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Home My WebLink About181-0352022-1019_Location_Clear_Kuparuk_28243-1_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10-27-2022 P. I. Supervisor FROM: Adam Earl SUBJECT: Final Location Clearance Petroleum Inspector Kuparuk 28243-1 CPAI PTD 1810350; Sundry 321-074 10-19-2022: I traveled to Kuparuk River Unit 1M pad for the final site clearance inspection of Kuparuk MP 28243-1. Brennen Green was the CPAI representative on location. The wellsite was clean, clear of any visible contaminates, and it looked satisfactory. No issues. Attachments: 2 pictures     2022-1019_Location_Clear_Kuparuk_28243-1_ae Page 2 of 2 Location Clearance – Kuparuk 28243-1 (PTD 1810350) Photos by AOGCC Inspector A. Earl 10/19/2022 You don't often get email from john.w.hanes@exxonmobil.com. Learn why this is important From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]RE: Kuparuk MP 28243-1 Date:Tuesday, October 18, 2022 2:05:36 PM Kuparuk 28243-1 (PTD 1810350) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Hanes, John W <john.w.hanes@exxonmobil.com> Sent: Tuesday, October 18, 2022 1:04 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Lonzo, Nicki M <nicki.m.lonzo@exxonmobil.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; Green, Brennen S (ASRC Energy Services) <Brennen.S.Green@contractor.conocophillips.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL]RE: Kuparuk MP 28243-1 Greg, Thanks for your e-mail below and I have received approval from Todd Griffith (ExxonMobil’s Alaska JI Manager) to designate Brennen Green to be the ExxonMobil witness for the final site clearance inspection. If you should have any questions or need anything further, please let me know. Thanks again for your assistance in this matter! Regards, John W. Hanes Senior Land Advisor U.S. Conventional / Commercial & Land ExxonMobil Upstream Company 22777 Springwoods Village Parkway Wellness 4.2B.328 Spring, Texas 77389 Office: (346) 474-9102 New Zoom office number as Skype has been decommissioned within ExxonMobil. Cell: (281) 728-8831 e-mail: john.w.hanes@exxonmobil.com The information in this electronic message may be privileged and confidential and is intended only for the use of the individual(s) and/or entity(entities) named above. If you are not the intended recipient, you are on notice that any unauthorized disclosure, copying, distribution, or taking of any action in reliance on the contents of the electronically transmitted materials is prohibited. From: Hobbs, Greg S [mailto:Greg.S.Hobbs@conocophillips.com] Sent: Monday, October 17, 2022 6:56 PM To: Hanes, John W <john.w.hanes@exxonmobil.com> Cc: Lonzo, Nicki M <nicki.m.lonzo@exxonmobil.com>; Byrne, Jan <Jan.Byrne@conocophillips.com>; Green, Brennen S (ASRC Energy Services) <Brennen.S.Green@contractor.conocophillips.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL]RE: Kuparuk MP 28243-1 External Email - Think Before You Click Good Evening John- Jan Byrne of our integrity group has confirmed that Brennen Green, one of our Well Integrity Supervisors is working to coordinate the site clearance inspection for 1M-17 and Kuparuk MP 28243- 1 within the next week, weather permitting. I called Jim Regg at the AOGCC and he confirmed that an e-mail from Exxon (Land or Legal Department) to himself (cc’d) would suffice for delegation of Brennen Green to be the Exxon witness for the final site clearance inspection. Thank-you for the help with this. Greg From: Hanes, John W <john.w.hanes@exxonmobil.com> Sent: Monday, October 17, 2022 1:01 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Lonzo, Nicki M <nicki.m.lonzo@exxonmobil.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: [EXTERNAL]RE: Kuparuk MP 28243-1 Greg, Let me know who at COP we should designate as representatives for the site inspection and I will work to get the appropriate internal approval and provide same to you via e-mail or however is deemed necessary. Thanks again for your help in coordinating the site inspection. Regards, John ----- John W. Hanes Senior Land Advisor U.S. Conventional / Commercial & Land ExxonMobil Upstream Company 22777 Springwoods Village Parkway Wellness 4.2B.328 Spring, Texas 77389 Office: (346) 474-9102 New Zoom office number as Skype has been decommissioned within ExxonMobil. Cell: (281) 728-8831 e-mail: john.w.hanes@exxonmobil.com The information in this electronic message may be privileged and confidential and is intended only for the use of the individual(s) and/or entity(entities) named above. If you are not the intended recipient, you are on notice that any unauthorized disclosure, copying, distribution, or taking of any action in reliance on the contents of the electronically transmitted materials is prohibited. From: Hobbs, Greg S [mailto:Greg.S.Hobbs@conocophillips.com] Sent: Friday, October 14, 2022 5:53 PM To: Hanes, John W <john.w.hanes@exxonmobil.com> Cc: Lonzo, Nicki M <nicki.m.lonzo@exxonmobil.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: [EXTERNAL]RE: Kuparuk MP 28243-1 External Email - Think Before You Click John, Mr. Regg has said his inspectors can do a site inspection if we do it as soon as possible. I have reached out to our engineers to see if we can get that arranged. Are you able to delegate our personnel as representatives for an Exxon inspection? I am assuming an e-mail will suffice here. My understanding, which I was not clear on earlier, is that we abandoned 1R-17 and MP28243-1. The pad is still a bit remote, and I am not sure of access. I will keep you posted. Thank-you for the help. Greg From: Hobbs, Greg S Sent: Wednesday, October 12, 2022 8:54 AM To: 'Hanes, John W' <john.w.hanes@exxonmobil.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Cc: Lonzo, Nicki M <nicki.m.lonzo@exxonmobil.com> Subject: RE: [EXTERNAL]RE: Kuparuk MP 28243-1 John, Per the discussion below, Erika asked for support on a call with the AOGCC to arrange the site inspection. This never occurred. There was then the note that you would be taking on the project. I was anticipating your engagement to finalize the site inspection. ConocoPhillips does not have a bond for the site. My suggestion would be to connect with Mr. Regg to see if we can get a site inspection in place prior to snow accumulation if that is still a possibility. My understanding form Mr. Regg’s e-mail is that there has to be interaction from Exxon with the AOGCC to designate the delegate for the inspection. Apologies for the confusion. Greg From: Hanes, John W <john.w.hanes@exxonmobil.com> Sent: Tuesday, October 11, 2022 12:23 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Cc: Lonzo, Nicki M <nicki.m.lonzo@exxonmobil.com> Subject: RE: [EXTERNAL]RE: Kuparuk MP 28243-1 Greg, Per the e-mail below, please confirm that the AOGCC site inspection for the subject well was done this past summer and if AOGCC provided a release. Such release is needed so that ExxonMobil’s Bond 82583272 can be cancelled and/or advise if ConocoPhillips now has a bond for such well/pad site as such has been transferred to the Kuparuk River Unit, with ConocoPhillips as Operator. If you have any questions or would like to discuss, please let me know. Thanks, John W. Hanes Senior Land Advisor U.S. Conventional / Commercial & Land ExxonMobil Upstream Company 22777 Springwoods Village Parkway Wellness 4.2B.328 Spring, Texas 77389 Office: (346) 474-9102 New Zoom office number as Skype has been decommissioned within ExxonMobil. Cell: (281) 728-8831 e-mail: john.w.hanes@exxonmobil.com The information in this electronic message may be privileged and confidential and is intended only for the use of the individual(s) and/or entity(entities) named above. If you are not the intended recipient, you are on notice that any unauthorized disclosure, copying, distribution, or taking of any action in reliance on the contents of the electronically transmitted materials is prohibited. From: Hobbs, Greg S [mailto:Greg.S.Hobbs@conocophillips.com] Sent: Monday, March 28, 2022 3:30 PM To: Denman, Erika /C <erika.denman@exxonmobil.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Cc: Hanes, John W <john.w.hanes@exxonmobil.com>; Griffith, Todd <todd.griffith@exxonmobil.com> Subject: Re: [EXTERNAL]RE: Kuparuk MP 28243-1 External Email - Think Before You Click Thank you Erika. Best with your move. Greg Get Outlook for iOS From: Denman, Erika /C <erika.denman@exxonmobil.com> Sent: Monday, March 28, 2022 11:51:35 AM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Cc: Hanes, John W <john.w.hanes@exxonmobil.com>; Griffith, Todd <todd.griffith@exxonmobil.com> Subject: RE: [EXTERNAL]RE: Kuparuk MP 28243-1 Hi Will/Greg I will be moving on effective March 31, 2022. Please coordinate the summer AOGCC site inspection for Kuparuk 28243-1 well with John Hanes, who I’ve cc’d on this email and who can also be reached at (832)625-4501. John will be following up with AOGCC to closeout any documentation requirements and the bond for Kuparuk 28243-1. Thank you for your assistance in helping to clarify this with AOGCC and for helping to coordinate location clearance. Regards, Erika From: Hobbs, Greg S [mailto:Greg.S.Hobbs@conocophillips.com] Sent: Thursday, March 3, 2022 1:45 PM To: Earhart, Will C <William.C.Earhart@conocophillips.com> Cc: Denman, Erika /C <erika.denman@exxonmobil.com> Subject: FW: [EXTERNAL]RE: Kuparuk MP 28243-1 External Email - Think Before You Click Will, FYI. We can work with Erika to get this done this summer. Greg From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, March 3, 2022 1:39 PM To: Denman, Erika /C <erika.denman@exxonmobil.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]RE: Kuparuk MP 28243-1 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Kuparuk 28243-1 (PTD 1810350) KRU 1M-17 (PTD 2012300) Before bond #82583272 can be released, AOGCC requires a location inspection when the site is clear of snow and ice accompanied by ExxonMobil or their designee. I checked well files and find no evidence of any location inspection at KRU 1M-pad. By regulation (20 AAC 25.170(a)), that inspection should have occurred during summer 2021 since the surface P&A of both KRU 1M-17 and Kuparuk 28243-1 were completed in April 2021. Please use the AOGCC web notice form and submit at least 48 hrs in advance of the location inspection. Jim Regg Supervisor, Inspections AOGCC 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. You don't often get email from erika.denman@exxonmobil.com. Learn why this is important 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Denman, Erika /C <erika.denman@exxonmobil.com> Sent: Wednesday, March 2, 2022 11:37 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Greg.S.Hobbs@conocophillips.com Subject: Kuparuk MP 28243-1 James, I am working on the release of the ExxonMobil Alaska Production (EMAP) AOGCC bond #82583272. I understand that there may be outstanding AOGCC requirements for the Kuparuk well 28243-1 (PTD 181-035) that may need to be addressed prior to bond closure. Do you have some time available to discuss those requirements and allow me to better understand what AOGCC requirements may be outstanding? I’d like to include Greg Hobbs of ConocoPhillips (CPAI) in the discussion since the well is located in Kuparuk and CPAI had helped complete the P&A. Our schedules are pretty open, so let me know if there is a time that would be convenient for you this week. Regards, Erika Erika A. Denman Environmental & Regulatory Advisor (Contractor) ExxonMobil Alaska Production, Inc. 3700 Centerpoint Drive, Suite 600 Anchorage, AK 99503 +1 907-564-3612 Office +1 907-350-2127 Cell 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Thursday, March 3, 2022 1:39 PM To:Denman, Erika /C; Greg.S.Hobbs@conocophillips.com Cc:Roby, David S (OGC) Subject:RE: Kuparuk MP 28243-1 Kuparuk 28243‐1 (PTD 1810350) KRU 1M‐17 (PTD 2012300) Before bond #82583272 can be released, AOGCC requires a location inspection when the site is clear of snow and ice accompanied by ExxonMobil or their designee. I checked well files and find no evidence of any location inspection at KRU 1M‐pad. By regulation (20 AAC 25.170(a)), that inspection should have occurred during summer 2021 since the surface P&A of both KRU 1M‐17 and Kuparuk 28243‐1 were completed in April 2021. Please use the AOGCC web notice form and submit at least 48 hrs in advance of the location inspection. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Denman, Erika /C <erika.denman@exxonmobil.com> Sent: Wednesday, March 2, 2022 11:37 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Greg.S.Hobbs@conocophillips.com Subject: Kuparuk MP 28243‐1 James, I am working on the release of the ExxonMobil Alaska Production (EMAP) AOGCC bond #82583272. I understand that there may be outstanding AOGCC requirements for the Kuparuk well 28243‐1 (PTD 181‐035) that may need to be addressed prior to bond closure. Do you have some time available to discuss those requirements and allow me to better understand what AOGCC requirements may be outstanding? I’d like to include Greg Hobbs of ConocoPhillips (CPAI) in the discussion since the well is located in Kuparuk and CPAI had helped complete the P&A. Our schedules are pretty open, so let me know if there is a time that would be convenient for you this week. Regards, Erika Erika A. Denman You don't often get email from erika.denman@exxonmobil.com. Learn why this is important 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. WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt_____________________ X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:_______________gnature01/24/2022Abby BellWd͗ϭϴϭϬϯϱϬͲ^Ğƚ͗ϯϲϮϵϭJRBy Abby Bell at 11:57 am, Jan 24, 2022 1H-119WLKRU50029235910000IPROFFINAL FIELD24-Jun-211H-117WLKRU50029236020000IPROFFINAL FIELD16-Jun-213H-31AWLKRU50103202050100CUTTERFINAL FIELD31-Jul-213S-611WLKRU50103207740000CUTTERFINAL FIELD11-Oct-211R-101WLKRU50029214040300SAMPLINGFINAL FIELD30-Jun-213H-37WLKRU50103208220000GLSFINAL FIELD29-May-21MP-1WLKRU50029205730000PERFFINAL FIELDMP-1WLKRU50029205730000PERFFINAL FIELDMP-1WLKRU50029205730000SCMTFINAL FIELD28-Mar-211G-02WLKRU50029208130000IPROFFINAL FIELD1C-190WLKRU50029231360000IPROFFINAL FIELD2L-318WLKRU50103206810000IPROFFINAL FIELD29-Mar-2101-Apr-2120-Feb-2119-Feb-2123-Feb-211J-1013F-045002923286000050029214490000KRUKRUWLWLPPROFIPROFFINAL FIELDFINAL FIELD12-Sep-2124-Jul-21 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt_____________________ X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:_______________gnature01/24/2022Abby BellWd͗ϭϴϭϬϯϱϬͲ^Ğƚ͗ϯϲϮϵϬJRBy Abby Bell at 11:57 am, Jan 24, 2022 1H-119WLKRU50029235910000IPROFFINAL FIELD24-Jun-211H-117WLKRU50029236020000IPROFFINAL FIELD16-Jun-213H-31AWLKRU50103202050100CUTTERFINAL FIELD31-Jul-213S-611WLKRU50103207740000CUTTERFINAL FIELD11-Oct-211R-101WLKRU50029214040300SAMPLINGFINAL FIELD30-Jun-213H-37WLKRU50103208220000GLSFINAL FIELD29-May-21MP-1WLKRU50029205730000PERFFINAL FIELDMP-1WLKRU50029205730000PERFFINAL FIELDMP-1WLKRU50029205730000SCMTFINAL FIELD28-Mar-211G-02WLKRU50029208130000IPROFFINAL FIELD1C-190WLKRU50029231360000IPROFFINAL FIELD2L-318WLKRU50103206810000IPROFFINAL FIELD29-Mar-2101-Apr-2120-Feb-2119-Feb-2123-Feb-211J-1013F-045002923286000050029214490000KRUKRUWLWLPPROFIPROFFINAL FIELDFINAL FIELD12-Sep-2124-Jul-21 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϭϬϯϱϬͲ^Ğƚ͗ϯϲϭϲϲJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1H-11950029235910000 KRU WLIPROFFINAL FIELD24-Jun-211H-11750029236020000 KRU WLIPROFFINAL FIELD16-Jun-213H-31A50103202050100 KRU WLCUTTERFINAL FIELD31-Jul-213S-61150103207740000 KRU WLCUTTERFINAL FIELD11-Oct-211R-10150029214040300 KRU WLSAMPLINGFINAL FIELD30-Jun-213H-3750103208220000 KRU WLGLSFINAL FIELD29-May-213F-0450029214490000 KRU WLIPROFFINAL FIELD23-Feb-211J-10150029232860000 KRU WLPPROFFINAL FIELD2-Mar-211D-0250029204290000 KRU WLIPROFFINAL FIELD17-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD18-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD20-Feb-21MP-150029205730000 KRU WLSCMTFINAL FIELD28-Mar-211G-0250029208130000 KRU WLIPROFFINAL FIELD1-Apr-211C-19050029231360000 KRU WLIPROFFINAL FIELD30-Oct-212L-31850103206810000 KRU WLIPROFFINAL FIELD24-Jul-21 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI:x- y- Zone- 4 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: Total Depth:x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 16"80 10.75"K-55 2930 7"K-55 6894 24. Open to production or injection?Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED 27. Date First Production:Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Kuparuk River Unit N/A Oil-Bbl:Water-Bbl: 1844-8850 N/A - suspended well, was not perforated Plugged and Abandoned Gas-Oil Ratio: Flow Tubing Choke Size: 245 bbl 15.8# Class G Surface - 1844'145 bbl 15.8# cold temp cmt (fullbore TxIA) Water-Bbl: PRODUCTION TEST N/A - suspended well, was not perforated Date of Test:Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 26#26 65# 45.5# 80 26 8780 CASING WT. PER FT.GRADE 567, 56 TOP SETTING DEPTH MD 26 TOP 8.75" 26 13.75"26 571,583 5,960,324 3713' FEL, 1246' FSL, Sec. 18, T11N, R11E, UM 2300 sx Dowell Arcticset II 5/24/1981 CEMENTING RECORD 5,960, 1754' TVD SETTING DEPTH TVD 5,96 ADL 28243 5/5/1981 8,850 / 6,949 N/A 92' HOLE SIZE AMOUNT PULLED suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary PO Box 196601, Anchorage, AK 99519-6601 4/13/2021 181-035 / 321-074 50-029-20573-00-00 Kuparuk 28243-1 ADL 28243 605' FWL and 470' FSL, Sec. 17, T11N, R11E, UM 4027' FEL, 1402' FSL, Sec. 18, T11N, R11E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ExxonMobil Production Company WAG Gas N/A 26" BOTTOM 4,4573.5" SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) TUBING RECORD 510 sx Class G 26 2930 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, NNNNNNJ G s d 1 0 p dB t Pf L s ((attttach Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 7:33 am, May 13, 2021 RBDMS HEW 5/13/2021 Abandonment Date 4/13/2021 HEW xG DSR-5/14/21DLB 05/14/2021VTL 9/9/21 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1757' 1757' Top of Productive Interval 8276' 6495' 8590' 6742' 8850' 6949' 31. List of Attachments: Summary of Operations, Wellbore Schematic, Abandonment photos, MIT test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Todd Griffith Contact Name:Claire Mayfield Asset Manager Contact Email:claire.c.mayfield@exxonmobil.com Authorized Contact Phone:(907) 564-3651 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Kuparuk "B" Sand Kuparuk "C" Sand If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Exxon 28243-1 Final P&A Status PTD: 181-035 Conductor: 16" Conductor 65# 80' MD /TVD Surface Cement: 10-¾” Surface Casing Cemented from Shoe (2,930' MD) to Surface 7" Production Casing x 10-¾” Surface Casing Outer Annulus Cemented from Surface to 2,300' MD Base of Permafrost: 1,757' MD / TVD (from 1M-17 geo logs) Production Casing Cement: Class G Cement from TD to 4110' MD SGW 4/16/21 1 Production Casing: 7" 26# K-55 BTC to 8,780' MD / 6,897' TVD Surface Casing: 10-3/4", 45.5#, K-55, BTC Set @ 2,930’MD / TVD Kill String: 3 ½”, 9.3# Run to 4,457' KB 2 5 Kuparuk C-Sand 8276' MD / 6495' TVD Kuparuk B-Sand 8590' MD / 6742' TVD TD: 8850' MD, 6949' TVD Tubing & Casing Punch Plug 1 & 2 Cement Interface at ~2029' in Tubing, ~1844' in IA. 3-½” Tubing & 7" Casing Perforated Until OA Circulation Achieved, Prior to Circulating Cement TxIAxOA Cement Plugs Plug #1: Coil Tubing placed. 245 bbls of 15.8# Class G from TD to TOC (Tubing TOC - 2029', IA TOC - 1844') 7" 26# Casing Capacity = 0.03826 bbl/ft Plug #2: Fullbore TxIAxOA to surface. 154 bbls of 15.8# Cold Temp Cement from top of Plug 1 to surface. 10-3/4" 45.5# Casing x 7" 26# Casing OA Capacity = .04857 bbl/ft. 7" 26# Casing x 3 1/2" 9.3# Tbg IA Capacity = 0.02636 bbl/ft. Item Depth - tops (KB) 1 All Strings Cut 6' Below Grade, Welded Plate Surface 2 3 1/2" Tubing (Grade Unknown) 4,457' 3 Secondary Tubing & Casing Punch 1,340' 4 Initial Tubing & Casing Punch 1,800' 5 WLEG 4,457' 3 4 WELLNAME DTTMSTART JOBTYPSUMMARYOPS28243-1 03/02/21 06:00: AM ABANDONMENT(P&A) INSTALL IA AND OA CASING VAVLE JEWELRY COMPLETE.28243-1 03/03/21 05:30: AM ABANDONMENTTAGGED TD @ 5990' RKB; RAN TEMPERATURE SURVEY W/ STOPS @ 5988', 1900', 1800', 1757', & 1700' RKB; CMIT TBG X IA TO 2500 PSI (PASS); MIT-OA TO 1000 PSI (PASS); READY FOR CTU.28243-1 03/22/21 02:00: PM ABANDONMENTMOB Deadhorse to 1M pad, MIRU. TEST BOPE.28243-1 03/23/21 12:00: AM ABANDONMENTRECOVER ALL DRIFT BALLS FROM COIL. RIH WITH UNDERREAMER. SAW NO MOTOR WORK DOWN TO HARD TAG AT 8734' CTMD. OPENED CIRC SUB AND CIRCULATED WELL OVER TO SEAWATER. RIH WITH HYDRAULIC BOW SPRING. MADE 3 ATTEMPTS TO LOCATE TT WITH NO SUCCESS. POOH. JOB IN PROGRESS.28243-1 03/24/21 12:00: AM ABANDONMENTRIH WITH UNDERREAMER WITHOUT A MOTOR. ATTEMPT TO LOCATE TUBING TAIL UNSUCCESSFUL. DISCUSS WITH ENG AND READY TO MOVE FORWARD WITH CEMENT. LAY IN 165 BBLS OF 15.8# CLASS G CEMENT FROM TD TO TUBING TAIL TAKING RETURNS UP THE TUBING. SHUT IN TUBING AND TAKE RETURNS UP THE IA PUMPING A TOTAL OF 65 BBLS. ESTIMATED CEMENT TOP IN IA @ ~2000'. SHUT IN IA AND BEGIN LAYING IN 15 BBLS OF CEMENT IN THE TUBING TAKING RETURNS UP THE TUBING. CLEAN DOWN TO ESTIMATED CEMENT TOP @ 2000' IN TUBING. WASH TUBING AND LAY IN FP IN TUBING FROM 2000' TO SURFACE. WASH UP ALL SURFACE LINES. RDMO. READY FOR SL/DHD IN 24 HOURS.28243-1 03/26/21 12:00: PM ABANDONMENTTAG @ 2054' SLM, 2029' CORRECTED TO TUBING HANGER. LEFT LRS HERE TO MITT & MITIA.28243-1 03/26/21 04:00: PM ABANDONMENTSTATE MIT'S28243-1 03/27/21 06:00: AM ABANDONMENT(P&A) AOGCC INSPECTOR BRIAN BIXBY WITNESSED CMITxIA TO 2230 PSI (PASSED) NEXT : ELINE28243-1 03/28/21 07:00: AM ABANDONMENTSTANDBY FOR TEMPERATURE PRIOR TO RIGGING UP DUE TO MANLIFT LIMITATIONS. LOG SCMT FROM CEMENT TAG AT 2064' RKB TO SURFACE AT 30 FPM. TOP OF CEMENT IN IA LOCATED AT 1844'. JOB CONTINUED ON 29-MAR-2021.28243-1 03/29/21 05:30: AM ABANDONMENTPERFORATE TUBING AND IA W/ 5' OF 2.00" POWERFLOW HSD, 1 SPF, 0 DEGREE PHASING ORIENTED TO THE HIGHSIDE. PERFORATED INTERVAL = 1800' - 1805', CCL TO TOP SHOT = 5.7' , CCL STOP DEPTH = 1794.3'. GOOD INDICATION OF TXIA COMMUNICATION. JOB COMPLETE.28243-1 03/29/21 01:00: PM ABANDONMENTPOST TBG PUNCH @ 1800' TO 1805' ELM CIRCULATE 65 BBL HOT DIESEL, ATTEMPT TO GAIN COMMUNICATION WITH OA, SWAP TO SW, CIRCULATE T/IA HOT SW, STILL NO COMMUNICATION TO OA, CONTINUE HOT SW CIRCULATION, RETURN TEMP 158° AT MIDNIGHT, IN PROGRESS.28243-1 03/30/21 12:00: AM ABANDONMENTCONTINUE HOT SW CIRCULATION THRU OUT DAY, UNABLE TO OBTAIN OA COMMUNICATION, RETURN TEMP 153° AT MIDNIGHT, IN PROGRESS.28243-1 03/31/21 12:00: AM ABANDONMENTCONTINUE HOT SW CIRCULATION THRU OUT DAY, UNABLE TO OBTAIN OA COMMUNICATION WITH PRESSURE TBG/IA TO 1800 PSI, IN PROGRESS.28243-1 04/01/21 12:00: AM ABANDONMENTCONTINUE HOT SW CIRCULATION , UNABLE TO OBTAIN OA COMMUNICATION, SWAP TBG/IA TO WARM DIESEL, ASSIST E/LINE PERFORATE TUBING. 28243-1 04/01/21 05:30: AM ABANDONMENTPERFORATE TUBING AND IA W/ 5' OF 2.00" POWERFLOW HSD, 1 SPF, 0 DEGREE PHASING ORIENTED TO THE HIGHSIDE. PERFORATED INTERVAL = 1340' - 1345', CCL TO TOP SHOT = 5.7' , CCL STOP DEPTH =. 1334.3'. INITIALLY UNABLE TO ESTABLISH OA COMMUNICATION, 6 SPF GUN BUILT AND BROUGHT TO LOCATION. LRS PUMPED 60 BBL HOT DIESEL WHILE RIH WITH GUN. OA COMMUNICATION ESTABLISHED WHEN PRESSURING UP TUBING TO 1000 PSI PRIOR TO FIRING. JOB COMPLETE.28243-1 04/01/21 09:00: PM ABANDONMENTOBTAINED OA COMMUNICATION AFTER 100 BBLS DIESEL POST TBG PUNCH, DISPLACE ARCTIC PACK GEL AND FLUSH OA WITH HOT DIESEL .75 BPM AT 400 PSI PUMP PRESSURE, 10 PSI OA PRESSURE, IN PROGRESS.28243-1 04/02/21 12:00: AM ABANDONMENTFLUSH OA WITH 90 BBL HOT DIESEL. READY FOR CEMENT.28243-1 04/03/21 06:00: AM ABANDONMENTCemented TxIAxOA to surface with 108 BBLS of 15.8ppg AS-1. 28243-1 04/09/21 01:00: PM ABANDONMENT(P&A) PJSM REMOVE TREE EXCAVATE AROUND CELLAR28243-1 04/10/21 07:00: AM ABANDONMENT(P&A) CUT AND REMOVE CELLAR BOX28243-1 04/11/21 06:00: AM ABANDONMENT(P&A) EXCAVATE TO 12' AND INSTALL 10'x16' PIPE FOR SHORING BOX. 28243-1 04/12/21 06:00: AM ABANDONMENT(P&A) CUT AND REMOVE 14'2" (6' below tundra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tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �51)(31z, DATE: 4/13/2021 P. I. Supervisor r FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector Kuparuk 28243-1 , ExxonMobil Alaska Production Inc. - PTD 1810350; Sundry 321-074 - 4/13/2021: 1 traveled out to KRU 1 M -pad to witness the surface abandonment of ExxonMobil's Well 28243-1. 1 observed hard cement in the tubing and all casing annular spaces and verified all the correct information on the marker plate. The wellhead was cut to 5 feet below natural grade and everything looked good. Attachments: Photos (2) 2021-0413—Surface—Abandon Kuparuk_28243-1_I1.docx Page 1 of 2 Surface Abandonment — Kuparuk 28243-1 (PTD 1810350) Photos by AOGCC Inspector L. Laubenstein 4/123/2021 RR jl%M fv�111 ` 7u`a9T;al r, A 2021-0413_ Surface_Abandon _Kuparuk_28243-1_11. docx Page 2 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� QIZ2�2azI DATE: March 28, 2021 P. I. Supervisor FROM: Brian Bixby SUBJECT: Plug Verification Petroleum Inspector Kuparuk 28243-1 - ConocoPhillips Alaska Inc. PTD 181-035�-Sundry 321-074 3/27/2021: 1 met with ConocoPhillips representatives Roger Mouser and Stefan Weingarth. Abandonment work is being done by CPAI on behalf of ExxonMobil Alaska. Discussed the issues they had the day before attempting to do MIT -T and MIT -IA (see Inspector Bob Noble report dated 3/26/2021). Plan forward (CMIT TxlA) was approved by Victoria Loepp (AOGCC Engineer). They rigged up a jumper from the tubing to the IA and a chart recorder. The test was charted but the chart recorder was not current on it's calibration. I had the DHD crews install current calibrated test gauges on the tubing, inner annulus and outer annulus. Pretest Pressures: Tubing 460 psi; Inner Annulus 970 psi; Outer Annulus 4 psi Test Result: Initial 15 min 30 min 45 min Result Tubing 2230 - 2175 2165 - IA 2230 _ 2185 2165 - P OA 8 9 9 2021-0327_Plug_Verification_Kuparuk_28243-1_bb.docx Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �Zefel 4 jzz( -7t7z( P.I. Supervisor FROM: Bob Noble Petroleum Inspector Section: 17 1 Township: Drilling Rig: N/A Rig Elevation: Operator Rep: Mark Adams Feet Casing/Tubing Data (depths are MD): Conductor: 161, O.D. Shoe@ Surface: 10 3/4" O.D. Shoe@ Intermediate: O.D. Shoe@ Production: 7" O.D. Shoe@ Liner: O.D. Shoe@ Tubing: 31/2" O.D. Tail@ Plugging Dat; Test Data: DATE: March 26, 2021 SUBJECT: Well Bore Plug & Abandonment Kuparuk 28243-1 ' CPA PTD 181-035, Sundry 321-074 11N Range: 11E Meridian: Umiat N/A Total Depth: 8850 ft MD Lease No.: ADL 28243 Suspend: P&A: X Tvoe Pluq ounded on Depth Btm Casing Removal: 80 - Feet Csg Cut@ Feet 2930 - Feet Csg Cut@ Feet 20 Feet Csg Cut@ Feet 8780 Feet Csg Cut@ Feet Feet Csg Cut@ Feet 4457 - Feet Tbg Cut@ Feet Tvoe Pluq ounded on Depth Btm Depth To MW Above Verified Fullbore - Bottom - 8780 ft MD 2054 ft MD' Wireline tag 0 F OA 20 20 20 20 inis.i 15 min 3n min 45 min Result Tubing 2200 2095 - 2000 - 1995 IA IA 0 0 0 0 F OA 20 20 20 20 1. ia�i 1r min 3n min 4.5 min Result Tubing 560 800 - 820 ' IA 2200 - 2025' 2000 � F OA 1 20 20 20 Remarks: Successful tag; Tubing and IA tests failed due to excessive pressure loss Attachments: none rev. 11-28-18 2021-0326_Plug_Verification_Kuparuk_28243-1_bn 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Renew Suspension __ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Kuparuk 28243-1 Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): Kuparuk River Unit 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): Casing Collapse Structural Conductor Surface 2700 Intermediate Production 4320 Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Todd Griffith Contact Name: Claire Mayfield Asset Manager Contact Email:claire.c.mayfield@exxonmobil.com Contact Phone:(907) 564-3651 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: 3/1/2021 3-1/2" Perforation Depth MD (ft): N/A 8757' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7" 16" 10-3/4"2904' 80' 2930' 6894'8780' Unknown TVD Burst 4,457' 4980 MD 4030 PO Box 196601, Anchorage, AK 99519-6601 50-029-20573 ExxonMobil Production Company Length Size Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 28243 181-035 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): N/A m n P 1 6 5 6 t __ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:14 am, Feb 08, 2021 321-074 X AOGCC inspection required after well head cutoff and before remedial cementing.Well abandonment marker to meet requirements of 20 AAC 25.120 Photo document all steps of surface abandonment All pressure tests to be charted for 30 min X 6,949 SFD 2/9/2021-00-00 SFD 2/9/2021 DSR-2/8/21 8,850 SFD 2/9/2021 10-407 X VTL 3/2/21 Comm. 3/2/21 dts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age 1 of 20 ConocoPhillips Alaska Inc. / ExxonMobil Alaska Production Inc. Well 28243-1 Plug and Abandonment Program Winter 2021 REVISED 2/24/21 Prepared by: _________________ Stefan Weingarth 907-265-6038 Wells Engineer Approved by: _________________ Ty Senden 907-265-1544 Well Integrity/Intervention Director Distribution: Contractor Team: Well Intervention Director 1 copy Schlumberger Coil email CPAI Wells Superindent 1 copy Schlumberger Cement email Well Supervisors 1 copy Halliburton Wireline email Well Integrity Specialists 1 copy Natalie Berryman Dye (DPE) 1 copy Jill Simek (Wells Engr) 1 copy Claire Mayfield (XOM PE) 1 copy Invoicing Details: Network Number: 10429427 SAP Reviewer: SGWEING SAP Approver: RTSENDE 1M-17 P&A Page 2 of 20 Contents 1. Job Objective: ........................................................................................................................................ 2 2. Well Status / Risks and Concerns: ......................................................................................................... 4 3. Current Well Schematic ........................................................................................................................ 5 Preparation: .................................................................................................................................................. 6 4. Well Abandonment: .............................................................................................................................. 7 5. Surface Remedial Work & Final Testing ................................................................................................ 9 Well Status (Post-Abandonment): .............................................................................................................. 11 6. Appendix ............................................................................................................................................. 15 a. Current Schematic: ............................................................................................................................. 15 b. Planned P&A Diagram: ........................................................................................................................ 16 c. GKA Road Map .................................................................................................................................... 17 d. Well History ......................................................................................................................................... 18 1. Job Objective: Conduct a Safe, Injury Free and Spill Free Operation. ExxonMobil well 28243-1 was originally drilled through the Kuparuk B&C-Sands in 1981. Logging was performed, though a testing completion was never run, with the wellbore remaining cemented. The well has had limited utility since being drilled and will thus be plugged back and abandoned during the 2021 winter season. The program will include building ice to access 1M pad, preparation work to service 28243-1’s wellhead, and drift runs with wireline. A coiled tubing fill cleanout is planned to prepare the wellbore for cementing. Two separate cement plugs will be pumped, with the lower production casing plug pumped via coiled tubing. The tubing, inner annulus and outer annulus will be cemented off with a single cement plug after perforating through the tubing and production casing to allow for OA circulation. Following final cement setting and testing, surface P&A operations will be completed. The project is estimated to be completed with under $750M and 18 days. 1M-17 P&A Page 3 of 20 High level program summary: 1. Kuparuk Roads & Pads to construct ice bridge across East Creek to allow for access to 1M pad. Roads & Pads will service the pad to allow for safely executing scope. 2. DHD crew to service tree valves. 3. LRS: x Pressure test wellbore to 2000 psi. 4. Slickline/Digital Slickline: x Pull BPV (if deployed). x Drift and tag TD at 8850’. x Perform temperature log to surface to confirm permafrost depth/temperature. 5. Pressure test OA to confirm original cement integrity. 6. Coiled Tubing/Cement Unit: x Pump Cement Plug #1 – 252 bbls 15.8# Class G Cement from TD to ~2000’ RKB TxIA. 7. Slickline/LRS: x Tag top of cement. x Pressure test cement to 2000 psi after 24 hour curing period. 8. Cement Unit: x Pump Cement Plug #2 – 168 bbls of 15.8# AS1 Cement circulated TxIAxOA. *Volumes pending previous cement plug’s depths. 9. DHD, Wells Support, and LRS: x Pressure test final surface plugs. x Bleed all surface pressures to 0 psi. x Excavate below grade. Remove wellhead and tree. Weld well identification cap covering all strings. Document scope completed. 1M-17 P&A Page 4 of 20 2. Well Status / Risks and Concerns: x Tree: unknown – determine connections once 1M pad is accessible. x Tree is 40 years old and has not been in service, valves may need to be serviced. x Unknown whether BPV and VR plugs are in tree. x Fluids in 3-1/2” tubing & 3/1-2” x 7” annulus: o 4457’ of diesel freeze protect (156 bbls) x Fluids in 7” production casing x 10-3/4” surface casing annulus: o 2300’ of diesel based Arctic Pack gel. o 15.8# Arctic Set VI cement from 2300’ to surface casing shoe at 2930’ RKB. x Fluids in 7” production casing, below 3-1/2” string to TOC: o 9.8 ppg mud from 4457’ to TOC at 8,780’ (165 bbls) x Permafrost depth at 1754’ TVD (1868’ RKB, using 1M-17 as analog). x Expected Kuparuk reservoir pressure 2549 psi (at datum of 6200’ TVD) with EMW of 7.9 ppg. Reservoir temperature 152° F. x Well Capacities: o 3-1/2” 9.3# Tubing = .0087 bbl/ft. ID = 2.992” o 3-1/2” x 7” Annulus = .0264 bbl/ft o 7” 26# Production Casing = .0383 bbl/ft. ID = 6.276” Safety: x Ensure the on-tour Wells Supervisor can always be reached by radio. x Monitor weather and follow ConocoPhillips Cold Weather Operating Procedures when applicable. x Keep non-intrinsically safe devices such as cell phones out of classified areas. x Ensure all equipment and tanks are electrically grounded. x Coordinate with Roads & Pads to scratch & plow ice pad as needed to minimize slips, trips & falls. x Report any accidents or spills to Wells Supervisor and Field Environmental Coordinator. Report near misses to Wells Supervisor. 1M-17 P&A Page 5 of 20 3. Current Well Schematic 1M-17 P&A Page 6 of 20 Preparation: Ensure DHD is available for necessary tree and integrity testing. Verify Schlumberger CTU and cement equipment is ready for P&A. 2” coil string is recommended to help reduce pump pressures and maximize rate. Coordinate with Kuparuk environmental for disposal of contaminant. Stage tanks and support equipment in secondary containment as needed. Equipment spread should be staged for minimal rig-up / rig-down between 1M-17 & 28243-1 to support operations for both wells if possible. FMC / DHD or Kuparuk Valve Crew and AES Support: 1. Verify tree cap connection and coordinate for appropriate crossovers (i.e. 3-1/8” Otis or 4-1/8” Otis connection). 2. Test and service wellhead valves as needed. 3. AES or Drilling Toolhouse support to set scaffolding, wrap and heat wellheat, work platform, hardline, etc. Notify AOGCC a minimum of 72 hours prior to beginning abandonment operations. Representative may witness tagging, pressure testing, surface plug, and marker installation. Verify with Wells Engineer that the 10-403 sundry for the P&A has been approved. 1M-17 P&A Page 7 of 20 4. Well Abandonment: Slickline / LRS: 1. Rig up and pressure test equipment. 2. Pull BPV (if any deployed). 3. Complete CMIT-TxIA (no packer) to 2000 psi. Record initial, 15 minute & 30 minute T/I/O pressures. 4. RIH with ball check bailer to tag TD at ~8780’. Note condition of tools and any solids recovered in bailer. Wellbore fluid has been sitting stagnant for nearly 40 years. It is likely a drift run will tag high off bottom as fluids have settled. 5. MU dual temperature gauges. 6. RIH with gauge for temperature gradient to TD. Perform 15 minute station stops at: a. Tag depth. b. 1900’ MD. c. 1800’ MD. d. 1757’ MD. e. 1700’ MD. Temperature profile will be used to help confirm base of permafrost for cement slurry. 7. Perform MIT-OA to 1000 psi, recording initial, 15 minute & 30 minute pressures to confirm OA cement integrity. Eline / Digital Slickline: 8. MU CBL/CCL/gamma logging toolstring. 9. RIH with logging toolstring to 3000’ RKB. Log from depth, up to surface. 10. Note any anomalies in log data. OA cement response may be muted, but TOC is expected in OA at ~2300’ RKB. Coiled Tubing / Cement Unit: 11. Coordinate with SLB cement crew to verify product and equipment are ready to start scope. Cement operations should be paired with Lookout 1 & 1M-17 cement demands. Adequate tanks and pump trucks should be staged in advance. Plug 1 will require a minimum of 252 bbls of cement to be pumped + excess. 12. Host Pre-Job safety and identify job hazards. 13. RU CTU, PCE, and Support Equipment. PT Lines. 14. Make up tubing tail locator or like TS to allow for locating bottom of 3-1/2” killstring. 15. RIH with locator to 4,457’ RKB, flagging pipe at tubing tail for depth correction. 16. POOH. Swap to DJN BHA. 17. RIH, performing FCO with seawater down to TD (expecting hard tag at ~8780’). Pump gel sweeps as needed, taking returns up the coil x tubing annulus to tanks. 18. PUH 10’ above hard tag to flag pipe. This will be the starting pump depth for the lower plug. 19. After reaching TD, POOH laying down seawater up to 2500’. 20. Lay down 1:1 diesel returns from 2500’ to surface (22 bbls) for freeze protection. 21. Lay down DJN BHA and make up BHA for pumping cement (Wells & Coil Supervisor to select nozzle). 1M-17 P&A Page 8 of 20 22. RIH to ~10-30’ above FCO hard tag. 23. Pump 10 bbl freshwater spacer at depth, taking returns up the coil x tubing annulus. Keep the IA shut in. 24. Lay 165 bbls of 15.8# Class G cement from bottom, pumping at rate recommended by SLB cement engineer. Continue laying cement while POOH, up to tubing tail. a. Take returns up the coil x tubing annulus, with the IA remaining shut in. b. Volume may be adjusted to compensate for FCO hard tag depth. 165 bbls of cement covers 7” production casing from 8780’ RKB up to tubing tail at 4457’ RKB. 25. Shut in coil x tubing returns. 26. Open IA, and pump away 65 bbls of cement to raise IA cement level up to ~2000’ RKB. 27. Shut in IA. 28. Open coil x tubing annulus. 29. Pump 20 bbls of cement while POOH to 2000’ RKB – laying 1:1 returns. 30. At 2000’ RKB, pump freshwater pill while picking up hole to 1950’ RKB. Circulate 20 bbls freshwater down coil, taking returns up coil x tubing annulus to contaminate and clear tubing for drift & perforation runs. 31. Pump 18 bbls diesel freeze protection while POOH to surface. a. TOC in tubing and IA should be left at ~2000’ RKB. b. Monitor and document returns to fluid tanks. Returns and contaminant should be coordinated for disposal with Kuparuk Environmental in advance. Forward appropriate fluid manifests. 32. Flush string and equipment as needed. 33. Rig down CTU. Slickline / LRS: 34. Coordinate with AOGCC to witness pressure testing and plug depth tag. Notification to witness operations should be made 72 hours in advance. 35. Allow for minimum of 24 hours for cement to cure. 36. Perform MIT-T and MIT-IA to 2000 psi recording initial, 15 minute, and 30 minute T/I/O pressures. 37. MU minimum of 2.60” x 5’ OAL dummy TS to drift for largest OD gun assembly. 38. RIH to tag TOC at ~2,000’ RKB. Eline / Digital Slickline / LRS: 39. MU 5’ tubing punch system (multiple gun systems sized to punch through 3-1/2” tubing and 7” production casing). 40. RIH with guns to 1800’ RKB. Correlate depths using previous logging run to target middle of tubing joint at ~1800’ RKB. This will allow for ~500’ of rathole in OA above existing cement where gel pack isn’t expected to flow. 41. Fire tubing punch through 3-1/2” tubing & 7” production casing. Note pre-and-post firing T/I/O pressures. 1M-17 P&A Page 9 of 20 42. With IA shut in, attempt pumping 130 bbls heated diesel pill down tubing, taking returns up the OA to confirm injectivity and flush out diesel based gel pack. a. Injectivity may not be achieved even after punching through 7” production casing since gel pack may have settled and become too viscous to pump. 43. If tubing to OA injectivity cannot be achieved: a. Shut in the OA. b. Open the IA to allow for taking returns and pump 150 bbls heated seawater down the tubing, followed by 63 bbls heated diesel. U-tube TxIA to allow for freeze protection swap. c. Re-attempt OA injectivity, by attempting to pump 130 bbls heated diesel pill down tubing, taking returns up the OA. d. If TxOA circulation can be achieved, proceed with cementing. e. If TxOA circulation can not be achieved, notify Wells Engineer at 907-444-7569. Tubing punch depth will be raised in increments of 200-500’ until TxOA circulation can be achieved. Cement Crew: 44. With the IA shut in, pump following down the tubing, taking returns up the OA to surface. Note – if multiple punches are required, cement volumes will need to be adjusted. Excess cement may be pumped in each stage per SLB cement engineer to verify adequate cement is brought to surface. a. 20 bbls warm diesel to preheat flow path and confirm circulation. b. 10 bbls fresh water spacer. c. 115 bbls (tubing and OA volume to 2000’) 15.8# AS1 cement. d. Shut in OA. e. Open IA and pump 53 bbls (2000’ IA capacity) of 15.8# AS1 cement down the tubing, taking returns up the IA. f. After confirming TxIAxOA cement remains full to surface, shut in and wait 30 minutes. Confirm cement remains to surface in all strings. Pump excess cement as needed. 45. Track fluid returns to tanks. 46. Shut in once IA lead cement returns displaced to surface. Cement engineer may recommend flowing back ~5 bbls of lead cement before shutting in. Volumes can be adjusted appropriately. 47. Wait 30 minutes and confirm cement remains full to surface. 48. Flush equipment as needed. Manifest contaminant & fluids. Wells Supervisor to coordinate disposal. 49. RDMO. 5. Surface Remedial Work & Final Testing AES Support / DHD: 50. Coordinate with AOGCC to witness pressure testing of surface plugs and pre-welding of cover plate. Notification to witness operations should be made 72 hours in advance. 51. Draw down all surface pressures to 0 psi prior to removing wellhead. 1M-17 P&A Page 10 of 20 52. Remove surface equipment. Excavate as needed to allow for cutting strings 4 feet below tundra ground level. 53. Cut off wellhead and casing strings at 4 feet below tundra ground level. 54. Top cement in tubing and annuli to surface as needed. 55. Photo document excavation, final casing cuts, measurement below grade, and cement top. 56. Coordinate for AOGCC representative to witness well condition prior to welding cover plate. 57. Weld ¼” cover plate over 16” conductor with labeling welded below. Photo document plate & final set. ExxonMobil Alaska Production Inc. Well 28243-1 PTD # 181-035 API # 50-029-20573-00-00 58. Remove cellar. Backfill with gravel from cellar & conductor as needed. If additional gravel is needed, contact Roads & Pads. Make final spot checks with Wells Supervisor. 59. Photo document site as left. 60. RDMO. AOGCC inspection requiredafter well head cutoff andbefore remedial cementing 1M-17 P&A Page 11 of 20 Well Status (Post-Abandonment): x Plug 1: 15.8# Class G cement pumped from approximately 8780’ to 2,000’ RKB in tubing and tubing x production casing annulus. Pressure tested to 2000 psi. Tagged with slickline prior to pumping surface plug. x Plug 2 (Tubing x Inner Annulus x Outer Annulus surface plug): o 15.8# AS1 cement from approximately 2,000’ RKB to surface. x Original 7” x 10-3/4” annulus plug: o Arctic Set VI cement from ~2300’ to surface casing shoe at 2930’ RKB. x All strings cut 4 feet below original grade & backfilled with gravel. x Labeled cover plate welded across all strings. x Cellar removed. Area backfilled with gravel. See Appendix for well suspension diagram. 1M-17 P&A Page 12 of 20 Directional Survey 1M-17 P&A Page 13 of 20 1M-17 P&A Page 14 of 20 1M-17 P&A Page 15 of 20 6. Appendix a. Current Schematic: 1M-17 P&A Page 16 of 20 b. Planned P&A Diagram: 1M-17 P&A Page 17 of 20 c. GKA Road Map 1M-17 P&A Page 18 of 20 d. 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([[RQ0RELO3URGXFWLRQ&RPSDQ\ /HQJWK 6L]H 3HUIRUDWLRQ'HSWK79'IW 7XELQJ6L]H 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/ &200,66,2186(21/< $XWKRUL]HG1DPH 7XELQJ*UDGH 7XELQJ0'IW 1$ $SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO)RUP5HYLVHG By Samantha Carlisle at 2:37 pm, Nov 05, 2020 320-471 6,949 SFD 11/6/2020 SFD 11/6/2020 No form required. 8,850 SFD 11/6/2020 gls 11/24/20 -00-00 * Suspended status valid until December 31, 2021 VTL 11/30/20 May DSR-11/24/2020 See AOGCC approval letter for abandonment during the 2021 ice road season.(attached) 5HQHZ6XVSHQVLRQ Docket Number: OTH-20-057 ConocoPhillips Alaska, Inc. (CPAI) Well Plug and Abandonments for 2021 and 2022 Ice Road Seasons &RPP 11/30/2020 dts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ertificate Of Completion Envelope Id: A11ACDB8380341C5B46D5EC5E539E77E Status: Completed Subject: Please DocuSign: Suspension Renewal Application Package.pdf Source Envelope: Document Pages: 7 Signatures: 2 Envelope Originator: Certificate Pages: 2 Initials: 0 Claire Mayfield AutoNav: Enabled EnvelopeId Stamping: Enabled Time Zone: (UTC-06:00) Central Time (US & Canada) Address Redacted claire.c.mayfield@exxonmobil.com IP Address: 158.26.2.167 Record Tracking Status: Original 11/5/2020 1:23:05 PM Holder: Claire Mayfield claire.c.mayfield@exxonmobil.com Location: DocuSign Security Appliance Status: Connected Pool: Main SecApp 1 Signer Events Signature Timestamp Todd Griffith todd.griffith@exxonmobil.com Staffing & Development Manager - Operations ExxonMobil General Security Level: Email, Account Authentication (None) Signature Adoption: Pre-selected Style Using IP Address: 158.26.65.169 Sent: 11/5/2020 1:26:06 PM Viewed: 11/5/2020 3:30:05 PM Signed: 11/5/2020 3:31:07 PM Electronic Record and Signature Disclosure: Accepted: 10/29/2020 9:14:03 PM ID: dbcb219a-b590-4bc2-bd04-2f402958c3a6 Company Name: Exxon Mobil Corporation In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 11/5/2020 1:26:06 PM Certified Delivered Security Checked 11/5/2020 3:30:05 PM Signing Complete Security Checked 11/5/2020 3:31:07 PM Completed Security Checked 11/5/2020 3:31:07 PM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE Exxon Mobil Corporation (ExxonMobil) [1] uses the DocuSign service to collect signatures, endorsements, and approvals for corporate purposes. DocuSign may be used by ExxonMobil to conduct corporate business endorsements and approvals or to gather electronic signatures from 3rd parties for business purposes. Please read the information below and if you can access this information electronically to your satisfaction and agree to these terms and conditions, please confirm your agreement by clicking the 'I agree' button. 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[1] ExxonMobil and/or ExxonMobil Affiliates mean (a) Exxon Mobil Corporation or any parent of Exxon Mobil Corporation, (b) any company or partnership in which Exxon Mobil Corporation or any parent of Exxon Mobil Corporation now or hereafter, directly or indirectly (1) owns or (2) controls, more than fifty per cent (50%) of the ownership interest having the right to vote or appoint its directors or functional equivalents ("Affiliated Company") and (c) any joint venture in which Exxon Mobil Corporations, any parent of Exxon Mobil Corporation or an Affiliated Company has day to day operational control. !!" "! ! ! ! Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Mr. Shon Robinson Alaska Wells Manager PO Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-20-057 ConocoPhillips Alaska, Inc. (CPAI) Well Plug and Abandonments for 2021 and 2022 Ice Road Seasons Dear Mr. Robinson, By letter dated November 23, 2020, CPAI proposed well plug and abandonment (P&A) programs for the 2021 and 2022 ice road seasons. The Alaska Oil and Gas Conservation Commission (AOGCC) approves the P&A programs for the wells listed below for the 2021 and 2022 ice road seasons with the P&A work to be completed by May 31, 2021 and May 31, 2022 respectively. May 31, 2021 Lookout 1 (PTD 201-003) KRU 1M-17 (PTD 201-230) Kuparuk 28241-1 (PTD 181-035) May 31, 2022 Scout 1 (PTD 204-006) Cassin 1 (PTD 212-182) Cassin 6 (PTD 212-196) Wells KRU 1M-17 and Kuparuk 28241-1 each require the submission and approval of an Application for Sundry Approvals for suspension renewal in January 2021. Approval of an Application for Sundry Approvals will be required for plugging and abandonment operations for each well. Approval is also granted for the deferral of the Scout 1 suspended well inspection to May 31, 2022. If you have any questions please contact Victoria Loepp at (907)793-1247 or at victoria.loepp@alaska.gov. Sincerely, Jeremy M. Price Chair, Commissioner cc Victoria Loepp, AOGCC JMPi Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Mr. Shon Robinson Alaska Wells Manager PO Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-20-057 ConocoPhillips Alaska, Inc. (CPAI) Well Plug and Abandonments for 2021 and 2022 Ice Road Seasons Dear Mr. Robinson, By letter dated November 23, 2020, CPAI proposed well plug and abandonment (P&A) programs for the 2021 and 2022 ice road seasons. The Alaska Oil and Gas Conservation Commission (AOGCC) approves the P&A programs for the wells listed below for the 2021 and 2022 ice road seasons with the P&A work to be completed by May 31, 2021 and May 31, 2022 respectively. May 31, 2021 Lookout 1 (PTD 201-003) KRU 1M-17 (PTD 201-230) Kuparuk 28241-1 (PTD 181-035) May 31, 2022 Scout 1 (PTD 204-006) Cassin 1 (PTD 212-182) Cassin 6 (PTD 212-196) Wells KRU 1M-17 and Kuparuk 28241-1 each require the submission and approval of an Application for Sundry Approvals for suspension renewal in January 2021. Approval of an Application for Sundry Approvals will be required for plugging and abandonment operations for each well. Approval is also granted for the deferral of the Scout 1 suspended well inspection to May 31, 2022. If you have any questions please contact Victoria Loepp at (907)793-1247 or at victoria.loepp@alaska.gov. Sincerely, Jeremy M. Price Chair, Commissioner cc Victoria Loepp, AOGCC JMPi Dear Commissioner Price, Due to low oil prices, budget constraints, and a need to minimize nonessential remote work considering spiking COVID-19 cases statewide, Conocophillips Alaska, Inc. is revising our winter 2021 ice road scope of work. Our initial plan was to execute the following P&A’s: x Lookout 1 x Scout 1 x Cassin 1 x Cassin 6 As has been discussed with AOGCC staff, we now propose to perform the following P&A’s instead, staying closer to infrastructure, in 2021: x Lookout 1 x 1M-17 x Well 28243-1 (for Exxon) With that change, we expect to perform the following P&A’s in 2022: x Scout 1 x Cassin 1 x Cassin 6 The Scout 1 well is overdue for its 5-year suspended well inspection under 20 AAC 25.110(e) because of last year’s early ice road exit due to measures taken to project against the COVID-19 pandemic. We do not believe that deferral of inspection until 2022 would present a safety or environmental risk. For the reasons described above, we seek modification of the inspection deadline for this well to May 31, 2022, as allowed under 20 AAC 25.110(n). Thank you for your consideration, Sincerely, Shon Robinson Manager, AK Wells Shon Robinson Alaska Wells Manager 700 G Street, ATO (99501) P. O. Box 100360 Anchorage, AK 99510-0360 Phone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y Samantha Carlisle at 4:49 pm, Aug 18, 2020 DSR-8/18/2020 -00-00 SFD 8/19/2020 SFD 8/19/2020 BB:HOO,QVSHFWLRQ BBBBB RBDMS HEW 8/19/2020 gls 8/28/20 ExxonMobil Upstream Oil & Gas Company Steve Williams Post Office Box 196601 Point Thomson Asset Manager Anchorage, Alaska 99519 907 334-2908 Telephone 907 202-2728 Cell A Division of Exxon Mobil Corporation August 18, 2020 Doc #ER-2020-OUT-180 Commissioner Jeremy Price, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 RE: Kuparuk 28243-1 Suspended Well Inspection Report Permit to Drill # 181-035 Dear Commissioner Price: Exxon Mobil Alaska Production Inc. hereby submits the report for the Kuparuk 28243-1 well inspection conducted on July 23rd, 2020 pursuant to 20 AAC 25.110(1). The attached report includes a description of the condition of the wellhead and surface location, well pressure readings, and photos of the well at the time of inspection. It also includes copies of the wellbore diagram and well location plats previously submitted to the AOGCC, since when no changes have been made. The inspection found no indications of well integrity concerns. The well was drilled and cased but has never been perforated. Tubing and casing pressure readings demonstrated good well integrity, and there were no hydrocarbon sheens or stains in the well cellar or elsewhere in the vicinity. Previous site visits similarly did not identify any signs of well integrity concerns, and there have been no changes to mechanical configuration of the well since the last report to the AOGCC. Please contact Claire Mayfield at (907) 564-3651 or via email at claire.c.mayfield@exxonmobil.com if you have any questions. Sincerely, SW:cm:lo For and On Behalf of ExxonMobil Alaska Production Inc. never been perforated. NOTE: Water in cellar needs to be re-mediated before a suspension renewal is issued. gls 8/28/20 Page 1/9 Suspended Well Inspection Report ExxonMobil Production Company July 23rd, 2020 Well Name: Kuparuk 28243-1 API Well Number: 50-029-20573-00-00 Permit to Drill Number: 181-035 Field: Kuparuk River Unit Surface Location: Township: 11N Range: 11E Section: 17 Meridian: Umiat Latitude/Longitude: Latitude: 70.3016489 Longitude: 149.4175191 Spud Date: 05/05/1981 Completion Date: 05/29/1981 Status Date: 05/29/1981 Status: Suspended Last Inspection: 03/22/2015 Work Procedure 1. AOGCC Inspector met ExxonMobil representatives at well site to witness and conduct the inspection. 2. The wellhead and water in well cellar were visually inspected for signs of hydrocarbon. No sheen on water nor other signs of hydrocarbons were found and no audible signs of loss of wellhead integrity. 3. ExxonMobil representatives photographed wellhead and cellar as found. 4. ExxonMobil operator attached a pressure gauge to the existing needle valve on the outside of the bottom hole adaptor. Operator opened the swab valve, upper master and lower master valves, and recorded a tubing pressure of 100 psi. Operator closed valves, bled off remaining pressure and removed gauge. 5. ExxonMobil operator attached pressure gauge to existing needle valve on the outside of bull plug on the inner casing annulus valve, opened the annulus valve, and recorded inner annulus casing pressure of 140 psi. Operator closed valves, bled off remaining pressure and removed gauge. 6. Wellhead sign and well pad were noted as in good visible condition. Condition of Surface Location The well is located on the Kuparuk 1M pad, which was in good condition as of inspection on July 23 rd, 2020 at 9:00am. Road to pad not accessible by typical passenger vehicle, so ExxonMobil traveled to pad via helicopter. See further surface location details below: The wellhead and water in well cellar were visually inspected for signs of hydrocarbon. water in cellar.. lots. Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 2/9 Condition of Surface Location (cont.) General location condition: Good Pad surface: Good, gravel Location cleanup needed: None Pits condition: Reserve pit in good condition, no sheen or debris observed Surrounding area condition: Good Water/fluids on pad: None Discoloration, sheens on pad, pits or water: None Samples taken None Access road condition: Not accessible by typical passenger vehicle in summer. A portion of the road that provides access to the pad is currently washed out. Photographs taken: Yes Condition of Wellhead The wellhead was in good mechanical condition as of inspection on July 23 rd, 2020 at 9:00am. No sheen on water in the well cellar nor other nearby signs of hydrocarbons were found. All valves were in closed position upon arrival. Valves operated adequately to obtain tubing and inner annulus casing pressure readings as shown in the table below, demonstrating good existing well integrity. No previous pressure data is available from 2015 or 2010 well inspections. Wellhead sign was also visible and in good condition. See further wellhead details below: Wellhead/tree/valve description, condition: No visible or audible leaks, good condition Cellar description, condition: Rectangular metal cellar box, filled with water – no sheen Rat Hole: None visible Wellhouse or protective barriers: Steel barricade in good condition Well identification sign: Good Tubing Pressure: 100 psi Annulus Pressure: 140 psi (inner annulus) Wellhead photos taken: Yes Work Required Recommendation from AOGCC that water level in well cellar be lowered below lowest wellhead valve to prevent freezing water from contacting and potentially compromising integrity of valve(s). Photographs taken: Yes NOTE:Recommendation from AOGCC that water level in well cellar be lowered below lowest wellhead valve to prevent freezing water from contacting and potentially compromising integrity of valve(s). Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 3/9 Wellhead Photos Front View: cellar full of water. Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 4/9 Side View with Needle valves indicated: Needle Valve Needle Valve Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 5/9 Back View: Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 6/9 Well Cellar: Pad (facing away from well): Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 7/9 Wellbore Diagram Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 8/9 Well Plats Suspended Well Inspection: Kuparuk 28243-1 ExxonMobil Production Company July 23rd, 2020 Page 9/9 Suspended WellInspection Review Report |nspectNo: suu46E200726180513 Date Inspected: 7/23/2020 ' Inspector: Adam Earl ' Type ofinspection: Subsequent ' WeUName: KUPARUKZ8243l Date A0G[ZNotified: 7/9/2020 ' Permit Number: 1810350 - | Operator: ExxonK4obi|Alaska Production Inc. ~ Suspension Approval: Completion Report - Operator Rep: Claire Mayfield � �—| Suspension Date: 5/29/1981 | Wellbore Diagram Avail? Location Verified? W Photos Taken? |fVerified, How? GPS ! Offshore? El Well Pressures (psi): Tubing,: lUO ' Fluid in Cellar? � |A: � 40 ' 8PV|nstaUed? [� — ^ l OA: VRP|ug(s)Installed? [] Wellhead Condition good. valves were easy tuoperate. ^ Condition ufCellar / full of clean water. No sheen or signs of leakage � Surrounding Surface Condition Area was inclean condition � Comments 0Awas under water incellar preventing apsi reading. Well sign was ingood condition with PTD and API ~ Supervisor Comments Photos (6) attached. Well cellar needs to be vac'd to remove water; OA gauge needs to be accessible (above the well cellar). V q / Thursday, August fiZO2U \ § % E »� , » « »' r }� ' [ mum_jq r..: oLL.v I C) ■ « « C 00 LO o U) . \ A � W :EOC C14 cp w c %0O Les � o Lo r- 00 \ A c � c \ o � LU km U F- 9 . \ § % E A or r t ; 1 1 .. r t r r -{ � SFl• 9M i + ! t f !J { a6 "c a ire �^ry ' ti� r, t •,. � raJ •;��• ' D �� 4 1 .`yl r i,�.s `• .t� , a i � t � ,� v • a 2 v { , J t + <+ !• s I". V 'Y 1l 1 r Ct � y P� •� - ,.� f r a•1� �. ' .yN �F a '.a �r D i >5 1 L.. 't • �. x h 1 1 ✓< : 1 d t .y A- Y RECEIVED • STATE OF ALASKA APR 24 201' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon Repair Well _ Plug Perforations _ Perforate _ Other Well Inspection Performed: Alter Casing _ Pull Tubing Stimulate-Frac _ Waiver Time Extension Change Approved Program Operat.Shutdown Stimulate-Other Re-enter Suspended Well 2 Operator ExxonMobil Alaska Production Inc. Well Class Before Work: 5.Permit to Drill Number: fU . Name: Development El Exploratory 181-035 3.Address: PO Box 196601 Stratigraphic Service _6.API Number: Anchorage,AK 99519-6601 50-029-20573 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 28243 Kuparuk 28243-1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Unit 11.Present Well Condition Summary: Note:there were no changes made to the wellbore configuration Total Depth measured feet Plugs measured feet true vertical feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet I Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate SCANNED Production MAY. 2 y Liner L 015 Perforation depth Measured depth feet True Vertical depth feet Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments: Inspection report&photos 15.Well Class after work. Copies of Logs and Surveys Run Exploratory n Development® RService n Stratigraphic n Daily Report of Well Operations 16.Well Status after work: Oil Gas p WDSPL — GSTOR n WINJ n WAG GINJ SUSP SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Irene T. Garcia Email irene.t.garcia@exxonmobil.com Printed Name Irene T. Garcia Title SSHE Manager Signature ).0 i Phone 907-564-3773 Date ¢/!1/`5 RBDMS4( APR 2 8 2015 v1- - 5& /i5 Form 10 404 Revised 10/2012 rr/ —761------_� ' Submit Original Only ExxonMobil Production Company Irene T.Garcia RECEIVED P. 0. Box 196601 SSH&E Manager Anchorage,Alaska 99519-6601 A P R 2 4 2015 907 561 3773 Telephone 907 564 3719 Facsimile AOGCC EkonMobil Production April 14, 2015 DC# R-2015-OUT-014 Commissioner Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 101 Anchorage, AK 99501 Re: Report of Well Inspection of Kuparuk 28243-1 Well Permit to Drill Number 181-035 Dear Commissioner Foerster: ExxonMobil Alaska Production Inc. hereby submits the attached report for the Kuparuk 28243-1 well inspection conducted on March 22, 2015 pursuant to 20 AAC 25.110(f). In addition to inspecting the well, ExxonMobil completed dismantling of the former fuel tank storage pit and disposed of the debris at the North Slope Borough landfill. The attached report includes a description and photos of the condition of the well and surrounding location. There were no signs or indications of well integrity concerns, e.g., there were no sheens or stains in the well cellar or elsewhere in the vicinity. Previous summer site visits similarly did not identify sheens or other signs of well integrity concerns. The well was drilled and cased but has never been perforated. In 2005, ConocoPhillips previously demonstrated well integrity, and there has not been any well entry or other work that might create new integrity concerns. There have been no changes to mechanical configuration of the well since the last report to the AOGCC and we are re-submitting the wellbore diagram used previously. Also attached is a copy of the location plats. Please contact me at 907-564-3667 or via email at irene.t.garcia@exxonmobil.com if you have any questions. Sincerely, Irene Garcia SSHE Manager Attachments Well Inspection Report Wellbore Schematic Location Plat A Division of Exxon Mobil Corporation EXXON MOBIL ALASKA PRODUCTION INC . 22 MARCH 2015 WELL INSPECTION REPORT KUPARUK 28243-1 API Well Number: 50-029-20573-00-00 Permit to Drill Number: 181-0350 Field: Kuparuk River Unit Township: 17N Range: 11E Section: 17 Meridian: Umiat Latitude:70.3016489 Longitude: 149.4175191 Spud:05/05/1981 Completion Date:05/29/1981 Status Date:05/29/1981 Status:Suspended Last Inspection:09/27/2010 WORK PROCEDURE 1. Upon arrival at the location the snow around the wellhead was inspected for signs of hydrocarbon. No hydrocarbon was found. 2. Snow was removed down to the level of the ice in the cellar. 3. A visual inspection of the wellhead was conducted with ExxonMobil representative and there were no visible or audible signs of loss of wellhead integrity. 4. There was a substance notified on the exterior of casing valve stem cover and the upper master valve balanced stem cover.After conference with FMC the substance was determined to be grease from inside the balanced stem.This does not pose an issue to wellhead integrity. 5. Grease was wiped from surfaces and disposed of properly. 6. Wellhead sign was mounted on wellhead cage WELLHEAD STATUS The wellhead was in good mechanical condition as of inspection on 22 March 2015 @ 1420.Valve position was not verified. Needle valves are installed on the bottom hole adaptor(B-11-AO)and outside of the inner casing annulus valve on a 3" line pipe x%2" line pipe bull plug. WELLHEAD PHOTOS Following are photos showing the condition of the wellhead,valves,and well cellar. 1 ' Page AS FOUND z 6, 0, I ... ._ . .._ ,,., , . . •A ete k 11111111F . ... —046 1 Y \ 1 •.•: ' 1Y'eAg Oa r a 21 AS LEFT at { PAtik 41111%** Kuparuk 28243-1 EXXONMOBIL 4 N2+.. 50 029 20573 00 00 location. 479'FSL 605 FWL +" T11N,RYE,SEC 17,UA wtnw 181-035 31 Page WELLHEADS AND VALVES If 0 —moil 111111111111111111. 410101' 1 b. ,......." , --- r a w� ' , kir: MB 4411111 '44 V. ` 4IPage WELLHEADS AND VALVES k '101 .. _40.. ..„ ....,..„.„.. ,,,,.. .. .t -4,.„,,,, P. Tif 110 � r is r tt 0 kik i A ii 1' SI Page MINOR GREASE ON VALVE STEM COVER t c , . t its itis. ( - : . .,. bias, .0 , . . ... .... „, ... . 4. i , 61 Page NEEDLE VALVES it-. e .,, d r T.x 104011111,41 ..: \ ' * xx♦ A 71 Page NEEDLE VALVES It 11 r ., .. , .. ,,,, 1 . .,... .,„,,,.. .... ... ..:. . , ... ,,..„ ,,,, kh, ,,,, .. .11.— ,...„.„6,..„ , ..,, . .. . . . ...... .,. „„ ... .. . , .. „, ,..........,,,,,, , ‘. ,,;:,,„ „...„,.......,,,,,.,,,,.. . . ,.., .. ..,. . ..„ „. . .. . , . ... ,.,..,, ... ....,..,.. „....,,,,.. , ., :„ ,,. ...„..: ., ,.. ....,,, , ..1 .., ,,..,,,,it v*, lidirillill'111LIIII4— ...... .,, .,,, -. ..,....,......„ ......,............„....„......,:.,........ ... ............_... ,.. . .41*".'' 81 Page , . . ... r'w .... • - ,. . , . # ge ' ?' .L. " ". t 4 N, S 6,0 44-.4 .t... , - rill.11111 II . . ; . . -ir . !e, 1 .3(111 wr Il J , 10 IX 411" to: if til ilk ilb • Awy %Or III Iiir Avo. 4 -, • .4!t14‘.113v7, ' • •Pt I. -. ' , At 4 i•, , ' ' _..e..."IIP ,,,r, 1 ir ' e - a ik •t:,,, i IN 9IPage b 6 � • I k v Q J I �� CL uJ Y iR w ,„ • Q � Z CC CL IuJ ce O • J i • W U- ,01 IN i 4 FROM: N r.• 7•9:f.'kr'?P.. „ +goz,:P-tea..Yd.+.•r r.ot • • .;rig.•• Y-•`' �s; I `1. EXISTING STATUS `i.�. 17 }T 3Y _.• aZ: art x�0 mai r {?" Y, T:h, rrrSf "r wr. rv,r• rti;Ws r tory n. . DIESEL i~ • 4* T �� V %, (DRNEN TO REFUSAL) t.YC•/ it Tt4�' ' r,;{{/ s;,o :c•2 CEMENT tt Tsir} rt /••',a u• I ",ti • rr r rr r { r. tt 1.1 P.*. 4f`1T Tt %Y />t r a ARCTIC PACK f>.: i DPci 0*:‘ \A Q \ TIZN ~ • O�Ute'' 1 sial« TIIN O Tree / 14 "1".. s °•' D 07iill r 1P 0 09 •.. y 18 1 �� to NtIN T II i {t O 1.041 iO d►sa `i "61 a>r r� 1ML3 “le SIN Q ill O �� !' NSL,136'2 wEL -se.7, TIIN.AIIE VICINITY MAP • SCALE I 250000 USGS man EEEMEYIt TPO , ALASKA / . . aqf Site sa 28ta3-MP ►-� .—y 1-� t d 14 MILES ltma • sa9ez3'oLa9'w ric 17 IS so ID 202I r: n2aIII • • :i '-'\ 1 • ILP j LJ TIIN, R I2 E FEB $ 1�b PLAN VIEW Div. of Minerals t Energy Mgt. Anchorage, Ale. I/2 1/4 0 1/4 IA 1 Motes: MILES Average fen** N OSSO i0' Sew rein ems obese M.S.L. Culverts *111 be installed et 24 me stream crossing. . • • Mafia rt nns• urqv, Y P I C A_ UM =1 10 N arsine Rawl AlliwmMt 12M1110 LIS. • PROPOSED ACCESS ROAD TO KUPIUNJK tbH3-MP , INS Sees.TOT•IS, T1111.11111..MIL,AK, ►erse•et • NEAR: BEECH! POINT, ALASKA Proem semis fres •fisting read te • stewed dNN site. APPLICATION SY: NOSK. OIL CORPORATION SHEET I OF I DATE SEPT,10,1980 T 26 '98 17:199072634966 PAGE.08 IIEv' DATE BY CX APP I REY DALE BY _ i"fir DESCRIPTION 4 7-- - I - LEGEND T12N T11N '( O FUTURE CONDUCTORS \.,�� • EXISTING CONDUCTORS U ° West s • AS STAKED CONDUCTORS —THIS SURVEY Soli 24Afi N W.S.• 1111. � A., `s-1c — ill 11 A 12 7 + r_,..., i 1 `'� N �STMR Y • 7, v..:" SCALE: e. % ' 1" s MI' 14 18 17 �i,■ 013 , F �` 05-H3 1 DS 1M 23 24 19 Im VICINITY MAP SCALE: 1" - 1 MILES Pcs rod-r;o Ay WELL 1M-17 tkCC.S:NS-likQ • LOCATED WITHIN PROTRACTED SEC. 17. TWP. 11 N., R. 11 E. UMIAT MERIDIAN Y = 5,960,383.6 017 X = 571,907.4 DOl- 1-0 LAT = 70 $;0/.40" 71° LONG = 149'25'03.24" n618' F.S.L.. 600' F.W.L. •MP 1 14s‘-o3S $taANNED OCT 0 4 2010 CIEs: 1. ALL COORDINATES ARE ALASKA STATE PLANE, NAD 27, ZONE 4. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. O 3. ALL DISTANCES ARE TRUE. 4. DATE OF SURVEY: 12/7/01, F.B. 101-64, PGS 64-66. 18117 1 0. LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS lit AREA: 1M MODULE:XXXX UNIT: 01 MIM " PHILLIPS Alaska, Inc. DS 1M (q.,,k.. A Subsidiary of PHILLIPS PETROLEUM COMPANY WELL CONDUCTOR 17 AS—STAKED LOCATION cAo1Ksi 13D2 12/6/01 DRAWING NO: NSK 6.113 - d2 ' SHEET: REV:or 1 I REV:0 ExxonMobil Production Com. ID • Joint Interest U.S. RECEIVED P. O. Box 196601 Anchorage, Alaska 99519 -6601 FEB 0 1 2013 f 907 561 5331 Telephone 907 564 3789 Facsimile AOGCC EkonMobil Production January 30, 2013 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 SCANNED APR 111013 Re: Kuparuk 28243 -1 PTD 181 -035 Dear Commissioner Foerster: On January 6, 2011, the Commission approved ExxonMobil's December 16, 2010, request to renew the suspended status of the subject well. An inspection of this well was performed on September 27, 2010, and the inspection team included an AOGCC representative. The results were reported to the Commission via ExxonMobil's October 27, 2010, which included submission of an AOGCC Form 10 -404, site photos, and the AOGCC inspector's Suspended Well Site Inspection Form. The Site Inspection Form noted that some work was necessary. During the summer of 2012, ExxonMobil conducted an onsite inspection of the location and confirmed that the noted site work is still an outstanding matter. Accordingly, we wish to advise that ExxonMobil plans to conduct site work during the summer of 2013. The work is expected to include repair /improvement to the wellhead barrier, cutting piling off at ground level, and removing timbers and other debris. We are still looking into the lined pit on the corner of the pad and will advise what action should be taken on that. We will keep you apprised of our plans so that the Commission may conduct a follow -up inspection after the work is complete. We would also note the Site Inspection Form references the existing reserve pit but does not indicate any concerns with it. For your information and records, this pit was closed by ADEC on March 17, 1999. A copy of their approval letter is attached for your files. Additionally, during the 2012 summer visit, shovel sheen testing was performed on open water thermokarst troughs and ponds located around the toe of the main gravel pad, as well as at regular intervals around the pit, with no hydrocarbon sheening noted. Thank you for bringing this matter to our attention, and please feel free to call me at 907 - 564 -3773 or via email at william .j.hanenberg @exxonmobil.com. Sincerely, . 4 4 )tp. William J. Hanenberg SSH &E Manager WJH:blc Attachment A Division of Exxon Mobil Corporation • • ` I = 1 1 TONY KNOWLES, GOVERNOR - -- _ L' ^- • DEPT. OF ENVIRONMENTAL CONSERVATION ' ifrAY DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVE Telephone: (907) 465 -5162 JUNEAU, ALASKA 99687 Fax: (907) 465 -5362 http: / /www.state.ak.us /dec/deh March 17, 1999 Mr. Al Robb III, P.G. Mobil Business Resources Corporation P.O. Box 650232 Dallas, TX 75265 -0232 Reference: Issuance of Approval for Final Closure for fourteen Inactive Reserve Pits located in South Central and North Slope Alaska Dear Mr. Robb: The Alaska Department of Environmental Conservation (ADEC) has completed review, field inspections, and public notice for fourteen of Mobil Business Resources Corporation's inactive reserve pit and closure applications and requests for final closure approval . The closure applications provided the required information describing the history of the site, the present condition of the site, results of any required water sampling and an assessment of the potential risks posed by the drilling waste to human health and the environment. ADEC coordinated review of the closure requests with the Alaska Department of Natural Resources, the Mental Health Trust, Tyonek Native Corporation and private land owners. Public notice requesting comments on the closure requests was published January 19 and 20, 1999 in both the Anchorage Daily News and the Peninsula Clarion. No objections to final closure approval were received in response to the public notice. ADEC has determined that the reserve pits at this site meet all the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440, ADEC grants final closure approval to Mobil Business Resources Corporation for the inactive reserve pits at the following fourteen drill sites: r . • • ( '.. r Mr. Al Robb III /` March 17, 1999 � Page 2 of 3 Well Name API Number Landowner 1. Echooka Unit* 1 50- 223 - 20008 -00 DNR 2. Staines River St # 1 50- 089 - 20008 -00 DNR 3. Prudhoe Bay Unit Nom -1 50 -029- 20426 -00 DNR 4. Hemi St 03 -09 -11 50 -029- 20018 -00 DNR 5. Kuparuk 28243 -1 50- 029 - 20573 -00 DNR 6. Mikkelsen Bay St -09 -19 50 -029- 20055 -00 DNR 7. West Kadleroshilik Unit # 1 50- 223 - 20009 -00 DNR 8. Gwydyr Bay State Unit # 1 50 -029- 20396 -00 DNR 9. Chuit St #1 50- 283 - 10005 -00 Tyonek Native Corporation 10. Chuit St #2 50- 283 - 10004 -00 Mental Health Trust 11. Moquawkie # 1 50- 283 - 10019 -00 Tyonek Native Corporation 12. W. Moquawkie # 1 50- 283 - 20035 -00 Tyonek Native Corporation 13. Moquawkie # 2 50 -283- 20015 -00 Tyonek Native Corporation 14. Niniichik Unit # 1 50- 133- 10003 -00 Private Land — A. L. Pearl Terms and Conditions This final closure approval is subject to the following terms and conditions: 1) In accordance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner /operator and the appropriate land owner /manager. Any person who disagrees with any portion of this decision may request an adjudicatory hearing in accordance with 18 AAC 15.200 -310. The request should be mailed to the Commissioner of the Department of Environmental Conservation, 410 Willoughby Avenue, Suite 105, Juneau, Alaska 99801 -1795. If a hearing is not requested within thirty (30) days of the date of this letter, the right • • Mr. Al Robb III " March 17, 1999 J Page 3 of 3 , of appeal is waived. Please remember that even if an adjudicatory hearing has been requested and granted, this decision remains in full effect during the process. Sincerely, Heather Stockard Solid Waste Program Manager hstockare,,envircon.state. ak.us cc: Gary Schultz, ADNR, Fairbanks Wendy Mahan, AOGCC, Anchorage Don Karabelnikoff, Tyonek Native Corporation A. L. Pearl, 13710 Algonquin Dr., Reno, NV 89511 -7220 H:\ HOME iRJPETERS\RSVPITIMOBIL\FINAL CLOSURES #2.DOC • ( SEAN PARNELL, GOVERNOR (tz( 1.1U L[E. 11/ [F n E ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dale Pittman Alaska Production Manager ExxonMobil Alaska Production, Inc. 0-55 P.O. Box 196601 1 � Anchorage, AK 99519 -6601 Re: Kuparuk River Field, Kuparuk River Oil Pool, KUPARUK 28243 -1 Sundry Number: 310 -448 Dear Mr. Pittman: 5 NED JAN 2U1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Y Daniel T. Seamount, Jr. -f< Chair DATED this LP day of January, 2011. Encl. ExxonMobil Production Company • Joint Interest U.S. - Alaska P.O. Box 196601 Anchorage, Alaska 99519 -6601 907 561 5331 Telephone 907 564 3789 Facsimile EonMobil Production December 16, 2010 RECEIVED DECII 2010 Commissioner Cathy Foerster 3 tas Cores, Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100,sr, 110,41e Anchorage, Alaska 99501 Re: Suspension Status Renewal Sundry 10 -403 for Kuparuk 28243 -1 Well PTD No. 181 -035 Dear Commissioner Foerster: ExxonMobil on behalf of ExxonMobil Alaska Production Inc., hereby submits the attached Sundry application to renew suspension status of the Kuparuk 28243 -1 (also referred to as MP- , 1) well under 20AAC25.507(b). 1. An inspection of this well was performed on September 27, 2010 and results were reported to AOGCC in a letter dated October 27, 2010. No anomalies regarding well integrity or site issues were found. 2. Well was originally suspended in 1981 and has not been perforated. 3. Available data and information indicate potential utility for the well for appraisal or development activity for identified sands in this area. It is also adjacent to Kuparuk River Unit 1 M -17 which is being held for future development of drill site 1M. ° Please find enclosed with the Sundry application the following information: • Photographic documentation of the well • Wellbore schematic • Well plats (one for Kuparuk 28243 -1 well, also referred to as Kuparuk 28243 -MP, dated 12/15/1980 and one for Kuparuk 1 M -17 well per AOGCC PTD #181 -035 well file that also shows Kuparuk 28243 -1, here known as MP1) If you have any questions or require additional information, please contact Gilbert Wong at (907) 564 -3607. Sincerely, I DDP /GSW:dgo Attachments A Division of Exxon Mobil Corporation • dx,\\ .'` RECEIVED DE STATE OF ALASKA `mo 2 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska OH & Gas Cons, Commission APPLICATION FOR SUNDRY APPROVALS Anchoroga 20 AAC 25.280 1. Type of Request: Abandon f ( << Plug for Redrill ❑ Perforate New Pool 1=1 Repair Well 1=1 Change Approved Program ❑ Suspend __I . Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ 7- 'tit Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Otherlemg& Sa5/,€IS; en IRK 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exxon Mobil Alaska Production Inc. Development El . Exploratory ❑ 181 -035 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196601, Anchorage, AK 99519 -6601 50- 029 -20573 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ KUPARUK 28243 -1 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 28243 Kuparuk River Unit 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,850 6,949' , 8,780' 6,894' NONE NONE Casing Length Size MD TVD Burst Collapse Structural - - - - - - Conductor - 16" 80' - - - Surface 2904 10 -3/4" 2,930' - 4030 2700 Intermediate - - - - Production 8757 7" 8,780 6,894 4980 4320 Liner - - - - - - Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3-1/2" Unknown 4,457' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG El 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gilbert Wong 907 - 564 -3607 Printed Name Dale Pittm Title Alaska Production Manager Signature Phone Date 907 - 564 -3689 COMMISSION USE ONLY (' Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �l V [� ' —`% Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / tat zo AAC zr Jio L Subsequent Form Required: / ,,T 'MIX r /frtE / / APPROVED BY / / 1 Approved by: / COMMISSIONER THE COMMISSION Date: `/ / b ' BDMS ' N 071011 /• y � l ; � lz :5 ,may ORiGINA 07 • • S I ji i ' .. ,, bit • / ' I ' Kuparuk -1 • III - Kuparik 1 M17 ro 1 i i, , ., , . .. ,. ,. ,.. , ....... ,„ ..,, ' z 41 A j ' ., ..d * y ., ww- r ir ` �s 'r "�`�� _' . s'. ,•: Z t' .. c i, {'^,,, . , - ?.z t x w..a .,., _ :: ,r s�. Xc. . � : .. , ,,.3r - • t , Y• ' ^d c a t -- _ :i: t` ., „ -':z :. ' ......s,. - ;..'r`”' .' -1, ,.'i t� `Y ' Z4 R *R ; Z ; � 4^rd". .'44°.i."? '� `'? ys '' ` y e # - : , a .. . a. . . '' , ' : x r '3_ < . ti ,. •-q. , 1 : .' e s I , r m x v _ w F It z + ' • `v ° - 1GRt�€ e +a*^vscts. _ 4. Y "E � °7y'•' �•T. ,t. P ,.:- aa. , 4 i s r o- '''' e" I ) , ‘,34. ' ' '''''''' :::. *.' *:-:: ' -''''- , , r s f ate. II 1-Et iZ8Z lnJednN ik t ,. a - .41, ... ^ ' , . ° ... i wof I ' ,...... 6 - * „. . .. it 6 * , WO * , ' 66 11, i 66” _ * A *** ., . t ... ...2 , . . .. , K uparu k 28243_1 0 .,,_ ••• .‘,...„. Kupartik 23243-1 . • iiir -- cr< Il e ..... ,,,.. tr- w ., , .. it ,... - , .... „, , . .. . - ,, . . . . -- -- - 7 11, . I___ii •-•:-...„ ”. ,-.-.. . . .•';:,.. ---- '? - , , . _ . ,.. - .... . , , . , ...„...... „„.„. .. :. .... .. ,. , igtic-Plow• • - ' - ith....„, ..., . _ ............... .. .„..,......._„ ... . _ :,- '.•, 4 , .7.'7. ----' -. • - - -...r. • ......,....... 111111MININI ..._ , roit. - , • ,.,,+-..,.,..,,,,...... •7"..e.rt,..,,.... .,.._ ' ..!;,.-.-......,_ • ' ,. - ,.-, -- :-, ,•;€-_,•-: -_-_•,•-:, , •,,,. ,..:-•_.::::*,.. ,..,,,,„. .„ „,.. iii■.'; *,,,, ,,, .. ...'-, , . ... - ' . ., : 'it t • , - ... _ - .... - . .... , , ' *16.- .., ,, , 4111 4111 . FROM: . r", nv.. vv, a921vv . .. ____ ., ay..-..co -`v vo•t-rr r.vi '.7:1";;;1 'i:i:i:i:i. >:;; EXISTING STATUS • ; f 1 1.1.1.1.5 1.1.1.1.1 / r•r.f•r•r• 'r•3. r• : i:i1i1i1i: < 'ryi1i1iyi: `t: 1 .11.1111.1 1.1.111.1 A r•r•r•r•r ' r.r.r.r.f. J . 4 11L11111L1 - 1111111.1 •; � :::::::. 'rtirtirtirtirti • �� y. (DR :.1 T.1..41: :: :. 1.1.4.1.1 •1ti:, 'r• r.r•f•r• . • 1. 4.1. 1 \ ;• 'r•t1r1t•r1 • 1.1.1.1.1 ........ • •r�� f.r.r.r.r 'f.i.i.i.i. �6" CSA 8� 1 ?.T1 .T1 ?1r.r1? 'r1i?i? :: 1 'tiy DIESEL : :• :' L'L•L•L•L• L•L'L' NENTOREFUSAL) • 1 1.vg.". 1'1.1.1. (i` {: 1 r.r.r.r.r ' :.�•+� 1.1.1.1. 1.1.1.1.1 • 4. 1. 1 .1. 1 . 1 . 1 .4 ?•/ • r•r•r•r•r ' r•r•r•r•r• CEMENT L.4'''' ............... .1.1.1.1• 1.1.4.1.1 ; 4 't•r1r1r•t• 1 r•.:. NT I / 1.1.1.1.1• L•1.1.1.1� ''l ::: r � :: . .'1i1T1T1r 'T1T1r .'1T. / r." - . • / •• 1 . 1 . 1 . 1 • 1.1.1.1.1 / 1111111141 1.1.1.1.1 , r•r• f•r• r 'r•r•r•r•r• . -fi 1. 1.1.1.1 r r •t•r.t 'r•t•r 12 ARCTIC ' 1 5'1'111.1 / ;::1 � i : � .i r r.r . r. J 'f.r.r. �4 PACK /1 .4.1.1.. 1.1.1.1.1 /.."::'..;.:4 r:d , } �' r.f•r•1r•r 'r•f•r•f•r• 1 ....• 1. rp:41 1 1 - : !.......:: r1r•r•r1r 'i•t•r1r1r. 1.1.1.1• 1.1.1.1.1 ./ f.r•r•r•r r•r•r•r•J• +�� 1.1.1.1• , 1. . ,4./ .. 'S TOP OF ARCTIC PACK CEMENT ./- 2300' •. •': •T .r.r-r.r T .r•f ▪ •r.r• 0 1.....:.....: : •: +� 1 L.L.L. 1.4.1.1.1 �:: 'L {a 9.8 PPG MUD •; ,• r •r•r•r•r •r•r•r•r• . • . 1"• • • •:1 : • 1 .1.1111 . . e.e.e ▪ 111 ... • + . ;: ice. ;- . . r.r.r.r r.t•r.r•r. `;. tir:1 5.1.1.1. 4.1.4.1.1 . :... .i iyr1r1rtity :1•'::. 'Cr : I • .' .V . * : :: : :: : : .' ' 4.1.4.1.1 , +'• r•r•f r.r•r•r•r• ' 1 0.3/4" CSA 2 930' MD • �r.:r 1.1.1.1. X1.1.1.1.1. t& •i 1. J•t•r r•f•J•J•r• . 1 'HM1•y \• 1.1.1.1.1 ± ;�• r.r•r•r•r r•r•r•r1r• CEMENTED TO SURFACE 1.1.1... 1.1.1.1.1 :r;Y. • •r•r•r•r•r r •r•J•r• . . . 111111?•.' Av s. ..% • T•r. 1.1.1.1• 1.1.1.1.1 45.51 K -55 BTC r•r•r T•r•r•r•r• I ,741:1:::::- r.t.t.t.r. + 1.1.1.1. 1.1.1...1 I c r.t•r•J•r• + 4.4.1.4. 1.4.4.1.4 t•t•r.r•r r.r.f•. I r 1.1.1.1. 1.1.1.1.1 •r•t•t•r r•r•r•r•r• 1.4.1.1. 1.1..1.1 ;•-•;J TOP OF r CEMENT EST AT 4110' r •r•r•r•r r•r•r•r•r• 1..1. 1.. .1.1.1. '. �, y'.. y : 1. r,r,f,.•,r i. r.J.r.r. r : K 1 y , ylyly •715 1.1.1.1• 1.1.1.1.1 r.'i:• :. % V.V.: {: % %%.V. Z., :: I� rV. rrrr.f.r 1;:i _ -_ - -- ----- _- , ..,Li 3 -1/2" TUBING AT 4,457' • :!.e ____ ____ ___ • KUPARUK C -SAND, 8276'MD 64 9 5 `TVD j .. - = - - - - - - =- - - .''I WELL IS NOT PERFORATED KUPARUK B -SAND 8590'MD �: :�� -- -- -- ---- - - --`.� 6742' TVD �" ------==- - - - - -- j � --� -- �--- - �-- 261 K-55 BTC • ti J r; f r .; _ ...;:: :•, 7" CSA 8,780' MD 6,894' TVD ARCO Alaska, Inc. 1 c• : z :1: ; ;:: >�� < TD= 6,850' MD, 6,949' TVD KUPARUK 28243 MOBIL- PHILLIPS #1 (MP -1) • SURFACE LOCATION: 479' FSL, 605' FWL SEC 17, T11 N. R11E, UM dOTTOMHOLE LOCATION: 1402' FSL, 4027 FEL, SEC 18, T11N. R11E, UM TWM, 12/13/90 December 13, 2010: Clarifications made on this wellbore diagram to reflect the level of drilling mud from 4,457' to TD and the displacement of drilling mud with diesel from 4,457' to the top. Data obtained from May 28, 1981 daily drilling report in AOGCC file. OCT 26 '98 17 :17 9072634966 PAGE.01 • o 11 �''v, I. ik ,,p „ ki 0 St Il i •• 0 21/ aa ( 1ti 1111 , \ TIZN ` d V' 1 1 'Jo TIIN 0 • - f True �.` •sad 1 V m 7.,,. • � ~ J 8 9 S O 1 21 � C W W 18 • 7 Reed IT 16 f • L 0 (7f1 a,A„K O 1/ R 74 w Y e 04 O � • y -3' N3L, 139'2 WEL °C `` P •c. 7, TIIN, RITE VICINITY MAP g ' ILS6S 010411 BE SCALE EY 3 POINT, ALASKA 4/ • • opened Drill Site s_ s assail 28243 -MP MILES . 70 OZ80' N • •nq.149 ° ZS'0t.49'W - 1817 " 1716 . 19 20 20 n r n h (I r • 1 J �U U `- T I I N, R I2 E FEB 6 190; PLAN VIEW Div. 02 Minerals 6 Energy Mgt. 1/2 I/4 0 1/4 1/Z ! /Anchorage, Ak. Notes: MILES Average terrain •1•votion 60' Scab I "s 1/2 Mile obese M.S.L. Culverts will be installed of 24• ( the strewn crossing. • 1 TUNDRA 3aeS TUMORS 111200 All= as r-N TYPI 021§ SS E ThO NN Revised Rood Alignment 12/15/80 N.T.S. • PROPOSED ACCESS ROAD TO KUPARUK 28243 - MP IN: Seem VI? 810, TIIN, R11E,ILM.,AK. • Puttee*: NEAR: SE Easy POINT, ALASKA Provide access from existing read to 0 Proposed drill sits. APPLICATION 8Y: MO81L ON. CORPORATION SHEET I OF 1 DATE SEPT. 10, 1980 :T 26 '99 17:19 9072634966 P1aGE•08 4 S • -- REV DATE BY CK APP 1 IIP2229N REV DATE BY T'filp DESCRIPTION LEGEND T12N T11N 'C 0 FUTURE CONDUCTORS • EXISTING CONDUCTORS 1 s Hest s p AS- STAKED CONDUCTORS -THIS SURVEY SaN 24A N w . s .. IL r DS -1C ,111V 61111 12 1 _...., r illg, � \ _I •SUR Y SCALE: TNI 1" = 200' j"1 ilk 13 17 9 M ' - P DS 1M k 24 ` ■ 0 m VICINITY MAP SCALE: 1" = 1 MILES 1 1 \e# t; � u i WELL 1M -17 ztcCc S SlbA, e ■ LOCATED WITHIN PROTRACTED SEC. 17, TWP. 11 N., R. 11 E. UMIAT MERIDIAN Y = 5,960,383.6 @17 X = 571,907.4 DOt —a33 LAT = 7Q0,07.40" " j —L° LONG = 149'25'03.24" ■.___/ 618' F.S.L., 600' F.W.L. •MP 1 -4/ iS\ -035 '""-- *ANNIE OCT 0 4 2010 NO 1. ALL TE C OORDINATES ARE ALASKA STATE PLANE, NAD 27, ZONE 4. 2 . ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. 0 3. ALL DISTANCES ARE TRUE. 4. DATE OF SURVEY: 12/7/01, F.B. L01 -64, PG'S 64 -66. 19�2s, LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS l AREA: 114 MODULE: XXXX UNIT: D1 6 6 PHILLIPS Alaska, Inc. DS 1M 66 A Subsidiary of PHILLIPS PETROLEUM COMPANY WELL CONDUCTOR 17 AS- STAKED LOCATION CAOD FILE N0. DRAWING NO SHEET: REV: LK6113D2 12/6/01 NSK 6.113 - d2 , � 1 OF 1 � 0 STATE OF ALASKA - ALASKA ND GAS CONSERVATION COMMISSIO REPORT SUNDRY WELL OPERATIO 1. Operations Abandon Li Repair Well Li Plug Perforations LJ Stimulate LJ Other L - J 1 Inspection per Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ 20 AAC 25.110 Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Mobil Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑., Exploratory ❑ 181 -035 3. Address: PO Box 196601, Anchorage, AK 99519 -6601 Stratigraphic❑ Service ❑ 6. 4PI Number: 50- 029 -20573 00 -pp 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 28243 ^ KUPARUK 28243 -1 9. Field /Pool(s): Kuparuk River Unit k + . �A (Y 10. Present Well Condition Summary: Total Depth measured 8,850 feet Plugs measured N/A feet true vertical 6,949 feet Junk measured N/A feet Effective Depth measured 8,780 feet Packer measured WA feet true vertical 6,894 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A N/A N/A Conductor N/A 16" 80' N/A N/A N/A Surface 2,904' 10 -3/4" 2,930' N/A 4,030 2,700 Intermediate N/A N/A N/A N/A N/A N/A Production 8,757' 7" 8,780' 6,894 4,980 4,320 Liner N/A N/A N/A N/A N/A N/A Perforation depth Measured depth N/A feet No 'C,! f. 4 l� True Vertical depth N/A feet . r we,LL fs C Tubing (size, grade, measured and true vertical depth) 3 -1/2" N/A A 1easQ'& i"as Can U40*1 0 ��tE�:QCaQ� Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A � t�U N f 1 � {� �E Treatment descriptions including volumes used and final pressure: N/A t! i� 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N Exploratory❑ Development ❑ ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations see Inspection Report 15. Well Status after work: Oil EJ Gas LJ WDSPL I GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑� SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Gilbert Wong 907 - 564 -3607 Printed Name Dale Pittman n Title Alaska Production Manager Signature 1� Phone 90 - 56 -3689 Date 10/27/2010 �IIA NOV 0'21t1p �! z •�o i Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk 28243 -1 Field /Pool: KRU/ Kuparuk Permit # (PTD): 181 -035 API Number: 50029205730000 Operator: Exxon Date Suspended: 5/29/1980 Surface Location: Section: 17 Twsp: 11N Range: 11 E UM Nearest active pad or road: Spine road near DS 1 D and DS 1 C Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General tin condition B in gravel e e oca o co d t o 12 wood earns set a 9 Pad or location surface: Good Gravel Location cleanup needed: None Pits condition: Reserve pit surface frozen with no visible hydrocarbon sheen Surrounding area condition: Good Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: none Samples taken: None Access road condition: Good gravel after stream crossing in a tucker Photographs taken (# and description): Yes, well and surround area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: No Visible leaks, good condition Cellar description, condition, fluids: Rectangular metal cellar box - frozen water Rat Hole: none visible Wellhouse or protective barriers: steel barricade that needs repair - see photo Well identification sign: none / Tubing Pressure (or casing if no tubing): None taken no gages Annulus pressures: Wellhead Photos taken (# and description): Yes of well head and cellar Work Required: Repair or improve wellhead barrier, remove pilings, pit at side of pad needs rubbish & Beams removed and liner repaired. Operator Rep (name and signature): Ian Ives (AES) AOGCC Inspector: Jeff Jones Other Observers: Roger Mouser (AES) Inspection Date: 3/27/2010 AOGCC Notice Date: 9/21/2010 Time of arrival: Time of Departure: Site access method: Tucker s . � �" the ";[•. N•.r t ,� 4w dim oil I'm ri a8" a aro- M " x .N.':: . r e' a ,• : $ ' w N* A . 'ZI ,� �' �.. 3 : v '�"'^� C �.« :. �� « 4r ml �'t'i � •L��4 �' �4: T { i ,.m � .. �} ' �'x;�s� #'�a' .,:. r � yv..' � .�,.� a y m . t . K. 4 ` a 4,ai. Aw � Y s , y .. . . . «.� m «{ y � : � \ � \ > \ � . �� 2 »`��° � . \\ � : � : : £ � � . .d �� t .� ~ . ` » : � ° � \ � (yi5 \ � � < ' - � � : 2 \ . \ \ X. : \ � . : � .� � . \ �� \� « \ 1 /° . \� � � \ < � ^ �� ~� ƒ � . ,�� \ §� � }�/ �� r , y � v : �� \ .� § 2 : / ° � } \��\ ^^ � �` /\ : .�� \ � ƒ ° ° � 2 . :> . y �. ` : : \ � \� \, .... . :: ,, .: � . \ { / . \. t � 2 � \ l� . } /. � �� \ . I M b m , I lk _w FROM: H nyrMnV/� iui +v a.vL. -. EXISTING STATUS • 'r.r:r:r.� ' r f f f•r � 4•: 1.1.1.1.1.1 1.1.1.1.1 •'.:1 {.y.1.y1.1 1•y1.1.1 ► '�+ : r•r•r•r•r '�•r•r•r•r• h•yyyL• yyyyy • ; L:i � r•J•r•r•J 'r•r•r•r•r• ' .J !�•L•L•1•L. L.1KK•1 f. r.r•r•r•r 'r•r.r•r•r• C +; /� } }3 }} ye . L }•l }ti } } }�•} � } + l r ti. tr 16 CSA 80 L.L•L DIESE L +t Lrtii'.:tii1i , iti J y r y r y J ti s •r•r• L, r'r'r{:1: i {iy: r r.. r (DRIVEN TO REFUSAL) � :•; � 1.1.1• 1.1.1 • tirti:'r•r•J 'r•r•r•r•r• �t {� L•1•L• L•L•L L•L r�J 1 L'• J•J•J•J•J r•J•r•r•r• {y!{ CEMENT t`" •r•r r• J• ryr.r~ rti4ti ;�� ••••• K•1.1.1• 1.1.1.1.1 � Lt•• • • •r•r• +' +' � •! +: 1.1.1.1• 1.1.1.1.1 � -`. 1.1.L .}. }•J•J•r r•J•r•r•r• �S1 :: • 1•L•1.1• 1.1•L•L•L 7. •�•r•J•r•r i•J•r•r•J• /'' v� 1.1.1.1• 1.1•L•L•L +tiyltl • .r.r•r.r•r , +•r•r•r•J• ARCTIC PACK L L•L•L• L•L•L•1.1 r• •r:.) ►' %s � .r.r.r.r.r 'r.r.r.r.r• }w 1.1.1.1. 1•L•1.1•L I;y,; r•r•r•r.r 'r•J•r•r•r• - . {A ti•L•L•1• 1•L•L•L•L I': •r r•J•r•r ' }.J.r.r.r. r: wt. 47•'•S •;•r•r•r•r 'r•r•r•r•r• y ,t 1 1.1.1.1. 1.1.1.1.1 t TOP ARCTIC PACK CEMENT .!- 2300' :�: OF ARCT + •. •• r•r•r•r•r r•r•r•r•r• -_- I•i:' •: {••,r 1.1.1•L• 1.1.1.1.1 •:1 ! *t. 1.1.1.1• 1.1•L•L•1 •!'' ' 9.8 PPG MUD ar t: :' :'+. +' +'+ ,.r. +' +' +' �':: •, ;,' L•• 1.1.1.1• K•1.1.1.1 +'•r �� :lt,L r•r•r•r•r r•r•r•r•r• ;f`;. �{� 1•L•1.1• ti•1•L•L•L k:r;• ^Stir } r.r.r.J.r..• • � L.L. L•L•L•1.1 Y k .: { f•r•r•r•J i•r•r•J•r• w1: rY;} Lr.:r 1.1.1.1. L•1.1.1.1 '•.•• 10. � CSA 2 930 MD y r•r•r•r•r r•r•r•J•J• Lr 1.1.1.1. 1.1.1.1.1 Vry r r•r•r•r r•r•r•r•r• ('FMENTM 70 SURFACE ir f; }� }� }�} �•J ~JyJ~Jy • R _J 1.1.1.1. 11.1.1.E 45.51 K -55 BTC 1 r•r•r•r•r }• }•r•r•r• 1 1.1'1'1' •1.1•L•L•L r•r•r•r•r r•r•J•r• 1.1.1•Y •1.1.1.1.1 �•r•r•r•r r•r•r•r• TOP OF r CEMENT EST AT 1110' 1.1.1.1• 1.1.1.1.1 r., 1.1.1.1• •1•L•1•L•1 yt •r ;•r•r•r•r r•r•r•J• Lb 1.1.1.1• •1.1.1.1.1 : L, r•r•r•r•r r•r•r•r• t 4! i! 1.L.L.L. {•1.L.L.1 •i '! }•J•r•J•J r•r•J•r• � 1t S•L•L•L• ti•1K•1•ti • yt 3 -1/2 TUBING AT 4457 - - - - - - - - - - - - - - - - - - - : +{___________ u - -- --------- - -- ----- - - - - -- :! ^. { �f------------- Y r �r.V ------------- •r+ , _ _ _ _ _ _ _ _ _ _ _ _ _ ___________ _ {N ----- - - - - -- -- l {\ -------- - - - - -- 1s1 -------------- ------ - - �yK - -- 1 KUPARUK C -SAND, 11276'MD 1 +f -== --= -- -- -- -- - - -- N r� • - 'ra•'I WELL IS NOT PERFORATED 6 4 93' T V D r % - - -- - -- ---------- - - - - -- +� [ +� - __-- - - - - -- - y1C• KUPARUK B -SAND, 8590'MD 6742' TVD t�+ - - -- ----- - ---- - - -- -- - ---- -- - -- = •+1-r------ - - - - -- rLr. ` ------- - - - - -- ��+ _ _____________ 2" K -65 8TC w ) r t' + •t Lrs��r 7" C 1S, A 8.780' MD; 6,89.' TVD ARCO Alaska. Inc rLr a`esr rLr Lt Y.L+v .f r KUPARUK 28243 MOBIL - PHILLIPS 81 (MP -1) TD. 8,850' MD, 6.949' TVD URFA LOCATION: 47V FSL, 6W FWL SE 17. Ti IN. R11E. UM a0TT0MFIOLE LOCATION: 1402' FSL, 402T FEL, SEC 18.711N. R11E, UM TWM. 12/13/90 October 25, 2010: Clarifications made on this wellbore diagram to reflect the level of drilling mud from 4,457' to TD and diesel displaced from 4,457' to the top. Data obtained from May 28, 1981 daily drilling report in AOGCC file. OCT 26 '98 17:17 90'72634966 PAGE.01 I w o � d « T12N� � 9 1 xis ng T!1N n 0 True D y a \/ 7 V ...�./ a 9 18 IT la o trier V W �7t�la�''.34" 14le 23 25 " W a = h 'J' NSL, 139'_+ WEL W w T. TIIN, Rt1E VICINITY MAP $ scAlk las0000 uS.GS OW1p ilEECHEY POINT, ALASKA / • oPosed Will Site s rat 29243-Mr MILES 1. TC 149 °25' OI.49' W 10 17 I7 16 19201 2021 t� ;. J'LJ '=.! T 11 N, R12E FEB 6 ?1Nrl11 VIEW Div. of Minerals 8 Energy Mgt. 1112 i/4 O 1/4 Ml ! Notes: Anchotage, AIL MILES Ave lorroin ao•otion 60' Scale N's 1/2 Mill above M.S.L. Culvert will be installed of 20 "m stroom crossing. .� A TaNOAA •• ••T YMMe W Wp TY P� G= UGT® Rtri»N Root AI al 12/1!►!YO N.TS. PROPOSED ACCE ROAD TO KUFOJM 18243 —MP IN: Sots T.,I7 M 1*, TIIN, RIlE, am, AK. Patlsoo: • NEAR: 9EECNY POINT, ALASKA Proviso oc fr existing mod to a proposed drift life. APPLICATION !Y: MOft OIL CORPORATIO N SNEET 1 OF 1 DATE SEPT 10, 198 ;T 26 '98 17:19 9072634966 PAGE. 08 R EV I DATE BY I CK I APP I M IFTION I REV DATE I W Y P I DESCRIPT LEGEND T1 2N T11 N O FUTURE CONDUCTORS • EXISTING CONDUCTORS 2 1 e est s 0 AS— STAKED CONDUCTORS —THIS SURVEY Sal 24A N W.S. T.P. . DS -1C 1 11 12 7 8 �SUR Y SCALE: THI 1" = 200'14 13 18 17 - os 1M 23 Za 18 to rn m VICINITY MAP SCALE: 1" = 1 MILES WELL 110-17 gctc LOCATED WITHIN PROTRACTED SEC. 17, TWP. 11 N., R. 11 E. UMIAT MERIDIAN Y = 5,960,383.6 017 X = 571,907.4 t� LAT = 7W.11 ,07.40" LONG = 149'2503.24" 618' F.S.L., 600' F.W.L. • MP 1 14s� -o35 %*.AWED aC ► - 4 2010 NOTES: 1. ALL COORDINATES ARE ALASKA STATE PLANE, NAD 27, ZONE 4. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL, O 3. ALL DISTANCES ARE TRUE. 4. DATE OF SURVEY: 12/7/01, F.B. 1.01 -64, KS 64 -66. 1e + 18120 LOUN.SBURY do ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: IM MODULE :Wx UNIT: D1 m Rups PHILLIPS Alaska Inc. DS 1M A Subsfdiory of PHILLIPS PETROLEUM COMPANY WELL CONDUCTOR 17 AS— STAKED LOCATION CADL 611302 12/6/01 DRAWING NO NSK 6 .113 — d2 SHEET: 1 OF 1 REV: 0 ExxonMobil Production Company* Dale Pitt# P. O. Box 196601 Alaska Production Manager Anchorage, Alaska 99519 -6601 Joint Interest U.S. 907 561 5331 Telephone 907 564 3677 Facsimile E�onMobil Production October 27, 2010 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission OCT 2 8 2010 333 West 7 Avenue, Suite 100 Absial all &(3 Cons. COW4Y33tOn Anchorage, Alaska 99501 AI71ihol`age Re: Inspection Notification Sundry 10 -404 for Kuparuk 28243 -1 Well PTD No. 181 -035 Dear Commissioner Foerster: ExxonMobil hereby notifies the Commission of the completion of the Kuparuk 28243 -1 well inspection per 20 AAC 25.110. A visual inspection of this well was performed by ConocoPhillips on ExxonMobil's behalf on September 27, 2010. Jeff Jones with the AOGCC accompanied ConocoPhillips to witness this inspection. The wellhead was in good condition, there were no visible leaks and no visible oil sheen on the ground at the well site or in any nearby water. Please find enclosed the following information: • Form 10 -404 Sundry Report • Suspended Well Site Inspection Form • Photographic documentation of the well • Wellbore schematic • Well plats (one for Kuparuk 28243 -1 well dated 12/15/1980 and one for Kuparuk 1 M -17 well per AOGCC PTD #181 -035 well file that also shows Kuparuk 28243 -1) If you have any questions or require additional information, please contact Gilbert Wong at (907) 564 -3607. Sincerely, /A,__,Q � DDP:jpc Attachments A Division of Exxon Mobil Corporation • I � p ExxonMobil Production Com. Dale Pittman I P.0.Box 196601 Alaska Production Manager Anchorage,Alaska 99519-6601 Joint Interest U.S. 907 561 5331 Telephone /64, � V 0KV//�907 564 3677 Facsimile EonMobil Production September 23, 2009 Naso FEB 0 3,2.017, Sa RECEIVED Commissioner Cathy P. Foerster SEP 2 4 2009 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Alaska Oil&Gas Cons.Commission Anchorage, Alaska 99501-3539 Anchorage RE: Request for Verification of Suspended and Shut-in Well Information Dear Commissioner Foerster: By letter dated January 29, 2009, the AOGCC requested verification of information regarding suspended long-term shut-in wells listed as operated by ExxonMobil or predecessor companies. The lists of Suspended and Shut In Wells attached contained a total of eleven wells. We have no revisions to the information for the Kuparuk 28243 1 well which is located within the Kuparuk River Unit operated by ConocoPhillips. As with your records, we understand that the Starichkof St 1 well was operated by Pennzoil, not by ExxonMobil or a predecessor company, and the lease and well currently is within the Cosmopolitan Unit operated by Pioneer. With respect to the 9 Point Thomson area wells, a sundry notice report was filed with the AOGCC on June 1, 2009, describing the location and well inspection and remediation work performed in March and April of this year. A copy of these reports, along with a summary of the well status is attached for your reference. Please advise if there is any further information we can provide in conjunction with this response. Sincerely, DDP:jpc Enclosures xc: Mr. Tom Maunder—AOGCC A Division of Exxon Mobil Corporation I I I L r 1110 ( O V IL\0 N. co co co Co N \ Co I \N �O `� N N VV� VO c c •�a O . .c � O o E \ N \ 0 �'N 0 E \0 \ N. a) 0 U) (..) '- M o o O CN 0 ♦ 1 O 0 0 O O (0 O 0 0 0 V CUN N N N O N v N N O O N C M 4- rt d' C �t 0 4 d' C J 't C CO .� co in CO Co 0 0 0 N Q Co a) Co QQ aa) 0.. 0 0 Co 0 0 O I 1-a) o 0 0 QU) L 0_ C. 0_ O. •••• 0_ E n O. 0 E QO •• • c c Cl) c ' co a) co c3OCC . .0 - - - - o = c - - o � - o = a �ffi 75 TD aa3: 4g u) = -a a a s Co a a? v v a) 0 v a) = cCo Co co co E Co a0) Co coE co O E 0 0O Oa) ▪ co)V/ C C C C L C Q' C C L O C L C -0 O O O 0 a5 0 c 0 O 5 0 0 5 2 _ — Cu0 Co0 co0 0 t 0 N Co 0 0 t C CO JJJJ IL 0 > 0 JU.. > JU O -0 O O O O 0 O O O O o W a a N N N N N N N N N N C C C C Co C C Cl) C LL —3 —3 - -3 CO V a V V V V V V V C Co V V V C V C V C CI) 0 = C C C 0 C 0 C 0 0 a) 0 a) V 0 V a) V V = ,N 0_ Q 0. C Q C 0. C C V la as U) Cl) CO < f/) < (I) < < M N O) i _ co C C C C .0) 0 ) D D 0 D , Co CO Co c c c c a =) cn cn 0 0 0 0 i U) a CD E E E E > 0 0 � � C C (0E .0 0 0 0 V) • z I— f— I— I— co co 2 CO U) rn d C "E'E' C U Y!) c O a. a. a. a. < < u) > N a) ExxonMobil Production co. Alaska Interest - Joint Interest U.S. P.O. Box 196601 Anchorage, Alaska 99519-6601 e RECEIVED JUL 2 6 2006 ,4ìaska Oil & Gas "0 'c . ... 11$. omrmssion Anchorage Date: July 14, 2006 EJf(onMobil Production 1'IÞ l~l-O~35 Mr. Steve McMains Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, #100 Anchorage, AK 99501-3539 Re: Suspended Well Report Update for Kuparuk 28243-1 In response to your letter requesting an ùpdated status report, ConocoPhillips has completed an inspection of the subject well and surrounding wellsite. Following is the information required for the report: 1) Current mechanical condition of well, including installed tubing and casing strings A visual inspection of the well and surrounding area revealed no mechanical or environmental concerns. A mechanical integrity test of the wellhead, tubing and casing was conducted and found no problems. A picture of wellhead and adjacent area is attached. 2) Date well was suspended and circumstances for suspending well This well was suspended after drilling in May 1981. Records indicate it was not considered economic to develop. 3) Analysis of future utility of the well Available data and information indicate potential utility for the well for appraisal or development activity for identified sands in this area. 4) Other information required by commission necessary to ensure that freshwater and hydrocarbon sources are protected No additional information currently required by commission. If you have any questions regarding this letter, please call Mark Pohler at (907) 564-3722. {~ \~f i..: Sonny Rix Operations Technical Manager RLR:ddm Attachment RLR\Suspended well Report·MP-1 Well.doc c: Don Dunham BP J. L. Von Cawvey, CP C. S. Luna M. A. Pohler A Division of Exxon Mobil Corporation Attachment 1 Kuparuk 28243..1 Wellhead lc-apfm 10j an95 PLUGGING & State of Alaska LOCATION REPORT CLEARANCE ALASKA OIL & GAS CONSERVATION COMMISSION PTD No. Memorandum To File: AP1 No. d92~-~-.~-6o Well Name Operator Location Abnd Date TD: ~.5-O , Completed Note casing size, wt, depth, cmt vol, & procedure. Long Csg: -'] Z~ ~:~ t~ ~'~,~ t~/~'6G Liner: Perf intervals - tops: Review the well file, and comment on plugging, well head status, and location clearance - provide loc. clear, code. plugs: Well head cut off: Marker post or plate: Location Clearance: Conclusions: , Code Signed Date Telecopy No. (9-07) 276-7542 July 10, 1987 Mobil Oil - Alaska c/o Phil Braithwaite P. O. Box 900 Dallas, TX 75221 Re: Application for suspended well status Kuparuk 28243 MP-1 Dear Mr. Braithwaite: A review of Our records shows the Kuparuk 28243 MP-1 well as suspended prior to April, 1986, In April, 1986 the AOGCC revised its regulations concerning suspended well status. Suspension of this well has not been applied for under current AOGCC regula- tions. By this letter the AO~C is requesting you to submit Form 10-403, Application for Sundry Approval, with justification for classi- fying the well as suspemded per 20 AAC 25.]10. I am including a Form 10-403, and a copy of the pertinent regulations. Please call Russ Douglass at (907) 279-1433 'if you have any que s t ion s. Sincerely, ~ ~? Lonnie 'C. ~ Smith Commiss loner EnclOsures jo/A.RAD.45 August 6, 1986 Telecopy No. (907) 276-7542 Mr. Randy Ruedrich Drilling Manager ARGo Alaska, Inc. P.'O. Box 100360 Anchorage, AK 99510-0360 Re: Extension of Suspended Status Tract Well T-3C KI{U West Sak SWPT No. 1 Term'Well A East Bay State No. 1 28~4:3~t~o~?~1- West Sak No. 24 Dear Mr. Ruedrich: A review of our records shows that the above referenced wells are suspended. Ail of the wells have tubing installed, and KRU West Sak SWPT No. 1, East Bay State No. 1 and West Sak No. 24 have perforations open to the well bore. Section ll0(a) of. the regulations states the Commission will, in its discretion, approve the suspension of a well if the well is capable of producing hydrocarbons in paying quantities or is reasonablY' demonstrated to have future value as a service well. Section 105(e) states that "[e]ach well to be abandoned or suspended must be plugged..-.to prevent the movement of fluid either into or between freshwater and hydrocarbon sources and to prevent all other fluid migration %-ithin the well bore." in compliance with Section 170(a) of the regulations, "It]he locatiOn of an abandoned well onshore or upon a historically stable is~d must be cleared within one year following well abandonment .... " Section 170(b) provides the means for an extension of time ~ a valid reason exists, and the wellbore is properly .plugged. Pr. Randy Ruedrtch August 6, 1986 Page 2 We are, therefore, requesting that you submit Form 10-403, Application for Sundr~ Approval, with (1) a program which will bring the status of these wells into compliance, with the new regulations; (2) justification for .keeping the wells in suspended status; and (3) a schedule for this summer when our field inspectors can accompany your representatives to the well sites for location clearance inspection. - ' Please call Harold J. Hedlund at (907) 279-1433 if you have any questions. _ Sincerely, _: Lonnie C. Smith ~i- Co-~ ssioner - jo/A.HJH. 06/07 October 17, 1985 Ms. Jo Ann Gruber ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Submittal of Form 10-403, Notices and Reports on "Sundry to Request an Extension of Time for Suspended Wells- Dear Ms. Gruber: It is requested that the Form 10-403 for the extension of time for suspended wells under 20 AAC 25.270(b) be submitted at an early date. The request should include: 1. A request for a one year extension. 2. A reason for the extension of time. 3. A description of future clean-up plans, if applicable- The following wells are included under this request: WW Eileen State No. 1 Delta' State No. 1 Delta State No. 2 East Bay State No. 1 Gull Is. State No. 1 Gull Is. State No. 2 Highland State No. 1 Kavik unit No. 3 · Ugnu SWPT-1 West Sak SW?T-1 ~ . West Sak River State No. 2 West Sak River State No. 3 -Sag Delta 31-11-16 Hemi Springs State No. 1 Prudhoe Bay State No. 1 Prudhoe Bay Unit Term A Prudhoe Bay Unit TR T-3C Put River State No. 1 Ravik State No. 1 West Beach No. 1 West Beach No. 2 West Beach No. 3 W. Mikkelsen State No. 1 West Sak River State lqo. 5 West Sak River State No. 6 West Sak 25590 No. 15 East Ugnu No. 1 Sincerely,, Lonnie C. Smith Commissioner dlf: A. HJH. 10 ALASKA OIL AND GAS CONSERVATION COMMISSION / . 3001 PORCUPINE DRIVE November 9, 1984 c / ANCHORAGE, ALASKA 99501-3192 ~ TELEPHONE (907) 279-1433 ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Submittal of Form 10-403, "Sundry Notices and Reports on Wells," to Request an Extension of Time for Suspended Wells, Gentlemen: It is requested that the Form 10-403 for the extension of time for suspended wells under 20 AAC 25.270(b) be submitted at an early date. The request should include: A request for a one year extension. A reason for the extension of time. A description of future clean-up plans, if applicable. The following wells are included under this request: -- Delta State No. 1 Delta State No. 2 East Bay State No. 1 Gull Is. State No. 1 Gull Is. State No. 2 HighlandState No. 1 Kavik Unit No. 3 Ugnu SWPT-1 West Sak SWPT-1 Kuparuk River State No. 1 N. Prudhoe Bay State No. 1 ~West Sak River State No. 1 West Sak River State No. 2 West Sak River State No. 3 West Sak 25631 No. 23 Sag Delta 31-11-16. NW Eileen State No. 1 Prudhoe Bay 'State No. 1 Prudhoe Bay Unit Term A Prudhoe Bay Unit TR T-3C Put River State No. 1 Ravik State No. 1 West Beach No. 1 West Beach No. 2 West Beach No. 3 W. Mikkelsen State No. 1 :Kuparuk 28243 No. 1~~ West Sak River State No. 5 West Sak River State No. 6 West Sak 25590 No. 15 East Ugnu No. 1 Yours very truly, Kugle~ Commissioner be:2.K~T September 20, 1983 ARCO. Alaska, Inc. P. O. Box 100-360 Anchorage, Alaska 99510 Re: Cleanup Inspection for the Following Suspended WellS: D.S. 11-14; Sec. 28, T1//.-], A15E, U.M. Delta State ~o. 1; Sec. 10, ~T101~, R16F., Delta State No. 2; Sec. 35, TllN, ~16E, U.~I. East Bay State No. 1; Sec. 15, Tll~, R15E, U.M. Gull Island ~o. 1; Sec.. 28, T12~, R15E, Gull Island ~o. 2; Sec. 28, T12~, R15L, U.M. b'ighland State Eo. 1; 'Sec. 24, T1/}~, RllE, Eavik Eo. 1; Sec. 7, T3N, R23E, Kavik No. 3; Sec. 8, T3k~, R23E, U.~. sec. 17, North Pr~6~ Bay S~ate Eo. 1~ Sec. 23, T12N, R14E, U.~.~. ~udhoe Bay State ~o. 1; Sec. 10, Tll~~, E14E, D.b~. Eavik State Eo. 1; Sec. 32, T9~, R9E, Te~ A (41-33-12-~4); Sec. 33, T12N, R14E, U.M. Tract ~11 T3C (17-11-15); Sec. 17, Ti~, R15E, Ugnu ~ ~o. 1; Sec. 7~ T12~,' R10E, West Bea~ State No. 1; Sec. 25, TI~, R14E~ U.}%. West ~ach State ~o. 2; Sec. 2.5, T12N, R14E, U.M. West Beach State ~o. 3; Sec. 25, T12~, R14E, U.M. West S~ Eo. 15; Sec. 5, T10N, RSZ, U.~. West S~ No. 23; Sec. 7, Ti~, R9~, West Sak Eo. 24; Sec. 5, Tll~, R11E, Wesk S~ P~ver State ~o. 3; Sec. 26, TI~, R9E, U.R. West S~ River State Eo. 5; Sec. 11, T10E, R10E, U.M. West S~ River State No. 6; Sec. 29, Ti~{, ~1~, U.~. BP ~t River 01-10-14; Sec. 11, T10~, R14E, U.M. BP ~t River 02-10-14; Sec~ 11, T10N, ~14E, ~.~. BP ~t River 11-10-14; Sec~ !!, TlON, R14E, U.M. BP.~t River 12-1~14; Sec. 11, T10N, R14E, BP ~t River 13-10-14; Sec. 13, T10N, Ri4E, U.M. BP ~t River i4-10-14; Sec. i3, TlON, ~14E, U.M. BP ~t River 17-10-15; Sec. 19, T10N, ~iSE, U.~4. Gentlemen Our representatives 'inspected these 32 well sites on. August 14 and August 23, 1983. The following wells wall require the submittal of form. 10-407, Well Completion or Recompletion Report and Log, to classif)'as suspended %~:11s. All requests for clansifications az¢ initia~ea ky the o[;erator on form 10-407~ ~avik. i~;o. 1 Prudhoe ~ay State 1~'o. 1 Term A (41-33-12-14) Tract Well T3C (17-11-15) The following wells need well signs: Eavik ~o. 1, ~ell sign not properly, attached and in l;oor condition. Prud/'~ioe Bay State !~o. i following well ~iteS need the ra~ hole covered~ ~ighland State ~o, 1 Eavik ~o. 1 Eavik State ~]o. 1 Tract Well T3C We.~t' Sak ~0 · 15 ~P ~t ~iver 13-10-14 The fcllowin~ we11 ~ite~ need imt~rovem~nt in houmekeepinW and trash removal ~ ; Pru~/~oe Bay Sta~ }~o. 1,' the woll house a15o is in f.4:or condition. We~t Sak }~o. 24. West Sak River State ~4o. 6 Tl~e following wells do 'not have all outlets on the ~ree ~,luggeO, ~xudttoe Bay State ~o. 1 ~orth Prud~oe Be}, State }~o. 1 Kavik }.~o. I All of the 32 listed well~ require the submittal of form 10-403, Sundry ~otices and Reports on Well~, to req~ue~t and. '3ustii~' an}. further extension o~ one ~ear for the suspended ~ites as required under 20 AAC 25.170(~) (1) (2) and (3). It is requested that deficiencies be corrected as soon as possible and photographic evidence sure'lied this office. Also ~,lease submit at an eaz'l~- date the r~quired ~ox~.s 10-403 and 10-407. A subsequent in~p~ctlon wil ~ necessary b}-' August, 1984. Sincerely' ..' Lonnie C. S~ith com~i ss ioner LCS/JRT: lc ~ 103 ~ E MEMORANDUM State of Alaska ALASKA .OIL AND GAS CONSERVATION COMMISSION C.~ertOnCh TO: DATE: Thru: Lonnie C. Smith Commi s s ione r FROM: Ben LeNorman · ~"~ .SUBJECT: Petroleum Inspector August 25, 1983 108B:S4 Inspect Thirty-two ARCO Locations for Surface Cleanup for Suspension, North Slope. Sunday, August 14, 1983: I departed my home at 3:15 pm for a 3:45 pm showup and 4:45 pm departure via Alaska Airlines, Flight No. 341 for Deadhorse arriving at 7:10 pm. Weather: +36°F, light wind, fog. ~4onday, ?ugust 15, 1983: Inspection of forty-one abandoned and suspended wells began at 9:00 am and 'continued until 3:30 pm on Wednesday, August 17. Separate reports cover abandoned wells and a BOPE test on ARCO's DS 4-20 Monday evening. I recommend to the Commission the following wells be approved for suspension: Delta State #2 Delta State #1 Gull Island #1 Gull Island #2 Team "A" 33-12-14 N. Prudhoe Bay State #1 Highland State #1 Mobil Kuparuk 28243 Ugnu SWPT #1 West Sak #23 West Sak ¢3 West Sak #5 Ravik State #1 West Sak #24 West Sak #15 West Sak #6 Kavik # 3 We st Beach State #1 West Beach State #2 West Beach State #3 East Bay State #1 T3C 17-11-15 Put River 01-10-14 Put River 02-10-14 Put River 11-10-14 Put River 12-10-14 Put River 13-10-14 Put River 14-10-15 Unknown DS 11-14 I recommend to the Commission the following wells not be approved until deficiences as noted on the suspended well and location report are corrected: Kavik # 1 Prudhoe Bay State · #1 I departed Deadhorse via Alaska Airlines, Flight #56 at 4:30 pm arriving in Anchorage at 6:10 pm and at my home at 6:40 pm. In summary, I inspected thirty-two ARCO locations for well sus- pension and location cleanup. Atta'chments Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: ~ .~y -- / %~ --~//~~ ~ //~,~/'/. Date Suspended Surface Location of Well . Permit . ~O~ Ft. F ~ L, ~~ Ft. F~L API No. seC. /~, T // ~, ~R~~,' ~M. Unit or Lease Name Fi el d & Pool ~~q~ Condition of Pi ts Well head - Ail' outlets plugged ~ No Well sign - Attached to we'll head Yes No Attached to wel~ guard Yes No Attached to /~s~-_~ ~4~_~ Z~/~;-z~_~'_~--~ ~._ _ Information correct ~ No Cellar - Opened ~ No Rat Hole Open Yes No Fi 1 led Ye s No Fi 1 led Ye s No Covered Yes No Covered ~ No WaterWell - Plugged off Capped Open Photographs taken to verify above conditions~ No Expla naton Work to.be done to be acceptable This well and location is (acceptable) (~aeza=..~-~.~.~) to be suspended for the perio~ of ..;-~,/~ .._ 19~ th~u -~-/~ . Inspected by: ~ ~,~/~~.~~. Da te: ~_~ --~ classified as Revised 8/24/82. Mobil Research and Development Corporation September 9, 1981 RESEARCH DEPARTMENT P.O. BOX 900 DALLAS, TEXAS 75221 Mr. John A. Levorsen Alaska Oil'& Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 403-4758 SHIPMENT OF CORE CHIPS FROM MOBIL-PHILLIPS KUPARUK NO. PRUDHOE BAY, ALASKA .~---'""~,~ Dear Mr. Levorsen: At the request of Mr. Bruce Greve of Mobil in Denver,.chip samples were taken from approximately each foot of core material from the subject weil. A total of 149, samples were. obtained and packaged separately (sample depth listing attached). Two boxes containing the samples were shipped to you this day by air freight. . Contact us if we can be of further help. Very truly yours, ~/~/ G.W. Nabor WHWi 1 son :jaw Att. cc: Bruce Greve, MOC, Denver R.L. Wood, MOC, Denver W.C. Skinner (w/o att.) J.J. Wise (w/o att.) Sem~l e, ,Dieptlh 8255' 5' 8256'6' 8257'7' 8258'3' 8259'4' 8260'4' 8261 ' 5' 8262'6' 8263'5' 8264 '7' 8265'5' 8266'2' 8267'4' 8268'7' 8269'4" 8270'5" 8271'3" 8272'3" 8273'5" 8274'3" 8275'3" 8276'7" 8277'5" 8278'6" 8279'7" 8280' ] 0" 8281 '9" 8282'4" 8283'5" 8284' 4" 8285'6" 8286'4" 8287'6" 8288'3' 8289 4' 8290 5' 8291 5' 8292 5' 8293 6' 8294 3" 8295'6' 8296 ' 4' 8297'7' 8298'6' 8299'4' 8300' 4' 83O ] ' 5' 8302'5' 8303'4' 8304' 10" MOB I L-PHI LLIPS KUPARUK NO. I CHIP SAMPLES ,~amp, l e, Dep th, 8305'5" 8306'3" 8307'3" 8308'9" 8309'4" 8310'4" 8311'5" 8323'4" 8324'4" 8325'5" 8326'5" 8327'6" 8328'5" 8329'5" 8330'2" 8331'7" 8332'3" 8333'5" 8334'5" 8335'4" 8336'2" 8337'5" 8338'6" 8339'3" 8340'4" 8341'5" 8342'5" 8343'4" 8344'4" 8'345'5" 8346'5" 8347'4" 8348'4" 8349'6' 8350'6' 835]'4' 8352'6' 8353'5' 8354'4' 8355'7' 8356'7' 8357'7" 8358'5" 8359'2" 8360'3" 8361'5" 8362'3" 8363'3" 8364'5" 8365'7" ,~amp le Depth 8366'6" 8367'5" 8368'3" 8369'6" 8370'3" 8371'4" 8372'5" 8373'8" 8374'4" 8375'3' 8376 6' 8377 7' 8378 4' 8379 6' 8380 2' 8381 6' 8382 7' 8383'2' 8384'5' 8385'8' 8386'4" 8387'3" 8388'7" 8389'5" 8390'4" 8391'6" 8292'7" 8393'3" 8394'4" 8395'4" 8396'4" 8397'7" 8398'5" 8399'6" 8400'2" 8401'3" 8402'4" 8403'9" 8404'M' 8405'5" 8406'7" 8407'4" 8408'4" 8409'3" 8410'5" 8411'7" I?E£EIVED 8413'5" 84)4'2" lilasl~l 0ii & ~a~ Co.~ Mobil Oil Corporation P.O. BOX 5444 DENVER, COLORADO 80217 CERTIFIED MAIL - RRR August 21, 1981 State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: John A. Levorsen Petroleum Geologist MOBIL OIL CORPORATION ADL# 28243 WELL #1 KUPARUK RIVER FIELD Gentlemen' Per your request of August 12, 1981 we are supplying you with the following' . The correct location for this well is 605' FWL and 479' FSL, Sec. 17, T11N, R11E, UM. ~ Two copies of a gyroscopic directional survey. A sepia copy of all logs run. A copy of digitally run logs (magnetic tape with print out). ~_~_Cnr~ chips.and. ..... well sam.nl~__~ are being recovered from our Field Research Lab in Dallas, Texas and will be submitted to you as soon as possible. Thank you for your cooperation in this matter. DLMatthews/sm E~nclosures RECEIVED AUG 2 ? 1981 Alaska 0il & Gas Cons. Commission Anchorage Very truly yours, C. J. Park Producing Accounting Supervisor ALASKA OIL AND GAS CONSERVATION COMMISSION ],IF $. HAt~I~ONO, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 TELEPHONE (907) 279- 1433 Date: To: Re: Receipt is acknowledged for the follow-lng: Qua nt i ty Description of Item ? o 70~ ~,.~.~/ '~ ? Yours very truly, ALASKA OIL & GAS CONSERVATION COMMISSION August 12, 1981 Mr. L. C. Case Division Regulatory Engineer Mobil Oil Corporation P.O. Bc~( 5444 Denver, CO 80217 Mobil Oil Cozporation ADL #28245 Well #1 Kuparuk River Field ~ar Mr. Case~ The surface location given for the subject well on the Permit to Drill application and on the Well Completion Report (605' FWL and 470' FSL, Sec 17, T11N, RllE, UM)disagrees with the location of slot 6 on the drill site registered survey plat and the departure diagram submitted for this well (605' FWL and 479' FSL, Sec 17, T11N, R11E, UM). Please indicate which surface location is correct. With co~.~pletion of-the well given as ~ay 29, 1981, the 30 day filing period ended June 28, and several regulations need your attention at this time. For deviated wells we require "a complete, continuous, multi-shot directional survey at intervals not more than 100 feet apart....' We request that you furnish us with two copies of the gyroscopic survey run on this well. The Commission required well samples be taken from this well and s~mitted. O~r regulations also require that the operator furnish us with a chip from each. foot of recovered core. We request that the well samples and core chips -be submitted, as required. The set of logs that accompanied the Well Completion report contained only blue line prints. A sepia copy of all logs run in the ~11 including the mud log is required, except for velocity surveys and ~perimental l~s. We request sepia c~ies of the logs run on this well be submitted. L. C. Case ~ 2 ~-~ugust 12, 1981 If any-~:lOgS run in the well were recorded digitally, we require ~t a coPy be made available to us for c-o~ying or that a copy be provide~ us, wi't~h the exception of 'dipmeter, velocity surveys, and ex~rimental logs. Thank you for your attention to these matters. Sincerely yours, ,/John Ao Levorsen ~etroieu~ ~eologist ALASKA OIL AND GAS CONSERVATION COMMISSION JAY I HAMMOND, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 TELEPHONE (907) 279- 1433 Re: Receipt is acknowledged for the following: Qua nt ity / /~- / / / DescriPtion of Item Yours very truly, ALASKA OIL & GAS CONSERVATION COMMISSION ~'"~ ~: STATE Of ALASKA ALASKA .~D GAS CONSERVATION C /SSION WELL COMPLET4. ti R RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well OIL [~( GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number MOBIL 0IL CORPORATION 81-35 3. Address 8. APl Number P. 0. Box 5444 Denver, Co3o. 80237 50-029-20573 4. Location of well at surface 605' FWL & 470'FSL, Sec. 17, TllN, RllE, UN. At Top Producing Interval 1246'FSL & 3713'FEL, Sec. 18, TllN, RllE,UM. At Total Depth 1402'FSL & 4027'FEL, Sec. 18, TllN, RllE,UM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 9-7-" MAT 63' I ADL 28243 t2. Date Spudded 13, Date T.D. Reached I 14. Date Comp., Susp. or Aband. 5/5/81 5/24/81 I 5/29/81 17. Total Depth (MD+TV~),) 18.Plug Back Depth (MD+TVD)I 19. Directional~SurVey I 20. Depth where SSSV set 8850'MD 6949r 8780'MD 6894' ..... IYESE:X NO[] I - feetMD 22. Type, Electric or Other Logs Run DIL~BHc, glk/~r, DIL~BHC~/FDC~CN'L~NGT 23. CASING, LINER AND CEMENTING RECORD 9. Unit or Lease Name 10. Well Number Kuparuk 28243HP-#3 '11. Field and Pool Kuparuk River 15. Water Depth, if offshore 16. No, of Completions - feet MSL - 21. Thickness of Permafrost 1900'+ SETTIN( DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 1 6" 10 3/4" 7" Conducto' K-SS 'K-.Eft Surfac~ Simfac~ 80' 2930' R7R0 ' 2300 .qax Arctic~q~t 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) None SIZE None 11 DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED ! None 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested WATER-BBL Casing Pressure WATER-BBL Flow Tubing Press. 28. PRODUCTION FOR IOI L-BBL GAS-MCF .TEST PERIOD I~ I' ' "" CALCULATED' i~ I OIL-BBL GAS-MCF 24-HOUR RA'TE CORE DATA ICHOKESIZE I GAS-OILRATIO OIL GRAVITY-Apl (~'~rr) Brief description of lithology, porosity, See attached. ~res, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED AUG l 0 1981 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE SUbmit in duplicate GEOLOGIC MARKERS NAME Kuparuk "C" Sand Kuparuk "B" Sand MEAS. DEPTH 8276' 8590' : ;.: ~ ', ~.. 1~. ' ,:, . ~.... ............ ........ . ...... Include interval t~ted, pressure data, all fluids r~over~ and gravity, GOR, and time of each phase. TRUE VERT. DEPTH 6495' 6742' No tests. .. 31. LIST OF ATTACHMENTS Well history, core & SWS analysis, directional survey & logs. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 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 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 inteFval 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 othE Item 23: Attach~ 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". CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS CORE ANAI...Y=,3~i;S REI::"(..t'sI MOBIL. CIlL,~ L,(..kF OI',,A! .I. ON I'~ LJP AI:~L. I'x KLiPARL.IK F. [. CII... N 0 R'i" H S L.. 0 F:' E ~, A I...,4.~ ix ~.. These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. K U P A R U K M P :il: ! i'~ U P A F;,' U t'-'.: F:'O 0 I... NORTH SL. OF:'I.=.'::, ALASKA CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TI~XAS L. 0 (2 A T I 0 N ~. 10-.-JUNE-..-81 C 0 R E A N A L. Y S ! S :., ':-c:; ~:.: t,,[ ..... UL. T 0... :0 Iii: A N-,S TA R K A N A t... Y S I S PAGE lA l::'II...i!~ NO ~. BF ....3-67:1. '¥'i q ANAt...Y,STS ,~ W,SI::', ........ LABORATORY: ANCHORAGE ~:": A N P L I::. .0 Iii: P "[' i-'i F:' E R N E A B I I... I T Y ( N.O .~ P 0 R (3 R A ! N I" L. U .i..'0 ,:., ~.~ ~ ..:.~ o N U N B E: R e E E T N A X :[ N L.t IH 90 .T.)E G ~.,..~ [!: R T ]: C A L ?. ~(:! Ii: N o 0 :[ L. W"f i:;,' i 8 '26 '3 o 0 0 .:. 04 0,07 4 · 4 :3 o 2 t 0, '7 ? 0 o 8 "~ 826 ~:.:; o 0 0 o 0 ............. ":~ 0 o r~ '::~ 4 ,, 4 :3 ,, ':~ ':~ 0 · '7 ,:.q ~::.~ o'" :I. ...~, :'.~ 8 ::28 i 00 0007 0 .:. 06 700 ~'J ,. 32 I .:. 8 89° ~ 4 8282 ~. 0 00:34 0 ,, 14 t 6,...::? :3 ,, 12. 4 ,, ";', 9:30:3 '::' ~::~ ? 8"z, 0 ¢.~ 2 76 ~.., .... .... ,., ., 0..:. ,~.":; 7 00 ic,':" 15 .., 7 .. 0 406 9...20 .,-:.'"' s ~!.,' r~'~ e /:, :::~.':~.q.a 0 c~, ':~'::: 4086 .~ '7, i 20 ':~' 2 ':~ 0, ,~:~ 71,1 ..s ~!~ ~ e 7 ............ 8 ':::' 8 ~::; 00 0018 0002 1,:. ''~ ~. 0.:3006 i 00 :':.~ d~:' .,~. '~ · :...':~ s ~.,' rn e 8 q,-~o ,... 0 ,':, 0:3::~ 1 '::' 2. :'~ ~. 02 1 '!, 7 690 I s~!.~e 9 ~....... ~.. ,q ''~ q "' 0 ~"~, 8:30 ,~', ..... :3 ,. .,.0 ,..':~ ':~, .,,.. 8 2086 2405 600 ........ 2 s ~:-'.; 'f'" "" .'.:.' .~..'.~ 'r 10 q ''~ q '''~ 0 00 ,,..,: ...... s ~ rn e !~ v s i d · ~:..,...,, o .:. ') © 0 o 02 7 .., ~? 3 ~ 12. 10 o 9 ':? 7° '::; 1 i ' 82.89 ~. 0 0,37 14 o 7 :.'.5 o 06 9 o 6 80 o 4 s a..'.m e 1,.-.. ''~ 8290 ,0 0 o 06 0 ,., o..~.5 .t. o ,. 7 :3 o 08 1 ,...o':~ :.3 8:3 ,~ 8 s ~..'.~ ~ e 1 S, 8 '291 o 0 :568 ,. 0 o 65 15 o 9 :3 ,, 0 ~:.:; i 4 · :3 81 o '7 s a.~ ~ e .0 v s i d i .a, 8 ,...':~ ~'. ,.... ''~ o 0 44 ,, 16 o 26 ,~ 2 2, ~..,..':: 14 ,.,:,~'" 80,8 s ~i.~ rn e i ":; 829 :':'~ ,, ."':, 2 -4:3 o c;~ 7 "~ '"' ., ........... ............... :':, ,, 6 ':~ ,. c~ 5 :L ':~ ,. 9 76, ':~ s a.~ rn e 16 82. 94 o 0 7:3, 16 S ,. 2 S, 5 2 .., 94 8 o 9 76 o '7 s ~.,' rn e 17 8 '2. 95 ,, 0 5 i 6 ,. 91 o :30 ,. 8 '2 .., 91 18 o 9 70 ,. 0 s ~5~ ~'~ e :L 8 8296 ,. 0 9 o 4 '7 5° 37 ',2',3 · 4 .3 o 04 6 o 6 88,4 ,.'~.~ a.~ m e 19 8 ~ 9":' 0 11 ~"~ ~ '''~ 2 ':~ 1 .:. c~ :.'5 · o :'5 7 o 5 85 o ~ ..... ..- .~. .:. ............ [.:..E~: ITt e ............... ~ ~.., , :i. S a.~ I't'~ ,."~ ':~ 0 8 ':~ e ....... :, ,. 0 i .:. "~ r~ 0, ',"~ 7 ') 0 .:. 6 S o ,"~-a 7 o 4 c ,: 21 8299 .:. 0 0 o 19 '2 o 69 18 ~. 9 .'3 .:..1. 5 3,5 88 ,, .c,~ s a.~ ~ e 22 8 S 00 ~ 0 2 '7 '.3 ~ 11 ~. :30 .., S 2 ,~ 9 '7 9 o '7 78 o 2 s .~. ~ e '2 '3 8 S 01 o 0 0,75 0 o 04 16 .:. ~;'~ .:::; o 0 S S ,, 7 9 S ,, :.'5 s ~.~ r~ e "-~"~ 9 S ':~ 24 8S0''~ 0 0 .., .,-....-.. 0 o 03 ~ ,, 9 3 o oq: 1, S ~ · .. o..-,...:. . .- ;.... . '"~":' 8 $ 0 S ,, (') 0 o '::' ''~ 0 o "~ '''~ 0 06 1 '? c-~ ':~ ......... ~, .,:. i 50 .S ,, .:. 9 s ~ ~ e :;~ ...,f - .. .:- . . '"'"" .q ~ 0 !::; ,, ,"'~ 4 o ~:; ~ ,=; c,~ C) ::> ":~ :3 ~3,0 ~ 6 o ~'~ o 0 0 ..::..,' ............. ~. ........... ~. . . . ., ,, . S .~[~ IT~ e 2 ........ 8 8306 .... ~"~ 4 ,. '? ? 3,0.4 i 8 .., :L 3 o :t. 4 :3 ,. I ,..q 9. o ~:;:s ~ r[~, e .0 f.i: S C: R I P T I 0 N s s .0 v 'f'".~..'~ r v s :i. d s 1 t. s t.; s 1 s d ::.~ v s :i. d These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. J<.: U P A R I..j K ~'"J F:' :tt:- 1 CORE LABORATORIES, INC. petroleum Reservoir Engineering DALLAS, TEXAS I) A T Iii: ~ 1 O-..-,.J U N ii!:.... 81 I::' 0 R M A T I 0 N ~ I) E A N'"-,:., [ A E i,, A N A I... Y b I S P A (3 E 2 A F:' I L. li:' N 0 ,'.'. B F ..... S'"' 671 ANAL. Y,STr~ o c, ", ,:., ,. W,.~t" , 'I"L· S · .'~ A M I" L. E t) E P 'l" I"1 NUMBER FEE:T 29 8:~074. 0 30 8308 00 31 '830900 110 32 8310o0 0 o04 33 832300 1710 34 8324 .., 0 <0 ,.. 01 "~;'::; 839,::; 0 1 '7":: 0 · ... '... .*,. ',., 4- . 36 83264. 0 0 ,. 02 37 832700 2924. 38 83 '2800 0002 39 83':) 9 00 o A · ...'~.. ." ;.,. 4, 40 8330,0 41 8 :.'5 31 ;, 0 0 0 2 7 42 83Z';2 o 0 0 o 0:2 4 :'.q. 83:~. :~ o 0 5() 0 · 4.4 8334,0 59 o 45 8:535 o 0 0 o 02 46. 833600 :L8 <. 47 8387 o 0 95 o 48 8338 o 0 49 8339 o 0 2 o 36 50 8340 o 0 0 o 98 51 8341 o 0 0085 52 83.42 o 0 I o 38 53 8343 ° 0 4 o59 !54 8344 o 0 7 .~ i0 [;5 8345°0 17° 56 8346 o 0 41 o · ~: 7 8 3 4 7 ,') 5 '~ ~ o ,. ....~. ° 58 8348 .., 0 -484. P E R H J::i: A B ! L.. I T Y H A X I M U M 90 D E G V E R T :J: C'. A 1... % ............................................................................... " ...... '": ; t'" '~" ~ ," . . . .-t ::. ~...~ 0 .L .L 0 ° .L 2 ' .L o 0 6 *"t 1::' "'-' · t::' .' ' ~ Z ~.. 0 ,.~,~ 1 + o0 1 ,.~ o ( M D ) P 0 R I) E N o ... 3.0 7 ;3, 09 0~80 : :L9:~3 3,01 ~:~3 0 ~05 18~8 3 ~ 15 .4~0 0, :35 27 : 0°02 5 0, O+ 04 S ,9 0 0 · 02 26 o 2 15o6 0 o 05 17 o 9 9o61 7°3 1,81 25°2 99° 25°9 < 0 o 01 0 o 8 0 + 05 22 o -4 58, 23 ~ 0 24,4 i ~09 16o6 0 · 58 15 · 4 0~58 15,2 0~98 16,,7 i o 14 18 ~ 0 4°85 20°7 26, 22,8 5"7° 28,0 F' L.. U ]: I) S A T S · 0 t L W 'l" R 89 ° 8 92'+ 1 90°6 89+ 2 '72~0 · . ~, .,:~ ~, ~)6 i ~ '2 8~.. ~9 3 ~ 04 0 ~ 8 93 ~ 6 '~70 16 'P 66~2 3 ~ 12 ;L~ 0 91 ~ 5 2~ 80 :i. 2~4 60, 4 2,69 12,1 53~:L 3, :t. 5 2,6 86,2 2,78 :1.3+3 61,6 2,74 15+9 65+3 3,05 0,8 92,1 2,69 11,9 70,5 2+6~ !-4+7 62°3 ':2 o 60 20,1 50 + 7 2,62 i ~5 75~9 2~62 5~3 73~2 2~62 3~7 76~3 2,62 I °2 78~6 2,6i 8~S 63~4 2~62 8ol 64~3 2o61 13o8 58,4 2,63 :~.7~ 7 ,..1 ~9 'P~67 1~)~4 57 8 2<.62 15,4 56,0 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made· The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no' warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. M C.I B i L. 0 i L. C 0 F;; P 0 R A T i 0 i".~ J":;UJ::'ARUJ":..' i'd i::' :jJ: :L CORE LABO'RATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE ~i~A C 0 R iii: A N A I... Y S I S R Ii!: S U L.. T S t) E A N'"' S ]"A R K A MA L.. Y S I S S A M P L.. ii!: i) ii!: F' "f' l"i F- E:. J".. M E "' :'~ ~.-~Ii ]: L. ]: TY (H.O) J" L) I,',:GRAIN F:'L..U I t) NUMBER F'EET MAX ]: i~'! U i"J 90.0E: E~ V !i!: I:;.: 'Y :[ CAL Z DEN o OI'L. W]"R I) E SCF;~' I F:'T I ON ..o ........................... o ............................................................................................... . .... ......................................................... 59 iii :349' 00 160 9, <;' 5 ".' ":' "'! ,:.. 1 o i : . 16: · 1 5607 s m m e · - ~,. ~ ~ (3 ...... 60 8:350 o 0 :3 o 12.. :L ~.~ .~..? '7. .1. 7 o 8 .,::"~ o ::~',., ":'~. 6 o B,~,.~i,0 1,"z8 0o77' 16 ":; ') 2 69 '7 ... , ....... o ~..~ .. '..7 ~. :.'~ o .. S ~.".~ III e 62 ,..-q ,.,"~ ,..'::~ .~-.. '') o (). i ,, 60 0 o 75 .1. ,,5 ..~ q:', ,,:."-~ o 61..~,.') ,, 8 ? 2 o 9 s m m e 6 J ' 8 :.':.~ '::;'~ 0 0 11 0 o 42 '7,4 "'~ 9'::; 5 o 1 6 ? o 9 s .~ m e ~ v,::. i d ......... ~' ~ '"' 6 9,7 ,,., ~:- .~ ,.:, ,~.. . ,r:. ,.., 8 ::555 .:. 0 4 .:. 71 I 0 ,....,-.. 18 o 1 '::' o 6 .1. 8 o 9 63 · 9 s .:.~ n'~ e 66 '~ ..... "-:~ ~ 0 0 L.. 87 180 ":' 8 ,b .... ~.., 0 9 ,,,,:.":. o, .,,. 2 ,.. 6 .1. 1 .,..'::' o I 5906 m m m e ............ ,":' o 2 67 8".'I 5 '700 4093 I .~. 07 1806 ':) 06 .,-.. 11 62~ 0 s m m e 68 835800 6095 2 .:. 6 ...... 9 .1. 909 '::' 062 1.4:09 '::,; ,..,'::' ,.....'::; ~..~ .~.~ m e 69 8 L-'~ 59 .:. 0 50 '::; 7 19 · 9 :'.' 062 1205 ':: .... . ....... ,,:. ,..~ :.7 ° (~, S ~B J¥~ e 70 Iii 360 ° 0 140 .L ~.., 0 2000 "::' o 6 .1. 12 ,, ',:5 '::"::' 71 8361 .:.. 0 14 ,:. 120 21 o 3 9 o 62 1 '::' 4 ...... ., ,, ,.. 40 9 s ..-'~ m e '? 2 8:56200 00 () 2 < 0001 i 08 S 006 0 · :.'5 96 · 9 s m m e g v s i d '7~. 8'36:500 7 · 94 6067 2005 2° 62 1704 50o 3 smme "7 =' ":i ........ , ,J 8 S 6 ,.. 00 '202 ~'-. i .., :38 .1. ':.70 ":i 2 · 62 902 66 · '2 s m m e 76 '"'"' '"' ' 0 5060 180.1. ,, 6 .1. :L 9 6 S 00 s ~ m e o,~,.~ o <. i .:. 99 2 00 . 7'7 8:367 .:. 0 :3059 15 ° 15 ° 4 206 .1. 5 o 0 76 ° 4 s '7. 8 R_ ,"~ ....... 6800 0095 ! ,..'::; o 3 2. ° 60 2 .,. .,'::' .... '78 .:. .,..? s e. m e "79 8369 ,... 0 i .., '-'..:.:'6 0063 .!. 4 o 7 2 o 60. :,305 78 o .4 s. mme 80 83'7000 0061 8000 1¥ 04 2 °59 303 7606 smme 8 :L 8 S '7100 0002 0 ° 45 2. ° 2 2 ° 98 2 ,-. 8 9409 s ~.,~ m e .~ v s i d 8 ') 8 S ':-:" ') 0 .".', .fi 05 c.., 1508 ":' 76 .:. ',..'~ ~::. m m e ............ .,,. 061 2 · '2 ... R,., S 8:3 ",.:' :300. .1. ,, ":', ,.,'::; 0078 :t. ,"'~,, · "', .,..'::' 0 -49. 906 '7..,..'::' o 8 s m m e; v c: ~,.) v l':.', 84 837,.'-~ ° 0 3 .., 72 I ° 88 .1. '7 ° 8 2063 .1. 4 ,, !' 67 85 8:3':~5, ..00 00 '.':)S ...... 0°:38 1:L00 .,_0982 6°:.'5 6:309. s-~:me; ~-; id_. 86 8:37600 '::; <:29 968 1 ".' ') ':) 6 () :L '::i 79 ') ,.. 0 ....... e , 0 ........ 0 .. 0 8".' .....8:377 <. 0 :.ii; 0 .a4 i 010 160 i .,:-.'~ 059. 506 77 0 c.' s m m e 88 8:37800 7 ,, 28 I 060 .!. 6 ,..1. ',2060 :L 02 81 ,, 9 s .~ m e These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. MObiL. OIL CORPORATIOiq KUPAh~UI,, MP:iI: 1 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 4A 0 A T E : 10-J U N E"-.81 F:' I L.. E: N (1.1 ~ B F .... ~- 671 FORMA'i"I ON ~z ANAL. YSTS ,~ WSF:', 'T'L.S C'.0RL:i: ANAL..YSIS F;:ESLtL..TS ~0 E A N'"' S T A R K A N A L Y S I S S A M F:' L.. E :[) E F:'"f' i"l P E R M E A B I L.. ! T Y ( M ~) ) P 0 R G RA I N F:' t... U 1.0 S A T S o "':~ ...... ' .... 9, ..... ' · i'~l, jM.~'i l:.I"~ FE:ET NAY: i HUH 90 ])E:G VERT i CAL. :~ [~EN, 0 :[ L WTR ].~E: .... (.,t~ I F'T ! ON 89 8~79., 0 6, 90 8 ~ 80,0 6 ~ 10 1 = ~ 96 17, 6 · ~ '7'.2,8 s ~T~ e 91 8:581,0 '38, 2,14 I ::~ '2, ..~C .L :~, 1 6 S, 7 s ~ ~T~ e ~':~ 8:38 ~:~, 0 26 :. .,,..~ ~ 18,. 9 .,.. 60 6 84 ~ 1 s ~:'~: e , '=' 2 ,. ~59 0 7 97 8:387,0 0, ~ 7 0,14 11 · 1 2 · 159 0,6 96, :~ s ;~ m e 98 8 ~ 88 · 0 0, ~ 0 0,1 ~5 11,0 :2,60 0,6 97,4 ~ ~ m e 99 8:~89,0 0,4[~ 0,17 11,5 2,60 0, 6: 94,9 s~me 100 8S90,0 0,66 0,07 11,0 2 ~ 60 0 ~ 6 94,2 s~me 101 8 :~ 91,0. 0,68 0. ,14 1 ~.":~, 8 ;~ ~ 60 0 , ,..,'::' 88 ,7 s ~ rt~ e 102 8 {~ 92,0 0,79 0,16 12,8 2,6 ~ 0,5; 90, ~; s ~T~ e 10:3 8 :~ 9 :~, 0 2,20 0, :L 4 :L 8,6 2,64 8,0 74, ~ E, S ~ V 'f' "" tTi ~ P ~:' n c: ~ ~' b i n e 1 s 104 8:~94 ~ 0 6,26 I ~5;8 :t. 8~ I 2~64 9,6 76,0 s~me 1015 8:59~5,0 8,24 :5, :t :t.19,6 2,68 :L1,[5 66,1 s~me 107 8S97,0 6, ~:~;0 8, S9 22,9 :~, 64 :1. 1, :L ~:~8,8 s~me 108 8 S 98 ,. 0 0 ,. S 1 0,04 1 S, 1 2 ~ 66 I, 0 96, ~; s s; v f' .-'f' ~ ~, s :i. d 109 8S99,0 0~S5; 0,07 12~ i 2~66 0,4 94~8 s~me 110 8400,0 18 ,. 0 ,. 6 ~; 19,0 2 ,. 6 ~ 8 · 8 71, i s s; v'f'- ~ ~ ~' ~' n c~ ~ ~' b i n e 1 s 11 i 8401 ~ 0 0,90 0 ,, 22 15; · 4 2 ~ 6 ~:) 4 ~ 2 87, ~:~:; s ~ m e; c c~ ~' b. i n e t s 112 8402,0 i ,75; 0,S8 16,6 2,66 2,7 85,,7 ss;v'f'-c~x~' ~:~].~..~c~ :i. 1~ 840S.~ 0 S,,2S I ,26 20,S 2,68 8~2 67,6 s~e 114 8404,.0 2,,S0 0,5;1 18,7 2,71 5,0 76,7 s~me 11 ~) 840,~.':~, 0 6 ,. 14 i ,. 64 19,9 2 ~. 68 S, .~. © 81 · '~', s ~e 116 8406,0 0~78 0,S9 17~4 2,76 0,4 94~ 1:t. 7 8407,0 7 ~. 3;5) 0,S6 :t. 8 ~. ~;2,77 0,S 9S,[5 s~me; v~ 1 ~..~e 118 8408 ,, 0 0 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions, expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. M 0 B I L.. 01 L. C 0 R F:'O R A T I 0 N i'{ UP A J:;.: U K J"'J P -'JJ: i CORE LABORATORIES, INC. Petroleum Reservoir Engineering F:'AGE 5A .'0 A'T'E : 10........1 LiN li!].... 81 F' I L.. E N 0 ~ Bi:: ..... 3-... 671 F' 0 R M A T i 0 N ,~ A N A I... Y o S ,..~ T ~ W S F:', 't" 1......~':" C 0 R E ~-~ N ~-~ L. ¥ .:: .... S 1'.. I ...... U t... I o D E A N.... S TA R K A !'4 A L.. Y S I S P E F;,' H E A B t L. I T Y ( H t) ) i'- U F,, [;~ R A 1 N F:' L.. U i .'0 S A T o 0 H A X I M U M 90 D E G V E R "f' I C A L 7,; D E N, 0 t L. W 1' R D E S C: R I P T i 0 N 0 o 03 0001 11 ° 5 S:,09 90 I 79 ° 1 i 020 00::61 1209 2.:0 '78 '20 5' 8 801 s ~) m e S ~. 44 0069 ':>0 .... 4 '), 99 2,.2 E.',o 04 se. me .,'::' .... ~. 00 I .... 4'"'.,.= .,..."~' .L' .:. ~ .,..9 ,, 94 0° 6= 880 I s ;.~ m e , ~ r" · ,:.':, ° 0 S .E) IT~ e 00 (, ::., 0 ,. 02 12° 1 3001 6,2 ':;'"" 002 S 8 · 4 2,. 98 I 0 5 93 o 2 s ~ m e These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineerin'g DALLAS, TEXAS C.~OF~:E ~..~NAL¥,:.I,.~ Ri:.::POI:~T FOF;: K~JF:'ARUK MP:lt:.l. K LI F:'A f;C U K F:' (] Ci'L. NOF;~TH ,:.,L..OF"E, AI...~:~Si'~r:./ These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (ali errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. M 0 B I L. 01 L. C 0 R F:' 0 R A T I 0 N J':: U F:' A R i...l K I'tF:' :t!: 1 ItUPARLJK F'OOL. N 0 R't" l-'i S L 0 P E, A L. A S i'{ A CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TIKXAS !)A'T'E ~ F O R H A T' I O N ,~ I) R L..G o F L.. LJ I t) ~ I... 0 C (.-1 'tr' I 0 N ~ 0 2 '--' ,.J U N E "" 81 C: 0 R E: A N A L.. Y S I S R t!i: S LJL 'l" S ,'.' ',c' S i) E A N'"' S T A R K ~-~ ix! A L l ,:.' I F:'A G E 1 A F:' I I... Iii: N 0 : B F ..... S"" 671 ANAt...YSTS : WSP, Tt...S L..ABORATORY: ANL, HUR~4LE: S A H F:' t... iii: .'0 E F:' T i"1 N U M B E R F' E E T' P E R M E A B I L.. ! '1" Y ( M :0 ) F' OR M A X I H LJM q~ 0 I) E G L.E. R~ 1 C A L Z P e '~"'f'o ¥, m e d o n s :L d e w m ! :L c: o T, e s t:.. R~4 .t. N t" I...I.J 1 I. ,.. A ] ,.~ · D E N o 01 L. W T R D E S C R I F:' T I 0 N · "~ 2, "~ i 40 .... C' 500 4 :L .,... '''~ A 0 3 ,:)o 6 67 z:, 7,7 4800 s s; 'f'"" o s~J ~' ':~ .461 S .:. 0 0, ''~ ~.. ~.. ~. 1 16 ~ :L ':~ ~ 6 9 0,0 9 6 ~ 0 s 1 t s t. S ,~ , o' 2 8 ~ 9 ':~ · 6 9 J. 8 ~ 8 7 0,8 s ~ v f"--m ~ 4 ~) .~.. 0 ,, 0 28 o ...... s 4 46:~0 o 0 54 ~ =43 ~ 6 2,68 9 ~ 6 78 ,, 4 s~me 5 46'35,0 41 · S30L:. 2,67 8,4 77, S s ~n'~e 6 4641,0 :5 S ,. :5 t, 9 ":' 67 ' ':~ 2 .!. ~: ~ 2 7:5, $ m m e 7 4650,0 10, 29,7 2 ~ 70 14,1 77 ,'7 s s; v 1~ .... i~ ,:~ ~' 8 4655,0 16 ~. S 0,8 '2 ~ 69 ]. S, 5 74,4 s m m e 9 4660,0 18, :5006 2,69 9 o 2 75 ~ 8 s ~ m e 10 4665 ~ 0 1 D, 2 S, 8 2,68 7,6 80 · 5 s s; v f'-.. o ~J ~' s h u 11 4711,0 1o49 26,2 2,70 4,1 84,2 ss;vf' ..... ~'~ sh~:~ 12 4714 ~ 0 11 '2 o S 4,4 2,68 19,5 70,6 s s; f~-. m sJ v :L S 4718,0 97 o :53, S 2 · ~,.~ ]. 6,7 71 · 8 s ~ m e 14 4725 ~ 0. ,...,= ,'::i ":' :52,9 ~_,'~ 69 14 ~ I 73,6 s ~ m e 15 47:50~0 .4'2, S206 2,69 17,5 69,4 smme 16 47 S 5 · 0 S 4 .~ S 2.. ,, 4 ~.o ~ 70 ]. 5 ~ 4 -~, 1 ~ 8 s m m e 17 4741,0 :38,, S2~0 '2,69 20~8 66~7 smme 18 4 '7, 4 ,..~:~ ~ 0 ]. 9, S 1 ~ 0 .~':~ ~ 70 1 .,.~ · 8 74 04 s m m e; s h ~ 19 4750 ~ 0 i ...... ':~ ~ 290 :~ ':~, 69 11 · 4 77 ,, i s ~ m e; ~- ~ u 20 4 z:, 5 q 00 1 ~' , S 0 ~ 6 '~ .. .:~ ~. m ~.. ....... ., .~.,. 67 11 ~ 2 7109 = n · -.~ 21 4 '7 ~ 000 660 '~') ,. 9 ':~ ~/, 8 1 © '~ ' ............... ,,.., .~. 7S~3 ss ~ f'-mS~T' ':~ ':~ 4800 .:. 0 7,55 ': ~:; 8 ~ 70 '~ 9 8 ]. ~ 6 S S ;~.' +'-" f' ~ ~' S h ~ 24 4976,.0 1 i7~ S308 2 ~68 9 ~ :L 76 ~ 9 smme These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. M 0 B t L. Cl I L. C: 0 R P 0 F.: A T ICl N t!L.JF:'ARUK MI::':II: ]. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS D A 'l" E : u .,.;.-" ,.J U N E"'-8 ]. I::' 0 R H A T I 0 N : C 0 R E A N A 1... Y S I S R Iii] S LJL.. T S !) E A N---S '!' A R K A N A L.. Y S I S F:'AG["' 2A F:' I L.. iii] N 0 : B F: ..... S'"' 671 ANAL. YS'I"S : WSF:'~ 'FL..S S A M J::' L.. E l) E J::' T J"J iN LJ H B E Ri::' E E 'i- 25 8415 o 0 26 8578 ,:. 0 2'7 8582 o 0 i::' E R H Iii: A B I t... I T Y ( M I) ) I::' OR G F;: A I N F:' L.. U I I) S A T S ~ i"i A X I H U f'i 9 0 ]0 Ii!: G V E R T I C A L. % D E N ,. O I L.. El T R · 4 7 ,. 21 · "', : ~. ,:~.."~ q 7 10 o '7. 7 4 ~ .,..9 ,:', ......... ,:'~, ,,.=~ ,..~:; o ,~ ~..:~ .,:. 6 ,:.~ : J. 9,0 68 ~ 9 12 o 22 o6 2 o67 :!. 1 o0 72 o 9 i.J E ,:~ (., I',, .[ F:' T I 0 N ~!~S ~ V'I"'"-~Y~.R~ T' , These analyses, opiriions or interpretations are based on observations and materials su'pplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions , expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. KUPARUK 28243 - MP ~ 5-5/6 5-8 5-9 5-10 5-11 5-12 This well was drilled by Brinkerhoff using Rotary equipment. All depth measurements refer to the Kelly Bushing assumed to be 9~-' above the concrete mat. History of Drilling a Kuparuk River Zone Well 16" casing was cemented at 80' as a conductor prior to moving in rotary equipment. Drilling to 1000' A 13 3/4" hole was spudded 5/5/81 at 9'30 a.m. and drilled 650'. A 13 3/4" hole was drilled from 650'/1000'. Directionally Drilling to 2946' A 13 3/4" hole was directionally drilled from 1000'/2946'. During the course of drilling, surveys were taken, of which there is a separate report attached to this history. Logging Schlumberger ran DIL and Sonic log from 1800'/80'. Circulate and condition hole. Condition hole for casing. Tag fill at 1900'. Ream from 1900'/1960'. Clean out to 2946'. Landing and Cementing 10 3/4" Casing at 2930' Ran 73 joints of 10 3/4" 45.5# K-55 casing totaling 2904' in- cluding float shoe ai~ 2930', float collar at 2888', and 6 central- izers. Casing was cemented with 50 Bbls. of water ahead of 2300 sax of Dowell Arcticset II with .2% D-46, displaced with water and mud. Completed cementing operation at 10:00 p.m. There were good cement returns to the surface. Install BOPE. Test BOPE to 2500 psi O.K. Clean out cement, float and shoe to 2956' using 8 3/4" bit Ran leak off test at 2956- 900 psi, equalized to 700 psi, total 2½ bbls. Drilling to 3440" An 8 3/4" hole was drilled 'from 2956'/3440'. Survey at 3108' and 3327'. Running gyro survey. R E C E IV E D AUG 1 0 1981 Alaska Oil & Gas Cons. Commission bnr, hnrnnn 5-13 5-13/17 5-17 5-17/19 5-19/22 5-23 5-23/24 5-24/25 5-25 5-26 5-27 5-28 Continued' running gyro survey. Drilling to 7975' An 8 3/4" hole was drilled from 3440'/7975' Survey at 3861' 6 ' 4395' 4739' 5242' 5779' 6279' 6595' 7 01' 7482' and 7895' Logging Schlumberger ran DIL- GR from 7972'/2930'. Drilling to 8255' An 8 3/4" hole was drilled from 7975'/8255'. Survey at 8195'. Coring Core //1 8255'/8289' Core //2 8289'/8323' Core (/3 8323'/8333' Core //4 .8333'/8338' Core //5 8339'/8372' Core //6 8373'/8415' Rec'd 34' sh. & sd. Rec'd 24' sh. & sd. Rec'd 10' sh. & sd. Rec'd 6' siltstone Rec'd 34' sil tstone Rec'd 42' sd. & siltstone Ream 8 3/4" hole from 8300'/8415'. Drilling to 8850' T.D. An 8 3/4" hole was drilled from 8415'/8850'. Logging Schlumberger ran DIL and Sonic log from 8832'/2930'. Shot 30 SWS, received 28. Ream from 8810'/8850. Landing and Cementing 7" Casing at 8780' Run 222 joints of 7" 26# K-55 casing totaling 8757', including float shoe at 8780' and float collar at 8739'. Casing was cemented with 20 Bbls. water ahead of 280 sax of class G cement, 3% KCL BWOW, 6% Attapulgite, 2.5% D-59, 1.0% D-65, 0.25% D-13, 0.20% D-46, tailed by 230 sax of class G cement with 3% KCL BWOW, 1.5% D-59, 0.75% D-65, 0.20% D-46, displaced with water and mud. The plug was bumped with 1800 psi. Completed cementing operation at 1:25 p.m. Ran gyro survey from 8700.'/surface. Pumped 100 Bbls. water ahead of 250 sax of Arcticset VI Cement in 7" x 90 3/4" annulus, displaced with 103 Bbls. Arctic pack. RECEIVED AUG 10 1981 Alaska Oil & Gas Cons. Commission Anchorage 5-29 Ran 144 joints of 3½" tubing totaling 4457'. Change over hole fluid to Diesel. Land tubing on donut. The BOPE was remOved. Wellhead installed. Released riO 5/29/81 4:00 a.m. Well suspended pending perforation and completion. RECEIVED AUG 10 1981 Alaska Oil & Gas Cons. Commission Anchorage SURVEY r)~TE: ~Y 2B, lq01 ~UqVEY EN..~INEER:~ OLDE~']U'RG-gOFTE~ REFERENCE '~E.%RING: ~00-00E ~ET~*{O') OF C~L,~,.JLA"PION q~OIU] ?)w CURVATURE VERTI~_~L qECTION ~'ALCUL~TED I,'~ t~ROPOSAL DIRECTIOM OF: '~ 79-00 FE E']~ * * * .~********************************* *Tq~.g qUPVEY Iq C,q~RRCT TO T~E * ***********************--***** LO0.0 200.0 400.0 500.0 5OO.O 700.0 ~00.0 ~gO.O 1~0.0 11) 0.0 1200.0 1309.0 1t00.0 15,.90.0 1700.0 1300.0 1900.0 2000.0 2100.0 5~04 · nEoTg 100. 300. ~00. 500. 700. 800. 900. 100n. 109g. 1199. 129~. l~gq. 14.78. 1597. 1695. 17~. lBg2. 20~6. 00 00 00 O0 0O o 0 71 31 53 ~5 15 q2 67 V E '!'~ T. gECT. 0.~0 9. ~0 O.0:3 0.00 0.00 0.00 O.00 0.00 0.0O 1.78 5.30 11.23 1~.46 31.20 oEV. 0 .DO O.00 9.~0 0. n0 0 .gO 90-0,9 ~ 77-31 O0-00 ~ 77-27 90-00 q 77-25 00-00 q 77-2~ 00-00 ~ 77-.7.2 O.O0 Oq-00 g 77-1't W 0.09 90-00 q 77-05 0.00 '30-00 ~ 77-02 9.00 q0-00 g 77-00 3.14 0g-30 q 73-55 1.53 3.71 5.32 8 .~3 12. ~0 01-15 q 78-59 03-00 S 8'7-01 01-15 q 75- 0~5 0,5-00 g 81-09 0q-15. $ 83-10 45.62 15.8~ lO-00 N .97-25 64.1q 17.79 19-30 g .98-51 ~2.42 13.{4 19-45 N 86-19 101.11 13.87 11-00 -~1 _B7-2.~ 121.95 21.00 13-15 W 94-31 25.25 147.14 16-00 N 81-45 W D-LEG nee lgO O.O0 ~'] 0.00 Z 0.00 ~.00 ~] ..'3.qO E 0.00 0.o0 ~1 0.00 E O.OO 0.O0 ~ O.00 E O.00 0.00 w O.oO ~ 0.00 0.00 ~,~ O.O0 g 0.00 0.00 W O.00 g 0.00 0.00 [~ 0.00 E 9.00 0.00 N 9.00 E 0.00 0.12 3 0.42 ~,~ 0.00 0.~3 3 1.99 !iq 0.75 9.93 S 5.58 W 1.'77 1.gl q ll.81 .q 1.45 3.75 9 29.55 W 1.83 5.-~4 S 32.84 W 2.26 6 . 03 S 48.67 5.45 ~ 66.45 4.87 S ..94.87 3.6~ $ 103.71 2.16 S 121.66 0.86'M 1.~9.72 ':4 2.30 0.56 0.53 0.32 2.33 2.84 ?:4AY '25, 19'31 qTATIOW 9IqPL.RCEMEN DIS" ~' '". ~N I'A I.....E BE4~- G . .,. JOB NUMBER: ME~. VERT. VERT. r)E .P TM DEPTH SECT . 2200 2300 2500 2700 299 0 3000 31'] 0 !400 3700 3~99 3990 .~900 4200 COrJ 'R~E OEV. .0 21Bl.58 173.19 31.10 .0 2274'89 214.37 . 0 2356.13 255.15 40.87 .0 245'5.42 300.11 45.01 .0 2543.51 347.43 %7.33 .0 2,529.66 393.18 50.75 .0 2713.04 453.35 55.1g .0 2792.99 513.52 .0 2969. ~9 577.79 .0 2943.80 6~4.7.0 55.91 .0 3,915.58 71.'~. 31 . ,9 30~4.57 78'5. . 0 3150.50 861.83 .9 321~.78 93~.3q .0 32'79.95 .o, .... .o SCIENTIFI'~,~ 9RILLI~'~ CONTROLS 1111 E%ST 90T~ ANC'~OR.AGE, AL~SKA I M RI'J~1 9 U RVE Y BY 13 M ,.r) M COO'ROI MATES LAT ITU DE OEPA RTURE 20-15 g 82-36 W 5.10 22-15 .,g82-17 ~ 9.88 2'5-00 g 82-45 W 15.18 27-30 ~ {]0-38 W 21.$9 29-00 N 79-45 W 29.74 3~-00 '~ 78-11 W ]9.45 35-00 ~ 77-39 "; 51.00 ]~-00 ~ 78-53 W 63.22 41-00 ~g 78-19 g 75.92 4]-00 .g 7g-l~ W 69.62 :'%5'-15 .?~ 79-13 '~'; 133. '72.39 47-39 ",~ 99-1% ~;~ 115. 75.1'3 59-00 ~ '31-07) W 123. 75.50 SO-Oq 'q ~1-21 /7 15[. '75.59 75.$q 7:S. 50 7,5.50 75.50 .0 3555.0'5 l.~73..93 50-00 '~ B1-2.'5 ,4 153. 5~-00 ',] 91-57 ~,. 17~. 53-00 "~ 31-36 i~ 195. 53-00 '~ 32-~7 '7 195. 5q-O0 :~ "]1-05 W 207. 80-51 ,~ 219. 180 ;53 i4 216.~6 W 2 55.9,.q W 301.51 W 34~.15 W ]q7.q6 451.93 519.84 573.85 5]9.37 O-LEG PER 100 4.26 2.00 3.75 1.78 1.56 3.10 3.01 4.07 2.03 2.00 03 g 707.55 ~ 2.35 93 g 773.87 ~ 2.37 14 N '35~.05 i~ 2.59 IR ~ g2~.72 W 3.24' qq ~ 100%.%0 .~ 3.40 5'3 ~I l{53.75 W "). 05 3.27 O. ",0 !]. '7 q 0.53 / PAGE 2 8,. 1981 S TATI ON 'O IgP LAC EMEN9 DI STAMCE BE A R! NG ) ~E~TH nEgTq ~ECT. 1303.q 379.9.q4 1549.97 75.l. 3 4400.0 37q~.45 1625.2'5 7~5.3! %500.9 ]qS~.~Q 1792.7[ 7~.~5 4.590.9 3922.50 1779.85 77. [~ 4709..9 ~q85.91 lq57.15 77.]3 1q33.~ 4350.95 1933.8q 7.'5.7'4 4930.9 {114.33 23l"].49 75.$9 ~3.90.0 .417~.5l 2937.0q 75.~0 5139.0 5200.0 4307.34 22%0.11 73. 53q0.0 %372.~5 2315.04 5!00.0 ~ 43..q. '35 2391. 5l 5509....0 45.04.15 2 ~-55.5'1 5500.0 ~570.q0 25~0.99 5700.0 4539.30 2~1~.85 , .- . o. v4S:;'3'C ' .7': 59]9.0 ~775,O2:~. 5990.0 4q{4.32 · 2q~']. 73 61')0. q 491.4.~ I ",29'34.00 ~q0. o 49~6.{3 297~..33 75.93 73.47 75.9{ 74. -~ 5 73.87 73.23 72.5 .q. 72.0q 7]. .32 I >~"] O 4q-45 7'] '{l-03 :q 231.52 'si 1533.97 q. ~9-'-~5 '{ 80-07 'q 24'$.}~ 59-00 ~1 .30-17 "~ 257.05 ~1 1534.51 W 5t-09 ,4 79-57 ,'.1. 270.33 30-15 '! 7~-3.3 ~q 2B4.0:5 ~,I 1335.5q W 33-00 q 79-27 ";/ 29':3.05 t.~ 1912.15 50-0.3 q 79- 35 :iq 311. q~ ~"~ 19~7.~3 50-00 q 7'9~3'7 7 325.'7"~ ~1 2052.83 50-09 q 30-05 ":,q 339.2:3 q 2133.23 ~q-45 q 79-32 4 35'2. 80 ~ 22~3.~9 iq-O0 q 79-3'5 cq 3~5.55 ~.1 2233.].i t':)-O0 "~ 79-ll ~.'I 330.il N 2352.32 43-15 ~,~ 79-29 :'q 39i.33 ~I 2,%35.05 .~q-O0 r'~ '30-15 "q {07.~2 q 2599.35 '17-15 '.,1 30-2q ,q ~13.87 '~ 2532.18 47-00 ',~ '31-07 .'~ ~31.53 'q 2'554.53 l~5-15 ~ 3~-~'3 '.q ~42.55 ~7 2725.37 ,~, ~5-03 ~ 3~-33 ,q ~53.37 "~ 2737.59 {-'I-33 '1 31-l'~ "'q {74.55 q 2937.75 .q D-LEG PER 10 0 0.2B '3 . 57 0.28 1.03 0.81 0.26 3.12 3.02 3.35 0.50 3.25 3.3,2 :3.78 '3.5 ~, · 3.75 3.53 · 3.95 :3.27 1.05 "). 53 , 1931 DIGT~NCE BE.~RING ) 5330.0 5357.37 30%~4.7q 59.~,5 43-30 ',~ 5{3-35 q ,~',3-3.03 q 39.q5.53 ;q 1.59 vIE%, S. VEPT. VE lit. q .'., ~T. 5{00.0 512q.qg 3ll2.3q ~500.0 5202.74 31q0.72 "5500.0 527~5.17 32~3.33 $700.0 33'1g. qO 3315.7l Gq00.0 5%22.73 33B.I. C15 Sqf) q.0 5'%93.91 7000.0 71'39..0 5533.15 72'30.0 5'70 3..0q 73.',00. Q 5773.95 3 519. '~59l. O0 c,~rj R gm,, SCIE?.<I'P!'FI?, 9RILLIN3 20',X]TROLS T xl' R[1>I ~ qY ~EnlRI ~ ~' r, ~T .T'P u,.r)E 53.8,~1 ,t3-39 ~,] '.'32-35 W ,%92.5'3 5'!.52 ,%3-00 ~] '33-%5 <q 500.82 ~,1 57.$8 ¢2-39 M ~3-3l ;q 50q.3~ '57.5~ ~2-30 ~ '33"58 '~,q 5~5.70 ~.52 ,14-00 '.~ 32-12 ':4 523.'3'5 70.2~', .4S-].5 ,q 4'5-{3 W '353,75 ~ 3~,~7.?]. 72.f)n .~5-15 ~ 32-03 <,~ 595.3! ~ 35:{2.:5q 71.,1~3 45-00 W q9-53 '4 50%.22 '~ 3513.38 70.55 45-09 ~3 33.1-31 70.25 't {-15 ~] 39-11 ;59.3l %3-30 ',] 79-23 53.~2 13-00 "1 77-~7 57.55 ~2-00 '~ 75-19 5'5. ?3 {l-00 ~ 75-?3 55.61 %l-00 q 7~-53 '~ 7L2.52 ~ ~lS?.~O 55.51 %1-00 "~ 59-23 S%.~4 ~0-00 '] 57-?5 ,53.q~ 39-33 "1 ~-25 "~ 7~?.~l '.l %332. ,r). -L ..,:,..,., 0.,95 0.53 .3.31 1.93 0.27 1..17 3.55 ':3.7ct '3. O3 1.29 1. % 1 1_.18 .3.33 3.54 1 l.~l 1931 3TA'T'I O'q iD I '31 A~l C E BE ~,RI ) V~RT. ,,OEV. TqRU>q q.U q,'Vr~ v ~Y n '4 0 q · qOOR O I .~',1 AT g $ O-LEG 'PER 10 1991 ~ T .A T I :.3 N OI ~T ) 0 ~ BE A.R I NG 8300.0 H5t3.39 ~ '~C)l. 85 3400.0 gSql. 51 8599.0 5570. q5 8500.0 5750.05 .1709.0 Sq2q.39 %521.31 4590.25 ~3q.75 . 3q- 30 "] 5 732.51 ~ 4332.12 W 80q. 22 q '~393.5q '~7 935.38 q 4443.55 <~ '~62.2~ q 4493.37 <q qqO.91 q 4552.50 L~CE'4E~T ~'r T~I'E ~EPT[-I ~q.75 ~'~'r ~:P ~1 79-56 1.93 1.8~ 0.q5 0. '7'5 1.47 ~fR~qC').r~T~ OIR~CPTO']RL 5104 '4RY 28, lqB1 VMRTIC%L '~ECTION ~';%LCUL~TEn,.. t"l ~ 400.0 11]0.0 1200.0 1399.0 1500.0 1500.0 1700. O 1t00.0 1930.0 2000.n nTH lnq. O0 500. '~. O ~qn. O,q 7no. q'9 qg.n .OO 1non. "~0 lrlqq, c~ 1.1qn.~l 12gn.71 1498.53 1597,25 16g'5.66 17q~. g5 lqg2.15 lg]9.~2 VE ~'P. O.nO O.OO 0.00 0.00 O.qO 1.7R 5.10 11.23 lq.46 31.20 t5.62 ~4.1~ 12.42 lO1.1l 121. g6 O .9.q ~ .00 9 ..~0 ,] . a9 O .O0 :). :) 0 0. '30 1.53 3.71 5.12 8 12.40 15.85 17.79 13.44 !1.87 21.00 I' :! "{ [.!",] 2 ~.1 R V E Y ~Y ~.9I',J~ OTM "~oV~ ~: , _~% .PT! RE 9q-O9 q 77-3]. 9O-OO q 77-77 q0-0q q 77-25 q]-O') q 77-2~ .q 9-00 g 77-22 3'3-00 q 77-1.'t W 30-0,9 q 7'7-05 ~q 30-03 q 77-02 ~/ qO-O0 q 77-00 ':.q 09-30 q 73-55 :.~ 01-15 q 78-59 q3-O0 3 2'7-01 91-15 q 75-03 ':~ q5-O0 ~ fll-Oq 0 q-15. ~ 93-19 19-00 ~ 37-25 10-30 g 38-51 "~ 19-45 g ~6-19 11-00 w q7-2~ 13-15 N <t4-31 .00 ~,] ,3.00 ~. O.Oq .OO w 0.00 ~ O.O0 .<10 ~1 :l.qO E q.00 ,3.00 '] 9.90 Z 9.00 o. O0 ..',1 9.00 ~ 0.00 O.O0 ,~I O.O0 ~ 9.00 0.00 N O.9O E O.O0 0.12 '3 0.42 :q 0.00 0.~3 ~ 1.99 ':q 0.7.5 9.03 S 5.5B W 1.'77 1.91 q ll.fll q 1.45 3.'75 S 29.55 W 1.83 5..~4 S 32.84 <.q 2.26 MAY '28, 1031 6.03 .q 4.9.67 .q, 2.30 5.45 q 66.45 W 0.56 4.57 S 94.87 W 0.53 3.${ S 103.71 W 0.32 2.16 S 12~.66 W 2.33 r) I $ T.~'] 2 g n~ ~ R 2130.0 2086.57 1{7.14 25.25 l$-00 ~ 81-45 iq 0.86 ,q 1,19.72 ',; 2.84 5404. M2~S. VER?. VERT, r)EP T~Y nEPTq SECT. r)2v. 2200,0 2181,58 172, lq 3l, 10 239,9,0 2274,.Bq 21%,37 ]6,21 2%09.0 2356.13 255.15 40.87 2590.0 2455.42 300.11 45.01 2500.0 2543.51 347.%3 %7.33 27,00.0 2'529.66 393.1,q 50.75 28,00.0 2713.94 453.35 55.lg 2gqq.0 27':)2.9q 5l].-52 3!').17 3000.0 2qfiq. ~%9 577.79 3130.0 29{3.80 ~,'1%. 70 '55.31 3!09.0 7915.5'3 71.%.31 3380.0 30q,l. 57 1400.0 315,9.59 .-'3-.51.83 3579.0 321~.78 9.19.3o 3.500.0 3279.95 101'1.9'1 3700.0 3343'~ )3 33'39.0 3 i07,.61~'''' 115:~. qO 3~}'.) 9.0 3471, ?s?S.l. 7. 1.121. oo_ '72. 75.13 73.5.1 75. '5 7 5.59 75.5~) 75. ~q '7 ~. ~ ,] 4200.0 3555.93 l~73.83 75.~1 SCIENTIFIC ORILLIq3 '3ONT~OLS llll E%gT B0'P~1 ¥{CqORIGE, ~Ln~q~A l N RU~'I .~r.J RVEY L~TITrJr)E OEP%RTURE 29-15 ,'q82-36 W 5.10 'q 22-15 '~]82-17 .q 9.86 ~ 25-0C) ,~ 92-45 W 15.1S ~ 27-30 ,~{80-38 W 21.,5'3 ~'{ 29-00 '~ 79-45 W 29.74 ~I 32-00 ~ 78-11 W 39.45 35-00 %1 77-30 'q 51.00 .1~-00 q 79-53 W 63.22 -%1-00 "] 78-19 ",~ 75. -92 tl-O0 "'1 7~-15 ':,q 37.~q 15-15 ,.'~ 79-13 iq 1'33.0:1 · 17-3,.9 ',I :3"3-1-% ,q 115. '31 59-0n 4 '3l-0') '~ 123.L~ 3}-09 ~''3-09 50-09 $q-O0 '1 ':31-57 q.. 17t.32 5.1-00 '1 31-36 ~q 1'.85.13 3]-00 'q 32-87 '1 195.32 33-00 '] "31-05 <1 2.97.~l C,q-]q "t 8'.3-51 4 719.53 180 .' 53 216. i6 255.9~ 301.51 34~.15 397 .c}6 W 45L. ~3 519. $4 <~ 573.35 '4 519.37 707.55 '"4 77].87 V 3 5 'T. 05 ,~ 1]91.-%0 .q 1'33 9.1 i '.I 123l. 73 l 3 '3 ?. 59 1333.37 1'1'53.75 PAGE 2 O-L~G D~R 10 0 4.26 2.00 3.75 1.78 1.56 3.10 3.01 4.07 2.03 2.90 !.35 2.37 2..,59 .1.2'% ,'). 40 .3.05 3.27 3.7-9 STATION DIST¥1CE BEARING 3.53 5{01 {397. fl 3729. q~ 15~q. n7 75.13 4{97.,.q 37~s,. 15 l'~25.23 75.3~ 157,.q. 9 t~5'1. ~q 1772. ~ L 75. ~'5 459~.9 3922.59 1779. ~5 77. L5 4709.q 3~15.91 ].~57.15 77.13 4337.9 4750.05 193]. 8~ '75.74 49]0.9 ~11{.33 231'].49 73.59 53.70.0 II7~.3l 2137.0.3 75.5,3 51]q.q ~2~2.t9 21'53.$3 75.50 52n0. O 4307.3'I 211,3.1I 75. %5 3330.0 S372.'15 2313.01 5%00.9 55"39.0 5700.0 5t3.0.9 5'3')7.q 1775.02'~ ' 27'~.3.72 5qqq.o 434,%. 32 .. 2932.73 6llq.q Iql~.ll 2q'34.00 ~299. q 49~,5.13 ~')7 ~.. 33 75..3') 7 5..",7 75.9% 7!.3~ 73..87 73.23 72.53 7 2.')') 7]..32 '~3'3r). 0 5357.!7 3,3~t.79 T ':t q U'I '3 '] ":' VS Y 5'3-0~ 'q 30-17 '; 257 5[-09 "~ 79-57 ,1. 270 33-15 '~ 7~-33 '.'~ 2'34 33-03 ',]79-27 "~ -33-03 ',!79-35 .'q 3,3-00 'q 79-37 '7 ~'J Oq ~] 37-05 I '3- ,'t $'t 7 3- 32 .la-O9 q 79-35 ',~ ~3-15 ~'! 7'.{)-29 'q '~.q-O0 ~ 33-15 'q 15-15 '1 3l-lq '~ · ~'%-33 ~] 3l-l'q ,7 29-1.95 '1 l-~12.15 W 311. ~1 '] 191 7.'~3 ,.q 325.73 "1 23'32.83 ;q 339.2'-{ ',1 2133.23 'q 352. 8,3 ~I 2213.{3 W 35 ~ 330 107 '{74 .{ 3-10 ",7 83-] 3 ,7 1'3 I .55 "l 22'33.1'1 .{$ ,q 2332.32 .33 '1 .$2 q 25,39.35 .87 '~ 2532. l~3 .5'3 ',1 2554.5) .55 '7 2725.17 .~5 '~ 2331.1~ .55 ~'1 2337.7~ .03 q 3335.33 ~GE 3 £ 1931 'og R 1.0 O 0.23 3.57 ']. 1.03 0.26 ,). 12 '3.0 ? 3.35 0.50 3.75 3.32 3.78 3.5% · '). 75 3.53 ].35 3.2'7 1.05 '). 53 DI '-G'P ¥]CE ) 1.59 V~, ql'. q ~3 CT. 3{5~. q6 35L3.q2 ~ Sql. tip ~Tg2.q2 ?:3.25 72.qq 7t.tq 7]. 53 7190.q 5q~4.91 ~q93.$3 70.54 73'] 0. q 39l~. 98 3~73.3'3 70.2_5 7790.9 5059.90 1911. 17 53.52 7'l]fl. O g13~.63 4979.15 ~7.53 ql]q.q · ,q2oq. q 1300.9 qY 13-39 82-39 ~2-q9 15-09 't 3q-3l 1~-15 r.1 ~q-ll ,~ ~-3q q 77-23 t3-09 "t 77-~7 12-0q 'q 73-19 ~1,~.'1 1.3-00 '] ~7-!~ ~ 7~],%~ ~1 1!7~,7~, ;7 · ';~.q! '3r)-'~r) ',1 ';~-23 '.7 7:37.';t ',1 1312. 12 ,~ q . 53 3.31 1..93 2a, .75 2~.q7 0.27 1.%7 0.3.3 .7 g . q3 .29 l.%1 OI ~T~'ICE BE~RI V~RT. ~EC?, PER 10.0 5513.39 9400,0 .55gl, 51 't.112,35 ~2, ~2 8599.0 ~17'~, ~5 ~521,3l ~. 8'~ 8~OO, 0 ~750.0$ 45~'1.2~ ~l, 95 ~700.0 6820.1~ ~639.75 ,S'1.8~ q 7 ,l q..q 7t2.,51 '~ ~332.1.2 ~'1 37-{5 !':T ~55-05 'q 30~. 22 3'~-00 '~ '~3-3~ ,~ ~52.2'1 37-~q '~ 52-0~ '~ 889,93 'I .149.) .17 '7 ',1 4552.59 '; 1,93 0.~5 9.75 1.47 .. # GR AT L,A D CTIOHAL DRILLING/NC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY MOBIL OIL AL 581 D13 JOB NUMBER Brian Nest NAME DEPTH INTERNAL DATES SURVEY' WAS TAKEN COMPANY 2824~-M,P, #1 WELL NAME KUPARUK .RIV..ER, ALASKA LOCATION , ,En.gineer TITLE 46O FROM 5/~81 FROM · .885O TO DATE 5/2d/81 TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company. ) COMPLETION REPORT FOE GLDD BY FH LINDSEY & ASSOC. MOBIL OIL CO WELL KUP, RIV,282¢3-MP ! CO~--~-O-TER METHOD(RADIUS OF CURVATURE) FIELD METHOD(AVERAGE) ~AGNETIC SINGLE SHOT SURVEY COMPUTER DATE( 5-27-81) SURVEY DATE( 5-04-813 RECORD OF SURVEY TRUE ,~EAS. DRIFT VERTICAL DEP T H ANGL--L-E'- ' DEPT-~ D H SUB DRIFT TOTAL COORDINATES C L 0 5 U R E 5 SEA ................ D[~EC D I STANCE ANGLE DEG, D M S DOG SEVERITY DEG/1OOFT O, O0 .SSUMED VERTICAL TO 460, 460 0 0 460.O0 368,00 N OoOOE 0,00 S 0.O0 W O.O0 S 0 0 0 W 960 0 15 959.99 867.99 N55,00W' 0,93 N 0.48 W 1.04 N 27 29 59 W -I-O-8-z~- -'I--I-5 ....... I'O-~'~-,-9"t~ ....... ~-'-~, 0 OW 0 · 93 N 2 · O0 w 2 · 2 ~ N 65 7 56 W 1180 3 0 1179,91 1087.91 N82.00W 0,11 N 5.38 W 5,39 N 88 43 ~9 W 1275 4 0 1274,73' 1182,73 585.00W 0,27 N 11,17 W 11.17 N 88 36 40 W ~'~7----5-"-'-Z~5 ...... I3-~-6-;'4'~ ...... I2'7~-;-~--0---~3-7~0-W ............... 0"~,-~'-'-~- .......i~'9-0--~- ........... 18 , 92 S 87 19 2 0 W 14.50 7 15 1458,80 1366.80 $84,00W 1553 g 15 1550,83 1458.83 sg0,oow 4 17 590.00W i737 10 15 1732.17 16 O. 2048 13 I5 2036.62 1944.62 N86.00W 2357 23 0 2329.93 2237,93 N84,00W ~ 29 0 2558,12 2466,12 NB2.00W 2-53 S 3.22 5 3.22 5 1.01 S 20.91 N 29,29 W 29,~0 S 85 3 49 W 42.61 W 42,73 S 85 ~0 ~ W 73.77 W 73.8~ S 87 29 ~O W 137804 W 137.05 S 89 3¢ 27 W 232.68 W 232.80 N 88 ll 27 W 343.14 W 343,78 N 86 30 ~5 W 0,000 0.00 0,050 0-63 0-807 2.13 1,827 5-32 I.O55 11-05 1.904 18,46 1-616 28,41 2.157 41.40 0,543 72.09 0-967 134 .)9 3.157 230"~3 2,369 341.57 2896 37 30 2796.24 2704.24 N80,OOW 45,33 N 497,34 W 499,40 N 84 47 30 W 3108 42 0 2959,20 2867,20 N84,00W 64.19 N 631,52 W 634.77 N 84 11 45 W 3327 46 45 3115,69 3023.69 N84,OOW ....... 8'~'~--~ ....... 7-§-3~:7'~--~ ..........787.88 N 84 9 2~ W 3861 49 0 3473,84 3381,84 N86.OOW 114,7~ N ~178.30 W 1183,87 N 84 26 22. W 4395 48 0 3827,68 3735.68 N83.00W 153.03 N 1576.35 W 1583,76 N 84 27 [7 W 4739 49 ~ ...... 4~'~;~ ..... ~'~'~ ....... ~;U~ ........ 1"~-;~i--~ ....... ~'~'~'-~'[~-~ ......... i~i';~"~--8~ 2 29 w 5~42 48 0 ~388.91 ~296.91 NSO,OOW 256.53 N 2202,22 W 2217.01N 83 21. ~9 W 577~ ~6 30 4753.42 4661,42 N78,00W 331,76 N 2589,~8 W 2610,35 N 82 41 53 W 6279 ...... 6 .... ...... ....... ........ 82 5 w 2.99~ ~97*66 2,285 633-08 2-169 785.82 0,472 1180,33 0,362 1579e00 0-576 1836.52 -0-199 2213-24 0.341 2607-~8 0,754 2959 MOBIL WELL KUP,28243 SINGLE SHOT SURVEY 2'7 MAY 8t RECORD OF SURVEY TRUE DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE D M DEG. D M $ DOG LEG SEVERITY SECt{Oh DEG/IOOFT OISi ~JCE 6595 42 0 5341.~3 5249.t~3 N79.00W 432.95 N 3145.~3 W 3175.09 N 82 9 ~ W 0.~25 3172,8[ 7001 45 0 56~5,90 5543.90 NTg,00W 486,28 N ~419~7~ W 3454,14 N 81 54 2~ W 0.7~9 3452,2~ 7895 60 15 6291,90 6199.90 N76,00W 609,11 N 4014,09 W 0060,04 N 81 22 17 W 0,677 4058.8S 8195 39 ~5 6521.71 8~29,.71 NTO,OOW 665,~6 N THE FOLLOWING INFORMATION IS EXTRAPOLATED TO ID ~OTTO~ HOLE CLOSURE 4662.66 FEET AT N 80 0 42 W HE~---A-S-U?-E?-~q-E.~?~U~`A-`Np~"~T-HE-R--~DA'Z6~F~-~--~v'-~"~¥~"E~EN lO0 FEET OF SUB SEA DEPTH, ~".' EASUR ED DEPTH 192 192. 100 0 0 292 292 · 200 0 0 492 492, 400 0 0 TRUE V E-R Ti ~[""~'0~"" MO£'TVD v ER l?! CAL DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 0.00 S 0.00 w O.O0 $ 0.00 W 0.00 $ 0.00 W 0.00 N 0,00 E 592 592. 500 0 0 0.07 N 0,00 792 792. 700 0 0 0.44 F~ 0.14 892 892, 800 0 0 0.72 N 0 ..................... ; ........... ' ............. : _: ........................... ,31 992 992. 900 ' o ............................. 6- ..................... !' (~'" N ...... 0;'~-7 1092 1092. 1000 0 0 0.82 N 2.i6 1192 1t92, 1100 0 0 0,19 N 6,02 0 1 2 1 2 3 . 5 9 11 14 2~ : 29 '40' . 50 51 52 1.40 2.90 B.22 3.22 3.15 2.65 1,65 0.00 2,46 5.81 10.34 21.52 33.64 49.4'6 ~ 66.55 104.97 126,70 150.99 180,96 217.24 259,91 23,63 N 362,19 33.06 N 423,87 57,15 N 573,45 67.36 N 661,75 77'~2 ~' 759"3f'-W 8~.44 N 865.17 98.53 N 973,98 107.78 ~ 1085-'~'29 116.15 N I198,61 125,31N 1312.99 1393 1493 1595 1696 1798 I O0'O 2~.~ ,~ 2105 2210 2316 2536 2650 2768 '' 2891 3019 .3153 ~ 2" 3439 :~5s7 ' -3737 3888 [J 404r~ 1392. 1300 0 1492. 1400 1 159~; ......i566 ........2 1592. 1600 4 1792. 1700 5 1992, 1900 10 2092. 2000 13 2 19'2" 21-~0' i 8 2292. 2200 24 2392, 2300 33 249~.' ' ~6-0 ...... 44 2592, 25C0 58 2692. 2600 76 2792, 2700 98 2892. 2800 127 29~2, 2900 160 3o92'- '3-60~' 2'00 3192. 3100 247 3292, 3200 295 3392. 3300 345 3492. 3400 396 3592. 3500 448 ) ".~OBIL WE~..~ KUP,28243 SINGLE SHOT Sb EY ~-.~.EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 1.00. FEET OF SUB SEA DEPTH, 27 MAY 81 TRUE DEPTH DEPTH SEA DIFFERENCE CORRECT ION TOTAL COORDINATES /4191 3692. 3600 499 51 136.02 N 1425.61 /+341 3792, 3700 5/+9 50 1/+8,24 N 1536,~7 ~4.92 3892, 3800 599 50 162,37 N 1647,99 46~2 3992, 3900 650 51 178,98 N 1759.10 .... .............................. _OAz-- ........ 99_9. ........... !o2 ............................. 4946 ~192, 4100 75~ 52 218,16 N 5097 ~292. ~200 805 5~ 237.7~ N 2095,58 ................ 5_2~9_ ................................ _~}_~z~_ ......... .~39.9 ......... a,%9 ..................................... ~_ ............................... Z_._S!_,.O~_._ ..a ....... a..e_O.~_?.g~._ 5395 ~492. ~00 903 5543 4592, 4500 951 48 297.25 N 2420.61 U ............ ~93~ ............................... ~3_.~_~_ ..... ~9_9 ....... 79~ .................... .~_Z .................................... 3~,~ ~ ~525,~ ~978 ~892, ~800 1086 ~} 359,~8 ~ 2728,91 6118 ~992, ~900 1126 40 377j76 N 2825,97 6393 5192. 5100 1201 37 408.48 N 3011,58 ~528 5292, 5200 1236 35 ~2~. 59 N 3101,5~ .................. -666~-' 5392-; ...... 5300- ....... 1-27I- ...................... 6800 5~92~ 5400 1308. 37 ~59,53 N ~282,12 6939 5592, 5500 1347 39 ~77.98 N 3377.01 7220 5792, 5700 I~28 40 515,5~ N 3570,26 ?358 5892, 5800 ~66 38 533.75 N 3663.92 ~ ......... -7A~5 ............. 59-9-2'; ............ 5~- ..... ~5~'~ .................. ~'? 7630 6092, 6000 1538 35 569.79 ~ 38~4,5~ 7763 6192. 6100 1571 33 5B9. O0 ~ 3930.71 ........ 7'~'5 ....... ~f~'2-; ..... 6-206 ....... 1'6o~ ........ 3'~ ..................... 6-6-9'*-'1i' 'a 401~-.'0-9-'~ 8026 8156 8286 8z~16 8546 8676 8S07 6392. 6300 1634 31 631.39 N 4095.49 6492. 6/+00 1664 30 657,09 N 417/+, 90 6692e 6600 172~ 30 713,80 ~ ~331,2X 6792. 6700 175~ 30 7~2.23 N ~A09,32 5B~'2. ~ 6800 - 1784 ....... ~"0 ............................ 7-70~66 N 4&'~8-~-*~"~ 6992e 6900 1815 31 799.2~ N 4565095 ........................................................................................................SINGLE SHOT SURVEY 27 ~AY 8L TRUE ~ ~"SU'~D v E~T'j'C'AL SOB DEPTH DEPTH SEA TOTAL COORDINATES .............................. i 6'6~0 ~ ~-c)--; .......... ~)-6 ?~,- 1. ,' 0 4'"~ ~' 0-, ~'~,' 2000 1989, 1897, 1,67 $ I26,25 W ~_0.~o_ ?.~_ZT.~. ~ ''/~.P.. . ........ p.5.~.~.o__....N~.~..~.., ~,.]~ .w ~000 3565, 3473. 122,72 N 1282,69 W 5000 q227, 41~5~ 225,18 N 202Z~,35 ~ 6000 ~907, Z~815, B62,87 N 274,~32 W ~000 6372, 6280. 626,69 N 4079,48 W ,oot 8OO 1200 1600 ~ERT I CAL.:. :.,,SECT ! 0 N MOBIL OIL CO. RABIUS OF CURVATURE MAGNETIC SINGLE 8HOT SCALE I"= !000' MAY 28t 1981 WELL KUR RIV. 28243-MP I 2000 $~oo~ ARE TVD 360 ' HORIZONTAL VIEW MOBIL OIL CO. WELL KUP. RIV. 28245-MP I RADIUS OF CURVATURE MAGNETIC SINGLE SHOT SCALE !" = I000' MAY 28t 1981 TVD = 70?.5' TMD = 8850' ALL DEPTHS ARE TVD " Chcck f~r tiumly c~:~p!iamce with ouu r~ulations. O[~rator, Well F. arr~ and N~unbcr Ce~pletion Rq~rt Wel 1 History Samples Mud Log. Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Lzxjs Run Digitized Log Eata Rc~]uircd Date Received t ' yes Rema ~,. s Yes Thru: ALASKA OIL AND GAS CONSERVATION COMMISSION Royle H. Hamilton .~ Chairman Lonnie C. Smith Commissioner Bobby Foste~ ~-~" Petroleum Inspector July 21, 1981 Inspect of Mobil's Kuparuk M.P. #1 Sec. 17, T11N, RILE, UM. Well Not Perforated. Mgnday. June 29, !981~ As the attached pictures show this loca- tion iS clean, 'tM well sign and well head in proper order. The reserve pit has not leaked but there is a small amount of diesel oil & B.S. floating on the water. In summary, I inspected Mobil's M.P. %1. Attachment: I spoke with Chris Cooper, Mobil drilling foreman ~n~erni~g- the diesel~on the reserve pit. Chris said he would have it removed. This will be checked by a Petroleum Inspector at a later date. Dg:i;%.~DU£EZE ARETIC PACK PROEEDU~[ Revised 3.'2:'."80 Make sure that a minimum of 6 hours has elapsed since bumping top plug , on 7" primary cement Job. Hook up lines to both sides of wellhead on 7' K lO-]/a" annulus. Fill the annulus with H~O by leaving one line broke orr and draining into cellar (this will &liminate any sit pockets in the annulus). Test lines to ~000 psi. Be aute to provide an outlet to take Arctic Pak samles. Inject ~00 bbls water down 7" x 10-]/~" annulus st maximum pu~,,p rate not to exceed 2000 psi surface pressure. NOTE: Minimum pump rate should be at least E BPH. Use either rig .pu?ps or service company cement pumps. Mix and inject at maximum rate 250 sx of either Permafrost "C" (15.2 ppg) or Arcticset I (la.B ppg) blended to give minimum of 2 hours pumpinq time. Mix water to be betwen 70° and 90°F. lake dry sa=pies. Immediatel~ foilow the cement with the appropriate barrels or light- weight At=:ic Pack that wii! place the Arctic Pack cement interface at 2~00'HD. Inject Arctic Pack at maximum tats. (Directional hole with 7" x 10-]/a" annuli requires 112. bbis.). NOTE: a) Honit°t end strap A=ctic Pack tank during injection ~f Arctic Pak to insure correct volume is pumped. b) The time delay between finishing injecting of cement until beginning of injection of Arctic Pak should be min:~ized as much as possible. c) Arctic Pak temperature should be less than ,0'r before pumping. Retort an Arctic Pak sample from the bottom or the storage tank just prior to the job to insure that pak is not contaminated. d) Catch a one point sample every 20 bbis. Retort and report results on report. e) A minimum pump rate of 2 BP~4 is' to be maintained fto~ time start pumping cement until finish pumping Arctic Pak. If this minimum rate cannot be maintained, then shutdo~ pu~ping operation until problem is corrected then resume pumping at higher rate. r) Use both service company pumps simultaneously to p~p cement end then Arctic Pack. Shut in 7" x lO-}/a" annulus. · · Pressure test 7" x 10-]/a" ~nnulus using diesel or Arctic Pak to 1000 psi for I hour~ after allowing the injected cement sufficient time to have set up (lB hour minimum). Bleed pressure orr, Under no conditions should an~ water base material be used for this. 8. Fill out downsqueeze Arctic Pack Report form and submit rot well records. CAU11ON: NOTE: a) go not exceed 2500 psi maximum surface pressure at anytime during this procedure. b) Work out operations schedule so that rotating or DP inside ?" casing wi~! not be necessary for a minimum of a hours after Arctic Pak and cement are in place. c) Honitor and limit 7" x 10-3/~" annulus pressure to 200 psi maximum dutinq remainder o~ rig operations. Subsequent circulat- ing may warm annulus and cause pressure increases. RECEIVEI) MAY 2 2 198I Tanks and vacuum trucks used for holding and ttansootting Arctic Pak will be inspected and kept free of any contaminating materials before use on each job. 1he_Arctic Pak premix must be in petfe=t cond:tionAJas~a0i~ & Ga5 Cons. Commission fo~ use in the ~ell. No water contaminants will'be allowed in tank Anchorage or truck bottoms. INTEROFFICE CORRESPONDENCE TO: R. L. Gretlein - 529 DENVER E&P DIVISION DATE: May 20, 1981 CC: Chris Cooper- North Slope Ken Sullivan - North Slope 7" CASING AND CEMENTING PROGRAM KUPARUK 28243-MP MOBIL-PHILLIPS #1 SECTION 18-T11N-R11,E-U.M. PRESENT SITUATION: 10-3/4" casing (45.5#/ft., K-55, Buttress) was set at 2930' M.D. and cemented to surface. A 8-3/4" hole is presently being drilled at a mud weight of 9.8_+ PPg. OBJECTIVE: It is planned to drill the 8-3/4" hole to 8700' M.D. (7000' T.V.D) and to run a full string of 7" casing. PROCEDURE: 1. After having reached setting depth of 7" casing, condition mud and run logs. RIH w/bit and circulate hole clean. Drop temperature disc. 2. Install 7" rams 'in BOP. 3. Run 7" casing (26#/ft., K-55, Buttress) equipped with float collar two joints above shoe to bottom and pick up 5 ft. Install heavy duty centralizers as follows: -One above shoe -One in center of every joint to the top of the Kuparuk River Sand at 8282'. -One in the center of every tenth joint from the top of the Kuparuk River sand to the base of the West Sak Sand (8282'-5008') -One in the center of every joint from the base of the West Sak Sand to the top of the West Sak Sand (5008'-4610') -One in center of every fifth joint from the 10-3/4" casing shoe at 2930' M.D. to surface (positive centralizers). RECEIVED MAY 2 2 198] Alaska Oil & Gas Cons. Commission Anchorage - -R. L. 'Gretlein ' ~AGE-2- ~ NOTE: Thread lock bottom three joints. Spray each pin. for make-up with aluminum templates. ~ke-up each joint to the listed minimum torque (4000 ft-lbs), then check to insure that the end of the triangle is buried. If base of triangle is not covered, increase torque until the required make-up placement is achieved. 4. ~ke-up cementing head and pressure test lines. Break circulation and circulate at least bottom up. 5. Cement 7" casing in one stage from 8700' to 4110'_+ as follows: a) Pu. mp 25 bbls of Spacer 1000 (weighted to match mud) drop bottom wiper plug. b) Mix and pump 240 sks* of Class "G" cement with 3% KC1 (BWOW) + 6% attapulgite + 2.5% D-59 + 1% D-56 +0.25% D-13 + 0.2% D-46 as lead cement followed by 200 sks* Class "G" cement with 3% KC1 (BWOW) + 1.5% D-59 + 0.75% D-65 + 0.2% D-46 as tail-in cement. CEMENT DESIGN LEAD SLURRY TAIL-IN SLURRY Fill up 7282'-4110'=3172' 8700' to 7282':1418' (Top @ .500' above West Sak Sd) (Top @ 1000' above Kuparuk Sd) Dry Volume (sks)* Slurry Weight (ppg) Slurry Yield (cu.ft./sk) Slurry Volume (cu.ft.) Mixwater Ratio (gal./sk) Slurry Temperature (°F) Thickening Time 240 200 11.9 14.2 2.59 1.48 620 295 15.14 7.38 60 60 6 hrs. @ 140°F 3.5 hrs. @ 140°F * NOTE · Cement volumes are given based on gauge hole volume plus 30% excess in open hole. The actual cement volume needs to be determined from caliper log plus 15% excess. The exact volume of the retarder needs to be determined by lab tests with cement samples taken out of the bulk at the location and with the same water which will be used for the cement job. Volume 7" csg. X 8-3/4" hole' 0.1503 cu.ft./lin, ft. Capacity of 7" csg. (26#/ft.): 0.2148 cu.ft./lin, ft. : 0.0382 bbls/lin, ft. c) Drop Bakerline double shut-off plug and bump plug with a. 500 psi increase in pressure. If plug does not bump after calculated volume was displaced stop pumping (do not overdisplace). Release pressure and check for flowback. RE~E~V~D MAY 2 2 1981 Alaska Oil & Gas Cons. Commission Anchorage R. L. 'Gretlein ):'AGE-3- 6. Nipple up 7" casing. Pressure test seal to 3000 psi with diesel (drain diesel from ports after test). 7. Arctic Pack 7" X 10-3/4" annulus with 250 sks Arcticset II ahead of the -~Pack. Slurry Weight: Slurry Yield: 1 5.8 ppg. 0.93 cu.ft./sk Water required: 4.1 gal/sk Thickening Time: 4 hrs. Interface between Arctic Pack and cement to be at 2300'_+ {capacity of 7" X 10-3/4" casing annul us:O. 2727 cu.ft./lin, ft. = 0.0486 bbls/lin, ft.; total Arctic Pack volume 112 bbls). Attached is the Downsqueeze Arctic Pack Pro- cedure used by ARCO. 8. Run tubing to 4000' open ended. Displace mud in hole with diesel. Install tree. Release rig. HDS/sc 28 W. G. Sole RECEIVED MAY 2 2 1981 Alaska Oil & Gas Cons. Commission /~chomge '- ~'~, STATE OF ALASKA ALASKA. iLAND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] 2. Name of Operator ~V[Obi I O'! I 'C~r.¢ 3. Address f~, O. BOX D_~jqgp.. 4. Location of Well OTHER [] 7. Permit No. 8. APl Number so- o:2-fl - Z o5'/3 9. Unit or Lease Name ~OPA~UY~ 10. Well Number 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 12. 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 ($U.~ ~9,~1~%~1~)~ 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 RECEIVED MAY 2 2 1981 Alaska 011 & Gas Cons. Commission Anchorage proposed work, for Abandonment see 20 AAC 25.105-170). 14. I hereby celtify tha~t t~e foregoin~ is true and correct to Signed~_ ./~~ /~i~,~ The space below for Commission use Conditions of Approval, if any: the best of my knowledge. Approved COpy Returned By Order of COMMISSIONER the Commission Approved by. ORIGINA[ SIGN[D' BY LONHIE C. SMITH Form 10-403 r-, _.. '-/ ,~ o~'~ Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Thru= ALASKA OIL AND GAS CONSERVATION COMMISSION Commissioner May 18, 1981 Harold R. Hawkins Petroleum Inspector B.O.P.E. Test on Mobil, Kuparuk Well #1 Sec. 18, TllN, RllE, UM Permit No. 81-35. May 11~. 1981: I lef~ Aro='s West Sak .well B-3 where I finished ~i%nes~ng~:::~ B.o.p.E. test, to Mobils, Kuparuk well No. 1, to perfo~ another B.O.P.E. test. May ~!2.,~_..!.~,,8~., I witnessed the B.O.P.E. test. On the day of May 7, 1981, I stopped by Mobil's well No. 1, to inspect the ~diverter. The diverter was not installed right under the API specifications R.P. 53. At that time the surface hole was drilled to 1,700 feet. Chris Cooper, Mobil oil super- visor, ordered another 6" line to be installed. ~_ay .!1.,~...19~1~.· ~en I Went back to the location to witness the B.O.P.E. test, the 6# diverter line had been added. A drawing is attached to this report, of the diverter before and after the changes. I gave an order to Mobil, *see remarks on field report. In summary, I witnessed the B.O.P.E. test on Mobil's Kuparuk well No. 1. The B.O.P.E. test's were satisfactory. 0&G #4 4/81 · STATE OF ALASKA ALASKA oIL & GAS ODNSERVATION CGMMfLSSION B .O.P.E. Inspection Report ~Inspector Operator ~ g5 .g~ 7/~ Well ?~D ~ ~ Location: Sec / ~/ .T//~ R//~M Prillinq Contractor ?,~)z;/.f.~..~~ Rig ~ ,~3 we l 7r/6, Representative.£/7~Y. ~Z'~ ~_~Z~ ~ ~/:;/3 ,fU~/~; Casing Set @ 2 ~ ~ ft. Repre sen%at ive-$~'~ ,-~.~/ ~//~' 2~ ~ Location, -Genera]__ ~f Well Sign ~ Ceneral Housekeepin~ ~f~ Reserve pit _ ~.~ BOPE Stack Test Pressure Annular Preventer Pipe Paros Blind Rams Choke Li~e Valves~ H.C.R. Valve Kil 1 Line Valves -- Check Valve__ ACCL%~UIATOR SYSTEM .Upper .Kelly Test Pr~.saure - '+?.~.~ ~5" Lo~r Kelly. Test~. Preslsure ...~,~ iff ,.~' 'Ball Type_ _ Test Pressure-i' ~- ,.~,~ "'.~ Ful 1 Charge Pres sure ..~g .3rd3 psig Pressure After Closure //~ ~ ~ psig P~p incr. clos. pres. 200 psig --- min~ Sec. Full Charge.pressure Attained: ~ mi.n~ Sec. z _ m..~, . .j-~?dd/... .... .. IContro~s ~ Master. ~Z]I~ - . · . _ . :e~Zy an(] ~oor Safe .ty Valves - ·. Ins ide BOP Choke Manifold NO. Valves_ !! No. flanges__Ag Adjustable Chokes ~.~ Hydrauically operated choke. Test .Pr. eS Sure Test Test Results: Failures- Repair or Replacement of failed equipment to be made within,--- . days.~and ' Inspector/Ccmmission offiCe notified. .... 6/ ' Inspector Test Time'., ,~ . hrs... M ,)~ .... ~ !~.' .... - ,, _, Distribution ' " orig. - AO.&CCC cC - Operator cc - SuPervisor Mobil Oil Corporation Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 I' I co~,,~m' 1 P.O. BOX 5 ~ ............ ", __ DeNveR, coLoRaDo 802~7R!:: ~ .... I~,:~',~,i 1 Apri~ 6, ~9~ ~ ...... ~.~.:~ ' CO~FER: RE' MOBIL OIL CORPO~TION ADL h28243 WELL ~1 KUPARUK RIVER FIELD NORTH SLOPE, ALAS~ Gen tl emen' This is to supplement the application for a permit to drill the captioned well in response to a telephone request from Jim Trimble. As shown on the attached drawing, the diverter system will consist of two 6" diameter lines venting in different directions. The butterfly valves will be equipped to open when the annular blowout preventer is closed. The other attached drawing shows that the choke manifold system has been revised to include two adjustable chokes. The maximum anticipated bottom hole pressure at 6500' TVD is 3400 psi based on a test in an offset well. The surface pressure, assuming a column of reservoir gas at a gradient of 0.1 psi/ft, was calculated to be 2750 psi. The Working pressure of the BOP will be 5000 psi and the internal yield pressure of the 10 3/4", 45.5 lb/ft, K-55 Buttress surface casing is 3580 psi. We trust this information completes your requirement. Yours very truly, L. C. Case Division Regulatory Engineer JLDougl ass/ie CF)NFIDENTIAL 20" SE;R/ES 600 HYDRZL 2000 PS! ~.P. 6" 2000 PSI ~UTTERFLY VA T~.$T FLAitGE[~ " 30C~0 PSI 2"~;;"$ERIE5 600 CHECK VALVE CASING HEAD 6" 2000 PSI BUTTERFLY VALVES Z" SEkIES 5,3,3 D.F. vALvE . 2" SERIES 6DD D.F. VALVE FIBRE ! I~//$ I$ A $C#£MArI¢ S,~T¢# AND O/VII' ~'0 ~ A$S£M8/.£Oo MOUNT£O O/M£NSlONA& ORAWlIV~. ' ' '~ ; :?, eZaM s~/o$ a~vo rzsr£o ~o $oob '~s*~...' '~. a" x ~" sruoozo ¢~os~ ~ 4. $" FLANG£O OAI'£ I/'.4LV£ ! I~UBL£ $1'UOl~O AOAP~£R ?0 COMMON RESEV RELIEF' V~LVE R"' COMPANION FLAA/~E' &IVO HIOH ~~URE NIPPLE R~ COMPANION ~~E- ~C~W R" HP BOLL PL O~ ' /1 /4. SPA/ER /rIPPlES ¢OttSlSY//V~ WE/.O F'LANGE ~1 R" /./NE PIPE. R" $1VOOEO EI. OOWS 3~ COMPANION FLANGE ~l~W 0~t~, · F/GORE $ April 3, 1981 Mr. L. C. Case Division ~gional Engineer Mobil Oil Corporation Box 5444 Denver, Colorado 80217 Re: Kuparuk River 28243 No. 1 Mobi I Oil Corporation Permit No. 81-35 Sur. Loc.: 605'FWL, 470.'FSL, Sec 17, T11N, R11E, UM. Bottomhole Loc.: 1460'FWL, 1270'FSL, Sec 18, TllN, RlIE, Dear Mr. Case: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud Icg are required. A directional survey is required. If available, a tape containing the digitized log information shall be. submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many 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 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~abitat 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 amended. Prior to Mr. L. C. CaSe Kuparuk River 28243 No. I -2- April 3, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after 'the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notificat~on so that w~ may have a witness present. Very truly yours, Hoyl~ }!. F~mi lton Alas,ka Oil & Gas Conservation Commission Enclosure cc: Department of Fish & C~e, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. ARCO Alaska, Inc. ~ North Slope E_ ,~loration & Producing Operations Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Paul B. Norgaard Vice President March 27, 1981 Mr. Hoyle Hamilton, Director Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ----ri- .ST]~T TEC_ '1 STAT 'F2C '1 CONFER: FILF: RE' LETTER OF NON-OBJECTION MOBIL OIL CORPORATION ADL-28243, WELL #1 KUPARUK RIVER FIELD NORTH SLOPE, ALASKA Dear Mr. Hamilton' Pursuant to 22 AAC 25.050. Deviation, this letter advises that ARCO Alaska, Inc., has no objection to Mobil Oil Corporation drilling the subject well. ARCO owns 100% interest in two leases, ADL-25650 and ADL-25649, which will be affected by the proposed action. Very truly yours, PBN/SRJ/gt ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~mrch 13, 1981 Mr. L. C. Case Dril ling Regulatory Engineer Mobil Oil Corporation P. O. Box 5444 Denver, Colorado 80217 Dear Mr. Ca se: The recent PERMIT TO DRILL OR DEEPEN forms that you submitted for well No. 1, Kuparuk River Field are old outdated forms. These outdated forms will be accepted this time, however in the future only new current forms will be accepted. Some copies of the new forms are attached. Additional forms are available at our office or they can be mailed to you on request at no charge. It should be noted, however, that in any event we cannot approve this permit until the bonding requirements of 20 AAC 25.025 have been satisfied. We have written letters to Mobil on December 15, 1980 and ~rch 3, 1981 on this subject. Sincere ly, ,, Hamilton Chairman Enclosure cc: M. J. Meyers no/encl. Mobil Oil Corporation March 6, 1981 P.O. BOX 5444 DENVER, COLORADO 80217 'Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 MOBIL OIL CORPORATION ADL #28243 WELL ~1 KUPARUK RIVER FIELD NORTH SLOPE, ALASKA Gentlemen: Enclosed is an application and filing fee for a drilling permit for the captioned well. It is proposed as a development well to be included in the ARCO proposed Kuparuk Unit. The well is to be directionally drilled toward ARCO's lease to the west. By copy of this letter we are asking ARCO to provide a letter of no objection to the directional drilling. JLDouglass/j enclosures Yours very truly, L. C. Case Drilling Regulatory Engineer cc: Mr. Gerry Pawelek ARCO P. O. Box 360 Anchorage, Alaska - REGISTERED MAIL SUBMIT IN TRIP~ Form 10401 REV. 1-1-7! (Othe~ inst~uction~ ~., revere side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL ~: DEEPEN ["] b, TYPE OF WELL OIL [~ GAS ~ SINGLE~'~ MULTIPLE r-~ WELL WELL OTHER ZONE ~._~ ZONE L_J 2. NAME OF OPERATOR MOBIL OIL CORPORATION ATTN: L. C. Case 3. ADDRESS OF OPERATOR Box 5444, Denver, CO 80217 4. LOCATION OF WELL 605' FWL & 470 FSL, Sec. 17, TllN, RilE, UM A( surface Top Kuparuk River Formation 6. LEASE DESIGNATION AND SERIAL NO. ADL #28243 7. ~ INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9.WELL NO. 1 10. FIELD AND POOL, OR WILl)CAT Kuparuk River il. SEC., T., R., M., (SO~OM HOLE OBJECTIVE) At ~opo~ prod. zone 1460' FWL & 1270' FSL, Sec. 18,TllN,RllE,UM Sec. 18-TllN-RllE, UM 13. DISTANCE IN ~LES A~ DIRECTION FROM NEAREST ~WN OR MST OFFI~* 12. 25 miles west of Deadhorse 14. BOND INFORMATION: r~E Blanket, , Surety and/or No. 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FI'. 1460 ' (Also to nearest dr~g, unit. ff any) Federal Insurance Co. #8084 0863 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, ~. Approx. 38'00 ' .21. ELEVATIONS (Show whether DF, RT, CR, etc.) 63' Ground Level 16. 19. No. OF ACRES IN LEASE 2,480 PROPOSED DEPTH 7000' TVD 8700' TMD ,~o.n, $200,000.,00 17.NO.ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START April 1, 1981 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASII~G' 'I WEIGHT PER FOOT, GRADE SETTING DEPTH ' QuantiW of ceme'n! ,: , , , , SEE AT~,ACHED t ROGRAM , IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen di~ectionally, give pertinent data on subiurface locations and measured and true vertical depths. Give blowout preventer program. 24. ! hereby certify that the Forego~ is True~!~ Correct , ~-. TITLE Div' Reg. Engineer (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED I MUD LOG X~s ~ NO ] ~YES DIRF~HONAL SURVEY REQUIRED [~YES [] NO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: [] NO A.P.I. NUMERICAL CODE PERMIT NO. <~ (~ 5,5"" APPROVAL DATE APFOVEDBY ..'~~~~ ~7~~ TITLE iC~:~irl~El,n ~Y OR'DEt(f/ O~ .THE CO~I$8|(~ee Instruction On Reverse Side April 3, 1981 DATE 04/03/81 TRUE TIIN 13 24 25 Control Point """"" '-'~N~- KUPARUK 28243-MP ..... ." .?¢' ~ Lat. 70° 18'07.80" ~" :':' " ,~'~ .;/'..~ ~' Long. 149 °25'01.49 -- .... ':~ x = 571~967 "-" 4 ~ F""% "~ ~'- '~.~ Y : 5,960,425 .......................~.~~. ~"~ Elev.=63~ CERTIFICATE OF SURVEYOR I hereby certify thor I om properly registered and licensed toproctice lend surveying in the State of Alesko and their this plot represents o location survey mode by me or under my direct supervision end their oil details ore correct, DATE SURVEYOR · ~....~..~.~55:1 Slope on 'fill pad I. Jr- WELL.I + WELL t --~ WELL I Jr- , WELL 120 Jr' WELL 5 I~0 ,~1 WELL 6 Jr- WELL 7 + WELL 8 ;ess i ~5d ~5o' Camp Sewage Logoon Rood 50' ,1-.-._._ ----._ i CONTROL [ '- --- --POINT I 640 I I I I I I I I KUPARUK 28243-MP LOCATED IN SECTION 17~TIIN~R!I Et U. M1AK. FOR MOBIL OI LCORPORATION SURVEYED BY BESSE, EPPS 8, POTTS ANCHORAGE ~ALASKA 907-54 DRILLING PROCEDURE KUPARUK 28243-MP MOBIL - PHILLIPS #l NORTH SLOPE, ALASKA This well is to be completed as a Kuparuk River development location in the SW 1/4 of Section 18-TllN-RllE-UM. The top of the Kuparuk River zone is to be penetrated at a location 1267'+ N and 3482'+ W from the SE corner of Section 18-TllN-RllE (8020' MD, 6500' TV~). - SURFACE LOCATION: Approximately 479'+ North and 605'+ East from the SW corner, Section 17, TllN-RllE, Umiat Meridian, Ala-ska (Pad Slot #~). BOTTOM HOLE LOCATION' 1350'+ North and 3920'+ West from the SE corner, Section 18-TllN-RllE, ApproXimately 4610'~ N 79o W of surface location. Total Depth 8700' MD {7000' TVD). GENERAL: Deviation from the recommendations may be necessary due to conditions arising during the drilling of the subject well. However, if possible, any deviations from this program, along with the reasons, should be discussed with the Drilling Manager prior to making the changes. If specific conditions make it unfeasible to discuss variations prior to their implementation, they should be reported, along with the reasons, to the Denver office as soon as possible. The projected casing, progra~m, is as follows: CASING SIZE DEPTH 16" O.D. 10-3/4" O.D. 7" O.D. 80'+ 2900'~ M.D. (2700'+ TVD) 8700'7 M.D. (7000'7 TVD) DEVIATION: It is possible that deviation problems will be encountered. Packed hole assembly and/or stiff hook-ups are recommended for use from the surface. Single shot direc- tional measurements will be made the first 30', 60' and 90' and thereafter every 90' to 1000'. From 1000' deviation measurements will be made as required for directional drilling accuracy. The KOP is 1000'. The angle will be built at 2~°/100' to 42o in a N 79o W direction · and held to total depth. RECEIVED ~aska Oil & Gas Cons. Commission Anchorage PAGE -2- RECOMMENDED MUD PROPERTIES DEPTH WEIGHT VISCOSITY FILTRATE FEET (MEASURED) PPG SEC. CC 0-750' 8.9-9.8 200-300 10-20 750-2900' 0.3-10 200-300 10-20 2,700-8700' 9.5-10.0 36-40 8-12 TREATMENT Spud Mud, use Aquagel and Quik-Gel to provide adequate vi scosi ty to clean the hole. Aquagel and Quik-Gel to pro- vide adequate viscosity to clean hole. Mud up a low solids non- dispersed system as follows: l) Drill cement with water and bypass returns to re- serve pi t. 2) Check make-up water to in- sure 80 ppm calcium for X- linking. 3) Add .5 ppb XC-Ploymer. 4} Add .1 ppb Chrome Alum. 5) After original cross link- ing, raise ph to g-lO with Caustic soda. 6) Add .3 pph DEXTRID. 7) Add 5-10 ppb Aquagel. 8) Add .25 ppb Aldacide. 8.0.P. REQUIREMENTS: A. From 16" conductor to 10-3/4" casing point, use Bag Type 20" series 600-2000 psi WOG, 20-3/4" bore. , B. From 10-3/4" casing point to 7" casing point: l) Bag Type 13-5/8" series 1500, 5000 psi W.O.G. 13-5/8" bore. 2) Double gate, 13-5/8" series 1500, $000 psi W.O.G. 13-$/8" bore, complete with 5" DP and blind rams. Alaska Oil & Gas Cons. CommiSsion Anchorage PAGE -3- CASING REQUIREMENTS- A. Surface conductor 16" O.D 80'+__ 16" O.D., new 65 lb/ft casing. B. surface casing 10-3/4" O.D. 0-2900'+ 10-3/4" 0 D. 45.5 lb/ft., K-55~Buttress. C. Production Casing 7" O.D. 0-8700'+ of 7" O.D., 26.0 lb/ft., K'55, Buttress. DRILLING PROCEDURE' 1. Drill 6~2,~_h°le to 80'+. This hole will be drilled with auger rig. The bottom of the 16" conductor sho~-ld be plugged with cement or wooden plug. The 16" conductor should be set in place and cemented to th_.~ through lb" tubing down the out- side of the.conductor with "Permafrost', slurry, ~n~ cement slurry should be kept at approximately 60°F While pumping into place. The lb" tubing should be run to the bottom of the conductor, 2. Nipple up wellhead and 20" bag type B.O.P. Pressure test BOP to 1000 psi and choke manifold, valves, etc., to 2000 psi. . Drill ~ hole through gravel beds to 1000' Directionally drill 12¼" hole to 2900'. Run eleE~ric logs (DIL-Sonic). Open 12¼" h~le to 15" from lO00' to 2900'. 4. ~Run 10-3/4" O.D. casing with centralizers on the first four joints. Set 10-3/4" O.D. casing string at 2900'+. Use duplex collar, float shoe, and Arcticset cement. Duplex collar should be run--one joint above guide shoe. Cement the 10-3/4" O.D. casing string from 2900'+ to surface. ' ........ 5 Nipple up 13-3/8" series 1500 BOP stack. Pressure test BOPE to 5000 psi. 6. Pressure test casing to 2000 psi. Install mud logging unit prior to drilling out 10-3/4" shoe. ~,~x~j .pe~t ? 7. Drill ~/8" hole to 8700'+ total depth. Exact depth to be determined by well site Geologist'S.~ Core as directed in the Kuparuk River interval. Run electric logs at total depth (DIL-BHC, CNL-FDC-GR & 4 arm caliper). 8. Run & set 7" casing. Cement with a light weight lead slurry with an open hole annular volume from 1000' aboVe the Kuparuk River sands to 500' abov~st Sa_~~~ds plus 15% eXcess, ih~e tail slurry to be Class G mix with an open hole annular volume from the casing shoe to 1000' above the Kuparuk River sands. 250 sax of Arcticset cement will be displaced down the 7" X 10-3/4" annulus with ~c Pack with a volume 'to place the Arctic Pack-Cement interface at 2300'+_ MD. A detailed program for cement & Arctic Pack placement will be furpJshed prior to the job. 9 A final completion Program for the Kuparuk River zone will be provided at a later date. RECEIVED MJH/Sf M.j. MeYer MAR 1 Oil & Gas Cons. CommJssJorl Anchorage CONFIDENTIAL 20" SERIES 600 HYDRIL 2000 PSI W.P. 2" 5000 PSI D.F. VALVES TEST FLAi'qGE i ~ i \ 2" 3000 PSI 20"" 600 CHECK VALVE 1 CAsISERIES NG HEAD 2" 5000 PSI D.F. VALVES '1 Z" SERIES 500 D.F. VALVE 2" SERIES 600 D.F. VALVE FIGURE I ,;ON FI DENTIAL 13-5/8" 5000 PSI BAG 13-5/8" 5000 PSI DOUBLE GATE ~OP-BLIND RAMS ON BOTTOM UULJU D[DOD DODo 2" 5000 PSI u.F. VALVES $" 5000 PSI D.F. VALVES '~ 2" '3000 PSI ~'-~--=='=-~-=-~ 2" 5000 PSI D.F. VALVE LVE I 13-5/8" SERIES I ' 'm CHECK VALVE 2" SERIES 1500 D.F. VALVE FIGURE 2 DIMENSIONAL Aato r£$r£o r~ $oo0 ~$'t,:., · B. 13. 3" X g" FLAN~..O 3" X g" STOOOEO ¢t~055 g" FL AIVGEO ~A rE VAI. Vg O00BL~ STOOD~O AOAP?g~ ~"' COMPRNION FL~NGK' HIGH P~KSSU~E NIPPL~ ~' COMPANION FL~NG~ - ,~" HP BULL PLUG ' · SPACER NIPPLES ¢ONsISrlNG WELD FLANGE & g# LINg PIPI:'. g" SrUDDED ELBOWS COMPANION FLANGE SCREW OUR ITIM APPROVE DATE , (1) Fee ~-- [~-/3-~./~.. l. Is the permit fee attached ................................. · (2) Loc. ~~ -/-~ 2. Is ~11 to be locabed in a dmfin~d pool ...................... (2 thru ~ . 3. Is ~ell located proper distance frcm property line .......... 4. Is v~ll located proper distance from other %~lls .................... 5. Is sufficient undedicated acreag~ available in this pool ............ 6. Is v~ll to be dmviated and is ~11 bore plat includmd ............... 7. Is operator the only affected p~rty ................................ 8. Can permit be approved before ten-day ~it .......................... (3) Admin ~9~_~'/~ 9. Does operator have a bond in force, ...................... "e e e e e · · · · e · · (~' thru 11) *N' 10. Is a conservation order needed ... '~,.. ................................. 11. Is admini$~ati~ approval needed .~ ................................. ........................................ 20) 13, Is enOugh cement ~sed to circulate on oonductor and surface ......... '14. ~ill oeman~ ~_te in surface and intarmediate or produc~_ion strings ... 1~. Will ce~nt co~r all knowa producti~ horizons ..................... 16. Will sur£ace casing protec~c ~resh ~ter zones ....................... 17. Will all casing giv~ adequate safety in collapse, tension and burst.. 18. Is this ~11 to be kicked off from an existing ~llbore ............. 19. Is old ~llbore abandonment procedure included on 10-403 ............ 20. Is adequate w~ll bore separation prOposed ........................... (5) BOPE 2~1 ~t~ ~_~ / 21. Isa div~rter system required ................ : .... ..-,.'.-'-;'% ...... 24') ! 22. Are necessary diagrams of diverter an.d. BOP e_qul.p~.nt:ttaTe~ 2~- 23. Does BOPE have sufficient pressure rating -'l~.St_~.O_~__o_c, 24. Does the choke ~ ma ni fol d conply w/API RP-53 (Feb.'/)... .............. (6) Add.-_~~ ~-/g'~~~ 25. Additional requiremsnts ........................... . .................. .._ Geology: En~ ~n~, ~,rin~: INITIAL ' GEO. UN±T 'ON/OFF POOL CIASS STATUS AREA NO. SHORE , re~: 03/10/81 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 7~7777 7777 11 11 11 11 11 11 11 11 I1 11 1111 1111 O0 O0 77 O0 O0 O0 77 oo oo O0 0000 77 O0 0000 O0 0000 77 O0 0000 00 O0 O0 77 O0 O0 O0 00 00 00 77 O0 O0 0000 00 77 0000 0000 00 77 0000 O0 00 O0 77 00 O0 00 00 77 O0 O0 000000 77 000000 000000 7'7 000000 77 77 77 77 77 77 77 77 77 77 77 77 666666 666666 66 66 66 66 66: 2:2 666:66' 6666,6.6 222,22222.22 222222 000000 1.1 7777777777 22222222 0000000000 7777777'777 22 ., 'i : 77 22 22 O0 . O0 1111 77 2 2 00:0000 11 77 22 t. 1 2,2 2 2 . O0 O0 O0 1 ! 22:': ' ~'0'000.':::'. 00'i :. ': 2.2 1, l 7777 ART* OS 10707 5497 DAT ;-dUh-81 1 ~!OB SHIP SEO 5497 E )9 $~IPPING INSTRUCTIONS ISSUED 23-dllL-B 1 19:04 ~ENIi3RA, CALIFURNIA 9~00~ ?CCC BY GHB PCCC SSSSSSSS SSSSSSSS ½S ~S $S $S SSSSSS SSSSSS SS SS SS ~ SS SSSSSSSS SSSSSSSS HH Hf~ IIII HH HH IIII HH itfi II HH HH II HH HN II HH HH II HHHHHHHHHH I1 H~HHHHHHHH I1 HH H~ 1I HH HH II HH HH II HH HH II HH HH IIII HH HH IIII 1I II ii II PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP · .T 0~ TT O00OO0 O,O000t) O0 O0 0 O0 0 0 ' ', ' ' "' ' ' 7 ' '0 *STAR! .USER PeAL (.1070.,62017] JOB ,SHIP SEQ.. 5497. DAI~E. 23-dUD, 81 19.37. 9 L~$ V~..:~S,tON 15.H01 791(-)3126 SCHLUMBERGER COMPUTING CENTER 10707,62017 R[;;EL H~{,ADER hENGI'H: 112 BYTES REEI~ NAME: P.C.A.L. SERVICE NAME: EDIT REEl, C{]NTINUATIQN NUi'qBER: O1 PREVIOIIS REEL NAME: C~')MMENTS: bls FORe, AT CUSTOMER TAPE DATE: 81/ 7t23 TAPE BEADER LENGTHt 132 BYTES T · DA E. 81/ 7/2,3 DIL RUN []NE WAS, LOGGE:D 0N 8-MAY-81.. THERE NA~,~V.ER A THOUSAND FOOT . GAP: B. ET~EEN' IBR[E WERE MERGED AT 7700. C 29,30 ~940~'; RM /V VV IV VV ~V VV IV VV ~V VV VV VV VV VV VV VV VV VV VV VV YV YV YV vv v¥ EEEEEEEEEE EE EE EEEEEEEE EEEEEEEE EE EE EEEEEEEEEE EEEEEEEEEE RRRRRRRB iiiiii RRRRRRRR IIIIII RR RR II R~ RR II RR RR II RRRRRRRR II RRRRRRRR II RR RR II RR RR II RR RR II RR RR II RR RR IIIIII RR RR IIIIII ~FFf'ff'FFFF' FFP'FFFf FFF Ff' Ff~ FF FFFFFFFf' FFFFFFFf' FF Ff FF FF Y¥ YY YY YY YY YY YY YY YY YY YY YY Y¥ YY YY YY YY YY YY 000000 000000 0.0 O0 O( oo Oo o( O0 O0 000000 000000 O0 O0 0000 0000 222222 222222 22 22 22 22 22 22 22 22 .*.START* USER PCAL [1070'7,62017] dOB SHIP SEQ. 5497 DATE 23 3 b 81 19.]7.09 ',.MON.IT'OR SWS .Kb i gE0-O'' 81. *START:* SW LE :FORT RANGE : I 1E TOWNSH1F : ~IN SECTION : 17 C[]UNTY : NORTH SLOPE STA~E : ALASFA D~;NS ITY : 800. DhTA FOI~MAT SPLCiFICATIt')N LENGTB: 890 BYTFiS F.~TP~ BLOCKS: TYPE SIZE REP Ct)DE ENTRY 0 I 66 0 DAT~]~ SPEC'IFICAII[]N B~OCKS: NAME TOOL U!",]IT API AP1 AP1 API FILE SIZE SAM REP PROCESS INDICATORS FT 0 0 0 0 0 4 MY 7 1 0 0 0 4 [)HM~ 7 12 46 0 0 4 OHMM 7 12 44 0 0 4 OHMM 7 22 1 0 0 4 GAPI 7 31 32 0 0 4 GAP1 42 31 32 0 0 4 IN 42 28 ! 0 '0 4 G/C3 42 44 0 0 0 4 PU 42 68 3 0 0 4 G/C~ 42 ~5 1 0 0 q C!C 42 42 1 0 0 q C~S 42 34 92 0 0 4 CPS 42- 34 9] 0 0 q GAP1 0 ~l 32 US/F ~ 32 0 52 ~V 6O ~PM 0 1 68 ! 68 1 68 1 68 1 68 ! 68 68 68 68 68 GAPI 0 0 0 0 O. 4 ~, 68 G'API :. 0 0 '. 0:' '0 :':'0 : ':. '~I USER DEFINED OUT[ JT ARRAY ..... OUTPUT SFLU ~O.UTPtlT GR. DL]PTH M Nk~l[]iq iC VALUE MNEMONIC VALUE MNLMONIC VALUE MNLMONIC VAbUE 8885. 000 SP -21 . 125 1LD 2.645 ILM 2. 697 SFLU 2. 959 GR 89. ]13 GR -94.500 CALl 5.656 DRHO -32768.000 NPHI 44.482 RHOB -.]2768.000 NRAI ].369 NCNL -1828.000 FCNL -496.000 GR 89.]13 DT 98.750 SP -21.125 THOR -19.484 POTA -0.063 URAN 5.9513 CGR -314.500 SGR --272.OOO RSO0.O00 8700.000 8600.000 SP -18.891 ILO 2.]91 ILM 2.482 SFLU 2.89] GR 89.000 GR 96.875 CALl 9.125 DRHO 0.148 NPHI 41.455 RHOB 2.453 NRAT 3.4]8 NCNb 1779.000 . 000 DT 99 188 SP -18 891 FCNL 463 750 GR 89. . . THOR 12.95] POTA 0.023 URAN 1.704 CGR 80.375 SGR 90.625 SP -18.016 ILD 2.264 ILM 2.334 SFLU 2.705 GR 96.875 GR 107,938 CALl 9.250 DRHO 0.082 NPHI 46.484 RHOB 2.396 NRAT 3.727 NCNb 1817.000 F'CNL 450.250 GR 961875 DT 105.188 SP -18.016 TH[.~R 12.1]] POTA 0.024 URAN 1.929 CGR 80.563 SGR 97,438 SP -19.031 ILO 3.607-/ ~ IbM - 3,668 SFL. U 4.180 PHI 4'1'5:53 RHOB:- 2045'000 FCNL 5 ~5..00.0 R 8.6 875 DT 9~.375 SP '19,0~1 THOR': '10 POTA ~:' CGR 67'375 SGR 94.688 8500.000 SP '23.375 I. LD ~,023 . ~L~.~ ~ .~.125~ SFLO 4.898 G9 76 ~3:'1 ].':' ',~ A/i~;i ,977 DRHO : : 0:33 PHI 29.V36 RHOB 2.396 NPAT 9~.844 NCNb 2~60.000 CND ~ 739.000 ]GR /:~.6~ : :'' 7.97 "~ 2.7 PI) TA 0,020 U R A N 2.006 C GR 60.813 '9'38 8400.OO0 SP -32.28t 1LD c . :> 50 3.844 GB 72.31.]. GR 65 813 . CALl 9 77] DRHO -0.006 ".: NPHI 39'8/93' ~': ;..R'.HOB '.: : ,:~..::~).2[ 59~. ~' :(:~:: ',N~AT']~:' ::-: · '-'3 ~ 40'~4':: '~:' NCNL ~ :2268.' 000 ~ ,,NL 65i,000 GR 72,~13 . DT 82,750 SP -32,281 THi]R · '~:'6 ;773.: '.' :..POTA ,: t':O,02 ~' ](~UR~N .'~" ~2'63I CGR 54' 62'5 SGR . 64.063 8 ~00. 000 SP -35. 438 ILD 1.8.~13 1L~t 22, ]~ 3 SFLU ~7. 750 : ~ ]GR 65 il 8'8' ' .GR.: ',,:, 56[:i ~.[CAL~ :DR,HO ,,,0 ~ 022 ~HOS 2,254 N~AT 3.258 ~CNL 1~92.000 GR: : :::/: : ~ :. 65 ~ ~.:88~~ (-~ ?: : :~ D:T~© 8:6 ~'563': S P: ' 352438 URAN 0.050 CGR 56.625 GR 109. 188 (;R 111.250 CALl 13.055 DRHO ~,0 005 NP~i ·: 5:2:; 3:44 · ' ' ~.'- 22 :.f:'!.::!! .NRAT , NCNL. 176,., ~ 000 [CNL 359.000 GR 109,1,80 DT 127,375 SP -14,406 THOR' . 1,0~ 43:0'::' "i ~:'' : 0.~9 O:~.:N:. :: :':5 i 965 C"GR 76.188 SGR 114 ..563 MNE~MUNIC VALUh MNEMONIC VALUE MNP.~MON 1C VALUE MNEMONIC VALUE 8100.000 SP -16.531 GR 107.938 NPHI 46.045 FCNL 433.500 THOR -999.250 SGP -999.250 IbD 1.757 ILM 1.808 GR 104.688 CALl 11.898 RH[)B 2.'~50 NRAI' 3.854 GR 107.938 DT 113.750 PI)TA -999.~50 URAN -999.250 SFLU 1.898 DRHO 0.039 NCNb 1748.000 BP -16.531 CGR -999.250 8000.000 SP -25.492 GR. 192.500 NPH! 49.609 FCNL 400.500 THOR -999.250 SGR -999.250 ILD 1.949 1bM 2.037 GR 197.250 CALl Il.q30 RHOB 2.412 NRAT 4.039 GR 192.500 DT 115.375 POTA -999.250 URAN -999.250 SFbU 2.426 DRHO 0.044 NCNb 1860.000 SP -15.492 CGR -999.250 7900.000 SP 13 992 34 GR NPBI 43 408 RHOB FCNL 476~500 GR G 999'250 498 ILM 1 55 95 23~.25t NRAT 3.701 .~75:: D.T I1~;563 -999.~50 URAN -999.250 SFLU 1.72~ DRHO 0.021 NCNb 1790.000 SP -13.992 CGR -999.250 7800.000 · SP -28.64! ILD 2"-785:.~' ' I'LM.' : ' 2:":830: SFLU GR 124.438 GR B 1]~?000 CALI 11.898 DRHO ~g ~(. L 465.250 GR .124.438 DT .113.563 SP UR:AN ,1,9:99::~:2:50:!:' SGR ~999.250 3-430 0.038 1890.000 7700,000 SP -12.383 ILD 2.721 !I,,M 2.850 SFLU .3.635 ~PHI 39,600 RHOB 2,299 ' NRAT 3,498 ~CNL 2062.000 ~ CN'L< :-". ::'9:~.~:~ 938 .~: :O.~-~' ~..:::':: :::~:- "' 12:' T}~OR -999,250 POTA 999.250 ORAN -~99',250 CGR -999.250 DR 0 0 019 Ft D 75 16 516 465 SFLU 1 468 234 0 FCNL DT 75 SP -38.438 8 :,R 999. 250 < .~ .: . ~ DEFTh 7300.000 7200.000 7100.000 7000.000 6900.000 ~NEMONIC VALUE 8P -25.594 GR 160.875 NPHI 47.314 FCNL 459.250 THOR -999.250 SGR -999.250 SP -16.781 GR 227.000 NPHI 46.338 FCNL 404.500 THOR -g99.250 SGR -999.250 SP -4.879 GR 156.625 NPH! 49.072 F'CNL 460.000 THOR -999. SP -4.668 G~. 162.250 NFHI 3:9'941 FCNL .5!~j 500 THOR' ;~;99 ;25'0 G $ .,~ 999. 250 .523 MNEMONIC VALIIE HN~MONI£ VALUE MNEMONIC VALUE ILD 1.905 ILM 2.025 SFLU 3.063 GR 154.625 CALl 11.641 DRHO -0.000 RHOB 2.322 N~AI 3.918 NCNL 1918.000 GR 158.125 DT 110.750 SP -32.531 POTA -999.250 URAN -999.250 CGR -999.250 iLD 2.109 ILM 2.197 SFLU 2.172 GR 216.750 CALl 11.055 DRHO 0.078 RHOB 2.344 NRAT 3.850 NCNb 1726.000 GR 201.250 D? 110.'750 SP -32.844 POTA -999.250 ORAN -999.250 CGR -999.250 GR1LD 13~ 709 ILM !.707 SFbU 1.551 ]875 CALl 11.313 DRHO 0.079 RHOB 2.375 NRAT 4.004 NCNL 1976.00~ GR 140.875 DT 103~750 SP -45.40 POTA -999.250 ORAN -999.250 CGR -999.250 ILD 2- ~i ~ILM:' : '2 711 St;L- 3 867 RGR 14~ ~75 1.~ 867 DRHO 0.023 HOB ~: :~3::0',1' . :':*.488' "NCNb : 1894,000 GR ,135.500 DT N .103.750 SP .-43.500 POTA -:... 999. 250 ':': 'ORA ::: · 799:9;~:50 CGR' 999'250 ' 805 NCNL 1.711.000 NPHI 45 166 R~OB 2.328 NRA't 3. FCNL: ':":407 ~ ~§0:':' ~:'G., ':,,."DT .,:.' .':. ': :',.I':1:2:~188""' :J ::'::,$P~::'::::': ,;~39,.:!56 I[.H.}~ 999.250 PUTA -9.99.250 ORAN -999.250 CGR -999.250 SGR:': ::: ~99'9',,~'50' I [~M SF U AT N( ,R 1 667 D' SP 9 DEPTH MNEMONIC VALUE 6500.000 6P -38 GR 98 NPHI ]6 FCNL 540 THOR -999 SGR -999 6400.000 SP -36 GR 76 NPHI 35 FCNL 554 THOR -ggg 8GR -g99 6300.000 SP -38 GR 79 NPHI FCNL 578 TH[IR -99~ SGR -99 6200.000 SP GR NPHI MNEMONIC VALUE MNEMONIC VAbUE MNEMONIC VALUE .781 ].LO 2.475 ILM 2.527 SFDU 2.494 .500 GR 92.250 CALl 11.563 DRHO 0.004 .035 RHOB 2.287 NRAT 3.289 NCNb 210o.000 .500 GR 85.688 DT 101.375 SP -42.594 .250 POTA -999.250 URAN -999.250 CGR -999.250 .250 .9~8 ILD 2.428 ILM 2.500 SFLU 2.820 .625 GR 72.688 CALl 11.531 DRHO 0.069 .986 RHOB 2.396 NRAT 3.285 NCNL 2024.000 .500 GR 76.313 DT 95.750 SP -42.406 .250 POTA -99g'250 URAN -999.250 CGR -999.250 .250 805 ILM 2.854 SFGU 2.656 406 ILD ~9'~8 GR 8 ~75 -CALl 11.531 DRHO 0.086 .62! RH{)B ~ 375 NRAT ~ 320 NCNb 2050.000 .000 GR 9 :el3 DT 9:750 SP -51.688 250 POTA -999.250 URAN -999.250 CGR -999.250 ]25'0 -38.766 ILD ~',~.178:: ::ILM': · 3.246 SFLU 108.063 GR 90.625 CALl 11.242 DRHO 33.-:i05 NCNb 3.299 THOR ,,9gg ] 2:,50': :~ SGR -999.250 -37.656 ILD 3.758 IbM 3.656 2.916 82~5'6'3 :...iGR'. ,'<76"688 0'026 NPHI 34 424 RHOB 2 252 N.RAT NCNb 2.324.000 FCNL :: .':656. 000" ~' .:GR' '.: ~'.: ~: :' '17'i~.:~ 993.191 TH R . 999 50 . POTA -999.250 URAN -999.250 CGR -999.250 N q 6 NCNL 2224 00 GR CAI 5.47 DRHO 0 038 FCNL 6~ GR 9 3 DT 000 38 D k P T ~ NNE~ONIC VALUE ~4N E,~-~ON IC VALUE 5~00,000 SP -55.250 ILD 3.4~9 GR 97.938 GR 96.500 NPHI 33.20] RHOB 2.385 FCNL 552.500 GR 91.125 THOR -999.~50 POTA -999.250 SGR -999.250 5600.000 SP -49.750 1LD 3.527 GR 94.125 GR 85.875 NPHI 38.330 RHOB 2.293 FCNL 559.000 GR 84.438 THOR -999.250 PUTA -999.250 SGR -999.250 5500.000 SP -44.688 ILD 2.881 G:R 92 ~063 GR 90.438 NPH]: 3?.842 RHOB 7~.262 FCNL 493'750 GR 7,750 THOR ~999.250 POTA -999.250 'SG:R 999-250 .... 5400. 000" SP "44 -438 ILD GR. 89. 125 GR 7.7 4 NPHI ' 4:'0 ': 7. 71 ~H'OB ~:28':'9 ~CNL ~417,250 GR . 76.750 THOR :" ': :i~;.':9:99 ~'!POT:A. NNEMf]N IC VALUE IL~ 3.422 CALI 13.492 NRA1 3.207 DT 103.563 URAN -999.250 ILM ].510 CALl 1.].453 NRAT 3.465 DT .109. URAN 999.~5050 ILM 809 3.430 108'563 URAN -999. 250 ,D 8 I M 3 NNEMONIC SFLU DRHO NCNL SP CGR SFLU DRHO NCNL SP CGR SFLU DRHO NCNL SP CGR SFLU SF] VALUE 3.795 0.103 1962.000 -38.844 -999.250 3.344 0.089 2041.000 -32.969 -999.250 2.330 0.050 187~.000 -2 i031 -999.250 2.666 38 N] -9' POTA NR 3 UR -~99 i0 S N( NL C R -999 Dc DRHO SP DtPTH MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE 4900.000 SP -76 GB 59 NPHI ]7 FCNb 723 THOR 8 SGR 56 .844 ILD 7.090 IbM 7.809 SFLU 9.203 .750 GR 60.094 CALl 11.172 DRHO 0.002 .988 R}{OB 2.117 NRA~ 3.387 NCNL 2654.000 .500 GR 5g.406 DT !14.375 SP -52.844 .219 POTA 0.O14 lJ~AN 0.723 CGR 57.219 .875 4800.O0O SP -51 GR 74 NPHI 40 FCNL 448 THOR 7 SGR 69 .000 GR 69.813 DT 116.563 SP -26.828 .629 POTA 0,019 oran 2.168 CGR 49.813 .06] 4700.000 SP -52. GR 81. NPHI 42. FCNL 458. THOR 938 ILD 5.000 1LM 4.809 SFLU 5.]71 375 GR 7].688 CAbI 12.461 DRHO 0.020 285 RHOB ~ ]22 NRAT 3.660 NCNb 1865.000 500 GR 7 '~000~ DT 110,56] SP -27.516 164 POTA 0.024 ORAN 2.7]6 CGR 57.438 5O0 4600 . 000 SP GR NPHI SGR -60'469. ILD 7:..02:0. :" 1bM; ' 6.688 SFLU 0.20] 4.1 88 GR 8 438 CALl 1].070 ORHO 0.072 '].262 NCNb I847.000 GR 96 B.13 DTN 11.7.375 SP -34.281 CGR ~ 61:.563 86.688 4500.0 }0 ~F -57 594 .!I~,D 666,]01 ILM 6.188 SFLU 6.215 :' :': :GR 7'~ !6'88'. . NPHI 38.916 RHOB .291 NRAT ~.55~ NCNL 2~26.000 · : ~ ::FCNL"": 4'91~000 .",. GR':~' :, :I~1:5:~'75:0:~~ :':SP ' : "39~625 T~OR . 7 758 POTA 0.0!8 ORAN 2.387 CGR 54.781 :: '. ' S'~;R ':: ' 68 ~ 06':~ I D] [0 0 D' 5 SP -40 4 ~8 -8 D RI B 9 T :] NCNb 2312 GR '0 GR 188 CALl FCNL i0 ;R DT 563 DE[TH ~,NLMf]N lC 4100.000 GR NPHI FCNL THtIR SGR 4000.O0O SP GR NPHI FCNL THOR SG~ 3900.000 BP GR NPHI FCNL THiJR SGR ]800,000: FCNI VALUE -86.188 36.28~ 43.311 531.5OO 3.408 31.844 -62.000 34.563 54.590 459.750 3.119 30.547 -43.313 71.000 44.482 491.500 6~ -578 '875 -52 -656 7 ,~. 8.7.5 :40 ,'7::23" MNEMONIC VALTIE MNEM[]NIC VALUE MNEMONIC VALUE ILD 6.680 ILH 8.781 SFLO 11.695 GR 30.063 CALl 9.031 DRHO O.015 ~HOB 2.076 NRAT 3.53~ NCNb 2045.000 GR 30.375 DT 135.000 SP -91.938 P(]TA 0.008 URAN 1.317 CGR 23.484 ILD 13.820 IbM 14.469 SFLU 14.852 GR 29 297 CALl 1,0.016 DRMO 0.000 RHOB 1~976 NRAT 4.242 NCNb 1912.000 GR 33.156 DT 135.375 SP -62.844 FOTA 0.009 URAN 1.557 CGR 21.516 ILD 7.582 ibm 7. 547 SFLU 7.625 GR 67,813 CALl 9,813 DRHO 0.011 RHOB NCNL 1348..~00 GR SP 40. 19 POTA CGR 50.125 ILD' <-: _8.664:':: '~- h' 8.81 3.'_ SFbU: 10-133 o.ooo 2':0 7: :/:, '.: ' ":'N'RA 4:~9.:.: ::'. NCNb '1988.000 ;R D 375 81 53 7 I M 7 N [vi NPHI 1 7 SF ,U 055 OB NR, T 3 5 N, INL 2084 000 FCNL ;R DT ~5 SI 58 969 MNEFil]NIC VAL[1E MNEMONIC VAb{IE MNEMONIC VASUE MNEMONIC VALUE 3300.0O0 SP -44.969 GR 57.281 NPH1 38.477 f'CNL 567,500 THOR 4.379 SGR 49.938 ILD 7.574 GR 52,906 RHOB 2,076 GR 47,500 POTA 0,018 IbM 7.785 CALl 10.430 NRAT 3.381 DT 130,000 URAN 1.442 SFLU 8.898 DRHO -0.013 NCNb 2050.000 SP -51,656 CGR 40.313 3200.000 SP -17.750 GR 72.313 NPHI 52.197 f'CNL 345.250 THOR 7.324 SGR 69.250 ILD 6.215 GR 73,813 BHOB 2. !13 6 :0 50 POTA ~ I6 IbM 5.684 CALI 1~.000 NRAT .195 DT 142.500 URAN 2.287 SFLU 4.602 DRHO -0.002 NCNb 1645.000 SP -33.125 CGR 48.063 3100.000 SP -29.594 GR 61.313 NPHI 43.750 ~CNL 443.75'0 GR 5 ]. 375 ILD ~,965 GR 5 ,875 CALI RHOB ~,082 NRAT GR 6 ,313 DT POTA 0,016 URAN · . 6,289 SFLU 3.871 11,203 DRHO 0,022 3,707 NCNb 1858.000 i36'750 SP -43.219 2.342 CGR 42.156 3000.0'00 8P '48.2.19:' ~ ' ILD GR 59,063. GR .FCNL 431 500 GR $GR 51.3,75 .07!8 NRAT.:' :' :.:'~::3: ~::~t< 1305,125 . SP -63.313 i,: 69::6:::: :C:GR' :' 4'3~ 500 -~1.06] ILD ;255. ]75 !L~ .2000. 000 :: ~,i;~:9'99.~ 250 NPHI '9992.5 00.0 RHOB ~999,2.50 . NRAT -999,250 NCNb '999,250 "781 SP': 03 ~::.:188 '[ C:NL~ : .' 99:9 .'250' : ':: '":' 'GR :::: .::: '~ .< :'--? .'::'::.':38 ~:8:1: :' ; THOR -999.250 POTA -999. 250.. [IRAN '999. 250 CGR -999.250 D: 999 0 S U -999 5O PO'~. U -' 0 C ;R 250 FCNB -~ 0 DT 999 250 SP .0 D~.'PTH 2500.000 2400.000 2300.000 2200.000 MNEM(JNiC VgLUE MNkMONIC VALIIE MNEMONIC VALUE MNEMONIC VALUE SP -999,250 ILD -999,250 IbM -999,250 SFLU -999.250 GP -999.25n GR -999.250 CALl -999.250 DRHO -999,250 NPHi -99925,000 RHOB -990,250 NRAT -999.250 NCNb -999.250 ~CNL -999.250 GR -999,250 DT -999.250 SP -999.250 THOR -999.250 POTA -999,250 URAN -999,250 CGR -999.250 SGR -999,250 SP -999.250 ILD -999.250 ILM -999.250 SFLU -999.250 GR -999.250 GR -999.250 CALl -999,250 DRHO -999.250 NPHI -99925.000 RHOB -999.250 NRAT -999.250 NCNb -999,250 FCNL -999.250 GR -999,250 DT -999,250 SP -999,250 THOR -999.250 POTA -999,250 URAN -999.250 CGR -999,250 SGR -999.250 SP -999,250 ILD -909.2.50 IbM -999.250 SFLU -999.250 GR -999.250 GR -999,250 CALl -999.250 DRHO -999.250 NPHI.-9~q'5~,000 RHOB -999 2.50 NRAT :999 ~50 NCNb -999,250 FCNL '250 GR -999:250' DT i999~ 50 SP -999.250 GR '9 992250 SP -9.99.250 SFLU 99 . 250 R . -999,250 GR -999 50 CALl -999,250 DRHO ~999.250 PHI -99'925~0.00 : -999 '~":NC:Nb ~999,250 ,250 ~ ,999,250 ~'CNL -999,250 GR -999 D ' -999,250 ': THO R' :' ';'~,'9:99 i 25 ' .'.PO T A'~,, 99 9: ~," ~DRA N.' ~'] ~ ':'~;,~:999~ ~:2 5::0 "999' 250 8G~ -999..25.0 2100.000 &P ~999 250 ILD ~999,250 =999,250 SFbU ~999,250 : ~. ]' : :G'R:- 999 ~ 25:0 ~R.':::' ~: :" ::~::<-':~?;':~,~999~- ~:25:0:'~ :~':', ::5;~-9 99 ~:~2:5.0 .DRHO: ;~, 99:9:." 250 NPHI -99925.000. ~HOB -999,250 NRAT -999,250 NCNL ~999.250 ', F:CN'h: '"' '-". 999 ~.:2'5,:0 '.~: ':.':: :'GR::~: :,: ::" :~'999:~25:0',~::.'::~~': :: D:T:" (':, :' ~ :"~J999'.:,~: ~50;: '. : .: SP'" :: ::: '9'9,:9:'250 THOR -999.250 PO.TA ,99,9,250 ORAN. -999.250 CGR -999.250 <: .:::: :'.'::. "::. ~:~,:R.-':G .: :: :..:.~'99 :,:'::~.'.::'::::::::(: :::/::::: :?::,::;: ?:..': :~'"::':::, ::~ ;. ::: ,: :: ,::' :::., ,,' ',: :':,' ' :: · : :: : -9 -999 50 GR 99' 50 D' ;0 SP -999 FC N b SGR -9 ,c 50 99' 0 I ~M S: -99 NP}]I -999: 0 RHOB -.~ 0 N] 999 N~INL -999 250 THO~.. -99~ 0 POTA N 999 !50 C 999 : GR 999 GR 99 iO C I 9 DI 0 -999 50 999 -999 250 0 $[ 250 8GR 999 !50 MNEMONIC VALUE ~NEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE 1.700.000 6P -44.03~ ILD 34.]75 ILM ]0.250 SFLU 40.781 GR 70.938 GR -999.250 CALI -999.250 DRHO -999.250 NPHI -99925.000 RHUB -999.250 NRAT -999.250 NCNb -999.250 f'CNL -999.250 GR -999.250 DT -999.250 SP -999.250 IHI)R -999.250 POTA -999.250 URAN -999.250 CGR -999.250 SGR -999.250 SP -bO.O00 ILD 187.250 IbM 211.125 Sf'bU 447.750 GR 35.40b GR -999.250 CALl -999.250 DRHO -999.250 NPHI -99925.000 RHOB -999.250 NRAT -999.250 NCNb -999.250 FCNL -999.250 GR -999.250 DT -999.250 SP -999.250 TH(IR -999.250 POTA -999.250 URAN -999.250 CGR -999.250 SG~ -999.250 1500.000 - 313 ILD . 50,719 ILM 45.750 SFLU 52.594 SP 5~500 GR ~999,1250 CALl -999.250 DRHO -999.250 GR 4 NPHI -9~925 00~ RHOB .999.250 NRAT 2999.250 NCNb -999.250 FCNL 999~25 GR 999,250DT' ,~999.250 SP -999.250 THOR -999 250 ?OTA -999.250 URAN -999.250 CGR -999.250 SGR -9'99~2'50 ~400.000 ~ :SP -54.78~ ILD: ~ '/I]7. ~.~ IbM }49.625:'' "- SFLU 338.750 GR 42 93B GR ~9.99.250 CALl -999.250 DRHO ]999.250 N'PHI '99'925~000'' .... - -' 999'250 fCNL :999 250 .GR :999,250 DT -999,250 SP :999,250 TH(]R~ C'GR i;,999'250 SGR -999.~50 ']9.03! ILD . 51..656 ILM . 38.656 SFLU . 62.938 37 ' 5'3 ~ ;GR:'. ;.,,~i~ 99i9 ~ 2'50 ~'~ LI<~ i' :i:' ~ ,~i,, 99'9; 2§'0 >: i · DR H 0 '" 999 ' ~ 5'0 NPHI-9~925,000 RHOB 2999.250 NRAT -999.250 NCNb -999.250 FC ~IL ' ~. '~; 999 ' 25 0.'" : ~ ~>~GR.-'~'~ ': ~.~. <' ~; ;~'999~ ~25>07 ~999~ ~RSO,-:: 'SP' :-:999' 250 T~{']R ~999.250 POTA ~999.2..50 URAN -999.250 CGR -999.250 · .-.:S'-'R~'. .", "999 ~,R:5:.~ :: :':: ': :::~::..:'.-~' > ::~ ~' :'::~::.: l 2:0'0. O00-;< <.. SP ,: "90 30 4 DRHO 9 9 0 -9~ GR DT SP 999 50 9 S 750 -' N NL -999 250 999 C ;R 9 250 C D] -999 50 DT Sf -¢ 250 DEPTH 900.000 ~00.000 700.000 ~I~EMONiC VALUE,'. MNEMONIC VALIIE MNEMON1C VALUE MNE.MDNIC VALUE 8P -92.188 ILD 106.000 iLM 68.06] SFLU 152.750 GR 48.8'1] GR -999.250 CALl -999.250 DRHO -999.250 NPHI -99925.000 RHOB -999.250 NRAT -999.250 NCNb -999.250 FCNL -999.250 GR -999.250 DT -999.250 SP -999.250 THOR -999.250 POTA -990.250 URAN -999.250 CGR -999.250 SGR -999.250 SP -115.250 ILD 79.063 ILM 54.188 SFLU 79.750 GP 57.281 GR 999.250 CALl -999.250 DRHO -999.250 NPH! -99925.000 RHOB ~999.250 NRAT -999.250 NCNL -999.250 FCNL -999.250 GR -999.250 DT 999.250 SP -999.250 THOR -999.250 PO.T~ -999.250 URAN ~999.250 CGR -999.250 SGR -999.250 SP -144.B75 ILD .137,250 SFLU .338.750 GR 53.21q GR 999,250 DRHO 999.250 NPHI -99925 000 RHOB 2999,250 NCNb -999.250 PCNL -9992250 GR ,1999,250 SP -999.250 THOR -999.,250 POTA -999,250 CGR -999.250 SGR -999.250 600 00.0.. : 8P -83.625 1:D, · 1.6:15.000::,:' : :. I~M 1:71'50:0 : : "8FbU ~63:6:.000 · GR 32.594. GR ~,9.99.2~0 ' CALl -999.250 DRHO ,999,250 NPHI -99925.000 : RHOB :NCNb ~999"250 FCNL 1999 250 GR ~999.250' DT -999,250 SP ~999,250 THOR CUR, '99'91250 SGR -999.250 -135 250 .. ILD ~332.000 i.L~ ~182.~75 8FbU ~940.000 2 $ ~ :]7'5:: ~::' ': :.: ::::' G:R".~' '.,.::: "::::';,;~;i'9:99' ~: '28 0:?! : 'J ':?:' ;iiii, 9'.9:9' 50 ':'~ :: ~'-':. :': D:RHO ' '~:' :" 9-99:' 250 FCNL -999 ;R 99 ;0 D~ SP -999 3 , l) ,0 99 .NPH NI -g N NL -999 -~ ;0 DRHO -99~ F('.NL 9 DT S~ -999 DEPTH 100.000 80,OOO MNEM()NIC VALUE MN E,~',(]N IC VALI]E MNEMON1C VALU~ MNEMONIC VALUE SP -152.625 1LD 2000.000 ILM 2000.000 SFLU 1.114 GR 23.906 GR -999.250 CALl -999.250 DRHO -999.250 NPHI -99925.000 RHUB -999.250 NRAT -999.250 NCNL -999.250 FCNL -999.250 GR -999.250 DT -999.250 SP -999.250 THOR -999.250 P(}TA -999.250 URAN -999.250 CGR -999.250 SGR -999.250 SP -q99.250 ILD -99q.250 ILM -999.250 SFLU -999.250 GR -999.250 GR -999.250 CALl -999.250 DRHO -999.250 NPHi -99925.000 RH00 -999.250 NRAT -999.250 NCNL -999.250 ~'CNL -999.250 GR -999.250 DT -999.250 SP -999.250 THOR -g99.250 POTA -9g9.250 URAN -999.250 CGR -999.250 SGR -999.250 ,SUM~AP¥- ~OF DAI:A RkC['II~D~ NiIMBE~ OF RECORDS: 1601 LENGTH OI~ RECORDS: 9!74 BYTES LENGI~H OF LAST PECO~D: 974 FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDiT .001 MAXIM[IN PHYSICAL RECURD LENGTH: NEXT FILE NAME: E O F TAPE TRAiLE? ' ,T'' 7TES LENG l-) .132 BY T.APE ':NAME i' '. 620l: TS~,RV1CE NA E.. EDIT APE CONTiNU. ArlON NU. BER~ 01 NEXT TAPE NAME: COMMENTS:' 1024 BYTES DATE ~: '.,. 81 ]:;?'17:/'2 3