete slotted liner 12.25" 8.5" TUBING RECORD DEPTH SET (MD) 7229' , . PACKER SET 7619' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST Method of Operation (Flowing, gas lift. etc.) Pre-produced Injector Production for OIL-BBL GAS-MCF 561 631 OIL-BBL GAS-MCF WATER-BBL Test Period --:> Calculated 6 WATER-BBL 24-Hour Rate .> 927 1104 CORE DATA 11 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". Form 10-407 Revised 1212003 NONE CONTINUED ON REVERSE CHOKE SIZE 53 Bean OIL GRAVITY -API (corr) not available GAS-OIL RATIO 1191 lVN191~O 0,..-,.'..., ~c.c.,~", t>o.1-... A\lJ,t.1,10US- R.e () k.u. ........~ tò~ '\ 28. - 29. e GEOLOGIC MARKERS FORMATION TESTS 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 05 West Sak A 8299' 3715' N/A 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 Date 7;?//oS- Printed Nam~ Rand 1" h omas Signature . . V" _ . . r '{.Ø2Q-/ Title: Phone Kuparuk Drillinq Team Leader -r! I? 1Zrr/1AC5 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. Prepared by Sharon Allsup-Drake INSTRUCTIONS 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 e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 4/25/2005 12:00 - 15:00 3.00 MOVE DMOB MOVE 15:00 - 00:00 9.00 MOVE MOVE MOVE 4/26/2005 00:00 - 08:00 8.00 MOVE MOVE MOVE 08:00 - 12:00 4.00 MOVE MOVE MOVE 12:00 - 00:00 12.00 MOVE MOVE MOVE 4/27/2005 00:00 - 12:30 12.50 MOVE MOVE MOVE 12:30 - 00:00 11.50 MOVE POSN MOVE 4/28/2005 00:00 - 12:00 12.00 MOVE RURD RIGUP 12:00 - 00:00 12.00 MOVE RURD RIGUP 4/29/2005 00:00 - 05:45 05:45 - 06:30 5.75 DRILL PULD SURFAC 0.75 WELCTL BOPE SURFAC 06:30 - 08:30 2.00 DRILL PULD SURFAC 08:30 - 09:30 1.00 DRILL SFTY SURFAC 09:30 - 11 :30 2.00 DRILL PULD SURFAC 11 :30 - 12:00 0.50 DRILL OTHR SURFAC 12:00 - 13:30 1.50 DRILL REAM SURFAC 13:30 -14:15 0.75 DRILL CIRC SURFAC 14:15 -16:00 1.75 DRILL REAM SURFAC Disconnected boiler, motor, pump and pit complex's and prepared same for move Moved rig off Kokoda 5 and began moving boiler, motor, pump and pit complex's to 2M pad, as of 24:00 hrs were at Alpine turn-off, worked on other complex's on Kokoda 5 preparing them for move Peak continue moving boiler, motors, pumps and pit modules to 2M pad. Arrived 2M @ 0500 hrs. Peak sows return to Kokoda for next group. Preparing modules on Kokoda #5 location f/ move to 1 E-1 05. Check and fuel. Prep pad f/ move. Load counter weights on two Peak Sows f/ moving subbase. Load rockwasher on peak trailer. Hook two sows to subbase and move off well @ 1100 hrs. Clean up well area. Load two pipe shed halves. Peak moving sub, rockwasher and 2 pipe shed halves f/ Kokoda #5 towards Kuparuk. At midnight leaving midway camp which is 26 miles f/ Kokoda #5. Peak moving sub, rockwasher and 2 pipe shed halves f/ Kokoda #5 towards Kuparuk. At midnight leaving midway camp which is 26 miles f/ Kokoda #5. Arrived @ Alpine cutoff @ 0500 hrs. Arrive 2L pad @ 0830 hrs. Change up some loads @ 2m pad. Continue to 1 E pad. Arrived @ pad @ 1230 hrs. Spot sub over 1E-105. Spot Pits, pumps, motors. Return with Sows to 2M pad. Leave 2M pad @ 1800 hrs w/ 2 pipe sheds, rock washer and boiler module. Sows leaving 1 E pad to return to Kokoda 5 @ 2100 hrs. Estimated to arrive @ 0100 hrs 4/28/05 to get camp modules. APC Crane set Sperry Sun shack on top of pit module @ 1800 hrs. Vetco gray work w/ crew on change out of upper and lower "0" ring seal on diverter adapter @ 1800 hrs test to 300 psi f/1 0 min.,. Crew rigging up modules, unloading trucks. Change out saver sub, tighten grabbers, service top drive. Slip and cut 38' of drilling line, adjust brakes, rig up interconnects. Prep pits, start taking on water @ 0800 hrs and start mixing spud mud. NU Diverter @ 0900 hrs. Unloading trucks. Prep f/ camp placement on 1 E pad. Rig on highline @ 09:00 hrs. Accept rig @ 12:00 hrs. Continue mixing spud mud. Camp arrived @ 1600 hrs. Camp and shop set by 18:00 hrs. Camp on highline @ 18:00 hrs. Set pipe sheds and rock washer, berm up around rockwasher. Loading dp into pipe shed. PU mousehole. Prep f/ PU of pipe and BHA. PU/MU 5" drill pipe, stand back in derrick 37 stands. Function test diverter system. Witness of test waived by AOGCC inspector Chuck Scheve. Initial pressure 2950 psi, after closing 1800 psi. Nitrogen bottles (5) avg 2325 psi. 200 psi buildup req 37 second, full charge 3 min 1 sec. (25 seconds to close annular.) Continue PUlMU 5" drill pipe, stand back in derrick 9 stands. Total of 46 stands of 5" dp. PU/MU 10 stands 5" HWDP w/ jars. PRE spud meeting w/ Rig Engineer Mike Greener, both crews attended, and third party team members. MU 16" BHA #1 to drill out conductor and drill to 263'. Fill conductor, check f/leaks. Pressure test mud line to 3000 psi. No leaks. Ream and clean out 20" conductor f/31' to 97'. 450 gpm @ 275 psi. Circ to shear mud. Ream and clean out conductor f/97' to 170'. 450 gpm @ 275 psi. PU wt 47K, SO wt 54K, Rot wt 49k Printed: 71612005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 4/29/2005 16:00 - 18:30 2.50 DRILL DRLG SURFAC Drlg 16" hole f/ base of conductor @ 170' to 263'. PU wt 51k, SO wt 54k, Rot wt 54K, ADT 1.77 hrs 18:30 - 19:00 0.50 DRILL SURV SURFAC Halliburton wireline gyro. Gyro @ 100' and 200'. 19:00 - 21 :30 2.50 DRILL TRIP SURFAC POOH to change BHA. 21 :30 - 00:00 2.50 DRILL PULD SURFAC Pickup/MU BHA #2. 4/30/2005 00:00 - 00:30 0.50 DRILL RIRD SURFAC RU Halliburton WL in derrick f/ gyro. 00:30 - 00:45 0.25 DRILL TRIP SURFAC RIH w/ BHA to 263' 00:45 - 01 :00 0.25 DRILL SURV SURFAC Run gyro @ 260' 01 :00 - 02:30 1.50 DRILL DRLG SURFAC Drilled 16" hole from 263' to 351' MD/351' TVD (88') ART .77 hrs, AST .32 hrs, 0-2K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1025 psi, rot wt 59K, up wt 56K, dn wt 60K. 02:30 - 03:15 0.75 DRILL SURV SURFAC Run gyro @ 351'. Ran survey twice. 03:15 - 04:30 1.25 DRILL DRLG SURFAC Drilled 16" hole from 351' to 441' MD/440'TVD (90') ART .6 hrs,AST .58 hrs, 2-5K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1200 psi, on bottom torque 1-2k ftIlb, rot wt 60K, up wt 60K, dn wt 62K. 04:30 - 05:00 0.50 DRILL SURV SURFAC Run gyro @441'. 05:00 - 06:15 1.25 DRILL DRLG SURFAC Drilled 16" hole from 441' to 531' MD/530' TVD (90') ART .43 hrs, AST .48 hrs, 2-8K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1225 psi, on bottom torque 1-2k ftIlb, rot wt 65K, up wt 66K, dn wt 67K. 06: 15 - 06:30 0.25 DRILL SURV SURFAC Run gyro @ 531'. 06:30 - 07:45 1.25 DRILL DRLG SURFAC Drilled 16" hole from 531' to 626' MD/625' TVD (95') ART .45 hrs, AST .56 hrs, 8-1 OK wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1225 psi, on bottom torque 2k ftIlb, rot wt 69K, up wt 69K, dn wt 70K. 07:45 . 08:30 0.75 DRILL SURV SURFAC Run gyro @ 626'. Ran survey twice. Still no picture. 08:30 - 10:00 1.50 DRILL DRLG SURFAC Drilled 16" hole from 626' to 718' MD/715' TVD (92') ART .36 hrs, AST .85 hrs, 8-12K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1300 psi, on bottom torque 2-4k ftIlb, rot wt 74K, up wt 73K, dn wt 75K. 10:00 - 10:45 0.75 DRILL SURV SURFAC Run gyro @ 718', and 626'. 10:45 - 12:00 1.25 DRILL DRLG SURFAC Drilled 16" hole from 718' to 781' MD/776' TVD (63') ART .0 hrs, AST 1.01 hrs, 23K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure 1400 psi, on bottom torque 2-4k ftIlb, rot wt 82K, up wt 82K, dn wt 81K. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 781' to 1553' MD/1411.56' TVD (772') ART .41 hrs, AST 8.82 hrs, 1 0-40K wob, 60 rpm's, 500 gpm, 9.0-9.2ppg mw, on btm pressure 1400-1600 psi, on bottom torque 2-6k ftIlb, rot wt 82-88K, up wt 82-93K, dn wt 81-85K. 5/1/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 1553' to 2328' MD/1734.99' TVD (775') ART 2.19 hrs, AST 6.28 hrs, 1 0-40K wob, 60 rpm's, 500-554 gpm, 9.2-9.3ppg mw, on btm pressure 1600-1900 psi, on bottom torque 5-11 k ftIlb, off bottom torque 4-9k ftIlb, rot wt 80-87K, up wt 93-102K, dn wt 84-70K. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 2328' to 3174' MD/2024.2' TVD (846') ART 4.71 hrs, AST 3.63 hrs, 1 0-40K wob, 60 rpm's, 554-613 gpm, 9.3-9.4ppg mw, on btm pressure 1900-2250 psi, on bottom torque 5-11 k ftIlb, off bottom torque 4-9k ftIlb, rot wt 80-83K, up wt 95-100K, dn wt 68-70K. 5/2/2005 00:00 - 07:00 7.00 DRILL DRLG SURFAC Drilled 16" hole from 3174' to 3607' MD/2176' TVD (433') ART 2.86 hrs, AST 2.44 hrs, 1 0-25K wob, 60 rpm's,613 gpm, 9.3-9.4ppg mw, on btm pressure 2300 psi, on bottom torque 7-11 k ftIlb, off bottom torque 5-9k ftIlb, rot wt 83-79K, up wt 1 00-115K, dn wt 70-62K. 07:00 - 08:00 1.00 DRILL CIRC SURFAC Circ at reduced rate (70 spm/900 psi), change shaker screens on all three shakers f/140's to 11 O's. 08:00 - 08:45 0.75 DRILL DRLG SURFAC Drilled 16" hole from 3607' to 3631' MD/2184.95' TVD (24') ART .38 hrs, AST 0.0 hrs, 1 0-25K wob, 60 rpm's, 613 gpm, 9.4ppg mw, on btm pressure 2350 psi, on bottom torque 1 Ok ftIlb, off bottom torque 9k ftIlb, rot wt 79K, up wt 115K, dn wt 62K. Printed: 7/612005 3:50:05 PM e e \ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/2/2005 08:45 - 09:15 09:15 -12:00 12:00 - 23:00 23:00 - 23:15 23:15 - 00:00 5/3/2005 00:00 - 01:15 01:15-01:30 01 :30 - 01 :45 01 :45 - 06:00 06:00 - 06:15 06:15 - 08:00 08:00 - 08:30 08:30 - 08:45 08:45 - 09:00 09:00 - 10:30 10:30 -12:45 12:45 - 13:45 13:45 -15:15 15:15 - 15:45 15:45 - 21:45 0.50 DRILL CIRC SURFAC Circ at reduced rate (75 spm/950 psi), change shaker screens on all three shakers f/11 O's to 84's. 2.75 DRILL DRLG SURFAC Drilled 16" hole from 3631' to 3748' MD/2228. 7' TVD (117') ART .88 hrs, AST 0.0 hrs, 1 0-25K wob, 60 rpm's, 613 gpm, 9.4ppg mw, on btm pressure 2300 psi, on bottom torque 10k ftllb, off bottom torque 5-9k ftllb, rot wt 85K, up wt 112-115K, dn wt 74-70K. 11.00 DRILL DRLG SURFAC Drilled 16" hole from 3748' to 4,395' MD/2,458.09' TVD (647') ART 3.99 hrs, AST 3.41 hrs, 0-28K wob, 60 rpm's, 613 gpm, 9.3-9.4ppg mw, on btm pressure 2300-2325 psi, on bottom torque 9-1 Ok ftllb, off bottom torque 8-10kftllb, rotwt 85-91K; up wt 112-131K, dn wt 70-64K. While drilling at 4,365' MD /2,447' TVD encounted gas. Gas was 249 units max. Monitored well. Took final surveys. Circulate to POOH. POOH and prepare to backream. Circulate bottoms up @ 4368' w/613 gpm /2300 psi. Rotate and recip. PU wt 132K, SO wt 65k, torque 9-12k. Max gas 70 units. SURFAC Monitor well. OK. SURFAC MU stand in derrick. RIH 27' to tag bottom @ 4395' with out pumps. Pump out to 4368'. 4.25 DRILL REAM SURFAC Backream out of hole f/4368' to 2574'. Lots of clay and sand while reaming @ 2574' @ shakers. Reduce pump rate f/613gpm/2250 psi to 338 gpm/1 OOOpsi. 60 rpm. Continue back reaming, pulling slow to 2296'. 0.25 DRILL OTHR SURFAC Change out shaker screens on # 2 shaker. 1.75 DRILL REAM SURFAC Continue to backream f/2296' to 1493' w/338pgm /1000 psi, 60 rpm. Change out shaker screens on #1 and #2 shaker. Backream out f/1493' to 1089' w/338 gpm /1000 psi, 60 rpm. Monitor well. Static. Attempt to pull out of hole on elevators. Hole swabbing. Backream out f/1 089' to 734' w/ 338gpm/1 000 psi, 60 rpm. Pump out f/ 734' to 170' w/296 gpm/600 psi. UD BHA #2. Clear rig floor. RU to run 13318" 68 Ib/ft,L-80, BTC. PJSM on running casing. Run 13 3/8" casing. Weatherford float shoe, 2 jts 13 318" 68#/ft L-80 BTC, weatherford float collar, check troats on jt #3, continue to run casing. First 3 joints have weatherford bow spring centralizers over stops 10' f/ pin end. First 3 joints were bakerlocked. Next 14 joints have centralizers over box. Total of 17 centralizers. Running out of down wt @ 2565'. Wash casing in hole w/ Frank's fillup tool. Wash f/2565' to 2804'. 5bpm w/ 350 psi. 6 bpm wI 400 psi. PU wt 185k, SO wt 65K. 21.5 bbls behind calc displacement @ 2804' Wash casing in hole w/ Frank's fillup tool. Wash f/2804' to 3905'. 21 Obpm w/350 psi. 6 bpm w/ 400 psi. PU wt 185k, SO wt 65K. 133/8" 68 #/ft L-80 BTC casing stuck @ 3905', Attempt to free casing while circulating wI Frank's fillup tool w/ 360 gpm /680 psi. Pull max 450k. Toolpusher attempted to push with a little top drive weight. No go. Circ and condition mud. 1.25 CASE OTHR SURFAC UD jt # 93. UD Frank's fillup tool. Blow down top drie. 1.25 CEMENT PULD SURFAC Clear rig floor. PUlMU 10' pup jt, 13318" 68#/ft L-80 BTC. MU Dowell cement head, and rig up equipment. 0.25 DRILL CIRC 0.75 DRILL TRIP 1.25 DRILL CIRC 0.25 DRILL OBSV 0.25 DRILL TRIP 0.50 DRILL 0.25 DRILL 0.25 DRILL 1.50 DRILL REAM OBSV TRIP REAM SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC . SURFAC SURFAC SURFAC SURFAC SURFAC 21 :45 - 00:00 2.25 CASE RUNC SURFAC 5/4/2005 00:00 - 02:45 2.75 CASE RUNC SURFAC 02:45 - 09:30 6.75 CASE OTHR SURFAC 09:30 - 10:45 10:45 - 12:00 2.25 DRILL 1.00 DRILL 1.50 CASE 0.50 CASE 6.00 CASE PULD OTHR RURD SFTY RUNC Printed: 7/6/2005 3:50:05 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E~ 105 ROT- DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/4/2005 12:00 - 12:45 12:45 - 15:00 15:00 -16:30 16:30 - 17:00 17:00 - 18:30 18:30 -21:30 21 :30 - 23:00 5/5/2005 23:00 - 00:00 00:00 - 02:00 0.75 CEMENTCIRC SURFAC Continue circ and condition mud and hole @315 gpm w/450 psi. Final MW 9.3+, PV20, YP 15,10 sec gel 2, 10 min gel 3. PJSMw/ creww/ continuing to circ. 2.25 CEMENT PUMP SURFAC Turn over to Dowell. Dowell pump 5 bbls water, test lines to 3500 psi. pump 50 bbls CW100 @ 8.34 ppg, follow w/50 bbls Mudpush w/ red dye @ 10.5 pþg, drop bottom plug, mix and pump 604 bbls (762sx) lead cement ASlite 10.7ppg @ 7bpm, mix and pump 94 bbls (214sx) tail cement DeepCrete 12.0 ppg @ 7bpm, drop top plug, follow w/20 bbls water. Turn over to rig to finish displacement. 1.50 CEMENT DlSP SURFAC Rig displace cement w/9.3+ ppg mud @ 7 bpm. Mudpush wi red dye observed @ shakers w/1270 stokes pumped, 10.8 ppg lead cement observed @ shakers w/2600 stokes pumped, slow pumps to 3 bpm @ 5300 strokes pumped, bump plug @ 5449 strokes (calculated 5512 strokes). Final pumping pressure 720 psi, bumped plug w/1300 psi. CIP 1635 hrs 5/4/2005. Hold f/5 min., bleed off to check floats. Floats holding. Calculated 291 bbls 10.8 ppg cement circ to surface. 0.50 CEMENTOTHR SURFAC Flush stack, RID Dowell cement head. 1.50 CASE NUND SURFAC Nipple down 16" diverter line. PU .21 1/4" diverter. 3.00 CASE OTHR SURFAC PU 13 3/8" casing to 305 k on weight indicator. Install Vetco Gray emergency slips. Slack off to block weight of 35 K. Calculated weight of casing in mud 226k. 1.50 WELCTL OTHR SURFAC Make hole in casing at +1' above starting head to drain jt #92. Make rough cut @ 1.04' above starting head. Pull remainder of jt # 92 out of hole, removed 31.10'. 1.00 WELCTL OTHR SURFAC Set diverter down. N/D 21 1/4" diverter. 2.00 WELCTL NUND SURFAC Continue N/D 21 1/4" diverter. Welder making final cut @ 71/4" above casing slips. Welder start welding on Vetco/Gray Socket weld x Threaded flange adapter. PIN H109976-3 Rev N/C H/N C8278 Bore 12.56" UD 13 318" casing equipment f/ rig floor. Change out bales, service top drive. Welder continue welding on head. PJSM on PU 5" dp f/ pipe shed. RU mouse hole and iron roughneck track. Welder continue welding on head. PU 5" dp f/ pipe shed, stand back in derrick. Welder finished welding head @ 0445 hrs. Continue PU 5" dp f/ pipe shed, rabbit to 2.90", stand back in derrick. Wrap head w/ insulation, let cool slowly. PU total of 39 stands f/ pipe shed. Clear rig floor. PU smaller pieces of BHA #3 to rig floor. Test welds on Vetco/Gray Socket weld x threaded flange adapter to 1800 psi. Found 3 leaks in welds. Welder reweld on Vetco/Gray Socket weld x threaded flange adapter. Pressure test weld to 1800 psi f/1 0 min. OK. Screw on flange to Vetco Gray adapter, NU Vetco/Gray Multibowl. NU 13518" BOPE. Test BOPE. Witness of test by AOGCC inspector John Crisp. Test annular to 250 psi low f/ 5 min., test to 3500 psi high f/5 min. Test all other componets including choke manifold and floor safety valves and dart valve to 250 psi low f/ 5 min and 5000 psi high f/5 min. Test accumulator. 02:00 - 03:45 1.75 CASE OTHR SURFAC 03:45 - 04:15 0.50 DRILL SFTY SURFAC 04: 15 - 04:45 0.50 DRILL PULD SURFAC 04:45 - 08:30 3.75 DRILL PULD SURFAC 08:30 - 10:30 2.00 DRILL OTHR SURFAC 10:30 -11:00 0.50 WELCTL OTHR SURFAC 11:00 -12:15 1.25 WELCTL OTHR SURFAC 12:15 - 12:30 0.25 WELCTL OTHR SURFAC 12:30 - 16:00 3.50 WELCTL NUND SURFAC 16:00 - 20:45 4.75 WELCTL BOPE SURFAC Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/5/2005 20:45 - 21 :30 0.75 WELCTL OTHR SURFAC Rig down test equipment. Install wear bushing (12 5/16'l 21 :30 - 00:00 2.50 DRILL PULD SURFAC MU BHA #3 (12 1/4" bit). upload MWD. 5/6/2005 Note: During pre tour meeting 22:30 hrs 5/4/2005, crew discussed picking up more drill pipe f/ pipe shed to stand back in derrick and to still to keep track of Doyon 15's 5" dp( stands which avg's about 2' longer than Doyon 14}. By the dicscussion it was determined that we had not drilled to the total depth of 4422' (2474' TVD). After adjusting pipe tally, TD drilled too was 4395' (2458'TVD). All previous DIMS reports f/ 4/29/2005 through 5/5/2005 have been corrected, surveys have been corrected. 00:00 - 00:30 0.50 DRILL OTHR SURFAC RIH one stand of flex collars and one stand of 5" HWDP to 260'. Strapping dp in hole. 00:30 - 00:45 0.25 DRILL OTHR SURFAC Shallow test MWD. Too much pump noise. Not a good test. 00:45 - 01 :30 0.75 DRILL TRIP SURFAC RIH to 910'. SLM on dp. 01 :30 - 01 :45 0.25 DRILL OTHR SURFAC Shallow test MWD. 132 strokes per minute (558 gpm), 1150 psi. All is good. 01:45-03:15 1.50 DRILL TRIP SURFAC RIH f/910' to 378ß'. SLM on DP. No correctiön. 03:15 - 03:30 0.25 DRILL REAM SURFAC Break circ @ 5bpm (210 gpm) w/500 psi. Wash f/3786' to 3814'. Tag float collar. PU wt 12ok, SO wt 60k. 03:30 - 04:30 1.00 DRILL CIRC SURFAC Circulate bottoms up after tagging plugs on top of float collar. Circ @ 65 spm (275 gpm) w/600 psi. 04:30 - 05:30 1.00 DRILL CIRC SURFAC Pull and set back a stand. RU testing equipment. Continue circ and condition mud @ 65 spm (275 gpm) w/600 psi. Circulating through 2" high pressure line. Circ totàl of 732 bbls. MW 9.1 +, 10 min gel 40, YP 21. 05:30 - 07:00 1.50 CASE DEQT SURFAC Test 133/8" 68#/ft, L-80, BTC casing. FC @ 3818' MD/2254' TVD. Test w/ 9.1 + ppg MW. Apply 3025 psi, hold f/30 min, chart test. No bleed off. Good test. 07:00 - 07:15 0.25 DRILL OTHR SURFAC Rig down test equipment. 07:15 - 08:45 1.50 DRILL REAM SURFAC Drill out (2) cement wiper plugs, Float collar @ 3818', cement, Float shoe @ 3905'. 08:45 - 10:45 2.00 DRILL REAM SURFAC Ream 16" hole below shoe f/3905' to 4072' MD. Appears to have sidetracked 16" hole @ 4027' MDI 2332.07' TVD. 10:45 -12:00 1.25 DRILL CfRC SURFAC Circulate bottoms up @ 4072'. Pumping 600 gpm w/1800psi. 12:00 - 12:45 0.75 DRILL LOT SURFAC POOH 2 stands f/4072' to 3886' inside of 13318" casing shoe. RU/ Perform LOT using 9.1 ppg mud. RID testing equipment. 12:45 - 13:00 0.25 DRILL TRIP INTRM1 RIH f/3886' to 4072'. 13:00 -19:15 6.25 DRILL DRLG INTRM1 Drilled 121/4" hole from 4072' to 4,722' MD/2591' TVD (650') ART 1.73 hrs, AST 2.96 hrs, 2-22K wob, 60-80 rpm's, 550-655 gpm, 9.1 ppg mw, on btm pressure 1600-2100 psi, on bottom torque 6-9k ftIlb, off bottom torque 8-9k ftIlb, rot wt 89-95K, up wt 11 0-127K, dn wt 64-75K, max gas units of 350 while drilling @ 4280' 19:15 -19:30 0.25 DRILL CIRC INTRM1 Circ prior to short trip. Circulate @ 600 gpm w/180o psi. 19:30 - 21 :00 1.50 DRILL TRIP INTRM1 Pump out of hole 7 stands f/4722' to 3885' (13 318" shoe @ 3905' MD/ 2285' TVD). Orient to high side prior to pulling out. Pumping 600 gpm wI 1800 psi. PU wt 1 05k. 21 :00 - 21 :45 0.75 DRILL TRIP INTRM1 RIH f/3885' to 4630'. MU top drive. Fill pipe, wash f/4630' to TD @ 4722'. SO wt 75K. 21 :45 - 00:00 2.25 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4722' to 4,908' MD/2656' TVD (186') ART .63 hrs, AST .23 hrs, 10-15K wob, 80 rpm's, 634-651 gpm, 9.1ppg mw, on btm pressure 1600-2000 psi, on bottom torque 6-1 Ok ftIlb, off bottom torque 8-9k ftIlb, up wt 119-115K, dn wt 75-80K, rot wt 93-96K. 5/7/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4908' to 5836' MD/ 3019' TVD (928') ART 2.9 Printed: 7/612005 3:50:05 PM · - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/7/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 hrs, AST 3.75 hrs, 5-25K wob, 80-90 rpm's, 550-668 gpm, 9.1 ppg mw, on btm pressure 1900-2250 psi, off bottom pressure 1400-2000, on bottom torque 6·12k ftllb, off bottom torque 6-12k ftllb, up wt 115-128K, dn wt 80-86K, rot wt 95-1 03K 12:00 - 00:00. 12.00 DRILL DRLG I NTRM 1 Drilled 12 1/4" hole from 5836 to 6597' MD/3341' TVD (761') ART 1.3 hrs, AST 4.16 hrs, 0-30K wob, 95 rpm's, 672 gpm, 9.1 ppg mw, on btm pressure 2150-2300 psi, off bottom pressure 2050-2200, on bottom torque 1 0-13k ftllb, off bottom torque 1 0-16k ftllb, up wt 127-155K, dn wt 86-83K, rotwt 1 04-1 07K. 5/8/2005 00:00 - 00:30 0.50 DRILL DRLG INTRM1 Drilled 121/4" hole from 6597' to 6679'MD/3370' TVD (82') ART 0.0 hrs, AST .56 hrs, 10-15Kwob, 95 rpm's, 672 gpm, 9.1ppg mw, on btm pressure 2300 psi, off bottom pressure 2200, on bottom torque 13-20k ftllb, off bottom torque 20-23k ftllb, up WI 155K, dn wt 84K, rot WI 112K. 00:30 - 04:45 4.25 DRILL REAM INTRM1 Backream out of hole f/6679' to 5468' @}OO gpm w/2300 psi, 95 rpm. Pulling 3'- 6'/min first 5 stands, then 10'-12'/min. 04:45 - 06:30 1.75 DRILL CIRC INTRM1 Pump 60 bbl hi vis sweep @ 680 gpm, 2300 psi, 95 rpm, pulling real slow. Circ sweep to surf. Circ total of 2BU. Increase of cuttings 15%. 06:30 - 07:30 1.00 DRILL REAM INTRM1 Backream out of hole f/5282' to 4725' @ 700 gpm w/2175 psi, 95 rpm. Pulling 10-12'/min. 07:30 - 08:45 1.25 DRILL CIRC INTRM1 Pump 60 bbl hi vis sweep @ 680 gpm, 2100 psi, 95 rpm, pulling real slow. Circ sweep to surf. Circ total of 2BU. Increase of cuttings 10-15%. 08:45 - 09:45 1.00 DRILL TRIP INTRM1 RIH f/4597' to 6584'. 09:45 - 10:00 0.25 DRILL REAM INTRM1 Fill pipe. Wash f/6584' to 6679'. 10:00 - 12:00 2.00 DRILL DRLG INTRM1 Drilled 121/4" hole from 6679' to 6773' MD/3406' TVD (94') ART 0.0 hrs, AST .85 hrs, 10-15K wob, 95 rpm's, 672 gpm, 9.1ppg mw, on btm pressure 2300 psi, off bottom pressure 2200, on bottom torque 15-18k ftllb, off bottom torque 15k ftllb, up wt157K, dn WI 80K, rot wt 11 OK. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 6773' to 7442' MD/3568' TVD (669') ART 3.32 hrs, AST 3.81 hrs, 1 0-25K wob, 95 rpm's, 676 gpm, 9.1 ppg mw, on btm pressure 2300-2400 psi, off bottom pressure2200, on bottom torque 14-15k ftllb, off bottom torque 14-17k ftllb, up wt 157-151 K, dn wt 76-80K, rot wt 1 07-11 OK. 5/9/2005 00:00 - 10:30 10.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 7442' to 8295' MD/3713' TVD (853') ART 5.31 hrs, AST 1.24 hrs, 1 0-35K wob, 95 rpm's, 676 gpm, 9.1 ppg mw, on btm pressure 2400-2500 psi, off bottom pressure 2200-2300, on bottom torque 13-15k ftllb, off bottom torque 14-18k ftllb, up wt 151-154K, dn wt 76-80K, rot WI 109-11 OK. 10:30 - 12:00 1.50 DRILL CIRC INTRM1 Pump 60 bbls weighted hi vis sweep @ 680 gpm w/ 2500 psi, rotating 95 rpm. 12:00 -12:45 0.75 DRILL OBSV INTRM1 Monitor wetl. 12:45 - 18:45 6.00 DRILL REAM INTRM1 Backream out of hole f/ 8295' to 3850' w/680 gpm/2500- 1975 psi, rotating 95 rpm. 133/8" shoe is @ 3905'. Mud weight is 9.2+. 18:45 -21:15 2.50 DRILL CIRC INTRM1 Circulate, pump 60 bbls hi vis sweep, continue pumping to total of 2 1/2 BU after sweep to surf, and hole is clean. No increase in cuttings. Pumping @ 680 gpm w/1975 psi. 21:15 - 22:15 1.00 DRILL TRIP INTRM1 Monitor well. Pull 5 stands on elevators f/3905' to 3440'. Proper fill. RIH 5 stands f/3440' to 3905'. 22:15 - 22:45 0.50 DRILL CIRC INTRM1 Circ, spot lube pill EMI 920 (f/ metal to metal). Pump 226 bbls, follow w/ 41 bbls mud, 20 bbls dry job, 10 bbls to chase dry job. Pumping @ 680 gpm w/1975 psi. Mud weight is 9.4 ppg. 22:45 - 00:00 1.25 DRILL TRIP INTRM1 Blow down top drive. POOH on elevators f/3850' to 3150' @ midnight to run 9 5/8" casing. 5/10/2005 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 POOH from 3,150' to 177', stood back HWDP and jars, LD ghost Printed: 7/6/2005 3:50:05 PM e . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E~1 05 ROT- DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/10/2005 00:00 - 01 :30 01:30 - 03:45 03:45 - 04:30 04:30 - 06:00 06:00 - 07:45 07:45 - 08:00 08:00 - 13:45 1.50 DRILL TRIP 2.25 DRILL PULD 0.75 WELCTL OTHR 1.50 WELCTL EQRP INTRM1 INTRM1 INTRM1 INTRM1 1.75 CASE 0.25 CASE 5.75 CASE RURD INTRM1 SFTY INTRM1 RUNC INTRM1 13:45 -15:00 1.25 CASE CIRC INTRM1 15:00 - 16:30 1.50 CASE RUNC INTRM1 16:30 - 17:30 1.00 CASE CIRC INTRM1 17:30 - 20:00 2.50 CASE RUNC INTRM1 20:00 - 21:30 1.50 CASE CIRC INTRM1 21 :30 - 00:00 2.50 CASE RUNC INTRM1 5/11/2005 00:00 - 01 :00 1.00 CASE RUNC INTRM1 01 :00 - 03:00 2.00 CEMENTCIRC INTRM1 03:00 - 03:30 03:30 - 05:30 05:30 - 07:15 07:15 - 08:45 08:45 -13:00 0.50 CEMEN1 RURD INTRM1 2.00 CEMENT CIRC INTRM1 1.75 CEMENT PUMP INTRM1 1.50 CEMENTDISP INTRM1 4.25 WELCTL EQRP INTRM1 reamer Downloaded MWD and LD BHA #3, LD NM flee DC's, MWD. and motor Pulled wear bushing and installed test plug Changed out top set of 3 1/2" x 6" VBR's to 9 5/8" csg rams and tested same to 250 psi low and 3,000 psi high RU Doyon's 9 5/8" csg equipment and Franks fill up tool Held PJSM with rig crew and tong operator on running of 95/8" csg RIH with 95/8",40#, L-80, BTC-M csg to 2,891', MU 9 5/8" Float shoe, 2 jts csg and float collar, thread locked btm 3 conn's and cire thru float equip and ck ok, RIH with 72 add. jts along with pup jts for spacing out to 2,891' Cire btms up at 2,891', staged pump rate up to 6 bpm at 300 psi, st wt up 120K, dn wt 62K RIH with 95/8" csg from 2,891' to 3,894', (Csg Shoe at 3,905') RIH with 26 add. jts, 100 total jts of csg in hole Circ a csg cap at 3,894' (300 bbls), staged pump rate up to 6 bpm at 400 psi, st wt up 144K. dn wt 63K RIH with an add 50 jts of 95/8" csg from 3,894' to 5,800' with no problems, 150 total jts in the hole Circ 200 bbls of mud to cond mud in open hole, staged pump rate up to 5 bpm at 380 psi, st wt up 207K, dn wt 70K RIH With an add 45 jts of 9518" csg from 5,800' to 7,520',195 jts of 215 in the hole, no problems RIH, st wt up 247K, dn wt 79K Fin RIH with 9 5/8" csg from 7,520' to 8,290' with no problems, ran a total of 215 jts of 95/8",40#, L-80, BTCM csg with 2 pup jts for space out, total ran including float equipment 8,264.87' Began circ and conditioning mud thru Franks fill up tool for cementing, cire 1.5X btms up, staged pump rate from 3.5 bpm at 500 psi to 7 bpm at 625 psi, st wt up 245K, dn wt 83K, reciprocated pipe with no problems and full returns LD Franks fill up tool and MUDowells cement head Fin circ and cond mud for cementing, circ at 7 bpm at 500 psi, st wt up 255K, dn wt 82K, initial MW out, 9.2+ ppg, 69 Vis, PV 15, YP 30, Conditioned mud to final MW of 9.2 ppg, 48 vis, 15 YP and 14 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while cire. Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 30 add. bbls of CW 100, Pumped 38 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 260.5 bbls, (650 sxs) of DeepCrete cmt at 12.4 ppg, 2.26 yield with additives, ave 3.7 bpm at 450 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped top plug. Rig displaced cement with 9.0 ppgMOBM, Bumped plug on calc displacement after pumping 621 bbls (96% pump eft.) ave 8 bpm while displacing cmt, Max pressure 1,230 psi, Slowed pump rate to 3 bpm (700 psi) with 20 bbls left to pump and bumped plug to 1,200 psi, ck floats and held, CIP at 08:42 hrs, Reciprocated pipe until 190 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, Stopped reciprocating with csg with. Shoe at 8,290' and Float Collar at 8,208', Calc TOC @ 5,035', Had full returns thru out job ND stack and RD cement head, PU on stack and installed 9518" Vetco Gray MB 222 (C-21) csg slips per well plan, PU and set slips with 75K st wt, cut oft csg and LD same, Installed 9 518" paekoft, NU stack and Printed: 7/6/Z005 3:50:05 PM e ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: tested packoffto 2,400 psi(80% of collapse) for 10 min and ck ok RU and performed LOT on 13 3/8" x 9 5/8" annulus to 16.1 ppg EMW, 801 psi at 2,285' TVD with 9.4 ppg MW, Flushed 13 3/8" x 95/8" annulus with 275 bbls water, initial rate 1.5 bpm at 850 psi, final rate 3 bpm at 960 psi, Sim-Ops, changed out top set of pipe rams from 9 5/8" csg rams back to 3 1/2" x 6" VBR's RU and tested 31/2;' x 6" VBR's and 133/8" 5M flange to 250 psi low and 3,500 psi high RD 9 5/8" csg equipment and RU to PU 5" DP, installed wear bushing Inspected 5" saver sub and ck ok, RU Uttle Red on 133/8" x 95/8" annulus PU 30·5" Lo- Tads to rig floor while Little Red freeze protected 13 3/8" x 95/8" annulus with 130 bbls diesel, ave 3 bpm at 1,100 psi Held PJSM on PU 5" DP with Lo-Tads and PU Sperry Suns Geo Span by-pass unit PU and spotted Sperry Suns Geo Span by-pass unit on the off drillers side of rig floor pU and stood back 14 stds of 5" Dp with Lo-Tads Fin PU and standing back 5" Dp with Lo-Tads, (PU an add. 46 stds, 60 stds total with Lo-Tads) MU 8 1/2" BHA #4 and RIH to 85', MU bit #3, Geo-pilot rotary system with Stratasteer LWD/MWD/PWD, oriented and uploaded MWD and shallow tested tool Held PJSM on loading of radioactive sources Fin MU BHA #4 and RIH to 385', loaded radioactive sources, PU 3-6 3/4" NM flex Dc's and RIH with HWDP and jars to 385' RIH from 385' to 8,100' Slip and cut 104' of drlg line, circ btms up while cutting drlg line at 175 gpm at 500 psi, rot wt 102K, up wt 162K, dn wt 79K, 9.0 ppg MOBM in and out RIH from 8,100' and tagged up at 8,196', LD 1 single PU to 8,165' (Fit Collar at 8,208') RU and tested 9 5/8" csg to 3,000 psi for 30 min PU single and RIH from 8,165' to 8,196', est circ and took SPR's Cleaned out cement on top of plugs from 8,196' and began drilling out plugs, drilling out plugs at 8,206' with 5-17 wob, 70 rpm's, 550 gpm at 2,750 psi, on btm torque 12-15K ft-Ibs, rot wt 110K, up wt 155K, dn wt 80K (fit Collar at 8,208') 1.75 CEMENTDSHO INTRM1 Fin drilling out plugs, fit collar at 8,208', shoe track, fit shoe at 8,290' and drill 20' of new formation from 8,295' to 8,315' MD/3, 718' TVD, drilled out at 5-17K wob, 70 rpm's, 550 gpm at 2,750 psi, rot wt 11 OK, up wt 155K, dn wt 80K, ADT .18 hrs Circ btms up for LOT, circ at 550 gpm at 2,750 psi with 8.9 ppg MOBM in and out, stood back 1 std RU and performed LOT to 12.3 ppg EMW, 650 psi at 3,712' TVD with 8.9 ppg MOBM . Drilled 8 1/2" hole in A2 lateral from 8,315' to 8,683' (368') ADT 2.19 hrs Circ btms up and est. PWD baseline, at 120 rpm's and 600 gpm, clean hole ECD was 10.6 ppg Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary steerable system from 8,683' to 9,169' MD/3,692' TVD (486') ADT 3.41 hrs, 5-15K wob, 120 rpm's, 150 spm, 636 gpm, off btm pressure 3,500 psi, on btm pressure 3,570 psi, off btm torque 1 OK ft-Ibs, on btm 12K 5/1112005 08:45 - 13:00 4.25 WELCTL EQRP INTRM1 13:00 -13:45 0.75 DRILL LOT INTRM1 13:45 -15:45 2.00 DRILL OTHR INTRM1 15:45 - 16:45 1.00 WELCTL BOPE INTRM1 16:45 -18:00 1.25 DRILL RIRD INTRM1 18:00 -18:30 0.50 RIGMNT RSRV INTRM1 18:30 - 2Ò:00 1.50 DRILL PULD INTRM1 20:00 - 20:15 0.25 DRILL SFTY INTRM1 20:15 ·21:15 1.00 DRILL PULD INTRM1 21 :15 - 00:00 2.75 DRILL PULD INTRM1 5/1212005 00:00 - 08:00 8.00 DRILL PULD INTRM1 08:00 - 11 :00 3.00 DRILL PULD INTRM1 11:00 -11:15 0.25 DRILL SFTY INTRM1 11:15 -12:00 0.75 DRILL PULD INTRM1 12:00 - 16:45 4.75 DRILL TRIP INTRM1 16:45 - 18:00 1.25 RIGMNT RSRV INTRM1 18:00 -18:15 0.25 DRILL TRIP INTRM1 18:15 -19:45 1.50 CASE DEQT INTRM1 19:45 - 20:00 0.25 DRILL TRIP INTRM1 20:00 - 00:00 4.00 CEMENTDSHO INTRM1 5/13/2005 00:00 - 01 :45 01:45 - 02:30 0.75 DRILL CIRC INTRM1 02:30 - 03:15 0.75 DRILL LOT INTRM1 03:15 - 06:30 3.25 DRILL DRLG PROD 06:30 - 07:15 0.75 DRILL CIRC PROD 07:15 - 12:00 4.75 DRILL DRLG PROD Printed: 7/6/2005 3:50:05 PM e . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT -DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/13/2005 07:15-12:00 4.75 DRILL DRLG PROD ft-Ibs, rotwt 112K, up wt 165K, dn wt 7SK, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 150 units, max gas 430 units 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary steerable system from 9,169' to 10,232' MD/ 3,703' TVD (1,063') ADT 7.03 hrs, 5-20K wob, 120 rpm's, 150 spm, 636 gpm, off btm pressure 3,600 psi, on btm pressure 3,625 psi, off btm torque 14-18K ft-Ibs, on btm 13-20K ft-Ibs, rot wt 11 OK, up wt 193K, dn wt 72K, 9.0 ppg MOBM, ave ECD 11.1 ppg, ave BGG 150 units, max gas 229 units, drilled thtu several concrètions and using Sperry Sun's Stratasteering tool to aid in geosteering 5/14/2005 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary steerable system from 10,232' to 11,474' MD/3,648' TVD (1,242') ADT 7.21 hrs, 6-14K wob, 120 rpm's, 150 spm, 636 gpm, 3,625 psi, off btm torque 16-20K ft-Ibs, on btm 15-16Kft-lbs, rot wt 110K, up wt 195K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.2 ppg, ave BGG 150 units, max gas 220 units, drilled thru several concretions and using Sperry Sun's Stratasteering tool to aid in geosteering 12:00 - 20:00 8.00 DRILL DRLG PROD Drilled 8 1/2" hole in A2 sand lateral from 11,474' to 12,208' MD/3,717' TVD (734') ADT 4.26 hrs, 5-15K wob, 120 rpm's, 141 spm, 600 gpm, 3,600 psi, off btm torque 16-19K ft-Ibs, on btm 16-20K ft-Ibs, rot wt 111 K, up wt 220K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.3 ppg, ave BGG 120 units, m¡;¡x gas 230 units, crossed fault at 11,420' MD/3,650' TVD as predicted and ·drilled thru btm lobe of A2 sand to determine formation dip, btm of lower A2 sand at 12,125' MD/3,691' TVD, to POOH and open hole sidetrack well per directional plan and geologist 20:00 - 22:30 2.50 DRILL REAM PROD Backreamed out of hole for open hole sidetrack from 12,208' to 11,297', backreamed out at 100 rpm's, 445 gpmat 2,200 psi with 15-17K torque. Note: Began changing out 6" liners in mud pumps over to 51/2" liners while backreaming out 22:30 - 23:00 0.50 DRILL CIRC PROD Circ hole at 11,297' while fin. changing out liners on mud pumps to 5 1/2" 23:00- 00:00 1.00 DRILL REAM PROD Began cutting trough for open hole sidetrack from 11,297' to 11,332' MD/3,653' TVD, cutting trough at 120 rpm's, 176 spm, 625 gpm at 3,650 psi, rot wt 11 OK, up wt 195K, dn wt 60K, off btm torque 15-16K ft-Ibs 5/15/2005 00:00 - 02:00 2.00 DRILL DRLG PROD Time drilled to sidetrack well from 11,332' to 11,341', sidetracked well at 11,332' MD/ 3,653' TVD, (9') ADT 1.93 hrs 02:00 - 12:00 10.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary steerable system from 11,341' to 12,245' MD/ 3,654' TVD (904') ADT 6.58 hrs, 8-20K wob, 120 rpm's, 176 spm, 625 gpm, 3,800 psi, off btm torque 15-18K ft-Ibs, on btm 15-17K ft-Ibs, rot wt 108K, up wt 207K, dn wt 57K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 100 units, max gas 228 units, using Sperry Sun's Stratasteering tool to aid in geosteering 12:00 - 16:00 4.00 DRILL DRLG PROD Drilled 81/2" hole from 12,245' to 12,627' MD/3,629' TVD (382') ADT 2.46 hrs, max gas 723 units 16:00 - 17:00 1.00 DRILL CIRC PROD Stood back 1 std and circ hole while trouble shoot MWD computer problem, re-bootedcomputers, circ and worked pipe from 12,622' to 12,595', circ at 500 gpm, 2,700 psi with 80 rpm's and 17K ft-Ibs torque 17:0Q -17:45 0.75 DRILL DRLG PROD Drilled 8 1/2" hole from 12,627' to 12,723' MD/3,625' TVD (96') ADT .89 hrs, max gas 412 units 17:45 - 18:45 1.00 DRILL OTHR PROD Circ hole while geologist evaluated logs 18:45 - 00:00 5.25 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary Printed: 7/612005 3:50:05 PM e . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5.25 DRILL DRLG PROD steerable system from 12,723' to 13,184' MD/3,631' TVD (461')ADT 2.8 hrs, 10-20K wob, 120 rpm's, 176 spm, 625 gpm, 4,050 psi, off btm torque 18-19K ft-Ibs, on btm 16-17K ft-Ibs, rot wt 112K, up wt 217K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ¡¡ve BGG 100 units, max gas 219 units, began using 5" HWDP at 12,820'. NOTE: at 13,000' taking several attempts to get survey and get Geo-pilot to cycle, slowed MWD data rate to improve survey signal, changed out jet on Geo span unit and clean screens on mud pumps and saw improvement in surveys and downlinking Geo span unit Drilled 8 1/2" Hole in A2 sand lateral from 13,184' to 13,252' MD/3,628' (68') ADT .34 hrs when rig and camp lost highline power Started rig generators and re-established circ and rotation with no problem, NOTE: rig off highline from 00:45 to 04:45 hrs Drilled 81/2" hole in A2 sand lateral from 13,252' to 13,539' MD/3,623' TVD, A2 sand TD, (287') ADT 1.57 hrs, 8-12K wob, 120 rpm's, 625 gpm at 4,100 psi, off btm torque 18-20K ft-Ibs, on btm 17 -18K ft-Ibs, rot wt 115K, up wt 220K, dn wt 68K with 60 stds of 5" DP with Lo-Tads and 8 stds of 5" HWDP in the hole, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave BGG 80 units, max gas 580 units, 0.25 DRILL CIRC PROD Circ hole to clear BHA, circ at 625 gpm at 4,000 psi 1.75 DRILL REAM PROD Backreamd out of hole from 13,539' to 12,911' and started packing off at 12,911', backreamed out at 120 rpm's, 625 gpm at 4,100 psi 3.00 DRILL REAM PROD Backreamed out slow due to packing off from 12,911' to 12,725', backreamed out at 600 gpm, 4,100 psi and 120 rpm's, pumped 30 bbl wt'd hi vis sweep at 12,800' with slight incre,,!se in cuttings back from sweep Backkreamed out of hole (BROOH) from 12,725' to 11,488' and started pulling tight and packing off at 11,488', would loose pàrtial returns when packing off then would slow pump rate Worked thru tight spot from 11,488' to 11,393', RIH 1 std to 11,550', Note: as of 12:00 hrs had lost 50 bbls of MOBM to formation while backreaming out BROOH from 11,550' to 10,500', no problems thru spot at 11,488', began pulling tight and packing off at 10,500', backreamed out at 120 rpm's, 15K ft-Ibs torque, 595gpm at 3,500 psi Worked thru tight spot from 10,500' to 10,492', slowed pump rate due to circ with only 50% returns, shut down pump and pulled 45K thru tight spot, then RIH to 10,500' and backreamed thru spot with no problems BROOH from 10,492' to 9,945' with no problems, backreamed at 120 rpm's, 15K ft-Ibs torque, 595 gpm at 3,200 psi RIH from 9,945' to 10,615' with no problems Pumped out of hole from 10,615' to 9,945' at 595 gpm, 3,200 psi with no problems BROOH from 9,945' to 8,709' and began to pull tight and packing off, backreamed at 120 rpm's, 595 gpm 3,200 psi Worked thru tight spot at 8,709' to 8,689', pulled 45-50K over and pulled thru spot, RIH past spot and backreamed out thru spot with no problems BROOH from 8,689' to 8,285' with no problems (9 5/8" csg shoe at 8,290') NOTE: While backreaming out of hole found 3 small pin hole wash outs, found 1 in middle of std # 102 and 1 between std #112-#113 and between #120-#121, lost an add 112 bbls of MOBM while Backreaming out, total lost 162 bbls 5/15/2005 18:45 - 00:00 5/16/2005 00:00 - 00:45 0.75 DRILL DRLG PROD 00:45 - 01 :30 0.75 DRILL OTHR PROD 01 :30 - 04:30 3.00 DRILL DRLG PROD 04:30 - 04:45 04:45 - 06:30 06:30 - 09:30 09:30 - 11 :30 2.00 DRILL REAM PROD 11 :30 - 12:00 0.50 DRILL REAM PROD 12:00 - 14:00 2.00 DRILL REAM PROD 14:00 -15:15 1.25 DRILL REAM PROD 15:15 -16:00 0.75 DRILL REAM PROD 16:00 - 16:30 0.50 DRILL TRIP PROD 16:30 - 17:15 0.75 DRILL TRIP PROD 17:15 - 19:30 2.25 . DRILL REAM PROD 19:30 - 20:00 0.50 DRILL REAM PROD 20:00 - 20:45 0.75 DRILL REAM PROD Printed: 7/612005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/16/2005 20:45 - 21 :00 21 :00 - 22:15 0.25 DRILL 1.25 DRILL OBSV PROD CIRC PROD 22:15 - 23:30 1.25 DRILL PULD PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 5/17/2005 00:00 - 03:00 3.00 DRILL TRIP PROD 03:00 - 05:15 2.25 DRILL CIRC PROD 05:15 - 06:45 1.50 DRILL CIRC PROD 06:45 - 07:00 0.25 DRILL OBSV PROD 07:00 - 11 :30 4.50 DRILL TRIP PROD 11 :30 - 11 :45 0.25 DRILL OBSV PROD 11:45 - 12:45 1.00 RIGMNT RGRP PROD 12:45 - 13:45 1.00 RIGMNT RSRV PROD 13:45 -15:45 2.00 RIGMNT RSRV PROD 15:45 -16:15 0.50 RIGMNT RGRP PROD 16:15 -19:30 3.25 DRILL TRIP PROD 19:30 - 22:45 3.25 DRILL PULD PROD 22:45 - 23:00 0.25 LOG SFTY PROD 23:00 - 00:00 1.00 LOG RURD PROD 5/18/2005 00:00 - 00:30 0.50 LOG RURD PROD 00:30 - 05:30 5.00 WAlTON EQIP PROD 05:30 - 10:15 4.75 LOG ELOG PROD 10:15 - 10:45 0.50 LOG RURD PROD 10:45 -11:30 0.75 CASE RURD CMPL TN 11 :30 - 12:00 0.50 CASE SFTY CMPL TN 12:00 - 16:00 4.00 CASE PULR CMPL TN 16:00 - 16:45 0.75 CASE PULR CMPLTN 16:45 - 18:00 1.25 CASE RUNL CMPL TN 18:00 - 18:30 0.50 CASE CIRC CMPL TN Monitored well at shoe, well-static Pumped 35 bbl wt'd hi vis sweep at shoe and circ 2 complete circ and was clean at shakers, had a slight increase in cuttings back from sweep, circ at 625 gpm, 3,150 psi, 120 rpm's, 12-18K ft-Ibs torque, rot wt 105K, up wt 180K, dn wt 76K Swapped· out 6 jts of 5" DP found to be washed out while BROOH RIH from 8,285' to 8,496' RIH from 8,496' to 13,539', had 20K drag at 11,356' and no other problems RIH Pumped 30 bbl wt'd hi vis sweep and circ hole clean, circ at 570 gpm at 4,100 psi, had no increase in cuttings back from sweep Displaced hole over from 9.1 ppg MOBM to 9.0 ppg SFMOBM, circ hole at 535 gpm at 3,450 psi, rot wt 110K, up wt 245K, dn wt 65K Monitored well-static POOH on elevators from 13,539' to 8,206', (95/8" Shoe at 8,290') no problems POOH Monitor¡¡¡d well inside csg shoe, well-static Removed shot pin hydraulic assembly on top drive for repair due to leak, (shot pin is locking pin for pipe handler) Slip and cut 57' of drlg line Changed out 4 1/2" IF saver sub on top drive Re-installed shot pin assembly on top drive, Note: hole took 4 bbls of mud in 4 1/2 hrs Dropped 2 318" rabbit on a wire and POOH from 8,206' to BHA #4 at 385', LD ghost reamer Stood back 2 stds NM flex Dc's, held PJSM and removed radioactive sources, LD a NM flex Dc and downloaded MWD, LD remaining BHA #4 with Geo-pilot and cleared rig floor, calc fill on trip out 117.6 bbls, actual fill 146.7 bbls Held PJSm with SWS and rig crew on RU of wire line and USIT logging tool with WELL TEC tractor tool RU SWS wireline and MU USIT logging tools with tractor tool Fin RU SWS wireline, hydraulic unit on winch failed Attempted to repair hydraulic switch on winch with no success, W.O. back up logging truck to arrive rig, RD sheaves, back up unit arrived at 04:30 hrs, RU sheaves andre_head wireline RIH with USIT logging tool and tool stopped at 7,200', cont RIH using tractor tool to 8,160', ran bond log from 8,160' to 4,792' and POOH with wireline LD US IT and tractor tool & RD SWS wireline RU Doyons 5 1/2" liner running equipment Held PJSM with rig crew on running of liner (crew change) PU and RIH with 5 1/2", 15.5#, L-80, BTCM Liner per well program to 5,856' (137 Jts total), ran 5 112" ROT silver bullet guide shoe with no float, ran a total of 92 jts (3,944') of 5 1/2" 15.5#,L-80, BTCM blank liner, ran 45 jts (1,881 ') of5 1/2", 15.5# L-80 BTCM liner, ran 121 - 5 1/2" x 8 1/2" spiralglide centralizers 11jt#3 thru # 123, ran 15 constrictor packers placed on blank liner to cover shale sections. MU Baker 190-47 seal bore ex!, 95/8" x 7" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,909", st wt up 95K, dn wt 67K, RIH with liner on 5" DI" to 8,283' (9 518" csg shoe at 8,290') Circ a DP capacity at the 9 518" csg shoe, circ at 3 bpm at 150 psi, st wt Printed: 716/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT- DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/18/2005 18:00 - 18:30 18:30 -21:45 21 :45 - 22:30 22:30 - 22:45 22:45 - 23:45 0.50 CASE CIRC CMPL TN up 127K, dn wt 75, set torque limiter on top drive to 4,500 ft-Ibs tòrque, pipe would not rotate unless pipe was moving, would rotate at 4 rpm's at 4,500 ft-Ibs torque 3.25 CASE RUNL CMPL TN Cont to RIHwith 5 1/2" liner on 5" DP from 8,283' and tagged btm at 13,539' with no problems RIH, PU liner tò setting depth, ran liner with 11 stds of 5" DP slick, 60 stds of 5" DP w/Lo- Tads, 8 stds HWDP and 1 std of slick 5" DP , st wt up 200K, dn wt 75K 0.75 CASE RUNL CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 5 bpm at 590 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, slacked off 25K, cont to set packer, pressured up to 4,000 psi and set ZXP packer and release HR running tool, no problems setting hanger/ packer, set "A2" sand liner with TOL @ 7,619' MD/3,601' TVD and shoe at 13,519' MD/3,624' TVD 0.25 CASE DEQT CMPL TN Tested ZXP packer to 1,000 psi for 5 min & checked ok 1.00 CASE CIRC CMPb TN PU and sat back down to reconfirme.d TOL at 7,619', PU from 7,619' to 7,555' and circ btms up, circ at 336 gpm at 800 psi, no gas at btms up, st wt up after setting liner 170K, 100K dn Monitored well-static, preparing to POOH POOH wet with liner running tool from 7,555' to 50', SLM out no corr. LD Baker running tool and cleaned rig floor Pulled wear bushing RU & attempted to set test plug, had trouble setting same, flushed out wellhead and changed out seal ring and finally got to hold pressure 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 waived witnessing of test Installed wear bushing Held PJSM, PU & MU Baker 9 5/8" whipstock assembly BHA #5 and RIH to 205', MU seal assembly, locator sub, unloader sub, then PU 2-DP pup jts & 1 jt of 5" DP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH to 205' RIH with whipstock assembly on 5" DP from 205' to 6,767' Made MADD pass from 6,767' to 6,817 (sensor depth 6,610'-6,660')' and correlated MWD to K-13, no corL circ at 450 gpm's at 1,425 psi, st wt up 147K, dn wt 80K Cont to RIH from 6,817' , oriented whipstock and tagged TOL at 7,619' Oriented whipstock 12 deg left of high side, tagged TOL at 7,619', set whipstock and sheared off from same, top of whipstock at 7,524' MD/3,583' TVD, st wt up 160K, dn wt 92K, RIH with whipstock milling assembly with 11 stds of slick 5" DP, 60 stds of 5" DP with Lo-tads, 8 stds and 1 single of 5" HWDP 1.00 WINDO\f\/CIRC PROD2 Displaced out 9.0 ppg SFMOBM with re-conditioned 9.0 ppg MOBM, circ at 535 gpm at 2,200 psi 15.25 WINDO\lVSTWP PROD2 Milled 81/2" window in "B" sand lateral from 7,524' to 7,540', cont to mill to 7,5550' when P-rate slowed to less than 1'/hr, possibly due to concretion, ADT 14.91 hrs, milled at 2-40K wob, 65-80 rpm's, 437 gpm at 1,625 psi, off btm torque 10K ft-Ibs, on btm 7-16K ft-Ibs, rot wt 120K, up wt 162K, dn wt 92K, pumped several wt'd hi vis sweep while milling window with no increase in cuttings back from sweeps, took 4 hrs to mill window, 10.91 hrs drilling formation below window 0.75 WINDO\f\/CIRC PROD2 Circ btms up while working mills thru window, circ at 437 gpm at 1,625 psi 23:45 - 00:00 0.25 CASE OTHR CMPL TN 5/19/2005 00:00 - 04:30 4.50 DRILL TRIP CMPL TN 04:30 - 05:15 0.75 DRILL PULD CMPL TN 05:15 - 05:45 0.50 DRILL PULD CMPL TN 05:45 - 08:45 3.00 WELCTL OTHR PROD2 08:45 - 13:00 4.25 WELCTL BOPE PROD2 13:00 - 13:15 0.25 WINDOVVPULD PROD2 13:15 - 16:45 3.50 WINDOVVPULD PROD2 16:45 - 21 :00 4.25 WINDOwrRIP PROD2 21 :00 - 21 :30 0.50 WINDOIiVCIRC PROD2 21 :30 - 22:00 0.50 WINDOWfRlP PROD2 22:00 - 23:00 1.00 WINDOVVSETW PROD2 23:00 - 00:00 5/20/2005 00:00 - 15:15 15:15-16:00 Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/20/2005 16:00 -16:15 16:15 - 19:30 19:30 - 20:00 0.25 WINDOVVOTHR PROD2 3.25 WINDOINTRIP PROD2 0.50 WINDOVliPULD PROD2 20:00 - 21 :00 1.00 WINDOVliPULD PROD2 21 :00 - 00:00 3.00 WINDOWfRIP PROD2 5/21/2005 00:00 ~00:30 0.50 WINDO¡RIP PROD2 00:30 - 01:15 0.75 WINDQ\ IRC PROD2 01 :15 - 02:00 0.75 WINDOVVSìWP PROD2 02:00 - 02:45 0.75 WINDOVVCIRC PROD2 02:45 - 03:00 0.25 WINDO\¡VOTHR PROD2 03:00 - 06:30 3.50 WINDOWTRIP PROD2 06:30 - 07:.30 1.00 WINDOVliPULD PROD2 07:30 - 09:00 1.50 WINDOVVOTHR PROD2 09:00 - 12:30 3.50 DRILL PULD PROD2 12:30 - 15:15 2.75 DRILL TRIP PROD2 15:15 -16:15 16:15 -17:00 1.00 RIGMNT RSRV PROD2 0.75 DRILL CIRC PROD2 17:00 - 00:00 7.00 DRILL DRLG PROD2 5/22/2005 00:00 c 12:00 12.00 DRILL DRLG PROD2 Monitored well-static, pumped dry job POOH from 7,550' to whipstock milling BHA #5 at 106' POOH and LD MWD and mills, gauged mills and lower 8" mill and upper 8 1/2" mill was in gauge, starting mill went in at 8" and came out at 7 1/2" and worn on btm due to possibly drilling on concretion, calc fill on trip out 67 bbls, actual fill 76.5 bbls MU BHA #7 with 8 1/2" bit #5 arid lower and upper mills with flex jt, 1-jt HWDP, bumper and oil jars RIH to 76' RIH from 76' to 6,888' RIH with BHA #6, 8 1/2" bit with lower and upper whipstock mills from 6,888' to 7,501' Est circ and rotation, rotated down thru whipstock and window with no pròblems, TOW at 7,524', BOW at 7,540', tagged gauge hole at 7,541' and cleaned out to 7,550', ròt wt 116K, up wt 145K, dn wt 100K, 80 rpm's, 9K ft-Ibs torque, circ at 455 gpm at 1,500 psi Drilled 8 1/2" hole from 7,550' to 7565' MD/3,589' ADT .8 hrs, drilled with 25-28K wob, 90 rpm's, 1 OK ft-Ibs torque, 455 gpm at 1,500 psi, drilled 3' of concretions from 7,550' to 7,553 before being able to drill to 7,565'. drilled a total of 25' of gauge hole from BOW for Geo-Pílot BHA Circ btms up while working mills thru window, circ at 455 gpm at 1,500 psi Monitored well-static, pumped dry job POOH from 7,565' to BHA #6 at 76' POOH LD BHA #6, 8 1/2" bit and upper mill in gauge, LD mills, jars, flex jt and jt of HWDP, cleared rig floor Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing MU 8 1/2" BHA #7 and RIH to 384', MU bit #6, Geo-pilot rotary system with Stratasteer LWD/MWD/PWD, oriented and uploaded MWD and shallow tested tool, held PJSM and loaded radioactive sources and RIH with HWDP and jars to 384' RIH with BHA #7 from 384' to 7,424', PU 2-8 1/2" ghost reamers while RIH, 1 reamer is 1,008' back from the bit and the 2nd one is 2,499' back Slip and cut 62' of drlg line and serviced top drive and drawworks Est circ and rotation, circ at 125 gpm at 550 psi and 10 rpm's, rotated down thru whipstock and window with no problems then washed to btm at 7,565', rot wt 11 OK, up wt 145K, dn wt 90K Drilled 8 1/2" hole in "B" sand lateral with Geo-Pilot assembly from 7,565' to 7,659' MD/3,598" TVD (94') ADT 6.35 hrs, 5"17K wob, 30-100 rpm's, 182 spm, 650 gpm, 3,100 psi, off btm torque 10K, on btm torque 11 K ft-Ibs, rot wt 11 OK, up wt 145K, dn wt 90K, 9.0 ppg MOBM, ave ECD 10.2 ppg, ave BGG 50 units, Drilled thru concretions from 7,568' to 7,570' and from 7,590' to 7,598' Directionally drilled 8 1/2" hole in "B" sand lateral with Geo pilot rotary steerable system from 7,659' to 8,446' MD/3,567' TVD (787') ADT 8.54 hrs, 5-15K wob, 100 rpm's, 173 spm, 615 gpm, 3,000 psi, off btm torque 11-14K ft-Ibs, on btm 11-15K ft-Ibs, rot wt 104K, up wt 157K, dn wt 75K, 9.0 ppg MOBM, ave ECD 10.7 ppg, ave BGG 100 units, max gas 303 units. NOTE: While Drlg at 8,030' light on Geo-pilot panel came on showing out of oil, decision was made by Sperry Sun to drill ahead till tool quits, back up tool was delivered to location. Drilled out of zone from 7,800' t.,¡'ID/3,61 0' TVD to 8,122' MD/3,600' TVD (322') Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: CommonWell Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1E-105 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5i22/2005 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral from 8,446' to 9,657' MD/3,530' TVD (1,211') ADT 8.94 hrs, 5,.15K wob, 120 rpm's, 186 spm, 660 9pm, 3,550 psi, off btm torque 14.5K ft-Ibs, on btm 13K ft-Ibs, rot wt 104K, up wt 163K, dn wt 70K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave BGG 170 units, max gas 376 units. Drilled thru several concretions last 24 hrs 5/23/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B"sand lateral With Geo pilot rotary steêrable system from 9,657' to 10,388' MD/3,518' TVD (731') ADT 10.14 hrs, 5-15K wob, 120 rpm's, 186 spm, 660 gpm, 3,600 psi, off btm torque 12-16K ft-Ibs, on btm11-15K ft-Ibs, rot wt 104K, up wt 170K, dn wt 63K, 9.0 ppg MOBM, aveECD 11.0 ppg, ave BGG 100 units, max gas 183 units. NOTE: Rig and Camp went off highline at 08:00 hrs to add additional breakers to system for Doyon 15 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directiònally drilled 8 1/2" hole in "B" sand lateral from 1 0,388' to 11,287' MD/3,536' TVD (899') ADT 9.53 hrs, 5-25K wob, 120 rpm's, 186 spm, 660 gpm, 3,800 psi, off btm torque 15.5K ft-Ibs, on btm 12-18K ft-Ibs, rot wt 105K, up wt 186K, dn wt 52K, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 175 units, max gas 368 units. Cont to Drill thru concretions in "B" Lat 5/24/2005 00:00 - 10:30 10.50 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 11287' to 11,976' MD/3,504' TVD (689') ADT 8.28 hrs, 4-25K wob, 120 rpm's, 173-186 spm, 615- 660 gpm, 3450-3950 psi, off btm torque 16K ft-Ibs, on btm 14-18K ft-Ibs, rot wt 105K, up wt 194K, dn wt 53K, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 260 units, max gas 321 units. Cont to Drill thru concretions in "B" Lat Trouble shoot geo-pilot failure. Pump 30 bbl weighted Hi-vis sweep surf -surf @ 660 gpm w/ 3900 psi and 120 rpm rotation. PU wt 180k, SO wt 53k, Rot wt 104k, torque 17k. Backream out of hole f/11 ,976' to 11,194' @ 40'/min., 11,194' to 10,700' @20'/min due to packing off POOH on elevatorsf/10,700' to 7409'. Noproblems. Monitor well- static. Pump dry job. . POOH f17409' to 108'. PJSM on removing RA sources. Remove RA sources. Download MWD/LWD tools. UD Geopilot and bit #6, FSF2565 ser # 10684400 PU/MU new geo-pilot and rebuilt bit. Bit # 7, FSF2565 ser # 10676838. Upload MWD/LWD tools. Upload MWD/LWD tools. PJSM on loading nuke sources. PU NMflex drill collar. Break in seals on Geo-pilot. Shallow test MWD. Load nuke sources. RIH, fill pipe every 25 stands. Test MWD, OK. RIH to 7426'. Service top drive and drawworks. Repair hyd fitting on top drive. Continue RIH f/7426' to 11,230'. Fill pipe every 25 stands. Tag up @ 11,230'. Rotated w/1 0 rpmand 3 bpm pump to go through window @ 7524'. Wash and ream in hole f/11,230' to 11,480'. Pump @ 462 gpm w/2300 psi. Rot wt 95k, torque 15-17k. Continue RIH f/11,480' to 11,866'. Precautionary ream f/11 ,866' to TD @ 11,976'. PU wt 180k, SO wt 60k, 10:30 - 11 :00 0.50 DRILL OTHR PROD2 11:00-12:15 1.25 DRILL CIRC PROD2 12:15 -'14:30 2.25 DRILL REAM PROD2 14:30 - 16:45 2.25 DRILL TRIP PROD2 16:45 -17:00 0.25 DRILL OBSV PROD2 17:00 -19:30 2.50 DRILL TRIP PROD2 19:30 - 20:00 0.50 DRILL SFTY PROD2 20:00 - 20:15 0.25 DRILL OTHR PROD2 20:15 - 22:45 2.50 DRILL TRIP PROD2 22:45 - 00:00 1.25 DRILL TRIP PROD2 5/25/2005 00:00 -.00:30 0.50 DRILL TRIP PROD2 00:30 - 01 :00 0.50 DRILL OTHR PROD2 01:00 - 01 :15 0.25 DRILL OTHR PROD2 01:15 - 04:30 3.25 DRILL TRIP PROD2 04:30 -05:00 0.50 RIGMNT RSRV PROD2 05:00 - 06:15 1.25 RIGMNT RGRP PROD2 06:15 - 09:00 2.75 DRILL TRIP PROD2 09:00 - 09:45 0.75 DRILL REAM PROD2 09:45-10:15 0.50 DRILL TRIP PROD2 10:15 -10:30 0.25 DRILL REAM PROD2 Printed: .716/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/25/2005 10:15 -10:30 0.25 DRILL REAM PROD2 Rot WI 109k, torque 15k, no pumps. 10:30 - 12:00 1.50 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "S" sand lateral from 11976' to 12056' MD/3,501' TVD (80') ADT .51 hrs, 7K wob, 120 rpm's, 185 spm, 657 gpm, 4100 psi, off btm torque 15K ft-Ibs, on btm 17K ft-Ibs, rot WI 104K, up WI 183K, dn WI 53K, 9.1 ppg MOSM, ave ECD 11.5 ppg, .max gas 180 units. Cont to Drill thru concretions in "S" Lat 12:00 -13:45 1.75 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "S" sand lateral from 12,056' to 12170' MDI 3,501' TVD (114')ADT1.17 hrs, 7-15Kwob,120rpm's, 185spm, 657 gpm, 4100 psi, off btm torque 15K ft-Ibs, on btm 17K ft-Ibs, rot WI 104K, up WI 183K, dn WI 53K, 9.1 ppg MOBM, ave ECD 11.5 ppg, max gas 202 units. Cont to Drill thru concretions in "S" Lat Reboot MWD computer, trouble shoot geo-pilot. Stand back 1 stand. Circ two bottoms @ 660 gpm wI 4050 psi. Rotate @ 120 rpm. torque 15k. Set deflection to zero on geo-pilot. Monitor well - static. POOH on elevators f/12,156' to 10,595'. Pump dry job. POOH on elevators f/1 0595' to 384'. No problems. Rack back HWDP and jars. Rack back NM flex DC's. PJSM on removing sources. remove sources. Download MWD. Change out Neutron density tool. Calc displ96 bbls, actual 125.75 bbls. Sreak biU UD geo-pilot. Change one of the 16/32 jets to a 18/32. Clean rig floor. PUlMU SHA #9. PU/MU geopilot, bit and MWD. Upload MWD/LWD. Shallow test MWD, PU 1 NM flex DC, PJSM on loading nuke sources, load sources. RIH wI SHA #9/bit7rr1, fill pipe every 25 stands. Slip and cut 64', 1 1/4" drilling line. Con't RIHf/7427' to 12060', filling pipe every 25 stands. PU WI 167k, SO WI 75k. Precautionary wash andream f/12060'to 12170'. Pumping 636gpm wI 4000 psi, rotating 120 rpm w/15k torque. Directionally drilled 8 1/2" hole in "S" sand lateral from 12,170' to 12324' MDI 3,505' TVD (154') ADT 1.65 hrs, 5-15K wob, 90-120 rpm's, 179-185 spm, 636-657 gpm, 3700-4100 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs, rot WI 105K, up WI 183-188K, dn WI 55-45K, 9.0 ppg MOSM, ave ECD 11.5 ppg, max gas 133 units. Cont to Drill thru concretions in "S" Lat 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "S" sand lateral from 12,324' to 13004' MD/3,479' TVD (680') ADT7.6 hrs, 5-25K wob, 120 rpm's, 185 spm, 657 gpm, 4000-4100 psi, off btm torque 16-17K ft-Ibs, on btm 15-19K ft-Ibs, rot WI 103-105K, up WI 188-190K, dn WI 35-51K, 9.0 ppg MOBM, ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in "S" Lat 5/27/2005 00:00 - 02:00 2.00 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "S" sandlateral from 13004' to 13105' MD/3,478' TVD (101')ADT 1.12 hrs, 7-17Kwob, 120 rpm's, 185 spm, 657 gpm, 4000 psi, off btm torque 16K ft-Ibs, on btm 15-19K ft-Ibs, rot WI 102-103K, up WI 190K, dn WI 35-45K, 9.0 ppg MOSM, ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in "S" Lat 02:00 - 04:00 2.00 DRILL OTHR PROD2 Trouble shoot MWD. Tools not working. 04:00 - 06:45 2.75 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "S" sand lateral from 13105' to 13304' MD/3,476' TVD (199') ADT 1.85 hrs, 5-17K wob, 120 rpm's, 185 spm, 13:45 -14:15 0.50 DRILL OTHR PROD2 14:15 -15:30 1.25 DRILL CIRC PROD2 15:30 - 17:30 2.00 DRILL TRIP PROD2 17:30-21:00 3.50 DRILL TRIP PROD2 21 :00 - 00:00 3.00 DRILL TRIP PROD2 5/26/2005 00:00 - 00:15 0.25 DRILL TRIP PROD2 00:15 - 00:30 0.25 DRILL OTHR PROD2 00:30 - 01 :00 0.50 DRILL PULD PROD2 01 :00 - 02:00 1.00 DRILL OTHR PROD2 02:00 - 02:45 0.75 DRILL OTHR PROD2 02:45 - 06:00 3.25 DRILL TRIP PROD2 06:00 - 07:00 1.00 RIGMNT RSRV PROD2 07:00 _ 09:15 2.25 DRILL TRIP PROD2 09:15 - 09:45 0.50 DRILL REAM PROD2 09:45 - 12:00 2.25 DRILL DRLG PROD2 Printed: 716/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT- DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 4/25/2005 6/20/2005 Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/27/2005 04:00 - 06:45 2.75 DRILL DRLG PROD2 06:45 - 07:30 0.75 DRILL OTHR PROD2 07:30 - 10:00 2.50 DRILL DRLG PROD2 10:00 - 10:30 0.50 DRILL CIRC PROD2 10:30 -12:00 1.50 DRILL REAM PROD2 12:00 -12:30 0.50 DRILL WIPR PROD2 12:30 - 13:45 1.25 DRILL WIPR PROD2 13:45 - 15:45 2.00 DRILL CIRC PROD2 15:45- 17:45 2.00 DRILL CIRC PROD2 17:45 - 18:00 0.25 DRILL OBSV PROD2 18:00 - 21 :30 3.50 DRILL TRIP PROD2 21 :30 - 22:30 1.00 DRILL OTHR PROD2 22:30 - 00:00 1.50 DRILL CIRC PROD2 5/28/2005 00:00- 00:45 0.75 DRILL CIRC PROD2 00:45 - 02:00 1.25 DRILL TRIP PROD2 02:00 - 05:45 3.75 DRILL TRIP PROD2 05:45 - 06:30 0.75 DRILL TRIP PROD2 06:30 - 07:00 0.50 DRILL PULD PROD2 07:00 - 08:00 1.00 DRILL PULD PROD2 08:00 - 08:30 0.50 DRILL PULD CMPL T2 08:30 - 09:00 0.50 FISH PULD CMPL T2 09:00 - 12:00 3.00 FISH TRIP CMPL T2 12:00 - 12:30 0.50 FISH TRIP CMPL T2 12:30 -13:45 1.25 FISH FISH CMPL T2 13:45 -14:30 0.75 FISH CIRC CMPL T2 14:30 -18:45 4.25 FISH TRIP CMPL T2 18:45 - 19:30 0.75 FISH PULD CMPL T2 19:30 - 20:00 0.50 FISH OTHR CMPL T2 20:00 - 20:45 0.75 RIGMNT RSRV CMPL T2 657 gpm, 4000-4150 psi, off btm torque 16K ft-Ibs, on btm 16K ft-Ibs, rot wt1 03-1 05K, up wt 190K, dn wt 35-45K, 9.0 ppg MOBM, ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in "B" Lat Confirm wI town on loss of survey's, as to how far to drill. Directionally drilled 81/2" hole in "B" sand lateral from 13304' to 13529' MD/3,479' TVD (225') ADT 1.62 hrs, 5-14K wob, 120 rpm's, 185 spm, 657 gpm, 4150-4300 psi, off btm torque 16-17K ft-Ibs, on btm 15K ft-Ibs, rot wt 105-109K, up wt 190-200K, dn wt 35-53K, 9.0 ppg MOBM, ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in "B" Lat Circ 15 min, attempt to get survey, no luck. SPR's, monitor well. Backream out of hole f/13529' to 12422'. Rotate 120 rpm, circ @ 620 gpm. POOH on elevators f/12422' to 11866'. Hole fill ok. RIH f/11866' to 13482', fill pipe, wash f/13482' to TD @ 13529'. Circ weighted 35 bbl hi-vis sweep, follow wI 3 BU @ 660 gpm wI 3850 psi. PU wt 220k, So wt 47k, torque 20k. Rotate @ 120rpm. Monitor well- static. Displace wI 947 bbls SFOBM @ 420 gpm wI 21 00 psi. Stand back 1 stand while circ. Over disp by 60 bbl, returns were 80% SFOBM/20% MOBM SPR's, monitor well-OK. Blow down top drive. POOH f/13479' to 7925'. No problems. Calc displacement 43.6 bbls, actual 60.1 Madd pass f/7925' bit depth to 7810' bit depth (115'). Logging tool fl 7840' to 7725' (115'). Good SFOBM by 75 bbls pumped. Pumping @ 500 gpm wI 2050 psi, 40 rpm. Hole started packing off. Working tight spot @ 7810-7818', hole packing off, increase rotary to 120 rpm, pumping 500 gpm. MU stand, work down to 7900' wI good circ. Circ 1 1/2 BU while working up to 7810'. Working tight spot @ 7810-7818', hole packing off, rotary @ 120 rpm, pumping 500 gpm. Work down to 7900' wI good circ. Circ while working up to 7810'. Hole still packing off @ 7818'. RIH to below where started circulating. RIH to 9194', no problenis.. POOH on elevators f/8194'-7500', to inside 9 5/8" casing. No problems. Monitor well. POOH f/7500' to 381'. Rack back stand of HWDP wI jars, PU a jt of dp- rack back 2NM flex drill collars, PJSM, remove nuke sources. Attempt to download MWD. No luck. UD MWD to download in pipe shed. Continue to work - LD BHA. Clean rig floor. PU whipstock retrieving tools fl beaver slide. MU BHA to retrieve whipstock. RIH, fill pipe every 25 stands. RIH to 6318'. PU 15 jts 5" HWDP, RIH to 7529'. PU wt 190k, SO wt 103k. Hook and pull free whipstock assembly. Stand back 1 stand. CBU @ 515 gpm wI 2950 psi. Monitor well- static. POOH wI whipstock assembly. Rabbit 75 stands dp wI 2.4" rabbit. UD Whipstock retrieving assembly. No whipstock assembly recovered. calc fill 68 bbls, actual 83 bbls Clean rig floor. Functioned blind rams. Service rig and top drive. Printed: 7/6/2005 3:50:05 PM · e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT- DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/28/2005 20:00 - 20:45 0.75 RIGMNT RSRV CMPL T2 Note: While picking 6 1/4" Bowen jars back up from ground to floor via beaver slide, Derrickman Jon Larson hurt left arm tailing jars through to floorhands on rig floor. 20:45 - 21:15 0.50 FISH PULD CMPL T2 PUlMU BHA to retrieve whipstock assembly. 21 :45 - 00:00 2.25 FISH TRIP CMPL T2 RIH wI whipstock retrieving BHA #2, fill pipe every 25 stands. RIH to 6319'. 5/29/2005 00:00 - 00:30 0,50 FISH TRIP CMPL T2 Con't RIH wI whipstock retrieving BHA#2 f/6319' to 7510', PU single dp. PU wt 185k, SO WI 105k 00:30 - 00:45 0.25 FISH FISH CMPL T2 Attempt to engage key slot in whipstock. Rotate 1/4 turn each time, latched in on 3rd attempt. 00:45 - 01 :00 0.25 FISH JAR CMPL T2 Pull to 225k on weight indicator, allow jars to hit, pull to 275k on indicator. Re-cock jars, PU and jar wI 300k on indicator, pull to 325k on indicator. Re-cotk jars, PU and jar w/300k on indicator, pulled whipstock free wI 318k on indicator. Continue PU to break off single. Dragging to as much as 235k fl first 20'. UD single dp. 01:00 - 01:15 0.25 FISH TRIP CMPL T2 Pull one stand HWDP-slow. Check fl swabbing, OK. 01:15-02:15 1.00 FISH CIRC CMPL T2 Circ one and a half BU (561 bbls) @ 420 gpm wI 1450 psi. Lost 22.2 bbls mud while circ. 02:15 - 02:30 0.25 FISH OTHR CMPL T2 Monitor well. 02:30 - 07:00 4.50 FISH TRIP CMPL T2 POOH slow wI whipstock retrieval assembly #2. Cal fill 65.04 bbls, actual 75.2 bbls. 07:00 ~ 09:00 2.00 FISH PULD CMPL T2 UD whipstock assembly (98.5') consisting of: 9 5/8" whipstock slide, debris barrier sub wI cup, ported drain sub, shear disconnect, bottom trip anchor, blanking sub, 1 jt 5" dp, 2- 5" dp pup jts, un loader sub, crossover, locator sub, seal assembly. 09:00 - 09:45 0.75 CASE RURD CMPLT2 Clean rig floor, RU casing equip to run 5.5" Blat liner. 09:45 - 10:00 0.25 CASE SFTY CMPL T2 PJSM wI all team members in running 5.5" liner. 10:00 - 12:00 2.00 CASE RUNC CMPL T2 PU/MU/RIH wI 5.5" L-80 BTCM slotted and blank liner per detail. Baker 5.5" guide shoe(no float), 5.5" 15.5 #/ft L-80 BTCM blank bent joint, 5 jts 5.5" blank, 1 jt slotted wI insert bushing @ pin end, 11jts 5.5" slotted, 7 jts 5.5" blank, 4 jts 5.5" slotted, 9 jts 5.5" blank, 5 jts 5.5" slotted, 15 jts 5.5" blank, 9 jts 5.5" slotted, 6 jts 5.5"blank, 11 jts 5.5" slotted, 7 jts 5.5" blank, 7 jts, 5.5" slotted, 7 jts, 5.5" blank, 7 jts 5.5" slotted, 6 jts 5.5" blank, 8 jts 5.5" slotted, 9 jts 5.5" blank, 3 jts 5.5" slotted, 21' blank 5.5" marker jt, 1 jt 5.5" blank, 3.77' blank 5.5" pup jt, 5.5" casing swivel, 5.5" x 7" crossover bushing, Baker Model B-1 hook hanger 9 5/8" x 7". Total length 5986.74'. Total of 18 constrictor packers were run to be placed @ 13260', 12710', 12450', 12245', 11890', 11641', 11045', 10641',10400',9910',9650',9300',9050',8700', 8500', 8134', 7780', and 7610'. Ran total of 53 jts in hole @ noon. 12:00 - 13:45 1.75 CASE RUNC CMPL T2 Continue running 5.5" L-80 BTCM 15.5 ppf L-80 slottted and blank "B" lateral liner. Total of 137+ insert + bent jt+ marker jt. 13:45 - 14:30 0.75 CASE RURD CMPLT2 RID Doyon casing tools. RU to PU Baker model B-1 Hook Hanger on 5" dp. PU/MU hook hanger. PU 93k, SO wt 63k 14:30 - 15:45 1.25 CASE RUNL CMPL T2 Run liner on 5" dp fl 5994' to 7530'. 15:45 -18:00 2.25 CASE OTHR CMPL T2 Orient bent joint to exit window. 18:00 - 23:15 5.25 CASE RUNL CMPL T2 Run 5.5" liner on open hole on 5" dp f/7530' to 13512'. PU wt 205k, SO wt 65k, Calc displacement 108 bbls, actual 119 bbls. 23:15 - 00:00 0.75 CASE OTHR CMPL T2 Orient to hook Baker B-1 95/8" x 7" hook hanger. Working pipe fl 13481' to 13515'. Turning pipe 1/4 turn, work torque and attempt to hook window. 5/3012005 00:00 - 01 :30 1.50 CASE OTHR CMPL T2 Orient to hook Baker B-1 95/8" x 7" hook hanger. Working pipe fl 13481' to 13515'. Turning pipe 1/4 turn, work torque and attempt to Printed: 716/2005 3:50:05 PM e . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 5/30/2005 00:00 - 01 :30 1.50 CASE OTHR CMPL T2 hook window. PU wt 205-225k, SO wt 75-55k. Hooked window w/61' in (4.23'low shows btm of window @ 7544.23') on stand 79. Hole taking weight on first 3 attempts to hook hanger and giving false hooks. Turned pipe 14 times until good confirmed hook. Hooked 3 times in the only place that would hook wI 61' in. Top of Baker hook hanger @ 7523.18', Baker guide shoe @ 13509.92'. Set all available weight to verify down--35k on indicator). CIRC CMPL T2 Break off top drive. Drop Baker's ball. Circ ball down @ 2bpm wI 225 psi, increase to 4bpm wI 625 psi. Slow down to 3bpm @ 1000 strokes wI 400 psi, con't pumping @ 3 bpm, ball reached seat @ 1540 strokes, increasing presure, ball seat blew @ 1725 psi. OTHR CMPL T2 Work left hand torque in pipe to release hook hanger running tool. Work pipe f/35k to 200k. Once finally released, PU wt 190-195k wlo liner. Set back down. Tag top with allDP wt available. Top in same spot-7523' (61.3' in on stand 79 w/35k on wt indicator) Pull stand 79 and set back (Pulled 61' out of hole+ 3' above floor in slips= 64'). Bottom of hook hanger ball seat, circ sub orifice BPV and guide assembly @ 7501'. PU wt 185k to 190k Circulate bottoms up @ 444 gpm wI 1500 psi. Circ total of 440 bbls. Monitor well. POOH wI Baker B-1 hook hanger running assembly. Service breaks and lay down liner running tools and ball sear, circ sub orifice BPV, and guide assemble. Clean rig floor. RU Doyon casing tools to run 4 1/2" LEM. PJSM on running LEM. PU/MU LEM assembly: Baker Seal assembly, 4 1/2" 12.6 ppf IBT box X STL pin x-o jt, (2) joints 41/2" 12.6 ppf L-80 1ST tubing, Cameo 41/2" DB nipple wI 3.563" ID profile, (1) jt 4 1/2" 12.6 ppf L-80 IBT tubing, LEM,4 1/2" 12.6 ppf L-80 IBT pup joint, 41/2" 12.6 ppf, IBT casing swivel, X-O bushing 5 1/2" hydril 563 box x 4 1/2" IBT pin, Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydri/563 box x 51/2" hydril 563 pin, Baker ZXP (7" hydril 563 pin), Saker Hydraulic setting tool, Baker running tool. While making up and lowering seàls into top of X-O below ZXP, seals hung up; ZXP sheared, slips moved to set position. RUlLO LEM BHA. Clean rig floor. RU to test BOPE. Witness of BOP test waived by AOGCC inspector John Crisp. Pull riser to check annular preventor, visual inspection. 14 day BOPE test. Tested annuiar to 250 psi low and 2800 psi high. Tested rams and valves to 250 psi low and 3500 psi high. Held each test 5 min. Tested accumulator. Tested IBOP valves and floor safety valves 250/3500, held each test 5 min. Rig down test equipment. PJSM on running LEM. PU/MU LEM assembly: Baker Seal assembly, 4 1/2" 12.6 ppf 1ST box X STL pin x-o jt, (2) joints 41/2" 12.6 ppf L-80 IBT tubing, Cameo 41/2" DB nipple wI 3.563" ID profile, (1) jt 41/2" 12.6 ppf L-80 IBTtubing, LEM, 4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf, IBT casing swivel, X-O bushing 5 1/2" hydril 563 box x 4 1/2" IBT pin, Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril563 box x 5 1/2" 01 :30 - 02:00 0.50 CASE 02:00 - 02:30 0.50 CASE 02:30 - 02:45 0.25 CASE OTHR CMPL T2 02:45 - 03:30 0.75 CASE CIRC CMPL T2 03:30 - 03:45 0.25 CASE OTHR CMPL T2 03:45 - 07:00 3.25 CASE OTHR CMPL T2 07:00 - 07:30 0.50 CASE OTHR CMPL T2 07:30 - 07:45 0.25 CASE OTHR CMPL T2 07:45 - 08:30 0.75 CMPLTN RURD CMPL T2 08:30 - 08:45 0.25 CMPL TN SFTY CMPL T2 08:45 - 10:30 1.75 CMPLTN PULD CMPLT2 10:30 - 12:00 1.50 CMPL TN PULD CMPL T2 12:00 - 12:30 0.50 CMPL TN OTHR CMPL T2 12:30 - 13:00 0.50 WELCTL BOPE CMPL T2 13:00 - 13:45 0.75 WELCTL BOPE CMPL T2 13:45 - 18:30 4.75 WELCTL BOPE CMPL T2 18:30 - 19:00 19:00 - 19:30 19:30 - 20:30 0.50 WELCTL OTHR CMPL T2 0.50 CMPL TN SFTY CMPL T2 1.00 CMPL TN PULO CMPL T2 Printed: 7/6/2005 3:50:05 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 1.00 CMPL TN PULD CMPL T2 hydrif 563 pin, Baker ZXP (7" hydrif 563 pin), Baker Hydraulic setting tool, Baker running tools. RID casing tools. RIH wI LEM to 5016' RIH wI LEM f/5016' to 7545'. PU wt 180K, SO wt 101K Tag up @ 7545', Orient and work through hook hanger. Con't RIH wI LEM assembly f/7545' to 7619'. Tag up @ 7619'. Attempt to work through- no luck, PU wt 195k, SO wt 105k. 2.25 CMPL TN OTHR CMPLT2 Tag up @ 7619'. Attempt to work through- no luck. PU wt 195k, SO wt 105k. Monitor well, POOH fl 7619' to 216'. RU and UD LEM assembly. Clean Rig Floor. PU seal assembly wI a bent joint 4 1/2" tbg, .¡. rest of LEM assembly. RU to RIH wI LEM assembly, RIH wI LEM assembly to 7619'. Tag up @ 7619'. Try to work by top of liner hanger- no luck. PU wt 185K, SO wt 107K, Rot wt 130k. 1.25 RIGMNT RSRV CMPL T2 Pull partial stand and 10' pup jt. Stand 77 in hole. Slip and cut 65' drilling line. 1.50 RIGMNT RSRV CMPL T2 Service top drive, inspect saver sub, clean rig floor. Prepare to take Oil base mud into pits. Prepare to remove solids free oif base mud fl pits and store into uprights. Prepare to take 9.0 ppg MOBM into Pits, remove 9.0 ppgSolids free oil base mud fl pits. Transfer to upright storage. Displace solids free 9.0 ppg to Mineral oif base mud 9.0 ppg @ 89 spm , (7.5 bpm) wI 900 psi. 35 bbls interface put in MOBM. SPR, monitor well. POOH with LEM assembly f/7566' to 207'. RU and UD LEM assembly. Clean Rig Floor. PU Baker tools to floor to handle 2 7/8" equiptment. MU Cleanout BHA: 4 11/16" x 3 518" Junk basket mill shoe, 3 5/8" Junk basket extension, 35/8" rev circ jet bushing, x-o , 14 jts 2 7/8" PAC drill pipe, x-o, Bowen bumper sub, Bowen Super jar, x-o (6.25" OD). RIH f/465' to 7615' wI cleanout assembly on 5" DP. Tag up @ 7615'. PU wt 156k, SO wt 106k, Rot wt 130k. Drop ball. Circ @ 210 gpm wI 900 psi ball to activate rev circ junk basket Milling f17615' to 7619' w/21 0 gpm @ 1050 psi. Rotate wI 50 rpm, torque 10-12k. Mill to 7649'. RIH wI mill -no rotation fl 7649' to 8071'. Circ @ 210 gpm w/1 000 psi. Pump Hi-vis sweep @ 320 gpm wI 2000 psi. SPR, Monitor well POOH slow fl 8071' to 7503'. RIH f/7503', took wt @ 7617', push to 7627', PU to 7580', RIH tag @ 7627', Rotate @ 50 rpm, 284 gpm wI 1650 psi. Milling f/7627' to 7635, slide fl 7635' to 7644', taking wt @ 7644', Rotate 7643' to 7646'. Torquing up @ 7646', Pull f/7646' to 7500' (up above hook hanger), RIH f/7500' to 7645', taking wt @ 7645'. Pull up above 7645', start pumping 80 spm wI 1650 psi, rotate 50 rpm, Mill on junk f/7644' to 7645', torqued up @ 7645', Pull up to 7640', free rotating, ran 7640' to 7648', taking a little wt @ 7648', PU, ran to 7712' 5/30/2005 19:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 5/31/2005 00:00 - 01:30 01 :30 - 04:30 04:30 - 05:00 0.50 CMPL TN RURD 3.00 CMPL TN TRIP 1.50 CMPL TN TRIP 3.00 CMPL TN OTHR 0.50 CMPL TN TRIP CMPL T2 CMPL T2 CMPLT2 CMPL T2 CMPL T2 05:00 - 07: 15 07:15 - 12:00 12:00 - 13:30 13:30 - 13:45 13:45 -15:00 15:00 - 20:00 20:00-21:15 4.75 CMPLTN TRIP 1.50 CMPL TN PULD 0.25 CMPL TN OTHR 1.25 CMPL TN PULD 5.00 CMPL TN TRIP 1.25 CMPL TN OTHR CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 21 :15 - 22:30 22:30 - 00:00 6/1/2005 00:00 - 01 :00 1.00 CMPL TN OTHR CMPL T2 01 :00 - 02:30 1.50 CMPL TN CIRC CMPL T2 02:30 - 02:45 0.25 CMPL TN OTHR CMPL T2 02:45 - 07:00 4.25 CMPL TN TRIP CMPL T2 07:00 " 08:30 1.50 CMPL TN PULD CMPL T2 08:30 - 09:30 1.00 FISH OTHR CMPL T2 09:30 - 11 :30 2.00 FISH PULD CMPL T2 11:30 -14:30 3.00 FISH TRIP CMPL T2 14:30 - 15:00 0.50 FISH CIRC CMPL T2 15:00 - 16:45 1.75 FISH MILL CMPL T2 16:45 - 18:30 1.75 FISH OTHR CMPL T2 18:30 - 19:45 1.25 FISH CIRC CMPL T2 19:45 - 20:00 0.25 FISH OTHR CMPL T2 20:00 - 21 :00 1.00 FISH TRIP CMPL T2 21 :00 - 21 :45 0.75 FISH TRIP CMPL T2 21 :45 - 00:00 2.25 FISH MILL CMPL T2 61212005 00:00 - bO:45 0.75 FISH MILL CMPL T2 00:45 - 01 :15 0.50 FISH MILL CMPL T2 Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 61212005 00:45 - 01:15 01:15 - 02:30 02:30 - 04:30 04:30 - 05:15 05:15 - 05:45 05;45 - 06:45 06:45 - 07:45 07:45 - 09:30 09:30 - 10:30 10:30-11:15 11:15 -12:00 12:00 - 15:45 15:45 - 16:15 16:15-18:30 18:30 - 19:00 19:00 - 19:30 19:30 - 19;45 19:45 - 21 :00 6/3/2005 21 :00 - 00:00 00:00 - 01 :30 01 :30 - 02:45 02;45 - 04:15 04:15 - 06:15 MILL CMPL T2 without rotation. MILL CMPL T2 Start rotating @ 7708' to 7729'. Slide f/7729' wlo rotation to 7837', then took wt. PU and slide to 8010'. PU , slide fl 8010; to 8052' taking a little extra wt @ 7977', slide to 8052'. PU, slide fl 8052' -8078', Rotate fl 8078' to 8087, torquing @ 8087'. PU wt 165-170K, SO wt 112k. CIRC CMPL T2 PU fl 8087' to 8078'. Pump 30 bbl hi-vis sweep@ 89 spm (316 gpm) wI 2000 psi. Calc surf-surf 6219 strokes (526 bbls). Surf to mill 112 bbls. Pump total of 9532 strokes (806.4bbls). Monitor well, POOH f/8087' to 7500'. RIH f/7500' to 8030' POOH f/8030' to 7500'. Pull tight @ 7973',7-8 k over pull. Can't POOH to above hook hanger. RIH f/7500' to 8089'. Slight bobble @ 7647'. Pump hi vis sweep. Pumping @ 90 spm, 320 g¡;Jm, wI 2050 psi. POOH f/8060' to 7500'. PU wt 165k. Pull tight @ 7647',12 k over, work pipe through, OK. RIH f/7500' to 8089'. Tag up @ 7648', work pipe, con't to 8089'. POOH fl 8089' to 7823'. No problems. PU wt 170K, SO wt 114k while on bottom. Continue POOH wI Cleanout BHA: 4 11/16" x 3 518" Junk basket mill shoe, 35/8" Junk basket extension, 3 5/8" rev circ jet bushing, x-o , 14 jts 2 7/8" PAC drill pipe, x-o, Bowen bumper sub, Bowen Super jar, x-o (6.25" OD). OTHR CMPL T2 Clean rig floor. PULD CMPL T2 RU Baker small tongs to lay down small BHA. UD 14 jts 2 7/8" DP, Break junk sub. Recovered over 1 Ib of steel junk fl 5.5" x 8.25" Weatherford spiralglider. Recovered some rubber fl Easy Solutions swell packer and ID metal fl swell packer. Clear Baker small tools fl rig floor. Clean rig floor. RU and PJSM on running Lateral Entry Module. PUlMU LEM assembly: Baker43/4" Seal assembly, 4 1/2" 12.6 ppf IBT box X STL pin x-o jt(bent), (2) joints 41/2" 12.6 ppf L-80 IBT tubing, Cameo 41/2" DB nipple wI 3.563" ID profile, (1) jt 41/2" 12.6 ppf L-80 IBT tubing, LEM, 4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf pup jt, IBT casing swivel, X-O bushing 5 1/2" hydril563 box x 41/2" IBT pin, Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril563 box x 51/2" hydril563 pin, Baker ZXP (7" hydriJ 563 pin), Baker Hydraulic setting tool, Baker running tools. 3.00 CMPL TN TRIP CMPL T2 RIH wI LEM assembly on 5" DP f/207' to 5499' 1.50 CMPLTN TRIP CMPLT2 RIH wI LEM assembly on 5" DP f/5499' to 7619'. Pu wt 170K, SO wt 110K. 1.25 CMPL TN TRIP . CMPL T2 RIH wI LEM assembly on 5" DP f/7619' to 7649' w/95k on wt indicator.:: Took slight amount ofwt@ 7635' (RS nipple), worked pipe, Run to 7647' (x-o bushing), set down 15K, worked pipe down to 7649' wI 95k on indicator. Saw some over pull to 195k when picked up (25k over). 1.50 CMPL TN TRIP CMPL T2 Work LEM down f/7649' to 7655' w/95k on indicator.:: Taking a little weight @ 7652', work down to 7655', then to 7655' w/95k on indicator. Picked up w/170K. SO wt 111 k. 2.00 CMPL TN TRIP CMPL T2 PU f/ 7655' to 7500', rotate pipe 1/2 round, slack off, tag up @ 7647' (x-o bushing), work, then PU again, rotate 1/4 turn, Tag up again, PU to 7500', turn 1/4, slack off to 7655' w/95k on indicator. Dragging to 0.50 FISH 1.25 FISH 2.00 FISH 0.75 FISH 0.50 FISH 1.00 FISH 1.00 FISH 1.75 FISH 1.00 FISH 0.75 FISH 0.75 FISH 3.75 FISH 0.50 FISH 2.25 FISH TRIP TRIP TRIP CMPL T2 CMPL T2 CMPL T2 TRIP CMPL T2 CIRC CMPL T2 TRIP CMPL T2 TRIP CMPL T2 TRIP CMPL T2 TRIP CMPL T2 0.50 FISH OTHR 0.50 FISH OTHR 0.25 CMPL TN SFTY 1.25 CMPL TN PULD CMPL T2 CMPL T2 CMPL T2 CMPL T2 Printed: 71612005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/312005 04:15 - 06:15 2.00 CMPLTN TRIP CMPL T2 185-190k wI PU, then free. 06:15 - 08:30 2.25 CMPL TN TRIP CMPL T2 Work pipe while circ @ 56 spm (199 gpm) wI 500 psi. PU wt 170k, SO wi 106, set down 65k, no extra movement down. 7655' final depth reached wI mule shoe and 95k on wi indicator.. 08:30 - 12:00 3.50 CMPL TN TRIP CMPL T2 Monitor well, POOH f17655' to 4307'. PU wt 172k, SO wi 110K 12:00 -13:30 1.50 CMPL TN TRIP CMPLT2 Continue POOH wI LEM assembly f/4307' to 207'. 13:30 -15:30 2.00 CMPL TN PULD CMPL T2 RU small tools and ready floor, Lay down 4 1/2" LEM assebly. 15:30 -16:00 0.50 CMPL TN OTHR CMPL T2 Clear and clean rig floor. 16:00 -17:00 1.00 WELCTL EQRP CMPL T2 . Change bottom pipe rams f/5" to 2 7/8", RU to test rams. 17:00 -17:45 0.75 WELCTL BOPE CMPL T2 Test bottom pipe rams to 250 psi low and 3500 psi high. Chart test. .17:45 - 19:00 1.25 FISH RURD CMPL T2 RU to MU small tool string to clean out A2 liner. 19:00 -19:15 0.25 FISH SFTY CMPLT2 PJSM on picking up small string to clean out liner. 19:15 -19:45 0.50 FISH PULD CMPLT2 MU 411/16" x 3 5/8" JB mill shoe, 35/8" junk basket extension, 3 5/8" rev circ jet bushing, x-o, x-o. 19:45 - 00:00 4.25 FISH TRIP CMPL T2 PUlMU 198 jts 2 7/8" 6.4ppf, L-80, hydril 511 tubing. 6/4/2005 00:00 - 02:45 2.75 FISH TRIP CMPL T2 Con't PU/MU 198 jts 2 7/8" 6.4ppf, L-80, hydril511 tubing to 5823'. PU wi 57k, SO wi 45k Drifted 2 7/8" wI 2" rabbit. 02:45 - 03:15 0.50 FISH OTHR CMPL T2 Rig down tongs fl handling 2 7/8". RUto handle a jt of 3 1/2" dp. 03: 15 - 04:30 1.25 FISH PULD CMPL T2 PU/MU Baker tools.:: double pin x-o, (2) boot baskets, bit sub, x-o, Bowen bumper sub, Bowen super jar, x-o. SO wi 47k 04:30 - 04:45 0.25 FISH TRIP CMPL T2 SLM, RIH 70' of first stand of 5" DP. 04:45 - 05:15 0.50 FISH CIRC CMPL T2 Circ drill string volume plus a little (50 bbls). 61 spm = 1850 psi. Check out torque. 50 rpm 1 k torque. PU wi 60k, SO wi 48k, rot wi 53k. 05:15 - 06:00 0.75 FISH TRIP CMPL T2 RIH wI cleanout assembly on 5" dp. Taking a little weight @ 7650'. 06:00 - 06:45 0.75 FISH TRIP CMPL T2 Taking a little weight @ 7650'. Continue till through CSR (bottom @ 7669'), then again @ 7708'. PU wi 90k, SO wt 69K, slack off to as much as 60K. Screw into 5", establish rotation wI 2000 ftllb torque. Rot wi 79k. 06:45 - 07:30 0.75 FISH TRIP CMPL T2 Continue RIH wI clean out assembly on 5" DP f/7708' to 8080'. No problems 07:30 - 09: 15 1.75 FISH CIRC CMPL T2 RU to displace well fl MOBM to solids free oil base mud @ 8080'. Circ @ 55 spm (4.65 bpm) (195 gpm) wI 1800 psi. 09:15 - 09:30 0.25 FISH OTHR CMPL T2 Check fl flow, OK. 09:30 - 10:00 0.50 FISH CIRC CMPL T2 Drop 5/8" ball to activate rev basket jet. Pump ball down @ 60 spm (5 bpm) (213 gpm) wI 2050 psi. 10:00 - 11 :30 1.50 FISH MILL CMPL T2 Mill fl 8093' to 8098'. PU wi 90k, SO wi 65k, Rot wi 83k, torque 2500-3000 ftllb. Pump 60 spm (5 bpm) (213 gpm) w/21 00 psi. 50 rpm 11 :30 - 12:00 0.50 FISH OTHR CMPL T2 Continue w/4 11/16" mill and rev basket cleanout assembly f/8098' to 8189'. 8226' 12:00 - 00:00 12.00 FISH OTHR CMPL T2 Continue w/4 11/16" mill and rev basket cleanout assembly fl 8189' to 12050'. Tagging collars every +1-42'. PU wi 155k, SO wi 63k. Tag @ 8226', mill @ 8224', then slide to next collar 8268', then slide to 8562' then to 8718', slide 8718'-9028', 9072' took WI, work past to 10214', work past, slide to 10345', worked past, slide to 10515', work pastto 10645', work past, slide to 11200', hung up @ 11240', worked thru, slide to 11460'. 6/5/2005 00:00 - 02:45 2.75 FISH OTHR CMPL T2 Continue w/4 11/16" mill and rev basket cleanout assembly f/12050' to 13155'. Pumping 60 spm (5 bpm) wI 21 00-2400 psi. PU wi 190-195k, SO wi 82K 02:45 - 03:00 0.25 FISH OTHR CMPL T2 Continue w/4 11/16" mill and rev basket clean out assembly f/13155' to 13341'. Pumping 60 spm (5 bpm) wI 2475 psi. PU wi 190-195k, SO wi Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/512005 02:45 - 03:00 0.25 FISH OTHR CMPL T2 82K Rot wt 127k, torque 13-14k to rotate. Note: Insert bushing is @ 13247' in "B" lateral. Insert bushing in A2 is @ 13452') SLM of 78 stands 2.35' longer. No correction 03:00 - 04:00 1.00 FISH OTHR CMPLT2 Approaching top of hook hanger wI upper mill (704" OD). Slack off 9.5', PU to 205K then free. Slack off while rotating, slight indication of top @ 8' in while rotating (13349.73'), rotate to 10' in (13251.73'). PU, start rotation again and slack off to 11' in (13352.73). PU wI 215k. Free up. 04:00 - 06:15 2.25 FISH CIRC CMPL T2 Circ HiNis sweep w/4 11/16"mill @ 13350' (8' in onjt after stand 78). Therfore the 7.4" mill is @ 7521.65'. Calculated surf- surf 641.8 bbls (7586 strokes). Circ @ 60 spm (5 bpm) 213 gpm wI 2500 psi.. ANN velocity in 5 1/2" x 27/8" = 316 ftlmin. 9 5/8" csg x 27/8" = 73 ftlmin. 9 5/8" x 5" dp = 97 ftImin. PU wt 193k, SO wt 85k. Monitor well. OK. POOH wI cleanout assembly f/13350' to 6355' Continue POOH wI clean out assembly f/6355' to 5889'. UD 3 1/2" dp & Baker tools.:: double pin x-o, (2) boot baskets, bit sub, x-o, Bowen bumper sub, BoWen super jar, x-o. SO wt 47k RID 3 1/2" handling tools, RUto UD 27/8" tubing. PJSM on laying down 2 7/8" tubing. UD 198 jts of 2 7/8" 6.4 ppf L-80 Hydril 511 tubing. Break and UD 411/16" x 3 518" JB mill shoe, 35/8" junk basket extension, 3 5/8" rev circ jet bushing, x-o, x-o. Clean out junk basket. Recovered 18 pounds 3 oz of metal fl 5 1/2" x 8 1/4" Weatherford spiralgliders. RID tools fl handling 2 7/8". RID Doyon double stack tongs. Clean rig floor. Pull wear bushing, set test plug. Prepare to change rams f/27/8" to 5" in lower BOPE. Change lower rams f/2 718" to 5". RU test equip. Test lower rams to 250 psi low and 3500 psi high, 5 min each. Charted test. Called AOGCC inspector Jeff Jones. Pull test plug, install Vetco Gray wear bushing, UD tools. RU to run Baker LEM. PJSM on running Baker LEM assembly, PU/MU LEM assembly: Baker4 3/4" Seal assembly, 41/2" 12.6 ppf IBT box X STL pin x-o jt(bent), (2) joints 4 1/2" 12.6 ppf L-80 IBT tubing, Cameo 41/2" DB nipple wI 3.563" ID profile, (1) jt 41/2" 12.6 ppfL-80 1ST tubing, LEM, 41/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf pup jt, IBT casing swivel, X-O bushing 5 1/2" hydril 563 box x 4 1/2" IBT pin, Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril 563 box x 5 1/2" hydril 563 pin, Saker ZXP (7" hydril 563 pin), Baker Hydraulic setting tool, Baker running tools. 04:30 - 04:45 0.25 CMPL TN RURD CMPL T2 RID equip. 04:45 -10:00 5.25 CMPLTN TRIP CMPLT2 RIH wI LEM assembly on 5" DP f/207' to 7523' (Fill pipe every 25 stds). Run assy through Hook Hanger to 7544' tag up bttm of window. PU and orient string 1/4 turn. RIH and only saw a few small bobbles on indicator. RIH to top of A2 ZXP @ 7619'. Up wt 189K, DN wt 105K. Work seals and set LEM in place. Had good solid location on depth and showed 20K releasefrorn locator ring when PU. Top of LEM @ 7509' MD (end of seals @ 7662' MD) Seals buried 12.57' in CSB 19.48' long. 10:00 - 11:15 1.25 CMPLTN PCKRCMPLT2 Drop Ball and pump to seat - Set ZXP Packer - Pressure up to 2500 psi and hold for 3-4 min. Work psi up to 4000 psi in 500 psi steps holding 06:15 - 06:30 0.25 FISH OTHR CMPL T2 06:30 - 12:00 5.50 FISH TRIP CMPL T2 12:00 -12:15 0.25 FISH TRIP CMPL T2 12:15 -13:00 0.75 FISH PULD CMPL T2 13:00 - 14:00 1.00 FISH RURD CMPL T2 14:00 -14:15 0,25 FISH SFTY CMPL T2 14:15 - 21:15 7.00 FISH PULD CMPL T2 21:15 -21:45 0.50 FISH PULD CMPL T2 21 :45 - 22:30 0.75 FISH RURD CMPL T2 22:30 - 23: 15 0.75 FISH OTHR CMPL T2 23:15 - 00:00 0.75 WELCTL EQRP CMPL T2 6/6/2005 00:00 - 01 :30 1.50 WELCTL BOPE CMPL T2 01 :30 - 02:00 0.50 WELCTL BOPE CMPL T2 02:00 - 02: 15 0.25 CMPL TN RURD CMPL T2 02:15 - 02:30 0.25 CMPL TN SFTY CMPL T2 02:30 - 04:30 2.00 CMPL TN RUNT CMPL T2 Printed: 71612005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 20:45 - 21:15 0.50 CMPL TN OTHR CMPL T2 21:15 - 21:45 0.50 CMPL TN PULD CMPL T2 21:45 - 23:15 1.50 RIGMNT RSRV CMPL T2 23:15 - 00:00 0.75 RIGMNT RSRV CMPL T2 6/7/2005 00:00 - 02:00 2.00 CMPL TN OTHR CMPL T2 02:00 - 02:15 0.25 FISH PULD CMPL T2 02: 15 - 03:45 1.50 FISH TRIP CMPL T2 03:45 - 05:00 1.25 FISH TRIP CMPL T2 05:00 - 06:30 1.50 FISH TRIP CMPL T2 06:30 - 07:45 1.25 FISH TRIP CMPL T2 61612005 10:00.-11:15 1.25 CMPL TN PCKR CMPLT2 each 3-4 min. Had no indication of packer set. Work wt from 50k DN , 205K up 11: 15 - 13:30 2.25 CMPL TN PCKR CMPL T2 Con't to attempt to set packer with pressure. Worked pressure from 2500 psi to 4000 psi 2 times without any sign of setting. Attempt to pressure up csg ann pumping down back side. Will not pressure up. Pumped 73 stks (6.2 bbls) 425psi. Worked pressure from 2500 psi to 4500 psi 3 times with no indication of packer setting. At this point we tryed to surge drill string. Pressuring up to 1000 psi and then release the pressure swiftly to surge the drill string. Afterword we attempted to pressure up 2500 psi to 4500 psi again to set packer. No indication. We attempted to pressure up again on thecsg ann. Will not test, Pumped 65 stks (5.5 bbls) During all attempts worked wt from 50K DN wt, 205K Upwt. 13:30 - 14:45 1.25 CMPL TN PCKR CMPL T2 After discussion with Baker Supv, Well Engineer and Rig Supv it was decided to safety off the ZXP with left had torq. The baker procedure on this tool is to work the wt from neutral point, torq string with left hand from 1/2 to 3/4 turn while working wt from 60K to 21 OK. 6 1/4 rounds of torque was worked down the string with no indication of a release. The LEM snap out up wt remained 220k and no sign of release was seen. 14:45 - 20:45 6.00 CMPLTN TRIP CMPLT2 Monitorwell, POOH wI LEM assembly (inspecting Lo-Tads on 5" dp, cahnged out Lo-tad on stand #10, #8 & #6). Drill string started pulling dry @ 896'. Calc displ 71.4 bbls, actual 89.7 bbls. No LEM assembly on end of DP. Running tools only. Clean rig floor. Break and lay down Baker running tool. Slip and cut drilling line. Service top drive. Recalibrateblock height fl Sperry Sun MWD fl depth tracking. Cleaned rig floor. Change out dies in rig tongs and on iron roughneck while waiting on running tool MU Baker HRD liner running tool to retrieve LEM assembly. RIH wI Baker LEM retrieval tools on 5" DP f/20' to 2415'., fill pipe @ 25 stands (2415', PU wt 75k, SO wt 69K, circ @ 22 spm (78 gpm) wl1 00 psi.) Con't RIH wI Baker LEM retrieval tools on 5" DP f/2415' to 4829'., fill pipe @ 25 stands (4829', PU wt 110k, SO wt 74K, circ @ 22 spm (78 gpm) wI 180 psi.) Con't RIH wI Baker LEM retrieval tools on 5" DP f/4829' to 6737'., mud started running over the top once started running HWDP (6360'), runs over 10' above floor, PU wt 155k, SO wt 92K, Con't RIH wI Baker LEM retrieval tools on 5" DP fJ 6737' t07386' and latched onto LEM, mud running over top 10' above floor, PU wt 189k, SO wt 105K, - Tag up solid at 7386' (This point by calulation would be the coupling at the top of the seals ( 21' up from mule shoe) tagging out at the 4.86"ID XO bushing 8.62' below bUm of window "S" La!. 07:45 -12:30 4.75 FISH TRIP CMPLT2 POOH with fish from 7,386' to running tool at 210', st wt up wt 195K- Appears to have additional weight to equal LEM assy, Pulling speed was kept slow to reduce swabbing. Hole took proper fill 12:30 -14:30 2.00 FISH PULL CMPL T2 LD running tool and LEM, at surface it was seen the retreiving tool worked as designed, made full insertion and latched. No damage was noted on the LEM assy only minor scoring. The seal assy did have scoring around the packing stem and the seals had to be replaced. All scoring marks were dressed with emery cloth to remove all sharp edges. Remove all tools and clean OSM from rig floor. Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 0.75 CMPL TN RURD CMPL T2 Remove old tools from shed and load in new ZXP packer, Finished installing new seals. Held PJSM with Baker rep on MU LEM assembly. PU LEM assembly #2 with ZXP packer and RIH to 210' RIH with LEM assembly on 5" DP from 210' to 7,523' to hook hanger, st wt up 195K, dn wt 105K 0.50 CMPL TN TRIP CMPL T2 Oriented LEM and located hook hanger at 7,523' and landed same with ZXP packer top at 7,462', snapped in & out of hanger several times to verify on depth and latching into hook hanger 1.00 CMPL TN PCKR CMPL T2 Dropped 1 3/4" phenolic ball and pumped down to seat, pumped down at 3.5 bpm at 380 psi, pressured up to 2,500 psi to set packer, then pressured up to 4,000 psi to release from setting tool, no problems setting packer Pressure tested ZXP packer and annulus to 1,000 psi for 5 min, good test PU out of ZXP packer, then rotated DP while setting 75K st wt down on packer, rotated at 15 rpm's with 14K ft-Ibs torque with 128K rot wt Began POOH with runnin9 tool, POOH from 7,462' to 7,382' POOH with Baker LEM running tool from 7,382' to 20' Made service breaks on running tool and LD same, cleared rig floor Held PJSM with Baker Rep, Sperry Sun and crew on PU & MU of whipstock assembly MU Baker 9 5/8" btm trip whipstock assembly BHA #15 and RIH to 580', MU seal assembly, locator sub, un loader sub, then PU 1-DP pup jt & 5 jts of 5" DP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD, PU 9-6 3/4" Dc's and RIH to 580' RIH with whipstock assembly from 580' to 6,850', RIH with 13 stds of 5" HWDP above 6 3/4" Dc's Made MADD pass from 6,850' to 6,885 (sensor depth 6,600'"6,635') and correlated MWD to K~13, circ at 450 gpm's at 2,100 psi RIH from 6,885' to 7,145' Oriented whipstock 15 deg's left of high side and tagged top of LEM at 7,462', set whipstock and sheared off from same, top of whipstock at 7,258' MD/3,528' TVD, st wt up 200K, dn wt 83K, RIH with whipstock milling assembly with 3 stds 6 3/4" Dc's, 13 stds of 5" HWDP and 57 stds of 5" DP with Lo-tads 1.25 WINDOVlfCIRC PROD3 Displaced hole over from 9.0 ppg SFMOBM to 9.05 ppg MOBM, circ at 568 gpm at 3,000 psi 5.50 WINDOVIISTWP PROD3 Milled 8 1/2" window for "D" sand lateral from 7,258' to 7,274', cont to mill to 7,304' MD/3,539' TVD (46'), ADT 5.5 hrs, milled at 2-1 OK wob, 90-120 rpm's, 490 gpm at 2,350 psi, off btm torque 13K ft-Ibs, on btm 8-20K ft-Ibs, rot wt 118K, upwt 185K, dn wt 85K, (20' of gauge hole below window for Geo-Pilot) last 2' took 15K wob to drill due to possible concretion Pumped 30 bbl weighted hi vis sweep and circ hole clean while working mills thru window, circ at 500 gpm at 2,400 psi, worked milis thru window without pumping and window looks good. Monitored well-static, pumped dry job POOH with whipstock milling assembly from 7,304' to 6,886' POOH with whipstock milling assembly from 6,886' to 380', stood back HWDP POOH LD 9-6 3/4" Dc's from 380' to 104' 6/7/2005 14:30 - 15:15 15:15 - 15:30 15:30 - 16:45 16:45 - 21 :30 0.25 CMPL TN SFTY CMPL T2 1.25 CMPL TN PULD CMPL T2 4.75 CMPLTNTRIP CMPLT2 21 :30 - 22:00 22:00 - 23:00 23:00 - 23:15 0.25 CMPL TN DEQT CMPL T2 23:15-23:30 0.25 CMPL TN PCKR CMPL T2 23:30 - 00:00 0.50 CMPL TN TRIP CMPL T2 6/8/2005 00:00 - 02:45 2.75 CMPLTNTRIP CMPL T2 02:45 - 03:30 0.75 CMPLTN PULD CMPL T2 03:30 - 03:45 0.25 WINDOVIISFTY PROD3 03:45 - 09:00 5.25 WINDOWPULD PROD3 09:00 - 13:30 4.50 '{VINDOWTRIP PROD3 13:30 - 13:45 0.25 WINDOVVCIRC PROD3 13:45 - 14:15 0.50 WINDOWTRIP PROD3 14:15 - 14:45 0.50 WINDOVIISETW PROD3 14:45 - 16:00 16:00 -21 :30 21 :30 - 23:00 1.50 WINDOVVCIRC PROD3 23:00 - 23:15 0.25 WINDolTHR PROD3 23:15 - 00:00 0.75 WIND0:ERIP PROD3 6/9/2005 00:00 - 03:00 3.00 WINDOWTRIP PROD3 03:00 - 03:45 0.75 WINootULD PROD3 Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: Downloaded MWD and L[} same, cont to POOH and LD Mills, upper 8 1/2" mill in gauge, cleared rig floor, note inspected saver sub while clearing rig floor and sub ck ok Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing MU 8 1/2" BHA #16 and RIH to 105', MU bit #110n Geo-pilot rotary system with Stratasteer LWD/MWD/PWD, uploaded MWD and shallow tested tool, held PJSM and loaded radioactive sources RIH to 105' RIH with BHA #16 from 104' to 7,231', RIH with flex Dc's, HWDP, jars and 5" DP, note ran 1 ghost reamer 1,042' back from bit and 2nd ghost reamer 2,533' back from bit. RIH from 7,231' to top of window at 7,258', washed down from 7,258' to 7,304', no problems going thru window, washed down at 500 gpm at 2,125 psi, rot wt 106K, up wt 150K, dn wt 80K Directionally drilled 8 1/2" hole in "D" sand lateral with Geo pilot rotary steerable system from 7,304' to 8,235' MD/3,514' TVD (931') ADT 6.88 hrs, from 7,304' to 7,808' drilled at 10-20K wob, 60-120 rpm's, 500 gpm, off btm pressure 2,200 psi, on btm 2,300 psi, from 7,808' drilled at 10-20K wob, 130 rpm's, 165 spm, 585 gpm, 2,900 psi, off btm torque 13K ft-Ibs, on btm 11 K ft-Ibs, rot wt 101 K, up wt 165K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.7 ppg, ave BGG 130 units, max gas 265 units. Drilled out of zone from 7,450' MD/3,563' TVD to 7,884' MD/3,549' TVD (434') 12.00 DRILL DRLG PROD3 Directionally drilled 81/2" hole in "D" sand lateral with Geo pilot rotary steerable system from 8,235' to 9,200' MD/3,486' TVD (965') ADT 7.75 hrs, 5-20K wob, 130 rpm's; 170 spm, 600 gpm, 3,100 psi, off btm torque 14-15K ft-Ibs, on btm 13-14K ft-Ibs, rot wt 105K, up wt 185K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 175 units, max gas 669 units. 12.00 DRILL DRLG PROD3 Directionally drilled 81/2" hole in "D" sand lateral from 9,200' to 9,625 MD/3,490' TVD (425') ADT 6.41 hrs, while drilling concretions would drill with 25-35K wob, 90 rpm's, 510 gpm at 2,300 psi, while drilling sand would drill at 5-15K wob, 130 rpm's, 175 spm, 620 gpm at 3,175 psi, off btm torque 15-17K ft-Ibs, on btm 13-14K ft-Ibs, rot wt 105K, up wt 173K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 120 units, max gas 487 units. 3.00 DRILL DRLG PROD3 Directionally drilled 81/2" hole in "D" sand lateral from 9,625' to 9,736 MD/3487' TVD (111 ') ADT 2.36 hrs, while drilling concretions would drill with 20-35K wob, 80-90 rpm's, 510 gpm at 2,300 psi, while drilling sand would drill at 10-15K wob, 130 rpm's, 175 spm, 620 gpm at 3,175 psi, off btm torque 14-17K ft-Ibs, on btm 14K ftllbs, rot wt 105K, up wt 175K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 120 units, max gas 345 units. After drlg thru concretion attempted to build angle by adjusting rpm's and pump rates and was unable to get acceptable build rate, no oil light came on the Geo-Pilottool at 00:35 hrs Monitored well-static, backreamed out.of hole from 9,736' to 8,674' MD. 90 rpm's 90, 600 gpm at 3,000 psi and 14k ft-Ibs torque POOH on elevators from 8,674' to 7,518', had small tight spot @ 7615, pulled 20K over pull and wipe clean, hole taking proper fill, pulled 25-30K over at 7,518' and swabbed and packed off slightly Pumped out of hole from 7,518' to 7,231' and clean up balled stab's at window, pumped out at 318 gpm at 1,100 psi. Assembly clean and 6/9/2005 03:45 - 05:30 1.75 WINDOIJIJPULD PROD3 05:30 - 06:30 1.00 WINDOlJliOTHR PROD3 06:30 -10:15 3.75 DRILL PULD PROD3 10:15 -13:45 3.50 DRILL TRIP PROD3 13:45 - 14:15 0.50 DRILL REAM PROD3 14:15 - 00:00 9.75 DRILL DRLG PROD3 6/10/2005 00:00 -12:00 12:00 - 00:00 6/11/2005 00:00 - 03:00 03:00 - 05:30 2.50 DRILL TRIP PROD3 05:30 - 07:15 1.75 DRILL TRIP PROD3 07:15 - 08:30 1.25 DRILL TRIP PROD3 Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/11/2005 07:15 - 08:30 1.25 DRILL TRIP PROD3 08:30 - 08:45 0.25 DRILL OBSV PROD3 08:45 -12:30 3.75 DRILL TRIP PROD3 12:30 -15:15 2.75 DRILL PULD PROD3 15:15 - 15:30 15:30 - 21 :30 0.25 DRILL PULD PROD3 6.00 WELCTL BOPE PROD3 21 :30 - 21 :45 0.25 DRILL PULD PROD3 21 :45 - 00:00 2.25 DRILL PULD PROD3 6/12/2005 00:00 - 00:15 0.25 DRILL PULD PROD3 00:15 - 03:45 3.50 DRILL TRIP PROD3 03:45 - 05:00 1.25 RIGMNT RSRV PROD3 05:00 - 05:15 0.25 DRILL REAM PROD3 05:15 - 07:00 1.75 DRILL TRIP PROD3 07:00 - 08"45 1.75 DRILL REAM PROD3 08:45 - 12:00 3.25 DRILL DRLG PROD3 12:00 - 00:00 12.00 DRILL DRLG PROD3 6/13/2005 00:00 - 02:45 2.75 DRILL DRLG PROD3 02:45 -.04:00 1.25 DRILL REAM PROD3 pulling good, hole taking proper fill. Monitored well above window and well was static, pumped dry job and blow down Top drive. POOH from 7,231' to 381' Stood back HWDP, jars and flex Dc's, held PJSM and removed radioactive sources, downloaded MWD and LD BHA #16 and cleared rig floor, found seals to have gone out of Geô-Pilot tool. Calc hòle fill 63.5 bbls, Actual fill 72.25 bbls Pulled Wear bushing RU and tested valves, rams and manifold to 250 psi high, 3,500 psi low, tested annular to 250 psi low and 2,800 psi high, tested LEL & H2S alarms along with high flow and trip tank alarms, Note: Chuck Scheve with AOGCC waived witnessing of test Installed wear bushing MU 81/2" BHA #17 and RIH to 123', MU bit #12 on Geo-pilot rotary system with Stratasteer LWDIMWDIPWD, uploaded MWD and shallow testèd tool breaking in bearings on Geo-pilot Held PJSM and loaded radioactive sources RIH with flex Dc's, HWDP and jars with BHA #17 from 123' to 7,039', While RIH began to take 10-15K dn weight at 7,060', PU to 7,039' Slip and cut 71' of drlg line Washed down from 7,039' to 7,138', washed down at 500 gpm, 2,200 psi, st up wt 165K, dn wt 80K RIH from 7,138' to 9,260', no problems going thru window, while RIH at 9,260' string dn wt was down to 50K Precautionary washed and reamed down from 9,260' to btm at 9,736', initial circ rate 200 gpm at 700 psi and staged circ rate up to 500 gpm at 2,500 psi and 100 rpm's, no problems washing to btm Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 9,736' to 10,082' MDI 3,483' TVD (346') ADT 1.9 hrs, 12-15K wob, 120 rpm's, 130 spm, 460 gpm, 2,250 psi, off btm torque 13K ft-Ibs, on btm 11-12K ft-Ibs, rot wt 103K, up wt 185K, dn wt 55K, 9.1 ppg MOBM, ave ECD 11.0 ppg, ave BGG 100 units, max gas 285 units Drilled 8 1/2" hole in "D" sand lateral with Geo"pilot rotary steerable from 10,082' to 11,435' MD/3,470' TVD (1,353') ADT 7.93 hrs, varied drilling perimeters in attempt to get Geo-pilot to steer due to soft sands and concretions, 1 0-25K wob, 90 - 130 rpm's, 130 spm, 460 gpm at 2,350 psi to 170 spm, 600 gpm at 3,550 psi, off btm torque 14-16K ft-Ibs, on btm 14-15K ft-Ibs, rot wt 104K, up wi: 205K, dn wt 40K, 9.05 ppg MOBM, ave ECD 11.5 ppg, ave BGG 150 units, max gas 1008· units, NOTE: Re-positioned camp on 1 E pad for Doyon 15 to move onto pad, camp off highline from 10:00 to 17:00 hrs Drilled 8 1/2" hole in "D" sand Lateral from 11,435' to 11,672' MDI 3,480' TVD (237') ADT 2.33 hrs, crossed fault at 11,334' MDI 3,465' TVD, anticipated throw 30', actual 20', while attempting to built angle with no succes drilled down into "C" shale, Drilled into "C" shale at 11,625'MD/3,488' TVD and drilled out of "C" back into "D" at 11,753' MD/3,477' TVD Backreamed out of hole slowwhile geologist evaluated log, began backreaming out at 600 gpm and at 11,650', #1 mud pump had a valve problem, cont to backream out to 11,358' at 355 gpm, 1,500 psi at 130 rpm's, circ a calc btms up, repaired valve on pump, found a piece of camlock rubber in valve Printed: 7fSfZ005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/13/2005 04:00 - 04:45 0.75 DRILL REAM PROD3 Washed down from 11,385' to 11,672', washed down at 142 gpm at 500 psi due to little down wt and drag 04:45 -12:00 7.25 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 11,672' to 12,094' MD/3,435' TVD (422') ADT 4.27 hrs, varied drilling perimeters in attempt to get Geo-pilot to build angle, while drilling in "C" shale was able to get adequate build rate, drilled with 10-25K wob, 90 - 130 rpm's, 130 spm, 460 gpm at 2,500 psi to 170 spm, 600 gpm at 3,600 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs, rot wt 104K, up wt 180K, dn wt 50K, 9.0 ppg MOBM, ave ECD 11.6 ppg, ave BGG 150 units, max gas 670 units, 12:00 - 00:00 12.00 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 12,094' to 12,688' MD/3,420' TVD (416') ADT 5.77 hrs, drilled with 9-25K wob, 130 rpm's, 146 spm, 520 gpm at 2,800 psi to 170 spm, 600 gpm at 3,700 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs, rot wt 109K, up wt 195K, dn wt 35K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 200 units, max gas 895 units, began PU 5" HWDP at 12,343' 6/14/2005 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable from 12,688' to 13,530' MDI 3,396' TVD (842') (T.D.) ADT 6.79 hrs, drilled with 10-25K wob, 90-130 rpm's, 166spm, 590 gpm at 3,850 psi, off btm torque 18·20K ft-Ibs, on btm 20-22K ft-Ibs, rot wt 125K, up wt 230K, dn wt 35K, (Blk Wt) 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 200 units, max gas 1,065 units, Cont to PU HWDP to TD well, drilled thru numerous concretions, lost approx 73 bbls MOBM while drlg 12:00 -12:15 0.25 DRILL OBSV PROD3 Monitored well-static 12:15 - 00:00 11.75 DRILL REAM PROD3 Backreamed out of hole from 13,530' to 7,775', BROOH at drlg rate at 130 rpm's, 586 gpm, fCP 3,900 psi, FCP 2,750 psi, rot wt 100K, up wt 180K, dn wt 78K, packed of while BROOH at 11,783',11,575',11,216', 10,690' and 7,858', lost approx 88 bbls of 9.0 ppg MOBM while BROOH 6/15/2005 00:00 - 00:30 0.50 DRILL REAM PROD3 Pumped 35 bbl weighted hi vis sweep and BROOH from 7,775' to 7,718', BROOH at 500 gpm, 2,400 psi and 100 rpm's, had 30% increase in cuttings back from sweep rot wt 100K, up wt 180K, dn wt 78K MADD pass for caliper log from 7,718' to 7,250', logged at 400 gpm, 1,400 psi and 50 rpm's, packed off at 7,560', 7,480' and 7,425' while logging out, POOH thru window to 7,138' with no problems in window Circ hole clean above window at 7,138', circ at 620 gpm, 2,800 psi, 130 rpm's with 1 0-12K ft-Ibs torque, circ 4X btms up and clean at shakers, had a large amount of shale back at btms up Repaired hyd. leak on filter housing on top drive Serviced top drive and drawworks RIH from 7,138' to 13,530', no problems RIH and going thru window, changed out 3 Lo-tads while RIH Pumped 35 bbl weighted hi vis sweep and circ 2 1/2X btms up and was clean at shakers, saw no increase in cuttings back from sweep, circ at 160 spm, 568 gpm,3,925 psi, 100 rpmswith 17-18K ft-Ibs torque Displace hole over from 9.0 ppg MOBM to 9.1 ppg SFMOBM, initial circ rate 568 gpm at 3,925 psi, final circ rate 547 gpm at 3,925 psi at 130 rpm's, rot wt 125K, up wt 225K, dn wt 55K Monitored well-static, obtained SPR's POOH on elevators from 13,530' to 7,230', no problems in open hole or pulling thru window Monitored well at window, well-static, dropped 2" rabbit POOH from 7,230' to BHA at 385' 00:30 - 04:00 3.50 LOG DLOG PROD3 04:00 - 06:00 2.00 DRILL CIRC PROD3 06:00 - 07:00 1.00 RIGMNT RGRP PROD3 07:00 - 07:30 0.50 RIGMNT RSRV PROD3 07:30 - 11 :30 4.00 DRILL TRIP PROD3 11:30 -13:30 2.00 DRILL CIRC PROD3 13:30 -14:45 1.25 DRILL CIRC PROD3 14:45 - 15:00 0.25 DRILL OBSV PROD3 15:00 -19:15 4.25 DRILL TRIP PROD3 19:15 -19:30 0.25 DRILL OBSV PROD3 19:30 - 22:15 2.75 DRILL TRIP PROD3 Printed: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1E-105 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/15/2005 22:15 - 00:00 6/16/2005 00:00 - 02:15 02: 15 - 02:45 02:45 - 07:15 07:15 - 07:45 07:45 - 08:15 08:15 - 13:15 13:15 -15:00 1.75 DRILL PULD PROD3 POOH LD 5 jts HWDP and jars, LD 2-NM Flex Dc's, held PJSM and removed radioactive sources, plugged into MWD and began downloading MWD, POOH to 139', calc fill on trip out 114 bbls, actual fill 140 bbls 2.25 DRILL PULD PROD3 Fin downloading MWD and LD remaining BHA #17, MWD and Geo-pilot, cleared rig floor 0.50 CASE RURD CMPL T3 RU Doyon's liner running equipment and held PJSM with rig crew and tong operator 4.50 CASE PULR CMPLT3 PU and RIH with 51/2",15.5#, L-80, STeM Liner with torque rings per well program to 6,068' (144 Jts total), ran 5 1/2" ROT silver bullet guide shoe with no float, ran a total of 71 jts (3,034') of 5 1/2" 15.5#, L-80, BTCM blank liner, ran 73 jts (3,075') of 5 1/2", 15.5# L-80 STeM slotted liner, ran 141 - 5 1/2" x7 5/8" x 8" aluminum solid body centralizers 1/jt #2 thru #143, ran 16 constrictor packers placed on blank liner to cover shale sections. 0.50 CASE PULR CMPL T3 PU 1jt of 7" 26#, L-80 BTC liner then MU Baker 7" HR liner setting sleeve, RIH to 6,178', liner up wt 95K, dn wt 65K 0.50 CASE RURD CMPL T3 RD Doyon's liner running equipment 5.00 CASE RUNL CMPL T3 RIH with 5 1/2" liner on 5" DP from 6,178' and tagged btm at 13,536' DP measurement, no problems RIH, took liner weights & torque readings at 6,640' and above window at 7,223'. At 6,640' linerwt up 103K, dn wt 68K, rot wt 82k, at 10 rpm's had 4K ft-Ibs torque and at 20 rpm's had 4,500 ft-Ibs torque. At 7,223' liner up wt 115K, dn wt 75K, rot wt 89K, at 10 rpm's had 5K ft-Ibs torque and at 20 rpm's had 4-6K ft-Ibs torque. Liner wt on btm, up wt 215K, dn wt 70K, with torque limiter set at 14,500 ft-Ibs was unable to rotate liner, calc liner displacement 87 bbls, actual 64 bbls, Ran liner with 5 stds slick 5" DP, 60 stds 5" DP with Loctads and 10 stds of HWDP 1.75 CASE RUNL CMPL T3 Dropped 1 1/2" ball and pumped down to seat, pumped down at 4 bpm at 60Ò psi then slowed to 1 bpm, with ball on seat pressured up to 3,000 psi to release running tool, then pressured up to 3,900 psi and blew ball seat, PU and st wt up was 175K, dn wt 105K, stood back 1 std with setting tool at 7,268', top of HR setting tool landed at 7,370.87' Circ btms up at 7,268', circ across whipstock face while circ btms up, circ at 70 spm, 250 gpm at 500 psi, 9.15 ppg SFMOBM in and out Monitored well-static POOH from 7,268' and LD Baker running tool, cleared rig floor, calc fill on trip out 69 bbls, actual 75 bbls Slip and cut 79' of drlg line and seNiced top drive Held PJSM and MU fishing BHA #18, MU Baker retrieving hook, 1 jt 5" HWDP, float sub, bumper and oil jars RIH to 61' RIH with fishing BHA #18 from 61' to 4,466' RIH with whipstock retrieving BHA #18 from 4,496' to 7,237' st up wt 175K, dn wt 105K Hooked whipstock at 7,263 on 3rd attempt. Worked whipstock pulling 1 OOK over with no movement, Pulled to 125k over st wt and hit jars, after 2nd hit pulled 330K st wt and whipstock came free, PU and stood back std, had 222K drag up wt, after standing back std string wt dropped to 179K 1.00 FISH CIRC CMPL T3 Circ btms up at 7,230', circ at 420 gpm, 1,375 psi, max gas 60 units at btms up 5.00 FISH TRIP CMPL T3 POOH slow with whipstock from 7,263' to BHA at 60' 2.00 FISH PULD CMPL T3 POOH and LD bumper jars, oil jars, whipstock, 1-5',5 jts 5" DP and 15:00-16:15 1.25 CASE CIRC CMPL T3 16:15 -16:30 0.25 CASE OTHR CMPL T3 16:30 - 20:00 3.50 DRILL TRIP CMPL T3 20:00 - 21:15 1.25 RIGMNT RSRV CMPL T3 21:15-21:45 0.50 FISH PULD CMPL T3 21 :45 - 00:00 2.25 FISH TRIP CMPL T3 6/17/2005 00:00 - 00:45 0.75 FISH TRIP CMPL T3 00:45 - 01 :30 0.75 FISH FISH CMPL T3 01 :30 - 02:30 02:30 - 07:30 07:30 - 09:30 Pñnted: 7/6/2005 3:50:05 PM e e Legal Well Name: Common Well Nàme: Event Name: Contractor Name: Rig Name: 1 E-1 05 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/17/2005 07:30 - 09:30 2.00 FISH PULD 09:30 - 10:00 0.50 CASE RURD 10:00 - 10:15 0.25 CASE SFTY 10:15 -11:30 1.25 CASE PULR 11 :30 - 17:00 5.50 CASE RUNL 17:00 -18:45 1.75 CASE OTHR CMPL T3 seal assembly, cleared rig floor, calc fill on trip out 64 bbls, actual 77 bbls CMPL T3 RU Doyon's liner running equipment CMPL T3 HeJd PJSM with rig crew and tong operator on running of PU and running of hook hanger with ECP pkr CMPL T3 MU "D" lateral hook hanger assembly with ECP Pkr RIH to 162', MU 5 1/2" bentjt, 1-6' pup jt, 1-jt of 51/2" 15.5#, L-80 IBTM blank liner, ECP, 1-6' pup jt and hook hanger assembly CMPLT3 RIH with hook hanger assembly from 162' to top of window at 7,258', st wt up 175K, dn wt 106K CMPL T3 Worked bent jt thru window after 4th attempt, RIH and tagged XO in HR setting sleeve at 7,425', did not see ECP Pkr go thru window, st wt up 185K, dn wt 104K 18:45 - 20:00 1.25 CASE OTHR CMPL T3 Oriented hanger to btm of window, after 6 attempts hooked hanger. PU and unhooked hanger, worked hanger by turning pipe 1/4 turn, rehooked and unhooked hanger 6 times while turning hanger to verify btm of window, btm of window @ 7,275.31. Top of Baker hook hanger @ 7,254.41' with 5 1/2" bent jt at 7,416', spaced out 9' above 7" x 5 1/2" XO at 7, 425', Set 30K wt down on hook 20:00 - 21:15 1.25 CASE CIRC CMPLT3 Dropped 29/32" ball and pumped down to seat, pumped at 4 bpm, 525 psi and slowed to 1 bpm at 200 psi, with ball on seat at calc strokes, pressured up to 500 psi then bled off 21 :15 - 22:30 1.25 CASE OTHR CMPL T3 Turned over to Dowell, pressure tested lines to 3,500 psi, then pressured up on ECP Pkr to 2,200 psi, bled off, pressured back up to 2,500 psi and did¡;¡'t see valve shear, cont to slowly increase pressure up to 3,800 psi, bled off, pressured up to 4,300 psi and blew ball seat. PU out of assembly to 7,144'. NOTE: Looking at Dowell chart it appears valve may have opened a\"1 ,555 psi and closed at 2,000 psi taking 0.8 bbls to pressure up and set packer Circ btms up at 7,144', circ at 295 gpm at 650 psi, no gas at btms up, st wt up 170K, dn wt 102K Monitored well-static POOH with hook hanger running toolfrom 7,144' to 6,328' POOH with hook hanger assembly running tool from 6,328' to 70' POOH LD running tool and cleared rig floor, calc fill on trip out 65 bbls, actual fill 73 bbls RU Doyon's tubing handling equipment Held PJSM with rig crew on running of LEM MU "D" sand LEM assembly with ZXP packer and RIH to 312' RIH with LEM from 312' to 7,250' to aböve hook hanger, st wt up 173K, dn wt 103K Oriented LEM and located hook hanger at 7,254' and landed same with ZXP packer top at 7,191' and end of seals at 7,493', snapped in & out of hanger 1 time to verify on depth and latching into hook hanger, Rehook and pull test 1 OK over to verify possitive hook, Set down 30K wt. on hook assembly. 10:15 - 11 :00 0.75 CMPL TN CIRC CMPL T3 Dropped 1 3/4" phenolic ball and pumped down to seat, pumped down at 4 bpm at 350 psi, pressured up to 2,500 psi to set packer, then pressured up to 3,900 psi to release from setting tool, no problems setting packer 11 :00 - 11 :15 0.25 CMPLTN DEQT CMPL T3 Tested ZXP packer and annulus to 1,000 psi for 5 min, good test 11 :15 - 12:15 1.00 CMPL TN CIRC CMPL T3 PU out ofZXP packer and set back down with dog sub to verify packer setting depth and circ btms up, circ at 285 gpmat 675 psi 22:30 - 23:15 0.75 CASE CIRC CMPL T3 23:15 - 23:30 0.25 CASE OTHR CMPL T3 23:30 - 00:00 0.50 CASE RUNL CMPL T3 6/18/2005 00:00 - 02:00 2.00 CASE RUNL CMPL T3 02:00 - 03:00 1.00 CASE OTHR CMPL T3 03:00 - 03:30 0.50 CMPL TN RURD CMPL T3 03:30 - 03:45 0.25 CMPL TN SFTY CMPL T3 03:45 - 05:00 1.25 CMPL TN PULD CMPL T3 05:00 - 10:00 5.00 CMPL TN TRIP CMPL T3 10:00·10:15 0.25 CMPL TN TRIP CMPL T3 Printed: 71612005 3:50:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-105 1 E-1 05 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 4/25/2005 Rig Release: 6/20/2005 Rig Number: Spud Date: 4/29/2005 End: 6/20/2005 Group: 6/18/2005 12:15 - 12:30 12:30 - 15:00 15:00 - 15:45 15:45 - 16:00 16:00 - 16:30 16:30 - 22:00 0.25 CMPL TN OBSV 2.50 CMPL TN TRIP 0.75 CMPL TN PULD 0.25 CMPL TN PULL 0.50 CMPL TN RURD 5.50 CMPL TN RUNT CMPL T3 CMPL T3 CMPL T3 CMPL T3 CMPL T3 CMPL T3 22:00 - 23:00 1.00 CMPL TN RUNT CMPL T3 23:00 - 00:00 1.00 CMPLTN RURD CMPL T3 6/19/2005 00:00 - 02:30 2.50 WELCTL NUND CMPL T3 02:30 - 06:30 4.00 DRILL PULD CMPL T3 06:30 - 08:30 2.00 WELCTL NUND CMPL T3 08:30 - 09:30 1.00 WELCTL OTHR CMPL T3 09:30 - 16:45 7.25 DRILL PULD CMPL T3 16:45 - 18:00 1.25 WELCTL EQRP CMPL T3 18:00-22:15 4.25 DRILL PULD CMPL T3 22:15 - 00:00 1.75 DRILL OTHR CMPL T3 6/2012005 00:00 - 01 :30 1.50 DRILL OTHR CMPL T3 Monitored well-static POOH with LEM running tool from 7,191' to 45' POOH LD LEM running tool Pulled wear bushing RU Doyon's tbg handling equipment and held PJSM Ran 4 1/2" 12.6#, L-80 IBTM tbg with completion assembly to 7,217', RIH and tagged no·go at 7,217' tbg measurement, ran a total of 230 jts, 7,106' of 4 1/2" tbg Spaced out completion string, MU Vetco Gray tbg hanger and landed tbg at 7,229', RILDS, landed tbg with open CMU sliding sleeve at 7,164', btm GLM at 6,713', upper GLM at 4,217' and DB-6 nipple at 504', st wt up 95K, down wt 57K, tested hanger seals to 5,000 psi for 15 min, good test, installed TWC RD Doyon's tbg handling equipment and landing jt, cleared rig floor ND BOP's, began to set back when one of the bridge crane's wouldn't work LD 144 jts of 5" DP from derrick while repairing bridge crane Set back BOP's and NU Vetco Gray 13 5/8" x 4 1/8" 5M Tree Tested tree to 500 psi low then to 5,000 psi high for 15 min, good test, pulled TWC Cont to LD DP from the derrick, LD 132 jts of 5" DP, 39 jts of 5" HWDP and 44 Lo-Tads, Sim-Ops: held PJSM and RU little Red, displaced hole over from 9.1 ppg SFMOBM to diesel thru choke manifold and open CMU sliding sleeve at 7,164', RU scaffolding over well RU lubricator and installed BPV, RD lubricator and secured well, RD scaffolding and began cleaning out SFMOBM in pits, SITP 400 psi, IA 400 psi, OA 160 psi Fin LD DP from the derrick, LD 123 jts of 5" DP and 16 Lo-Tads, LD a total of 408 jts of 5" DP, 39 jts HWDP and 60 Lo-Tads, RD mouse hole Cont to clean mud pits, Sim-Op: Slip and cut 52' of drlg line, rig off highline at 22:15 hrs Fin. cleaning mud pits and rock washer, Sim-Ops: changed out 41/2" IF saver sub on top drive. RELEASED RIG @ 01 :30 Hrs 6/20/05 Printed: 7/6/2005 3:50:05 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1E 1E-105 e Job No. AK-ZZ-0003677560, Surveyed: 16 May, 2005 Survey Report 29 June, 2005 Your Ref: API 500292324300 Surface Coordinates: 59599~0.60 N, 550300.48 E (70018' 05.1619" N, 149035' 33.3322" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959980.60 N, 50300.48 E (Grid) Surface Coordinates relative to Structure: 217.60 N, 412.44 E (True) Kelly Bushing Elevation: 93.58ft above Mean Sea Level Kelly Bushing Elevation: 93.58ft above Project V Reference Kelly Bushing Elevation: 93.58ft above Structure e &p...........y-&u., P,RI.L.LING SSRVICSS A HaUibur«:H\ ComP'l'ny Survey Ref:slly2177 Halliburton Sperry-Sun SUlvey Report for Kuparuk 1E - 1E-105 Your Ref: API 500292324300 Job No. AK-ZZ-0003677560, Surveyed: 16 May, 2005 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) (°/1 o Oft) 11264.49 91.180 179.520 3562.01 3655.59 4734.15 S 5183.07 E 5955281.25 N 555515.12 E 4734.15 Tie-On Point 11332.00 90.840 181.170 3560.82 3654.40 4801.65 S 5182.66 E 5955213.76 N 555515.17 E 2.495 4801.65 Window Point 11359.46 89.510 179.730 3560.74 3654.32 4829.10 S 5182.44 E 5955186.30 N 555515.14 E 7.138 4829.10 11453.30 87.220 180.870 3563.41 3656.99 4922.90 S 5181.95 E 5955092.50 N 555515.27 E 2.726 4922.90 11547.28 85.800 181.580 3569.13 3662.71 5016.68 S 5179.95 E 5954998.71 N 555513.90 E 1.689 5016.68 e 11641.28 87.490 183.460 3574.64 3668.22 5110.42 S 5175.82 E 5954904.95 N 555510.40 E 2.687 5110.42 11737.48 91.690 184.260 3575.32 3668.90 5206.37 S 5169.35 E 5954808.95 N 555504.56 E 4.444 5206.37 11832.53 92.170 182.930 3572.12 3665.70 5301.18 S 5163.39 E 5954714.10 N 555499.24 E 1.487 5301.18 11927.93 90.740 180.970 3569.70 3663.28 5396.49 S 5160.15 E 5954618.78 N 555496.64 E 2.543 5396.49 12022.54 91.240 180.450 3568.07 3661.65 5491.08 S 5158.97 E 5954524.18 N 555496.10 E 0.762 5491.08 12118.49 91.860 179.110 3565.47 3659.05 5586.99 S 5159.34 E 5954428.28 N 555497.11 E 1.538 5586.99 12211.56 91.980 179.260 3562.35 3655.93 5680.00 S 5160.66 E 5954335.28 N 555499.05 E 0.206 5680.00 12308.56 93.100 178.210 3558.05 3651.63 5776.87 S 5162.80 E 5954238.42 N 555501.84 E 1.582 5776.87 12403.62 93.710 178.200 3552.41 3645.99 5871.72 S 5165.78 E 5954143.59 N 555505.45 E 0.642 5871.72 12499.93 94.700 179.300 3545.35 3638.93 5967.74 S 5167.87 E 5954047.59 N 555508.19 E 1.534 5967.74 12594.98 94.140 178.930 3538.02 3631.60 6062.50 S 5169.34 E 5953952.84 N 555510.28 E 0.706 6062.50 12691.34 92.160 178.940 3532.73 3626.31 6158.69 S 5171.12 E 5953856.66 N 555512.72 E 2.055 6158.69 12786.88 90.740 178.860 3530.31 3623.89 6254.18 S 5172.96 E 5953761.19 N 555515.19 E 1.489 6254.18 12876.18 88.890 178.950 3530.60 3624.18 6343.46 S 5174.66 E 5953671.92 N 555517.49 E 2.074 6343.46 12967.48 88.080 180.330 3533.01 3626.59 6434.73 S 5175.24 E 5953580.66 N 555518.68 E 1.752 6434.73 13059.02 88.650 179.250 3535.62 3629.20 6526.23 S 5175.57 E 5953489.17 N 555519.63 E 1.334 6526.23 e 13151.51 90.760 180.280 3536.10 3629.68 6618.71 S 5175.95 E 5953396.69 N 555520.62 E 2.539 6618.71 13243.64 91.060 180.420 3534.63 3628.21 6710.82 S 5175.39 E 5953304.57 N 555520.68 E 0.359 6710.82 13336.19 91.490 180.560 3532.58 3626.16 6803.35 S 5174.60 E 5953212.05 N 555520.51 E 0.489 6803.35 13426.49 90.180 181.150 3531.26 3624.84 6893.62 S 5173.25 E 5953121.76 N 555519.76 E 1.591 6893.62 13499.70 90.630 181.050 3530.74 3624.32 6966.82 S 5171.84E 5953048.56 N 555518.85 E 0.630 6966.82 13539.00 90.630 181.050 3530.31 3623.89 7006.11 S 5171.12 E 5953009.26 N 555518.39 E 0.000 7006.11 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 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13539.00ft., The Bottom Hole Displacement is 8707.82ft., in the Direction of 143.569° (True). 29 June, 2005 - 14:51 Page 2 of 3 DrillQuest 3.03.06.008 Western North Slope Comments Measured Depth (ft) 11264.49 11332.00 13539.00 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-105 Your Ref: API 500292324300 Job No. AK-ZZ-0003677560, Surveyed: 16 May, 2005 ConocoPhil/ips Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3655.59 3654.40 3623.89 4734.15 S 4801.65 S 7006.11 S Tie-On Point Window Point Projected Survey e 5183.07 E 5182.66 E 5171.12 E Survey too/program for 1 E-1 05 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 722.00 29 June, 2005 - 14:51 0.00 722.00 719.95 13539.00 719.95 CB-SS-Gyro (1E-105PB1) 3623.89 MWD+IIFR+MS+SAG (1E-105PB1) e Page 3 of3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1E 1E-105PB1 e Job No. AK-ZZ-OlJ03677560, Surveyed: 2 May, 2005 Survey Report 29 June, 2005 Your Ref: API 500292324370 Surface Coordinates: 5959980.60 N, 550300.48 E (70· 18' 05.1619" N, 149035' 33.3322" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 959980.60 N, 50300.48 E (Grid) Surface Coordinates relative to Structure: 217.60 N, 412.44 E (True) Kelly Bushing Elevation: 93.58ft above Mean Sea Level Kelly Bushing Elevation: 93.58ft above Project V Reference Kelly Bushing Elevation: 93. 58ft above Structure Eip.............y-EiUf1 pAIL.L.ING seRVices A Hial/jÞult<:m CØ<!1p4rny Survey Ref: svy2109 Halliburton Sperry-Sun Survey Report for Kuparuk 1E· 1E-105PB1 Your Ref: API 500292324370 Job No. AK-ZZ-0003677560, Surveyed: 2 May, 2005 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) (0/100ft) 0.00 0.000 0.000 -93.58 0.00 0.00 N 0.00 E 5959980.60 N 550300.48 E 0.00 CB-SS-Gyro 100.00 0.000 0.000 6.42 100.00 0.00 N 0.00 E 5959980.60 N 550300.48 E 0.000 0.00 200.00 0.000 0.000 106.42 200.00 0.00 N 0.00 E 5959980.60 N 550300.48 E 0.000 0.00 271.00 0.600 38.000 177.42 271.00 0.29 N 0.23 E 5959980.89 N 550300.71 E 0.845 -0.29 361.00 2.400 41.000 267.38 360.96 2.09 N 1.76 E 5959982.70 N 550302.22 E 2.001 -2.09 e 446.00 4.100 72.000 352.25 445.83 4.37 N 5.81 E 5959985.01 N 550306.26 E 2.808 -4.37 535.00 4.600 82.000 441.00 534.58 5.85 N 12.37 E 5959986.53 N 550312.81 E 1.019 -5.85 628.00 7.800 85.000 533.44 627.02 6.92 N 22.36 E 5959987.67 N 550322.79 E 3.457 -6.92 722.00 9.500 91.000 626.37 719.95 7.34 N 36.47 E 5959988.18 N 550336.90 E 2.045 -7.34 MWD+IIFR+MS+SAG 846.67 19.890 98.740 746.81 840.39 3.93 N 67.80 E 5959984.98 N 550368.26 E 8.463 -3.93 937.57 25.700 94.540 830.58 924.16 0.01 N 102.77 E 5959981.30 N 550403.25 E 6.634 -0.01 1029.41 26.340 92.150 913.11 1006.69 2.33 S 142.98 E 5959979.23 N 550443.47 E 1.337 2.33 1123.53 30.460 88.060 995.89 1089.47 2.30 S 187.71 E 5959979.55 N 550488.20 E 4.839 2.30 1216.50 36.360 85.260 1073.47 1167.05 0.78 N 238.78 E 5959982.97 N 550539.25 E 6.558 -0.78 1307.24 39.510 83.770 1145.03 1238.61 6.13 N 294.29 E 5959988.70 N 550594.72 E 3.615 -6.13 1401.44 42.580 83.740 1216.07 1309.65 12.86 N 355.77 E 5959995.84 N 550656.16 E 3.259 -12.86 1492.98 48.630 82.730 1280.08 1373.66 20.59 N 420.69 E 5960004.01 N 550721.02 E 6.656 -20.59 1587.06 55.520 82.930 1337.87 1431.45 29.84 N 494.28 E 5960013.75 N 550794.55 E 7.325 -29.84 1679.80 61.930 82.370 1385.99 1479.57 39.99 N 572.85 E 5960024.42 N 550873.05 E 6.931 -39.99 1770.32 64.170 83.390 1427.01 1520.59 49.98 N 652.91 E 5960034.95 N 550953.04 E 2.671 -49.98 1865.22 65.680 83.150 1467.23 1560.81 60.06 N 738.27 E 5960045.60 N 551038.33 E 1.608 -60.06 e 1957.94 67.730 82.940 1503.89 1597.47 70.37 N 822.80 E 5960056.48 N 551122.79 E 2.221 -70.37 2050.85 68.450 83.200 1538.56 1632.14 80.77 N 908.37 E 5960067.45 N 551208.29 E 0.817 -80.77 2144.61 66.380 83.560 1574.57 1668.15 90.75 N 994.36 E 5960078.01 N 551294.21 E 2.236 -90.75 2236.37 68.480 84.410 1609.79 1703.37 99.63 N 1078.62 E 5960087.44 N 551378.41 E 2.443 -99.63 2330.22 71.210 83.890 1642.12 1735.70 108.61 N 1166.25 E 5960097.01 N 551465.98 E 2.955 -108.61 2422.23 68.780 84.560 1673.60 1767.18 117.31 N 1252.27 E 5960106.29 N 551551.93 E 2.728 -117.31 2515.21 69.160 84.670 1706.96 1800.54 125.46 N 1338.67 E 5960115.01 N 551638.28 E 0.423 -125.46 2610.87 69.050 84.150 1741.08 1834.66 134.16 N 1427.61 E 5960124.31 N 551727.16 E 0.521 -134.16 2699.63 70.050 .84.140 1772.09 1865.67 142.64 N 1510.34 E 5960133.35 N 551809.84 E 1.127 -142.64 2793.05 69.820 81.770 1804.15 1897.73 153.40 N 1597.42 E 5960144.69 N 551896.84 E 2.396 -153.40 2886.21 69.720 81.820 1836.36 1929.94 165.88 N 1683.94 E 5960157.75 N 551983.27 E 0.119 -165.88 2978.66 71.420 81.800 1867.11 1960.69 178.30 N 1770.24 E 5960170.75 N 552069.48 E 1.839 -178.30 3074.68 71.860 82.700 1897.36 1990.94 190.59 N 1860.53 E 5960183.64 N 552159.70 E 1.001 -190.59 3170.51 69.100 83.240 1929.38 2022.96 201.64 N 1950.17 E 5960195.30 N 552249.25 E 2.929 -201.64 29 June, 2005 - 14:33 Page 20f4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-105PB1 Your Ref: API 500292324370 Job No. AK-ZZ-0003677560, Surveyed: 2 May, 2005 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) (0/100ft) 3265.49 69.390 82.500 1963.04 2056.62 212.67 N 2038.30 E 5960206.91 N 552337.31 E 0.790 -212.67 3358.32 68.960 83.790 1996.04 2089.62 223.03 N 2124.44 E 5960217.84 N 552423.38 E 1.379 -223.03 3453.76 70.690 84.410 2028.95 2122.53 232.23 N 2213.54 E 5960227.64 N 552512.42 E 1.912 -232.23 3548.14 69.270 85.440 2061.27 2154.85 240.08 N 2301.87 E 5960236.08 N 552600.69 E 1.821 -240.08 3643.18 67.960 84.380 2095.92 2189.50 247.93 N 2390.01 E 5960244.52 N 552688.78 E 1.726 -247.93 --e 3736.58 68.090 83.870 2130.87 2224.45 256.79 N 2476.17E 5960253.96 N 552774.88 E 0.525 -256.79 3831.72 69.380 83.300 2165.38 2258.96 266.70 N 2564.28 E 5960264.46 N 552862.91 E 1.466 -266.70 3924.71 67.730 82.310 2199.37 2292.95 277.54 N 2650.14 E 5960275.87 N 552948.71 E 2.032 -277.54 4022.63 67.320 83.290 2236.81 2330.39 288.88 N 2739.91 E 5960287.81 N 553038.40 E 1.015 -288.88 4118.05 70.920 85.310 2270.81 2364.39 297.71 N 2828.61 E 5960297.24 N 553127.03 E 4.260 -297.71 4212.80 72.640 85.940 2300.44 2394.02 304.57 N 2918.34 E 5960304.70 N 553216.72 E 1.922 -304.57 4308.87 68.500 85.840 2332.39 2425.97 311.06 N 3008.69 E 5960311.80 N 553307.02 E 4.310 -311.06 4343.79 68.000 86.300 2345.33 2438.91 313.29 N 3041.04 E 5960314.24 N 553339.36 E 1.883 -313.29 4395.00 68.000 86.300 2364.51 2458.09 316.35 N 3088.43 E 5960317.62 N 553386.72 E 0.000 -316.35 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are ralative to Well. Northings and Eastings are relative to Well. Global Northings and Eðstings 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 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4395.00ft., The Bottom Hole Displacement is 31 04.59ft., in the Direction of 84.152° (True). e 29 June, 2005 - 14:33 Page 3 of4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-105PB1 Your Ref: API 500292324370 Job No. AK-ZZ-0003677560, Surveyed: 2 May, 2005 ConocoPhillips Western North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4395.00 2458.09 316.35N 3088.43 E Projected Survey -- Survey too/prOgram for 1E-105PB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 722.00 0.00 719.95 722.00 4395.00 719.95 CB-SS"Gyro 2458.09 MWD+IIFR+MS+SAG e 29 June, 2005 - 14:33 Page 40f 4 DrillQuest 3.03.06.008 e e Survey Ref: svy2147 Halliburton Sperry-Sun Western North Slop.e ConocoPhillips Kuparuk 1E 1E-105PB2 Job No. AK-ZZ_0003677560, Surveyed: 14 May, 2005 Survey Report 29 June, 2005 Your Ref: API 500292324371 Surface Coordinates: 5959980.60 N, 550300.48 E (70018' 05.1619" N, 149035' 33.3322" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface. Coordinates relative to Project H Reference: 959980.60 N, 50300.48 E (Grid) Surface Coordinates relative to Structure: 217.60 N, 412.44 E (True) Kelly Bushing Elevation: 93.58ft above Mean Sea Level Kelly Bushing Elevation: 93. 58ft above Project V Reference Kelly Bushing Elevation: 93.58ft above Structure EiPE!...........y-SU., CU=tIL.L.ING S&AVlces A H.mbvrtoo ComP'l'r'I)' Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-105PB2 Your Ref: API 500292324371 Job No. AK-ZZ_0003677560, Surveyed: 14 May, 2005 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) 4022.63 67.320 83.290 2236.81 2330.39 288.88 N 2739.91 E 5960287.81 N 553038.40 E -288.88 Tie-On Point 4027.00 67.480 83.390 2238.49 2332.07 289.35 N 2743.92 E 5960288.31 N 553042.40 E 4.227 -289.35 Window Point 4091.30 69.800. 84.300 2261.91 2355.49 295.76 N 2803.45 E 5960295.12 N 553101.89 E 3.841 -295.76 4187.99 69.810 85.070 2295.28 2388.86 304.17 N 2893.81 E 5960304.13 N 553192.19 E 0.747 -304.17 4278.71 67.540 85.620 2328.27 2421.85 311.03N 2978.03 E 5960311.56 N 553276.36 E 2.565 -311.03 e 4371.46 65.740 84.110 2365.05 2458.63 318.64 N 3062.83 E 5960319.74 N 553361.11 E 2.449 -318.64 4465.85 67.490 84.360 2402.51 2496.09 327.34 N 3149.03 E 5960329.02 N 553447.24 E 1.870 -327.34 4559.40 67.700 87.520 2438.18 2531.76 333.46 N 3235.28 E 5960335.71 N 553533.46 E 3.131 -333.46 4652.82 69.090 89.780 2472.58 2566.16 335.50 N 3322.11 E 5960338.33 N 553620,27 E 2.697 -335.50 4746.04 69.360 90.530 2505.64 2599.22 335.26 N 3409.26 E 5960338.68 N 553707.42 E 0.806 -335.26 4834.93 67.970 90.710 2537.98 2631.56 334.37 N 3492.06 E 5960338.34 N 553790.22 E 1.575 -334.37 4927.04 70.670 90.560 2570.51 2664.09 333.42 N 3578.22 E 5960337.96 N 553876.39 E 2.935 -333.42 5019.70 68.890 90.970 2602.53 2696.11 332.26 N 3665.16 E 5960337.38 N 553963.33 E 1.965 -332.26 5111.86 68.260 89.850 2636.20 2729.78 331.64 N 3750.94 E 5960337.34 N 554049.12 E 1.322 -331.64 5206.21 67.440 90.380 2671.77 2765.35 331.47N 3838.33 E 5960337.75 N 554136.50 E 1.013 -331.47 5298.24 68.970 91.010 2705.94 2799.52 330.43 N 3923.77 E 5960337.29 N 554221.95 E 1.780 -330.43 5388.54 69.680 91.040 2737.82 2831.40 328.92 N 4008.24 E 5960336.34 N 554306.43 E 0.787 -328.92 5484.78 68.160 91.720 2772.44 2866.02 326.76 N 4098.01 E 5960334.78 N 554396.21 E 1.711 -326.76 5576.15 65.190 97.280 2808.63 2902.21 320.22 N 4181.61 E 5960328.81 N 554479.85 E 6.463 -320.22 5669.81 63.830 101.870 2848.96 2942.54 306.18 N 4264.94 E 5960315.3.3 N 554563.28 E 4.656 -306.18 5767.07 64.510 106.630 2891.35 2984.93 284.63 N 4349.75 E 5960.294.35 N 554648.23 E 4.460 -284.63 e 5859.72 65.810 112.500 2930.30 3023.88 256.47 N 4428.92 E 5960266.72 N 554727.59 E 5.918 -256.47 5952.82 64.300 118.570 2969.59 3063.17 220.13N 4505.05 E 5960230.89 N 554803.96 E 6.129 -220.13 6045.65 63.420 125.600 3010.53 3104.11 175.92 N 4575.61 E 5960187.15 N 554874.81 E 6.863 -175.92 6137.88 64.710 125.860 3050.87 3144.45 127.49 N 4642.94 E 5960139.17 N 554942.46 E 1.421 -127.49 6230.83 65.200 128.200 3090.22 3183.80 76.78 N 4710.15 E 5960088.91 N 555010.01 E 2.341 -76.78 6323.69 64.370 131.290 3129.79 3223.37 23.08 N 4774.74 E 5960035.64 N 555074.96 E 3.140 -23.08 6418.72 64.920 136.200 3170.50 3264.08 36.28 S 4836.75 E 5959976.70 N 555137.37 E 4.705 36.28 6514.30 64.380 139.650 3211.44 3305.02 100.38 S 4894.62 E 5959912.99 N 555195.67 E 3.310 100.38 6606.15 67.170 144.700 3249.14 3342.72 166.53 S 4945.93 E 5959847.18 N 555247.42 E 5.861 166.53 6701.83 68.080 149.020 3285.58 3379.16 240.60 S 4994.28 E 5959773.44 N 555296.26 E 4.282 240.60 6797.54 73.330 155.250 3317.22 3410.80 320.42 S 5036.39 E 595.9693.90 N 555338.90 E 8.234 320.42 6892.96 75.380 161.170 3342.97 3436.55 405.70 S 5070.46 E 5959608.85 N 555373.54 E 6.348 405.70 6987.46 75.240 165.990 3366.95 3460.53 493.35 S 5096.29 E 5959521.37 N 555399.96 E 4.936 493.35 7081.44 75.010 170.230 3391.09 3484.67 582.21 S 5115.00E 5959432.64 N 555419.26 E 4.367 582.21 29 June, 2005 - 14:42 Page 2 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-1tJ5PB2 Your Ref: API 500292324371 Job No. AK-ZZ_0003677560, Surveyed: 14 May, 2005 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) (0/100ft) 7175.65 76.140 173.860 3414.56 3508.14 672.56 8 5127.62 E 5959342.39 N 555432.48 E 3.920 672.56 7270.49 76.010 173.840 3437.38 3530.96 764.08 8 5137.48 E 5959250.93 N 555442.96 E 0.139 764.08 7367.22 77 .490 174.810 3459.56 3553.14 857.77 8 5146.79 E 5959157.30 N 555452.89 E 1.815 857.77 7458.74 79.870 175.720 3477.52 3571.10 947.208 5154.19 E 5959067.93 N 555460.90 E 2.777 947.20 7554.37 78.680 175.080 3495.31 3588.89 1040.85 8 5161.72 E 5958974.33 N 555469.06 E 1.407 1040.85 e 7650.04 79.750 177.730 3513.22 3606.80 1134.648 5167.61 E 5958880.58 N 555475.57 E 2.942 1134.64 7746.31 80.440 178.770 3529.78 3623.36 1229.428 5170.51 E 5958785.82 N 555479.10 E 1.283 1229.42 7845.20 79.940 178.680 3546.63 3640.21 1326.84 8 5172.68 E 5958688.41 N 555481.92 E 0.514 1326.84 7936.63 80.080 178.720 3562.49 3656.07 1416.868 5174.72 E 5958598.41 N 555484.57 E 0.159 1416.86 8030.89 81.540 178.420 3577.54 3671.12 1509.888 5177.04 E 5958505.41 N 555487.51 E 1.580 1509.88 8125.98 81.510 179.230 3591.56 3685.14 1603.91 8 5178.97 E 5958411.39 N 555490.07 E 0.843 1603.91 8223.87 79.820 178.850 3607.44 3701.02 1700.49 8 5180.59 E 5958314.83 N 555492.34 E 1.768 1700.49 8267.36 79.130 178.750 3615.38 3708.96 1743.24 8 5181.48 E 5958272.09 N 555493.52 E 1.603 1743.24 8362.72 81.900 178.530 3631.09 3724.67 1837.268 5183.72 E 5958178.08 N 555496.38 E 2.914 1837.26 8459.26 86.000 180.750 3641.27 3734.85 1933.23 8 5184.31 E 5958082.12 N 555497.62 E 4.823 1933.23 8556.99 90.890 182.300 3643.92 3737.50 2030.868 5181.71 E 5957984.47 N 555495.67 E 5.249 2030.86 8653.06 93.230 181.680 3640.47 3734.05 2126.808 5178.38 E 5957888.51 N 555492.98 E 2.520 2126.80 8748.13 93.650 180.790 3634.76 3728.34 2221.688 5176.33 E 5957793.62 N 555491.57 E 1.034 2221.68 8843.72 95.330 180.060 3627.28 3720.86 2316.978 5175.62 E 5957698.33 N 555491.50 E 1.915 2316.97 8942.80 96.200 179.660 3617.32 3710.90 2415.558 5175.86 E 5957599.76 N 555492.40 E 0.966 2415.55 9040.38 95.190 179.240 3607.64 3701.22 2512.64 S 5176.80 E 5957502.67 N 555493.98 E 1.120 2512.64 e 9136.70 93.390 178.910 3600.44 3694.02 2608.67 S 5178.35 E 5957406.65 N 555496.18 E 1.900 2608.67 9230.20 90.240 179.090 3597.48 3691.06 2702.108 5179.98 E 5957313.24 N 555498.43 E 3.374 2702.10 9329.71 89.510 179.050 3597.69 3691.27 2801.59 8 5181.59E 5957213.76 N 555500.71 E 0.735 2801.59 9426.02 88.460 179.400 3599.40 3692.98 2897.88 S 5182.90 E 5957117.48 N 555502.66 E 1.149 2897.88 9523.01 88.520 179.200 3601.95 3695.53 2994.83 8 5184.08 E 5957020.54 N 555504.49 E 0.215 2994.83 9618.89 87.350 179.590 3605.41 3698.99 3090.64 S 5185.09 E 5956924.74 N 555506.15 E 1.286 3090.64 9710.73 86.800 180.610 3610.10 3703.68 3182.368 5184.93 E 5956833.02 N 555506.60 E 1.261 3182.36 9812.68 89.030 181.880 3613.81 3707.39 3284.21 8 5182.72 E 5956731 .16 N 555505.07 E 2.517 3284.21 9910.52 89.890 181.530 3614.73 3708.31 3382.00 S 5179.81 E 5956633.35 N 555502.81 E 0.949 3382.00 10007.15 90.130 181.350 3614.71 3708.29 3478.60 S 5177.38 E 5956536.74 N 555501.03 E 0.310 3478.60 10102.05 91.000 181.460 3613.77 3707.35 3573.46 S 5175.05 E 5956441.86 N 555499.34 E 0.924 3573.46 10197.25 92.360 182.260 3610.98 3704.56 3668.57 8 5171.96 E 5956346.74 N 555496.89 E 1.657 3668.57 10298.00 94.150 180.770 3605.26 3698.84 3769.128 5169.30 E 5956246.17 N 555494.90 E 2.310 3769.12 10392.64 95.020 181.300 3597.70 3691.28 3863.44 8 5167.60 E 5956151.85 N 555493.83 E 1.075 3863.44 29 June, 2005 - 14:42 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E· 1E-105PB2 Your Ref: API 500292324371 Job No. AK-ZZ_0003677560, Surveyed: 14 MéW, 2005 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) (0/100ft) 10489.33 93.580 179.260 3590.45 3684.03 3959.84 S 5167.13 E 5956055.44 N 555494.00 E 2.578 3959.84 10585.65 94.400 179.790 3583.75 3677.33 4055.93 S 5167.93 E 5955959.36 N 555495.44 E 1.013 4055.93 10682.99 92.400 179.610 3577.97 3671.55 4153.09 S 5168..44 E 5955862.20 N 555496.60 E 2.063 4153.09 10779.21 91.480 178.530 3574.72 3668.30 4249.24 S 5170.00 E 5955766.07 N 555498.81 E 1.474 4249.24 10875.91 92.230 178.510 3571.59 3665.17 4345.86 S 5172.49 E 5955669.47 N 555501.95 E 0.776 4345.86 e 10971.68 92.040 178.060 3568.02 3661.60 4441.52 S 5175.36 E 5955573.83 N 555505.46 E 0.510 4441.52 11068.56 91.050 178.120 3565.41 3658.99 4538.31 S 5178.59 E 5955477.06 N 555509.33 E 1.024 4538.31 11165.24 90.870 178.550 3563.79 3657.37 4634.93 S 5181.39E 5955380.46 N 555512.79 E 0.482 4634.93 11264.49 91.180 179.520 3562.01 3655.59 4734.15 S 5183.07 E 5955281.25 N 555515.12 E 1.026 4734.15 11357.93 92.670 181.800 3558.87 3652.45 4827.52 S 5181.99 E 5955187.88 N 555514.67 E 2.914 4827.52 11453.64 91.850 180.070 3555.10 3648.68 4923.14 S 5180.43 E 5955092.25 N 555513.75 E 1.999 4923.14 11547.30 92.160 179.980 3551.82 3645.40 5016.74 S 5180.39 E 5954998.65 N 555514.34 E 0.345 5016.74 11641.09 92.170 179.190 3548.28 3641.86 5110.46 S 5181.07 E 5954904.94 N 555515.64 E 0.842 5110.46 11737.87 91.420 178.790 3545.24 3638.82 5207.18S 5182.77 E 5954808.23 N 555518.00 E 0.878 5207.18 11831.11 87.140 178.350 3546.42 3640.00 5300.36 S 5185.10 E 5954715.07 N 555520.95 E 4.614 5300.36 11926.98 82.490 177 :950 3555.08 3648.66 5395.76 S 5188.18 E 5954619.69 N 555524.67 E 4.868 5395.76 12023.62 77.610 177.290 3571.77 3665.35 5490.84 S 5192.13 E 5954524.64 N 555529.25 E 5.094 5490.84 12119.27 73.270 176.730 3595.81 3689.39 5583.27 S 5196.95 E 5954432.25 N 555534.69 E 4.573 5583.27 12174.40 70.620 175.500 3612.90 3706.48 5635.56 S 5200.50 E 5954379.98 N 555538.59 E 5.254 5635.56 12208.00 70.620 175.500 3624.05 3717.63 5667.16 S 5202.98 E 5954348.40 N 555541.29 E 0.000 5667.16 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. e 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 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12208.00ft., The Bottom Hole Displacement is 7693.35ft., in the Direction of 137.445° (True). 29 June, 2005· 14:42 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-105PB2 Your Ref: API 500292324371 Job No. AK-ZZ_0003677560, Surveyed: 14 May, 2005 ConocoPhif/ips Western North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4022.63 4027.00 12208.00 2330.39 2332.07 3717.63 288.88 N 289.35 N 5667.16 S 2739.91 E 2743.92 E 5202.98 E Tie-On Point Window Point Projected Survey e Survey too/proqram for 1E-105PB2 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 722.00 0.00 722.00 719.95 12208.00 719.95 CB-SS-Gyro (1E-105PB1) 3717.63 MWD+IIFR+MS+SAG (1E-105PB1) e 29 June, 2005 - 14:42 Page 5 of 5 Dri/lQuest 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-1 05 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,264.49' MD 11,332.00' MD 13,539.00' MD (if applicable) 15-Jul-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 )6 ~~ %- Signed 1lJðlL Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ,( ö )'" - ~ ~ ~ F~ . . AOGCC Helen Warmàn 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-1 05 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,264.49' MD 11,332.00' MD 13,539.00' 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. :::h;:e~;:~8 Signed FiLJ lJ~,ti Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 15-Jul-05 J...tJF- ~~~ ~'/L . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-1 05 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 4,395.00' MD (if applicable) . 15-Jul-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. :::o;~e~:~ Signed tJ ð.ÁI Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ;) ~.ç- tJl1\1 (2~ . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1E-105 PB1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00 I MD 4,395.00' 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 /) / J Date)() ~JJ\-tr Signed ~... diLl Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 15-Jul-05 ~ ~ S- - ~ t ~ F. If ~ . . 15-Jul-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1E-105 pb2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,022.63 I MD 4,027.00' MD 12,208.00' 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 ')0 ~~. r-' Signed Please call me at 273-3545 if you have any questions or concerns. Regards, I I t14wJ aiM Carl Ulrich Survey Manager AUachment(s) } tr~ ~V~ ~jL . . 15-Jul-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-1 05 PB2 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,022.63' MD 4,027.00 I MD 12,208.00' 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 Signed tJ ô ItLJ Date ~ Û kl~ ~\Ì- Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ tj'-- CI~~ F: 'I t. Change rams and test after csg Jeff This is the test chart after re-moving the 9 5/8' csg rams and re-installing the 3 1/2" X 6" VBRs. This test is the rams, door seal and well head break. «1E-105 BOP Rams Chart 051105.pdf» Dearl Gladden / Peter Wilson Doyon 141 CPAI Supervisor Office Phone 659-7170 Cell 943-1054 Fax 659-7103 Mail - NSK 33 e-mail-N1334@conocophillips.com lE-105 BOP Rams Chart .. lE-105 BOP Rams Chart Content-DescrIptIOn: 05ll05.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/12/2005 10:52 AM Revision to 1 E-l 05 Permit to Drill package. . . Hi Tom - Please find attached a revision to the proposed drilling program for 1E-105. The revision includes the steps to be done after the intermediate hole section is cased and cemented, so that the rig can be released for the exploration work in mid-February. As I mentioned on the phone our plan is to case and cement the intermediate hole section of 1E-105, move Rig 141 to NPRA for exploration work, move back to 1E pad in late April, drill and complete 1E-117, and then move back onto 1E-105 to complete the remaining drilling operations. Additionally I have include the steps we will take with regard to 1E-105PB1, a well bore we will drill and abandon in order to gain geologic information in order to better geo-steer the 1E-105 well bore. With regard to the Area of Review for the nearby wells, we will complete this review and send the AOGCC the required information in the near future. My conclusion from our recent conversation is that the AOGCC will issue Permits to Drill for 1E-105, 1E-105L1, and 1E-105L2 (assuming all other issues have been adequately addressed and resolved) without the Area of Review being completed. However such Permits to Drill would have a stipulation that the well could not be operated as an injector until the integrity of nearby wells was verified. If my conclusion is incorrect and we need to provide some more information before the Permits to Drill can be issued, please let me know ASAP. «1 E-1 05 Drilling Program Revision.pdt» Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 "G" Street Anchorage, Alaska 99501 steve.mckeever@conocophillps.com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 "The short fortune-teller who escaped from prison was a small medium at large." C t t D . t· . 1 E-l 05 Drilling Program on en - escnp Ion. R .. df eVISlOn.p Content-Type: application/octet-stream Content-Encoding: base64 lE-lOS Drilling Program 20f2 1/27/20053:56 PM . . .~ lQ::. ~~'!3 rVd ~ r?b. , ¡ , l6 17 I ¡ i~ i! "'" FRANK H. MURKOWSKI, GOVERNOR ~1,ASIiA OIL AND GAS CONSERVATION COMMISSION 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 IE-I05 ConocoPhillips Alaska, Inc. Permit No: 205-006 Surface Location: 391' FSL, 224' FEL, SEC 16, TUN, RIOE, UM Bottomhole Location: 1338' FNL, 345' FEL, SEC. 27, TIIN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (Kuparuk IE-105PH) and API number (50-029-23243-70) from records, data and logs acquired for well Kuparuk IE-105. In your application it was stated that this well and the subsequent multi-lateral wellbores would be pre-produced and then converted to injection service after a minimum of 30 days production. Regulation 20 AAC 25.402(c)(15) requires determination of the mechanical condition of any well penetrating the injection zone within a one-quarter mile radius of a proposed injection well. In the case of IE-105, there are a number of West Sak wells and at least one Kuparuk well within one-quarter mile of the proposed trajectory. As currently planned, IE-105 and the subsequent multi-lateral wellbores to be drilled from it are designed to meet the requirements for injection wells as specified in 20 AAC 25.412. However prior to converting IE-105 and the multi-laterals to injection service CPAI must provide information sufficient for the Commission to determine that all of the surrounding wells were satisfactorily cemented to confine any fluids within the West Sak sands. Your application also indicates that, after setting production casing, operations will be shutdown to allow the rig to be employed in NPRA. Please notify the Commission via electronic mail when operations are shutdown and when they are resumed. No sundry notice is necessary per 20 AAC 25.072(a). 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. PI e provide at least twenty-four (24) hours notice for a representative of the Commission . ess any required test. Contact the Commission's petroleum field inspector at (901 659 6 ager). BY ORDER OF THE COMMISSION DATED this~day of February, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1£-105 . . Subject: 1E-105 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 24 Jan 2005 10:24:38 -0900 To: Mike.R. Greener@conocophillips.com CC: Randy Thomas <Randy.L.Thomas@conocophillips.com> Mike, I was looking further into the package for IE-IDS and on there are two directional planning packages, IE-IDS PBl and IE-IDS. I do not find any "text" or description regarding drilling a pilot hole and then doing an open hole sidetrack. It is appropriate to include some discussion of your intent. Based on the sidetrack point and the lengths given some 1300' of hole will be "abandoned". Is there an expectation that that section will contribute production to the well?? Thanks, Tom Maunder, PE AOGCC 1 of 1 1/24/2005 10:38 AM IE-105. -105Ll, -105L2 . . Subject: IE-lOS, -105L1, -105L2 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 24 Jan 2005 09:38:40 -0900 To: Mike.R.Greener@conocophillips.com CC: Gary Targac <Gary.Targac@conocophillips.com>, Randy Thomas <Randy.L. Thomas@conocophillips.com> Mike and Gary, With regard to these wells, is there a plan to pre-produce?? Since the wells will ultimately be injectors, the Area of Review task must be done. AOR means that the cementing record of any penetration that falls within 1/4 mile distance of the planned wellbore track must be examined to assure that such penetrations do not provide a potential conduit out of the intended zone. The pertinent beginning "point" is where the motherbore penetrates the top of the West Sak and the ending "point" is the furthest extent of the toe of any of the laterals. Based on our preliminary review of the trajectory, the WS wells you potentially need to examine are: 1E-114 and laterals, 1D-123, 1D-126, 1D-127, 1E-126 and laterals, 1E-168 and laterals. The potential Kuparuk wells are 1E-33, 1E-33PB1, 1J-09, 1E-34 and 1E-22. 1E-03 or 1E-103 may also need to be checked. I can't determine the name on the plot I am looking at. My source of the information is a plan view of the proposed well trajectories. A few of the wells, 1E-34, 1J-09 and 1E-22 will likely fallout since their WS penetrations are probably outside the 1/4 mile distance. The only "wild card" that you also need to consider are any "lost" hole sections that may have been drilled. Please call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 1/24/2005 10:38 AM Conoc~illips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com January 7'\ 2005 RECEIVED JAN 11 2005 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue Suité 100 Anchorage, Alaska 99501 Alaska '¡~4 (1tll1$. Commission Am:nofbge Re: Applications for Permit to Drill, West Sak Injector, lE-I05, lE-I05 Ll, lE-105 L2 Dear Commissioners: II ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for a pre-produced onshore injection well, a Tri- lateral horizontal well in the West Sak "A2", "B" and "D" sands. The main bore of the well will be designated lE- 105, the "B" sand lateral will be designated lE-105 Ll, and the "D" sand lateral will be designated lE-105 L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each ofthese well bores. The expected spud date of lE-l 05 is February 5th, 2005. 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 . 1 a. Type of Work: Drill 0 Re-entry 0 RedrillU 11 b. Current Well Class: Stratigraphic Test 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 391' FSL: 224' FEL: Sec. 16, T11N, R10E, UM ¡/ Top of Productive Horizon: 1155' FNL, 354' FEL, Sec. 22, T11N,R10E, UM / Total Depth: 1338' FNL, 345' FEL, Sec. 27, T11N, R10E, UM ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550300 16. Deviated wells: Kickoff depth: 300 ft. 18. Casing Program Size Hole 30" 16" y- 5959981 Zone- 4 Maximum Hole Angle: 96° Specifications Weight Grade Coupling Length 62.5# H-40 Welded 80' 68# L-80 BTC 4537' 40# L-80 BTCM 8180' 15.5# L-80 BTCM 5473' Casing 20" 12.25" 13.325" 9-5/8 " 8.5" 5.5" 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Size . ~y RECEI\IED J" JAN 1 1 2005 Exploratory U Dev~!D~~t Qiill ð G i!$h Cûn~" ~~~~~í~~~~D Service 0 Development Gas E]\nc orage Single Zone 0 5. Bond: LJ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-105 6. Proposed Depth: 12. Field/Pool(s): MD: 13653' " TVD: 3625' Kuparuk River Field 7. Property Designation: " ADL 25651/25660 8. Land Use Permit: West Sak Pool ~. // LÞ 'Az~ r ,,{ ¡-IV 13. Approximate Spud Date: ALK 469/470 9. Acres in Property: 2560 2/5/2005 14. Distance to Nearest Property: 10206' 10. KB Elevation 15. Distance to Nearest .eu",' 0 Þ t C-(2k -<-ao ,,,.0 Well within Pool: ~F-114, Hì2'@ê{þ1QI"looó > (Height above GL): 28 feet 17. Anticipated Pressure (see 20 MC 25.035) Max. Downhole Pressure: 1654 psig I Max. Surface Pressure: 1250 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 225 sx AS I 2474' 870 sx AS Lite, 210 sx DeepCrete 3675' 630 sx DeepCrete 3625' slotted liner Top MD 28' 28' TVD 28' 28' 28' 3560' MD 108' 4537' 8180' 13653' , 28' 7562' (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD perfOration Depth TVD (ft): Drilling Program 0 Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: Randy Thomas ~~ Commission Use Only Permit to Drill I API Number: I Permit Approval Isee cover letter Number: ;2.CJS- OCb 50- 62t1 - 23z Y3~()Õ Date: for other requirements Conditions of approval: Samples required 0 Yes ~ No Mud log required 0 Yes ~ No H en sulfide measures ~ Yes 0 No Directional survey required ~ Yes 0 No \XL\\-\-'I \C,. ~~, '3(:>'~ \~,=>\. ßC)\> \It'>~ \",\f(~o. \ ~ \'-\~v'(c;. \ ~C!>\O" \,J'\.~ ~:M.c;. \ \ ~,,'<. "" O~ ~ ~«'$\"~ ~ w~'<."r' ~-\ ~~" ~ "':. \><t, þ.. \C) ~ \3 BY ORDER OF r.."l ¡(' COMMISSIONER THE COMMISSION Date' "" '1"¡ D':> ORIGINAL 20. Attachments: Filing Fee 0 Property Plat 0 BOP Sketch LJ Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Form 10-401 Revised 3/2003 . Shallow Hazard Analysis 0 20 MC 25.050 requirements 0 Contact Mike Greener @ 263-4820 Title Kuparuk Drilling Team Leader Phone -z....bS-68:S0 Date I I? los PreDared bv Sharon. AI/suo-Drake Submit in duplicate · .Plication for Permit to Drill, Well 1E-105 Revision No.O Saved: 10-Jan-05 Permit It - West Sak Well #lE-I05 Application for Permit to Drill Document Moximiz$ Well Vglue Table of Contents 1. Well Name............... ..... ........... ............... ............ ....... ..... ....... ... ..... ......... .......... ..... ...... .............. 2 Requirements of 20 AA C 25.005 (f).. .......... ........ ..... ..... ............ ........ ..... ...... .............. .... ................... ....... ........ .......2 2. Location Summary ... ......... .......... ............ ..... ..... ............. ..... ............ ~........... ....... ....... ..... ..... .... 2 Requirements of 20 AA C 25. 005( e)(2) .......... ........ ............................. ... ........... ..... .................. ..... ..... ......... ..... ........2 Requirements of 20 AA C 25. 050(b) ..... ............ .............. ................. ..... ...... ..... .., ......... ....... ....... ..... ........... ............ ..3 3. Blowout Prevention Equipment Information ....................................................................... 3 Requirements of 20 AA C 25. 005( e)( 3).. ...... ...... ................... ............ ....... ..... ..... ......... .... ........ ......... .............. ....... ...3 4. Drilling Hazards Information . ....... ............. ................. ... ....................... ........ ........... ........ ..... 3 Requirements of 20 AAC 25.005 (e)( 4 )...................................................................................................................3 5. Procedure for Conducting Formation Integrity Tests......................................................... 3 Requirements of 20 AAC 25.005 (e)(5 )...................................................................................................................3 6. Casing and Cementing Program............................................................................................ 4 Requirements of 20 AA C 25. 005( e)( 6).... ............ ... .... ..... .... ............ ................. ........... .............. ......... ....... ..... ....... ..4 7. Diverter System Information .................................................................................................4 Requirements of 20 AA C 25. 005( e )(7)..... ........ ....................... ............... ...... ........ ...... ............ ...... .............. .............4 8. Drilling Fluid Program...... ... .... ........ .... ........................... .............. ... ......... ........ ............. ........ 4 Requirements of 20 AA C 25. 005( e)( 8) ............ .............................. ......... ..... ........... ....... ....... .............. ...... ............ ...4 Suifaee Hole Mud Program (extended bentonite) ..................................................................................................4 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 (e)(9 )...................................................................................................................5 10. Seismic Analysis.................. ......... .................... .... ..... ....... ....... ...... ....... ........ ...... .............. .......... 5 Requirements of 20 AAC 25.005 (e)( I 0 ).................................................................................................................5 11. Sea bed Condition Analysis.............. ...... .... ....... ... ....... ...... ........... ....... ... .... ......... ..... .... ..... ...... 5 Requirements of20 AAC 25.005 (e)( I I ).................................................................................................................5 1E-105 PERMIT IT. doc Page 1 of 8 Printed: 10-Jan-05 ORIGiNAL · .Plication for Permit to Drill, Well 1 E-105 Revision No.O Saved: 10-Jan-05 12. Evi den ce of Bonding .... ..... ... .... ....... ......... ..... ...... .................. .... ... ... .................................... .... 5 Requirements of20 AAC 25.005 (c)( 12).................................................................................................................5 13. Proposed Drilling 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 AA C 25.005 (c)( 14) ......... ..... .... ................... ........... .... .................... '.' .... .... ........ ...................... 7 15 . Attachments ............... ............ ... ....... ....... ....................... ....... ..... ...... ........ ........... ......... ............ 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 of20 AAC 25.005 if) Each wel! must be identified bi' a unique name designated by the operator and a unique APlnumber assignul by the eommi.uion under 20 AAC 25.i)4(J(b). For a well with multiple well branches, each branch must .çiJnilarl.v be identified by a unique name and API mld)er by adding a suffix to the name de,çjgnatedfÓr the 1-vel! by rhe operator and [0 the number assigned to the 'l'vell by the co!nmission. The well for which this Application is submitted will be designated as IE-105. 2. Location Summary Requirements of20 AAC 25.005(c)(2) An application .fiJr a Permit tu DriilnlUst be accumpanied by each ofthefÒllowing ilwLI'. exceptfÒr an item a/rea{¡-v onj¡¡ewith the commission and identified ÙI the applïcation: (2) Ii plat ident{lying the propulV and the property's OHmer.I' and showing (A)the coordinafN o/the proposed !ucatÙm of the weli at the surfáce. al the top (if each objeetivefol7nation, and at total depth, referenced to ¡;ovemm<,ntaj section lines. (B) the coordinates (it the proposed location '?f the well at the swface, retàenced 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 weli at the top (<{'each objectÏvejÓrmation and at total depth: Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,959,981 ' Eastings: 550,300 4,889' FNL, 224' FEL, Section 16, TllN, RlOE L RKB Elevation I 94.1' AMSL r Pad Elevation 66.1' AMSL Location at Top of Productive Interval (West Sak "A2" Sand) 1,155' FNL, 354' FEL, Section 22, TllN, RlOE ASP Zone 4 NAD 27 Coordinates Northings: 5,958,470 Eastings: 555,464 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: 8,180 3,675 3,581 Location at Total Depth 1,338' FNL, 345' FEL, Section 27, T11N, RlOE Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: 13,652 3,625 3,531 ASP Zone 4 NAD 27 Coordinates Northings: 5,953,009 Eastings: 555,521 and (D) other i/¡júrmation required by 20 AAC 25.050(1)); ORIGiNAL 1E-105 PERMIT IT. doc Page 2 of 8 Printed: 10-Jan-05 · .Plication for Permit to Drill, Well 1E-105 Revision No.O Saved: 10-Jan-05 Requirements of20 AAC 25.050(b) If a well is to be intentionally deviated. the application for a Permit to Drill (Form 1O-40]) must (l) include a plat, drawn {() a suitable scale. showing the path of the proposed wellbore, including all adjacent wellbores within 200feet of any portion of'the proposed well; Please see Attachment I: Directional Plan and (2 )for all well,· within 200/Út of the proposed wellbore (/1) list the name.v or the operaturs of those H'ells, to the extent that ¡hose names are known or discuverable in public records, and show that each named operator has beenfumished a copy of the application by certijied mail; or (B) state that the applicant is the only affected OWNer, The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AA C 25. 005( c)( 3) An application[<Jr a Permit to Drill must be accompanied by each (!! the /Òllowing items. except{or an item already 011 Jïie with the commission /lnd identijied in the appfication; (3) a diagram and description orthe blowout prevention equipment (ROPE) as required by 20 AAC 25,035. 20 AAC 25.1136, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete welllE-105. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. ."... 4. Drilling Hazards Information Requirements of 20 AA C 25.005 (c)( 4) An appiicatÙm for a Permit to l)rill nutst be acc(nnparâed b.v each (~l thefÒlIoi1/ing iterns, exceptfor an itan a1ready OIl file 1-vith the COlJu¡Ûssion and identified in ¡he appiicalÍun: (4) inforrruuion on drilling h£l¡;irds, including (iI) the /'iUnimum downhole presSIIre that may be encounlered. criteria used to determine it, and /'iULrimulII potentia! surface pressure based on a methane gradient: The expected reservoir pressures in the West Sak sands in the lE-105 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) is 1 ,25Ó psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak 1\2 sand formation is 3,675'. The MPSP is calculated thusly: MPSP = (3,675 ft)(0.45 - 0.11 psi/ft) =1,250 psi ' (B) data on potentia! ,gas zones; The well bore is not expected to penetrate any gas zones. and rCi data conceming potemial causes of hole problemv such as abl1urmaliy geo-pressured strata, 10.1'1 circulation zones. and zones that have a prupensity jÌir differential slicking: Please see Attachment 2: lE-105 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of20 AAC 25.005 (c)(5) An applicatiun for a Permit to Drill must be accompanied by each of'the.fÌJllowing items, exceptjÓr an item already on .file with the commission and identified in the applicatiun: (5) a descriptioll oftlie procedurejiJr conductingjÒrl!lalion inte!?rit)' le.l'ts, as required under 20 AAC 25JJ30(j); lE-105 will be completed with 9-5/8" 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. ORIGINAL 1£-105 P£RMIT IT. doc Page 3 of 8 Printed: 10-Jan-05 · .Plication for Permit to Drill, Well1E-105 Revision No.O Saved: 10-Jan-05 6. Casing and Cementing Program Requirements of20 AAC 25.005(c)(6) An application JÓr a Permit to Drill must be accompllnied by each (lfthef(lllowing items. except jar an item already onfile with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 A4.C 25.030, and a description olany slotted liner. pre-pojimlted liner. or screen to be installed: I Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Fbg Size Weight úngth MD/TVD MD/TVD OD (in) (in) (/b(ft) Grade Connection (ft) (ff) (ff) Cement Program 20" 40" 62.5 H-40 Welded 80 28' /28' 80' / 80' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 4,537 28' /28' 4,537' /2,474' 870 sx ArcticSet Lite Lead, 210 sx DeepCRETE Tail Cement Top planned @ 5,033' 9-5/8" 12-1/4" 40 L-80 BTCM 8,180 28' /28' 8,180' 13,675' MD I 2,655' TVD. Cemented wI 630 sx DeepCRETE 5-1/2 8-1/2" A2 Sand 15.5 L-80 BTCM 5,473 7,562' 13,560' 13,653' /3,625' Slotted- no cement ./ slotted Lateral (lE-105) 5-112 8-1/2" B Sand Lateral 15.5 L-80 BTCM 6,168 7,472' /3,552' 13,640' 13,453' Slotted- no cement slotted (lE-105 LJ) 5-112 8-1/2" D Sand Lateral 15.5 L-80 BTCM 6,392 7,242' /3,499' 13,634' 13,399' Slotted- no cement slotted (lE-105 L2) 7. Diverter System Information Requirements of 20 AA C 25. 005( c )(7) AI! applicatiol! jilr a Permit to Drill mllSI be accompanied by each of the /Ólluwing items. except for an ilem alrea{rv on file with Ihe commission and iliet/Ii/ied in 11u: applìcalion: (7) a diagram and description (¡(the diverter system as required by 20 AAC 25.035, unless this requirelP.ent is waived by the commission under 20 AAC 25JJ35(h)(2); A 21-114",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of IE- 105. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AA C 25. 005( c)( 8) An applicalionjìJr a Permir to Drill must be accumpanied by each olthe/ÒUowing ¡¡ems. exceptfor an item alreadv onjiiewitli the commission and ideniified in the applicalion: (8) a drilling fluid program, including a diagram and description 4lhe dri!iing jluid system, as required by 20 AA C 25JJ33; Dríl1ing will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 10-3/4" Casing Point Initial Value Final Value Initial Value Density (ppg) 8.5 9.2 9.2 Funnel Viscosity 150 250 200 (seconds) Yield Point 50-70 50-70 30-50 (cP) Plastic Viscostiy 20-45 20-45 15-20 (lbIJOO sf) pH 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate NC-8.0 NC-8.0 5.0-7.0 (cc/30min)) ORIGINAL Final Value 9.6 300 30-50 15-20 8.5-9.0 5.0-7.0 1E-105 PERMIT IT. doc Page 4 of 8 Printed: 10-Jan-05 · .Plication for Permitto Drill, We1l1E-105 Revision No.O Saved: 10-Jan-05 *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4" Casing Shoe to 7-5/8" Casing Point Lateral Mud Program (MI VersaPro Mineral Oil Base) A2, B, D sand laterals Density (ppg) Funnel Viscosity (seconds) Plastic Viscostiy (lb/lOO sf) Yield Point (cP) API Filtrate (cc /30 min)) Chlorides (mg/l) pH MET Initial Value 9.0-9.1 45-60 Density (ppg) Plastic Viscostiy (lb/l00 sf) Yield Point (cP) Value 9.0 r 15-25 18-28 <4.0 80:20 >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 12-18 26-35 HTHP Fluid loss (ml/30 min @ 200psi & 1500 Oil/Water Ratio Electrical Stability 9. Abnormally Pressured Formation Information Requirements of20 AAC 25.005 (c)(9) An application/i;r a Permit tu Drill must be accompanied by each of ¡he following items, except for an item already on/He with the commissiun and identified in the application: (9)/or an o.ploratory or stratigraphic test well, a tabulatioJl setting out the depths ,<{predicted abnormaify geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 4-6 <500 9.0-9.5 <20.0 10. Seismic Analysis Requirements of 20 AA C 25.005 (c)( 10) All application for a Permit to Drill must be accompanied by each ofthefÒllowing items, exceptIor an item alrew¡',. olljile with the commission and identified in the application: (10) for an exploratory or stratigraphic test well. a seismic refraaion or reflection analysis as reqllir<~d by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AA C 25.005 (c)( 11 ) An application for a Permit to Drill must be accompanied by each (if ¡he f(¡flowing items, except for an item already onfHe with the cOlnmission and identified in the application: (11 )f(¡r a well drilled/rom an '<f¡:fhore platjÒrm. mobile bottomjÌJunded structure. jack-up rig. orjloating drilling vessel. an analysis of seabed conditions as required by 20 AAC 25.06f(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AA C 25.005 (c)( 12) An applicatioll/iJr a Permit to Drill mllst be accorrqJailied by each ofthef(¡llowing items. except{or an item alread,. onjïie with the commission and identified in the application: (12) evidence showing that the requiremmts of 20 AAC 25.025 fBonrling}íwve been nit'[: Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. ORIGINAL 1E-105 PERMIT IT. doc Page 5 of 8 Printed: 10-Jan-05 . . The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +1- 108' RKB. Install landing ring on conductor. Move in I rig up Doyon Rig 141. Install 21-114" Annular with 16" diverter line and function test. Spud and directionally drill 16" hole to casing point at +1- 4,537' MD I 2,474' TVD as per directional plan. Run MWD tools as required for directional monitoring. Run and cement 13-3/8",68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to t'.. ~ 2500 psi for 30 minutes and record results. Perform top job if required. ~ f¥:)~~ \~ ~Oþ~ Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as des~r~d ~bJve in Section 3 ~bov~test to 3,000 psi (annular preventer to 1500 psi) NotifY AOGCC 24 hrs before test. PU 12-1/4" bit and 6-114" drilling assembly, with MWD, L WD & PWD. RIH, clean out cement to top offloat equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 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) Directionally drill to 9-5/8" casing point at 8,180' MD I 3,675' TVD, the prognosed top of the A2 sand. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 5,033' MD 12,655' TVD ifUgnu formation is not oil bearing. (Top of cement to be 500 feet (MD) above shallowest oil bearing sand ifUgnu is oil bearing). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. r Application for Permit to Drill, Well 1 E-1 05 Revision No.O Saved: 27-Jan-05 13. Proposed Drilling Program Requirements 0/20 AAC 25.005 (c)(J 3) An apphcCltionfÓr a Permit to Drill must be accompanied by each (?fthef()lhrwing items. exceptIor an item already onfile wÜll fhe commÙ;sion and identified in the app!ictltìon: 1. 2. 3. 4. 5. 6. 7. 8. 9. 12. RHI with.Dpen ended 4-1/2" tubing to a depth 01"3200 tl MD. 1988 feet TVD.Make up tubing.hanger and hang tubing. Set back pressure valve. JJ..NLPDJ.e...Q9\YfL!2QYi::. N.i ppl e up al}(.Lt.e~LP:ee~.Pl!11Þ..¡.tçk..pre§2.L1TeYªtYe. 14. Displace well to diesel by pumping down the tubin¡l. taking returns fi"om the annulus. 15. Install BPV. Rig dowr and move oi1'welJ. Ö~\;'t)~ \ ~ \) . ! 6. Following exploration operations, and operations on 1 E-117. move baek onto IE-I05 (approximately on rvIav lO, 2005). 17. Rig up and displace diesel from well with 9.0 ppg. fluid. Install BPV 18. Nipple d9wn tree. Nipple up and test 13-5/8 x 5,000 psi. Pull BPV. 19. Rig up and pun tubing. -hh20. PU 8-112" PDC Bit and 6-114" 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 -hh21. 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 8-112" lateral modeled to be less than 12.0 ppg). 14..;:2..4._ DirectionaUv drill to TD of lE-105PBl at 12. In to gain geologic in1Òrmation. PuB back to 10.855' ["1D and Dgirectionally drill 8-112" hole to TD of lE-I05ßt +1- 13,653' MD 13,625' TVD as per directional plan. ·l~23. POOH, back reaming out oflateral. POOH. +&24. Run USIT log for cement bond. 1 E-105 PERMIT IT Revised with suspension. doc 1 E 105 PERMIT IT. doc Page 6 of 8 Printed: 27-Jan-05 ~ l-\- ~I .~:J- . . Application for Permit to Drill. Well 1E-105 Revision No.O Saved: 27-Jan-05 , T,",\~ ~~\ ~ ~ ~-on(~ Note: Remaining operations are covered under the I E-I 05 L1 and I E-I 05 L2 Application jor Permit to Drill, and are provided here for information only. 19,27. Run and set Baker WindowMaster whipstock system, at window point Of~D 13~VD, the top of the "B" sand. '1'-\~d :6S;) ~?JL Mill 8-112" window. POOH. +1-:25. PU and run 5-112" slotted liner. 18-:26. Land liner, set liner hanger @ +1- 7,650' MD 13,582' POOlI. 2-h29. ~30. Pick up 8-112" drilling assembly with L WD and MWD and PWD. RIH. Drill to TD of "B" sand lateral at 13:6'40' MD / 3,,fs3' TVD, as per directional plan. POOH, back reaming out of lateral. POOH. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. PU and run 5-112" slotted liner. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. Release hanger running tool. POOH. 23-3]. U,32. .:2S.- ~., ~_..).). Yi-:34. 2735. 2&,36. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly.and release ITom assembly. POOR. 29-037. Run and !it;[ B¡¡lœt W111dowMaster whipstock system, at window point of~MD 13~TVD, the top of the "D" sand. ")d-~' "'S'-f\~ :;;0,38. Mill 8-112" window. POOH. J-h39. Pick up 8-112" drilling assembly with L WD and MWD and PWD. RIH. ./ ../ J.b40. Drill to TD of"D" sand lateral at 13,634' MD 13,399' TVD, as per directional plan. 33A 1. POOH, back reaming out of lateral. POOH. 3442. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. ::&:43. PU and run 5-112" slotted liner. ;;'6,44. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. ;;+'45. Release hanger running tool. POOH. ;;,&46. Make up junction isolation I re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 3,9-,47. POOH, laying down drill pipe as required. ~48. PU injection as required and RIH to depth. Land tubing. Set BPV. 41·,49. Nipple down BOPE, nipple up tree and test. Pull BPV. 4b50. Freeze protect well with diesel by pumping into 4-112" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. *51. Set BPV and move rig off. 4+.52. Rig up wire line unit. Pull BPV. ~2.;.?,___Set gas lift valves in mandrels. Operate well on gas lift for +/- +WJ9.days. Shut well in. 4f;-;54. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 1£-105 PERMIT IT Revised with suspension.doc-1E-105··PERMITITdGG Page 7 of 8 Printed: 27-Jan-05 't ,,- 19. ~~20. . .Plication for Permit to Drill, Well 1 E -105 Revision No.O Saved: 10-Jan-05 13. Proposed Drilling Program Requirements of20 AAC 25.005 (c)(13) An applicationfÒr a Permit to Drill must bt' accompanied by each a/thefollowing item!', except fot au item alrewiy onßle with the commission and identified in the application: 1. 2. 3. The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +1- 108' RKB. ring on conductor. Move in 1 rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. Spud and directionally drill 16" hole to casing point at +1- 4,537' MD 1 2,474' TVD as per directi MWD tools as required for directional monitoring. Run and cement 13-3/8",68#, L80, BTC casing to surface. Displace cement with mud and ressure test casing to ~ ~ 2500 psi for 30 minutes and record results. Perform top job if required. ~ D-\\~ <'-t... \ ~ .\.o~~ c\:> ""-'tofe) c.è}. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described aboy. in Section 3 above and test to J9iJ1.4 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. fI1'.... PU 12-1/4" bit and 6-114" drilling assembly, with MWD, LWD & PWD. RIH, ean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the at collar. 4. 5. 6. 7. Drill out cement and between 20' and 50' of new hole. Perform formatio ntegrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) Directionally drill to 9-5/8" casing point at 8,180' MD 13,675' TVD he prognosed top of the A2 sand. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement nd displace with mud (top of cement to be 5,033' MD 12,655' TVD ifUgnu formation is not oil bearing. (Top 0 ement to be 500 feet (MD) above shallowest oil bearing sand if U gnu is oil bearing). Pressure test casing to 3 00 psi for 30 minutes and record results. ~V\(~~~(t~ Biesel. 8. 9. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-518" annulus with water, followed b 'l;) \. 12. PU 8-112" PDC Bit and 6-1/4" drilling assembly, w· MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is ta ed more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of ne hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (e ected ECD's in 8-1/2" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 8-1/2" hole to TD at +1 3,653' MD 13,625' TVD as per directional plan. 15. POOH, back reaming out of lateral. Th \ ~ ~((:~\ Vt..\ ~ ~OS ..00<0 16. Run USIT log for cement bond. 17. PU and run 5-1/2" slotted liner. 18. Land liner, set liner hanger @ 1-7,650' MD 13,582'. POOH. ~ ~ Note: Remaining operation 'are covered under the lE-105 Ll and lE-105 L2 Application for Permit to Drill, and are provided here for informatio only. Run and set Baker W· dowMaster whipstock system, at window point of 7,562' MD 1 3,560' TVD, the top of the "B" sand. 21. Pick up 8-112" rilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD "B" sand lateral at 13,640' MD 13,453' TVD, as per directional plan. 23. POOH, b reaming out oflateral. POOH. 24. RIH wit whipstock retrieval tool. Retrieve whipstock and POOH. 1E-105 PERMIT IT. doc Page 6 of 8 Printed: 10-Jan-05 ORIGINAL · .Plication for Permit to Drill. Well 1E-105 Revision No.O Saved: 1 Jan-05 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and packer atop assembly and release from assembly. POOH. to depth. Orient and set 25. PU and run 5-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. ,...- 29. Run and set Baker WindowMaster whipstock system, at window point of7, "D" sand. , MD / 3,560' TVD, the top of the L"d- 30. Mill 8-1/2" window. POOH. 31. Pick up 8-1/2" drilling assembly with L WD and MWD and PW 32. Drill to TD of "D" sand lateral at 13,634' MD / 3,399' TV 33. POOH, back reaming out of lateral. POOH. 34. RIH with whipstock retrieval tool. Retrieve whipst 35. PU and run 5-1/2" slotted liner. 36. . Orient hanger to window and land hanger. 37. Release hanger running tool. POOH 38. Make up junction isolation / re-e y assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and reI se from assembly. POOH. 39. POOH, laying down drill Ipe as required. 40. PU injection as requ' d and RIH to depth. Land tubing. Set BPV. 41. , nipple up tree and test. Pull BPV. ~0~~~ð \(à, RIH. 42. well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to 43. 44. Ri up wire line unit. Pull BPV. et gas lift valves in mandrels. Operate well on gas lift for +1- 180 days. Shut well in. 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 AA C 25.005 (c)( 14) A.n applicationJÓr a Permit to Drífl mllstc be accompanied bv each o(fhefÓí!owing ilems, exccptJÓr an item already onfìle with the commission and identified in the application: (/4) a general description (~f how the operator plans to dÎ,\pose (¡fdrilling mud and cultings and a statement (if whether the ('perator intends to requt'st authorization under 20 AAC 25.080/or an annular disposal operation in ¡he wel!.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a ./ permitted annulus on IE 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 IE 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 substances, 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. ORIGINAL 1£-105 PERMIT IT. doc Page 70t8 Printed: 10-Jan-05 · 15. Attachments Attachment 1 Doyon 141 West Sak 2004 3ksi BOP Configuration (1 page) Attachment 2 Directional Plan (23 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 CemCADE Summary (2 page) Attachment 5 Well Schematic (1 page) ORIGINAL .PIiCatiOn for Permit to Drill, Well 1E-105 Revision No.O Saved: 10-Jan-05 1E-105 PERM/TIT.doc Page 8 of 8 Printed: 10-Jan-05 IE-I" Drillin2 Hazards lummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole /13-3/8" Casin2 Interval Hazard Broach of Conductor Risk Level Low Gas Hydrates Moderate .I Running Sands and Gravels Hole swabbing on trips 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 12-1/4" Open Hole / 9-5/8" Casin2 Interval Hazard Running Sands and Gravels Gas Hydrates Risk Level Low Low Stuck Pipe Low Abnonnal Reservoir Pressure Lost circulation Hole swabbing on trips Low 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 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Abnonnal Reservoir Pressure Stuck Pipe Risk Level Low Low Lost Circulation Hole Swabbing on Trips 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 ORIGINAL 1£-105 Drilling Hazards Summary. doc prepared by Steve McKeever 1/4/2005 10:18 AM Rig: Doyon 141 Location: West Sak Client: CPA) Revision Date: 12/22/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 133/8",72.0# casing at 4,537' MD Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 500' MD above Ugnu C (3147' MD annular length). Tail Slurry Minimum thickening time: 240 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.3132 ft3/ft x 3147 x 1.40 (40% excess) = 0.4257 ft31ft x 80' (Shoe Joint) = 1379.9 ft3 + 34.1 ft3 = 1414.0 ft31 2.26 ft3/sk = Round up to 630 sks 1379.9 ft3 34.1 ft3 1414.0 ft3 625.7 sks BHST = 81°F, Estimated BHCT = 70°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 2.0 Pause 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Pause 0.0 0.0 5.0 23.0 MUDPUSH II 6.0 40.0 6.7 29.7 DeepCRETE 6.0 251.8 42.0 71.7 < Top of Tail at Pause 0.0 0.0 5.0 76.7 5,033' MD Mud 7.0 599.2 85.6 162.3 Mud 3.0 15.0 5.0 168.3 < 95/8",40.0# casing in 12 1/4" OH TD at 8,180' MD (3,675' TVD) MUD REMOVAL Recommended Mud Properties: 9.3 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 19-22, Ty ? 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR1G1NAL Rig: Doyon 141 location: West Sak Client: CPAI Revision Date: 12/22/2004 Prepared by: Mike Martin location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 emaH: martin 13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 108' MD < Base of Permafrost at 1,977' MD (1,539' TVD) < Top of Tail at 3,737' MD < 133/8", 72.0# casing in 16" OH TD at 4,537' MD (2,474' TVD) Mark of Schlumberger IUlblPgep 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 3,737' MD. Lead Slurry Minimum pump time: 310 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (108') x 1.00 (no excess) = 0.4206 ft31ft x (1977' - 108') x 3.50 (250% excess) = 0.4206 ft31ft x (3737' - 1977') x 1.35 (35% excess) = 110.1 ft3 + 2751.4 ft3+ 999.3 ft3 = 3860.8 ft3 /4.45 ft3/sk = Round up to 870 sks 110.1 ft3 2751.4 ft3 999.3 ft3 3860.8 ft3 867.6 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 210 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.4206 ft31ft x (4537' - 3737') x 1.35 (35% excess) = 0.8315 ft3/ft x 80' (Shoe Joint) = 454.2 ft3 + 66.5 ft3 = 520.7 ft3/ 2.52 ft3/sk = Round up to 210 sks 454.2 ft3 66.5 ft3 520.7 ft3 206.6 sks BHST = 49°F, Estimated BHCT = 65°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 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 7.0 704.4 100.6 133.9 DeepCRETE 5.0 92.7 18.5 152.4 Pause 0.0 0.0 5.0 157.4 Water 5.0 20.0 4.0 161.4 Pause 0.0 0.0 5.0 166.4 Mud 7.0 625.0 89.3 255.7 Mud 3.0 15.0 5.0 260.7 MUD REMOVAL Recommended Mud Properties: 9.5 ppg. Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21. Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL . . .--f'.r :8: :8: .--f'.r --.b L 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-~" to 6" variables To be tested to 250 psi and 3,000 psi at initial ~ ? installation and every 14 days thereafter. i( ~ ? 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 ~ ../ ConocoPhillips Alaska Doyon 141 West Sak 3 ksi BOP Configuration 13-5 BOP 3K diagram.vsd Sheet 1 of 1 prepared by Steve McKeever 8/11/2004 ORIGINAL . . ~ 5.........................mm.r-'I..m....................... ..... r- DFtIL.LINI3 A Halliburton Company y ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-1 05 Plan 1E-105 PB1 Plan: 1 ..105 PB1 (wp05) Proposal Report 10 January 2005 OR\G\NAL -1200 I, , -800 , I , -400 ,I, o 400 800 "íl"IL~"'1 ~- Begin BUild@3"/100ft(300'md,300'tvdll ~ol1tJnue·BUild @4~/100 {633'md,631.tvdJ! ---- ~COntinU.BUild@6"/100(883'md,872'tvdll ~ ~Sail@68.5'('69"md,'4341vd11 ~ ~ IBUild&Tum@3'/100ft(1792'md,14711vdll 1200 I, 1600 ¡II I Vertical Section at 180.00~ (800ftJin) 2000 2400 2800 I I II I I ¡II ¡¡I II I I 3200 ,I, 3600 ,I, 4000 I II 4400 ,I i 4600 5200 I II I J 11 0- 400- 800- !;; _ Top K15 ~ 2000-::L §. 1200"::2 Permafrost 1600-:: Top T3 ....-/ ~- 18€!g1n 8ui!d & TUrrI@5Q/100(5831'md,2782'tVd)1 4400- 4800- I -1200 , I ' -800 I II -400 I' o I ¡ II I I I 1200 1600 , I ' 2000 , I ' 2400 , I ' 2800 , I ' 3200 , I ' 3600 , I' 4000 , I' 4400 I I J ¡ 4800 1000- -500- -1000- -1500- c: :§ -2000- o o o ~ ~ :£-2500- .c t: o S. ::¡;; -3000- :; o (f) -3500- -4000- -4500- -5000- -5500- -8000- -8500- West(-)/Eas!(+) (1000 ft/in) 2000 2500 3000 3500 4000 , , I , , , , I I , I , I , I , , I , , I , I , , I 500- (300'md.300'tvd) I 40/100 (633'md,631.tvd) I @ 6'/100(883'md,872'tvd) I I,.,' '"7'''00 "",'·m<.vozw> 1 0- I Sail @ 6850 ¡Sail (7142'md, 3473'tvd) l I Build & Tum@3"/100ft(1792'md,1471"tvd)1 l BUild @4°/1ooft(8193'md,367Ttvd) I In A-Sand (8501 'md,3698'tvd)- Begin Undulations I Undulations Sail Fault #1 Crossing Begin Drop @4'/100 (11575'md.362Ttvct) ¡Sail@70'(12002'md, 3713'tvd) I , I ' , , , I ' , , I I ' , , , I -500 500 1000 , I ' , , , I I , I , I ' I , 'I ' , , , I' , i , I" " I' 1500 2000 2500 3000 3500 4000 4500 Wes!(-)/East(+) (1000ft/ín) . . y ConocoPhillips Alaska Halliburton Company Planning Report - Geographic IipIilr"r"Y-1iUI1 D...L.....ING ....VIC.. A Halliburton COmpany 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 Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5,959,980.600 ft , 550,300.480 ft / ft Latitude: Longitude: Ground Level: 70018' 05.162" N 149035' 33.332" W 66.100ft Well Position +N/-5 +EI-W bggm2004 12/2/2004 24.510 80.743 57,579 Audit Notes: Version: 17 Phase: PLAN Tie On Depth: 28.000 28.000 0.000 0.000 180.000 111012005 10:03:25AM Page 20f9 COMPASS 2003.11 Build 48 ORIGlt~P\L . . y ConocoPhillips Alaska Halliburton Company Planning Report - Geographic sp...."y-.UI1 apUL.L.INCI ..RVICe. A Halliburton Company EDM 2003.11 Single User Db ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-105 Plan 1E-105 1 E-105 + 28 KB @ 94.1000 (66.1 L + 28 KB @94.100ft(66.1 28.000 0.000 0.000 28.000 -66.10 0.000 0.000 5,959,980.600 550,300.480 0.00 0.00 SHL: 4889' FNL & 224' FEL: SEC 16-T11N-R10E 100.000 0.000 0.000 100.000 5.90 0.000 0.000 5,959,980.600 550,300.480 0.00 0.00 199.999 0.000 0.000 199.999 105.90 0.000 0.000 5,959,980.600 550,300.480 0.00 0.00 300.000 0.000 0.000 300.000 205.90 0.000 0.000 5,959,980.600 550,300.480 0.00 0.00 KOP - Begin Build @ 3°/10Oft (300'md.300'tvd) 400.000 3.000 83.000 399.954 305.85 0.319 2.598 5,959,980.936 550,303.075 3.00 -0.32 500.000 6.000 83.000 499.635 405.53 1.275 10.384 5,959,981.944 550,310.855 3.00 -1.28 600.000 9.000 83.000 598.768 504.67 2.866 23.338 5,959,983.621 550,323.796 3.00 -2.87 633.333 10.000 83.000 631.644 537.54 3.536 28.799 5,959,984.328 550,329.252 3.00 -3.54 Continue Build @4°/1oo (633'md,631.tvd) 700.000 12.667 83.000 697.004 602.90 5.133 41.801 5,959,986.012 550,342.242 4.00 -5.13 800.000 16.667 83.000 793.726 699.63 8.218 66.927 5,959,989.265 550,367.344 4.00 -8.22 883.333 20.000 83.000 872.819 778.72 11.412 92.940 5,959,992.632 550,393.332 4.00 -11.41 Continue Build @ 6°/1OO(883'md,872'tvd) 900.000 21.000 83.000 888.430 794.33 12.123 98.733 5,959,993.382 550,399.120 6.00 -12.12 1,000.000 27.000 83.000 979.742 885.64 17.077 139.085 5,959,998.606 550,439.434 6.00 -17.08 1,100.000 33.000 83.000 1,066.305 972.21 23.168 188.690 5,960,005.028 550,488.992 6.00 -23.17 1,200.000 39.000 83.000 1,147.170 1,053.07 30.328 247.003 5,960,012.578 550,547.251 6.00 -30.33 1,300.000 45.000 83.000 1,221.451 1,127.35 38.479 313.387 5,960,021.172 550,613.572 6.00 -38.48 1,400.000 51.000 83.000 1,288.333 1,194.23 47.532 387.114 5,960,030.717 550,687.230 6.00 -47.53 1,500.000 57.000 83.000 1,347.085 1,252.98 57.387 467.376 5,960,041.108 550,767.416 6.00 -57.39 1,600.000 63.000 83.000 1,397.062 1,302.96 67.936 553.294 5,960,052.232 550,853.253 6.00 -67.94 1,691.000 68.460 83.000 1,434.452 1,340.35 78.042 635.602 5,960,062.887 550,935.483 6.00 -78.04 Sail@68.5° (1691'md,1434'tvd) 1,691.667 68.500 83.000 1,434.697 1,340.60 78.118 636.217 5,960,062.967 550,936.098 6.00 -78.12 1,700.000 68.500 83.000 1,437.751 1,343.65 79.063 643.913 5,960,063.963 550,943.787 0.00 -79.06 1,791.667 68.500 83.000 1,471.347 1,377.25 89.457 728.566 5,960,074.923 551,028.360 0.00 -89.46 Build & Turn @ 3°/100ft (1792'md.1471 'tvd) 1,800.000 68.519 83.268 1,474.400 1,380.30 90.384 736.264 5,960,075.901 551,036.051 3.00 -90.38 1,825.070 68.578 84.073 1,483.569 1,389.47 92.956 759.455 5,960,078.628 551,059.222 3.00 -92.96 Sail @68.6° (1825'md,1484'tvd) 1,900.000 68.578 84.073 1,510.935 1,416.84 100.158 828.835 5,960,086.294 551,128.546 0.00 -100.16 1,977.115 68.578 84.073 1,539.100 1,445.00 107.570 900.239 5,960,094.184 551,199.891 0.00 -107.57 Base of Permafrost 2,000.000 68.578 84.073 1,547.458 1,453.36 109.770 921.430 5,960,096.525 551,221.065 0.00 -109.77 2,100.000 68.578 84.073 1,583.982 1,489.88 119.382 1,014.024 5,960,106.756 551,313.583 0.00 -119.38 2,200.000 68.578 84.073 1,620.505 1,526.40 128.994 1,106.618 5,960,116.986 551,406.102 0.00 -128.99 2,300.000 68.578 84.073 1,657.028 1,562.93 138.606 1,199.212 5,960,127.217 551,498.621 0.00 -138.61 2,400.000 68.578 84.073 1,693.551 1,599.45 148.218 1,291.806 5,960,137.448 551,591.139 0.00 -148.22 2,500.000 68.578 84.073 1,730.074 1,635.97 157.830 1 ,384.400 5,960,147.678 551,683.658 0.00 -157.83 1/1012005 10:03:25AM Page 30f9 COMPASS 2003.11 Build 48 ORIGINAL . . y ConocoPhillips Alaska Halliburton Company Planning Report - Geographic IiipEll""'I""'Y-SiiUl1 DPtlL.LING ....VIC.. A Halliburton COmpany EDM 2003.11 Single User Db nocoPhillips Alaska Inc.(Kuparuk) paruk River Unit paruk 1 E Pad 1E-105 1E-105 PB1 05 PB1 2,600.000 68.578 84.073 1,766.597 1,672.50 167.442 1,476.994 5,960,157.909 551,776.177 0.00 -167.44 2,609.590 68.578 84.073 1,770.100 1,676.00 168.364 1,485.874 5,960,158.890 551,785.050 0.00 -168.36 Top T3 2,700.000 68.578 84.073 1,803.121 1,709.02 177.054 1,569.588 5,960,168.140 551,868.696 0.00 -177.05 2,800.000 68.578 84.073 1,839.644 1,745.54 186.666 1,662.182 5,960,178.370 551,961.214 0.00 -186.67 2,900.000 68.578 84.073 1,876.167 1,782.07 196.278 1,754.777 5,960,188.601 552,053.733 0.00 -196.28 3,000.000 68.578 84.073 1,912.690 1,818.59 205.890 1,847.371 5,960,198.832 552,146.252 0.00 -205.89 3,100.000 68.578 84.073 1,949.213 1,855.11 215.502 1,939.965 5,960,209.062 552,238.770 0.00 -215.50 3,200.000 68.578 84.073 1,985.736 1,891.64 225.114 2,032.559 5,960,219.293 552,331.289 0.00 -225.11 3,300.000 68.578 84.073 2,022.259 1,928.16 234.726 2,125.153 5,960,229.524 552,423.808 0.00 -234.73 3,400.000 68.578 84.073 2,058.783 1,964.68 244.338 2,217.747 5,960,239.754 552,516.326 0.00 -244.34 3,444.677 68.578 84.073 2,075.100 1,981.00 248.632 2,259.115 5,960,244.325 552,557.661 0.00 -248.63 Top K15 3,500.000 68.578 84.073 2,095.306 2,001.21 253.950 2.310.341 5,960,249.985 552,608.845 0.00 -253.95 3,600.000 68.578 84.073 2,131.829 2,037.73 263.562 2,402.935 5,960,260.216 552,701.364 0.00 -263.56 3,700.000 68.578 84.073 2,168.352 2,074.25 273.174 2,495.529 5,960,270.446 552,793.882 0.00 -273.17 3,800.000 68.578 84.073 2,204.875 2,110.78 282.786 2,588.123 5,960,280.677 552,886.401 0.00 -282.79 3,900.000 68.578 84.073 2,241.398 2,147.30 292.398 2,680.718 5,960,290.908 552,978.920 0.00 -292.40 4,000.000 68.578 84.073 2,277.922 2,183.82 302.010 2,773.312 5,960,301.138 553,071.439 0.00 -302.01 4,100.000 68.578 84.073 2,314.445 2,220.34 311.622 2,865.906 5,960,311.369 553,163.957 0.00 -311.62 4,200.000 68.578 84.073 2,350.968 2,256.87 321.234 2,958.500 5,960,321.600 553,256.476 0.00 -321.23 4,300.000 68.578 84.073 2,387.491 2,293.39 330.846 3,051.094 5,960,331.830 553,348.995 0.00 -330.85 4,400.000 68.578 84.073 2,424.014 2,329.91 340.458 3,143.688 5,960,342.061 553,441.513 0.00 -340.46 4,500.000 68.578 84.073 2,460.537 2,366.44 350.070 3,236.282 5,960,352.292 553,534.032 0.00 -350.07 4,537.135 68.578 84.073 2,474.100 2,380.00 353.639 3,270.667 5,960,356.091 553,568.388 0.00 -353.64 T3+675 -13 318" Casing 4,600.000 68.578 84.073 2,497.060 2,402.96 359.682 3,328.876 5,960,362.522 553,626.551 0.00 -359.68 4,700.000 68.578 84.073 2,533.584 2,439.48 369.294 3,421.470 5,960,372.753 553,719.069 0.00 -369.29 4,800.000 68.578 84.073 2,570.107 2,476.01 378.906 3,514.065 5,960,382.984 553,811.588 0.00 -378.91 4,900.000 68.578 84.073 2,606.630 2,512.53 388.518 3,606.659 5,960,393.214 553,904.107 0.00 -388.52 5,000.000 68.578 84.073 2,643.153 2,549.05 398.130 3,699.253 5,960,403.445 553,996.626 0.00 -398.13 5,100.000 68.578 84.073 2,679.676 2,585.58 407.742 3,791.847 5,960,413.676 554,089.144 0.00 -407.74 5,200.000 68.578 84.073 2,716.199 2,622.10 417.354 3,884.441 5,960,423.906 554,181.663 0.00 -417.35 5,300.000 68.578 84.073 2,752.723 2,658.62 426.966 3,977.035 5,960,434.137 554,274.182 0.00 -426.97 5,381.180 68.578 84.073 2,782.372 2,688.27 434.769 4,052.203 5,960,442.442 554,349.288 0.00 -434.77 Begin Build & Turn @ 5°/100 (5831'md.2782'tvd) 5,400.000 68.332 85.049 2,789.283 2,695.18 436.428 4,069.629 5,960,444.218 554,366.701 4.99 -436.43 5,500.000 67.122 90.292 2,827.207 2,733.11 440.205 4,162.047 5,960,448.612 554,459.083 5.00 -440.20 5,532.915 66.761 92.038 2,840.100 2,746.00 439.589 4,192.325 5,960,448.200 554,489.361 5.00 -439.59 Top Ugnu C 5,600.000 66.087 95.622 2,866.939 2,772.84 435.487 4,253.660 5,960,444.509 554,550.716 5.00 -435.49 5,700.000 65.238 101.030 2,908.175 2,814.07 422.312 4,343.769 5,960,431.939 554,640.903 5.00 -422.31 5,800.000 64.586 106.504 2,950.602 2,856.50 400.780 4,431.689 5,960,410.998 554,728.956 5.00 -400.78 5,900.000 64.138 112.029 2,993.898 2,899.80 371.054 4,516.751 5,960,381.845 554,814.207 5.00 -371.05 6,000.000 63.901 117 .585 3,037.732 2,943.63 333.361 4,598.307 5,960,344.702 554,896.006 5.00 -333.36 1/1012005 10:03:25AM Page 4 of9 COMPASS 2003.11 Build 48 ORIGINAL . . Conoc~illips Alaska Halliburton Company Planning Report - Geographic spEi!l'""r'y-sUl1 D.UL..LINCI .....VIC.. A Halliburton Company 6,100.000 63.877 123.153 3,081.772 2,987.67 287.987 4,675.737 5,960,299.852 554,973.730 5.00 -287.99 6,141.661 63.930 125.474 3,100.100 3,006.00 266.898 4,706.636 5,960,278.972 555,004.767 5.00 -266.90 Top Ugnu B 6,200.000 64.066 128.714 3,125.681 3,031.58 235.278 4,748.451 5,960,247.636 555,046.789 5.00 -235.28 6,300.000 64.467 134.247 3,169.126 3.075.03 175.635 4,815.897 5,960,188.452 555,114.626 5.00 -175.64 6,320.861 64.577 135.398 3,178.100 3,084.00 162.361 4,829.254 5,960,175.268 555,128.070 5.01 -162.36 Top Ugnu A 6,400.000 65.074 139.734 3,211.777 3,117.68 109.512 4,877.560 5,960,122.749 555,176.724 5.00 -109.51 6,500.000 65.880 145.158 3,253.308 3,159.21 37.413 4,932.972 5,960,051.029 555,232.612 5.00 -37.41 6,600.000 66.874 150.507 3,293.403 3,199.30 -40.115 4,981.710 5,959,973.837 555,281.863 5.00 40.12 6,700.000 68.046 155.770 3,331.757 3,237.66 -122.481 5,023.405 5,959,891.759 555,324.104 5.00 122.48 6,800.000 69.382 160.941 3,368.080 3,273.98 -209.059 5,057.737 5,959,805.422 555,359.012 5.00 209.06 6,828.731 69.795 162.411 3,378.100 3,284.00 -234.620 5,066.202 5,959,779.921 555,367.647 5.00 234.62 Ki3 6,900.000 70.870 166.018 3,402.093 3,307.99 -299.188 5,084.447 5,959,715.482 555,386.322 5.00 299.19 7,000.000 72.494 170.999 3,433.538 3,339.44 -392.184 5,103.331 5,959,622.624 555,405.826 5.00 392.18 7,100.000 74.240 175.889 3,462.176 3,368.08 -487.339 5,114.245 5,959,527.554 555,417.376 5.00 487.34 7,141.633 75.000 177.901 3,473.218 3,379.12 -527.419 5,116.418 5,959,487.493 555,419.816 5.00 527.42 Sail @ 75° (7i42'md, 3473'tvd) 7,200.000 75.000 177.901 3,488.325 3,394.22 -583.760 5,118.482 5,959,431.172 555,422.258 0.00 583.76 7,241.633 75.000 177.901 3,499.100 3,405.00 -623.947 5,119.955 5,959,391.000 555,424.000 0.00 623.95 Top West Sak D ·iE·i05 PBi Ti (D top) 7,300.000 75.000 177.901 3,514.207 3,420.11 -680.288 5,122.020 5,959,334.680 555,426.442 0.00 680.29 7,310.633 75.000 177.901 3,516.959 3,422.86 -690.551 5,122.396 5,959,324.420 555,426.887 0.00 690.55 Build @3°/i00ft(73ii'md,35i7'tvd) 7,381.834 77.137 177.901 3,534.100 3,440.00 -759.608 5,124.927 5,959,255.388 555,429.880 3.00 759.61 TopC 7,400.000 77.682 177.901 3,538.060 3,443.96 -777.325 5,125.577 5,959,237.678 555,430.647 3.00 777.33 7,472.062 79.846 177.901 3,552.100 3,458.00 -847.954 5,128.165 5,959,167.075 555,433.709 3.00 847.95 TopB 7,477.206 80.000 177.901 3,553.000 3,458.90 -853.015 5,128.351 5,959,162.015 555,433.928 3.00 853.02 Sail @ 80° (7477'md,3553'tvd) 7,500.000 80.000 177.901 3,556.958 3,462.86 -875.448 5,129.173 5,959,139.591 555,434.900 0.00 875.45 7,600.000 80.000 177.901 3,574.323 3,480.22 -973.863 5,132.780 5,959,041.212 555,439.165 0.00 973.86 7,644.785 80.000 177.901 3,582.100 3,488.00 -1,017.938 5,134.395 5,958,997.153 555,441.076 0.00 1,017.94 Top A4 7,700.000 80.000 177.901 3,591.688 3,497.59 -1,072.278 5,136.387 5,958,942.833 555,443.431 0.00 1,072.28 7,800.000 80.000 177.901 3,609.053 3,514.95 -1,170.692 5,139.994 5,958,844.454 555,447.696 0.00 1,170.69 1/10/2005 10:03:25AM Page 50f9 COMPASS 2003.11 Build 48 ORIGINAL . . ConocóP"t,illips Alaska Halliburton Company Planning Report - Geographic &P&l"T'Y-SlUI1 r"PULLING ~.PtVI"'.. A Halliburton Company EDM 2003.11 Single User Db ConocoPhj jps Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-105 Ian 1E-105 PB1 7,892.413 80.000 177.901 3,625.100 3,531.00 -1,261.640 5,143.327 5,958,753.540 555,451.638 0.00 1,261.64 Top A3 7,900.000 80.000 177.901 3,626.418 3,532.32 -1,269.107 5,143.601 5,958,746.076 555,451.961 0.00 1,269.11 8,000.000 80.000 177.901 3,643.782 3,549.68 -1,367.522 5,147.208 5,958,647.697 555,456.227 0.00 1,367.52 8,100.000 80.000 177.901 3,661.147 3,567.05 -1,465.936 5,150.815 5,958,549.318 555,460.492 0.00 1,465.94 8,180.351 80.000 177.901 3,675.100 3,581.00 -1,545.014 5,153.713 5,958,470.270 555,463.919 0.00 1,545.01 9518" Casing . 11SS'FNL & 354'FEL : SEC 22-T11N-R10E (S1S0'md,3675'tvd)· Top A2 - 9 5IS" Casing 8,192.806 80.000 177.901 3,677.263 3,583.16 -1,557.271 5,154.162 5,958,458.017 555,464.451 0.00 1,557.27 Build @l4°/100 ft (S193'md,3677'tvd) 8,200.000 80.281 177.958 3,678.495 3,584.39 -1,564.354 5,154.419 5,958,450.936 555,464.754 3.98 1,564.35 8,300.000 84.204 178.747 3,691.988 3,597.89 -1,663.378 5,157.263 5,958,351.943 555,468.261 4.00 1,663.38 8,400.000 88.128 179.525 3,698.672 3,604.57 -1,763.123 5,158.766 5,958,252.220 555,470.431 4.00 1,763.12 8,500.000 92.053 180.299 3,698.512 3,604.41 -1,863.103 5,158.919 5,958,152.254 555,471 .254 4.00 1,863.10 8,501.414 92.109 180.310 3,698.461 3,604.36 -1,864.516 5,158.912 5,958,150.840 555,471.256 4.00 1,864.52 Land In A-Sand (8501'md,3698'tvd)- Begin Undulations -1E-105 PB1 T2 (A-landing) 8,600.000 93.587 180.310 3,693.562 3,599.46 -1,962.976 5,158.379 5,958,052.389 555,471.382 1.50 1,962.98 8,700.000 95.087 180.310 3,685.999 3,591.90 -2,062.685 5,157.839 5,957,952.688 555,471.510 1.50 2,062.68 8,751.414 95.859 180.310 3,681.095 3,586.99 -2,113.864 5,157.562 5,957,901.513 555,471.575 1.50 2,113.86 8,800.000 95.859 180.310 3,676.135 3,582.03 -2,162.195 5,157.300 5,957,853.186 555,471.637 0.00 2,162.19 8,900.000 95.859 180.310 3,665.927 3,571.83 -2,261.671 5,156.761 5,957,753.718 555,471.765 0.00 2,261.67 8,901.414 95.859 180.310 3,665.782 3,571.68 -2,263.078 5,156.754 5,957,752.312 555,471.766 0.00 2,263.08 9,000.000 94.346 179.924 3,657.015 3,562.92 -2,361.270 5,156.553 5,957,654.130 555,472.223 1.58 2,361.27 9,100.000 92.811 179.534 3,650.775 3,556.67 -2,461.070 5,157.025 5,957,554.344 555,473.363 1.58 2,461.07 9,200.000 91.275 179.146 3,647.211 3,553.11 -2,560.997 5,158.177 5,957,454.437 555,475.183 1.58 2,561.00 9,237.414 90.700 179.000 3,646.567 3,552.47 -2,598.401 5,158.782 5,957,417.042 555,476.039 1.59 2,598.40 9.300.000 89.574 179.000 3,646.417 3,552.32 -2,660.976 5,159.875 5,957,354.482 555,477.550 1.80 2,660.98 9,400.000 87.774 179.000 3,648.732 3,554.63 -2,760.930 5,161.619 5,957,254.552 555,479.964 1.80 2,760.93 9,500.000 85.974 179.000 3,654.186 3,560.09 -2,860.761 5,163.362 5,957,154.744 555,482.374 1.80 2,860.76 9,531.414 85.408 179.000 3,656.547 3,562.45 -2,892.082 5,163.909 5,957,123.430 555,483.131 1.80 2,892.08 9,600.000 85.408 179.000 3,662.038 3,567.94 -2,960.437 5,165.102 5,957,055.091 555,484.781 0.00 2,960.44 9,679.414 85.408 179.000 3,668.395 3,574.30 -3,039.585 5,166.483 5,956,975.963 555,486.692 0.00 3,039.58 9,700.000 85.778 179.000 3,669.977 3,575.88 -3,060.106 5,166.841 5,956,955.446 555.487.188 1.80 3,060.11 9,800.000 87.578 179.000 3,675.771 3,581.67 -3,159.919 5,168.584 5,956,855.657 555,489.598 1.80 3,159.92 9,900.000 89.378 179.000 3,678.426 3,584.33 -3,259.864 5,170.328 5,956,755.735 555,492.011 1.80 3,259.86 9,973.414 90.700 179.000 3,678.375 3,584.28 -3,333.266 5,171.609 5,956,682.351 555,493.784 1.80 3,333.27 10,000.000 91.146 178.828 3,677.947 3,583.85 -3,359.843 5,172.113 5,956,655.780 555,494.466 1.80 3,359.84 10,100.000 92.824 178.177 3,674.482 3,580.38 -3,459.745 5,174.725 5,956,555.908 555,497.746 1.80 3,459.75 10,196.678 94.447 177.546 3,668.351 3.574.25 -3,556.158 5,178.325 5,956,459.531 555,501.991 1.80 3,556.16 10,200.000 94.447 177.546 3,668.094 3,573.99 -3,559.466 5,178.467 5,956,456.223 555,502.154 0.00 3,559.47 10,300.000 94.447 177.546 3,660.340 3,566.24 -3,659.074 5,182.735 5,956,356.656 555,507.089 0.00 3,659.07 10,400.000 94.447 177.546 3,652.585 3,558.49 -3,758.681 5,187.003 5,956,257.089 555,512.023 0.00 3,758.68 10,455.000 94.447 177.546 3,648.320 3,554.22 -3,813.465 5,189.351 5,956,202.328 555,514.737 0.00 3,813.47 10,500.000 93.813 178.050 3,645.080 3,550.98 -3,858.315 5,191.074 5,956,157.495 555,516.761 1.80 3,858.32 10,600.000 92.402 179.169 3,639.660 3,545.56 -3,958.135 5,193.496 5,956,057.703 555,519.850 1.80 3,958.13 10,700.000 90.988 180.286 3,636.702 3,542.60 -4,058.086 5,193.971 5,955,957.768 555,520.994 1.80 4,058.09 10,708.812 90.864 180.384 3,636.560 3,542.46 -4,066.896 5,193.919 5,955,948.957 555,521.002 1.80 4,066.90 1110/2oo510:03:25AM Page 60f9 COMPASS 2003.11 Build 48 ORIGINAL . . y ConocoPhillips Alaska Halliburton Company Planning Report - Geographic 1iiplill'"'I'""'Y-IBu-, DPUL.LINII ..AVIC.. A Halliburton Company EDM COf\oCOPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pac! Plan 1E.105 10,721.332 90.637 180.381 3,636.396 3,542.30 -4,079.415 5,193.836 5,955,936.440 555,521.002 1.81 4,079.41 End Undulations Sail @ 90.6° (10721'md,3636'tvd) -1E-10S PB1 13 (End Undulations) 10,800.000 90.637 180.381 3,635.521 3,541.42 -4,158.076 5,193.312 5,955,857.784 555,521.005 0.00 4,158.08 10,900.000 90.638 180.382 3,634.408 3,540.31 -4,258.068 5,192.646 5,955,757.800 555,521.008 0.00 4,258.07 11,000.000 90.638 180.383 3,633.294 3,539.19 -4,358.059 5,191.978 5,955,657.816 555,521.010 0.00 4,358.06 11,100.000 90.639 180.384 3,632.179 3,538.08 -4,458.051 5,191.308 5,955,557.832 555,521.009 0.00 4,458.05 11,200.000 90.639 180.385 3,631.064 3,536.96 -4,558.043 5,190.637 5,955,457.848 555,521.007 0.00 4,558.04 11,300.000 90.640 180.386 3,629.948 3,535.85 -4,658.034 5,189.964 5,955,357.864 555,521.004 0.00 4,658.03 11,375.876 90.640 180.387 3,629.100 3,535.00 -4,733.904 5,189.452 5,955,282.000 555,521.000 0.00 4,733.90 Fault #1 Crossing (11376'md,3629'tvd) -1E-105 PB1 T4 (Fault #1 Crossing) 11,400.000 90.640 180.386 3,628.831 3,534.73 -4,758.026 5,189.289 5,955,257.880 555,520.999 0.00 4,758.03 11,500.000 90.638 180.383 3,627.715 3,533.61 -4,858.017 5,188.618 5,955,157.896 555,520.997 0.00 4,858.02 11,575.876 90.637 180.381 3,626.870 3,532.77 -4,933.887 5,188.112 5,955,082.032 555,520.999 0.00 4,933.89 Begin Drop @4°/100 (11S7S'md,3627'tvd) . 1E-105 PB1 TS (Begin Drop) 11,600.000 89.674 180.381 3,626.805 3,532.70 -4,958.010 5,187.952 5,955,057.911 555,521.000 3.99 4,958.01 11,700.000 85.674 180.382 3,630.865 3,536.77 -5,057.905 5,187.287 5,954,958.023 555,521.004 4.00 5,057.90 11,800.000 81.674 180.382 3,641.884 3,547.78 -5,157.273 5,186.625 5,954,858.662 555,521.007 4.00 5,157.27 11,900.000 77.674 180.383 3,659.808 3,565.71 -5,255.631 5,185.968 5,954,760.312 555,521.009 4.00 5,255.63 12,000.000 73.674 180.383 3,684.549 3,590.45 -5,352.499 5,185.320 5,954,663.451 555,521.010 4.00 5,352.50 12,091.812 70.000 180.384 3,713.165 3,619.07 -5,439.719 5,184.736 5,954,576.238 555,521.009 4.00 5,439.72 Sail @ 70° (12092'md, 3713'tvd) 12,100.000 70.000 180.384 3,715.966 3,621.87 -5,447.413 5,184.685 5,954,568.544 555,521.009 0.00 5,447.41 12,191.811 70.000 180.384 3,747.367 3,653.27 -5,533.685 5,184.106 5,954,482.279 555,521.009 0.00 5,533.68 1E-102 PB1 BHL : S144'FNL & 332'FEL: SEC 22-T11N-R10E (12192'md,3747'tvd) - 1E-10S PB1 16 (BHL PB1) 1/1012005 10:03:25AM Page 70f9 COMPASS 2003.11 Build 48 ORIGINAL . . conoc~illips Alaska Halliburton Company Planning Report - Geographic 1ip"''''Y-&UI1 ø.UL.' INII ....VIC.. A Halliburton Company EDM Db ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-105 Plan 1E-105 PB1 1E-105 PB1 (wp05) 1E-105 .1 GL + 28 KB @ 94.10Oft (66.1 GL + 28 KB) .1 GL + 28 KB @ 94.100ft (66.1 GL + 28 KB) 3,747.367 1E-105 PB1 T6 (BHL PB1) -5,533.733 5,184.092 5,954,482.230 555,520.995 - Point 3,698.461 1 E-1 05 PB1 T2 (A-Landing) -1,864.516 5,158.912 5,958,150.840 555,471.256 - Point 3,626.870 1E-105 PB1 T5 (Begin Drop) -4,933.887 5,188.112 5,955,082.032 555,520.999 - Point 3,629.100 1E-105 PB1 T4 (Fault #1 Crossing) -4,733.904 5,189.452 5,955,282.000 555,521.000 - Point 3,636.396 1E-105 PB1 T3 (End Undulations) -4,079.415 5,193.836 5,955,936.440 555,521.002 - Point 3,499.100 1 E-1 05 PB1 T1 (D top) -623.947 5,119.955 5,959,391.000 555,424.000 - Point 4,537.135 8,180.351 2,474.100 3,675.100 13-318 9-518 16 12-1/4 1/1012oo510:03:25AM Page 80f9 COMPASS 2003.11 Build 48 ORJGI~fAL . . Conoc~illips Alaska Halliburton Company Planning Report - Geographic ~"'\I-15UI1 þ'UL....INCI .....VIC.. A Halliburton Company EDM 2003.11 Single User Db ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1,977.115 1,539.100 Base of Pennafrost 68.58 84.07 107.57 900.24 2,609.590 1,770.100 Top 13 68.58 84.07 168.36 1,485.87 3,444.677 2,075.100 Top K15 68.58 84.07 248.63 2,259.12 4,537.135 2,474.100 13+675 68.58 84.07 353.64 3,270.67 5,532.915 2,840.100 Top Ugnu C 66.76 92.04 439.59 4,192.33 6,141.661 3,100.100 Top Ugnu B 63.93 125.47 266.90 4,706.64 6,320.861 3,178.100 Top Ugnu A 64.58 135.40 162.36 4,829.25 6,828.731 3,378.100 K13 69.80 162.41 -234.62 5,066.20 7,241.633 3,499.100 Top West Sak D 75.00 177.90 -623.95 5,119.96 7,381.834 3,534.100 TopC 77,14 177.90 -759.61 5,124.93 7,472.062 3,552.100 TopB 79.85 177.90 -847.95 5,128.17 7,644.785 3,582.100 Top A4 80.00 177.90 -1,017.94 5,134.40 7,892.413 3,625.100 Top A3 80.00 177.90 -1,261.64 5,143.33 8,180.351 3,675.100 Top A2 80.00 177.90 -1,545.01 5,153.71 1/1012005 10:03:25AM Page 90f9 COMPASS 2003.11 Build 48 ORfGIN.AL . . Halliburton Company Anticollision Report çompany: Field: Reference Site: Reference Well: R.e~rence WeUpath: ConócôPl'1illips Alaska Inc. J«uparukRiver ~it Kuparuk 1 E pad Plan fE-105 Plan 1E-10$PB1 Date: 1/212005 . Time:. 15:10:22: Co-ordinate(N.I1:) Reference: Vertical (TVD)Reference: NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MO Interval: 25.000 ft Depth Range: 28.000 to 12191.842 ft MaximumRadius: 1416.384 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/12/2004 Validated: No Planned From To Survey ft ft 28.000 800.000 Planned: 1E-105 (wp05) V6 800.000 12191.842 Planned: 1E-105 (wp05) V6 Version: 2 Toolcode Tool Name CB-GYRO-SS MWD Camera based gyro single shot MWD - Standard Casing Points MD ft 4537.000 8180.000 12191.842 TVD ft 2474.051 3675.039 3747.368 Diameter in 13.375 9.625 4.500 HoleSize in 16.000 12.250 8.500 Name 13 3/8" 95/8" 41/2 Summary Offset Wellpath Reference Offset Ctr-Ctr.No-Go .,AIlowable Site Well Wellpath MD MD Distance Area ·l)eviation ft ft ft ft ft Kuparuk 1D Pad 1 D-126 1D-126 V2 9467.962 6475.000 960.057 231.427 728.631 Pass: Major Risk Kuparuk 10 Pad 1D-127 1D-127 V2 11271.064 7375.000 747.145322.920 424.225 Pass: Major Risk Kuparuk 1 E Pad 1E-104 1E-104 V3 224.933 225.000 40.818 4.653 36.165 Pass: Major Risk Kuparuk 1 E Pad 1 E-112 1E-112 V1 570.834 575.000 201.040 10.412 190.628 Pass: Major Risk Kuparuk 1 E Pad 1 E-112 1E-112L 1 VO 570.834 575.000 201.040 10.146 190.894 Pass: Major Risk Kuparuk 1 E Pad 1E-112 1E-112L2 V1 570.834 575.000 201.040 10.146 190.894 Pass: Major Risk Kuparuk 1 E Pad 1 E-112 1E-112PB1 V2 570.834 575.000 201.040 10.146 190.894 Pass: Major Risk Kuparuk 1 E Pad 1 E-114 1E-114 V1 6970.412 6800.000 161.999137.193 24.806 Pass: Major Risk Kuparuk 1 E Pad 1 E-114 1E-114L 1 V1 6970.420 6800.000 162.001 132.686 29.315 Pass: Major Risk Kuparuk 1 E Pad 1E-114 1 E-114L2 VO 6970.416 6800.000 162.002132.718 29.284 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1E-126 V1 2422.189 2850.000 301.660 85.115 216.545 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1 E-126L 1 V1 2422.189 2850.000 301.660 85.115 216.545 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1 E-126L2 V1 2422.189 2850.000 301.660 85.381 216.279 Pass: Major Risk Kuparuk 1 E Pad 1E-168 1E-168V1 5696.408 9075.000 913.583206.582 707.001 Pass: Major Risk Kuparuk 1 E Pad 1E-168 1E-168L1 V3 5636.308 9050.000 762.897 206.938 555.959 Pass: Major Risk Kuparuk 1 E Pad 1 E-168 1E-168L2 V1 5634.650 9050.000 715.305213.586 501.719 Pass: Major Risk Kuparuk 1 E Pad 1E-168 1E-168PB1 V3 5696.408 9075.000 913.583206.580 707.003 Pass: Major Risk Kuparuk 1 E Pad 1 E-18 1E-18 V1 624.798 625.000 141.463 10.952 130.511 Pass: Major Risk Kuparuk 1 E Pad 1 E-19 1E-19 V1 549.908 550.000 80.775 9.092 71.683 Pass: Major Risk Kuparuk 1 E Pad 1 E-20 1 E-20 V1 449.910 450.000 19.016 7.971 11.045 Pass: Major Risk Kuparuk 1 E Pad 1 E-21 1 E-21 V1 424.500 425.000 40.940 7.216 33.724 Pass: Major Risk Kuparuk 1 E Pad 1 E-22 1 E-22 V1 399.251 400.000 102.039 7.643 94.396 Pass: Major Risk Kuparuk 1 E Pad 1 E-23 1 E-23 V1 521.895 525.000 160.541 9.266 151.275 Pass: Major Risk Kuparuk 1 E Pad 1 E-24 1 E-24 V4 373.273 375.000 223.877 7.232 216.645 Pass: Major Risk Kuparuk 1 E Pad 1 E-24 1 E-24A V1 373.273 375.000 223.877 7.232 216.645 Pass: Major Risk Kuparuk 1 E Pad Plan 1E-108 (C1) Plan 1E-108 (C1) V2 PI 473.635 475.000 80.967 9.973 70.994 Pass: Major Risk Kuparuk 1 E Pad Plan: 1E-102 1 E-1 02 (SVYS) V4 149.994 150.000 100.859 3.363 97.496 Pass: Major Risk Kuparuk 1 J Pad Plan 1J-166 1J-166 L 1 V1 Plan: 1J- 11927.695 12494.182 1280.688350.510 930.178 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 L2 V2 Plan: 1J- 11917.478 12484.729 1285.889 352.122 933.766 Pass: Major Risk Kuparuk 1 J Pad Plan 1J-166 1J-166 V3 Plan: 1J-166 12059.862 12425.000 1275.563364.448 911.116 Pass: Major Risk Kuparuk Non-Pad KUP-01 KUP-01 VO 2206.856 1625.000 112.202 72.052 40.150 Pass: Major Risk Site: Kuparuk 1 D Pad Well: 10-126 Rule Assigned: Major Risk Wellpath: 1D-126 V2 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis ..... Ctr-çtJ" MD TVD MD TV» Ref Offset TFO+AZI TFO-HS CasinglfflÐistan~Area ft ft ft ft ft ft deg deg in ft ft ft 9284.205 3646.339 5500.000 3003.049 41.639 26.799116.037 297.037 9.625 1415.159214.540 1200.619 Pass 9291.006 3646.363 5525.000 3023.021 41.675 26.893 115.544 296.544 9.625 1394.852 215.324 1179.528 Pass 9297.710 3646.401 5550.000 3043.313 41.710 26.979 115.019 296.019 9.625 1374.865216.110 1158.755 Pass OR!GINAL ^'''.TI,c''OLUS¡ON SE111NGS TraveHing Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [25ft/in] -.10.0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vsCenm>toÜntre SeparatiQn [15ftlin] 180'1.1·\1 Plan 1E~J05 PH] (\\p05)(Plan 1E~ 105/Plan JE"105 PEl) <> .þ ¡;:¡ ð .9 ~ ¡;:¡ <> U Measured Depth [ft] I ~~ " -. . y . ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-1 05 Plan 1 E-1 05 Plan: 1 E-1 05 (wp05) Proposal Report 03 January, 2005 .t=J......y-.ur, OAlt: LINClSe,.V1C.S A Halliburton Company ORIGINAL = 1 Prognosed Fault #1 Crossing (11377'md.3672'tvd) 2625- I Begin Build @ 3'/100ft (11485'md.3682'tvd) 1 I Sail @ 93.25' (11748'md,3688·tvd)1 1 Begin Dir @ 3'/100ft (12089'md ,3671 'tvd) I - I Sail @92.23' (12123'md,3669tvd) 1 - ~' conocôPbilli~ .AJåska o :::0 ,~ G) «~ Z » 4025 I I 4200 I I I I I 4900 I I I I I I I 5075 I I I 4375 I I I I I I I 4550 I I I I I 4725 I I I 2800- r- t. 2975- '2 4'2 o - E 3150- .<:: ã. Q) Q 13 - 'f: 3325- ~ Q) 2 f-- "oo~ I''''" '''@Me ~~"M?~II - - te.105-P 1:ßYP~ \.- 1 E-1 05 (wp05) 3675- 3850- 11E-105T1 (FaUIt#1) 5250 I I I I I ~ a'UL1:fIlllG ...,,"~~.. cI!'~""""",,, Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Plan 1E·105 Wellbore: Plan 1E·105 Plan: 1E·105 (wp05) . Vertical Section at 180.00' (350 ft/in) 5425 5600 5775 5950 6125 6300 6475 6650 6825 7000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I, I I I I I I I I I I I I I Begin Dir@ 3'/100ft (12389'md.3659'tvd) I Sail @ 91.9' (12399'md,3659·tvd) I I Begin Dlr@ 3'/10Off (12689'md,3649'tvd) I ¡Sail @92.2' (12699'md,3649'tvd)1 7175 I I I I . -2625 -2800 -2975 -3500 ~3675 :t 1E-105 T41 -3850 - I Sidetrack Point - 3824'FNL & 320'FEL - SEC 22-T11N-R10E : Begin Drop @ 3'/100 (10855'MD,3635'TVD) I I I I I I I I I I I I I I I I I I I I I I I I 'I ' I I I I I I I I I I I I I I I I I I I I I I I I I I , I I I I I I I I 4025 4200 4375 4550 4725 4900 5075 5250 5425 5600 5775 5950 6125 Vertical Section at 180.00' (350 ft/in) 11 E-1 05 BHL : 1338'FNL & 345'FEL -SEC27-T11 N-R10E (13653'md,3625'tvd) I = I I I I I I I I I I I I I I I I I I I ' I I I I I I I I I I I 6300 6475 6650 6825 7000 7175 ~(rps ~ -1250 I I I I I -625 I I I o I I I I I I I . . 625- 0- A Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Plan 1E-105 Wellbore: Plan 1E-105 Plan: 1E-105 (wp05) ~ D.~)'·,. 1....-v'lV'C~. "'..~~ 625 I I I 1250 I I I I I West(-)/East(+) (1250 ft/in) 1875 2500 3125 3750 I I I I I I I I I I I I I I I I I I I I I I 5625 I I I I I 6250 I I I I I I I -625- 4375 I I I I I 5000 I I I 113 318" Casing ~ '\ 195/8" Casing -115S'FNL & 354·FEL. SEC 22-T11N-R10E (8180'md.3675'vd) -.. -1250- - Sidetrack Point· 3824'FNL & 320'FEL . SEC 22-T11N·R10E : Begin Orop@3"/100 (10855'MO,3635'TVO) -1875- prognoSed Fau~ #1 Crossing (11377'md,3672'vd) L :5 -2500- ~ - ~ Begin Build @ 3"/100fl (1148S'md.3682'tvd) I N ..- +' -3125- Sail @93.2S' (11748'md,3688'tvd) :c - 1:: o ~ ? -3750- Begin Oir@ 3"/10011 (12089'md,3671'tvd) I :c :; o (f) Sail@92.23' (12123'md,3669tvd) I -4375- 11E-105 T1 (Fault#1) -5000- 1E-102 PB1 BHL - IBegin Oir@ 3"/1000 (12389'md,36S9'tvd) I -5625- -6250- -6875- -7500- Sail @ 91.9" (12399'md,36S9'vd) I IBegin Oir@3'/10oo (12689'md,3649'tvd) I - Begin Oir@3"/10oo(13213'md,3629'Vd)1 ISail@90.4' (13272'md,3628'vd) Sail @ 92.2" (12699'md,3649'tvd) I I I -1250 I I I I I 625 I I I I I I I -625 I I I o -625 -0 --625 --1250 --1875 (f) --2500 0 c ! - Z --3125 g. ::r 2 ~ ~ =--3750 ~ o ~ 2: --4375 --5000 --5625 --6250 --6875 I I I I I I I 1250 1E-105 BHL I I I I I I I I I I 2500 3125 --7500 1338'FNL & 345'FEL-SEC27-T11N-R10E (13653'md,3625'tvd) I' - I I I I I I I I I I I I I I I I I I I I I I I I I I I 3750 4375 5000 5625 6250 I I I 1875 West(-)/East(+) (1250 ft/ín) ORIGINl\L. . . ConocöPhillips Alaska Halliburton Company Planning Report - Geographic !iif:J.......,y-.u., QPtILLING ..PtVIC.. A Halliburton Company ,,"C_'""""-;'~,C:;:;Cià'S<"'-;'~'" -';,};<:;:Æ":'i;;" OM 2003.11 Single User Db onocoPhillips Alaska Inc.(Kuparuk) uparuk River Unit Kuparuk 1 E Pad Plan 1E-105 Plan 1E-105 1 E-105 (wp05) Well Plan 1E-105 66.1 GL + 28 KB @ 94. 100ft (66.1 GL + 28 KB) 66.1 GL + 28 KB @ 94. 1 OOft (66.1 GL + 28 KB) 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 Position Uncertainty O.OOOft 0.000 ft O.OOOft Northing: Easting: Wellhead Elevation: 5,959,980.600 ft 550,300.480 ft ft Latitude: Longitude: Ground Level: 70" 18' 05.162" N 149" 35' 33.332" W 66.100ft Well Position +N/-5 +EI-W bggm2004 12/6/2004 24.505 80.743 57,580 Audit Notes: Version: 8 Phase: PLAN Tie On Depth: 10,855.200 28.000 0.000 0.000 180.000 --- 1/3/2005 4:16:25PM Page 2 of 5 COMPASS 2003.11 Build 48 ORIGINAL . . Conoc~hillips Alaska Halliburton Company Planning Report - Geographic IIpE1i!r4""Y-1lU11 aAH..LING SeAVICeS A Halliburton Company EDM 2003.11 Single User Db ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-105 10,855.200 90.637 180.381 3,634.907 3,540.81 -4,213.272 5,192.945 5,955,802.593 555,521.007 0.00 4,213.27 Sidetrack Point - 3824'FNL & 320'FEL - SEC 22-T11N-R10E: Begin Drop@ 3°/100 (10855'MD,3635'TVD) 10,900.000 89.295 180.382 3,634.934 3,540.83 -4,258.070 5,192.646 5,955,757.798 555,521.009 3.00 4,258.07 11,000.000 86.295 180.384 3,638.783 3,544.68 -4,357.982 5,191.978 5,955,657.894 555,521.009 3.00 4,357.98 11,043.116 85.000 180.385 3,642.056 3,547.96 -4,400.972 5,191.689 5,955,614.907 555,521.009 3.00 4,400.97 Begin Sail @ 84.7° (11043'md,3642'tvd) -1E-10S T1 (Fault #1) 11,100.000 84.947 180.385 3,647.040 3,552.94 -4,457.636 5,191.309 5,955,558.248 555,521.007 0.09 4,457.64 11,200.000 84.853 180.385 3,655.929 3,561.83 -4,557.237 5,190.639 5,955,458.653 555,521.005 0.09 4,557.24 11,300.000 84.760 180.385 3,664.981 3,570.88 -4,656.825 5,189.970 5,955,359.073 555,521.002 0.09 4,656.82 11,377.409 84.687 180.385 3,672.100 3,578.00 -4,733.904 5,189.452 5,955,282.000 555,521.000 0.09 4,733.90 Prognosed Fault #1 Crossing (11377'md,3672'tvd) 11,400.000 84.687 180.385 3.674.192 3,580.09 -4,756.397 5,189.301 5,955,259.508 555,520.999 0.00 4,756.40 11,485.409 84.687 180.385 3,682.100 3,588.00 -4,841.437 5,188.729 5,955,174.474 555,520.997 0.00 4,841.44 Begin Build @ 3°/100ft (1148S'md,3682'tvd) 11,500.000 85.124 180.385 3,683.395 3,589.30 -4,855.970 5,188.632 5,955,159.942 555,520.997 2.99 4,855.97 11,600.000 88.124 180.384 3,689.281 3,595.18 -4,955.783 5,187.962 5,955,060.137 555,520.995 3.00 4,955.78 11.700.000 91.124 180.383 3.689.936 3,595.84 -5,055.768 5,187.292 5,954,960.160 555,520.995 3.00 5,055.77 11,748.363 92.576 180.383 3,688.374 3,594.27 -5,104.103 5,186.969 5,954,911.828 555,520.996 3.00 5,104.10 Sail @ 93.2So (11748'md,3688'tvd) -1E-10S T2 11,800.000 92.677 180.383 3,686.008 3,591.91 -5,155.685 5,186.625 5,954,860.251 555,520.996 0.20 5,155.68 11,900.000 92.873 180.383 3,681.166 3,587.07 -5,255.565 5,185.957 5.954,760.378 555,520.998 0.20 5,255.57 12,000.000 93.069 180.383 3,675.982 3,581.88 -5,355.428 5.185.290 5,954,660.522 555,520.999 0.20 5,355.43 12,088.665 93.243 180.383 3,671.100 3,577.00 -5,443.957 5.184.698 5,954,572.000 555,521.000 0.20 5,443.96 Begin Dir@3°/10Oft (12089'md,3671'tvd) 12,100.000 92.905 180.383 3,670.492 3,576.39 -5,455.275 5,184.623 5,954,560.682 555,521.000 2.99 5,455.28 12,122.314 92.234 180.384 3,669.492 3,575.39 -5,477.566 5,184.474 5,954,538.393 555,521.000 3.01 5,477.57 Sail @ 92.23° (12123'md,3669tvd) 12,200.000 92.234 180.384 3,666.464 3,572.36 -5,555.191 5,183.954 5,954,460.774 555,521.000 0.00 5,555.19 12,300.000 92.234 180.384 3,662.567 3,568.4 7 -5,655.113 5,183.285 5,954,360.859 555,521.000 0.00 5,655.11 12,388.936 92.234 180.384 3,659.100 3,565.00 -5,743.979 5,182.690 5,954,272.000 555,521.000 0.00 5,743.98 Begin Dir@ 3°/100ft (12389'md,36S9'tvd) " 1E-10S T3 12,399.967 91.903 180.384 3,658.702 3,564.60 -5,755.003 5.182.616 5.954,260.977 555,521.000 3.00 5,755.00 Sail @91.9° (12399'md,36S9'tvd) 12,500.000 91.903 180.384 3,655.380 3,561.28 -5,854.979 5,181.947 5.954,161.009 555,521.000 0.00 5,854.98 12,600.000 91.903 180.384 3,652.060 3,557.96 -5,954.921 5,181.278 5,954,061.074 555,521.000 0.00 5,954.92 12,689.131 91.903 180.384 3,649.100 3,555.00 -6,044.002 5.180.681 5,953,972.000 555,521.000 0.00 6,044.00 Begin Dir @ 3'/100ft (12689'md,3649'tvd) - 1E-105 T4 1/3/2005 4:16:25PM Page 3 of 5 COMPASS 2003.11 Build 48 ORfG'~\JAL . . ConocriPhillips Alaska Halliburton Company Planning Report - Geographic Slplll'T'y-sUl1 OI'tIL.L.INI3 IU!!I'tV(~e!S A Halliburton Company EDM 2003.11 Single User Db ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-105 Plan 1E-105 1 E-105 (wp05) 12,698.783 92.192 180.384 3,648.755 3,554.66 -6,053.647 5,180.617 5,953,962.356 555,521.000 3.00 6,053.65 Sail @ 92.2° (12699'md,3649'tvd) 12,700.000 92.192 180.384 3,648.709 3,554.61 -6,054.863 5,180.608 5,953,961.139 555,521.000 0.00 6,054.86 12,800.000 92.192 180.384 3,644.883 3,550.78 -6,154.787 5,179.940 5,953,861.222 555,521.000 0.00 6,154.79 12,900.000 92.192 180.384 3,641.057 3,546.96 -6,254.712 5,179.271 5,953,761.305 555,521.000 0.00 6,254.71 13,000.000 92.192 180.384 3,637.232 3,543.13 -6,354.637 5,178.602 5,953,661.388 555,521.000 0.00 6,354.64 13,100.000 92.192 180.384 3,633.406 3,539.31 -6,454.561 5,177.933 5,953,561.471 555,521.000 0.00 6,454.56 13,200.000 92.192 180.384 3,629.581 3,535.48 -6,554.486 5,177.264 5,953,461.554 555,521.000 0.00 6,554.49 13,212.564 92.192 180.384 3,629.100 3,535.00 -6,567.041 5,177.180 5,953,449.000 555,521.000 0.00 6,567.04 Begin Dir @ 3°/100ft (13213'md,3629'tvd) . 1E-10S TS 13,272.346 90.399 180.384 3,627.748 3,533.65 -6,626.803 5,176.780 5,953,389.242 555,521.000 3.00 6,626.80 Sail @90.4° (13272'md,362S'tvd) 13,300.000 90.399 180.384 3,627.556 3,533.46 -6,654.456 5,176.594 5.953,361.591 555,521.000 0.00 6,654.46 13,400.000 90.399 180.384 3,626.859 3,532.76 -6,754.451 5,175.925 5,953,261.603 555,521.000 0.00 6,754.45 13,500.000 90.399 180.384 3,626.163 3,532.06 -6,854.447 5,175.256 5.953,161.616 555,521.000 0.00 6,854.45 13,600.000 90.399 180.384 3,625.467 3,531.37 -6,954.442 5,174.586 5,953,061.628 555,521.000 0.00 6,954.44 13,652.634 90.399 180.384 3,625.100 3,531.00 -7,007.073 5.174.234 5,953,009.000 555,521.000 0.00 7,007.07 1E-10S BHL : 133S'FNL & 34S'FEL -SEC27-T11N-R10E (136S3'md,362S'tvd). 41/2" -1E-10S Toe 3,659.100 1E-10S T3 -5,743.979 5,182.690 5.954,272.000 555,521.000 - Point 3,672.100 1E-10S T1 (Fault #1) 4,733.904 5,189.452 5,955,282.000 555,521.000 - Point 3,629.100 1E-10S TS -6,567.041 5,177.180 5,953,449.000 555,521.000 - Point 3,649.100 1E·10S T4 -6,044.002 5,180.681 5,953,972.000 555,521.000 . Point 3,625.100 1E-10S Toe -7,007.073 5,174.234 5,953,009.000 555,521.000 - Point 3,671.100 1E-10S T2 -5,443.957 5.184.698 5,954,572.000 555,521.000 - Point 1/3/2005 4:16:25PM Page 4 of 5 COMPASS 2003.11 Build 48 ORJGINAL~ . . ConocJPhillips Alaska Halliburton Company Planning Report - Geographic s;p&I'T'IV-!IUI1 DPtH"ILINII !JI!PtVIc:,eUI A Halliburton Company 4,537.135 8,180.351 13,652.633 2,474.100 3,675.100 3,625.100 13-3/8 9-5/8 4·112 16 12-1/4 8-1/2 1,977.115 1,539.100 Base of Permafrost 68.58 84.07 107.57 900.24 2,609.590 1,770.100 T3 68.58 84.07 168.36 1,485.87 3,444.677 2,075.100 K15 68.58 84.07 248.63 2,259.12 4,537.135 2,474.100 T3 + 675' 68.58 84.07 353.64 3,270.67 5,532.915 2,840.100 Top Ugnu C 66.76 92.04 439.59 4,192.33 6,141.661 3,100.100 Top Ugnu B 63.93 125.47 266.90 4,706.64 6,320.861 3,178.100 Top Ugnu A 64.58 135.40 162.36 4,829.25 6,828.731 3,378.100 K13 69.80 162.41 -234.62 5,066.20 7,241 .633 3,499.100 Top West Sak D 75.00 177.90 -623.95 5,119.96 7,381.834 3,534.100 TopC 77.14 177.90 -759.61 5,124.93 7,472.062 3,552.100 TopB 79.85 177.90 -847.95 5,128.17 7,644.785 3,582.100 A4 80.00 1 77. 90 -1,017.94 5,134.40 7,892.413 3,625.100 A3 80.00 177.90 -1,261.64 5,143.33 11,409.810 3.675.100 A2 84.69 180.39 -4,766.16 5,189.24 1/3/2005 4:16:25PM Page 5 of 5 COMPASS 2003.11 Build 48 OR G'~!ÞíL, . . Halliburton Company Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 100.000 ft Depth Range: 10855.200 to 13652.636 ft Maximum Radius:1 0000.000 ft Reference: Error Model: Scan Method: Error Surface: Plan: 1E-105 (wp05) & NOT PLANNED P~OGRP ISCWSA Ellipse Trav Cytinder North Ellipse + Casing Casing Points 13652.630 3625.100 5.500 8.500 51/2" Plan: 1E-105 (wp05) Date Composed: Version: Tied-to: 12/12/2004 3 From: Definitive Path Principal: Yes Summary Kuparuk 1 D Pad 10-127 10-127 V2 11325.233 7414.300 726.248 322.686 403.562 Pass: Major Risk Kuparuk 1 E Pad 1 E-126 1E-126V1 11835.241 10300.000 1367.640431.362 936.279 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1 E-126L1 V1 11529.043 10000.000 1197.767 396.460 801.306 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1E-126L2 V1 11032.992 9500.000 1177.456367.592 809.864 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 L 1 V1 Plan: 1J- 13549.822 10900.000 1277.713 389.026 888.687 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 L2 V2 Plan: 1J- 13540.726 10900.000 1281.870391.909 889.962 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 V3 Plan: 1J-166 13568.304 10900.000 1275.641 398.764 876.877 Pass: Major Risk Kuparuk 1J Pad Plan 1J-170 Plan 1J-L4 LatA VO Out of range Site: Kuparuk 10 Pad Well: 10-127 Rule Assigned: Major Risk Wellpath: 1D-127V2 Inter-Site Error: 0.000 ft $et TVD It ft tJ¢9 de€¡ 10863.520 6500.000 3373.560 59.970 46.458 103.332 282.948 9.625 1166.041 320.030 846.011 Pass 10909.688 6600.000 3437.088 60.377 46.982 100.785 280.401 9.625 1096.769 324.445 772.324 Pass 10956.657 6700.000 3503.263 60.786 47.520 97.815 277.432 9.625 1030.752328.582 702.169 Pass 11005.959 6800.000 3570.800 61.228 48.088 94.440 274.056 9.625 968.770 332.290 636.480 Pass 11058.083 6900.000 3639.458 61.787 48.677 90.630 270.246 9.625 911.442 335.556 575.886 Pass 11110.757 3647.982 7000.000 3709.231 62.329 49.233 86.280 265.897 9.625 859.318337.796 521.523 Pass 11162.824 3652.600 7100.000 3780.059 62.872 49.786 81.334 260.951 9.625 813.596 338.361 475.236 Pass 11214.744 3657.249 7200.000 3851.806 63.415 50.337 75.799 255.415 9.625 775.760336.627 439.133 Pass 11266.460 3661.923 7300.000 3924.445 63.963 50.888 69.719 249.335 9.625 746.995331.998 414.997 Pass 11317.878 3666.615 7400.000 3997.821 64.511 51.455 63.204 242.820 9.625 728.139 324.087 404.052 Pass 11325.233 3667.289 7414.300 4008.327 64.590 51.539 62.247 241.863 9.625 726.248 322.686 403.562 Pass Site: Kuparuk 1 E Pad Well: 1 E-126 Rule Assigned: Major Risk Wellpath: 1E-126 V1 Inter-Site Error: 0.000 ft 10928.916 3635.505 9400.000 3585.248 60.544 66.202 268.200 87.817 7.000 1319.672376.930 942.742 Pass 11025.255 3640.576 9500.000 3579.887 61.438 67.431 267.756 87.373 7.000 1327.895 383.101 944.795 Pass 11123.488 3649.107 9600.000 3574.973 62.462 68.635267.186 86.803 7.000 1334.354388.862 945.492 Pass 11222.511 3657.948 9700.000 3572.483 63.498 69.803 266.715 86.332 7.000 1341.197394.529 946.668 Pass 11321.817 3666.976 9800.000 3572.473 64.553 70.998 266.343 85.959 7.000 1346.809400.313 946.496 Pass 11421.532 3676.187 9900.000 3576.612 65.739 72.207 266.138 85.754 7.000 1350.665406.473 944.192 Pass 11523.416 3685.24810000.000 3582.342 67.162 73.387 266.018 85.635 7.000 1355.543412.901 942.642 Pass 11628.983 3690.02010100.000 3587.871 68.735 74.641 266.D76 85.692 7.000 1360.176418.597 941.579 Pass 11734.385 3688.966 10200.000 3590.694 70.552 76.098 266.246 85.863 7.000 1363.157424.396 938.762 Pass 11835.241 3684.35510300.000 3588.820 72.071 77.460 266.373 85.990 7.000 1367.640431.362 936.279 Pass OR'C'l~' ð ~t.J,~\¡l-. ~'t: ~. ( .:. o ;0 (j) :¡:-~ z: ):> f-' c ~ænf'. 'IanlE-105 -56 -50 -0 270 -50 -56 WELLDErAILS +N/-S +EI-W NÜrl11ing fasting 550300.48 La1itud~ Longitude. Slot 70Q18'05.162N 149"3S'33.332W N/A 217.648 412.464 5959980.60 o ~G C) so 18cr6 LEGEND ID-127 (lD-127),MajorR;isk 1&126 (l&l26),MaJOf"Risk = l~g~8~t::2:~~:~ - Plao lJ-l66(1J.l66Ll).~OJRisk - PJanl1'l66&J.l66U),~aJoIRisk - PJanlJ-1661J.166),Ma,¡orRisk - Plan lJol70 Ian U-L4U1tA},MajorRm:. -PIanlB-lOS - IB-I05(wp05) ANTI-COLLISION SETTINGS Inte1pOlatioD Metbod:MD Interval: 100.000 Depth Range. From: 1 0855.100 T,,; 13652.636 MaximrunRange: 10000.000RefereJ1ce~ Plan: IE.I05 (wpOS) From Colour 10855 10955 11055 11305 11555 11805 12305 12805 13305 õO Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [25ft/in] COMPANY DBTAllS ConoooPhîllips Alaska we. Engineering Alpine. CalcuIwon Method: Mminnnn~. EII'orSysftm.: ISCWSA Scan Me1b(\d: Trav Cylinder North w=;t~= ~~:~~s~Casing ToMD 10955 11055 11305 11555 11805 12305 12805 mg~ -30.0 - 0 270 90 -5.0 -10.0 -15.0 -20.0 -25,0 -30.0 SURVEY PROGRAM Dt¢.IF'm DeptJTo bw.ylPlan J0855:100 B6.ü,6~6 PIamt.:!: IE-JOS(wpO.Ç)V3 WEll.PAmDErAILS Plan lE-lO~ """ PamrtWdlpoQb: r"'01IMD; Pbm 1&I~PB1 108~5.2(1(1 Rig I«f.Dsu.n: 1&104 94.100fI ~ +~ ~ V.$cdiOll - 1&(1.000· 0,00(1 0.000 o 30,0 From Colour 10855 10955 11 055 11305 11555 11805 12305 12805 13305 ToMD 10955 11055 11305 11555 11805 12305 12805 13305 13805 -25.0 . -20.0 -15.0 . -10,0 -5.0 90 18J0.v Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [15ft/in] SECTION DETAILS S,< MD [no ,<,; 1VD +NI.s +EI-W DLog rF~ vs", r""" I 10855.200 90.639 180.384 3634.904 -4211273 5192.938 0,00 0.000 4213.2.73 , 11043.155 85.000 180.384 3642.053 -4401.012 5191.681 3.00 -18().000 4401.013 18-105 FauJt#1 PC 3 11377.409 84.685 180.384 3672.100 -4733.905 5189.451 0,09 180.000 4133.905 18-105 FauM1 Pt2 4 11485.409 84.685 180.384 3682.104 -4841.438 5188.731 0,00 0.000 4841.438 , 11748.443 92.576 180.384 3688.386 -5104.184 5186.912 3,00 -0.002 5104.184 ~~~g;: ~~B 6 12088.667 93.249 180.384 3671.100 -5443.958 5184.697 0.20 0.000 5443.958 7 12122.516 92.233 180.384 3669.481 -5477.768 5184.471 3,00 179.995 5477.768 8 12388.937 92.233 180.384 3659.100 -5743.981 5182.689 0.00 0.000 5743.981 1B-105Pt6(v1) 9 12399.9-45 91.903 180.384 3658.703 -5754.981 5182.615 100 -179.999 5754.981 10 12689.133 91.903 180.384 3649.100 -6044.003 5180.680 0,00 0.000 6044.003 18-1OSPt7(vl) 11 12698.7&4 92.192 180.384 3648.755 ...(.(153.647 5180.615 3,00 0.000 6053.647 " 13212.566 92.192 18{).384 3629.100 -6567.042 5177.178 0,00 0.000 6567.042 IB-I-5Pt8(v1) 13 13272.347 90.399 18{).384 3627.748 -6626.80-4 5176.778 3.00 -180.000 6626.804 l4 13652.636 90.399 180.384 3625.100 -7007.075 5174.232 0,00 0,000 7007.075 18-105 Toe-(v1) @O' 13-5/8' 4·112".12.6 #.L-80,lBTM I J \r- "D" Liner. L80, BTCM, R3 l;fí slotted and I/S blank, (0.125" x 2.5" slot 32 per toot, 5.9ry;) open area} 2" x In MO<le at 2400' TVD. e, wlth 3,812" mpple, one (1) JÜllltabùve 05 L2 "D" Sand Window 7,241' MD! 3,499' TVD degree nipple set@ 500' DB ~ :::> IE> 105 L2: 8-1/2" D s,1ud lateral 3.634' MD! 3.399' TVD TD / IE-I05 LI: 8-1/2" "8" sand lateral 13,640' MD! 3,453' TVD TO 'B" Liner, 5-112".15.5#, L80, BTCM, R3 slotted and blank. (0.125" x 2,S" ,Jot 32 per foot, 5.91}i¡ open area) 105 Ll "B" Sand Wìndow 7,472' MD! 3,552' TVD Lateral Bake· ~ !4. m "1'!W m"'" ~~ã. <!> :<1> <!> mn ""'0.- ...,)¡, ::r S: o <!> :::! "'3", ~æ.t ¡;¡'= .... ~ o .... KRU 1 E...1 05 Proposed Service West Sak II A2n Sand 2050060 SFD 1/1212005 Feet . SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 ~~~~~~~E srllre æ HLIf5C11 !1fCtE:lCC ~tk ~J/~ 6-1/1A-O/oe> - CII&CH· A·S E chase. Manhallan Bank USA. . N.A. Valid UP. To 5000 Dollars .~ . ~.".'"_."~'",." tk~~-:iß~ 1:0 j ~ ~OO ~~~1:2 ~8~? ~110 7112 71;111 ~088 ~ . 1088 DATE If:];. ( cJIli ~-14/311 1$ fa:;. tb . "DOLLARS ~ ~=:ztealuru Oel¡ÙllionBac:k. ~m""'''-·''<m.,...--'~~''·-·'_''''''''''f.:W'''''''''''''''_''''~~'''''''~.'_·---·-···- _".. ..'_ """"~'_""m,..__·__~'''' "'. - --<""---- --, .".....--~. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 1::/2/(7 / E - ID5' PTD# 2f)Ç-(){)0 /Development t/' Service CHECKWHAT APPLIES ADD-ONS (OPTIONS) M1JLTI LATERAL (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new wellboresegment of existing well,. . Permit No, .' API No. . Production. sbould continue to be reponed as a function' of tbe original API number. stated above. . .'PU,OT /~~ HOLE )n accordance witb· 20 AAC 25.005(1), all records, data and logs acquired .for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dumber (50 ðz1-Z3.Z¥3-7ò 70/80) from records, data and logs acquired for well (name on permit). SP.ACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25..0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e::sception. (Company Name) assumes tbe liability of any protest to tbe spacing .e:lception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater 1han 30' sample intervals from below tbe permafrost or from wbere samples are fint caught and ] 0' sample iDter:vals through target zones. 1+ I 5 Date ~\~ Of) i Date: ~ Geologic Commissioner: Engineering Commissioner: Date P 35 36 37 38 39 _SJ!abed _condjtjpo $urvey CQnta_ct namelphon_eJor-'Nee!sly progress report$ [expIQratpryonly] No YJ!$ _NA NA NA Appr SFD Date 1/12/2005 -<if Qff-shpre) _SJ!ismicanalysjs_ Qf $baJlow gas.zpoes. PJ!rmit can Þe _D.ata_PJeseoted on_ pote_ntial oveJRressuœ _ZOne$ IŒU j E-Pad WJ!stS_al< wells_have mea_sured Expected re$ervojr pre$$Ure i$8,3 in 2004. 8,6_ppg _EMW; INjllbJ!dril!eçt INjtb 9.00iJ-Þased mud. Geology iS$ued INfo hydrogen sulfide meaS_Ure$ 32 33 34 MeçbanicaLcoodjt[on pt well$ within ,6.0R yerified (forßervjce INe only) Appr Date TEM 1/27/2005 ,.an .tM.. .-n:~ 'tJ.-- 18 19 20 21 22 23 24 25 26 27 28 29 30 31 (May 84) WQr!s will occur withoutoperation .shutdown Js presence Qf H2S gas_ probaÞle C_hoke manifold compJies w/API RF'-53. BOPE$.dp _BOPEpres$ raJiog appropriate; _test to (put psig in "comments) they meet DJiUiog flujd_ program schematic & equip meet reguJations. istaçtequate Ita re-dril!, has a lOA03 fQr abançtonme.nt _Adequate wellbor~ separatjo_n proposeçt Jtdjver:ter Jeq_uiJed, doe$ jt _AdequatetanJ<age_oJ re_serve pit beJ!O approved Casing d~sÎ9ns adequaJe fw known -Pfo_ductiye horizon_s C, T~ 8& permafrost CMT vol adeq uate_ to .CMT wil! coyer all known USDWs _CMT v_ol adequ_ate_ to ci rc_u late. on .cond_uctor_ ie-in long .string to surf csg Conductor S_urfacJ! .casing_ pJotects all & surtCJSg Ye$ NA Yes No_ No_ Yes Y_es NA YJ!s Ye$ Yes Ye$ YJ!s YJ!s No No No_ trom 22 t076ppmH2S ,6.çcordi.ng to_ recent mes_sage, operatioos_ wil! Low lellel H2S in WS ha$ Þeen reported on 1 Prelimioary reyiew ofAOR well$ does_n_ot beSD, E pa_d, ",~" indicaJe any proþlem$. CP,6.UO provide_ çompleteAOR. rigJo to.JPRA. U"..I $bo_uld_precluçte H2S on rig. Rig ba_s_sensorsand alarm $ettjng9:5fS to .send reg uJation M,6.SE' calçuJatedat 1250 p$i, 30QOp$i appr_oprjate.. 8HE' expected between 8._3_- .8.6.EMW. Planneçt MW to 9, t in 12.25" hole and 9.0 in WS. ProJ5:imity- analysis performe_d, Jrayeling cy-lioder plot iocJu_ded Gy-rQs_ pO$sib1e. Rig js equippe_dwith $teeLpjts. No_ reseJ"ve_pjtplano~d, All waste toapprove_d anouJus or Cla$s J well, ,6.1[ Slotted hyçtrocarbQnzoo~s_will ioer proposeçt be cpvered. Annular _dispos.al my be. reque$tJ!d. Engineering Appr '. 1/12/2005 12 13 14 15 16 17 stringpJQv[ded ACMP finding of Consistencyha$ Þee.njssued forJhis project Pre-produ_ced Well _AJI we!]s.within 5-day wait IQcatJ!d within area and_strata _authorized by_ njeçtioo incpmment$) (For Date Compa :ONC : A~ o it feE te_nUI uewl !b_E JQcat e po _v.~ JQcal :;e_ ',v,. W~IIJQcal :;e from otb~r _S_utficient _~v' v~",.v ~_. ~ ,,.....,.' Jf dJ!viated, js weJlbQre plat PTD#: 2050060 Administration incJuded Operator only- affected party W~II 'A'o.lI we!]s ~~·ð~",' ~"~i'~""'<;! in_dJiUiog unjt <r^m driJling unit 2 3 4 5 6 7 8 9 10 11 b_oundary_ KRU We$t S¡ I We!] i$ more_ "'... , to.JQ re$trictioos as to wel! POOl, ·h~n 500 feet fJQm an externaJ prope_rty in CO_ 4968 spaciog goyerned by _ConseNation_ Qrçter ine.. OrdJ!r # (put 10# 1l4_mile_ar~a_of reyiew jdJ!otified (Fpr servjc_eweU only) _ _ injector; duration of pre-produGtioo lJ!ss than_ 3. montbs_ (For service well QnJy) Can permit _Operator can Þe cao Þe Field & Pool NC KUPARUK RIVER, WEST SAK OIL PJ!rmit PJ!rmit has_apprppriateJ).ond inJorce issueçt INjtbQut COn5EHva_tion order iS$ueçt INitbQut be approved before ad_m in istrative_ apprpvaJ 490150 nitial ClassfType Yes Yes _YJ!$ YJ!s _YJ!$ YJ!s Ye$ _YJ!s YJ!s YJ!$ YJ!$ YJ!s Yes YJ!s YJ!s YJ!s NA M aquif~rs eXJ!mpted.40CFR1<17.102-<b)(3). ,6.rea Injeçtjo_n_Qrde.r No._2B_ 1:;-126_& LaJ~rals, J ~:1:14 & laterals, 1E-16.8_& laJerals. _1 ~:33._ tD_-12;3, 1D-126, D- j 27_ No, 4Q68 Surtacelpçation an_d top_ prQd_uçtjve jnJervaJ in AD.L02565j ;rD jnADL Q2566.0, Well Name: KUPARUK RIV U WSAK 1E-105 SER I PEND GeoArea 890 Unit 11160 Program SER On/Off Shore On Well Annular bore seg Disposal o o . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Dec 01 07:44:00 2005 l"ò 4-4-D cQ05-DOw Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/12/01 Origin.................. .STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name..... ..UNKNOWN Comments............... ..STS LIS Writing Library. \JP Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/12/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments................ .STS LIS Writing Library. ~'\; -Á r~ Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-105PB2 500292324371 ConocoPhillips Alaska, Inc. Sperry Drilling Services 14-NOV-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003677560 E. QUAM D. GLADDEN MWD RUN 3 MW0003677560 E. QUAM D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 391 224 MSL 0) 93.58 66.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 CASING SIZE (IN) 13.375 9.625 DRILLERS DEPTH (FT) 3905.0 8290.0 # . . 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-105 PB1 WELLBORE AT 4027'MD/2332'TVD, BY MEANS OF AN OPEN-HOLE SIDETRACK. 4. MWD RUN 1 (COMPRISING 1E-105 PB1) WAS DIRECTIONAL ONLY AND IS NOT PRESENTED 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). NO VALID SEXP DATA WERE ACQUIRED DURING MWD RUN 2 DUE TO TOOL PROBLEMS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 3 REPRESENT WELL 1E-105 PB2 WITH API#:50-029-23243-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12208'MD/3718'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SST LITHOLOGY, VARIABLE HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.0 - 9.15 PPG MUD SALINITY: 35,000 - 44,000 PPM CHLORIDES . . 11,000 PPM CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name.......... ...STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/12/01 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 RPS RPM RPD FET ROP NCNT FCNT NPHI RHOB DRHO PEF RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 8204.5 8204.5 8204.5 8217.5 8217.5 8217.5 8243.5 STOP DEPTH 12170.0 12162.0 12162.0 12162.0 12162.0 12208.0 12116.0 12116.0 12116.0 12130.0 12130.0 12130.0 12162.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: BIT RUN NO 2 3 MERGED MAIN PASS. $ MERGE TOP 3862.0 8295.0 MERGE BASE 8295.0 12208.0 # Data Format Specification Record Data Record Type..................O 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 DEPT ROP MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3862 12208 8035 16693 3862 12208 ROP MWD FT/H 3.04 708.42 182.71 16361 4028 12208 GR MWD API 23.76 172.01 74.1639 16617 3862 12170 RPX MWD OHMM 3.55 2000 26.2853 7838 8243.5 12162 RPS MWD OHMM 2.71 2000 20.8559 16565 3880 12162 RPM MWD OHMM 4.27 2000 22.5089 16565 3880 12162 RPD MWD OHMM 0.13 2000 25.3637 16565 3880 12162 FET MWD HOUR 0.18 93.81 2.88751 16565 3880 12162 NPHI MWD PU-S 15.64 52.45 38.9714 7824 8204.5 12116 FCNT MWD CNTS 556 3066 963.193 7824 8204.5 12116 NCNT MWD CNTS 106672 193322 138277 7824 8204.5 12116 RHOB MWD G/CM 0.438 2.712 2.19424 7826 8217.5 1213 0 DRHO MWD G/CM -2.671 0.314 0.0231915 7826 8217.5 1213 0 PEF MWD BARN 0.72 14.25 2.27265 7826 8217.5 12130 First Reading For Entire File......... .3862 Last Reading For Entire File.......... .12208 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/12/01 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...... .05/12/01 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 2 header data for each bit run in separate files. 2 .5000 . VENDOR TOOL CODE GR FET RPD RPS RPM ROP $ START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 STOP DEPTH 8250.5 8243.0 8243.0 8243.0 8243.0 8295.0 # 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................ ..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 . 09-MAY-05 Insite 66.37 Memory 8295.0 4027.0 8295.0 63.4 81. 5 TOOL NUMBER 126027 116184 12.250 3905.0 LSND 9.00 74.0 9.0 350 4.1 3.500 2.420 5.000 6.000 68.0 101. 2 68.0 68.0 . . 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 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3862 8295 6078.5 8867 3862 8295 ROP MWD020 FT/H 3.04 708.42 179.314 8535 4028 8295 GR MWD020 API 23.76 172.01 72.6401 8778 3862 8250.5 RPS MWD020 OHMM 2.71 2000 13.1974 8727 3880 8243 RPM MWD020 OHMM 4.27 2000 14.8065 8727 3880 8243 RPD MWD020 OHMM 0.13 2000 15.4171 8727 3880 8243 FET MWD020 HOUR 0.18 93.81 3.96865 8727 3880 8243 First Reading For Entire File......... .3862 Last Reading For Entire File.......... .8295 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..05/12/01 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...... .05/12/01 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 NPHI FCNT NCNT PEF RHOB DRHO FET RPX RPS 3 header data for each bit run in separate files. 3 .5000 START DEPTH 8204.5 8204.5 8204.5 8217.5 8217.5 8217.5 8243.5 8243.5 8243.5 STOP DEPTH 12116.0 12116.0 12116.0 12130.0 12130.0 12130.0 12162.0 12162.0 12162.0 . RPD RPM GR ROP $ 12162.0 12162.0 12170.0 12208.0 8243.5 8243.5 8251.0 8295.5 # 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 CTN ALD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 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 . 14-MAY-05 Insite 66.37 Memory 12208.0 8295.0 12208.0 70.6 96 .2 TOOL NUMBER 163686 125889 179954 10640599 8.500 8290.0 Oil Based 9.10 73.0 .0 35000 2.3 .000 .000 .000 .000 .0 133.0 .0 .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 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8204.5 12208 10206.3 8008 8204.5 12208 ROP MWD030 FT/H 5.69 299.34 186.414 7826 8295.5 12208 GR MWD030 API 45.38 112.74 75.8703 7839 8251 12170 RPX MWD030 OHMM 3.55 2000 26.2853 7838 8243.5 12162 RPS MWD030 OHMM 4.93 2000 29.3831 7838 8243.5 12162 RPM MWD030 OHMM 5.09 1809.23 31.0849 7838 8243.5 12162 RPD MWD030 OHMM 1. 06 2000 36.4385 7838 8243.5 12162 FET MWD030 HOUR 0.19 89.64 1. 68374 7838 8243.5 12162 NPHI MWD030 PU-S 15.64 52.45 38.9714 7824 8204.5 12116 FCNT MWD030 CNTS 556 3066 963.193 7824 8204.5 12116 NCNT MWD030 CNTS 106672 193322 138277 7824 8204.5 12116 RHOB MWD030 G/CM 0.438 2.712 2.19424 7826 8217.5 12130 DRHO MWD030 G/CM -2.671 0.314 0.0231915 7826 8217.5 12130 PEF MWD030 BARN 0.72 14 .25 2.27265 7826 8217.5 1213 0 First Reading For Entire File......... .8204.5 Last Reading For Entire File.......... .12208 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/12/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/12/01 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. . . . . . . . . . . . . . . . . . . . .05/12/01 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 . . /34-d~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 14 14:33:23 2005 t)D5~DO~ Reel Header Service name............ .LISTPE Date.................... .05/11/14 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.................... .05/11/14 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-105PB2 500292324371 ConocoPhillips Alaska, Inc. Sperry Drilling Services 14-NOV-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003677560 E. QUAM D. GLADDEN MWD RUN 3 MW0003677560 E. QUAM D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 391 224 MSL 0) 93.58 66.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 CASING SIZE (IN) 13.375 9.625 DRILLERS DEPTH (FT) 3905.0 8290.0 # 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-105 PB1 WELLBORE AT . . 4027'MD/2332'TVD, BY MEANS OF AN OPEN-HOLE SIDETRACK. 4. MWD RUN 1 (COMPRISING 1E-105 PB1) WAS DIRECTIONAL ONLY AND IS NOT PRESENTED 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP), AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). NO VALID SEXP DATA WERE ACQUIRED DURING MWD RUN 2 DUE TO TOOL PROBLEMS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 3 REPRESENT WELL 1E-105 PB2 WITH API#:50-029-23243-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12208'MD/3718'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SST LITHOLOGY, VARIABLE HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.0 - 9.15 PPG MUD SALINITY: 35,000 - 44,000 PPM CHLORIDES FORMATION WATER SALINITY: 11,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/11/14 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 RPS RPM RPD FET ROP NCNT FCNT NPHI RHOB DRHO PEF RPX $ . 1 . and clipped curves; all bit runs merged. .5000 START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 8204.5 8204.5 8204.5 8217.5 8217.5 8217.5 8243.5 STOP DEPTH 12170.0 12162.0 12162.0 12162.0 12162.0 12208.0 12116.0 12116.0 12116.0 12130.0 12130.0 12130.0 12162.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: BIT RUN NO 2 3 MERGED MAIN PASS. $ MERGE TOP 3862.0 8295.0 MERGE BASE 8295.0 12208.0 # 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 Unit s . . . . . . . . . . . . . . . . . . . . . . . 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3862 12208 8035 16693 3862 12208 ROP MWD FT/H 3.04 708.42 182.71 16361 4028 12208 GR MWD API 23.76 172.01 74.1639 16617 3862 12170 RPX MWD OHMM 3.55 2000 26.2853 7838 8243.5 12162 RPS MWD OHMM 2.71 2000 20.8559 16565 3880 12162 RPM MWD OHMM 4.27 2000 22.5089 16565 3880 12162 RPD MWD OHMM 0.13 2000 25.3637 16565 3880 12162 . . FET MWD HOUR 0.18 93.81 2.88751 16565 3880 NPHI MWD PU-S 15.64 52.45 38.9714 7824 8204.5 FCNT MWD CNTS 556 3066 963.193 7824 8204.5 NCNT MWD CNTS 106672 193322 138277 7824 8204.5 RHOB MWD G/CM 0.438 2.712 2.19424 7826 8217.5 DRHO MWD G/CM -2.671 0.314 0.0231915 7826 8217.5 PEF MWD BARN 0.72 14.25 2.27265 7826 8217.5 12162 12116 12116 12116 12130 12130 12130 First Reading For Entire File......... .3862 Last Reading For Entire File.......... .12208 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/11/14 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...... .05/11/14 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 RPD RPS RPM ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 STOP DEPTH 8250.5 8243.0 8243.0 8243.0 8243.0 8295.0 # 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: 09-MAY-05 Insite 66.37 Memory 8295.0 4395.0 8295.0 63.4 81. 5 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 126027 116184 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 3905.0 . . # 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: LSND 9.00 74.0 9.0 350 4.1 3.500 2.420 5.000 6.000 68.0 101.2 68.0 68.0 # 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.....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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3862 8295 6078.5 8867 3862 8295 ROP MWD020 FT/H 3.04 708.42 179.314 8535 4028 8295 GR MWD020 API 23.76 172.01 72.6401 8778 3862 8250.5 RPS MWD020 OHMM 2.71 2000 13 . 1974 8727 3880 8243 RPM MWD020 OHMM 4.27 2000 14.8065 8727 3880 8243 RPD MWD020 OHMM 0.13 2000 15.4171 8727 3880 8243 FET MWD020 HOUR 0.18 93.81 3.96865 8727 3880 8243 First Reading For Entire File......... .3862 Last Reading For Entire File.... ..... ..8295 File Trailer Service name.... ........ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/11/14 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...... .05/11/14 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 NPHI FCNT NCNT PEF RHOB DRHO FET RPX RPS RPD RPM GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 8204.5 8204.5 8204.5 8217.5 8217.5 8217.5 8243.5 8243.5 8243.5 8243.5 8243.5 8251.0 8295.5 # 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 CTN ALD $ STOP DEPTH 12116.0 12116.0 12116.0 12130.0 12130.0 12130.0 12162.0 12162.0 12162.0 12162.0 12162.0 12170.0 12208.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 14-MAY-05 Insite 66.37 Memory 12208.0 8295.0 12208.0 70.6 96 .2 TOOL NUMBER 163686 125889 179954 10640599 8.500 8290.0 Oil Based 9.10 73.0 .0 35000 2.3 .000 .000 .000 .000 .0 133.0 .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 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 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8204.5 12208 10206.3 8008 8204.5 12208 ROP MWD030 FT/H 5.69 299.34 186.414 7826 8295.5 12208 GR MWD030 API 45.38 112.74 75.8703 7839 8251 12170 RPX MWD030 OHMM 3.55 2000 26.2853 7838 8243.5 12162 RPS MWD030 OHMM 4.93 2000 29.3831 7838 8243.5 12162 RPM MWD030 OHMM 5.09 1809.23 31.0849 7838 8243.5 12162 RPD MWD030 OHMM 1. 06 2000 36.4385 7838 8243.5 12162 FET MWD030 HOUR 0.19 89.64 1.68374 7838 8243.5 12162 NPHI MWD030 PU-S 15.64 52.45 38.9714 7824 8204.5 12116 FCNT MWD030 CNTS 556 3066 963.193 7824 8204.5 12116 NCNT MWD030 CNTS 106672 193322 138277 7824 8204.5 12116 RHOB MWD030 G/CM 0.438 2.712 2.19424 7826 8217.5 12130 DRHO MWD030 G/CM -2.671 0.314 0.0231915 7826 8217.5 12130 PEF MWD030 BARN 0.72 14.25 2.27265 7826 8217.5 12130 First Reading For Entire File......... .8204.5 Last Reading For Entire File.......... .12208 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number... ....... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Next File Name........ ...STSLIB.004 Physical EOF Tape Trailer Service name........ .....LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/11/14 J'. ,.. . . 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...... ............. ..05/11/14 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 . . $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 14 09:16:21 2005 /õ4ó2tJ ó)05 -ô()(p Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name.... ........ .LISTPE Date. .......... ... ...... .05/11/14 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.................... .05/11/14 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA lE-105 500292324300 ConocoPhillips Alaska, Inc. Sperry Drilling Services 14-NOV-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 MW0003677560 E. QUAM D. GLADDEN MWD RUN 3 MW0003677560 E. QUAM D. GLADDEN MWD RUN 4 MW0003677560 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 10 391 224 93.58 66.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 CASING SIZE (IN) 13.375 9.625 DRILLERS DEPTH (FT) 3905.0 8290.0 # 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-105 PB2 WELLBORE AT . . 11332'MD/3653'TVD, BY MEANS OF AN OPEN-HOLE SIDETRACK. 4. MWD RUN 1 (COMPRISING 1E-105 PB1) WAS DIRECTIONAL ONLY AND IS NOT PRESENTED 5. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 3 & 4 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) , AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). NO VALID SEXP DATA WERE ACQUIRED DURING MWD RUN 2 DUE TO TOOL PROBLEMS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 4 REPRESENT WELL 1E-105 WITH API#:50-029-23243-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13539'MD/3624'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SST LITHOLOGY, VARIABLE HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.0 - 9.15 PPG MUD SALINITY: 35,000 - 44,000 PPM CHLORIDES FORMATION WATER SALINITY: 11,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 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 RPS RPM RPD ROP NPHI FCNT NCNT PEF DRHO RHOB RPX $ . 1 . and clipped curves; all bit runs merged. .5000 START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 8204.5 8204.5 8204.5 8217.5 8217.5 8217.5 8243.5 STOP DEPTH 13501.0 13493.5 13493.5 13493.5 13493.5 13539.0 13447.5 13447.5 13447.5 13461.0 13461.0 13461.0 13493.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 2 3 4 MERGED MAIN PASS. $ MERGE TOP 3862.0 8295.0 11332.5 MERGE BASE 8295.0 11332.0 13539.0 # 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3862 13539 8700.5 19355 3862 13539 ROP MWD FT/H 0.31 708.42 181.013 19023 4028 13539 GR MWD API 23.76 172.01 74.5017 19279 3862 13501 RPX MWD OHMM 3.55 2000 24.4942 10501 8243.5 13493.5 RPS MWD OHMM 2.71 2000 20.5971 19228 3880 13493.5 RPM MWD OHMM 4.27 2000 22.1138 19228 3880 13493.5 . . RPD MWD OHMM 0.13 2000 24.7029 19228 3880 13493.5 FET MWD HOUR 0.18 93.81 2.57309 19228 3880 13493.5 NPHI MWD PU-S 15.19 53.39 40.2878 10487 8204.5 13447.5 FCNT MWD CNTS 556 3066 974.496 10487 8204.5 13447.5 NCNT MWD CNTS 106672 193322 138993 10487 8204.5 13447.5 RHOB MWD G/CM 0.438 2.759 2.20112 10488 8217.5 13461 DRHO MWD G/CM -2.671 0.314 0.0294235 10488 8217.5 13461 PEF MWD BARN 0.91 14.25 2.22478 10488 8217.5 13461 First Reading For Entire File......... .3862 Last Reading For Entire File....... ... .13539 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 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... ....05/11/14 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 RPS RPM RPD FET ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 3862.0 3880.0 3880.0 3880.0 3880.0 4028.0 STOP DEPTH 8250.5 8243.0 8243.0 8243.0 8243.0 8295.0 # 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: 09-MAY-05 Insite 66.37 Memory 8295.0 4027.0 8295.0 63.4 81. 5 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 126027 116184 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 . . DRILLER'S CASING DEPTH (FT): 3905.0 # 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: LSND 9.00 74.0 9.0 350 4.1 3.500 2.420 5.000 6.000 68.0 101.2 68.0 68.0 # 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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3862 8295 6078.5 8867 3862 8295 ROP MWD020 FT/H 3.04 708.42 179.314 8535 4028 8295 GR MWD020 API 23.76 172 . 01 72.6401 8778 3862 8250.5 RPS MWD020 OHMM 2.71 2000 13 . 1974 8727 3880 8243 RPM MWD020 OHMM 4.27 2000 14.8065 8727 3880 8243 RPD MWD020 OHMM 0.13 2000 15.4171 8727 3880 8243 FET MWD020 HOUR 0.18 93.81 3.96865 8727 3880 8243 First Reading For Entire File..... .....3862 Last Reading For Entire File.... ...... .8295 File Trailer Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/11/14 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...... .05/11/14 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 NPHI FCNT NCNT PEF DRHO RHOB RPD FET RPS RPX RPM GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 8204.5 8204.5 8204.5 8217.5 8217.5 821 7.5 8243.5 8243.5 8243.5 8243.5 8243.5 8251.0 8295.5 # 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 CTN ALD $ STOP DEPTH 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 11332.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: 11-MAY-05 Insite 66.37 Memory 11332.0 8295.0 11332.0 70.6 96 .2 TOOL NUMBER 163686 125889 179954 10640599 8.500 8290.0 oil Based 9.10 73.0 .0 35000 2.3 .000 .000 .000 .000 .0 133.0 .0 .0 . . 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 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 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8204.5 11332 9768.25 6256 8204.5 11332 ROP MWD030 FT/H 5.69 280.15 184.465 6074 8295.5 11332 GR MWD030 API 45.38 104.11 74.9963 6163 8251 11332 RPX MWD030 OHMM 3.55 2000 30.702 6178 8243.5 11332 RPS MWD030 OHMM 4.93 2000 34.6137 6178 8243.5 11332 RPM MWD030 OHMM 5.09 1809.23 36.6246 6178 8243.5 11332 RPD MWD030 OHMM 1. 06 2000 43.1726 6178 8243.5 11332 FET MWD030 HOUR 0.2 89.64 2.00675 6178 8243.5 11332 NPHI MWD030 PU-S 15.64 52.45 38.8275 6256 8204.5 11332 FCNT MWD030 CNTS 556 3066 969.676 6256 8204.5 11332 NCNT MWD030 CNTS 106672 193322 138396 6256 8204.5 11332 RHOB MWD030 G/CM 0.438 2.712 2.1915 6230 8217.5 11332 DRHO MWD030 G/CM -2.671 0.314 0.016504 6230 8217.5 11332 PEF MWD030 BARN 0.91 14.25 2.33913 6230 8217.5 11332 First Reading For Entire File......... .8204.5 Last Reading For Entire File.......... .11332 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/11/14 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...... .05/11/14 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 PEF GR RPS RPM RPD FET FCNT NCNT DRHO RHOB NPHI ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 11332.5 # 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 CTN ALD $ STOP DEPTH 13493.5 13461.0 13501. 0 13493.5 13493.5 13493.5 13493.5 13447.5 13447.5 13461.0 13461.0 13447.5 13539.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): f! 16-MAY-05 Insite 66.37 Memory 13539.0 11332.0 13539.0 85.8 94.7 TOOL NUMBER 163686 125889 179954 10640599 8.500 8290.0 Oil Based 9.00 93.0 .0 37000 2.4 .000 .000 .000 .000 .0 141.8 .0 .0 . . 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 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 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11332.5 13539 12435.8 4414 11332.5 13539 ROP MWD040 FT/H 0.31 279.75 179.55 4414 11332.5 13539 GR MWD040 API 47.37 115.8 77.5658 4338 11332.5 13501 RPX MWD040 OHMM 5.14 54.89 15.6227 4323 11332.5 13493.5 RPS MWD040 OHMM 5.21 57.38 15.5043 4323 11332.5 13493.5 RPM MWD040 OHMM 5.21 113.18 16.1279 4323 11332.5 13493.5 RPD MWD040 OHMM 5.76 78.58 17.0536 4323 11332.5 13493.5 FET MWD040 HOUR 0.2 16.14 0.565184 4323 11332.5 13493.5 NPHI MWD040 PU-S 15.19 53.39 42.4469 4231 11332.5 13447.5 FCNT MWD040 CNTS 729 3002 981.623 4231 11332.5 13447.5 NCNT MWD040 CNTS 123005 192008 139875 4231 11332.5 13447.5 RHOB MWD040 G/CM 2.082 2.759 2.21519 4258 11332.5 13461 DRHO MWD040 G/CM -0.041 0.202 0.0483264 4258 11332.5 13461 PEF MWD040 BARN 0.91 6.19 2.05748 4258 11332.5 13461 First Reading For Entire File......... .11332.5 Last Reading For Entire File.......... .13539 File Trailer Service name..... ....... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/11/14 Maximum Physical Record. .65535 File Type.......... ..... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .05/11/14 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.................... .05/11/14 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
