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211-050
1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Tuesday, September 23, 2025 5:09 PM To:Scott Warner Cc:Donna Ambruz Subject:RE: [EXTERNAL] RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Scott. Cement on either plug at 3300 or 2815 is acceptable. Bryan From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, September 23, 2025 3:20 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Thanks Bryan. If we end up pushing fluid away and seƫng another plug prior to perforaƟng, can the cement be placed on that plug rather than the plug at 3300’? The plug will be set at ~2815’ if we end up needing to push fluid away and isolate the current intervals that are open. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, September 22, 2025 3:54 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Scott, Hilcorp has approval to add the additional perfs listed below on the condition that 25’ of cement is placed on the CIBP at 3300’ MD. Regards CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Bryan From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Monday, September 22, 2025 3:18 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, We’ve perforated up to the BEL 45 interval without success. I’m requesƟng approval to move forward with perforaƟng the remaining intervals listed in the sundry, which were previously not approved due to shallowest allowable perf calculaƟons. The highest CIBP currently set in the wellbore is at 3,300’ MD, leaving the BEL 50, 48, and 45 open. Depending on the fluid level, we may displace fluid with nitrogen and set an addiƟonal plug prior to perforaƟng the remaining intervals. Please let me know if you approve or have any concerns. Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:45 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Please distribute as necessary. Thank you. 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. 3 Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, September 22, 2025 3:54 PM To:Scott Warner Cc:Donna Ambruz Subject:RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Scott, Hilcorp has approval to add the additional perfs listed below on the condition that 25’ of cement is placed on the CIBP at 3300’ MD. Regards Bryan From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Monday, September 22, 2025 3:18 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, We’ve perforated up to the BEL 45 interval without success. I’m requesƟng approval to move forward with perforaƟng the remaining intervals listed in the sundry, which were previously not approved due to shallowest allowable perf calculaƟons. The highest CIBP currently set in the wellbore is at 3,300’ MD, leaving the BEL 50, 48, and 45 open. Depending on the fluid level, we may displace fluid with nitrogen and set an addiƟonal plug prior to perforaƟng the remaining intervals. Please let me know if you approve or have any concerns. Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 To help protect your priv acy, Microsoft Office prevented automatic download of this picture from the Internet. From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:45 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893 SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250813 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 24-06RD 50133204990100 206013 4/2/2025 YELLOWJACKET GPT-PERF MPB-24 50029226420000 196009 7/9/2025 READ CaliperSurvey MPB-34 50029235690000 216139 7/7/2025 READ CaliperSurvey MPF-45 50029225560000 195058 7/30/2025 READ CaliperSurvey ODSK-41 50703205850000 208147 8/9/2025 READ CaliperSurvey ODSN-25 50703206560000 212030 6/22/2025 READ CaliperSurvey ODSN-31 50703205650000 208003 8/11/2025 READ CaliperSurvey PBU 06-11A 50029204280100 225042 7/13/2025 BAKER MRPM PBU 13-19 50029206900000 181180 6/4/2025 HALLIBURTON WFL-TMD3D PBU 14-18C 50029205510300 225040 6/24/2025 BAKER MRPM PBU 14-43A 50029222960100 225041 7/30/2025 BAKER MRPM PBU C-01B 50029201210200 212053 7/19/2025 BAKER MRPM SD-07 50133205940000 211050 7/27/2025 YELLOWJACKET SCBL SP 12-S3 50629235130000 214067 7/18/2025 YELLOWJACKET PERF Please include current contact information if different from above. T40771 T40772 T40773 T40774 T40775 T40776 T40777 T40778 T40779 T40780 T40781 T40782 T40783 T40784 SD-07 50133205940000 211050 7/27/2025 YELLOWJACKET SCBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.15 10:11:56 -08'00' 1 Gluyas, Gavin R (OGC) From:Rixse, Melvin G (OGC) Sent:Monday, August 4, 2025 5:32 PM To:Scott Warner Cc:McLellan, Bryan J (OGC) Subject:20250804 1730 APPROVED TO PERF: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Scott, Hilcorp is approved to perforate per Sundry 325-362. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan McLellan From: Scott Warner <scott.warner@hilcorp.com> Sent: Monday, August 4, 2025 4:12 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, Attached is the CBL for SD-07. Requesting approval to proceed with perforations as per sundry. We are currently running a PNL log. Once that is complete, we plan to mill ~230' of cement to get to the lower proposed intervals and then blow the well dry with N2 in prep for perforating. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 2 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, July 22, 2025 5:17 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Scott, Hilcorp can include these perfs with Sundry 325-362, pending AOGCC review and approval of CBL results. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, July 22, 2025 3:34 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, Hilcorp would like to add a few additional sands to the already approved SD-7 sundry. We successfully completed the workover and plan to run the CBL this week. Once I have the CBL in hand I will forward on to you before beginning perforations. Well Name Zone Top MD Bottom MD Top TVD Bottom TVD Footage SD-07 BEL 51 ±3,310' ±3,330' ±2,139' ±2,148' ±20' SD-07 BEL 82 ±4,827' ±4,837' ±2,798' ±2,803' ±10' SD-07 BEL 120 ±6,511' ±6,521' ±3,530' ±3,535' ±10' SD-07 BEL 120 ±6,545' ±6,553' ±3,545' ±3,549' ±8' SD-07 BEL 133 ±6,642' ±6,656' ±3,587' ±3,593' ±14' Thanks, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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. 3 Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:45 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Rixse, Melvin G (OGC) To:Scott Warner Cc:McLellan, Bryan J (OGC) Subject:20250804 1730 APPROVED TO PERF: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Date:Monday, August 4, 2025 5:31:36 PM Scott, Hilcorp is approved to perforate per Sundry 325-362. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan McLellan From: Scott Warner <scott.warner@hilcorp.com> Sent: Monday, August 4, 2025 4:12 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, Attached is the CBL for SD-07. Requesting approval to proceed with perforations as per sundry. We are currently running a PNL log. Once that is complete, we plan to mill ~230' of cement to get to the lower proposed intervals and then blow the well dry with N2 in prep for perforating. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, July 22, 2025 5:17 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Scott, Hilcorp can include these perfs with Sundry 325-362, pending AOGCC review and approval of CBL results. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, July 22, 2025 3:34 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, Hilcorp would like to add a few additional sands to the already approved SD-7 sundry. We successfully completed the workover and plan to run the CBL this week. Once I have the CBL in hand I will forward on to you before beginning perforations. Well Name Zone Top MD Bottom MD Top TVD Bottom TVD Footage SD-07 BEL 51 ±3,310'±3,330'±2,139'±2,148'±20' SD-07 BEL 82 ±4,827'±4,837'±2,798'±2,803'±10' SD-07 BEL 120 ±6,511'±6,521'±3,530'±3,535'±10' SD-07 BEL 120 ±6,545'±6,553'±3,545'±3,549'±8' SD-07 BEL 133 ±6,642'±6,656'±3,587'±3,593'±14' Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:45 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Tuesday, July 22, 2025 5:17 PM To:Scott Warner Cc:Donna Ambruz Subject:RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Scott, Hilcorp can include these perfs with Sundry 325-362, pending AOGCC review and approval of CBL results. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, July 22, 2025 3:34 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, Hilcorp would like to add a few addiƟonal sands to the already approved SD-7 sundry. We successfully completed the workover and plan to run the CBL this week. Once I have the CBL in hand I will forward on to you before beginning perforaƟons. Well Name Zone Top MD Bottom MD Top TVD Bottom TVD Footage SD-07 BEL 51 ±3,310' ±3,330' ±2,139' ±2,148' ±20' SD-07 BEL 82 ±4,827' ±4,837' ±2,798' ±2,803' ±10' SD-07 BEL 120 ±6,511' ±6,521' ±3,530' ±3,535' ±10' SD-07 BEL 120 ±6,545' ±6,553' ±3,545' ±3,549' ±8' SD-07 BEL 133 ±6,642' ±6,656' ±3,587' ±3,593' ±14' Thanks, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 ScoƩ Warner Kenai – OperaƟons Engineer Office: (907) 564-4506 Cell: (907) 830-8863 To help protect your priv acy, Microsoft Office prevented automatic download of this picture from the Internet. From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:45 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Scott Warner Subject:RE: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Date:Tuesday, July 1, 2025 12:15:00 PM Attachments:image003.png Approved. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Monday, June 30, 2025 10:32 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Bryan, I am requesting a change to the approved sundry. Due to the low reservoir pressures we have I would like to pump 12.5 ppg instead of the 15.3 ppg. Everything else would stay the same. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:45 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-07 AOGCC 10-403 325-362 PTD 211-050 Approved 06-25-25 Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: N2 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,794'N/A Casing Collapse Structural Conductor Surface 2,470psi Intermediate 4,790psi Production Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng AS-1X Pkr; ZXP Pkr; and SSSV 3,212' MD / 2,096' TVD; 6,850' MD / 3,678' TVD and 445' MD/TV 7,883'3,711'2,309' Ninilchik Beluga-Tyonek Gas 20" 10-3/4" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINILCHIK UNIT S DIONNE 7CO 701C Same ~729psi See Schematic Length June 30, 2025 11,790'4,940' 3-1/2" 7,879' Perforation Depth MD (ft): 7,033' 4-1/2" See Attached Schematic 6,890psi 5,210psi 117' 3,757' 117' 1,697' Size 117' 7-5/8"7,033' 1,697' MD Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 3,315' 1,436' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0384372 / FEE-CIRI 211-050 50-133-20594-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY 8,430psi Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:21 am, Jun 16, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.13 17:25:40 - 08'00' Noel Nocas (4361) 325-362 X A.Dewhurst 20JUN25 Perforations above 1820' are not allowed as part of this sundry. BJM 6/24/25 10-404 BOP test to 3000 psi. Annular test to 2500 psi. DSR-6/18/25 Submit 3-1/2" liner CBL to AOGCC and obtain approval before perforating. Perform MIT on IA to 1500 psi once job is complete and well is on line, within 30 days. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.25 12:07:02 -08'00'06/25/25 RBDMS JSB 062625 Well Prognosis 02/01/2022 Well Name: SD-07 API Number: 50-133-20594-00-00 Current Status: Shut in Gas Well Permit to Drill Number: 211-050 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP Pre Workover: 943 psi @ 2144’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure Pre Workover: 729 psi Based on 0.1 psi/ft gas gradient to surface Maximum Expected BHP Post Workover: 1602 psi @ 3641’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure Post Workover: 1238 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.78 psi/ft using 15 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.78-0.1) = 1238 psi / 0.68 = 1820‘ TVD (Will not perforate above top of pool @ 1865’ MD) Top of Applicable Gas Pool: 1865’ MD/ 1511’ TVD Well Status: Shut in gas producer since September 2014 Brief Well Summary SD-07 was drilled and completed as a Tyonek gas well in 2011. The 2011-2012 wellwork operations included perforating and testing several Tyonek intervals but the well never produced over 150 mcfd. In 2013 the well was recompleted to access the Beluga sands. The BEL 51, 56, 59, 60, 100, and 110 were perforated over the course of a year with only the BEL 51 showing decent gas and pressure responses. All sands besides the BEL 51 were plugged back in July 2014 due to water and sand production. Ultimately the BEL 51 proved to also be making sand and by November 2014 the well sanded up and was shut in. The purpose of this sundry is to recomplete the well with a 3-1/2” monobore to lower required unload rates, allow the ability to selectively perforate individual zones that were bypassed and allow simpler plug options if needed. Notes Regarding Wellbore Condition x Inclination o Max deviation of 64° - sail angle of 64° from 1790’ - 7245’ MD o Max DLS of 5.6°/100’ @ 1293’ MD x Min ID o 2.813” @ 3211’ MD – X Nipple o 2.850” @ 445’ MD – SSSV o 2.992” – 3-1/2” tubing x Recent Tags o 5/30/25: Coil tubing cleaned out tubing from 2714’ to just below WLEG at 3331’ CTM/3340’ MD o 3/2/25: SL RIH w/ 2” x 6’ DDB to 2714’ KB. Bailed from 2665’ – 2714’ KB over two days Pre rig work: 1. MIRU Eline 2. PT Lubricator to 250/3000 3. RIH with tubing punch and punch tubing just below packer at ~3223’ MD 10-3/4" per Scott Warner 6/17/25 -bjm 0.68 = 1820‘ TVD Well Prognosis 02/01/2022 a. Bottom of AS1-X Packer is at 3220’ MD b. This is to bleed packer gas before tubing is pulled 4. RIH with tubing punch and punch tubing above packer at ~3208’ MD a. Top of AS1-x Packer is at 3211’ MD b. This is to allow circulation prior to pulling the packer 5. RDMO Eline Procedure: 1. MIRU 401 2. Install TWC, ND tree, NU BOP 3. Test BOPE ¾ Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 24 hours in advance of test to allow them to witness test). ¾ If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised, ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. ¾ BOPs will be closed as needed to circulate the well during this workover. 4. Pull TWC 5. Circulate well prior to pulling packer @ 3212’. Bullhead fluid to ensure well is dead as needed. a. Coil tubing cleaned out tubing from 2714’ to bottom of tubing at 3315’ MD prior to rig arrival b. Well should be liquid packed but ensure no gas has migrated since the cleanout 6. Pick up on hanger with short joint 7. Pull AS1-X 7-5/8” x 3-1/2” Packer a. Packer should’ve been set in compression b. Rotate ¼ turn to the right at the packer and pick up while holding right hand torque c. Internal bypass should open, allowing pressure to equalize d. Once pressure is equalized, continue to pick up to release the upper slips, relax elements and release the lower slips allowing packer to be removed e. If packer does not release, emergency release can be applied by 800-1000 ft-lbs of right-hand torque which will break the J-pin ring and allow the packer to be pulled. Do not move down hole if this is done as the packer will reset. 8. Circulate well upon packer release 9. Pull and lay down 3-1/2” tubing 10. MU cleanout assembly and cleanout 7-5/8” casing from top of fill to TOC at 3701’ MD a. Cleanout with junk mill if possible to avoid trip to surface after fill is cleanout b. Junk mill will be used to mill/cleanout cement on top of PosiSet plug at 3711’ MD 11. Mill cement on top of PosiSet plug from 3701’ - 3711’ MD a. Plug is in 64° of deviation- use caution when approaching 10’ of milling depth. Once milling depth has stalled and/or ROP has changed, verify depths and POOH b. Inspect mill on surface for indication that mill was working over top of PosiSet Plug Mandrel 12. MU washover shoe assembly and washover PosiSet plug at 3711’ MD a. Washover shoe should have enough length to swallow the distance from the top to the bottom slips. Length should be 22” but account for 36” to ensure top of tool to bottom slips can be swallowed 13. POOH and confirm PosiSet Plug has been removed a. Depending on what is recovered, additional clean out runs may be made using Overshots, Mills, Reverse Junk Baskets, etc. 14. MU cleanout assembly and cleanout 7-5/8” casing from top of fill estimated to be at 4054’ SLM to top of tubing cut at 6800’ MD (from SL tag on 7/15/14 prior to plug being set) 15. POOH Well Prognosis 02/01/2022 16. RIH w/ 3-1/2” tubing a. SSSV should be set at ~150’ MD b. Ensure sleeve is installed across SSSV prior to running tubing to prevent cement contamination during cement job c. Ensure centralizers are placed as per procedure i. 140 centralizers in total 17. RU cementers 18. Mix and pump ~15.3 ppg cement, taking returns up the 3-1/2” x 7-5/8” annulus 19. Planned TOC in 3-1/2” x 7-5/8” annulus = + 1500’ MD a. 3-1/2” capacity: 0.0087 bbl/ft b. 3-1/2” x 7-5/8” capacity: 0.0340 bbl/ft c. 180 bbls cement in 3-1/2” x 7-5/8” annulus d. 0.1 bbls cement in 3-1/2” tubing below retainer e. Total ~180 bbls cement 20. RDMO cementers 21. RDMO 401 Post Rig Work: 1. MIRU E-line and pressure control equipment. 2. RIH, tag float collar, and complete CBL (submit CBL to AOGCC and obtain approval prior to perforating) 3. RD E-line 4. MIT 3-1/2” x 7-5/8” annulus to 1500 psi for 30 min 5. MIRU Coil Tubing and pressure control equipment 6. PT BOPE to 250 psi low / 3,000 psi high a. Provide AOGCC 24hr notice for BOP test 7. RIH & clean out wellbore to float collar, displace liner to 8.4 ppg water if needed a. PU motor and mill at OE discretion if tag is high 8. Reverse out wellbore with N2 (~59 bbls) 9. Trap N2 pressure on tubing per OE/RE recommendation for perforating a. ~1200 psi applied trapped pressure = 20% underbalanced b. Confirm pressure with OE prior to RD 10. RDMO CTU E-line Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,000 psi high 3. RIH and perforate Beluga 5 – BEL 134 sands from bottom up with 2” 60 deg phased perf guns: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Bottom MD Top TVD Bottom TVD Footage BEL 5 ±1,867' ±1,931' ±1,512' ±1,540' ±64' BEL 10 ±1,986' ±2,009' ±1,564' ±1,574' ±23' BEL 13 ±2,032' ±2,067' ±1,584' ±1,599' ±35' BEL 16 ±2,152' ±2,187' ±1,636' ±1,651' ±35' BEL 20 ±2,230' ±2,240' ±1,669' ±1,674' ±10' BEL 23 ±2,280' ±2,291' ±1,691' ±1,696' ±11' 6790' of tubing displacement volume = 59 bbls. -bjm Perforations above 1820' are not allowed as part of this sundry. See shallowest allowable perf TVD calculation on page 1 of procedure. -bjm Well Prognosis 02/01/2022 BEL 25 ±2,312' ±2,323' ±1,705' ±1,710' ±11' BEL 25 ±2,336' ±2,345' ±1,716' ±1,719' ±9' BEL 30 ±2,368' ±2,382' ±1,729' ±1,736' ±14' BEL 45 ±2,818' ±2,845' ±1,925' ±1,937' ±27' BEL 48 ±2,970' ±3,008' ±1,991' ±2,008' ±38' BEL 48 ±3,078' ±3,088' ±2,038' ±2,042' ±10' BEL 50 ±3,241' ±3,261' ±2,109' ±2,118' ±20' BEL 53 ±3,446' ±3,466' ±2,198' ±2,207' ±20' BEL 54 ±3,542' ±3,558' ±2,240' ±2,247' ±16' BEL 54 ±3,574' ±3,593' ±2,254' ±2,262' ±19' BEL 54 ±3,602' ±3,625' ±2,266' ±2,276' ±23' BEL 56 ±3,763' ±3,802' ±2,336' ±2,353' ±39' BEL 65 ±4,269' ±4,309' ±2,686' ±2,573' ±40' BEL 70 ±4,395' ±4,409' ±2,611' ±2,617' ±14' BEL 73 ±4,505' ±4,518' ±2,659' ±2,664' ±13' BEL 74 ±4,558' ±4,581' ±2,682' ±2,692' ±23' BEL 75 ±4,628' ±4,654' ±2,712' ±2,723' ±26' BEL 78 ±4,666' ±4,676' ±2,728' ±2,733' ±10' BEL 82 ±4,837' ±4,859' ±2,803' ±2,812' ±22' BEL 83 ±4,885' ±4,896' ±2,824' ±2,828' ±11' BEL 88 ±4,926' ±4,943' ±2,841' ±2,849' ±17' BEL 90 ±4,979' ±4,987' ±2,865' ±2,868' ±8' BEL 90 ±4,996' ±5,008' ±2,872' ±2,877' ±12' BEL 91 ±5,126' ±5,138' ±2,928' ±2,934' ±12' BEL 92 ±5,277' ±5,296' ±2,994' ±3,002' ±19' BEL 92 ±5,327' ±5,354' ±3,016' ±3,028' ±27' BEL 95 ±5,578' ±5,592' ±3,125' ±3,131' ±14' BEL 95 ±5,597' ±5,624' ±3,133' ±3,145' ±27' BEL 95 ±5,639' ±5,649' ±3,151' ±3,156' ±10' BEL 96 ±5,736' ±5,750' ±3,194' ±3,200' ±14' BEL 97 ±5,752' ±5,771' ±3,200' ±3,209' ±19' BEL 98 ±5,840' ±5,859' ±3,239' ±3,247' ±19' BEL 98 ±5,871' ±5,885' ±3,252' ±3,258' ±14' BEL 99B ±5,995' ±6,019' ±2,437' ±3,316' ±24' BEL 100 ±6,123' ±6,143' ±3,362' ±3,370' ±20' BEL 115 ±6,306' ±6,326' ±3,441' ±3,450' ±20' BEL 120 ±6,413' ±6,423' ±3,488' ±3,492' ±10' BEL 134 ±6,766' ±6,780' ±3,641' ±3,647' ±14' a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate Well Prognosis 02/01/2022 c. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed e. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. f. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO 5. If necessary, run cap string to aid with water production if encountered post perforating. a. SSSV will be locked out at surface if cap string is run Post Perforation MIT: 6. Perform MIT on 3-1/2” x 7-5/8” annulus to 1500 psi once job is complete and well has been brought online within 30 days a. 7-5/8” casing set at 7033’ MD / 3757’ TVD b. .25 psi/ft x 3757’ TVD of casing shoe = 939 psi c. 1500 psi surface pressure is required Attachments: 1) Actual Schematic. 2) Proposed Schematic 3) Wellhead Diagram 4) Rig 401 BOP Diagram 13-5/8” 5) Coil Tubing BOP Schematic 6) Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Updated by SRW 6-5-25 SCHEMATIC Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Susan Dionne 07 PTD: 211-050 API: 50-133-20594-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-65 / PE 18.75 Surf 117' 10-3/4"Surface 45.5 / L-80 / BTC 9.95 Surf 1,697' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 7,033' 4-1/2"Liner 12.6 / L-80 / BTM Mod 3.958 6,850'11,790' TUBING DETAIL 3-1/2"Tubing 9.3#/ L-80 / IBT 2.992 Surf 3,315' JEWELRY DETAIL No Depth ID Item 1 445’2.850 SSSV (445’ TVD) 2 3,211’2.813 X Nipple 3 3,212’3.000 AS1-X 7-5/8” x 3-1/2” Packer (2096’ TVD) 4 3,315’3.000 WLEG 5 3,711’N/A PosiSet Plug w/ TOC @ ~3,701’ (7-16-14) 6 6,850'N/A ZXP Liner Packer w/ 10' Tieback Extension 7 6,881'N/A Flex-Lock Liner Hanger 8 8,300’N/A CIBP with TOC @ 8,263’. This is a 37’ plug 9 10,510'N/A CIBP 10 10,640'N/A CIBP 11 10,800'N/A CIBP 12 11,050'N/A CIBP 13 11,332'N/A CIBP 14 11,570'N/A CIBP PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status BEL_51 3,322’3,348’2,144’2,155’42 6/3/2013 Open BEL_56 3,736’3,762’2,324’2,336’50 6/20/2013 Isolated BEL_59 4,100’4,120’2,487’2,491’20 6/1/2014 Isolated BEL_60 4,191’4,209’2,522’2,530’18 6/1/2014 Isolated BEL_100 6,028’6,048’3,319’3,329’20 5/28/2014 Isolated BEL_110 6,202’6,214’3,396’3,401’12 5/28/2014 Isolated T-65 10,543'10,585'6,633'6,675'42'7/31/2012 Isolated T-10A 8,314’8,332’4,517’4,531’18’9/4/2012 Isolated T-10A 8,353’8,356’4,548’4,550’3’9/4/2012 Isolated T-67 10,640'10,645'6,730'6,735'5'Isolated T-69 10,681'10,694'6,770'6,783'13'6/25/2012 Isolated T-83 10,840'10,865'6,930'6,955'25'4/3/2012 Isolated 10,851'10,861'6,940'6,950'10'2/13/2012 Isolated 10,872'10,887'6,962'6,977'15'4/3/2012 Isolated T-90 11,101'11,111'7,191'7,201'10'12/3/2011 Isolated T-140 11,541'11,551'7,630'7,640'10'12/3/2011 Isolated T-140A 11,591'11,605'7,680'7,694'14'11/25/2011 Isolated OPEN HOLE / CEMENT DETAIL 10-3/4"13-1/2" hole cemented w/515 sks (231 bbls) 12 ppg Type I cement (50 bbls to surface) 7-5/8"9-7/8" hole cemented with 252 bbls 12.5 ppg Class G cement lead with 57.6bbls 15.8ppg class G tail cement. 10 bbls cement seen back at surface 4-1/2" Liner 6-3/4" hole cemented w/ 397 sks (181 bbls) 11 ppg Class G cement. Full returns during job INCLINATION DETAIL Sail angle of 64° from 1,790-7,245' MD _____________________________________________________________________________________ Updated by SRW 6-11-25 PROPOSED Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Susan Dionne 07 PTD: 211-050 API: 50-133-20594-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-65 / PE 18.75 Surf 117' 10-3/4"Surface 45.5 / L-80 / BTC 9.95 Surf 1,697' 7-5/8"Intermediate 29.7 / L-80 / BTC 6.875 Surf 7,033' 4-1/2"Liner 12.6 / L-80 / BTM Mod 3.958 6,850'11,790' TUBING DETAIL 3-1/2"Tubing 9.3#/ L-80 / IBT 2.992 Surf ~6,790’ JEWELRY DETAIL cont’d on pg 2 No Depth ID Item 1 150’2.81”SSSV (150’ TVD) PERFORATION DETAIL cont’d on pg 2 Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status BEL 5 ±1,867'±1,931'±1,512'±1,540'±64'TBD Proposed BEL 10 ±1,986'±2,009'±1,564'±1,574'±23'TBD Proposed BEL 13 ±2,032'±2,067'±1,584'±1,599'±35'TBD Proposed BEL 16 ±2,152'±2,187'±1,636'±1,651'±35'TBD Proposed BEL 20 ±2,230'±2,240'±1,669'±1,674'±10'TBD Proposed BEL 23 ±2,280'±2,291'±1,691'±1,696'±11'TBD Proposed BEL 25 ±2,312'±2,323'±1,705'±1,710'±11'TBD Proposed BEL 25 ±2,336'±2,345'±1,716'±1,719'±9'TBD Proposed BEL 30 ±2,368'±2,382'±1,729'±1,736'±14'TBD Proposed BEL 45 ±2,818'±2,845'±1,925'±1,937'±27'TBD Proposed BEL 48 ±2,970'±3,008'±1,991'±2,008'±38'TBD Proposed BEL 48 ±3,078'±3,088'±2,038'±2,042'±10'TBD Proposed BEL 50 ±3,241'±3,261'±2,109'±2,118'±20'TBD Proposed BEL 53 ±3,446'±3,466'±2,198'±2,207'±20'TBD Proposed BEL 54 ±3,542'±3,558'±2,240'±2,247'±16'TBD Proposed BEL 54 ±3,574'±3,593'±2,254'±2,262'±19'TBD Proposed BEL 54 ±3,602'±3,625'±2,266'±2,276'±23'TBD Proposed BEL 56 ±3,763'±3,802'±2,336'±2,353'±39'TBD Proposed BEL 65 ±4,269'±4,309'±2,686'±2,573'±40'TBD Proposed BEL 70 ±4,395'±4,409'±2,611'±2,617'±14'TBD Proposed BEL 73 ±4,505'±4,518'±2,659'±2,664'±13'TBD Proposed BEL 74 ±4,558'±4,581'±2,682'±2,692'±23'TBD Proposed BEL 75 ±4,628'±4,654'±2,712'±2,723'±26'TBD Proposed BEL 78 ±4,666'±4,676'±2,728'±2,733'±10'TBD Proposed BEL 82 ±4,837'±4,859'±2,803'±2,812'±22'TBD Proposed BEL 83 ±4,885'±4,896'±2,824'±2,828'±11'TBD Proposed BEL 88 ±4,926'±4,943'±2,841'±2,849'±17'TBD Proposed BEL 90 ±4,979'±4,987'±2,865'±2,868'±8'TBD Proposed BEL 90 ±4,996'±5,008'±2,872'±2,877'±12'TBD Proposed BEL 91 ±5,126'±5,138'±2,928'±2,934'±12'TBD Proposed BEL 92 ±5,277'±5,296'±2,994'±3,002'±19'TBD Proposed BEL 92 ±5,327'±5,354'±3,016'±3,028'±27'TBD Proposed BEL 95 ±5,578'±5,592'±3,125'±3,131'±14'TBD Proposed BEL 95 ±5,597'±5,624'±3,133'±3,145'±27'TBD Proposed BEL 95 ±5,639'±5,649'±3,151'±3,156'±10'TBD Proposed BEL 96 ±5,736'±5,750'±3,194'±3,200'±14'TBD Proposed BEL 97 ±5,752'±5,771'±3,200'±3,209'±19'TBD Proposed BEL 98 ±5,840'±5,859'±3,239'±3,247'±19'TBD Proposed BEL 98 ±5,871'±5,885'±3,252'±3,258'±14'TBD Proposed BEL 99B ±5,995'±6,019'±2,437'±3,316'±24'TBD Proposed BEL 100 ±6,123'±6,143'±3,362'±3,370'±20'TBD Proposed BEL 115 ±6,306'±6,326'±3,441'±3,450'±20'TBD Proposed BEL 120 ±6,413'±6,423'±3,488'±3,492'±10'TBD Proposed BEL 134 ±6,766'±6,780'±3,641'±3,647'±14'TBD Proposed OPEN HOLE / CEMENT DETAIL 10-3/4"13-1/2" hole cemented w/515 sks (231 bbls) 12 ppg Type I cement (50 bbls to surface) 7-5/8"9-7/8" hole cemented with 252 bbls 12.5 ppg Class G cement lead with 57.6bbls 15.8ppg class G tail cement. 10 bbls cement seen back at surface 4-1/2" Liner 6-3/4" hole cemented w/ 397 sks (181 bbls) 11 ppg Class G cement. Full returns during job INCLINATION DETAIL Sail angle of 64° from 1,790-7,245' MD _____________________________________________________________________________________ Updated by SRW 6-11-25 PROPOSED Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Susan Dionne 07 PTD: 211-050 API: 50-133-20594-00-00 PERFORATION DETAIL cont’d from pg 1 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL_51 3,322’ 3,348’ 2,144’ 2,155’ 42 6/3/2013 Isolated BEL_56 3,736’ 3,762’ 2,324’ 2,336’ 50 6/20/2013 Isolated BEL_59 4,100’ 4,120’ 2,487’ 2,491’ 20 6/1/2014 Isolated BEL_60 4,191’ 4,209’ 2,522’ 2,530’ 18 6/1/2014 Isolated BEL_100 6,028’ 6,048’ 3,319’ 3,329’ 20 5/28/2014 Isolated BEL_110 6,202’ 6,214’ 3,396’ 3,401’ 12 5/28/2014 Isolated T-65 10,543' 10,585' 6,633' 6,675' 42' 7/31/2012 Isolated T-10A 8,314’ 8,332’ 4,517’ 4,531’ 18’ 9/4/2012 Isolated T-10A 8,353’ 8,356’ 4,548’ 4,550’ 3’ 9/4/2012 Isolated T-67 10,640' 10,645' 6,730' 6,735' 5' Isolated T-69 10,681' 10,694' 6,770' 6,783' 13' 6/25/2012 Isolated T-83 10,840' 10,865' 6,930' 6,955' 25' 4/3/2012 Isolated 10,851' 10,861' 6,940' 6,950' 10' 2/13/2012 Isolated 10,872' 10,887' 6,962' 6,977' 15' 4/3/2012 Isolated T-90 11,101' 11,111' 7,191' 7,201' 10' 12/3/2011 Isolated T-140 11,541' 11,551' 7,630' 7,640' 10' 12/3/2011 Isolated T-140A 11,591' 11,605' 7,680' 7,694' 14' 11/25/2011 Isolated JEWELRY DETAIL contd on pg 2 No Depth ID Item 2 6,850' N/A ZXP Liner Packer w/ 10' Tieback Extension 3 6,881' N/A Flex-Lock Liner Hanger 4 8,300’ N/A CIBP with TOC @ 8,263’. This is a 37’ plug 5 10,510' N/A CIBP 6 10,640' N/A CIBP 7 10,800' N/A CIBP 8 11,050' N/A CIBP 9 11,332' N/A CIBP 10 11,570' N/A CIBP 1 McLellan, Bryan J (OGC) From:Scott Warner <scott.warner@hilcorp.com> Sent:Tuesday, June 24, 2025 12:42 PM To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] SD-7 (PTD 211-050) RWO sundry Bryan, Apologies, that’s correct—I mistyped and entered 6970 instead of 6790, which was incorrect. The correct displacement volume is 59.073 bbls. I had considered running a joint or two, similar to a standard open hole cement job. However, due to the proposed perforaƟon at 6766–6780 Ō / BEL 134, I was aiming to keep the Ňoat collar as low as possible. The next planned perforaƟon is at 6413–6423 Ō / BEL 120, and given the distance between the two, I felt that any potenƟal over- displacement—should the Ňoat equipment fail—would not pose a signiĮcant issue. ScoƩ Warner Kenai – OperaƟons Engineer Oĸce: (907) 564-4506 Cell: (907) 830-8863 To help protect your priv acy, Microsoft Office prevented automatic download of this picture from the Internet. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, June 24, 2025 12:31 PM To: Scott Warner <scott.warner@hilcorp.com> Subject: RE: [EXTERNAL] SD-7 (PTD 211-050) RWO sundry Scott, I get 59 bbls displacement for 6790’ of 3.5” tubing. Can you send your calculations to see where the discrepancy is? If you run a joint or two of tubing below your Ʋoat collar, you’ll be less likely to overdisplace and contaminate cement in the annulus. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <scott.warner@hilcorp.com> Sent: Tuesday, June 24, 2025 11:26 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] SD-7 (PTD 211-050) RWO sundry Bryan, Since we are in cased hole, I had planned to not have a shoe track/only running a Ňoat equipment to allow for the wiper plug to seat and prevent backŇow. Planned displacement is the 3-1/2” tubing volume/ ~61 bbls which is what should be required to bump the plug. Let me know if you need anything else. Thanks, ScoƩ Warner Kenai – OperaƟons Engineer Oĸce: (907) 564-4506 Cell: (907) 830-8863 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 23, 2025 3:20 PM To: Scott Warner <scott.warner@hilcorp.com> Subject: [EXTERNAL] SD-7 (PTD 211-050) RWO sundry Scott, I need a bit more detail about the cement job for this well. 1. Are you planning to install a shoe track in the 3-1/2” liner? If so, what is the length. 2. Please provide cement displacement calculations. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aI j - a .-0 Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Colo Items: ❑ Maps: rayscale Items: ‘s: ©R m RT roN 11(1p) I E Poor Quality Originals: ❑ Other: ❑ Other: IMPBY: Maria Date: v /s/ Project Proofing BY: AD Date: &//t7t/ILf.. /s/ ri4p 1 Scanning Preparation if x 30 = I ca0 + 1 8 = TOTAL PAGES 13 (Count does not include cover sheet) BY: Maria Date: lufpf... /s/ Production Scanning Stage 1 Page Count from Scanned File: ( 3 g (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: YES NO BY: +_ Date: g/ ` � `�' /s/ V14P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 0 NO _,-. TOTAL PAGES: (0 b Digital version appended by: Meredith Michel //IFDate: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: ao S Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o i o a I. 4 < d « O cn RJ ca in N Z 'C a - a) O N r- e) M U 2 O ^OO ( Z▪l N(/j go I Q 0 N. Z CO4* 0 J _ o > c Z a t Q N- (A _O 0) O a w o J a Q Z Q 76 � m 0) 0) m-101 °) (n °Q' (1) ID a`� U - `) o o _1 o ao m C m U 2 u) (n U Q O C C p E E T O a) •a) a) a) a) J d p O N O U Q 0) l.L LL LL lL it Z 1/3 C U d Ea ns 0 .c c c c c c a) m lI CO oIW p li •- O o 0 0 0 0 L0 Wp E I— U N J U p Q j Q >Q> Q j aa) ai m a0i CD ,_w U Ce J Z I E 1 E W 2 H 2 F- 2 H W W W W W N S ojU N N N N N a) a1 .. a d. Q - > N N N N 0 (n : as 0 � W CO Z Q m a ) N N N N N IX 0. 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E � o � J 0. Iii. 0 2 U U 1 CL c M O CC r C O m OV E Q `H` ? d0 = U °° " 7 sazoco _ N �O Cl) f0 C ~ o al _ z 03 v aCN 0 a)) E m n rn o I' E a) s '6, co t...) 1*1 V/ J p c a ) CC E Z o o g a G a •° m O �� Q Z Eo o 4 co 11 IIIIIIM Z Nii co z I o of /.g / in in c c1mi o E a IY V a) o Y v N r c h 0 o) I- ca a) 2 - g O A y o. 7 o E a E o Eo o aoi E E Zr) 2 0 a 0 1 U U IIIIMIMMINIIIIIIIIMIWIIIMMIMIIMIMIIIIIIIIMIWMIMIIIIIIMMIMIMMMIMI OF evw0�\\I%%jos,, THE STATE Alaska Oil and Gas ��`��_1�' 0fALAS� Conservation Commission '07 GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op Anchorage,Anchorage, Alaska 99501-3572 ALASMain: 907.279.1433 Fax: 907.276.7542 Mike Dunn Operations Engineer Hilcorp Alaska, LLC a 1 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Ninilchik Unit,Ninilchik Pool/SD Tyonek Underfined Gas Pool, Ninilchik Unit S Dionne 7 Sundry Number: 313-533 Dear Mr. Dunn: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, MaV64jT'V Cathy P. Foerster 4A Chair, Commissioner DATED this 10 day of October, 2013. Encl. iplikk RECEIVED STATE OF ALASKA .�p I� p C T 10 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION •I ( 1 r 7S /0)/0,a.., APPLICATION FOR SUNDRY APPROVALS AOGC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Q • Pull Tubing❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q • 211-050• 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Anchorage AK,99503 50-133-20594-00-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? 648 Will planned perforations require a spacing exception? Yes ❑ No 0 • Ninilchik Unit S Dionne 7 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0384372 d -&: .i cos- , 7,.,,;6, 4 Ninilchik Pool/SD Tyonek Undefined Gas Pool • 11• PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,794 • 7,883 , 8,263' 4,477' 8,263' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" 117' 117' Surface 1,697' 10-3/4" 1,697' 1,436' 5,210psi 2,470psi Intermediate 7,033' 7-5/8" 7,033' 3,757' 6,890psi 4,790psi Production Liner 4,940' 4-1/2" 11,790' 7,879' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 3,315' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): AS-1X 7-5/8"and SSSV 3,212'(MD)/2,096'(TVD)and 445'(MD)/445'(TVD) 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/7/2013 Oil ❑ Gas LI - WDSPL ❑ Suspended ❑ 16.Verbal Approval: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Dunn Email mdunnaa.hilcorp.com Printed Name ike D n Title Operations Engineer Ar Signature i/ Phone 907-777-8382 Date 10/7/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k3 — 533 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0— y b y 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /Q — 3 70 /2Tl � Submit Form and t� Form 10-403(Re ised 10/2012) Appr re lifajiQn 1 NdAlLmonths from the date of appro Attachments in Duplicate • Well Prognosis Well: SD-7 xilcorp Alaska,LLQ Date: 10/9/2013 Well Name: Ninilchik Unit Susan Dionne 7 API Number: 50-133-20594-00-00 Current Status: SI Gas completion Leg: N/A Estimated Start Date: October 14th, 2013 Rig: N/A Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Future Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 211-050 First Call Engineer: Mike Dunn (907)777-8382 (0) (907) 331-8228 (M) Second Call Engineer: Chris Myers (907)777-8333 (0) (907) 398-9955 (M) AFE Number: Current Bottom Hole Pressure: —1,506psi Maximum Expected BHP: —1,506psi @ 3,400' TVD Calculated using 0.443psi/ft gradient Max.Allowable Surface Pressure: —1,387psi (Based on 0.035 psi/ft gas gradient) Well Status Originally drilled and completed as a gas well in 2011.The well is currently flowing intermittently at 1,300Mcfd & "80Bwpd. The 2011-2012 well-work operations included perforating and testing several Tyonek intervals. The well flowed at low rates until the workover recomplete into the BLG 45 & 50. Initial rates were 3.1MMcfd at 495psi, but quickly dropped to 1.8Mcfd at 300psi. The well has begun to make more water (^'80bwpd) and has taken as many as 8 days to return to normal production after compression shut-downs. The additional perforations should improve the wells ability to maintain unloading rate. Summary Procedure: 1. RU E-line and test lubricator to 250psi low/2,500psi high. 2. Open well and flow the well at a rate that achieves an underbalance. 3. RIH with GR/CCL & perf guns and correlate on depth and perforate ±6,028' to ±6,052' and ±6,202' to ±6,218' (in that order,top down to minimize debris flow up the well)while flowing the well. WLOH. 4. Open well to the pre-perf choke setting. Measure flow and determine amount of additional flow. 5. With the Lead Operator,Contact Reservoir Engineer to determine if contingency perfs are to be added. 6. If contingency perfs are not to be added, RD E-line. 7. Turn well over to production supervision. Contingency: 1. If additional perfs are to be added: 2. RIH with GR/CCL& perf guns and correlate on depth and perforate ±4,102' to ±4,124', ±4,192' to ±4,230', ±4,272'to ±4,296'. (in that order,top down to minimize debris flow up the well)while flowing the well. WLOH. 3. RD E-line. 4. Turn well over to production &flow test well. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic • Ninilchik 14 SCHEMATIC Well: SusanField Dionne 07 1lacorp Alaska,LLC Last Cornoleted:7/2011 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm . x 20" Conductor 129.5/X-65/PE 18.75 Surf 117' 4, ' 10-3/4" Surface 45.5/L-80/BTC 9.95 Surf 1,697' t' .% 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 7,033' 4-1/2" Liner 9.3/L-80/8rd 3.958 6,850' 11,790' z0 * y TUBING DETAIL 1 q 3-1/2" Tubing 12.6#/L-80/IBT 3.958 Surf 3,315' s' *.e, a JEWELRY DETAIL M4* No Depth ID Item 10-a/4^" 11 1 445' 2.850 SSSV �I 2 3,211' 2.813 "X"Nipple '7,; mo2 `„ 3 3,212' 3.000 AS1-X 7-5/8"24-29.7#6.67 Packer >f a o= 4 3 4 3,315' 3.000 WLEG 4Y45 6,850' N/A ZXP Liner Packer w/10'Tieback Extension s;; 6 6,881' N/A Flex-Lock Liner Hanger 'I ' B-45 7 8,300' N/A CIBP iIT 8 10,510' N/A CIBP 1 t;° 9 10,640' N/A CIBP B-50 10 10,800' N/A CIBP ;« 11 11,050' N/A CIBP ,i 12 11,332' N/A CIBP V"' Y '+" 13 11,570' N/A CIBP 04 ,4 14 11,660' N/A Landing Collar ,4 15 11,703' N/A Float Collar IA Tubing cut @6,800 ., 16 11,790' N/A Float Shoe 2/19/2013 ,.' ':_ 5 PERFORATION DETAIL 6 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status B-45 3,322' • 3,348' 2,144' 2,155' 42 6/3/2013 Open s/8't 1 • _ B-50 3,736' . 3,762' 2,324' 2,336' 50 6/20/203 Open 7- T-095 10,543' • 10,585' 6,633' 6,675' 42' 7/31/2012 Isolated Minimum iO3.910@4-1/7'x,'' •' Cement Top T-03 8,314' • 8,332' 4,517' 4,531' 18' 9/4/2012 Isolated ppupjoint+/-6,900 `.4i -7240'MDw/Radial Bo„dlog T-03 8,353' • 8,356' 4,548' 4,550' 3' 9/4/2012 Isolated Tyonek 10,640' • 10,645' 6,730' 6,735' 5' Isolated r'*/ : T-095 10,681' • 10,694' 6,770' 6,783' 13' 6/25/2012 Isolated TOC @8,263' This is T., 37 plug '* 10,840' 10,865' 6,930' 6,955' 25' 4/3/2012 Isolated , s ey 7 T-110 10,851' ' 10,861' 6,940' 6,950' 10' 2/13/2012 Isolated " " 10,872' • 10,887' 6,962' 6,977' 15' 4/3/2012 Isolated c>. T-118 11,101' • 11,111' 7,191' 7,201' 10' 12/3/2011 Isolated LK 07 '1,1 _g, T-130-2 11,541' • 11,551' 7,630' 7,640' 10' 12/3/2011 Isolated 4q'- T-138 11,591' 11,605' 7,680' 7,694' 14' 11/25/2011 Isolated 'a csomax,8 'N 9 W OPEN HOLE/CEMENT DETAIL 110 10-3/4" 13-1/2"hole cemented w/515 sks(231 bbls) 12 ppg Type I cement ' 7-5/8" 9-7/8"hole cemented w/574 sks(235 bbls) 12.5 ppg Class G cement 4-1/2"Liner 6-3/4"hole cemented w/397 sks(181 bbls)11 ppg Class G cement. Full returns during job t INCLINATION DETAIL 11 V 2 "� `A"" KOP @ 300'MD/TVD 1. t Build 4.0°/100'from 300-1,790' 13 Hold 64°from 1,790-7,245'MD 1' •;' ,. Final angle of 0.9°@ TD of 11,794'MD !III t14 4-1/2"-„,,mL, -1/2"-„,,m as 16 5 TD=11,794' FBTD=11,660' MAX HOLE ANGLE=64°A 1,790' Revised By:TDF 6/27/2013 Ninilchik Field 14 PROPOSED Well: Susan Dionne 07 Ililcorp Alaska.LLC Last Comoleted:7/2011 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm If�, 20" Conductor 129.5/X-65/PE 18.75 Surf 117' I i+ :, A 1 10 3/4" Surface 45.5/L-80/BTC 9.95 Surf 1,697' k� 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 7,033' r y + 4-1/2" Liner 9.3/L-80/8rd 3.958 6,850' 11,790' 20" t 4 t 4 4-' TUBING DETAIL 1 1r 1 > 3-1/2" Tubing 12.6#/L-80/IBT 3.958 Surf 3,315' '' JEWELRY DETAIL No Depth ID Item lo-s/a""� 1 445' 2.850 SSSV «j 2 3,211' 2.813 "X"Nipple 2 ;" 3 3,212' 3.000 AS1-X 7-5/8"24-29.7#6.67 Packer tt=< !=.0, 3 4 3,315' 3.000 WLEG 111 5 6,850' N/A ZXP Liner Packer w/10'Tieback Extension 1f, ,* s, 1 6 6,881' N/A Flex-Lock Liner Hanger x,: B.45 7 8,300' N/A CIBP A 8 10,510' N/A CIBP 9 10,640' N/A CIBP ; B-50 10 10,800' N/A CIBP 11 11,050' N/A CIBP 12 11,332' N/A CIBP 71 &55'60865 13 11,570' N/A CIBP r 14 11,660' N/A Landing Collar 15 11,703' N/A Float Collar Tubing cut @6,800 >BLG1308130A 16 11,790' N/A Float Shoe 2/19/2013 i 9 *1 V op = � 5 PERFORATION DETAIL j� •.' 6 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status t:. III ' 1IIP B-45 3,322' 3,348' 2,144' 2,155' 42 6/3/2013 Open 7.50 i ;:B -50 3,736' 3,762' 2,324' 2,336' 50 6/20/203 Open BLG-55 4,100' ' 4,120' 2,483' 2,491' 20 Future Future Minimum ID:3.910@41/2'(`:• • Cement Top BLG-60 4,191' • 4,209' 2,522' 2,530' 18 Future Future ppuploinr+/-6,900 7 240'MD w/Radial - - �s BLG-65 4,272' • 4,299' 2,557' 2,569' 27 Future Future Y BLG-130 6,025' • 6,049' 3,319' 3,329' 24 Future Future P7 roc@&263 '-' BLG-130A 6,202' 6,220' 3,396' 3,404' 18 Future Future maisa 37 plug s �'I' T-095 10,543' 10,585' 6,633' 6,675' 42' 7/31/2012 Isolated . 1 s , , .7 T-03 8,314' 8,332' 4,517' 4,531' 18' . 9/4/2012 Isolated t `� T-03 8,353' 8,356' 4,548' 4,550' 3' 9/4/2012 Isolated Tyonek 10,640' 10,645' 6,730' 6,735' 5' Isolated '1- T-095 10,681' 10,694' 6,770' 6,783' 13' 6/25/2012 Isolated 10,840' 10,865' 6,930' 6,955' 25' 4/3/2012 Isolated 8 1-110 10,851' 10,861' 6,940' 6,950' 10' 2/13/2012 Isolated 10,872' 10,887' 6,962' 6,977' 15' 4/3/2012 Isolated io ,/,:',9 1-118 11,101' 11,111' 7,191' 7,201' 10' 12/3/2011 Isolated 1-130-2 11,541' 11,551' 7,630' 7,640' 10' 12/3/2011 Isolated or,' ,;js10 1-138 11,591' 11,605' 7,680' 7,694' 14' 11/25/2011 Isolated 'I111 if -11 OPEN HOLE/CEMENT DETAIL 10-3/4" 13-1/2"hole cemented w/515 sks(231 bbls) 12 ppg Type I cement 12 7-5/8" 9-7/8"hole cemented w/574 sks(235 bbls) 12.5 ppg Class G cement 1.1 A: 4-1/2"Liner 6-3/4"hole cemented w/397 sks(181 bbls)11 ppg Class G cement. Full returns during job , 13 ice* a INCLINATION DETAIL !15 KOP @ 300'MD/TVD 41/2" : !i 16 Build 4.0°/100'from 300-1,790' Hold 64°from 1,790-7,245'MD TD=11,794' PBTD=11,660' Final angle of 0.9°@ TD of 11,794'MD MAX HOLE ANGLE=64°A 1,790' Revised By:TDF 10/7/2013 STATE OF ALASKA • ALA6rNA OIL AND GAS CONSERVATION COMMI_.,,ON REPORT OF SUNDRY WELL OPERATIONS ! i_ 1 1.Operations Abandon Li Repair Well Li Plug Perforations L] Perforate U Other U Complete Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Name: Development D • Exploratory ❑ 211-050 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20594 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL00384372 Ninilchik Unit S Dionne 7 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): .10.Field/Pool(s): N/A Ninilchik Field/Beluga Undefined Gas Pool 11.Present Well Condition Summary: Total Depth measured 11,794' feet • Plugs measured 8,263 feet true vertical 7,883' feet Junk measured N/A feet Effective Depth measured 8,263' feet Packer measured 3,212 feet true vertical 4,477 feet true vertical 2,096 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" 117' 117' Surface 1,697' 10-3/4" 1,697' 1,436' 5,210psi 2,470psi Intermediate 7,033' 7-5/8" 7,033' 3,757' 6,890psi 4,790psi Production Liner 4,940 4-1/2" 11,790 7,879' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 3,315' 2,141' 3,212'(MD) 445'(MD) Packers and SSSV(type,measured and true vertical depth) AS-1X 7-5/8" SSSV 2,096'(TVD) 445'('TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 122 0 156 226 Subsequent to operation: 0 1,830 26 176 229 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory D Development Q - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑✓ - WDSPL❑ GSTOR ❑ WINJ ❑ 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: 313-057 Contact Chris Kanyer Email ckanyerahiIcorp.com Printed Name(in;2 .i Chris Kanyer Title Reservoir Engineer Signature Phone 907-777-8377 Date 6/27/2013 Form 10-404 Revised 10/2012 S'2/./3 RBDMS JUL - 8 2018ubmit Original Only Ninilchik Field II SCHEMATIC Well: Susan Dionne 07 Flacon,Alaska,LLC Last CornDleted:7/2011 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm N. 20" Conductor 129.5/X-65/PE 18.75 Surf 117' t * 10 3/4" Surface 45.5/L-80/BTC 9.95 Surf 1,697' i': 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 7,033' It 4-1/2" Liner 9.3/L-80/8rd 3.958 6,850' 11,790' 20" # 3. 4, TUBING DETAIL ' 1' 1 ►; ' 3-1/2" Tubing 12.6#/L-80/IBT 3.958 Surf 3,315' „1 JEWELRY DETAIL No Depth ID Item 10-3/4" to 1 445' 2.850 SSSV r. 2 3,211' 2.813 "X"Nipple ' 14 2 3 3,212' 3.000 AS1-X 7-5/8"24-29.7#6.67 Packer e'►' ►' 3 4 3,315' 3.000 WLEG w 5 6,850' N/A ZXP Liner Packer w/10'Tieback Extension r•,' * 6 6,881' N/A Flex-Lock Liner Hanger 3 615 7 8,300' N/A CIBP 8 10,510' N/A CIBP :• 9 10,640' N/A CIBP X50 10 10,800' N/A CIBP 11 11,050' N/A CIBP 12 11,332' N/A CIBP 13 11,570' N/A CIBP 14 11,660' N/A Landing Collar ..• 15 11,703' N/A Float Collar Tubing art @6,800' y,+ ,' 16 11,790' N/A Float Shoe 2/19/2013 = : 5 PERFORATION DETAIL lrt 6 Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 1' B-45 3,322' " 3,348' • 2,144' 2,155' 42 6/3/2013 Open 750 Ym t B-50 3,736' • 3,762' - 2,324' 2,336' 50 6/20/203 Open T-095 10,543' • 10,585' ' 6,633' 6,675' 42' 7/31/2012 Isolated Minimum ID:3.910@4-1/2" li Cement Top T-03 8,314' 8,332' 4,517' 4,531' 18' 9/4/2012 Isolated ppup joint-/-6,90tl -...0 , 7240'MD 'Radial •c d� -� T-03 8,353' 8,356' ' 4,548' 4,550' 3' 9/4/2012 Isolated Tyonek 10,640' • 10,645' • 6,730' 6,735' 5' Isolated -g: T-095 10,681' . 10,694' • 6,770' 6,783' 13' 6/25/2012 Isolated TDc@8,263' rn,s,sa '.4 37 plug ;1 j•ii 10,840' - 10,865' • 6,930' 6,955' 25' 4/3/2012 Isolated •"�'i 7 T-110 10,851' - 10,861' . 6,940' 6,950' 10' 2/13/2012 Isolated 'f, *, 10,872' 10,887' • 6,962' 6,977' 15' 4/3/2012 Isolated 1-118 11,101' - 11,111' • 7,191' 7,201' 10' 12/3/2011 Isolated T-130-2 11,541' ' 11,551' • 7,630' 7,640' 10' 12/3/2011 Isolated .¢ 1-138 11,591' 11,605' • 7,680' 7,694' 14' 11/25/2011 Isolated � a8 51,, 't OPEN HOLE/CEMENT DETAIL •d10 10-3/4" 13-1/2"hole cemented w/515 sks(231 bbls) 12 ppg Type I cement I * 7-5/8" 9-7/8"hole cemented w/574 sks(235 bbls) 12.5 ppg Class G cement i*+ 4-1/2"Liner 6-3/4"hole cemented w/397 sks(181 bbls)11 ppg Class G cement. Full returns during job ' ' 2 INCLINATION DETAIL KOP @ 300'MD/TVD Build 4.0°/100'from 300-1,790' t*° -.-- 13 Hold 64°from 1,790-7,245'MD `;; 'A'14 Final angle of 0.9°@ TD of 11,794'MD VA4-1/2,. , tf hte0 5 16 TD=11,794' PBTD=11,660' MAX HOLE ANGLE=64°(x)1,790' Revised By:TDF 6/27/2013 Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date Susan Dionne 07 50-133-20594-00 211-050 2/18/13 Daily Operations: 2/13/2013-Wednesday No operations to report. 2/14/2013-Thursday No operations to report. 2/15/2013- Friday No operations to report. 2/16/2013-Saturday No operations to report. 2/17/2013-Sunday PT to 250 low and 2500 psi high. Went in hole with 3.5" OD CIBP and tied into schematic. Joe had the perf log from Sep 2012.The collars wouldn't line up and it looked like were at least 14' off. The depth of the plug to set is 8,300'.The top perf is at 8,314'so not much room for error. Slickline didn't have any trouble running the dummy bridge plug thru the set of perfs so decided to go down past the two sets of perfs and back up through them to get get right plug depth. If we did hang up in perfs we could set plug and it would amount to a couple more runs with bailer. Went down past the perfs and logged back up.We were 17' deeper than the perf tie in log. Would have set plug 2 to 3' into perfs going by the way we tied into the schematic. Couldn't find a tally and the schematic doesn't tell you much as far as jewelry to tie into. Got on depth with perf log and set plug at 8,300'. Good set. POOH. Rig lubricator down. Secure well. Night crew will blow well down. Plan on dumping cement late morning. 2/18/2013- Monday Wait on fuel and Pollard Hot oil truck. Hot oiler took on 25 bbls of water. Heated water up to 80 degrees and pumped into the tubing. Bleed tubing to 0 psi. Rig up lubricator, pressure tested lubricator to 250 psi low and 2,500 psi high. Made two runs with a 3"x30' dump bailer filled with 15.6 ppg cement. Tagged plug at 8,300'. Dump bailed 25.8' of cement. Est TOC at 8,274'. Cement in place at 20:00 hrs. Rig down lubricator and move to SD-2. Notified AOGCC by e-mail that we were going to pressure test and tag at 22:00 hrs 2-19-13. 2/19/2013-Tuesday Pumped 129 total bbls of 80 deg water down 4-1/2"tubing mixed with some methanol. With 120 bbls away pumped 30 gal of diesel to freeze protect. Also had some methanol in water. Pressured up tubing to 2,200 psi and charted test for 1 hour. Test good. Rig up Pollard lubricator. Pressure tested to 250 psi low and 2,500 psi high. RIH with 3.50"spectrue jet ciutter,tie into plug setting log and tag top of cement at 8,263' (est TOC was 8,275'). Gives us 37' of cement on top of plug. Spotted cutter and severed 4-1/2"tubing at 6,800'. Looks like a good cut. POOH and rig lubricator down and clean up area. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SD-07 50-133-20594-00-00 211-050 2/14/13 Daily Operations: 3/13/2013-Wednesday No operations to report. 3/14/2013 -Thursday RU baker pump truck. Circulate well w/nxs-lube and n-vis mixed w/fsw. Pumped the whole job 2 bpm at 100 psi. Rd pump truck. Sifn. 3/15/2013- Friday No operations to report. 3/16/2013-Saturday MIRU. Set back pressure valve in hanger. ND tree. NU bops. 3/17/2013-Sunday Preparing for AOGCC BOPE test. State Rep.Jim Regg waived witness. Performed bope test, annular 250psi low/2,500psi high and BOP equipment 250psi low/3,000psi high. Removed back pressure valve.Screwed 4.5" pup into slick jt. Sooh Id 4.5"tbg. 3/18/2013-Monday FOOH Id 4.5"tbg. Recovered 161 jts and one cut piece. RU pollard wl. Ran gr/cbl log from 6,768'to 500'. RD wl.Tested 3.5" var pipe rams. Sih w/bit and scraper pu 3 .5"tbg. 3/19/2013 -Tuesday FIH pu 3 .5"tbg. Went down to 3,790' w/scraper. Cir well clean. Cir well w/clean KCL water. POOH w/scraper. Wih w/ 3.5" Class A completion setting. Set arrow set lx pkr at 3,211',eot at 3,315'and SSSV at 442'. Pressure test tbg and csg to 2,000 psi .Tested ok. Set back pressure valve . ND bope. NU tree. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SD-7 50-133-20594-00 211-050 2/18/13 Daily Operations: 5/29/2013-Wednesday No operations to report. 5/30/2013-Thursday No operations to report. 5/31/2013- Friday No operations to report. 6/1/2013-Saturday No operations to report. 6/2/2013-Sunday Hold PJSM. Discuss JSA. Spot open top tank. RU flow line to tank. RU slicklline unit. MU tool string 1-3/4" RS, 2-1/8" x 10 stem, LSSJ, OJ, 3-1/2" swab cups. Swab down 3-1/2"to 3070'kb. (30 runs). RD slickline unit. 6/3/2013-Monday JSA and PTW. Mobe equipment and rig up on well. Start pressure up tubing for perf. Arm gun. Pressure test lubricator to 250 psi low and 2,500 psi high. RIH with 2-1/2"x26' HC, 6 spf, 60 deg perf gun and ran a strip from 3,500'to 3,000'and tied into Pollard CBL/, dated 18-mar-13. We noticed that Haliburton log had 2 columns of CCL depths and they were different. Called town,sent the log we just ran to them to figure it out. Got it straight and spotted perf gun from 3,322'to 3,348' per Final Approved Peri Request Form dated 5/24/13 submitted by Geologist. Tubing pressure 500 psi when gun was fired. Tubing pressure started rising immediately and was at 660 psi in approx 5 min. POOH. All shots fired. Rig down lubricator and turn well over to production. Cleaned up work area.Tubing pressure was 745 psi. 6/4/2013 —Tuesday No operations to report. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SD-07 50-133-20594-00 211-050 2/18/13 6/20/13 Daily Operations: 6/19/2013-Wednesday No operations to report. 6/20/2013 -Thursday PTW and JSA. Spot equipment. Rig up lubricator and pressure test to 250psi low/ 2,500psi high. RIH with 2-1/2"x26' HC, 6 spf, 60 deg phase perf gun and tied into Pollard CBL/GR/CCL log dated 13-mar-13. Spotted gun from 3,736' to 3,762'. Well was flowing 7MMSCFD and tubing pressure was 450 psi. Fired gun and gained 10 psi pressure. POOH. Rig down lubricator and cleaned up work site. 6/21/2013 - Friday No operations to report. 6/22/2013 -Saturday No operations to report. 6/23/2013 -Sunday No operations to report. 6/24/2013 - Monday No operations to report. 6/25/2013 -Tuesday No operations to report. 11 Schwartz, Guy L (DOA) From: Tom Fouts <tfouts@hilcorp.com> 5—D Sent: Tuesday, May 28, 2013 1:22 PM To: Schwartz, Guy L (DOA) Subject: FW: SD-7 Perf interval update Attachments: SD 07 10-403 APPROVED 2-13-2013.pdf Guy. FYI. Tom Fouts I Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907)777-8398 Mobile: (907) 351-5749 From: Chris Kanyer Sent: Tuesday, May 28, 2013 1:04 PM To: Tom Fouts Subject: SD-7 Perf interval update SD-7 Sundry 313-057 Update: We will be perforating the SD-7 well (PTD#211-050) during the next week as part of work approved in sundry 313-057. We have completed all rig work(Sundry steps 1-14) prior to Eline perforating operations. We have been awaiting approval of a spacing exception prior to perforating. We plan to perforate the Beluga 45 &50, as planned, but have updated perforation intervals as follows: • Beluga 45: +/-3,322'to +/-3,348' • Beluga 50: +/-3,736'to +/-3,762' We plan to perforate the Beluga 45,flow test('cone week) and then add the Beluga 50 perfs. Please let me know if you have any questions. Chris Kanyer j Reservoir Engineer !Meng;Alawla. ckanyer@hilcorp.com Direct: (907) 777-8377 Mobile: (907) 250-0374 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) 50 Sent: Friday, February 15, 2013 10:31 AM To: 'Tom Fouts' Cc: Chris Kanyer; Clint Chanley; Larry Greenstein; Re James B DO Subject: RE: Susan Dionne 02 Sundry#313-058 & usan Dionne 07 Sundry#313-057 Tom, I did not catch that in reviewing the sundry. SD-7 has a ScSSSV currently and SD-02 doesn't. Requirement for ScSSSV is based on the wells proximity to public roads and waterways etc. per 20 AAC 25.265 (d)(2). I am assuming the wellheads already has a SVS system. Please provide me with some justification based on that regulation. ( maps and Arial photos etc) Please also send me diagrams of the current production tree and SVS systems. Guy Schwartz Senior Petroleum Engineer SCANNED APR 0 9 2013, AOGCC 793-1226 (office) 444-3433 (cell) From: Tom Fouts [mailto:tfouts@hilcorp.com] Sent: Friday, February 15, 2013 9:21 AM To: Schwartz, Guy L (DOA) Cc: Chris Kanyer; Clint Chanley; Larry Greenstein Subject: Susan Dionne 02 Sundry # 313-058 & Susan Dionne 07 Sundry# 313-057 Guy, I am contacting you clarify that both of the approved sundries for SD 02 and 07 do not include the installation of a SSSV. This email is to request a waiver/exemption for the installation of a SSSV for these wells. In the future we will include this type of request as a cover letter to the sundry to provide transparency. Sincerely, Tom Fouts I Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 2/19/2013 _ i3 • Ninilchik Field INE PROPOSED Well: Susan Dionne 07 xacornAl ,LLC Last Completed:7/2011 aska CASING DETAIL hh ?.. Size Type Wt/Grade/Conn ID Top Btm ad( i - vJ .,' -41 I 20" Conductor129,5/X-65/PE18,75 Surf 117° , 10 3/4" Surface 45.5/L-80/BTC 9.95 Surf 1,697' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf _ 7,033' • 4-1/2" Liner 12.6#/1-80/Hydril 563 3.958 6,850' 11,790' 20" TUBING DETAIL H la 4-1/2" Tubing 12.64/L-80/IBT 3.958 Surf ±3,300' JEWELRY DETAIL No Depth ID Item 3/4.,,4 ' la ±300' SSSV 1 ±3,200' Retrievable Packer 2 ±3,270' "X"Nipple ' y$ . 1 3 ±3,300 WLEG X 2 4 6,850' ZXP Liner Packer w/10'Tieback Extension lin 5 6,881' Flex-Lock Liner Hanger 3 :345 6 ±8,300' CIBP • 7 10,510' CIBP -•- 8 10,640' CIBP - 9 10,800' CIBP 10 11,050' CIBP 11 11,332' CIBP , 12 11,570' CIBP 13 11,660' Landing Collar 14 11,703' Float Collar 15 11,790' Float Shoe 4 PERFORATION DETAIL ° 5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status • I Pk" B-45 ±3,324' ±3,366' ±2,154' ±2,163' 42 Future Future 7_50' I� of.' ±3,524' ±3,557' ±2,232' ±2,246' 33 Future Future B-SO ±3,580' ±3,624' ±2,256' ±2,276' 44 Future Future fvininxn la.3.910 4-1/T,4 '',,� Cement ±3,731' ±3,781' ±2,322' ±2,344' 50 Future Future PPPP0t+/_6.901 - •+i 7,24CM)w/Radial .\ Bond Log 1-095 10,543' 10,585' 6,633' 6,675' 42' 7/31/2012 Isolated T-03 8,314' 8,332' 4,517' 4,531' 18' 9/4/2012 Isolated roc@xaz7s.ms:', 1:.• ,'!. T-03 8,353' 8,356' 4,548' 4,550' 3' 9/4/2012 Isolated a 2S phg Tyonek 10,640' 10,645' 6,730' 6,735' 5' Isolated 6 T-095 10,681' 10,694' 6,770' 6,783' 13' 6/25/2012 Isolated 10,840' 10,865' 6,930' 6,955' 25' 4/3/2012 Isolated j• T-110 10,851' 10,861' 6,940' 6,950' 10' 2/13/2012 Isolated :.;t: 10,872' 10,887' 6,962' 6,977' 15' 4/3/2012 Isolated 1i": ..ti 1-118 11,101' 11,111' 7,191' 7,201' 10' 12/3/2011 Isolated .,- ' 7 T-130-2 11,541' 11,551' 7,630' 7,640' 10' 12/3/2011 Isolated tom. a`.:8,6 1-138 11,591' 11,605' 7,680' 7,694' 14' 11/25/2011 Isolated OPEN HOLE/CEMENT DETAIL ....9 10-3/4" 13-1/2"hole cemented w/515 sks(231 bbls) 12 ppg Type I cement v,..; V. _ 7-5/8" 9-7/8"hole cemented w/574 sks(235 bbls) 12.5 ppg Class G cement t" 4-1/2"Liner 6-3/4"hole cemented w/397 sks(181 bbls)11 ppg Class G cement. Full returns during job tea A. INCLINATION DETAIL KOP @ 300'MD/TVD Build 4.0°/100'from 300-1,790' 5 - ,12 Hold 64°from 1,790-7,245'MD 13 Final angle of 0.9"@ TD of 11,794'MD 4-1/2"=7. i,•!" ',14 • 15 TD=11,794' PBTD=11,660' MAX HOLE ANGLE=64°0 1,790' Revised By:TDF 2/18/2013 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, February 13, 2013 4:08 PM To: 'Chris Kanyer' Cc: Shane Bennett-(C); Tom Fouts; Billy Applewhite-(C) Subject: RE: SD-7 PTD 211-050 Change in plug depth duly noted and approved. I will make a note in our well file. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Chris Kanyer [mailto:ckanyer@hilcorp.com] Sent: Wednesday, February 13, 2013 3:20 PM To: Schwartz, Guy L (DOA) Cc: Shane Bennett- (C); Tom Fouts; Billy Applewhite- (C) Subject: SD-7 PTD 211-050 Guy, After additional review of the Ninilchik Unit Susan Dionne 7 well's information (PTD 211-050)for sundry submitted on 2/4/2013,a CIBP was set at 10,510'and perforations were added by Marathon in September 2012 in the Tyonek at 8,314-8,332'and 8,353-8,356' 6 SPF 60 degree phasing.This changes only our set depth of our CIBP from 10,500'to 8,300'MD(4,506'TVD) . The pressure test of this plug w/ 25'of cement will remain at 1,500psi (4,506'x.25psi/TVD ft= 1,127psi). Please let me know if you have any questions. Chris Kanyer Reservoir Engineer M Description: HAK_Logo ckanyer@hilcorp.com Direct: (907) 777-8377 Mol)ile: (x)07) 250-0371- 2/13/2013 50-03742/13/2013 („4) �I j�7 st THE STATE Alaska Oil and Gas °fALAsKA Conservation Commission GOVERNOR SEAN PARNELL �wa 333 West Seventh Avenue O�;�mm m•. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Shane Bennett Operations Engineer Hilcorp Alaska, LLC a ( I - 0 5V 3800 Centerpoint Drive Anchorage, AK 99503 Re: Ninilchik Field, Beluga Undefined Pool, S Dionne 7 Sundry Number: 313-057 Dear Mr. Bennett: 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, oit Cathy P. F. rster Chair DATED this / day of February, 2013. Encl. colot. RECEIVED • STATE OF ALASKA ASP�5 FEB 0 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION a. APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1 Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑✓ • Perforate Q ' Pull Tubing 0 Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other. Complete 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 ` 211-050 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Anchorage AK,99503 50-133-20594-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 648 Will planned perforations require a spacing exception? Yes ❑ No 0 . Ninilchik Unit S Dionne 7 • 9.Property Designation(Lease Number): 10.Field/Pool(s):SRI f E(r cje" L4' h�:xl ADL0384372 Ninilchik Pool/SD Gas Pool / z--2 .(3 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): 11,794 r 7,883 • 10,640 6,730 10,640, 10,800, 11,050,11,332& N/A 11,570 Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" 117' 117' Surface 1,697' 10-3/4" 1,697' 1,436' 5,210psi 2,470psi Intermediate 7,033' 7-5/8" 7,033' 3,757' 6,890psi 4,790psi Production Liner 4,940' 4-1/2" 11,790' 7,879' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,543-10585 6,633-6,675 4-1/2" 12.6#/L-80 6,861 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Packer and Baker TE-5 SCSSV 6,850(MD)/3,678(TVD)and 166(MD)/166(TVD) Pe ,IN .-12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development Li •Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/18/2013 Oil ❑ Gas Q WDSPL ❑ Suspended ❑ 16.Verbal Approval: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 1 7.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chri Myers Email cmvers(fahiIcorp.com Printed Name y, - Ben ett • Title Operations Engineer Signature �i!i-Gr Phone 907-777-8425 Date 2/4/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Ti./. Mechanical Integrity Test ❑ Location Clearance ❑ tither. - • * lei o , o`1.s Go�-. f,nJ o•. s �s r.,-1 i.-is�o� %z, 4J/, • ✓ ,4-p4 --- Spacing Exception Required? Yes ❑ No M Subsequent Form Required: /D— `io`l RBDMS FEB 13 gIEIA APPROVED BY Lpproved by: j____a___ .....,_..., COMMISSIONER THE COMMISSION Date: 2-/ 3 13 Submit Form andOoR �7 o ( is of 12 Approved application is valid for 12 months from he date of approval. Atta ments i D plicate i�^,� J Well Prognosis , Well: SD-7 llilcorp Alaska,LI) Date:2/4/2013 Well Name: Ninilchik Unit Susan Dionne 7 API Number: 50-133-20594-00-00 Current Status: SI Gas completion Leg: N/A Estimated Start Date: February 20, 2013 • Rig: Cloverleaf Rig 4 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 211-050 First Call Engineer: Shane Bennett ✓ (907)777-8425 (0) (325) 203-7487 (M) Second Call Engineer: Chris Myers (907)777-8333 (0) (907) 398-9955 (M) AFE Number: Current Bottom Hole Pressure: –2,881 psi Maximum Expected BHP: –2,881 psi @ 6,654' TVD Calculated using .433psi/ft gradient Max.Allowable Surface Pressure: –2,455 psi — (Based on 0.064 psi/ft gas gradient) e36 ,0 Brief Well Summary This well was drilled and completed as a gas well in 2011.The 2011-2012 wellwork operations included perforating and testing several Tyonek intervals.The well is flowed at low rates since 2012. The proposed completion plan isolating the Tyonek perfs (10,543'-10,585')with a bridge plug in the liner and dump bailing a 25 ft of cement on top of the plug. After pressure integrity of plug back isolation of the Tyonek intervals,the 4.5"tubing will then be cut and pulled from above the ZXP liner top packer. A new 4.5"tubing& packer completion will be run to test the shallower Beluga intervals. Summary Procedure 1. RU E-line and test lubricator to 250psi low/2,500psi. 2. RIH and set bridge plug at+/- 10,500'to isolate the open Tyonek perfs(10,543'top of perfs). Dump bail 25' of cement on top of plug and pressure test t2,5fipsi. l/ 3. RIH and tag TOC at+/- 10,475. __ 2006 �0 5 2.843 ,,t;'") 4. RIH and cut 4.5" tubing at+/-6,800'. i`44, tJal4c4-. 5. RD Eline. g.), 6. RU Cloverleaf Rig 4�e TLi_ Ywc. f►-oN^ Q`!"" 7. Set two way ch, ke'c ND Tree. 4 8. NU BOP and pressure test BOP to 250 psi low/3,000 psi high. (/�� -(a Z Soo? 9. POOH with 4.5" tubing from seallkre in ZXP liner top packer at 6,850'. 10. RU E-line and RIH GR/CBL,from 6,g50'� t500'. 11. RD E-line. L"` 54"0 , 12. RIH with x nipple, retrievable packer at+/-3,200',tubing tail to+/-3,300'. 13. Land tubing in hanger and set retrievable packer. 14. ND BOP and NU tree. 15. RU E-line and test lubricator to 250psi low/2,500psi. . 16. Perforate the Beluga 45 &50 sand at+/-3,324'to+/-3,366',+/-3,524'to+/-3,557',+/-3,580'to+/- , 6 3,624'and +/-3,731'to+/-3,781'. 17. RD Eline. 18. Turn well over to production &flow test well. Well Prognosis Well: SD-7 Ililcorp Alaska,LI) Date:2/4/2013 Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic • Ninilchik Field SCHEMATIC Well: Susan Dionne 07 gacornauu a,LLC Last Cornoleted:7/2011 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm ji i 1 20" Conductor 129.5/X-65/PE 18.75 Surf 117' 10-3/4" Surface 45.5/L-80/BTC 9.95 Surf 1,697' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 7,033'#/L-80/Hydril 563 3.958 6,850' 11,790' zd' ti 4-1/2" Liner 12.6" 4 TUBING DETAIL k,, 1 >' ' f 4-1/2" Tubing 12.6#/L-80/IBT 3.958 Surf 6,861' ; i his 04 JEWELRY DETAIL No Depth ID Item 2 1 166' 3.958 Baker TE-5 SCSSV(5K Equalizing) 10-3/4"" 2 1,514' Baker Chemical Injection Nipple 1'4i3 6,850' ZXP Liner Packer w/10'Tieback Extension 1 4 6,881' Flex-Lock Liner Hanger 5 10,640' CIBP v.' 6 10,800' CIBP 7 11,050' CIBP ka 8 11,332' CIBP 1' 9 _ 11,570' CIBP irkj , 10 11,660' Landing Collar 11 11,703' Float Collar 12 11,790' Float Shoe 0 PERFORATION DETAIL .... ' x u� 4 6gOD Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 5 4 T-095 10,543' 10,585' 6,633' 6,675' 42' 7/31/2012 Open ' .. Tyonek 10,640' 10,645' 6,730' 6,735' 5' Isolated 3 1-095 10,681' 10,694' 6,770' 6,783' 13' 6/25/2012 Isolated 10,840' 10,865' 6,930' 6,955' 25' 4/3/2012 Isolated T-110 10,851' 10,861' 6,940' 6,950' 10' 2/13/2012 Isolated II 4 J J 10,872' 10,887' 6,962' 6,977' 15' 4/3/2012 Isolated 7.5/8- .• , - 1-118 11,101' 11,111' 7,191' 7,201' 10' 12/3/2011 Isolated T-130-2 11,541' 11,551' 7,630' 7,640' 10' 12/3/2011 Isolated Mininum ID:3.910@4-1/2,,r 1`f Cement Top T-138 11,591' 11,605' 7,680' 7,694' 14' 11/25/2011 Isolated ppuploint+/-6,903, '''' 74CIMD w/Radial -fiord Lag r,,;, ,,� OPEN HOLE/CEMENT DETAIL *i T.*41 10-3/4" 13-1/2"hole cemented w/515 sks(231 bbls) 12 ppg Type I cement 7-5/8" 9-7/8"hole cemented w/574 sks(235 bbls) 12.5 ppg Class G cement 't u; 4-1/2"Liner 6-3/4"hole cemented w/397 sks(181 bbls)11 ppg Class G cement. Full returns during job INCLINATION DETAIL 1.j..4 KOP @ 300'MD/TVD Build 4.0°/100'from 300-1,790' Hold 64°from 1,790-7,245'MD { Final angle of 0.9°@ TD of 11,794'MD f!6 I'p;` Y' , it 4 /c11 4 +1/2" ' ,*S 211 TD=11,794' PBTD=11,660' MAX HOLE ANGLE=64°A 1,790' Revised By:TDF 1-18-2013 Ninilchik Field PROPOSED Well: Susan Dionne 07 ���Alaska ,>�c., 11 Last Comoleted:7/2011 CASING DETAIL J SType Wt/Grade/Conn ID Top Btm C 20"ize Conductor 129.5/X-65/PE 18.75 Surf 117 10-3/4" Surface 45.5/L-80/BTC 9.95 Surf 1,697' 7-5/8" Intermediate 29.7/L-80/BTC 6.875 Surf 7,033' Zo 4-1/2" Liner 12.6#/L-80/Hydril 563 3.958 6,850' 11,790' v 4 TUBING DETAIL j 4-1/2" Tubing 12.6#/L-80/IBT 3.958 Surf ±3,300' 4 i ,, JEWELRY DETAIL 0 No Depth ID Item lo-3/4"" s 1 ±3,200' Retrievable Packer 2 ±3,270' "X"Nipple 04 3 ±3,300 WLEG 3. _" .t 1 4 6,850' ZXP Liner Packer w/10'Tieback Extension 25 6,881' Flex-Lock Liner Hanger kAiit '' �U\ U 6 ±10,500' CIBP 3 ,. B-45 /aq 7 10,640' CIBP f' J 8 10,800' CIBP 9 11,050' CIBP .-J B-J0 - E-_,.....:..- 10 11,332' CIBP 11 11,570' CIBP 12 11,660' Landing Collar iP,. 13 11,703' Float Collar 14 11,790' Float Shoe " 1 ' PERFORATION DETAIL 1f ' Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date ' Status 1+- , 4 B-45 _ ±3,324' _ ±3,366' ±2,154' ±2,163' 42 Future Future f 5 ±3,524' ±3,557' ±2,232' _ ±2,246'c33 Future Future IC •�. • B-50 ±3,580' ±3,624' ±2,256' ±2,276' 44 Future Future ±3,731' ±3,781' ±2,322' ±2,344' 50 Future Future 7-5/8" - T-095 10,543' 10,585' _ 6,633' 6,675' 42' 7/31/2012 Isolated � n<To Tyonek 10,640' 10,645' 6,730' 6,735' 5' Isolated b5ninum 163910@41/Y'j. " P ppupjoint+/-6,900 ,..ti - ' 2,240'MD w/Radial T-095 10,681' 10,694' 6,770' 6,783' 13' 6/25/2012 Isolated ` Bond 10,840' 10,865' 6,930' 6,955' 25' 4/3/2012 Isolated T-110 10,851' 10,861' 6,940' 6,950' 10' 2/13/2012 Isolated ,04 , 10,872' 10,887' 6,962' 6,977' 15' 4/3/2012 Isolated 4,.; T-118 11,101' 11,111' 7,191' 7,201' 10' 12/3/2011 Isolated 1-130-2 11,541' 11,551' 7,630' 7,640' 10' 12/3/2011 Isolated tk, T-138 11,591' 11,605' 7,680' 7,694' 14' 11/25/2011 Isolated TCC @±10,,475 Ms N 4 Dazs plug • .4HOLE/CEMENT DETAIL tai ,6 10-3/4" 13-1/2"hole cemented w/515 sks(231 bbls) 12 ppg Type I cement 7-5/8" 9-7/8"hole cemented w/574 sks(235 bbls) 12.5 ppg Class G cement @ `7 4-1/2"Liner 6-3/4"hole cemented w/397 sks(181 bbls)11 ppg Class G cement. Full returns during job • , `$ INCLINATION DETAIL rF KOP@300'MD/TVD Build 4.0°/100'from 300-1,790' h Hold 64°from 1,790-7,245'MD , 0 Final angle of 0.9°@ TD of 11,794'MD x 1 ""'12 .r 4-1/2"?' ,+E 1.-'11:413 TD=11,794' PBTD=11,660' MAX HOLE ANGLE=64°A 1,790' Revised By:TDF 2/5/2013 . II Ninilchik Unit 2013 BOP Stack Hi1M,rp Alaska,IAA. Knight Oil Tools Rental 02/05/2013 Ninilchik Unit SD#7 Cloverleaf#4 BOP 1111111111 3.98' 0 0 11 1 'i i l[ 11 in Vr III 1.11111 1-111 1.11 Clw-u ( ' 4 54' ®® ENNIS 2 7/8-5 variables 0 11"-5000 IP ::i - Blind _ III 1 II 06ykl,+ Choke and Kill valves •�2�1i .. - - A1116p� 21/1610M �i76 s7o 9P,`1�6 One Handwheel Sil 41 0 ti One HCR IP 111 1.11 11,1 111 1-1114 m 2.00' ,. ( 't w/2 : ..EFO& L 1 )f Cw _ 'i1 lb � . #' 1 1.111.11111 - . a L,_ Page 1 of 1 `Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, February 08, 2013 4:47 PM To: 'Shane Bennett-(C)' Cc: Keith Elliott; Chris Myers; Chris Kanyer; Billy Applewhite-(C); Regg, James B (DOA) Subject: RE: 403's SD-2 and SD-7 (PTD 204-107 and PTD 211-050) Shane, a4 You have verbal approval to proceed with the preliminary E-line work as outlined in your Y4 • submitted sundry applications for S Dionne-2 and S Dionne-7 . As we discussed submit the Cloverleaf 4 rig package as soon as possible. We will need that ' A ., before the rig inspection so we have time to review and comment. ,-- frr Regards, \ v/ • �" Guy Schwartz 1 A Senior Petroleum Engineer AOGCC , pitr, 793-1226 (office) , i 444-3433(cell) • `/ ' From: Shane Bennett- (C) [mailto:sbennett@hilcorp.com] /,e \ Sent: Friday, February 08, 2013 4:28 PM # To: Schwartz, Guy L(DOA) ;' Cc: Keith Elliott; Chris Myers; Chris Kanyer; Billy Applewhite - (C) 4r11 - Subject: 403's SD-2 and SD-7 i 4 Guy per are phone conversation on the SD-2 and SD-7 wells. I wanted to confirm • ".4 F the verbal, for the go ahead with E-Line, pertaining to the setting of plug, /;, \. dumping 25'+ of cement, SI 24hrs, tag TOC and cut 4 Y2" tubing. No further WO V work will be performed until AOGCC rig inspection and OK is given. } Thank you, Shane Bennett if , Shane Bennett-(C) • `4 Operations Engineer—Alaska r'� \_ sbennett@hilcorp.com x AI , O(907)777-8425 ,; C(325) 203-7487 H (325) 643-2405 r` , o• / 1Ai . i'' Pr s I 1 t 1 2/8/2013 STATE OF ALASKA ALr,—,<A OIL AND GAS CONSERVATION COMrvii.SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑1 SPLUG ❑ Other ❑ Abandoned [11 Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development I] • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _Single Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: ">Y01• ,,22 Marathon Alaska Production LLC Aband.: 9/4/2012 \21'1+6120 ,�l 0..5 0 IA�J 3.Address: PO Box 1949 Kenai,AK 99611-1949 6.Date Spudded: 13.API Number: ! 6/15/2011 50-133-20594-00-00 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 368'FSL,1,105'FEL,Sec.6,TIS,R13W,S.M. 7/9/2011 Ninilchik Unit Susan Dionne 7 Top of Productive Horizon: 8. KB(ft above MSL): 141' 15. Field/Pool(s): 1,885'FSL,401'FWL,Sec.7,TIS,R13W,S.M. GL(ft above MSL): 120' Ninilchik Unit Total Depth: 9. Plug Back Depth(MD+TVD): SD Tyonek Undefined Gas • 542'FSL,774'FEL,Sec.12,T1S,R14W,S.M. 11,660'MD+7,747'TVD 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: ` Surface: x- 213,338.03 y- 2,236,847.50 Zone- 4 • 11,794'MD+7,883'TVD CIRI /-f:f3A 4T 57Z 7 Z/7` TPI: x- 209,786.50 y- 2,233,075.80 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: ? c'.1 Total Depth: x- 208,582.88 y- 2,231,749.96 Zone- 4 166'MD+166'ND ADL 384372 18.Directional Survey: Yes E No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: Triple Combo,MagTrak,TestTrak,Sonic,Bond Log N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20" 129.5 ppf X-65 Surface 117' Surface 117' 10-3/4" 45.5 ppf L-80 Surface 1,697' Surface 1,436' 13-1/2" 515 sks 7-5/8" 29.7 ppf L-80 Surface 7,033' Surface 3,757' 9-7/8" 574 sks .i-277 s-ks 4-1/2" 12.6 ppf L-80 6,850' 11,790' 3,677' 7,882' 6-3/4" 397 sks 24.Open to production or injection? Yes ❑ No ❑ 25. TUBING RECORD See attached well schematic SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4-1/2" 6,850'MD 6,850'MD/3,677'TVD 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. -u Was hydraulic fracturing used during completion? Yes ❑ No ❑ i u"0lW.F! 1015 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED s '1 RECEIVED NOV 0 9 2012 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): AOGGC 9/14/2012 Flowing-intermitent, low rate well, multi point well test not possible Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 9/14/2012 1.5 Test Period .—► 70 0 n/a n/a Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 757psi 274psi 24-Hour Rate —.0. n/a 70 0 n/a 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ Sidewall Cores Acquired? Yes ❑ No E If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. ARCMS NOV 13 2012�W Form 10-407 Revised 10/2012 ;4_,_ 2•ZZ L NTINUED ON REVERSE / Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base Beluga B2 3560.71 2248.07 Beluga B3 5061.94 2900.61 Be_ lu9a 64 6089.63 3347.07 Tyonek T1 6720.88 3621.45 Tyonek T2 8246.56 4463.82 Formation at total depth: 31. List of Attachments: See Attachment List 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Marini Email: MaMarini@MarathonOil.com Printed Name: Mike Marini Title: Production Engineer Signature: / ;//QWa�'rj-e Phone: 907-283-1370 Date: 11/5/2012 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. 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. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection, Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: 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. Form 10-407 Revised 10/2012 S ;� Permit#: 211-050 S D - 7 fik. .fo API#: 50-133-20594-00-00 Ninilchik Unit Marathon O i l Prop.Des: ADL-384372 CIRI C-061505 368'FSL, 1,105'FEL, Alaska Production LLC KB elevation: 141'ASL(21'AGL) Sec.6, T1 S, R13W, S.M. Conductor Latitude: 60°06'46.69"N Longitude: 151°34'24.99"W 20" X-65 129.5 ppf PE Spud: 6/15/2011 @ 13:00 hrs Top Bottom TD: 7/9/2011 @ 8:00 hrs I MD 0' 117' Rig Released: 7/23/2011 @ 12:00 hrs J PA#: Surface Casing 10-3/4" L-80 45.5 ppf BTC LL Top Bottom MD 0' 1,697' Baker TE-5 SCSSV(5k Self-Equalizing TVD 0' 1,436' @ 166'MD(Top)3.958"ID 13-1/2"hole cemented w/515 sks(231 bbls) 12 3.81"X profile(Drifted to 3.80") ppg Type I cement Intermediate Casing Baker Chemical Infection Nipple 7-5/8" L-80 29.7 ppf BTC @ 1,514'MD(Top) 5000 psi Burst Disk Top Bottom MD 0' 7,033' TVD 0' 3,757' 9-7/8"hole cemented w/574 sks(235 bbls) 12.5 Tie-back: 3.958"ID 4-1/2" L-80 12.6 ppf IBT Mod • Top Bottom KOP @ 300'MD/TVD MD 0' 6,861' TVD 0' 3,681' Build 4.0°/100'from 300-1,790' Hold 64°from 1,790-7,245'MD Note 3.81"X profile at 166 ft MD(SCSSV) Final angle of 0.9°@ TD of 11,794'MD Liner 4-1/2" L-80 12.6 ppf Hydril 563 1 Top Bottom ZXP Liner Packer with 10'Tieback Extension MD 6,850' 11,790' @ 6,850'MD(Top) TVD 3,677' 7,882' Flex-Lock Liner Hanger 0 6,881'MD(Top) 6-3/4" hole cemented w/397 sks(181 bbls)11 ppg Landing Collar 0 11,660'MD(Top) • • : = Float Collar 0 11,703'MD(Top) Float Shoe 0 11,790'MD(Bottom) a ' + Perforations Cement Top 7240 ft MD w/Radial Bond Log i4- ! Sands MD ft TVD (CBL ran 11/17/2011) i TO3X 8,314-8,332 18' 4,517-4,531 (09/04/2012) TO3X 8,353-8,356 3' 4,547-4,550 (09/04/2012) i Minimum ID: 3.910"ID CIBP at 10,510 ft MD(set 09/04/2012) 4-1/2" L-80 12.6 ppf Pup Jt Isolated Perforations Below seal bore extension(+-6900') 1095 10,543-10,585 42' 6,632-6,674 (07/31/2012) Wet(isolat'd) CIBP at 10,640 ft MD(set 07/31/2012) T097 10,681-10,694 13' 6,770-6,783 (06/25/2012) CIBP at 10, (set 06/25/2012) T110 10,851800ftMD 10,861 10' 6,940 6,950 (02/13/2012) 10,840-10,865' 25' 6,929-9,954 (04/03/2012) 10,872-10,887' 15' 6,961-6,976 (04/03/2012) Tight(isolat'd) I • CIBP at 11,050 ft MD(set 02/13/2012) T118 . 11,101-11,111 10' 7,190-7,200 (12/03/2011) Tight f _ (isolat'd) CIBP at 11,332 ft MD(set 02/05/2012) T130-2 • 11,541-11,551 10' 7,630-7,640 (12/03/2011) Wet TD PBTD (isolat'd) 11,794 MD 11,660 MD CIBP at 11,570 ft MD(set 12/01/2011?) 7,883'TVD 7,747'TVD T138 • 11,591-11,605 14' 7,680-7,694 (11/25/2011) Wet (isolat'd) Well Name&Number: Susan Dionne#7 Lease: Ninilchik Unit Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations(MD): 10,681-10,694 ft MD Perf(TVD): 6770-6783 ft TVD Angle @ KOP&Depth: 4°/100° 0 300 ft MD Angle @ Perfs. 0.4 Date Completed: 08/01/2012 Ground Level: 141'(AMSL) RKB: 21'(AGL) Revised by: Mike Sulley Revision Date: 09/05/2012 \,.,J Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,Ti S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Daily Operations Report Date: 6/12/2011 Job Category: DRILLING 24 Hr Summary Accept Rig from Maintenance @ 06:00hrs 6/11/2011. R/U rig. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 10:00 4.00 RURD RIG AF Accepted rig from maintenance @ 06:00hrs 6/11/2011. PJSM. Pulled carrier off of the mud boat. Installed scoping rams. Spotted carrier on the mud boat. Sat cuttings box. Sat centrifuge connex. Made up scoping rams mounts and lines. Mounted mud flap on the pit trailer. Replaced brake adjuster onto pump trailer. PJSM. Leveled carrier. 10:00 18:00 8.00 RURD RIG AF PJSM w/crane hands. Crane operations: Installed grey iron and flow line, panic line,choke house,stairs,poorboy degasser,and centrifuge. Preped mast to stand.Crane operations:derrick house,driller's side grey iron,stairs, BOP connex and stairs,derrick house,and back windwalls. Stood up mast. Replaced 3 GFI breakers 1 in pits,2-carrier. Replaced missing mud flap on the mud pits. Report Date: 6/13/2011 Job Category: DRILLING 24 Hr Summary R/U rig Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 18:00 12.00 RURD RIG AF PJSM. Plugged in rig elec.cables. Serviced lines and koomey hoses. Transferred fuel to camp generator. PJSM. Prepped derrick to scope up and scoped up derrick. PJSM. R/U catwalk and beaver slide. R/U BOP connex stairs. R/U derrick guide wires and adjusted. PJSM. Inspected and repaired tumbuckle safety cables. PJSM. R/U torque tube and hang. Installed tumbuckles and strong back. Installed hydraulic cylinder tarps. R/U centrifuge house electrical and mud lines. R/U dresser sleeves and pop off lines between pit and pump modules. M/U flanges for poorboy on pump roof. Laid water line to rig. Inspected tugger lines. 18:00 00:00 6.00 RURD RIG AF Monitored rig. Entered JSA's and safety material into the new rig floor computer. 00:00 06:00 6.00 RURD RIG AF PJSM. Adjusted top drive torque tube. Installed the tarp over the top drive service lines. Replaced the window in the rig floor back wind wall. Ran water line to the rig. Replaced the drive line from the#2 carrier motor to the dennison hydraulic pump. Inspected the tugger lines and P/U the top drive. M/U the service loop to top drive a.Changed the mud pump liners and swabs to 5". Tested the koomey bottle pressure(OK). Changed the saver sub, grabber dies and DP guide on the top drive. Report Date: 6/14/2011 Job Category: DRILLING 24 Hr Summary R/U rig. N/U diverter and diverter line.Trouble shoot leak on starter head. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com prig tongs, fill-up 06:00 09:00 3.00 RURD RIG AF PJSM. R/U spinners, mud manifold, line,bleeder line,kill hose,choke line and splash guard. 09:00 10:30 1.50 RURD 'RIG 'AF PJSM. Installed bows and tarp on carrier. Changed breakers for the heater in the pump room. Welded a 2"nipple on the conductor. • 10:30 12:00 1.50 RURD RIG AF PJSM. Installed 4"valves on the starter head. Dressed the final cut on the conductor. 12:00 14:00 2.00 RURD RIG AF PJSM. Prep conductor and install starter head.Test to 300psi/15 min OK. 14:00 18:00 4.00 RURD RIG 'AF PJSM. P/U and N/U the 21 1/4"annular. N/U adaptor spool to side outlet. Spotted#3 mud pump and mud storage tank(Hansen tank). Bermed in Hansen tank. R/U derrick board and Geronimo line. R/U flowline adaptor. Cut and prepped bell nipple. Tightened the nuts and bolts on the stack. C/O valve on#1 mud pump. 18:00 00:00 6.00 RURD RIG AF PJSM. Cont.to prep bell nipple and installed. N/U knife valve. Trouble shot mud pump power and repaired. R/U water line to rig. R/U#3 mud pump. Changed the swabs and liners on the#3 mud pump. Tested gas alarms. N/U diverter line. Repaired bracket f/tongs on drillers side. www.peloton.com Page 1/31 Report Printed: 11/7/2012 :11491 Operations Summary Report - Marathon Oil Well Name: SUSAN DIONNE Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 00:00 04:00 4.00 RURD RIG AF PJSM. Cont.to N/U diverter line. R/U kill line to conductor. R/U trip tank fill up line and return line. R/U suction line and pop off line to#3 mud pump. R/U"U"tube and choke line to poorboy. R/U koomey lines to diverter and function tested. Chained off diverter stack and line, Fired up boiler. 04:00 05:00 1.00 RURD RIG AF PJSM. Sat pipe racks and loaded with 5"DP. 05:00 06:00 1.00 RURD RIG AF PJSM. Tested gas alarms. Filled riser with water and starter head leaked. Investigated leak on starter head. Report Date: 6/15/2011 Job Category: DRILLING 24 Hr Summary Prepped to test diverter system. Seals leaked in the starting head. Injected plastic and tested starter head OK. Cleaned radiators on carrier engines.Trouble shot leaking knife valve. P/U 5"DP and HWDP. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 09:00 3.00 TEST BOPE TA MSBO PJSM. Tightened flanges on adaptor spool and bell nipple(leaks). 09:00 12:00 3.00 TEST BOPE TA MSBO Filled diverter stack with water and knife valve leaked. N/D diverter line and remove knife valve and changed seal in knife valve. Injected plastic into seal area of starter head. Test starter head to 300psi/10min. Fill pits with water and mix spud mud. Laid liner,felt and matting boards for AIM mud disposal tank. 12:00 18:00 6.00 TEST BOPE TA MSBO PJSM. Removed knife valve and changed out o-ring seal. Cont.to mix spud mud. Tested knife valve(failed).Removed knife valve. Changed out actuator to spare knife valve. Installed spare knife valve and tested(failed). Changed actuator back to original knife valve. Cleaned radiator and air charger on#1 mud pump. Tested top drive rotation and functioned grabber override. 18:00 22:00 4.00 TEST BOPE TA MSBO PJSM. Installed knife valve and tested(failed). Removed knife valve. Cont. to mix spud mud. Disassembled knife valve cleaned and replaced seal. Tested 1,2,and 3 mud pumps and interlocks. Tested mud pump#3 ESD. Tested stroke counters. R/U Baker sensors. Installed mouse hole. 22:00 02:30 4.50 PULD DP AF PJSM. Prepped rig floor to P/U 5"DP. Strapped 5"DP. C/O elevator inserts to 5".Drift 5"DP and strap. 02:30 04:30 2.00 TEST BOPE TA MSBO PJSM. Installed knife valve and tested(failed). Removed valve,turned and re-installed. 04:30 06:00 1.50 PULD DP AF P/U 5"HWDP DP and rack back. Tested knife valve(OK). Report Date: 6/16/2011 Job Category: DRILLING 24 Hr Summary Tested diverter(AOGCC witness). P/U BHA. Drilled F/98'to 275'. POOH and P/U remainder of BHA#1. Cont. RIH. Cont.to drill F/275'to 739'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 06:30 0.50 SERVIC RIG AF PJSM. Serviced rig,top drive and greased blocks. 06:30 07:30 1.00 NUND BOPE AF PJSM. N/U diverter line and chained down. 07:30 08:00 0.50 PULD BHA AF PJSM. Prep to P/U BHA. 08:00 09:30 1.50 TEST BOPE AF Diverter function test and state inspection(AOGCC,Jeff Jones). 09:30 12:00 2.50 PULD BHA AF P/U BHA. Orient motor and MWD. 12:00 13:00 1.00 REPAIR RIG 'AF While P/U BHA and organize rig repaired the annular 4-way valve on the accumulator. 13:00 17:30 4.50 DRILL ROT AF Spud well @ 13:00hrs 6/15/2011. Drilled 13.5"vertical hole F/98'to 275'365 GPM 60 RPM 440psi 0-5KWOB. 17:30 18:00 0.50 CIRC MUD AF Pumped 25bb1 200 Vis sweep and circulated out. 18:00 18:30 0.50 TRIP DP AF POOH to 68'. 18:30 19:30 1.00 TRIP DP AF P/U remainder of BHA#1(3 MCSDP)and RIH to 269'(6'of fill). 19:30 22:00 2.50 DRILL ROT AF Drilled 13.5"vertical hole F/275'to 361'425GPM 700PS1 0-5K WOB 60RPM Rot=4.2hrs 22:00 00:00 2.00 DRILL ROT AF Drilled 13.5"build section F/361'to 462' 0 RPM 0 TQ 400GPM 750PS1 8WOB Rot=0 Slide=1.2hrs P/U 50K S/O 49K Rot1-2K Ft-lb 45K www.peloton.com Page 2/31 Report Printed: 11/7/2012 • /' \ / Operations Summary Report - Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,Ti S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 00:00 06:00 6.00 DRILL ROT AF Drilled 13.5"build section F/462'to 739' 50-70RPM 2-3KTQ 400-500GPM 750-1150 PSI 5-10KWOB Rot=1.0hrs Slide=3.2hrs P/U 62K SIO 58K Rot 60K 2-4K ft-lb Report Date: 6/17/2011 Job Category: DRILLING 24 Hr Summary DrilledF/739'to 1705'. Pumped sweep and circ.out. POOH to 184'. L/D shock sub. Service rig. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 12:00 6.00 DRILL ROT AF Drilled 13 1/2"build section F/739'to 1053'ART=1.2hrs AST=2.9hrs 500- 550gpm 1150-1350psi 70RPM 3KFt-Ib 15k WOB P/U 70K S/O 60K Rot 65K 2-4KTQ 12:00 18:00 6.00 DRILL ROT AF Drilled 13 1/2"build section F/1053'to 1387'ART=1.2 hrs AST=2.5hrs 550- 600gpm 1350-1600psi 70-80RPM 3-5KFt-lb 15-25k WOB P/U 72K S/O 61K Rot 67K 2-4K TQ 18:00 00:00 6.00 DRILL ROT AF Drilled 13 1/2"build section F/1387'to 1663 ART= 1.3hrs AST=2.6hrs 600gpm 1600-1750psi 80RPM 6KFt-lb 25k WOB P/U 70K S/O 60K Rot 65K Note:N/U 13 5/8"BOP's on carrier while drilling. 00:00 01:30 1.50 DRILL ROT AF Drilled 13 1/2"build section F/1663 to 1705 ART=.5hrs AST=.7hrs 600gpm 750psi 80RPM 6KFt-Ib 25k WOB P/U 72K 5/0 61K Rot 67K 4-6KTQ 01:30 02:30 1.00 CIRC MUD AF Pumped hi-vis sweep and circulate clean 600 GPM 1400psi 80RPM. No increase in cuttings with sweep. Flow check(OK). 02:30 05:30 3.00 TRIP DP AF POOH to 100'(hole in good condition). L/D shock sub and X/O's. 05:30 06:00 0.50 SERVIC RIG AF Service the rig. Report Date: 6/18/2011 Job Category: DRILLING 24 Hr Summary Conditioned hole for casing. L/D BHA. R/U to run 10 3/4"CSG. Run 10 3/4"45.5ppf L-80 Butt CSG to 1697'. Cemented 10 3/4"casing. R/D cementers and prep to N/D Diverter. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 07:30 1.50 TRIP DP AF PJSM. RIH w/DP sat down @ 1052'. Reamed through obstruction at 1052'. Cont.to RIH to 1705'. 07:30 08:30 1.00 CIRC MUD AF Pumped 50bbl 200 vis sweep and circulated out. A large volume of cuttings observed across the shakers at B/U. Trip gas 300 units. 08:30 10:30 2.00 TRIP DP AF PJSM. Flow checked(OK). POOH w/DP to 620'(reamed tight spot at 963') 10:30 12:30 2.00 TRIP DP AF RIH to 1705'(reamed through tight spots @ 1100', 1189', 1434'). 12:30 14:30 2.00 CIRC MUD AF Pumped a 50bbl 200 vis sweep and circulated out. Cont.to circulate 2 B/U. No increase of cuttings across shakers. Flow check(OK) 14:30 16:00 1.50 TRIP DP AF PJSM. POOH to 120'(hole in good condition). 16:00 17:30 1.50 PULD BHA AF PJSM. L/D directional BHA and bit. BHA and Bit badly balled up with clay. 17:30 18:00 0.50 CLEAN RIG AF Clean and organize riig floor. 18:00 20:30 2.50 RURD CSG AF R/U rig floor to run CSG. C/O to long bales. R/U Weatherford CSG tongs. 20:30 21:00 0.50 SAFETY MTG AF Safety meeting for running casing. 21:00 22:30 1.50 RUN CSG AF M/U shoe track and Bakerlok. Check floats(OK). 22:30 00:30 2.00 RUN CSG AF Cont.to run 10 3/4"45.5PPF L-80 Butt special drift casing to 1697'.P/U 87K S/O 55K 00:30 02:00 1.50 CIRC MUD AF R/U cement hose and circulate CSG and condition mud for cementing 250GPM. Reduced YP F/18 to10. 02:00 02:30 0.50 SAFETY MTG AF Safety meeting prior to cementing casing. 02:30 04:30 2.00 PUMP CMT AF Pumped 20bbls 8.4ppg Mud Clean 2 preflush with rig. Switched to BJ unit and pump 2bbls water. Tested lines to 2000psi(OK). Dropped bottom plug. Mixed and pumped 515sxs type 1 cement w/15%LW5e,20%MPA1, 1%A-7, So .6%CD-32, .05%Static Free, 1GPHS FP-6L to yield 213bbls 12.0ppg slurry. Dropped top plug and kicked it out with 5bbls water F/BJ. Switched to rig and displaced w/150bbls 9.1 ppg mud. Bumped plug w/1600psi 1000psi over last displacement pressure.Check float(OK).CIP@04:30hrs. Full returns w/50bbls cement to surface. www.peloton.com Page 3/31 Report Printed: 11/7/2012 • I \ / Operations Summary Report - Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) _ Ops Code Activity Code Status Code _ Com 04:30 06:00 1.50 CLEAN RIG AF R/D cement head. Flushed diverter stack. Prepped to N/D diverter. Report Date: 6/19/2011 Job Category: DRILLING 24 Hr Summary N/D diverter while WOC.Removed starter head. Installed wellhead on 10 3/4"CSG. N/U BOP. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 12:00 6.00 NUND BOPE AF PJSM. R/D kill line,bleeder line,fill up line,and trip tank return line. N/D diverter line,knife valve and adaptor flange. PJSM. Loaded pipe racks with 5"DP. Hot bolt diverter stack. R/D chains and turnbuckles. R/D trip tank actuator. Hauled off spud mud. R/U rig tongs and spinners. 12:00 16:30 4.50 NUND BOPE AF PJSM. Prepped to N/D. Released wt from CSG string. Rough cut 10 3/4" casing. L/D bell nipple and flow line.Removed diverter"T"and annular. Removed starter head outlet valves. . Hammered up 13 5/8"BOP stack. Cleaned pits. C/O shaker rubbers on#1 and#2 shakers. 16:30 17:00 0.50 NUND WLHD AF PJSM. Removed starter head. 17:00 20:00 3.00 NUND WLHD AF PJSM. Cut 20"casing. Cut 10 3/4"casing. Dressed cut on 10 3/4"CSG and installed Vetco 10 3/4"sliploc 11"5M wellhead. 20:00 21:00 1.00 NUND WLHD AF Test wellhead to 1700psi 10min. Run in lockdowns. 21:00 00:00 3.00 NUND BOPE AF PJSM. N/U 11"5M X 13 5/8"5M DSA. N/U 24"13 5/8"spacer spool. N/U 13 5/8" 5M R,S,Rd,A Shaffer LWS stack. Grease choke manifold valves. Clean cuttings box. 00:00 06:00 6.00 NUND BOPE AF PJSM. N/U BOPE. Installed choke line HCR. Hooked up koomey lines. N/U choke and kill lines. N/U bell nipple,flowline,bleeder line,trip tank fill and return lines. Installed chains and turnbuckes to stack. Installed drip pan. Installed mouse hole. Mixed Flopro mud. Report Date: 6/20/2011 Job Category: DRILLING 24 Hr Summary N/U BOPE. Test BOPE. Test CSG to 1500psi. P/U 5"DP. M/U BHA. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 07:30 1.50 PULD EQIP AF PJSM. C/O to short bales and DP elevators. 07:30 09:30 2.00 TEST BOPE AF PJSM. Installed the test plug. Shell tested the BOP. Repaired leaks on the grey lock on the choke line and gland nut on the wellhead. 09:30 13:30 4- .00 TEST BOPE AF PJSM. Tested BOPE 250/3000psi 5min. Tested annular,upper and lower TD valves,upper variable rams,lower pipe rams(tightened spacer spool flange due to leak then tested OK),TIW valve,dart valve,inside and outside kill line valves,choke manifold valves 1-12. Performed koomey test. Pulled the test joint and tested the blind rams(test witnessed by AOGCC Matt Herrera). 13:30 14:00 0.50 TEST BOPE AF Pulled test plug and R/D test equipment. 14:00 15:00 1- .00 TEST CSG AF Tested 10 3/4"casing to 1500psi/30 min. 15:00 15:30 0.50 RUNPUL WBSH AF Ran wear bushing. 15:30 16:00 0- .50 PULD DP AF Prepped rig floor to P/U DP. 16:00 21:30 5- .50 PULD DP AF P/U drifted and racked back 96 jnts of 5"DP. 21:30 00:30 3.00 PULD DP AF P/U drifted and RIH w/50 jnts 5"DP. 00:30 02:00 1.50 CIRC MUD AF Circ. B/U X2 390GPM. 02:00 03:00 7 1.00 PULD DP AF POOH and rack back and strap 50jnts of 5"DP(Total 146jnts of 5"DP picked up). 03:00 06:00 ; 3.00 PULD BHA AF P/U BHA#2.9 7/8"PDC,Autotrack,GR-Res. Report Date: 6/21/2011 Job Category: DRILLING 24 Hr Summary RIH w/BHA#2 9 7/8"bit and Autotrak. Drill shoe track and shoe to 1697' Clean old hole to 1705'. Drill 1705'to 1725' Displace to 9.0ppg Flopro Perform 15ppg FIT. Drill F/1725'to 3283'. Ops Trouble Start Time End Time Our(hr) Ops Code Activity Code Status Code Com 06:00 06:30 0.50 PULD BHA AF Cont.to M/U BHA#2 9 7/8"PDC,Autotrack,GR-Res. 06:30 07:00 0- .50 TRIP DP AF RIH w/5"DP to 1591'. Wash down to 1610'. 07:00 09:00 2.00 'DRILL CMT AF Tag cement @ 1610'. Drill cement and float collar @ 1612'. Drill shoe track and shoe @ 1697'. Clean old hole 1697'to 1705'. 09:00 09:30 0.50'DRILL ROT AF Drill 9 7/8"tangent section 1705'to 1725'ART=.3hrs 425GPM 1100psi 50RPM 10 WOB 3K Ft-lb P/U 73K S/O 50K Rot 65K. 09:30 10:30 1.00 CIRC MUD AF Displace to 9.0ppg Flopro Mud. www.peloton.com Page 4/31 Report Printed: 11/7/2012 • Operations Summary Report -Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S, R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code_ Com -10:30 11:30 1.00 TEST LOT AF Perform fit test to 15ppg EMW. 11:30 18:00 6.50 DRILL ROT AF Drill 9 7/8"tangent section 1725'to 2286' ART=4.3hrs 530GPM 1350psi 70RPM 15 WOB 5K Ft-lb P/U 74K S/O 54K Rot 65K. Added 1%Low Torq to mud @ 1900'. 18:00 00:00 6.00 DRILL ROT AF Drill 9 7/8"tangent section 2286'to 2810'ART=4.3hrs 530GPM 1450psi 70RPM 12 WOB 5K Ft-lb P/U 80K S/O 54K Rot 63K. 00:00 06:00 6.00 DRILL ROT AF Drill 9 7/8"tangent section 2810' to 3283'ART=4.6hrs 530GPM 1600psi 70RPM 12 WOB 5K Ft-lb P/U 92K S/O 55K Rot 68K. Report Date: 6/22/2011 Job Category: DRILLING 24 Hr Summary Drilled 3283'to 3425'. Circ.clean. POOH to 3292'. B/R 3292'to 1697'. CBU X 3 @ 1700'. RIH to 3238'. Ream 3238'to 3425'. Drilled 3425'to 4246'. Ops I Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 08:00 2.00 DRILL ROT AF Drilled 9 7/8"tangent section 3283' to 3425'ART=1.4hrs 530GPM 1600psi 70RPM 12 WOB 5K Ft-lb P/U 92K S/O 55K Rot 68K. 08:00 09:00 1.00 CIRC MUD AF CBU. Pumped a hi-vis sweep and circulate clean 600GPM 1850 PSI 80RPM. 09:00 10:00 1.00 TRIP DP AF Flow checked(OK). POOH to 3292'. B/R 3292'to 3210'. 10:00 10:30 0.50 WORK PIPE TA NDSP Worked stuck pipe free at 3210'. 10:30 11:00 0.50 CIRC MUD AF CBU @ 3210' 600GPM 1750PSI 800RPM. 11:00 16:00 5.00 REAM OH AF B/R 3225'to 1697'600GPM 8ORPM(needed 600GPM for adequate power to the motor). 16:00 17:00 1.00 CIRC MUD AF CBU X 3 at 1700'while serviced the rig. Large quantity of cuttings across shakers. 17:00 19:00 2.00 TRIP DP AF RIH and tagged at 3238'. Reamed 3238'to 3425'600GPM 80RPM. Before trip: P/U 92K S/O 55K ROT 68K After trip: P/U 85K S/O 63K Rot 72K 19:00 00:00 5.00 DRILL ROT AF Drilled 9 7/8"tangent section 3425' to 3805' ART=3.4hrs 600GPM 1850psi 70RPM 12 WOB 5K Ft-lb P/U 92K S/O 55K Rot 68K. 00:00 06:00 6.00 DRILL ROT AF Drilled 9 7/8"tangent section 3805' to 4246'ART=4.2hrs 600GPM 1900psi 70RPM 12 WOB 6K Ft-lb P/U 100K S/O 68K Rot 75K. Report Date: 6/23/2011 Job Category: DRILLING 24 Hr Summary Drilled 4246'to 5196'. Circ.clean.B/R to 3000'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 12:00 6.00 DRILL 'ROT 'AF Drilled 9 7/8"tangent section 4246'-4564'ART=3.4 hrs 600GPM 1900psi 70RPM 14 WOB 7K Ft-lb P/U102K S/O 57K Rot 75K. Pumped a 50bbl low- vis sweep @ 4550'9.3ppg 28vis. 12:00 18:00 6.00 DRILL 'ROT AF Drilled 9 7/8"tangent section 4564'-4943'ART=4.1 hrs 600GPM 2150psi 70RPM 12 WOB 6K Ft-lb P/U 110K S/O 63K Rot 83K. Pumped a 50bbl low- vis sweep @ 4890'9.3ppg 28vis. 18:00 22:00 4.00 DRILL ROT AF Drilled 9 7/8"tangent section 4943'-5196'ART=2.7hrs 600GPM 2100psi 70RPM 12 WOB 8K Ft-lb P/U 125K S/O 62K Rot 82K. 22:00 00:00 2.00 CIRC MUD AF CBU. Pumped a 50bbl Low-vis sweep and circ.out. Circ.until shakers clean. 600GPM 80RPM. Flow check(OK). 00:00 06:00 6.00 REAM OH 'AF B/R 5196'to 3000'600GPM 80RPM. Tight @ 4444'. Report Date: 6/24/2011 Job Category: DRILLING 24 Hr Summary B/R F/3000'to 1717'. Pump Low-vis sweep and CBU. C/O saver sub and grabber dies. Serviced rig. RIH to 5196'. Drilled 5196'to 5256'. Freed stuck BHA. Drilled 5256'to 5324'. Freed stuck BHA. Drilled 5324'to 5577'. Freed stuck BHA. Drilled 5577'to 5703'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 08:30 2- .50 REAM OH AF Cont.to B/R 3000'to 1717'. 08:30 09:00 0.50 CIRC MUD AF Pump a 50bbls low-vis sweep and circulate out. 09:00 10:30 1.50 REPAIR RIG TA MSTD PJSM. C/O the saver sub and grabber dies on the top drive. 10:30 11:30 1- .00 SERVIC RIG AF PJSM. Serviced the rig,top drive,crown and blocks. 11:30 '14:30 3- .00 TRIP 'DP AF PJSM. RIH to 5196'washed last stand down. 14:30 '15:15 0- .75 DRILL ROT 'AF Drilled 9 7/8"tangent section 5196'to 5258'ART=.7hrs 600GPM 2050psi 70RPM 15 WOB 9K Ft-lb P/U 115K 5/0 65K Rot 86K. www.peloton.com Page 5/31 Report Printed: 11/7/2012 ,ii V/J Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date 'Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 15:15 16:15 1.00 WORK PIPE TA NDSP BHA stuck while B/R @ 5210'.Work BHA free @ 5210' Samples showed coal. Circ.and ream area where BHA was stuck. 16:15 17:15 1.00 DRILL ROT AF Drilled 9 7/8"tangent section 5258'-5324'ART=.6hrs 600GPM 2100psi 70RPM 15 WOB 9K Ft-lb P/U 115K S/O 65K Rot 86K. 17:15 18:15 1.00 WORK PIPE TA NDSP BHA stuck @ 5324'. Freed stuck BHA @ 5324'.Samples showed coal. 18:15 19:30 1.25 CIRC MUD AF Circ.and increased MW 9.3ppg to 9.5ppg due to unstable coals. 19:30 00:00 4.50 DRILL ROT AF Drilled 9 7/8"tangent section 5324'-5500'ART=2.4hrs 600GPM 2100psi 70RPM 15 WOB 9K Ft-lb P/U 115K S/O 65K Rot 86K. 00:00 01:30 1.50 DRILL ROT AF Drilled 9 7/8"tangent section 5500'-5577'ART=1.2hrs 600GPM 2100psi 70RPM 15 WOB 8K Ft-lb P/U 116K S/O 64K Rot 87K. 01:30 03:00 1.50 WORK PIPE TA NDSP BHA stuck @ 5577'. Freed stuck BHA @ 5577'.Samples showed coal. 03:00 06:00 3.00 DRILL ROT AF Drilled 9 7/8"tangent section 5577'-5703'ART=2.0hrs 600GPM 2100psi 70RPM 15 WOB 9K Ft-lb P/U 116K S/O 64K Rot 87K. Increased MW 9.5ppg to 9.6ppg while drilling Report Date: 6/25/2011 Job Category: DRILLING 24 Hr Summary Drilled 5703'to 6944'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 12:00 6.00 DRILL ROT AF Drilled 9 7/8"tangent section 5703'-5957'ART=3.4hrs 600GPM 2100psi 70RPM 15 WOB 9K Ft-lb P/U 125K S/O 63K Rot 86K. 12:00 18:00 6.00 DRILL ROT AF Drilled 9 7/8"tangent section 5957'-6273'ART=3.9hrs 600GPM 2300psi 70RPM 15 WOB 10K Ft-lb P/U 125K S/O 65K Rot 91K. Pumped a 9.6ppg 50bbl low-vis sweep followed by a 9.6ppg 50bbl hi-vis sweep @ 6055' yielded a significant increase in cuttings across shakers. 18.00 00:00 6.00 DRILL ROT AF Drilled 9 7/8"tangent section 6273'-6589'ART=3.7hrs 600GPM 2400psi 70RPM 15 WOB 10K Ft-lb P/U125K S/O 65K Rot 91K. Pumped a 50bbl low-vis 9.6ppg sweep @6496'yielded a significant increase in cuttings. 00:00 06:00 6.00 DRILL ROT AF Drilled 9 7/8"tangent section 6589'-6944'ART=4.4hrs 600GPM 2450psi 70RPM 15 WOB 10K Ft-lb P/U130K S/O 63K Rot 90K. Report Date: 6/26/2011 Job Category: DRILLING 24 Hr Summary Drilled 6944'to 7050'.Circ&cond mud. Backream f/7050'-3236'. Pump Hi-Vis sweep. POH. LD Autotrack BHA. P/U Cleanout BHA. RIH. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 08:00 2.00 DRILL ROT AF Drilled 9 7/8"tangent section 6944'-7050'ART=1.3hrs 600GPM 2450psi 70RPM 15 WOB 10K Ft-lb P/U130K S/O 63K Rot 90K. 08:00 10:00 2.00 CIRC MUD AF CBU. Pumped a 50bbl low-vis sweep and circulated the shakers clean. 10:00 10:30 0.50 REPAIR RIG TA MSFL Circ.w/pumps 1&2 while change a swab in pump#3. '10:30 12:00 1.50 REAM OH AF Backreamed f/7050'-6680'. 12:00 23:00 11.00 REAM OH AF PTSM;Continue backreaming f/6680'-3236'. 23:00 00:00 1.00 CIRC MUD AF Circ. Hi-Vis sweep surface to surface. Yielded large quantity of cutting over shakers. 00:00 03:00 3.00 TRIP DP AF POH w/BHA.SLM-No correction 03:00 05:00 2.00 PULD BHA AF LD Autotrack BHA. 05:00 06:00 1.00 PULD BHA AF MU cleanout BHA. Report Date: 6/27/2011 Job Category: DRILLING 24 Hr Summary Cont.to RIH w/cleanout BHA to the CSG shoe. Slip drilling line and service rig at the CSG shoe. Cont.to RIH. Work though tight spot @ 6010'. Cont.to RIH and wash to 7050'. Pump sweep and circ.clean.POOH to 5000'(tight). RIH to 7050. Pump sweep and circ.clean. POH. LD HWDP&Cleanout BHA.Test run 7 5/8"hanger. C/O upper rams to 7 5/8"and test(OK). Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 06:30 0.50 TRIP DP AF Cont.to RIH to CSG shoe at 1697'. 06:30 08:00 1.50 SERVIC RIG AF Service the rig. Slip drilling line. 08:00 12:30 4.50 TRIP DP AF Cont.to RIH. W/R tight spot @ 6710'. Cont.to RIH to 7050'wash last two singles down. 12:30 14:00 1.50 CIRC 'MUD AF Pump 50 bbl low-vis sweep and circ. until shakers clean 600GPM 80RPM. 14:00 17:00 3.00 TRIP 'DP AF POOH to 5000'w/DP(tight). 17:00 18:30 1.50 TRIP 'DP AF RIH to 7050(no tight spots). www.peloton.com Page 6/31 Report Printed: 11/7/2012 ;/N.J Operations Summary Report -Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 18:30 20:00 1.50 CIRC MUD AF Circ&cond mud.Circ Lo-Vis sweep with minimal cuttings returned. 20:00 01:00 5.00 TRIP DP AF POH w/5"DP. 01:00 02:00 1.00 PULD BHA AF LD HWDP&cleanout BHA. 02:00 02:30 0.50 RUNPUL WBSH AF Pull wear bushing. 02:30 03:00 0.50 RUN CSG AF Make Test run w/csg hanger and mark landing joint. 03:00 04:00 1.00 NUND BOPE AF Close blind rams.Change upper rams to 7 5/8" 04:00 05:00 1.00 TEST BOPE 'AF Run test plug and jt.Test 7 5/8"rams to 250/3000 psi(OK). Report Date: 6/28/2011 Job Category: DRILLING 24 Hr Summary R/U CSG tools.Run 175 jts 7 5/8",29.7#,L-80 BTC as per plan.Circ @ shoe&on bottom.Circ&cond mud.RU BJ.Safety meeting.Test lines.Start pumping cement. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 10:00 4.00 RURD CSG AF PJSM. Cont.to R/U casing tools. 10:00 10:30 0.50 SAFETY MTG AF Safety meeting prior to running casing. 10:30 11:30 1.00 RUN CSG AF M/U shoe track(Bakerlok first 4 joints). Circulate through shoe track and check floats(OK). 11:30 12:00 0.50 SAFETY MTG AF Safety meeting for running casing with the crew coming on duty. 12:00 15:00 3.00 RUN CSG AF Cont.to run 7 5/8"29.7ppf L-80 Butt-mod casing 15:00 15:30 0.50 CIRC MUD AF Circ.B/U at the shoe. 15:30 23:00 7.50 RUN CSG AF Cont.running casing to 6983'.MU landing joint&hanger. 23:00 01:00 2.00 CIRC MUD AF Break circ.Connection on hanger running tool leaking slightly.Continue circ &reciprocate while wait on 0-ring. 01:00 01:30 0.50 REPAIR EQIP TA MSTB Drain landing joint.Change out 0-rings in hanger running tool. 01:30 03:00 1.50 CIRC MUD AF Resume circ @ 6 bpm 640psi.Land hanger.FS @ 7032';FC @ 6947'.Ran total of 175 Jts,7 5/8",29.7#,L-80,BTC casing. 185k PU;70k SO. 03:00 03:30 0.50 SAFETY MTG AF Hold safety meeting prior to cementing.RU cement head. 03:30 06:00 2.50 PUMP CMT AF Break circ w/rig.Switch to BJ&pump 3 bbls H2O. Tested lines to 250/ 2500psi(OK). Dropped bottom plug. Pumped 30bbls 10 ppg Seal Bond J�. spacer. Mixed and pumped 574 sxs(252 bbls)Lead,Class'G'cement @12.5 ppg w/.05%Static Free, 1%CaCI, .2%CD-32,.3%FL-52,2%Sodium r-1 Metasilicate,20%MPA1.Tail in w/279 sxs(57.6 bbls)Class'G'@ 15.8 ppg N w/.1%R3,.5%EC!,.6%FL63,.3%CD32, .1%ASA301,.05%Static Free. If‘ Dropped top plug and kicked it out with 5bbls water F/BJ. Switched to rig and /B displaced. Report Date: 6/29/2011 Job Category: DRILLING 24 Hr Summary Displaced cement.Checked floats. R/D cement head and lines. Flushed stack and flow line. Set packoff and test to 5000psi. C/0 upper and lower pipe rams and inspected ram cavities.Adjust torque tube.RU floor f/DP.LD 5"DP from mousehole.Change saver sub and grabber dies.RU to PU 4"DP. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 07:00 1.00 PUMP CMT AF Displaced cement w/10bbls water and 309bbls 9.7ppg mud. Did not bump the plug(the plug did not leave the head with the first 5bbls of water that was pumped,displaced cement 5bbls short of the float collar). Checked floats (OK). 10bbls cement circulated to surface. CIP @ 07:15hrs. 07:00 09:00 2.00 PUMP CMT AF R/D cement lines and cement head. L/D fill up tool,landing joint,and elevators. 09:00 10:00 1.00 PUMP WTR AF Flush stack,flow line and hanger. 10:00 11:00 1.00 RURD OTHR AF Install bales and DP elevators. R/D stabbing board. 11:00 13:00 2.00 RURD OTHR AF Set packoff and energize seals. Test to 5000psi/15min(OK). 13:00 15:30 2.50 RURD OTHR AF PJSM. C/0 upper rams to 2 7/8"X 5 1/2"variable rams. C/0 lower pipe rams to 4"rams. Opened blind ram cavities and inspected for cement. Inspected annular for cement. 15:30 18:00 2.50 RURD OTHR AF PJSM.Install turnbuckles&adjust torque tube.RU spinner.Set pipe racks. 18:00 03:30 9.50 PULD DP AF PJSM.RU&LD 5"DP from mousehole. 03:30 06:00 2.50 RURD OTHR AF Change out saver sub,grabber dies,and pipe guide.Clean&inspect grabber box. Report Date: 6/30/2011 Job Category: DRILLING 24 Hr Summary PJSM. Set pipe racks and loaded w/4"DP. Repaired top drive. P/U 4"DP.Circ.Stand back DP.P/U 4"DP. www.peloton.com Page 7/31 Report Printed: 11/7/2012 o, / Operations Summary Report -Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 10:00 4.00 REPAIR RIG TA MSTD PJSM. Wrote a JSA for Top Drive repair. L/D Top drive slide and replaced coupler seals on the top drive hydraulics line. Changed the Teflon inserts on the slide.Changed liners to 4"on#2 mud pump. Changed oil on the#1 generator. Set pipe racks and loaded with 4"DP. Clean pits Hauled off mud. 10:00 11:00 1.00 RUNPUL WBSH AF PJSM. Installed safety clamp and cable on the mud line sensor. Installed the wear bushing. Hauled off mud. 11:00 12:00 1.00 PULD DP AF PJSM. R/U and P/U 4"DP. 12:00 20:00 8.00 PULD DP AF PTSM.Change out torque make-up line.PU,drift,MU&RIH w/176 jts 4"DP. 20:00 21:00 1.00 CIRC MUD AF Circ&cond mud. 21:00 01:30 4.50 TRIP DP AF PJSM.POH w/DP.SLM. 01:30 06:00 4.50 PULD DP AF PU,drift,MU&RIH w/ 4"DP. Report Date: 7/1/2011 Job Category: DRILLING 24 Hr Summary P/U 4"DP and rack back. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 12:00 6.00 PULD DP AF P/U 4"DP and rack back(354 total jnts). Due to waiting on Baker LWD tools rig released to maintenance 12:00hrs 6/30/2011 Susan Dionne Pad. Report Date: 7/3/2011 Job Category: DRILLING 24 Hr Summary Test BOPE.M/U 6 3/4"bit and drill out assy.RIH to 5000'and BOP drill. Cont.to RIH to 6740'.Wash down to tag @ 6886'.Drill plugs,shoe track,&firm cement to 7050'.Drill new hole to 7070'.CBU and displace to new 9.2 ppg mud.FIT test to 1150 psi(15 ppg EMW).Circ and cond mud. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 06:30 0.50 RUNPUL WBSH AF Rig accepted back from maintenance 06:00hrs 7/2/2011. i PJSM.Pull wear bushing. 06:30 10:30 4.00 TEST BOPE AF PJSM. R/U to test BOPE. Test annular to 250/2500psi 5min. Test lower 4" pipe rams,upper 2 7/8"X 5 1/2"variable rams,1-12 cmv's,inner and outer manual kill line valves,choke line HCR valve,choke line manual vale,upper and lower top drive valves,4"dart valve and TIW valve to 250/3000psi 5min. Perform koomey performance test(OK). Pull test joint and test blind rams to 250/3000psi 5min(Test waved by Chuck Sheavy AOGCC). Pull test plug. 10:30 11:00 0.50 RUNPUL WBSH AF PJSM. Run wear bushing. 11:00 12:00 1.00 TEST CSG AF PJSM. R/U to test casing. Prime pumps. 12:00 13:00 1.00 TEST CSG AF PJSM. Test 7 5/8"casing to 3000psi/30min(OK). 13:00 14:30 1.50 PULD BHA AF PJSM. M/U 6 3/4"bit,bit sub w/float and RIH P/U 4"HWDP and Jars. 14:30 17:30 3.00 TRIP DP AF PJSM. RIH w/4"DP to 5000'. 17:30 18:00 0.50 SAFETY DRIL AF BOP/Choke drill. 18:00 18:30 0.50 TRIP DP AF Continue RIH w/DP to 6740'. 18:30 19:30 1.00 WASH FILL AF Wash down.Tag cement @ 6886'. 19:30 22:00 2.50 DRILL CMT AF Drill plugs,shoe track,&cement f/6886'to 7050'. 22:00 23:00 1.00 DRILL ROT AF Drill 20'new hole f/7050'to 7070'. 23:00 01:00 2.00 CIRC MUD AF CBU.Pump spacer around w/new 9.2 ppg FloPro mud. 01:00 01:30 0.50 TEST LOT AF Stop pumping.Circ kill line.Shut in.Perform FIT to 1150 psi(15 ppg EMW). Final SI pressure after 10 min--970 psi.Open well up. 01:30 02:30 1.00 FLOW CHEK AF LD single.Flow check well.Take SPR and pressure. 02:30 06:00 3.50 CIRC MUD AF Circ&cond mud. Report Date: 7/4/2011 Job Category: DRILLING 24 Hr Summary Circ.POH.MU directional BHA.Shallow test tools-OK.RIH on 4"DP.Wash f/7049 to 7070'.Drill f/7070'to Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 12:00 6.00 CIRC MUD 'AF Circ. 12:00 12:30 0.50'CIRC MUD AF PTSM.Mix&pump dry job. 12:30 17:00 4.50 TRIP BHA AF PJSM.POH w/4".LD bit&bit sub. www.peloton.com Page 8/31 Report Printed: 11/7/2012 ii �,,j) Operations Summary Report •Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status _ Code Com 17:00 23:30 6.50•PULD BHA AF PJSM. MU^6.75"drlg assembly. Bit,Autotrak,OnTrak,LithoTrac,MagTrak. PJSM. Load RA sources.PU Sonic tool,float sub, RIH on HWDP&jars. 23:30 00:00 0.50 CIRC MUD AF Shallow test directional tools-OK. 00:00 03:00 3.00 TRIP BHA AF RIH w/drlg assembly to 7049'. 03:00 04:00 1.00 CIRC MUD AF Fill pipe. Down link tool.Wash f/7049'--7070'.Establish drilling parameters. 04:00 06:00 2.00 DRILL ROT AF PJSM.Drlg f/7070'--7147'. Report Date: 7/5/2011 Job Category: DRILLING 24 Hr Summary Drill 6.75"prod hole w/rotary steerable assembly f/7140'to 8238'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 00:00 18.00'DRILL ROT AF Continue drlg w/rotary steerable assembly. Pumped HiVis sweep @ 7750'. -20%increase in cuttings.PU: 108k;SO:60k;ROT:80.75 RPM;5/10k WOB;250 gpm; 1850 psi;Torque 5k. 00:00 06:00 6.00 DRILL ROT AF Continue drlg w/rotary steerable assembly. PU: 108k;SO:60k;ROT:80.75 RPM;5/10k WOB;250 gpm; 1850 psi;Torque 5k. Report Date: 7/6/2011 Job Category: DRILLING 24 Hr Summary Drld prod hole to 8369'.Circ Lo-Vis sweep. Short trip to shoe. Minor drag f/7500'--7300'. RIH. Precautionary wash 60'to bottom.Continue drlg f/8369'to 9064'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 08:00 2.00 DRILL ROT AF Continue drlg w/rotary steerable ass'bly. P/U 108k:S/0 60k:ROT:80,75 RPM:5/10k WOBL 250 gpm: 1850 psi:Tq 5k 08:00 10:30 2.50 CIRC MUD AF Circulate Btm/u-Pump Lo-vis Sweep&prep for wiper Trip. Large increase (200%)i cuttings w/sweep. 10:30 13:00 2.50 TRIP WIPR AF PJSM.Perform Wiper trip to shoe-Some 0/pull from 7450'to shoe-No Bk/reaming Req'd. 13:00 13:30 0.50 SERVIC RIG AF Service rig.Top drive,blocks&crown. 13:30 14:30 1.00 TRIP WIPR AF PJSM.RIH to 8308'.Precautionary wsh to 8369'. 14:30 06:00 15.50 DRILL ROT AF PJSM.Continue drlg 6.75"production hole w/rotary steerable assembly f/ 8369 to 9064' Report Date: 7/7/2011 Job Category: DRILLING 24 Hr Summary Drld prod hole to 9822'.Circ Lo-Vis sweep.Well flowing.Raise mud wt 0.2 to 10 ppg. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 02:00 20.00 DRILL ROT AF Drill 6.75"production hole w/rotary steerable assembly f/9064'to 9822'. 02:00 '04:30 2.50 CIRC MUD AF Circ&cond mud.Pump Lo-Vis sweep.200%cuttings increase w/sweep. 04:30 06:00 1.50 CIRC MUD AF 'Prep f/short trip.Check for flow.Well flowing slightly.Circ to raise mud wt from 9.8 ppg to 10 ppg. Report Date: 7/8/2011 Job Category: DRILLING 24 Hr Summary Increase mud wt to 10 ppg. Short trip f/9821'to 8306'. Hole in good shape.Sery rig. RIH.Wash 60'to bottom.Drill f/9821'to Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code _ Corn 06:00 06:30 0.50 CIRC MUD AF Continue Increase Mud Wt f/9.8 PPG to 10.00 PPG 06:30 07:30 1.00 FLOW CHEK AF 'Monitor Well-Static 07:30 09:00 1.50 TRIP WIPR AF Perform Wiper Trip to 8306'-Smooth-No O'pull 09:00 10:00 1.00 SERVIC RIG AF Rig service 10:00 11:00 1.00 TRIP WIPR AF RIH to 9758-Smooth 11:00 11:15 0.25 WASH FILL AF Safety Wsh f/9758'to 9822' 11:15 06:00 18.75 DRILL ROT AF Drlg 6.75"production hole. Background gas fluctuating f/50 to 150 units. Max connection gas @ 760 units Report Date: 7/9/2011 Job Category: DRILLING 24 Hr Summary Drill 6.75"production hole f/10,720'to 11,720'. Ops Trouble Start Time End Time _ Dur(hr) Ops Code Activity Code Status Code Corn 06:00 06:00 24.00 DRILL ROT AF Drill 6.75"production hole as per plan.Background gas @ 50-75 units; Connection gas @ 200-300 units. www.peloton.com Page 9/31 Report Printed: 11/7/2012 • Operations Summary Report 'Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name Licensed State/Province Country Seward Meridan,Sec.6,T1S, R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Daily Operations Report Date: 7/10/2011 Job Category: DRILLING 24 Hr Summary TD 6.75"hole.Circ&cond. POH to shoe.Cut&slip drag line. POH. LD BHA. MU BHA. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 08:00 2.00 DRILL ROT AF Continue drill 6.75"Production hole w/Rotary Steerable Ass'bly f/11720'to 11794'(Planned TD)_ 08:00 '12:30 4.50 CIRC MUD AF CBU++Pump Lo-Vis Sweep&then Hi-Vis Sweep then LoTorque pill& Monitor Well. 12:30 -15:00 2.50 TRIP BHA AF POH to 9821'.SLM. 15:00 '15:30 0.50 CIRC 'MUD AF Pump dry job. 15:30 18:30 3.00 TRIP -BHA AF Continue POH to shoe(6948').SLM.Hole in good shape. 10k overpull 1 std below shoe. 18:30 20:00 1.50 SERVIC RIG AF PJSM.Cut&slip drlg line. 20:00 02:00 6.00'TRIP -BHA AF Continue POH. 02:00 02:30 0.50 PULD -LOG AF PJSM. Unload RA source 02:30 03:30 1.00 PULD BHA AF Download logging data f/MagTrak 03:30 05:00 1.50 PULD BHA AF Continue LD BHA. 05:00 06:00 1.00 PULD 'BHA AF MU clean out/test BHA Report Date: 7/11/2011 Job Category: DRILLING 24 Hr Summary MU BHA.RIH.Tight @ 7076'.Start washing&reaming down.80 rpm;250 gpm; 10k WOB.Ream f/7076'to 9655'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 08:00 2.00 PULD BHA AF MU clean out/testing BHA. 08:00 09:00 1.00 PULD BHA AF PJSM. Plug in&test TesTrak tool-OK.Continue MU BHA. 09:00 14:00 5.00 TRIP DP AF RIH w/BHA on 4"DP.Tight ©7076'(130'out of shoe.) 14:00 06:00 16.00 REAM OH AF Wash&ream open hole f/7076'to 9655' @ 80 RPM w/250 GPM. 10k WOB. Report Date: 7/12/2011 Job Category: DRILLING 24 Hr Summary Continue washing&reaming down.80 rpm;250 gpm; 10k WOB. Ream f/9655'to 11,617'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status _ Code Corn 06:00 06:00 24.00 REAM OH AF Wash&ream open hole f/9655'to 11,617' @ 60-80 RPM w/250 GPM. 10k WOB. Backream each stand. Report Date: 7/13/2011 Job Category: DRILLING 24 Hr Summary Ream to 11,677'.Circ&cond mud.Take pressure points&log w/TesTrak. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 08:00 2.00 REAM OH CS Continue Ream f/11,617'to 11,677'-Decide to Log w/Tes Trac(24 sets)& then clean/out to TD w/slick ass'bly 08:00 10:00 2.00 CIRC MUD AF Circulate Btms/up 10:00 06:00 20.00 LOG OH 'AF Log 1st 4 sets/of 24-11,643', 11,597', 11,563'&11,463' -Re-set Tracker.Log&test the following points: 11,514', 11,559', 11,148', 11,152', 11,083', 11,080', 11,049', 11,047'11,090', 11,052'11,042', 11,040', 10,921', 10,899', 10,902', 10,897', 10,730', 10,608', 10,594', 10,916', 10,904', 10,900', 10,928',9884',9888',9447' Report Date: 7/13/2011 Job Category: DRILLING 24 Hr Summary Finish taking pressure points.POH. Download TesTrak tool&LD BHA. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code _ Corn 06:00 13:30 7.50 LOG OH AF Finish Take Pressure Points&Log w/Tes Trac Total Press Pts(DPM)= 11,643', 11,597', 11,563', 11,561', 11,459', 11148', 11,152', 11,083', 11,080', 11,049', 11,047', 11,090', 11,052', 11,052', 11,052', 11,042', 11,040', 10,921', 10,899', 10,902', 10,897', 10,730', 10,608', 10,594', 10,916', 10,904', 10,900', 10,928',9884',9888',9447',9452',9310',9282',8420',8373',8373',7900', 7897',7601',7480',7472,7476',&7319' 13:30 16:30 3.00 TRIP DP AF POOH w/DP&Tes Trac BHA 16:30 19:30 3.00 PULD BHA AF Stand back HWDP. LD BHA. Download&LD TesTrak tool.Stabilizers in BHA were full 6.75"gauge. www.peloton.com Page 10/31 Report Printed: 11/7/2012 1 VI Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Daily Operations Report Date: 7/14/2011 Job Category: DRILLING 24 Hr Summary MU BHA.RIH to shoe.Sery rig.RIH.Wash to bottom.Circ&cond. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 19:30 20:00 0.50 PULD BHA AF PJSM.MU BHA. 20:00 23:00 3.00 TRIP DP AF RIH w/4"DP to 6993'. 23:00 00:00 1.00 SERVIC RIG AF Lube&service top drive,crown,blocks,and carrier. 00:00 02:30 2.50 TRIP DP AF RIH f/6993'to 11,500'.Taking weight. 02:30 04:00 1.50 REAM OH •AF Wash&ream to TD @ 11,794'. 04:00 06:00 2.00 CIRC MUD AF Circ&cond hole.Pump LoVis followed w/HiVis sweep. Report Date: 7/15/2011 Job Category: DRILLING 24 Hr Summary Circ. B/U. Pump sweeps and CBU. Drop rabbit POOH B/R 11,600'to 11,575'. Cont.POOH to the 7033'. RIH to 11,794'wash through bridge @ 11,300'. Cont. RIH and wash last 80'to bottom w/8'fill. Pump sweeps and CBU.POH.LD HWDP.Test rams f/4.5"pipe.RU casing crew. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 07:30 1.50 CIRC MUD AF CBU pump a 30bbl low-vis sweep followed by a 30bbl hi-vis sweep w/nut plug.and circ.clean. Nut plug returned over the shakers indicating 35% washout. 07:30 13:00 5.50 TRIP DP AF PJSM. Drop a 2.375"rabbit and POOH to the casing shoe at 7033'(had to B/R F/11,600'to 11,575'). 13:00 16:30 3.50 TRIP DP AF RIH and TAG @ 11,300'. Wash through obstruction w/250GPM no rotation. Cont.to Rh-land wash last 80'to bottom w/8'fill. 16:30 18:30 2.00 CIRC MUD .AF Pump a 30bbl lo-vis sweep followed by a 30bbl hi-vis sweep w/nut plug.Nut plug returned over shakers indicating 35%washout. Circ.out with 280GPM 1700psi 70RPM TQ 9-11K Ft-lb Up 180K DN 85K Rot 120K 18:30 01:30 7.00 TRIP DP AF PJSM.Check f/flow.Pull 5 stds.Pump dry job.POH.Hole in good condition. 01:30 03:00 1.50 PULD BHA AF PJSM.LD BHA.Recovered rabbit. 03:00 04:30 1.50 PULD EQIP AF PJSM.MU cement head&DP pup.Pull wear ring&MU 4.5"test jt.&test plug. 04:30 05:00 0.50 TEST BOPE AF Test upper pipe rams to 250/3000 psi-OK. Run wear bushing. 05:00 06:00 1.00 RURD CSG AF RU casing crew. Report Date: 7/16/2011 Job Category: DRILLING 24 Hr Summary R/U casing tools. Run 4.5"liner.Circ liner volume. RIH to shoe.Circ string volume.RIH.Wash 30'to bottom.Circ&cond while reciprocate&rotate.Safety meeting.Pump spacer.Start pumping cement. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 08:30 2.50 RUN .CSG AF Cont.to R/U casing tools. 08:30 10:00 1.50 RUN CSG AF PJSM for running casiing. M/U shoe track(Bakerlok). Float shoe,2jnts,Float collar and Landing collar. Circulate through shoe track and check floats(OK). 10:00 15:30 5.50 RUN CSG AF Cont.to run 4 1/2"12.6ppf L-80 Hydril 563 Liner(total 117jnts,4884')M/U torque 9100ft-lb. 15:30 16:30 1.00 RUN CSG AF Changed to short bales and DP elevators. 16:30 18:30 2.00 RUN CSG AF M/U Baker 7 5/8"X 4 1/2"Flex-Lock liner hanger tools.Mix packer gel. 18:30 19:00 0.50 CIRC MUD AF Circ liner volume. 19:00 20:30 1.50 RUN 'CSG AF Continue RIH w/liner on 4"DP to 7018'. 20:30 21:00 0.50 CIRC MUD AF Circ string volume @ shoe.PUW: 190k;SOW:42k;ROT:55K;3K torque w/ 28 rpm. 21:00 01:00 4.00 RUN CSG AF Continue RIH w/liner on DP to 11,765'. 01:00 02:00 1.00 WASH FILL AF PJSM.PU&MU cement head.Wash to 11,794'.(-8'fill) 02:00 04:00 2.00 CIRC MUD AF Circ.Rotate&reciprocate.PUW: 180k;SOW:60k;Rot: 125k; 10 RPM w/10k torque on upstroke 7k on downstroke.200 GPM. 04:00 05:00 1.00 SAFETY MTG AF Il PJSM w/all personnel.Pressure test BJ lines to 250/4800 psi. 05:00 06:00 1.00 PUMP CMT AF < Pump 60 bbls 10.5 ppg SealBond Spacer.Mix and pump 397sxs Class"G" -' ,, cement5 w/15%bwoc BA-90, .05%bwoc Static Free,.15%bwoc R-3, 1.4% ,V bwoc FL-63, 1%bwoc CD-32,1 GPHS FP-6L,22%bwoc LW-7-6 to yield 170bbls 11.0ppg slurry(40%excess over 6 3/4"gauge hole). www.peloton.com Page 11/31 Report Printed: 11/7/2012 if-A. J Operations Summary Report •Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Daily Operations Report Date: 7/17/2011 Job Category: DRILLING _ 24 Hr Summary Cement 4 1/2"liner. Release liner running tool and circ.clean. POOH and L/D 4"DP and liner hanger RT.Test BOPE. P/U polish mill assy and RIH to 2845'. Clean and organize rig while WOC. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 07:30 1.50 PUMP CMT AF Washed up cement lines. Dropped wiper dart and displaced w/147bbls(2bbls over calculated)10.1 ppg mud. Bumped plug w/2800psi 1500psi over last displacement pressure. Bled off pressure and checked floats(OK). CIP@07:30hrs. Continued to rotate 20rpm and reciprocate 6'strokes until last 30bbls of displacement pumped. 07:30 08:30 1.00 PUMP CMT AF Pressured up to 2800psi and set liner hanger. S/O and confirmed liner hanger is set. Pressured up to 3800psi and released the liner hanger running tool from the liner hanger assy. Verified tool is released. Circulated B/U 260GPM from the liner top(circulated out 100bbls of contaminated spacer/mud and 5-10 bbls contaminated cement). Liner shoe @ 11,790' Liner Top @ 6866'. 08:30 09:00 0.50 RURD OTHR AF PJSM. R/D cement head. 09:00 09:30 0.50 CIRC MUD AF P/U to clear liner hanger tool from seal bore and circulated B/U 260gpm. 09:30 11:00 1.50 TRIP DP AF PJSM. POOH to 4487'and racked back DP. 11:00 16:30 5.50 PULD DP AF PJSM. POOH and L/D 142 jnts 4"DP. 16:30 17:30 1.00 PULD BHA AF L/D Baker liner hanger running tools. 17:30 21:00 3.50 TEST BOPE AF PJSM. R/U to test BOPE. Pull wear bushing.Test annular to 250/2500psi 5min. Test lower 4"pipe rams,upper 2 7/8"X 5 1/2"variable rams, 1-12 cmv's,inner and outer manual kill line valves,choke line HCR valve,choke line manual vale,upper and lower top drive valves,4"dart valve and TIW valve to 250/3000psi 5min. Perform koomey performance test(OK). Pull test joint and test blind rams to 250/3000psi 5min(Test waved by Jeff Jones AOGCC). Pull test plug. 21:00 21:30 0.50 RUNPUL WBSH AF R/D test Equipment. Ran wear bushing. 21:30 22:00 0.50 SLPCUT DLIN AF PJSM. Slip 33'drilling line. 22:00 23:00 1.00 TRIP DP AF PJSM. M/U polish mill assy and RIH to 2845'. 23:00 00:00 1.00 WAITON CMT AF While WOC,cleaned and scrubed rig floor and greased choke manifold valve. 00:00 06:00 6.00 WAITON CMT AF While WOC,cleaned rig floor,scrubed pit walls,needle guned,scrubed under carrier,cleaned dog house. Report Date: 7/18/2011 Job Category: DRILLING 24 Hr Summary RIH w/polish mill. Polished the top of liner. POOH and L/D the polish mill assy and P/U the ZXP packer. RIH w/the ZXP and set. Test casing and liner to 1500psi/30min. POOH L/D DP. R/U to run TBG. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 08:00 2.00 TRIP DP AF PJSM. RIH F/2845'to 6865'. Tagged TOL @ 6866'. 08:00 08:30 0.50 CIRC MUD AF PJSM. Dress top of liner and polish seal bore w/polish mill.91GPM 350psi 40RPM 10K WT. 08:30 10:30 2.00 CIRC MUD AF Circ.B/U X 2. Observed cement cutting across shakers at first B/U. Cont.to circ.clean. 10:30 14:00 3.50 TRIP DP AF Flow check(OK). Pump dry job. POOH w/polish mill. 14:00 14:30 0.50 'PULD PKR AF Inspect and L/D the polish mill. P/U the 4 1/2"X 7 5/8"ZXP liner top packer. 14:30 19:30 5.00 TRIP DP AF RIH w/the ZXP packer. 19:30 20:30 1.00 SETREL PKR AF Located liner top while pumping 1 bbl/min. Stung seals into seal bore. Dropped setting ball. Test lines to 5000psi w/BJ. 20:30 22:00 1.50'SETREL PKR AF Set ZXP w/4000psi w/BJ. Pull tested packer w/10,000lb and S/O 20,000. Released from packer w/20 turns.New TOL@ 6851'. P/U and verified released. Layed out one joint of DP and R/U cemet line to DP. Tested lines to 5000psi. Attempted to shear ball seat but it appeared ball seat was washing out. R/D cement line and dropped dart for the pump out sub. Attempted to activate the pump out sub without success. 22:00 23:00 1.00 TEST CSG AF Closed annular and circulated down DP and kill line through an open choke. Closed choke and tested 4 1/2"liner and 7 5/8"casing to 1500psi/3omin(OK). www.peloton.com Page 12/31 Report Printed: 11/7/2012 • Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 23:00 23:30 0.50 CIRC MUD AF Pumped down DP and pressured up to 2000psi and opened the pump out sub.Circulate through pump out sub. Checked flow(OK)Pumped dry job. 23:30 05:00 5.50 PULD DP AF POOH w/ZXP setting tool and L/D DP. L/D ZXP setting tools. 05:00 06:00 1.00 RURD CSG AF R/U to run TBG. Report Date: 7/19/2011 Job Category: DRILLING 24 Hr Summary R/U TBG handling tools.Run 4 1/2"TBG completion. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 08:00 2.00 RURD CSG AF R/U TBG handling tools. 08:00 08:30 0.50 SAFETY MTG AF Safety meeting prior to running TBG. 08:30 15:00 6.50 RUNPUL TBG AF Run 4.5"12.6PPF L-80 IBT-mod TBG completion to 5384'. 15:00 18:00 3.00 RUNPUL TBG AF M/U chemical injection mandrel. Tested control line to 2000psi 10min(OK). Cont.to run 4 1/2"TBG to 6728'banded control line 2 bands per joint. 18:00 20:00 2.00 RUNPUL TBG AF M/U SCSSV and installed the control line. Tested the control line to 5000psi 10min(OK).Ran 4 1/2"TBG to 6870'banded control lines 2 bands per joint. . 20:00 21:30 1.50 RUNPUL TBG AF Installed circulating head and circulated down and stung seals into seal bore. Spaced out tubing string w/9.83'pup below a full jnt of tubing to give a 1.7' space out. 21:30 23:00 1.50 RUNPUL TBG AF M/U TBG hanger and landing joint. Installed circulating hose.Fed control lines through the TBG hanger. R/D tubing handling tools. 23:00 02:00 3.00 CIRC CFLD AF Pumped 50bbl spacer and displace to 3%KCL brine. Spotted corrosion inhibitor in the annulus. 02:00 05:00 3.00 TEST EQIP AF Landed out the TBG hanger. Tested TBG to 1500psi 10min(OK). Tested hanger seals to 5000psi 10min(OK).Tested annulus to 1500psi 10min(OK). Released landing joint and L/D.Set BPV. 05:00 06:00 1.00 RURD OTHR AF R/D Pollard control lines and banding. Empty and clean pits. Report Date: 7/20/2011 Job Category: DRILLING 24 Hr Summary N/D BOPE. N/U tree and test. Set BPV. R/D pumps and topdrive. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 07:00 1.00 CLEAN RIG AF PJSM. Flush all pump and mud lines,BOP stack,choke manifold and poorboy degasser. 07:00 12:00 5.00 NUND BOPE AF PJSM. L/D mouse hole. R/D flow line,fillup line,bleeder line,trip tank line, drip pan,turnbuckles,and koomey lines. Remove UPR's,R/D choke and kill lines. Haul off fluid and clean pits. N/D annular. R/D Canrig shack. Empty and clean pits. 12:00 17:00 5.00 NUND BOPE AF N/D BOPE. Empty and clean pits. Pickle pump#3. Clean and empty pits. 17:00 21:30 4.50 TEST TREE AF N/U tree. Test seals to 5000psi/10min. Pull BPV.Set TWC. Fill tree with methanol water. Test tree to 5000psi/10min. Pul TWC and set BPV. 21:30 00:00 2.50 RURD RIG AF R/D floor,mud manifold,shut down boiler,pickle pumps 1 and 2. Prep DD trailer for transport. Clean trip tank. Load trailers. 00:00 06:00 6.00 RURD RIG AF PJSM. R/D dresser sleeves,pop of lines for pumps#1 and#2. R/D suction and service lines for pump#3. R/D poorboy degasser. Clean rig floor and cellar. R/D geolograph. Palletize and band rig equipment. Remove saver sub from top drive. R/D top drive service loop and torque bushing. Report Date: 7/21/2011 Job Category: DRILLING 24 Hr Summary R/D rig. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 12:00 6.00 RURD 'RIG AF PJSM. R/D the top drive. Install ports to check end compartments in the pits. Blow down steam lines. R/D centrifuge. Clean hanson tank. 12:00 18:00 6.00 RURD RIG AF PJSM. Load out top drive and torque tube. R/D strong back and floor plate turnbuckles,trip tank gauge. Clean pits. Clean rental tank. R/D stairs on vacant camp trailers. Blind flange piping in pits to end compartments. Test SCSSV(function test). www.peloton.com Page 13/31 Report Printed: 11/7/2012 Operations Summary Report • Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code _ Corn 18:00 00:00 6.00 RURD 'RIG AF PJSM. R/D pump#3 electric and utility lines. Remove a broken bolt on manhole covers on pits end tanks,seal and bolt down. R/D tarps and bows on carrier. L/D beaver slide. R/D BOP connex stairs,auto driller,load out matting boards. Pump out boiler condensate tank and blow down. Unplug choke house. R/D derrick board. R/D lights on choke house and dog house. 00:00 '06:00 6.00 RURD RIG AF PJSM. R/D vacant camp trailers. Monitor rig. Report Date: 7/22/2011 Job Category: DRILLING 24 Hr Summary R/D rig. Loaded trailers. Prepped rig to move. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code _ Status _ Code Com 06:00 12:00 6.00-RURD RIG AF PJSM. Cleaned hansen tank. Shiped out"C"model loader to Cannery Loop. Preped to move camp. 12:00 13:00 1.00 SAFETY MTG AF 1 hour weekly safety meeting. 13:00 18:30 5.50 RURD RIG AF PJSM. Loaded matting boards. Moved pump#3. Prepped derrick to scope down. Washed hansen tank. Moved hansen tank. Fueled camp generator. Transferred fuel from rig to truck. Unplugged pits,pump room,dog house, water tank,boiler house,bop connex,sub base,emptied water tank. 18:30 21:00 2.50 RURD RIG AF PJSM. Craned back winwalls and floor plate, BOP connex,DS stairs and platform,ODS stairs and platform,poor boy degasser,centrifuge and fuel tank. 21:00 00:00 3.00 RURD RIG AF R/D brake handle. R/D rig floor hydraulics,prepped derrick to lay over, R/D cuttings tank and storage unit and load. Removed berm. 00:00 01:00 1.00 SAFETY MTG AF 1 hour weekly safety meeting. 01:00 07:00 6.00 RURD RIG AF PJSM. R/D outside lights on pits and pump room exhaust fans. R/D boiler stack and blow down lines. R/D generator exhaust lines. Removed berms and load out dunage. PJSM. Lay down mast. Fold up carrier windwalls. Removed turnbuckles loer carrier off of jacks and prep carrier for move. Report Date: 7/23/2011 Job Category: DRILLING 24 Hr Summary R/D Rig. Released rig to CLU 12 @ 00:00hrs 7/23/2011. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 12:00 6.00 SAFETY MTG AF PJSM. Fill camp water. Load trailers. R/D hand rails and landings. PJSM. Crane dog house and choke house,grey iron,flow line,stairs,derrick house, R/D camp units. 12:00 00:00 12.00 MOB RIG AF PJSM. R/D rig. Prep rig to move. Move camp. Lay liner and matting boards on CLU Pad 3 for CLU 12. R/U rig camp on CLU 3 Pad. Rig released to CLU 12 @ 12:00 hrs 7/23/2011. Report Date: 10/12/2011 Job Category: COMPLETION 24 Hr Summary Spot and rigup CTU and Tanks. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 07:00 1.00 SAFETY MTG AF Hold PJSM. Discuss JSA and BJ checklist. Issue permit. 07:00 11:00 4.00 RURD COIL AF Spot Coiled Tubing equipment. Respot tanks.Start rigging up. 11:00 16:00 5.00 RURD COIL AF Rig up flowback equipment and choke manifold.Continue rigging up coiled tubing.Spot and rig up filter unit. Start moving water and mixing 300 Bbl 6% KCI. 16:00 19:00 • 3.00 RURD COIL AF - Continue Mixing first 240 Bbl 6%KCI.Secure location and release crew. Report Date: 10/13/2011 Job Category: COMPLETION 24 Hr Summary Finis rigging up CTU. Fill and test lines and BOP 250 psi/4500 psi.Pump pig through CT. Rig back for night. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 '07:30 1.50 TRAVEL TRCK AF BJ meet at Nikiski shop and hold safety meeting.Travel to SD location 07:30 08:30 1.00 SAFETY MTG AF Hold PJSM. Discuss JSA and assign tasks. Discuss BJ checklist and job plan. Issue permit. 08:30 14:30 6.00 RURD COIL AF Unload BOP.Unload and spot toolroom.Finish rigging up iron. RU BOP on well.PU injector and 16'lubricator. www.peloton.com Page 14/31 Report Printed: 11/7/2012 .1J Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 14:30 17:30 3.00 TEST BOPE AF fill and test surface lines.Test blind rams 250 psi/4500 psi.Pump pig through CT.Test pipe rams 250 psi/4500 psi.Bleed down.Rig back lubricator and injector and prepsre for night. 17:30 18:00 0.50 SECURE 'WELL AF Secure well and location.Leave location. Report Date: 10/14/2011 Job Category: COMPLETION 24 Hr Summary Pull BPV. PU 3.80"mill and motor and stab on.test lubricator connection to 4500 psi.Open well and RIH.Clean out to 11,663'CTMD RKB. PTest 4-1/2"csg to 1530 psi. Test good. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 07:00 1.00 TRAVEL TRCK 'AF Hold BJ travel safety meeting.Travel to KGF. 07:00 08:00 1.00 SAFETY MTG AF Attend Ninilchik monthly safety meeting. 08:00 08:30 0.50 TRAVEL TRCK AF Travel from safety meeting to Susan Dionne pad. 08:30 09:30 1.00 SAFETY MTG AF Hold PJSM.Discuss JSA and assign tasks.Discuss BJ checklist and issue permit. 09:30 11:30 2.00 'RURD COIL AF Start equipment.Spot light plants.Pull BPV.RU hand pump to operate SSSV.Open SSSV.Opening pressure is 1200 psi with about 15 pumps to open SSSV.Continue pumping to 3500 psi. 11:30 14:30 3.00 RURD COIL 'AF PU Weatherford motorhead assy and pull test to 10,000#.Pressure test motor head assy to 4500 psi.Pick up 3.80"mill and motor.Stab on well and test lubricator to 4500 psi. 14:30 23:00 8.50 RUNPUL COIL AF RIH 3.80"mill through SSSV at 166'.Start pump at 0.5 BPM and continue RIH.Stop at 11,663'CTMD RKB. Circulate and short trip.POH while circulating at 1.75 bpm. At 2800'PTest casing to 1530 psi for 10 min. Test good. Bring on N2 @ 1600'to blow down coil. 23:00 00:00 1.00 RURD COIL AF Rig back CT unit for eline rig up.Secure well and leave location. Report Date: 10/15/2011 Job Category: COMPLETION 24 Hr Summary RU eline unit and PU CBL.Attempt to RIH.Tagging hard at 1570'(below injection mandrel).Unable to pass 1570'. Ops Trouble Start Time End Time Dur(hr) Ops Code _ Activity Code Status Code Com 06:00 07:00 1.00 SECURE WELL AF SDFN 07:00 08:00 1.00 SAFETY MTG 'AF Hold PJSM.Discuss Pollard JSA and checklist.Assign tasks.Issue permit 08:00 10:00 2.00 RURD ELEC AF Spot and rigup eline truck.PU roller centralized CBL with 3.60"roller bogey on bottom of string.Stab on well. 10:00 14:00 4.00 RUNPUL ELEC AF RIH CBL.Tag hard obstruction at 1570'.We can see injection mandrel above obstruction on CCL.We II is 58 Deg at obstruction.We can run 200'/min above obstruction.Loosen roller centralizers and make second attempt. Same tag.Remove 3.60"roller bogey from bottom of tool string and rerun tools.Same hard tag.Arrange for slickline unit in AM to clear out obstruction 14:00 15:00 1.00 SECURE 'WELL AF Rid down eline unit and secure well and location.Close permit and leave location. Report Date: 10/16/2011 Job Category: COMPLETION 24 Hr Summary RU slickline unit with 3"bailer.Bail 14 trips at 1568'down to 1620'and recover 20 gal of solids.RD slickline and prep for CT. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 07:00 1.00 SAFETY MTG AF Hold PJSM.Discuss Pollard JSA and checklist.Assign tasks. Issue permit 07:00 08:00 1.00 RURD SLIK AF Rig up slickline unit.PU 4'X 3"drive down bailer.Stab on well. 08:00 17:30 9.50 RUNPUL SLIK AF RIH 3"bailer.Tag at 1568'and work bailer.Run 6 times and recover 1 gal (full)from each bailer.Change to 6'bailer.Run 8 times with 2 gal recovery each run.Total recovery is about 20 gal of solids.Worked down to 1620'. 17:30 18:00 0.50 SECURE WELL AF Rig back unit and secure well and location.Release crew.Start loading water for coiled tubing cleanout in the AM. Report Date: 10/17/2011 Job Category: COMPLETION 24 Hr Summary RU CTU.Jet well from surface to 2400'at 1.75 BPM to clean out solids.Circ 1.75 bpm back to surface. RU Slickline. RIH 3"bailer and tag at 1510'.Unable to pass 1510'. POH and recover full bailer of same contaminated solids.Test solids with soap.Soap removes substance stabilizing solids and reduced putty to solids and water. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 06:30 0.50 SAFETY MTG AF BJ pre travel safety meeting. 06:30 07:30 1.00 TRAVEL TRCK AF Travel from BJ shop to Ninilchik. www.peloton.com Page 15/31 Report Printed: 11/7/2012 f/' A.,J Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 07:30 08:30 1.00 SAFETY MTG 'AF Hold prejob safety meeting.Discuss JSA and BJ checklist.Assign tasks and issue permit. 08:30 09:30 1.00 RURD COIL AF RU coiled tubing.PU 2.8"nozzle and sta on.Shell test to 1500 psi. 09:30 12:00 2.50 RUNPUL COIL AF RIH pumping 1.75 BPM at 4000 psi.RIH 30-40 fpm to 2400 psi.Pump 10 minutes on bottom and POH at 60'/min. 12:00 12:30 0.50 SAFETY MTG AF Hold Pollard safety meeting.Discuss Pollard JSA and checklist.Assign tasks. Add Pollard to existing permit. 12:30 13:00 0.50 RURD SLIK AF Rig up slickline.PU 3"bailer to drift well. 13:00 15:00 2.00 RUNPUL SLIK AF RIH 3"bailer.Tag at 1510'.Work bailer w/o making progress.POH and dump full bailer with same putty like solids as before.RIH w/o bailer to bypass solids.No luck.RUH with brush,No luck. 15:00 16:30 1.50 RURD SLIK AF Stand by and attempt to break putty recovered from well.Mixing with soap and water breaks solids out of putty.Discuss with Baker chemical and MI. Decide to attempt jetting with hot soapy water to clean solids out of 4-1/2". 16:30 17:00 0.50 SECURE WELL AF Secure well and location.Release all crews. Report Date: 10/18/2011 Job Category: COMPLETION 24 Hr Summary RU CTU.Jet well from surface to 2400'at 1.75 BPM to clean out solids.Circ 1.75 bpm back to surface. RU Slickline.RIH 3"bailer and tag at 1559'.Unable to pass 1569'.POH and recover full bailer of same contaminated solids. RIH 3.8"mill to 2400'and POH milling.RIH slickline.Tag at 1499'.Grab sample and POH. Ops Trouble Start Time ' End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 06:30 0.50 SAFETY MTG AF BJ pretravel safety meeting. 06:30 07:00 0.50 TRAVEL TRCK AF Travel from Nikiski to Ninilchik 07:00 08:00 1.00 SAFETY MTG AF Hold prejob safety meeting.Discuss BJ JSA and checklist.Assign taSKS AND ISSUE PERMIT. 08:00 09:00 1.00 RURD COIL AF RU CT with swirl jet nozzle.Stab on well and shell test to 1500 psi.Circulate 130 DegF water with soap through CT. 09:00 12:00 3.00 RUNPUL COIL AF RIH jetting well at 1.75 BPM with hot soapy water.Stop at 2400'.POH jetting. 12:00 12:30 0.50 RURD COIL AF Stand back CT to RU slickline. 12:30 14:30 2.00 RUNPUL SLIK AF RIH 3"bailer.Tag at 1559'.POH 3"bailer.RIH 2.25"swage.Tag at 1565'. POH.RIH 3"bailer and work on bottom.Recover full bailer and send sample to MI.Rig back slickline. 14:30 15:30 1.00 RURD COIL AF RU CT with motor and 3.80"mill.Shell test to 1500 psi.Water is 80 DegF. 15:30 18:00 2.50 RUNPUL COIL AF RIH milling.SD pump to pass SSSV.Tag at 1290'.Mill down to 2400'.SD pump to pass chemical injection mandrel/.Occasional weight loss but no motor stalls and no other tags.POH rotating mill.SD pump at injection mandrel)and SSSV. 18:00 18:30 0.50 RURD COIL AF Rig back CT to RU slickline. 18:30 -19:30 1.00 RUNPUL SLIK AF RIH 3"bailer.Tag at 1499'.Work on bottom and POH.Recovered 3/4 full bailer. 19:30 '20:00 0.50 RURD SLIK AF 'Rig back slickline.Blow down CT with N2.Release crews. Report Date: 10/19/2011 Job Category: COMPLETION 24 Hr Summary Rig down and release BJ coiled tubing and Pollard wireline. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 08:00 08:30 0.50 SAFETY MTG AF BJ pretravel safety meeting. 08:30 09:30 1.00 TRAVEL TRCK AF Travel from Nikiski to Ninilchik 09:30 10:30 1.00 SAFETY MTG 'AF Hold prejob safety meeting. Discuss BJ rigdown JSA and assign tasks. Discuss checklist.Issue permit. 10:30 14:30 4.00 RURD COIL AF Rigdown coiled tubing unit and pumps. 14:30 15:00 0.50 SAFETY MTG AF Hold Pollard prejob safety meeting.Discuss JSA and assign tasks.Discuss checklist.Add Pollard to existing permit. 15:00 17:00 2.00 RURD SLIK 'AF 'Rigdown slickline unit.Release all equipment 17:00 17:30 0.50 SECURE WELL -AF Secure well and location and leave. Report Date: 11/15/2011 Job Category: COMPLETION 24 Hr Summary Spot and rigup Baker coiled tubing,pump,and N2 unit.Test BOP www.peloton.com Page 16/31 Report Printed: 11/7/2012 • .iiViJ Operations Summary Report •Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S, R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date 'Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:00 08:30 0.50 SAFETY 'MTG 'AF Hold prejob safety meeting.Discuss Baker JSA and safety meeting check list. Assign tasks and issue permit. 08:30 15:00 6.50 RURD COIL 'AF Spot and RU coiled tubing unit,pump,and N2 unit. 15:00 16:00 1.00 TEST 'BOPE 'AF Test BOP stack 250 psi low,4500 psi high.Good test.AOGCC Bob Noble waived state witness at 10:00 AM Sunday Nov 13th. 16:00 16:30 0.50 SECURE WELL AF Secure well and leave location.Water will be transferred and heated in the night. Report Date: 11/16/2011 Job Category: COMPLETION 24 Hr Summary Perform tubing acid wash with 15%HCI and 10%surfactant as per MI recommendation. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 08:00 09:00 1.00 SAFETY •MTG AF Hold PJSM.Discuss Baker JSA and safety meeting checklist. Issue permit. 09:00 11:00 2.00'RURD COIL AF RU CTU.Stab on injector. 11:00 11:30 0.50 TEST 'EQIP AF Shell test injector/BOP 250 psi low and 4500 psi high. 11:30 13:00 1.50 RUNPUL COIL AF Tag ice at swa valve.Jet with hot water and melt ice plug. 13:00 15:00 2.00'RUNPUL COIL AF RIH CT to 11,600'. 15:00 17:00 2.00'PUMP ACID AF Pump 24 Bbls 15%HCI with 10%surfactant.Chase with 30 Bbl water at 1 BPM.Pump 2nd stage of 14 Bbls 15%HCI with 10%surfactant.Displace to CT nozzle plus 10 Bbls. 17:00 19:00 2.00'RUNPUL 'COIL AF POH at 100 FPM while displacing acid with water. 19:00 20:00 1.00 RURD COIL AF Rig back coiled tubing for eline rigup. 20:00 20:30 0.50 SECURE WELL AF Secure well,close permit,and leave location. Report Date: 11/17/2011 Job Category: COMPLETION 24 Hr Summary Wait on Wind.30 MPH and above winds. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 '18:00 12.00 WAITON 'WTHR TS WD 30 MPH plus winds.SD all work. Report Date: 11/18/2011 Job Category: COMPLETION 24 Hr Summary Run CBL 11,644'-6,700'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 09:00 10:00 1.00'SAFETY MTG AF Hold PJSM.Discuss Pollard Eline JSA and safety meeting checklist.Assign tasks. Issue permit. 10:00 11:30 1.50 'RURD ELEC AF RUeline.PU CBL tool.Stab on. 11:30 12:00 0.50 RUNPUL ELEC AF RIH.Tag at 1500'. 12:00 12:30 0.50 'LOG CSG AF Log free pipe pass. 12:30 14:00 1.50 RUNPUL ELEC AF Tag 2 times with small gains in depth.3rd time worked tool to 1550'and dropped through. Run to bottom with no problems. 14:00 17:00 3.00 LOG CSG AF Log CBL from 11,644'to 6,700'.Log 200'repeat pass. 17:00 17:30 0.50 RUNPUL ELEC AF POH CBL tool. 17:30 18:00 0.50 RURD ELEC AF Rig down and release eline unit. 18:00 06:00 12.00 SECURE WELL AF Secure well and location and close permit. Leave location Report Date: 11/19/2011 Job Category: COMPLETION 24 Hr Summary Reverse out fluid to 6,000'.N2 pump went down.Could not resume pumping N2. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 07:30 08:30 1.00 SAFETY 'MTG AF Hold prejob safety meeting.Discuss Baker JSA and safety meeting check list. Assign tasks and issue permit. 08:30 11:00 2.50 RURD COIL AF Start equipment.RU CTU. PU nozzle without check valves to reverse circulate and stab on well. 11:00 14:30 3.50 WAITON OTHR TA MSCT N2 pump will not run properly.Call for mechanic and repair N2 pump. 14:30 15:00 0.50 TEST EQIP AF 'Shell test BOP 250 psi/4500 psi.Good test. 15:00 17:00 2.00 RUNPUL COIL AF RIH reversing with N2. Reverse down to 6,000'.N2 unit started missing.SD N2 and trap pressure in well. 17:00 18:30 1.50 WAITON 'OTHR TA -MSCT -Work on N2 pump. Unable to repair pump. 18:30 19:30 1.00 RUNPUL COIL AF 'POH. www.peloton.com Page 17/31 Report Printed: 11/7/2012 r/j*". Operations Summary Report - Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time • End Time Dur(hr) Ops Code Activity Code Status Code Com 19:30 20:00 0.50 RURD COIL AF Trap 1200 psi on well.Blow down CT.Rig back coil.Will change out pump in AM and continue job. 20:00 20:30 0.50 SECURE WELL " AF Secure well and location.Close permit and leave location.Will return to perforate in 1 week. Report Date: 11/20/2011 Job Category: COMPLETION 24 Hr Summary Replace N2 pump.RIH and continue reversing fluid.Plugged CT with ice.Tarp reel and thaw overnight. Ops Trouble Start Time _ End Time Dur(hr) Ops Code Activity Code Status Code Corn 07:30 08:30 1.00 SAFETY MTG AF Hold prejob safety meeting. Discuss Baker JSA and safety meeting check list. Assign tasks and issue permit. 08:30 10:30 2.00 RURD COIL AF Start equipment.Spot in N2 pump and connect.Stab on well.Ambient temp is 4 DegF. 10:30 11:00 0.50 TEST EQIP AF Shell test to 250 psi low.4500 psi high. 11:00 17:00 6.00 RUNPUL COIL AF RIH pumping N2 down backside.Open returns at 6000'.Reverse to 6,600'. Lost returns.Work on regaining returns. Ice plug about 800'from CT swivel. POH.Trap 2200 psi on tubing. 17:00 18:00 1.00 RURD COIL 'AF Rig down coiled tubing and cover reel with tarp. Heat reel to thaw overnight. Heat water in supply and return tanks. 18:00 '18:30 0.50 SECURE WELL 'AF Secure well and location.THP=2200 psi N2. Report Date: 11/21/2011 Job Category: COMPLETION 24 Hr Summary Thaw coil.RIH and reverse out to 11,660'.Trap 2330 psi N2 pressure on CT for Perforating. Release CT unit. Ops Trouble Start Time End Time Dur(hr) Ops Code _ Activity Code Status Code Corn 07:30 08:30 1- .00 SAFETY MTG AF Hold prejob safety meeting.Discuss Baker JSA and safety meeting check list. Assign tasks and issue permit. 08:30 12:30 4.00 RURD COIL AF Thaw CT and fill with 50/50 McOH. 12:30 13:00 0- .50 RURD COIL AF Fill CT with 120 Deg water.Open well and use well pressure to reverse water out. 13:00 19:12 6.20 RUNPUL COIL AF RIH. Pump N2 to repressure well.Slow speed to 50'/min at 5600'to reverse out remaining water from well. Reverse to 11,660'. POH.Adjust well pressure to 2230 psi for perforating. 19:12 20:12 1- .00 RURD COIL AF Rig down and release coilerd tubing spread to SD-4 for v-string job. Remove BOP's and install tree cap. PTest tree cap w/well pressure. Test good. 20:12 20:42 0- .50 SECURE 'WELL AF Secure well and location.Close permit and leave location. Report Date: 11/22/2011 Job Category: COMPLETION 24 Hr Summary RD coil tubing unit. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status • Code Com 12:00 12:45 0- .75 SAFETY MTG 'AF Hold PJSA. Discuss alarms, muster area,and wind direction. Discuss emergemcy response. Watch walking surfaces. Very slick. Much clutter in front of tanks and around well head. Discuss JSEA and make job assingnments. 12:45 17:45 5- .00 RURD COIL AF Rig down coil. Rack up iron and hoses,tanks and liners. Vac up MEOH and move tanks to SD 4. Vac out both tanks and haul to G8,1(approx 350 bbls). Left 2"flowline from wellhead to choke to gas buster in place for N2 blow down from perforating. 17:45 18:15 0- .50 SECURE WELL 'AF Secure loc. Move equipment to SD 4. Report Date: 11/26/2011 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E-line to perforate Tyonek intervals. RIH w/CCL/GR and 3.375"perf guns loaded 4 SPF @ 60deg and perforate first interval f/11,591'-11,605' MD. Well showed little pressure increase. RD for night. Well built 185 psi(SITP)overnight(7 hours). Ops Trouble Start Time End Time Dur(hr) Ops Code • Activity Code Status Code Com 07:30 '09:15 1- ,75 SAFETY 'MTG 'AF Held PJSM w/Pollard wireline,CH2MHill,and operators. Discussed job hazards,weather conditions,and perf operations. Obtained safe work permit. 09:15 09:45 0.50 RURD OTHR AF Cleared location of snow. RU heater for frozen flowback lines. www.peloton.com Page 18/31 Report Printed: 11/7/2012 Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) 'Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 09:45 12:45 3.00 RURD ELEC AF RU Pollard E-line. Spot trucks,MU lubricator and tool string. Thaw frozen equipment. Well SI,SITP:2300psi. 12:45 13:30 0.75 RURD ELEC AF Held explosives meeting. Check fire and arm tool string. CCL to top shot= 8'. 13:30 14:30 1.00 TEST BOPE AF PT lubricator to 3500 psi. Repaired leaking o-ring twice. Good test. 14:30 16:30 2.00 RUNPUL ELEC AF RIH w/CCL/GR and 14'x 3.375"pert guns loaded 4 SPF @ 60deg. Tag bottom @ 11,632'MD. Bleed well pressure(N2)to 1985psi. 16:30 17:00 0.50 CORL FORM AF Correlate from Baker Hughes OH log dated 6/20/2011. Pull into position @ 11,583'(CCL depth)and perforate Tyonek interval f/11,591'-11,605'MD(OH log). Positive indication of firing,lost 200#on weight indicator and well pressure rose 5psi immediately. 17:00 19:00 2.00 RUNPUL ELEC AF POOH w/spent guns. Hung up in SSSV @ 166'MD. Work tools and unable to pass. RU heater and cycle valve. Pass through no problem. SSSV pump frozen at surface. Guns to surface,all shots fired. No indication of wet zone. 19:00 19:30 0.50 RURD ELEC AF RD Eline unit for night. LD lubricator,secure well(shut in),sign out,and leave location. Well built 185 psi(SITP)overnight(7 hours). Report Date: 11/27/2011 Job Category: COMPLETION 24 Hr Summary Decision to run static PT and determine fluid level prior to perforating next interval. Switch over from e-line to slickline and PU smaller lubricator. RIH w/tandem PT gauges,moving slow in deviated section. Sit down @ 2800'and POOH. Add additional weight bar and roller bogie. RIH w/tandem PT gauges and tag bottom @ 11,606'MD. POOH w/memory tools @ 120fpm. Found fluid level @ 10,671'MD and BHP of 3170psi. RD Pollard for night. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status ! Code Corn 07:30 08:45 1.25 SAFETY MTG AF Held PJSM w/Pollard wireline,CH2MHill,and operators. Discussed job hazards,weather conditions,and job scope. Obtained safe work permit. 08:45 10:15 1.50 RURD ELEC AF RU Pollard wireline. Change over unit to slickline. PU smaller lubricator, memory PT string on roller bogies,and stab on well. Well SI-SITP 2215psi. 10:15 -10:30 0.25 TEST BOPE AF PT lubricator to 3500 psi. Good test. 10:30 13:00 2.50 RUNPUL SLIK AF RIH w/RS,KJ,RB, 10'stem,RB,OJ,and tandem PT tools. Tools falling very slow through deviated section,possibly pushing debris on low side of hole. POOH to reconfigure tool string. 13:00 18:00 5.00 RUNPUL SLIK AF RIH w/RS,KJ,RB, 10'stem,RB,OJ,5'stem,RB,and tandem PT tools. Tools still falling slow to 8200',then RIH normal. Tag fill(sticky)@ 11,606'. Pick up to 11,601'and perform 5min bench. POOH to surface @ 120fpm and perform 5 min bench at tubing hanger. OOH-fluid level @ 10,671'MD. @ TD(11,601'MD)-145 degF and 3170psi. 18:00 19:00 1.00 RURD ELEC AF RD Eline unit for night. LD lubricator,secure well(shut in),sign out,and leave location. Well shut in @ 2250psi. Well steadily built 6psi/hr throughout day. Report Date: 12/2/2011 Job Category: COMPLETION 24 Hr Summary MIRU BJ N2 to displace water from well. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 09:00 10:00 1.00 SAFETY MTG AF Arrive location,sign in,receive safe work permit,hold PJSM-topics discussed-reviewed JSA,assigned jobs,slips,trips,falls,eye wash station, high pressure,emergency numbers,emergency vehicles,muster area,active gas production pad,red lights for fire,blue lights for gas emission,sirens for audible,stop the job authority,and keeping the focus on the job. Emphasize that we are in no hurry today. 10:00 11:00 1.00 RURD OTHR AF RD BJ N2 equipment on SD 4 and move to SD 7. RU N2 equipment to flow line. Pump open SSSV with 4000 psi on hand pump. 11:00 11:00 TEST EQIP AF Test N2 pumping lines to 5000 psi. Test good. www.peloton.com Page 19/31 Report Printed: 11/7/2012 Operations Summary Report - Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 11:00 11:00 PUMP N2 AF Begin pumping N2 into well. Time Treating Pressure N2 rate N2 Cum Total (psi) (scf/min (scf) 11:10 250 0 11:15 2406 1000 11:20 2570 1020 12.6K 11:25 2700 1250 19K 11:30 2780 1250 23.7K 11:35 2910 1250 30.6K 11:40 3000 1250 35.6K 11:45 3140 1250 42.6K 11:50 3260 1250 49.3K 11:55 3380 1250 55.2K 12:08 3700 1000 71.1K 12:23 3966 700 86K 12:38 4043 300 92K 12:51 4046 200 95K Shut down pumping. Close well in,but open to Skada for monitoring pressure. 11:00 11:00 RURD EQIP AF RD N2 pumping equipment 11:00 11:00 SECURE WELL AF Secure wellhead. Bleed pressure on SSSV and close. Report Date: 12/3/2011 Job Category: COMPLETION 24 Hr Summary MIRU Pollard slick line to run PT survey to determine fluid level. No fluid detected in wellbore. Max pressure @ 11600'3488 psia. max temp 144 degrees F. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 13:30 14:00 0.50 SAFETY MTG AF Arrive location,sign in,receive safe work permit,hold PJSM-topics discussed-reviewed JSA,assigned jobs,slips,trips,falls,eye wash station, high pressure,emergency numbers,emergency vehicles,muster area,active gas production pad,red lights for fire,blue lights for gas emission,sirens for audible,stop the job authority,and keeping the focus on the job. Emphasize that we are in no hurry today. 14:00 15:24 1.40 RURD SLIK AF Spot equipment. PU lubricator. MU tool string 1/34"RS,KJ,RBoggie,5' lead stem,KJ,Rboggie,5'lead stem,OJ,sj,tandem PT gauges. Carry tool string to wellhead. 15:24 15:36 0.20 TEST EQIP AF Test lubricator to 3000 psi. Test good. MU manual pump on SSSV and pump open w/4300 psi. 15:36 19:06 3.50 RUNPUL SLIK AF Stop at 21'for 5 min bench. Coninue RIH at 120 fpm to 11,610. stop for 5 min bench. POOH at 120 fpm. stop at 21'for 5 min bench. Tag at 11,610'. PU 10'. max pressure @ 11600' 3488 psi max temp 144 degree F Fluid level. None seen 19:06 19:36 0.50 RURD SLIK AF LD tools and lubricator. Prepare to run CIBP tomorrow. 19:36 19:51 0.25 SECURE WELL AF Secure well and location for the night. Turn in permit and leave loc. Report Date: 12/4/2011 Job Category: COMPLETION 24 Hr Summary RU Pollard E-line to set bridge plug and continue perforating. Set bridge plug @ 11,580'MD. Confirm set with tag and negative pressure test. Bleed well pressure(N2)down from 2690 psi to 1920 psi for underbalance. RIH w/10'x 3.375"perf guns loaded 6 SPF @ 60deg and pert 11,541'-11,551'MD(correlated from OH log). All charges fired, pressure built 12 psi in 15 min. RIH w/10'x 3.375"perf guns loaded 6 SPF @ 60deg and pert 11,101'-11,111'MD(correlated from OH log). All charges fired, little to no pressure response. POOH and RD Pollard. Well continues to show little response. SITP 1930psi. Having trouble operating safety valves so we will monitor the well overnight and continue preparing for production in the morning. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 08:00 08:45 0.75 SAFETY MTG AF Held PJSM w/Pollard wireline,CH2MHill,Baker Hughes Coil,MOC and operators. Discussed job hazards,weather conditions,simultaneous operations,and job scope. Obtained safe work permit. 08:45 09:45 1.00 RURD ELEC AF 'RU Pollard wireline. PU CIBP setting toolstring. 09:45 10:00 0.25 SAFETY MTG AF Held explosives safety meeting. Radio silence on pad. 10:00 10:15 0.25 TEST BOPE AF PU lubricator and tool string,stab on well. PT lubricator to 3500 psi. Good test. www.peloton.com Page 20/31 Report Printed: 11/7/2012 • Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,Ti S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 10:15 15:00 4.75 RUNPUL ELEC AF RIH w/GR/CCL,setting tool and 4 1/2"WEA CIBP. Correlate and pull into position(11,569.5'CCL depth)to set plug @ 11,580'MD. Confirm set with tag and negative pressure test. Bleed well pressure(N2)down from 2690 psi to 1920 psi for underbalance. POOH. 15:00 15:45 0.75 PULD PGUN AF MU GR/CCL,and 10'x 3.375"pert guns loaded 6 SPF @ 60deg. PU into lubricator and stab on well. 15:45 18:30 2.75 RUNPUL ELEC AF RIH(SITP=1920psi)and correlate from Baker Hughes OH log dated 6/20/2011. Pull into position @ 11,533.3'(CCL depth)and perforate Tyonek interval f/11,541'-11,551'MD(OH log). Positive indication of firing,pressure built 12 psi in 15 min. OOH-all charges fired,guns wet. 18:30 19:00 0.50 PULD PGUN AF MU GR/CCL,and 10'x 3.375"pert guns loaded 6 SPF @ 60deg. PU into lubricator and stab on well. 19:00 21:45 2.75 CORL FORM AF RIH(SITP=1930psi)and correlate from Baker Hughes OH log dated 6/20/2011. Pull into position @ 11,094'(CCL depth)and perforate Tyonek interval f/11,101'-11,111'MD(OH log). Positive indication of firing,little to no pressure increase. OOH-all charges fired,guns wet. 21:45 22:30 0.75 RURD ELEC AF RD Pollard and prepare to move to SD 4 in AM. LD lubricator,secure well (shut in),sign out,and leave location. SITP: 1930psi. Attempt to hook up automated SSSV with no success. Leave well shut in overnight,monitor,and attempt to flow in AM. Report Date: 12/5/2011 Job Category: COMPLETION 24 Hr Summary No wellwork performed. Bled well pressure,monitored pressure and composition of vented gas(looking for Methane)See daily time log comments. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 10:00 22:00 12.00 FLOW TEST AF Date Time WHP Comment (psig) 12/4/2011 9:24 AM 1984 Well SI Overnight 12/4/2011 10:23 AM Open well to lower N2 pressure 12/4/2011 10:38 AM 1601 "Bled well to±1600 psi then SI No indication of methane during flow" 12/4/2011 10:39 AM 1626 1 minute SIWHP 12/4/2011 10:48 AM 1632 10 minute SIWHP 12/4/2011 10:58 AM 1634 20 minute SIWHP 12/4/2011 11:18 AM 1637 40 minute SIWHP 12/4/2011 11:27 AM 1638 49 minute SIWHP 12/4/2011 11:28 AM Open well to lower N2 pressure 12/4/2011 11:41 AM 1404 "Bled well to±1400 psi then SI No indication of methane during flow" 12/4/2011 11:42 AM 1416 1 minute SIWHP 12/4/2011 11:51 AM 1419 10 minute SIWHP 12/4/2011 12:01 PM 1420 20 minute SIWHP 12/4/2011 12:11 PM 1422 30 minute SIWHP 12/4/2011 12:12 PM Open well to lower N2 pressure 12/4/2011 12:47 PM 1001 "Bled well to±1000 psi then SI No indication of methane during flow" 12/4/2011 12:48 PM 1009 1 minute SIWHP 12/4/2011 12:57 PM 1012 10 minute SIWHP 12/4/2011 1:07 PM 1014 20 minute SIWHP 12/4/2011 1:27 PM 1018 40 minute SIWHP 12/4/2011 2:17 PM 1024 90 minute SIWHP 12/4/2011 3:57 PM 1035 190 minute SIWHP 12/4/2011 4:00 PM Open well to lower N2 pressure 12/4/2011 4:24 PM 800 "Bled well to±800 psi then SI No indication of methane during flow" 12/4/2011 4:25 PM 807 1 minute SIWHP 12/4/2011 4:34 PM 810 10 minute SIWHP 12/4/2011 4:44 PM 811 20 minute SIWHP 12/4/2011 5:24 PM 815 60 minute SIWHP 12/4/2011 6:24 PM 821 120 minute SIWHP 12/4/2011 11:24 PM 846 7 hr SIWHP Left well SI overnight 12/5/2011 7:00 AM 881 SIWHP 12/6/2011 7:00 AM 980 SIWHP www.peloton.com Page 21/31 Report Printed: 11/7/2012 • 1/44,/ Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S, R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Daily Operations Report Date: 12/6/2011 Job Category: COMPLETION 24 Hr Summary RU Pollard wireline to perform static PLT survey with memory tools and attempt to determine if there is crossflow between the two open zones. Log well with 120,90,60,and 30 fpm up and down passes. OOH and check tools-good data. RD Pollard. SITP 1250psi. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:00 08:45 0.75 SAFETY MTG AF Held PJSM w/Pollard wireline,CH2MHill,and operators. Discussed job hazards,weather conditions,and job scope. Obtained safe work permit. 08:45 10:15 1.50 RURD SLIK AF RU Pollard wireline. PU CIBP setting toolstring. 10:15 10:30 0.25 TEST BOP—E— AF PU lubricator and tool string,stab on well. PT lubricator to 1500 psi. Good test. 10:30 15:30 5.00 RUNPUL SLIK AF RIH w/RS, RB,5'stem, RB,5'stem, RB,OJ, RB,and GR/CCL/CAP/Tandem PT/Spinner tool. Perform static PLT test as follows:5 min bench at tubing hanger,RIH 120 fpm to 11,575'MD RKB and perform 5 min bench. POOH 120 fpm to 11,350'and perform 3 min bench. POOH 120 fpm to 11,050'and perform 3 min bench. RIH 90 fpm to 11,575'and perform 5 min bench. POOH 90 fpm to 11,350'and perform 3 min bench. POOH 90 fpm to 11,050' and perform 3 min bench. RIH 60 fpm to 11,575'and perform 5 min bench. POOH 60 fpm to 11,350'and perform 3 min bench. POOH 60fpm to 11,050' and perform 3 min bench. RIH 30 fpm to 11,575'and perform 5 min bench. POOH 30 fpm to 11,350'and perform 3 min bench. POOH 30 fpm to 11,050' and perform 3 min bench. POOH 120 fpm to tubing hanger and perform 5 min bench. 15:30 16:45 1.25 RURD SLIK AF LD tools and lubricator. Check data-good data. Secure well(shut in),sign out,and leave location. SITP: 1250psi. Report Date: 2/1/2012 Job Category: COMPLETION 24 Hr Summary MIRU Baker to displace wellbore w/N2. Pumped 161,500 scf N2 in order to displace fluid from wellbore. Final SIWHP 4000 psi. Trending available on SKADA. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:30 09:00 0.50 SAFETY MTG AF Arrive location,sign in,receive safe work permit,hold PJSM-topics discussed-reviewed JSA,assigned jobs,slips,trips,falls,eye wash station, high pressure,emergency numbers,emergency vehicles,muster area,active gas production pad,red lights for fire,blue lights for gas emission,sirens for audible,stop the job authority,and keeping the focus on the job. Emphasize that we are in no hurry today. 09:00 10:36 1.60 RURD OTHR TA MSSM RU N2 equipment to flow line. No air at wellhead. Run airline from SSD 6 WH to SD 7. Open SSV and install cap. Pump open SSSV with 4000 psi and block in. Start cooling down pump unit. 10:36 13:42 3.10 WAITON EQIP TA MSSM N2 booster pump leaking from mechanical packing. Can not proceed. Call for mechanic to replace booster pump. 13:42 14:27 0.75 RURD OTHR TA MSSM Cool down N2 pumps and lines. 14:27 14:57 0.50 TEST EQIP AF PTest lines to 500 psi low/5000 psi. One leak. Retest to 5000 psi. Test good. www.peloton.com Page 22/31 Report Printed: 11/7/2012 j`%09. Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Otr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 14:57 18:57 4.00 PUMP N2 AF Open well and begin pummping. Time Pressure Rate Cum N2 (psi) (scf/min) (Mscf) 15:00 1650 500 1.5 15:04 increase rate 15:05 1700 700 3.4 15:10 1830 1000 9.6 15:15 1922 1000 14 15:20 2030 1000 19 15:25 2140 1000 24 15:30 2240 1000 29 15:35 2355 1000 34 15:40 2460 1000 39 15:45 2560 1000 44 15:50 2700 1000 49 15:55 2830 1000 54 16:00 2960 1000 59 16:05 3060 1000 64 16:10 3200 1000 69 16:15 3360 1000 74 16:20 3460 1000 79 16:25 3570 1000 84 16:30 3700 1000 89 16:35 3840 1000 94 16:36 decrease rate to 700 16:39 3900 pressure breaks back 17:05 3550 700 112 17:10 3580 700 116 17:17 3700 500 124 17:38 3800 500 131 17:55 3900 400 140 18:14 3960 400 146 18:25 3980 400 150 18:40 4000 400 156 19:00 4090 350 160 19:20 4100 350 161.5 final job complete 18:57 19:57 1.00 RURD EQIP AF Rig down N2 equipment. Replease 3000 psi gauge w/5000 psi. Open well to SKADA 19:57 20:12 0.25 SECURE WELL AF Secure well. Turn well over to night shift operator. Report Date: 2/5/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E Line to run Perforation Log and determine fluid level. Observe both perforation intervals at 11,101-11,111'and 11,541 -11,551' with the CCL. Both appear to be on depth. Tag CIBP at 11,568'. Memory PT analysis determines fluid level at 11,373'. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:30 09:15 0.75 SAFETY MTG AF Arrive location,sign in,receive safe work permit,hold PJSM-topics discussed-reviewed JSA,assigned jobs,slips,trips,falls,eye wash station, high pressure,emergency numbers,emergency vehicles,muster area,active gas production pad,red lights for fire,blue lights for gas emission,sirens for audible,stop the job authority,and keeping the focus on the job. Emphasize that we are in no hurry today. 09:15 11:15 2.00 RURD ELEC AF Spot equipment. PU lubricator. MU tool string. Attempt to RU truck to run Gamma/CCL and memory gauges to perform PT survey. 11:15 13:24 2.15 WAITON OTHR TA MDLG Grease injector and hoses full of"summer"grease. Install Frost Fighter in an attempt to thin grease in hoses and replace with winter grease. 13:24 13:54 0.50 RURD ELEC TA MDLG Carry lubricator to wellhead. 13:54 14:24 0.50 TEST EQIP AF Pressure test lubricator to 4000 psi. Test good. 14:24 21:54 7.50 LOG CSG AF Perform 5 min bench at tubing hanger. RIH w/gamma/CCL and memory PT gauges. Tag CIBP @ 11,568'. Stoop for 20 min bench. Adjust counter head angle. Normalize encoder/E line depths. 21:54 23:54 2.00 LOG CSG AF POOH. 5 min bench at surface. 23:54 00:39 0.75 RURD ELEC AF Bleed lubricator. RD tools for the night. Check data on gauges. 00:39 00:54 0.25 SECURE WELL AF Secure wellhead and location. www.peloton.com Page 23/31 Report Printed: 11/7/2012 Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S, R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Daily Operations Report Date: 2/6/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E-line to set CIBP and isolate sterling perforation interval T130-2. Plug successfully set @ 11,332'MD RKB. RD and secure well to monitor. Well shut in. SITP 2660psi. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 10:00 11:00 1.00 SAFETY MTG AF Held PJSM w/Pollard and operator. Discussed job hazards,working with explosives and pinch points. 11:00 14:00 3.00 RURD ELEC AF RU E-line truck and equipment. MU tools and check fire. PU lubricator and tool string,stab on well.Quick test connection to 3000psi. Good test. 14:00 23:30 9.50 SETREL PLUG AF RIH w/RS,CCL,GR,PT,setting tool and 4.5"WEA CIBP. Tool string falling slowly. Perform up and down passes,logging PT. Correlate log and set CIBP @ 11,332'MD RKB. Confirm set w/tag. POOH. 23:30 01:00 1.50 RURD ELEC AF LD lubricator and tool string. RD e-line truck and equipment. Secure well, sign out,and leave location. Report Date: 2/7/2012 Job Category: COMPLETION 24 Hr Summary Observe T118 interval(zone 3). Drawdown well to 1500 psi and observe well response. SCSSV panel acting up. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 03:00 04:00 1.00 BLOWDN 'TBG AF Initiate bleed down of well to observe well response. Well initially at 2642 psi, bleed well down to 2000 psi 04:00 04:30 0.50 'BLOWDN TBG AF Negligible pressure response. Bleed well down to 1500 psi,observe,monitor over night. Report Date: 2/8/2012 Job Category: COMPLETION 24 Hr Summary Observe T118 interval(zone 3). Work on SCSSV panel. Drawdown well to 0 psi and observe well response. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:00 09:00 1.00 BLOWDN 'TBG AF 1543 psi on well. Bleed well down further to 1250 psi,troubles with SCSSV. 09:00 15:00 6.00 REPAIR "EQIP TA MDOT Service SCSSV panel. 15:00 18:00 3.00 SECURE 'WELL AF Well SITP at 1253 psi-no change. Take well to zero pressure,venting N2 through test separator,maintaining flow rate above unload. Well depleted to zero,no feed in. Shut in well and observe. Report Date: 2/9/2012 Job Category: COMPLETION 24 Hr Summary Observe T118 interval(zone 3). Drawdown well to 0 psi and observe well response. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code _ Status _ Code Com 08:00 18:00 10.00 BLOWDN TBG AF Observed well, no feed in,-20 psi on well. Report Date: 2/10/2012 Job Category: COMPLETION 24 Hr Summary Observe T118 interval(zone 3). Drawdown well to 0 psi and observe well response. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com Report Date: 2/10/2012 Job Category: COMPLETION 24 Hr Summary Observe T118 interval(zone 3). Drawdown well to 0 psi and observe well response. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 08:00 18:00 10.00 BLOWDN TBG AF Observe well following blowdown. No well response. Report Date: 2/11/2012 Job Category: COMPLETION 24 Hr Summary Apply Nitrogen pressure to displace any fluid influx into wellbore,prep for BP and perfing. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:00 09:00 1.00 SAFETY MTG AF Hold PJSM,review warning systems,wind conditions,job hazards,discuss icy conditions,rain adding risk,slip trips and falls,compressed gas risks. Eval pad for spotting equipment. 09:00 10:45 1.75 RURD OTHR AF Spot N2 equipment, RU lines,transfer N2 between tanks,cool down equipment. 10:45 11:00 0.25 TEST EQIP AF Test lines to 5000 psi. www.peloton.com Page 24/31 Report Printed: 11/7/2012 • Operations Summary Report • Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 11:00 14:15 3.25 PUMP N2 AF Pump N2 job,pumping volumetric N2 volumes to pressure wellbore to 4000 psi. Note:pressure response linear,job pumped per volumetric csg capacity. time rate press cum 11:00 500 -200 0 11:30 1000 —500 13,500 12:07 1500 1050 50,000 13:08 1500 2340 140,000 14:05 1000 3970 227,000 14:18 0 4072 240,215 14:15 15:00 0.75 DEMOB RIG AF RD N2 equip. 15:00 18:00 3.00 WAITON 'OTHR AF Observe well. Pressure following N2 job close to 4000 psi static(some difference between pumping and static,and time to line well out to observe pressure). Pressure declined to 3850 psi at 5:30 PM. Decided to close in wing valve to ensure pressure not leaking off to flowline;will open wing valve periodically through the night to get pressure to SCADA gauge. Planning to set BP and perf zone 4. Report Date: 2/14/2012 Job Category: COMPLETION 24 Hr Summary Isolate T118(Zone 3)with a BP,perforate T110(zone 4) Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 07:30 08:30 1.00 SAFETY MTG AF Hold JSEA,review light signals,muster points,wind sock,stop the job,icy conditions,load carrying,review the job. Start,setup light plant. Open wing, 2716 psi(SCADA gauge isolated since 2/12/2012 at 2PM,2740 psi). 08:30 10:00 1.50'RURD ELEC AF RU E-Line. Pressure test lubricator to 250/4000 psi. Tested low w/trapped N2 pressure,tested high with diesel. Dropped test diesel to aid tools dropping. MU BP,setting tool,GPT tool,roller bogies and weight bar,rope socket. 10:00 12:00 2.00 RUNPUL ELEC AF RIH w/BP. 12:00 12:15 0.25 CORL FORM AF Pull correlation pass,get on depth. GPT tool indicated no fluid in wellbore, only N2 gradient. 12:15 14:00 1.75 RUNPUL ELEC AF RIH,pull up,set BP at 11050 ft MD,tag BP,POOH. Bleed pressure off of well,from 2740 down to—2200 psi. 14:00 16:00 2.00 RUNPUL ELEC AF LD BP setting assembly,PU pert assembly, 10 ft 3-3/8",owen SDP 3.125" 311 NTX perf gun,gamma gun,rope socket,RIH,tag BP,pull correlation pass,get on depth,bleed wellbore pressure down to perscribed 1775 psi. 16:00 17:00 1.00 PERF CSG AF Perf T110 interval with 10 ft gun,perforating 10851-10861 ft MD,good indication that gun fired,POOH. LD gun,all charges fired. 17:00 18:30 1.50 RURD ELEC AF RD E-Line. Turn in paperwork. Report Date: 2/18/2012 Job Category: COMPLETION 24 Hr Summary PT Survey Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 06:30 0.50 SAFETY MTG AF Held safety meeting 06:30 08:30 2.00 RURD SLIK AF Rig up Slickline,Prepare Tandem Gauges,Pressure test lubricator to 2000psi 08:30 11:30 3.00 RUNPUL SLIK AF RIH with tandem PT Gauges to 21'for a 3 min bench. Continue RIH @ 180' fpm to tag Bridge Plug at 11050'. Stop for a 3 min bench. Continue PUH @ 120'fpm to midperfs at 10856'and stop for a 3 min bench,PUH to 10500' and stop for a 3 min bench, POOH @120'per minute. Stop for a 3 min bench at 21' 11:30 12:30 1.00 RURD SLIK AF Rig Down Slickline Report Date: 4/4/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E line to perforate the T110 Tyonek formation(10,840'- 10,865'and 10,872'-10,887'). Shooting 3-3/8"Owen Super Hero 3-1/8"charges SDP3125-311 NT4 loaded 60 degree phase,6 SPF. Well bled down to 1900 psi at 13:30. All pressures available on SCADA. two interruptions when we had to close the wing valve in order to bleed the lubricator down(swab valve leaked). Did not bleed the well down for the second pert run. Well continued to build pressure. www.peloton.com Page 25/31 Report Printed: 11/7/2012 Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Otr/Otr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) _ Ops Code Activity Code Status Code Corn 08:00 08:30 0.50 SAFETY MTG AF Hold PJSM. Discuss emergency procedures,muster area,alarms,and wind direction. Discuss JSEA and make job assignments. Obtain Safe Work Permit. 08:30 11:00 2.50 RURD ELEC AF Spot equipment. PU 35'of lubricator. MU tool string-RS,gamma Ray/CCL, 25'of 3-3/8"guns loaded w/Owen 3-1/8"Super Hero charges at 60 degree phased,6 SPF. 11:00 11:15 0.25 SAFETY MTG AF Hold Explosives SM. Turn off all cell phones. Notify operations. Post signage and guard at the gate. 11:15 11:30 0.25 RURD ELEC AF Arm guns. PU lubricator and carry to well head. 11:30 11:45 0.25 TEST EQIP AF Test lubricator to 4000 psi w/50/50 MEOH. Dump MEOH DH. Open SSV and SCSSV. Trap pressure on SCSSV. 11:45 15:30 3.75 PERF CSG AF RIH(1). Tag CIBP at 11,050'. Run correlation passes. Get on depth. Bleed well pressure down to 1900 psi(13:30). Pull up into position at 10,832'(8' from CCL to top shot). Perforate 10,840'-10,865' to BHI LWD Quad Combo open hole logs dated 7/14/11. Feel guns fire. Pulled 500 lbs over gun weight to unstick guns. POOH. 15:30 15:45 0.25 RURD ELEC AF OOH. All shots fired. Guns wet. Break out guns. Load 15'of guns for second run. 15:45 15:54 0.15 SAFETY MTG AF Hold Explosives SM. Turn off all cell phones. Notify operations. Post signage and guard at the gate. 15:54 16:06 0.20 RURD ELEC 'AF Arm guns. PU lubricator and carry to well head. 16:06 18:21 2.25 PERF CSG AF RIH(2). Tag CIBP at 11,0050'. Run correlation passes. Get on depth. Did NOT bleed well pressure down between runs.Let it continue to build- approx.2050 psi. Pull up into position at 10,864'(8'from CCL to top shot). Perforate 10,872'-10,887'(15')to BHI LWD Quad Combo open hole logs dated 7/14/11 (17:20). Feel guns fire. Guns lost weight when fired. POOH. 18:21 19:21 1.00 RURD ELEC AF OOH. Guns wet. All guns fired. RD Eline unit. Install tree cap. Open wing valve and line up well to flow. Unblock SCSSV. Sign off Critical Defeat Log. Discuss flowing well parameters with night operator. Do not flow well below 1300 psi as per Houston Sub Surface group. '19:21 19:36 0.25'SECURE WELL AF Seccure well and location for the night. Turn in permit and sign out. Report Date: 5/2/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard slickline to run PT Survey. Unable to equalize pressure across SSCV and get it open. RD and move to KGF. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 08:00 08:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms,muster area,and emergency response. Discuss JSA and make job assignments. Obtain SWP. 08:30 08:30 RURD SLIK AF RU wireline unit. PU lubricator. Make up tool string. PT lubricator. Unable to open SSCV. 1600 psi on wellhead. Suspect 2200+psi under SSCV. Attempts to open with pump fail. Attempt to open SSCV with manual pump also fail. Close wing and SSV. Monitor WHP for an hour and only gain 20 psi WHP. PT 3"quarter turn valve on flow line. It leaks. Wing and SSV are also leaking. Move unit to KBU 42-6 in KGF. Shut in well over the next several days indicator that master valves are holding. Equalize across SSCV. See 2200 psi under SSCV. Report Date: 5/16/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard Slickline,Conduct memory PT survey while SI looking for water Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 06:00 06:30 0.50 SAFETY MTG AF Conduct Safety Meeting,discussed rig up and procedure for the day 06:30 08:00 1.50 RURD SLIK AF Rig up slickline,pressure test lubricator to 2600psi 08:00 12:00 4.00 RUNPUL SLIK AF RIH with 2.6"gauge ring to 11120'KB,tag fill,POOH RIH with tandem pressure temperature gauges at 180'/min to 11000ft,make 5 min stop POOH at 180'/min making 3 min stop's every 2000ft will download and analyze data 12:00 13:00 1.00 RURD SLIK AF RDMO Slickline www.peloton.com Page 26/31 Report Printed: 11/7/2012 It�\,.;J Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Daily Operations Report Date: 6/20/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E line to set CIBP and pert T-97 zone. Unable to get below 10,600'because of interference with the line in the grease tubes. RD. Ops Trouble Start Time End Time _ Dur(hr) Ops Code Activity Code Status Code Corn 08:00 08:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms,muster area,and emergency response. Discuss JSA and make job assignments. Obtain SWP. 08:30 11:45 3.25 RURD 'ELEC AF Spot equipment. RU E line unit. PU lubricator. Make up tool string-RS, 10' tungsten stem,3-1/8"Gamma/CCL,XO,thrd protector. Pressure on SSCV line less that 400 psi. Repressure line. Unable to tell of SSCV openned. Determined best path forward was to tag SSCV to make sure it was open. Did this with non-explosive tool string in order to avoid POOH with live explosive charges. 11:45 12:00 0.25 TEST EQIP AF PT lubricator. Test good. 12:00 12:30 0.50 RUNPUL ELEC AF RIH(1)w/3-1/8"CCL. Log thru SSCV and determined that it was open. POOH. 12:30 12:54 0.40 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. 12:54 16:45 3.85 RUNPUL ELEC AF Check fire to head. Arm plug and setting tool for 4-1/2"CIBP. RIH(2)w1- 11/16"GPT tool,XO,3"fireing head and 4-1/2"CIBP(3.58"OD plug). Set down at 8100'. w/t set down again at 8850',work thru again at 9350',and again at 9630'. Work up and down a few times. Drop to 10,230'. And finially set down at 10,570'. Unable to work our way further down hole. The quick PU and set downof the line tend to indicate possible interference with new line in the grease tubes,were recently changed. (200'had also been cut off the line.).POOH 16:45 17:15 0.50 RURD -ELEC AF MU slimmer,heavier tool string- RS,Rboggie, 1-3/4"x 3'stem,3-1/8" shooting gamma/CCL,XO,XO,2-1/4"x 3'stem,1-3/4"x 5'stem,SSSJ,XO, RBoggie(26'overall) to try again just to make sure we weren't pushing dirt down hole. 17:15 19:36 2.35 RUNPUL ELEC AF RIH(3)with above tools. Set down at 10,570'. Work tools, Drop to 10.636'. Continue to work tools. Fall to 10,775'. Continue to work tools but unable to get any deeper. POOH. Still appears we have a surface problem in the grease tubes. 19:36 20:21 0.75 RURD -ELEC AF RD unit for the night. Losing unit for tomorrow. Install tree cap. Test good. 20:21 20:36 - 0.25 SECURE WELL AF Close all tree valves and secure the well for the night. Report Date: 6/26/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E line to set CIBP and perf T-97 zone. Set CIBP at 10,800',abandoning the T-110 zones. Bleed SIWP to 1845 psi for under balance. Pull correlation passes to get on depth. Perforate the T-97 zone with the 3-3/8"Connex guns loaded 6 SPF w/3-1/8"charges on 60 degree phasing. Perforate 13 feet from 10,681-10,694'on open hole Advanced LWD magnetic Resonance Log. OOH gun inspection indicates all shots fired. Leave well shut in overnight. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 09:00 09:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms,muster area,and emergency response. Discuss JSA and make job assignments. Obtain SWP. 09:30 10:15 0.75 RURD ELEC AF Spot equipment. RUE line unit. PU lubricator. Make up tool string-RS, 10' tungsten stem,3-1/8"Gamma/CCL. Pressure on SSCV line less that 400 psi. Repressure line. Unable to tell of SSCV openned. Line pressure dropped on SSCV and valve closed. Determined best path forward was to tag SSCV to make sure it was open. Did this with non-explosive tool string in order to avoid POOH with live explosive charges. 10:15 10:30 0.25 TEST EQIP AF PT lubricator. Test good. 10:30 10:48 0.30 RUNPUL ELEC AF RIH(1)w/3-1/8"Gamma Gun. Log thru SSCV and determined that it was open. POOH. 10:48 11:00 0.20 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. 11:00 13:45 2.75 RUNPUL ELEC AF Check fire to head. Arm plug and setting tool for 4-1/2"CIBP. RIH(2)w/3- 1/8"Gamma Gunl,XO,3"fireing head and 4-1/2"CIBP(3.58"OD plug)to 10,850'. Log up thru interval to 10,650,. Correlate depths to open hole Advanced LWD Magnetic Resonance Log. PUH to 10,789'(11'from center of CCL to top of CIBP). Set CIBP. PUH. RIH and set weight down on CIBP. Confirm set at 10,800'. POOH. 13:45 13:57 0.20 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. www.peloton.com Page 27/31 Report Printed: 11/7/2012 • \:J Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,Ti S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 13:57 16:57 3.00 LOG CSG AF Check fire. OK. Arm guns. RIH(3)w/13'of Connex guns. Bleed SIWP to 1845 psi for under balance. Tag CIBP at 10,800'. Pull correlation passes to get on depth. Pull up into position @ 10672.5'(8.5' from center of CCL to top shot). Perforate the T-97 zone with the 3-3/8"Connex guns loaded 6 SPF w/3-1/8"charges on 60 degree phasing. Perforate 13 feet from 10,681- 10,694'on open hole Advanced LWD magnetic Resonance Log. OOH gun inspection indicates all shots fired. Leave well shut in overnight. 16:57 17:42 0.75 RURD ELEC AF RD E line unit. Re install tree cap and PT with WHP. Test good. 17:42 17:57 0.25 SECURE WELL AF Close swab valve. Leave well open to SKADA. Secure well. Turn in permit. Sign out and leave loc. Report Date: 7/21/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E Line to run PT Survey. Fluid level at 7230 ft and PBTD at 10795ft,mid pert TO97 pressure:2705 psi. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 08:00 08:30 0.50 SAFETY MTG AF Held Safety Meeting,discussed rig up and operations for the day 08:30 10:00 1.50 RURD ELEC AF Rig up Pollard E Line,pressure test lubricator to 2600psi. 10:00 12:00 2.00 RUNPUL ELEC AF SITP: 1190 psi. RIH with 3.66"gauge ring and tandem pressure temperature gauges at 180'/min and tag bottom at 10795ft,made 5 min stop.POOH at 180'/min making 3 min stop's every 2000ft. Fluid level at 7230ft. Mid pert pressure of T097 interval:2705 psi. 12:00 13:00 1.00 RURD ELEC AF RDMO Pollard E Line Report Date: 7/27/2012 Job Category: COMPLETION 24 Hr Summary MIRU Baker Hughes N2 pumper to displace water from wellbore in preparation to perforate. Pump 185,200 scf of N2 in order to increase well pressure from 1250 psi to 4000 psi. Shut in well with pressure. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:00 08:30 0.50 SAFETY MTG AF Hold PJSM,review warning systems,wind conditions,job hazards,discuss icy conditions,rain adding risk,slip trips and falls,compressed gas risks. Eval pad for spotting equipment. 08:30 09:15 0.75 RURD OTHR AF Spot N2 equipment,RU lines,transfer N2 between tanks,cool down equipment. 09:15 09:30 0.25 TEST EQIP AF Test lines to 500 psi. Test good. Continue test lines to 5000 psi. Test good. 09:30 13:30 4.00 PUMP N2 AF Pump N2 job,pumping volumetric N2 volumes to pressure wellbore to 4000 psi.Note:pressure response linear,job pumped per volumetric csg capacity. time 13:30 14:30 1.00 DEMOB RIG AF Close all valves of the tree. RD N2 equip. 14:30 15:30 1.00 WAITON OTHR AF All valves closed on tree because of suspected leakage. Will monitor pressure thru the day tomorrow on SKADA gauge. Planning to set BP and pert next zone. Report Date: 8/1/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E line.SITP 2650 psi. PU 4-1/2"Owen CIBP and 1-11/16"GPT tool. RIH(1)to 10,670'.Only N2 gradient observed by GPT tool(NO water in wellbore). Set CIBP at 10,640'. PUH 200'. Set back down on CIBP to verify set. PU 3-1/8"Gamma Gun and 22'of 3-3/8" guns loaded with 3-1/8"Owen SuperHero charges,6 SPF,60 degree phased SDP 3125-311 NT4 charges. RIH(2)and tag CIBP. Run corelation logs to get on depth. Flow well pressure down to 1750 psi. Perforate 22'from 10,563'-10,585'on BHI LWD Quad Combo open hole logs. Well shot at 17:25. Pressure build up from 1750 psi to 2065 psi prior to shooting second interval. Buildup recorded in SCADA. RIH(3)w/3-1/8"Gamma Gun and 20'of 3-3/8" guns loaded with 3-1/8"Owen SuperHero charges,6 SPF,60 degree phased SDP 3125-311 NT4 charges. RIH to tag CIBP. 18'of fill noted on top of CIBP. Run corellation passes to get on depth. Flow well pressure down to 1750 psi. Perforate 10,543'-10,563'on BHI LWD Quad Combo open hole logs. Shut in well immediately after perforating to allow debris to fall. Well had only built to 1800 psi in the next two hours while we POOH and RD. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 07:00 07:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms,muster area,and emergency response. Discuss JSA and make job assignments. Obtain SWP. 07:30 09:57 2.45 RURD ELEC AF Spot equipment. RU E line unit. PU lubricator. Make up tool string-RS, RBoogie,8'tungsten stem,RBoogie, 1-11/16"GPT Tool,setting tool,4-1/2" CIBP(3.50"OD.) 15'CCL to top of plug. 09:57 10:09 0.20 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. www.peloton.com Page 28/31 Report Printed: 11/7/2012 t ,Jj Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1 S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 10:09 10:27 0.30 RUNPUL ELEC AF Check fire to head. Arm plug and setting tool for 4-1/2"CIBP. 10:27 10:42 0.25 TEST EQIP AF PT lubricator. Test to 300 psi. Test to 4000 psi. Test good. Bleed MEOH back to pump unit. 10:42 14:57 4.25 RUNPUL ELEC AF RIH(1)w/1-11/16"GPT Tool!,Baker#10 setting tool,and 4-1/2"Owens CIBP(3.50"OD plug)to 10,670'. Log up thru interval to geton depth. Correlate depths to open hole Advanced LWD Magnetic Resonance Log. PUH to 10,625'(15'from center of CCL to top of CIBP). Set CIBP. PUH. RIH and set weight down on CIBP. Confirm set at 10,640. POOH. 14:57 15:09 0.20 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. 15:09 15:33 0.40 RUNPUL ELEC AF Check fire to head. PU 3-1/8_Gamma Gun. Arm 22'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge. 15:33 18:33 3.00 RUNPUL ELEC AF RIH(2)w/3-1/8"Gamma Gun w/ 22'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge to 10,640. Log up thru interval to get on depth. Correlate depths to open hole BHI LWD Quad Combo. PUH to 10,555.5'(7-1/2'from center of CCL to top shot). Perforate 10.563'-10,585'. POOH. Well shut-in toallow debrie to fall and to monitor pressure build up. Recorded on SKADA. 18:33 19:21 0.80 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. 19:21 22:21 3.00 RUNPUL ELEC AF RIH(3)w/3-1/8"Gamma Gun w/ 20'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge to 10,640. 18'of fill noted on top of CIBP. Log up thru interval to get on depth. Correlate depths to open hole BHI LWD Quad Combo. PUH to 10,535.5'(7-1/2'from CCL to top shot). Bleed well pressure down to 1750 psi. Perforate 10.543'-10,563'. POOH. Well shut-in toallow debrie to fall and to monitor pressure build up. Recorded on SCADA. 22:21 23:06 0.75 RURD ELEC AF RDd E line unit,tool string,and lubricator. 23:06 23:36 0.50 SECURE WELL AF Secure well head and location. Turn in permit. Sign out and leave loc. Report Date: 8/2/2012 Job Category: COMPLETION 24 Hr Summary Vetco serviced tree(leaking valves),flow/vent N2,attempt to flow well,no feed in. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 06:00 14:00 8.00 REPAIR EQIP TA MSOT Vetco serviced the tree,and then the well was vented to purge the N2, bleeding pressure down to 1400 psi initially,then down to 1000 psi,with limited pressure supporUfeed in—suspect water. Will need a tank to flow test. Report Date: 8/5/2012 Job Category: COMPLETION 24 Hr Summary RU arctic iron,tank,flow tested well,well flowed 1 BPM water rate,no gas. Shut well in with—200 psi SITP. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status _ Code Com 06:00 14:00 8.00 FLOW TEST AF T095 interval testing,flowing to a tank. Started blowing down SD-7 @0900 pressure was steady at 1228#blew down t 0 in 45 minutes,45 minutes after reaching 0 pressure water made it to surface without any gas column.At 1040 hrs well had unloaded 40 bbls very little gas,water temperature 50° Shut the well in @ 1200 hrs to remove 0 plate restriction from flow line.Well was shut in for 30 minutes when we opened the well we got a small burst of gas and instantly water started flowing. At 1300 hrs well had unloaded 164 bbls temperature of 52°pressure of 180 psi. Well continued to unload water reaching a rate of 1.3 bbls a minute pressure remained at 180 psi and temperature continued to rise reaching 63°with little to no gas other than a occasional bubble. Shut in well @ 1630 hrs.Pressure built to 225#over night. Report Date: 8/30/2012 Job Category: COMPLETION 24 Hr Summary MIRU Baker Hughes N2 pumper to displace water from wellbore in preparation to perforate the TO3X interval. Pump 4-1/2 hours at 750 scf/min. Pressure steadily and linearly increased throughout the job from 350 psi to 2640 psi. At 184,000 scf pumped away,the pressure leveled off and held steady at 2640 psi. Pumped a total of 200,000 scf. Shut well in with 2640 psi. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:00 08:30 0.50 SAFETY MTG AF Hold PJSM,review warning systems,wind conditions,job hazards,discuss icy conditions,rain adding risk,slip trips and falls,compressed gas risks. Eval pad for spotting equipment. www.peloton.com Page 29/31 Report Printed: 11/7/2012 Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,Ti S,R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Corn 08:30 10:00 1.50 RURD OTHR AF Spot N2 equipment,RU lines,transfer N2 between tanks,cool down equipment. 10:00 10:15 0.25 TEST EQIP AF Test lines to 500 psi. Test good. Continue test lines to 5000 psi. Test good. 10:15 15:00 4.75 PUMP N2 -AF Pump N2 job,pumping volumetric N2 volumes to pressure wellbore to 2640 psi.Note:pressure response linear,job pumped per volumetric csg capacity vs time. Pumped a total of 200,000 scf. 15:00 16:00 1.00 DEMOB RIG AF Close all valves of the tree. RD N2 equip. 16:00 16:30 0.50 WAITON OTHR AF All valves closed on tree. Will monitor pressure thru the weekend on SCADA gauge. Planning to set BP and perf next zone. Report Date: 9/5/2012 Job Category: COMPLETION 24 Hr Summary MIRU Pollard E line to set 4-1/2"CIBP. Perforate TO3X Tyonek sands. Set CIBP at 10,510'. Load 3'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge. Bleed well pressure down to 1200 psi to achieve underbalance. Perforate 8353'-8356'. Monitor pressure response. Load 18'of 3- 3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge. Perforate 8314'-8332'. Leave well shut in and turn over to operations to flow well. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 08:00 08:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms,muster area,and emergency response. Discuss JSA and make job assignments. Obtain SWP. 08:30 09:30 1.00 RURD ELEC AF Spot equipment. RU E line unit. PU lubricator. Crane truck has a problem. RD crane truck. 09:30 10:15 0.75 WAITON EQIP AF Crane truck fails. Wait on replacement crane. 10:15 11:00 0.75 RURD ELEC AF Continue RU. PU lubricator. MU wireline valve and QTS. Make up tool string-RS,6'tungsten stem,3-1/8"I,setting tool,4-1/2"CIBP(3.50"OD.). 10'CCL to top of CIBP. 11:00 11:12 0.20 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. 11:12 11:30 0.30 RUNPUL ELEC AF Check fire to head. Arm plug and setting tool for 4-1/2"CIBP. 11:30 11:45 0.25 TEST EQIP AF PT lubricator. Test to 300 psi. Test to 3000 psi. Test good. Bleed MEOH back to pump unit. 11:45 14:45 3.00 RUNPUL ELEC AF RIH(1)w/3-1/8"gamma/CCL,Baker#10 setting tool,and 4-1/2"Owens CIBP(3.50"OD plug)to 10,510'. Run correlation passes to get on depth. Correlate depths to open hole BHI LWD Quad Combo. PUH to 10,500'(10' from center of CCL to top of CIBP). Set CIBP at 10,510'. PUH. RIH and set weight down on CIBP. Confirm set at 10,510'. POOH. 14:45 14:54 0.15 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. 14:54 15:06 0.20 RUNPUL ELEC AF Check fire to head. PU 3-1/8_Gamma Gun. Arm 3'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge. 15:06 16:51 1.75 RUNPUL ELEC AF RIH(2)w/3-1/8"Gamma Gun w/ 3'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge to 8500'. Bleed well pressure down to 1200 psi for underbalance. Log up thru interval from 8500'back to 8100'to get on depth. Correlate depths to open hole BHI LWD Quad Combo. PUH to 8345'(8'from center of CCL to top shot). Perforate 8353'- 8356'(16:11). POOH. Well shut-in to allow debrie to fall and to monitor pressure build up. Recorded on SCADA. OOH Check guns. All shots fired. Guns dry. No pressure responce on SCADA. 16:51 17:00 0.15 SAFETY MTG AF Hold explosives safety meeting with all parties. Shut down all cell phones. Post signage and guard at the gate to location. 17:00 17:12 0.20 RUNPUL ELEC AF Check fire to head. Arm 18'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge. 17:12 19:00 1.80 RUNPUL ELEC AF RIH(3)w/3-1/8"Gamma Gun w/ 18'of 3-3/8"guns loaded 6 SPF,60 degree phased with Owen Super Hero 3-1/8"charge to 8500'. Log up thru interval from 8500'back to 8100'to get on depth. Well pressure is 1210 psi. Correlate depths to open hole BHI LWD Quad Combo. PUH to 8306'(8' from center of CCL to top shot). Perforate 8314'-8332'(18:13). PUH to 2100#line tension. Guns stuck. Slack off to 500#. Pick back up and guns pull free at 2100#. POOH. Well shut-in to allow debrie to fall and to monitor pressure build up. Recorded on SCADA. OOH Check guns. All shots fired. No imediate pressure responce on SCADA. 19:00 20:00 1.00 RURD ELEC AF LD lubricator. RD Eline unit. www.peloton.com Page 30/31 Report Printed: 11/7/2012 fiA.jj Operations Summary Report Marathon Oil Well Name: SUSAN DIONNE 7 Qtr/Qtr,Block,Sec,Town,Range Field Name License# State/Province Country Seward Meridan,Sec.6,T1S, R13W NINILCHIK-SUSAN DIONNE 211050 ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 43.28 6.40 6/15/2011 7/13/2011 Ops Trouble Start Time _ End Time Dur(hr) _ Ops Code Activity Code _ Status Code Com 20:00 20:15 0.25 SECURE 'WELL AF Reinstall tree cap. Leave swab valve closed. Both masters and wing valve open to SCADA. Quarter turn flow line valve to facilities is closed. Turn well over to production. Turn in permit. Sign out and leave loc. www.peloton.com Page 31/31 Report Printed: 11/7/2012 DATAAOGGED /)1 t 0 3a !Well: Susan Dionne#7 ./i\ /2013 !Path: .M K BENDER 4% !Reference North is: TRUE 2...2_.9 !Magnetic Declination is: 17.7 !True to Grid Converges 0 !Tie In Point data: !MD 0.00 INC 0.00 Azicorr 0.00 TVD 0.00 N/S 0.00 E/W 0.00 MD(ftKB) Incl(0) Azm(0) Date Method TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 0 MWD 0 0 0 0 0 245 0.32 222.96 6/16/2011 MWD 245 0.68 -0.5 -0.47 0.13 307 0.22 222.88 6/16/2011 MWD 307 0.98 -0.71 -0.67 0.16 368 1.02 219.06 6/16/2011 MWD 367.99 1.64 -1.22 -1.09 1.31 427 3.68 212.5 6/16/2011 MWD 426.94 4.03 -3.23 -2.44 4.52 487 6.75 213.92 6/16/2011 MWD 486.68 9.43 -7.78 -5.44 5.12 545 9.59 215.76 6/16/2011 MWD 544.09 17.61 -14.53 -10.17 4.92 604 12.11 219.28 6/16/2011 MWD 602.03 28.68 -23.31 -16.96 4.41 664 14.3 224.56 6/16/2011 MWD 660.44 42.37 -33.46 -26.14 4.16 726 17.23 224.1 6/16/2011 MWD 720.1 59.2 -45.51 -37.91 4.73 785 19.95 224.45 6/16/2011 MWD 776.02 77.99 -58.98 -51.04 4.61 850 23.18 225.66 6/16/2011 MWD 836.46 101.83 -75.84 -67.96 5.02 913 25.9 227.27 6/16/2011 MWD 893.77 127.9 -93.84 -86.94 4.45 976 28.79 229.98 6/16/2011 MWD 949.72 156.61 -112.94 -108.67 4.99 1,040 31.72 228.65 6/16/2011 MWD 1,005.00 188.57 -133.97 -133.11 4.7 1,103 34.68 228.86 6/16/2011 MWD 1,057.71 222.8 -156.71 -159.04 4.7 1,166 38.07 229.12 6/16/2011 MWD 1,108.43 259.86 -181.22 -187.23 5.39 1,230 41.48 229.5 6/16/2011 MWD 1,157.61 300.44 -207.91 -218.28 5.34 1,293 44.98 228.6 6/16/2011 MWD 1,203.51 343.23 -236.19 -250.86 5.64 1,356 48.19 227.22 6/16/2011 MWD 1,246.80 388.72 -266.87 -284.8 5.34 1,419 51.07 226.62 6/16/2011 MWD 1,287.60 436.51 -299.66 -319.85 4.63 1,483 54.11 225.73 6/16/2011 MWD 1,326.48 487.18 -334.86 -356.52 4.88 1,547 57.28 225.62 6/16/2011 MWD 1,362.54 539.92 -371.79 -394.33 4.96 1,611 60.07 225.59 6/16/2011 MWD 1,395.81 594.46 -410.04 -433.39 4.36 1,651 61.83 226.5 6/16/2011 MWD 1,415.24 629.32 -434.31 -458.57 4.83 1,728 63.27 225.88 6/20/2011 MWD 1,450.73 697.44 -481.61 -507.87 2 1,791 64.19 226.19 6/20/2011 MWD 1,478.61 753.77 -520.83 -548.53 1.53 1,855 64.19 226.39 6/20/2011 MWD 1,506.48 811.2 -560.64 -590.18 0.28 1,917 64.18 226.81 6/20/2011 MWD 1,533.48 866.81 -598.99 -630.73 0.61 1,981 64.2 226.42 6/20/2011 MWD 1,561.34 924.21 -638.56 -672.61 0.55 2,044 64.32 226.93 6/20/2011 MWD 1,588.70 980.75 -677.5 -713.89 0.75 2,107 64.26 226.72 6/20/2011 MWD 1,616.03 1,037.29 -716.34 -755.28 0.32 2,171 64.28 226.42 6/20/2011 MWD 1,643.82 1,094.73 -755.98 -797.15 0.42 2,235 64.22 226.09 6/20/2011 MWD 1,671.62 1,152.19 -795.83 -838.8 0.47 2,296 64.25 225.65 6/20/2011 MWD 1,698.14 1,206.98 -834.09 -878.23 0.65 2,360 64.3 225.53 6/20/2011 MWD 1,725.92 1,264.51 -874.43 -919.42 0.19 2,423 64.2 225.09 6/20/2011 MWD 1,753.29 1,321.14 -914.34 -959.76 0.65 2,487 64.32 225.1 6/20/2011 MWD 1,781.08 1,378.69 -955.04 -1,000.59 0.19 2,550 64.18 225.14 6/20/2011 MWD 1,808.45 1,435.33 -995.08 -1,040.80 0.23 2,613 64.26 224.91 6/20/2011 MWD 1,835.85 1,491.96 -1,035.17 -1,080.93 0.35 2,677 64.19 224.32 6/20/2011 MWD 1,863.68 1,549.52 -1,076.20 -1,121.40 0.84 2,740 64.26 224.37 6/20/2011 MWD 1,891.08 1,606.19 -1,116.77 -1,161.06 0.13 2,830 64.22 224.37 6/20/2011 MWD 1,930.19 1,687.16 -1,174.71 -1,217.74 0.04 2,866 64.22 224.76 6/20/2011 MWD 1,945.85 1,719.54 -1,197.81 -1,240.49 0.98 2,930 64.26 224.88 6/20/2011 MWD 1,973.66 1,777.09 -1,238.69 -1,281.12 0.18 2,993 64.21 225.17 6/20/2011 MWD 2,001.05 1,833.73 -1,278.79 -1,321.25 0.42 3,057 64.26 224.72 6/20/2011 MWD 2,028.87 1,891.28 -1,319.59 -1,361.97 0.64 3,120 64.22 225.09 6/20/2011 MWD 2,056.25 1,947.93 -1,359.78 -1,402.02 0.53 3,183 64.22 225.32 6/21/2011 MWD 2,083.65 2,004.55 -1,399.75 -1,442.28 0.33 3,246 64.25 225.21 6/21/2011 MWD 2,111.03 2,061.18 -1,439.68 -1,482.59 0.16 3,309 64.26 224.97 6/21/2011 MWD 2,138.40 2,117.83 -1,479.74 -1,522.77 0.34 3,373 64.09 225.31 6/21/2011 MWD 2,166.28 2,175.33 -1,520.38 -1,563.61 0.55 li 3,436 64.22 225.23 6/21/2011 MWD 2,193.74 2,231.92 -1,560.28 -1,603.89 0.24 3,500 64.19 225.16 6/21/2011 MWD 2,221.59 2,289.43 -1,600.89 -1,644.77 0.11 3,563 64.19 225.45 6/21/2011 MWD 2,249.02 2,346.04 -1,640.78 -1,685.09 0.41 3,626 64.19 225.56 6/21/2011 MWD 2,276.45 2,402.63 -1,680.52 -1,725.54 0.16 3,689 64.21 225.77 6/21/2011 MWD 2,303.87 2,459.21 -1,720.16 -1,766.11 0.3 3,752 64.25 225.89 6/21/2011 MWD 2,331.26 2,515.80 -1,759.69 -1,806.81 0.18 3,815 64.23 226.27 6/21/2011 MWD 2,358.64 2,572.37 -1,799.05 -1,847.68 0.54 3,878 64.29 226.07 6/21/2011 MWD 2,386.00 2,628.95 -1,838.35 -1,888.62 0.3 3,942 64.18 226.67 6/21/2011 MWD 2,413.82 2,686.39 -1,878.12 -1,930.34 0.86 4,004 64.25 226.52 6/21/2011 MWD 2,440.79 2,742.02 -1,916.48 -1,970.89 0.25 4,068 64.23 224.92 6/21/2011 MWD 2,468.61 2,799.51 -1,956.72 -2,012.16 2.25 4,131 64.22 223.14 6/22/2011 MWD 2,496.00 2,856.20 -1,997.51 -2,051.59 2.54 4,195 64.27 221.72 6/22/2011 MWD 2,523.81 2,913.83 -2,040.05 -2,090.48 2 4,258 64.26 220.26 6/22/2011 MWD 2,551.17 2,970.58 -2,082.89 -2,127.70 2.09 4,322 64.18 218.65 6/22/2011 MWD 2,579.01 3,028.16 -2,127.39 -2,164.32 2.27 4,385 64.25 217.8 6/22/2011 MWD 2,606.41 3,084.78 -2,171.95 -2,199.42 1.22 4,448 64.25 217.34 6/22/2011 MWD 2,633.78 3,141.38 -2,216.92 -2,234.02 0.66 4,511 64.3 216.98 6/22/2011 MWD 2,661.13 3,197.96 -2,262.16 -2,268.30 0.52 4,574 64.26 217.23 6/22/2011 MWD 2,688.47 3,254.53 -2,307.42 -2,302.54 0.36 4,638 64.25 217.13 6/22/2011 MWD 2,716.27 3,312.00 -2,353.35 -2,337.38 0.14 4,701 64.22 217.22 6/22/2011 MWD 2,743.65 3,368.56 -2,398.56 -2,371.66 0.14 4,764 64.22 216.94 6/22/2011 MWD 2,771.05 3,425.10 -2,443.82 -2,405.87 0.4 4,827 64.26 216.72 6/22/2011 MWD 2,798.43 3,481.64 -2,489.23 -2,439.88 0.32 4,890 64.26 216.67 6/22/2011 MWD 2,825.79 3,538.17 -2,534.74 -2,473.79 0.07 4,954 64.19 216.5 6/22/2011 MWD 2,853.62 3,595.57 -2,581.01 -2,508.14 0.26 5,017 64.23 216.51 6/22/2011 MWD 2,881.03 3,652.07 -2,626.61 -2,541.88 0.07 5,080 64.26 216.68 6/22/2011 MWD 2,908.40 3,708.58 -2,672.17 -2,575.71 0.25 5,144 64.09 216.33 6/23/2011 MWD 2,936.28 3,765.95 -2,718.47 -2,609.98 0.56 5,209 64.26 216.15 6/23/2011 MWD 2,964.60 3,824.20 -2,765.66 -2,644.57 0.36 5,271 64.3 216.09 6/23/2011 MWD 2,991.51 3,879.79 -2,810.78 -2,677.50 0.11 5,334 64.36 215.92 6/23/2011 MWD 3,018.80 3,936.29 -2,856.72 -2,710.88 0.26 5,397 64.22 216.35 6/23/2011 MWD 3,046.13 3,992.79 -2,902.56 -2,744.35 0.65 5,460 64.22 216.18 6/23/2011 MWD 3,073.53 4,049.26 -2,948.30 -2,777.91 0.24 5,525 64.16 216.23 6/23/2011 MWD 3,101.83 4,107.51 -2,995.52 -2,812.47 0.12 5,587 64.31 216.4 6/23/2011 MWD 3,128.78 4,163.10 -3,040.51 -2,845.54 0.35 5,650 64.23 216.99 6/23/2011 MWD 3,156.13 4,219.63 -3,086.01 -2,879.45 0.85 5,713 64.26 217.42 6/23/2011 MWD 3,183.50 4,276.20 -3,131.21 -2,913.76 0.62 5,777 64.22 217.47 6/23/2011 MWD 3,211.32 4,333.68 -3,176.97 -2,948.81 0.09 5,841 64.32 217.39 6/23/2011 MWD 3,239.10 4,391.18 -3,222.75 -2,983.85 0.19 5,904 64.26 217.36 6/23/2011 MWD 3,266.43 4,447.78 -3,267.86 -3,018.30 0.1 5,968 64.25 217.27 6/24/2011 MWD 3,294.23 4,505.26 -3,313.71 -3,053.25 0.13 6,031 64.3 217.26 6/24/2011 MWD 3,321.58 4,561.84 -3,358.88 -3,087.62 0.08 6,094 64.25 217.42 6/24/2011 MWD 3,348.92 4,618.43 -3,404.00 -3,122.04 0.24 6,158 64.22 216.98 6/24/2011 MWD 3,376.74 4,675.89 -3,449.91 -3,156.89 0.62 6,221 64.23 216.92 6/24/2011 MWD 3,404.14 4,732.43 -3,495.25 -3,190.99 0.09 6,284 64.22 217.14 6/24/2011 MWD 3,431.53 4,788.97 -3,540.54 -3,225.16 0.31 6,347 64.26 216.67 6/24/2011 MWD 3,458.91 4,845.51 -3,585.91 -3,259.23 0.67 6,410 64.2 216.98 6/24/2011 MWD 3,486.30 4,902.04 -3,631.32 -3,293.23 0.45 6,474 64.23 216.87 6/24/2011 MWD 3,514.14 4,959.47 -3,677.39 -3,327.85 0.16 6,536 64.26 216.81 6/24/2011 MWD 3,541.08 5,015.11 -3,722.08 -3,361.33 0.1 6,599 64.29 216.59 6/24/2011 MWD 3,568.43 5,071.65 -3,767.59 -3,395.25 0.32 6,661 64.23 216.62 6/24/2011 MWD 3,595.35 5,127.28 -3,812.42 -3,428.56 0.11 6,725 64.19 216.84 6/24/2011 MWD 3,623.20 5,184.69 -3,858.61 -3,463.02 0.32 6,789 64.29 216.67 6/24/2011 MWD 3,651.01 5,242.11 -3,904.79 -3,497.51 0.29 6,853 64.25 216.66 6/25/2011 MWD 3,678.80 5,299.54 -3,951.03 -3,531.94 0.06 6,916 64.18 218.29 6/25/2011 MWD 3,706.20 5,356.12 -3,996.05 -3,566.45 2.33 6,980 64.16 219.69 6/25/2011 MWD 3,734.09 5,413.65 -4,040.83 -3,602.69 1.97 6,999 64.24 219.94 6/25/2011 MWD 3,742.36 5,430.75 -4,053.97 -3,613.64 1.26 7,120 63.99 218.02 7/4/2011 MWD 3,795.19 5,539.48 -4,138.58 -3,682.12 1.44 7,182 64.23 219.13 7/4/2011 MWD 3,822.26 5,595.18 -4,182.19 -3,716.90 1.66 7,245 64.33 220.85 7/4/2011 MWD 3,849.60 5,651.91 -4,225.67 -3,753.37 2.46 7,308 61.15 222.61 7/4/2011 MWD 3,878.46 5,707.90 -4,267.47 -3,790.63 5.63 7,370 57.91 222.83 7/4/2011 MWD 3,909.89 5,761.32 -4,306.72 -3,826.88 5.23 7,433 57.49 222.36 7/4/2011 MWD 3,943.56 5,814.56 -4,345.92 -3,862.92 0.92 7,496 56.99 222.87 7/4/2011 MWD 3,977.65 5,867.54 -4,384.91 -3,898.79 1.05 7,560 56.75 223.73 7/4/2011 MWD 4,012.63 5,921.11 -4,423.92 -3,935.55 1.19 7,623 55.44 223.89 7/4/2011 MWD 4,047.77 5,973.36 -4,461.65 -3,971.74 2.09 7,686 52.54 223.11 7/4/2011 MWD 4,084.80 6,024.29 -4,498.61 -4,006.82 4.71 7,749 52.16 222.93 7/4/2011 MWD 4,123.29 6,074.16 -4,535.07 -4,040.86 0.64 7,813 52.03 223.23 7/4/2011 MWD 4,162.60 6,124.64 -4,571.96 -4,075.35 0.42 7,875 51.34 222.22 7/4/2011 MWD 4,201.04 6,173.28 -4,607.69 -4,108.35 1.69 7,938 49.06 222.31 7/4/2011 MWD 4,241.37 6,221.68 -4,643.51 -4,140.90 3.62 8,001 46.76 222.82 7/4/2011 MWD 4,283.59 6,268.42 -4,677.94 -4,172.52 3.7 8,063 44.59 221.84 7/4/2011 MWD 4,326.91 6,312.77 -4,710.72 -4,202.39 3.68 8,125 42.8 221.67 7/4/2011 MWD 4,371.74 6,355.60 -4,742.67 -4,230.92 2.89 8,189 40.64 220.5 7/4/2011 MWD 4,419.51 6,398.18 -4,774.77 -4,258.91 3.59 8,253 38.82 219.22 7/4/2011 MWD 4,468.73 6,439.06 -4,806.16 -4,285.13 3.12 8,317 37.52 220.08 7/5/2011 MWD 4,519.04 6,478.59 -4,836.62 -4,310.37 2.19 8,378 37 220.16 7/5/2011 MWD 4,567.59 6,515.50 -4,864.86 -4,334.16 0.86 8,440 36.33 221.99 7/5/2011 MWD 4,617.32 6,552.52 -4,892.77 -4,358.48 2.07 8,505 35.14 222.47 7/5/2011 MWD 4,670.09 6,590.48 -4,920.88 -4,384.00 1.88 8,569 33.46 222.98 7/5/2011 MWD 4,722.95 6,626.54 -4,947.37 -4,408.46 2.66 8,632 31.64 223.18 7/5/2011 MWD 4,776.06 6,660.42 -4,972.13 -4,431.61 2.89 8,695 29.59 223.19 7/5/2011 MWD 4,830.27 6,692.50 -4,995.52 -4,453.57 3.25 8,757 27.65 224.14 7/5/2011 MWD 4,884.69 6,722.17 -5,017.01 -4,474.06 3.21 8,821 25.76 223.13 7/5/2011 MWD 4,941.86 6,750.92 -5,037.82 -4,493.92 3.04 8,884 23.91 223.22 7/5/2011 MWD 4,999.04 6,777.37 -5,057.11 -4,512.02 2.94 8,947 22.17 222.09 7/5/2011 MWD 5,057.01 6,802.02 -5,075.24 -4,528.73 2.85 9,009 20.55 219.94 7/6/2011 MWD 5,114.75 6,824.59 -5,092.27 -4,543.56 2.9 9,073 18.78 219.18 7/6/2011 MWD 5,175.01 6,846.12 -5,108.87 -4,557.28 2.79 9,136 16.91 217.49 7/6/2011 MWD 5,234.98 6,865.39 -5,124.00 -4,569.26 3.08 9,200 15.42 218.44 7/6/2011 MWD 5,296.45 6,883.16 -5,138.05 -4,580.22 2.36 9,263 14.39 221.47 7/6/2011 MWD 5,357.33 6,899.36 -5,150.47 -4,590.61 2.05 9,326 11.82 224.68 7/6/2011 MWD 5,418.68 6,913.63 -5,160.93 -4,600.33 4.24 9,389 9.9 226.83 7/6/2011 MWD 5,480.55 6,925.47 -5,169.22 -4,608.82 3.11 9,453 8.54 223.31 7/6/2011 MWD 5,543.73 6,935.70 -5,176.45 -4,616.10 2.3 9,516 7.19 218.18 7/6/2011 MWD 5,606.13 6,944.31 -5,182.95 -4,621.74 2.41 9,578 5.67 215.6 7/6/2011 MWD 5,667.74 6,951.23 -5,188.49 -4,625.92 2.49 9,642 4.69 204.09 7/6/2011 MWD 5,731.48 6,956.87 -5,193.45 -4,628.83 2.22 9,705 4.1 192.95 7/6/2011 MWD 5,794.30 6,961.30 -5,198.00 -4,630.39 1.64 9,768 2.73 176.12 7/6/2011 MWD 5,857.18 6,964.32 -5,201.69 -4,630.79 2.67 9,829 1.81 182.12 7/7/2011 MWD 5,918.14 6,966.08 -5,204.10 -4,630.73 1.56 9,892 1.54 191.19 7/7/2011 MWD 5,981.11 6,967.58 -5,205.93 -4,630.93 0.6 9,956 1.28 209.42 7/7/2011 MWD 6,045.09 6,969.02 -5,207.39 -4,631.45 0.81 10,020 0.34 187.5 7/7/2011 MWD 6,109.08 6,969.87 -5,208.20 -4,631.82 1.52 10,083 0.35 85.28 7/7/2011 MWD 6,172.08 6,969.89 -5,208.37 -4,631.66 0.85 10,147 0.39 272.1 7/7/2011 MWD 6,236.08 6,969.88 -5,208.35 -4,631.68 1.15 10,211 1.8 273.39 7/7/2011 MWD 6,300.07 6,970.65 -5,208.28 -4,632.90 2.2 10,274 0.43 46.7 7/7/2011 MWD 6,363.06 6,971.02 -5,208.06 -4,633.72 3.36 10,336 0.17 78.05 7/7/2011 MWD 6,425.06 6,970.72 -5,207.88 -4,633.46 0.48 10,399 0.78 258.5 7/7/2011 MWD 6,488.06 6,970.99 -5,207.95 -4,633.78 1.51 10,461 1.85 263.09 7/7/2011 MWD 6,550.04 6,972.08 -5,208.15 -4,635.19 1.73 10,525 1.14 264.94 7/7/2011 MWD 6,614.02 6,973.31 -5,208.33 -4,636.85 1.11 10,588 0.83 273.34 7/7/2011 MWD 6,677.01 6,974.05 -5,208.36 -4,637.93 0.54 10,649 0.9 259.61 7/7/2011 MWD 6,738.00 6,974.71 -5,208.42 -4,638.84 0.36 10,714 0.9 274.95 7/8/2011 MWD 6,802.99 6,975.41 -5,208.47 -4,639.85 0.37 10,777 0.18 319.7 7/8/2011 MWD 6,865.99 6,975.70 -5,208.35 -4,640.41 1.24 10,841 0.71 135.46 7/8/2011 MWD 6,929.99 6,975.71 -5,208.56 -4,640.20 1.39 10,904 2.12 131.32 7/8/2011 MWD 6,992.97 6,975.73 -5,209.61 -4,639.05 2.24 10,966 0.87 125.27 7/8/2011 MWD 7,054.94 6,975.67 -5,210.63 -4,637.80 2.03 11,029 0.44 105.58 7/8/2011 MWD 7,117.94 6,975.51 -5,210.98 -4,637.18 0.76 i 11,092 0.8 292.1 7/8/2011 MWD 7,180.94 6,975.55 -5,210.88 -4,637.35 1.97 11,156 2.16 291.65 7/8/2011 MWD 7,244.92 6,976.11 -5,210.26 -4,638.89 2.13 11,220 0.5 283.76 7/8/2011 MWD 7,308.90 6,976.66 -5,209.75 -4,640.28 2.6 11,282 2.3 97.67 7/8/2011 MWD 7,370.88 6,976.09 -5,209.85 -4,639.31 4.51 11,345 3.37 87.06 7/8/2011 MWD 7,433.81 6,974.08 -5,209.93 -4,636.21 1.88 11,408 1.43 82.65 7/8/2011 MWD 7,496.75 6,972.18 -5,209.73 -4,633.58 3.09 11,472 1.02 86.79 7/8/2011 MWD 7,560.73 6,971.18 -5,209.60 -4,632.22 0.65 11,534 0.63 86.03 7/9/2011 MWD 7,622.73 6,970.54 -5,209.54 -4,631.33 0.63 11,596 0.4 118.88 7/9/2011 MWD 7,684.72 6,970.25 -5,209.62 -4,630.80 0.59 11,658 0.31 294.43 7/9/2011 MWD 7,746.72 6,970.25 -5,209.66 -4,630.76 1.14 11,740 0.93 317.1 7/9/2011 MWD 7,828.72 6,970.26 -5,209.08 -4,631.42 0.8 11,794 0.93 317.1 7/9/2011 MWD 7,882.71 6,970.17 -5,208.44 -4,632.01 0 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 29, 2011 12:42 PM To: 'Skiba, Kevin J. (MRO)' Cc: Ellis, Michael (MRO); Mullin, Mickey(MRO); Sulley, Michael B. (MRO) Subject: RE: SD-7(211-050) Update Kevin, et a, I don't believe anything further is needed. I will put a copy of this message in the file. Also, please include the PTD number on messages about wells. That helps us get to the proper file more quickly. Call or message with any questions. Tom Maunder, PE AOGCC From: Skiba, Kevin J. (MRO) [mailto:kskiba@marathonoil.com] Sent: Tuesday, November 29, 2011 9:48 AM To: Maunder, Thomas E (DOA) Cc: Ellis, Michael (MRO); Mullin, Mickey (MRO); Sulley, Michael B. (MRO) Subject: SD-7 Update Tom, SD-7 was completed into the Tyonek formation on 11-25-11. The 11,591'-11,605' interval was wet. Marathon intends to set a bridge plug at -11,570' MD to isolate this interval. The next target intervals are 11,541'-11,551' & 11,101'-11,111. Let me know if you have any questions. Thanks, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC Office (907) 283-1371 Cell (907) 394-1880 Fax (907) 283-1350 IT] Safe, Clean, and Responsible 11/29/2011 Marathon Oil Company f' Alaska Asset Team P.O. Box 1949 Marathon oil Kenai,AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RECEIVED November 5, 2012 NOV 0 9 2012 Mr. Stephen McMains AOGCC Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 ail -0' Reference: 10-407 Well Completion Report and Log Field: Ninilchik Unit Well: Susan Dionne #7 Dear Mr. McMains: Enclosed please find the 10-407 Well Completion Report and Log for Ninilchik Unit well SD-7. Completion operations on the Tyonek formation were finalized on September 4th, 2012. After a 10 day buildup production was initiated on September 14th, 2012. Due to extremely low and intermittent rates a multi point well test was not possible. Current gas production is under 100 mcfd at 250 psi. Please call me at (907) 283-1370 if you have any questions or require additional information. Sincerely, e( dr(/(ca/744/4.i. Mike Marini Production Engineer Enclosures: 10-407 Well Completion Report & Log cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS Wireline and LWD Log's CLS MRO Regulatory File ilia [E BF n [Lnan / SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS333 W.7th AVENUE,SUITE 100 II CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Rowland C. Lawson FAX (907)276-7542 Advanced Drilling Engineer Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Re: Ninilchik Field, Tyonek Pool, Susan Dionne #7 Marathon Oil Company Permit No: 211-050 Surface Location: 368' FSL, 1105' FEL, SEC. 06, T1S, R13W, SM Bottomhole Location: 438' FSL, 779' FEL, SEC. 12, T1S, R 14W, SM Dear Mr. Lawson: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Marathon Oil Company assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. del ;r.sio' er ( ir DATED this - day of April, 2011. cc: Department of Fish & Game, Habitat Section w/o end. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) 1444 REcr:,N o asfa.0 STATE OF ALASKA - 'APR 0 4 ALASKA OIL AND GAS CONSERVATION COMMISSION 41,5"--// PERMIT TO DRILL #;lqa COI t L 20 AAC 25.005 ta.Type of Work: lb.Proposed Well Class: Development-Oil U Service- Winj ❑ Single Zone Q lc.Specifytillifftwosed for. Drill ❑, Rednil ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket O Single Well ❑ 11.Well Name and Number: Marathon Oil Company Bond No. 5194234 Ninilchik Unit-Susan Dionne#7 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 3128,Houston,TX 77253 MD: 11,794 ND: 7,869 Ninilchik Unit 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Tyonek Pool Surface: 368'FSL and 1,105'FEL Sec.6,T1S,R13W,S.M. ' CIRI Lease C-061505&ADL384372 Top of Productive Horizon: 8.Land Use Permit: 13.Ap. • i ate Spud Date: 1,450'FSL and 123'FWL,Sec.7,T1S,R13W,S.M. . 15/2011 Total Depth: 9.Acres in Property: 14. s *ance to Nearest Property: 438'FSL and 779'FEL Sec.12,T1S,R14W,S.M. ' C-061505(1371.7ac)ADL384372(3507.84ac) Univ.AK Tr.21 120ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 163 feet 15.Distance to Nearest Well Open Surface:x- 213,338.032 y- 2,236,847.50 Zone-4 GL Elevation above MSL: 142 feet to Same Pool: Paxton#2 1814 ft Susan Dionne#5 1465 ft 16.Deviated wells: Kickoff depth: 400 feet 17.Maximum Anticipated Pressures in psig(see 20 5.035) Maximum Hole Angle: 64.271 degrees Downhole: 3642psi Surface: 844.psi 18.Casing Program: Specifications Top - Setting Depth - Bottom ----"Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) Driven 20" 129.25 X-65 PE 96 0 0 117 117 13 1/2" 10 3/4" 45.5 L-80 BTC 1,664 0 0 1,685 1,432 498SX 9 7/8" 7 5/8" 29.7 L-80 BTC 7,208 0 0 7,029 3,839 Lead 574SX Tail 275SX 6 3/4" 4 1/2" 12.6 L-80 Hydril-563 4,765 6,829 3,665 11,794 7,869 301SX ' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Rowland C.Lawson Title Advanced Drilling Engineer Signature --/Z-Z--„, C Phone X07-39 y-©783 Date y-q- zo i f Commission Use Only Permit to Drill API Number: Permit Approva See cover letter for other Number: ,J//O O 50-13�?O,S91/D000 Date: 1 La requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbe methane, as hydrates,or gas contained in shales: V� Other: 1. • Samples req'd: Yes❑ No ( Mud log req'd: Yes No !J -�'e -{ 3DPE l0 Tovo est . H25 measures: Yes❑ No D' :ctional svy req'd: Yes No ❑ �� PPROVED BY THE COMMISSION DATE: ��►4 ) ��1 ,COMMISSIONER ORIGINA Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(9)) Submit in Duplicate Worldwide Drilling North America / j\ Marathon P.O.Box 3128 MARATHON Oil Company Houston,TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 April 1, 2011 Daniel T. Seamount, Jr. RECEIVED Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Ataskc &qos Cons.Cnniros3011 Anchorage, AK 99501 Anchorage Reference: Drilling Permit Application Field: Ninilchik Field Well: Ninilchik Unit—Susan Dionne #7 Dear Mr. Seamount Enclosed please find the PERMIT TO DRILL application, along with the associated attachments. The intent is to drill a well in the Tyonek Pool in the Ninilchik Unit. For the directional data we utilize the National Geodetic Survey conversion in the program CORPSCON to calculate the State Plane Coordinates in NAD 27 for the planned and actual wellpaths from the NAD 83 data and present both in our directional survey attachment for the 10-401. We also provide the same data electronically, so that the AOGCC has this for data input into their database. If you require further information, I can be reached at 907-394-0953 or by e-mail at rclawson@marathonoil.com. Sincer ly, Rowland C. Lawson Advanced Drilling Engineer Enclosures Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit AA MARATHON MARATHON OIL COMPANY DRILLING PROGRAM Susan Dionne 7 Originator: Rowland C. Lawson April, 4 2011 Date Reviewed by: Don Hall Date Jim Thompson Date 4/4/2011 CONFIDENTIAL MATERIAL Page 1 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit TABLE OF CONTENTS 1. Emergency Response Information 4 1.1 Directions to Location 4 1.2 Rig Contact Numbers 4 1.3 Marathon Emergency Response Contacts 4 1.4 Outside Emergency Response 4 1.5 Marathon Contact List 5 2. Regulatory Agency Contacts 5 2.1.1. Internal Regulatory Contact 5 2.1.2. External Regulatory Contact 5 3. Regulatory Compliance 5 4. Drilling Program Summary 6 4.1 General Well Data 6 4.2 Working Interest Owners Information 6 4.3 Geologic Program Summary 6 4.4 Summary of Potential Drilling Hazards 7 4.5 Formation Evaluation Summary 7 4.6 Drilling Program Summary 8 4.7 Casing Program Summary 10 4.8 Casing Design 10 4.9 Calculation of Maximum Anticipated Pressures(MAWP and MASP) 10 4.10 Casing Test Pressure Calculations 12 4.11 Blowout Prevention Equipment, Testing and General Procedures 12 4.11.1. Function Testing 12 4.11.2. Pressure Testing 13 4.12 Wellhead Equipment Summary 13 4.13 Directional Program Summary 13 4.14 Directional Surveying Summary 15 4.15 Drilling Fluid Program Summary 15 4.16 Drilling Fluid Specifications 15 4.17 Solids Control Equipment 16 4.18 Cement Program Summary 17 4.19 Bit Summary 17 4.20 Hydraulics Summary 18 4.21 Formation Integrity Test Procedure 18 4/4/2011 CONFIDENTIAL MATERIAL Page 2 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit Attachments Group Attachment Attached Commercial Information AFE Days/Cost vs.Depth Curves X Project Objectives and Scorecard RSO Coding Information X Requisitions Vendor List Bonus Program Drilling Contract Regulatory/HES Information Emergency Evacuation Plan X H2S Contingency Plan n/a Regulatory Permits X Regulatory Rules and Regulations Risk Analysis Miscellaneous Programs(Vendors) Bit Proposal X Cement Proposal X Directional Plan X Fluids Program X Wellhead Equipment—Description/Drawings Drill String and BHA Summary Rig Mobilization/Mooring Procedure n/a Geological Information Location Map w/offsets X Offset Data Proposed Formation Pore Pressure,Mud Wt&Fracture Gradient X Temperature Curves Geologic Structure Maps Geologic Cross Section Bathymetry Map n/a Analysis Riser Analysis n/a Station Keeping Analysis—Mooring/DP n/a Stress Check Casing Design File X Maximum Allowable Overpull Miscellaneous Information Wellbore Diagram n/a Rig Elevations X Well Location Diagram X BOP Schematic X BOP Well Control Bridging Document Detailed Casing Specifications X Detailed Drill Pipe Specifications 4/4/2011 CONFIDENTIAL MATERIAL Page 3 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 1. Emergency Response Information 1.1 Directions to Location Method Directions Air Latitude-60°06'46.689"N Longitude-151°34'24.993"W (NAD 83) From the Kenai airport,go 0.5 mile South on Willow Street. Turn East on Main Street Loop,go 0.3 miles. Continue East on Ground Bridge Access Road 3.2 miles. Turn West on Kalifornsky Beach Road. Go West and then South,go 16.9 miles. Turn South on Sterling Highway,go 18.8 miles. Turn West onto road to the pad(Sterling Highway milepost 128.6). 1.2 Rip Contact Numbers Contact Office Cell Glacier Drilling Rig 1 Inlet Drilling Tool Pusher 907-283-1314 907-394-1321 Marathon Supervisor 907-283-1312 907-394-1317 1.3 Marathon Emergency Response Contacts Individual Postion Main Phone Alternative Kenai Gas Field Emergency Number 907-283-6465 CERT 24 hrs Notification 1-800-MOC-CERT CERT Crisis Center Houston 713-296-4230 713-296-4237 1.4 Outside Emergency Response Location Contact Phone Fire Kenai/Soldotna,Alaska 907-262-4792 Ambulance Hospital Kenai/Soldotna,Alaska Central Peninsula Hospital 907-262-4404 Kenai Police 907-283-7879 Police Kenai/Soldotna,Alaska Soldotna Police 907-262-4455 State Police 907-262-4453 Coast Guard 800-478-5555 Spill and Contamination Alaska Alaska State Spill Reporting National Response Center Oil/Toxic Chemical Spills 800-424-8802 Best Practices: 1 Policy: Post emergency notification information on rig floor, company man's and tool pushers' office. Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 4 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 1.5 Marathon Contact List Contact Title Office Mobile Facsimile Home Rowland Lawson Drilling Engineer 907-283-1312 907-394-0953 907-394-1313 Don Hall Drilling Superintendent 713-296-3271 713-775-1668 713-499-6733 Jim Thompson Drilling Manager 713-296-2730 713-232-9347 713-513-6019 David Gorney Geologist 713-296-3473 713-591-8866 Clyde Scott Reservoir Engineer 713-296-2336 Nick Miller Completion Engineer 713-296-1920 713-294-1735 Mike Ellis Production Engineer 907-283-1337 907-394-1324 Rowland Lawson Drilling Supervisor 907-283-1312 907-394-0953 907-283-1313 2. Regulatory Agency Contacts 2.1.1. Internal Regulatory Contact Contact Title Office Phone Cell Phone Home Phone Facsimile Kevin Skiba Regulatory Compliance 907-283-1371 907-394-1880 907-283-1350 2.1.2. External Regulatory Contact Contact Title Office Phone Facsimile 24 hr Emergency Pager AOGCC 907-793-1236 3. Regulatory Compliance Regulation Requirement 20 AAC 25.035 e 10 A BOP testing interval requirement is now 4 days. 20 AAC 25.035 e 10 F Requirement for a 24 hour notice to AOGCC prior to BOP test. Comments 4/4/2011 CONFIDENTIAL MATERIAL Page 5 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4. Drilling Program Summary 4.1 General Well Data Well Name Susan Dionne 7 Lease/License Surface Location 368'FSL, 1,105'FEL,Sec.6,T1S,R13W,S.M. WBS Code DD.11.23631.CAP.DRL Slot/Pad Susan Dionne Field Ninilchik Unit Spud Date 6/15/11 (est.) KB(above MSL) 163' County/Province Kenai Peninsula API No. GL(above MSL) 142' State/Country Alaska Permit No. Perm.Datum KB Total MD 11,794 Well Class Development Water Depth N/A Total TVD 7,869 Rig Contractor Glacier Drilling Water Protection Depth Rig Name Glacier Rig 1 Best Practices: 1 Comments: 4.2 Working Interest Owners Information Company Working Interest Address Phone Facsimile Marathon 60% P.O.Box 196168 907-561-5311 907-565-3076 Anchorage,AK 99519-6168 Chevron-Texaco 40% 4.3 Geologic Program Summary Surface Location Coordinates—NAD 83 From Lease/Block Lines 368'FSL, 1,105'FEL,Sec.6,T1S,R13W,S.M. Latitude 60°06'46.689"N Longitude 151°34'24.993"W UTM North(Y) 2,236,599.16' UTM East(x) 1,353,364.83' Tolerance Pore Pore MD-RKB ND—RKB Pressure Pressure Possible Formation (ft) (ft) (psi) (ppg) . Lithology Fluid Content Tyonek (Primary Target) 10,767 6,842 4.4-8.9 Sandstone Gas 4/4/2011 CONFIDENTIAL MATERIAL Page 6 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit Horizontal Depth(KB) Displacement(ft) MD ND +N/-S +E/-W Tolerance Target (ft) (ft) Location (Y) (X) (ft) UT1B Coal 7,229 3,839 1,450'FSL, 123'FWL,Sec.7,T1S,R13W,S.M. -4,197' -3,746' Circle 200'radius T81 Coal 10,767 6,842 459'FSL,759'FEL,Sec. 12,T1S,R14W,S.M. -5,188' -4,626' Circle 200'radius T135 Coal/TD 11,794 7,869 438'FSL,779'FEL,Sec. 12,T1S,R14W,S.M. -5,209' -4,646' Circle 200'radius 4.4 Summary of Potential Drilling Hazards Depth KB Hazard Event Discussion Precautions (ND) Bit or BHA balling Surface Hole Maintain high pump rates to keep bit and BHA clean. Use extra circulation time if necessary. Intermediate Use good hole cleaning techniques with sufficient Excessive pumping on bottom could Excessive Torque &Production pump rates. Add lubricant where necessary. result in hole washout and formation Hole breakdown due to excess ECD. Production Formation Losses Hole Minimize serge on trips by limiting RIH speeds. Limit RIH speeds to prevent loses. Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +1- MD (1,600' TVD) to total depth of the well. These sands will run from slightly depleted to slightly above normal pressure. The Flo-Pro mud system that will be properly weighted to hydraulically control all sands and lost circulation materials will be available on location, if required. Best Practices: 1 Comments: 4.5 Formation Evaluation Summary Interval LWD Electric Logs Mud Logs Surface None None None 0'—1,685'MD Intermediate None LWD Gamma Ray/Resistivity. Basic with GCA,shale density,temperature in and 1,685'—7,029'MD out,sample collection(10'samples). Production None LWD Gamma Ray/Resistivity/Density Basic with GCA,shale density,temperature in and 7,029'—11,794'MD Neutron/NMR/Testrak/.Shuttle Sonic. out,sample collection(10'samples). Completion N/A GR,CCL,CBL � N/A Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 7 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.6 Drilling Program Summary Drive Pipe: N/A Conductor: 20"set to approximately ,1', prior to drilling rig move. MIRU drilling rig. NU diverter. 1. RU conductor rig. Drill/Drive 20"conductor to+/-100 ft. RKB. RD conductor rig. 2. Move in and rig up rotary drilling rig. 3. Install starting head 20"SLC x 21 1/4",2M flanged. 4. Nipple up 21 1/4",2M diverter, 16"diverter valve, and 16"diverter line. 5. Function test diverter and diverter valve. / Best Practices: 1 Comments: Surface: Drill 13-1/2"hole to+/- 1,685' set 10-3/4"casing. 1. Drill a 13 1/2"hole to 1,685' MD(1,432'TVD)per the directional plan. 2. At TD circulate hole clean. Make wiper trip. TOOH(SLM). 3. Run and cement 10 3/4"casing. 4. Cut off 10 3/4"casing and LD same. NDdiverter. 5. Install 10 3/4"slip lock connection X 11"5M� flanged multibowl wellhead. 6. NU 11"5M X 13 5/8"adapter spool. NU-13 5/8"5M BOP'S. Test BOP's and choke manifold to 250 -0-09/Psi. 7. Set wear bushing. Test surface casing to 1,500 psi/30min. i Best Practices: 1 During cementing operations,take returns in the cellar, instead of into the pits. Eliminates the clean up of pits from cement that circulated to surface. Vac trucks will pull from cellar. Comments: Intermediate: Drill 9-7/8"hole to+/-7,029'set 7 5/8"casing. 1. PU 9 7/8"PDC bit and Autotrak BHA w/Gamma Ray and Resistivity LWD. Drill out float equipment and 20'of new formation. Displace to Flopro mud U. 2. Test shoe to a FIT of 5,ppg. Estimated leakoff EMW is 18.5 ppg. 3. Drill 9 7/8"directionarhole to 7,029'MD(3,752'TVD)as per directional program,short tripping as required. 4. At TD circulate hole clean. Make wiper trip. TOOH(SLM)L/D Autotrak and LWD. 5. M/U Cleanout BHA. RIH to TD. Circ.hole clean. POOH L/D 5"DP and BHA. 6. Pull wear bushing. Run test plug 7. Change out 2 7/8"X 5''/z'upper variable pipe rams with 7 5/8"casing rams. Test casing rams w/7 5/8"test joint to 3,000 psi. "- 8. Run 7 5/8"Casing and land hanger in multibowl wellhead. Circulate 1 1/2"casing volumes and cement 7 5/8"casing. 9. Back out landing joint. Run test plug.Change out upper pipe rams with 2 7/8"X 5 variable rams. CIO bottom rams to 4" DP rams. Run 4"test joint and test BOP's to 250/3,000 psi. , 10. Set wear bushing. Test intermediate casing to 3,000 psi. Best Practices: 1 Pre-heat mud mix water and mud in the pits to help in early shaker screen blinding issues with the mud. Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 8 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit Production Liner: Drill 6 3/4" hole to +/- 11,794' set 4-1/2" liner. Tie back to surface with 4-1/2"tubing. 1. PU enough 4"DP to drill to 11,794'. 2. PU 6 3/4"bit and Au rak BHA w/full complement of LWD and Testrak. Drill float equipment and 20'of new formation.CBU. 3. Test shoe to a FIT f 1pg: Estimated leakoff EMW 16.5 ppg. 4. Drill a 6 3/4"hole town anticipated TD of 11,794' MD(7,869'TVD)as per the directional program,short tripping as required. 5. At TD circulate hole clean. Make wiper trip. TOOH. LD Autotrak BHA. 6. PU cleanout BHA. RIH and circ. hole clean. Drop rabbit and POOH. 7. LD 4"DP that is not required to run the 4/12"Liner. 8. Pull wear bushing and run test plug w/4 'A"test joint. Test upper variable rams 250/3000psi. Pull test plug. Run wear bushing. 9. RU and run 4 1/2"Hydril 563 casing liner with hanger on drill pipe. Run liner to TD with top of liner at approximately 6830'MD. On bottom reciprocate and rotate liner while circulating the hole. 10. RU cementing company. Cement 4 1/2"while reciprocating and rotating pipe. Drop wiper plug and displace w/viscosified brine, bump plug to pressure up and set the liner hanger. Release hanger running tool, pick up and clear seal area of any cement. Pick up out of liner. 11. Circulate hole clean. If cement circulates,TOOH. If cement doesn't circulate,WOC,then prepare and pump liner top job. 12. Once cement is either circulated or the liner top is squeezed, PU polish mill for 4 1/2"along with string mill for 7 5/8"casing. Make cleanout trip to top of 4 1/2"liner with mill combo on drill pipe. Polish 4 1/2"liner seal bore. 13. Run 4 1/2"liner hanger packer with hydraulic pusher tool. Stab into polish bore receptacle and set packer. TOOH laying down drill pipe. 14. Pull Wear bushing. Run 4 1/2" IBT tubing with seal unit and subsurface safety valve. Space out tubing. Test subsurface safety valve. Displace hole with 3% KCL, place corrosion inhibitor in the annulus and land hanger(SSSV should be in the open position). ND BOP,NU tree and test to 5,000 psi. 15. Rig down and move out drilling rig. Best Practices: 1 Make up torque shown for the Hydril 563 will be 9500ft-lb. The final make up torque for the liner should exceed any potential torque that would be used to release the running tool from the hanger. Comments: Completion: Completion will be done without a rig. 1. The completion will encompass work to run a cement bond log, displace the well fluid with nitrogen, perforate several Tyonek intervals, and lest,,the well for rate and pressure. The testing process will include the possibility of venting 10mm cu ft of gas oVer-a'168hr period. No stimulation of the perforated intervals is anticipated. • Best Practices: 1 Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 9 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.7 Casing Program Summary MD(ft) Connection API Ratings Casing Makeup Hole = a) =o w Size Weight ID Drift O.D. Torque Size m U g- Y (in) Top Bottom (lbs/ft) (in) (in) Grade Type (in) (ft-lbs) (in) 10 3A* 0 1,685 45.5 9.950 9.875 L-80 BTC 11.750 N/A* 13 1/2 5210 2,470 1,041 7 5/8 0 7029 29.7 6.875 6.750 L-80 BTC 8.500 N/A* 9 7/8 6,890 4,790 683 4 1/2 6,829 11,794 12.6 3.958 3.833 L-80 Hydril 563 5.200 9,500 6 3/4 i 8,430 7,500 288 *Check to see that the 10 3/4'45.5 casing is special drift casing. Best Practices: 1 Have float equipment made up at Tubescope's yard prior to bringing casing to location. Buck on all equipment to the pin end and not make up to box below, due to rig height restrictions. 2 Make up torque shown for the Hydril 563 is 80% of yield. The final make up torque for the liner should exceed any potential torque that would be used to release the running tool from the hanger. *- Make up buttress connection to proper mark, not to a torque value. Comments: 4.8 Casing Design Casing Shoe Safety Factors Setting Maximum Casing Depth Mud Wt Frac. Form Surface n a Size Weight TVD When Set Grad Press Pressure IIo (in) (lb/ft) Grade (ft) (lb/gal) (lb/gal) (lb/gal) (psi) 00 v i- 10 10 3/4 45.5 L-80 1,432 9.4 (18.5 8.9 1,235 2.02 3.54 3.54 .._, - E . 7 5/8 29.7 L-80 3,752 9.6 16.5 8.9 2,844 2.30 2.56 2.68 41/2 12.6 L-80 7,869 9.8 16.5 8.9 2,844 1.11 1.87 1.97 4.9 Calculation of Maximum Anticipated Pressures (MAWP and MASP) Setting Casing Depth Size TVD MAWP* MASP** Mud/Gas (in) (ft) (psi) (psi) Percentage 10 3/4 1,432 3,550 1,235 0/100 7 5/8 3,752 4,823 2,844 0/100 4 1/2 7,869 4,823 2,844 0/100 * MAWP= Maximum allowable working pressure ** MASP= Maximum anticipated surface pressure The calculation method for MASPBHP is the required standard AOGCC use of a Bottom Hole Pressure—0.1 psi/ft gas gradient. 4/4/2011 CONFIDENTIAL MATERIAL Page 10 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit Surface casing: 10 3/4" (1,685' MD, 1,432'TVD) MASPfrac=((Fracture gradient at shoe)x.052 x TVDshoe)-Hydrostatic pressure of gas column at the shoe. MASPfrac=(18.5 ppg x.052 x 1,432')-(0.1 psi/ft x 1,432') MASPfrac= 1,378 psi-143 psi MASPfrac= 1,235 psi. MASPbhp=BHP open hole td— Hydrostatic pressure of gas column at the shoe. MASPbhp=(8.9 ppg x.052 x 3,752') —(0.1 psi/ft x 3,752') MASPbhp= 1,736 psi—375 psi MASPbhp= 1361 psi MASP=MASPfrac= 1235psi MAWP=(0.7 x Casing Burst)—(Mud Wt.—Backup Fluid Wt.)x.052 x TVD MAWP=(0.7 x 5,210)—(9.6—8.3)x.052 x 1,432' MAWP=3,647 psi—97 psi=3,550 psi Intermediate casing: 7 5/8" (7,029'MD,3,752'TVD) MASPfrac=((Fracture gradient at shoe)x.052 x TVDshoe)-Hydrostatic pressure of gas column at the shoe. MASPfrac=(16.5 ppg x.052 x 3,752')-(0.1 psi/ft x 3,752') MASPfrac=3,219 psi-375 psi MASPfrac=2,844 psi. MASPbhp=BHP open hole td-Hydrostatic pressure of a gas column MASPbhP=(8.9 ppg x.052 x 7,869')—(0.1 psi/ft x 7,869') MASPbhp=3,642 psi—787 psi MASPbhp=2,855 psi MASP=MASP frac=2,844/psi MAWP=(0.7 x Casing Burst)—(Mud Wt.—Backup Fluid Wt.)x.052 x TVD MAWP=(0.7 x 6,890)—(9.6—9.6)x.052 x 7869' MAWP=4,823 psi—0 psi=4,823 psi Production liner: 4 1/2" (Top—6,820' MD,3,662'TVD)(Bottom—11,794' MD,7,869'TVD) MASP=MASP75/8•=2,844 psi MAWP=MAWP7518•=4,823 psi Best Practices: 1 Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 11 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.10 Casing Test Pressure Calculations Casing test pressures calculations are based on the lesser of (1)MASP,or(2)70%of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Best Practices: 1 Comments: 4.11 Blowout Prevention Equipment, Testing and General Procedures BOP PROGRAM Casing Test Test Casing Test Fluid Pressure Size MAWP MASPpress Density BOPS Low/High Casing (in) (psi) (psi) (psi) (lb/gal) Size&Rating (psi) (1)13-5/8"5M annular I (1)13-5/8"5M pipe ram Z Surface 10 3/4 3,550 1,235 1,500 9.4 (1)13 5/8"5M blind ram ; 250/3,000 ' (1)13-5/8"5M drilling spool with 3-1/8"5M outlets (1)13-5/8"5M pipe ram LI- (1) F(1)13-5/8"5M annular (1)13-5/8"5M pipe ram Intermediate 7 5/8 4,823 2,844 3,000 9.6 (1)13 5/8"5M blind ram 250/3,000 ' (1)13-5/8"5M drilling spool with 3-1/8"5M outlets (1)13-5/8"5M pipe ram (1)13-5/8"5M annular (1)13-5/8"5M pipe ram Production 4 1/2 4,823 2,844 3,000 9.6 (1)13 5/8"5M blind ram 250/3,000 (1)13-5/8"5M drilling spool with 3-1/8"5M outlets (1)13-5/8"5M pipe ram Blowout Preventers The blowout preventer stack will consist of a 13-5/8"x 5000 psi annular preventer,a 13-5/8"x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8"x 5000 psi drilling spool(mud cross)with 3-1/8"x 5000 psi outlets,and a 13-5/8"x 5000 psi single pipe ram. The choke manifold will be rated 3-1/8"x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster,and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the driller's console. 4.11.1. Function Testing Function Regularly. 4/4/2011 CONFIDENTIAL MATERIAL Page 12 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.11.2. Pressure Testing The Marathon Drilling Supervisor will verify all pressure tests of BOP's, surface lines, seals, casings and FIT or LOT tests. All tests are to be recorded on the IADC and daily drilling reports. Best Practices: 1 Comments: 4.12 Wellhead Equipment Summary Component Description Casing Hanger Type 10 3/4"x 7 5/8"Fluted Casing Head 11"3M X 10-3/4"Slip Loc W/2,2"LPO,Landing Base for 20"Conductor,U,AA,PSL1,PR1 / Mandrel Tubing Head 11"11.M Studded Bottom X 11"(5M FIg Top,W/2,2-1/16"5M Studded Outlets,U,AA,PSL1,PR1 10 3/4"x 4 1/2"Mandrel Adapter Flange 117 5M X 4-1/16"5M W/Seal Pocket and 3"H BPV Threads Best Practices: 1 Comments: Use a drilling spacer spool on the 10-3/4"casing head to allow for a B-Section contingency. 4.13 Directional Program Summary Build Turn Coordinates Sec. MD TVD Rate Rate Dogleg Inclination Azimuth +N/-S +E/-W VS No. Description (ft) (ft) (°/100') (°/100') (°/100') (deg) (deg) (ft) (ft) (ft) 1 Tie On 0 0 0 0 0 0 226.00 0 0 0 2 KOP 400 400 0 0 0 0 226.00 0 0 0 3 Build up Section 5.00 0 5.00 226.00 4 End of Build 1,685.42 1,432.31 5.00 0 5.00 64.271 226.00 -450.46 -466.46 646.63 5 Hold Section 0 0 0 64.271 226.00 6 End of Hold 4,000 2,437.10 0 0 0 64.271 226.00 -1,898.89 -1,966.36 2,725.86 7 Turn Section 0 -2.78 2.5 64.271 8 End of Turn 4,328.79 2,580.08 0 -2.78 2.5 64.270 216.87 -2,120.62 -2,162.10 3,021.62 9 Hold Section 0 0 0 64.270 216.87 10 End of Hold 6,861.9 3,679.78 0 0 0 64.270 216.87 -3,946.09 -3,531.39 5,295.49 11 Turn Section 0 2.78 2.5 64.270 12 End Of Turn 7,028.60 3,752.18 0 2.78 2.5 64.271 221.50 -4,062.44 -3,626.24 5,445.46 13 Hold Section 0 0 0 64.271 221.50 14 End of Hold 7,280.00 3,861.32 0 0 0 64.271 221.50 -4,232.07 -3,776.30 5,671.93 15 Drop Section -2.50 0 2.50 221.50 16 End of Drop 9,850.84 5,925.93 -2.50 0 2.50 0 221.50 -5,203.40 -4,635.66 6,968.84 17 TD 11,793.91 7,869.00 0 0 0 0.00 221.50 -5,203.40 -4,635.66 6,968.84 4/4/2011 CONFIDENTIAL MATERIAL Page 13 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit Comments: Vertical section calculated from a reference azimuth of 221.70°taken from surface location to bottom hole location. Potential Well Interference: Well Distance(ft)C-C Min Ell Sep Depth(MD) Susan Dionne 1 104' 93' 1,430' Susan Dionne 5 276' 65' 4,500' Susan Dionne 6 59' 59' 25' Continuous survey monitoring and anti-collision calculations will take place to avoid interference mainly with Susan Dionne#5.The wellbore will need to be drilled very close to the plan to avoid interference. See attached directional plan and anti-collision analysis for more details. Best Practices: 1 o — 0 111111111111 1000— . . 10 3/4^ 1 2000— ' - -- --_- - �� -- -_-. — - II -1500 -_-__ U . 83000 _ u) - v 7 5/8 o 4000 - 9 Z __ IIIIIII 0 - SD7UT1BCoal TO 5000 — ?-3000 11111 _ foFr 2 6000 # —— 1 -4500 SD ma Coal 7000 SD 7 T81 Coal SD 7 781 Coal W mi.. = • 4 112" 8000 — , SD7 T135 Coal BottomSD 7 T135 Coal Bottom Hole _.. 'Hole ..- I 11111111 1111 ` 1111 iiiiliiii ` iiiiittil ' lit -6000 0 1000 2000 3000 4000 5000 6000 7000 -6000 -4500 -3000 -1500 0 Vertical Section at 221.700°(2500 ft/in) West(-)/East(+) Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 14 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.14 Directional Surveying Summary Other Survey Interval MD(ft) MWD Survey Magnetic Multishot Gyro Multishot Remarks Tool Surface 0—1,685' X Intermediate 1,685'—7,029' X Production 7,029'—11,794' X Best Practices: 1 Comments: 4.15 Drilling Fluid Program Summary Interval—TVD Minimum Inventory From To Density Gel (ft) (ft) (lb/gal) Fluid Description Additives Viscosifier Barite Gel,Gelex,Soda Ash,Caustic, Barite,Polypac 0 1,432 8.6—9.4 Gel/Gelex Spud Mud Supreme UL Flo-Vis,PolyPac UL,KCI,SafeCarb 10&40, 1,432 3,752 8.9—9.6 3%Flo-Pro w/Safecarb Asphasol Supreme,Lubetex,Caustic,Conqor 404,Sodium Meta Bisulfate,Klagard Flo-Vis,DualFlo,KCI,Greencide 25G,SafeCarb 3,752 7,869 9.0'—9.8 3%Flo-Pro w/Safecarb 10,KlaGard,Barite,Caustic,Conqor 404, SafeScav NA,Lubetex,Asphasol Supreme Best Practices: 1 Comments: 4.16 Drilling Fluid Specifications Interval—ND LSRV Drill From To Density Vis 1 min PV YP Fluid Loss Solids (ft) (ft) (lb/gal) (sec/qt) (Ib./100ft2) (cP) (lb/100 ft2) (cc) _ pH (%) 0 1,432 8.6—9.4 45-100 N/A 15-24 25-35 NC—12 +/-9.5 <6 1,432 3,752 8.9—9.6 40,000 10-16 12-18 5-7 +/-9.5 <6 3,752 7,869 9.0—9.8 40,000 10-16 12-18 4-6 +/-9.5 <6 Best Practices: 1 As a standard practice for tie-back string completions, displace the drilling mud above top of liner with brine treated with corrosion inhibitor(Congor 303A)at a concentration of 1 drum per 100 barrels of fluid. Comments: See mud prognosis for details. Sized CaCO3(SafeCarb)will be used to control leakoff. 4/4/2011 CONFIDENTIAL MATERIAL Page 15 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.17 Solids Control Equipment o 0 Q) U 4) N (m6 @ (7) C cu _7 N N N U _ m m p - - o L U7 N ' U) 7 5 Q) Interval 0 U 0 U N Comments 0—11,794'MD X X X X Closed Loop System, Full Containment, Run shakers with finest screens possible Equipment Specifications Item (quantity,design type,brand,model,flow capacity,etc) Shaker 2—Swaco Mongoose PT Desander N/A Desilter 1 —Derrick Model 0522 Mud Cleaner N/A Centrifuge 1—MI/Swaco units Cuttings Dryer N/A Cuttings Injection Marathon G&l Facility Zero Discharge N/A Best Practices: 1 Have vacuum trucks pull fluids from trough above slop pit to more efficiently pull fluids for disposal. This minimizes water added to the solids to suspend for pickup by the trucks, thus minimizing total volume to be disposed of. Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 16 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.18 Cement Program Summary Depth Gauge Top of Cement Gauge Ann Vol Slurry Casing Hole - Ann Vol With OH Density Open Hole Thickening Size MD TVD Size MD ND To TOC Excess Lead/Tail Excess Time (in) (ft) (ft) (in) (ft) (ft) (ft3) (ft3) (PP9) (%) (hrs) 20 117 117 Driven p/Pc 10 3/4 1,685 1,432 13 1/2 0 0 677 /1110 12.0 75 " 3:55 7 5/8 7,029 3,752 9 7/8 1185 1125 1260 720 12.5/15.8 40 / 3:51 41/2 11,794 7,869 63/4 6,829 3,665 688 885, 10.5 30 7 5:00 Mix Water Compressive Casing Slurry TOC Strength Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (lb/gal) OT ////(M ) (ft3/sx) (ft3) (ft) (gal/sx) Type (cc) (%) 8 hr 24 hr 10 3/4 Tail Type I Cement 12.0 2.32 1155 0 9.52 Fresh 600 0 1565 Lead Class"G" 12.5 574 2.47 1418 1,185 13.78 Fresh 500 0 993 7 5/8 Tail Class"G" 15.8 27� 1.17 323 6,029 4.97 Fresh 40 0 3223 4 1/2 Tail Class"G" 10.5 301' 2.98 885 6,829 12.31 Fresh 50 0 747 Best Practices: 1 Pump several fluid calipers at TD to help with the hole volume determination from the open hole caliper log. Comments: See cement prognosis for details and spacer specifications. Actual cement volume on production hole will be based on caliper data and cement ECD calculations. 4.19 Bit Summary Interval—MD Type Recommended Estimated Expected From To Size WOB Rotating Minimum ROP (ft) (ft) (in) Manufacturer Model No. IADC (kips) RPM Hours (ft/hr) 0 1,685 13 1/2 Christensen MXL-1 117 20—50 80—300 1,685 7,029 9 7/8 Christensen HCD504ZX M123 Up to 28 Motor 7,029 11,794 6 3/4 Christensen DP 505X M223 Up to 20 Motor Best Practices: 1 Comments: See bit prognosis for additional information. Back up bits for the 9 7/8"hole section will consist of a PDC bit. Back up bits for the 6 3/4"hole section will consist of 6 3/4"TCI tricone bits. 4/4/2011 CONFIDENTIAL MATERIAL Page 17 of 18 Susan Dionne 7 Marathon Oil Company Drilling Program Alaska Business Unit 4.20 Hydraulics Summary Max Press @ Displacement @ Max Rate @ Liner ID Stroke 90%WP 95%Vol.eff 95%Vol.eff Hole Sections Used Qty Make Model (in) (in) (psi) (gal/stroke) (spm/gpm) On 5 8 2,597 2.04 125/255 Surface 3 National Oil Well A600PT 5 8 2,597 2.04 125/255 Intermediate 5 8 2,597 2.04 125/255 Production Est. Hole Pump Standpipe Openhole Nozzle AP at Depth-MD Size Rate Pressure Min AV MW ECD Size bit (ft) (in) (gpm) (psi) (fpm) (ppg) (ppg) (32"s) (psi) Remarks(Drill string configuration) 3—18's 0—1,685 13 1/2 625 1,902 97 9.4 385 MI Virtual Hydraulics @ 1,685'MD 7--_ 1 -16 1,685—7,029 9 7/8 550 2,436 185 9.6) 10.47 6—12's 616 MI Virtual Hydraulics @ 7,029'MD 7,029—11,794 6 3/4 269 1,766 214 9.6 11.15 6—11's 303 MI Virtual Hydraulics @ 11,794'MD Best Practices: 1 Comments: See mud program (Virtual Hydraulics)for additional information. 4.21 Formation Integrity Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests(LOT)are to be conducted as described below: 1. Drill 20'to 25'of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer,and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Best Practices: 1 Comments: 4/4/2011 CONFIDENTIAL MATERIAL Page 18 of 18 Marathon Oil Well Susan Dionne 7 Diverter Flow line 21 1/4"2M Diverter — 16"Automatic Knife Valve Diverter Spool II\IllllIU 16" Diverter Line Marathon Oil Susan Dionne 7 BOP Stack Flow Nipple MIliffli 13 5/8" 5M Annular Preventer IIIIIIV mmi 13 5/8" 5M Double Ram Preventer Pipe Ram 2 1/16° 5M Blind Ram Check Valve 2 1/16" 5M Manually 3 1/8" 5M Manually Operated Valves Operated Valve ---- X —1-- X -�'I Kill - Choke Ii—_ ©]I' X 13 5/8" 5M Cross } K 3 1/8" 5M Hydraulically Pipe Ram Operated Valve 13 5/8" 5M Single Ram Preventer > < Bottom of Single gate must be 4 24-45" from ground level for Glacier 1 rig placement. 13 5/8" 5M x 13 5/8" 5M Drilling Spool N\ I 11" 5M x 13 5/8" 5M DSA Marathon Oil Well Susan Dionne 7 Choke Manifold 7 To Gas Buster To Blooey Line Bleed off Line to - II II _ ark u TN 411) Tip;win, i .. . l, /l 1„1 I II 000 000 8 0,8 8 II iI I' iI ( ii Il JI I I Il II I t l I I 1 i I I I < < MEIN 0 © I1 'I i I i I I 0 0 MEMu II. TilK• 11 g © ii', i 7 [ ;] I 3"5M Valves T 1 I 2 9/16" 10M Swaco 3 1/8" 5M Manually Hydraulically Operated Adjustable Choke Choke Gauge Block e l l l l Choke Hose to HCR L (from BOP Stack) 0-6,000 psi Choke Control Pressure Gauge Pressure Sensor Z o� zJ a a°- as x J O ?O g V 2 K.-. Qw a h WI- Y/-• t tt X O IX-I 0.p N - 6 MF s O L E ,, X W a WW 6 m dQ .-a -)7a N 0 I» CI''D F. a O> LE,,, 0 d 0(3 F SJ Z Li l- �:' /MN IWO [al i0] ., d •fc 1 ■I 1 1. a ril a ia _ s ti ■i"u' J ���__ ., - t*HOCI — �Xl11il1 ..c 1: E PI:"....7111 JgI I 11[ ,.11 i O 0. . s E aa4 ^ i+ Ai — ;/"If NAMIIIIMINNI/111* C II ca a X:..., ,7:5",,,--....•7•111.11121 11 u h p a 'T' T111111 C. r J_ . iix n c LI! n so 0 x 'Us_ s 3 x i' 4.. _ tel SI a Q - a c NI 7..-. .•_-::=... =7 I v, ,... ,,,.„,,,,I.111o D U o � re �•�a �� — _ o I 1 O , - _ _. C., — — C/ -- „„-------j.,..----� GESS 4yOp0 — / pG N \ \ /z ' /���` SD NO. 7AS-BUILT \;976 2/ / \ \, NAD27 ASP ZONE 4 / ` 2-1Y1”BRASS CAP N 24^CMP L N:2236847.5 E 2114462 24462.00779 77 ,4°."\:>C14(..... i �E:213338.03 I --mil ,, LATITUDE: 60°06'48.899"N__ / / LONGITUDE: 151°34'17.183"W ��� / //if// ELEV. 141.63' NGVD29 J j �� /� / 1105' FEL /k \2.- //1"-9./S4 � // / 368' FSL ‘,.. // / ,r, mow•„-, ._____. / „, /� / 1105' FEL I I y r N I BUSHES "/ / / / EXISTING CSP SD-6 o� / I /�12^x 80.7 N=2236792.85 / Z -� / / E=213314.73 ®i / ELEV=141.66 L\T � CO ` SUSAN DIONNE PAD I EXISTING CSP / SECTION 6 T1 S R13W S.M.,AK SD-2 12^x60.2' PORTION OF GOV'TLOT2 / ELEV=138.54' PARCEL 2 KPB RES.99-25 N 2236706.324 © / E 213021.899 EXISTING SUSAN DIONNE PAD / CONITROL '05/. BUILDING RI / .J' QUONSET 0 SD-3 ® WATER WELL / ELEV=139.21' :Aye C//:=./ CONNEX NN 21297'7.81 '-` COMMUNICATIONS TOWER / I BOLLARD(TYPICAL) f Z ELECTR OAL OSD-1 SLEV=139.31' 0 ELEV=139.59' 0 BUILDING ON SKIDS /a¢, I N 2236631213177.451 10.0 x14.0 N 2238832.185 50,4 Std E .148 � / 4:$\ _ VALVE CONCRETE PAD FOR E 212950.360 ELEV=138.61' • t1"I• 15. I �.1 BUILDING COMPRESSOR BUILDING N 2236587.519 E 213102.356 - FIRODUCTION m ® I 777:17,10_, I N 2236453 004 ® (BUILDING Ie.s� E 214434.704 /// •151' 37.9' J} 67E' 'CAUTION" GLO 0104 I° . • LR'OREU P55 T1SR13W _ IOOs1C6 ELEV.=139,33. — 22." — UNDERGROUND P SEr'NL0.-o E.n.PL. SS7S8 Ple�e r I 919 / 8 8 N 223115.872 54.7.285 E 21311 33'SECTION LINE EASEMENT --__y FLEV.135.73'•^ SECTION 6 1 SECTION 7 ..- N. 4725-S _ E 11/16 33'SECTION LINE EASEMENT T - - AURORA COMMUNICATIONS PROPERTY BUTLER PROPERTY -- 1987 ``.NN��X%111 1.BASIS OF HORIZONTAL COORDINATES AND ELEVATIONS IS K V SD NO. 7 AS-STAKED ,,+" NAD83 ASP ZONE 4 1976 / AP � `' CMV N:2236599.18 N2237524.389 EA 354488.872 1'1// F // ,. E:1353364.96 / / •• • M • • • INN••• ••••••• ••00 / / j / •• • • •• • • • INN••••• •••N• • /// ELEV. 141.34' NGVD29 I / / / 1105' FEL _ :z /1 // / 368' FSL // �4/ •� 1105' FEL ° 4)P / 1 WARES r / SD-6 �\ G= / EXISTING CSP N=2236544.55®-� o 1rx80.7 E=1353341.52 (!� -"' ELEV=141.66 ®LLQ,, . /M 4"'. '• 6 T1S R13W S.M.,AK 50-2 EXISTING CSP POR y`41 N OF GOVT LOT 2 W2236458.02 .... 12 x60.2' 2. PARCEL 2 KPB RES.99-25 E=135304869 •� ELEV-,138.54',0 EXISTING SUSAN DIONNE PAD • ® CONTROL QUONSET • 5D-3 ® WATER WELL. BUILDING . N=2236429.51 .../. • ZCONNEX • E=1353005.49 SD-5 COMMUNICATIONS TOWER ti°' ELEV=139.21' N=2236383.15 BOLLARD(TYPICAL) 1 .E=1353203.94 •SD-1 •ELEV=139.59' ELECTRICAL p N=2236383.89 Bu4DINc ON SKIDS /aQ E=1352977.16SD-4 �Y� 144.4.0 I VALVE CONCRETE PAO FOR F ELEV=139.31' N=223633922 ti'? 15 `" '-"Z4.':;;,•,:, " 6.• fir BUILDING COAR'RESSOR BUILDING E=1353129.15 QOM I ELEV=138.61'• FIR.ODUCTION � ";;• L; !,j1 cn nn BWLDING II,5' I0-,,,: + N 2236204.704 ® D104 ,.71 7_, env E 1354461.499 "----- ----- _ _ „CAUTION' • GLO N=2236281.91 ,cN PRESSURE • MRN-GAT/ — —40, -�,_ E=1353775.65 226, UNDERGROUND • Ti 5 R13W • IS ELEV:139.33'_ _ "^fll.� LERAL GAGKn.L. S 58 . .. . .... . . . . . . . . . . . . • E1/18 . . . . . . . . . 1919 1 — / N=2236235.98 ..4,4,, \. E=1353142.67 33'SECTION LINE EASEMENT • ELEV.135.73' SECTION 6 SECTION 7 ' 4725-S •• E 1/16 33'SECTION LINE EASEMENT ' ' BUTLER PROPERTY AURORA COMMUNICATIONS PROPERTY 1987 /BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003) ,,,,S1/4`4.1,1,1110 CORS ARP",IS AN OPUS STS A CORS ARPOLUTION FROM",ANDGS OZANIINATES WAAS 1 CORSONS"KEN5 ARP"TO G i.�P�E OF qs ,, ESTABLISH THE POSITION OF"DIO 3"ON SUSAN DIONNE PAD.THE . �� GEODETIC POSITION OF DIO 3 WAS DETERMINED TO HAVE A " �g�1' � * i AO THE ALASKA STATE PLANE COORDINATES(ASP)ZONE 4•ARE •••• .�... i Fc, STAN A. MCLANE.• .. N=2236337.935 E=1352842.572 ELEV. 139.79'(NGVD29) rj "a›'' 4637—S BASIS OF VERTICAL CONTROL IS NGS BM V82 PID TT0586 LOCATED li it " 8,T...�iq. AT MILEPOST 127.6 OF THE STERLING HIGHWAY HAVING AN SCALE 11s ow```�� ELEVATION OF 283.59 FEET NDVD29 ACCORDING TO NGS 0 100 200 \PUBLISHED DATA. I FEET 1 M AR pTI-IO' PROJECT REVISION' 0 DATE 12/21/10 OIL COMPANY SD NO. 7 ON SUSAN DIONNE PAD NINILCHIK I DRAWN BY. BOB — I.0.RA1HON ALASKA RBCiHD�i AS-STAKED SURFACE LOCATION DIAGRAM SCALE 1'=100' PROJECT NO. 103121 ENGINEERING/MAPPING/SURVEYING/TESTING ----- ----- ----- ____.,,. BOOK NO. 10-23 CCon uLting Inc P.O.BOX 488 SOLDOTNA,AK.99669 LOCATION McL_4NE VOICE:(907)283-4218 FAX(907)283.3285 SEC. 6 T1S R13W SHEET EMAIL:SAMCLANE@MCLANECG.COM SEWARD MERIDIAN, ALASKA 1 OF 1 SD-3 SD-3 1 2 i NINILCHIK UNIT Ni ,LcFI,, I I[ DIONNE-PAXTON P.A. 1S-14W 1S-13W a 4y PAXTON 3 1 'ONEK TI TR 10 ...._ / 6513'MD/3588'TVD ' SD-4 ADL 359242 TYONEK '-i SUSAN DIONNE 7 WELL 6767'MD/3653'TVD 3000'NOTIFICATION RADIUSfro , K Tl 2,1 SD 5687' D/3608'TVD / 1 PAXTON 4 / A I TYONEK _= YONEK Tl 11 ' PAXTON 1 6659'MD/3598'TVD 5270'MD/3669'TVD 12 TR 30 D-5 ,J C-061505 7 TVONEK TI 5277'MD/3645'T D v oo y a4 TR1 1 TR 8 F i ADL 384372 " �\ �' i \ •-•\ OPTYONEK '� EST.6720'M D TR 8 3C20'TVD ' 153 PAXTON 2 ADL 384372 . 111 11111111°41,4111,4. 4T1 R 162 ; . ID TR 21 1 1.7)4'1 S Univ of 7869" Alaska „■ ..- '\ --ii pr '"{ '1 TR8 TR31 11. R31 C-060385 ADL 384372 C-060385 JSlk _ 14 TR 163 ,, 82 ,ILAL OM, MEI 180 Ar _kr Arc ANN ®� a,..f.k-oV TR 174 NinilchUnit Bodary / 7 - Dionne-Paxton P.A. 1 Notificationik RadiusunO 1S-14W 1S-13W Marathon Alaska Production LLC i Ninilchik Unit-Dionne/Paxton P.A. 1:12000 0 0.50 Susan Dionne#7-Location Exception nu iae _ I I I I Exhibit"A" or °"" MILES Tract Ownership Listed on Exhibit"B" NAD27/Alaska on 4(EPSG 26734) February 2011 QO Transverse Mercator �a.GJ -O Clarke 1866 spheroid Natural origin[150 00 00W,54 00 00N] L VC MARATHON Oil Company BAKER Location: Cook Inlet,Alaska(Kenai Peninsula) Slot: SD#7 N1uh MARATHON Field: Ninilchik Field(NAD83) Well: Susan Dionne#7 ES Facility: Susan Dionne Wellbore. Susan Dionne#7 Plot reference wellpath is Susan Dionne#7 Version#7 True vertical depths are referenced to Glacier#1 (RKB) Grid System: NAD83/TM Alaska SP,Zone 4(5004), US feet Measured depths are referenced to Glacier#1 (RKB) North Reference:True north Glacier#1 (RKB)to Mean Sea Level: 162 feet Scale:True distance Mean Sea Level to Mud line(At Slot:SD#7):0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by:jonethoh on 13-Feb-11 Location Information Facility Name _ Grid East(US ft) Grid North(US ft) Latitude Longitude Susan Dionne 1354461.500 2236204.700 60°06'43.062"N 151°34'03.175"W Slot Local N(ft) Local E(ft) _ Grid East(US ft) Grid North(US ft) Latitude Longitude SD#7 368.34 -1105.73 1353364.830 2236599.160 60°06'46.689"N 151°34'24.993"W Glacier#1 (RKB)to Mud line(At Slot:SD#7) 162ft Mean Sea Level to Mud line(At Slot:SD#7) Oft Glacier#1 (RKB)to Mean Sea Level 162ft Targets Name MD(ft) TVD(ft) Local N(ft) Local E(ft) Grid East(US ft) Grid North(US ft) Latitude Longitude SD#7 UT1B Coal(NAD83)19-Nov-10 7228.60 3839.00 -4197.38 -3745.62 1349520.36 2232492.19 60°06'05.345"N 151035'38.875"W SD#7 T81 Coal(NAD83)19-Nov-10 6842.00 -5187.74 -4626.25 1348616.41 2231523.09 60005'55.588"N 151°35'56.238"W SD#7 T135 Coal(NAD83)Revised 05-Jan-11 7869.00 -5209.21 -4645.74 1348596.41 2231502.09 60005'55.377"N 151°35'56.622"W Well Profile Data Design Comment MD(ft) Inc(0) Az(0) TVD(ft) Local N(ft) Local E(ft) DLS(°/100ft) VS(ft) Est RKB:162' 0.00 0.000 226.000 0.00 0.00 0.00 0.00 0.00 KOP 400.00 0.000 226.000 400.00 0.00 0.00 0.00 0.00 End of Build/Csg Pt 1685.42 64.271 226.000 1432.31 -450.46 -466.46 5.00 646.63 Begin Left Turn 4000.00 64.271 226.000 2437.10 -1898.89 -1966.36 0.00 2725.86 End of Turn 4328.79 64.270 216.874 2580.08 -2120.62 -2162.10 2.50 3021.62 Begin Right Turn 6861.90 64.270 216.874 3679.78 -3946.09 -3531.39 0.00 5295.49 End of Turn/Csg Pt 7028.60 64.271 221.500 3752.18 -4062.44 -3626.24 2.50 5445.46 UT1B Coal 7228.60 64.271 221.500 3839.00 -4197.38 -3745.62 0.00 5625.63 Begin Angle Drop 7280.00 64.271 221.500 3861.32 -4232.07 -3776.30 0.00 5671.93 End of Drop 9850.84 0.000 221.500 5925.93 -5203.40 -4635.66 2.50 6968.84 T81 Coal Horizon 10766.91 0.000 221.500 6842.00 -5203.40 -4635.66 0.00 6968.84 T135 Coal Horizon 11793.91 0.000 221.500 7869.00 -5203.40 -4635.66 0.00 6968.84 Hole and Casing Sections Start End Start End Start Start End End Name MD(ft) MD(ft) Interval(ft) TVD(ft) TVD(ft) Local N(ft) Local E(ft) Local N(ft) Local E(ft) Wellbore 13 1/2"Open Hole 0.00 1685.42 1685.42 0.00 1432.31 0.00 0.00 -450.46 -466.46 Susan Dionne#7 10 3/4"Casing Surface 0.00 1685.42 1685.42 0.00 1432.31 0.00 0.00 -450.46 -466.46 Susan Dionne#7 9 7/8"Open Hole 1685.42 7028.68 5343.26 1432.31 3752.21 -450.46 -466.46 -4062.50 -3626.28 Susan Dionne#7 7 3/4"Casing Intermediate 0.00 7028.68 7028.68 0.00 3752.21 0.00 0.00 -4062.50 -3626.28 Susan Dionne#7 6 3/4"Open Hole 7028.68 11793.91 4765.23 3752.21 7869.00 -4062.50 -3626.28 -5203.40 -4635.66 Susan Dionne#7 4 1/2"Casing Production 0.00 11793.91 11793.91 0.00 7869.00 0.00 0.00 -5203.40 -4635.66 Susan Dionne#7 Bottom Hole Location MD(ft) Inc(0) Az(0) TVD(ft) Local N(ft) Local E(ft) Grid East(US ft) Grid North(US ft) Latitude Longitude 11793.91 0.000 221.500 7869.00 -5203.40 -4635.66 1348606.62 2231507.66 60005'55.434"N 151°35'56.424"W 1111 IX ti — 111 ill rer- Ts 0e, en '" LILzmi, 11 illi l NEo NuOO wMoul2 C cu C V V as OM M c.i o °C6 w w �: o o OOON 0 g.... 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Y #F f11 �1 So , 41111 .� IIII1�111Iil11111111i11�i�l I11 III 1 111 Id111°1�i� III I - III IM Ij�ti� ,p I 1111E _ . .�� 11111IP1il11iIr1111 = = •- 1 ARATHON w1111111 ell: Susan Dionne #7 ,11 11 11, 11 11 ,111 Prepared by: Jim Dwyer Senior Project Engineer M-I SWACO Reviewed by: Hal Martens M-I SWACO Presented to: Rowland Lawson Drilling Engineer Marathon - 4 4 I il 11;1`1111 11111 111 I 1V 1I11,Irpy 111 IIY- x�-' ' Y111i111yi11111i11111�11i11111F1 uYiIII11111i i11i1111Iii1111-1N111I1111hI1h11I11I111111111fi4 1111111III1I1111111IIi1dllllllll III�IIh111111PII�11IIII�haIIW1=VIIII�p111111i114111j1i 111111111 a 4111IIhI11II11 is 14p11111 , I111111 1I 111111111 I 1111111 { �La1IIIlIli11I1111111111iIj1i111j1111111111111111111IIIi111111j1��11r1111111i�1i1i111111jI1I11111 r 'kWt- 1�Iy�111111I°i1111IIIII1111111111111Iilllllll II11111111�I111�p111i11u1 II 1 0iii'1111111tl{ih11111111111111111111I 111111 h l4 1 1f` VIII Ii "I IiY II1I111y�r+a`1IIII'IIII yr . r 1 111,III111 u1111r _ {Il,r,$,IPmow' kr 11,1,1,11 I,1.11.'1 __,_''',,..11,,,,,,4,1'„^,'Y,11'III 01''1�1II lil S 4 Tis ' III 11+1, a a iC. '- I :11,4,41,1,710,1'11 "r1ti " l , 111 ' ilili 3 ti11i - TN11111 ,i`,01l,m1,1h11II,I'I IullilP11t1hl11 II ,, 11 11111'1111111Iollhll'1IIhI ph I I4, 'II I� Vh �' , 1I " 1�0'� Ii14101 ' 111�1uVo-z - -11=----i1104+,+,101', Marathon Oil Company PO Box 190168 ' R 0,, 111'1' 1' ll 1 F, Anchorage,Alaska 99519 '�1I1,1111111111111,111III111,11h 111,11lIH11,0 1,1 I„� 1�li11111i 1,111111111111101,111 1 111'11i�1 '�,1�1111111111,111,1,111 11111111„11',1,1 p1IIlII1111111jyI0111,1111111 1111 1�I1I 1� ATTN: Rowland Lawson i1 1 11 111''hti1,1;1lllp!;Id11I1111;1'111h11'lli'11'11II11I q t11 111111 111111j1 IIIA Ilalrt� �, 1111111. 11 ' 11�11 I' 1111I1111111jI 1111111 1111I111I111Il 11 °X11,'11 1 11, Rowland: a V�1ll 11x1 1 s�11I'111I'�1�I, ” "1 Enclosed is the drilling fluid program for the Susan Dionne#7 Well. The following is a brief synopsis of the program. Overview: SD #7 is a development well targeting the Tyonek T135 Coal at.the Susan Dionne field. A Gel/Gelex spud mud is recommended for the surface interval. Flo-Pro fluids will be used for the intermediate 'i: and production intervals. After logging the production interval, the well will be completed with 4- 1/2"liner cemented in place. Surface Interval: A standard fresh water Gel/Gelex spud mud will be used. Initial funnel viscosity should be in the 50 —75 sec/qt range. Lower funnel viscosity to 45 — 60 sec/qt after gravel has been drilled. Lower fluid loss to 10 - 12 cc's API prior to running surface casing. Lubricant should be added early as a preventative measure with a minimum of 3% LoTorq. p' Intermediate and Production Intervals: These intervals will be drilled with a 3% KCL Flo-Pro mud system. New fluid will be used after drilling out surface casing. Fluid loss should be maintained @ 4 - 6 cc's API for this interval. Lubricant should be added early as a preventative measure with a minimum of 3% LoTorq. Completion: The completion will consist of a 4-1/2"liner cemented in place. Corrosion control(Conqor 303) will be added to the 3%KC1 brine. S IS 11,,1ii1I I11I�111 1111''1l1 r,r1,,,,',,,',,?,,,,--iui Jim Dwyer ,`°',,,,1111+11M 1'1I11INII11 1,,,,,�1111,��,1, Il�> s„,_-,, ,, ,I', 1,,1 10111'1111'11111111 pr�11'1�1,11 ' 1 r111a1 Project Engineer/M-I SWACO } rq 7111 1111 1 111111'111''a I'q - 11 1'I I1�1� ,- Reference Wells: Susan Dionne 3,4, 5,6 ;,;'aiH1'{4la ; '-'',4,.,Y NOTE: This program is provided as a guide only. Well conditions will always dictate fluid properties r�9equired + 1Ilr,h114hIh171'111II,,,,111I1111,1111 1,1060rr-„ ' 11111111 1„ 1 k,3ary IIIE f ,1 9{11111,11,11111;11,; 11101!1 j0,th11',11 §til — _ Il{ ,,,,,,!I,IIpVhM1111111119PI111;P4M'11y'yli11dI1�6111141114gIm11V,Wk II I. , s # .fr �y - para 4Y9{d� �ri� i'''';.-1.1.i., ..7-,--_-;=._.71.11,41,1'1 1 I1IlIt or �i x €�rri111 IIIu� V yfi6 11,,01I11N,,;1111 ,'.':',,,..—:* s - I' 1lk ,,t' 1 €1I ,V S1Iw01,,II F � iiiO1141411rdr M Skt � �� s 177 "pia 4 ? 1 IIIR Y� a - - 111 1 I 111,1'S'"14 h10111 j11111 I II 1�1m I I IIII �11 �I I --.-17011!11111111 II � j � 1111h 1111111II11111�II11 f i I�W111 z VIII 11111111111111111 �` I IIII I IIII IIII 11111111111 II I1 II111�II1�11111111 V i111II I�'y1111111111111111111 1111I1��h1IIIII IIII11111}1,III,IIIIIIIII1,11lill IiIIIIhIIIIiIhIiIIII�IIIIiIIiIIiIIhIIIIvIIIlhIl11�11 Irll��llllY IVIIIhIuI^III1,111hIo EXECUTIVE SUMMARY SOur goal is zero spills and zero incidents and 100% VE compliance while providing fluids and solids control1,111 services to Marathon Oil Company. I Mi SWACD9 The centrifuge will continue to assist in removal of LGS for minimizing mud weight and dumping and dilution of fluids. Dump and diluting will be minimized with use of onsite centrifuge. MiSWACO We expect to drill this well for a product cost of less than $28.00 per foot without any hole problems or severe losses to formation. A.°! We estimate the use of less than 6300 barrels to drill this well, not withstanding any losses to the formation. 11,g111111111f11 11111 I I N111111 Illlp 1IIh11111111111 111 111P1 III Ii~91 II111111111111 Irl? a' 1 111�111111411j1111111,1, 1110111�1111I II11111111111111111 H11�11111�1�1 11, VIII 1IIlI1110111111 1 1 1 1i. 0 k 111111119 _ s titlI�IIIII+,lHy1+111141,1IS11IgrlNl1�411�Iw"I I(IIII I11t1111111o11�1p1� !h9+11 1�fIV11�h111111�1111111�111111111Vill11+1Vi�li� _ 1� V �9��1111 III IIII IIII II 11 I 11 1?ill 11J1* 1111I1111IIi11I1111111111111X1111111111111111111111111111111111411111111�11i1,1,11,1,,1911011,1l1$1111,1,1111,111 11i1111i11h11 11111i1,111$1 11111111 1111+1 F0 ti 111111 1111I11Ii11111Ih011[4111+111111 1,111Vp111IlIf 1i 1i1 1 11,1,11,1„ II as, III 11 II+Ip�1 0 s41 111 111111 1 1 I 1..a �R11oi16111,1�1}11 i,l�llhl ! ,11,111111110,114,1 '•��^. Mi SWACO Section 1 — Objectives / Benchmarks / Goals Goal / Objective Achieve Health, Safety and Environmental Goals Benchmark No Accidents, No harm to people, No damage to environment Performance Days away from work, medical treatments, fluids discharge, spills Measure Goal / Objective No NPT on well Benchmark No NPT due to mud properties out of specification. Performance Daily review of mud properties with mud engineer and project Measure engineer Goal / Objective Minimal losses to formation Benchmark Control and/or minimize seepage losses in under pressured sands. Performance Verify losses per hole section on well with OneTrax Measure Goal / Objective No NPT on well Benchmark No hole cleaning issues upon following the program and/or rig site mud engineers recommendations. Performance Monitor NPT on daily Marathon reports Measure I MiBw c Section 2 Well Design Susan Dionne 7 Casing Hole Casing Depth TVD Mud Mud Weight Cost Sum Size Size Program (MD-SS) (TVD-SS) System (ppg) Days ft ft in in Conductor 100' 1685 1432 GEL SPUD 8.6—9.4 $25,383 5 10.75" 13.5" 7.625" 9.875" 7029 3752 FLOPRO 9.0—9.6 $198,512 8 3%KCL 4.5" 6.75" 11,794 7869 FLOPRO 9.0—9.8 $117,321 8 Liner 3%KCL Cost does include engineering charges ©1995-2010MILL.C. qp„.. MD: Operator: Mi SWAGQ �.,M L« =--� TVD Well Nam VIRTUAL NYDRAULICS' 'irPro' Date:a°'J ate 2!2212011 I CPunp'Y Sd2ha..._ _ Directional Profile Marathon Susan Dionne 7 0 I i 1 �4 1 (411104(00( e (((((( roborr (((((((( 6 (((((((((((((((( 11 1 CI 4 lC 0. ((�i,. 5 i 41 j j mi 1 8 a 0 1 2 3 4 5 6 8 Horizontal Displacement(1000 ftl ,111111 1I IIII I 11111 aifll�liCI,�I,��111 1r I'll II,III �., 1�i1iII III 'IIIlI1�1111'IIIIll11��1111I'Id1I'`1111`lll'IIIII�lIIl1111III�111I11,hh111'�11Pti `` r X11111111 it 1dIlil hull11111111 VIII 11 VIIIIll1,11'�11111111'111111111'111�1111i11I11I1111111 1111 I IIititil11�l Illl 1111111'11,111 hI6I11 IIIII1111i ll l IMII:�1� 6� VII III III II f, 111 ,'IVI-ry'4 - :� tigi 01011111 II1,1'I 1101 1,11, ali1I7lIIII1lII0 V� IJtill1i11IIII I1111I 011 fll, 0 l+ 00-0.0 � I11 a� 00II I - — 11, 1••' ,'Ii FORMATION TOPS Ili11I491u111�a w I1'u111lu1IP111411IV,lI _ !�l'III1l11II,1111 ESTIMATED PORE PRESSURES #u1 1111 Pore Pressure Formation Estimated Tops ( .D) 1 II��, (ppg) VI UT1B Coal 3839' Tyonek T81 Coal 6842' 7.7 -8.8 1 Tyonek T 135 Coal 7869' Section 2 — Well Design "; EMS Mud Cuttings and Mud Target Goals (bbls.) LlI Performance 13.5" OH 9.875" OH 6.75" OH Benchmark Section Section Section Section Length 1685 5344 4765 Cuttings11 l Discharges** 298 506 2111 Mud*** ;" Discharges 1816 1196 205 11 Mud + Cuttings Discharges 2179 1674 410 EMS Mud Cuttings and Mud Target Goals (bbls./ft.) hT. Performance 13.5" OH 9.875" OH 6.75" OH 11, 11 1111I1 Benchmark Section Section Section - 111u�gl,I," �.�1�1'4,111'11111I'll' Section Length 1685 5344 4765 4,,111laa 111111I11,i111,1I1 1 Cuttings Discharges .177 .0947 .0443 Mud Discharges .885 .237 .0443 IIA Mud + 1` Cuttings 1.06 .331 .0886 Discharges ** Gauge hole cuttings j°1 *** Includes mud on cuttings yq 11'1 I IlIIIii 111111111 111 Iilijl'h11h.i4iIh Ihlii 1'11111P 11111 1161,1 III11 11,I11111iIII ' h� �I Ilh tiII ww''/�/� Mi�.�.�� ACO IIII iiIjl ly Hill li ii 1,l tll I'hI IVI li 1111 hill„M, I'�IIIILII u Section 3 — Challenges Potential Problems lt III L AlS _ Discussion / Recommendations yaw . IIII�II'lhlh='ll COMMUNICATION — The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. WHOLE MUD LOSSES TO THE FORMATION - Maintain proper bridging material concentration in the mud system while drilling the intermediate and production intervals 4 FLUID LOSS CONTROL — In the intermediate and production intervals the API fluid will be I�.u: I'I'�;I maintained in the 4 — 6 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum . 11 LSRV — When drilling with a FloPro fluid, the low shear rate rheology should be maintained ti around 30 — 40,000 cps. In addition to adequate additions of FloVis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSRV. DRILL SOLIDS — MBT — The MBT should be kept at less than 5 ppb in the production interval through aggressive use of solids equipment and dilution as needed. MIXING CONDITIONS — Whenever possible all treatments to the mud system should be ade as pre-mix additions. Polymers and KCI should first be mixed in fresh water in that ordermand then blended into the active system over one or two circulations as needed. CORROSION — Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of+/- 2000 PPM. CORROSION - Sodium Meta Bisulfate additions should be made daily as needed with any fluid in the hole. Maintain a DO reading of less than 3 ppm MYACIDE 25G ADDITIONS — Myacide 25G additions should be made daily when drilling in the production interval, in the range of 5 gallons per day. WEIGHTING UP —All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. *4.1„_= u.l ..r...,. r..11lll l.' I,,+a ter.:; j,l i'i'i 1 illllllll��.q,- 1�,�ryIII!IlII111 II ^• ISI,,iIIllllMvif- llll� VIIII Ali II'r°Ilan 111111 ill}, 110111II11 :1 , liilq 'r I�y�� �``klub 14 411 ^1111 17 0 �G1i4c1111 111111 1T �111�' �II���III1114IIhllllll k ,r y911�II�I�I)p 1��111 11p�I�II1111�I�f II�PII�ju111111 4 1 �l A J 111111 11111110--- 1111 I IIS"�,1 k[ 11111'111III MVI 11„11 Section 3 -- Challenges/ Potential Problems 6 01 f�9 Hole Cleaning Recommendations 11111IIIIl1r1� I�i1 11111;1�11�'11111 411���11{�1IIIIIIIhI 1111111111i,111�111111I,11 1111111 - '. u11111111111u111111 11111 111 �a,�Ia11a�1111111 ❑ Low-shear rate viscosity "LSRV" values (6 and 3 rpm) has a greater impact on hole cleaning than yield point, in addition to providing barite suspension under dynamic as well as static conditions. Optimize rheology to increase hole cleaning efficiency of fluid (Adjustment of Yield Point and 6 rpm readings). ❑ Rheology and Hydraulics calculations will be run daily and the mud properties will be adjusted as needed to maximize hole cleaning. ❑ Use the highest possible annular velocity to maintain good hole cleaning. Annular velocity provides the upward impact force necessary for good cuttings transport. ❑ Control drill to manage difficult hole cleaning situations. Penetration rates determine the annular cuttings load. Use the PWD data (if available) to determine when it is necessary to stop drilling 11 and circulate the hole. ❑ Keep cuttings concentration less than 5% (by volume) in order to minimize drilling problems. 00110:0❑ Sweep Recommendations: 111111 • Don't recommend the use of sweeps unless hole conditions dictate the necessity. ❑ Hi- Vis sweeps are recommended to use if needed. The volume should be enough to cover at least 200-300 annular volume of the open hole. The recommended rheology of the sweep 111 would have the Yield Point in the 35-40 range and the 6 RPM readings in the 15-20 range ❑ Weighted sweeps are another option, but Hi-Vis sweeps are preferred. ❑ The need to pump LCM sweeps will be dictated by hole conditions. Bit/BHA Balling Recommendations ❑ The young clay formations can absorb high volumes of water and can be extremely sticky and problematic regardless of the degree of inhibition. ❑ The drilling rate should be controlled to keep the concentration of cuttings in the annulus below 5%. ❑ Short trips should be made as necessary to minimize buildup of cuttings in areas of hole washout. ❑ During trips, the BHA can accumulate cuttings that will potentially ball it. Recommend circulating for a short period to circulate up any formation that may have adhered to the BHA or bit during the trip. I11111111111i111 �5"„w1u111,II11j1111111,1,.1, 11Pg1111�ti11111�1111I111111111'1�y 1 till VONi1 y111111111111y � m�a 411 ^^ IIIIItiIIV Il E` IIIIII4111111111111�1 � �#i 11111111 11111111,,,' _ s{ 111 1111ti�G�4�� i X11I;I�� � Il�d�h i1111,11111�1111,1�1h g111�1'1 1' I11111hk. 111 r -fi,11111,1111111111111111111111111111 111jj1111Y11h 711111111111 h11 SII IP I^ �1� 1i 1111 �� tlIl111,1A{IIIb 1�1r-� ~11111111�ilh1 1 1,11141 J11111 1111111 c_- 1 !,�< �' - - 1111111111111111 1111111ij1 Ili ''�”. ,- a at1 r 1111 h si;1;1��i1�13711i11�1111r1I11 l':.� "11.1 Mi SWACD Section 4 — Lessons Learned & Offset Mud Data Offset well #1: Susan Dionne 6 Depth of Mud Wt. TVD Description of Information concerning the Event or Problem Event/ (ppg) (Feet) Event/ Problem Problem 135'-2031' 8.7 1580 Hole cleaning Gravel below conductor 15'fill after wiper trip.Casing cemented @2031 with full returns 5085" 9.6 3150 Tight hole on Tight hole at 4150"on wiper trip with pumping out of wiper trip hole necessary. 6737' 9.6 4520' Solids buildup Volcanic ash layers caused increased solids and need for dump and dilution. • • Offset well #1: Susan Dionne 5 Depth of ' Mud Wt. TVD Description of Information concerning the Event or Problem Event/ (ppg) (Feet) Event I Problem Problem 120'-802" 8.7 0 Hole cleaning Boulders,tight connections below conductor 15'fill after wiper trip 1630 9.6 1299 Losses Lost circulation after 75 bbls away on surface cement job 4200' 9.6 2726' Sliding problem Difficulty sliding until 3% LoTorq added Offset well #2: Susan Dionne 4 Depth of Mud Wt. TVD Description of Information concerning the Event or Problem Event/ (ppg) (Feet) Event/ Problem Problem 561 8.8 561 Stuck pipe Loose boulder stuck pipe at 200'. 3117 9.2 2100 Tight hole Tight hole on wiper trip @2673' 6116 9.7 3405 Tight Hole Pump out of hole from 4590-4179 ----4 AF ', 44--P4'441,1.4 .-4444 441,1111111111, 4,..44-4-_—=--= -_--- 44.41.6.444:4444444.4.- 4_--444,4,4„414.44g::4 4,4 Me SWACO Offset well #3: Susan Dionne 3 Depth of Mud Wt. TVD Description of Problem Information concerning the Event or Problem Event/ (ppg) (Feet) Problem _ 1875 9.1 Trip for motor 3100 9.3 Build new mud 4190 9.55 Clay issues c‘'l 1-4 Drilling ahead with lotsdoiluftcelamy Wiper trip t....' 4756 9.5 Hit bridge. Dump andreducesolids i--- 5245 9.8 3434' 4,m Wiper trip Hit bridges, raised mud wt to 9u.8d,torurne7d'u' r,„ _,,,1„1,,IiIII,,111111e1„1,1wlin,11,1,31111111111:11111111,11:1i111111:11111:11,1:11,111111,11 „,:„ ..,11 111.1.,„,,,,sii),„1,11,11,1111111111,ILL,A., , -='- _ '!, -1 ',----. - ,I,,,,,,,,,,,-,11.'1, '11,1,1t,kil ,y).0 11,',",'41,p111101111111111111111 y_-, 1111111it1111,h111111,,I,,...41,.:1,,Iii'-i12:-It:,„,....i, , 1.1.11.,-,11,,;-,1,,!,,,z1lr',e'6.4-;&26111111,1111111,11111'11,11.1'.'hillh_l'ILIIII„ l' '111''1'111'11'1'11111 'sr,1,.X,e, _..._. . . ---- . - .„ , ,... . ° ,, 11 11 . , ,. ._ ., ..... \ 1 4.4444 4 4'.11.11,1 , ,,,11111111111111h'141111111!1111111111111,44_4-4,4,4-iq4 111111'111Ill'I'll'1114'H 11'1'11'1114444'41'1,1 ,',,',41,444.7-7:11111 1', 1,4,1 4 1111,1441111114144,..4-44.4,,4,,,,,,,4111 4.,*_, 4st,4441 ill,1 41 4 1 4 114y4141,41.4,'g..41,`,14.54.4444,' �tiyl�'9k4 11 tl.i,a�xa. "va !t 7y r7 th rm0 * k , J ,�_ , ¢ _...II s _4 ys - Section — Surface Interval (0' — ' X85') I i 1 II �111,11114'—,-,1-111 S� iiiql lh1 ,1 Depth Interval 1685' MD (1432' TVD) (13.5" OH, 10.75" Casing) 001 Drilling Fluid System Spud Mud Key Products MI GEL, Gelex, Caustic Solids Control Mongoose shakers, desilter, CD 500 centrifuge lg Potential Problems Hole Cleaning, Hole Stability INTERVAL MUD PROPERTIES 1 10414 . De th Plastic Yield API Fu n l TVD Mud Wt. Viscosity Point Fluid Loss Viscosity IGS (ft) (ppg) (cp) (Ib/100ft2) (ml/30min) (seclgt.) pH °!o 1685 8.6 -9.4 15-24 >30 <18 60 - 100 8.0-9.0 < 6 I D Treat drill water with Soda Ash to reduce hardness. D Build spud mud with 20—25 PPB M-I Gel to +1- 100 sec.qt funnel viscosity. D Lower funnel viscosity to +1-60 after gravel zone has been drilled. D Add Gelex as needed to maintain sufficient viscosity for hole cleaning. D Increase funnel viscosity if fill on connections begins to occur. } I" D Reduce fluid loss with additions of Polypac Supreme UL prior to running surface casing. , 'k' 111 D Add 2 — 5 PPB of MIX II to mud system if seepage losses becomes a problem. D Condition mud prior to cementing casing to reduce yield point and gel strengths. not SWACO a., i k101111111,11111;11,111111.11.11111011,1111111V111111' 0111t1111I111111,1,1111 VIII II Illi 11111111tl 111�1111111I III i�1�11I 1 X11111111 "ut�1 1111 IP lq �1 I!CIIIIIIII,I PiI Ipllllllll "1!1 11,PIP Hydraulics / Hole Cleaning: Virtual Hydraulics Graphs The following graphs look at the ECD + cuttings at 1685' casing shoe and moving cuttings concentration (MCC) in the annulus while drilling the section. VH SNAPSHOT Ns s%J O M ®1995-2010 M4 L.L.C. 625 GPM MD:1685 ft Operator:Marathon 11 S in.Drlliplpe TV D:t432 ft Well Name:S usan Dionne? VIRTUALNYI'RAULICS'Sna p Shot` Bit Keret Peninsula Date:3/10/2011 Country:Alaska Depth Geometry Angle Dstt•Igr PV(cP) Va Hole Clean Presstae Dist nation (ft) MDRVD CsgOD/ID r) ptllith YP,LSYP(Ib'10062) (ft/min) India (%) (Itl lin 0 45 90 9.2 9.8 10.0 10.4 24 28 32 36 0 120 240 VG 0 F P B1t=412 Ann=4.1 DS=54.7 1 f f_ 0[ n 18.00( 14 OW . . i - III --• e 111 40` _ 11 Drilling Riid __ 11I11 Muhtd W e 9 Water-Bas9.4 Mud 111® 1 Test Tem P 120 °F 001 1 _ I _ -._ „ ®I, System Deo Flaw Rate 825 gal/m in F o: 11I11 Penetration Rate 150 NM e0c 4 Rotary Speed 100 rpm c I ■'I,� Nozzles on B 15 10001h1 _..____ 11111 Bit Nozzles 0.942 In, I L,0,,to6. -_ ___ LPresslrre Losses „o, . , Bingham Plastic zai ,Ii® Mrg tri511 psi MWD 450 psi . Motor350 psi „I,1 Bitit385 psi 3a� � 1 Bit On/Off 100 psi 11111 1 Annulus 38 psi +40 - - -1 ,' I Surface Equip 42 poi 150, U-Tube Effect 26 psi ® `— Total 9yawn 1902 pal ., +fioi II I I I ESD ECD m 10.2 Csg S hoe 9A9 9.92 10.27 n i 3.501 TD 9.50 10.021037 vac n3z 1 ---:' e ESD PV iW Yet.Wml2 Rma ECD �YP toot ..T pc5tc.... I QV __.J9aaumnw i , lwni111I II 1 3 u Al -. }:II 11111�II11I�„Inl l�IIIIII,� _ �� 41011u 1 WIMI'I'11 111111I1a1111111111111111111111i1111111111'1111 VIMIIIIIi,1111111 a4 i 1110 1jlti�+i1114141Ili11; h1Ih.1 11" 1 _ fI� h 1„,,,„1,,,,,,...-,, t0,r 11 dIIl � p r/„s , r 1a ,�1,1 1 , 1 I11,mi, � 1 I,,,,,,� 111111,(1l1ll11,,dy� � zrIeiN1F '� i } x 4,),,,,,,N---,---,,,r,Y t 1 x s 1r” ` It a iP11111011 1rl 1 1101 ,-r; w ln i 13 . (; .r.. 11. 11 i - Ih i) / 11x1 iIII 11111 Io,N4,,,I IkIM NIIi11111111111111111pk1 1111 a-` +11 911',111,{111111d111,11�,l,^III V1111111 - ,4k s---------t ..-6,,,,,,,t I/140114p,fa,,, ;reg 1'11110,:!1111V101010,'1_40 ',i7r li, $O IWC 1"4 glut,"I' VH HOLE CLEANING ._p�{{N0�_ri ©1995-2010 M-I L.L.C. 625 GP M MD:7665 ft Operator:Marathon .-- _-x' OriilP� ND:1424 ft Well Nam e:S usan Dionne? VIRTUAL BVDRAULICS'VRDR* Bit ate:3/15 n Location: Kenai Peninsula Date:3/10/2011 Country:Alaska , Hole Cleaning Marathon Susan Dionne 7 1 00 • Poor Hde Clearing 1 t { ♦111_1 __ ._....._.�. _.. __;. 1111.... 111__1 .. .i. 0 75 .,.,, ,,,�w _........ 11 11 I 3 ; --- x Fair Hde Clearing c _.._. ;.. _ _:—_.. _ ........ m c 0.50 m I ._ U m _ I Goad Hde Clearing 0 25 11_11 i -l — ROP Movtlr Very Good Hde Clearing ROP 200 R% Clearing- — ROP 1501Pohr I f -- -- — 0 ! 400 500 600 700 800 Flow Rate(gal/min) u:q[il�u41j11111i1111111111111111111111I11111�II111IIII111JIII11I Y. i t rl l �� 111, 1i Ii ai �3 1 t liil 11111 1iI11, lII 4i i�11111F II 3i ii tsi1V�11,1111,11 T1ii1i111llllil,llli111OIlllllllllldlli i11i,ryI11111IIt!-,1:':E-.r'*0-1:'1',.-11',.r11,-1-11!1!-1:111t:1'!iF1rl;IIII Illlli III 1� �lllllii�:111111 11111'c" i1 III 1111) II1l1 ill III II '��1?hlhlllllll'111111111111IIhlli41�IIIIIIh111III�1111111111111i1i111111Y;i41111'11i11111,1� �11 il��l�i° �', (a11i1111111�11j11111pI1111111111111111111�1I141111111111110111111111;11111,III1141111�11P11,111'1111 - Section 5 — Intermediate Interval (1685 - 7029') Depth Interval 7029' MD (3752' TVD) (9.875" OH, 7.625" Casing) Drilling Fluid System FLOPRO Flo-Vis/ PolyPac UL/ KCI / SafeCarb F & M /Asphasol Supreme/ Key Products LoTorq / Caustic Soda/Conqor 404/Sodium Meta Bisulfite/ Klagard Solids Control Mongoose shakers, desilter, CD 500 centrifuge Potential Problems Hole Cleaning, Hole Stability, Seepage losses INTERVAL MUD PROPERTIES beitith Plastic Yield API TVD Mud Wt Viscosity Point Fluid Loss LSRV LGS 41, (lb/100ft2) (rn1/30nnin) I Mill Ct) pH 004 11111h(PPY) 7029 9.0—9.6 10 - 16 12 - 18 5 - 7 30—40000 9— 9.5 < 6 • Use one rig pit for drilling out surface casing. In other rig pits, build new FloPro fluid. • NOTE: LoTorq additions at 3% minimum will be made after mud is sheared down so no losses over shakers. • If running coals become a problem, treat with a 4-6 PPB addition of Asphasol Supreme. • Periodic additions of LoTorq will be needed to maintain 3% minimal concentration. )%. Condition mud prior to running 7.625" casing. 4 rr') a 1 i f��{ ISI+I�III'll u100( ' I 4 j�ilo-II Ill�Illllllllll11 IlI ll 'lllll+lI II Ili h�llllIlll1llllIIIlll IIIilll IVII 'l i111111,111I111111111111111„!1.1111,10.:1I1I'Ill 'l ,liljlllllllilll) llli lll'l' I llll'l'ill llh,1,l11 IIIIll ll'llIIlllll ISllllli,lllllll ILI l lll, ,I{ IIlilllI I,, l llll llik llI ll'i , IIIl 7` _r 'a „i ' I ^sai / H le Hydraulics Cleaning: Virtual Hydraulics Graphs The following graphs look at the ECD + cuttings at 7029' and moving cuttings concentration (MCC) in the annulus while drilling the section. VH SNAPSHOT llll''1llll'llili' Ii'IIII�llllllllllllll'lllllllllllllllllllll''''l'l'llIlilillllllllllllllllllliillill ■�M C1995-2010 M L.L.C. 550 GPM MD:7029 R Operator:Mar aOum ��c TV D:3752 8 Well Name:S usan Dionne 7 VIRTUAL HYDRAUIJCS'Snap$bo * 96 Bn512e:9675 Ixatlar KenalPeNnsula p • Dare:319!2011 Gantry:Alaska Depth Gearnatry Are De00lty PV(cP) Va Hde Clam Pressure Dist idrban (1 MD7IVD Csg ORAD �) QNgi) VP,l3YP(Ib110011� (gmin) Index (%) Int (in 0 45 90 9.8 10.0 10.1 10.8 8 16 — 2/ 32 0 200 400 VG G F P Bit=42.8 AM=6.5 DS=48.7 501 III -_._—_ y. _.... _. 4{ 001 3 F 1501 —_. ___ II 080 10.15( I DrlUlr0� ase 9.902 l R.OPRO NT 200: I Metl WsI 6 8.6 Ideal Teal Temp 720 'F 2501 ° I ( SyaM1t Dab Row Reb 550 555,5.99°991 eilm In 3001 ._1__ , Penetratlon Rale 811110°0220.-102.-11:11;°°°7-102-41:21 0 1N1r RaMry Speed 700 rpm 3501 1 - WNprt on Blt 10 f0001M Blt Noazlss 12-12-12-12-12 • a0oc _ 12-0-0-0-0 Presstee Losses asap . MadOed P'v735°0500'01 we ^ DrIII8trin0 701 psi - MWD 550 psi s00. Mohr 300 psi BK 616 psi 5501' I BSOnlOII 100 psi 1 i 1 � 1 , Arrau 122 psi 6001 Surface Equip 25 psi I l �- - U Tub Effect 22 psi Total System 2436 psi fi 501 ESD ECD *Cut T —- Csg Shoe 9.72 10.22 10.33 FV , 7001 /029 6 1s0�rrr� s.e1s [ erns�I 1—¶sura �~ Tm� ,', e .I t .=.1. a .vreusr®73 mawn3�I�47 1rI� II' , '14 fit y i;I ll'IIIII'lilIl'6'f' , k�lhl"ll"III A 111V111111114,'''',',1III - Dill+'"I�IIIIIII Il lllll llilig11 ` 1I 7 III III+ IF llllll lglllllll i'1I'lllll l"I I,h , 41I IIIIIII ''IIII ' h11t'lllllll6l4h 1'lllil'lll0l'lllll4ll''11 ,1:4110N1141111100!1011100101111.14'lll,l11 *0 IllllV Mars r° I'll.: )� 7 N0,0...:-.Lx...--04.00-04----w110,!--0%-i.0„01-04,1„L,1,1-Z0 ,77' �l �dl5 l { °I '006 M9 Pt) till ,4i' 1':11'1011:1000r0101,1010.'„0&100- 0-0,07,,Illll �lll1 1IIlil'l00t,„l' l l l kI I : II011',1,11111111'11111111,11,111111k10:'01 lhYr Y I III IrII I',llIlIllllillll ,,41h00,0k0-000.01000.00,1g-„i70.- IIiIIIIIIIII,,llI ll ,f ,, II r — u M gNf�lGfiZ.� 1T 9wTal lig VH HOLE CLEANING 4 MMiSW' S50OPM MD:7029 ft Operator:Marathon A ®19952010 Ma L.L.C. ,�, Ttrka111-1.L.C. BO ND:J752 ft WNINam e:SusanDionne 7 VIRTUAL RVDRAULICS'VRDR' °� Bit Date:31912011 In Location: Kenai Peninsula Date:Ji0i2011 Cou*y Alaska Hole Cleaning Marathon Susan Dionne 7 1.00 .-- --r---T ROP 25 NM roi. — — ROP 5011M 1 - — ROP 751bh �. .. ." 1 Poor Hde Clearing •- — ROP 1001thu - --. __ 1 _....__.. f ......- ..--.-�.....- __.-.-..-- .-...._..._.- .. ._......-. 075-- 1 i , l 1 i 1 Fair Hde Chrirg' { C ` _____ ___._ _....7 ____t.__�_____—. l. 0.501 d I U ,_ --_ - d Y _ Good Hde Clewing - , ? Il Very Good Hde Clearing II oT — , t 400 500 600 700 Flow Rate(gal/min) ,Ih'Il,lllglrr.,y%IIIhlIl111111 I 1 .v. • mlgillllrll II$, 1 I l l�l1l7+'d11171111111ti111�.01111ll�hrtt,,y �Ii 111111 11111 1111 111 1111 i1" v4 �1111111�1111111.1VIII11IIII111III� 11II111101. 1111111�i�I,1111 I111iIil11111II N1V111,11 'k1,11II11I1.110 r+ttx-:' w �' :r -. 'll• 1111IIIIIIl1.11.1liPtINI rt 4V011,l111I 01,1 11III�+i 0.1 rti 171 IIII 1001Vh '11161IIIIIIIII rl " dill d1ili V11111111I�V11hll lli�i *14 k �I�II III 1 , 4 lllillll i1ll 111111 III'�1Il1VI1l1 1�11111 IIIIIIVI111i111 �� �11j111 11I' Ii,p", 111 IIII,IIII, u 1 111111','111�Ila,s..,r Mi SWACO Section 6 - Production Interval (7029 - 11,794') Depth Interval 11,794' MD (7869' TVD) (6.75" OH, 4.5" Liner) Drilling Fluid System FLOPRO Flo-Vis / PolyPac UL/ KCI / SafeCarb F & M I Asphasol Supreme I Key Products LoTorq / Caustic Soda / Conqor 404/ Sodium Meta Bisulfite/ Klagard Solids Control Mongoose shakers, desilter, CD 500 centrifuge Potential Problems Hole Cleaning, Hole Stability, Seepage losses INTERVAL MUD PROPERTIES Depth Plastic Yield API '"ii' TVD Mud Wt. Viscosity Point Fluid Loss LSRV LGS (ft) (ppg) (cp) (111/100ft2) (m1/30min) 1 min Cp pH 11,794 9.0 — 9.8 10 - 16 12 - 18 4 - 6 30 —40000 9— 9.5 < 6 New FloPro mud will be built for the production interval. Old mud can be used for drilling of cement and float equipment if space is available in pit system. If running coals become a problem, treat with a 4-6 PPB addition of Asphasol Supreme. D Periodic additions of LoTorq will be needed to maintain 3% minimal concentration. D Condition mud prior to running 4.5" liner. Mi SWACO Iu1Ulllh91,u19p0lhd9,1,hi114101011l,quillipgl,10,0t :5 I 0 Hydraulics / Hole Cleaning: Virtual Hydraulics Graphs The following graphs look at the ECD + cuttings at 11,794' and moving cuttings concentration (MCC) in the annulus while drilling the section. VH SNAPSHOT M'SWACO ©19962010 M-Ie.L.0 111-1 c 270 GPM MD:11794 ft Operator:Marathon 9.6 peg ND:7869 ft Well Name:S usan Dlonne7 VIRTUAL HYDRAULICS'S118pSh0 * BitSle:6.75 in Location: Kenai Peninsula Da :3/912011 Cautery:Alaska Depth Geometry Ane Density PV(cP) Va Hde Clean Pressure DletrihbNon (ft) MD/ND Csg ODIIO r) 01Y¢I) YP,LSYP019100R) 06mirl) Index (%) I'II lin 0 45 90 9.6 10.4 11.2 8 16 24 32 0 300 600 VG G F P Bit=22 Ann.39.2 DS•38.8 100f . I \ , 20oI I 11111 i 300< Ii 1 ��DrYlingFitld , ROPRO NT II MW Weight 9.6 INgal i 4001 Test Temp 120 •F . IN , I II System Data Flow Rate 270 geilm in 6000 II Panetrason Rate 60 Mr Rotary Speed 100 rpm II Weight on Bit 10 1000 IIA 1 '.11111 Bit Nozzles 11.11.11-01.11 7000 7029 7.62 0.0-0-0.0 3152 11111 Pressure Lasses eoo/ Modified Power Law / . --- 111 DrillShing 534 psi MWDBit 154 psi 9,00f Malar 144 psi BitOnfOff 303 psi 100 psi 1000•. 11111 Arnim 539 psi 11000 11111 Talal S ystem P 1767 pal ' EE 1200.1;1794 6.75. `1 —— - I CsgShoe 9.74 11.04 1112 II � TD 9.75 11.07 11.15 ESC, PV ECD =YP l I I WI-Vnlnax --(-4 "tete, cnrym, —)ev4 E. sea Vet•., toft sI.-Meeum.Mm nmo tk7v l'litn zry 141I1111II l 4 l 1 11 I rte'r. 111!,0 .1 y k1 iifTod1 '11 j1ii4I, lI1aki ,41 11111 1IIgp1I 6,, ll r 1:0 —ssIIIaI1IIIIIIII�1��i,l IIl ,1ix - Ir,. {l1111 VH HOLE CLEANING +ti I,qpp8,1117 -44,t.X11I11I �II - �IIIIIIIINII�11'I�yu'•E� 8k1�ll�s��'T �a�:°:,14�i��1i91�I���1111I1f1111�r�°li'I ihllil�,l� FYN Ari a 01995-2010 M4 L.L.C. 1711 GPM MD:11794 d Operator:Marathon I,'S'II I •u.ka WI LLC TV D:7868 ft Well Name:S usan Dionne 7 1Lt'I„11 , VIRTUAL RIIDRAULI CS'VRDH* 9epeg Bit Date:3/9/2011 in Location:ComaAKenai laska Peninsula Date:3/9/2011 Cou*V:Alaska .,, Hole Cleaning Marathon Susan Dionne 7 1.00 ROP25i Ill — ' -� �_ -T ilii — ROP 50fu1 ROP75flM ---- --- — --- - - -- -- --- _ It ROP 100 ftTr - Pm tNdaCNril� I { A -__.. – -_-_--___._- i i, 0.75--- , I i –vC 4 - kritV. — — d 4- --_.— Fair H C e 050 ..,� a ! d x Goad Hde Cleating 0.25 I ..,, ,,„ 200 300 400 500 Flow Rate(gal/min) ij _ ry i4liiiitlin ,.a,f yiiiiF iiii kiiti . 5;. 5: X 1111 : 1111111111111111111'+1'lll111 lllllll,1h111111911IIIII'I1III�th11 1h111hlh111hhill 1111111lh1'IIIIII�I IIIIIIIIII,�GI'Ilf1 M ''''11111111d1'1111111'1111111111,0$1111111,1'11111110111 Ii ' SII 111 X11 1111 11!,X I IgVlll�1 1 r � '� I I I Id r � ply id4r�11i1 1111 f111�II 1161 i iii1ji,li1i11 1111111'111111111,11''11111111111i1'�1�ti10,1 1 1IIIIiI1111111i1I11iill'VI Section 7 - Solids Control Equipment Solids Removal Equipment Recommendations: Ihh1hhilh 1 1h1� The recommended SRE for this well are: Mongoose Shakers and CD 500 centrifuge. Recommended shaker screens sizes are as follows: 111 Interval Recommended Screen Sizes Recommended Screen. Sizes 11111;1 (Shaker 1) (Shaker 2) 0—1685' (Surface) 165—200 mesh 165—200 mesh 1685—7029' (Intermediate) 200—230 mesh 200—230 mesh 7029— 11,794' (Production) 230—275 mesh 230—275 mesh11 11 11 1111 hl 111 1111 y+ a,a i111'I1li1111'11111111 1 1111,111 hh 11'1111101101- **111111 111111111111 lh 11111:10111111111:111111'1100 1111 ! 111111I �11111111111111i114IIII 1 - ...Y 1 , 111111111'1 111 11i 1 �'.,I. M g1Flx1„ 1111t; li '11111111 1 111111111111 u Section 8 Summaryof Product Usage and Cost '111'114[1,1111,1!1,111141,11111;111110,1',1,•'•,,11'111111 ;11111y111;11111111 v 1 'IIII 1x111 11 4 '11 411111 14111h11111�111111�111111111ti11�1d rdli u��1 u u1111111u1y11 ,1J11I 1i 1 1 1 11 I11 1 I� 1`1,1 ' 111111111111111i11ry 1111111111111;1111h111111,11111111111JV1111,1 Er”, 13.5 in Hole Sections(0-1685 ft.) ProductUnit Size Units Required M-I Gel 50#Sx. 774 50#Sx. 13 Caustic Soda Gelex 2#Sx. 32 50#Sx 52 Polypac Supreme 13 Sodium Bicarb 50# Sx CF Desco 25# Sx. 34 Ili Soda Ash 50# Sx 13 Total Estimated Product Cost $20,383 9.875 in Hole Section (1685 - 7029 ft. Product Unit Size Units Required) 11� M-I WATE 50# Sx. 1817 111111111411111,d�1�N"�If`i�{�r,J 1M44[I4�11u<<1111111111111111 111 Asphasol Supreme 50#Sx. 273 SafeCarb 50# Sx. 454 Soda Ash 50# Sx. 11 Caustic 50#Sx. 23 PolyPac UL 50#Sx. 57 FloVis 50#Sx. 136 Sodium Metabisulfite 50#Sx. 23 Myacide 5 gal 10 Defoam X 5 gal 13 Conqor 404 55 gal 5 KlaGard 55 gal4‘v 31 LoTorq 55 gal 54 ,,, , KCL 50#Sx. 500 Bicarb 50#Sx. 11 Total Estimated Product Cost $190,512 11 1111 ' � 1111111l4w11111111111111111111111111 11 �1 1 +11 1 �N111N111111�111111 1 .11 11 111141111111 11l 1' 11111,111i111j1111111111111 X111if1111111111111111j11111111111111111i11111111111111111�1,h11�..:i1111 11)1 1111111V1�111111111i11111 1111PJ�11111111111111111111111111011g111,111iIIh1111111111111 °I' II11 1 Mi SWACQs.- 6.75 in Hole Section (7029—11,794 ft) Product Unit Size , Units Required M-I WATE 50# Sx. 1373 Asphasol Supreme 50# Sx. 92 SafeCarb 50# Sx. 229 Soda Ash 50# Sx. 11 Caustic 50# Sx. 11 PolyPac UL 50#Sx. 23 FloVis 50# Sx. 69 Sodium Metabisulfite 50# Sx. 11 Myacide 5 gal 10 Defoam X 5 gal 6 Conqor 404 55 gal 4 KlaGard 55 gal 29 LoTorq 55 gal 27 KCL 50# Sx. 252 Bicarb 50# Sx. 11 3r Total Estimated Product Cost $109,321 Product Cost and Engineering for P10, P50, P90 Estimated Drilling Fluid Related Costs Engineering Depth Interval Costs Interval Cumulative (ft) Product Costs ($) Days Cost Cost ($) ($) ($) • Surface $20,383 $5,000 5 $25,383 $25,383 Intermediate $190,512 $8,000 8 $198,512 $223,895 Production $109,321 $8,000 8 $117,321 $341,216 P10 P50 P90 Total Estimated Product and Engineering Cost $255,912 21 $341,216 $597,128 r P10: Utilizing used fluids with no hole or other problems P50: Utilizing new fluids with no significant hole or mechanical problems P90: Utilizing new fluids with significant hole problems, excessive lost circulation or change of scope u4111illlllllhlllllll0,, +II hlVll 1141]18 W'A 1:,:012111,1,11011110 ly kE I Ililllt 011ll I�IIII�1141111VI I lll�ll lull llljllll4l 01 III_Illy 1 IIIIIIIIgIIIIlllllllllglllllllllllllll I IIIllilwlllhll94lll1111 fly+ P1„f x � 111 ll�l Illi Illl�0,1' . J,, , �I,II � il;l g .,, k NI 13/AfMilosp.- 111f ' dils ' / a110 li� 1-4 I1111 11 � I�r1 Ii � , e 11l ,,i rth1 � �(: 11I ¢r a 1 I!II1J li 0 1 ,1r Appendix 1 — Lost Circulation Recommendations i• , i 111 ,;III N p1 II�II11li111,1;II�,1i ril 11 y1111 l 11��141I1�I111111111,1 ll II j1111i1111 III11111111 11t1011i 1111 11 II i 1111 1I I II 1,11111111411,1141 I"VIII �IIII111611u111111„1111111 1 11;11111II111 I II 11111 illi 111111 II1111IIIII111�IiII 1 Iiu1111 1 I1 11111ji111 11111'1 111ti1111I11111i 11111119111'0111 v!1 a11110011$10111!�: 1111111111111. rr. ,1,',11114111'1111 .L'I Lost Circulation /Seepage Action plan: ❑ Have sufficient sized LCM on rig begin be in interya l. ❑ Recommend hourly addition of LCM to keep a concentration in the system at all times. The addition of 3 Calcium Carbonate (M, C), MIX II (cellulosic fiber), G-Seal (graphite) and Diamond Seal (coarse ground jl'1,' graphite)can be adjusted as needed to combat losses. ,11 ❑ The particle size of the LCM is important. If the expected loss zone particulars are known, then plan to ;'!II11I1 have LCM to offer a particle size distribution so the majority of the LCM has a D50 to cover 1/3 the I expected pore throat size and a D90 of cover the pore throat size. The D90 material should make up 10% 1 of the total LCM ppb pumped. ❑ Coordinate size and amount of LCM sweeps with MWD personnel on rig. ❑ The majority of losses can happen when running casing, circulating to cement and while cementing. The II use of Virtual Hydraulics surge calculations is recommended to establish safe casing running speeds.The 11111 use of open-float and bypass tools should be considered to help minimize surge pressures to formation. '1, 1,1 ill 1111 Id 11 ;1 i. 3' 9hg111�1111111111W 1r --g ,-ti. s,�11111111j111111i11111I1111111I111I1111111piI1I1�111111111111 7 i1 t 4 .. lll�lEllAff � V ' ^',Ive.;sa- MP 4Ik1 Oi v..;1,, .^ aiN1�r�:.0 u oillry11111 .. Nal011111pivinl t"n,.,b' Appendix 1 — Lost Circulation Recommendations The following proactive lost circulation decision tree can be modified to include any contingencies that Marathon requires. The flowchart allows for planning of lost circulation material needs ox11�„111�I d�111,11111�€ �� �'htil�lullIlIllllllllllll ig4 11'i1111' No LCM Restrictions `1�111+'�['�'4'1i mil iIIIIPII I'1'�i111 111'1 1 Losing fluid while drilling � h11”1�j1111111'1 III11'10111'II 1 4j1'11�11 11Ik II'1I111111;11111111111111111111 �I1i11111p1111111,11h11VI111Ai61111111I1i'111i11111 111,11 1 Measure rate of loss 11 X111 1 11111 1 X11 ill Seepage losses Partial losses Severe losses 5 -20 bbl/hr 20 -60 bbl/hr 60—200 bbl/hr or Total loss of returns If fault related drill across fault If fault related drill across fault If fault related drill across fault ,1 1-1.5 times the length of the 1-1.5 times the length of the 1-1.5 times the length of the 1 throw before treating losses throw before treating losses throw before treating losses 1 - 1 Spot 45 ppb pill*: Spot 80 ppb pill: 1 Contact Drilling/ X111 G-SEAL Plus 10 ppb G-SEAL 15 ppb , , No success I_ Asset Engineer M-1-X 11 M 15 ppb -0M-I-X it C 20 ppb JF► for approval SAFE CARB 40 10 ppb M-I SEAL M 10 ppb NUTPLUG F 5ppb250 1NUTPLUG10 15 ppb F ppb ; Magma Fiber 5 ppb Magma Fiber 10 ppb Pumpthru BHA Spot 80 ppb pill e Circ sub required Circ sub required G-SEAL 15 ppb M-I-X II C 20 ppb M-I SEAL M 10 ppb SAFECARB 250 15 ppb t NUTPLUG F 10 ppb Magma Fiber Reg 10 ppb 1 Squeeze high-fluid-loss pill*: FORM-A-SQUEEZE 80 ppb(2sx/bbl)in water Weighted up to desired density Pump thru BHA I l ` 'to success p *The particle size of these products is smaller than Nut Plug M Spot plug: `Vi=e Gunk Squeeze or FORM-A-SET AK 11_ (!s M 9NWLI,,.. - �..rr rg A F LCM Restrictions Losing fluid while drilling Measure rate of loss V / ,. Seepage losses Partial losses Severe losses 60—200 bbl/hr or Total loss 5 -20 bbl/hr 20 -60 bbl/hr of returns 1 1 • If fault related drill across fault If fault related drill across fault If fault related drill across fault 1-1.5 times the length of the 1-1.5 times the length of the 1-1.5 times the length of the throw before treating losses throw before treating losses throw before treating losses 1 Spot 50 ppb pill*: Spot 85 ppb pill No jContact Drilling /Asset Circ sub required Engineer for approval SAFECARB 40 20 ppb No SAFECARB 250 20 ppb ..-110 SAFECARB 40 20 ppb MIX II (M) 10 ppb SAFECARB 250 25 ppb k SAFECARB 500 30 ppb Pump thru BHA MIX II(M) 10 ppb Spot 100 ppb pill \ Circ sub required I G-SEAL 20 ppb �.>>ucce M-I-X II C 20 ppb " °""` SAFECARB 250 25 ppb 1 + SAFECARB 40 25 ppb MAGMA FIBER 10 ppb Contact Drilling/Asset Engineer for approval Spot 80 ppb pill V Circ sub required Squeeze high-tluid-loss pill: G-SEAL 15 ppb \ 'NU,le FORM-A-SQUEEZE M-I-X H C 20 ppb M-1 SEAL M 10 ppb 80 ppb(2 sx/bbls)in water SAFECARB 250 15 ppb Weighted up to NUTPLUG F 10 ppb desired density Magma Fiber 10 ppb Pump thru BRA I + * The particle size is smaller than Nut Plug Medium Spot plug: Gunk Squeeze or FORM-A-SET AK Appendix 2 — Minimum Time to Circulate Prior To POOH 11111111,1111,11111111, 1 011110111,11 The BP model simply Predicts the minimum flow rate required for adequate cuttings transport. No predictions are available for the rate at which cuttings are removed. Because the cuttings move more slowly than the circulating mud, it is essential that sufficient bottoms-up are circulated prior to r tripping. A SINGLE BOTTOMS-UP IS NEVER ENOUGH! The minimum on bottom circulation time prior to tripping will be influenced by hole size, inclination and flow history (i.e. mud properties and flow rate). These factors will affect the height of any residual cuttings beds. Recent work by Exxon has indicated that the volume of cuttings left behind �,,I11 during normal drilling operations can be considerable. They recommend selection of bits/BHAs with I1 large bypass areas to facilitate tripping out of the hole. Before tripping, monitor the shakers to ensure the cuttings return rate is reduced to an acceptable background level. The figures in the table below are guidelines based on simple slip velocity considerations and field experience: WELL INCLINATION SECTION LENGTH FACTOR RANGE 17-1/2 inch HOLE 12-1/4 inch HOLE 8-1/2 inch HOLE 0°-10° 1.5 1.3 t3 10°-30° 1.7 1.4 1.4 30°-60° 2.5 1.8 1.6 1 60°+ 3.0 2.0 1.7 I Procedure 1. Effective length=Section length x section length factor. 2. Circulation time= Effective Length x B/U11 Measured depth at B Example Since in practice not all of the section back to surface will be deviated at the same angle, the overall minimum circulation time prior to tripping should be apportioned in direct relation to the relative lengths of section at each angle. 11111 III 1111111 1,11 1111 , 1100M0 I'I I� % V1 i ;1IIIu � 6 11 Mi SWACO Appendix 3 — HSE Issues Safety Recommendations for Mud System �H1'l dl I�a 01� Ii 4. , Vel l *4�I,N IIT; 1. The rig crew should be briefed on the makeup of the drilling fluid and its cost. Safety and care should be used when drilling with any drilling fluid. An M-I Engineer will brief rig crews about H'II } drilling fluid and basic safety procedures. 2. MINIMIZE contact with the drilling fluid; although it's non-toxic, it can irritate skin. VIINiilill i IlliiilllliillillililiililiiIliilii9�liICiINII ry ii 3. Wear personal protective equipment when you must work with the mud. Proper equipment I'h'll'lll includes: a. Safety glasses or goggles b. Hard hat c. Steel toed boots or shoes (recommend rubber for shaker and drill crew) IIS d. Protective clothing (disposable suits or slicker suits) e. Barrier cream f. Rubber gloves Note: As always, follow the rig and operators safety rules 4. If you get mud on your skin, wash it off as soon as possible. Do not allow mud to stay in contact with your skin for longer than 30-40 minutes. Do not wash with rig soap! Use GOJO mechanics degreaser or other similar type product. 5. If clothing becomes saturated with drilling fluid, then change your clothes. Do not continue to work in clothes saturated with mud. 6. Designate one rig washing machine for muddy clothes. Do not wash other clothes in this machine. 7. Protective Equipment that has worked well on other jobs: a. Disposable suites: TYVEK BRAND b. Rubber boots: GOODALL BRAND POLY GRIP BOOTS MODEL #A1541 c. Coverall pants: GOODALL ARMOR LITE OVERALL, MODEL #C2522 d. Coverall Jacket: GOODALL ARMOR LITE JACKET, MODEL#C2520 8. Common sense when working with drilling fluid will prevent any safety problems. If you get drilling fluid on you, wash it off. If you have to work with or around the mud, wear your protective equipment. Watch your step and clean up any spills. ri 9 I IlIl111ti1' ;511'11,1111111111111 u ro MI inti,,Clalgeow, 11111111,0 1111111 1 I, Ikv,,: 7 1, 14 1111�1I1'I�,1.1I1111ii1i1i11111i11111i11i 1y r FIs I111111I1j11111�111 11 1111 l 111NIl11I 0011M-_411- Appendix 1r1111111I1111 1ti 1e01111�I1I111�II III Ii1'111111� —I� II i1Ili�IN11 ��I I IIII 111111111111 Iii 1111 �nIlls lII1Iiti111 JI,IIII��1 1111'{14+111'llj'a11I1';1111'�III;hi11 ` },III s:, A endix 4 — Recommended DrillingPractices I,I�ix ���� _ � + ll'rl I pi���sti,,��r i liI'INlii1ili�lNllil l irl�V 1l'l IIlI14111AIIli!I'l1i17 "1111111111116' IIIlllllll 6a A. Operational Procedures: 1 I11111'Illl�lyi II,IIt �I,'1'111P111�111''111111I11dI11hI1llIi1111111I1i111PdlIIlI1111111111 1 p 11�11'11II1111d1I,11 .��f 111111111111111I11611III1111111 1 1. Stage into open hole several increments breaking circulation each time and circulating for a period of time to get the fluid moving. 2. Idle pumps when beginning circulation to minimize surge pressures 3. Work pipe and rotate while circulating to help break up gel strengths hillgwp111I1p11Ip11111111111iIi111vI,IIoIIIIIg1I1III11111111111IIIlIi1IIiI1111111111111111111111 4 4. Look for signs of barite sag when staging in the hole. Light mud near the riser section could be 5. indicative of a sag problem. If sag is a problem, the depth increment for staging might have to be shortened to prevent lost circulation problems. Deviated holes will have a tendency to aggravate barite sag problems. These type sections may require higher yield points or low shear rate viscosities than the above recommended ranges to compensate for this tendency. el i on.. 9, , 11< ILI I it s s �!y' 1 r:l a l�l itk ItNldlllh'IIill1111'II gIInllgql 111 , wcuii ur 111u�sp111111111 1,111+111111hC11lll�lll4'li Alaska Department of Natural Resources Land Administration System Page 1 of 2 Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I find Alaska DNR Case Summary File Type: ADL File Number: 384372 f1 Printable Case File Summary See Township,Range,Section and Acreage? w Yes No ( New Search I LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 384372 yp Search for Status Plat Updates As of 04/05/2011 Customer: 000050694 MARATHON ALASKA PRODUCTION LLC PO BOX 196168 ANCHORAGE AK 995196168 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 12/06/1994 Total Acres: 3507.840 Date Initiated: 10/19/1993 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/10/2009 Case Subtype: CI COOK INLET Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: S Township: 001S Range: 014W Section: 01 Section Acres:650 Search Plats Meridian: S Township: 001S Range: 014W Section: 02 Section Acres:650 Meridian: S Township: 001S Range: 014W Section: 11 Section Acres:640 Meridian: S Township: 001S Range: 014W Section: 12 Section Acres:571 Meridian: S Township: 001S Range: 014W Section: 13 Section Acres:382 Meridian: S Township: 001 S Range: 014W Section: 14 Section Acres:615 Legal Description 10-19-1993 **SALE NOTICE LEGAL DESCRIPTION** TRACT 78-072 T. 1 S., R. 14 W., SEWARD MERIDIAN,ALASKA SECTION 1, PROTRACTED,ALL,650 ACRES; SECTION 2, PROTRACTED,ALL,650 ACRES; SECTION 11, PROTRACTED,ALL,640 ACRES; SECTION 12, SURVEYED, FRACTIONAL, SE1/4SE1/4,40 ACRES; SECTION 12, UNSURVEYED,ALL TIDE AND SUBMERGED LANDS,530.78 ACRES; SECTION 13, SURVEYED,FRACTIONAL,E1/2,320 ACRES; SECTION 13, UNSURVEYED,ALL TIDE AND SUBMERGED LANDS,61.78 ACRES; SECTION 14, UNSURVEYED,ALL TIDE AND SUBMERGED LANDS,615.28 ACRES. THIS TRACT CONTAINS 3,507.84 ACRES MORE OR LESS. 10-31-2001 ***ENTIRE LEASE COMMITTED TO THE NINILCHIK UNIT******** T. 1 S.,R. 14 W., SEWARD MERIDIAN,ALASKA http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber-3 8437... 4/5/2011 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME /Y//✓/Cel//�C ai✓i> /40,teiV PTD# '/>Q5-0 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: / // .45# L41/7" POOL: '��it/fr G-4 Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC / EXCEPTION 25.055. Approval to perforate and(produc /Inject is contingent 1/ upon issuance of a conservation orde approving a spacing exception. A4 9,,e47.?jbi) ©%L assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 m3 GI 0 o D a 01O v CO n v 3 o o D D r co NJ 3 0 s< m (7). r 0 = a3.o A A A ) o m N (Q . v v v o o X/ ° n N.) 0) NCI' N 01 7 O 3 N Oo a O OLi N CO 0) CO 0) 0) 0) CO CO CO CO N.) N.) N.) N.) N N N3 CV N N . . . .� -, co co .J CA C11 A 0) N.) .> -, 0• n CO CO V 0) (n A 0) N -+ O CO OD V 0) (n A 0) N -� O CO 0) 0) (.n A CO N — CD v m 0 (n (n 0 m K * 0 v13 oo O + > = > 0 0 0 C) to 0 v -D g 0 -0 -0 O OU) * g C r- -0 z ? n O 0 0 0 CD 0 0 0 7' 0 0 = °: O' 0 °- m K K K c o — 0 0) 0 CD -o -0 a c 0 0 0 7 CD O 7C N1:0 CD 7 O — CD (D N 7 7 CD CD j 7 0 3. -o R m (n 0 m m 0 0 c c Cp _ < < 0 c 0 v m 0 0 0 0 0 ° D fA 0 1 2 0- 0 ai 0 0. CD 3 -o y m 0) a 0) n _ o o (D 0 Q n v 0 ° o o m ? m v v g CO D D -1 7 co0) N 0., E -, (D �' (D 0 0) 0) C) 0 0) 0) 0) O 7 C)) 0 O 7 C/) 0 p: Cn 0 n n 01 C) -. 0 0 7 ? 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N �7 5. 5 CJ m w 0 * 3 m m u)) O fAi - = o It cri 7rn ), 7 N 0 N ul �� o 0 0 E' (n �* c 2 0 Ci o co 3 . v = 7 - O v 7 o ?N Nv (n 16 o << z z 0 N 0 0 0 0 0 N n 0 N N 0 0 N n0 0 0 0 0 N n N 0 0 m < a. CO n Z D N N (D 0-) N N (7 O N 7 Z `� 0 co (/) x O * C). 2 d a 0) 7 0 co p' 7 N C* co CCD CD N 0 <' A .(D. Z 0 CD 7 N CO C (D - .(1 (D CD j Cn CO C CD 3 Q (n A x CQ (n co 'O ° A 7 ° (D (D 0) -O N co n ° CC) 0 D co N N O. `G N J (0 N CD CO 7 cri m - 7 cn 0 x (o 7 w Z_ _ (D 0 A CD N 7 0 co N 7c O r ° c ( A 0 I C)) 0 o n 8 m (I) o c C A "N c Z cn - 0 -71 N Cn o 0 D O C) z z N ( m n b Cu 01 7 v (n 0) Aal -a- c...)w N a CO 0) O 3 7 O • 0 m 3 < 0 m O 7 D 0 0 C - • o- 0 O m n 0 O m 0 0) 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. SUSAN DIONNE 7 Kenai Borough, Alaska June 15 to July 9, 2011 Provided by: Approved by: David Gorney Compiled by: Ralph Winkelman John Lundy Distribution Date: July 28, 2011 Robert Silva SUSAN DIONNE 7 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 3 1.1 Equipment Summary ...................................................................................................................... 3 1.2 Crew................................................................................................................................................ 3 2 GENERAL WELL DETAILS ................................................................................................................... 4 2.1 Well Objectives ............................................................................................................................... 4 2.2 Well Resume .................................................................................................................................. 4 2.3 Hole Data ........................................................................................................................................ 5 3 GEOLOGICAL DATA ............................................................................................................................. 6 3.1 Lithology Review ............................................................................................................................. 6 3.2 Sampling Program ........................................................................................................................ 21 4 DRILLING DATA .................................................................................................................................. 22 4.1 Daily Activity Summary ................................................................................................................. 22 4.2 Surveys ......................................................................................................................................... 26 4.3 Bit Record ..................................................................................................................................... 31 4.4 Mud Record .................................................................................................................................. 32 4.5 Drilling Progress Chart .................................................................................................................. 34 5 DAILY REPORTS ................................................................................................................................ 35 Enclosures 2”/100’ Formation Log (MD and TVD 2”/100’ LWD Combo Log (MD and TVD) 2”/100’ Drilling Dynamics Log (MD) Final Well Data on CD/ROM SUSAN DIONNE 7 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computer – Drill Floor Monitor LabersaB 0 Computer – Pit Monitor Azonix 0 Computer for Company Man RigWatch (HP Compaq) 0 Computer for Tool Pusher RigWatch Remote (HP Compaq) 0 Computers for Mudloggers (2) Data editing, RigWatch Master, and RigWatch Remote (all HP Compaq) 0 Ditch gas QGM gas trap (mounted in possum belly) Flame ionization total gas & chromatography. 0 Hook Load /Weight on bit Transducer plugged into Geolograph 0 Mud Flow In Derived from Strokes/Minute and Pump Output 0 Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 4 Ball-Float sensors. 2 Sonar sensors 0 Pump Pressure Standpipe Transducer 0 Pump Stroke Counters (3) 3 Digital Micro switches 0 Rate of Penetration Depth Encoder Sensor 0 RPM Feed from Warrior Top Drive 0 Torque Feed from Warrior Top Drive 0 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Mud Loggers Years *1 Days *2 Sample Catchers Years Days Technician Days John Lundy 19 21 Greg Hammond 1 15 Steve Forrest 2 Ralph Winkelman 20 27 Larry Resch 9 30 Craig Silva 32 9 Craig Silva 32 8 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. Note: Craig Silva caught samples for 8 days and then consulted on LWD TesTrak operations. SUSAN DIONNE 7 4 2 GENERAL WELL DETAILS 2.1 Well Objectives The objective of Susan Dionne #7 is to drill and log a single zone gas development well in the Ninilchik Unit, Tyonek Pool with a minimum of hole problems or other concerns. 2.2 Well Resume Operator: Marathon Oil Company Well Name: Susan Dionne #7 Field: Ninilchik Unit, Tyonek Pool County: Kenai Borough State: Alaska Company Representatives: Rowland Lawson; Larry McAllister; Tom Anglen Location: Surface Coordinates 368’ FSL 1105’ FEL, Sec 6 T1S R13W SM, X = 213338.032 Y = 2236847.50 Ground Elevation 142.00’ AMSL Rotary Table Elevation 163.00’ AMSL Classification: Development (Gas) API #: 50 – 133 – 20594 – 00 – 00 Permit #: 211 – 050 Activity Code: WBS# DD.11.23631.CAP.DRL Rig Name /Type: Glacier #1 /Land /Double Spud Date June 15, 2011 Total Depth Date: July 9, 2011 Total Depth 11794’MD, 7883’TVD Primary Targets Tyonek Primary Target Depths UT1B Coal (7146’MD, 3809’TVD), T81 Coal (10731’ MD, 6820’ TVD), Primary Target Depths T135 Coal (Near TD) (11757’ MD, 7846’ TVD) Total Depth Formation: Tyonek Completion Status: Completion will be done without rig. LWD-MWD Services. Baker Hughes Inteq, Schlumburger Directional Drilling Baker Hughes Inteq Wireline Logging Services None Drilling Fluids Service MISwaco CANRIG Logging Geologists: Ralph Winkelman, John Lundy CANRIG Sample Catchers: Greg Hammond, Larry Resch, Craig Silva SUSAN DIONNE 7 5 2.3 Hole Data Hole Section Maximum Depth TD Formatio n Mud Weight (ppg) Dev. (oinc) Casing Diam. Shoe Depth LOT (ppg) MD (ft) SSTVD (ft) MD (ft) SSTVD (ft) Conductor 117 (+46) Recent 8.6 0.00 20” 117 (+46) 13-1/2” 1705 1276.72 Sterling 9.3 64.25 10-3/4” 1697 1273.96 15.0 9-7/8” 7050 3601.58 Beluga 9.7 64.24 7-5/8” 7032 3593.75 15.0 6-3/4” 11794 7719.75 Tyonek 10.1 0.93 4-1/2” 11790 7715.75 Standard Completion Note: Hanger for 4 ½” Production Liner was set at 6866’. SUSAN DIONNE 7 6 3 GEOLOGICAL DATA 3.1 Lithology Review Sand (1705’-1840’) = medium gray with moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, trace light gray to light to medium greenish gray fine to coarse upper, dominantly fine upper to medium upper; angular to sub- angular; poor to fair sorting; dominantly unconsolidated; trace ashy supported grains; very fragile; trace thin coal beds Tuffaceous Claystone/Tuffaceous Siltstone (1800’-1920’) = medium light to light gray with light brown and light brownish gray secondary hues; very soft and fragile; irregular, shapeless to slightly rounded cuttings; silty to clayey texture; dull luster; moderate to very soluble; slightly expansive; poor to fair cohesiveness and adhesiveness; trace dark brown to black micro-thin carbonaceous laminations and inclusions; trace thin coals. Sand/Conglomeratic Sand (1870’-1980’) = medium to medium light gray with light greenish gray secondary hues overall, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, trace black, white and light to medium green to greenish gray; very fine upper to very coarse lower, dominantly medium; angular to sub-angular; poorly sorted; dominantly unconsolidated. Tuffaceous Claystone/Tuffaceous Siltstone (1930’-2010’) = medium light to light gray with light brownish gray and light greenish gray secondary hues; very soft and fragile to slightly firm; silty to clayey to smooth texture; dull to earthy to trace waxy luster; irregular shaped cuttings; hydrophilic; moderate to very soluble; slight to moderately expansive; ; poor to fair adhesiveness; fair to good cohesiveness; non calcareous; trace dark brown to black micro- thin carbonaceous laminations and inclusions; trace thin coals. Coal/Carbonaceous Shale (2010’-2060’) = black with dark brown secondary hues; very firm to moderately hard; platy to flaky; planar fracture dominant; earthy to slightly resinous; smooth to slightly resinous; trace visible outgassing bubbles present. Sand (2040’-2130’) = medium gray with moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, trace light gray to light to medium greenish gray; fine to coarse upper, dominantly fine upper to medium upper; angular to sub- angular; poor to fair sorting; dominantly unconsolidated with trace calcite cemented sandstone; medium to coarse grain; medium to dark gray; fragile. Tuffaceous Claystone/Tuffaceous Siltstone (2100’-2180’) = medium light to light gray with light brown and light brownish gray secondary hues; very soft and fragile; irregular, shapeless to slightly rounded cuttings; silty to clayey texture; dull luster; moderate to very soluble; slightly expansive; poor adhesiveness; fair to good cohesiveness; non calcareous; trace to common dark brown to black micro-thin carbonaceous laminations and inclusions. Sand/Conglomeratic Sand (2160’-2260’) = medium to medium light gray with light greenish gray secondary hues overall, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, trace black, white and light to medium green to greenish gray; fine lower to coarse upper, dominantly medium lower to upper; angular to sub-angular; poor to fair sorting; dominantly unconsolidated; slight to moderately calcareous. Coal (2220’-2300’) = black with dark brown secondary hues; firm to hard and brittle; massive to platy and flaky; planar fracture dominant with conchoidal and bird-eye fracture present; earthy to resinous luster; smooth to slightly gritty texture; trace outgassing bubbles. SUSAN DIONNE 7 7 Tuffaceous Claystone/Tuffaceous Siltstone (2280’-2380’) = medium light to light gray with light brown and light brownish gray secondary hues; soft to moderately firm; irregular, shapeless to slightly rounded cuttings; silty to clayey texture; dull luster; moderate to very soluble; slightly expansive; poor adhesiveness; fair to good cohesiveness; non calcareous. Sand/Sandstone (2340’-2420’) = medium to medium light gray with light to medium greenish gray secondary hues overall individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, trace black, white and light to medium green to greenish gray; fine lower to coarse lower, dominantly medium lower to upper; angular to sub-angular; poor to fair sorting; dominantly unconsolidated; slight to moderately calcareous; trace thin coals. Tuffaceous Claystone/Tuffaceous Siltstone (2400’-2480’) = medium light to light gray with light brown and light brownish gray secondary hues; soft to moderately firm; irregular, shapeless to slightly rounded cuttings; silty to clayey texture; dull luster; soluble; slight to moderately expansive; poor adhesiveness; fair cohesiveness; non to slightly calcareous; trace dark brown to black micro-thin carbonaceous laminations and particles. Sand/Sandstone (2480’-2580’) = medium to medium light gray; slight greenish secondary hue; medium lower to fine upper and medium upper; occasional larger grains; predominantly translucent white to clear quartz/glass in the finer material; medium to medium dark lithics in the larger grain; occasional stringers of conglomerate in the same mineralogical distribution; dominantly angular to sub-angular; common sub- discoidal; scattered sub-rounded grains; trace phlogopite mica, banded dusky gray and yellow jasper; interbedded with occasional thin to moderate coals and tuffaceous clay/siltstone; very calcareous overall. Tuffaceous Claystone/Tuffaceous Siltstone (2540’-2620’) = medium light to light gray with light brown and light brownish gray secondary hues; soft to slightly firm; irregular hydrated masses to slightly rounded irregular cuttings; hydrophilic; expansive when wet; poorly adhesive; poorly to moderately cohesive; trace to common micro-thin carbonaceous lamina; trace to scattered fine coal particles; trace to very slightly calcareous; interbedded with sandstone. Sand/Sandstone/Tuffaceous Sandstone (2640’-2740’) = medium to medium light gray; light greenish to brownish secondary hues; soft to very soft and disaggregated; poorly to moderately well sorted; generally medium lower to fine upper and medium upper grain; tuffaceous material is fine lower to very fine upper grain with scattered fine upper; coarser fraction is primarily medium gray/greenish gray lithics with 40 to 50% translucent white to clear quartz and light to dark gray lithics; finer material is 80% translucent white angular quartz/volcanics with minor darker moderately spheroidal grains; principally matrix supported in soft gray white to very light brownish white ash; slightly calcareous individual masses. Coal (2700’-2800’) = very dark gray to grayish brown and black; very firm to hard; irregular angular hackly fragments; harder fragments display slight conchoidal fracture and cleat; slightly to moderately silty in part; some with moderate amounts of micro-fine pyrite; slight de-gassing; trace carbonaceous shale and silty/sandy lignite. Tuffaceous Claystone/Tuffaceous Siltstone (2800’-2900’) = medium light to light gray with light brown and light brownish gray secondary hues; soft to slightly firm; hydrophilic; irregular masses to slightly rounded firmer cuttings; expansive; soluble; poorly adhesive; poorly to moderately cohesive; trace to abundant micro-thin carbonaceous lamina; trace to scattered coal fines inclusions; trace to very slightly calcareous; interbedded with sandstone and occasional thin coals. Tuffaceous Sandstone/Sandstone/Sandstone Conglomerate (2860’-3020’) = medium light to medium gray; slight brownish to greenish to secondary hues; soft to disaggregated; moderately well to poorly sorted; fine lower to very fine upper in the tuffaceous sandstone; medium lower to fine upper, medium upper and coarse lower in the coarser material; finer material is 80% translucent white angular quartz/volcanics with minor darker moderately spheroidal grains; coarser fraction is dominated by medium to medium dark lithics with variable translucent white and clear quartz/volcanics; angular to sub-angular throughout; trace brown limonite stained grains; trace dark gray to black mafic mineral grains; primarily matrix supported in very slightly brownish gray ash/clay; rare intact fragments are very slightly calcareous. SUSAN DIONNE 7 8 Tuffaceous Claystone/Tuffaceous Siltstone (3000’-3120’) = medium light to light gray with light brown and light greenish gray secondary hues; soft to slightly firm; hydrophilic; irregular masses to slightly rounded firmer cuttings; expansive; easily lost in washing; poorly adhesive; poorly to moderately cohesive; abundant to common micro-thin carbonaceous lamina; trace to common coal fines inclusions; trace to very slightly calcareous; interbedded with sandstone and abundant thin to moderate coals. Tuffaceous Sandstone/Sand/Sandstone (3120’-3240’) = medium light to medium gray with a slight brownish to greenish secondary hue; soft to disaggregated; moderately well sorted; fine lower to very fine upper and medium lower grain; angular to sub-angular; translucent white to clear colorless quartz/volcanics dominate; common medium gray and gray-green lithics in the larger grain; trace brownish yellow limonite; trace to common phlogopite mica flakes; scattered vari-color jasper; trace dark gray to black mafic mineral grains; principally matrix supported in soft off white to brownish white ash/clay; grades to and interbedded with associated tuffaceous silt/claystones; trace to common micro-thin and thin coaly lamina; common thin coal intervals; rare intact fragments are very slightly calcareous. Tuffaceous Sandstone/Sand/Sandstone (3240’-3400’) = medium light to medium gray with a slight brownish to greenish secondary hue; soft to disaggregated; moderately well sorted; fine lower to very fine upper and medium lower grain; medium lower to fine and medium upper grain below 3320’; uniformly angular to sub-angular; translucent white to clear colorless quartz/volcanics in the finer grain; dominantly gray lithics below 3320’; common medium gray and gray-green lithics in the larger grain; trace brownish yellow limonite; trace to common phlogopite mica flakes; scattered vari-color jasper; trace dark gray to black mafic mineral grains; primarily matrix supported in soft off white to brownish white ash/clay becomes grain supported in part and note white ash residue on sand grains below 3320’; matrix is brownish white ash; grades to and interbedded with associated tuffaceous silt/claystones; trace to common micro-thin and thin coaly lamina; common thin coal intervals; rare intact fragments are very slightly calcareous. Coal/Carbonaceous Shale (3400’-3440’) = black with dark brown and dark gray secondary hues; firm to slightly hard and brittle; flaky, scaly to platy; planar fracture dominant with trace conchoidal and bird-eye fracture; earthy to resinous luster; smooth to slightly gritty texture; trace out-gassing bubbles. Tuffaceous Claystone/Tuffaceous Siltstone (3480’-3560’) = medium light to light gray with slight brownish and greenish gray secondary hues; soft to moderately firm; hydrophilic; amorphous masses to slightly rounded firmer cuttings; expansive; easily lost in washing; poorly adhesive; poorly to moderately cohesive; trace to common micro-thin carbonaceous lamina; trace to common coal fines inclusions; trace to very slightly calcareous; interbedded with sandstone and occasional thin coals. Tuffaceous Sandstone/Sand/Sandstone (3500’-3680’) = medium light to medium gray with a slight brownish to greenish secondary hue; disaggregated to soft; moderately sorted; fine upper to medium lower and medium upper grain; locally moderately well sorted fine upper grain; angular to sub-angular and sub- discoidal; predominantly medium to medium dark gray lithics; 30 to 40% translucent white to clear colorless quartz/volcanics; trace dark gray to black mafic mineral grains; trace phlogopite mica and limonite; scattered mottled yellow jasper; primarily matrix supported in soft expansive hydrophilic ash/clay; locally grain supported; trace limonite stained firm waxy ash; trace pale greenish white mineral grains; interbedded with thin to moderate tuffaceous silt/claystone and ash beds; occasional very thin coal/carbonaceous shale stringers; rare intact fragments are very slightly calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (3680’-3780’) = medium light to light gray with slight brownish and greenish gray secondary hues; soft to moderately firm; hydrophilic; amorphous masses to slightly rounded firmer cuttings; expansive; easily lost in washing; poorly adhesive; poorly to moderately cohesive; common to abundant micro-thin carbonaceous lamina; trace to common coal fines inclusions; commonly very slightly to slightly sandy; included sand is very fine lower grain translucent white angular volcanics shards and quartz; common thin fine to medium grain sand intervals and coals; trace to very slightly calcareous; interbedded with sandstone and occasional thin coals. SUSAN DIONNE 7 9 Tuffaceous Sandstone/Sand/Sandstone (3780’-3900’) = medium light to medium gray with a slight brownish to greenish secondary hue; disaggregated to soft; moderately sorted; fine upper to medium lower and medium upper grain in the upper zone grading to poorly sorted with medium upper, coarse and very coarse with increasing depth; scattered granule fragments; angular to sub-angular and sub-discoidal; predominantly medium dark to medium gray lithics;3o to 40% translucent white to clear colorless quartz/volcanics; trace dark gray to black mafic mineral grains; trace phlogopite mica and limonite; trace to abundant brick red, orange, brown pale greenish white and pale rose grains beginning at 3880’; primarily matrix supported in soft expansive hydrophilic ash/clay; locally grain supported; trace limonite stained firm waxy ash; interbedded with thin to moderate tuffaceous silt/claystone and ash beds; occasional very thin coal/carbonaceous shale stringers; rare intact fragments are very slightly calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (3900’-4000’) = medium light to medium gray with slight brownish and greenish gray secondary hues; soft to moderately firm; amorphous masses to slightly rounded firmer fragments; hydrophilic; expansive; easily lost in sample preparation; poorly adhesive; poorly to moderately cohesive; common to abundant micro-thin carbonaceous lamina and coal fine inclusions; commonly very slightly to moderately sandy; sand is very fine lower grain trans- lucent white angular volcanics shards and quartz; occasional thin fine to medium grain sand intervals and coals; trace to very slightly calcareous; interbedded with sandstone and occasional thin coals. Tuffaceous Sandstone/Sand/Sandstone (4000’-4160’) = medium light to medium gray with a slight greenish secondary hue; disaggregated to soft; moderately sorted; fine upper to medium and fine lower predominate; trace to scattered larger sand grains and occasional granule size lithic fragments; angular to sub-angular and sub-discoidal; medium dark to medium gray and greenish gray lithics predominate; 30 to 40% translucent white to clear quartz/volcanic glass; trace black mafic mineral grains; trace to scattered brown and orange fragments; scattered phlogopite mica; primarily matrix supported in soft expansive off white ash/clay; occasional partial grain support; interbedded with similar tuffaceous silt/claystone and occasional thin to moderate coals; non to very slightly calcareous. Sand/Tuffaceous Sandstone/Tuffaceous Siltstone (4160’-4260’) = medium dark gray to grayish black with olive gray hues; 40% quartz/colorless volcanics with medium light to dark gray and occasional pale yellow-orange to red and blue-green lithics with scattered biotite and conglomeratic fragments of dark gray to brownish black siltstone; tuffaceous siltstone is medium light to medium gray; soft amorphous to firm tabular masses; carbonaceous micro-laminae commonly interbedded. Tuffaceous Siltstone/Sand/Tuffaceous Sandstone/Coal (4260’-4340’) = medium light to medium dark gray with brownish black to black hues; soft amorphous hydrophilic to firm masses; poorly cohesive; sand 40% quartz and volcanic glass shards with dark gray to grayish black and occasional orange lithics and biotite; matrix supported fine to upper medium grain tuffaceous sandstone fragments; sub-bituminous coal fragments and carbonaceous interbeds. Sand/Conglomeratic Sand (4340’-4440’) = medium gray; moderate salt and pepper appearance, individual grains dominantly light to medium gray, dark gray, clear to translucent quartz and volcanic glass, light to medium greenish gray; very fine upper to very coarse upper, dominantly medium upper to lower; angular to subangular; poor to fair sorting; disaggregated; trace light gray to light grayish white clayey supporting matrix; very soft; soluble; non calcareous; trace dark brown to black carbonaceous material. Coal (4440’-4460’) = black with very dark brown and dark gray secondary hues; very firm to slightly hard and brittle; flaky to platy, occasionally splintery; planar fracture dominant with trace conchoidal and bird- eye fracture; earthy to resinous luster; smooth to slightly silty to gritty texture; lignitic to sub bituminous; slight trace visible outgassing bubbles present. Tuffaceous Claystone/Tuffaceous Siltstone (4460’-4540’) = medium light to light gray with light brownish gray secondary hues; very soft and fragile to slightly firm; irregular shaped cuttings silty to clayey texture; dull to slightly waxy luster; soluble; slight to moderately expansive; poor to fair adhesiveness; fair cohesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; trace thin coal beds; trace very light gray ashy tuff; very fragile. SUSAN DIONNE 7 10 Sand/Sandstone (4530’-4640’) = medium gray with scattered salt and pepper appearance individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black, light to medium green to greenish gray; very fine lower to trace coarse lower, dominantly fine upper to medium lower; angular to sub-angular; poor to fair sorting; dominantly unconsolidated with common medium to dark gray sandstone; very fine grain; moderately hard; brittle at times moderate to very calcareous; commonly grading to a hard siltstone; trace thin coal beds. Tuffaceous Claystone/Tuffaceous Siltstone (4620’-4700’) = medium light to light gray; very soft and fragile to slightly firm; irregular shaped cuttings silty to clayey texture; dull to slightly earthy luster; moderate to very soluble; slight to moderately expansive; poor to fair adhesiveness; fair cohesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; trace thin coal beds; trace very light gray ashy tuff; very fragile; very calcareous. Sand/Sandstone (4680’-4780’) = medium gray with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black, light to medium green to greenish gray; very fine lower to trace coarse lower, dominantly fine upper to medium lower; angular to sub-angular; poor to fair sorting; dominantly unconsolidated with trace light to medium gray sandstone; very fine grain; fragile; very calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (4740’-4820’) = light to very light gray; very soft; shapeless, amorphous cuttings; silty to clayey texture; dull luster; hydrophilic; very soluble; moderately expansive; poor cohesiveness; poor to fair adhesiveness; non calcareous trace light to medium light gray siltstone; brittle to firm; very calcareous; commonly grades between silty sandstone and sandy siltstone; trace thin coals; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Sand/Sandstone (4800’-4880’) = medium gray with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black, medium to greenish gray; very fine lower to coarse lower, dominantly fine upper to medium lower; angular to sub-angular; poor to fair sorting; dominantly disaggregated with trace to common light to medium gray, fine grain sandstone; firm to moderately hard to brittle; very calcareous; trace thin coals. Tuffaceous Claystone/Tuffaceous Siltstone (4880’-4960’) = medium light to light gray; very soft and fragile to slightly firm; irregular shaped cuttings silty to clayey texture; dull to slightly earthy luster; moderate to very soluble; slight to moderately expansive; poor to fair adhesiveness; fair cohesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Sand/Sandstone (4940’-5020’) = medium light gray to greenish gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, dark gray to greenish gray, trace rust and orange lithics; very fine lower to medium upper, dominantly fine upper to lower; angular to sub-angular; moderately well sorted; dominantly unconsolidated with trace medium light gray sandstone; fine to very fine grain; brittle; very calcareous cement. Tuffaceous Claystone/Tuffaceous Siltstone (5000’-5080’) = light gray with light yellowish gray secondary hues; very soft to slightly firm; irregular, rounded to shapeless and globular cuttings; silty to clayey texture; dull to slightly waxy luster; hydrophilic; very soluble; moderately expansive; poor to fair cohesiveness; poor adhesiveness; trace dark brown to black micro-thin carbonaceous laminations and inclusions; non calcareous; trace thin coal beds. Coal (5075’-5130’) = grayish black to black with brownish black hues; sub- bituminous with interbedded carbonaceous siltstones and tuffaceous siltstones and claystones; conchoidal fracture to bedding plane parting. Tuffaceous Siltstone/Tuffaceous Claystone/Calcareous Tuff (5080’-5200’) = medium gray to olive black with dark greenish gray hues; expansive hydrophilic tuffaceous claystone grading to firm tabular siltstone with occasional carbonaceous interbedding; intermixed disaggregated sand and sandstone fragments; calcareous tuff reacts with acid. Tuffaceous Sandstone (5105’-5200’) = upper to lower very fine; silt/ash matrix supported; sub-rounded to sub-angular. SUSAN DIONNE 7 11 Coal (5200’-5320’) = black with dark brown secondary hues; very firm to moderately hard, brittle at times; massive to platy and flaky; planar fracture dominant with abundant conchoidal and bird-eye fracture; earthy to resinous to waxy luster; smooth to silty texture; abundant outgassing observed; trace amber present in numerous thin beds and occasionally thicker beds. Tuffaceous Claystone/Tuffaceous Siltstone (5240’-5320’) = very light to light gray; very soft; irregular, rounded to shapeless, globular cuttings; sticky; silty to clayey texture; dull luster; hydrophilic; very soluble; moderate to very expansive; poor to fair cohesiveness fair adhesiveness; very calcareous; trace light gray sandstone; very fine grain; fragile; very calcareous. Coal/Carbonaceous Shale (5310’-5400’) = very dark gray to black and brownish gray; moderately hard to hard; splintery irregular to slightly blocky sub-tabular fragments; hackly; very shaly character overall; silty in part; common ash residue on fractures and partings; common conchoidal fracture on harder coal fragments; no visible cleat; trace pyrite. Tuffaceous Sandstone/Sandstone/Sand Complex ( 5380’-5500’) = medium to medium light gray with slight yellowish to greenish secondary hues; mottled gray and yellow white in part; slightly firm to hard and disaggregated loose sand; friable in part; fine lower to very fine upper and medium lower grain; sub- angular to angular; translucent white to rare clear colorless quartz/volcanics predominate; 40 to 50% medium to light gray lithics; trace dark gray and black mafic mineral/lithics; trace locally common pale rose and orange jasper; trace brown limonite stained quartz and occasional limonite masses; trace amber color clear quartz; grades to and interbedded with similar tuffaceous siltstone; generally matrix supported in yellowish white to very light gray white ash/clay; below 5460’ friable calcite cemented grain supported hard ashy sandstone; common thin to moderate ash with abundant very fine grain angular volcanic shards; occasional coal/carbonaceous shales; moderately calcareous overall. Coal/Carbonaceous Shale (5500’-5560’) = medium to dark brownish gray to black; very firm to hard; splintery irregular to slightly blocky/sub-tabular; fragments; hackly; moderately shaly in part; moderately silty to slightly sandy lignitic; grading to carbonaceous shale; trace ash residue on fractures and partings; occasional harder blocky sub-bituminous fragments show poor conchoidal fracture. Tuffaceous Siltstone/Tuffaceous Claystone (5600’-5700’) = medium light to medium gray with a slight to very slight olive green secondary hue; soft to slightly firm and trace firm; globular clayey to irregular slightly rounded fragments; grades from clean tuffaceous claystone to slightly sandy tuffaceous siltstone with trace to abundant micro-thin to thin carbonaceous lamina; non to slightly adhesive; slightly to non cohesive; expansive; moderately hydrophilic; interbedded with thin tuffaceous sandstones, occasional hard very fine grain calcareous sands, and both silicic and calcareous tuff/ash trace to non calcareous overall. Sand/Sandstone (5740’-5830’) = medium to medium light gray to greenish gray overall with moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray, dark gray; very fine lower to medium lower, dominantly fine upper to lower; angular to sub-angular; moderately well to well sorted; friable to unconsolidated; common sandstone fragments are same as individual grains with a light gray ashy/clayey supporting matrix/cement; very calcareous; very fragile; common to abundant coals. Tuffaceous Claystone/Tuffaceous Siltstone (5810’-5900’) = very light gray to light gray with light yellowish gray secondary hues; very soft to slightly firm; shapeless, globular to rounded cuttings; silty to clayey texture; dull luster; very soluble; moderately expansive; poor to fair cohesiveness and adhesiveness; non to slightly calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; abundant thin coals. SUSAN DIONNE 7 12 Sand (5880’-5960’) = medium to medium light gray to greenish gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light o medium gray to greenish gray, dark gray; very fine lower to medium lower, dominantly fine upper to lower; angular to sub-angular; moderately well to well sorted; friable to unconsolidated; non to slightly calcareous. Coal (5940’-6000’) = black with dark brown and dark grayish brown secondary hues; firm to hard; platy to flaky; planar fracture dominant with trace conchoidal fracture; earthy to resinous luster; smooth to gritty texture; poorly developed; occasionally grading to carbonaceous shale; no to trace visible out gassing bubbles. Tuffaceous Claystone/Tuffaceous Siltstone (5980’-6080’) = very light gray to light gray with light yellowish gray secondary hues; very soft to slightly firm; silty to clayey texture; dull luster; hydrophilic moderately expansive; moderate to very soluble; poor to fair cohesiveness; poor adhesiveness; trace thin coals and dark brown to black micro-thin carbonaceous laminations and inclusions; trace light to medium gray ashy tuff; very fragile; non calcareous overall. Sand/Sandstone (6050’-6160’) = medium to medium light gray to greenish gray overall with moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light medium gray to greenish gray, dark gray; very fine lower to medium lower, dominantly fine upper to lower; angular to sub-angular; moderately well to well sorted; friable to unconsolidated; common sandstone fragments are same as individual grains with a light gray ashy/clayey supporting matrix/cement; very calcareous; very fragile; trace thin coals. Coal (6110’-6200’) = black with dark brown secondary hues; very firm to moderately hard; brittle at times; platy to flaky; planar fracture dominant; smooth to slightly gritty texture; earthy to resinous luster; lignitic to sub-bituminous; no outgassing observed; present as very thin beds. Tuffaceous Claystone/Tuffaceous Siltstone (6180’-6280’) = very light gray to light gray with light yellowish gray secondary hues; very soft to slightly firm; irregular shaped cuttings; silty to clayey texture; dull luster; hydrophilic moderately expansive; moderate to very soluble; poor to fair cohesiveness; poor adhesiveness; trace thin coals and dark brown to black micro-thin carbonaceous laminations and inclusions; trace light to medium gray ashy tuff; very fragile; very calcareous overall. Sand/Sandstone (6240’-6330’) = medium to medium light gray to greenish gray overall, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to greenish gray, dark gray; very fine lower to medium lower, dominantly fine upper to lower; angular to subangular; moderately well to well sorted; friable to unconsolidated; common sandstone fragments are same as individual grains with a light gray ashy/clayey supporting matrix/cement; very calcareous; very fragile. Tuffaceous Claystone/Tuffaceous Siltstone (6300’-6380’) = very light gray to light gray; very soft to slightly firm; irregular shaped cuttings; silty to clayey texture; dull luster; hydrophilic moderately expansive; moderate to very soluble; poor to fair cohesiveness; poor adhesiveness; trace dark brown to black micro- thin carbonaceous laminations and inclusions; moderate to very calcareous. Sand/Sandstone/Conglomeratic Sand (6380’-6560’) = medium to medium light gray; slight greenish secondary hue in bulk; firm to hard and disaggregated; moderately poorly to moderately sorted; medium lower to fine upper grain in the upper zone; grades to medium upper , coarse and scattered granule with depth; occasional 3 to 5 mm pebble fragments; sub-angular to angular; translucent white and yellowish white quartz/volcanics predominate; common to abundant clear colorless quartz/volcanics; 20 to 30% light to medium gray lithics; trace dark gray lithic/mineral grains; trace brown, yellow and orange mineral grains; trace small angular pyrite masses; intact fragments are primarily well indurated grain supported, calcite cemented; locally clean grain supported with fair visible porosity; thin to moderately bedded with abundant tuffaceous silt/claystone interbeds and occasional poor quality coal/carbonaceous shale , silicic ash and calcareous tuff inter- beds; slightly to moderately calcareous overall. SUSAN DIONNE 7 13 Tuffaceous Siltstone/Tuffaceous Claystone (6500’-6600’) = medium to medium light gray with a slight greenish secondary hue; slightly firm to soft sticky fragments; trace moderately firm; silty to smooth clayey texture; silts- stone tends to be slightly sandy; dull earthy to silky luster; micro-sparkly appearance in part; hydrophilic; expansive; slightly to non adhesive; moderately cohesive; trace to common micro-thin carbonaceous lamina; trace coal fines inclusions; interbedded with and grading to fine and very fine grain calcite cemented silty sandstone; soft light bluish gray non tuffaceous siltstone and both silicic and calcareous ash/tuff; very slightly to non calcareous. Coal (6600-6700’) = very dark brownish black to black; moderately hard; sub-bituminous; hackly; irregular angular to splintery fragments; some fragments display poor conchoidal fracture and cleat; abundant ash residue on fractures and partings; trace carbonaceous shale. Sand/Sandstone/Conglomeratic Sand (6660’-6560’) = medium to medium light gray; slight greenish to bluish secondary hues; disaggregated to slightly firm; trace hard; moderately to poorly sorted; fine upper to medium lower grain predominate; locally with abundant medium upper; trace fine lower to very fine grain; sub-angular to angular; translucent white and yellow white to clear colorless quartz/volcanics with 20 to 30% light to medium gray lithics; trace dark gray lithics; trace dark to medium brown; scattered yellow and orange; generally matrix supported with some local grain supported sands; trace well indurated calcite cemented sandstone; occurs as moderate beds and thinner interbeds in associated tuffaceous silt/claystone complex; generally very slightly to moderately calcareous. Tuffaceous Siltstone/Tuffaceous Claystone (6800’-6900’) = medium to medium light gray with a slight greenish secondary hue; slightly firm to soft; trace moderately firm; silty to sandy and smooth clayey texture; pronounced microsparkly luster in silts, dull earthy in claystones; hydrophilic; expansive; easily lost in sample preparation; slightly to non adhesive; slightly cohesive; trace to abundant micro-thin carbonaceous lamina; scattered coal fines inclusions; interbedded with and grading to fine and very fine grain calcite cemented silty sandstone; trace light bluish gray non tuffaceous siltstone and both silicic and calcareous ash/tuff; very slightly to non calcareous. Sand/Sandstone (6900’-7000’) = medium light gray with a slight brownish secondary hue; soft to disaggregated; moderately well to well sorted; medium lower to fine upper grain predominates; trace to common fine lower; scattered medium upper; trace very fine grain calcite cemented sandstone; sub- angular to angular; translucent white and yellowish white to clear colorless quartz predominates; abundant to 20 % light to medium gray lithics; trace dark gray lithics; scattered brown, yellow and orange grains and mica flakes; rare thin tuffaceous siltstone and ash interbeds; occasional thin coal/carbonaceous shales; individual grains show some crystalline overgrowth residues; no intact fragments with visible matrix; trace to common off white to light brownish white calcareous tuff; overall very slightly calcareous. Sandstone (7000’-7050’) = light to medium light brownish gray; soft to disaggregated; very fine upper to fine lower grain; moderately to very silty to clean sand in part; grades to similar tuffaceous siltstone; non to very slightly calcareous. Sand/Sandstone (7050’-7120’) = medium light to medium gray; soft to disaggregated; moderately to moderately well sorted; medium lower to fine upper and medium upper; trace coarse; scattered lithic pebble fragments; angular to sub angular; primarily translucent white to clear quartz/volcanics; common hard angular dark to medium gray lithics; overall pepper in salt appearance; trace mottled clear and yellow jasper; trace brick red to orange jasper and brown lithics; trace to common mica; occasional thin coals; appears to be primarily ash supported in soft white to slightly yellow hydrophilic ash; common to trace hard angular fine grain well sandstone/tuffaceous sand; grades to very tuffaceous moderately sandy siltstone; moderately to very calcareous. Sand/Tuffaceous Sandstone (7200’-7300’) = very light gray with light bluish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, trace greenish gray, rust and black; very fine lower to medium lower, dominantly fine upper to lower; angular to sub-angular; moderately well sorted; very loosely consolidated with white to light grayish white ash component; very calcareous overall; very fragile to pulverulent. SUSAN DIONNE 7 14 Sand/Sandstone/Tuffaceous Sandstone/Conglomeratic Sand (7280’-7370’) = very light gray with light yellowish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass with trace amounts of light greenish gray, medium to dark gray, rust, black and pale rose; very fine lower to trace very coarse upper, dominantly fine upper to lower; angular to trace subrounded, dominantly sub- angular; moderately well sorted; dominantly unconsolidated with common ash supported sandstone; very calcareous; very fragile. Coal (7375’-7395’) = black with dark brown and dark gray secondary hues; very firm to moderately hard; occasionally brittle; platy to flaky; planar fracture dominant with trace conchoidal and bird-eye fracture present; earthy to resinous luster; smooth to silty texture; dominantly bituminous to sub-bituminous; trace to scattered outgassing bubbles present; commonly grading to carbonaceous shale. Tuffaceous Siltstone/Tuffaceous Claystone (7400’-7480’) = light brownish gray to medium light gray; soft to fragile; irregular shaped cuttings; silty to slightly gritty texture; dull, earthy luster; moderately soluble and expansive poor to fair cohesiveness; poor adhesiveness; slight to moderately calcareous; common to abundant dark brown to black micro thin carbonaceous laminations and inclusions; medium light gray siltstone commonly grades to very fine silty sand-stone/sandy siltstone. Sand/Tuffaceous Sandstone (7200’-7300’) = very light gray with light brownish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, trace greenish gray, rust and black; very fine lower to medium lower, dominantly fine upper to lower; angular to sub-angular; moderately well sorted; very loosely consolidated with white to light brownish gray ash component; very calcareous overall; very fragile to pulverulent. Coal (7595’-7710’) = black with dark brown and dark gray secondary hues; very firm to moderately hard; brittle to fragile; platy to flaky; planar fracture dominant with trace conchoidal and bird-eye fracture present; earthy to resinous luster; smooth to silty texture; dominantly bituminous to sub-bituminous; abundant outgassing bubbles present. Tuffaceous Siltstone/Tuffaceous Claystone (7600’-7680’) = light brownish gray to medium light gray; soft to fragile; irregular shaped cuttings; silty to slightly gritty texture; dull, earthy luster; moderately soluble and expansive poor to fair cohesiveness; poor adhesiveness; slight to moderately calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions. Sand/Sandstone/Tuffaceous Sandstone (7660’-7740’) = light gray with yellowish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, trace light greenish gray, medium to dark gray and rust lithics; very fine lower to medium lower, dominantly fine upper to lower; angular to sub-angular; moderately well sorted; dominantly unconsolidated with common light gray ash supported pieces; very fragile; moderate to very calcareous trace light gray to light brownish gray sandy siltstone/silty sandstone; very fragile; non to slightly calcareous. Tuffaceous Siltstone/Tuffaceous Claystone ( 7720’-7800’) = medium light to light gray with yellowish and brownish gray secondary hues; very soft and fragile; silty to clayey to slightly gritty texture; dull, earthy to slightly sparkly luster; slight to moderately expansive; moderate to very soluble; moderate to very calcareous. Coal (7800’-7880’) = very dark grayish black to black and medium brown; hard to very firm and firm; irregular angular to tabular and splintery/hackly fragments; shaly in part; sub-bituminous to lignitic vigorous prolonged outgassing; some fragments display micro-banding of higher quality coal and contaminant particulate material; trace to common conchoidal fracture; cleat present some fragments; trace fragments with abundant micro-fine pyrite. SUSAN DIONNE 7 15 Tuffaceous Sand/Sandstone (7880’-7980’) = light to medium light gray with a slight greenish to yellowish secondary hue; soft to firm and disaggregated; moderately well to well sorted; fine upper to very fine upper predominate; common very fine lower; trace medium lower; sub angular to angular; translucent white to clear colorless quartz/volcanics; common medium to light gray lithic/mineral grains; trace dark gray, brown, reddish brown; and yellow grains; trace mica; appears to be entirely matrix supported in soft hydrophilic yellowish white to very light brownish white ash; matrix is very soluble and easily washes away in circulation and sample preparation; common thin coal stringers and ash interbeds; grades to similar sandy tuffaceous siltstone and tuffaceous claystone; moderately calcareous. Tuffaceous Siltstone/Claystone (7980’-8100’) = medium light to medium gray with a slight greenish to yellowish secondary hue; soft to firm; slightly rounded-eroded irregular to tabular fragments; silty to sandy texture; dull earthy luster; microsparkly appearance in part; trace to abundant micro thin to thin carbonaceous lamina; common fine to very fine grain coal fines in part; hydrophilic; non to slightly cohesive; non to slightly adhesive; contains trace to abundant very fine grains quartz/volcanics sand; slightly calcareous. Coal (8100’-8200’) = very dark grayish black to black and medium brown; hard to very firm and firm; blocky to tabular and splintery/hackly fragments; slightly shaly in part; sub-bituminous to lignitic; vigorous outgassing quickly subsides; generally at least slightly silty; trace to common conchoidal fracture; cleat becoming more pronounced; grades to brown silty to slightly sandy lignite; trace limonite stained silt on some fractures and partings. Sand/Sandstone/Tuffaceous Sand (8100’-8200’) = light to medium light gray; slight brownish to yellowish secondary hues; soft to firm and disaggregated; well to moderately well sorted; very fine upper to fine lower and fine upper grain; scattered larger grains; sub-angular to angular; primarily translucent white to translucent quartz/volcanics with variable to 20% medium to light gray lithic/mineral grains; trace pale rose, brown, reddish brown and gray-blue grains; trace limonite and mica flakes; matrix supported in off white to brown- white hydrophilic ash; interbedded with thin to moderate tuffaceous siltstone/claystone, ash and coals; slightly to moderately calcareous. Coal (8250’-8300’) = very dark grayish black to black and medium brown; hard to very firm and firm; splintery/hackly to blocky/tabular fragments; moderately shaly; sub-bituminous to lignitic; vigorous outgassing quickly subsides; slightly silty; grades to very silty carbonaceous shale and lignite; appears as moderate beds with abundant thin tuffaceous silt/clay sand interbeds; occasionally as thicker coals. Sand/Sandstone (8300’-8360’) = light to very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray, light greenish gray black and pale rose; very fine lower to trace medium upper, dominantly fine lower to upper; angular to sub-angular; well to moderately well sorted; dominantly unconsolidated with scattered calcareous cemented sandstone; fragile; fine grain; common light brown to light brownish gray sandstone that grades between sandy siltstone/silty sandstone; fragile; non to slightly calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (8400’-8500’) = light brownish gray to yellowish gray; very soft; fragile; irregular shaped cuttings; silty to clayey texture; dull, earthy luster; slight to moderately expansive; moderate to very soluble; poor cohesiveness and adhesiveness; non calcareous; trace to common dark brown to black micro thin carbonaceous laminations and inclusions; abundant bluish white to yellowish gray ashy tuff; very fragile; very calcareous commonly acts as a supporting matrix for loose fine sand. Sand/Sandstone/Tuffaceous Sandstone (8480’-8570’) = light to very light gray with yellowish gray secondary hues overall with individual grains dominantly clear to translucent quartz and volcanic glass with trace amounts of dark gray, greenish gray, rust and pale rose lithics; very fine lower to fine upper, dominantly fine lower; angular to sub-angular; moderately well sorted; dominantly unconsolidated with abundant grayish white to bluish white ashy tuff as supporting matrix; very fragile; moderate to very calcareous; common light brown to light brownish gray sandstone; very fragile that grades between silty sandstone and sandy siltstone; slight to moderately calcareous. SUSAN DIONNE 7 16 Tuffaceous Siltstone/Claystone 8580’-8700’) = medium light to medium gray with a slight greenish secondary hue; slightly firm to soft; irregular blocky to sub-discoidal fragments and soft fluffy hydrated masses; dull earthy to matte luster; commonly with micro- sparkly appearance; slightly to very sandy; grades to silty tuffaceous claystone and tuffaceous sand; slightly to very carbonaceous; clean to abundant very thin to micro thin carbonaceous lamina; interbedded with occasional thin to moderate coals and both silicic and calcareous tuff/ash; trace very fine mica and pale orange to pale rose jasper volcanics; trace small angular pyrite masses and pyritic coal; slightly to very slightly calcareous. Coal (8700’-8800’) = very dark grayish black to black and medium brown; hard to firm; splintery/hackly to blocky; moderately to very shaly, slightly silty; sub-bituminous to lignitic; initial vigorous outgassing quickly subsides; grades to very silty carbonaceous shale and lignite; occurs as moderate to thin beds and abundant very thin interbeds; interbedded with tuffaceous sandstone/siltstone and ash; trace micro-fine pyrite and small pyrite masses. Tuffaceous Sand/Sandstone (8700’-8900’) = medium light gray with a slight greenish to brownish secondary hue; mottled in part; soft to very firm and disaggregated; moderately well to well sorted; fine lower to fine upper and very fine upper; scattered medium lower; sub-angular to angular; translucent white to clear quartz/volcanics predominate; 30 to 40% medium to light gray lithic/mineral grains; trace dark gray, rose, medium orange gray and brown grains; trace mica and pyrite; generally matrix supported in firm to soft hydrophilic light to medium light gray/brownish gray ash; local grain support; thinly bedded/interbedded with similar tuffaceous silt/claystone and both silicic and calcareous tuff/ash; abundant thin coal and carbonaceous shale interbeds; sandstone is occasionally carbonaceous; occasional massive coals; slightly to moderately calcareous. Tuffaceous Siltstone/Claystone 8900’-9000’) = medium to medium light gray and brownish gray; slight greenish to yellowish secondary hues in part; slightly firm to soft and firm; dull earthy to matte luster; commonly with micro-sparkly appearance; slightly to very sandy; grades to silty tuffaceous claystone and tuffaceous sand; slightly to very carbonaceous; clean to abundant very thin to micro-thin carbonaceous lamina; interbedded with occasional thin to moderate coals and both silicic and calcareous tuff/ash; trace jasper, orange volcanics, very fine mica and rose quartz; very slightly to slightly calcareous. Tuffaceous Sand/Sandstone (9000’-9100’) = medium light gray with a slight brownish to yellowish secondary hue; slightly firm to disaggregated to firm; well to moderately sorted; sub-angular to angular; fine upper to fine lower, in the upper zone becoming medium lower to fine upper and medium upper with depth; scattered larger grains; translucent white to clear quartz/volcanics predominate; 30 to 40% medium to light gray lithics; trace dark gray and brown-gray lithics; primarily ash matrix supported; locally grain supported; interbedded with tuffaceous silt/claystone, coals, and ash slightly calcareous. Coal/Carbonaceous Shale (9070’-9140’) = black with dark brown secondary hues; very firm to hard; platy to flaky; planar fracture dominant with trace birdeye and conchoidal fracture present; earthy to resinous luster; smooth to silty texture; trace visible outgassing bubbles observed; commonly grades to dark brown carbonaceous shale; firm to hard; dull luster; matte texture. Sand/Sandstone/Tuffaceous Sandstone (9160’-9250’) = light gray with light brownish gray and yellowish gray secondary hues overall; individual grains dominantly clear to translucent quartz and volcanic glass; trace light to medium gray, light greenish gray, white, black, rust and red grains; very fine lower to coarse lower, dominantly fine upper to lower; angular to subangular; poor to fair sorting; dominantly disaggregated with abundant ashy tuff supported sandstone; very fragile; individual sand grains attached to very calcareous bluish/grayish white ash; common to abundant thin coals. Tuffaceous Claystone/Tuffaceous Siltstone (9240’-9320’) = medium light to light gray with light brownish gray secondary hues; soft, mushy; irregular cuttings; silty to clayey to slightly gritty texture; dull luster; hydrophilic; soluble; slight to moderately expansive; poor cohesiveness and adhesiveness; non to slightly calcareous; trace to common dark brown to black micro thin carbonaceous laminations and particles. Coal/Carbonaceous Shale (9290’-9340’) = black with dark brown secondary hues; very firm to hard; platy to flaky; planar fracture dominant with trace birdeye and conchoidal fracture present; earthy to resinous luster; smooth to silty texture; slight trace visible outgassing. SUSAN DIONNE 7 17 Sand/Conglomeratic Sand/Sandstone/Tuffaceous Sandstone (9350’-9440’) = light gray with bluish white secondary hues overall from ash content, individual grains dominantly clear to translucent quartz and volcanic glass, trace light to medium greenish gray, translucent green, pale rose, orange, white and black lithics; very fine lower to very coarse upper, dominantly fine upper to medium upper; angular to sub- angular; poorly sorted; dominantly unconsolidated with abundant bluish white/gray ashy tuff supported grains; very fragile; very calcareous; trace coal. Tuffaceous Claystone/Tuffaceous Siltstone (9420’-9520’) = medium light gray to light brownish gray with light olive gray secondary hues; soft; irregular rounded cuttings with trace pdc bit action appearance; silty to clayey to slightly gritty texture; dull to earthy luster; hydrophilic; moderately soluble and expansive; poor to fair cohesiveness poor adhesiveness; non to slightly calcareous; trace dark brown to black micro- thin carbonaceous laminations and particles. Coal (9470’-9550’) = black with dark brown secondary hues; firm to hard; occasionally brittle; platy to flaky; planar fracture dominant with scattered conchoidal and birdeye fracture present; polished to resinous luster; smooth to slightly silty texture; bituminous; abundant outgassing. Sand/Conglomeratic Sand/Sandstone/Tuffaceous Sandstone (9540’-9700’) = light gray; mottled; slight bluish gray secondary hue throughout; slight yellow to brownish staining in part; soft to slightly firm and disaggregated; moderately to poorly sorted; dominantly fine upper to medium lower; locally medium lower to medium upper with variable % fine, very fine, coarse and scattered very coarse grains; angular to sub- angular; scattered sub-spheroidal; predominantly translucent white/smokey and clear colorless quartz/volcanics; 20% light gray and gray-green lithics; trace dark gray to black mafic mineral/lithics give a salt and pepper appearance; trace brick red, orange and pale rose jasper/volcanics; trace clear greenish and yellow mineral/volcanics; primarily matrix supported in soft hydrophilic bluish white to yellow white ash; locally some grain support; rare intact non tuffaceous fragments; abundant silicic and calcareous tuffs; common thin to moderate coals and tuffaceous siltstone interbeds. Tuffaceous Siltstone/Tuffaceous Claystone (9640’-9820’) = medium light gray to brownish gray and brown; soft to slightly firm; irregular cuttings fragments; dull earthy luster; silty to slightly sandy texture; hydrophilic; slightly cohesive; non to slightly adhesive; trace to abundant micro-thin carbonaceous lamina; grades to lignitic tuffaceous siltstone; interbedded with thin to moderate coals, carbonaceous shales, silicic to calcareous tuff/ash and thicker tuffaceous sands, conglomerate and conglomeratic sands; sands range from very fine lower to granule and scattered small pebbles; slightly calcareous. Coal (9850'-9900') = black with dark brown secondary hues; firm to hard; occasionally brittle; platy to flaky; planar fracture dominant with scattered conchoidal and birdeye fracture present; polished to resinous luster; smooth to slightly silty texture; bituminous; trace to common outgassing. Sand/Sandstone/Conglomeratic Sand/Tuffaceous Sandstone (9860'-9960') = very light gray with yellowish gray secondary hue; abundant varicolored lithics, dominantly clear to translucent quartz and volcanic glass, trace orange, rust, pale rose, light translucent green, medium to dark gray and greenish gray grains; very fine lower to very coarse upper, dominantly fine upper to medium upper; poorly sorted; dominantly unconsolidated with common white ashy tuff supported sandstone; fragile; non calcareous. Tuffaceous Siltstone/Tuffaceous Claystone (9940'-10000') = very light gray to light yellowish gray; very soft and fragile; irregular, rounded cuttings; silty to slightly gritty texture; dull, earthy to slightly sparkly luster; moderate to very soluble; slightly expansive; trace dark brown to black micro thin carbonaceous laminations and inclusions; non to slightly calcareous; occasionally grading between sandy siltstone/silty sandstone. SUSAN DIONNE 7 18 Sand/Sandstone/Conglomeratic Sand/Tuffaceous Sandstone (10000'-10100') = very light gray overall with abundant varicolored grains, dominantly clear to translucent quartz and volcanic glass, trace orange, rust, pale rose, light translucent green, medium to dark gray and greenish gray; very fine lower to very coarse upper, dominantly fine upper to medium upper; angular to trace sub-rounded, dominantly subangular; poorly sorted; disaggregated; abundant bluish/grayish white ashy tuff supported sandstone; very fragile; non to moderately calcareous. Coal (10070'-10140') = black with dark brown secondary hues; firm to hard; occasionally brittle; platy to flaky; planar fracture dominant with scattered conchoidal and birdeye fracture present; polished to resinous luster; smooth to slightly silty texture; bituminous to sub-bituminous; occasionally grading to carbonaceous shale; trace to common outgassing. Tuffaceous Siltstone/Tuffaceous Claystone (10140'-10200') = very light gray to light yellowish gray; very soft and fragile; irregular cuttings habit; silty to slightly gritty texture; dull, earthy to slightly sparkly luster; soluble; slightly expansive; poor to fair cohesiveness; poor adhesiveness; non to slightly calcareous. Sand/Tuffaceous Sandstone/Conglomeratic Sand (10200'-10300') = very light to light gray overall with abundant varicolored lithics, dominantly clear to translucent quartz and volcanic glass, trace orange, rust, pale rose, light translucent green, medium to dark gray and greenish gray; very fine lower to very coarse upper with scattered pebble fragments, dominantly fine upper to medium lower and medium upper; mixed matrix and grain support; matrix is mottled yellowish gray ash/tuff; non to slightly calcareous. Sand/Tuffaceous Sandstone/Conglomeratic Sand (10300'-10400') = medium light yellowish gray to brownish gray; sample is primarily disaggregated loose sand locally dominated by mottled gray/yellow tuffaceous sandstone and light gray silica cemented sandstone; angular to subangular and slightly rounded; medium lower to fine upper and medium upper predominate; common to very abundant coarse and granule with occasional small slightly rounded to angular pebbles; and pebble fragments; translucent white to clear colorless quartz/volcanics dominate; trace to abundant light to medium gray and brownish gray lithics trace to common yellowish brown, orange, red orange, pale green and blue-gray lithic/mineral grains; scattered pale rose and medium green mineral/volcanics; generally ash matrix supported; some local grain support; slightly calcareous. Tuffaceous Siltstone ( 10400'-10500') = medium light gray to brown; slightly firm to soft; irregular angular eroded to blocky fragments; dull earthy luster; gritty to silty texture; carbonaceous in part; common micro thin carbonaceous lamina; trace light to medium gray carbonaceous laminated tuffaceous claystone and shale; slightly to non calcareous. Sand/Tuffaceous Sand/Sand Conglomerate (10420'-10580') = medium light gray with a slight bluish secondary hue; mottled yellowish gray in the tuffaceous material; poorly sorted above 10520' well sorted in the show interval; angular to sub-angular; trace slightly rounded; translucent white to smokey and clear colorless quartz/volcanics predominate; 10 to 20% light gray lithic mineral; trace to abundant dark gray to black mafic mineral grains in the well sorted clean grain supported material present in show samples between 10520 and 10580' (salt and pepper sand)trace pale rose pale green, mottle red orange and light blue-gray lithic/mineral grains; principally grain supported; interbedded with thin carbonaceous tuffaceous siltstone, ash and thin coals; coals may be clastic rather than as beds; slightly calcareous. Coal (10600'-10640') = black to very dark gray-black and dark brown-black; moderately hard; brittle; hackly in part; common conchoidal fracture; pronounced cleat; abundant outgassing; slightly silty/lignitic in part; grades to carbonaceous shale. SUSAN DIONNE 7 19 Tuffaceous Siltstone (10620'-10720') = medium brownish gray to medium and light gray with slight bluish secondary hues; slightly firm; crumbly/carbonaceous in part; dull earthy to micro-sparkly luster; silty to sandy texture; common micro-thin carbonaceous lamina; trace fluffy brown sandy carbonaceous siltstone; grades to similar carbonaceous silty tuffaceous sandstone; common sandstone and thin coal interbeds; material is non adhesive; slightly cohesive; very slightly to non calcareous. Coal (10700'-10780') = black to very dark gray-black and dark brown-black; moderately hard; brittle; hackly in part; splintery to irregular blocky fragments; common conchoidal fracture; pronounced cleat; slightly silty in part; grades to silty carbonaceous sand, carbonaceous shale and tuffaceous carbonaceous siltstone; common thin sand and ash interbeds; sand/conglomeratic sand/tuffaceous. Sandstone (10760'-10840') = medium to medium light gray; abundant multi-colored grains, dominantly clear to translucent quartz and volcanic glass with trace amounts of light to medium greenish gray, medium to dark gray, black and light translucent green grains; very fine lower to pebble (4mm), dominantly fine upper to medium upper; angular to trace subrounded pebble, dominantly subangular poorly sorted; dominantly disaggregated; abundant light bluish/grayish white ashy tuff supporting matrix; very fragile. Sand/Sandstone/Conglomeratic Sand/Tuffaceous Sandstone (10850'-10940') = light to very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace amounts of light to medium gray, light greenish gray, orange, black, white and light to medium translucent green; very fine upper to pebble and pebble fragments, dominantly fine upper to medium upper; angular to subrounded pebbles, dominantly subangular; poorly sorted; unconsolidated with trace to common ashy tuff supporting matrix; light bluish/grayish white; very fragile; non to very calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (10940'-11020') = light brownish gray to light gray with yellowish gray secondary hues; very soft; fragile; irregular, rounded cuttings; silty to slightly gritty texture; dull to earthy to slightly sparkly luster; moderate to very soluble; non to slightly expansive; poor cohesiveness and adhesiveness non to slightly calcareous; trace to common dark brown to black micro thin carbonaceous laminations and inclusions; light grayish brown siltstone commonly grades between silty sandstone and sandy siltstone; fragile; moderately calcareous. Sand/Conglomeratic Sand/Tuffaceous Sandstone (11020'-11090') = medium to medium light gray with abundant multi colored grains/clasts present, dominantly clear to translucent quartz and volcanic glass with trace amounts of light to medium greenish gray, medium to dark gray, black and light translucent green; very fine lower to pebble fragments, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poorly sorted; dominantly disaggregated. Sand/Sandstone/Conglomeratic Sand (11090'-11150') = very light gray over all with individual grains dominantly clear to translucent quartz and volcanic glass, trace amounts of varicolored lith very fine upper to trace very coarse upper, dominantly fine upper to medium lower; angular to subangular; moderately well sorted in fine to medium, poorly sorted in coarse range; disaggregated. Tuffaceous Claystone/Tuffaceous Siltstone (11140'-11240') = light brownish gray to light gray with yellowish gray secondary hues; soft to moderately firm; irregular to pdc bit action shaped cuttings; silty to gritty texture; earthy to slightly sparkly luster; moderate to very soluble; non to slightly expansive; poor adhesiveness; poor to fair cohesiveness; non to slightly calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions. Coal/Carbonaceous Shale (11230'-11250') = black with dark brown secondary hues; firm to hard; platy to flaky; planar fracture dominant with trace conchoidal and birdeye; smooth to silty texture; earthy to resinous luster; sub bituminous to bituminous; occasionally grading to a very dark brown carbonaceous shale/siltstone; trace outgassing. SUSAN DIONNE 7 20 Sand/Sandstone/Conglomeratic sand/Tuffaceous Sandstone (11260'-11340') = light to very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, with abundant varicolored liths; very fine upper to very coarse upper, dominantly fine upper to medium upper; angular to subangular with trace subrounded pebbles and pebble fragments; poorly sorted; unconsolidated with scattered ashy tuff supported grains; moderate to slightly calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (11360'-11440') = light brownish gray to light gray with yellowish gray secondary hues; slightly firm to soft and firm; dull earthy to silky/sub waxy luster; gritty/silty to waxy texture irregular to tabular fragments; slightly to non and moderately carbonaceous; slightly to non cohesive/adhesive; interbedded with firm sub-fissile smectite (logged as claystone), sand/tuffaceous sand/conglomeratic sand complex, moderate silicic and calcareous ash/tuffs and occasional thin lignitic/sub-bituminous coals; non to very slightly calcareous. Ash/Tuff (11400'-11500') = light gray-white to white, yellowish white brownish white and pink; soft to slightly firm fluffy/hydrophilic to waxy; clean to sandy; occurs as thin interbeds, matrix and blebs in associated tuffaceous sediments; both silicic and calcareous tuff/ash are present, occasionally as admixed material; tuffaceous sandstone/conglomeratic sand. Conglomerate (11480'-11620') = medium light gray with a slight yellowish secondary hue; soft to disaggregated; well to poorly sorted; angular to subangular predominate; occasional slightly rounded larger grains; fine upper to medium lower in the upper zone to medium lower, medium upper, coarse and granule with scattered larger fragments as depth increases; translucent white to clear and slightly smokey quartz/volcanics pre- dominate; trace to common light gray lithic/mineral grains; trace dark gray to black mafic mineral/lithics; trace pale rose, orange-red, mottles clear and red, pale blue and pale green lithic/mineral grains; primarily matrix supported in soft hydrophilic white to yellowish white, pink and brown ash/tuff; locally grain supported in part; slightly calcareous. Tuffaceous Siltstone/Tuffaceous Claystone (11600'-11700') = medium brown to medium brownish gray to light gray; slightly firm to soft and firm; dull earthy to silky/sub-waxy luster; gritty slightly sandy texture; irregular angular fragments; poorly fissile in part; moderately to very and non carbonaceous; common to abundant carbonaceous micro lamina; grades to similar shale; occurs as interbeds in the associated sand complex; non to very slightly calcareous. Conglomerate (11700'-11794') = medium light gray with a slight yellowish to brownish secondary hue; soft to disaggregated and very firm; moderately to poorly sorted; angular to sub-angular predominate; occasional slightly rounded larger grains; medium lower to fine upper, medium upper, coarse and scattered granule; translucent white to clear colored and slightly smokey quartz/volcanics predominate; trace to common light and very light gray lithic/mineral grains; trace black mafic mineral/volcanics; trace pale rose, orange, pale blue and rust; bluish white ashy tuff acts as a supporting matrix; very fragile; non calcareous. SUSAN DIONNE 7 21 3.2 Sampling Program SAMPLE MANIFEST: SUSAN DIONNE 7: BOXED WASHED AND DRIED SAMPLES 10 BOXES TOTAL: 1 SET OF 10 BOXES Operator: Marathon Oil Company Well Name: Susan Dionne 7 Field: Ninilchik Unit, Tyonek Pool County: Kenai Borough State: Alaska Company Representatives: Rowland Lawson, Larry McAllister, Tom Anglen Location: 368’ FSL, 1105’ FEL Sec 6, T1S, R13W SM Classification: Development, Gas API #: 50-13320594-00-00 Permit #: 211050 Activity Code: AFE # DD.11.23631.CAP.DRL Rig Name /Type: Glacier #1 /Land /Double Total Depth 11794’MD/7883’TVD Total Depth Formation: Tyonek Total Depth Date: July 9, 2011 Logging Geologists: Ralph Winkelman, John Lundy, Greg Hammond Sample Catchers: Craig Silva, Larry Resch Set Type and Purpose Interval Frequency Distribution 1 Washed and Dried Reference Samples 1700’ to 11794’ 20’ Intervals Fugro Data Solutions, Inc C/O Marathon Oil 3311 South US Highway 77 Schulenburg, Texas 78956 BOX INTERVALS: 1700’-2800’; 2800’-3760’; 3760’-4800’; 4800’-5700’; 5700’-6840’; 6840’-7800’; 7800’-8600’; 8600’-9700’; 9700’-10800’; 10800’-11794’TD SUSAN DIONNE 7 22 4 DRILLING DATA 4.1 Daily Activity Summary 6/13/2011: Rig up unit. Rig up drilling rig. 6/14/2011: Rig up unit. Rig up drilling rig. 6/15/2011: PTSM; pickup drift, makeup, stand back 5” drill pipe. PJSM; install knife valve, leaked, turn knife valve, pickup drift, makeup, stand back 5” HWDP and jars. PJSM; service rig and top drive and grease blocks. PJSM; nipple up diverter line and chain down, pickup lift subs, X-Os, stab, test diverter with state representative, test alarms and PVTs. PJSM; pickup, makeup bit, motor, pony, stabilizer, MWD and orient. PTSM; pickup, makeup X-O, shock sub, X-O pxp, organize rig floor. PJSM; drill from 98’ to 275’, pump 25 bbl sweep high vis. PJSM; pull out of hole from 275’ to 78’. PJSM; pickup BHA and run into hole, (3 CSNOP), from 78’ to 269’, tag 6’ fill. PJSM; drill from 269’ to 462’. 6/16/2011: PTSM; drill from 462’ to 739’ ART-1 AST-3. Drill from 739’ to 1053’. PTSM; drill from 1053’ to 1390’. Continue drilling from 1390’ to 1664’. 6/17/2011: PTSM; drill from 1664’ to 1705’. Circulate hole clean, pump high viscosity sweep, check flow. PJSM; pull out of hole with 5” drill pipe and HW drill pipe. Lay down shock sub and x-o’s, pull out of hole to shoe. Clean floor. PJSM; service rig top drive, grease crown and blocks. PJSM; run into hole to 1705’. Ratty from 1052’ to 1705’. Pump high viscosity sweep, circulate hole clean. PJSM; check flow, pull out of hole with 5” drill pipe to 620’. Tight at 963’. PJSM; run into hole to 1334’. Tight at 1100’. PTSM; continue running into hole from 1334’ to 1705’, circulate high viscosity sweep (b/u gas 43 units). PJSM; check flow, fill trip tank, pull out of hole from 1705’ to 765’. PJSM; pull out of hole from 765’, stand back HW drill pipe and jars, lay down BHA. Clear and clean floor. Rig up to run 10-3/4” casing. PJSM; change out bales, swap over tongs, rig up fill up line, rig up Weatherford. PJSM; run 10-3/4” casing, check floats, continue run into hole to 1250’. 6/18/2011: PTSM; run into hole with 10-3/4” casing as per progress to 1697’. Circulate and condition. Rig down Weatherford. PJSM; rig up cement head pump 20 bbls preflush with dxc, pump 2 bbls water, test lines from 2500 psi, drop plug, mix and pump bbls slurry, drop second plug, pump 5 bbls water. 149.88 bbl mud. Bump plug with 1000 psi over. Bleed off. Check floats. Cement in place at 0430. Rig down cement head and line. Lay down slips and mousehole. Flush lines and stack. PJSM; rig down kill, bleeder, fill up and trip tank lines. Nipple down diverter line, knife valve and adaptor flange. PJSM; load pipe racks with 5” drill pipe. Hot bolt diverter stack. Rig down chain and turnbuckle and trip tank actuator. Haul off mud. Rig up rig tongs and spinners. PTSM; gather tools, release weight, cut 10-3/4” casing, lay down, riser, flowline, remove diverter, remove cement dump valves, hammer up BOP stack, continue cleaning pits, change out shaker rubbers #1 and #2. PJSM; with Vetco, remove starter head and mark casing. PJSM; cut 20” casing, cut 10-3/4” casing, prep cuts and install well head. Test well head to 1700 psi for 10 minutes, run in lock. PJSM; nipple up, make up DSA and riser spool, bring BOP stack and make up, grease choke HSE valves, clean cuttings box. 6/19/2011: PTSM; hammer up flanges on spools and stack choke and kill valves, install fitting on stack and HCR, hookup Koomey lines. Rig up kill, choke lines, bell nipple, riser, flow line extension, bleeder, fill up and trip tank lines. Turnbuckle to stack, drip pan. Install mouse hole. Mix mud. PJSM; pick up, rig up test equipment, leak on matt board head. PJSM; change bails and elevators. Pick up PBA and install. PJSM; install plug in wellhead. Shell test BOPs. Fix leaks on gray lock on choke line and gland on wellhead. Finish installing BPA. PJSM; test BOPs to 250-3000 psi. Test annular, upper, lower Kelly cock, upper and lower pipe rams, floor, part, inside and outside kill valves. PTSM; test lower pipe rams, (3000 psi high test fail), hammer up spacer spool, test lower pipe rams (good), Koomey performance test, test blind rams, valves # 3, #4. Rig down test equipment, dart valve, floor valve, test plug, test joint. SUSAN DIONNE 7 23 PJSM; casing test, test casing to 1500 psi for 30 min. Set wear ring, run in lockdowns. PJSM; prep rig floor to pickup 5” drill pipe. PJSM; run into hole, pick up, drift, make up 5” drill pipe. PJSM; pull out of hole with 5” drill pipe, stand back, strap. PJSM; run into hole, pick up, drift, make up 5” drill pipe. PJSM; pull out of hole with 5” drill pipe, stand back, strap. PJSM; run into hole, pick up, drift, make up 5” drill pipe. 6/20/2011: PTSM. Continue picking up, drift and run into hole with 5” drill pipe to 1612’. Circulate hole. PJSM. Pull out of the hole, strap and stand back 5” drill pipe stands from 1612’. PJSM. Pick up/make up 5” drill pipe and run into hole to 720’. Continue running into hole with BHA from 720’ to 768’. Flow test tools. Run into hole with 5” drill pipe from 768’ to 1591’. Wash to 1610’. Ream cement from 1610’ and drill out float equipment to 1697’. Ream cement from 1697’ to 1705’. Drill from 1705’ to 1725’. Circulate and displace mud system to Flow-Pro mud. PJSM. Rig up and perform FIT to 15ppg-EMW. Drill from 1725’ to 1726’. PTSM. Drill from 1726’ to 2810’. 6/21/2011: PTSM. Drill from 2810’ to 3425’. Circulate bottoms up. Pump hi-viscosity sweep. PJSM. Pull out of the hole from 3425’ to 3294’. Ream to 3210’ (tight). Circulate bottoms up. Pull out of the hole from 3210’ to 2982’. PTSM. Pull out of the hole with 5” drill pipe from 2982’ to 1712’. Circulate bottoms up. PJSM. Service rig, top drive, blocks, crown and carrier. PJSM. Run into hole from 1712’ to 3301’. Wash from 3301’ to 3425’. PJSM. Drill from 3425’ to 3805’. 6/22/2011: PTSM; drill from 3805’ to 4249’. Troubleshoot charge pressure on pump #3. Drill from 4248’ to 4564’. PTSM; drill from 4564 to 4943’. Continue drilling from 4943’ to 5196’. Circulate bottoms up, pump low viscosity sweep. 6/23/2011: PTSM. Check for flow. Back ream from 5196’ to 1653’. Circulate bottoms up. PJSM. Change out saver sub and grabber dies. PJSM. Service rig, top drive, crown and blocks. PJSM. Run into hole from 1653’ to 2918’. PTSM Run into hole from 2918’ to 5133’. Wash from 5133’ to 5196’. PJSM. Drill from 5196’ to 5323’. Unable to pick up off bottom at connection. Work pipe free. Weight up to 9.5 PPG-MWE. Continue drilling from 5323’ to 5500’. 6/24/2011: PTSM. Drill from 5500’ to 5577’. Unable to pick up off bottom at connection. Work pipe free at 5577’. Drill from 5577’ to 5745’. Circulate while changing out liner, wear plate and gasket on #2 mud pump. Drill from 5745’ to 5957’. PTSM. Drill from 5957’ to 6273’. Mix and pump high and low viscosity sweep at 6050’. Continue drilling from 6050’ to 6689’. Mix and pump high and low viscosity sweep at 6496’ 6/25/2011: PTSM. Drill from 6589’ to 7050’. Circulate and replace swab in pump #3. Pump 50 bbls low viscosity sweep. Check for flow. Back ream from 7050’ to 6680’. PTSM. Back ream out of hole from 6688’ to 3236’. Circulate sweep. 6/26/2011: PTSM. Check for flow. Pull out of the hole from 3236’ to 768’ (SLM – no correction). PJSM. Stand back HWDP and jars. Lay down Filter, X-O, ATK motor, ontrack and bit (plugged into ontrack). Clean and clear floor. PJSM. Make up BHA #3 and run into hole to 1681’. PJSM. Service rig. Lube crown, blocks, top drive and carrier. PJSM. Slip drilling line. Continue running into hole from 1681’ to 7000’. Wash from 7000’ to 7050’. PTSM. Circulate. Pump sweep. Circulate bottoms up. Spot low torque pill. PJSM. Pull out of the hole from 7050’ to 5000’. PJSM Run into hole from 5000’ to 7050’. PJSM. Circulate and condition. PJSM. Pull out of the hole from 7050’ to 2200’ 6/27/2011: PTSM. Pull out of the hole from 2200’ to 607’. Lay down BHA #3. Pull wear bushing. Dummy run landing joint. PJSM. Change out 2 7/8 x 5 ½” upper rams with 7 5/8” casing rams. PJSM. Rig up[ and test 7 5/8” casing rams (250 – 3000 psi). Swap tongs, remove elevators and short bales. Change out snub post. Make up swedge. Rig up tongs. Move torque tube. PJSM. Run 7 5/8” casing as per program. PTSM. Continue running 7 5/8” casing as per program to shoe. Circulate bottoms up. Continue running 7 5/8” casing as per program to 6983’. Pick up/make up landing joint. 6/28/2011: Standby SUSAN DIONNE 7 24 6/29/2011: Standby 6/30/2011: Standby 7/1/2011: Standby 7/2/2011: Perform various rig maintenance. Pull wear ring. Rig up to test BOPE. Test annular to 250psi Low /2500psi High. Test gas alarms and PVT system. Perform accumulator drawdown test. Test all other BOPE (CMVs 1-12, kill line, Demco valve, upper and lower top drive valves, inside and outside kill lines, HCR and manual choke valves, upper and lower pipe rams, blind rams, floor valve, dart valve) to 250psi Low /3000psi High. Rig down BOPE testing equipment. Install wear ring. Rig up to test casing. Test casing to 3000psi for 30 minutes. Pick up, make up and run in hole bit, bit sub, 15 joints of HWDP and jars. Run in hole 4" drill pipe to 5035'. Perform BOP drill and choke drill. Continue running in hole with 4" drill pipe to 6739'. Wash down from 6739' and tag top of cement at 6886'. Drill out shoe track (cement, float, cement, casing shoe, rat hole) from 6886' to 7050'. Drill 20' of hole from 7050' to 7070'. Circulate bottoms up. Mix pre-displacement spacer. 7/3/2011: PTSM. Build and pump spacer. Displace with flow-pro mud. PJSM. Rig up and FIT test to 15ppg/MWE. Flow check. Lay down single. Circulate. Service and lubricate rig. Change out belt . Circulate and build mud. Change-out snub line. Load pipe rack. Prep casing. Work on #2 Carrier. Circulate. Prep casing. Oil cooler repaired on #2 carrier. Service mud line valves. Service choke manifold valves. Build dry job. PTSM. Pump dry job. PJSM. Pull out of the hole with 4” drill pipe heavy weight drill pipe and jars. Lay down bit and bit sub. PJSM. Pick up and make up bit, AutoTrack, OnTrack, litho track and plug in. Pick up and make up Mag Track. Strap sub and plug in. PJSM. Load radio active sources in tools. Pick up and make up sonic tool and filter, sub, float, CSOPs, and change over sub. Run into hole with HWDP and jars. Shallow test tools. 7/4/2011: PTSM. Run into hole with 4” drill pipe from 796’ to 7049’. PJSM. Wash from 7049’ to 7070’. PJSM. Down link and establish drilling parameters. PJSM. Drill from 7070’ to 7427’. PTSM. Drill from 7427’ to 7993’. Pump high vis sweep at 7750’. 7/5/2011: PTSM. Drill from 7993’ to 8369’. Circulate bottoms up. Pump low viscosity sweep. PJSM. Pull out of the hole from 8369’ to 7500’ (Short trip).PTSM. Pull out of the hole from 7500’ to shoe. PJSM. Service rig and top drive. Grease blocks and crown. PJSM. Run into hole with 4” drill pipe to 8308’. Wash from 8308’ to 8369’. PJSM. Drill from 8369’ to 8805’. 7/6/2011: Drill from 8805’ to 9748’. 7/7/2011: Drill from 9748’ to 10453’. 7/8/2011: Drill from 10453' to 11519'. 7/9/2011: Drill to TD @ 11794' MD. Circulate bottoms up then pump a 60 bbl low vis sweep followed by a 45 bbl high vis sweep, circulating bottoms up. Spot low torque pill. Pull out of hole to 9821'. Pump dry job. Pull out of hole to shoe (7032'). Cut and slip drill line. Continue pulling out of hole, 1593' as of midnight. 7/10/2011: Continue pulling out of the hole. Lay down bottom hole assembly #5 including downloading logging while drilling tools. Make up bottom hole assembly #6, and shallow test logging tools. Run in hole to casing shoe on elevators. Wash and ream from shoe (7032') to 8915' as of midnight. 7/11/2011: Run in hole with pressure logging tools on drill string from 8915' to 11443'. 7/12/2011: Run in hole with pressure logging tools on drill string from 11443 to 11678'. Pressure test formation as per plan. SUSAN DIONNE 7 25 7/13/2011: Continued with pressure logging program. Circulated bottoms up when logging program was completed. Pump dry job. Lay down pressure logging bottom hole assembly. Pick up clean out bottom hole assembly. Run in hole. Circulate at the shoe, and continue running in the hole. 7/14/2011: Continue with clean out run. Pump high vis sweep with nutplug to determine hole gauge. Circulate bottoms up and pull out of the hole. 7/15/2011: Continue pulling out of the hole, lay down bottom hole assembly. Test 4.5" variable rams. Rig up to run liner. Run liner to 10950' as of midnight. 7/16/2011: Run in hole with 4/5" liner. Circulate and condition hole. Pump cement. Pull out of hole while laying down excess drill pipe. Test BOPs. Pick up and run in hole with Polish Mill. 7/17/2011: Run in hole with Polish Mill assembly to top of liner. Polish out casing and liner bore with mills. Circulate bottoms up twice. (Note indications of cement at surface on first bottoms up). POOH. Lay down Polish mill assembly. P/U, M/U Packer assembly. RIH. Set ZXP packer and test to 1550psi. Begin POOH laying down 4” drill pipe. 7/18/2011: Continue POOH laying down 4” drill pipe. Break and lay down Packer running/setting tool, pump and crossover. Pull wear bushing. Change bails and elevators. Rig down rig tongs and spinners. Lay down subs and handling tools. Rig up Weatherford. P/U, M/U, RIH Seal/Tie-Back assembly and 4 ½” tubing as per Marathon. Rig up Pollard to run and band chemical injection line to string for last 1500’. Include SCSSV in upper tubing string. RIH to 6865’. Sting into packer CSR and pressure down to make sure seals engage. Pull from packer and space out. Install hanger and control lines. Pump 49 bbls of HiVis spacer. Shut down and clean Pit #5. Prep to displace. 7/19/2011: Displace annulus with inhibited KCL brine. Spot corrosion pill in annulus. Sting back into packer tie-back sleeve and land tubing. Secure tubing hanger. Pressure test annulus. Remove landing joint for 4 ½” string. (Hanger will have control line penetrations). Rig down Pollard. Drain stack. Test hanger. Install BPV. N/D BOPE. Perform operations to install and test tree. SUSAN DIONNE 7 26 4.2 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0 0 0 0 0 0 0 0 245 0.32 222.96 245.00 -0.50 -0.47 0.68 0.13 307 0.22 222.88 307.00 -0.71 -0.67 0.98 0.16 368 1.02 219.06 367.99 -1.22 -1.09 1.64 1.31 427 3.68 212.50 426.94 -3.23 -2.44 4.03 4.52 487 6.75 213.92 486.68 -7.78 -5.44 9.43 5.12 545 9.59 215.76 544.09 -14.53 -10.17 17.61 4.92 604 12.11 219.28 602.03 -23.31 -16.96 28.68 4.41 664 14.30 224.56 660.44 -33.46 -26.14 42.37 4.16 726 17.23 224.10 720.10 -45.51 -37.91 59.20 4.73 785 19.95 224.45 776.02 -58.98 -51.04 77.99 4.61 850 23.18 225.66 836.46 -75.84 -67.96 101.83 5.02 913 25.90 227.27 893.77 -93.84 -86.94 127.90 4.45 976 28.79 229.98 949.72 -112.94 -108.67 156.61 4.99 1040 31.72 228.65 1005.00 -133.97 -133.11 188.57 4.70 1103 34.68 228.86 1057.71 -156.71 -159.04 222.80 4.70 1166 38.07 229.12 1108.43 -181.22 -187.23 259.86 5.39 1230 41.48 229.50 1157.61 -207.91 -218.28 300.44 5.34 1293 44.98 228.60 1203.51 -236.19 -250.86 343.23 5.64 1356 48.19 227.22 1246.80 -266.87 -284.80 388.72 5.34 1419 51.07 226.62 1287.60 -299.66 -319.85 436.51 4.63 1483 54.11 225.73 1326.48 -334.86 -356.52 487.18 4.88 1547 57.28 225.62 1362.54 -371.79 -394.33 539.92 4.96 1611 60.07 225.59 1395.81 -410.04 -433.39 594.46 4.36 1651 61.83 226.50 1415.24 -434.31 -458.57 629.32 4.83 1728 63.27 225.88 1450.73 -481.61 -507.87 697.44 2.00 1791 64.15 226.19 1478.63 -520.82 -548.53 753.76 1.46 1855 64.19 226.39 1506.52 -560.63 -590.17 811.18 0.29 1917 64.18 226.81 1533.52 -598.98 -630.72 866.79 0.61 1981 64.20 226.42 1561.38 -638.55 -672.59 924.20 0.55 2044 64.32 226.93 1588.74 -677.49 -713.87 980.73 0.75 2107 64.26 226.72 1616.07 -716.33 -755.27 1037.27 0.32 2171 64.28 226.42 1643.86 -755.96 -797.14 1094.71 0.42 2235 64.22 226.09 1671.66 -795.82 -838.78 1152.17 0.47 2296 64.25 225.65 1698.18 -834.07 -878.21 1206.96 0.65 2360 64.30 225.53 1725.96 -874.42 -919.40 1264.49 0.19 2423 64.20 225.09 1753.33 -914.33 -959.74 1321.12 0.65 SUSAN DIONNE 7 27 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2487 64.32 225.10 1781.12 -955.02 -1000.57 1378.67 0.19 2550 64.18 225.14 1808.49 -995.06 -1040.78 1435.31 0.23 2613 64.26 224.91 1835.89 -1035.16 -1080.91 1491.95 0.35 2677 64.19 224.32 1863.72 -1076.18 -1121.39 1549.50 0.84 2740 64.26 224.37 1891.12 -1116.76 -1161.04 1606.17 0.13 2803 64.22 224.37 1918.50 -1157.31 -1200.72 1662.85 0.06 2866 64.22 224.76 1945.90 -1197.73 -1240.53 1719.51 0.56 2930 64.26 224.88 1973.71 -1238.62 -1281.16 1777.06 0.18 2993 64.21 225.17 2001.10 -1278.72 -1321.30 1833.71 0.42 3057 64.26 224.72 2028.92 -1319.51 -1362.01 1891.25 0.64 3120 64.22 225.09 2056.30 -1359.70 -1402.07 1947.90 0.53 3183 64.22 225.32 2083.70 -1399.67 -1442.32 2004.52 0.33 3246 64.25 225.21 2111.08 -1439.60 -1482.63 2061.15 0.16 3309 64.26 224.97 2138.45 -1479.67 -1522.82 2117.80 0.34 3373 64.09 225.31 2166.33 -1520.30 -1563.65 2175.30 0.55 3436 64.22 225.23 2193.79 -1560.20 -1603.93 2231.89 0.24 3500 64.19 225.16 2221.64 -1600.81 -1644.81 2289.41 0.11 3563 64.19 225.45 2249.07 -1640.70 -1685.13 2346.01 0.41 3626 64.19 225.56 2276.50 -1680.45 -1725.59 2402.60 0.16 3689 64.21 225.77 2303.92 -1720.09 -1766.16 2459.18 0.30 3752 64.25 225.89 2331.31 -1759.62 -1806.85 2515.77 0.18 3815 64.23 226.27 2358.69 -1798.98 -1847.72 2572.34 0.54 3878 64.29 226.07 2386.05 -1838.28 -1888.66 2628.92 0.30 3942 64.18 226.67 2413.87 -1878.05 -1930.38 2686.37 0.86 4004 64.25 226.52 2440.84 -1916.41 -1970.94 2741.99 0.25 4068 64.23 224.92 2468.65 -1956.65 -2012.20 2799.49 2.25 4131 64.22 223.14 2496.05 -1997.43 -2051.63 2856.17 2.54 4195 64.27 221.72 2523.86 -2039.98 -2090.52 2913.80 2.00 4258 64.26 220.26 2551.22 -2082.81 -2127.74 2970.55 2.09 4322 64.18 218.65 2579.05 -2127.31 -2164.36 3028.13 2.27 4385 64.25 217.80 2606.46 -2171.87 -2199.46 3084.75 1.22 4448 64.25 217.34 2633.83 -2216.85 -2234.06 3141.35 0.66 4511 64.30 216.98 2661.17 -2262.08 -2268.34 3197.93 0.52 4574 64.26 217.23 2688.51 -2307.35 -2302.58 3254.50 0.36 4638 64.25 217.13 2716.31 -2353.28 -2337.42 3311.97 0.14 4701 64.22 217.22 2743.70 -2398.49 -2371.70 3368.53 0.14 4764 64.22 216.94 2771.10 -2443.74 -2405.91 3425.08 0.40 4827 64.26 216.72 2798.48 -2489.16 -2439.92 3481.61 0.32 4890 64.26 216.67 2825.84 -2534.66 -2473.83 3538.14 0.07 4954 64.19 216.50 2853.67 -2580.94 -2508.18 3595.55 0.26 SUSAN DIONNE 7 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 5017 64.23 216.51 2881.08 -2626.53 -2541.93 3652.04 0.07 5080 64.26 216.68 2908.45 -2672.09 -2575.75 3708.55 0.25 5144 64.09 216.33 2936.33 -2718.40 -2610.02 3765.93 0.56 5207 64.26 216.15 2964.65 -2765.59 -2644.61 3824.17 0.36 5271 64.30 216.09 2991.55 -2810.71 -2677.54 3879.76 0.11 5334 64.36 215.92 3018.85 -2856.64 -2710.92 3936.26 0.26 5397 64.22 216.35 3046.18 -2902.48 -2744.39 3992.76 0.65 5460 64.22 216.18 3073.58 -2948.23 -2777.95 4049.23 0.24 5525 64.16 216.23 3101.88 -2995.44 -2812.51 4107.48 0.12 5587 64.31 216.40 3128.83 -3040.43 -2845.58 4163.07 0.35 5650 64.23 216.99 3156.18 -3085.94 -2879.49 4219.61 0.85 5713 64.26 217.42 3183.55 -3131.13 -2913.80 4276.17 0.62 5777 64.22 217.47 3211.37 -3176.90 -2948.85 4333.65 0.09 5841 64.32 217.39 3239.15 -3222.68 -2983.89 4391.15 0.19 5904 64.26 217.36 3266.48 -3267.79 -3018.35 4447.75 0.10 5968 64.25 217.27 3294.28 -3313.63 -3053.29 4505.23 0.13 6031 64.30 217.26 3321.63 -3358.80 -3087.66 4561.81 0.08 6094 64.25 217.42 3348.97 -3403.93 -3122.08 4618.41 0.24 6158 64.22 216.98 3376.79 -3449.84 -3156.93 4675.86 0.62 6221 64.23 216.92 3404.19 -3495.17 -3191.03 4732.40 0.09 6284 64.22 217.14 3431.58 -3540.47 -3225.20 4788.95 0.31 6347 64.26 216.67 3458.96 -3585.84 -3259.27 4845.49 0.67 6410 64.20 216.98 3486.35 -3631.25 -3293.27 4902.02 0.45 6474 64.23 216.87 3514.19 -3677.32 -3327.89 4959.44 0.16 6536 64.26 216.81 3541.13 -3722.01 -3361.38 5015.08 0.10 6599 64.29 216.59 3568.48 -3767.51 -3395.29 5071.62 0.32 6661 64.23 216.62 3595.40 -3812.35 -3428.60 5127.25 0.11 6725 64.19 216.84 3623.25 -3858.53 -3463.06 5184.66 0.32 6789 64.29 216.67 3651.06 -3904.71 -3497.55 5242.08 0.29 6853 64.25 216.66 3678.85 -3950.96 -3531.98 5299.52 0.06 6916 64.18 218.29 3706.25 -3995.98 -3566.49 5356.09 2.33 6980 64.16 219.69 3734.14 -4040.75 -3602.73 5413.63 1.97 6999 64.24 219.94 3742.41 -4053.89 -3613.69 5430.72 1.26 7120 63.99 218.02 3795.24 -4138.51 -3682.16 5539.45 1.44 7182 64.23 219.13 3822.31 -4182.11 -3716.94 5595.15 1.66 7245 64.33 220.85 3849.65 -4225.60 -3753.41 5651.88 2.46 7308 61.15 222.61 3878.50 -4267.39 -3790.68 5707.87 5.63 7370 57.91 222.83 3909.94 -4306.65 -3826.92 5761.29 5.23 7433 57.49 222.36 3943.60 -4345.85 -3862.96 5814.54 0.92 7496 56.99 222.87 3977.69 -4384.84 -3898.83 5867.51 1.05 SUSAN DIONNE 7 29 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 7560 56.75 223.73 4012.67 -4423.84 -3935.59 5921.08 1.19 7623 55.44 223.89 4047.81 -4461.57 -3971.79 5973.33 2.09 7686 52.54 223.11 4084.85 -4498.53 -4006.87 6024.26 4.71 7749 52.16 222.93 4123.33 -4535.00 -4040.90 6074.13 0.64 7813 52.03 223.23 4162.65 -4571.88 -4075.39 6124.61 0.42 7875 51.34 222.22 4201.09 -4607.62 -4108.39 6173.25 1.69 7938 49.06 222.31 4241.42 -4643.43 -4140.94 6221.65 3.62 8001 46.76 222.82 4283.64 -4677.87 -4172.56 6268.39 3.70 8063 44.59 221.84 4326.96 -4710.65 -4202.43 6312.74 3.68 8125 42.80 221.67 4371.79 -4742.60 -4230.96 6355.57 2.89 8189 40.64 220.50 4419.55 -4774.69 -4258.95 6398.15 3.59 8253 38.82 219.22 4468.77 -4806.08 -4285.17 6439.03 3.12 8317 37.52 220.08 4519.09 -4836.54 -4310.41 6478.56 2.19 8378 37.00 220.16 4567.64 -4864.78 -4334.21 6515.48 0.86 8440 36.33 221.99 4617.37 -4892.69 -4358.53 6552.49 2.07 8505 35.14 222.47 4670.13 -4920.80 -4384.04 6590.45 1.88 8569 33.46 222.98 4723.00 -4947.30 -4408.50 6626.51 2.66 8632 31.64 223.18 4776.10 -4972.06 -4431.65 6660.40 2.89 8695 29.59 223.19 4830.32 -4995.45 -4453.61 6692.47 3.25 8757 27.65 224.14 4884.74 -5016.93 -4474.11 6722.15 3.21 8821 25.76 223.13 4941.91 -5037.74 -4493.96 6750.89 3.04 8884 23.91 223.22 4999.08 -5057.04 -4512.06 6777.34 2.94 8947 22.17 222.09 5057.06 -5075.17 -4528.77 6801.99 2.85 9009 20.55 219.94 5114.80 -5092.19 -4543.60 6824.57 2.90 9073 18.78 219.18 5175.06 -5108.79 -4557.32 6846.09 2.79 9136 16.91 217.49 5235.03 -5123.92 -4569.31 6865.36 3.08 9200 15.42 218.44 5296.50 -5137.97 -4580.26 6883.14 2.36 9263 14.39 221.47 5357.38 -5150.40 -4590.65 6899.33 2.05 9326 11.82 224.68 5418.73 -5160.86 -4600.38 6913.60 4.24 9389 9.90 226.83 5480.60 -5169.15 -4608.86 6925.44 3.11 9453 8.54 223.31 5543.77 -5176.37 -4616.14 6935.67 2.30 9516 7.19 218.18 5606.18 -5182.88 -4621.78 6944.28 2.41 9578 5.67 215.60 5667.79 -5188.42 -4625.96 6951.20 2.49 9642 4.69 204.09 5731.53 -5193.38 -4628.87 6956.84 2.22 9705 4.10 192.95 5794.34 -5197.92 -4630.43 6961.27 1.64 9768 2.73 176.12 5857.23 -5201.61 -4630.83 6964.29 2.67 9829 1.81 182.12 5918.18 -5204.03 -4630.77 6966.05 1.56 9892 1.54 191.19 5981.16 -5205.85 -4630.97 6967.55 0.60 9956 1.28 209.42 6045.14 -5207.32 -4631.49 6968.99 0.81 10020 0.34 187.50 6109.13 -5208.13 -4631.86 6969.84 1.52 10083 0.35 85.28 6172.13 -5208.30 -4631.70 6969.86 0.85 SUSAN DIONNE 7 30 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 10147 0.39 272.10 6236.13 -5208.27 -4631.72 6969.86 1.15 10211 1.80 273.39 6300.12 -5208.21 -4632.94 6970.62 2.20 10274 0.43 46.70 6363.11 -5207.99 -4633.76 6971.00 3.36 10336 0.17 78.05 6425.11 -5207.81 -4633.50 6970.69 0.48 10399 0.78 258.50 6488.10 -5207.87 -4633.83 6970.96 1.51 10461 1.85 263.09 6550.09 -5208.08 -4635.23 6972.05 1.73 10525 1.14 264.94 6614.06 -5208.26 -4636.89 6973.29 1.11 10588 0.83 273.34 6677.06 -5208.29 -4637.97 6974.03 0.54 10649 0.90 259.61 6738.05 -5208.35 -4638.89 6974.68 0.36 10714 0.90 274.95 6803.04 -5208.40 -4639.90 6975.39 0.37 10777 0.18 319.70 6866.04 -5208.28 -4640.45 6975.67 1.24 10841 0.71 135.46 6930.04 -5208.48 -4640.24 6975.68 1.39 10904 2.12 131.32 6993.02 -5209.53 -4639.09 6975.70 2.24 10966 0.87 125.27 7054.99 -5210.56 -4637.85 6975.64 2.03 11029 0.44 105.58 7117.99 -5210.90 -4637.22 6975.48 0.76 11092 0.80 292.10 7180.99 -5210.80 -4637.40 6975.52 1.97 11156 2.16 291.65 7244.96 -5210.19 -4638.93 6976.08 2.13 11220 0.50 283.76 7308.95 -5209.68 -4640.32 6976.63 2.60 11282 2.30 97.67 7370.93 -5209.78 -4639.35 6976.06 4.51 11345 3.37 87.06 7433.85 -5209.85 -4636.25 6974.05 1.88 11408 1.43 82.65 7496.80 -5209.66 -4633.62 6972.15 3.09 11472 1.02 86.79 7560.78 -5209.52 -4632.26 6971.15 0.65 11534 0.63 86.03 7622.77 -5209.47 -4631.37 6970.52 0.63 11596 0.40 118.88 7684.77 -5209.55 -4630.84 6970.22 0.59 11658 0.31 294.43 7746.77 -5209.58 -4630.80 6970.23 1.14 11740 0.93 317.10 7828.77 -5209.00 -4631.46 6970.23 0.80 31 4. 3 B i t R e c o r d BI T NO . SI Z E “ TY P E S / N JE T S / TF A IN O U T F T H R S AV E RO P Ft / H R CO N D I T I O N RR 1 1 3 . 5 ” H C C M X 1 5 1 6 9 8 6 9 3x 1 8 , 1 x 1 6 0. 9 4 1 8 11 1 7 1 7 0 5 1 5 8 8 2 2 . 4 7 7 0 . 6 7 1 - 2 - W T - A - E - 1 - N O - T D 2 9 . 8 7 5 H C C H C D 5 0 4 Z X 7 1 3 5 0 9 6 6x 1 2 0. 6 6 2 4 17 0 5 7 0 5 0 5 3 4 4 5 6 . 3 3 9 4 . 8 7 1 - 1 - N T - A - X - I - N O - T D (2 R R ) 9 . 8 7 5 H C C H C D 5 0 4 Z X 7 1 3 5 0 9 6 6x 1 2 0. 6 6 2 4 17 0 5 7 0 5 0 1- 1 - N T - A - X - I - N O - T D Cl e a n o u t r u n o n l y 3 6 . 7 5 H C C S T X - 1 5 1 2 4 2 2 5 3x 2 0 0. 9 2 0 4 70 5 0 7 0 7 0 2 0 1 . 0 1 1 9 . 8 1 - 1 - N O - A - E - I - N O - B H A 4 6 . 7 5 H C C D P 5 0 5 X 7 1 2 3 1 5 9 5x 1 1 0. 4 6 4 0 70 7 0 1 1 7 9 4 4 7 2 4 8 5 . 1 5 5 . 5 1 - 1 - C T - T - X - N O - T D 3R R 6 . 7 5 H C C S T X - 1 5 1 2 4 2 2 5 3x 2 0 0. 9 2 0 4 11 7 9 4 1 1 7 9 4 0 0 0 NG Cl e a n o u t r u n o n l y 4R R 6 . 7 5 H C C D P 5 0 5 X 7 1 2 3 1 5 9 5x 1 1 0. 4 6 4 0 11 7 9 4 1 1 7 9 4 0 0 0 NG Cl e a n o u t r u n o n l y SU S A N D I O N N E 7 32 4. 4 M u d R e c o r d Co n t r a c t o r : M I S w a c o Mu d T y p e : G e l / G e l e x S p u d M u d 1 1 7 ’ – 1 7 2 5 ’ ; F l o P r o 1 7 2 5 ’ – 1 1 7 9 4 ’ Da t e D e p t h MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T p H Cl (ml/l) Ca (ml/l) 6/ 1 4 / 2 0 1 1 0 8 . 6 5 7 1 5 2 0 1 3 / 2 5 / 2 9 1 5 . 0 2 4 . 0 0 / 9 6 0 2 6 . 0 9 . 5 2 4 0 4 0 6/ 1 5 / 2 0 1 1 3 3 2 8 . 9 5 0 1 4 1 9 1 3 / 2 4 / 2 8 1 4 . 0 2 4 . 0 / 9 6 0 . 7 5 2 6 . 0 9 . 3 6 0 0 4 0 6/ 1 6 / 2 0 1 1 1 5 3 6 9 . 1 5 4 1 4 1 7 1 2 / 2 7 / 3 4 1 2 . 0 2 5 . 0 / 9 5 0 . 2 5 2 7 . 0 8 . 7 4 0 0 4 0 6/ 1 7 / 2 0 1 1 1 7 0 5 9 . 3 5 3 1 7 1 8 1 0 / 2 1 / 2 6 9 . 0 2 6 . 0 / 9 4 0 . 1 0 2 8 . 0 8 . 3 3 4 0 4 0 6/ 1 8 / 2 0 1 1 1 7 0 5 9 . 3 4 3 1 2 1 0 4 / 5 / 6 9 . 0 2 6 . 0 / 9 4 0 . 1 0 2 8 . 0 8 . 3 3 4 0 4 0 6/ 1 9 / 2 0 1 1 1 7 0 5 9 . 3 4 2 1 2 1 0 4 / 5 / 6 9 . 0 2 6 . 0 / 9 4 0 . 1 0 2 8 . 0 8 . 3 3 4 0 4 0 6/ 2 0 / 2 0 1 1 2 5 3 9 9 . 3 4 9 1 0 1 9 8 / 9 / 1 1 7 . 0 1 7 . 0 1 / 9 2 0 . 2 5 0 . 0 9 . 5 2 9 0 0 0 1 6 0 6/ 2 1 / 2 0 1 1 3 5 8 4 9 . 3 4 6 1 0 2 0 1 0 / 1 4 / 1 7 7 . 4 1 6 . 5 / 9 3 0 . 2 5 7 . 5 9 . 9 2 3 0 0 0 1 6 0 6/ 2 2 / 2 0 1 1 5 1 4 5 9 . 3 4 6 1 0 2 1 1 0 / 1 4 / 1 7 6 . 0 1 6 . 0 1 / 9 4 0 . 1 5 9 . 0 9 . 5 2 3 0 0 0 1 6 0 6/ 2 3 / 2 0 1 1 5 3 5 4 9 . 5 4 6 1 0 2 0 9 / 1 4 / 1 7 6 . 1 1 7 . 0 1 / 9 2 0 . 1 0 7 . 5 9 . 4 2 3 5 0 0 1 6 0 6/ 2 4 / 2 0 1 1 6 4 5 0 9 . 7 4 9 1 0 2 5 1 1 / 1 5 / 1 8 6 . 1 1 7 . 5 2 / 9 1 0 . 2 0 8 . 5 9 . 6 2 4 5 0 0 1 4 0 6/ 2 5 / 2 0 1 1 7 0 5 0 9 . 7 4 7 1 2 2 4 1 2 / 1 6 / 1 9 6 . 2 1 8 . 0 2 / 9 0 0 . 1 0 9 . 0 9 . 7 2 5 0 0 0 1 4 0 6/ 2 6 / 2 0 1 1 7 0 5 0 9 . 7 4 6 1 1 2 4 1 2 / 1 6 / 1 8 6 . 1 1 7 . 5 3 / 9 0 0 . 1 0 9 . 0 9 . 6 2 3 0 0 0 1 4 0 6/ 2 7 / 2 0 1 1 7 0 5 0 9 . 7 4 5 1 1 2 3 1 1 / 1 5 / 1 7 6 . 0 1 7 . 5 3 / 9 0 0 . 1 0 9 . 0 9 . 5 2 2 0 0 0 1 4 0 6/ 2 8 / 2 0 1 1 7 0 5 0 9 . 7 4 4 1 1 2 2 9 / 1 3 / 1 5 6 . 4 1 / 8 . 0 3 / 8 9 T R 9 . 0 9 . 6 2 2 0 0 0 1 6 0 6/ 2 9 / 2 0 1 1 7 0 5 0 S t a n d b y 6/ 3 0 / 2 0 1 1 7 0 5 0 S t a n d b y 7/ 1 / 2 0 1 1 7 0 5 0 S t a n d b y 7/ 2 / 2 0 1 1 7 0 5 0 9 . 7 4 8 1 2 2 3 1 0 / 1 4 / 1 6 6 . 2 1 8 . 0 3 / 8 9 T R 9 . 0 9 . 5 2 2 0 0 0 1 6 0 7/ 3 / 2 0 1 1 7 0 7 0 9 . 2 5 2 1 2 1 8 7 / 1 0 / 1 1 6 . 6 1 4 . 5 2 / 9 4 0 . 0 0 2 . 0 1 0 . 0 2 2 5 0 0 3 6 0 7/ 4 / 2 0 1 1 7 8 6 8 9 . 3 5 6 1 2 2 7 1 0 / 1 4 / 1 7 5 . 4 1 4 . 8 2 / 9 3 0 . 2 0 2 . 5 9 . 2 2 4 0 0 0 2 0 0 7/ 5 / 2 0 1 1 8 8 0 0 9 . 5 5 7 1 5 3 4 1 3 / 1 9 / 2 2 4 . 4 1 6 . 0 3 / 9 1 0 . 2 5 4 . 0 1 0 . 3 2 5 0 0 0 2 0 0 7/ 6 / 2 0 1 1 9 7 0 6 9 . 8 5 8 1 4 3 4 1 3 / 2 0 / 2 5 4 . 8 1 8 . 0 3 / 8 9 0 . 2 5 4 . 5 1 0 . 0 2 4 5 0 0 1 2 0 7/ 7 / 2 0 1 1 1 0 4 6 2 1 0 . 1 4 9 1 6 2 8 1 0 / 1 7 / 2 1 5 . 0 1 9 . 5 2 / 8 9 0 . 7 5 5 . 0 9 . 8 2 1 0 0 0 1 2 0 7/ 8 / 2 0 1 1 1 1 5 0 0 1 0 . 1 4 8 1 3 2 8 1 0 / 1 5 / 2 0 5 . 2 1 1 0 . 0 5 / 8 6 0 . 2 5 6 . 7 5 9 . 7 1 9 5 0 0 2 0 0 7/ 9 / 2 0 1 1 1 1 7 9 4 1 0 . 1 4 7 1 2 2 8 8 / 1 3 / 1 5 6 . 2 1 1 0 . 0 5 / 8 5 0 . 2 0 6 . 7 5 9 . 5 1 9 0 0 0 1 8 0 7/ 1 0 / 2 0 1 1 1 1 7 9 4 1 0 . 1 4 7 1 2 2 2 6 / 1 0 / 1 3 5 . 0 1 1 0 . 0 5 / 8 5 0 . 2 5 5 . 0 9 . 6 1 8 0 0 0 2 0 0 7/ 1 1 / 2 0 1 1 1 1 7 9 4 1 0 . 1 5 5 1 8 2 8 9 / 1 4 / 1 9 3 . 8 1 1 1 . 0 5 / 8 4 0 . 2 5 7 . 5 9 . 7 1 8 0 0 0 1 8 0 7/ 1 2 / 2 0 1 1 1 1 7 9 4 1 0 . 1 5 0 1 6 2 6 7 / 1 0 / 1 2 3 . 7 1 1 0 . 0 5 / 8 5 0 . 2 0 8 . 0 9 . 7 1 7 5 0 0 1 6 0 SU S A N D I O N N E 7 33 Co n t r a c t o r : M I S w a c o Mu d T y p e : G e l / G e l e x S p u d M u d 1 1 7 ’ – 1 7 2 5 ’ ; F l o P r o 1 7 2 5 ’ – 1 1 7 9 4 ’ Da t e D e p t h MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T p H Cl (ml/l) Ca (ml/l) 7/ 1 3 / 2 0 1 1 1 1 7 9 4 1 0 . 1 5 4 1 5 2 6 8 / 1 0 / 1 4 4 . 0 1 1 0 . 0 5 / 8 5 0 . 2 5 8 . 0 9 . 7 1 6 9 0 0 1 8 0 71 4 / 2 0 1 1 1 1 7 9 4 1 0 . 1 5 4 1 5 2 5 8 / 1 1 / 1 3 4 . 0 1 1 0 . 0 5 / 8 5 0 . 2 5 8 . 0 9 . 5 1 7 5 0 0 2 0 0 7/ 1 5 / 2 0 1 1 1 1 7 9 4 1 0 . 1 4 7 1 3 2 2 8 / 1 0 / 1 2 4 . 0 1 1 0 . 0 5 / 8 5 0 . 2 0 8 . 0 9 . 4 1 7 5 0 0 2 0 0 7/ 1 6 / 2 0 1 1 1 1 7 9 4 1 0 . 1 5 1 1 4 2 3 8 / 1 2 / 1 4 4 . 4 1 1 0 . 0 5 / 8 5 0 . 2 0 8 . 0 9 . 8 1 7 0 0 0 2 0 0 7/ 1 7 / 2 0 1 1 1 1 7 9 4 1 0 . 2 5 0 1 5 2 1 7 / 1 1 / 1 3 4 . 5 1 1 0 . 0 5 / 8 5 0 . 2 0 8 . 0 9 . 8 1 7 0 0 0 2 0 0 7/ 1 8 / 2 0 1 1 1 1 7 9 4 1 0 . 1 5 2 1 4 2 4 7 / 1 2 / 1 5 4 . 6 1 1 0 . 0 5 / 8 5 0 . 2 0 8 . 0 9 . 8 1 7 0 0 0 1 8 0 7/ 1 9 / 2 0 1 1 ( 6 8 6 5 ) 8 . 5 2 8 K C L B r i n e 8 . 4 1 4 5 0 0 3 2 0 Ab b r e v i a t i o n s : MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y PV = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t G e l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e Lo s s F C = F i l t e r C a k e O / W = O i l t o W a t e r r a t i o S o l s = S o l i d s S d = S a n d c o n t e n t M B T = M e t h y l e n e B l u e A l , P m = A l k a l i n i t y , M u d p H = A c i d i t y / B a s i c i t y C l = C h l o r i d e s C a = H a r d n e s s C a l c i u m n r = N o t R e c o r d e d SU S A N D I O N N E 7 34 4. 5 D r i l l i n g P r o g r e s s C h a r t D A Y S V E R S U S D E P T H 0 10 0 0 20 0 0 30 0 0 40 0 0 50 0 0 60 0 0 70 0 0 80 0 0 90 0 0 10 0 0 0 11 0 0 0 12 0 0 0 6 / 1 1 / 2 0 1 1 6 / 1 2 / 2 0 1 1 6 / 1 3 / 2 0 1 1 6 / 1 4 / 2 0 1 1 6 / 1 5 / 2 0 1 1 6 / 1 6 / 2 0 1 1 6 / 1 7 / 2 0 1 1 6 / 1 8 / 2 0 1 1 6 / 1 9 / 2 0 1 1 6 / 2 0 / 2 0 1 1 6 / 2 1 / 2 0 1 1 6 / 2 2 / 2 0 1 1 6 / 2 3 / 2 0 1 1 6 / 2 4 / 2 0 1 1 6 / 2 5 / 2 0 1 1 6 / 2 6 / 2 0 1 1 6 / 2 7 / 2 0 1 1 6 / 2 8 / 2 0 1 1 6 / 2 9 / 2 0 1 1 6 / 3 0 / 2 0 1 1 7 / 1 / 2 0 1 1 7 / 2 / 2 0 1 1 7 / 3 / 2 0 1 1 7 / 4 / 2 0 1 1 7 / 5 / 2 0 1 1 7 / 6 / 2 0 1 1 7 / 7 / 2 0 1 1 7 / 8 / 2 0 1 1 7 / 9 / 2 0 1 1 7 / 1 0 / 2 0 1 1 7 / 1 1 / 2 0 1 1 7 / 1 2 / 2 0 1 1 7 / 1 3 / 2 0 1 1 7 / 1 4 / 2 0 1 1 7 /15/2 011 7 /16/2 011 7 /17/2011 7 /1 8 /2 0 11 7/1 9/2 011 7/2 0/2 011 7 /21/2 011 DA T E D E P T H ( F T ) 13 1/2" Hole 9 7/8" Hole 6 3/4" Hole S U S A N D I O N N E 7 SUSAN DIONNE 7 35 5 DAILY REPORTS Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE June 15, 2011 DEPTH 462 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 117 24 HOUR FOOTAGE 345 CASING INFORMATION 18.75" @ 117' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" MX1 3-18's, 16cj 5169869 117 in hole 345 5.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 325.8 @ 363 15.0 @ 127 60.1 173.92 FT/HR SURFACE TORQUE 4332 @ 343 118 @ 458 778.4 206.75 AMPS WEIGHT ON BIT 18 @ 410 -2 @ 302 3.4 16.36 KLBS ROTARY RPM 64 @ 145 -6 @ 458 28.4 0.44 RPM PUMP PRESSURE 838 @ 460 250 @ 362 498.5 752.75 PSI DRILLING MUD REPORT DEPTH 460 MW 8.9 VIS 50 PV 14 YP 19 FL 14 Gels 13/24/28 CL- 600 FC 2/ SOL 4 SD 0.75 OIL /96 MBL 26 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 362 0 @ 403 0.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 1969 @ 418 49 @ 389 223.2 CONNECTION GAS HIGH 5 ETHANE (C-2) @ @ AVG 1 PROPANE (C-3) @ @ CURRENT 1 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PTSM; pickup drift, makeup, stand back 5” drill pipe. PJSM; install knife valve, leaked, turn knife valve, pickup drift, makeup, stand back 5” HWDP and jars. PJSM; service rig and top drive and grease blocks. PJSM; nipple up diverter line and chain down, pickup lift subs, X-Os, stab, test diverter with state representative, test alarms and PVTs. PJSM; pickup, makeup bit, motor, pony, stab, MWD and orientate. PTSM; pickup, makeup X-O, shock sub, X-O pxp, organize rig floor. PJSM; drill from 98’ to 275’, pump 25 bbl sweep high vis. PJSM; pull out of hole from 275’ to 78’. PJSM; pickup BHA and run into hole, (3 CSNOP), from 78’ to 269’, tag 6’ fill. PJSM; drill from 269’ to 462’. EPOCH PERSONNEL ON BOARD 1 DAILY COST 3250.00 REPORT BY Hammond Page 1 of 1Daily Report 6/20/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 16, 2011 DEPTH 1664 PRESENT OPERATION Drilling to casing TD TIME 2400 YESTERDAY 462 24 HOUR FOOTAGE 1202 CASING INFORMATION 18.75" @ 117' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1611 60.07 225.59 1395.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" MX1 5169869 3-18s, 16cj 117 still in 1547 21.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 193.2 @ 470 10.7 @ 1032 91.0 42.02 FT/HR SURFACE TORQUE 6739 @ 1217 103 @ 817 1087.4 221.43 AMPS WEIGHT ON BIT 33 @ 1576 0 @ 904 16.4 7.04 KLBS ROTARY RPM 86 @ 1208 -6 @ 1644 16.3 0.44 RPM PUMP PRESSURE 1792 @ 1545 655 @ 474 1288.0 1386.70 PSI DRILLING MUD REPORT DEPTH 1662 MW 9.1 VIS 54 PV 14 YP 17 FL 12 Gels 12/27/34 CL- 400 FC 2 SOL 5 SD 0.25 OIL 0/95 MBL 27 pH 8.7 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 93 @ 1318 0 @ 475 27.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 18434 @ 1318 23 @ 597 5397 CONNECTION GAS HIGH 134 ETHANE (C-2) @ @ AVG 59 PROPANE (C-3) @ @ CURRENT 61 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 30 PENTANE (C-5) @ @ HYDROCARBON SHOWS Methane gas intervals INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 770-810, 1290-1420, 1590-1670 29u, 93u, 71u LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PTSM; drill from 462’ to 739’ ART-1 AST-3. Drill from 739’ to 1053’. PTSM; drill from 1053’ to 1390’. Continue drilling from 1390’ to 1664’. EPOCH PERSONNEL ON BOARD 2 DAILY COST 3250.00 REPORT BY Greg Hammond Page 1 of 1Daily Report 6/17/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\20110 ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 17, 2011 DEPTH 1705 PRESENT OPERATION Running in casing TIME 2400 YESTERDAY 1664 24 HOUR FOOTAGE 41 CASING INFORMATION 18.75" @ 117' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1651 61.83 226.50 1415.24 1705 64.25 226.50 1439.72 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" MX1 5169869 3-18s, 16cj 117 still in 1588 22.47 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 107.2 @ 1665 8.1 @ 1705 52.8 8.12 FT/HR SURFACE TORQUE 6475 @ 1705 162 @ 1695 1414.2 6475.70 AMPS WEIGHT ON BIT 30 @ 1704 7 @ 1664 22.6 27.78 KLBS ROTARY RPM 64 @ 1696 -6 @ 1694 14.2 57.59 RPM PUMP PRESSURE 1593 @ 1674 1386 @ 1664 1539.7 1524.61 PSI DRILLING MUD REPORT DEPTH 1705 MW 9.3 VIS 53 PV 17 YP 18 FL 9 Gels 10/21/26 CL- 340 FC 2 SOL 6 SD 0.1 OIL 0/94 MBL 28 pH 8.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 @ 1664 25 @ 1705. 36.2 TRIP GAS 27 CUTTING GAS @ @ WIPER GAS 309 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7512 @ 1664 3882 @ 1704 5438.8 CONNECTION GAS HIGH 73 ETHANE (C-2) @ @ AVG 73 PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 6 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PTSM; drill from 1664’ to 1705’. Circulate hole clean, pump high viscosity sweep, check flow. PJSM; pull out of hole with 5” drill pipe and HW drill pipe. Lay down shock sub and x-o’s, pull out of hole to shoe. Clean floor. PJSM; service rig top drive, grease crown and blocks. PJSM; run into hole to 1705’. Ratty from 1052’ to 1705’. Pump high viscosity sweep, circulate hole clean. PJSM; check flow, pull out of hole with 5” drill pipe to 620’. Tight at 963’. PJSM; run into hole to 1334’. Tight at 1100’. PTSM; continue running into hole from 1334’ to 1705’, circulate high viscosity sweep (b/u gas 43 units). PJSM; check flow, fill trip tank, pull out of hole from 1705’ to 765’. PJSM; pull out of hole from 765’, stand back HW drill pipe and jars, lay down BHA. Clear and clean floor. Rig up to run 10-3/4” casing. PJSM; change out bales, swap over tongs, rig up fill up line, rig up Weatherford. PJSM; run 10-3/4” casing, check floats, continue run into hole to 1250’. EPOCH PERSONNEL ON BOARD 2 DAILY COST 3350.00 REPORT BY Greg Hammond Page 1 of 1Daily Report 6/18/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\20110 ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 18, 2011 DEPTH 1705 PRESENT OPERATION Nippling up TIME 2400 YESTERDAY 1705 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 117' 10-3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1705' MW 9.3 VIS 43 PV 12 YP 10 FL 9 Gels 4/5/6 CL- 340 FC 2 SOL 6 SD 0.1 OIL 0/94 MBL 28 pH 8.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PTSM; run into hole with 10-3/4” casing as per progress to 1697’. Circulate and condition. Rig down Weatherford. PJSM; rig up cement head pump 20 bbls preflush with dxc, pump 2 bbls water, test lines from 2500 psi, drop plug, mix and pump bbls slurry, drop second plug, pump 5 bbls water. 149.88 bbl mud. Pump plug with 1000 psi over, displace pi psi, bleed off, check floats, cement in place at 0430. Rig down cement head and line. Lay down slips and mousehole. Flush lines and stack. PJSM; rig down kill, bleeder, fill up and trip tank lines. Nipple down diverter line, knife valve and adaptor flange. PJSM; load pipe racks with 5” drill pipe. Hot bolt diverter stack. Rig down chain and turnbuckle and trip tank actuator. Haul off mud. Rig up rig tongs and spinners. PTSM; gather tools, release weight, cut 10-3/4” casing, lay down, riser, flowline, remove diverte, remove cement dump valves, hammer up BOP stack, continue cleaning pits, change out shaker rubbers #1 and #2. PJSM; with Vetco, remove starter head and mark casing. PJSM; cut 20” casing, cut 10-3/4” casing, prep cuts and install well head. Test well head to 1700 psi for 10 minutes, run in lock. PJSM; nipple up, make up DSA and riser spool, bring BOP stack and make up, grease choke HSE valves, clean cuttings box. EPOCH PERSONNEL ON BOARD 2 DAILY COST 3250.00 REPORT BY Greg Hammond Page 1 of 1Daily Report 6/20/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 19, 2011 DEPTH 1705 PRESENT OPERATION Picking up drillpipe TIME 2400 YESTERDAY 1705 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 117' 10-3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1705' MW 9.3 VIS 42 PV 12 YP 10 FL Gels 4/5/6 CL- 340 FC 2 SOL 6 SD 0.1 OIL 0/94 MBL 28 pH 8.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS no circulation @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PTSM; hammer up flanges on spools and stack choke and kill valves, install fitting on stack and HCR, hookup Koomey lines. Rig up kill, choke lines, bell nipple, riser, flow line ext., bleeder, fill up and trip tank lines. Turnbuckle to stack, drip pan. Install mouse hole. Mix mud. PJSM; pick up, rig up test equipment, leak on mattboard head. PJSM; change bails and elevators. Pick up PBA and install. PJSM; install plug in wellhead. Shell test BOPs. Fix leaks on gray lock on choke line and gland on wellhead. Finish installing BPA. PJSM; test BOPs to 250-3000 psi. Test annular, upper, lower Kelly cock, upper and lower pipe rams, floor, part, inside and outside kill valves. PTSM; test lower pipe rams, (3000 psi high test fail), hammer up spacerspool, test lower pipe rams (good), Koomey performance test, test blind rams, valves # 3, #4. Rig down test equipment, dart valve, floor valve, test plug, test joint. PJSM; casing test, test casing to 1500 psi for 30 min. Set wear ring, run in lockdowns. PJSM; prep rig floor to pickup 5” drillpipe. PJSM; run into hole, pick up, drift, make up 5” drillpipe. PJSM; pull out of hole with 5” drillpipe, stand back, strap. PJSM; run into hole, pick up, drift, make up 5” drillpipe. PJSM; pull out of hole with 5” drillpipe, stand back, strap. PJSM; run into hole, pick up, drift, make up 5” drillpipe. EPOCH PERSONNEL ON BOARD 4 DAILY COST 4190.00 REPORT BY Greg Hammond Page 1 of 1Daily Report 6/20/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 20, 2011 DEPTH 2810 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 1706 24 HOUR FOOTAGE 1104 CASING INFORMATION 10-3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2740' 64.26 224.37 1891.13' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9-7/8" HCC-HCD504ZX 7135096 6-12s 1706 1104 8.86 still in DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 199.7 @ 2227 7.8 @ 1726 138.9 155.27 FT/HR SURFACE TORQUE 7283 @ 2674 2188 @ 1998 4392.2 4875.43 AMPS WEIGHT ON BIT 23 @ 2227 1 @ 2604 11.7 9.51 KLBS ROTARY RPM 86 @ 2168 21 @ 2737 70.5 79.02 RPM PUMP PRESSURE 1520 @ 2767 748 @ 2108 1329.1 1430.76 PSI DRILLING MUD REPORT DEPTH 2539'/1803' TVD MW 9.3 VIS 49 PV 10 YP 19 FL 7 Gels 8/9/11 CL- 29000 FC 1 SOL 7 SD 0.25 OIL /92 MBL - pH 9.5 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 283 @ 2756.00000 10 @ 1720.00000 72.8 TRIP GAS CUTTING GAS @ 2810.00000 0 @ 2810.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 57820 @ 2756.00000 598 @ 2514 14476.9 CONNECTION GAS HIGH ETHANE (C-2) 84 @ 2757.00000 0 @ 2805 1.2 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 35/40 PENTANE (C-5) @ @ HYDROCARBON SHOWS Gas: 239u @ 1792'; 239u @ 2338'; 284u @ 2785' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Interbedded tuffaceous siltstone, tuffaceous claystone, sand/sandstone with occasional coals. PRESENT LITHOLOGY 50% sand, 30% tuffaceous siltstone, 20% tuffaceous claystone DAILY ACTIVITY SUMMARY PTSM. Continue picking up, drift and run into hole with 5” drill pipe to 1612’. Circulate hole. PJSM. Pull out of the hole, strap and stand back 5” drill pipe stands from 1612’. PJSM. Pick up/make up 5” drill pipe and run into hole to 720’. Continue running into hole with BHA from 720’ to 768’. Flow test tools. Run into hole with 5” drill pipe from 768’ to 1591’. Wash to 1610’. Ream cement from 1610’ and drill out float equipment to 1697’. Ream cement from 1697’ to 1705’. Drill from 1705’ to 1725’. Circulate and displace mud system to Flow-Pro mud. PJSM. Rig up and perform FIT to 15ppg-EMW. Drill from 1725’ to 1726’. PTSM. Drill from 1726’ to 2810’. EPOCH PERSONNEL ON BOARD 4 DAILY COST 4190.00 REPORT BY John Lundy Page 1 of 1Daily Report 6/21/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 21, 2011 DEPTH 3805 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 2810 24 HOUR FOOTAGE 995 CASING INFORMATION 10 3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3752 64.25 225.89 2331.31' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HCC-HCD504ZX 7135096 6-12s 1706 still in 2099 18.26 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 176.2 @ 2985 8.4 @ 3363 117.3 111.03230 FT/HR SURFACE TORQUE 7224 @ 3785 3025 @ 2915 5091.6 6314.20313 AMPS WEIGHT ON BIT 24 @ 3175 -4 @ 3046 10.7 6.46972 KLBS ROTARY RPM 86 @ 3426 21 @ 3174 71.5 71.87740 RPM PUMP PRESSURE 2003 @ 3472 1166 @ 3423 1665.8 1855.95593 PSI DRILLING MUD REPORT DEPTH 3584/2258 tvd MW 9.3 VIS 46 PV 10 YP 20 FL 7.4 Gels 10/14/17 CL- 23000 FC 1 SOL 6.5 SD 0.25 OIL /93 MBL 7.5 pH 9.9 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 914 @ 3342 9 @ 3426.00000 158.6 TRIP GAS CUTTING GAS @ @ WIPER GAS 33u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 178446 @ 3342 1822 @ 3426.00000 31453.8 CONNECTION GAS HIGH ETHANE (C-2) 299 @ 3338 0 @ 3177.00000 29.5 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 30/38 PENTANE (C-5) @ @ HYDROCARBON SHOWS GAS; 3255' -586u, 3342'- 914u, 3458' - 391u, 3552' - 262u, 3610' 392u, 3668' - 335u, 3755' - 527u, INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Interbedded Sandstone, tuffaceous sandstone, sandstone conglomerate, tuffaceous siltstone/claystone with occasional ash and coal interbeds. PRESENT LITHOLOGY 70% Sand/sandstone complex; 10% Ash, 10% Tuffaceous siltstone, 10% Tuffaceous claystone. DAILY ACTIVITY SUMMARY PTSM. Drill from 2810’ to 3425’. Circulate bottoms up. Pump hi-viscosity sweep. PJSM. Pull out of the hole from 3425’ to 3294’. Ream to 3210’ (tight). Circulate bottoms up. Pull out of the hole from 3210’ to 2982’. PTSM. Pull out of the hole with 5” drill pipe from 2982’ to 1712’. Circulate bottoms up. PJSM. Service rig, top drive, blocks, crown and carrier. PJSM. Run into hole from 1712’ to 3301’. Wash from 3301’ to 3425’. PJSM. Drill from 3425’ to 3805’. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00, RW 555.00 REPORT BY John Lundy Page 1 of 1Daily Report 6/22/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE June 22, 2011 DEPTH 5196 PRESENT OPERATION Wiper trip TIME 2400 YESTERDAY 3805 24 HOUR FOOTAGE 1391 CASING INFORMATION 10 3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5080' 64.26 216.68 2908.46' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HCC-HCD504ZX 7135096 6-12s 1706 still in 3490' 32.68 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 157.4 @ 4635 7.9 @ 4557 111.1 82.68 FT/HR SURFACE TORQUE 9323 @ 4942 3803 @ 4375 6995.8 8971.53 AMPS WEIGHT ON BIT 33 @ 4322 1 @ 4565 13.4 12.38 KLBS ROTARY RPM 86 @ 3985 36 @ 4818 72.9 64.73 RPM PUMP PRESSURE 2244 @ 4892 896 @ 4249 1942.5 2043.65 PSI DRILLING MUD REPORT DEPTH 5196' MW 9.3 VIS 46 PV 10 YP 21 FL 6 Gels 10/14/17 CL- 23000 FC 1/ SOL 6 SD 0.15 OIL 1/94 MBL 9 pH 9.5 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 475 @ 4223 22 @ 3995 121.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 83520 @ 4403 4555 @ 3995 23766.6 CONNECTION GAS HIGH ETHANE (C-2) 125 @ 4222 0 @ 4555 7.4 AVG PROPANE (C-3) 191 @ 4283 21 @ 4292 1.1 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 20/25 PENTANE (C-5) @ @ HYDROCARBON SHOWS Gas. 4100'-4140': 338u; 4190'-4240': 475u; 4270'-4300': 375u; 4400'-4430': 440u; 4630'-4640': 251u; 4770'-4800': 292u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Interbedded tuffaceous siltstone, tuffaceous claystone, tuffaceous sandstone, sand, and calcareous tuff with occasional coal PRESENT LITHOLOGY 30% tuffaceous siltstone, 20% tuffaceous claystone, 20% tuffaceous sandstone, 10% sand, 10% tuff, 10% coal DAILY ACTIVITY SUMMARY PTSM; drill from 3805’ to 4249’. Troubleshoot charge pressure on pump #3. Drill from 4248’ to 4564’. PTSM; drill from 4564 to 4943’. Continue drilling from 4943’ to 5196’. Circulate bottoms up, pump low vis sweep. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00, RW 565.00 REPORT BY Greg Hammond Page 1 of 1Daily Report 6/23/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 23, 2011 DEPTH 5500 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 5196 24 HOUR FOOTAGE 304 CASING INFORMATION 10 3/4" @1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5460' 64.22 216.18 3073.60' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HCC-HCD504ZX 7135096 6-12s 1706 still in 3794 36.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 161.2 @ 5262 13.2 @ 5451 92.5 65.49741 FT/HR SURFACE TORQUE 10175 @ 5274 236 @ 5324 7850.7 7738.29688 AMPS WEIGHT ON BIT 27 @ 5197 4 @ 5357 13.4 14.84230 KLBS ROTARY RPM 79 @ 5264 0 @ 5324 70.9 64.73412 RPM PUMP PRESSURE 2120 @ 5312. 279 @ 5324 1991.6 1982.36548 PSI DRILLING MUD REPORT DEPTH 5354/3028 tvd MW 9.5 VIS 46 PV 10 YP 20 FL 6.1 Gels 9/14/17 CL- 23500 FC 1 SOL 7 SD 0.1 OIL 1/92 MBL 7.5 pH 9.4 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 359 @ 5447.00000 16 @ 5197.00000 117.5 TRIP GAS CUTTING GAS @ @ WIPER GAS 195U CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 74423 @ 5447.00000 3326 @ 5197.00000 23306.5 CONNECTION GAS HIGH ETHANE (C-2) 87 @ 5499.00000 0 @ 5396.00000 10.0 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 50/55 PENTANE (C-5) @ @ HYDROCARBON SHOWS GAS: 5209 - 172u; 5317 - 198u; 5339 - 338u; 5447' - 238u; 5500' - 289u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Transition; Interbedded Sand/Tuffaceous sand complex, tuffaceous siltstone/claystone and ash with occasional moderate to massive coal/carbonaceous shales. PRESENT LITHOLOGY 30% Tuffaceous sand/sand complex ; 50% Tuffaceous siltstone, 20% Ash/tuff. DAILY ACTIVITY SUMMARY PTSM. Check for flow. Back ream from 5196’ to 1653’. Circulate bottoms up. PJSM. Change out saver sub and grabber dies. PJSM. Service rig, top drive, crown and blocks. PJSM. Run into hole from 1653’ to 2918’. PTSM Run into hole from 2918’ to 5133’. Wash from 5133’ to 5196’. PJSM. Drill from 5196’ to 5323’. Unable to pick up off bottom at connection. Work pipe free. Weight up to 9.5 PPG-MWE. Continue drilling from 5323’ to 5500’. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3835.00 RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 6/24/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jun 24, 2011 DEPTH 6589 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 5500 24 HOUR FOOTAGE 1089 CASING INFORMATION 10 3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6536 64.26 216.81 3541.15' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 5/8" HCC-HCD504ZX 7135096 6-12s 1706 still in 4883 50.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 161.2 @ 6529 9.0 @ 5958 95.9 111.55872 FT/HR SURFACE TORQUE 11746 @ 6475 5594 @ 5608 9249.4 11232.46484 AMPS WEIGHT ON BIT 34 @ 6400 4 @ 6255 12.7 14.27144 KLBS ROTARY RPM 86 @ 5531 43 @ 6402 74.0 79.02067 RPM PUMP PRESSURE 2524 @ 6550 1202 @ 5768 2160.0 2415.22217 PSI DRILLING MUD REPORT DEPTH 6450/ 3503' tvd MW 9.7 VIS 49 PV 10 YP 25 FL 6.1 Gels 11/15/18 CL- 24500 FC 1 SOL 7.5 SD 0.2 OIL 2/91 MBL 8.5 pH 9.6 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 521 @ 6500 34 @ 5832 150.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 101544 @ 6500 6300 @ 5749 29416.0 CONNECTION GAS HIGH ETHANE (C-2) 105 @ 6405 0 @ 6580 11.0 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 20/45 PENTANE (C-5) @ @ HYDROCARBON SHOWS See Mudlog, numerous gas shows INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga: Interbedded Sand/sandstone/tuffaceous sandstone; Tuffaceous and non tuffaceous siltstone; tuffaceous claystone, coal/carbonaceous shale and ash. PRESENT LITHOLOGY 30% Sand/sand conglomerate/tuffaceous sandstone; 40% tuffacveous siltstone; 20% Tuffaceous claystone; 10 % Ash. DAILY ACTIVITY SUMMARY PTSM. Drill from 5500’ to 5577’. Unable to pick up off bottom at connection. Work pipe free at 5577’. Drill from 5577’ to 5745’. Circulate while changing out liner, wearplate and gasket on #2 mud pump. Drill from 5745’ to 5957’. PTSM. Drill from 5957’ to 6273’. Mix and pump high and low vis sweep at 6050’. Continue drilling from 6050’ to 6689’. Mix and pump high and low vis sweep at 6496’. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00; RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 6/25/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson; Tom Angles DATE Jun 25, 2011 DEPTH 7050 PRESENT OPERATION POOH, Backreaming TIME 2400 YESTERDAY 6589 24 HOUR FOOTAGE 461 CASING INFORMATION 10 3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7050 64.24 221.00 3764.57 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 5/8" HCC-HCD504ZX 7135096 6-12s 1706 still in 5344 56.33 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 132.3 @ 7000 10.2 @ 6653 94.6 67.59167 FT/HR SURFACE TORQUE 11907 @ 6998 7870 @ 6590 10255.5 10380.94434 AMPS WEIGHT ON BIT 48 @ 6656 4 @ 6970 14.5 12.61943 KLBS ROTARY RPM 79 @ 6589 57 @ 7041 73.3 71.87740 RPM PUMP PRESSURE 2528 @ 6873 1752 @ 6845 2417.1 2353.93286 PSI DRILLING MUD REPORT DEPTH 7050/3764tvd MW 9.7 VIS 47 PV 12 YP 24 FL 6.2 Gels 12/16/19 CL- 25000 FC 1 SOL 8 SD 0.1 OIL 2/90 MBL 9 pH 9.7 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 437 @ 6987 35 @ 7036 152.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 85386 @ 6987.00000 6996 @ 7036.00000 29887.0 CONNECTION GAS HIGH ETHANE (C-2) 177 @ 6987.00000 0 @ 6781.00000 26.1 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS Gas: 6590-6710 - max gas 376U; 6880 - 7030 - max gas 437u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga: Interbedded Tuffaceous sand.sand complex, Tuffaceous siltstone/claystone with ash, coal and carbonaceous shaale interbeds. PRESENT LITHOLOGY 60% Sand/sandstone; 30% Tuffaceous siltstone, 10 % Ash DAILY ACTIVITY SUMMARY PTSM. Drill from 6589’ to 7050’. Circulate and replace swab in pump #3. Pump 50 bbls low viscosity sweep. Check for flow. Back ream from 7050’ to 6680’. PTSM. Back ream out of hole from 6688’ to 3236’. Circulate sweep. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00 RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 6/26/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson; Tom Anglen DATE Jun 26, 2011 DEPTH 7050 PRESENT OPERATION POOH TIME 2400 YESTERDAY 6589 24 HOUR FOOTAGE 461 CASING INFORMATION 10 3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7050 64.24 221.00 3764.57 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 5/8" HCC-HCD504ZX 7135096 6-12s 1706 still in 5344 56.33 1-1-NT-A-X-I-NO-TD TD #3 (#2RR) 9 5/8" HHC-HCD504ZX 7135096 6-12s 7050 7050 0 N/A 1-1-NT-A-X-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7050/3764tvd MW 9.7 VIS 46 PV 11 YP 24 FL 6.1 Gels 12/16/18 CL- 23000 FC 1 SOL 7.5 SD 0.1 OIL 3/90 MBL 9 pH 9.6 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 157u CUTTING GAS @ @ WIPER GAS 102u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 20/22 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga: Interbedded Tuffaceous sand.sand complex, Tuffaceous siltstone/claystone with ash, coal and carbonaceous shaale interbeds. PRESENT LITHOLOGY 60% Sand/sandstone; 30% Tuffaceous siltstone, 10 % Ash DAILY ACTIVITY SUMMARY PTSM. Check for flow. Pull out of the hole from 3236’ to 768’ (SLM – no correction). PJSM. Stand back HWDP and jars. Lay down Filter, X-O, ATK motor, ontrack and bit (plugged into ontrack). Clean and clear floor. PJSM. Make up BHA #3 and run into hole to 1681’. PJSM. Service rig. Lube crown, blocks, top drive and carrier. PJSM. Slip drilling line. Continue running into hole from 1681’ to 7000’. Wash from 7000’ to 7050’. PTSM. Circulate. Pump sweep. Circulate bottoms up. Spot low torque pill. PJSM. Pull out of the hole from 7050’ to 5000’. PJSM Run into hole from 5000’ to 7050’. PJSM. Circulate and condition. PJSM. Pull out of the hole from 7050’ to 2200’ EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3295.00 RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 6/27/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson; Tom Anglen DATE Jun 27, 2011 DEPTH 7050 PRESENT OPERATION Circulating csg TIME 2400 YESTERDAY 7050 24 HOUR FOOTAGE 461 CASING INFORMATION 10 3/4" @ 1697' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7050 64.24 221.00 3764.57 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7050/3764tvd MW 9.7 VIS 45 PV 11 YP 23 FL 6 Gels 11/15/17 CL- 22000 FC 1 SOL 7.5 SD 0.1 OIL 3/90 MBL 9 pH 9.5 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 122 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 15/35 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga: Interbedded Tuffaceous sand.sand complex, Tuffaceous siltstone/claystone with ash, coal and carbonaceous shaale interbeds. PRESENT LITHOLOGY 60% Sand/sandstone; 30% Tuffaceous siltstone, 10 % Ash DAILY ACTIVITY SUMMARY PTSM. Pull out of the hole from 2200’ to 607’. Lay down BHA #3. Pull wear bushing. Dummy run landing joint. PJSM. Change out 2 7/8 x 5 ½” upper rams with 7 5/8” casing rams. PJSM. Rig up[ and test 7 5/8” casing rams (250 – 3000 psi). Swap tongs, remove elevators and short bales. Change out snub post. Make up swedge. Rig up tongs. Move torque tube. PJSM. Run 7 5/8” casing as per program. PTSM. Continue running 7 5/8” casing as per program to shoe. Circulate bottoms up. Continue running 7 5/8” casing as per program to 6983’. Pick u/make up landing joint. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML 3295.00 RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 6/28/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WE ... Marathon Oil Company Susan Dionne Field DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson Tom Anglen DATE Jul 02, 2011 DEPTH 7070 PRESENT OPERATION Circulating bottoms up and mixing spacer for displacement TIME 24:00 YESTERDAY 7050 24 HOUR FOOTAGE 20 CASING INFORMATION 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75 HCC STX-1 5124226 3x20 7050 7070 20 1.01 In Hole Finished clean-out DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 141.0 @ 7055 9.1 @ 7061 58.2 18.0 FT/HR SURFACE TORQUE 7870 @ 7051 7385 @ 7060 7952.4 7532.8 AMPS WEIGHT ON BIT 26 @ 7057 5 @ 7051 14.0 10.2 KLBS ROTARY RPM 79 @ 7051 64 @ 7058 77.5 71.9 RPM PUMP PRESSURE 831 @ 7059 737 @ 7064 836.2 798.7 PSI DRILLING MUD REPORT DEPTH 7070 / 3773 TVD MW 9.7 VIS 48 PV 12 YP 23 FL 6.2 Gels 10/14/16 CL- 22000 FC 1 SOL 8.0 SD Tr OIL 3/89 MBL 9.0 pH 9.5 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 7 @ 7054 3 @ 7058 6.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 1464 @ 7054 735 @ 7058 1229.6 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0.5 / 1.0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Note very abundant cement returns. Major Sand/Sand PRESENT LITHOLOGY (CEMENT RETURNS)..........SAND/SANDSTONE DAILY ACTIVITY SUMMARY Perform various rig maintenance. Pull wear ring. Rig up to test BOPE. Test annular to 250psi Low / 2500psi High. Test gas alarms and PVT system. Perform accumulator drawdown test. Test all other BOPE (CMVs 1-12, kill line, Demco valve, upper and lower top drive valves, inside and outside kill lines, HCR and manual choke valves, upper and lower pipe rams, blind rams, floor valve, dart valve) to 250psi Low / 3000psi High. Rig down BOPE testing equipment. Install wear ring. Rig up to test casing. Test casing to 3000psi for 30 minutes. Pick up, make up and run in hole bit, bit sub, 15 joints of HWDP and jars. Run in hole 4" dril pipe to 5035'. Perform BOP drill and choke drill. Continue running in hole with 4" drill pipe to 6739'. Wash down from 6739' and tag top of cement at 6886'. Drill out shoe track (cement, float, cement, casing shoe, rat hole) from 6886' to 7050'. Drill 20' of hole from 7050' to 7070'. Circulate bottoms up. Mix pre-displacement spacer. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML 3295 RW 565 REPORT BY Craig Silva Page 1 of 1Daily Report 7/4/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily R ... Marathon Oil Company Susan Dionne Field DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson Tom Anglen DATE Jul 03, 2011 DEPTH 7070 PRESENT OPERATION RIH to bottom W 6 3/4" Bit TIME 24:00 YESTERDAY 7070 24 HOUR FOOTAGE 20 CASING INFORMATION 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75 HCC DP505X 7123159 5-11s 7070 0 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION \ @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7070 / 3773 TVD MW 9.2 VIS 52 PV 12 YP 18 FL 6.6 Gels 78/10/11 CL- 22500 FC 1 SOL 4.5 SD - OIL 2/94 MBL 2 pH 10.0 Ca+ 360 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0.5 / 1.0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Note very abundant cement returns. Major Sand/Sand PRESENT LITHOLOGY (CEMENT RETURNS)..........SAND/SANDSTONE DAILY ACTIVITY SUMMARY PTSM. Build and pump spacer. Displace with flow-pro mud. PJSM. Rig up and FIT test to 15ppg/MWE. Flow check. Lay down single. Circulate. Service and lubricate rig. Change out belt . Circulate and build mud. Change-out snub line. Load pipe rack. Prep casing. Work on #2 Carrier. Circulate. Prep casing. Oil cooler repaired on #2 carrier. Service mud line valves. Service choke manifold valves. Build dry job. PTSM. Pump dry job. PJSM. Pull out of the hole with 4” drill pipe heavy weight drill pipe and jars. Lay down bit and bit sub. PJSM. Pick up and make up bit, autotrack, ontrack, litho track and plug in. Pick up and make up Mag Track. Strap sub and plug in. PJSM. Load radio active sources in tools. Pick up and make up sonic tool and filter, sub, float, CSOPs, and change over sub. Run into hole with HWDP and jars. Shallow test tools. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00; RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 7/4/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 04, 2011 DEPTH 7993 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 7070 24 HOUR FOOTAGE 923 CASING INFORMATION 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7938 49.06 222.31 4241.41 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75 HCC DP505X 7123159 6-11s 7070 still in 923 15.0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 147.6 @ 7238 3.9 @ 7616 69.7 37.66163 FT/HR SURFACE TORQUE 7576 @ 7788 3803 @ 7130 5216.5 5007.56055 AMPS WEIGHT ON BIT 22 @ 7934 1 @ 7863 7.8 7.19029 KLBS ROTARY RPM 86 @ 7655 57 @ 7788 70.5 79.02067 RPM PUMP PRESSURE 2369 @ 7351 798 @ 7070 2042.3 1957.46667 PSI DRILLING MUD REPORT DEPTH 7868/4276 tvd MW 9.3 VIS 56 PV 12 YP 27 FL 5.4 Gels 10/14/17 CL- 22000 FC 1 SOL 4.8 SD 0.2 OIL 2/93 MBL 2.5 pH 9.2 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 256 @ 7836 6 @ 7071 61.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 47529 @ 7836 1324 @ 7070 11639.3 CONNECTION GAS HIGH ETHANE (C-2) 86 @ 7836 0 @ 7179 12.7 AVG PROPANE (C-3) 40 @ 7680 0 @ 7374 8.8 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 35/50 PENTANE (C-5) @ @ HYDROCARBON SHOWS GAS: 7150 -140u; 7380 - 245u; 7550 - 135u; 7600 - 184u; 7835 - 257u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Transition: Interbedded Tuffaceous sandstone, sand, tuffaceous siltstone and tuffaceous claystone with occasional coals and ash interbeds. PRESENT LITHOLOGY 30% Tuffaceous sandstone, 20% sand/sandstone, 20% tuffaceous siltstone, 10% tuffaceous claystone, 20% ash DAILY ACTIVITY SUMMARY PTSM. Run into hole with 4” drill pipe from 796’ to 7049’. PJSM. Wash from 7049’ to 7070’. PJSM. Down link and establish drilling parameters. PJSM. Drill from 7070’ to 7427’. PTSM. Drill from 7427’ to 7993’. Pump high vis sweep at 7750’. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 4435.00 RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 7/5/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 05, 2011 DEPTH 8805 PRESENT OPERATION Drilling TIME 2400 YESTERDAY 7993 24 HOUR FOOTAGE 812 CASING INFORMATION 7 5/8: @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8757 27.65 224.14 4884.74 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75 HCC DP505X 7123159 5-11s 7070 still in 1735 29.33 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 118.5 @ 8372 11.7 @ 8118 62.6 19.39509 FT/HR SURFACE TORQUE 7694 @ 8792 4567 @ 8039 6069.6 7371.26221 AMPS WEIGHT ON BIT 22 @ 8755 -1 @ 8622 7.0 11.09314 KLBS ROTARY RPM 86 @ 8025 57 @ 8389 76.4 71.87740 RPM PUMP PRESSURE 2302 @ 8742 1520 @ 8496 2056.8 2133.67383 PSI DRILLING MUD REPORT DEPTH 8800/4940tvd MW 9.5 VIS 57 PV 15 YP 34 FL 4.4 Gels 13/19/22 CL- 25000 FC 1 SOL 6 SD 0.25 OIL 3/91 MBL 4 pH 10.3 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 525 @ 8255 27 @ 7994. 112.1 TRIP GAS CUTTING GAS @ @ WIPER GAS 1383 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 98404 @ 8255 5574 @ 7994 21859.3 CONNECTION GAS HIGH 300 ETHANE (C-2) 236 @ 8255 0 @ 8717 31.5 AVG 34 PROPANE (C-3) 81 @ 8255 0 @ 8175 17.0 CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 35/50 PENTANE (C-5) @ @ HYDROCARBON SHOWS GAS; 8085' - 178o; 8145' - 337u; 8255' - 525u8335' - 276u; 8635' - 190u; 8765' - 274u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Transition: Interbedded Tuffaceous sand/sandstone; Tuffaceous siltstone/claystone; Coal, carbonaceous shale and ash. PRESENT LITHOLOGY 40% Tuffaceous sand/sand; 20% Tuffaceous siltstone; 10% tuffaceous claystone; 10% carbonaceous shale; 20% ash/tuff DAILY ACTIVITY SUMMARY PTSM. Drill from 7993’ to 8369’. Circulate bottoms up. Pump low viscosity sweep. PJSM. Pull out of the hole from 8369’ to 7500’ (Short trip). PTSM. Pull out of the hole from 7500’ to shoe. PJSM. Service rig and top drive. Grease blocks and crown. PJSM. Run into hole with 4” drill pipe to 8308’. Wash from 8308’ to 8369’. PJSM. Drill from 8369’ to 8805’. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00; RW 565 REPORT BY John Lundy Page 1 of 1Daily Report 7/6/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily R ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 07, 2011 DEPTH 9748 PRESENT OPERATION Drilling TIME 01:01:07 YESTERDAY 8805 24 HOUR FOOTAGE 943 CASING INFORMATION 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9705 4.1 192.95 5794.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75 HCC-DP505X 7123159 5-11s 7070 still in 2678 47.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.1 @ 9256 5.3 @ 9706 58.7 27.10619 FT/HR SURFACE TORQUE 8751 @ 9708 5903 @ 9127 7228.8 7620.84570 AMPS WEIGHT ON BIT 22 @ 9346 -8 @ 9443 7.4 9.51429 KLBS ROTARY RPM 86 @ 9191 64 @ 9064 77.5 86.16394 RPM PUMP PRESSURE 2714 @ 9346 1620 @ 9706 2241.2 2388.40820 PSI DRILLING MUD REPORT DEPTH 9706/5813tvd MW 9.8 VIS 58 PV 14 YP 34 FL 4.8 Gels 13/20/25 CL- 24500 FC 1 SOL 8 SD 0.25 OIL 3/89 MBL 4.5 pH 10.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 438 @ 9015 12 @ 9289 113.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 90123 @ 9015.00000 2575 @ 9289.00000 23058.6 CONNECTION GAS HIGH 110 ETHANE (C-2) 126 @ 9015.00000 0 @ 9668.00000 27.3 AVG 5 PROPANE (C-3) 53 @ 9015.00000 0 @ 9668.00000 11.0 CURRENT 0 BUTANE (C-4) 9 @ 9333.00000 0 @ 9716.00000 0.3 CURRENT BACKGROUND/AVG 45/52 PENTANE (C-5) 5 @ 9748.00000 1 @ 9738.00000 0.1 HYDROCARBON SHOWS GAS: 8865' - 236u; 8975' - 219u; 9015' - 438u; 9070' 137u; 9130' - 164u; 9230' - 264u; 9330' - 400u; 9435' - 234u; 9480' - 252u; 9540' - 300u; 9630' - 187u; 9690' - 273u; INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek: Interbedded Tuffaceous and sandstone/conglomeratic sand/conglomerate, tuffaceous siltstone/claystone silicic and calcareous ash/tuff and coal. PRESENT LITHOLOGY 20% Tuffaceous sandstone; 50% sand; 10% Tuffaceous siltstone; 20% Ash/tuff. DAILY ACTIVITY SUMMARY PTSM. Drill from 8805’ to 9064’. Continue drilling from 9064’ to 9287’. PTSM. Drill from 9287’ tp 9748’ EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00; RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 7/9/2011 file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Marathon\Daily R ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 07, 2011 DEPTH 9748 PRESENT OPERATION Drilling TIME 01:01:07 YESTERDAY 8805 24 HOUR FOOTAGE 943 CASING INFORMATION 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9705 4.1 192.95 5794.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75 HCC-DP505X 7123159 5-11s 7070 still in 2678 47.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.1 @ 9256 5.3 @ 9706 58.7 27.10619 FT/HR SURFACE TORQUE 8751 @ 9708 5903 @ 9127 7228.8 7620.84570 AMPS WEIGHT ON BIT 22 @ 9346 -8 @ 9443 7.4 9.51429 KLBS ROTARY RPM 86 @ 9191 64 @ 9064 77.5 86.16394 RPM PUMP PRESSURE 2714 @ 9346 1620 @ 9706 2241.2 2388.40820 PSI DRILLING MUD REPORT DEPTH 9706/5813tvd MW 9.8 VIS 58 PV 14 YP 34 FL 4.8 Gels 13/20/25 CL- 24500 FC 1 SOL 8 SD 0.25 OIL 3/89 MBL 4.5 pH 10.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 438 @ 9015 12 @ 9289 113.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 90123 @ 9015.00000 2575 @ 9289.00000 23058.6 CONNECTION GAS HIGH 110 ETHANE (C-2) 126 @ 9015.00000 0 @ 9668.00000 27.3 AVG 5 PROPANE (C-3) 53 @ 9015.00000 0 @ 9668.00000 11.0 CURRENT 0 BUTANE (C-4) 9 @ 9333.00000 0 @ 9716.00000 0.3 CURRENT BACKGROUND/AVG 45/52 PENTANE (C-5) 5 @ 9748.00000 1 @ 9738.00000 0.1 HYDROCARBON SHOWS GAS: 8865' - 236u; 8975' - 219u; 9015' - 438u; 9070' 137u; 9130' - 164u; 9230' - 264u; 9330' - 400u; 9435' - 234u; 9480' - 252u; 9540' - 300u; 9630' - 187u; 9690' - 273u; INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek: Interbedded Tuffaceous and sandstone/conglomeratic sand/conglomerate, tuffaceous siltstone/claystone silicic and calcareous ash/tuff and coal. PRESENT LITHOLOGY 20% Tuffaceous sandstone; 50% sand; 10% Tuffaceous siltstone; 20% Ash/tuff. DAILY ACTIVITY SUMMARY PTSM. Drill from 8805’ to 9064’. Continue drilling from 9064’ to 9287’. PTSM. Drill from 9287’ tp 9748’ EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3635.00; RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 7/7/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 08, 2011 DEPTH 11519. PRESENT OPERATION Drilling TIME 2400 YESTERDAY 10453 24 HOUR FOOTAGE 1066 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11472 1.02 86.79 7560.78 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75 HCC DP505X 7123159 5-11s 7070 still in 4449 78.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 126.1 @ 11211 13.4 @ 10799 61.3 43.15874 FT/HR SURFACE TORQUE 10733 @ 11212 7195 @ 10846 9089.7 9852.41504 AMPS WEIGHT ON BIT 31 @ 11407 -8 @ 10580 8.3 9.14172 KLBS ROTARY RPM 79 @ 10454 43 @ 10525 69.7 57.59085 RPM PUMP PRESSURE 2888 @ 11300 1951 @ 10621 2522.0 2725.50024 PSI DRILLING MUD REPORT DEPTH 11500/7600tvd MW 10.1 VIS 48 PV 12 YP 28 FL 5.2 Gels 10/15/20 CL- 19500 FC 1 SOL 10 SD .25 OIL 5/86 MBL 6.75 pH 9.7 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 760 @ 10553.00000 25 @ 11467.00000 157.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 113464 @ 10553 5354 @ 11467 29379.1 CONNECTION GAS HIGH 265 ETHANE (C-2) 379 @ 10548 9 @ 11464 58.4 AVG 29 PROPANE (C-3) 66 @ 11242 0 @ 10775 21.2 CURRENT 0 BUTANE (C-4) 17 @ 11413 0 @ 10471 0.5 CURRENT BACKGROUND/AVG 33/55 PENTANE (C-5) 6 @ 11414 0 @ 11406. 0.1 HYDROCARBON SHOWS GAS: 10455 - 410u; 10550' - 760u; 10612' - 446u; 0650' - 179u; 10685' - 278u; 10710' - 356u; 10735' - 282u; 10828' - 308u; 10855' - 483u; 10635' - 200u; 11512' - 253u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION NOTE: TRACE AMOUNTS OF C4 AND C5 GASSES WERE PRESENT FROM 11400' TO 11519'. NO FLUORESENCE, OIL ODOR OR OTHER OIL INDICATORS WERE OBSERVED. LITHOLOGY Tyonek: Interbedded Tuffaceous sandstone/sandstone conglomerate complex, Tuffaceous siltstone, tuffaceous claystone, ash/tuff and occasional coal/carbonaceous shale interbeds. PRESENT LITHOLOGY 50% Tuffaceous sandstone, 1% sand, 10% conglomeratic sand, 10% tuffaceous siltstone, 20% ash/tuff. DAILY ACTIVITY SUMMARY PTSM. Drill from 10453' to 11002'. PTSM. Drill from 1102' to 11519'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML 3835.00; RW 565.00 REPORT BY John Lundy Page 1 of 1Daily Report 7/9/2011 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL ... Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 09, 2011 DEPTH 11794' PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 11519' 24 HOUR FOOTAGE 275' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.7 HCC DP505X 7123159 5-11s 7070' 11794' 4724' 85.1 TBD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 86.1 @ 11589' 15.3 @ 11625' 48.4 58.94971 FT/HR SURFACE TORQUE 11261 @ 11735' 9353 @ 11623' 10489.0 10968.20020 AMPS WEIGHT ON BIT 14 @ 11561' 1 @ 11588' 9.0 8.76114 KLBS ROTARY RPM 71 @ 11622' 50 @ 11780' 61.7 57.59085 RPM PUMP PRESSURE 2913 @ 11561' 2459 @ 11526' 2735.7 2792.53540 PSI DRILLING MUD REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 47 PV 12 YP 28 FL 6.2 Gels 8/13/15 CL- 19000 FC 1/ SOL 10 SD 0.2 OIL 5/85 MBL 6.75 pH 9.5 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 350 @ 11688' 0 @ 11773' 116.7 TRIP GAS NONE CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) 71889 @ 11688' 53 @ 11773' 22606.0 CONNECTION GAS HIGH NONE ETHANE (C-2) 183 @ 11688' 0 @ 11772' 50.1 AVG NONE PROPANE (C-3) 69 @ 11686' 0 @ 11772' 21.9 CURRENT 0 BUTANE (C-4) 10 @ 11706' 0 @ 11772' 1.2 CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) 19 @ 11707' 0 @ 11716' 0.9 HYDROCARBON SHOWS GAS: 11600' - 256u; 11645' - 175u; 11688' - 351u; 11707' - 304u. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION NOTE: TRACE AMOUNTS OF C4 AND C5 WERE PRESENT AT 11688'. C1 - C4 WITH TRACE C5 WERE PRESENT AT 11707'. NO FLUORESENCE, OIL ODOR OR OTHER OIL INDICATORS WERE OBSERVED. LITHOLOGY Tyonek: Interbedded Tuffaceous sandstone/sandstone conglomerate complex, Tuffaceous siltstone, tuffaceous claystone, ash/tuff and occasional coal/carbonaceous shale interbeds. PRESENT LITHOLOGY 30% TUFFACEOUS SILTSTONE; 20% TUFFACEOUS SANDSTONE; 10% SAND; 10% SANDSTONE; 10% CONGLOMERATE; 10% CONGLOMERATE SANDSTONE; 10% ASH/TUFF DAILY ACTIVITY SUMMARY DRILL TO TD @ 11794' MD. CIRUCLATE BOTTOMS UP THEN PUMP A 60 BBL LOW VIS SWEEP FOLLOWED BY A 45 BBL HIGH VIS SWEEP, CIRUCLATING BOTTOMS UP. SPOT LOW TORQUE PILL. PULL OUT OF HOLE TO 9821'. PUMP DRY JOB. PULL OUT OF HOLE TO SHOE (7032'). CUT AND SLIP DRILL LINE. CONTINUE PULLING OUT OF HOLE, 1593' AS OF MIDNIGHT. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3835; RW $565 REPORT BY Tollef Winslow Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 10, 2011 DEPTH 11794' PRESENT OPERATION RIH TIME 24:00:00 YESTERDAY 11794' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6 3/4 HCC DP505X 7123159 5-11s 7070' 11794' 4724' 85.1 1-1-CT-T-X-I-NO-TD TD 3RR 6 3/4 HCC STX-1 5124225 3-20s 11794' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 47 PV 12 YP 22 FL 5.0 Gels 6/10/13 CL- 18000 FC 1/ SOL 10 SD 0.25 OIL 5/85 MBT 5.00 pH 9.6 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NONE CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) @ @ CONNECTION GAS HIGH NONE ETHANE (C-2) @ @ AVG NONE PROPANE (C-3) @ @ CURRENT 51 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 51/50 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue pulling out of the hole. Lay down bottom hole assembly #5 including downloading logging while drilling tools. Make up bottom hole assembly #6, and shallow test logging tools. Run in hole to casing shoe on elevators. Wash and ream from shoe (7032') to 8915' as of midnight. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML $4320, RW $535 REPORT BY Tollef Winslow Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 11, 2011 DEPTH 11794' PRESENT OPERATION RIH WITH PRESSURE TEST TOOL. TIME 24:00:00 YESTERDAY 11794' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6 3/4 HCC DP505X 7123159 5-11s 7070' 11794' 4724' 85.1 1-1-CT-T-X-I-NO-TD TD 3RR 6 3/4 HCC STX-1 5124225 3-20s 11794' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 55 PV 18 YP 28 FL 3.8 Gels 9/14/19 CL- 18000 FC 1/ SOL 11 SD 0.25 OIL 5/84 MBT 7.50 pH 9.7 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NONE CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) @ @ CONNECTION GAS HIGH NONE ETHANE (C-2) @ @ AVG NONE PROPANE (C-3) @ @ CURRENT 29 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 30/50 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run in hole with pressure logging tools on drill string from 8915' to 11443'. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML $4320, RW $535 REPORT BY Tollef Winslow Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 12, 2011 DEPTH 11794' PRESENT OPERATION PRESSURE TESTING TIME 24:00:00 YESTERDAY 11794' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6 3/4 HCC STX-1 5124225 3-20s 11794' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 50 PV 16 YP 26 FL 3.7 Gels 7/10/12 CL- 17500 FC 1/ SOL 10 SD 0.2 OIL 5/85 MBT 8 pH 9.7 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NONE CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) @ @ CONNECTION GAS HIGH NONE ETHANE (C-2) @ @ AVG NONE PROPANE (C-3) @ @ CURRENT 25 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 25/25 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run in hole with pressure logging tools on drill string from 11443 to 11678'. Pressure test formation as per plan. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML $4470, RW $535 REPORT BY Tollef Winslow Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Larry McAllister; Tom Anglen DATE Jul 13, 2011 DEPTH 11794' PRESENT OPERATION RIH, CLEAN OUT RUN TIME 24:00:00 YESTERDAY 11794' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6 3/4 HCC STX-1 5124225 3-20s 11794' 11794' 0 0 - TD 4RR 6 3/4 HCC DP505X 7123159 2x14, 3x15 11794 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 54 PV 15 YP 26 FL 4.0 Gels 8/10/14 CL- 16900 FC 1/ SOL 10 SD 0.25 OIL 5/85 MBT 8 pH 9.7 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NONE CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) @ @ CONNECTION GAS HIGH NONE ETHANE (C-2) @ @ AVG NONE PROPANE (C-3) @ @ CURRENT 18 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 18/18 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued with pressure logging program. Circulated bottoms up when logging program was completed. Pump dry job. Lay down pressure logging bottom hole assembly. Pick up clean out bottom hole assembly. Run in hole. Circulate at the shoe, and continue running in the hole. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML $4320, RW $535 REPORT BY Tollef Winslow Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson; Tom Anglen DATE Jul 14, 2011 DEPTH 11794' PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 11794' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4RR 6 3/4 HCC DP505X 7123159 2x14, 3x15 11794' 11794' 0 0 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 54 PV 15 YP 25 FL 4.0 Gels 8/11/13 CL- 17500 FC 1/ SOL 10 SD 0.25 OIL 5/85 MBT 8 pH 9.5 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 266 CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) @ @ CONNECTION GAS HIGH NONE ETHANE (C-2) @ @ AVG NONE PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue with clean out run. Pump high vis sweep with nutplug to determine hole gauge. Circulate bottoms up and pull out of the hole. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML $2970, RW $535 REPORT BY Tollef Winslow Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson; Tom Anglen DATE Jul 15, 2011 DEPTH 11794' PRESENT OPERATION Running Liner TIME 24:00:00 YESTERDAY 11794' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4RR 6 3/4 HCC DP505X 7123159 2x14, 3x15 11794' 11794' 0 0 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 47 PV 13 YP 22 FL 4.0 Gels 8/10/12 CL- 17500 FC 1/ SOL 10 SD 0.25 OIL 5/85 MBT 8 pH 9.4 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NONE CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) @ @ CONNECTION GAS HIGH NONE ETHANE (C-2) @ @ AVG NONE PROPANE (C-3) @ @ CURRENT 71 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 71/71 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue pulling out of the hole, lay down bottom hole assembly. Test 4.5" variable rams. Rig up to run liner. Run liner to 10950' as of midnight CANRIG PERSONNEL ON BOARD 3 DAILY COST DML $2970, RW $535 REPORT BY Tollef Winslow Marathon Oil Company DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson; Tom Anglen DATE Jul 16, 2011 DEPTH 11794' PRESENT OPERATION Run in Hole w/ Polish Mill TIME 24:00:00 YESTERDAY 11794' 24 HOUR FOOTAGE 0' CASING INFORMATION 20" @ 117' 10 3/4" @ 1697' 7 5/8" @ 7032' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740' 0.93 317.10 7828.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11794' MD / 7882' TVD MW 10.1 VIS 51 PV 14 YP 23 FL 4.4 Gels 8/12/14 CL- 17000 FC 1/ SOL 10 SD 0.2 OIL 5/85 MBT 8 pH 9.8 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 278 CUTTING GAS @ @ WIPER GAS NONE CHROMATOGRAPHY (ppm) SURVEY NONE METHANE (C-1) @ @ CONNECTION GAS HIGH NONE ETHANE (C-2) @ @ AVG NONE PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run in hole with 4/5" liner. Circulate and condition hole. Pump cement. Pull out of hole while laying down excess drill pipe. Test BOPs. Pick up and run in hole with Polish Mill. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML $2970, RW $535 REPORT BY Tollef Winslow Marathon Oil Company Ninilchik Unit DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jul 17, 2011 DEPTH 11794 PRESENT OPERATION Pulling out of hole laying down 4" DP TIME 24:00 YESTERDAY 11794 24 HOUR FOOTAGE 0 CASING INFORMATION 4 1/2" @ 11790' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11740 0.93 317.10 7828.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 10.2 VIS 50 PV 15 YP 21 FL 4.5 Gels 7/11/13 CL- 17000 FC 1 SOL 10.0 SD 0.2 OIL 5/85 MBT 8.0 pH 9.8 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Wait on cement. Run in hole with polish mill assembly from 2845' to 6865'. Tag top of liner. Dress and polish top of liner. Circulate bottoms up 2 times. Fill trip tank. Check for flow. Pump dry job. Pull out of hole with mill to surface. Break and lay down polish mill assembly. Pick up, make up and run in hole liner top packer assembly on 4" drill pipe to 6866'. Tag and lower into seal assembly. Drop ball. Test lines to 5000psi. Set packer and release. Retest lines to 5000psi. Attempt to blow ball seat. Drop bar. Rig up and test casing to 1500psi. Pump and blow out ball seat. Pump dry job. Rig up to lay down drill pipe. Pull out of hole from 6865' with seal assembly, breaking and laying down 4" drill pipe. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML: 2970 RW: 535 REPORT BY Craig Silva Marathon Oil Company Ninilchik Unit DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jul 18, 2011 DEPTH 11794 PRESENT OPERATION Preparing to displace annulus with brine TIME 24:00 YESTERDAY 11794 24 HOUR FOOTAGE 0 CASING INFORMATION 4 1/2" @ 11790' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 6865 MW 10.2 VIS 50 PV 15 YP 21 FL 4.5 Gels 7/11.13 CL- 17000 FC 1 SOL 10.0 SD 0.2 OIL 5/85 MBT 8.0 pH 9.8 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue POOH laying down 4" drill pipe. Break and lay down Packer running/setting tool, pump and crossover. Pull wear bushing. Change bails and elevators. Rig down rig tongs and spinners. Lay down subs and handling tools. Rig up Weatherford. P/U, M/U, RIH Seal/Tie-Back assembly and 4 1/2" tubing as per Marathon. Rig up Pollard to run and band chemical injection line to string for last 1500'. Include SCSSV in upper tubing string. RIH to 6865'. Sting into packer CSR and pressure down to make sure seals engage. Pull from packer and space out. Install hanger and control lines. Pump 49 bbls of HiVis spacer. Shut down and clean Pit #5. Prep to displace. CANRIG PERSONNEL ON BOARD 3 DAILY COST DML: 2970 RW: 535 REPORT BY Craig Silva Marathon Oil Company Ninilchik Unit DAILY WELLSITE REPORT Susan Dionne 7 REPORT FOR Rowland Lawson DATE Jul 19, 2011 DEPTH 11794 PRESENT OPERATION Complete installation and testing of tree TIME 24:00 YESTERDAY 11794 24 HOUR FOOTAGE 0 CASING INFORMATION 4 1/2" @ 11790' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH (6865) MW 8.5 VIS 28 PV YP FL Gels Inhibited KCL Brine CL- 14500 FC SOL SD OIL MBT pH 8.4 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Displace annulus with inhibited KCL Brine. Spot corrosion pill in annulus. Sting back into packer tie-back sleeve and land tubing. Secure tubing hanger. Pressure test annulus. Rig down Pollard. Remove landing joint for 4 1/2" string. (Hanger will have control line penetrations). Drain stack. Test hanger. Install BPV. N/D BOPE. Perform operations to install and test tree. CANRIG PERSONNEL ON BOARD 3 DAILY COST ML: 2970 RW: 535 Rig Down: 2300 REPORT BY Craig Silva
