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HomeMy WebLinkAbout183-180ORIGINATED TRANSMITTAL DATE: 5/31/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5441 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5441 2V-07 50029210550000 Injection Profile (IPROF) 9-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 183-180 T40505 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.30 13:07:54 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2V-07 KUPARUK RIV UNIT 2V-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2V-07 50-029-21055-00-00 183-180-0 W SPT 5691 1831800 1500 1140 1140 1140 1140 280 370 370 370 4YRTST P Bob Noble 6/14/2024 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 2V-07 Inspection Date: Tubing OA Packer Depth 370 2010 1900 1865IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240616142240 BBL Pumped:1.9 BBL Returned:1.4 Thursday, July 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.07.25 12:46:59 -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: CPAI 2V-07 (PTD # 183-180) Results of 30 day monitor period for suspect IA pressure fall off. Date:Thursday, December 16, 2021 12:37:31 PM Attachments:image001.png AnnComm Surveillance TIO for 2V-07.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, December 16, 2021 12:36 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2V-07 (PTD # 183-180) Results of 30 day monitor period for suspect IA pressure fall off. Chris- Kuparuk injector 2V-07 (PTD #183-180) is nearing the end of the 30 day monitor period. The well passed the initial diagnostics consisting of tubing and inner casing pack off tests, an MIT-IA and an IA DDT. Throughout the duration of the 30 day monitor the IA has shown no further indications of IA pressure fall off and will therefore be returned to normal injection status. If the well displays any indications of loss of integrity the well will be reported as required. Please let me know if you have any questions or disagree with the plan. Attached is a cop of the 90 day TIO plot and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, November 18, 2021 2:49 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2V-07 (PTD # 183-180) IA pressure fall off. Chris- Kuparuk injector 2V-07 (PTD # 183-180) has had an IA pressure fall off post operations charging the IA to establish the proper T/I/O pressure differentials. DHD will perform the initial set of diagnostics while the well is left on injection. Depending on the results of the initial tests, the well will remain on injection for a 30 day monitor period or the proper paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the 90 day TIO plot and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag" RKB (Est. 27' of Rathole) 7,255.0 6/3/2019 2V-07 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 6/3/2019 2V-07 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.5 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.5 Set Depth (ftKB) 3,097.6 Set Depth (TVD) … 2,685.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 36.7 Set Depth (ftKB) 7,446.2 Set Depth (TVD) … 6,178.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 18.7 Set Depth (ft… 7,113.3 Set Depth (TVD) (… 5,911.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 18.7 18.7 0.05 HANGER GRAY TUBING HANGER 3.500 1,900.8 1,758.6 38.89 SAFETY VLV BAKER FVL SAFETY VALVE, LOCKED OUT 11/1/87 2.813 6,816.7 5,681.4 40.95 PBR BAKER PBR 3.000 6,830.4 5,691.8 40.79 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 6,975.4 5,803.1 38.92 BLAST RING BLAST RINGS (3) 2.867 7,089.9 5,892.8 38.12 LOCATOR BAKER LOCATOR SUB 2.992 7,090.8 5,893.5 38.12 PACKER BAKER FB-1 PACKER 4.000 7,093.3 5,895.4 38.10 SBE BAKER SEAL BORE EXTENSION 2.992 7,111.4 5,909.7 37.97 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,112.8 5,910.8 37.96 WLEG BAKER WIRELINE RE-ENTRY GUIDE ELMD TTL @ 7116' during IPROF on 02/27/06 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,990.0 7,065.0 5,814.4 5,873.2 C-4, UNIT B, 2V -07 4/18/1984 12.0 APERF 5 1/2 CSG Gun 7,171.0 7,185.0 5,956.8 5,968.0 A-4, 2V-07 1/15/1984 4.0 IPERF 2 1/8" TT 7,197.0 7,228.0 5,977.5 6,002.2 A-3, 2V-07 3/12/1984 4.0 APERF 2 1/8" TT 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 6,771.1 5,647.1 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/2010 2 6,868.1 5,720.5 MMH FMHO 1 INJ DMY BEK 0.000 0.0 5/22/2010 3 6,937.0 5,773.3 MMH FMHO 1 INJ DMY BK 0.000 0.0 5/22/2010 4 7,075.0 5,881.1 MMH FMHO 1 INJ DMY INT 0.000 0.0 7/14/2015 Hi Seal Pkg Notes: General & Safety End Date Annotation 12/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: Locked Out 2V-07, 6/4/2019 7:18:55 AM Vertical schematic (actual) PRODUCTION; 36.7-7,446.2 APERF; 7,197.0-7,228.0 IPERF; 7,171.0-7,185.0 WLEG; 7,112.8 NIPPLE; 7,111.4 SBE; 7,093.3 PACKER; 7,090.8 LOCATOR; 7,090.0 INJECTION; 7,075.0 APERF; 6,990.0-7,065.0 INJECTION; 6,937.0 INJECTION; 6,868.1 PACKER; 6,830.4 PBR; 6,816.7 GAS LIFT; 6,771.1 SURFACE; 36.5-3,097.6 SAFETY VLV; 1,900.8 CONDUCTOR; 36.5-117.0 HANGER; 18.7 KUP INJ KB-Grd (ft) 36.01 Rig Release Date 1/16/1984 Annotation Last WO: End Date 2V-07 H2S (ppm) Date... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292105500 Wellbore Status INJ Max Angle & MD Incl (°) 45.67 MD (ftKB) 6,300.00 WELLNAME WELLBORE2V-07 From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2V-07 (PTD # 183-180) IA pressure fall off. Date:Tuesday, November 30, 2021 12:07:22 PM Attachments:image001.png AnnComm Surveillance TIO for 2V-07.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, November 18, 2021 2:49 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2V-07 (PTD # 183-180) IA pressure fall off. Chris- Kuparuk injector 2V-07 (PTD # 183-180) has had an IA pressure fall off post operations charging the IA to establish the proper T/I/O pressure differentials. DHD will perform the initial set of diagnostics while the well is left on injection. Depending on the results of the initial tests, the well will remain on injection for a 30 day monitor period or the proper paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the 90 day TIO plot and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag" RKB (Est. 27' of Rathole) 7,255.0 6/3/2019 2V-07 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 6/3/2019 2V-07 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.5 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.5 Set Depth (ftKB) 3,097.6 Set Depth (TVD) … 2,685.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 36.7 Set Depth (ftKB) 7,446.2 Set Depth (TVD) … 6,178.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 18.7 Set Depth (ft… 7,113.3 Set Depth (TVD) (… 5,911.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 18.7 18.7 0.05 HANGER GRAY TUBING HANGER 3.500 1,900.8 1,758.6 38.89 SAFETY VLV BAKER FVL SAFETY VALVE, LOCKED OUT 11/1/87 2.813 6,816.7 5,681.4 40.95 PBR BAKER PBR 3.000 6,830.4 5,691.8 40.79 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 6,975.4 5,803.1 38.92 BLAST RING BLAST RINGS (3) 2.867 7,089.9 5,892.8 38.12 LOCATOR BAKER LOCATOR SUB 2.992 7,090.8 5,893.5 38.12 PACKER BAKER FB-1 PACKER 4.000 7,093.3 5,895.4 38.10 SBE BAKER SEAL BORE EXTENSION 2.992 7,111.4 5,909.7 37.97 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,112.8 5,910.8 37.96 WLEG BAKER WIRELINE RE-ENTRY GUIDE ELMD TTL @ 7116' during IPROF on 02/27/06 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,990.0 7,065.0 5,814.4 5,873.2 C-4, UNIT B, 2V -07 4/18/1984 12.0 APERF 5 1/2 CSG Gun 7,171.0 7,185.0 5,956.8 5,968.0 A-4, 2V-07 1/15/1984 4.0 IPERF 2 1/8" TT 7,197.0 7,228.0 5,977.5 6,002.2 A-3, 2V-07 3/12/1984 4.0 APERF 2 1/8" TT 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 6,771.1 5,647.1 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/2010 2 6,868.1 5,720.5 MMH FMHO 1 INJ DMY BEK 0.000 0.0 5/22/2010 3 6,937.0 5,773.3 MMH FMHO 1 INJ DMY BK 0.000 0.0 5/22/2010 4 7,075.0 5,881.1 MMH FMHO 1 INJ DMY INT 0.000 0.0 7/14/2015 Hi Seal Pkg Notes: General & Safety End Date Annotation 12/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: Locked Out 2V-07, 6/4/2019 7:18:55 AM Vertical schematic (actual) PRODUCTION; 36.7-7,446.2 APERF; 7,197.0-7,228.0 IPERF; 7,171.0-7,185.0 WLEG; 7,112.8 NIPPLE; 7,111.4 SBE; 7,093.3 PACKER; 7,090.8 LOCATOR; 7,090.0 INJECTION; 7,075.0 APERF; 6,990.0-7,065.0 INJECTION; 6,937.0 INJECTION; 6,868.1 PACKER; 6,830.4 PBR; 6,816.7 GAS LIFT; 6,771.1 SURFACE; 36.5-3,097.6 SAFETY VLV; 1,900.8 CONDUCTOR; 36.5-117.0 HANGER; 18.7 KUP INJ KB-Grd (ft) 36.01 Rig Release Date 1/16/1984 Annotation Last WO: End Date 2V-07 H2S (ppm) Date... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292105500 Wellbore Status INJ Max Angle & MD Incl (°) 45.67 MD (ftKB) 6,300.00 WELLNAME WELLBORE2V-07 MEMORANDUM TO: Jim Regg P.I. Supervisor �(� FROM: Lou Laubenstein Petroleum Inspector Well Name KUPARUK RIV UNIT 2V-07 IInsp Num: mitLOL201116094200 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 23, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2V-07 KUPARUK RIV UNIT 2V-07 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21055-00-00 Inspector Name: Lou Laubenstein Permit Number: 183-180-0 Inspection Date: 11/14/2020 Monday, November 23, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2V-07 Type IIIA W TVD 5691 TUbing 1470 1470 -1 1470 1470 pTj) 1831800 'Type Test SPT ,Test psi 1500 ' IA 935 2210 - 2130 2100 BBL Pumped: 1.5 ' BBL Returned: 1.5 OA 220 280- zao , L -- Interval -- -L --- - -- 4YRTST P/F P - — Notes: Standard 4 yesr test Monday, November 23, 2020 Page 1 of 1 1�2U ZV-6-7 Regq, James B (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophiIIips.com> Sent: Monday, June 15, 2020 9:58 AM To: Regg, James B (CED); DOA AOGCC Prudhoe Bay; Wallace, Chris D (CED); Brooks, Phoebe L (CED)' > �" t>14g�3i� Subject: KRU 2V & 2W pad SW MITIA's 6-14-20 i Attachments: MIT KRU 2V-07 SI WELL 06-14-20 .xlsx; MIT KRU 2W-04 &08 06-14-20.xlsx; MIT KRU 2V PAD 06-14-20.xlsx 0 Attached are the 10-426's for the SW MITIA's performed on 2V and 2W pads 6-14-20. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM coROto:M'WpS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: ii m.reaoicDalaska.ocv AOGCC.Insoectorsfojalaskaaovi phoebe. brooksdialaska.aov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2V Pad 06/14/20 Beck / Green chris.wallace a.alaska aov 1`' (,I G7 I &310 Well 2V-07 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fail PTD 1831800 Type Inj N Tubing 2200 2200 - 2200 s 2200 N = Not Injecting Type Test P Packer TVD 5692 BBI -Pump 2.3 IA 690 3000 2880 2850' Interval 4 Test psi 1500 - BBL Return 2.3 OA 240 240 240 240 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type hi Tubing Type Test Packer TVD BBL PUMP IA Interval Test psi BBL Return - OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: 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 Notes: 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 Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test 1=Initial Test P=Pass G=Gas O= Other (describe in Notes) 4=Four Year Cycle F=Fail S=Slum/ V= Required by Vadanoe 1=Inconclusive 1= Industrial Wastewater O= Other (describe in notes) _ N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 2V-07 V WELL 06-14-20 i Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday,April 3, 2018 9:43 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2V-07 (PTD 183-180) Update 4-3-18 Attachments: 2V-07 90 day TIO 4-3-18.JPG; MIT KRU 2V-07 diagnostic MITIA&MITOA 3-5-18.xlsx Chris, KRU WAG injector 2V-07(PTD 183-180)was reported March 3, 2018 for an unexplained OA pressure increase. The well passed a diagnostic MITIA and MITOA after which the well did not exhibit OA pressurization during the 30 day monitor period. CPAI plans to return the well to 'normal'status at this time. A 90 day TIO, and 10-426 are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 4ftWELLS TEAM corocatops SCANNED 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, March 3, 2018 9:17 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of unexplained OA repressurization 2V-07 (PTD 183-180) 3-3-18 Attachments: 2V-07 schematic.pdf; 2V-07 90 day TIO plot 3-3-18.JPG Chris, KRU WAG injector 2V-07(PTD 183-180) is experiencing an unexplained OA repressurization. The well was returned to water injection in mid January,after having been shut in since October 2016. There have been recent repeated OA pressure bleeds when nearing its DNE of 1000psi. Between the return to injection after an extended shut-in period and increase in temperature in February, a thermal response was initially suspected to be the cause of the repressurization. DHD will be mobilized to perform an MITIA and MITOA to confirm barriers and then put on a monitor for 30 days, pending passing MITs. Follow-up communication will be provided at the conclusion of the monitor. Please let us know if you disagree with the path forward. Attached are the 90 day TIO plot and schematic. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 SCANNEV 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, March 08, 2015 4:28 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; CPF2 Prod Engrs; NSK Problem Well Supv Subject: RE: 2V-07 (PTD 183-180) Report of OA pressure rise update 03-08-15 Attachments: Picture (Device Independent Bitmap) 1.jpg; 2V-07 45 day TIO plot.JPG Chris, The additional monitoring period is almost complete. The IA and OA pressures have continued to maintain a good differential between the two. The pressure fluctuations appear to be thermally related and coincide with temperature spikes in injection. I have attached a 45 day TIO plot to cover the entire monitor period. It is ConocoPhillips intention to return the well to normal injection under AIO 2C. If there are any additional indications of communication, it will be reported and further diagnostics performed at that time. Please let me know if you disagree. SCANNEU 1 Well m2V- Notes: Start NaDate e 1x22'20015 Days 45 F #11/A End Date 3I8/2015 #NIA Annular Communication Surveillance 4000 _WHP LAP 2`00 OAP BHT - 12 2000 — 12 2500 — 12 Te 2000 0. - 12 1500A.4411 _P 1000Ilf — 12 E00 / � — 12 c 12 Jan-1E Jan-1E Jan-1E Jan-1E Feb-1E Feb-15 Feb-1E Feb-1E Feb-1E Mar-1E Mar-1E Mar-1E a000 w _ 515_- Sllf E. Ceo-la Mar-1E Date Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 • 2 From: NSK Problem Well Supv Sent: Monday, February 23, 2015 10:02 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: 2V-07 (PTD 183-180) Report of OA pressure rise 01-23-15 update 2-23-15 Chris, The monitor period on 2V-07 is nearing completion. Diagnostics with DHD were performed on 1/25/15 and all tests passed (MITIA/MITOA/T&IC-POTs). During most of the 30 day monitor period,the IA and OA looked to be cooperating, with only minor thermal fluctuations. However there was a larger OA pressure increase when a larger temperature spike occurred. Since we are monitoring for a slow leak, CPAI intends to extend the monitor out an additional 14 days to ensure that temperature swings are not masking a potentially smaller leak. Please let me know if you disagree with the plan. « File: 2V-07 90 day TIO 2-23-15.JPG » « File: MIT KRU 2V-07 Diagnostic non witnessed 01-25-15.xls>> Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 From: NSK Problem Well Supv Sent: Friday, January 23, 2015 8:10 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: 2V-07 (PTD 183-180) Report of OA pressure rise 01-23-15 Chris, KRU injection well 2V-07 (PTD 183-180) is experiencing an unexplained, slowly rising OA pressure. Yesterday a bleed was needed when nearing the OA's DNE pressure. The well is currently on water injection and CPAI intends to keep the well on injection during initial DHD diagnostics which will include MITOA/MITIA/OA drawdown/packoff testing. Pending passing tests, a 30 day diagnostic monitor period is planned to either refute the possible IAxOA communication or submit an AA application if communication appears to persist. A follow-up email will be sent at the conclusion of the 30 day monitor. The well will be shut in if either of the MITs fail. Please let us know if you disagree with the plan. « File: 2V-07 90 day TIO 01-23-15.JPG » « File:2V-07 schematic.pdf» Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 3 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, February 23, 2015 10:02 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: 2V-07 (PTD 183-180) Report of OA pressure rise 01-23-15 update 2-23-15 Attachments: 2V-07 90 day TIO 2-23-15.JPG; MIT KRU 2V-07 Diagnostic non witnessed 01-25-15.xls Chris, The monitor period on 2V-07 is nearing completion. Diagnostics with DHD were performed on 1/25/15 and all tests passed (MITIA/MITOA/T&IC-POTs). During most of the 30 day monitor period,the IA and OA looked to be cooperating, with only minor thermal fluctuations. However there was a larger OA pressure increase when a larger temperature spike occurred. Since we are monitoring for a slow leak, CPAI intends to extend the monitor out an additional 14 days to ensure that temperature swings are not masking a potentially smaller leak. Please let me know if you disagree with the plan. 1 Well Name 2V-07 Notes: Start Date 11/2512014 Days 90 End Date 2123/2015 Annular Communication Surveillance 4000 - — 134 _WHP _LAP 3500 OAP O'JHT — 132 3000 — 130 2500 — 128 on 2000 Ct. L — 126 1500 t � �r — 124 1000 r 1 500 — 122 0 120 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 Mar-15• ;ooc_ t.4001%ormo"li~whaisir. .,.1 15CC s•41 tl J 1000 SCA Sep-14 Dec-14 Mar-15 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr 909 From: NSK Problem Well Supv Sent: Friday, January 23, 2015 8:10 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: 2V-07 (PTD 183-180) Report of OA pressure rise 01-23-15 2 Chris, KRU injection well 2V-07 (PTD 183-180) is experiencing an unexplained, slowly rising OA pressure. Yesterday a bleed was needed when nearing the OA's DNE pressure. The well is currently on water injection and CPAI intends to keep the well on injection during initial DHD diagnostics which will include MITOA/MITIA/OA drawdown/packoff testing. Pending passing tests, a 30 day diagnostic monitor period is planned to either refute the possible IAxOA communication or submit an AA application if communication appears to persist. A follow-up email will be sent at the conclusion of the 30 day monitor. The well will be shut in if either of the MITs fail. Please let us know if you disagree with the plan. « File: 2V-07 90 day TIO 01-23-15.JPG » « File: 2V-07 schematic.pdf» Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907)659-7000 pgr 909 3 N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to• jim.reaaaalaska.gov, AOGCC.Inspectors(a)alaska.00v phoebe.brooks@alaska.gov chns.wallaceaalaska.00v OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT I PAD: Kuparuk/KRU/2V DATE: 01/25/15 OPERATOR REP: Hight/Riley AOGCC REP: not witnessed Packer Depth Pretest Initial 15 Min 30 Min. 45 Min. 60 Min. Well 2V-07 Type Inj. W TVD 5,692' Tubing 1,900 1,900 1,900 1,900 Interval 0 P.T.D. 1831800 Type test P Test psi 1500 Casing 975 3,000 2,975 2,965 P/F P Notes: Diagnostic MITIA OA 440 590 590 590 Well 2V-07 Type Inj. W TVD 5,692' Tubing 1,900 1,900 1,900 1,900, Interval 0 P.T.D. 1831800 Type test P Test psi 1500 Casing 1,175 1,225 1,225 1,225 P/F P Notes: Diagnostic MITOA OA 520 1800 1750 1740 Well Type Inj TVD Tubing Interval P.T.D. Type test Test psi Casing P/F - Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing, P/F - Notes: OA Well Type Inj TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Infecting A=Temperature Anomaly Survey 0=Other(descnbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2V-07 Diagnostic non witnessed 01-25-15 xls Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday,January 23, 2015 8:10 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: 2V-07 (PTD 183-180) Report of OA pressure rise 01-23-15 Attachments: 2V-07 90 day TIO 01-23-15.JPG; 2V-07 schematic.pdf Chris, KRU injection well 2V-07 (PTD 183-180) is experiencing an unexplained, slowly rising OA pressure. Yesterday a bleed was needed when nearing the OA's DNE pressure. The well is currently on water injection and CPAI intends to keep the well on injection during initial DHD diagnostics which will include MITOA/MITIA/OA drawdown/packoff testing. Pending passing tests, a 30 day diagnostic monitor period is planned to either refute the possible IAxOA communication or submit an AA application if communication appears to persist. A follow-up email will be sent at the conclusion of the 30 day monitor. The well will be shut in if either of the MITs fail. Please let us know if you disagree with the plan. SCANNED AN 2l13' 1 Well Name 2V-07 Notes: Start Date 1025,2014 Days 90 End Date 1,'23;2015 Annular Communication Surveillance 4000 _ 134 _MP IA 2`00 _OAP VJHT - 132 3000 n"\ - 13C 2.00 •� - 12E to 2000 Q. - 12c 100 I - 12z 1000 1 r E00 12� [i • • 12( Oct-14 Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-1E Jan-1E Jan-15 Feb-1F ;KC m _•J 5_C Oct-14 Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Cec-14 Jan-1F Jan-15 Jan-1F Feb-1F Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 2 KUP 2V-07 ConocoPhillips ° Well Attributes Max Angle&MD TD Alask2.Inc. Wellborn API/UWI Field Name Well Status Incl(°) MD 000) Act 131n1(ftKB) �anmPrvll,ps 500292105500 KUPARUK RIVER UNIT INJ 45.67 6,300.00 7,450.0 Comment H2S(ppm) Dab Annotation End Date KB-Grd(ft) Rig Release Date Well contig:-2V.07,10/4/2012 9 10 20 AM SSSV:Locked Out Last WO: 36.01 1/16/1984 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,209.0 5/15/2010 Rev Reason:DRILL DATES osborl 10/4/2012 Casing Strings HANGER,19 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.5 117.0 117.0 65.00 1440 WELDED Cooing Description String 0... String ID...Top(ftKB) Set Depth(f...Sot Depth(TVD)...String Wt...String...String Top Thrd ' SURFACE 95/8 8.921 36.5 3,097.6 2,685.5 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth If,..Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 36.7 7,446.2 6,178.5 26.00 J-55 BTC Tubing Strings a' Tubing Description String 0... String ID...Top(NKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 111 TUBING 31/2 2.992 18.7 7,113.3 5,911.8 9.30 J-55 EUE8rdABM I Completion Details Top Depth (TVD) Top Incl Noel... TOP(Ne) 09(13) P) Item Description Comment ID(In) c0NDuCTOR,� 18.7 18.7 0.33 HANGER GRAY TUBING HANGER 3.500 3e-117 lar 1,900.8 1,758.6 38.89 SAFETY VLV BAKER FVL SAFETY VALVE,LOCKED OUT 11/1/87 2.813 1 6,816.7 5,682.1 41.13 PBR BAKER PBR 3.000 6,830.4 5,692.2 40.94 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 SAFETY VLV, 1,901 6,975.4 5,803.1 38.92 BLAST RING BLAST RINGS(3) 2.867 in- 111 7,089.9 5,892.8 38.16 LOCATOR BAKER LOCATOR SUB 2.992 s 7,090.8 5,893.5 38.15 PACKER BAKER FB-1 PACKER 4.000 7,093.3, 5,895.4 38.13 SBE BAKER SEAL BORE EXTENSION 2.992 7,111.4 5,910.3 38.29 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,112.8: 5,911.4 38.27 WLEG BAKER WIRELINE RE-ENTRY GUIDE ELMD TTL @ 7116'during '2.992 (PROF on 02/27/06 SURFACE, A zerforations&Slots 37-3,098 Shot Top(TVD) Btm(TVD) Dens IT Top(ftKB)Bhn(ftKB) (NKB) (NKB) Zone Date (sh... Type Comment GAS LIFT, 6,990.0 7,065.0 5,814.4 5,873.3 C-4,UNIT B, 4/16/1984 12.0 APERF 51/2 CSG Gun 8,771 2V-07 7,171.0 7,185.0 5,956.9 5,968.0 A-4,2V-07 1/15/1984 4.0(PERF 21/8"TT 7,197.0 7,228.0 5,977.5 6,001.9 A-3,2V-07 3/12/1984 4.0 APERF 21/8"TT PBR,0,817 Notes:General&Safety End Date Annotation 12/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER,0.030 INJECTION. 0,808 INJECTION, 0,937 6.990.7,06 APERF.5 - INJECTION, - 7ION, LOCATOR, 7.090 t PACKER,7,091 SBE.7.093 ? illii. , NIPPLE.7,111 WLEG,7,113 Mandrel Details (PERF. Top Depth Top Port 7,171.7,185 (TVD) Incl OD Valve Latch SW TRO Run Stn Top(NKB) (ftKB) P) mow Model (in) Sore Type Typo On) (psi) Run Data Com... 1 6,771.1 5,647.2 41.40 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/2010 2 6,868.1 5,720.6 40.41 MMH FMHO 1 INJ DMY BEK 0.000 0.0 5/22/2010 APERF._-_ _ - 3 6,937.0 5,773.4 39.46 MMH FMHO ' 1 INJ DMY BK 0.000 0.0 5/22/2010 7,i W-7,228 4 7,075.0 5,881.1 38.29 MMH FMHO 1 INJ DMY 'BTM 0.000 0.0 5262010 Ext Pkg PRODUCTION 3J-7 446 . TD 7450 ect Well History File ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. } ~/~_- ._/ ~_ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other. No/Type [] Poor Quality Originals: [] Other: NOTES: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) ~'~ Logs of various kinds. BY: BEVERLY BREN VINCENT(~) MARIA Project Proofing BY: BEVERLY [] Other LOWELl, DATE: ?-'~ /S/ Scanning Preparation BY: Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: I~1 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: )/~'YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned (individual page [special attention] scanning completed) RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned,wpd ~~- ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ VO ~~~ ~~ ~~ Log Description NO.4985 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11 /25/08 2V-07 12096561 INJECTION PROFILg=' _ 10/31/08 1 1 3A-11 12100434 INJECTION PROFILE -_ 10/31!08 1 1 iG-09 12100434 INJECTION PROFILE ~ 3 ~ 11/01/08 1 1 2V-11 12061724 PRODUCTION PROFILE ~- ~ 11/02/08 1 1 2C-14 12096565 PRODUCTION PROFILE L~ - 11/04/08 1 1 30-01 11975792 LDL 3 11/05/08 1 1 3F-09 12100435 PRODUCTION PROFILE 11/06/08 1 1 2V-12 12096567 PRODUCTION PROFILE - 11/06!08 1 1 3A-07 12096568 INJECTION PROFILE '-' 3 11/07/08 1 1 2A-20 12100434 INJECTION PROFILE ~ 11/08/08 1 1 iG-17 11975792 LDL - 11/09/08 1 1 2U-04 12100434 INJECTION PROFILE f. 11/10/08 1 1 2U-05 12096572 INJECTION PROFILE ~ 11/12/08 1 1 1F-06 12100457 PRODUCTION PROFILE 11/13/08 1 1 iB-06 12080456 PRODUCTION PROFILE 11/13/08 1 1 18-05 12080457 INJECTION PROFILE ~(} 11/14/08 1 1 2U-f0 12080459 PRODUCTION PROFILE "~ 11/16/08 1 1 2C-15 12100462 PRODUCTION PROFILE C 11/18/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. L • MEMORAI~iDIJM TOE Jim Regg `~ P.L Supervisor ~~' ~~ ~-~(7~~T FROM: Jeff Jones Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June I t, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2V-07 KUPARUK RIV L7MT 2V-07 Src: Inspector NON-CONFIDENTIAL Reviewed Bv• P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 2V-07 Insp Num: mitJJ080610173603 Rel Insp Num: API Well Number: 50-029-210ss-00-00 Permit Number: 183-180-0 i Inspector Name: Jeff Jones Inspection Date: 6/2/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 iVlin. Well 2v-°7 Type Inj. I W TVD s69z i IA tsoo I sooo zs7o I zsso i p T. I ss IBOO TypeT s SPT Test psi ~ ~ soo p ~ t 7s ~ 2so zso j zso Interval 4YRTST p~, P ~ ,~ _ Tubing,, is00 tsoo I tsoo ! tsoo Notes' 3.1 BBLS diesel pumped; no exceptions noted. ~t9~~~~L% JUL ~ ~ ZQ~~ Wednesday,.lune 11, 2008 Page 1 of 1 J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM MISSION Mechanical Integrity Test OPERATOR: Phil/ips Alaska, Inc. FIELD I UNIT I PAD: Kuparuk I GKA /2V E-Mail to; Tom_Maunder@admin.5tate.ak.u5 and Bob_Flecken5tein@admin.5tate.ak.u5 DATE: 101912000 ~~Iiiiiiiilli: II: iil~i¡ili;t li¡¡llpA~R ,~ PTD: 1831790 S P DSL b.(jJ6 'f -.- .Nell #: 2V-06 S b,DeO COMMENTS: PRETEST START '15 MIN SO MIN :.'. REQ TaG TIME : TIME.. TIME Hi cASIN,t;; '. . T~~" TEST CSG TBG . TB~ . . TSG STAR1\¡¡ P F SIZE I WT (: GRADE SIZE PRESS PRESS CSG eSG eSG'. TIME m¡ :; PRESS PRESS.. . 'PRESS'. m~ :, :. /'! ?:;#I J.55 35" 1 11~):} ? 'no ;; ŒJ') 2,000 2,000 14:38 O0 1 15') ? S()[) 2,500 2.500 PTD: 1831800 I S I P I DSL I 5,692 I 7" / 26# / J-55 13.5" I 1,423 I 3,000 I 3,000 Well #: 2V-07 S 6,830 1,500 2,200 COMMENTS: PTD: 1840910 I G I P I DSL I 5,725 I 7" / 26#/ J-55 13.5" I 1,431 I 3,800 I 3,800 Well #: 2V-O8A S 8,285 1,500 2,320 COMMENTS: PTD: I I I I I I I 0 Well #: COMMENTS: PTD: Nell #: rOMMENTS: 0 TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER 8.5 P.P.G. 6.8 Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector OPERATOR REP SIGNATURE: Peter Nezaticky , AOGCC REP SIGNATURE: 0O1009-MIT KRU 2V-1.2,3.4,5,6,7,SA.xls 3,000 I 3,000 I 14:24 \°10 2,175 2,150 3,800 1 3,800 I 14:15 1O10 2,280 2,260 1010 1010 Grad. 0.35 0.00 0.44 0.00 0.00 WELL TEST: Initial 4 - Year X Workover Other Waived: Jeff Jones (Rev 9/23/99) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Kr:'f¡ l(ß~ Email to:Tom_Maunder@adminstate.akus;Bob_Fleckenstein@admin.state.ak.us; and Jlm_Re69@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2V DATE: 06/28/04 OPERATOR REP: Sauvageau 1 Arend - APC AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 2V-01 Type Inj S T.V.D. 5778 Tubing 1500 1500 1500 1500 Interval 4 P.T.D. 1831580 Type Test P Test psi 1500 Casing 1150 2200 2200 2200 P/F P Notes: Well 2V-02 Type Inj S T.V.D. 5705 Tubing 2150 2150 2150 2150 Interval 4 P.TD. 1831610 Type Test P Test psi 1500 Casing 1150 2700 2660 2640 P/F P Notes: Well 2V-03 Type Inj S T.V.D. 5689 Tubing 1150 1150 1150 1150 Interval 4 P.T.D. 1831640 Type Test P Test psi 1500 Casing 850 1920 1900 1900 P/F P Notes: Well 2V-04 Type Inj S T.V.D. 5538 Tubing 950 950 950 950 Interval 4 P.TD. 1831650 Type Test P Test psi 1500 Casing 150 1900 1890 1880 P/F P Notes: Well 2V-05 Type Inj S T.V.D. 5672 Tubing 2300 2300 2300 2300 Interval 4 P.T.D. 1831760 Type Test P Test psi 1500 Casing 950 1750 1720 1710 P/F P Notes: Well 2V-06 Type Inj G T.V.D. 5636 Tubing 2550 2550 2550 2550 Interval 4 P.TD. 1831790 Type Test P Test psi 1500 Casing 900 1700 1690 1690 P/F P Notes: Well 2V-07 Type Inj S TV.D. 5692 Tubing 2500 2550 2550 2550 Interval 4 P.T.D. 1831800 Type Test P Test psi 1500 Casing 900 1750 1720 1710 P/F P Notes: Well 2V-08A Type Inj S TV.D. 5725 Tubing 2450 2450 2450 2450 Interval 4 P.T.D. 1840910 Type Test P Test psi 1500 Casing 1550 2980 2900 2880 P/F P Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T est during Workover 0 = Other (descnbe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 2V 06-28-04.xls 7/13/2004 ALASKA OIL AND GAS CONSERVATION CC~vFISSION MECHANICAL INTEGRITY TEST " ' PRETEST' START 15 MIN ~ ...... *P *I TYPE OF PKR CASING TBG REQ TBG "' TIb~. TIME WElL ~ --- ANNULUS TVD SIZE/WT/GRADE SIZE'TEST CSG TBG TBG 2~G CCt4MENTS ~ *N FLUID MD PRESS PRESS CSG CSG CSG '.. PRESS PRESS PRESS ,,,, , , , , ,,,,,,, , , , , , , ~ , ,, ,,~, . ,, ,,, , , ,,~, , ,, ,, , , , ,~, ~, ,, ,, , ,,, , , *TUBING INJECI'ION FLUID: P ', P~ WATER INJ S - SALT WATER II~ H - HISCIIK~ INJF. A'TION .~. · . . ,$fz - - / 20 AAC 25.030(a) 20 AAC 25.412(c) 20 AAC 25.252(d) '--" STATE OF ALASKA "-" ALASk,-,, OIL AND GAS CONSERVATION COMN,,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other ~ 2. Name of Operator ARCO Alaska, In¢, 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 2013' FSL, 113' FWL, Sec. 8, T11N, R9E, UM At top of productive interval 1308' FSL, 1438' FWL, Sec. 17, TllN, RgE, Urvl At effective depth 1508' FSL, 1534' FWL, Sec. 17, T11N, R9E, UM At total depth 1559' FSL, 1559' FWL, Sec. 17, TllN, RgE, UM 11. Present well condition summary Total depth: 7450' measured 6181' feet Plugs (measured) true vertical feet Perforate [] Pull tubing [] Effective depth: measured 7356' feet Junk (measured) true vertical 6105' feet Casing Length Size Cemented Structural Conductor 80' 16" 218 SX CS II Surface 3073' 9-5/8" 800 Sx PF E & ~m+me~m~4e 250 Sx PFC Production 7421' 7" 320 SX Class G & ~ 250 Sx PFC Perforation depth: measured 6990'-7069', 7171'-7185' true vertical 5814' -5873', 5957' -5968' 5. Datum elevation (DF or KB) RKB 114 Feet 6. Unit or Property name Kuparuk River Unit 7. Well numbeL_____....... ........ 24/--Z ....... --.% ,-. 8. Approval number h g3-1RF) ) . --- _PI number 55_~0~ 029-210 10. Pool Kuparuk River 0il Pool Measured depth 105' 3098' 7446' ~ue Vertical depth 105' 2686' 6178' , 7197'-7228' MD , 5978'-6003' TVD Tubing (size, grade and measured depth) 3 1/2", J-55, 9.3# w/tail @ 7118' Packers and SS~Val~t~t~e~-~ ~'s~e~8c~Baker FB-1 pkr @ 709~i~,~',~,S~SV @ 1901' MD 12. Stimulation or cement squeeze sumll~/a~y V [~ ~ JUL - ! 1988 Intervals treated (measured) N?A Treatment description including volumes used and final pressure Alaska.0jl & Gas C0rls, C0/lllT/i$$10rl N / A Anchorage Prior to well operation Subsequent to operatio[n~nj'- ) Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2400 3720 0 160 250 0 0 2235 1500 1500 13. 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢~¢,~.,f./~ ~ ~/~./,~,.,~~ Title Form 10-404 Rev. 12-1-8~r~' Date ~)~ Submit in Duplicate ¢ . v Alaska, c. DRILLSITE STATUS REPORT DATE: //- 2 ~ ' ~'~ TIME: ,~- ¥'O~ DRILL$1TE ~.- ~/ , , , A ~ ~ pFTsiP TEMPCHOKE ?"CSG ,0"CSG GAS INJ METER WELL F BEAN PSI PSI TEMP HCF TOTAL SI/HR :REMARK q e. ~ 1(,.3 5.2' I?-2_Ii11o [vo 0 , lo Y. R l g 9 35° la/-2 55-0 ~-y.5- /',, !1 P. 13 5 q-~/- 95° ?o I Z ~. ~ 159 q~' 1'/-2 13 T. /1 1'// 3P z~ I ~ P ~ l~ 3p .. . TOT*L · ~, INJECTION WELLS,TATUS NO. N ~) A__OWABL~,__ ,. ~%JI.~W H ' 'CHART I TOTAL TOTAL J ~ TE_MP CHOKE 7" CSG 10"CSG METER CALC INJ INJ WELL ~r/" PSI F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR I ~.z. ,'9 ~ ~9°~ 2~ /~-25 ~-oo ~.,2~- .. ?ff2 .. o 2 ~,0 ~ %o17 l~o 320 , , q ~Z~ ~ 99°3~ ~ (~ ~3~o9 3z?~ ,, ~ ~z ~ ~99o 1¢ 1/~' ~o2z~33 13~/ o E ~z R ~ 235-0 ll~o 137~o ~3~ o HzO HEADER PRESS = 2Z~O =~ 99° TOTAL FOR O.S. m~o~ ® /z'q~"- q-s° DRILL SITE PROD TEST PROD TEST BATH BLANKET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI OUT I~° 1~2° !~3 I~S l?~' if ~ CHEMICALS TYPE GAL/DAY STATE OF ALASKA ALA,..A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 114' feet 3. Ad~l~)eS~Ox 100360, Anchorage AK 99510 6. Unit or P[,o. perty name , Kuparuk ~lver Unit 4. Location of well at surface ~¢~11 number 2013' FSL, 113' FWL Sec .8 T11N R9E UM At top of productive interval ' ~ ' ' 1308' FNL, 1438' FWL, Sec. 17, T11N, RgE, UM At effective depth 1508' FNL, 1534' FWL, Sec. 17, T11N, RgE, UM At total depth 1559' FNL, 1559' FWL, Sec. 17, T11N: RgE: UM 11. Present well condition summary Total depth: 8. Permit number P~r..~.i t #83- !80 9. APl number 50-- 10. Pool Kunar~lk Rivpr (lil Pnnl ! measured 7450' MD feet true vertical 6181' MD feet Plugs (measured) None Effective depth: measured 7356' MD feet true vertical 6105' MD feet Casing Length Size Structural Conductor 80' 16" Surface 3073' 9-5/8" Production 7421 ' 7" xxlxi~(XXXXX Perforation depth: measured true vertical Junk (measured) None Cemented Measured depth 218 SX CS-II 105' MD 800 SX PF-E 3098' MD 250 SX PF-C ~ue Vertical depth 105' TVD 2686' TVD 320 SX Class G & 7446' MD 250 SX PF-C 6990'-7069' MD, 7171'-7185' MD, 7197'-7228' MD 6178' TVD 5814'-5873' TVD, 5957'-5968' TVD, 5978'-6003' TVD Tubing (size, grade and measured depth) 3-1/2", J-55, 9.3# w/tail @ 7113' MD Packers and SSSV (type and measured depth) Baker FHL PKR @ 6830'/Baker FR-1 P~[~ ~ 709!'/Baker FVL SSSV @190!' MD 12.Attachments Description summary of proposal [] Detailed operations program (Proposed Conversion to Waterflood In~ectnr~ ~-~ ~.. 13. Estimated date for commencing operation 14. If pr~o~l ~ v~ly approved Su~uent Work Repo~ ~ Alasl.::~ Name of approver Fo~No./O' Yd~Dat~/~z~ Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /'~d~,-~ //~ ~c~,.~4...i¢7~¢'). Title Sr. Operations Engineer Y Commission Use Only Conditions of approval Approved by [] Plug integrity [] BOP Test~.~FI Location clearance ~o;':~'-'~ ~ ........ by order of -- · ~ Commissioner the commission Date'~ Form 10-403 Rev 12-1-85 Submit in triplicate APPI.ICATION FOR SUNDRY APPROVAL - ATTACHMENT Proposed Conversion of Kuparuk Well 2V-7 to Water Injection Service ARCO Alaska, Inc. ARCO Alaska, Inc. proposes to convert Kuparuk Well 2V-7 from oil production status to water injection service in order to increase recovery of drill site 2V reserves through waterflood. Conversion will complete the direct-line-drive pattern on the Eastern side of drill site 2V. Conversion will initially allow water injection into the 'A~ Sand as part of the ongoing Water-Alternating-Gas (WAG) injection project currently in-place at this drill site. Future water injection into the 'C~ Sand may also take place. ~A~ Sand water injection is proposed to commence approximately July 15, 1986. · . · ~ ....... ~-."-~' t ¥" ~:'-: ;-2';-i~.)i' STATE Of ALASKA ' ' ALASKA ~L AND GAS CONSERVATION CC~vlMISSION D LOG 1. Status of Well Classification of Service Well REV i 5ED OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICEx] WAC INJECTOR .. 2. Name of Operator 7. Permit Number ARCO Alaska, lnc. 83-180 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21055 4. Location of well at surface 9. Unit or Lease Name 2013' FSL, 113' FWL, Sec. 8, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1308' FNL, 1438' FWL, Sec.17, TllN, R9E, UM 2V-7 At Total Depth 11. Field and Pool 1559' FNL, 1559' FWL, Sec.17, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 114'I ADL 25655 ALK 2581 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 1§. Water Depth, if offshore 16. No. of Completions 01/07/84 01/15/84 04/18/84* N/A feet MS L 1 17. Total Depth (MD+TVD) !18. Plug Back Depth (MD~TVD)19. Directional Survey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 7450'ND, 6181 'TVD 7356'HD, 6105'TVD YES ~] NO [] 1901 ' feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, GR/CBL/CCL, Gyro, CCT,/Temg. log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 105' 24" 218 sx CS II 9-5/8" 36.0# J-55 Surf 3098' 12-1/4" 800 sx PF E & 250 sx PFC 7" 26.0# J-55 Surf 7446' 8-1/2" 320 sx Class G & 250 sx PFC 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) . Perforated w/12 spf, 120° phasing 3-1/2" 7113' 6830' & 7091' 6990 ' -7065 'MD 5814 ' -5873 ' TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. Perforated w/4 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7171'-7185'MD 5957'-5968'TVD See attached Add.;ndum, dated 12/29/87, 7197'-7228'MD 5978'-6003'TVD for fractur, data. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested .PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. COREDATA D j~'"'~ !V I- Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Ii\ L ~ ."-- ~-~ None jAi~ 2 2 ?'";~"~ .L:.' :) ~sl~ 0ii & Gas Cons. C0mm,. Anch0r~.ge *Note: Drilled RR 1/16/84. Perforated well & ran tubing 4/18/84. Perforations added 5/7/84. Fractured well 8/8/84. wC4/33: DAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... NAME ............................... In'clYde i~terval t~ted~ Pressure data, all fluids r~°ver~ and graviW,' ..... MEAS~ 'DEPTH TRUE VERT. DEPTH GOR, and time of each phase. _ . . ~ ...... ~ ...... . ; · .. ; . · Top Upper Sand -,6989 ~ 58i3 ~ N/A . ... ' , :~-, i ~, " Base Upper Sand 70~8~ 5859~ Top Lower Sand '~' .~' 7151~ 59~1~ ':- ...:. ,.~ ,:' :.-" ,-'. . - .' Base Eower Sand 7322~ 6077~ -' ..... ,~: ,;:. :~ ~_,. . ~:: ~.~..'[' ~.'¢ , .... , .:' . . ..3 :. . : .: :':~ ,';, I ;.".-~ ;_~ ~ ; . : ,'., , · .. ' .. . . . · ' ...::.i:, ',, . ' '" . . - . . ~ . , . . _ . 31. LIST OF ATTACHMENTS Addendum (da~ed 12/29/87) . 32. I hereby ce~ify that the foregoing is' true and corr~t to the best of'~Y knowledge · : :~ : ~.. -, ,.: ._: . · ~;- .' ... .:. INSTRUCTIONS .. General: This form is designed for submitting a complete and correct well Completion report and log on all types of lands and leases in Alaska. Item 1' ClaSSifiCatiOn of serViCe Wellsi JGas 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 pertinent to such interval. Item 21' Indicate whether from ground level (G L) 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 ADDENDUM WELL: 2V-7 8/5/84 8/6/84 8/7/84 8/8/84 MIRU Camco E-line unit. Test BOPE lubricator to 2500# psi. RIH w/CCL/temp log from 7300' to 6800' for static baseline. Dropped back downhole to tagged fill at 7341'. TOH w/CCL/temp log. RD Camco. Secure well. B.J. Hughes to check out frac equipment. Add volume to frac fluid tanks. Frac of "A" sand postponed until flow test of "A" sand complete. Restriction milled out. Wait on frac. Finished 24 hr shut-in. RU B.J. Hughes. Pressure test lines at 5000 psi, ok. Pressure test 3-1/2" x 7" annulus to 1500 psi, ok. Hole safety meeting. Fracture stimulate "A" sand perfs 7171'-7185' and 7197'-7228' w/lO00# 100 Mesh SN and 11,100# 12/20 SN. R/A tagged w/7390 gal gelled water and displaced w/2600 gal gelled diesel. Air 12.0 pbm at 3700 psi. ISIP 2770#, Frac in lace 1430 hrs, 8/7/84. Bleed annulus pressure to zero. RD B.J., MIRU Camco. Test lubricator and WL BOPs at 3500 psi, ok. Run CCL/temp log f/6800'-7300'. POOH to 6800' to rerun at specified intervals. SITP 800 psi. RECEIVED Co.,h ........ /2._ / S/A? ' -/Date ~ ~':~'~: ARCO Alaska, Inc. ~ .~ ~_~- ~?=' ~ ...... .~~~'~ !~_ Post Off,ce Box 100360 ~~??~ ^nchor=ge, A~=~k~ 9~5~0-~3~0 ' Telephone 907 276 1215 ~' ~-~ ~ January ~ 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk Water Injection Wells for the fourth quarter of 1986. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachme~qt !. If you have any questions concerning the information reported, please contact me at (907) 263-4386. Si ncerely, ~---.~ (~7~, ~. Roberts, dr. Operations Fn§ineer JWR/SPT' 'pg'O052 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlenlicRichlieldCompany '~'-;~_.~. ATTACHMENT 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FOURTH QUARTER 1986 SUBMITTAL WELL NUMBER APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY SURVEY 20706 20711 20713 21234 21210 21307 20950 21281 21055 02/22/83 03/01/83 03/01/83 11/16/85 lO/28/85 lO/28/85 11/01/85 11/11/86 11/27/86 12/86 12/17/86 12/26/86 11/22/86 11/23/86 11/2q/86 11/25/86 12/85 12/85 SURVEY SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SURVEY SURVEY FOLLOWUP FOLLOWUP FOLLOWUP NITIAL NITIAL NITIAL NITIAL NITIAL NITIAL WELL COMPLETION ZONES TAKING WATER INJECTION BWPD A&C SS A 1347 A&C SS ' A&C A&C SS A&C A&C SS A&C A&C SS A~C A&C SS A&C A&C SS A&C A&C SS A 4000 A&C SS A 974 ARCO Alaska, Ir~~''*'- Post Offic, -,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in'form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85,'prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED SEP 2 0 Alas~;a 0~ ~ ~s .Cons. Commission .. ^r~chorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '-', ALASF/-"OIL AND GAS CONSERVATION ~.OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well , COMPLETED WELL OTHER [] N/A 7. Permit No. see attached 8. APl Number s0- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 1 1. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i l Po0] N/A I see attached 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: {Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans r"] Repairs Made Pull Tubing [] Other X~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) (Submit in Duplicate) [] Altering Casing [] [-] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of J^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion.~ to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SEP 2 o 19B5 AlasKB Oil & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /~'~ ~~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-$0 Approved Copy .Returned / By Order of COMMISSIONER the Commission Date__ Submi~ "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 ' 8 2D- 2 -- 4 - 5 - 7 _10 -11 -14 -16 2E-10 -12 '-13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 ' 4 - 7 -11 -14 -16 2V- 2 - 4 -- 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK: 0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 2O 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 25658 25657 I! 25656 25644 25643 25655 25644 25655 25642 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " lO/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 !! Alaska Oil & G~s Cons. Co,mm .... or~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Receipt of the following material which was transmitted via ~.J"~-~~' /'~-,¢'~>'/ .,, is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy YES sent tO sender N0 ARCO Alaska, Inc. ~/~.__..,, ~'o.' 0.~'~,~:,4':~, 35C, '~e:ephor, e 907 277 5637 Date: 10/05/84 Transmittal No: 4739 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 tted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU Surveys/Pressure Analysis lB-2/' 9/08/84 1F-2 9/15/84 . 2V-6 ~ 8/17/84 2V-7 8/17/84 2V-3 8/17/84 2C-6 8/18/84 Camco Otis I! II !I II ll SEQUENCE OF EVENTS 9/08/84 SB~ 9/15/84 8/17./_84 ( PB'Ul' ..--' 8/17/84 SET 8/17/84 ,::t PBU- ;'~;;--~ · _. · 8/18/84 c-' ?BU \. ~.. ....... /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron D&M Dzilling DISTRIBUTION ' ':" . i:~f-?~:. '"'~ W.V. Pasher :, ,. C. R '"'Smith G. Phillips State of Alaska Geology Phillips Oil Sohio Mobil J.J. Rathmell Union KSK Operations R & D Well Files ARCO Alaska, Ir Post Office dox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 31, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2V Pad Wells 1-8, 8A Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944, Sincerely, · Gruber Associate Engineer JG/tw GRU1/L20 Enclosure If :-: C~ ' ft ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany *' I* PHASE I-A 3UILT WELLS I thru 8 A DR~'~-'.' SITE g-V CONDUCTORS A,~- c3UILT LOCATIONS REV. I: CHANGE WELL NUMBERING PER NSK DRILLING, REMOVE PROPOSED LOCATION 1,2,11 & 12. REMOVE NOTE RE: ORIGINAL LOCATIONS 7 58; SHOW AS. BUILT LOCATIONS FOR CONDUCTORS 5 E~ 6. REV. 2:; ADD CONDUCTOR 8.A. Y:5,966,598.45 LAT. 70° 19'11.8641" X-- 508,42.1.81 LONG. 149055' 54.2.15" 168' FEL 1893'FSL Y= 5,966,718.54 LAT. 70° 19' 13.0452'' 'X= 508,421.75 LONG. 149° 55' 54.215'' 167'FEL 2013' FSL :5 Y=5,966,838.52 LAT. 70°19'14 2254" X: 508,42.1.94 LONG. 149°55'54 ,7.04" 166' FEL 2133' FSL Y=5~966,958,61 . LAT. 70° 19'15.4065" X= 508,47-1.81 LONG. 149° 55' 54.20:5" 166' FEL 2_253' FSL Y=5~966,958.46 LAT. 70° 19' 15.4020" X= 508,701 .94 LONG. 149°55~46.028" 114' FWL 2253'FSL " X= 508,701 .9?- R£CEIV £ ,,.' 8 ' 7 Y=5~966~718.55 ~fl~,.~ X= 508,701.89 DAVID LUC( II :5' FWL Ataska Oil & Gas 5276- _ Cone. Cor, m~8 .. ¥=5,966,598.58 ,..,., ,,. . ,Anchorage l~O~x= 508,70~ .BS ~'$$J0,'{ ~ ' J II ?-' F W L 9A Y= 5,966~590. LOCATED IN PROTRACTED SECTIONS 7 ~8 ~ x- 508,70~ 89 TOWNSHIP IIN.~ RANGE 9 E.~ UMIAT MER. .~ ~' FWL ' .aTE, a,S~s OF LOCiPrO. ~S MO.U~ENT ~Z-~ S ~X I 6 Y=5~ 966~838.50 LAT. 70°19'14.2221" LONG. 149°55'46.033'' 2133' FSL LAT. 70°19'13.047-0" LONG. 149° 55'46.037" 2013' FSL LAT. 70° 19'11 .8673" LONG. 149° 55'46.042-" 1893' FSL LAT. 70°19'11.7798'' LONG. 149°55'46.042:" 1884 ° FSL I HEREBY CERTIFY THAT' I AM PROPERLY '- REGISTERED AND LICENSED TO PRACTICE · LAND-SURVEYING IN THE STATE OF .~LASKA AND THAT THIS PLAT REPRESENTS A SURVEY · MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCT. P_.O~ 198:5. CONDUCTORS 5 & 6 SURVEYED NOV. 5 , 198:51 8.A SURVEYED JULY 11,1984. ARCO Alaska, Inc. Kuparuk Project North Slope Drilling DRILL SITE 2-V AS- BUILT CONDUCTOR LOCATIONS date: NOV. 9 , 1983 drawn by: E.W. IClll: ! "= 400 dwg. no.: 9.05.222.11d2 rev. August 3, 19B4 Arco Alaska Inc. P.O. Box 360 Anchorage, A1 aska 99510 To Whom This MaY concern' and 2V-6 are headings- The final printS for the Kuparuk CBL logs for Wel-1 2V-? being redistributed because we inadvertentlY switched please return all CBL final prints for 2V-6 and 2V-? that are not labeled as corrected copies- 'David Douglas RECEIVED AUG 2 4 l 84 Alaska Oil & Gas Cons. Commission Anchorage p.O. E)ox 102436 Anchorage, AK 99510 Telephone (907), 562.2538 KUPARUK ENGINEERING Transmittal / Date Run # DISTRIBUTION NSK Operations Dr il 1 lng .G, ~'lb§y/Ken ~tate of AK Blueline ,~m-~ / Bluellne & Sepia Sign & return the attached AlaSka O# & Ga$_~on$ Comm' ATTN: - ' .... ~ ATO-1115B P.0. Box 100360 Anchorage, AK 99510 CH ]~l~Jm L. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 7, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2V-7 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to fracture this well. Since we expect to start this work on August 7, 1984, your earliest approval will be appreciated. Verbal approval for this work has been received from M. Minder, AOGCC. If you have any questions, please call me at 263-4970. Sincerely, Area~-D'ril 1 ing Engineer JBK/JG/tw GRU8/L85 Enclosures RECEIVED AUG 0 7 198~ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~", STATE OF ALASKA __*-'-XM iSSiON ALASKA ',..., L AND GAS CONSERVATION C( SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~]X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-180 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21055 4. Location of Well Surface: 2013' FSL, 113' FWL, Sec. 8, TI.IN, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 114' 6. Lease Designation and Serial No. ADL 25655 ALK 2581 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2V-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations ~ Abandon [] Stimulation Stimulate Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to fracture this well. This work will be done as follows: 1. MIRU E-line unit. Run Temp/CCL log. 2. RU frac equipment and pump frac. 3. Run post-frac logs. 4. RD E-line unit. Estimated Start: August 12, 1984 Verbal approval received from M. Minder, AOGCC, 08/07/84. RECEIVED AUG 0 7 Alaska Oil & Gas Co~s. Commissi0p Anchor~?,; 14. I hereby ce, r,t~fy that the foregoing is true and correct to the best of my knowledge. // Signed Title The spac w~o sion use Conditions of APprov~l,~f any: Date · ~T i,SN~IE C. SMITH B¥Orderof Approved by. COMMISSIONER the Commission Approved .Cop,/' Returned Date Form 10~,03 GRU8/SN26 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELLS 3 thru¢_~ · · -~-', 5276- S ........ LOCATED IN PROTRACTED SECTIONS TOWNSHIP !1~, RANGE 9E.~UMIATMER. NOTE:BASIS OF LOCATION IS MONUMENT 32-1 I~ ?_X SOUTH; BASIS OF ELEVATION iS TBM 83-43-25 AS SET BY LHD E~ ASSOC. REV. I: C'('~,GE WELL NUMBERING PER NSK DRILLING, ,,FMOVE PROPOSED LOCATION i,2_.,II Et, IZ. REMOVE NOTE RE: ORIGINAL LOCATIONS 7 & 8; SHOW AS-BUILT LOCATIONS FOR CONDUCTORS 5 8~ 6. Y: 5,966,598.45 X: 508,4Z1.81 168' FEL LAT. 70° 19' I 1.8641" LONG. 149°55'54.Z!5" 1893' FSL . Y= 5,966, 718..54 'X: 508, 4ZI.75 167' FEL LAT. 70° 19' 1:5.045Z" LONG. 149° 55'54.?_13" 2013' FSL Y= 5,966,838.52- X= 508,4ZI.94 166' FEL LAT. 70° 19' 14 .2254" LONG. 149°55'54 204~ 2135' FSL 'f:5,966,958.6 I ×: 508,47-1.81 166' FEL LAT. 70° 19' 15 . 4065-~ LONG. 149° 55'54.203" 2253' FS L y:5,966,95B.46 X: 508,701 .94 114' FWL LAT. 70° 19' 15.4 020" LONG. 149° 55'46-028" 225:5' FS L _ . Y=5,966,838.50 X= 508,701 , 114 FWL LAT. 70° 19' 14 . 2221 ' LONG. 149° 55'46-033" ?133' FSL Y:5,966,718 X: 508,701 I I 3' FWL LAT. 70° 19' 1:5.0420' LONG. 149° 55'46.037" ZOI3' FSL 8 . Y:5,966,598.58 X: 508,701.86 IIZ' FWL LAT. 70° 19'11 .8623" LONG. 149° 55'46.04P-" 1893' FSL Ajask8 Oil & f:r:-~ go;t:.4..: :.-:i:fitl;sJ011 I HEREBY CERTIFY THAT' i AM I~ROPERLY-- .REGISTERED AND LICENSED TO PRACTICE 'LAND -SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVE MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCT. 20~ 198;5. CONDUCTORS 5 8~ 6 SURVEYED NOV. 5 ~ 1983. ARCO Alaska, Inc. Kupmruk Project North Slope Drlllin DRILL SITE 2-V AS- BUILT CONDUCTOR LOCATIONS dalm' NOV. 9 , 198~ I $cal,' I"= 400 dr=wn by' E.W. I dwg. no.' 9.05.22Z.I: rev. I KUPARUK ENGINEERING Well Name: Transmittal LOG- DISTRIBUTION NSK Operation Blueltne Dr il 1 ing Bluellne Geology/L. J. B1/Se R&D Bluellne D&M Blueline State B1/SE F.G. Baker Bluel/ne G eology/Ken Film ECEIVE sign & return the attache copy as receipt A,:..,a ',- & Gas Cons. Return to: ARCO ALASKA, INC. ATTN: ATO-1115B P.0. Box 100360 Anchorage, AK 99510 OHFinal ALASKA OIL A#D GAS ~,OflS£1TVATIO# ~,O.~lf~ISSIO~ Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501=3'192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~-/~-~/ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please 'submit the above missing material. Sincerely, Chairman KUPARUK ENGINEERING Well Name: Transmittal Date ,_ ~/z ~/~o o/I-7 Run # (oqq, ~, a CO~p~I. DISTRIBUTION NSK Operations Drilling Geolbgy /Keri State of AK Bluel~ne Blueline Film Blueline & Sepia Sign & return ~e~a~~d copy as receipt of" ~"~ ;',,l, '-'"v/~'9. f.3 Return to: ARCO A~S~, INC. ATTN: Pau~ ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ARCO Alaska, Ir'~'''' Post Offic,. ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 26, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2V-7 Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263 -4944. Sincerely, d. Gruber Associate Engineer JG:tw GRU7/L15 Enclosure RECEIVED MAY 2 2 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~-'"~- STATE OF ALASKA . "'-- ~'~__.__ ALAS~ .)IL AND GAS CONSERVATION ~, MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG K 1. Status of Well Classification of Service Well ~ OIL [~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-180 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21055 4. Location of well at surface 9. Unit or Lease Name 2013' FSL, 113' FWL, Sec.8, T11N, PgE, UN ~A~:~N-~ Kuparuk River Unit At Top Producing Interval ~ VERIFIED . lO. Well Number 1308' FNL, 1438' FWL, Sec.17, T11N, PgE, UN~_.~?:.~i~, 2V-7 At Total Depth i!~ H~ ~"- l~ 11. Field and Pool 1559' FNL, 1559' FWL, Sec.17, TllN, PgE, UM t-~--'L--&'-'~:~-~/~-----~lKuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 114' RKB ADL 25655, ALK 2581 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/07/84 01/15/84 04/18/84 N/A feet MSL 1 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7450'MD,6181 'TVD 7356'MD,6105'TVD YES I~ NO [] 1901 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 218 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3098' 12-1/4" 800 sx Permafrost E & '.50 sx Permafrost C 7" 26.0# J-55 Surf 7446' 8-1/2" 320 sx Class G & 250 s:( Permafrost C 2~. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7113' 6830' & 7091' 6990' - 7065' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED-~I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F! 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alaska Oil & 6,.% r, ~. ,,.,o ,o. Comnfission Anchorage Form 10-407 GRUT/WC08 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . . . Top Upper Sand ' 6989' 5813' Base Upper Sand 70z~8-7 58597 Top Lower Sand .-- - 71517 59/+1 ~ N/A Base Lower Sand 73227 60777 · . : ,. · . . · . .: .. .. ; 31 LIST OF ATTACHMENTS Drilling His~:ory~ ComPle~:i°n Sun~nary~ Gyroscopic Survey {2 copies) 32. I hereby certify that the foregoing }s true and correct to the best of my knowledge . Signed Title AFea DFi]l'~no Enor. Date INSTRUCTIONS General' This form i's designed for submitting a complete and correct well completion report and log on all types of lands· and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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". Fnrrn 1 ~-~7 2V-7 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1500 hrs, 01/07/84. Drld 12-1/4" hole to 3116'. Ran 71 jts 9-5/8" 36# J-55 HF/ERW BTC csg w/shoe @3098'. Cmtd 9-5/8" csg w/800 sxs of Permafrost "E" and 250 sxs Permafrost "C". Bumped plug w/1500 psi - floats held - ok. ND 20" hydril & diverter. Instld 11" packoff. NU BOPE and tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS and 10' new form. Tstd form to 12.8 ppg - EMW - ok. Drld 8½" hole to 7442'. Ran logs DIL/SFL/GR/SP/FDC/CNL/CAL f/7442' to 3098'. Cont drlg 8½" hole to 7450 TD as of 1/15/84. Ran 171 its 7" 26# J-55 HFERW BTC csg w/shoe @ 7446. Cmtd 7" csg w/320 sxs class "G". Bumped plug w/3000 psi - floats held - ok. ND BOP. Installed 7" packoff and tstd to 3000 psi - ok. Displace brine from top of well~ Performed Arctic pack. Secured well and released rig @ 1600 hrs on 1/16/84. HILL/DH84 2/10/84 ih Alaska Oii& 623 Cons. Commission 2V-7 COMPLETION SUMMARY RU Gearhart/Eastman-Whi pstock. Ran GR/CBL/CCL. Gearhart/Eastman-Whipstock. Secured well. Ran Gyro. RD Accepted rig @ 0200 hrs, 4/16/84. ND tree. NU BOPE & tstd - ok. Spotted Bridge Sal pill f/6450' - 7100'. Perforated the following intervals W/12 spf, 120° phasing' 7045' - 7065' 7025' - 7045' 7005' - 7025' 6990' - 7005' Ran gauge ring/JB. RIH & set FB-1 pkr @ 7091'. Ran 3½" completion assy w/tail @ 7113', pkr @ 6830' & SSSV @ 1901' Pressured tbg to 4000 psi & set top pkr. Set BPV. ND BOPE. NU tree & ts~d to 5000 psi - ok. Disp well/30 bbls diesel & crude oil. Tested SSSV. Set BPV. Secured well & released rig @ 1900 hrs, 4/18/84. GRU7/CS08 RECEIVED MAY 2 2_ !.984 Alaska Oil & Gc.s Cons. Commission Anchorage ARC:O AI..~F';KA, INC, ............. F" e--"i'Er-~'..~ T--Ii~..EL---RO'i--7-..':,~iT'_~]~-- O Y R 0 ,J u ~ M U: ¢4 c):.:: ::: ,4. 7 t) ',.: :3 / I<UF'ARUK FIELD, IxlEIRTH '..--.;L. FiPE, ~LAF-;F'.'A '.iii;IGMA-GYRf"I., 0-7356 MIl-, '..=.;I...IFtVEYOR: F'EFFERK. ORN/JAI-IN-, DATE RI_IN: 12-MAR-:::4 SI]_-.q~A '300 NO': 3'.-7.','_-.., "'PI-iUH. E 'NU :. U64 FORE'.::; I GHT "- NORTH SURVEY TAKEN FROM WELL. HEAD -- --;I:RE:~ Tllill Whtpstock A PETROLANE COMPANY REC:OR£~ OF c,I...IRVEY RADIUS OF CURVATURE IvlETI--IOD :i ARCr';t AI...'P.p'::;I<R., Z NCo F' A E[ 2 V, W E L L. Iq tT.I: 7 '.::; Z 61'1~-0 Y R 0 I. OJ F' A R L, i;!? 'i!-~'i-~E'~j-'--'~T:FF~?Fi-T.~TE; 6i:~; E, ALASKA JO]]4 N n: PlO 3:.'::4 Z (') 23'7 C: CI M F' I..I T A T I 0 N 'T I ME DATE 1-:~7 ~. 0'4 CF'~F(----~,.~PT F'AI.];[:7. 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F., .-,~.-,.. ( )._ 1 ,.-, .,( .._~ ..... 1997 2.:4 2C) (') '::~::: 4, ::i!: () C),, :2:2 42 '.S i:F.:._,~:"l~J~J._ E .. , '1~1 J~l~"~l,, ~J~ . j'~- ....... i~_~ · ~J~J, - -11~.~,. .' ~j ~J~ll~ ) 1::: c. 6'4 E . . · 1.-:: 21 _. Ei: i~ .... 4.4. C)('). :32 14 S 18':::5 E 1C.~2C) .... I 76 E '::' c) '-': n 'T":' '.=; 211'''' F 0 'l'[::'-,- .... . · '-, , - . . 4500,, ..,':"~'.... 6 ,.E: 1,:.~. ,..,':' E 10F). ._~:R'-"'9_ ~... 05 '21F)2:. 65 2' .' ~ ' .'=-' 7/:,C}. 9'-.-~.. El 2104.20 S 21 12 E 0. :3:':: ,--,,:~ 2011 71 S 778 '-;.~ 4. 6 ()() :3 :l .~l ('~ '-' 19:3 [:, E 100 '--":~ F) &,:.,,.~,~o 21 .,,=/'-,. ~,~'":-~ :37':22. '""' E ~.'-' 15'7 11 21 ':.) E 0 "::/- . ....,'~"~ . # ,.., ...., # # · ,_ ._ · ,~,, · · .., ,.., ,~ 4 7(.)(..) .... ~"~:.I ............ ._-..._,'-~=:-'-'.-_.. ....... z.o"~= ......................... ~.. 100,~----'-"g'-':z'.: .... 1-~::~.",=;---7-'~.,..cF, r_-.. 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L) (..). ..:,,:: ..... ,..., ~::,~ x 1 ! ,:::, E:. 1 (2) 0 ....... ~i c) c) 9 · 4 0 ~,:, 4 z., ,5, 2 ~a,. ~_,,c~ ...... =:: _._) '-~ ......./- ~., ..'-~ ........................... ,:2 ::~ ,:' 1 (") 2'2 /- o [ 2 ~B 4. 3 2'::' "::, g': :' Alaska Oil & ARCO AI...~{.ISKA.~ I hi[.-.:. ...... L) 1' F~, U F' A I'~ ~::, v' W E L L I\1["*~: -/ '.31 Ii M ~-"* ..... ' '" ,JOB NO: AO:3:E:4Z02:'::7 i<I...['I.::'A'if!~UI.;!i- F'IELD, NORTH '.3LOF'E, ALASKA COMI::'UTA]"I ON F:'AC.'iE: Nf')... T I I"1 E D n'r E; TRUE -I;,i'l!~'¢..~i~]:'l.-j'RE::[~ [[RIFT DRIFT C:OI. JRg:E VERTICAL VERTICAL SUBSEA R E C: T A N [~- _-O--E-~--R'---L.'-~-E-~--EI-R--E ............ DCU3EEE: DEF'TH ANGLE DIRECTION LENGTH DEPTH SEC:TION TVD F: n 0 R D I N A T E '.:; DISTANCE DIRECTION :::;IEVEIRIT" FEET D M D M FEET FEET FEET FEE]' FEET FEET r'~ M DG/10OF' 6000. 40 38 S 21 44 E /::,100. 4.2 2 S 22 36 E ..... ;.'::,2C)0" ........ -4-:3 47 '._=; 'P:3 2C~ E 6:--',00. 45 40 S 24 14 E /_', 40 C), 4.5 4 S 24 2/'_-, E ................. _' lc)0. 5086.25 2906.57' 4972.25 2712.45 S 104/_-,. 16 E 2907.20 ::; 2.1 5 E 1.74. R ~' 2,972 57 ~047 .~c, '2'F.~7:3 24 100. ._ 1 E, 1. ..::,:, , _ , ..._, 277 3 .61 S 1071 , 0'.'.';.' E . '.E: 21 7 E 1 , ":;... 10C~, ._,.-'.:,4. ~.)..- =, 51 'T..'EC-5 :,-~F- 28:3/_-, 30' ~:---l~7'7'~,7_'7'-'E~---~-":-C-)'~-l-'-~Z'? ..... S-'2']'[ .......... ' ' · . _ 0._ E 3111 :--: 21 1:3 E I 9'? 1 ¢~ C~ F, :':: ('l.~ /-, 0 :-4110 77 ~ 191 /:, C~ 2' 900.7 C~ S 1 ]. 26. ' ~ .59 . 100. !5375.84 3181.7:3 5261.84 27;./-,5. 54 S 1155.:_::8 E :"::1:--':2.6/:, '._R 21 17 E 0./:,::": . 7000 :'38..:,'-'-:'._, .=,c" 2/:, 1':). E "=~" .'?, 5707.'?0 :3:327.6 1 .... '=' 1 :327 90 E ':'.~'::'":' 77 ':' :21 45 E 1 3 10 thrum5821.7 (~mii c~ .:, / u, '? 1 c~(.} .::::, 4 S 26 1 E 1 c"}~59(}i}. 1 ~m~~~:~~ 2::248.3,:27. S 1 '"'~'=', 26 E :'::644,62 '.:!: '" --' ,~, ,_1 ..I .... ...I .,.I ....- I I .-,,'- ........ ,:,,:, a: .... .... .:.-- .... ...- .......... ..... ,..,....,..-, 7 '7300 ":"~ P'~ 8 '-' ~:' "" z ,~.c . '-:, -.. ', ,= ~.' .':, ,:'¢ ,:~"., ,"' ,-, ..: .... S .-.'-.[ E l,)/~:,(~,./:,.l,. : ,7~~l~,~,f:~q~i~l~f~ ]/,c,O E .'::7/-,'; ,]2 ': ' '::;' .... .... ......, ........ z. 1 ... 7 E 1 '":'/-' F' R f'),_lliE C T I:Z I) 1" 0 P B T D ..................... '- ................ ~ .................................... .A PETROLANE COMPANY 7'::F;/". o,:.i ":;,:, S 2P; 24 E 56 6104 -93 '-'-"-'= ,=-,.-¢c,.-. 93 _ .:,/:.,..,. 34 ..,;; ,.,. .: .... ~_ 1 i, 4 S 1421 '-":'~ 1 E :"::797 F:./:, '.:J; .... ti ._! ,_ ._ ~,.,~ i, n · · # . . .. F:'RO .11:::- (": T E I] T"] 'T D F I'N AI2-'CcosrjR'E-::'"EfIRECTI'EIIq~. J ' D I .:, I A! IL.E A R E:r"~ A l_ A SIE A ~ i[ N C. ....... ~..-: b, Q. Z ~.~":~.L 3 / ::;-I-t.".~'PfA"':3(iO ' NO: :::~,, F'ROBE N;3: I:.'"'0REF;IGHT: NORTH SURVEY TAKEN FROM WELLHEAD B~',:~:'i.,i,,~ Eastman ~ ~o~Whi~~o~ · A PETROLANE COMPANY AI:.?i20 ~L.~-~SKA, ]' IxlL-:. , F'~D :,EtV., WELL MCi: -7 SIGMPI-GVRCI 'K Li F' f-~i:-'~-I.] I:i!.:-' "[:E ~:-~Ei~[-~--~jii~JE-T-H-'-~.~Ei~i-P E., AL~'.::I<A JOB NO: AO3:F:4Z0237 C 0 M F' U T A T I ~]~ N T I ME DATE 1-%i-i~_--A~F,~.,-4:- P AGIF_ NO. , . 1 ................... MARKER .......... ............ C 0 D E .................. blAME TRUE '.:. _IB.:,EA MEASLIRED VERTICAL, MKI-TVD VERTICAL R E C T A N--i3"~-I]--L-7-~---R-----KF-E-q]_f~--f_T-R-E ..... ~?ERT'I. CAI.] DEF'TH DEF'TH DIFF DEF'TH C 0 0 R D I N A T E '._=; DI:--;TAhICE DIRECTION TI.-'tICI<I',,IESS FEET FEET FEE]' FEET FEET FEET D f"l TOP UF'F'E".R .SAND BASE UF:'F'E:R SAND .... i-Eq:'-' 'L.' r:i'i~l 'ET. I~-:.--: A N D BASE LOWIER '._.;AND 704:::. 00 585'.-?. 35 1188.6 5'745.35 3354.28 S 1:341. O:E: E 3612.44. S 21 4.8 7151.00 5'P40.52 1210.5 5:~75:~-~41 1.2::T~~':9~-E ...... ]~~'-]~2-~2'~-E ............................ 7:322.00 6077.41 1244.6 5':~6:3.4.1 3503.55 S 14-1:3.40 E :3777.S~1 S 21 SE', E Eastman ,.': A PETROLANE COMPANY Suggested form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. ' Operator, W~i 1 ~an~ and Number ' Reports and Materials to be received by: Date Required Date Received Remarks · , _ Completion Report Yes · -.. 7s~~s ~re ~ips -' ~ - Core ~scr~p~n Registered S~ey Pla~ ) · Inclina~°n S~ey ,Drill St~ Test Re~s ~~~. __ ,. ~ ~ ~ .=. ARCO Alaska, Ir~-'' Post Offic= ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2V-7 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Si ncerely, d. Gruber Associate Engineer JG' tw GRU7/L16 Enclosure If RECEIVED MAY 0 ? tgl Alaska 0il & Gas Cons. Cmmmis~n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASI~-'~IL AND GAS CONSERVATION ~- MMISSION SUNDRY riOT-ICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL;~ OTHER [] 2. Name of Operator ARCo Alaska, Inc. 3. 'Address P, 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 2013' FSL, 113' FWL, Sec. 8, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) !!~.' RKB 12. 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number 50- 029-21055 9. Unit or Lease Name Kupsruk R~.';sr 'J~it 10. Well Number 2V-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool AD'- 25555 ^LK 2581 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ]~ Altering Casing Stimulate - [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). RU Gearhart/Eastman-WhiPstock. Ran GR/CBL/CCL, Ran Gyro. RD Gearhart/Eastman-Whipstock. Secured well. Accepted rig ~ 0200 hfs, 4/16/84. ND tree. NU BOPE & tstd - ok. Spotted Bridge Sal pill f/6450' - 7100'. Perforated the following intervals W/12 spf, 120° phasing: 7045' - 7065' 7025' - 7045' 7005' - 7025' 6990' - 7005' Ran gauge ring/JB. RIH & set FB-1Pkr ~ 7091'. . . 1901'. Pressured tbg to 4000 psi & set top pkr. well w/30 bbls diesel & crude oil. Tested SSSV. Ran 3½" completion assy w/tail ~ 7113', pkr @ 6830' & SSSV Set BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp i Set BPV. Secured well & released rig ~ 1900 hfs, 4/18/84. RECEIVED MAY 0 7 ]gM 14. I hereby~e~tify~hat the foregoing is true,ao~d correct to the best of my knowledge. Signed ~')--- Title ....... The space~f ~ ~o ion use Conditio~ Approval~: Alaska Oil & I~as Cons, Commisslo~ Anchorage Approved by CQMMISSIONER By Order of the Commission Date Form 10~,03 Rev. 7-1-80 GRU7/SN05 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING Date: ~~Z-~ Well Name: Transmittal _Log Date Run ~L DISTRIBUTION NSK Operat ions Blueline Dr il 1 ing Blu el ine Geolbgy /K~n _ p~l~ C~e of AK.' Blueline & Se~4~ Sign &~x~veturn the attached. ~ copy/~s./' re cei~ t,~..f,d~a .~ ':,:..'.~ A · ~"~'"~-,, ~ . ~ , , . .'IL) .,-.: . . .,w,~,, ~ ~,uli rn to: ARCO-'~A~S~,:.'~ZNC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING TO' TRANSMITTAL - . FROM' D. FaS Allison DATE' March 15, 1984 WELL NAME' 2V- 7 Transmitted herewith are the following- PLEASE NOTE:~- BLUELINE, (~ SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY DIL-SFL-GR P & R 2"/5" Density 'Neutron P & R 2"/5" Cyberlook . 1/15/84 Run 1 !1 ~! ti R~ ACKNOWLEDGED' DATE: /~LEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' D FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 KUPARUK ENGI~,iEERIHG TRAHSMITTAL # ~,.~:7~/~ TO' FRO.q: D. Fay Allison WELL NAME' see below Transmitted herewith are 'the following' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM~TAPE, PC - PHOTOCOPY Well Descript ion Date t~url R~'PT ACKNOWLEDGED' ,~LEASE RETURH RECEIPT TO' ARCO ALASY, A, IHC. ATTiI' D. FAY ALLISON - ATO/lllS-B P. O. BOX 100360 AHCHORAGE, AK. 99510 ,-ARCO,Alaska, Inc. Post Office b...~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2F-! 2V-6 WSP #3 2F-2 2V-7 WSP #13 2F-3 2V-8' Hemi Spring St #1 2F-4 2B-5 Thank you. Sincerely, District Drilling Engineer JBK/SHi:ih ARCO Alaska. inc. is a subsidiary of AtianticRichfieidCompaRy _, ~--, STATE OF ALASKA ?_. MONTHLY ALASKA' 'LAND GAS CONSERVATION C( :MISSION REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well l~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 :4. Location of Well 2013' FSL, 113' FWL, Sec. 8, TllN, RgE, UM at surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. PAD 78' 114' RKB ADL 25655 ALK2581 For the Month of January Workover operation [] 7. Permit No. 83-180 8. APl Number 029-21055 50- 9. Unit or Lease Name KPK River Unit 10. Well No. 2V-7 11. Field and Pool KPK River Field KPK River Oil Pool 84 ,19 cmtd & tstd 9-5is" 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1500 hrs, 01/07/84. Drld 12¼" hole to 3116'. Ran, csg. Cont drlg 8~" . Ran 2 hole to 7442' & tstd 7" csg. Displ brine from top of released rig @ 1600 hrs. on 01/16/84. logs. Cont drlg 8½" hole to 7450'TD. Ran, cmtd well. Performed arctic pack. Secured well and 13. Casing or liner run and quantities of cement, results of pressure tests 9=5/8'' 36# J-55 HFERW BTC csg w/shoe @ 3098. Permafrost "C". Cmtd w/800 sxs Permafrost "E" & 250 sxs 7" 26# J-55 HFERW BTC csg w/shoe @ 7446. Cmtd w/320 sxs class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP/FDC/CNL/CAL f/7442 '-3098' 1 6. DST data, perforating data, shows of 1-12S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . SIGNED be/filed m duplicate with the Alaska NOTE-- R epo~r/o n Oil and Gas ~onservatio~,/~ommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 HILL/M~i 05 Submit in duplicate 2V-7 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1500 hrs, 01/07/84. Drld 12-1/4" hole to 3116'. Ran 71 jts 9-5/8" 36# J-55 HF/ERW BTC csg w/shoe @3098'. Cmtd 9-5/8" csg w/800 sxs of Permafrost "E" and 250 sxs Permafrost "C". Bumped plug w/1500 psi - floats held - ok. ND 20" hydril & diverter. Instld 11" packoff. NU BOPE and tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS and 10' new form. Tstd form to 12.8 ppg - EMW - ok. Drld 8½" hole to 7442'. Ran logs DIL/SFL/GR/SP/FDC/CNL/CAL f/7442' to 3098'. Cont drlg 8½" hole to 7450 TD as of 1/15/84. Ran 171 jts 7" 26# J-55 HFERW BTC csg w/shoe @ 7446. Cmtd 7" csg w/320 sxs class "G". Bumped plug w/3000 psi - floats held - ok. ND BOP. Installed 7" packoff and tstd to 3000 psi - ok. Displace brine from top of well. Performed Arctic pack. Secured well and released rig @ 1600 hrs on 1/16/84. HILL/DH84 ~/lO/84 ih MEMORANDUM . State of Alaska ALASKA OIL A~) GAS CONSERVATION COt-~MISSION TO: C.V../'~~=~o,, O,T,: ~a,~a=~ ~, Chai~~ ~_.~ ~,,e ~o: 4I. 10 ~U: Lonnie C. Smith Co~issioner ~ELe~o~e ~o: ~o~: Doug ~~ SUB0eC~: Witness BOP Test at Petrole~ inspector ARCO's Kupa~k 2V-7 Well. Sec. 8, TllN,R9E,~, Pe~it No. 83-180, Doyon Rig No. 9. M~lay. Jan~ua. ry.9,~,1984: After witnessing the BOP test at ARCO's Kuparuk~2F-2 Well I traveled to ARC0's Kuparuk 2V-7 Well to witness the BOP test there. Tuesday, January I0, 1984: The BOP test commenced at 1:00 am and {¢~s'~-0hCiUded at '3:00 am'. There were no failures and I filled out an A.O.G.C.C. BOP test report which is attached. In summary, I witnessed the successful BOP test at ARCO's Kuparuk 2V-7 Well. Attachment 02-00IA(Rev. 10/79) O&a #4 4/8o STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well ~ V- 7 Location: Sec ~ Drilling Contractor Date ?Jell Representative ~' .~ Z~'/") ~'~ Permit Representat ivy- Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams L ~ ~ ~/ Blind Rams. Choke Line ValvesS//4 H.C.R. Valve Kill Line' ValVes Check Valve' Test Pres sure ACCUMULATOR SYSTEM Pressure 40~ ~ psig Full Charge -Pressure After Closure /~d~ O' psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: ~ Controls: Master O~ Remote ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly 7 ~'~est Pressure ~ Lower Kelly ! ~ Test Pressure Ball Type ~ ~Test Pressure Inside BOP ~ ~est Pres sure Choke Manifold [ ~-T~st Pressure No. Valves /--~ No. flanges Adjustable Chokes Hydrauically operated choke min z~/ sec min 4 F sec Test Results: Failures ~O~-- Test Time ~- Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: hrs. ~P daYS and Distribution orig; - A0&GCC cc - Operator cc - Supervisor Inspector ARCO Alaska, Inc. Post Office B~.,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 28, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2V-7 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on February 10, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, rilling Engineer JBK/GRU5L83-tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .___ STATE OF ALASKA ALASKA L AN D GAS CONSERVATION Cf ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER IZ~x 2. Name of Operator 7. Permit No. ARCO Alaska, inc. 83-180 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21055 · . 4. Location of Well Surface: 2013' FSL, 113' FWL, Sec.8, TllN, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 114' RKB 6. Lease Designation and Serial No. ADL 25655 ALI( 2581 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2V-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Tubing [] Other ~ Pulli.ng Tubing Pull (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: February 10, 1984 14. I 'hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~J~l,~ ~", _~-¢~ Title Area D rilli.g El~gineer The space~~ Co~mission use Condition~ of APproval, if any: Approved by. COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 GRUS/SN45 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate December 19, 1983 Mr. Jeffrey B. Kew!n Area Drilling Engineer ARCO Alaska, Inc. P. O. Box-100360 Anchorage, Alaska 99510 Re ~ Kuparuk River Unit 9_V-7 ARCO Alaska, Inc. Permit No. 83-180 Sur. Loc. 20!3'FSL, l13'F~.~, Sec. 8, TI!N, RgE, UM. Btmh°!e Loc. 1515'F~UJ, 1391~F%U~, Sec. 17, TllN, RgE, Dear Mr. Kewin~ Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch'chip from each foot of recovered.core is required. Samples of well cuttings and . mud log are not required. A continuous directional sur~,ev is required as per ~0.AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys ~nd dip~eter surveys. }~ny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS !6.05.870 and the reg~latlons promulsated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Hebltat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, .Chapter 70) and by the Federal Water Pollution Control Act, as a~nde~. Prior to commencing operations you may be contacted by a representative of the Department of EnviroDanental Conservation. To aid us in scheduling field work, please notify this office ~ . 2~ hours 'prior to comma, c~ng installation of th~ blowout preven- tion ~uzoment So that a representative of the Commission may Mr. Jeffrey B. K '~tn Kupan,~k Ri~er Unz~ 2V-7 Oecember 5.9, 1983 be present to witness testing of the equipment before the surface ca~ing shoe is drilled. ~ere a divert~r ~ystem is required, please also notify this ofziee 24 hour, prior to commencing equipment installation so that the Commiss~on may witn~ test~:ng before drilling below the shoe of the conductor pip~. In the event of suspension or abandonment, please give this office adeq~uate advance notif~cation so that wa raav have ~ ~tness pre,eot. Verv~ tru_,ly your~, ~ Chai~an of ' " ' A~ ~.a Oil and Gas Conse~,ation Co~i~sion Enc!o~ure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Bo~ ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 6, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2V-7 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2V-7, along with a $100 application fee. Diagrams showing the proposed horizontal and vertical projections of the wellbore. · A proximity plat. A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on January 2, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. SinQeTely, _ /amea D~xl 1 lng Engineer JBK/JG5L56' tw Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ , STATE OF ALASKA ALASKA O,L AND GAS CONSERVATION COM~vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE I~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 2013' FSL, 113' FWL, Sec.8, T11N, RgE, UM At top of proposed producing interval 1236' FNL, 1290' FWL, Sec. 17, T11N, RgE, UH At total depth 1515' FNL, 1391' FWL, Sec. 17, T11N, RgE, UM 5. Elevation in feet (indicate KB. DF etc.) RKB 114' PAD 78' 11. Field and pool Kuparuk River Field 6. Lease designation and serial no. ADL 25655 ALK 2581 9. Unit or lease name :. :'%',¢., ';'¢~I~!i~' Kuparuk River Unit ~? 10. Well number :L~-_, ..~ 2V-7 ":' '-" '.7.'.., ~-.':~ ,.': .';.. ~ .":':2' ¢% Kuparuk River Oil Pool ~ 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2V-6 well 120' (~ surface feet 18. Approximate spud date 01/02/84 16. Proposed depth (MD & TVD) 7402' MD, 6210' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 Hole '~4" !2-1/4" ~ 2-1/4" ~-1/2" SIZE Casing 16" 9-5/8" 9-5/8" 7~, Weight 65.5# 36.0# 47.0# 26.0# 22. Describe proposed program: 14. Distance to nearest property or lease line miles 1236 feet 17. Number of acres in lease feet 2467+ 20. Anticipated pressures MAXIMUM HOLE ANGLE 36.4 o (see 20 AAC 25.035 (c) (2) Proposed Casing, CASING AND LINER Grade I Coupling Length .-4o ! WeldI 80 j- s HF-F I L- O !I 1128' I _iner and Cementing Program SETTING DEPTH MD TOP TVD 36' I 36' I 35' I 35' 1929' 11800' I 33' I 33' I 2711 _ 3115 psig@ 8f)°F Surface · psig@ 60~q ft. TD (TVD) MD BOTTOM TVD 116'I 116' 1929'11800' 3057'12714' QUANTITY OF CEMENT (include stage data) + 200 cf 875 sx Permafrost E 250 sx Permafrost C 7402' 16210' 310 sx Class G neat I I ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7402' MD (6210' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2711 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig will be covered under a separate sundry notice. 2V-6 will be 120' away from 2V-7 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the- di spos.~l~pr~Cess. The spacey t;9t¢ ~ssiO'~'use TITLE Area Drilling Engineer DATE /.~/./'~ CONDITIONS OF APPROVAL Samples required I--lYES [~NO Permit number APPROVED BY Mud log required Directional Survey required I APl number [-]YES ~NO [ ~ES E]NO I 50-0 7.... Approval date I  .12/.1~3 ., SEE COVER LETTER FOR OTHER REQUIREMENTS , /'/ //. /.,,~~OMMISSIONER DATE December 19; 1983 ~.~..¢,,' ,/F.. ~.~~'/~~,4~ by order of the Commission Form 10~401 GRUS/PD18 ' ~/ Submit in triplicate Surface Diverter Ssstem ~xx 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter by/ 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell .nipple. 16" Conductor that gas or fluid flow to surface is 'detected. If necessary, manually over: ride and close ball valve to upwind diverter line. Do not. shut in well under ~ circumstances. --~ Close annular preventer in the event Maintenance & Operation ~- 1. Upon initial installation close annular I preventer and verify that ball valves ! - have opened properly. I 2. Close annular preventer and blow air ~_ . through diverter lines every 12 hours~ ._.~t,,__ 5000 PSI '~R. SRRA BOP STA'CK.~, [ I RNNUL.qR -1 P REV9ENTO'q/J ) .- _ · . _ o _ _L_t .= BLIND RRHS . - 8o_- . _%, - ) P I PE RR,qS C ) ) -Lt. PIPE Rtq~S : o _ ) :s ..() . .' . 'C · d csG _ i -. . . 1. 16" Bradanhaad 2. 16" 2000 PSI × i0g 3SC3 2SI casing head 3. 10" 3000 PSI tubing head 10" 3000 PSi × 13-5/8= 5COO adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" 5000 PSI and kill lines 7.. 13-5/8" 5000 PSI 8. 13-5/8" 5000 PS! 9. 13-5/8" 5000 PSI 5. 6. 7. · 8. pipe ra~s drilling s-pool w/choke pipa_' ra~- _- .. _. bl i,nd r~ -- -. anr=lar -- - ACCI~-IULATOR r. Ag$£I T1r T=._ST ~-IECK J~,q) FILL ACCI~TOR -~_..S-T_RI"OI~_ l~ P.~oDP~R L.E'VElj WITH HYDP. AULIC FLUID, 2. .~SU~ I'HAT ACO~.~._A,TO,~ PP-.,:,.~C~,.E ,[.% ~ PSI Will4 1500 PSI ~,~I-P~F_~ OF 3- OBSERVE TI~qE Th?.N CLUE ALL L~ITS ~.SLY A~qD RECORD T~LE T]~_ ~ P ~RESSt~ .:~Ei-'.AI~- ' I,"~ ~,.R ALL bTIITS ~ CLfSE~ NI'F4 ~_~,A.................~G!~G F'd:--tP OFF. 4. P, EC~D ON IADC REPORT. LZMIT IS 45 SE~'{~ CI. OSINT~ T~E ~ 12=0 PSI P~'v.~ClNIh~ PP-,E.SSUP~E. - 1Z. 13-5/8' EOP STAY.( TEST I. FILL BOP STAG< A~;D MA.-'(I,:OLD ~'liT(. X.c'J:I"IC DI-.~SEL. 2.. C'~EG~ I"~.AT ALI. HOLD C'"'-,.,~'~ S~ X.~ RILLY TP,.A ~CTED. PREDETEF..~It~ DEPT'-' i%.~%T ~ ?l.'J~ WILL SEAT A[~ SEAT IN ~L~..a~. ?J~"~ I)~ Cr~_~N SCR~S IN HEAD. CLOSE A~;~'IUL~.~. P?,~'~ ~(TER AJ'JD C~-.O.tLES A,)~) :-'YPASS YALVES (~ Fb%qIFOLD. TEST ALL CC~{PO;~'FFS TO 250 .:'SI ~'~ ~P l0 MII~TES. INC..-REA.SE PRESSUF~ TO 1800 PSI ~J(D NC~.J7 1:DR lO MINUTES. BLEED TO ~0 ~I. OP-~(-AIC'(ULY~R PP,~/~,---~, A~ID Cl.~E ~ SET PfPE P,.~,",S. I~JCREASE-PRE.SSU2E TO 3003 ~I' ~'{D Hr~__l) .=02 lO O_OSE VALVES DIRECTLY' UP'Sl~'.{. OF G-"r',-4~. BLEED D~,.,'NSTRS_~~, P?~.ESSL~'~ ~ ZERO PSI T'O TT~-T Y~'~VES. TEST P~A.!N!;,.'G UKI'ES~'-'~_ Y~.LYES, IF A.){Y, WI'TH 3.~,J-9 PSi UPSll'.-~E,-~4 ¥,:~VE A~iD ZERO PSI D~",{STR~. B'~-.~ ~-'i'~ ~i ' TO 7FRO PSI. - ',":, 9. 0P-~l TDP SET OF PiPE RA-~ A~{J) ~._~-~_ SET OF. PIPE ~'~?~S. lO. IN~x. EAS. PP. ESSU?-' TO 3~-'~ P~I ~.,g .~OLD ~R l0 ,_ H!)~JTF_S. BLEED TO ZD>J3 PSI. I I. 0~ BOTTOM SET OF PIPE ?.A,~S. BA~"( C~--F ~JJ~ ~" . NI:~ JOINT A~(D PULL ~ OF ~----~. C)_fISE $LulND " R~.'qS .aJiD TEST TO 3000 PS! Fi~R lO i!.I~:~3'I-ES. BLEED TO ZERO PSI. SI~.E HA,'tIFOLD -~','g LI?~ ~.F_ F'o~J_ &~: ~C DIFqEI A,';D ALL YALY~F_S A~'~ S-ZP[ 'I]t POSIT] ~"I. TY_ST SYPWiDPIPE YALYES TO 30.CI3 PSI. TEST KEI_L¥ C~ A~D I,~ID~~ ~ TO 3~ PSI PZCO.RD TEST [NF0~D~ATIO~ ~ !~_~-,~ I~ TEST FOP~N SIG;I YJJD SEJ,.~ TO ~_~ILLI~---~ YISOR. - 13. 14. 15. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc 62' thru 8) '(8) (3) Admin -~,D~,~ ,,"i,. (z9 thru 11) (4'0" a~d ~) (12 thru 20) ('21 thru 24) l. Is 2. Is 3. Is 4. Is 5. Is 6. Is YES /,,,"'~ff~ the permit fee attached .......................................... well to be located in a defined pool ............................ well located proper distance from property line ...... · ~"~' well located proper distance from other wells ........ sufficient undedicated acreage available in this pool i',~' well to be deviated and is well bore plat included .. :',,/-~..,,, __ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. NO Does operator have a bond in force .................................. ~_~. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional reqUirements ............................................. ~ Additional Remarks: ~ ~)'~/q,~-.l~ ~/~;//,'~'~ '~/~;7 o'~ ,~'~ [-z~,~,~ ~_* ~ ~ REMARKS C) ["*1 rtl Geology: Engineering: JAL ~7/~'~'MT~ ~_ rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIx. .. No special 'effort has been made to chronologically organize this category of information. ,o V t~,; R I, F' ]' C A T l.'. 0 N RECEIVED NOV 2 6 I~ Alaska Oil & Gas Cons. Anchorage bVP OlO.H02 VER1FICATIO!~ I_,ISTING PAGE ** RFE[, t~}!]A'DER ** SERVICE DATE :~4/'10/ 2 ORIGIN : REEL ~,:~ ME : CONTI~[~AT.ION ~ :01 PREVIDI~S ** TAPE I~EADER ** SERVICE !4AHE :EDIT DATE :~4/10/ 2 ORIGIN :FS1A TAPE CONTINbATIUN PREV If~l.)S TAPE : CO~ME~TS : FILE NAME :MDYT ,001 SERVICE NAME : VER8i~ DATE . MAXIMUN bENGT~t : 1024 FILE TYP~ PREVI(3U$/FILE : ~ N E ~,~, C 0 N T E N T S 00 o 00 o 016 065 o 0 o 0 o 0 o 04 065 000 o 00 00 B 065 0 0 0 o 0 0 0 0 2 0 6 5 0 0 o o 0 0 0 0 4 0 6 5 00o 0o0 002 0 00 o 00 0 0 8 065 000 000 006 065 0 0 0 00 0 0 04 06 5 $ C H L U pi ~ E R G E R ALASKA DIVI$1rl~',F Ctl~,~PttTI~G CENT,'IR WELL = 2V-7 FIELD = KLJPARUK CDU :'~TY = ;'1. SLOPE STATE,? = AI, ASK ~ANGE : 9E TAFE DENSITY = 800 BPI df~B # 69561. BASE !,,,OG-' DIL , RUN # I , DATE; !~I3GGE[) 15-dA~!,,84 BOTTO~ LOG INTERVAL = TOP L('}G INTERVAL, = CAS I ~!(;-Lt'~GGER = BIT SIZE = 7465 FT. 3081 FT, 9,650 IN. ~ 3098 8.500 i N, LVP 010.N02 VERIFJ'C.~TIO~'~ LISTING PAGE 3 X C POb¥['~Ek tO.PO 40 00 9:50 5,80 2,28o (a 68 2,400 ~ 68 2.280 a ~8 1,125 f~ 1.45 A I,] D S T t.)r,l E DATA FOR~'!AT RECORD ** E~TRY tJbOCF, S TYPE SIZE REPR CODE EN'r R'Y 2 1 66 0 4 i 66 8 4 73 60 9 4 65 ,lin 16 :1 66 l 0 1 66 0 'DATUM SPECIFIC~'~"'"'IION BL, OCt~$ MNE~ SERVICE SER¥ICE U;~t.IT API AP1 APl: aPI FiLE SIZE SPb REPR iD .ORDER ~ bOG TYPE CLASS DEPT FT 00 000 O0 0 0 4 8FLU - DIL r.,~'H~,"'; O0 220 01. 0 0 4 IBM [:~I [, OH a~,'~ 00 12o 44 0 0 4 I L D D '[ L, (] H ~ ~: r) 0 120 46 0 0 4 5 P D I;k~ ~a v 00 010 0 ~ 0 0 4 GR D t b ('.; ~ P I 00 310 01 0 0 4 ~R FDN G~PI 0U 31 u 01 0 0 4 q () 4 N P H'.I F D ~ P ~1 00 8. 0 00 0 D R H 0 [' D ~ G / C 3 00 356 0 1 0 0 4 RHO[~, FD}L G/C] oo ]5o 02 0 0 4 N C N [,~ F D' N C P S 0 ~ 330 ] 1 ~ 0 4 FCN[, FI.)N CPS O0 330 30 0 0 4 CAhI FDN I~ oO 280 01 0 0 N R A T F D N o 0 420 01 0 ('.) 4 P R U C g $ S CODE (OCTAU) 1 68 o000u0000000o0 68 00000000000000 1, 68 0000(,)0000000o0 68 000000~0000(:)00 i 6H 0000000OU0000o 1 68 00000000000000 :1 68 O000()O000000C~O 68 000000(')0000000 1 68 000O0000o00000 1. 6~ 0C)000000000000 1 68 00000000000000 1 68 00o0000000o000 68 00000000000000 1 68 ooo00000000000 LVP 010.F!02 VERIFICATIOt,~ I,ISTING PAGE 4 RNRA 0 F) 00 ('1 0 ',) 0 0 1 t~a O000000000uO00 ** DA'fA D g PT SP DRHO CALl DEPT SP DRHO CA b [ DEPT DRHO CAI,,1 DEPT SP. DRHO CALl DEPOt SP DRNO CAI.,I DEPT SP DRHI) CALl DEPT SP DRHO CALl DEPT SP DR HO CAL ! DEP[ DRHO CA~I DEPT SP D R H 0 CALI 7 465.50t,)0 -20.2500 -999.25Oa -999,2500 7400. u 000 . 8,3594 0 1475 ,0 .,73 7300.0000 '16,8.4,37 O, '9518 8,679'? 7200 0000 '4'" .., 2: 4375 0.01,37 B.2422 7100,0000 -40,$437 0, o 1 32 8.67~9 7000 0000 -57 ' , 59.]8 - 0,0024 8,8750 6900. 0000 -51 .3750 ,21. 09 6800 t}O00 -59 1250 00l 86 9 O859 6700. 00 O0 6 g :,37 bO -~ 2500 6600 0000 0 ' - .2500 9.9687 SFI, u G R RHOR_ SFI_,O GR N R A T SFLU GR NRAT 8PI,,U GR RHOB NRAT g F L U G R RHO~ N R A T S F b U GR RHO8 NRAT 8F't, iJ NRAT S F L b G~ R H 0 B NRA'[' S F [.~ U G R R H !3 H N iR A T GR R ri 0 B 1 , 3'~99 I I;~,~ 100.8125 GR -999.2500 -999,2500 RriRg 4,25'18 II..,;q 99.0000 GR 2.2852 NCNL 2.8906 RNRA 2.91.41. Ib~ 104,3750 GR 2.53~3 NCNL 3.3379 RNRA 31,093~ 39.9687 2,2109 NCNL 2.8086 RNRA 8 6953 II.,~ 77,1875 (;R 2,3984 NCNL 2.8223 RNRA 7 1 5000 . 78,5625 2,724~> 3,3496 4.8867 I,L M 263,0 O 0 () {; R 2. 2988 NCNI,, 4.7227 RNRA, 2.34,5! NCNL 3.9082 R N R A a.2305 ibf4 250,0000 GR -999,2500 [,~, C N 1.~ -999,2500 RNRA 2.0O59 -999.2500 -999.2500 -999,2500 3.71~8 99.0000 2554.0(~00 3.11.52 2.7~{52 104,3750 2050.0000 3.6992 17.7188 39,9687 3194,0000 3.0!,56 6,9766 77.1875 2706,0000 3.17'17 36.1250 78.5625 000 2230. 758 3. 3,464a 263,0000 173~.oo00 4.3594 17 ~7324 8 '? 5 o 2114,0000 4. 3633 3.41. 60 250,0000 -999,250() -999. 2500 3,2129 141.1250 -999,2~,)0 -999.250o I la l) 3.0957 NPHI -999. 2500 FCNL -999. 2500 I.bD 3,6~16 mPHI 3i,3'750 FCNb 819,5000 ILD 2,8496 NPHI 40,2832 F C N L 55 ti ,, 00 00 I.b[) 22. 6094 NPHI 31. 3477 ["C I'~ L 1. 059,0000 I LD b. 6445 NPHI 31,0059 FCNL 851. 5000 It.,[) 36,6563 N P'H i 4. 0,234, 4 F C N [,~ 606.5000 ILD 3.6152 N P H i o 4., .4531 F'CNL 397.0o00 ILD 3,8555 NPHI 49.9512 F C'N L, ~ B 4,250 u I I.., D 3, b 1 '7 2 NPHi -999. 2500 FCN[,~ -999. 251)0 I L D 3,1836 N'.PH I -999,25(,)0 FC.N.b -999,2500 LYP OIO,H0~ VERIFICATION LIST[N(; PAGE 5 DEPT 6500,0000 SF'i.,I.~ 4. SP -66,2500 GP, 123, DRHO -999,2500 RHO .F.. -909. CALl 9.4063 N~AT -999, DEPT 63(.)0 0000 SFLU 3 SP -73:4375 GR DRHO -999,2500 RHE)P -999 CALl 1 !.., 1797 NRAT -999, DEPT 6200,0000 SFLU 6, SP -67,3750 GR 106. DRHC) -999,2500 RH~B 999, CALl 9,32~ql NRAT Z999, 2969 5625 2500 2500 4219 3125 2500 2500 3262 ~375 2500 2500 1680 6250 2500 2500 DEPT 6100,0000 SFI.,U 3,5059 SP '-82,4375 GR 128 0000 ORHO Q99,~500 RHOB -999:2500 CALl I I, 1250 N R A.'I' -999.2500 DEPT 6000,0000 SFLU 3, SP -76 6250 G~ 97, DRHi'J '999' CALl 10,2500 RH[!!~ '~99, .()234 NRA -999. DEPT 5900,0000 SFLb 3 . SP .' 79, ~ 750 GR 92, DRH{3 999,2500 RHOB -999, CALl -999,2500 ~, ~ A~',' -999  EPT 5800,000U SFbU 3, P -260,5000 GR 104. DRHO -999,2500 RI-'{O,~ -999, CALI -999,~500 NRAT -999, D .,PT 5700, ()000 SFLU 4 SP -129,7500 GR 137 D R H [) - 99 g, 25 () 0 R H 013 -9 5) 9 CALl -999,2500 Nt~AT -999 DEPT 56()0. O00t, SFLU 3, SP 'l 13.3125 GR 162, O R H [) - 99 o, 2500 R H 0 ),? - 999, CALl -99~.2500 NRAT -999. DEPT 5500, O00u SFI,ii I, SP -21,500o GR I 35, DRH© -999.250() R H [}~:~ -999, 3340 6[~75 2500 250O 3301 5625 2500 25o0 9199 3125 2500 2500 1289 7500 25O0 2500 1406 5 o 00 250 u 250O 760'l 1250 25OO bi C N L, IL~ GR ~"; C ii L R ~i R A 1 N C 5.1 L, RNRA I bh G R N C N I.~ GR NCNL, RNRA GR NCNI', I Llq GR NCNI, RNRA I GR ~ C N L RNRA (; R NCNL RNRA 1 bM (; R RNRA I. l.,a (; R NC .m I., 2,986~ 1.23.5625 -990.2500 '909,2500 4,0352 116.3125 -999,2500 -999,2500 3.4043 108.4375 -999,2500 -999,2500 3,9004 106,6250 -999,2500 -999'2500 3.4629 128,0000 -999.2500 -999.2500 3,3516 97,6875 '999,250O -999,2500 3 4902 -999' ,250() -999,2500 -999,2500 3,8027 -999.2500 -999,2500 -999,250() 3.52]5 -999,2500 -9~9,2500 -999,2500 2 7246 '999' ,2500 -999,2500 '999,2500 1.6807 -999,~50(') -999, 500 I L,D NPH I. I I,,D HPhl FCNL Ihb B P H 1 FC~I. 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R ~, 2,404.3 Ib~. 108,0625 aR -999,~500 NCN[: -999. 500 ~NRA 2 , 5605 ,~ . 99,5000 -999,2500 2 4629 109 0625 GR 1999 2500 NCNL -999 2500 RNR~ 2 6992 123,5625 -999,2500 NCNL -999,2500 RNR.A 2,5'762 91,0000 GR -999,2500 1,4463 -999.2500 NPHI -999.2500 FCN[, -999.~S00 3,0137 ILl) -999,2500 NPHi -999,2500 FCNL -999,2500 2,5176 IBD -999,2500 NPHI -999,2500 FCNL -999.2500 2.4414 IBD -999,2500 NPHI -999.2500 FCNb -999.2500 2 7715 1999:2500 NPHI -999,2500 FC.NL -999,2500 2.4805 ~ 999,2500 q99,2500 -999,25O0 2 5879 I[,D '999' ,2500 NPH1 '999.2500 FCN[, -999.2500 2,5938 iLD '999.2500 ~4PHI -999,2500 FCNb -999,2500 2.7051 I L: if.',) -999,2500 NPHI -99:9. 2500 -999.250o 2,6777 -999.2500 NPHI, 1.3672 -999,2500 -999.2500 3.0332 -999.2500 -999.2500 2,5859 '999,2500 -999.2500 2,4219 -999 2500 -999[2500 2 7383 -999!2500 -999 25u0 2,5273 99. 250() 2,4668 '999,~500 -999.2500 ,6563 -99 ,2500 -999,2500 2,6836 -999,2500 '999.2500 8887 2500 -999.2500 -999,2500 bYP 010.H02 VERIFICATIO~',~ L]'$TING PAGE 7 DRHO CAbi DEPT SP D R H 0 CALl DEPT SP DR HO CALl DEPT SP DRHO CALl DEPT SP DRHO CALl DEPT SP ORHO CALl DEPT SP D R H [3 CAI../ DEPT SP DRHO CALI -999,2b00 Ri{[}~3 -999.2500 NRAT 4300.0000 SFLU -41.5313 GR -999,2500 RHO~ -999.2500 NRAT 2 200,0000 SFLU 39,5313 GR ~99.25()0 RH[iS -gQ9.2500 NRAT 4100.0000 SFLU -39,0625 GR :~99 2500 RHC:'S 99:25U0 ~RA'] 4000 0()00 SFI.,U -40'0313 G~ , -999,2500 RHO¢ -999.2500 'NRA -999 250(,, 999 '. 2500 900,0000 SFLU -41,7813 GR 999.2500 RHOB -999.2500 NRgT -99~,~50~ NC~L -999,25G0 RNRA 3800 0000 SFLLi . -42,0000 GR -999,2500 RHOE -999.2500 NRAT 2,6445 IL, M 104.5625 GR · 99.250(') kNRA 3700,0000 -44,5000 GR -999.25()0 RHO[3 -999.2500 NRAT 3.7188 109.7500 GR -999.2500 -999.2500 DEPT 3600, OOO ~_~bU SP -47, 687 GR 2500 R}iO[~ DRHO -999,. , .... ~ CALl -999,250C NRAT 2.7988 Ibl~i 91,2500 GR -999,2500 ~,CNL -999.2500 RNRA DRHO CALl 3.9395 I 86,0000 (;R -999. ~500 t;:CNL -999,250() S~E PT P D R t.'.~ 0 CAb I 2 B906 ILM . 100,4375 G~ -999,2500 t..~CNL -999.2500 RNRA DEPT 2 7012 IL~ 86.B125 GR - 9 {~ 9,250 ~) ~4 C -999,250u [{NRA 2,826.2 112.~5oo (;R - 999,2500 -999,2500 RMRA 3~O0,00oo SFLu 48,2500 GR -g99,2500 RHO[% -~gg.2500 NRAT 4.4 }q 05 I L 95,7500 -999. 2500 NC -999.2500 RNRA 34. 00 00 (,) 0 $ F b t.1 -53,7813 ¢;R - 99 g. 2500 R t.~ 013 -999.2500 NRAT 6,5938 ILM 86,6875 aR -999,2500 NCNIb -999,250u RNRA 33U(), 0000 SFI.,tt 5,2813 Ib~ -999.2500 -999.2500 3,0625 -999.2500 -999.2500 -999,2500 2.7656 '999,2500 '999.2500 '999.2500 3,6895 -999.2500 -999.2500 -999,2500 2.9141 -999.2500 -999,2500 -999,2500 4,0938 -999,2500 -999.2500 -999.2500 3.0742 -999.2500 -999,2500 -99g. 2500 3. 0527 '999,2500 -999.2500 -999. 2500 2,888 '~ -999.25 -999, ~5()0 '999. 500 4, o469 -999. 2500 "999,2500 -999.25LU 6, ,~4 02 -999, ?,:500 -999, ~50() - 999.2500 5. 625o F C ~t L I !,D :',~ P H I FCN[, I I.., D N PHI F C 1,~ b I N P H I FCN L I LD NPHI FCN L I I,.., D FCN [,,, -999 . 2500 3,2520 '999.2500 -999'2500 2,9219 :~99.250') 99.2500 3.9004 -999.2500 -999,2500 3,0996 '999,2500 -999.2500 4,4023 -999.2500 -999,25OO ,3,2637 -999. 2500 '999,2500 3.5U20 -,999,2500 999,250() 3. !,172 -999,2500 -999,2500 ~. 8'189 -999,2500 -999.25()0 7,6523 -999,2500 -~99. 2500 6,2617 LvP OlO,[tt) 2 YERI['iCATII3I, t [i:I:5;TI'.NG PAGE 8 SP -51 ,2,197 GR DRMO -999. 2500 RHEi~ CALl -999. ?500 ~RAT 81.4375 GR -999.2500 NCN[, -999.2500 DEPT 3200.0000 SF"I,0 8P '52.7500 G~ DRHO '999.2500 RPOB CALI -999,2500 NRAT 6.8867 77.1~75 -999.2500 -909.2500 P~iRA DEPT 3100.0000 SFLU SP -44.5000 GR DRHO -999.2500 RHOg CALl -999,2500 NRA'i 11.6250 ILi~ 69.5000 GR '999.2500 ~CNL -999.2500 RNRA DEPT 3081.0000 5FLU SP -4.7070 GR DRHO -999,2500 PHOb CA[,I -999.2500 ~,~RAT 2000,0000 lb~ 46.5938 GR -999.2500 NC~;L -999,~500 RNRA ** FI.I.,[;: TRAIbER ** FILE F]~I~E :EDIT .001 SERVICE NAME : YERSIO~~ ~ : DATE : MAXI~UN LENGTH : 1024 FILE TYPE : NEXT FILE NA~E : -999.2500 -9q9.2500 -999.2500 7,0391 -~99.2500 -999.2500 -999.2500 1.~330 -999.2500 -999,2500 -999,2500 2000.0000 -999.2500 -999,2500 -999,2500 NPHI FC ~ I~ P H I FC~L I bD NPH1 I b D NPH 1 ["C~L -999.2500 -999.2500 8.3281 -999.2500 -999.2500 2.2109 -999. 2500 -999. 2500 1,].1328 -999,2500 -999,2500 ** TAPE TRAILER ** SERVICE NAME :EDIT DATE :~i4t10/ 2 ORIGIN :FSla T A P E .i:~ A ~'; E : CONTIN[.I~TION ~ :01 NEXT TAPE NA~i'E : ** REE:L TRAILER SERVICE NAklE :EDIT ~ATE :8~/1,0/ 2 RIGIN REEL ~,~AF~E CONTINUATION ~ 101 NEX REEL NA E : EOF