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Home My WebLink About190-134CAUTION: 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-24 (PTD 190-134) Report of suspect IA pressure increase Date:Thursday, March 7, 2024 8:11:56 AM Attachments:AnnComm Surveillance TIO for 3G-24.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, March 7, 2024 7:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3G-24 (PTD 190-134) Report of suspect IA pressure increase Chris, KRU 3G-24 (PTD 190-134) (AIO 2C.040) is exhibiting suspect IA pressure increase. The plan is for DHD to conduct initial diagnostics including an MITIA, pack off tests, and adjusting pressures to set the well up for a 30 day monitor. Any required paperwork for continued injection or corrective action will be submitted upon conclusion of the diagnostics and monitor period. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 3G-24 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3G-24 2024-02-29 1800 850 -950 IA 3G-24 2024-03-07 25 800 775 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 26' of Rat Hole 9,684.0 8/22/2021 3G-24 famaj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pre-CTD Wellwork, Set Flow-Thru X-Lock 11/20/2021 3G-24 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.5 Set Depth (ftKB) 4,572.5 Set Depth (TVD) … 3,102.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 9,930.7 Set Depth (TVD) … 6,074.4 Wt/Len (l… 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.4 Set Depth (ft… 9,705.5 Set Depth (TVD) (… 5,903.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection H563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 31.4 31.4 0.03 Hanger 2.950 7.100 Cameron Type CXS 7 1/16" x 3.5" Cameron Type CXS Tubing Hanger 517.7 516.3 10.93 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE SN# 0004556488-2 9,340.9 5,648.4 50.48 GAS LIFT 2.992 5.935 SLB MMG 3.5" X 1.5" MMG, L-80, 9.3# HYD563. SOV W/RKP LATCH, SN# 21913-05 9,400.6 5,687.1 48.83 Locator 2.992 3.500 Baker 80-40 Baker Locator No-Go 9,401.7 5,687.8 48.80 Seal Assembly 2.980 5.890 Baker 80-40 3.5" EUE 80-40 SEAL ASSEMBLY (3' from fully located, 11.82' Seals) 9,410.6 5,693.6 48.53 PBR (Polished Bore Receptacle) 2.970 5.000 Baker 80-40 3.5" EUE 80-40 "PBR" POLISH BORE RECEPTACLE 9,574.4 5,807.1 44.23 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE W/ RHC Plug installed SN# 4371615 9,625.6 5,844.1 43.09 Tandem Wedge 2.992 5.935 Norther Solutions Luter Wedge 7" x 3.5" 350-700 Outer Wedge Assy 9,639.6 5,854.3 42.78 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE EUE SN# 00004556488-1 9,645.4 5,858.6 42.65 Tandem Wedge 2.992 5.935 Norther Solutions Outer Wedge 7" x 3.5" 350-700 Outer Wedge Assy 9,659.4 5,868.9 42.33 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE EUE SN# 00004556488-2 FLOW-THRU X-LOCK INSTALLED 11/20/21 9,705.0 5,902.9 41.26 Mule shoe 2.992 4.473 Halliburto n WLEG 3.5" WLEG, EUE-M Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,571.0 5,804.6 44.30 FISH Stuck CoilTrack 12/11/2021 0.000 9,631.0 5,848.0 42.97 WHIPSTOCK 11/30/2021 3.500 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 9,340.9 5,648.4 50.48 Vanoil MMG 1 1/2 INJ DMY RK 0.000 0.0 11/19/2021 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,618.0 9,658.0 5,838.5 5,867.9 A-2, A-1, 3G-24 1/8/1991 4.0 IPERF 180 deg. phasing, 4 1/2" JRC 3G-24, 1/4/2022 6:29:59 AM Vertical schematic (actual) PRODUCTION; 35.0-9,930.7 OTHER; 9,848.0 Mule shoe; 9,705.0 Nipple - X; 9,659.4 Tandem Wedge; 9,645.4 Nipple - X; 9,639.6 IPERF; 9,618.0-9,658.0 Tandem Wedge; 9,625.6 FISH; 9,571.0 Nipple - X; 9,574.4 Packer (Tubing); 9,421.8 PBR (Polished Bore Receptacle); 9,410.5 Seal Assembly; 9,401.7 Locator; 9,400.6 GAS LIFT; 9,340.9 SURFACE; 34.5-4,572.5 Nipple - X; 517.7 CONDUCTOR; 35.0-115.0 Hanger; 31.4 Casing 1; 0.0 KUP INJ KB-Grd (ft) 31.35 Rig Release Date 10/12/1990 3G-24 ... TD Act Btm (ftKB) 9,940.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032014500 Wellbore Status INJ Max Angle & MD Incl (°) 62.36 MD (ftKB) 3,900.00 WELLNAME WELLBORE3G-24 Annotation Last WO: End Date 11/1/2021 H2S (ppm) DateComment SSSV: LOCKED OUT MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 20, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-24 KUPARUK RIV UNIT 3G-24 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/20/2023 3G-24 50-103-20145-00-00 190-134-0 W SPT 5716 1901340 3000 2814 2816 2814 2814 920 1120 1120 1120 REQVAR P Adam Earl 8/1/2023 MIT IA tested as per AIO 2C.040 to max ant. Inj. Psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3G-24 Inspection Date: Tubing OA Packer Depth 1540 3450 3420 3420IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230802195416 BBL Pumped:1.9 BBL Returned:1.9 Wednesday, September 20, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO 2C.040 James B. Regg Digitally signed by James B. Regg Date: 2023.09.28 12:23:57 -08'00' 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-24 (PTD 190-134) Update and return to water injection Date:Wednesday, July 20, 2022 8:48:31 AM Attachments:AnnComm Surveillance TIO for 3G-24.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Wednesday, July 20, 2022 8:28 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-24 (PTD 190-134) Update and return to water injection Chris, KRU 3G-24 (PTD 190-134) was brought on gas injection July 15th and the IA pressure quickly increased. The IA pressure was bled multiple times, but continued to repressurize. Due to the apparent continued TxIA on gas injection the well was WAG’d back to water injection yesterday and the plan is to continue water injection only under AIO 2C.040. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 3G-24 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING3G-24 2022-07-16 2000 1000 -1000 IA3G-24 2022-07-17 1900 1000 -900 IA3G-24 2022-07-18 2000 1000 -1000 IA3G-24 2022-07-19 1500 400 -1100 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: RKB 26' of Rat Hole 9,684.0 8/22/2021 3G-24 famajLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: Pre-CTD Wellwork, Set Flow-Thru X-Lock 11/20/2021 3G-24 claytgCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.06 Top (ftKB)35.0 Set Depth (ftKB)115.0 Set Depth (TVD) …115.0 Wt/Len (l…62.58 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.92 Top (ftKB)34.5 Set Depth (ftKB)4,572.5 Set Depth (TVD) …3,102.2 Wt/Len (l…36.00 GradeJ-55 Top ThreadBTCCasing DescriptionPRODUCTION OD (in)7 ID (in)6.28 Top (ftKB)35.0 Set Depth (ftKB)9,930.7 Set Depth (TVD) …6,074.4 Wt/Len (l…26.00 GradeJ-55 Top ThreadAB-MODTubing StringsTubing DescriptionTubing – Production String Ma…3 1/2 ID (in)2.99 Top (ftKB)31.4 Set Depth (ft…9,705.5 Set Depth (TVD) (…5,903.3 Wt (lb/ft)9.30 GradeL-80 Top ConnectionH563Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 31.4 31.4 0.03 Hanger 2.950 7.100 Cameron Type CXS 7 1/16" x 3.5" Cameron Type CXS Tubing Hanger 517.7 516.3 10.93 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE SN# 0004556488-2 9,340.9 5,648.4 50.48 GAS LIFT 2.992 5.935 SLB MMG 3.5" X 1.5" MMG, L-80, 9.3# HYD563. SOV W/RKP LATCH, SN# 21913-05 9,400.6 5,687.1 48.83 Locator 2.992 3.500 Baker 80-40 Baker Locator No-Go 9,401.7 5,687.8 48.80 Seal Assembly 2.980 5.890 Baker 80-40 3.5" EUE 80-40 SEAL ASSEMBLY (3' from fully located, 11.82' Seals) 9,410.6 5,693.6 48.53 PBR (Polished Bore Receptacle) 2.970 5.000 Baker 80-40 3.5" EUE 80-40 "PBR" POLISH BORE RECEPTACLE 9,574.4 5,807.1 44.23 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE W/ RHC Plug installed SN# 4371615 9,625.6 5,844.1 43.09 Tandem Wedge 2.992 5.935 Norther Solutions Luter Wedge 7" x 3.5" 350-700 Outer Wedge Assy 9,639.6 5,854.3 42.78 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE EUE SN# 00004556488-1 9,645.4 5,858.6 42.65 Tandem Wedge 2.992 5.935 Norther Solutions Outer Wedge 7" x 3.5" 350-700 Outer Wedge Assy 9,659.4 5,868.9 42.33 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE EUE SN# 00004556488-2 FLOW-THRU X-LOCK INSTALLED 11/20/21 9,705.0 5,902.9 41.26 Mule shoe 2.992 4.473 Halliburto n WLEG 3.5" WLEG, EUE-M Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,571.0 5,804.6 44.30 FISH Stuck CoilTrack 12/11/2021 0.000 9,631.0 5,848.0 42.97 WHIPSTOCK 11/30/2021 3.500 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 9,340.9 5,648.4 50.48 Vanoil MMG 1 1/2 INJ DMY RK 0.000 0.0 11/19/2021 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,618.0 9,658.0 5,838.5 5,867.9 A-2, A-1, 3G-24 1/8/1991 4.0 IPERF 180 deg. phasing, 4 1/2" JRC 3G-24, 1/4/2022 6:29:59 AMVertical schematic (actual) PRODUCTION; 35.0-9,930.7 OTHER; 9,848.0 Mule shoe; 9,705.0 Nipple - X; 9,659.4 Tandem Wedge; 9,645.4 Nipple - X; 9,639.6 IPERF; 9,618.0-9,658.0 Tandem Wedge; 9,625.6 FISH; 9,571.0 Nipple - X; 9,574.4 Packer (Tubing); 9,421.8 PBR (Polished Bore Receptacle); 9,410.5 Seal Assembly; 9,401.7 Locator; 9,400.6 GAS LIFT; 9,340.9 SURFACE; 34.5-4,572.5 Nipple - X; 517.7 CONDUCTOR; 35.0-115.0Hanger; 31.4Casing 1; 0.0 KUP INJ KB-Grd (ft)31.35 Rig Release Date10/12/19903G-24...TDAct Btm (ftKB)9,940.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI501032014500 Wellbore StatusINJ Max Angle & MDIncl (°)62.36 MD (ftKB)3,900.00WELLNAME WELLBORE3G-24 AnnotationLast WO:End Date11/1/2021H2S (ppm) DateCommentSSSV: LOCKED OUT 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-24 (PTD 190-134) Report of intent to inject gas Date:Thursday, July 7, 2022 1:26:26 PM Attachments:AnnComm Surveillance TIO for 3G-24.pdf MIT KRU 3G-24 1-8-22.xlsx From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, July 7, 2022 10:09 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-24 (PTD 190-134) Report of intent to inject gas Chris, KRU 3G-24 (PTD 190-134) currently operates under AIO 2C.040 for continued water injection only due to known TxIA communication on gas injection. A RWO was completed November 2021 during which a new Baker FHL packer was set at 9422’ and new 3.5” Hyd 563 tubing was installed. CPAI intends to WAG the well to gas injection for a 90 day monitor to verify if the new completion has eliminated the TxIA communication on gas. If TxIA communication on gas no longer exists an AA cancelation request will be submitted to return the well to normal WAG ability. If TxIA communication on gas remains the well will be returned to water injection to continue operation under the current AIO. The most recent passing SW MITIA from 1/8/2022 is attached. A 90 day TIO plot and wellbore schematic are also attached. Please let me know if you disagree with or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 3G-24 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 26' of Rat Hole 9,684.0 8/22/2021 3G-24 famaj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pre-CTD Wellwork, Set Flow-Thru X-Lock 11/20/2021 3G-24 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.5 Set Depth (ftKB) 4,572.5 Set Depth (TVD) … 3,102.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 9,930.7 Set Depth (TVD) … 6,074.4 Wt/Len (l… 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.4 Set Depth (ft… 9,705.5 Set Depth (TVD) (… 5,903.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection H563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 31.4 31.4 0.03 Hanger 2.950 7.100 Cameron Type CXS 7 1/16" x 3.5" Cameron Type CXS Tubing Hanger 517.7 516.3 10.93 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE SN# 0004556488-2 9,340.9 5,648.4 50.48 GAS LIFT 2.992 5.935 SLB MMG 3.5" X 1.5" MMG, L-80, 9.3# HYD563. SOV W/RKP LATCH, SN# 21913-05 9,400.6 5,687.1 48.83 Locator 2.992 3.500 Baker 80-40 Baker Locator No-Go 9,401.7 5,687.8 48.80 Seal Assembly 2.980 5.890 Baker 80-40 3.5" EUE 80-40 SEAL ASSEMBLY (3' from fully located, 11.82' Seals) 9,410.6 5,693.6 48.53 PBR (Polished Bore Receptacle) 2.970 5.000 Baker 80-40 3.5" EUE 80-40 "PBR" POLISH BORE RECEPTACLE 9,574.4 5,807.1 44.23 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE W/ RHC Plug installed SN# 4371615 9,625.6 5,844.1 43.09 Tandem Wedge 2.992 5.935 Norther Solutions Luter Wedge 7" x 3.5" 350-700 Outer Wedge Assy 9,639.6 5,854.3 42.78 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE EUE SN# 00004556488-1 9,645.4 5,858.6 42.65 Tandem Wedge 2.992 5.935 Norther Solutions Outer Wedge 7" x 3.5" 350-700 Outer Wedge Assy 9,659.4 5,868.9 42.33 Nipple - X 2.813 4.250 Halliburto n X Nipple 3.5" x 2.813" X-NIPPLE EUE SN# 00004556488-2 FLOW-THRU X-LOCK INSTALLED 11/20/21 9,705.0 5,902.9 41.26 Mule shoe 2.992 4.473 Halliburto n WLEG 3.5" WLEG, EUE-M Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,571.0 5,804.6 44.30 FISH Stuck CoilTrack 12/11/2021 0.000 9,631.0 5,848.0 42.97 WHIPSTOCK 11/30/2021 3.500 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 9,340.9 5,648.4 50.48 Vanoil MMG 1 1/2 INJ DMY RK 0.000 0.0 11/19/2021 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,618.0 9,658.0 5,838.5 5,867.9 A-2, A-1, 3G-24 1/8/1991 4.0 IPERF 180 deg. phasing, 4 1/2" JRC 3G-24, 1/4/2022 6:29:59 AM Vertical schematic (actual) PRODUCTION; 35.0-9,930.7 OTHER; 9,848.0 Mule shoe; 9,705.0 Nipple - X; 9,659.4 Tandem Wedge; 9,645.4 Nipple - X; 9,639.6 IPERF; 9,618.0-9,658.0 Tandem Wedge; 9,625.6 FISH; 9,571.0 Nipple - X; 9,574.4 Packer (Tubing); 9,421.8 PBR (Polished Bore Receptacle); 9,410.5 Seal Assembly; 9,401.7 Locator; 9,400.6 GAS LIFT; 9,340.9 SURFACE; 34.5-4,572.5 Nipple - X; 517.7 CONDUCTOR; 35.0-115.0 Hanger; 31.4 Casing 1; 0.0 KUP INJ KB-Grd (ft) 31.35 Rig Release Date 10/12/1990 3G-24 ... TD Act Btm (ftKB) 9,940.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032014500 Wellbore Status INJ Max Angle & MD Incl (°) 62.36 MD (ftKB) 3,900.00 WELLNAME WELLBORE3G-24 Annotation Last WO: End Date 11/1/2021 H2S (ppm) DateComment SSSV: LOCKED OUT Submit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901340 Type Inj W Tubing 1675 1675 1675 1675 Type Test P Packer TVD 5701 BBL Pump 2.3 IA 925 3280 3240 3230 Interval V Test psi 3000 BBL Return 2.3 OA 820 1085 1085 1080 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3G Pad Lou Laubenstein Miller 01/08/22 Notes:MITIA post RWO per Sundry # 321-461 and to maximum anticipated injection pressure per AIO 2C.040 Notes: 3G-24 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al In t eg r ity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 3G-24 1-8-22 (002) MEMORANDUM TO: Jim Regg J�J 1/zCZv P.I. Supervisor I' tt fI 1 FROM: Lou Laubenstein Petroleum Inspector Well Name KUPARUK RIV UNIT 3G-24 Insp Num: mitLOL220111092038 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 20, 2022 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-24 KUPARUK RIV UNIT 3G-24 Src: Inspector Reviewed By: P.I. Supry S� Comm API Well Number 50-103-20145-00-00 Inspector Name: Lou Laubenstein Permit Number: 190-134-0 Inspection Date: 18/2022 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well YP J g l t6zs 16zs 1675 -' 1675 Type In' F 'TVD 5716 Tubin - - — - - 2a PTD 19o13ao I,Type Testi SPT Test psi 300— IA 925 3280 3240 3230 BBL Pumped: 2.3 BBL Returned 2.3 OA 820 _ !, 1085 1085 Ioso - — -- Interval REQVAR PIF - P Notes: MIT -IA to maximum anticipated injection pressure per AIO 2C.040 post RWO per Sundry # 321-461 ;/ Thursday, January 20, 2022 Page 1 of 1 ! 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" # $! % " "&'( ) &$*"" +,$ -.,# / #'0$ 10 2$$ " ## ! 3 .3 4 $ 5, 67 $89:6 8 , ;,6 8 , <,6 8 - #, ;, - #, <, ;6 8 6;,8=)6;,8 55*9 $: "'19 &9&9 0 *//9 7 ) <) <;,6 8<,6 8 & /" !) , () -. ,# # *- , + !) " 07 0$=,7 '<#,>>> 7?> >"" #>0$= ! "$ "- " @ " #$ >"" #! $ 0( ; 0 7" 00A;0 B34 $ -. 34 $ <-,(4 #";;00$- C->"", ""-> - '92B 55/B '91**+99 $: 5'2%5'+2B 525'B +2/5%+2'2B -$#D&9& /%:&E )()1EC7 #) < ;F <#67)8 *+/2B 55/B , ;,6 8 'E 5%+:2E 29B +B *+1/B '91*B1E 7%29 5'59B *529 '*9 /+&9 +B /9&B ! -7G 7G07$,>"$- <0$";;00$ "! &9"&+&29 #$$%&' (#))* *+,-*.% (.99/'9D DG55+9 $,-*,.-#,*%$-,,-,, " )D0 (./-#%$: ( 01 " 23( 01 > ;,6 8 5*9*B;,+'25B<, 12+B;,'/&B<, , <,6 8 @ 10 # !# ! !# @$ ,! , /! ",: -, = " 65918&'/%*& A H 9%*9/ # 9:&9& 1 2 4125*#6 56 2 5 17 By Samantha Carlisle at 9:20 am, Nov 02, 2021 321-564 Digitally signed by R. Tyler Senden DN: CN=R. Tyler Senden, O=Intervention and Integrity, OU=AK Wells, E=r.tyler.senden@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.11.01 16:21:03-08'00' Foxit PDF Editor Version: 11.0.0 R. Tyler Senden SFD 11/2/2021 X BOP test pressure to 4500 psig Annular test pressure to 2500 psig DSR-11/2/21 X VTL 11/3/21 X 10-404 dts 11/3/2021 JLC 11/3/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.04 00:00:05 -08'00' RBDMS HEW 11/4/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 29, 2021 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set an Inner Wedge in KRU 3G-24 (PTD #190-134) in order to drill three CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC. The well is currently being worked-over at the time of this writing (10/29/2021) to install a Tandem Wedge setup for CTD operations. CTD operations are planned to begin November 2021. Pre-rig work is required prior to CDR3 arrival and will begin early November, which is outlined in the Operations Summary, below. Attached to this application are the following documents: 10-403 Sundry Application for KRU 3G-24 Operations Summary in support of the 10-403 sundry application ¼-Mile Review Current wellbore schematic Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, Jeff Connelly ConocoPhillips Alaska Coiled Tubing Drilling Engineer Digitally signed by Jeff Connelly DN: C=US, OU=CTD, O=ConocoPhillips, CN=Jeff Connelly, E=jeff.s.connelly@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.11.01 11:10:38-08'00' Foxit PDF Editor Version: 11.0.0 Jeff Connelly Wedge set up will have flow-through capabilities. SFD 11/2/2021 Page 1 of 1 10/29/2021 KRU 3G-24 (PTD #190-134) CTD Summary for Sundry Summary of Operations (Sundry application items in bold): KRU well 3G-24 is equipped with 3-1/2” tubing and 7” production casing. The CTD sidetrack will utilize three laterals to target the A-sands to the north and south of 3G-24. The 3G-24 CTD laterals will provide injection support to the 3H-01 & 3G-25X wells, increasing A-sand resource recovery and throughput. A ¼-Mile Review of surrounding wells is included in this Sundry Application. A planned rig workover is underway to install tandem wedges to facilitate cutting a window with CTD to enable CTD operations (Work-over is currently underway by Nabors 7ES as of 10/29/21). Once the work-over is complete E-line will set an inner wedge at ~9634’ MD. CDR3-AC will mill a window in the 3-1/2” tubing and 7” casing at 9634’ MD and the 3G-24L1 lateral will be drilled to TD at 13,700’ MD, targeting the A-sand to the north. It will be completed with 2-3/8” slotted liner from TD up to 12,100’ MD with a liner-top aluminum billet. 3G-24L1-01 will kick-off the billet at 12,100’ MD and drill to TD of 13,700’, again to the north. Slotted liner will be run from TD to 9840’ MD with a liner-top aluminum billet. 3G-24L1-02 will kick off the billet at 9840’ MD and drill to TD of 13,500’, to the south. Slotted liner will be run from TD to the top-of-whipstock at 9634’ MD with a deployment sleeve. CTD Prep Work, Drill, and Complete 3G-24 CTD Laterals: November 2021 Pre-CTD Work (Sundry applications items in bold): 1.RU Slick-line: Brush and flush nipple profiles, drift tubing and set X-lock. 2. RU E-line: Log GR/CCL, & Set inner wedge. 3.Prep site for Nabors CDR3-AC. Rig Work (for reference): 1.MIRU Nabors CDR3-AC rig using 2” coil tubing. NU 7-1/16” BOPE, test. 2.3G-24L1 Lateral (A-sand - North) a.Mill 2.80” window at 9634’ MD. b. Drill 3” bi-center lateral to TD of 13,700’ MD. c.Run 2Ǫ” slotted liner with aluminum billet from TD up to 12,100’ MD. 3.3G-24L1-01 Lateral (A-sand - North) a.KO aluminum billet at 12,100’ MD b.Drill 3” bi-center lateral to TD of 13,700’ MD. c.Run 2Ǫ” slotted liner with aluminum billet from TD up to 9,840’ MD. 4.3G-24L1-01 Lateral (A-sand - South) a.KO aluminum billet at 9,840’ MD b.Drill 3” bi-center lateral to TD of 13,500’ MD. c.Run 2Ǫ” slotted liner with deployment sleeve from TD up to TOWS at 9634’’ MD. 5.Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work (For reference): 1. Return to production 3G-24L, 3G-24L1-01, & 3G-24L1-02 Quarter Mile Injection ReviewWell NameStatusCasing SizeTop of C-Sand oil pool (MD)Top of C-Sand Oil Pool (TVDSS)Top of A-Sand oil pool (MD)Top of A-Sand Oil Pool (TVDSS)Top of Cement (MD)Top of Cement (TVDSS)Top of Cement Determined ByReservoir StatusZonal IsolationCement Operations SummaryMechanical Integrity3H-05 P&A 7" 6764 5796' 6836' 5855'Plug 1 = 3147'Plug 2 = 1032'Plug 3 = 52'Plug 1 = 2791'Plug 2 = 954'Plug 3 = 24'Log (original) Well is P&A'd with no communication with reservoirMotherbore perforations cement squeezed, and well P&A'd. Plugs 1, 2, & 3 pumped in 7" production casing. TOC's at 52', 1032', & 3147' RKBOrigninal 7" CMNT ('87): 500 sx Class GPlug 3: 41 bbl pumped, 15.7#, returns to surfacePlug 2: 70 bbl cement pumped to IA & tubingPlug 1: 158 bbl, 15.8 ppg cmnt P&A final site clearance received 5/16/19 from AOGCC Matt Herrara. Total of 13'-2" of wellhead removed , marker plate welded and buried >4 below original tundra.3G-24 1/4-Mile Review Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last tag: 20' Rat Hole 9,678.0 8/16/2019 3G-24 jhansen8 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Plug & Measured BHP 3/9/2020 3G-24 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.5 Set Depth (ftKB) 4,572.5 Set Depth (TVD) … 3,102.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 9,930.7 Set Depth (TVD) … 6,074.4 Wt/Len (l… 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description TUBING 3.5"x2.875" @9420' String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.4 Set Depth (ft… 9,527.3 Set Depth (TVD) (… 5,773.6 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.4 31.4 0.03 HANGER WKM GEN IV HANGER 3.500 1,785.2 1,631.7 42.71 SAFETY VLV OTIS FMX SAFETY VALVE - LOCKED OUT 2.813 9,420.0 5,699.9 48.25 XO Reducing CROSSOVER 3.5 x 2.875 2.875 9,426.3 5,704.1 48.06 PBR CAMCO OEJ PBR 2.312 9,443.8 5,715.9 47.54 PACKER CAMCO HRP-1-SP PACKER 2.347 9,514.9 5,764.9 45.52 NIPPLE CAMCO D NIPPLE NO GO 2.250 9,526.6 5,773.1 45.27 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 9,336.0 5,645.3 50.62 PATCH 3.5" HALLIBURTON PERMANENT PATCH (SEE DRAWING IN WORKING FILE) 12/24/200 5 2.360 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,618.0 9,658.0 5,838.5 5,867.9 A-2, A-1, 3G-24 1/8/1991 4.0 IPERF 180 deg. phasing, 4 1/2" JRC Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,983.7 2,304.3 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1996 2 5,497.2 3,586.2 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1991 3 6,846.5 4,281.9 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1991 4 7,803.6 4,780.8 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1996 5 8,714.8 5,279.2 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1991 6 9,371.2 5,667.9 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/20/2019 Ext PKG 7 9,467.7 5,732.1 CAMCO TGPD 1 1/2 PROD DMY RK 0.000 0.0 1/9/1991 Notes: General & Safety End Date Annotation 11/29/2016 NOTE: Waivered for water injection only, TxIA communication on gas. 8/31/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3/6/2008 NOTE:SSSV CONTROL LINE LEAK - LAST GX SEALANT TREATMENT 3G-24, 3/10/2020 8:00:33 AM Vertical schematic (actual) PRODUCTION; 35.0-9,930.7 IPERF; 9,618.0-9,658.0 SOS; 9,526.6 NIPPLE; 9,514.9 PRODUCTION; 9,467.7 PACKER; 9,443.8 PBR; 9,426.3 GAS LIFT; 9,371.2 PATCH; 9,336.0 GAS LIFT; 8,714.8 GAS LIFT; 7,803.6 GAS LIFT; 6,846.5 GAS LIFT; 5,497.2 SURFACE; 34.5-4,572.5 GAS LIFT; 2,983.7 SAFETY VLV; 1,785.2 CONDUCTOR; 35.0-115.0 HANGER; 31.4 KUP INJ KB-Grd (ft) 37.21 Rig Release Date 10/12/1990 3G-24 ... TD Act Btm (ftKB) 9,940.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032014500 Wellbore Status INJ Max Angle & MD Incl (°) 62.36 MD (ftKB) 3,900.00 WELLNAME WELLBORE3G-24 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Nipple @ 5021' (2.813" ID)3-1/2" MMG gas lift mandrel @ 9325' MDPBR 9395' MDPacker @ 9406' MD (4.0" ID)3-1/2" Nipple @ 9560' MD (2.813" ID)3-1/2" Nipple @ 9626' MD (2.813" ID)3-1/2" Nipple @ 9646' MD (2.813" ID)Northern Solutions WEDGE (see details)7" 26# J-55 shoe @ 9931' MDA-sand perfs 9618' - 9658' MD9-5/8" 36# J-55 shoe @ 4573' MD16" 62# H-40 shoe @ 115' MDProposed KOP @ 9634' MD3G-24L1 wp02TD 13,700' MDWOB = 13,700' MDTop of Billet @ 12,100' MDNorthern Solutions Wedge* 3-1/2" 9.3# L-80 Base Pipe* 5.905" OD (12.9' long)* ~23.14' Total Length* 0.625" Bore thru Upper Tray* 1.125" Bore thru Lower Section* HES 2.81" X Nipple below 3G-24L1-02 wp02TD 13,500' MDWOB = 12,502' MDTop of Liner ~ 9634' MD3G-24L1-01 wp01TD 13,700' MDWOB = 13,700' MDTop of Billet @ 9,840' MDNORTHNORTHSOUTH 1 Davies, Stephen F (CED) From:Connelly, Jeff <Jeff.S.Connelly@conocophillips.com> Sent:Tuesday, November 2, 2021 10:07 AM To:Davies, Stephen F (CED) Subject:RE: [EXTERNAL]KRU 3G-24 (PTD 190-134; Sundry 321-564) - Question HelloSteve, TheAͲSandperforationswillremainopen.TheXͲLockthattheinnerwedgeisseton,andtheinnerwedgeitselfhave flowthroughcapabilities.Thatsaid,we’replanningtoKOandmillthewindowat~9634’MD,whichputstheexitinthe AͲSandperforations.Toanswerplainly,theexistingperforationswouldremainopentoreceiveinjection. Pleasereachoutiftherearefurtherquestions. Regards, Jeff From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Tuesday,November2,20219:59AM To:Connelly,Jeff<Jeff.S.Connelly@conocophillips.com> Subject:[EXTERNAL]KRU3GͲ24(PTD190Ͳ134;Sundry321Ͳ564)ͲQuestion CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Jeff, Ijustneedtocheckwithyou:Willthewedgesetupproposedfor3GͲ24isolatetheexistingperforationsinthewell,or willthoseperforationsstillremainopentoinjection? Thanksandstaysafe, SteveDavies AlaskaOilandGasConservationCommission(AOGCC) CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Hobbs, Greg S To:Loepp, Victoria T (OGC); Phillips, Ron L Cc:Senden, R. Tyler Subject:RE: [EXTERNAL]KRU 3G-24 Sundry BOP test pressure (PTD 190-134/ Sundry 321-461) Date:Monday, October 4, 2021 11:37:50 AM Thanks for the clarification Victoria, I asked Ron to reach out. Greg From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, October 4, 2021 11:35 AM To: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]KRU 3G-24 Sundry BOP test pressure (PTD 190-134/ Sundry 321-461) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Ron, It would be desirable if you would come up with a BOPE test pressure that would cover most MPSPs in your workover program, such as 3500 psig. On this well 107 psig is too close especially being at the point where the number of rams requirement changes(3000 psig). Remember 3H-26 where we were chasing pressure, numerous requests for BOPE test pressure changes and requests for changes in the number of rams? We want to avoid that. Victoria From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Monday, October 4, 2021 10:24 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: KRU 3G-24 Sundry BOP test pressure (PTD 190-134/ Sundry 321-461) Good morning Victoria, On well KRU 3G-24 my MPSP in box #11 on the 10-403 is calculated at 2893 psi. On the Procedure page of the application step #3 I said we would test the BOPE to 3,000 psi. In the past you have always required the BOPE test to the same pressure I have calculated. I take my MPSP and round up to the nearest hundred and add 100 psi. In this case that is 107 PSI above MPSP. Do you round up differently? I will change the way I round up if necessary so that my procedure and the approved Sundry match. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From:Phillips, Ron L To:Loepp, Victoria T (OGC) Cc:Hobbs, Greg S; Senden, R. Tyler Subject:RE: KRU 3G-24 Sundry BOP test pressure (PTD 190-134/ Sundry 321-461) Date:Monday, October 4, 2021 10:26:07 AM Attachments:Sundry_321-461_100121.pdf Victoria, Here is the approved sundry I referenced below. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Phillips, Ron L Sent: Monday, October 04, 2021 10:24 AM To: Victoria T Loepp <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S (Greg.S.Hobbs@conocophillips.com) <Greg.S.Hobbs@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: KRU 3G-24 Sundry BOP test pressure (PTD 190-134/ Sundry 321-461) Good morning Victoria, On well KRU 3G-24 my MPSP in box #11 on the 10-403 is calculated at 2893 psi. On the Procedure page of the application step #3 I said we would test the BOPE to 3,000 psi. In the past you have always required the BOPE test to the same pressure I have calculated. I take my MPSP and round up to the nearest hundred and add 100 psi. In this case that is 107 PSI above MPSP. Do you round up differently? I will change the way I round up if necessary so that my procedure and the approved Sundry match. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 ! " # $! % " &&&&&&&&&&&&&&&&&&& '$("" )*$ +,*# - #./$ 0/ 1$$ " ## ! 2 3 ,2 4 $ 5* 67 $8936 8 * :*6 8 * ;*6 8 + #* :* + #* ;* :6 8 6:*8<=6:*8 55(9>.91>5.05>)11->'15- $$ " / 7 = ;= ;:*6 8;*6 8 "? %%= :@ ##5(((>:*>3)0.>;*01)>:*3.-'>;* ' -" != * A= +, *# # (+ * ) != " /7 /$<*7 .;#*BB B 7CB " #B/$< ! "$ +"+ " 590%'.)%.-' * " #$ " #! $ /A : / 7" //D:/ >24 $ +, 24 $ ;+*A4 # ":://$+ ?+":://$ * " " + B + 7 E F$ B :*6 8 +7G 7G/7$*B"$+ ;/$":://$ '9"')'19 *7'))(07G'.. 59%-( A,99-.9H HG55)9 )9%9-%'9()%99 " =H/ G C-B%'( G= #3G= # !" 5)'0- )> -9'> )> ()0-> .90(>55-> .IH.')1J 5.')IH-.J 19> ()-1> 5.1>%5.)1> 515.> )1-5>%)1.1> * ;*6 8 F 0IH'.J F 0/ # ! # ! !# F 933'9' -)IH5- 6,'%031E5('9>8 * :*6 8 <%)) 9%(9- # -3'9'9 "# $ %#$&"'()&") $ & "#* By Samantha Carlisle at 8:34 am, Sep 10, 2021 321-461 Ron Phillips Digitally signed by Ron Phillips Date: 2021.09.09 14:41:08 -08'00' SFD 9/10/2021 DSR-9/13/21SFD 9/10/2021 X 10-404 X VTL 10/1/21 BOP test to 3500 psig Annular preventer test to 2500 psig X dts 10/1/2021 JLC 10/1/2021 Jeremy Price Digitally signed by Jeremy Price Date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on Phillips Digitally signed by Ron Phillips Date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asing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 34.5 Set Depth (ftKB) 4,572.5 Set Depth (TVD) … 3,102.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 35.0 Set Depth (ftKB) 9,930.7 Set Depth (TVD) … 6,074.4 Wt/Len (l… 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description TUBING 3.5"x2.875" @9420' String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 31.4 Set Depth (ft… 9,527.3 Set Depth (TVD) (… 5,773.6 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.4 31.4 0.03 HANGER WKM GEN IV HANGER 3.500 1,785.2 1,631.7 42.71 SAFETY VLV OTIS FMX SAFETY VALVE - LOCKED OUT 2.813 9,420.0 5,699.9 48.25 XO Reducing CROSSOVER 3.5 x 2.875 2.875 9,426.3 5,704.1 48.06 PBR CAMCO OEJ PBR 2.312 9,443.8 5,715.9 47.54 PACKER CAMCO HRP-1-SP PACKER 2.347 9,514.9 5,764.9 45.52 NIPPLE CAMCO D NIPPLE NO GO 2.250 9,526.6 5,773.1 45.27 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 9,336.0 5,645.3 50.62 PATCH 3.5" HALLIBURTON PERMANENT PATCH (SEE DRAWING IN WORKING FILE) 12/24/2005 2.360 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 9,618.0 9,658.0 5,838.5 5,867.9 A-2, A-1, 3G- 24 1/8/1991 4.0 IPERF 180 deg. phasing, 4 1/2" JRC Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,983.7 2,304.3 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1996 2 5,497.2 3,586.2 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1991 3 6,846.5 4,281.9 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1991 4 7,803.6 4,780.8 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1996 5 8,714.8 5,279.2 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/9/1991 6 9,371.2 5,667.9 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/19/1996 7 9,467.7 5,732.1 CAMCO TGPD 1 1/2 PROD DMY RK 0.000 0.0 1/9/1991 Notes: General & Safety End Date Annotation 10/9/2005 NOTE: TBG LEAK @ 9347 (TecWel LDL) 3/6/2008 NOTE:SSSV CONTROL LINE LEAK - LAST GX SEALANT TREATMENT 8/31/2010 NOTE: View Schematic w/ Alaska Schematic9.0 11/29/2016 NOTE: Waivered for water injection only, TxIA communication on gas. Comment SSSV: LOCKED OUT3G-24, 12/5/2016 4:02:48 PM Vertical schematic (actual) PRODUCTION; 35.0-9,930.7 IPERF; 9,618.0-9,658.0 SOS; 9,526.6 NIPPLE; 9,514.9 PRODUCTION; 9,467.7 PACKER; 9,443.8 PBR; 9,426.3 GAS LIFT; 9,371.2 PATCH; 9,336.0 GAS LIFT; 8,714.8 GAS LIFT; 7,803.6 GAS LIFT; 6,846.5 GAS LIFT; 5,497.2 SURFACE; 34.5-4,572.5 GAS LIFT; 2,983.7 SAFETY VLV; 1,785.2 CONDUCTOR; 35.0-115.0 HANGER; 31.4 Annotation Last Tag:SLM Depth (ftKB) 9,677.0 End Date 10/22/2013 Annotation Rev Reason: WAIVER FOR WATER INJ SEE NOTES Last Mod By pproven End Date 12/5/2016 KUP INJ KB-Grd (ft) 37.21 Rig Release Date 10/12/1990 Annotation Last WO: End Date 3G-24 H2S (ppm) Date ... TD Act Btm (ftKB) 9,940.0 Well Attributes Wellbore API/UWI 501032014500 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 62.36 MD (ftKB) 3,900.00 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, July 19, 2019 9:46 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3G-24 (PTD 190-134, AIO 2C.040) Suspect IA Behavior Hi Chris, We completed first-round diagnostics on KRU injector 3G-24 (PTD 190-134, AIO 2C.040). On 7/11/19 we performed passing T POT, T PPPOT, IC POT, IC PPPOT, and achieved a passing MIT -IA to 3000 psi but failed a DDT -IA on 7/12/19 indicating a one-way leak in the inner annulus. The well has been shut-in since 4/16/19 due to interference with the rig location. The well will be secured and remain SI while we develop a plan for further intervention work to determine the source of the failing draw down test. Please let me know if you have any questions or disagree with this plan forward. Sincerely, SaemCarltA&(HeA tv) Well Integrity & Compliance Specialist, Alpine & CPF3 Wells Data Analytics KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 Cell: 907-331-7514 sara a carlisle(a)conocoplullins com From: ell Integrity Compliance Specialist WNS & CPF3 Sent: Frida July 5, 2019 1:19 PM To: chris.walla alaska.gov Cc: CPA Wells Supt 030@conocophillips.com> Subject: KRU 3G-24 (PTD -134, AIO 2C.040) Suspect IA Behavior Chris, KRU injector 3G-24 (PTD 190-134, AIO 2C.040) shewled a suspect IA pressure increase while shut-in. There is a rig on 3G pad that may inhibit immediate diagnostics, but CPA ' tends to send DHD to perform diagnostics to investigate when the well can be accessed. If a mechanical integrity issue i entified, we will follow-up with you about a path forward. Otherwise, we will continue to operate the injector pecified in AIO 2C.040. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, July 5, 2019 1:19 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3G-24 (PTD 190-134, AIO 2C.040) Suspect IA Behavior Chris, KRU injector 3G-24 (PTD 190-134, AIO 2C.040) showed a suspect IA pressure increase while shut-in. There is a rig on 3G pad that may inhibit immediate diagnostics, but CPAI intends to send DHD to perform diagnostics to investigate when the well can be accessed. If a mechanical integrity issue is identified, we will follow-up with you about a path forward. Otherwise, we will continue to operate the injector as specified in AIO 2C.040. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 30,2017 TO: Jim Regg cp P.I.Supervisor V I30/I.7 SUBJECT: Mechanical Integrity Tests �f CONOCOPHILLIPS ALASKA,INC. 3G-24 FROM: Chuck Scheve KUPARUK RIV UNIT 3G-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-24API Well Number 50-103-20145-00-00 Inspector Name: Chuck Scheve Permit Number: 190-134-0 Inspection Date: 8/26/2017 r Insp Num: mitCS170827081902 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-24 Type Inj W 'TVD 5716 ' Tubing 2689 • 2689 " 2689 2689 PTD 1901340 Type Test SPT Test psi 1500 IA 560 3390 3290 - 3270 - BBL Pumped: 52 " BBL Returned: 5 OA 300 - 560 560 560- Interval REQVAR P/F P ✓ Notes: MITIA per AIO 2C.040 h` 2 { Wednesday,August 30,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,August 10,2017 P.I.Supervisor i'Ne� 6' , lz1(i7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3G-24 FROM: Chuck Scheve KUPARUK RIV UNIT 3G-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry St312-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-24 API Well Number 50-103-20145-00-00 Inspector Name: Chuck Scheve Permit Number: 190-134-0 Inspection Date: 8/5/2017 Insp Num: mitCS170806072735 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-24 Type Inj w TVD 5716 - Tubing 2670 2675 2680 - 2690- PTD 1901340 ' Type Test SPT Test psi' 3000 - IA 1 820 3380 - 3250 3230 BBL Pumped: I— 6.7 . BBL Returned: 4.8 - OA 270 490 490 • 490 - Intervai] REQVAR P/F I v" Notes: MITIA per AIO 2C.040 eco-meter showed IA to have fluid to surface and fluid was observed during rig up. The 6.7 bbls pumped along with gas observed dunng teed off is why I called the test inconclusive. n ' a s (4c..et,c,.u-S l.i 9.e S l.tiC e C.P— i l Xt'- c 4 JR5 OtAtutivcs y re SCikecta .e. ..tA — SPS C2k—1tC p/ SCANNED -1,j; Thursday,August 10,2017 Page 1 of 1 .-laC;t#it A-06 Cc 5jeo N1i CS17060607z735 Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, August 6, 2017 11:12 AM To: Regg,James B (DOA) Cc: DOA AOGCC Prudhoe Bay;Wallace, Chris D (DOA); Senden, R. Tyler Subject: KRU 3G-24 (PTD 190-134, AA 2C.040) MITIA Attachments: KRU 3G-24 TIO 90-day plot 8-6-17 jpg; MIT KRU 3G-15, 23 and 24 08-05-17 .xlsx Jim, CPAI performed a witnessed MITIA on injector KRU 3G-24 (PTD 190-134, AA 2C.040)yesterday. The test was called 'inconclusive' by the inspector on site, though CPAI believes the MIT to be a pass based on established criteria and will include the Pass result in the submitted 10-426. Injector 3G-24 received Administrative Approval in 2016 for continued water-only injection due to identified TxIA communication while on gas injection. CPAI believes gas entrainment in the IA fluid is most likely the reason for the BBL Pump/BBL Return difference since the IA fluid level was at surface and the gas entrained IA fluids were never addressed. Based on historic pressure trends and the MIT pressure results(attached 90-day TIO plot and form 10-426), we believe the well maintains integrity. However,to confirm the gas-entrainment theory, CPAI intends to degas the annulus and reschedule a second state-witnessed MIT before the end of August (the anniversary test month). The well will be left on water injection. Please let us know if this plan is acceptable, or if another course of action is preferred. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday,August 6, 2017 11:12 AM To: Regg,James B (DOA) Cc: DOA AOGCC Prudhoe Bay;Wallace, Chris D (DOA); Senden, R.Tyler Subject: KRU 3G-24 (PTD 190-134 AA X.040) MITIA Attachments: KRU 3G-24 TIO 90-day plot 8-6-17 jpg; MIT KRU 3G-15, 23 and 24 08-05-17 .xlsx Jim, CPAI performed a witnessed MITIA on injector KRU 3G-24(PTD 190-134,AA 2C.040)yesterday. The test was called 'inconclusive' by the inspector on site,though CPAI believes the MIT to be a pass based on established criteria and will include the Pass result in the submitted 10-426. Injector 3G-24 received Administrative Approval in 2016 for continued water-only injection due to identified TxIA communication while on gas injection. CPAI believes gas entrainment in the IA fluid is most likely the reason for the BBL Pump/BBL Return difference since the IA fluid level was at surface and the gas entrained IA fluids were never addressed. Based on historic pressure trends and the MIT pressure results(attached 90-day TIO plot and form 10-426),we believe the well maintains integrity. However,to confirm the gas-entrainment theory, CPAI intends to degas the annulus and reschedule a second state-witnessed MIT before the end of August(the anniversary test month). The well will be left on water injection. Please let us know if this plan is acceptable,or if another course of action is preferred. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. 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K) U K) U) N o 1() N ml U a '6O O aa cal E S E v m a T..) Z U 8 1.1 OC 'in Jia �" aJ 7 "1 ..:,k.Q of Nt o 0 N Cr N t- Cr a-+ Qct C 1_ Y Z OD 'r Z 4- N ,- 4- ,- N '- N O a+ E G) v v C@ Kg-- �1 g 1' m U Y Y U = i Q C9 7 E Z a a Q N is -.. M M M N r, M M N N o 0 W N E E C C C m {/1 ,..1 p 10 •.0 G! OND Ia" $ QG1 H a` a f°- H • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday,August 28, 2016 12:24 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: KRU 3G-24 (PTD# 190-134) update 8-28-16 Attachments: MIT KRU 3G-24 diagnostic MITIA 7-30-16.xls Chris, After being reported for IA pressurization KRU WAG injector 3G-24(PTD#190-134) passed diagnostic testing including pack off tests and an MIT-IA on 7-30-16 (see attached 10-426). The well was brought online for the 30 day monitor period, but was shut in early due to previously scheduled well work. The well was once again brought online on 8-21- 16. CPAI requests to restart the 30 day monitor period from this date with the intention of applying for an AA to continue water injection only at the end of the monitor period. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 Pager(907)659-7000 pgr. 123 WELLS TEAM ;CANNES) j 3 conourphoups -From: NSK Problem Well Supv Sent: rsday,July 28,2016 2:49 PM To:Wallace, ris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Ty - <R.T Ier.Senden • conoco•hilli•s.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: KRU 3G-24(PT. ° 90-134) IA pressurization Chris, KRU WAG injector 3G-24(PTD#190-134) is disp . • : IA pressurization while on gas injection. Operations bled the IA pressure down, but the IA has pressured back up. The • .n is to WAG the well to water injection as soon as possible for a 30 day monitor period. DHD will perform initial diagnostics'• luding an MITIA and pack off tests, and they will draw down the IA pressure to set up for the observation during the mon , period. Attached is a 90 day TIO plot and wellbore schematic. Please let us know if you have any questions or disa: -e with this plan. Regards, Rachel Kautz Well Integrity Engineer,ConocoPhillips Alaska,Inc. Temp.Slope Phone:907-659-7126 1 e • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, July 28, 2016 2:49 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: KRU 3G-24 (PTD# 190-134)IA pressurization Attachments: 3G-24.pdf; 3G-24 90-day TIO plot.JPG Chris, KRU WAG injector 3G-24 (PTD# 190-134) is displaying IA pressurization while on gas injection. Operations bled the IA pressure down, but the IA has pressured back up. The plan is to WAG the well to water injection as soon as possible for a 30 day monitor period. DHD will perform initial diagnostics including an MITIA and pack off tests, and they will draw down the IA pressure to set up for the observation during the monitor period. Attached is a 90 day TIO plot and wellbore schematic. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz Well Integrity Engineer,ConocoPhillips Alaska, Inc. Temp.Slope Phone:907-659-7126 %AHMED FEB 0 62017 1 • W L .U 5 El/ • W = z 0 0 0 o z � � Q W W y o u, W cN u a LL_ O — m ca c) 0Il W ,- i a 9 c a W m yo u, W °O (r N N a th N (O CO 0 0 W E" EN 2 N. c.-1- N Q H r-7: ti O J� v •1 J (V (V W 0 0 dOap .-1 O CO CO 0 p 0 v q• i .1a '1' lilt II, ID .-\ .. s c to ""illikZir' 0 co, \ 2 O CO CI)es E E Q U L N rs a1 0 Oc c CE C ;71j IV 2 no o j r c1 N O N 0 m ob. M N •l ~ 2 1 I 1 I m m •+ I) (p T"O 'r'> (npw I5(� • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, May 26, 2016 3:20 PM To: Wallace, Chris D (DOA) Subject: FW: 3G-24 (PTD #190-134) Unexpected increase in IA pressure Attachments: 3G-24 Monitor Period TIO plot.JPG Chris- Kuparuk injector 3G-24 (PTD#190-134) in nearing the end of its monitor period. All of the initial diagnostics consisting of MIT-IA, IA DDT and T& IC pack off tests passed. The IA has remained stable while on both water and gas injection, therefore it is CPAI's intentions to return the well back to normal injection status. Attached is an TIO plot from the water and gas injection period. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 WELLS TEAM ConocoPhillipsSCANNED ,SUN 0 1 2016 From: NSK Problem Well Supv Sent: Sunday, February 28, 2016 9:53 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R. Tyler<R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: 3G-24 (PTD#190- 34,tUnexpected increase in IA pressure Chris- Kuparuk injector 3G-24(PTD#190-134) has shown alrunexpected increase in IA pressure. The IA was bled down after the initial pressure anomaly and has continued to show an CA pressure increase. CPAI intends to WAG the well to water injection and perform initial diagnostics consisting of tubing and in'rreasing pack off tests and a MIT-IA. A series of IA �,., bleeds will be conducted prior to performing the IA DDT. If the diagnostic's pass the well will be monitored for a 30 day water injection period. At the completion of the 30 days of water injection, if the i&has remained stable, the well will be WAG'd back to gas for 30 days to investigate the potential for a successful IA DDT white on gas injection post performing the IA de-gassing bleeds. Please let me know if you have any questions or disagr` with the plan. Attached are a 90 Day TIO plot and a wellbore schematic. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907)943-0450 WELLS TEAM ConocoPhillips 1 , ..,.. • dwalialpilo • D (D c) cp 0 LCD 0 C CV . 1 . 1 . 1 , i il .1 .1 ii 11 il .1 ,t a A 1 .I i 1 I -„,!! • • i, : - • (0 • • • , lk ' _. ;,... . • ,--- . CZ -- ì . • ----- or- ( 6 ,. . . • • . . . • • . k _ • co . . . - 'T- - 1) • . --,--- . -, _. --,_ —,_. • —_, - . : —.— CU ourz:. . • . ' . • . • CD . . • A • • . __ • . _ . , . _ - : ,..0 , _____ , : - •,_ , . . _ t i I J - . •____-- < - •(: - cs . . (N ce) ' - • ) - . . • . -. . • - (1) 4-• -. 4-do :------7—=', ..__' — — • /- 0 - . -_, --..... - , a —,-- : •0 - ,...-- • . ;; — ci.. : c < 0 :-•:. c : . ( • • - ; , _ r.L_ rz, t— - • ;- - ; .• . ; ;. - ; • . -- • . • .: — _ 'ffil 2 .: . — L.f5 _ . . • : . ..'---- • • 0.1 . • . , • . . • . • (.0. . — 1-- • . 0_ cl_ -• k . l, • • • .---- . - I < - / ' • . [ — c,I W - : . , . _ - . '---_ • 1---___ • 1 L.L.1 , I . 1 , 1 , ii 1, 1, I. I. 1, i: I, II il II ll ? I I sS CD Y a_ 0 (NI 0 Li_ 0 0 0 0 CO 04 1- ISd • S Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, February 28, 2016 9:53 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: 3G-24 (PTD #190-134) Unexpected increase in IA pressure Attachments: 3G-24.pdf; 3G-24 90 Day TIO plot 28 Feb 16.JPG Chris- Kuparuk injector 3G-24 (PTD#190-134) has shown an unexpected increase in IA pressure. The IA was bled down after the initial pressure anomaly and has continued to show an IA pressure increase. CPAI intends to WAG the well to water injection and perform initial diagnostics consisting of tubing and inner casing pack off tests and a MIT-IA. A series of IA bleeds will be conducted prior to performing the IA DDT. If the diagnostics pass the well will be monitored for a 30 day water injection period. At the completion of the 30 days of water injection, if the IA has remained stable,the well will be WAG'd back to gas for 30 days to investigate the potential for a successful IA DDT while on gas injection post performing the IA de-gassing bleeds. Please let me know if you have any questions or disagree with the plan. Attached are a 90 Day TIO plot and a wellbore schematic. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 WELLS TEAM Cups MAR 1 72316 W U d • e VI 0 U C co a 0 w c, w W Ce L d ,- 13 6 6l '= a, W E IA ._ LU ,l-) Ce LT) a .- r: I- m 4^ N N F N c 1 't J N J w C ,, A6ap IN CJ CJ . U . tl. CC) (5) V VA U 54, ZO Al 7.2 f:-.' 10 W013 .t..."' -,, V ' C • 7 C O w « ea c Cij W m C] C E E • OU • 1..\--" .... ec B 7 o C i C a __cam...• ltl in a n, u n ca u-) co 1- .1. Q O O • (.5 b ?) co '2 ii I 3 MM N II 1 N a. aI-- 3or ' I U, Yl E 4: y . o 0 0 {q �" CJ rJ CJ U U U CJ CJ CJ C}„ - Lig i `• Z O LI 1 o " o ;J, CD u CD u) t+ y -, •, r, o, CA 4v Od 18�0lJIII m tv03 ? Isd cnCDw • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,August 21,2015 TO: Jim Regg cq P.I.Supervisor Ref.P I /I S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-24 FROM: John Crisp KUPARUK RIV UNIT 3G-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-24 API Well Number 50-103-20145-00-00 Inspector Name: John Crisp Permit Number: 190-134-0 Inspection Date: 8/15/2015 Insp Num: mitJCr150821101946 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r 3G 24 - Type Inj W'TVD 5716 - 1Tubing 2705 • 2705 2703 2705 . T PTD 1901340 Type Test SPT Test psi 1500 4 IA 910 2000 1915 . 1905 • Interval4YRTST - P/F P OA ; 370 440 440 . -- ------ - � 440 - , Notes: 2.1 bbls pumped for test. SCANNED Friday,August 21,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I q~) ''1''~ ~-~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED .~' Logs'of various kinds. n Other COMMENTS: · Scanned by: ianna Vincent Nathan Lowell __ [] TO RE-SCAN Notes:. Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07, 2011 TO: Jim Regg f P.I. Supervisor '\ ee 1 (C.( ( 1( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -24 FROM: Jeff Jones KUPARUK RIV UNIT 3G -24 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G - 24 API Well Number: 50 103 - 20145 - 00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110906084810 Permit Number: 190 -134 -0 Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well , 3G -24 • 'Type Inj. 1 w I TVD 5716 IA r 640 — 3075 - 3040 3010 1 3010 40 1 9013 - - -- SPT 1500 - - � — - -- 200 280 _ - -- 280 280 P.T.D TYpeTest Test psi OA 280 Interval 4YRTST p/F P • Tubing 2456 J 2454 2455 2455 , 2456 Notes: 6 BBLS diesel pumped. 1 well inspected; no exceptions noted. . - ;J f It . • Wednesday, September 07, 2011 Page 1 of 1 • ~~ . . ConocoPh~llips Alaska P.O. BOX 100360 ANCHORA6E, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • SEP a 2 2aos ~6~~~~ ~~I ~ ~~s ~Ana..~o 'ssion AnGho-+ ( I ~f ~~~ ~~~~~~ ' . .. ] A 4~r~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~' and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~ ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ~ r~ ~: ;'p ~ `,~ !@ ~~ 2.~' '-,r.:~~ -" ~~~~~ ~~~~ ,~ ~~ ~~rl~ ConocoPhillips Alaska Inc. °" ~~e~ ~ ~'~~~^ef~ ~~~~ ~~ ~~Rry ,~;~e. fTn~~r~9~~cat:~~~ ~`r.~d°..4:N~F9'f~¢.:PS'„TF Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field e{I Name Pl # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor , , Corrosion inhibitorl sealant date bbls ft - a~ ---. 1J-03 50029230020000 2010240 22" N/A 22" N/A 4.1 $/29/2009 1J-09 50029230060000 2010440 28" N/A 28" N/A 6.2 8/29/2009 1J-10 50029230100000 2010710 12" N/A 12" N/A 2.3 8/29/2009 1J-133 50029233150000 2061060 3' N/A 3' N/A 23.8 8/30/2009 3~-24 50103201450000 1901340 18" WA 18" N/A 5.1 8/30/2009 1A-19 50029221110000 1901610 30" N/A 30" N/A 3.8 8/30/2009 2Z-04 50029209650000 1830860 19" ~ N/A 19" N/A 3.5 8/30/2009 2Z-05 50029209560000 1830760 12" N/A 12" N/A 2.1 8/30/2009 2Z-07 50029209460000 1830640 9" N/A 9" N/A 8.5 8/30/2009 2Z-15 50029213620000 1851080 9" N/A 9" N/A 2.8 2Z-21 50029218770000 1881250 3' N/A 3' N/A 19.6 8/30/2009 1J 3G 7A 8~ 22PAD MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 0. tßl I P.I. Supervisor I f\ê1? ' ~ 0 7 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPIDLLIPS ALASKA INC 3G-24 KUPARUK RIV UNIT 3G-24 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3G-24 API Well Number: 50-103-20145-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820173622 Permit Number: 190-134-0 Inspection Date: 8/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 3G-24 Type Inj. N TVD 5716 IA 400 2430 2370 2370 P.T. I ."UI.>4U TypeTest :>1'1 Test psi 1500 OA 0 0 0 0 Interval 4YRTST 1/F P ./ Tubing 3100 3100 3100 3100 Notes: Pretest pressures observed for 30+ minutes and found stable. / SCANNED SEP 1 0 2007 Wednesday, August 22, 2007 Page I of I . . /:f£ RECEIVED 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D Other [2] WINJ to WAG Alter Casing D Pull Tubing D Perforate New Pool D Waiver 0 Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 190-1341 . 3. Address: Stratigraphic 0 Service [2] 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20145-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' "' 3G-24 ,.,. 8. Property Designation: 10. Field/Pool(s): ADL 25547 ALK 2661 Kuparuk River Fiéld 1 Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 9940' ( feet true vertical 6081'< feet Plugs (measured) Effective Depth measured 9679 feet Junk (measured) true vertical 5883' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 4482' 9-518" 4572' 3102' PROD. CASING 9840' 7" 9930' 6074' Perforation depth: Measured depth: 9618 - 9658' 5CANNED JUL ,~ 5 2007 true vertical depth: 5839 - 5868' Tubing (size, grade, and measured depth) 2-7/8", J-55, 9527' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 9444' SSSV= SSSV SSSV= 1785' 12. Stimulation or cement squeeze summary: RBDMS BFL JUL 0 3 2007 Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 568 1400 2309 Subsequent to operation 1000 800 3738 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service [2] Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG [2] GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Bob Christensen I Bob Buchholz Printed Name Robert W. Buchholz ¿ Z Title Production Engineering Tec;Ãan Signature ~1~>r2" ~~~ Phone 659-7535 Date t5 (t If) þ ORrGtNAL Å~(~ .~?~;? - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUN 1 9 2007 ,~.laska Oil & Gas Cons. Commissi Anchorage Form 10404 RevIsed 04/2004 SubmIt Onglnal Only . . 3G-24 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/10/07Commenced WAG EOR Injection Service 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 ias r.nn. 1'. 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 O_oraø~ ·.....Ion Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 190-134/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 99510 50-103-20145-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 3G-24 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9940' feet true vertical 6081' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 4482' 9-5/8" 4572' 3102' PROD. CASING 9840' 7" 9930' 6074' Perforation depth: Measured depth: 9618-9658 'lei> ~~~~El' I 7 1'1 ., Ii? 'ínfì6 ,,?," <"/1,;. ! i;; .); "" H ~ .!L c L, '" u!;J true vertical depth: 5839-5868 Tubing (size, grade, and measured depth) 2-7/8", J-55, 9527' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 9444' SSSV= SSSV SSSV= 1785' 12. Stimulation or cement squeeze summary: Intervals treated (measured) RBDMS 8Ft .iAN1 j 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 305-372 Contact McConnell / Loveland Printed Name Marie McConnell ~ Title Problem Well Supervisor Signature ~--'/~¿t'~~~ Phone 659-7224 Date 1/3/2006 / e e RECEIVED STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION JAN 1 3 2006 REPORT OF SUNDRY WELL OPERA TI8Nso;, & G , Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only , e 3G-24 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 12/28/200sISet permanent tbg patch from 9336' to 9358' 1/3/2006 MITIA to 2510 psi passed as witnessed by AOGCC Inspector Jeff Jones. Pre-MITIA pressures T/I/O=1540/1540/0. Pressured up IA with .3 bbl of diesel. Start MITIA T/I/O=1540/251 0/0. 15 min T/I/O=1540/2460/0, 30 min T/I/O=1540/2440/0, for a total loss of 70 psi during test. Bled IA down. Final T/I/O=1540/1550/0. MEMO.RANDUM TO: Jim Regg. ~~tf. )/4/0(' P.I. Supervisor Z 1. (' FROM: Jeff Jones Petrolcum Inspector Well Name: KUPARUK RIV UNIT 30-24 [nsp Num: mjtJJ060104085455 Rei Insp Num Packer Type Inj. N TVD ".".' ."_.._.,~,'~ - ,~. ~ ..,...... .. TypeTest SPT Test Well 3G-24 -""'-'.'-'-".._-'-',""~-''" ,. "- "-_.",.. ...,-.... P.T. 1901340 Jº-t.~IYªJ~~3Y..~._..... P IF p Notes Post tubing patch repair, sundry #305-372. 1 well house inspected; no exceptions noted. .....,,, ,~---,-"' ".,,---_.,.._--_.._~_.- Wednesday, January 04, 2006 ') State of Alaska Alasl<a Oil and Gas Conscrvation Commission DATE: Wednesday, January 04, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-24 KUPARUK RIV UNIT 3G-24 Src: Inspector NON-CONFIDENTIAL API Well Number 50-103-20145-00-00 Permit Number: 190-134-0 \~o·-- \3L( Reviewed By: P.I. Suprv SP-ß- Comm Inspector Name: Jeff Jones Inspection Date: 1/3/2006 Pretest Initial 15 Min. 30 Min. 45 Min. 60.Min. 2440 5716 IA 1540 2510 2460 . ..-,-.....---...---...---..-" .'"-"'--".-"-".--'". --.-..,,-,.'''...-...--.....-----.--. ----'"'_..,'~"..... _..~--- ..~--_...- "- ..~._.,-.~.. ,. 1429 OA 0 0 0 . .,,- .-.",.."'.,.-.".....- "..."..-".-..,,-. ....,...--.,-..-....-."-,,-.-.-.--..... o Tubing 1540 1540 -1..............._._.............._.. 1540 1540 _._.. ~_"_...~..~.._..~____"..,'"'_,_."_.._..."'..,,.~ ..,.ø.._.._.",."'_,__,,'_ SCANNED! ,JAN 11 20D5 Page I of I SSSV (1785-1786, 00:3.500) Gas Lift ~ndrellDum my Valve 1 (2984-2985, 00:5.313) Gas Lift ~ndrellDum my Valve 2 (5497-5498, 00:5.313) Gas Lift ~ndrellOum my Valve 3 (6847-6848, 00:5.313) Ga s Lift mdrellOum my Valve 4 (7804-7805, 00:5.313) Gas Lift mdrellDummy Valve 6 (9371-9372, 006.000) PBR (9426-9427, 00:2.875) PKR (9444-9445, 00:6.151) Production ~ndrellOummy Valve 7 (9468-9469. 00:5.460) PLUG (9515-9516, 00:2.250) ) ') KRU 3G-24 CònQcoPhUUp$·Ala$I<~J In~~ ! 3G·24 " ~ .. ... ¡>till: . biillM TUBING (9420-9527. 00:2.875, -- 10:2.441) ~ __ (9527.9~~; -----f-.=.:- 002875) Perf - (9618·9658) - - J:;:::::::::::?':::;:~'" 1M ¡ir'l 'Í;~ ]"";;.:..,',~,,.I .:.:.:.:.:-:.;., ~ 1::: ::: . ~"~ ~ I Gas Lift MandrelsNalves ~ St MD TVD Man Mfr Man Type V Mfr I~.:..:. . .~...l_ ~ ~~~ ;~~~ ~~~~~~~: ~~~g ~ \':: . I) ~~J~ J':~~ 11,:I1'Jrr~J 1=r.1H':.. ~ ::::.' 1···\ J -'?(IJ J-::<1 n,:I.1'J"", Frll-i') ~ ¡ ~ ~'~1~, ::.:-~rl.:r,lrJrr"j FI1H'~' J ~ I: ;")"'1 ~.~..:~ r'~I:(I) :¡:,r,,:,: ~ I ~ Production MandrelsNalves Gas Lift - --~~ :':.:: 1~..: St MD TVD Man Mrr Man Type V Mfr mdrellOum m y ~ ~ ::' :: . Valve 5 ~ ;:::'" .... 7 9468 5733 Cameo TGPD (8715-8716, ~ ..... ., 00:5.313) ~ ¡Other (plugs, equip., etc.) - JEWELRY . I Depth TVD Type ~ \ 1785 1631 SSSV Otis 'FMX' ~ ¡ 9426 5704 PBR Cameo 'OEJ' --- ~ J\:.'~. ~ 9444 5716 PKR Cameo 'HRP-1-SP' ~ ~ 9515 5765 NIP Cameo 'D' Nipple ~ '.:::.':' I '~r 9515 5765 PLUG 2.25" CA-2 PLUG set 9/22/2005 , 9527 5774 TTL ~ 9527 5774 SOS Cameo , General Notes ~ Date I Note i I 10/9/2005 TBG LEAK @ 9347 (TeeWel LDL) i ~ ~ ~ ~j ì ..... I" î]¡;;.: .. API: 501032014500 SSSV Type: TRDP Annular Fluid: Well Type: INJ Orig Completion: 10/12/1990 Last W/O: Angle @ TS: 44 deg @ 9608 Angle @ TO; 41 deg @ 9940 Rev Reason: TAG FILL, PULL SLV, Set Plug, TBG Leak Last Update: 10/30/2005 Reference Log: Last Tag: 9679 Last Tag Date: 9/20/2005 I Casing String - CONDUCTOR Description I Size CONDUCTOR 16.000 Casing String - SURFACE Description I Size SUR. CASING 9.625 Casing Stril1g - PRODUCTION : Description I Size I PROD. CASING 7.000 ¡Tubing String - TUBING Size Top Bottom 3.500 0 9420 2.875 9420 9527 Perforations Summary. Interval TVD 9618 - 9658 5839 - 5868 Ref Log Date: TD: 9940 ftKB Max Hole Angle: 62 deg @ 3900 Top Bottom TVD Wt Grade Thread 0 115 115 62.58 H-40 Top Bottom TVD Wt Grade Thread 0 4572 3102 36.00 J-55 Top Bottom TVD Wt Grade I Thread 0 9930 6074 26.00 J-55 TVD Wt Grade Thread 5700 9.30 J-55 EUE 8RD AB MOD 5774 6.50 J-55 EUE 8RD Status Ft SPF Date Type Com ment 40 4 1/8/1991 4112" 180 deg. phasing JRC Zone A-2,A-1 V Type Latch Vlv Cmnt Port TRO o Date Run 9/19/1996 n T;;? 1 1 ~ 1~" 1 ~ 1 ~ 1:'~ 1 ~ 1 ~.~ 1 VOD DMY I:.r, 1".' e,r.l. c,r.l, e,l I, i:.r , BK 0.000 I:: J: Î} 00(ì I~ ¡. (I (11)(1 ~---=.7~1 (11)(1 t,,- (I ('(11"' (". (I I:' (I 1,0 1 .-:-' 1 (I 1 I) 1 (I 1 ': t=~ . ~ _~~I__--::'~=,;"~ __ V Type VOD latch - Port TRO-oãïe- \ïïV Run Cmnt 1/9/1991 DMY 1.5 RK 0.000 o Description ID 2,813 2.312 2.347 2.250 0.000 2.441 2.441 --.----,.-..--..-.-----.-.-.----- e e ~.,~' 11.' :..ifi:'.. ~ \.' I~;.. rF·..· ü:l/!JñjH. ,. ' ""'" P). H \ W U '. L.:::::J P.'. 0·... '.. IU·... r.' . ~' d UlJ ' @ in . ¡ß\ I ¡ J..J ì n \ II ! u lJ~'. FRANK H. MURKOWSKI, GOVERNOR AIfASJiA OIL AND GAS CONSERVATION COMMISSION Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 \~~.- , .,'.:i7ï \q&., ::)ç^~NED DEC 1 620œ Re: KRU 3G-24 Sundry Number: 305-372 Dear Ms. McConnell: 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 holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, "'2;"" DATED thisL day of December, 2005 Encl. Or) Izj ?/S C¡I} í2-/'. ¡~ RECEIVED STATE OF ALASKA jlf l){ ALASKA OILAND GAS CONSERVATION COMMISSION f.f' DEC 0 6 Z005 APPLICATION FOR SUNDRY APPRO V A~laska Oil & Gas Cons. Commission 20 AAC 25 280 e 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Dri7ber: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 190-134 . 3, Address: Stratigraphic 0 Service 0 6. API Number: / P. O. Box 100360, Anchorage, Alaska 99510 50-103-20145-00 7. KB Elevation (ft): 9, Well Name and Number: RKB 90' 3G-24 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field 1 Kuparuk 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): 9940' 6081' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115 SUR. CASING 4482' 9-5/8" 4572' 3102 PROD. CASING 9840' 7" 9930' 6074 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9618-9658 5839-5868 2-7/8" J-55 9527' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= CAMCO 'HRP-1-SP' pkr= 9444' SSSV= SSSV SSSV= 1785' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory D Development D Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/06/05 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL 0 Commission Representative: 17. I hereby that the foregoing is true and correct to the best my knowledge, Contact: McConnell 1 Loveland Printed Name ~McConnell ~ Title: Problem Well Supervisor ~//~. ,./ ~/æ Date 12/02/05 Signature z: ;¡r..ø' Phone 659-7224 // ",. Commission Use Only SU3;0mber~~7 Conditions of approval: Notify Commission so that a representative may witness \. -l;:J Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Othe' ro \> ~':z;.~' dc)~"'C. a-S- · ~ "1 S"'eq,e" ?Iii;' ,~ L\ RBDMS BFl DEC 0 7 Z005 App~ed by;;~ V/tt APPROVED BY ,/ COMMISSIONER THE COMMISSION Date: I~- t ... () S V V'-.../' - Form 10-403 Revised 7/2005 ORIGINAL Submit in Duplicate e e ConocoPhillips Alaska, Inc. Kuparuk We1l3G-24 (PTD 190-134) SUNDRY NOTICE 10-403 TUBING REPAIR 12/02/05 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk We1l3G-24 with a tubing patch. On Sept 15, 2005, the AOGCC was notified of a failed MITIA. Subsequent diagnostics identified a very small tbg to IA leak. A Tecwel sonic LDL located the leak in the tbg at 9346'. The plan is to patch the tubing with a 20' retrievable patch centered over the leak. Following a successful MITIA, the well will be returned to normal water injection. REPAffiPLAN 1. Set a 20' long, 3.5" retrievable patch trom 9336' - 9356' centered over the leak at 9346'. 2. MITIA as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post repair. NSK Problem Well Supervisor e e CønøcoPhilUpsAJaska, Inc. KRU 3G-24 ~\:I-"" .'.......... ........ API: 501032014500 Well Tvpe: INJ Angle @ TS: 44 deQ @ 9608 ~ L..J. SSSV Tvpe: TRDP OriQ Completion: 10/12/1990 Angle @ TD: 41 deg @ 9940 1 Annular Fluid: LastW/O: Rev Reason: TAG FILL, PULL SLV, ~C::-C::-'.' Set Plug, TBG Leak (171 , T.:.:....:.~..I =\p."'erencë I qr I""fl <:;¡ Cate: Last Update: 10/30/2005 01' "" Ii :..~~::;~ I ü9 957;:) rD: 9940 ftKB ! LaC¡t T~;; :hm:- : H/20120C:~ \"':.~x r"I:::,,:,,: f,r:~]=e: 62 deg @ 3900 i: : Casing String - CONDUCTOR 10: , Description Size Top I Bottom I TVD Wt I Grade I Thread I :' , ¡.¡ t), CONDUCTO¡¡ ~6 (.\00 (, I 115 I 115 62,58 I H-40 I mdrel. ~ I Casing String - SURFACE ............... (291' , I Description Size Top Bottom TVD Wt I Grade Thread 01' t su" cr-::; ,I\(i 9.625 .. 4572 3102 36,00 I J-55 ~Casing String - PRODUCTION ,. " .".',. ! Description Size Top 'Bottom TVD Wt Grade Thread ',]' I ---.EB..QD, CASIN<L-_, I 7,000 _ I o ~O I 6074 26,00 J-55 mdrel; Tubing String - TUBING ~ .'... ',........... ....... I (54¡ , '. ' . l I Size I Top I Bottom I TVD Wt I Grade Thread 01' 3,500 0 9420 5700 9,30 I J-55 EUE 8RD AB MOD I 2,875 I 9420 I 9527 I 5774 6,50 I J-55 EUE 8RD Perforations Summary .. ,. ] Interval TVD Zone Status Ft SPF Date TYDe Comment mdrel. 9618 - 9658 5839 - 5868 I A-2,A-1 I I 40 I 4 I 1/8/1991 41/2" 180 deg, phasing JRC (68t " : I Gas Lift MandrelslValves .' ........'.... 01 St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vly Run Cmnt ,. 1 2984 2305 MeMurrav FMHO DMY 1,0 BK 0,000 0 9/19/1996 mdrel. ' ]( ~ 2 5497 3586 MeMurrav FMHO DMY 1,0 BK 0,000 0 1/9/1991 3 6847 4282 MeMurrav FMHO DMY 1,0 BK 0,000 0 1/9/1991 (78C.' I 4 7804 4781 MeMurrav FMHO DMY 1,0 BK 0,000 0 9/19/1996 01' 5 8715 5279 McMurray FMHO DMY 1,0 BK 0,000 0 1/9/1991 6 9371 5668 MACCO SPM-2 DMY 1,5 RK 0,000 0 9/19/1996 Pròdüction MahdrelslValves : ., St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv andrei, ]'; 1 Run Cmnt 7 I 9468 I 5733 Cameo TGPD DMY 1,5 I RK I 0,000 0 I 1/9/1991 I (87' Other DluQS eaÜÎD., .Eltc,}-JEWELRY 01' DeDth TVD TYDe DescriDtion ID 1785 1631 SSSV Otis 'FMX' 2,813 " ~ 9426 5704 PBR Cameo 'OEJ' 2,312 tI~: 9444 5716 PKR Cameo 'HRP-1-SP' 2,347 mdrel, ," :< 9515 5765 NIP Cameo 'D' Nipple 2,250 (93/ . . 9515 5765 PLUG 2,25" CA-2 PLUG set 9/22/2005 0,000 01' 9527 5774 TTL 2,441 9527 5774 SOS Cameo 2,441 1\:10"":" I I Date I Note (94, I 10/9/2005 TBG LEAK (cj) 9347 TeeWel LDL 01' " I~-~ (94' ' .. 01' I] i prc' IIiI mdrell (94E '~ O¡ (951 I I O[ . , .. (94, t 01' I[ .. ~ (952,·..,J...."'u, ! OD:2,875) Perf - - (9618-9658) - - - - - - e e Name of Recipient Page 1 of 1 12/04/05 December 3,2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the following Sundries for ConocoPhillips Alaska, Inc: , 30-19 (PTD 197-050) 10-403 Sundry Application to pull and reset the liner patch. ~ 3G-24 (PTD 190-134) 10-403 Sundry Application to patch the tbg leak. 4- lL-23 (PTD 191-062) 10-404 Sundry Report oftbg leak patch repair work. lQ-04 (PTD 184-234) 10-404 Sundry Report of attempted tbg leak repair work. Please call me or MJ Loveland at 659-7224 if you have any questions. SI·n~erel., c __0" ~ lY, ;#~#~/~ Marie McConnell Problem Well Supervisor Attachments RE: 1A-09 (PTD 1811520) cause offailed MW identified by ne... e Sub.iect: RE: lA-09 (PTD 1811520) cause of failed MITIA identified by new LDL tool From: NSK Problem Wcll Supv <11 1617@conocophillips.com> Date: Mon, 17 Oct 2005 09:21 :53 -0800 To: NSK Problcm Wel1 Supv <n1617@conocophillips.com>, Thomas Maunder <tom _.maunder@admin.state.ak.us> CC: James Rcgg <jim_rcgg@admin.statc.ak.us> Tom, The other wells are: 3G-24 - tbg leak found between bottom GLMs at 9346' A ,,~o - \ ~ '-\ 3F-13A - Tbg leak to OA found in the packer at 5678' /" 30-19 - casing leak found in the liner at 5512' All these will have sundries for repair that will report the leak depths once a repair plan is decided. Marie -----Original Message----- From: NSK Problem Well Supv Sent: Monday, October 17, 2005 9:14 AM To: 'Thomas Maunder' Cc: 'James Regg' . Subject: RE: lA-09 (PTD 1811520) cause of failed MITIA identified by new LDL tool .-f ., Tom, The work load here is such that if a report isn't required there isn't time or resources to create it or it would take time away from monitor the wells for integrity and catching any compliance issues to avoid NOVs, our highest priority. The email was something I sent you as a courtesy as I thought you'd be interested from both a well and engineering prospective. This work will be reported on the summary list of completed wellwork submitted to AOGCC as required. If a repair is made on this well, the sundry will mention the leak depth. Yes, our internal guidelines have changed, internal waivers are no longer issued for failed MITIAs if the well also had a failed MITOA. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, October 17, 2005 8:01 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: lA-09 (PTD 1811520) cause of failed MmA identified by new LDL tool Marie, Good news on the new diagnostic tool. Is it possible to submit a "report" of the work on IA-09? You could submit it with a 404. What are the other wells that you indicate were successfully logged? You state that IA-09 no longer meets CP AI internal requirements. Have the internal requirements changed? Look forward to your reply. 10f2 3/6/200610:18 AM RE: IA-09 (PTD 1811520) cause of failed MIl identified by ne... e Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 10/16/20054:18 PM: Tom, This note is to inform you of recent diagnostic results on 1A-09 (PTD 1811520). This well has a failed MITIA (Sundry approval 303-307) that was assumed to be a packer or casing leak as an MITT wlTTP passes. The leak rate was too slow to identify the depth with known logging tools. A new ultrasonic leak detect logging tool (tecwel) was ran in the well on 10/8/05 and identified the leak depth at 2574'. I reviewed the 303-307 sundry for the failed MITIA and didn't see any issues. CPAI has determined this well no longer meets our internal requirements and the well has been 51. The leak is in close proximity to the OA cmt shoe and the OA shoe leaks. At this time, it is uncertain when or how the well will be repaired, but the appropriate sundry will be submitted at that time. Tecwel can measure leak rates down to something around a quart or cup per minute. Three other wells with small leaks were logged successfully. Marie McConnell Problem Well Supervisor 659-7224 20f2 3/6/200610:18 AM 3G-24 (PTD 190-134) Report of Failed MITIA e e Sub.iect: 3Cì-24 (PTD 190-134) Report of Failcd MlTlA From: ~SK Problem Well Sup\' <n 1617@:;coT1ocophillips.com> Date: Thu, 15 Scp 2005 22 :33: 15 -0800 To: Thomas Maunder <tom_maunder@admin.statc.ak.us>, James Rcgg <:jim. rcgg~iiadmin.state.ak.us:>, Robert Fleckenstcin <bob__ncckcnstein@admin.statc.ak.us> Tom & Jim, 3G-24 water injector failed a diagnostic MITIA today per the attached report. The well was shut in and added to the monthly failed MIT report. A plug will be set in the tbg and diagnostics will be performed to evaluate if the TxlA communication is due to a tbg or packer leak. A 10-403 or administrative relief will be submitted as appropriate depending on results of diagnostic work. The diagnostic MITIA was performed as the IA could no longer be maintained below 2000 psi. The IA was found at 2200 and bled to 1730 psi on 9/14/05. The IA was found at 3000 psi this morning, bled down to 1700 psi, then climbed to 2000 psi in 3 hours. Prior to 9/14/05, the well did not have any sign of TxlA communication. The last MITIA passed on 8/4/2003. A 90 day plot of wellhead pressure is attached. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 3G-24 9-15-05.xls» «3G-24.pdf» «3G-24 90 day WHP trend 9-15-05.jpg» Content-Description: MIT KRU 3G-24 9-15-05.xls MIT KRU 3G-24 9-15-05.xls Content-Type: appIication/vnd.ms-excel "Content-Encoding: base64 Content-Description: 3G-24.pdf Content-Type: application/octet-stream Content-Encoding: base64 3G-24 90 day WHP trend 9-15-05.jpg Content-Type: Content-Encoding: .. 3G-24 90 day WHP trend Content-DescnptIOn: 9 15 05 . . - - .Jpg image/jpeg base64 1 of 1 12/6/2005 1:57 PM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRU 13G 09/15/05 Rodgers 1 Sauvageau - AES Packer Depth Pretest Initial 15 Min. 30 Min. We1l13G-24 I Type Inj. I W TVD I 5,716' Tubing 2450 2450 2450 I ntervall 0 p.T.D.11901340 I Type test I P Test psi 1500 Casing 2980 3500 3200 P/FI F Notes: Diagnostic MITIA due to suspected TxlA comm OA 280 280 280 We1l13G-24 I Type Inj. I W TVD I 5,716' Tubing 2450 2450 2450 I ntervall 0 P.T.D.11901340 I Type test I P Test psil 1500 CasinQ 3200 3500 3200 P/FI F Notes: Bumped up to restart test OA 280 280 280 We1l13G-24 I Type Ini. I W TVD I 5,716' TubinQ 2450 2450 2450 2450 I ntervall 0 P.T.D.11901340 I Type test I P Test psi I 1500 Casing 3200 3500 3200 3020 P/FI F Notes: Bumped up to restart test. Well SI due to failure OA 280 280 280 280 Weill I Type Ini.' TVD I Tubing I ntervall p.T.D.1 I Type test I Test psil Casing P/FI Notes: OA Well' I Type Ini.1 TVD I Tubing I ntervall P.T.D.I I Type test Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential T em perature Test INTERVAL Codes I = Initial Test 4= Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 3G-24 9-15-05.xls 3G-24 90 day WHP trend 9-15-05 jpg (JPEG 1 e, 1132x718 pixels) mailbox:///FlemaiUdefaultlMaiUancmaill.state.ak.us/NSKprbmwell... 1 of 1 12/6/2005 1 :56 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. ~//~ FIELD / UNIT / PAD: Kuparuk/KRU/3G DATE: 08/04/03 OPERATOR REP: Arend/Brake - APC AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Welll3G-10 I Type,njl Sp [ T.V.D. 15789 I Tubing I 20001 20001 20001 2000[Interval P.T.D. I1900840 Type Test Test psi] 1500 ] Casing ] 13501 24601 2420] 2420] P/F Notes: 2 Yr MIT required by internal Waiver Well13G-12 I Type Inj P.T.D. I1900730 Type Test Notes: T.V.D. I~e~e I TubingI 23501 23501 23501 235011nterva~ Test psiI 1500 I CasingI 12501 23501 23001 22801 P/F P.T.D. I1901160 Type Test Test psiI 1500 I Casing I 11401 24°°1 238°1 238°1 P/F Notes: P.T.D.]1901210 Type Test Test psiI 1500 I Casing I 1240l 24501 24251 24251 P/F Notes: A header pressure anonomile occurred right before the start of the test WelII3G-16 Type lnj I G I T.V.D. I 5764 I Tubing I 31001 31001 31001 31001 Interval P.T.D.]1901040 Type Testl P I TestpsiI 1500 I Casing I 13001 2400l 24001 2400l P/F Notes: Well J3G.24 P.T.D. 11901340 Notes: TypeTest Test psi] 1500 ] Casing I 12°°l 21°°1 21°°1 21oo1 Test Details: TYPE INJ codes F: Fresh Water Inj G: Gas Inj S = Salt Water Inj N - Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 ~OANNED SEP ~ ~ 2083 MIT KRU 3G 08-04-03.xls 8/5/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Randy Ruedrich Commissioner ,., Jim Regg P.I. Supervisor DATE: August 4, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3G Pad KRU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: 3G-10 I 190-084 Packer Depth Pretest Initial 15 Min. 30 Min. Type,nj.I s I T.V.D. 15789 I Tubingl~000 I~000 I~000 I~000 I,nterva, I 4 TypetestI P ITestpsil 1447 ICasingI 1350I 2460I 2420I 2420I P/F I P 190-073ITypetestl P ITestpsil 1422 I Casingl 1250I 2350I 2300I 2280I P/F I P 190-116ITypetestl P ITestpsil 1445 I CasingI 1140I 2400I 2380I 2380I P/F I P WellI 3G-15 , P.T.D.I 190-121 Notes: WellI 3G-16 P.T.D.I 190-104 Notes: P.T.D. I 190-134 Notes: I Type testI P I Testpsil 1432 ICasingI 1240I 2450I 2425I 2425I P/F I P I Typelnj. I e I T.~.~. I 5764 I Tubing I 3100 I 3100 I 3100 I 3100 I,nterva, I 4 I TypetestI P ITestpsil 1441 I Casingl 1300 I 2400 I 2400 I 2400I P/FI P I s I T.V.b.I ~ ITubing I2350 I2350 I235° I2350 I lntervall 4 I Type testI P I Testpsil 1429 I CasingI 1200I 2100I 2100I 21ooI P/F I P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3G Pad in the Kupamk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures' 0 Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 2003-0804 MIT KRU 3G-24 cs.xls 8/15/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging_ Pull tubing __ Alter casing __ Repair well __ Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2538' FNL, 270' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1300' FNL, 1940' FWL, Sec. 14, T12N, R8E, UM At effective depth 1270' FSL, 1870' FWL, Sec. 14, T12N, R8E, UM At total depth 1016' FNL, 1806' FWL, Sec. 14, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Length 80' 4537' X Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9940' 6129' 9618' 5839' Size 1 6" 9 5/8" 6. Datum elevation (DF or KB) RKB 90 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-24 feet 9896' 7" feet feet feet feet 9. Permit number/Approval number 90- 1 34/96- 1 55 10. APl number 50-103-20145 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Junk (measured) None Cemented Measured depth True vertical depth 175 Sx AS I 1 15' 1 15' 970 Sx AS III & 4572' 31 02' 600 Sx Class G 274 Sx Class G & 9931 ' 607 4' 154 Sx Class G RECEIVED measured 9618'-9658' true vertical 5839'-5868' Tubing (size, grade, and measured depth) 2-7/8" L-80 , 6.5#,1PC, EUE ABMOD, W/Tail @ 9527' Packers and SSSV (type and measured depth) Camco HRP-I-SP Pkr. @ 9444', Otis FMX SSSV @ 1785' 13. Stimulation or cement squeeze summary ,,~ Converted oil producer to water injector.. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation 15. Attachments Wellbore schematic Copies of Logs and Surveys run__ Daily Report of Well Operations __ Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 250 48 226 1000 0 0 2727 1 0 0 0 16. Status of well classification as: Tubing Pressure 160 1085 Oil Gas __ Suspended Service H20 Injector 17. Form 1~-~4 / I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator Suspend~ Operation Shutdown Re-enter suspended well__ Alter casing __ Repair well__ Plugging ~ Time extension Stimulate Change approved program __X Pull tubing ~ Variance_ Perforate __ Other ~ 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ IExploratory __ S e rvSit~eatig rap hic.._- ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 270' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1300' FNL, 1940' FWL, Sec. 14, T12N, R8E, UM At effective depth 1270' FSL, 1870' FWL, Sec. 14, T12N, R8E, UM At total depth 1016' FNL, 1806' FWL, Sec. 14, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9940' feet Plugs (measured) 61 2 9' feet None measured 961 8' true vertical 5 8 3 9' Length Size 80' 16" 4537' 9 5/8" 9896' 7" measured 9618'-9658' feet Junk (measured) feet None Cemented RKB 90 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-24 9. Permit number 90-134 10. APl number 5o-1 03-201 45 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical:'de'l~{l~',': 175 Sx AS I 1 15' 1 15' 970 Sx AS III & 4572' 3102' 600 Sx Class G 274 Sx Class G & 9 9 31 ' 6 0 7 4' 154 Sx Class G true vertical 5839'-5868' Tubing (size, grade, and measured depth) 2-7/8" L-80 , 6.5#,1PC, EUE ABMOD, W/Tail @ 9527' Packers and SSSV (type and measured depth) Camco HRP-1-SP Pkr. @ 9444', Otis FMX SSSV @ 1785' 13. Attachments Description summary of proposal ~X Detailed operation program __ BOP sketch Convert well from oil producer to water injector. 14. Estimated date for commencing operation August 10, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil . Gas Suspended Service Water Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,,,~~ ,,~~~..,~,-. Title Wells En~]ineerin~l Tech C," ~ / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test f Subsequent form require 10- ~ IIAppr°val No.~,~, _/~ Approved by order of the Commission Original Signe::'- [3avid W. J0hnstr~,' Commissioner Form 10-403 Rev 08/10/88 ¢,oproved Copy ' Returned- Date (~'~'-~/~:~ SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Kuparuk Well 3G-24 ARCO Alaska requests approval to convert Well 3G-24 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 5839' and 5868' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. "~ STATE OF ALASKA '~--' 0 RIG I N~.A L ALA~r,,A OIL AND GAS CONSERVATION CO~v,,v,,SSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS ['~ SUSPENDED [---] ABANDONED ["-] SERVICE ~'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-134 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20145 4 Location of well at surface .... ~:.P:~.-: ~: ~ ~ ~ 9 Unit or Lease Name ~'~,.~. ~- -~;~,~i~-~~ KUPARUK RIVER 2538' FNL, 270' FEL, SEC 23, T12N, R8E, UM At Top Producing Interval 10 Well Number At Total Depth .,'~-~_..~ ..~ i! 11 Field and Pool 1133' FNL, 1884' FWL, SEC 14, T12N, R8E, UM ~ .... ~'[~..~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 89'I ADL 25547 ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 10/05/90. 10/10/90. 14;)9,~.I NA feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9940' MD, 6081' TVD 9840' MD, 6005' TVD YES [~ NO ['-'] 1785' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR, CN, SFD, CET, DGR, GYRO 23 CASING, LINER AND CEMENTING RECORD SE'I-I-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 175 SX AS I 9-5/8" 36~ J-55 SURF 4572' 12-1/4' 970 SX AS III, 600 SX CLASS G 7" 26~ J-55 SURF 9931' 8-1/2" 274 SX CLASS G, 154 SX CLASS G TAIL 24 Perforations open to Production (MD+'I-VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9527' 9444' 9618'-9658' W/4-1/2" CSG GUN @ 4SPF MD 5838'-5868' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 ~ Submit in duplicate Rev. 7-1-80 C(]q~NUEDON REVERSE SIDE ~ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, ail fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9608' 5831' NA KUPARUK C DO'If'OM 9616' 5837' KUPARUK A TOP 9616' 5837' KUPARUK A BOTTOM 9720' 5914' 1 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~x'~~//~~~ Title AREA DRILLING ENGINEER Date .~~-~~/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oh,~,,d Gas Company Well History - Initial Report - Dali- Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. County. parish or borough NORTH SLOPE ILease or Unit Imitle ADL:25547 ALK:2661 COMPLETION IState AK Well no. 3q-24 KUPARUK Auth. or W.O. no. AK5296 IDate IHour 10/05/90 Opera[or ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 01/08/91 (10) TD: 0 PB: 0 SUPV: DB / LA 01/09/91 (11) TD: 0 PB:-9840 SUPV:DB/LA Complete record for each day reported NORDIC 1 _ SPOT RIG OVER WELL 9-5/8"@ 4573' MOVE RIG FROM 3G-14 TO 3G-24 01:00 IAnCOW~ 55. 252072 IPrior status if a W.O. MW:10.8 NaCl/Br DAILY:S14,257 CUM:$916,738 ETD:S916,738 EFC:$1,680,000 MU & TEST CL @ TBG HANGER 9-5/8"@ 4573' MW:10.8 NaCl/Br ND MASTER VALVE & THA, NU BOPE & TEST, RU HLS & PERF 9658'-9618' IN THREE RUNS W/4.5" CSG GUNS @ 4SPF 180 DEG PHASE, ORIENTED, TIED INTO EWR LOG OF 10/10/90 & PET LOG OF 11/15/90, RD HLS, RU & RUN 3.5" COMP ASSY W/2-7/8" TAIL, DROPPED TEST CL TO 5000 PSI WHEN MU TO SSSV & TBG HANGER, DROP BALL 10 JTS BEFORE MU HANGER, MU & TEST CL @ TBG CUM:$965,869 ETD:S965,869 EFC:$1,680,000 HANGER DAILY:S49,131 The above is correct Signature ~ For form preparation and dislr.,~io~ see Procedures Manual, Sectib. n)10, Drilling, Pages 86 and 87. ~ IDate I T;tle ! v / Driiiin~ ..... oupt. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. ARCO O,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is eot required upon completion, report completion and representative test data in blocks provided. The "Final Reporl" form may be used for reporhng the entire operation if space is available. I Accounting cost center code District Slate ARCO ALASKA INC. AK County or Parish NORTH SLOPE Lease or Unit ADL: 25547 ALK:2661 ITitle COMP LET I ON no. 3(~-24 KUPARUK Auth. or W.O. no. AK5296 Operator ARCO Spudded or W.O. begun S?UD A.R.Co. W.l. Date Iotal number of wells (active or inaclive) on this, cst center prior to plugging and ] bandonment of this well 5~ .2520'~2 our 01;00 Prior stalus if a W.O. 10/05/90 Date and deoth Complete record for each day reported as of 8:00 a.'m~ NORDIC 1 01/10/91 (12) TD: 0 PB: 9840 SUPV:GB/SK RIG RELEASED 9-5/8"@ 4573' M-W:10.8 NaCl/Br MU & TEST CL @ TBG HANGER TO 5000 PSI F/15 HIN, LAND TBG HANGER, RAN 37 SS BANDS, RILDS, PRESS UP ON TBF TO 2500 PSI & SET PKR, HOLD TBG, PRESS ANN TO 1000 PSI, HOLD 10 MIN, BLEED OFF ANN, HOLD 1200 PSI ON TBG, BOLDS, PU & SHEAR OEJ @ 98K (32K OVERPULL), BLEED OF TBG, RELAND HANGER, RILDS, TEST SSSV, WITH 500 PSI DIFF, 15 MIN, BLEED TBG, PULL LANDING JT, SET BPV, ND BOPS, NU WKM GEN IV 5KPSI TREE, TEST PO TO 5KPSI UNABLE TO GET THRU TREE TO RETRIEVE BPV, STEAM ACCUATOR VALVE, PRESS ON ACC VALVE TO FULLY OPEN, PULL BPV, OPEN SSSV TEST ANN TO 2500 PSI F/15 MIN, OK SHEAR BALL @ 3450 PSI, BLEED OFF ANN & TBG REV CIRC 13 BBL DIESEL CAP INTO ANN, INJECT 5 BBL DIESEL CAP INTO TBG, SHUT IN PT=50 PSI, PC=0PSI RD LINES, SECURE WELL, RELEASE RIG, DAILY:S157,265 CUM:$1,123,134 ETD:S1,123,134 EFC:$1,680,000 Old TD Released Classifications (oil. gas, etc.) Producing method INew TD PB Depth Date Kind of rig Type completion (single, dual. etc.) I Official reservo r name s Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Product;on !Oil on test Gas cer Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity AIIol,Vable E~fec'. .e corrected The above is correct For form preparat, .... dd,st,i~n,f ¢__7/o~"-/ ¢/ Drilling Supt. see Procedures Manual, Sectiort,~, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively -~ as they are prepared for each well. I Division of AtlanhcR~cn~,e~dCornpany A GYRODATA DIRECTIONAL SURVEY FOR ARCO ALASKA INCORPORATED KUPARUK RIVER UN!T, WELL NUMBER 3G-24 NORTH SLOPE BOROUGH, ALASKA. DATE : 06 DECEHBER i990 0ate_t o/~ ~fDc'~ _ O~XD/£ :s~POD G0'£ M 0G'6I N 0'GZ8 M 9'§£Z N £'££L M II'ZE ~ 6'0E8 £'EG£I £'E98I I£'£G 00IZ Z 96'§ M 9£'6I N 6'G9£ M 0'£9Z N 8'£0£ M £6'6I N 0'E9£ E'I69I Z'IS£I 66'0G 000g Z £0'Z M 9£'6I N 9'I£9 M 9'ZEE N 9'££9 M 6£'8I N I'899 9'9Z9I 9'9I£I 60'G9 006I 6~'Z M £9'6I N 0'g09 M Z'00Z N £'£9§ M 60'6I N 6'96§ ~'Eg§I §'E99I 60'£9 008I 9£'Z M 99'6I N 9'G£G M E'8£I N 8'90G M 6g'6I N 9'Z£G 0'8L9I 0'89GI I§'09 00£I L 09'£ M E9'6I N £'EL9 ~ 0'£~I N 9'~99 M 09'6I N 8'699 9'009I 9'069I ~£'A£ 009I L ZZ'£ M 09'6I N 9'£I9 M 9'££I N I'06£ M £9'6I N 9'II9 §'6I£I G'609I GI'9£ 00GI L 9I'0 M Z9'6I N 8'6§£ ~ 9'6II N £'6££ M £I'6I N 6'£G£ Z'~£ZI Z'GZ£I £6'0£ 009I L 9£'0 M E9'6I N 9'80£ M 9'g0I N 6'06E M I£'6I N 8'90£ 9'69II 9'6£EI 68'0£ 00£I 99'0 M 9£'6I N £'L~E M £'~8 N 8'ZgZ M 9L'6I N 0'9~Z 9'£90I 9'£~II £§'0£ 00gI £0'9 M 9E'6I N 0'£0E M £'89 N 9'~6I M 9£'6I N 6'~0E 0'££6 0'£90I £8'6E 00II 99'6I N 6'I9I M 6'£G N £'EGI M 9£'£I N I'I9I 8'L98 9'££6 £8'£E 000I L 86'6I N §'GET M 6'Z9 N 6'£II M £0'8I N 6'9ZI £'96L L'988 §6'8I 006 89'0E N 6'96 M E'££ N 6'88 M £8'8I N ~'96 9'669 9'68£ I£'9I 008 98'0E N £'£9 M 6'£Z N 6'E9 M 0£'0E N I'£9 9'£09 9'£69 9£'~I 00£ §£'0Z N £'E9 M L'gI N 9'6£ M 9I'£Z N I'Z9 9'90G 9'96g £9'£I 009 66'9 M L9'8I N G'IZ M 8'9 N 9'0E M 99'IZ N 9'IE 8'809 8'869 I6'£ M £6'9I N 6'L M £'Z N G'L M LZ'LI N 8'L 8'60£ 8'66£ 9I'I M 6£'9Z N 6'I M 8'0 N 8'I M 99'II N 6'I 0'0IZ 0'00£ EZ'0 M 99'££ N 9'0 M E'0 N 9'0 M 8Z'££ N 9'0 0'0II 0'00E 60'0 M Gt'9£ N I'0 ~ 0'0 N I'0 M §I'9£ N I'0 0'0I 0'00I 00I/ ONIHYH~ HDNZSIG Q~HH-~q~M-NOH~ ONIHYH~ ~DNASIQ ~Q ~H~SO~D SHA~NIQHOOD-~AI~H NOIAD~HIQ NOIADHS A~AHflS ~0 QHODHH SHAdHG-~DI~HHA G£'0I 00~ L 9£'G 009 L Gg'I 00£ L 1£'0 00Z L 60'0 00I N~DNI S~HN S ggIOZ-£0I-0g £gZD06IIX¥ ~ 00' 06 06/ T/T 06/§O/gI ...... a~qmnN Id~ . ..... asqmnN qo£ :'UOy%~A~IE ~XH . .... ~Q A~A~ns · .... uo~g~ndmoD · DUI 's~oyAasS ~poaAD ' 6~OHS ~OH :''xOZaAInS 9Z-D£ ~X : ...... 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G096 009§ 98'1§ £9Z6 00GG E£'ZG G806 ££'GG II68 00£G 9'0 M 9I'VE N I0£9 M 998Z 6'0 M 06'£E N 9E0~ M ~0Z I'0 M 9~'~Z N L919 M 999I 9909 M 9£'I£ N IOL9 0G£G 099G 98'GG 0006 99£G M £9'6E N 0£8G £6£9 £889 9£'£§ 0008 £6~9 M ~9'~Z N ZE0~ 69Z9 6~£9 ~L'6§ 000£ 0E8£ M §£'9Z N 9919 9~£Z 998£ ~6'8~ 0009 G'0 M G0'£Z N 60££ M 96ZI ~'0 M Ig'ZZ N £GgZ M ££6 6'0 M G6'IE N 06GI M G6G 0'9 M 9£'6I N 99£ M £9Z 6'9 M 99'6I N E9I M 9§ 00I N Gg0~ M 99'9E N £0~£ ZgE~ Z£££ 06'£G 000G N E£EZ M 9I'§Z N 9GgZ 0Z£E OISZ 60'E9 0009 N g£9I M 89'£Z N 88GI £EZE £I£Z IE'6G 000£ N 90£ M £6'6I N Z9£ I69I ISLI 66'0g 000Z N £§I M 9£'£I N I9I 988 8L6 £8'£E 000t DNIHYH~ iSIQ GYHHq~HM-~O~ ~NIHYH~ ASIG S-~QS ~ ~DN~ HH~SO~D SHA~NIGHOOD-~H NOIAO~HIG ADHS SHI~HG-AH~A N~ONI by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 12/05/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-24 Section at: N,25.22,W Surveyor..: ROB SHOUP Computation...' RADIUS OF CURVATURE Survey Date...' 11/15/90 RKB Elevation.' 90.00 ft Job Number · AKl190G253 AP1 Number · 50-103-20145 INTERPOLATED MARKERS REPORT Surface Location' 2538 SNL 270 WEL S23 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" CASING PROJECTED TD MEAS INCLN DEPTH ANGLE 0 0.00 4572 57.51 9608 43.49 9616 43.31 9616 43.31 9720 40.79 9930 40.51 9940 40.51 VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -90 3102 3012 5831 5741 5837 5747 5837 5747 0 N 0.00E ON 0E 2946 N 24.85 W 2717 N 1144 W 7164 N 18.76 W 6477 N 3060 W 7169 N 18.67 W 6482 N 3062 W 7169 N 18.67 W 6483 N 3062 W 5914 5824 6074 5984 6081 5991 7238 N 17.63 W 7374 N 17.56 W 7380 N 17.56 W 6549 N 3083 W 6679 N 3124 W 6685 N 3126 W 8rsst LanJ 9irs£tionsl ~?y'llin~ £~£. <KB>O 700 i400 2i00 2800 T 35oo V O 4200 4900 5600 6300 7000 7700 8400 9t00 9800 700 VERTICAL SECTION VIEN ARCO ALASKA, INC. KRU 36-24 Section at: N 25.22 W TVD Scale.' I inch = 1400 feet Oep Scale.' i inch = 1400 feet Drawn · 12105/90 Marker Identification MD TVO SECTN A) KB 0 0 0 A --- 8) PROJECTED TD 9940 608! 7380 I I ,--. 1 0 700 !,~no 2i00 2800 3500 4200 4900 5600 6300 7000 Sect ion Departure INCLN 0.00 .51 ~arke~ Idenbifica~on ~0 N/$ E/~ KB 0 0 N 0 PROJECTED TO 9940 8885 N 3t28 PLAN VIEW ARCO ALASKA, INC. KRU 3G-24 CLOSURE .....: 7380 ft N 25.06 W DECLINATION.: 0.00 E SCALE .......: I inch = iiO0 feet DRANN .......: i2/05/g0 7150 6600 6050 55OO 4950 4400 3850 3300 2750 2200 i650 itO0 ' 550 z " 0 ',, 550 3300 2750 2200 i650 iiOO 550 0 550 iiO0 t650 2200 2750 3300 <- t~EST · EAST -> COmPlETiON ~ATE br__ULUL-~It.,AL MA! !-HIAL-5 iNVENTORY LiST CO, CONTACT ,~/~CO, . checl('off or list data as it is received *list recei~ved date for 407, if not reauirCd list as NR -- _ t cored :n{c~a:s core analysis ~[ d. ditch intc~als I digital data 8 ..... I ' 5} I I "' i l I I I I I :I I II III I 7:) I ! I i ....... , ARCO Alaska, Inc. Date' March 8, 1991 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 8030 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-24 1A-17 3G-23 3G-02 3G-15 Receipt Drilling Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Acoustic Cement Bond Log 1 1-14-90 6603-9725 12-31-90 5400-8438 1 1-15-90 4200-7282 1 1-12-90 41 00-6545 State of AlaSka Alaska 0ii & Ga~' (;0mmiss[~n ARCO Alaska, Inc. Date: February 4, 1991 Transmittal #: 8000 RETURN TO: ARCO Alaska, Inc. ATTN: Mafia Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. signed copy of this transmittal. 3G-0~ 3G-2 3G-04~. 3G-15~( 3 G- 22,.X?,/ 33~ Receipt Drilling ; Acknowledge' Please acknowledge receipt and return one Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Icg Pulse Echo Cement EvalUation Log Acoustic Cement Bond Log Acoustic Cement Bond Log Squeeze Record State of AlaSka 10-3-90 5229-9682 I 1-1 5-90 6698-9704 I 1-1 6-90 4900-7939 I 1-14-90 4500-7815 I 1 -1 8-90 6600-9595 I 1 ~23-90 ......8466-11 ~513 1 1-1 6-90 4892-7962 I 1-1 8-90 6600-9616 1 -20-91 9200-9800 ate: ..... FEB 5 1991 Alaska Oil & 6as Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Repair well _ Plugging _ Pull tubing _ 5. Type of Well: Development .X__. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 270' FEL,SEC 23,T12N,R8E,UM At top of productive interval 1300' Fnl, 1940' FWL, Sec. 14, T12N, R8E, UM At effective depth NA At total depth 1016"FNL, 1806' FWL, Sec. 14, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 9940' (approx) true vertical 6129' Effective depth: measured NA (approx) true vertical NA Operation Shutdown .~_ Re-enter suspended well _ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) (approx) (approx) feet Plugs (measured) feet feet Junk (measured) feet RKB 90' 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 3G-24 9. Permit number 90-134 10. APl number 50-103-20145 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 O' 1 6" Surface 4537' g 5/8" Intermediate Production 9896' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 175 SX AS I 970 Sx AS III& 600Sx Class G 274Sx class G 154 Sx class G Measured depth True vertical depth 1 1 5' 11 5'approx. 4572' 3111 '(approx) 9931' 6122' (approx) RECEIVED OEO - 4 1990 Alaska Oil & Gas Cons. 60mmissi0t~ Anchorage 13. Attachments Description summary of proposal_ Detailed operation program X BOP sketch 14. Estimated date for commencing operation January. 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil . X Gas __ Suspended Service 17. Ihereby certify~~ Signed //~. ~(,~. ' c,-. is true and correct to the best of my knowledge. Title Area Drilling Engineer FOR COMMISSION USE ONLY Date //~'"~/¢~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED B~ LONNIE O. SMITH Approved Copy R~tur~d I Commissioner IApproval No. /- SUBMIT IN TRIPLICATE ARC~., Oil and Gas Company~,~ Well History - Initial Report - Daily Instruction,,: Prepare and submit the "lltlflal [~rt" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. County, parish or borough NORTH SLOPE Lease or Unit ADL 25547 Title DRILLING Field KUPARUK Auth. or W.O. no. AK5296 ALK 2661 Well no. 3G-24 Operator ARCO I ARCO W.I. 55.2521 IOate IHour Prior status il a W.O. 10/05/90 01:00 DEC - ¢ 199 Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 10/05/90 (1) TD: 775' ( 775) SUPV:AK5296 10/06/90 (2) TD: 4015' (3240) SUPV:PW 10/07/90 ( 3) TD: 4600'( 585) SUPV:PW 10/08/90 (4) TD: 0' ( 0) SUPV :PW 10/09/90 (5) TD: 8470'(8470) SUPV:PW 10/10/90 (6) TD: 9495'(1025) SUPV:PW lO/11/9o ( 7) TD: 9940'( 445) SUPV:PW Complete record for each day re~rted DOYON 14 DRILLING MW: 8.9 VIS: 78 MOVE RIG OFF 3G-23, SPOT CONVEYOR ON 3G-24. NU 20" DIVERTER SYSTEM & RIG FLR PU BHA. TEST DIVERTER & CHECK FOR LEAKS. SPUD WELL, DRILLING. DAILY:S74,064 CUM:$74,064 DRILLING DRILLING. ETD:S74,064 EFC:$1,680,000 MW: 9.6 VIS: 53 DAILY:S65,543 CUM:$139,607 ETD:S139,607 EFC:$1,680,000 DISPLACING CEMENT 9.625 MW:10.0 VIS: 44 DRILLING SURFACE HOLE TO 4600' CBU. WIPER TRIP, CLEAN BALLED UP TOOLS. CIRC FOR 9-5/8 CSG. DROP SURVEY. POH LAYDOWN BHA. RUN 107 JTS 9-5/8 CSG. CIRC AND CEMENTING. DAILY:S130,234 CUM:$269,841 ETD:S269,841 EFC:$1,680,000 DRILLING 9-5/8"@ 4573' MW: 9.5 VIS: 40 CEMENTING 9-5/8 CSG. LOST RETURN AFTER 122 BBLS DISPLACEMENT. BUMP PLUG W/ 2000 PSI FLOATS, HELD OK. REMOVE 20" DIVERTER SYSTEM. RUN 100', 1" CHF AND MIX 140 SX ASI FOR TOP JOB. 15.8 PPG SLURRY. INSTALL CHF & NU, BOP ;;~.~.~.~¢TEST BOP AND ACCUMULATOR, CHOKE MANIFOLD TO 250/3000 .~<~il/'CUT & SLIP DRLG LN PICK UP BHA, RIH TAG FL CLR, TEST ~. :~ii2000 PSI. DRILL FC & SHOE, TEST, 2000 PSI, DRILL SHOE '.ij~:<~OI~iATZON. DRL TO 5054', POH (WASHOUT), DRL TO 5720'.. '~Y:$161,123 CUM:$430,964 ETD:S430,964 EFC:$1,680,000 DRILLING 9-5/8"@ 4573' MW: 9.8 VIS: 38 DRILLING 5720' TO 8470'. DAILY:S50,007 CUM:$480,971 ETD:S480,971 EFC:$1,680,000 DRLG @ 9495' 9-5/8"@ 4573' MW:10.9 VIS: 40 DRILL FROM 8470' TO 9293'. CBU AND POH FOR LEAK-OFF TEST. LOT BLED OFF TO 11.2 PPG EMW. POOH AND CHANGE TO ROTARY BHA. DRILL FROM 9293' TO 9495'. DAILY:S54,123 CUM:$535,094 ETD:S535,094 EFC:$1,680,000 CIRC FOR 7" CASING 9-5/8"@ 4573' MW:10.9 VIS: 39 DRLG F/9495'-9940', CBU, POH DOWNLOAD RLL, S&C DRLG LINE, CALIBRATE RLL, RIH CIRC & COND FOR 7" CSG. DAILY:S77,999 CUM:$613,093 ETD:S613,093 EFC:$1,680,000 , ,..,A'he above is c, arrect AlasKa Oil & Gas Cons. Com. Signature Anchorage For form preparation ar/~tdistribution, see Procedures Manualk.,~ection 10, Drilling, Pages 86 and 8~ AR3B~5~I-D Number all daily well history forms consecutively Page no. as they are prepared for each well. ARCO ,.,,I an~ Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pertormed. Number ali drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets undl final completion. Report official or representative test on "Finel" form. 1) Submit "Interim" sheets when filled out but not less Irequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish ISlate ARCO ALASKA INC. I NORTH SLOPE I AK t Lease or Unit I ADL 25547 ALK 2661 Field JWell no. 3G-24 KUPARUK Date and depth as of 8:00 a.m. 10/12/90 (8) TD: 9940'( 0 SUPV:PW Complete record for each day while drilling or workover in progress DOYON 14 CEMENTING 7" CSG 9-5/8"@ 4573' MW:10.9 VIS: 0 CIRC, SPOT DIESEL PILL ACROSS KINGAK SHALE. POH, LDDP AND BHA. RUN 131 JTS 7"26 PPF J-55 BTC CSG. RUN CSG SLOWLY. NOT GETTING RETURNS WHILE RUNNING IN. STOP AND ATTEMPT TO CIRC. NO RETURNS. CONTINUE TO RUN IN. CSG ON BQTTOM, SHOE @ 9930', FC @ 9840'. BATCH MIX CMT PUMP 10 BBL FW, TEST LINES TO 3500 PSI, PUMP 35 BBL ARCO SPACER @ 11.7 PPG, 103 BBL LEAD CMT @ 12.5 PPG, AND 35 BBL TAIL CMT @15.8 PPG. DISPL W/377 BBL BRINE. DAILY:S176,996 CUM:$790,089 ETD:S790,089 EFC:$1,680,000 DEC 199 Alaska Oii& 6as Cons. Commissio[~ ;Anchorage The above is correct For form p~eparation andrd~str"f~ution see Procedures Manual ~e~tion 10, Drilling, Pages 86 and 87,,./ AR3B-459-2-B INumber all dai]y well history forms conseculively as they are prepared for each well. ARC Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or SoJd, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest is no[ required upon completion, report completiOn and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire ooeration if space is available. _ t Accounting cost center code District State ARCO ALASKA INC. AK Field KUPARUK County or Parish NORTH SLOPE ILease or Unit ADL 25547 ALK 2661 ITitle DRILLING Well no. 3G-24 Auth. or W.O. no. AK5296 Operator A.R.Co. W.I. AlteC Date5 5.2 5 2 1 Spudded or W.O. begun SPUD 10/05/90 Date and depth as of 8:00 a,m. 10/13/90 (9) TD: 9940'( 0) SUPV:PW Complete record for each day reposed DOYON 14 I olal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well I our I Prior status if a W,O. 01:00 RIG REL - FINAL REPORT 9-5/8"@ 4573' MW: 0.0 VIS: 0 DISPL CMT W/377 BBL BRINE WATER (10.8 PPG). BUMPED PLUG W/3 000 PSI. HELD 15 MIN. FLOATS HELD OK. RECIP CASING THROUGHOUT JOB. ND BOPE. SET SLIPS ON 7" CSG. INSTALL PACKOFF. TEST TBG SPOOL TO 3000 PSI. PUMPED 80 BBL DIESEL IN 7" X 9-5/8" ANNULUS TO FREEZE PROTECT. DAILY:S112,392 CUM:$902,481 ETD:S902,481 EFC:$1,680,000 REEEIVE Old TD New TO I PB Deplh Released rig Date IKind of rig Classifications (oil, gas, etc.) J Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I Potential test data Well no. Date Reservoir !Producing Interval lOll or gas Test lime Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date correcled The above is correct · For for distribu ion, see Procedures Ma~uaj~ Section 10, Drilling, Pages 86 a'1~,'87. AR3B-459o3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no. Olvl~on of AtlanticRIchfleldCompany ARCO Alaska, Inc. Date: October 26, 1990 Transmittal #: 7933 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-15 3G-24 LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return 10-22-90 3500-7991 GT(~ 10-22-90 4600-9940,1~ qJ, 77 Receipt Acknowledged' '- ..... Date' DISTRIBUTION: Lynn Goettinger RECEIVED OCT 3 1 1090 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: October 26, 1990 Transmittal #: 7932 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-15 3G-24 3 G - 1 5 Dual Gamma Ray Compensated I 0 - 1 6 - 9 0 3 5 0 0 - 7 9 91 Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic 1 0 - 1 6 - 9 0 Wave Resistivity Formation Exposure Time Dual Gamma Ray Compensated 1 0 - 1 1 - 9 0 Neutron Porosity Simultaneous Formation Density 3G-24 Dual Gamma Ray Electrmagnetic 1 0- 1 1 -90 4600-9940 Wave Resistivity Formation Exposure Time Receipt Acknowledged' ,~~~~~- *---- Date: 3500-7991 4600-9940 DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) October 4, 1990 Telecopy: (907)276-7542 A Wa]~e ~-~cBr~d~ Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River ~Jnit 3G-24 ARCO Alaska, Inc. Permit Mo. 90-134 Sur. Loc. 2538'FI~, 270'FEL, Sec. 23, T12N, RSE, UM. Btm~hole Loc. 1016'F!P~, !806'F~, Sec. 14, T12N, RgE, ~.~. Dear Mr. McBride Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting dete~inations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, : Lonnie C. iS~i'th Commissioner Alaska Oil and Gas Conservation Commission BY ORDER OF ~!E COM~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conserx~ation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION C, OMMIS,~ION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill _ lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen _ Service m Development Gas ~ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKI~ 9g', pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 270' FEL, Sec. 23, T12N, R8E, UM Kup~ruk River Unit At top of productive interval (TARGET) 8. Well number Number 1300' FNL, 1940' FWL, Sec. 14 , T12N, R8E, UM 3G-24 #U630610 At total depth 9. Approximate spud date Amount 1016' FNL, 1806' FWL, Sec 14, T12N, R8E, UM 04-OCT-90 $200,000 ;12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) property line 3G-23 10032' MD 1016' @ TD feet 23'@ 450 feet 2560 6041 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300' feet Maximum hole angle 58° Maximum surface 1830 psig At totaldepth (TVD) 3400psi~ @ 6041 18. casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casinc~l Weic~ht Grade Couplinc, l Length IVD TVD IVD TVD linclude stac~e dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 Cu.Ft. 12.25 9.625 36.0# J-55 BTC 4413 35' 35' 4448' 3090 1880 Cu. Ft. AS III & HF-ERWl 690 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MO[ 4763'1 35' 35' 4798' 3275' 200 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 5234' 4798' 3275' 10032' 6041 Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Sudace Cu. Cu.,. ,. RECEIVED Intermediate Production Liner ~.)~.,. ~ [,~, ,~.. Perforation depth: measured true vertical ...... ~;.~ 0.ii .~,, ~..~$ ~0rls, C.D_~._~.i$S[.!;- i 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program _~_ Drilling fluid program _X Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements .~. 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _//~'~ ~ Title Area Drilling Engineer Date ~'~,/~/~'~J / Commission Use Only I~ermit Number IAPl number I Appr°val date '1 0 / 0~ / O~0 I See cover letter for ?(~ -/,~ ~? 50-~'"~-~- ~.~,~/'~-~-?,,~" - other recluirements conditions of al~proval Samples required ~Y e s .~ N o Mud log required~ Ye s ~ N o Hydrogen sulfide measures ~ Yes ~' N o Directional survey required ~"Yes ~ N o Required working pressure for BOPE ~2M; ~. 3M'~ 5M' ~ 10M' ~ 15M Other: ? / "~; ~ ~ ~//'/ '~ ! by order of Approved by ( ~ ~ Commissioner the commission Date ,J ~ ~- ~ ~ c~ (~ Form 10-401 Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (3G-24) Spud to 9-5/8" Drill out to surface casing weight UD Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 1 5-4 0 4- 8 APl Filtrate 1 0-1 2 8- 1 0 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up 10.8 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1830 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-24 will be 3G-23. As designed, the minimum distance between the two wells would be 23' at 450'. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 250 _ 200 _ 150 _ 100 _ 5O 5O 200 I I I I I 150 I 100 I 5O \1 1 O0 \ \ \ \ \ \ 900 \ \ \ \ '~700 900 200 1 50 1 O0 50 0 50 I I 100 -'~,00 ~5oo ,.,~~ ~oo / ~oo 1. ! 0 150 2OO 700 50 1 O0 1 50 200 25O 2OO 150 100 5O 5O r-lull! LUDI ! /~L I"r~uJI:L, I !UIq ----'-'CALE 1 IN. = 1000 FEET 7000 6000 _ 5000 _ 4000 _ 3000 _ 2000 _ 1000 _ m 1000 _ ARCO ALASKA. Ine. Pad 3G. Well No, 24 Proposed Kuparuk Field. North Slope. Alaska 4000 3000 I WEST-EAST 2000 1000 I I 1 000 I TD LOCATION, 1016' FNL. 1806' FWL SEC. 14. T I2N. R8E TARGET LOCATION' 1300' FNL. 1940' FWL SEC. 14. T I2N. R8E TARGET TVD-5845 THD=9662 DEP=?205 NORTH 6518 WEST 3070 SURFACE N 25 DEG 13 MIN W ISURF.~CE 7205' (TO TARGET) 12538 ENL. LOCATION, 270' FEE SEC. 23, T12N. RSE Pad 3G, Well No, 24 Proposed Kuperuk Field, North Slope, Alaeka ~~7 0 ~ RKB ELEVAT[ON~ go' KOP TVD=300 THD=300 DEP=O 1 000 2000 3000_ 4000_ 5000_ 6000_ 7000. 0 3 9 15 21 27 33 BUILD 3 DEO PER 100 FT B/ PERHAFROST TVD=1605 THD=1737 DEP=515 T/ UGNU SNDS TVD=1775 THD=1985 DEP=697 $? EOC TVD=1921 THD=2237 DEP=901 T/ W SAK SNDS TVD=2410 THD=3161 DEP=1686 B/ N SAK SNDS TVD=2890 THD=4070 DEP=2457 9 5/8' CSG PT TVD=3090 THD=4448 DEP=2778 K-lO TVD=3170 THB=4600 DEP=2907 AVERAGE ANGLE 58 DEG 6 HI N K-5 TVD=4760 THD=7609 DEP=5461 TARGET - T/ ZONES C-A TVD=5845 THD=9662 DEP=7205 B/ KUP SNDS TVD=5935 THD=9832 DEP=7349 TD / LOG PT TVD=6041 THD=lO032 DEP=7519 I 1 000 I ! I I 2000 3000 4000 5000 VERTICAL SECTION i 6000 i 7000 8000 GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 3G PAD . . . 10. 11. 12. 13. 14 15 16 17 18 19 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. RIVER UNI , 20" DIVERTER SCHEMATIC ! I 3 f 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16' CONDUCTOR 2. SUP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20' - 2000 PSI DRILLING SPOOL WITH TWO 10- OUTLETS. 5. 10' HCR BALL VALVES WITH 10' DIVERTER LINES. A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20' - 2000 PSI ANNULAR PREVENTER SRE ~ , 6 5 4 I3 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RE~ THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BCP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSi AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3(XX) PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TESTANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BUND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOM~ PUMP. 13. RECORD TEST INFORMA~ ON BLOWO[JT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2(XX) PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PS! X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL ENES 6. 13-5/8' - 50(X) PSI DOUBI != RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/8g DOYON 14 (2) Loc (8) (9 'ii) ' ' ~.~'::/~ /a -~-. °2 11. (i0 13) i2.. 13. (4) Cas~ ~.,...,.../~. .... o-:~ > (14 nh~ i2) (23 thra 28) Is the permit fee attached .......................................... /3 2. Is well to' be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~.~ 4. Is well located proper dis:anco from other wells ........ ~ ........... ~ 5. Is sufficient undadica:ed acreage available in this pool ............ '~ 6. Is well :o be deviated and is we!!bore plat included ................ 7. Is operator the only affected parry ......... i ....................... 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. I?. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ is a conservation order needed ...................................... ~ Is ad~4~JsTrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ ' IS c6nductor string provided ........................................ /p~ Will surface casing protect all zones reasonably e-xoected to i serve as an u~der~round source of drinking water ..................... /~ Is enough cement used to circulate on conductor and su~ace ......... Will cement tie in surface and intermediate or production strings . ..' Will cement cover ~ known productive horizons ..................... Will all casing give adequate safety in collaose, tension cud burst.. Is this well to be kicked off from an er-~sting we!lbore ............. Is old wellbore abandonment procedure included on 10-403 ............ " Is adequate wellbore separation proposed ............................ Is a diver=er system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate /~ Are necessary diagrm?,~ and descriptions of diver=ar and BOPE attached. //--~ Does BOPE have sufficient pressure rating - Test to ~O~O psig .. ~._ Does :he choke manifold comply w/API RP-53 (Nay 84) .................. Is the presence of H2S gas probable ............................. ~... (6) 0THE~ (29 rev: 01/30/89 6. 011. ~or 29. 30. 31. 32. exT. loratory and StraTigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed condi:ions presented Additional requirements ............................................. Additional Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° 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. I I I I I I I I I I I I I I I I I I I e e Memory Multi-Finger Caliper Log Results Summary ý~rn ç /if - '-CÞ Hitt; Company: ConocoPhillips Alaska, Inc. Well: ~.., Log Date: November 10, 2005 Field: Kuparuk Log No. : 6038 State: Alaska \~C Run No.: 1 API No.: 50-103-20145-00 Pipe1 Desc.: 3.5" 9.3 lb. J-55 Top Log Intvl1.: Surface Pipe 1 Use: Tubing Bot. Log IntvI1.: 9,420 Ft. (MD) Pipe2Desc.: 2.875" 6.5 lb. J-55 Top Log Intvl1.: 9,420 Ft. (MD) Pipe2 Use: Tubing Bot. Log IntvI1.: 9,476 Ft. (MD) -\~~ Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: 'S-...)~ ~c)S-\~ð L{O~ \ (\~ '-G~ This caliper data is tied into the X-over (3.5" X 2.875") @ 9,420' (Driller's Depth). This log was run to assess the condition of the 3.5" and 2.875" tubing with respect to corrosive and mechanical damages. The 3.5" tlJbiAtttomJedappear&tobe m,goøcito fair condRion with respect to corrosive damage, witb,a maximum wall penetration of 33% recorded in joint 303 (9,250'). The damage appealS mainly in the form of isolated pitting. No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the 3.5" tubing logged. The 2.875" tubing logged appears to be in good condition with respect to corrosive damage. No significant wall penetrations, cross-sectional wall loss, or 1.0. restrictions are recorded throughout the tubing interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. ~. F:1 J.. t 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting Corrosion ( 33%) ( 24%) ( 23%) ( 23%) ( 22%) Jt. Jt. Jt. Jt. Jt. 303 @ 301 @ 302 @ 304 @ 0.1 @ 9,250 Ft. (MD) 9,199 Ft. (MD) 9,212 Ft. (MD) 9,273 Ft. (MD) 7 Ft. (MD) 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing logged. 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing logged. Pro.A.ctìve Diagnostic Services, Ine. / P.O. Box 1369, Stafford, TX 77497 DECEIVED Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS(cÜmemorylog.conf'\. . . Pruchoe Bay Field Office PI,one: 659-2307 Fax: (907) 659-2314 NOV 1 () 2005 Alaska Oil & Gas Cons. Commission Anchorage I I I I I I I I I I I I I I I I I I I e e 2.875" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 11 %) are recorded throughout the tubing interval logged. 2.875" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded throughout the tubing interval logged. 2.875" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing interval logged. I Field Engineer: D. Cain Witness: C. Fitzpatrick I Analyst: M. Tahtouh ProActive Diagnostic Services, Ine. / P.O. Bo>< 1369, Stafford, r< 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylÜ\:;¡.com Prudhoe Bay Field Office Phone: 659-2307 Fax: (907) 659-2314 I I P S Report Overview ody Region Analysis I Well: Field: Company: Country: 3e-24 Kuparuk ConocoPhìllips Alaska, Inc USA Survey Date: 1'001 Type: 1'001 Size: No. of Fingers: I November 10, 2005 MFC 24 No_ 99628 1.69 24 M. rahtouh Upper I Penetration ami Metal loss (% wan) I penetration body metal loss body penetration I 250 200 150 100 I so o 1 to jO% o to 1% !O to 20% 20 to 40% 40 to 85% over 85% I I elM 1 312) o o o o o I ,---------- Damage Configuration ( body) 60 40 elM 4 elM 2 I elM 3 I 20 o I Isolated pitting elM 5 general hne nng hole I pos~ corrosion CO!TOSIOn corrosion ¡ble hole I --_._~---_.~ Upset Damage Profile (% wall) metal 1055 50 100 o elM 6 Bottom of Survey = 307.1 I I Analysis Overview page 2 I I I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3G-24 Kuparuk ConocoPhillips Alaska, Inc. USA November 10, 2005 Appro,. Tool Deviation Appro,. Borehole Protìle ClM 1 ClM 2 C;L¡\!1 3 ClM 4 ClM 5 ClM 6 307.1 o 50 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 307.1 I I 8 1177 2421 1647 4865 +-' LL c 6079 -£; a. () o 7308 8535 9420 100 I Alaska, me. S ConocoPhillips USA November 10, LATIO 3G-24 OINT TAB Well: Field: Company: Country: Survey Date: J EPO PDS )-55 3.5 in 9.3 0.254 in 0.254 in 2.992 in Wall: Upset Wall: NominallD. I I 'b' Profil! (0!c, wall) 5 100 n 2005 Min D 1 Pen. - Depth (Ft.) It. T I ¡oint No. I _ 45 ~.. 1329 46 11º-º-- __3ì 1390 48 _~4(tl o -- ,-- Comments ~.- Lt. Deposits. PUP COŒlSiolL- ;2~ 0.03 0.0.1. 0.02 0.03 0.03 CUB 0.03 0.03 O.OI 2.91 0.03 L2Çt . 0.03 2.90. .QJ12. 2.90 102 J 2.2P, 2.90 2.89..l.t. D§;>21i1~ Shallow pitti!IK._ QJ)2._ _p.03 _QJLL 0.03 .JJ.OL .~Q.03._ _Q,O 3 --º,-1l1. .ß.03 0.01 0.03 1!JII. .I}.01. .ß03 1!J)2 0.03 - u _Ji._ --.1lJi... 302~ 3 3 ~-L~ _..J^63..__ 394 516 L 54ì 20 5ìL. 608 ._ 22 __ 639 669 _£4__º-9.(2 __.)5 _. ì30 26_ì60 ì90 . ;21:1.821 .. 29 _._ ._ 852 _3JL.. 882 910 33 I I I I I I I I Lt. Dpnn"it" Shallow pitting. .2,92 .;;./)1 Dining. 2.91 2.90 2.89 2.89 2.89 _L89 2.91 2.90 2.89 pitting. .. CUB 0.03 0.01:. 0.02 0.02. I I I Body Metal Loss Body I Page I I I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in 3G-24 Kuparuk ConocoPhìllips Alaska, Inc. USA November 10/ 2005 Well: Field: Company: Country: Survey Date: Jt. Depth - ______n_ Pen. Met;;1 Joint Pen. Min. Damage Profile No. (Ft.) I Body I.D. Comments (%wall) (I; I (Ins.) (Ins.) 0 50 100 50 1482 0 ~Q.02~. 9 2 2.91 .~: 51 1512 0 Q.JR. ~ I 2.90 52 ~1543 . 0 0.03 i3 ) 2.91 Shallow Dittìl1lz. :1r 53 1573 0 0.02 6 I 2.91 I =-it~ÞmÞ 0 0.03 10 ) 2.90 :1r )4 0 0.03 I I 2.88 :1r 561664 _ 0 0.02 7 2 2.88 I !II --- 57 1694 0 ÇJm 10 3 2.91 58 1725 0 (UB I ) 2.87 58.1 _J755 . 0 0.02 7 0 2.97 PUP I 5: .2 1765 0 () 0 2.81 SSSV 5: .3 17/4 0.02 (; I 2.96 PUP IJIII , 9 1782 0.03 I I 2.90 iB 0 1812 0.02 q ) 2.90 1843 0.02 q ) 2.90 2 1873 0 0.03 .3 >' 2.89 19m 0 0.02 ) 2.89 64 1933 U 0.ü2 1 2.90 65 1964 0.ü2 I 2.90 iB 66 1994 0.02 1 2.91 :1r I--~--' ~9L~ 2025 I 0.03 i±t±.=i== 2.90 iB -.- 68 2055 ( 0.03 2.91 · 6' -. o.m 10 ) iB .2085 I 2.89 7( 211-.2.. 0 0.03 13 ) 2.90 Shallow Diaìng. iB 7 2J46 I) O.!B I ) 2.90 iB 7: 2176 I) 0.02 9 I 2.89 11II T 2207 I) 0.02 I) 1 2.90 11II 7L I) .. ~PI' · 2238 0.02_ 1 2.89 75 22 6.2~ I 0.03 ) 2.89 IiIiI 76 .:2299 I 0.02 II I 2.90 Lt. DeDO);j.ts. IJIII 2329 I 0.02 I) 1 2.90 · ...2360 I 0.03 13 I 2.87 Shallow Ditting. Lt. DeDosits. IiIiI 2390 ( Q&2 b I 2.88 IJIII ~ 2421 I 0.03 '3 ¡ 2.90 Shallow Ditting. 11II I 0.03 i3 I 2.90 Shallow Ditting. · I "fttl I 2.91 IiIiI I I) I 2.89 IJIII I 4 I) I 2.88 Shallow Ditting. Lt. 11II I) ) 2.88 Lt. IiIiI 86 _;!602 () 0.02 I 2.88 IJIII 87 2632 () 0.02 ) 2.88 III 88 2663 () 0.03 ,I 1 2.90 11II 89 2694 () JL02 I 2.89 _..~~ 90 2724 () 0.ü2 I .89 . 91 2755 I 0.03 12 >' .87 I) 11 I .90 ~---_..- 92 2785 0.03 93 2816 I) 0.02 II I .90 94 2846 ( 0.03 I 1 2.90 Shallow Dittim:¡. 95 2877 I) 0.03 1 1 2.89 Shallow Ditting. J..J.. 96 2908 I 0.03 I I 2.89 Shallow Ditting. Body Metal Loss Body Page 2 I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in ¡¡oint I No. Jt. Depth (Ft.) I 7 2933 C).1 2963 '3 2c)75 ___ 99 3006 _lillL 3036 10 11066 102 3098 HB 3123 104 3153 . .105_. _.31 f>Z.. 106 32P 107 3243 108 3278 109 3309 110 3340 111 3371 112 3402 I 3 3432 114 3462 115 3493 116 3524 _HZ. 3554 118 3535 119 ! 3616 120 3647 121 3677 122 3708 123 3738 1243768' 125 3800 126 )830 11 38§Q_ II 3891 1: 3921 r 3951 U I 3980 I :2 4010 U3 4040 1--.134. 4070 135 4101 I 36 41.32 137 4162 138 4193 139 4224 140 4255 141 4286 ._142 4316 143 4347 144 4378 145 4409 I I I I I I I I I I I I I I I'HI ill", ! o Pen. Body (Ins.) 002 o 0.03 0.02 0.02 O,(U 0.02 0.03 0.05 . 0.03 0.02 0.03 0.01 0.02 0.03 0.04 0.03 0.02 0.02 0.03 0.02 O,(ß 0.02 0.02 0.02 O.G2 0.G2 0.G2 0.03 (UP 0.G2 0.03 0.02 0.02 0.03 0.03 0.03 0.01 0.02 0.02 0.G2 0.03 0.02 0.02 0.G2 O,(}) 0.03 0.03 ü.03 0.02 I o I I I I ! I o o o o !I P P P P II n -II !I !I \1 P II (I II o I) II () II !I o (I !) II !I (I P Pe! 1\\(-11'11 ) o 3 I 8 ) 7 D I I ') ) ') 10 ¡ ') 1 ') 8 0 ß :2 ') I ß I 11 1 (I ) 7 I II 6 ¡ 7 2 12 2 131 13 ) 6 ) 6' ') 2 8 ) 13 3 8 I 91 9 :2 91 12) 121 I) 3 7 3 Well: Field: Company: Country: Survey Date: 3G-24 Kuparuk ConocoPhillips Alaska, Inc. USA November 10, 2005 Min. 1.0. (Ins.) 2.B7 N/A 2.B5 2.B8 2.90 2.8R 2.87 2.90 2.90 SI1allow 12illiDg.______~~.~..___.._____. 2.89_ _._______________ ._._______. __.... 2.87 2.89 Shallow Ditting. 2.88 Lt. DeDosits. 2.90 2.88 2.8 2.8 2.8 2.8 2.8 2.90 2.87 2.88 2.90 2.89 2.89 2.89 2.90 2.86 2.90 2.89 2.87 2.90_ _Lt. Deposits.. 2.91 2.90 2.B8 Shallow Ditting. 2.87 Shallow Dining. 2.B8 2.B'L 2.89 __ 2.89 2.89 Shallow Dittin"'. 2.89 2.89 2.88 2.90 2.90 2.89 2.89 2.90 Lt. DeDosits. "'¡ 1 I ..' o 1 1 Comments 1 t. [)~!2º2.Í!?~._._____. ClM 1 (latch @ C):OO) .___.._ ._~ Slìallow pittif1&.1LQ.?J)9~¡t?__.._.__.___ .: III ..---.--.-.... II III --~~-~-----,~"~~--" .~.~ Page 3 --- ------------~---_._------~--~ Damage ProtÎle (%wall) 50 100 o 'Ii pm 11II 11II · III III · 11II · 11II · 11II · · III ¡ill III · Body Metal Loss Body I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in 3G-24 Kuparuk ConocoPhillips Alaska, Inc. USA November 10, 2005 Well: Field: Company: Country: Survey Date: I Joint Jt Depth Pel Pen. Perl. tvlet'!I Min. Damage Profile I No. (Ft.) Body LD. Comments (O¡;,wall) I ) (Ins.) ~ 0 .50 100 146 4439 0.03 10 v ~ I . 147"l'4470 () 0.D2 7 I 2.87 III 148 4501 0 0.03 ¡ [) 2.89. :}/' 149 4531 0 0.02 7 I v 2.<ill III 150 4562 0 0.03 13 3 ;2.8~L ...5!J<lJlowQi!1:i!1g. :}/' 151 4591 0 0.02 9 2 2.90 :}/' -. 152 4620 0 0.03 10 ;2J}5L .LtJ2?posits. :}/' ~jttr 0 0.03 10 .. 2.87 0 v --_._-~~--~-~-~---- _._1 682 0.D2 ) 2.89 It. Dem?sit;;.. .155....... 712 0 0.02 I ) 2.88 2.9Ö ... ~ - ------.- ---- t'"' - >') 0.02 I L>i).~j 4.:>... 157 4773 I 0.02 .. 2.89 ._-,-~-,.~._~ .~_._..~-~_.__.._- 158 4804 0.D2 I 2.88 159 ~[Js 0.02 2.89 -~._.~~_.... 160 0_02 2 18 161 l) D 18 162 D 18 163 l) 11 164 0 2.91 165 5014 () 0.02 2.90 166 5041 0 0.03 10 2.89 I It. DeDosits. 167 5072 0 _~10 3_ .L 2.91 Sh<\lIpw pitting. 168 5HJ:} 0 .0.03 2.91 .:2!b,!low pitting. 169 5132 0 0.02 2.89 170 5161 0 0.01 2.91 ~,~.,- 171 5190 0 0.02 2_90 172 0 0.02 -~- 5220 2.8z.. _lLI!E'Dosits. 173 n ~..._-_.. 5248 (J.02 2.90 _m___~'__ n -.., 1M.. 5278 0.02 2.89 I I 175 5307 n . 0.02 2.87 I 176 5338 n 0.02 2.90 177 5369 U 0.02 I _1·9fL. 8 3J99., 0 CL02 I 2.90 J' ~,.- .-. 9 ( 0.03 2.91 Shallow DittinK.._..._.. 0 I O. 12 I 1 .1 I U N GlM 2 (latch @ 3:30) 181 O.! 12 ) ~ c--lß2 5525 O. 12 3 III! I 183 5557 CL03 ¡ 1 · 184 5588 CL02 2 2.89 !II 185 5617 n 0.02 Ii .. 2.88 ~ , 186 5648 0.02 ¡ 2.87 1 17 5679 0.03 ¡ 2.88 1 18 5711 0.03 ) 2 2.89 Shallo~ nittim;¡:.Li:.· ---} ~. 5741 0.02 2.88 5772 0.02 ~ ~ .., 191 5803 0.01 192 5833 ì 0.02 I · _193 5864 ( 0.02 4 2.90 !II .-.- . '. 194 5895 ( dW 3 12 I 2.88 It. · Body Metal loss Body Page 4 I I I I I I I I I I I I I I I I I I I RT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in 3G-24 Kuparuk ConocoPhillips Alaska, Inc. USA November 10,2005 Well: Field: Company: Country: Survey Date: ¡oint It. Depth Pen. Pen. Pen. ,\l\eI;11 Min. Damage Protîle No. (Ft) I. i'Sf'! Body I.D. Comments (%wall) (1 I (Ins.) (Ins.) 0 50 100 __1;)2__ ~5CJ26 0 CL03 10 4 2.88 I 196 5957 0 0.01 4 ) 2.90 . ~J2ill!Q5j ts. _._ ~. ~.~~.~----~~~---------~--~ I .197_ 598í 0 0.03 ¡ I 2.812 198 6017 0 0.03 ¡ I ) 2.88 199 6047 0 0.03 I I 2.88 ...20Q 6079 0 CL03 10 ) '2~¿9 201 6109 0 0.02 8 2.812 202 6139 0 0.03 3 2.87 /III, 203 6171 II 0.02 ) 2.90 II! 204 6201 0 0.D2 4 2.90 III 205 6231 0 0.03 3 2 2.89 ~? -. 6262 0 O.fB 3 2 2.89 207 629L._ U 0.03 0 I 2.91 ") 6322 0.02 ¡ 2.88 I 2 P ") I ') pQsits. !IIIi I I 2 2.89 I ) 2.86 1.1. 2 3 U 0.03 I 2.88 214 )' (I 0.02 ( ) 2.90 --- (I 9 ) I .21:5--. ..... 6536 0.02 1,87 1.1. DeDosits. 0 9 2:B6· -- -..2lJi__ ._J2565._ 0.D2 I ~217.._. 6596 0 0.02 4 _.2,Jt') , .................... 218 6?27. 0 0.0) ) 2.88 I . 219 . 0JûL 0 0.02 ) 2.812.. _ U.[)fJ2osits. I--:W)' 6688 0 0.02 I 2.88 221 6718 0 0.03 ) ) 2.90 222 6748 0 0.02 , ).90 ____ ~~H 223 6779 0.03 J87 1.1. Deposits. 224 6809 CUB ).87 Shallow pitting. 224.1 6840 0 ( N/A CLM 3 (Latch @ 2:00) I 225 6847 0.D2 2.90 226 6878 Iì 0.D2 2.87 1.1. Deposits. --- . 227 6908 0.02 . 2.90 228 6939 2.90 Shallow pitting. ----_._.~..__.~---~-~~---- 229 6970 2.90 230 7000 2.89 I t ¡¡",nnelk 231 7032 2.87 I t ¡¡",nneÎk 232 7063 0.02 2.88 I 233 7093 0.02 2.90 234 7124 0 0.03 II 2.87 235 7154 0 (103 13 2.86 Shallow nittimL ~- _21 86.~ f' 0.02 2.89 7216 0.03 ) 2.88 .~-_..._- 238 7247 0.02 2.89 239 7277 0.03 ) 2.90 1.1. DeDosits. 240 ;;'308 0.02 2.89 241 7339 0 0.02 2.88 1.1. DeDosits. J 242 7369 0 0.03 ¡ 2.90 ~-----------~-~~------ 243 7401 U CUB 10 ·2'--'" 2.90 Body Metal Loss Body Page 5 I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3G-24 Kuparuk ConocoPhillips Alaska, Inc. USA November 10,2005 I I I r Joint Jt Depth Pel Pen. PerL I ;\!¡eI;11 Min. Damage Profile i No. (Ft) I Body ID. Comments (%wall) I I Ins) (Ins.) (Ins.) 0 50 100 _244._. 74i2 () 0.02 Ii ) 2.88 F1 245 7462 0.03 ] 1 I 2.89 i!IIJ - 12 !TIll 246 7492 O·D]_ 2.88 247 752.'1 .0.02 9 2.89 II 248 7554 I 0.02 i 2.90 1M! _249 7584 () OOi- 17 2.89 Shallow Ditting,_Jt. U<:J2Q?!!s.'-..._ i!IIJ ~^~_.~------ ~ 250 7616 0.02. {) 2.89 Lt. D (ill.Q511s,______ III ------ 251 7647 0.03 2.90 i!IIJ 252 7678 0.04 ... 2.89 Shallow niWI!K____....._.....__..__.___ ')1:"" 7709 ..0.03_ 2.88 SI )allº.\YJ?ittilliL.1t_QE>E()~its. I ~::u 254 7739 I 0.03 ¿ 2.90 Shallow Dilting. 255 -- 7770 I 0.03 2.90 255.1 7800 () 0 CLM 4 (Latch @ 1 :(0) 256 7807 () 0.02 2'17 7837 () 0.01 i I I 2Sf! if!(,fI (I 0 2SCJ 7900 () 0 Lt npnnçìtç 260 79iO I) 0 Lt ponnc;<.- 2(,1 7958 () 0 262 7988 I) CUB I) 2.87 Lt. Denosit.<;. 263 8019 n 0.02 () 2.91 L t. Df120SL1<;, ^~~~^'^ 264 8049 I) 0.0 :;=-----'-L. ) 2.89 Lt. Deoosits. 1--.- n 265 8079 OJU_. 9 2.87 266 8110 () QJ22 Ii ) 2.90 267 8140 () CUB 10 ) 2.86 Lt. DeJ.2i2ill~,_~_ - II 0.0_2__):1_ ) _268.. 8171 2.91 269 8201 n Q.02_ - - H ) 2.90 270 WI"? () 0.02 Ii I 2.89 "'- ~).... -- 271 8263 () 0.02.. (, I 2.91 ~~~------ 272 8293 () .0.02 Ii 2 2.89 L t. D~i)Osits. 273 8324 () 0.02 \) ! 2.90 .. 274 8353 () Q.03__ 13 4 2.89 Shallow oittin2:. 275 8383 () 0.03 II I 2.90 276 8414 I) 0.02 g I 2.88 277 8444 I) 0.02 g ) 2.90 278 8472 () 0.04 IS ) 2_90 Shallow oittilìQ. 279 8'104 I) 0.02 i 2.8f! I t nonn,,;t<- 280 Wii5 () CUB 12 2.89 281 8SM () I 0.02 \) 12,90. 282 8593 0 Ct02 (, - 2.90 ..- 'i 4 283 8622 0 0.01 2.90_ ---^ 284 8652 0 0.03 II 2.88 2J1L __[)§83 _ () 0.02 () ) 2.87 _28~L .. 8713 () 0 0 0 N/A GLM 5 (Latch @ 3:0m _286 8721 () 0.04 14 ) 2.86 Shallow Ditti¡w. Lt. Depo~l!L______ 1--_211L 8751 () 0.02 Ii I 2.88 I 288__ __ 8781__ () 0.02 () 2 2.89 ^^^~ ----- 28CJ 8811 () 0.02 () ) 2.88 I - 290 8841 I) 0.03 n 4 2.CJO Shallow oittin2:. 291 8873 () 0.01 6 I 2.90 Body Metal Loss Body Page 6 I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3G-24 Kuparuk ConocoPhillips Alaska, Ine. USA November 10, 2005 I I Joint Jt Depth PPII Pen. PPI\. ;\!tet:11 Min. Damage Profile No. (Ft.) ! .( Body ID. Comments (%wall) (Ins.) (Ins.) 0 50 100 292 8904 I' 0.02 13 3 2.1313 I I _293 -ä'-)34- ! 11,03" 13 3 2.90 Shallow Dittimr. Lt. DeDosits. 294 8964 0.03 10 2 2.90 295 13995 _0.02 9 1 2.90 296 9625~ 0.02 13 4 2.90 I 297 9056 0 0.04 14 ) 2.137 Shallow Ditting. Lt. DeDosits. " - . 298_ 9086 0 0.02 13 it 2.87 Lt. DeDosits. 299 9117 0 çLQJ H 3 2.90 i 300 9147 0 0.03 -- 3 2.91 301 9178 0 0.06 it 2.137 Isolated Ditting. 302 9209 ( 0.06 3 2.136 Isolated Ditting. Lt. DeDosits. 303 9239 ( 0.013 5 2.88 Isolated Ditting. Lt. DeDosits. 304 9269 0.06 ) 2.139 Isolated Ditting. 305 9300 0.04 :: 2.87 Shallow Ditting. '6 0.' )5 ) 2.139 Shallow Ditting. (J.; )2 3 2.90 I F'UP 0 0 riA CL A 6 IIÜrh Ii'¡) 10:(0) 9: 0 0.' 13 ) :)0 F'L III '7 9 0 0.1 )2 I 36 _to )eDosits. III I 3< ¡ 9' 0 0 fA :<-c VER TO 2.875 TUBINC I I I I I I Body Metal Loss Body I I I I I I I I Page 7 I ------ ------- - - - - - - S Rep rt Cross S ns Well: Field: Company: Country: Tubin : 3G-24 Kuparuk ConocoPhillips Alaska, Inc USA Survey Date: Tool Type: Tool Size: No. of Fingers: November 10, 2005 MFC 24 No. 99628 1.69 24 Tahtouh Cross Section for Joint 3 Tool speed = 56 NominallD = 2.992 Nominal OD = 3.500 Remaining wall area = 98 % Tool deviation = 56 0 at depth 9249.577 ft = 33% Wall Penetration HIGH SIDE = UP Cross Sections page 1 - - - - - - - - - - - - - - - - DS art Cross S ans Well: Field: Company: Country: 3G-24 Kuparuk ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: November 10, 2005 MFC 24 No. 99628 1.69 24 for 301 at depth 9198.616 Tool speed = 57 NominallD 2.992 Nominal aD = 3.500 Remaining wall area = 99 % Tool deviation = 52 0 Finger 10 Penetration = 0.062 ins Isolated Pitting 0.06 ins = 24% Wall Penetration HIGH SIDE = UP Cross Sections page 2 - - - I I Pipe: 8odyWall: Upset Wall: Nominal 1.0.: I I loint )t Depth No. (Ft.) I ...~L . 9420 .2 9425 .3 9442 9450 .5 9460 ~..ji.. 9467 .7 9476 I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH 2.875 in 6.5 ppf )-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3G-24 Kuparuk ConocoPhillips USA November 10, 2005 Comments Damage ('Yo o 50 100 Page 1 I I SSSV I (1785-1786. OD:3.500) I Gas Lift mdrel/Dummy Valve 1 I (2984-2985. OD:5.313) I I Gas Lift -------- ~ndrellDummy Valve 2 I (5497-5498. 00:5.313) Gas Lift mdrellDummy I Valve 3 (6847-6848. : OD:5.313) I Gas Lift- mdreifDummy Valve 4 (7804-7805. 00:5.313) I Gas Lift mdrel/Dummy Valve 5 (8715-8716. 00:5.313) I I Gas Lift ;¡¡ndrellDummy Valve 6 (9371-9372. 00:6.000) I PBR--- (9426-9427. OD:2.875) I PKR (9444-9445. OD:8.151) I Production mdrellOummy Valve 7 (9468-9469. OD:5A60) I I PLUG (9515-9516. OD:2.250) I ruBING : (9420-9527. OD:2.875, ID:2.441) SOS (9527-9528. OD:2.875) I '-- -- - - Pelt (9618-9658) I API: 501032014500 SSSVTvoo: TRDP Annular Fluid: Reference Loq: ~aQ: 9679 ~te: Description CONDUCTOR "" DescriDtion SUR. CASING .DDf"Ir'l1 Description ~OD. CASING Size 3.500 2.875 Interval 9618 - 9658 TVD 5839 - 5868 Gal Lift St MD ND Man Mfr -- -;2984 . 2305 MeMurra .'--, .=11II5497 ..3586 - av .__ 4282 av ~ 4781 av ~5279 av 9371 5668 MACCO Man Mfr 7 94681 57331 Cameo. 1 èâû¡i:I.""t, Depth ND Type 1785 1631 SSSV 9426 5704 PBR 9444 5716 PKR ~9515_. --====-_...5765 . NIP 5765 PLUG 5774 TTL 5774 SOS 005.'1 TBG LEAK @ - -- --- -- ~~-~^ ----- Well Tvoo: INJ Oria Co.mDletio.n: 10/12/1990 LastWIO: . __ _R_eflco.g Date: ___ ___ TD: 9940ftKB MaXHŒeAnQle~ I Size I TOD ~I ND 1 16.000 1 0 I 115 I 115 KRU 3G-24 Anale @ TS: 44 dea @ 9608 Anale @ ill: 41 dea @ 9940 Rev Reaso.n: TAG FILL PULL SL V. Set PluQ. TBG Leak Las, upo.a¡e: 1013012005 I Wt I Grade I Thread I 62.58 I H-40 I Size I Too I Bottom I ND I Wt I Grade I ThrealL 9.625 I 0 1 4572 I 3102 1 36.00 I J-55 I Size 7.000 I 1 I Bottom I 1 9930 1 Top o Too o 9420 ND 6074 I Wt I Grade I Thread 1 26.00 1 J-55 I I Bottom I ND I Wt I Grade I Thread : ~~~ : ~~~ : -Ws ~:~~: EUE :~~ :DMOD I lone 1 Status I Ft ISPF 1 Date I TVDe I Comment 1 A-2.A-1 1 1 40 1 4 1 11811991 4J~~' 1180 deg. phasing Date Vii, Run Cmnt 1.5 RK 1 0.000 I 0 I 11911991~ Descriptic~I1__~________. I ID 2.813 I 2.312 I 2.347 2.250 0.000 ---..- --..~.-------_._- .. - 2.441 ..- 2.441 Man Type I VMfr I FMHO FMHO FMHO FMHO FMHO SPM-2 Man Type VMfr TGPD IC\JI1!: DV V Type VOD DMY 1.0 BK DMY 1.0 BK DMY 1.0 BK DM'(_ ~__~ DMY 1.0 BK DMY 1.5 RK V Type VOD DMY Otis 'FMX' Cameo. 'OEJ' Cameo. 'HRP-1-SP' Cameo. 'D' Nipple 2.25" CA-2 PLUG set 9/22IgQQL____ Cameo. Letch Port TRO 0.000 0.000 0.000 0.000 0.000 0.000 o o o o o o Date Run 911911996 119/1991 11911991 911911996 11911991 9/1911996 VIII Cmnt Latch Port TRO **** LIS READ **** 90 -1.31/ ....I O~er ? ~~ 1q (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: 3G24 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ; ; ir~ ,(" !T~ I \ # ,. í ..,,~ .'~ t. i: ! 'v' L OCT 3 ï 11) ,', ('1 ") ,)u i.: /'lp//Q ():. & I', '. . \¡c·.,)V~ ",II \, U'è'-' "I-'~J" C'r .. . . . .. , u._; \.1_'1 c>. ..JI/JI[W;SIOD PdicnoragÐ . J¥dl( OFILMED Date /D/ ~Î.Lha I ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G24.MWD SERVICE NAME: SSDS VERSION #: V2.4 DATE: 90/10/19 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-24// API#: 5a-1a3-2a145//DATE: la-OCT-90 LOCATION: 2538' FNL & 270' FEL, SEC 23, TWP. 12N, RANGE 8E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA. USA// RIG: DOYON 14// CO. REP. PAUL WHITE// SSDS ENG.: HANIK & BRADLEY// COMMENTS: NEUTRON & DENSITY ARE CALIPER CORRECTED NO TOOL WEAR COMPENSATION REQUIRED. POST-JOB CALIBRATIONS MATCH PRE-JOB CALIBRATION WITHIN EXPECTED STATISTISTICS. NO TOOL MOTION CORRECTIONS WERE REQUIRED. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY DESCRIPTION 4 1 66 255 LOG DIRECTION, DOWN 0 1 66 TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 NFa MWD 0 0 0 0 1 4 0 1 68 NFl MWD 0 0 0 0 1 4 0 1 68 NNO MWD 0 0 0 0 1 4 0 1 68 NN1 MWD 0 0 0 0 1 4 0 1 68 GRC MWD API 0 0 0 0 1 4 0 1 68 NPSC MWD P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY DESCRIPTION 4 1 66 255 LOG DIRECTION, DOWN 0 1 66 TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 NFO MWD 0 0 0 0 1 4 0 1 68 NFl MWD 0 0 0 0 1 4 0 1 68 NNO MWD 0 0 0 0 1 4 0 1 68 NNl MWD 0 0 0 0 1 4 0 1 68 GRC MWD API 0 0 0 0 1 4 0 1 68 NPSC MWD P.U. 0 0 0 0 1 4 0 1 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR RHOB ROP CAL FXE NFO NFl NNO NN1 GRC NPSC 4300.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -899.325 4400.000 19.215 .500 -999.250 8.440 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -899.325 4500.000 10.988 3.250 68.555 8.600 .903 414.000 429.000 2360.000 2296.000 45.947 52.976 4600.000 6.392 1.990 171.946 9.650 1.495 527.000 493.000 2456.000 2376.000 82.223 40.821 4700.000 4.078 2.180 140.813 9.020 .600 511.000 497.000 2536.000 2520.000 76.226 40.919 4800.000 5.665 2.210 200.000 8.950 .583 543.000 519.000 2488.000 2488.000 93.482 41.406 4900.000 5.309 2.280 319.775 8.620 .574 519.000 519.000 2616.000 2552.000 85.186 41.879 5000.000 4.490 2.220 274.311 8.750 1.863 497.000 503.000 2360.000 2344.000 88.544 47.330 5100.000 4.719 2.290 270.578 8.660 .495 493.000 519.000 2472.000 2344.000 88.539 46.098 5200.000 5.211 2.360 194.854 8.690 .504 569.785 560.939 2543.263 2527.754 84.400 39.773 5300.000 4.207 2.350 281.250 8.550 .494 551.000 535.000 2664.000 2600.000 93.465 40.142 5400.000 4.440 2.330 202.769 8.570 .624 543.000 591.000 2664.000 2632.000 94.712 38.193 5500.000 4.141 2.210 296.837 8.780 .554 679.000 663.000 2856.000 2808.000 127.345 30.672 5600.000 4.050 2.340 207.003 8.620 .514 583.000 615.000 2744.000 2776.000 88.117 34.594 5700.000 4.301 2.330 205.479 8.820 .710 647.000 535.000 2920.000 2824.000 76.472 31.943 5800.000 3.672 2.260 297.070 8.700 .586 583.000 511.000 2728.000 2792.000 57.768 35.958 5900.000 3.451 2.360 177.204 8.770 .631 599.000 615.000 2776.000 2872.000 100.184 32.630 6000.000 2.902 2.680 196.037 8.730 .776 567.000 527.000 2728.000 2744.000 98.144 36.968 6100.000 3.756 2.630 238.630 8.520 .482 681.703 633.594 2871.784 2946.162 98.824 30.957 6200.000 3.752 2.540 307.617 8.780 .610 647.000 591.000 2936.000 2920.000 101.194 30.668 6300.000 4.322 2.390 230.713 8.710 .798 711.000 655.000 2840.000 3016.000 112.238 29.114 6400.000 4.051 2.550 197.985 8.780 1.020 599.000 631.000 2872.000 2952.000 93.213 30.892 6500.000 2.557 2.510 116.016 8.560 .953 559.000 527.000 2616.000 2696.000 91.972 39.144 6600.000 2.493 2.360 210.645 8.560 .924 570.552 557.816 2616.574 2572.735 95.704 39.689 6700.000 3.061 2.410 184.171 8.700 1.113 599.000 559.000 2376.000 2552.000 133.923 41.841 6800.000 4.456 2.480 192.920 8.630 .644 591.000 576.623 2550.454 2510.416 130.642 40.626 6900.000 4.998 2.600 218.796 8.640 .691 631.000 607.000 2600.000 2488.000 127.873 38.655 7000.000 3.644 2.560 228.076 8.640 .867 559.000 527.000 2360.000 2472.000 130.241 44.747 7100.000 3.613 2.410 218.796 8.630 .856 560.401 563.825 2705.897 2680.248 98.555 37.579 7200.000 3.821 2.290 86.886 8.610 .894 591.000 583.000 2712.000 2776.000 101.287 35.663 7300.000 4.130 2.370 164.835 8.790 .788 615.000 599.000 2664.000 2632.000 104.465 35.709 7400.000 4.029 2.420 259.654 8.600 .846 620.995 580.197 2627.211 2686.385 101.706 37.061 7500.000 4.410 2.410 222.001 8.720 .869 639.053 615.036 2733.833 2667.905 111.642 34.595 7600.000 4.384 2.370 195.408 8.710 .832 595.800 583.316 2726.192 2736.479 100.536 35.404 7700.000 4.775 2.390 180.134 8.770 .644 599.000 615.000 2808.000 2712.000 103.150 33.819 7800.000 4.625 2.480 218.279 8.980 .663 607.000 615.000 2760.000 2872.000 105.966 31.715 7900.000 4.576 2.400 168.750 8.990 .784 631.081 617.685 2669.423 2647.891 108.429 33.958 8000.000 4.189 2.500 247.383 9.030 .563 593.673 588.493 2713.643 2870.873 120.496 32.473 8100.000 4.650 2.440 202.344 8.680 .601 631.000 559.000 2776.000 2904.000 96.361 33.452 8200.000 7.911 2.610 51.563 8.790 .772 647.000 687.000 3112.000 3144.000 65.120 26.092 8300.000 4.757 2.450 105.971 8.790 .566 599.000 586.534 2733.396 2702.232 98.003 34.789 8400.000 6.183 2.520 202.539 8.710 1.088 599.000 575.000 2728.000 2664.000 101.520 36.189 8500.000 4.314 2.380 165.554 8.810 .681 599.000 599.000 2616.000 2584.000 111.677 37.054 8600.000 5.034 2.520 206.250 8.860 583.000 2776.000 2776.000 93.254 33.796 8700.000 4.548 2.500 226.861 8.930 615.000 2792.000 2664.000 130.569 33.542 8800.000 4.268 2.530 241.040 8.880 551.000 2600.000 2712.000 109.473 36.743 8900.000 6.534 2.490 151.904 8.900 647.570 2790.860 2817.717 82.895 31.155 9000.000 5.027 2.470 165.874 9.010 568.715 2530.289 2494.859 129.082 39.582 9100.000 5.094 2.490 115.816 8.910 583.000 2696.000 2680.000 99.210 34.489 9200.000 4.735 2.490 174.944 9.180 597.386 2540.807 2531.193 138.301 36.727 9300.000 3.705 2.260 68.588 8.820 649.600 2581.061 2530.122 249.945 40.049 9400.000 3.282 2.350 51.298 8.820 573.645 2390.546 2404.318 127.415 43.645 9500.000 2.480 2.410 84.702 8.920 538.398 2297.207 2394.935 123.569 46.639 9600.000 2.107 2.310 83.125 8.830 503.000 2321.485 2308.838 129.703 48.262 9700.000 6.589 2.520 68.787 9.080 577.260 2690.717 2763.667 84.637 33.930 9800.000 3.049 2.390 65.102 8.890 574.742 2662.861 2681.523 89.887 35.998 9900.000 -999.250 2.420 63.960 8.820 -999.250 -999.250 -999.250 91.598 -899.325 10000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -899.325 ** 543 DATA RECORDS ** FROM 4300.00 TO 10000.00 FT ** FILE TRAILER** FILE NAME: 3G24.MWD SERVICE NAME: SSDS VERSION #: V2.4 DATE: 90/10/19 MAX. RECORD LENGTH: 1024 FILE TYPE: EO NEXT FILE NAME: .692 .641 .705 .973 1.505 .793 .830 .946 1.018 1.011 .666 .873 16.530 -999.250 -999.250 ********** END OF FILE (EOF # 2) ********** 591.000 615.000 599.000 620.143 573.285 631.000 629.798 682.501 565.698 519.620 530.066 576.535 587.913 -999.250 -999.250 ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: 3G24 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********