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215-016
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI34-W6 NIKAITCHUQ SI34-W6 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 SI34-W6 50-629-23534-00-00 215-016-0 N SPT 3459 2150160 1500 592 1950 162 160 REQVAR F Guy Cook 5/2/2025 MITIA every 2 years to maximum anticipated injection pressure but no less than 1500 psi. as per AIO 36.004. Testing was completed with a triplex pump and calibrated gauges. We were not able to get to the test pressure of 2500 that they wanted to test at. The pressure stopped increasing at T/IA/OA = 1950/1940/260. After pumping stopped and before 5 minutes had passed the pressures were at 1011/1002/140. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI34-W6 Inspection Date: Tubing OA Packer Depth 581 1940IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250429140508 BBL Pumped:13.8 BBL Returned:0 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 99 9 9 9 9 MITIA every 2 years r AIO 36.004 not able to get to the test pressure of 2500 pressure stopped increasing at T/IA/OA = 1950/1940/260. James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 12:27:34 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI34-W6 NIKAITCHUQ SI34-W6 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 SI34-W6 50-629-23534-00-00 215-016-0 W SPT 3459 2150160 1500 1179 1832 1803 1782 162 175 166 165 REQVAR F Kam StJohn 4/25/2025 AOGCC CMIT 2 year as per AIO 36.004. Third attempt. Bled down from ending pressures of second attempt (mitKPS250426101011); repressured for third attempt. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI34-W6 Inspection Date: Tubing OA Packer Depth 1159 1814 1784 1762IA 1762 165 45 Min 1742 60 Min Rel Insp Num: Insp Num:mitKPS250426101533 BBL Pumped:0.8 BBL Returned:2.6 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 9999 9999 99 9 9 9 9 3UHVVXUHORVVDYHUDJLQJSVLSHUPLQXWHLQFUHPHQWMEU James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 11:18:03 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI34-W6 NIKAITCHUQ SI34-W6 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 SI34-W6 50-629-23534-00-00 215-016-0 W SPT 3459 2150160 1500 1644 1778 1752 1729 166 168 166 165 REQVAR F Kam StJohn 4/25/2025 AOGCC CMIT 2 Year as per AIO 36.004. 2nd attempt (first attempt - inspection mitKPS250426100711). We bumped up the pressure to try again (pretest = end pressure from first attempt); still a Fail – loss of about 20 to 22 psi every 15 min. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI34-W6 Inspection Date: Tubing OA Packer Depth 1623 1758 1732 1709IA 1707 165 45 Min 1687 1686 165 60 Min 1667 Rel Insp Num: Insp Num:mitKPS250426101011 BBL Pumped:0.8 BBL Returned: Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 99999 99999 9 9 9 9 9 9 9 2nd attemptCMIT 2 Year Fail – loss of about 20 to 22 psi every 15 min James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 11:13:25 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI34-W6 NIKAITCHUQ SI34-W6 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 SI34-W6 50-629-23534-00-00 215-016-0 W SPT 3459 2150160 1500 706 1736 1695 1667 165 177 168 166 REQVAR F Kam StJohn 4/25/2025 AOGCC CMIT 2 Year per AIO 36.004. First attempt. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI34-W6 Inspection Date: Tubing OA Packer Depth 285 1716 1674 1647IA 1644 166 45 Min 1623 60 Min Rel Insp Num: Insp Num:mitKPS250426100711 BBL Pumped:1.9 BBL Returned: Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9999 9 9 9 9 3UHVVXUHORVVQRWWUHQGLQJWRZDUGSVLMEU James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 11:10:22 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: SI34-W6 (PTD #2150160) CMIT-TxIA Failed Date:Friday, May 9, 2025 2:37:41 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, May 9, 2025 9:42 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: Not Operable: SI34-W6 (PTD #2150160) CMIT-TxIA Failed Mr. Wallace, PWI well SI34-W6 operates under AA AIO 36.004 for TxIA communication requiring a 2 year CMIT-TxIA due in June 2025. With ice road availability an initial AOGCC witnessed CMIT-TxIA was performed on 4/25/25 against a CAT standing valve, and failed (See email below on 4/26 with notification). On 4/30/25 a wireline retrievable plug was set and initially passed an internal CMIT-TxIA but while performing the AOGCC witnessed CMIT- TxIA on 5/2/25 a pressure falloff was experienced at 1900 psi and we could no longer build pressure against the plug. A second plug was set on 5/8/25 and failed an internal CMIT-TxIA. The well is now classified at Not Operable and will remain shut in until compliance with AIO 36.004 is restored. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, April 28, 2025 1:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: Injector SI34-W6 (PTD #2150160) CMIT-TxIA Mr. Wallace, As follow up to the below notification on PWI well SI34-W6 (PTD #2150160) which operates under AA AIO 36.004. Our plan forward is to set a wireline retrievable plug and re-attempt a witnessed CMIT- TxIA in the coming days. The well will remain shut in until the upcoming CMIT-TxIA is completed and results are communicated to the AOGCC. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, April 26, 2025 3:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Stephen Soroka <Steve.Soroka@hilcorp.com>; Chris Casey - (C) <Chris.Casey@hilcorp.com> Subject: Injector SI34-W6 (PTD #215016) CMIT-TxIA Mr. Wallace, Water injector SI34-W6 (PTD #215016) operates under AA AIO 36.004 for slow TxIA communication. A witnessed CMIT-TxIA performed on 04/25/25 did not pass. The well will remain shut in until a plan forward can be made. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 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 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Injector SI34-W6 (PTD #215016) CMIT-TxIA Date:Monday, April 28, 2025 7:59:35 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, April 26, 2025 3:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Stephen Soroka <Steve.Soroka@hilcorp.com>; Chris Casey - (C) <Chris.Casey@hilcorp.com> Subject: Injector SI34-W6 (PTD #215016) CMIT-TxIA Mr. Wallace, Water injector SI34-W6 (PTD #215016) operates under AA AIO 36.004 for slow TxIA communication. A witnessed CMIT-TxIA performed on 04/25/25 did not pass. The well will remain shut in until a plan forward can be made. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 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 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] [AOGCC_Public_Notices] Area Injection Order 36.004 amended (Nikaitchuq) SI34-W6 (PTD 2150160) Date:Thursday, July 13, 2023 1:48:56 PM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Thursday, July 13, 2023 1:48 PM To: Lopez Keith <Keith.Lopez@eni.com> Cc: Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Hart David <David.Hart@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] [AOGCC_Public_Notices] Area Injection Order 36.004 amended (Nikaitchuq) SI34-W6 (PTD 2150160) Keith, AOGCC has discussed and re-evaluated this CMIT against several AOGCC and EPA guidance criteria. The test fails against multiple criteria, but the extended CMIT 30-60 min IA values do indicate a potential decreasing/stabilizing trend, and there is the potential that extending the test another 15 to 30 minutes would make a more definitive result. AOGCC deems this test as INCONCLUSIVE for purposes of the Amended AIO 36.004, however AOGCC will not require a retest. The next CMIT will be due before or during June 2025. Eni and AOGCC will monitor the monthly TIO plots as per the AIO and any indication of a change to the overall mechanical condition will initiate a well shut-in, and additional measures including, probably, a retest and potentially a more frequent annual CMIT. In addition, AOGCC would suggest that Eni review the CMIT procedure used and see if, for the future, there may be additional preparation that could/may assist this well achieve a more definitive test result. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Lopez Keith <Keith.Lopez@eni.com> Sent: Tuesday, June 27, 2023 1:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Hart David <David.Hart@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com> Subject: RE: [EXTERNAL] [AOGCC_Public_Notices] Area Injection Order 36.004 amended (Nikaitchuq) Mr. Wallace, Thank you for your reply. We will bring the well back on injection awaiting the AOGCC final determination on the CMIT. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, June 26, 2023 5:05 PM To: Lopez Keith <Keith.Lopez@eni.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Hart David <David.Hart@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com> Subject: RE: [EXTERNAL] [AOGCC_Public_Notices] Area Injection Order 36.004 amended (Nikaitchuq) Keith, I have reviewed the CMIT and last few TIOs that you have provided monthly. I do not have any concerns about continuing injecting under AIO 36.004. AOGCC will defer a final decision on the CMIT determination of pass/fail until after Jim has had time to review and confer with the inspector, which will probably be after July 10. Any questions or concerns please get back to me. Thanks and Regards, th 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. Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7 Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Lopez Keith <Keith.Lopez@eni.com> Sent: Monday, June 26, 2023 1:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Iannucci Giorgio <Giorgio.Iannucci@eni.com>; Hart David <David.Hart@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: FW: [EXTERNAL] [AOGCC_Public_Notices] Area Injection Order 36.004 amended (Nikaitchuq) Mr. Wallace, On 06/25/23, ENI conducted the state witnessed combo MIT on SI34 per the amended AIO 36.004. The state inspector called the test failed due to no stabilizing trend. Reviewing the data, ENI does not agree with the interpretation of not having a stabilizing trend. The test was conducted for 60 minutes, and both the tubing and IA pressure losses declined every 15 minutes with the last decline at only 16 psi and 13 psi respectively. If the failure stands, the next step would be to re-enter the well and set a different type of plug to retest at ~$330,000. ENI realizes that the stabilizing trend is highly interpretable, but due to the high intervention cost and the pressure trends attached we request that the data be reviewed by the AOGCC again. We have the wellwork crew and equipment on standby waiting a second review by the AOGCC. We would like to have a meeting with the AOGCC tomorrow if possible if further discussion is necessary. Please let me know if there is additional data that would help the AOGCC review this test. Thank you for your time. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Security Warning: This email originated from outside of the organization. Do not click links or open attachments unless you have verified the sender’s email address and know the content is safe. Keith.Lopez@eni.com From: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Sent: Thursday, May 18, 2023 4:16 PM To: AOGCC_Public_Notices <AOGCC_Public_Notices@list.state.ak.us> Subject: [EXTERNAL] [AOGCC_Public_Notices] Area Injection Order 36.004 amended (Nikaitchuq) Docket Number: AIO-23-012 Request to Amend Area Injection Order 36.004: Water Injection Nikaitchuq Unit SI34-W6 (PTD 2150160), Schrader Bluff Oil Pool Samantha Carlisle Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 __________________________________ List Name: AOGCC_Public_Notices@list.state.ak.us You subscribed as: keith.lopez@eni.com Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/keith.lopez%40eni.com ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Eni US Operating Co. Inc. SI34-W6 NIKAITCHUQ SI34-W6 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 SI34-W6 50-629-23534-00-00 215-016-0 W SPT 3459 2150160 1500 304 1705 1676 1655 160 220 178 169 REQVAR I Kam StJohn 6/25/2023 2 year CMIT per AIO 36.004 CMIT failed due to it not having a stabizing trend over a 1 hour witness. Test determined to be inconclusive once reviewed. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI34-W6 Inspection Date: Tubing OA Packer Depth 192 1659 1632 1615IA 1637 165 45 Min 1600 1621 162 60 Min 1587 Rel Insp Num: Insp Num:mitKPS230625114906 BBL Pumped:4.9 BBL Returned:4.6 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 99 9 9 9 MEU 9 9 2 year CMIT per AIO 36.004 not having a stabizing trend Test determined to be inconclusive once reviewed. James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 14:50:51 -08'00' From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: SI34-W6 (PTD 2150160) Amended AA 36.004 CMIT Witnessing Requirement Date:Tuesday, May 23, 2023 8:44:49 AM From: Wallace, Chris D (OGC) Sent: Thursday, May 18, 2023 4:52 PM To: Lopez Keith <Keith.Lopez@eni.com> Subject: SI34-W6 (PTD 2150160) Amended AA 36.004 CMIT Witnessing Requirement Keith, Request to Amend Area Injection Order 36.004: Water Injection Nikaitchuq Unit SI34-W6 (PTD 2150160), Schrader Bluff Oil Pool Please note the amended AA AIO 36.004 has the condition to perform an AOGCC witnessed CMIT as soon as possible. There was miscommunication when our inspector went to witness the MITIA on 4/16/23 and left without witnessing the eventual CMIT performed and mentioned in the AIO 36.004 amendment request. As we are now in May and therefore passed the due dates required for the original AIO 36.004, a witnessed CMIT will put us back on track. In 2025 Eni would of course have the opportunity to reschedule all the AA testings into April if that is better for scheduling efficiency etc. http://aogweb.state.ak.us/TestWitnessNotification/ For the SI34-W6 test witness request, 48 hours notice is required and the inspection team has requested you include in the notice remarks section “this CMIT test is for revising the administrative approval AIO 36.004. This is to validate the in-house CMIT done after inspector left the location 4/16/2023”. This will remind the inspection team of this wells unique status. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, May 23, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Eni US Operating Co. Inc. SI34-W6 NIKAITCHUQ SI34-W6 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/23/2023 SI34-W6 50-629-23534-00-00 215-016-0 W SPT 3459 2150160 1500 468 508 474 179 169 169 REQVAR F Brian Bixby 4/22/2023 MITIA as per AIO 36.004. Initial Reading are after pumping about 5 plus minutes, the 15min reading is after pump shut down and block in for 1 minute. It would pressure up past 690 psi. Fluid going straight to the tubing. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI34-W6 Inspection Date: Tubing OA Packer Depth 474 690 490IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230422161314 BBL Pumped:6.2 BBL Returned: Tuesday, May 23, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 MITIA as per AIO 36.004.15min reading is after pump shut down and block in for 1 minute. James B. Regg Digitally signed by James B. Regg Date: 2023.05.23 13:19:07 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 5, 2021 TO: Jim Re �ppp'``` C P.I. Supervisor \-7� J 14l / SUBJECT: Mechanical Integrity Tests L 1 Eni US Operating Company Inc. 5134-W6 FROM: Guy Cook NIKAITCHUQ S134-W6 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ru—_ NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ S134 -W6 API Well Number 50-629-23534-00-00 Inspector Name: Guy Cook Permit Number: 215-096-0 Inspection Date: 4/30/2021 Insp Num: mitGDC210501113550 Rel Insp Num: it erva Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer. ✓ Wednesday, May 5, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- Well S134w6Typeln' w.TVD Tubin �z7 a27 PTD 2150160 T e Test SPT" Test psi I -3450 1500 —427 - lA 612 1733 - 1711 - 1696 BBL Pumped 33 BBL Returned: —37 OA 200 300 , 280 - 260 I t I 4YRTS1 P/F�_ P it erva Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer. ✓ Wednesday, May 5, 2021 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg $' �'7 DATE: Tuesday,October 03,2017 Jim Re P.I.SupervisorC SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC SI34-W6 FROM: Adam Earl NIKAITCHUQ SI34-W6 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvs NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI34-W6API Well Number 50-629-23534-00-00 Inspector Name: Adam Earl Permit Number: 215-016-0 Inspection Date: 9/27/2017 Insp Num: mitAGE170927181222 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well SI34-W6 ' Type Inj W TVD 3459 Tubing 484 485 ' 485 485 485 PTD 2150160 Type Test SPT Test psi 1500 IA 653 1647 • 1613 ` 1591 ' 1574 ------ ---- - BBL Pumped: 3 4 BBL Returned: 3.6 OA 200 245 • 240 230 228 Interval 1 4YRTST P/F P Notes: SCANNED E5 . 42,9-. ) Tuesday,October 03,2017 Page 1 of I Lel o • ri o I w • o o f0 N ai.\ M En E w M } C J J H cIl 'ci co co co co co LL N _U a`�il O E $ v $ a w _ • CO co IIco M M M M M z W J -i W W D. -i W W J •W I O co 0 U) U) U) U) U) J D IWi U' LL O Iwl LL LL Q ce LL o (0 y ui hi hi hi ai < 0 0 0 > 0 0 0 > 0 0 0 Z In E E E E E Z 2 2 2 f- 2 2 2 f- 2 2 2 H LL NNNNNNNNNNNN Q4? a) N a) a) N CO CO CO CO CO CO CO CO CO CO CO CO CO coro co it it it ii: it � U, F N � N N N O co co co co co co co co co co co co co Z CU O coco c U)- co co U) U) in U) U) U) U) U) U) U) U) U) U) U) U) CO C CO coCO CO CO CO co 0 E 0 O) 0 (i) 0 0 N 0 It a LL it it it it LL LL it it it LL it N LL U O U U U (O U U U U U C7 U U U U U U U U N _ _ _ _ _ _ _ _ _ _ _ _ _ _ V 7 co E -E �O 'E N 'c (O -E • E E E E 'E 'E E E 'E E E E E E E Z o o E o 0 0 0 0 o 0o 0 0 0 0 0 0 0 0 0 0 0 Q (n J U D ) i U'p U U d U U U U U U U O U U U U U COL (0 7 N N 7 CO CU W CU CU N N CO CO CU CO CO CO CO CU E wU wU w wM w wre w w w w w w w w w w w w O Z CO co co CO in CO co CO coCO co (n Cn co co CO uO co Om U Y > O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 •0 N N N N N N N N N N N N N N N N N N W (N N N N N N N N N N N N N N N N N N cc dH d N N N N N N N N N N N N N N N N N N Q V V R R V V V V V R R R V (.) z W z 0 0 Z QIa0O W co W cococo coNC'/ CO CO M O o To' N N N N N (n O Ci. 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Inc.Alaska Dispatched To: Makana Bender Well No: Sl34-W6 Date Dispatched: 23-Jun-15 Job#: 14AKA0070 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product 5 Contents on CD N/A VISION*Resistivity 2"MD R + Er`IV x x VISION*Resistivity 2"TVD x _ x VISION*Resistivity 5"MD c JUN 2 3 2U1� x x VISION*Resistivity 5"TVD x x VISION*Resistivity 5"MD IMAGE x x Digital Data N/A Contents on CD N/A ASCII/DLIS x Survey 1 Contents on CD ASP Final Survey x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:PDF x Survey:PDF/xls x Please sign and email a copy to: Please sign and email a copy to: ioshua.zuber(a�enipetroleum.com AlaskaPTSPrintCenter(a slb.com Attention:Joshua Zub r Atte ti n:Stephanie Pacillo Y Received By: ✓wV `e.. UD CD . tc CD D7 o _I 1200020 aONr� NNONn TSTA 12,72a21:422 NOV M NONOW N 0 Y^ O 00000 ONN N Ua0Ua DCDNp O .OPOOOD PNNV pNOppM CO NNNNNNNN N � .- pyM * OUa0NN NNMa . n AMN00 . 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O ANmWO NM M y 'g O NN NNNNN NNNNM MMMM MNMm mN N N N N N NNN N N NNN N N NNN N 00000 N N N N 0 N C m 0 G W 10 a n - (V o m - N U 0 r m 1 p o CO 0 0 215016 25957 Schlumberger Transmittal#: 23JUN15-SPO2 Drilling& Measurements DATA LOGGED MWD/LWD LogProduct Delivery i9�20tE M.K.BENDER Customer: ENI Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No: Sl34-W6 BestDT Date Dispatched: 23-Jun-15 Job#: 14AKA0070 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product 1 Contents on CD N/A SonicVISION BestDT _ x x 13,250' -23,800' MD 1 EC�{,. JUN 2 3 201r; AOGC Digital Data N/A Contents on CD N/A ASCII/DLIS x Survey N/A Contents on CD CD 1 Contents on CD Data: DLIS/ASCII x Graphics: PDF x Please sign and email a copy to: Please sign and email a copy to: joshua.zuber(a�enipetroleum.com AlaskaPTSPrintCenter(a�slb.com Attention:Joshua Zuber ✓ Attentio :Step ie Pacillo fi) Received By: 21 5016 25 958 Schlumberger Transmittal#: 23JUN15-SPO3 Drilling&Measurements DATA LOGGED MWD/LWD Log Product Delivery 1" /2015 M.K.BENDER Customer: ENI Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No: S134-W6 T.O.C. Date Dispatched: 23-Jun-15 Job#: 14AKA0070 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product RECEIVED 1 Contents on CD N/A SonicVISION Top of Cement x x JUN 2 3 2015 -AOGCC Digital Data N/A Contents on CD N/A ASCII/DLIS x Survey N/A Contents on CD CD 1 Contents on CD Data: DLIS/ASCII x Graphics: PDF x Please sign and email a copy to: Please sign and email a copy to: ioshua.zuberenipetroleum.com AlaskaPTSPrintCenter(a�slb.com Attention:Joshua Zuber Atga4taAtte tion: t phanie Pacillo MReceived By: V 21 5016 25723 HALLIBURTON RECEIVED APR 2 2 2015 • Sperry Drilling AOGCC To: Alaska Oil and Gas Conversation Commission 333 W 7th Ave Suite 100 DATA LOGGED Anchorage, AK 99501 5 /obi/2015 ;vi K.BENDER Attn: Meredith Guhl From: Sperry Drilling - Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield@Halliburton.com Re: Eni Petroleum Well — SI34-W6 AFE # 6932 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports 1 Final Data Listing on CD-ROM 1 Sets of Final Logs — for each well contains: • 2" Color Log — Formation Evaluation TVD • 2" Color Log — Formation Evaluation MD • 2" Color Log — Drilling Engineering MD • 2" Color Log — Gas Ratio MD Received By: Print Name Sign Name Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Lt Z I DATE:Monday,April 20,2015 TO: Jim Regg P.I.Supervisor `Q�l I S SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC SI34-W6 FROM: Matt Herrera NIKAITCHUQ SI34-W6 Petroleum Inspector Src: Inspector Reviewed P.I.Supr .) - NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI34-W6 API Well Number 50-629-23534-00-00 Inspector Name: Matt Herrera Permit Number: 215-016-0 Inspection Date: 4/17/2015 Insp Num: mitMFH150417165614 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well_' SI34-W6 Type Inj W'TVD 3459 - Tubing 478 479 477 478 - PTD� 2150160 - Type Test SPT Test psi 1500 • IA 924 . 1779 - 1761 - 1757 Interval IINITAL P/F P v OA 205 245 - 220 220 • Notes: 2 6 BBL'S Diesel to bring IA to MIT Pressure . Monday,April 20,2015 Page 1 of 1 STATE OF ALASKA ALASK. L AND GAS CONSERVATION COMMIS J WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WNJ ❑✓ WAG ❑ WDSPL ❑ No.of Completions: Service n . Stratigraphic Test ❑ 2.Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: ENI US Operating Co. Inc. Aband.: 3/31/2015• 215-016 = 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 2/20/2015- 50-629-23534-00-00• 4a. Location of Well(Governmental Section): 7.Date TD Reached: .v.& 14.Well Name and Number: Surface: 4428.8 FSL 1483.4 FEL S19 T14N R9E UM 12/6/2014 3//sits-14.2.0 SI34-W6 I Top of Productive Horizon: 8. KB(ft above MSL): 53.9 15. Field/Pool(s): 4155 FSL 1130 FEL 26 T14N R8EUM GL(ft above MSL): 13.1 Total Depth: 9. Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool . 4497 FSL 3761 FEL 22 T14N R8EUM N/A 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 511426.58 y- 6053610.33 Zone- 4 •23886'MD/3299'TVD = ADL 0391283.0388574,0388575.0388577 • TPI: x- 501424.69 y- 6048048.35 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 493509.36 y- 6053672.13 Zone- 4 N/A ADL 417493 18. Directional Survey: Yes 7- No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) • 1859'MD/1759'TVD 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Sonic .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 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 36.95 2803 36.95 2417 16 10.7 ppg Lead: 436 bbls N/A 12.5 ppg Tail:64 bbls 9.625 40 L-80 35.63 13304 35.63 3462 12.25 12.5 ppg LiteCRETE:205 bbls N/A 4.5 15.5 L-80 13102 21532 3462 3299 8.75 Liner with ICD&Swelling Pac N/A 24. Open to production or injection? Yes ❑✓ No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4.5 13,122' 12,974'MD!3,459'TVD Liner with ICD ������� Li26. ACID, FRACTURE,CEMENT SQUEEZE. ETC. 2( f 1 RWas hydraulic fracturing used during completion? Yes No Li 1 ` ` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED <, n APR 15 2015 AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period ...*N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate -0. N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No[i] - Sidewall Cores Acquired? Yes ❑ No U 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. Form 10-407 Revise 10/2012 8Smit original only Akt?) (01 /S 0)61715° RBDM �� APR 1 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1859 1759 Top Ugnu 2465 2217 Top Lower Ugnu 10847 3042 Top Schrader Bluff 11778 3274 Top N Sand 12085 3345 Top OA Sand 13011 3460 Formation at total depth: OA sand 23886 3299 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary,Cement reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Email: giuseppe.maugeri@enipetroleum.com Printed Name: Marc Kuck Title: Drilling and Completion Engineering Manager Signature: Phone: (907)865-3328 Date: 4/13/2015 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 lb: 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 N C Ngo 2 o o r OC) d o co in Q1 R E 1Z! - Cl) M O 0 M �. 4.' Int Q 0 a .c .� o_ J C Nco. ts Y , .,- O 4 a) U OL ._ i c13 a 0 0 > d O N . 4N • N `� m — V ,,� A. Lo I C• _ Q i 73 ' o C ._ ' N § J }, iv* L. c2 OC m Y a J V o tart m co E c N x °' o O mili ft �- a� z o m `� _ MaiTo a X H I N Yco _d Q Q = I ❑ 2 CU N -0 Q c 1 N CID_ •�CO _ X ti 1 ❑ = d % V t.) c C o _ M 2 N p Q M = U ch ❑ N ca o X oo No o 2 p os .00 4-P ❑ c� M y r2 o �,6' To Co Q r �4 CO L O (n L > Co , +_1.0 O+ M O (6 N O M 07 N N _C O) e cfl N cc N O 0 C 2 O f� CO lD Ln FA ‘ii M co-cy) N Q O N N c N Q I o . N ch - �\ 0 0 0 0 0 0 0 7A/ S` . U U U U U U U Y ooih � b) tiboo Q7 Q N LA L 00 r- CO CO C Q O M CO OD OD CO O O O d7 CO COTi) C r� co N N o _ W Y V 2 U U U U U U U 03 Nam .,,.a. .� Q ,= O p C1 Cl. 0 0ooo a c ti o co r c) in - U 1 CO CO _ O ❑ N N O O) f - In = _ . Y 2 Co U o T- O N. M to Wcfl ti o0 z el co v. D N N W4W4i W = N N N E rl tL Q CL d O fill* Eni E&P Divisionwell Name:sl �R ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • n Date:2/18/2015 - Report#: 1 API/U WI:50-629-23534-00-00 e II (I IIpage 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 1 1.22 1 1.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-WO DRILLING 2/20/2015 7,331.05 7271.92 205.69 354 -1.10 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(`C) Weather Wind 0.00 120.0 -12.2 Partly Cloudy WC 2' SSW @ 7 MPH Daily summary operation 24h Summary Prep rig for move:Blow down all transfer lines.R/D ODS Suitcases.R/D all interconnects under rig floor.RID Choke,Bluy,and Flow lines.Prep Rockwasher.Install Mud Pump#2 and R/U manifold.Prep rig floor for skidding.Blow down H2O and Steam lines.Lay and weld Herculite for Rockwasher.Lay rig mats for Rockwasher and pull forward.R/D DS suitcases.Skid rig floor off well and raise stompers. Stage Pump#3 on west side of rig.Move Pit Mod away from Sub.Remove 2 sections of Diverter line via Crane.C/O air boot on Flow Line interconnect.Install Diverter line PUP.Move and spot Sub over 5134-W6.Move and spot Pit complex.Skid rig floor.Rig up service lines.Spot Mud Pump#3 and Rockwasher.Cont.rigging up service lines.Spot Mud Lab and Mud Logger shacks.R/U and swap over to main generator power.Work on kenning around rig.Spot DS suitcases. Operation at 07.00 Cont.to rig up. 24h Forecast Cont.to rig up.Set starter well head and test.N/U Diverter Stack.Perform Diverter Stack test.Flood and test all lines.Transfer Spud Mud.P/U M/U BHA. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 MOB A 2 P PJSA Prep rig for move:Blow down all transfer lines.R/D ODS Suitcases.R/D all interconnects under rig floor.R/D Choke, Bluy,and Flow lines.Prep Rockwasher.Install Mud Pump#2 and R/U manifold.Prep rig floor for skidding.Blow down H2O and Steam lines. • 06:00 07:00 1.00 7.00 MOB A 2 P PJSA Lay and weld Herculite for Rockwasher.Lay rig mats for Rockwasher and pull forward.R/D DS suitcases. 07:00 09:00 2.00 9.00 MOB A 2 P PJSM Skid rig floor off well and raise stompers. 09:00 10:30 1.50 10.50 MOB A 2 P PJSM Stage Pump#3 on west side of rig.Move Pit Mod away from Sub. 10:30 12:00 1.50 12.00 MOB A 2 P PJSM Remove 2 sections of Diverter line via Crane.C/O air boot on Flow Line interconnect. 12:00 18:00 6.00 18.00 MOB A 2 P PJSM Install Diverter line PUP.Move and spot Sub over S134-W6.Move and spot Pit complex.Skid rig floor.Rig up service lines. 18:00 00:00 6.00 24.00 MOB A 2 P PJSA Spot Mud Pump#3 and Rockwasher.Cont.rigging up service lines.Spot Mud Lab and Mud Logger shacks.R/U and swap over to main generator power.Work on berating around rig.Spot DS suitcases. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 • Em representative Bernie Leas ENI Rig Clerk akrgclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Charlie Huntington Doyon Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') Eni E&P Divisionwen Name:SiOR ENI Petroleum Co.lnc. Daily Report Well Code:29543 Field Name:NIKAITCHUO !If* eII APIIU WI:50-629-23534-00-00 2^ri Date:2/19/2015 - Report#: 2 II II page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331 05 7,271 92 205.69 35.4 -0.10 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 0.00 123.0 -15.0 Overcast WC-6' W @ 7 MPH Daily summary operation 24h Summary M/U Interconnects under ng floor and between Pit and Sub.RAJ DS suitcases.R/U Mud Pump#3.Spot ODS Suitcases.C/O drive shaft of Mud Pits auger.Berm around rig.Stage Well Head and Grey Loc clamps on BOP landing via crane and secure in Cellar.N/tJ Starting Head,Riser and Diverter Stack as per Vetco Gmy Rep onsite.Test connections to 5,000 PSI for 10 Min.N/U Flow Riser and Diverter Line.SIMOPS Bring on 700 bbl 8.75 ppg Spud Mud to Pits.Cont.RIO Pump room and Mud Pump#2.Finish Bemtirg around Beaver Slide.PJSA Perform Diverter test and Koomey draw down W/5"D.P.Annular closed in 28 Sec.,Knife Valve open in 3 Sec.Witnessed waived by Bob Noble 2-20-15.Dummy run 13 3/8"Hanger as per Vetco Grey Rep onsite.Service and inspect TDS-8,Saver Sub and change gear oil and fitter.Cut and slip drilling line,service Drawworks and adjust brakes.Bring BHA Stabs and X/O to rig floor.Install Mouse Hole and long Mouse Hole in Rotary Table.P/U MN 5 stands 5"HWDP and Jam.PAl M/U 8"NMFC. Operation at 07.00 - Clean out 20"Conductor. 24h Forecast Cont.to M/U NMFC.P/U M/U 16"BHA#1.Clean out 20"Conductor to 160'.POOH and P/U M/U BHA#2.Drill to 280'MD and POOH,P/U 5"HWDP and Jar.RIH and drill ahead 16"Surface hole as per Well Plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 MOB A 2 P 'PJSA M/U Interconnects under rig floor and between Pit and Sub.R/U DS suitcases.R/U Mud Pump#3.Spot ODS Suitcases.CIO drive shaft of Mud Pits auger.Berm around rig. 0600 07:00 1.00 7.00 DRILL C 20 P •PJSA Stage Well Head and Grey Loc clamps on BOP landing via crane and secure in Cellar. 0700 11:00 4.00 11.00 DRILL C 20 P r PJSA N/U Starting Head.Riser and Diverter Stack as per Vetco Grey Rep onsite.Test connections to 5,000 PSI for 10 Min. 11:00 14:30 3.50 14.50 DRILL C 20 P -PJSA N/U Flow Riser and Diverter Line.SIMOPS Bring on 700 bbl 8.75 ppg Spud Mud to Pits. 14:30 16:30 2.00 16.50 DRILL A 20 P 'PJSM Cont.R/U Pump room and Mud Pump#2.Finish Benning around Beaver Slide. 16:30 17:30 1.00 17.50 DRILL C 12 P PJSA Perform Diverter test and Koomey draw down W/5"D.P.Annular closed in 28 Sec.Knife Valve open in 3 Sec. Before function Annular 950 PSI,Manifold 1500 PSI,System 3,000 PSI,After function Annular 950 PSI,Manifold 1,500 PSI,System 1,650 PSI.200 PSI increase in 32 Sec.Total system recharge 146 Sec.5 bottle Nitrogen average 2,400 PSI. Witnessed waived by Bob Noble 2-20-15. 17:30 18:00 0.50 18.00 DRILL C 20 P PJSA Dummy run 13 3/8"Hanger as per Vetco Grey Rep onsite. 18:00 19:00 1.00 19.00 DRILL E 25 P PJSA Service and inspect TDS-8,Saver Sub and change gear oil and filter. 19:00 21:30 2.50 21.50 DRILL E 25 P PJSA Cut and slip drilling line,service Drawaorks and adjust brakes. 21:30 22:30 1.00 22.50 DRILL E 20 P "PJSA Bnng BHA Stabs and X/O to rig floor.Install Mouse Hole and long Mouse Hole in Rotary Table. 22 30 00:00 1.50 24.00 DRILL E 20 P "PJSA P/U M/U 5 stands 5"HWDP and Jars.P/U M/U 8"NMFC. Daily Contacts Position Contact Name Company Title ! E-mall Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907.685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Charlie Huntington Doyon Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher rg15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1* Eni E&P Division Well Name:Si OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ • en 11 Date:212012015 - Report#: 3 API/UWI:50-629-23534-00-00 page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 090 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 320.95 318.31 308.45 5.82 53.0 122.0 -13.3 Overcast WC-7" NE @ 20 MPH Daily summary operation 24h Summary L/D Mouse Hole,clean and clear rig floor.P/U M/U 16"Clean Out BHA#1 as per Schlumberger DD and MWD onsite.Test high Press.Mud Line to 4,000 PSI charted.Flood Diverter Stack and check for teaks.Clean out 20"Conductor to 165'MD 500 GPM.350 PSI,40 RPM,TRO 1.5K.POOH to 30'.Have Pm Spud meeting with all companies at SID.Perform PJSM for DAM BHA.PN M/U BHA#2 as per Schlumberger DD and MWD.to 117'.Wash down to 165'MD 560 GPM,600 PSI.Drill 16"Surface F/165'to 392'MD.BROOH F/392'to 117'MD 560 GPM,500 PSI,40 RPM,TRQ 2K.MN remaining BHA#2 to 341'MD.Wash down to 392'MD.500 GPM,425 PSI.(NM STAB,5"HWDP and Jar)Drill 16"Surface F/392'to 1,053'MD(1,044'TVD)650 GPM,1,000 PSI,40 RPM,TRO 3-4K,TQF 2-3K. WOB 2-20K,HST 127K,SLK 126K,ROT 128K.Max Gas 46 units.ECD 9.96 ppg W/9.2 ppg MW.ADT 2.69,AST 2.11 ART 0.58.Bit Hrs 5.82,Jar Hrs 5.82. Operation at 07.00 Drill 16"Surafce @ 1,365'MD. 24h Forecast Drill 16"Surface to 2,900'as per plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00.30 0.50 0.50 DRILL E 20 P PJSA L/D Mouse Hole,clean and clear rig floor. 00:30 01:30 1.00 1.50 DRILL E 20 P PJSA P/U M/U 16"Clean Out BHA#1 as per Schlumberger DO and MWD onsite. 01:30 02:30 1.00 2.50 DRILL E 12 P PJSA Test high Press.Mud Line to 4,000 PSI charted.Flood Diverter Stack and check for leaks. 02:30 04:00 1.50 4.00 I DRILL E 3 P PJSA Clean out 20"Conductor to 165'MD 500 GPM,350 PSI,40 RPM,TRQ 1.5K.POOH to 30'. 04:00 05:00 1.00 5.00 DRILL E 20 P Have Pm Spud meeting with all companies at SID.Perform PJSM for D/U BHA. 05:00 07:00 2.00 7.00 DRILL E 20 P PJSA PN MN BHA#2 as per Schlumberger DD and MWD.to 117'.Wash down to 165'MD 560 GPM,600 PSI.(NMSTAB, X/O,GYRO,TELESCOPE and ARC) 07:00 12:00 5.00 12.00"DRILL E 3 P PJSA Drill 16"Surface F/165'to 392'MD 560 GPM,650 PSI,40 RPM,TRO 2K,TQF 2K,WOB 2-8K,HST 90K,SLK 90K, ' ROT 90K.Max Gas 0.ADT 2.15,ART 2.15,Bit Hrs 2.15,Jar Hrs 2.15. 12:00 14:00 2.00 14.00 I DRILL E 6 P •PJSA BROOH F/392'to 117'MD 560 GPM,500 PSI,40 RPM,TRQ 2K. 14:00 15.30 1.50 15.50 I DRILL E 20 P I PJSA M/U remaining BHA#2 to 341'MD.Wash down to 392'MD.500 GPM,425 PSI.(NM STAB,5"HWDP and Jar) 15:30 18:00 2.50 18.00 DRILL E 3 P PJSA Drill 16"Surface F/392'to 680'MD(679'TVD)650 GPM,900 PSI,40 RPM,TRO 3K,TQF 1K,WOB 2-10K,HST 100K,SLK 100K,ROT 100K.Max Gas 0.ECD 9.4 ppg W/9.1 ppg MW.ADT 0.98,AST 0.42 ART 0.56,Bit Hrs 3.13,Jar Hrs 3.13. 18:00 00:00 6.00 24.00"DRILL E 3 P "PJSA Drill 16"Surface F/680'to 1,053'MD(1,044'IVO)650 GPM,1,000 PSI,40 RPM,TRO 3-4K,TQF 2-3K,WOB 2- 20K,HST 127K,SLK 126K,ROT 128K.Max Gas 46 units.ECD 9.96 ppg W/9.2 ppg MW.ADT 2.69,AST 2.11 ART 0.58. Bit Hrs 5.82,Jar He 5.82. Daily Contacts Position Contact Name Company _ Title E•mall Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrgclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Charlie Huntington Doyon Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P Division (Well Name:SI JR ENI Petroleum Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO eII^ Co.n Date:212112015 - Report#: 4 APIIUWI:50-629-23534-00-00 II II page 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-01G ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 190 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 858.32 738.65 537.36 11.69 46.0 126.0 -15.0 Snow WC-17° NNE @ 25 MPH Daily summary operation 24h Summary Drill 16"Surface FI 1,053'to 2,816'MD(2,422'ND)800 GPM,1,800 PSI,40 RPM,TRO 7-8K,TOF 6K,WOB 10-30K,HST 160K,SLK 130K,ROT 142K.Max Gas 1,005 units.ECD 10.15 ppg W/9.4 ppg MW.ADT 11.69,AST 7.82,ART 3,87,Bit Hrs 17.51,Jar Hrs 17.51.Monitor well,static.Went to MWD @ 1,065'MD.BROOH as per K&M Schedule F/2,816'to 2,268'MD.850 GPM,1,625 PSI,60 RPM,TRO 5K,ECD 10.16 ppg.HST 155K,SLK 132K,ROT 142K.Lost 4 bbl during back reaming. Operation at 07.00 BROOH as per K&M Schedule at 1,334'MD. 24h Forecast Cont.to BROOH F/2,268'to BHA#2.L/D BHA#2.P/U MN GBR Volant tools and Equip.RIH 13 3/8"Csg as per tally. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 11324 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 G 50 6.00 DRILL E 3 P PJSA Drill 16"Surface F/1,053'to 1,551'MD(1,551'TVD)700 GPM,1,320 PSI,40 RPM,TRO 6-8K,TQF 2-4K.WOB 15- 25K,HST 139K,SLK 129K,ROT 133K.Max Gas 114 units.ECD 10.26 ppg W/9.25 ppg MW.ADT 3.91,AST 2.77,ART 1.14,Bit Hrs 9.73,Jar Hrs 9.73.Monitor well,static.Went to MWD @ 1,065'MD. • 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 16"Surface F/1,551'to 2,079'MD(1,940'ND)750 GPM,1,480 PSI,40 RPM,TRO 7-8K,TOF 4-6K,WOB 10- 20K,HST 155K,SLK 130K,ROT 140K.Max Gas 1,005 units.ECD 10.20 ppg W/9.35 ppg MW.ADT 3.02,AST 1.76,ART 1.26,Bit Hrs 12.75,Jar Hrs 12.75.Monitor well,static. 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 16"Surface Fl 2,079'to 2,660'MD(2,338'ND)800 GPM,1,760 PSI,40 RPM,TRO 7-8K,TOF 5-6K,WOB 10- 30K,HST 160K,SLK 130K,ROT 142K.Max Gas 554 units.ECD 10.16 ppg W/9.4 ppg MW.ADT 3.74,AST 2.56,ART 1.18,Bit Hrs 16.49,Jar Hrs 16.49.Monitor well,static. 18.00 20:00 2.00 20.00 DRILL E 3 P PJSA Drill 16"Surface F/2,660'to 2,816'MD(2,422'ND)800 GPM,1,800 PSI,40 RPM,TRO 7-8K,TQF 6K,WOB 10- 30K,HST 160K,SLK 130K.ROT 142K.Max Gas 118 units.ECD 10.15 ppg W/9.4 ppg MW.ADT 1.02.AST 0.73,ART 0.29,Bit Hrs 17.51,Jar HIS 17.51.Monitor well,static. 20.00 00:00 4.00 24.00 DRILL E 6 P BROOH as per K&M Schedule F/2,816'to 2,268'MD.850 GPM,1,625 PSI,60 RPM,TRO 5K,ECD 10.16 ppg.HST 155K, SLK 132K,ROT 142K.Lost 4 bbl during back reaming. Daily Contacts Position _ Contact Name - Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigc)erksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Mails Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Charlie Huntington Doyon Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mod Wright(gIL) P LeakOff(kgEcm') Iriff* Eni E&P DivisionWell Name:SI, JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ n Date:2/22/2015 - Report#: 5 APIIUWI:50-629-23534-00-00 e II (I II page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331.05 7.27192 205.69 35.4 2.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 858.32 738.65 0.00 125.0 -20.0 Blowing Snow WC- NE @ 38 MPH Gust 35° To 46 MPH Daily summary operation 24h Summary BROOH as per K&M Schedule F/2,268'to 400'MD.850 GPM.1.200 PSI,60 RPM,TRQ 3K,ECD 9.85 ppg.HST 110K,SLK 107K,ROT 108K.PJSM WI all essential personnel.L/D BHA#2 as per Schlumberger DD and MWD onsite.Stand back 5"HWDP,Jar and NM FC.16"Bit Grade 1-1-WT-A-E-IN-NO-TD.Clean and clear rig floor of BHA#2 components.Prep for 13 3/8"Csg.job.PJSM W/all essential personnel.MOB&stage GBR CRT and handling Equip. Finish loading GBR CRT and Equip.to rig floor.R/U Volant,long bails W/Link Tilt and Bail Ext. M/U 133/8"Csg,L-80,68.08 BTC Shoe Track to 120'MD.Baker Loc and test Shoe Track.RIH 13 3/8"Csg.F/120' to 2,763'MD.Total 70 Jnts run.Break Circ.every 10 Jnts.SLK 187K. Operation at 07.00 Perform Surface cement job. 24h Forecast P/U M/U Hanger and Landing Jnt as per Vetco Grey Rep onsite.Land Hanger and Csg.@ 2,803'MD.Blow down TDS-8 and R/U to Com Coo and condition Spud Mod to<20 YP Perform Cement job. Clean all surface Equip.N/D Diverter Stack and NI/LI BOPE. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.30 6.50 6.50 DRILL E 4 P PJSA BROOH as per K&M Schedule F/2,268'to 400'MD.850 GPM,1,200 PSI,60 RPM,TRQ 3K,ECD 9.85 ppg.HST 110K,SLK 107K,ROT 108K. 06:30 -10:00 3.50 10.00 DRILL E 4 P PJSM WI all essential personnel.L/D BHA#2 as per Schlumberger DD and MWD onsite.Stand back 5"HWDP,Jar and NM FC.16"Bit Grade 1-1-WT-A-E-IN-NO-TD. 10:00 10:30 0.50 10.50 DRILL E 20 P PJSA Clean and clear rig floor of BHA#2 components.Prep for 13 3/8"Csg.job. 10:30 12:00 1.50 12.00 DRILL G 20 P PJSM W/all essential personnel.MOB&stage GBR CRT and handling Equip. 12:00 -14:00 2.00 14.00'DRILL G 20 P PJSM Finish loading GBR CRT and Equip.to rig floor.RN Volant,long bails W/Link Tilt and Bail Ext. 14:00 "15:00 1.00 15.00 DRILL G 4 P PJSA M/U 13 3/8"Csg,L-80,68.08 BTC Shoe Track to 120'MD.Baker Loc and test Shoe Track. l5:00 18:00 3.00 18.00 DRILL G 4 P PJSA RIH 13 3/8"Csg.F/120'to 600'MD as per tally.Break Circ.every 10 Jnts 3 bpm,8-PSI,SLK 100K. 18:00 00:00 6.00 24.00 DRILL G 4 P PJSA RIH 13 3/8"Csg.As per tally Fl 600'to 2,763'MD.Total 70 Jnts run.Break Circ.every 10 Jnts.SLK 187K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Charlie Huntington Doyon Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12 415 L-80 -0 12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') Eni E&P Division 'Well Name:SI OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO e.� Date:2/23/2015 - Report#: 6 APIIUWI:50-629-23534-00-00 II 11 Wellbore name: S134-W6 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3 99 11.22 ,..1.22 Rig Information Contractor Rig Name Rig Type • DOYON RIG 15 LAND RIG ' Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0134-716 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 3.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 858.32 738.65 0.00 121.0 -13.3 Overcast WC-2" E @ 7 MPH Daily summary operation 24h Summary P/U M/U 13 3/8"Hanger as per Vetco Grey Rep onsite.Land Hanger @ 2,803'MD.HST 250K,SLK 187K.Blow down TDS-8.R/U Cement line and valves.Circ.and condition mud as per MI Swaco plan forward to<20 YP for cement job.Shut down rig pumps and Schlumberger pumped 10 bbls.H2O to fill lines and tested lines to 807/3,683 psi.-good.Switched back to rig pumping 100 bbls.of Mud Push II @ 10.1 ppg-rate of 4 bpm @ 130 psi.Shut-down,release from Volant tool and drop bottom plug.SLB mix&pump Lead slurry 436.24 bbls W/10.7 ppg ASL B809[2.77 ft3/sk Yield,mix water at 13.506 gal/sk.]-Pump rate of 5.8 bpm @ 400 to 550 psi.,Tail slurry 64.34 bbls W/12.5 ppg LiteCRETE[1.56 fi3/sk Yield,mix water at 5.436 gaUsk.]-Pump rate of 4.0 bpm @ 400 to 450 psi.Shut down, release from Volant and drop top plug-SLB pump 10 bbls H2O and wash up.Displace with 399 bbls W/9.3 ppg Spud Mud with ng pump at 5.5 bpm w/450 psi,final pressure 370 psi.Plug bumped Press.up to 850 PSI and hold for 5 Min.Check floats,holding.Cement in place @ 09:35 hr.174 bbl of cement was seen at surface.Drain Stack and fill W/Contam Pill.Rinse and R/D Volant tools and Equip.L/D Landing Joint.Install Bails and 5"Elevators.MN Stack washer and flush Stack.L/D GBR Csg.Equip.from rig floor.N/D Diverter Stack,Diverter Line,lower riser and Starting Head.Prep and set Mufti Bowl.Test upper and Lower Hanger seals to 2,000 PSI for 10 Min.Witnessed by CO Rep onsite.N/U Lower High Press.Riser.N/U BOPE.SIMOPS Load 5"D.P.in Pipe Shed.Level rig floor. R/U for body test for BOPE. Operation at 07.00 • P/U M/U 5"D.P.from Pipe Shed and rack back in Derrick. 24h Forecast Test BOPE body.Process 5"D.P.P/U MN 5"D.P.F/Pipe Shed and rack back in Derrick.Test BOPE and 13 3/8"Csg.P/U M/U BHA#3. Llthology Shows MAASP(kgflcm') Mud Weight(gIL) 11144 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL G 4 P PJSM P/U M/U 13 3/8"Hanger as per Vetco Grey Rep onsite.Land Hanger @ 2,803'MD.HST 250K,SLK 187K. 00:30 02:30 2.00 2.50 DRILL G 20 P PJSA Blow down TDS-8.R/U Cement line and valves. 02:30 05:30 3.00 5.50 DRILL H P PJSA Circ.and condition mud as per MI Swaco plan forward to<20 YP for cement job. 05:30 10:30 5.00 10.50 DRILL H P PJSM W/all essential personnel.Blow air thru cement Iine.Shut down rig pumps and Schlumberger pumped 10 blots.H2O pa- to fill lines and tested lines t0 807/3,683 psi.-good.Switched back to rig pumping 100 bbls.of Mud Push II @ 10.1 ppg- (� rate of 4 bpm©130 psi.Shut-down,release from Volant tool and drop bottom plug.SLB mix&pump Lead slurry 436.24 3� a bbls W/10.7 ppg ASL B809[2.77 ft3/sk Yield,mix water at 13.506 gaVsk.]-Pump rate of 5.8 bpm @ 400 to 550 psi.,Tail )3 g slurry 64.34 bbls W/12.5 ppg LIteCRETE[1.56 ft3/sk Yield,mix water at 5.436 galsk.]-Pump rate of 4.0 bpm @ 400 to 450 psi.Shut down,release from Volant and drop top plug-SLB pump 10 bbls H2O and wash up.Displace with 399 bbls WI 9.3 ppg Spud Mud with rig pump at 5.5 bpm w/450 psi,final pressure 370 psi.Plug bumped Press.up to 850 PSI and J hold for 5 Min.Check floats,holding.Cement in place @ 09:35 hr.174 bbl cement was seen at surface. i+ 10:30 11:30 1.00 11.50 DRILL H 20 P PJSA Drain Stack and fill W/Contam Pill.Rinse and R/D Volant tools and Equip.L/D Landing Joint. 11:30 13:00 1.50 13.00 DRILL H 20 P PJSA Install Bails and 5"Elevators.MN Stack washer and flush Stack. 13:00 13:30 0.50 13.50 DRILL G 20 P PJSA LID GBR Csg.Equip.from rig floor. 13:30 17:00 3.50 17.00 DRILL C 5 P PJSM N/D Diverter Stack,Diverter Line,lower riser and Starting Head. 17:00 20:00 3.00 20.00 DRILL C 5 P PJSA Prep and set Multi Bowl.Test upper and Lower Hanger seals to 2,000 PSI for 10 Min.Witnessed by CO Rep onsite. N/U Lower High Press.Riser. • 20:00 23:30 3.50 23.50 DRILL C 5 P PJSA N/U BOPE.SIMOPS Load 5"D.P.in Pipe Shed.Level rig floor. 23:30 00:00 0.50 24.00 DRILL C 20 P PJSA R/U for body test for BOPE. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigcIerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Charlie Huntington Doyon Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12 415 L-80 -012 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P DivisionWell Name:Si.. OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • 2,sII Date:2124/2015 - Report#: 7 APIIUWI:50-629-23534-00-00 �I I�npage 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 9134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 4.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 850.32 738.65 0.00 120.0 -11.7 Scatterd Clouds WC SW @ 26 MPH -11° Daily summary operation 24h Summary Cont.N/U BOPE.Install short mouse hole. R/U and perform body test on BOPE and Choke Manifold.SIMOPS Load and process 5"D.P.into Pipe Shed.Inspect Saver Sub.Blow down Choke and drain BOPE stack.Unscrew from test plug and L/D test joint.Change Saver Sub due to normal wear.Re install Bell Guide Assy.from Csg.job.Break down TIW and X/O for 13 3/8"Csg X/O.Install long mouse hole and L/D 3 stands 5"HWDP from Derrick.P/U M/U 5"D.P.from Pipe Shed and rack back in Derick.Total of 122 stands.RAJ test Equip.for ROPE.Test BOPE W/5"test joint. Operation at 07.00 -- P/U M/U BHA#3. 24h Forecast Finish testing BOPE.Test 13 3/8"Csg.to 2,500 PSI for 30 Min.P/U M/U 12.25"Bit and BHA#3.RIH and drill out 13 3/8"Shoe Track and 20'of new hole to 2,836'MD.Displace Spud Mud to new LSND. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr)_Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL C 5 P PJSM Cont.N/U BOPE.Install short mouse hole.SIMOPS Load and process 5"D.P.into Pipe Shed. 01:00 02:30 1.50" 2.50 DRILL C 12 P PJSA R/U and perform body test on BOPE and Choke Manifold.SIMOPS Load and process 5"D.P.into Pipe Shed. Inspect Saver Sub. 02:30 03:00 0.50 3.00 DRILL C 20 P PJSA Blow down Choke and drain BOPE stack.Unscrew from test plug and L/D test joint. 03:00 05:00 2.00 5.00 DRILL E 25 P PJSM Change Saver Sub due to normal wear. 05:00 05:30 0.50 5.50 DRILL E 20 P PJSA Re install Bell Guide Assy.from Csg.job.Break down TIW and X/O for 13 3/8"Csg X/O. 05:30 06:00 0.50' 6.00 DRILL E 20 P PJSA Install long mouse hole and L/D 3 stands 5"HWDP from Derrick. 06:00 17:00 11.00 17.00 DRILL E 20 P PJSM P/U M/U 5"D.P.from Pipe Shed and rack back in Derrick.Total 01 122 stands. 17:00 18:00 1.00 18.00 DRILL C 20 P PJSM R/U test Equip.for BOPE. In 18:00 00:00 6.00 24.00 DRILL C 12 P PJSA Test BOPE W/5"test joint:Test Annular 250 PSI low and 2,500 PSI high.Valves 1-14 on Choke Manifold.Upper- �i and Lower Pipe Rams to 250 PSI low and 3,500 PSI high for 5 Min all charted.Perform Koomey draw down:Start Press. -F" System 3,000 PSI,Manifold 1,500 PSI,Annular 700 PSI.After function System Press.1,500 PSI,Manifold 1,400 PSI, V Annular 700 PSI.200 PSI increase 41 Sec.Total system recharge 194 Sec.Average 5 bottle Nitrogen charge 2,400 PSI. Daily Contacts Position Contact Name Company Title I E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm") Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 864.41 741.64 LSND 1114.4 33.0 1559.9 115.7 Eni E&P Division WeIlName:Sl OR rill* ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ nDate:212512015 - Report#: 8 APIIUWI:50-629-23534-00-00 l�II II II page 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7.271.92 205.69 35.4 5.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 1,072.29 790.60 217.93 4.65 46.9 124.0 -8.3 Overcast WC-3" SSW @ 22 MPH Daily summary operation 24h Summary Cont.BOPE with Blind Rams to 250 PSI low and 3,500 PSI high.Test both Manual Chokes and Super Choke to 1,500 PSI.All tests charted.Witness waived by AOGCC Bob Noble on 2-23-15.Pull test plug and set Wear Bushing as per Vetco Grey Rep onsite.Wear Bushing ID 12.31",OD 13.438",HT 53.31". Perform 13 3/8"Csg test to 2,500 PSI for 30 Min all charted.Witnessed by Co Rep onsite. Bring and stage BHA#3 components to rig floor.P/U M/U 12.25"T507X Hughes Bit,Xceed,TeleScope 825,12.125"NM ILS,ARC 825,X/O,Hi Tool,Tercel GDR Stab,8"NM FC,Saver/Float Sub,5" HWDP and Jar as per Schlumberger DD and MWD to 348'MD.RIH BHA#3 WI 5"D.P.F/348'to 1,749'MD.Fill D.P.and perform shallow hole test as per Schlumberger MWD @ 750 GPM,1.000 PSI. RIH W/5"D.P.F/1,749'to 2,682'MD.Wash down F/2,682'to 2,721'MD.Tag FC.Drill out Shoe Track to 2,820'MD.750 GPM,1,300 PSI,TRO 5-10K, WOB 2-10K,60-80 RPM,HST 150K,SLK 125K, ROT 130K.Stop @ 2,820'MD due to mud rheology and condition mud.Drill out witnessed by Co Rep,Hughes and ENI HSE Rep onsite.Finish cleaning out FI 2,820'to 2,836'MD @ 750 GPM,1,300 PSI,80 RPM,TRQ 2-4K,WOB 2-4K.BROOH to 2,772'MD.PJSM W/all essential personnel.Displace Spud Mud W/9.3 ppg LSND as per MI Swam plan.Pump 45 bbl Hi Vis spacer and chase W/395 bbl 9.3 ppg LSND @ 7 bpm,200 PSI,40 RPM.Reciprocate F/2,772'to 2,679'MD.Monitor well,static.Clean surface Equip.RAJ and perform FIT,Press.up to 470 PSI @ 1/2 bpm.Pumped 1.5 bbl and.5 bbl returned.EMW 13.00 ppg.Blow down,R/D test Equip.Service TDS-8,Block and Hook.Drill 12.25'Intermediate FI 2,836'to 3.518'MD(2.598'TVD)900 GPM,1,580 PSI,RPM 140-190,TON 8K,TOE 5K,WON 2-13K,HST 140K,SLK 120K,ROT 130K.ADT 4.65,Bit Hrs 4.65,Jar Hrs 22.15.Max Gas 113 units.ECD 9.71 peg W/9.3 ppg MW. Operation at 07.00 Drill 12.25"Intermediate @ 3,987.0'MD. 24h Forecast Drill 12.25"Intermediate to TD @-13.641'MD.SIMOPS Load and process 9 5/8"Csg in Pipe Shed. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL C 12 P PJSM Cont.BOPE with Blind Rams to 250 PSI low and 3,500 PSI high.Test both Manual Chokes and Super Choke to 1,500 PSI.All tests charted.Witness waived by AOGCC Bob Noble on 2-23-15. 00:30 02:00 1.50 2.00 DRILL C 20 P PJSA Pull test plug and set Wear Bushing as per Vetco Grey Rep onsite.Wear Bushing ID 12.31",OD 13.438",HT 53.31". Blow down surface testing Equip.and tools. 02:00 03:00 1.00 3.00 DRILL G 12 P PJSM Perform 13 3/8"Csg test to 2,500 PSI for 30 Min all charted.Witnessed by Co Rep onsite. 03:00 03:30 0.50 3.50 DRILL E 20 P PJSM Bring and stage BHA#3 components to rig floor. 03:30 07:00 3.50 7.00 DRILL E 20 P PJSM P/U M/U 12.25"T507X Hughes Bit,Xceed,TeleScope 825,12.125"NM ILS,ARC 825,X/O,Hi Tool,Tercel GDR Slab,8"NM FC,Saver/Float Sub,5"HWDP and Jar as per Schlumberger DD and MWD to 348'MD. 07:00 07:30 0.50 7.50 DRILL E 4 P PJSA RIH BHA#3 W/5"D.P.F/348'to 1,749'MD. 07:30 08:30 1.00 8.50 DRILL E 12 P PJSA Fitl D.P.and perform shallow hole test as per Schlumberger MWD @ 750 GPM,1,000 PSI. 08:30 09:00 0.50 9.00 DRILL E 4 P PJSA RIH W/5"D.P.F/1,749'to 2,682'MD.HST 148K,SLK 122K. SPR @ 2,816'MD(2,422'ND W/9.3 ppg MW MP#2 30-110,40-130 MP#3 30-110,40-130 09:00 12:00 3.00 12.00 DRILL E 3 P PJSM Wash down F/2,682'to 2,721'MD.Tag FC.Drill out Shoe Track to 2,820'MD.750 GPM,1,300 PSI.TRQ 5-10K, WOB 2-10K,60-80 RPM,HST 150K,SLK 125K,ROT 130K.Stop @ 2,820'MD due to mud rheology and condition mud. Drill out witnessed by Co Rep,Hughes and ENI HSE Rep onsite. 12:00 12:30 0.50 12.50 DRILL E 3 P PJSM Finish cleaning out F/2,820'to 2,836'MD @ 750 GPM,1,300 PSI,80 RPM,TRQ 2-4K,WOB 2-4K.BROOH to 2,772'MD. 12:30 14:30 2.00 14.50 DRILL E 9 P PJSM W/all essential personnel.Displace Spud Mud W/9.3 ppg LSND as per MI Swam plan.Pump 45 bbl Hi Vis spacer and chase W/395 bbl 9.3 ppg LSND @ 7 bpm.200 PSI,40 RPM.Reciprocate F/2,772'to 2.679'MD.Monitor well,static. Clean surface Equip. 14:30 16:00 1.50 16.00 DRILL E 11 P PJSA R/U and perform FIT,Press.up to 470 PSI @ 1/2 bpm.Pumped 1.5 bbl and.5 bbl returned.EMW 13.00 ppg.Blow down,R/D test Equip. 16:00 16:30 0.50 16.50 DRILL E 25 P PJSA Service TDS-8,Block and Hook. SPR @ 2,836'MD(2,432'ND)W/9.3 ppg ME MP#2 30-140,40.160 MP#3 30-140,40-160 16:30 18:00 1.50 18.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/2,836'to 2,934'MD(2,477'ND)850 GPM,1,330 PSI,RPM 80-90,TON 7K,TOE 5K, WOB 2-10K,HST 145K,SLK 122K,ROT 135K.ADT 0.95,Bit Hrs 0.95,Jar Hrs 18.45.Max Gas 52 units.ECD 9.7 ppg W/ 9.3 pug MW. 18:00 00:00 6.00 24.00 DRILL E 3P PJSA Drill 12.25"Intermediate F/2,934'to 3,518'MD(2,598'ND)900 GPM,1,580 PSI,RPM 140-190,TON 8K,TQF 5K, WOB 2-13K,HST 140K,SLK 120K,ROT 130K.ADT 3.7,Bit Hrs 4.65,Jar Hrs 22.15.Max Gas 113 units.ECD 9.71 ppg W/ 9.3 ppg MW. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener "ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Sups. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondriiling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB( TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 864.41 741.64 LSND 1114.4 33.0 1559.9 115.7 Eni E&P Division Well Name:Si. OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ • 2^n Date:2126/2015 - Report#: 9 APIIUWI:50-629-23534-00-00 II II U page 1 of 1 Wellbore name: SI34-W6 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331.05 7271.92 205.69 35.4 6.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) P09 Temperature(°C) Weather Wind 1.870.25 829.34 797.97 15.38, 51.9 124.0 -1.1 Snow WC 15° SSW @ 30 MPH Daily summary operation 24h Summary Drill 12.25"Intermediate F/3,518'to 6,136'MD(2,721'ND)900 GPM,2,040 PSI,RPM 140-190,TON 9K,TQF 5K.WOB 2-12K,HST 152K,SLK 102K,ROT 130K.ADT 15.38,Bit Hrs 20.03.Jar Hrs 37.53.Max Gas 150 units.ECD 10.18 ppg W/9.3 ppg MW.Monitor well,static. Operation at 07.00 D411 12.25"Intermediate @ 6,698'MD. 24h Forecast D81112.25"Intermediate to TD @-13,641'MD.SIMOPS Load and process 9 5/8"Csg in Pipe Shed. Lithology Shows MAASP(kgfiern') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 12.25"Intermediate Fl 3,518'to 4,266'MD(2,621'ND)900 GPM,1,750 PSI,RPM 140-190,TQN7-8K,TOF 4- 5K,WOB 6-10K,HST 140K,SLK 119K,ROT 131K.ADT 3.7,Bit Hrs 8.35,Jar Hrs 25.85.Max Gas 150 units.ECD 9.99 ppg W/9.25 ppg MW.Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 12.25"Intermediate Fl 4,266'to 4,826'MD(2,651'ND)900 GPM,1,780 PSI,RPM 140-190,TON 8-10K,TOF 4 -6K,WOB 8-10K,HST 155K,SLK 110K,ROT 132K.ADT 3.68,Blt Hrs 12.03,Jar Hrs 29.53.Max Gas 82 units.ECD 9.98 ppg W/9.3 ppg MW.Monitor well,static. SPR @ 4,733'MD(2,647'ND)W/9.3 ppg MW MP#1 30-190,40-210 MP#2 30-190,40-210 . MP#3 30-190,40-210 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/4,826'to 5,479'MD(2,688'ND)900 GPM,1,850 PSI,RPM 140-190,TON 8-9K,TOF 5K,WOB 2-10K,HST 152K,SLK 100K,ROT 130K.ADT 4.74,Bit Hrs 16.77,Jar Hrs 34.27.Max Gas 123 units.ECD 9.96 ppg WI 9.3 ppg MW.Monitor well,static. 10 00 00.00 6.00 24.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/5,479'to 6,136'MD(2,721'ND)900 GPM.2,040 PSI,RPM 140-190.TON 9K,TQF 5K, WOB 2-12K,HST 152K,SLK 102K,ROT 130K.ADT 3.26,BO Hrs 20.03,Jar Hrs 37.53.Max Gas 40 units.ECD 10.18 ppg W/9.3 ppg MW.Monitor well,static. SPR @ 5.754'MD(2,701'ND)W/9.3 ppg MW MP#1 30-200.40-240 MP#2 30-200.40-240 MP#3 30.200,40-240 Daily Contacts Position Contact Name Company Title E-mall Office Mobile Em representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Mails Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) IVO(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 864.41 741.64 LSND 1114.4 33.0 1559.9 110/ Eni E&P Division WeIlName:SI JR PYliC ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ • E Date:2/27/2015 - Report#: 10 API/UWI:50-629-23534-00-00 l�II �I II page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..'Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 7.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,646.58 868.25 776.33 15.26 50.9 118.0 -14.4 Overcast WC-15 E o_,21 MPH Daily summary operation 24h Summary Drill 12.25"Intermediate F/6,136'to 8,683'MD(2,848'ND)900 GPM,2,320 PSI,RPM 140-190,TON 11-12K,TQF 7-8K,WOB 6-10K,HST 158K,SLK 106K,ROT 132K.ADT 15.26,Bit Hrs 35.29,Jar He 52.79.Max Gas 50 units.ECD 10.25 ppg W/9.3 ppg MW.Encountered dynamic loss of 35 bbl F/6,607'to 6,973'MD.Monitor well,static. Operation at 07.00 Drill 12.25"Intermediate @ 9,020'MD 24h Forecast Drill 12.25"Intermediate Fl 8,683'to TO @—13,500'MD.SIMOPS Load and process 9 5/8"Csg in Pipe Shed. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00" 6.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/6,136'to 6,973'MD(2,741'ND)900 GPM,2,000 PSI,RPM 140-190,TON 9-11K,TOP 5 -7K,WOB 4-10K,HST 160K,SLK 105K,ROT 134K.ADT 4.08,Bit His 24.11,Jar He 41.61.Max Gas 50 units.ECD 10.19 ppg W/9.35 ppg MW.Monitor well,falling.Lost 35 bbl dynamic loss F/6,607'to 6,973'MD. 06:00 12:00 6.00" 12.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/6,973'to 7,534'MD(2,790'ND)900 GPM,2,200 PSI,RPM 140-190,TON 9-11K,TQF 6 -7K,WOB 8-12K,HST 155K,SLK 110K,ROT 135K.ADT 3.41,Bit Hrs 27.52,Jar Hrs 45.02.Max Gas 14 units.ECD 10.43 ppg W/9.3 ppg MW.Monitor well,static.No losses. SPR©6,783'MD(2,763'ND)W/9.3 ppg MW MP#1 30-230,40-250 MP#2 30-230,40-250 MP#3 30-230,40-250 12:00 18:00 6.00 18.00 DRILL E 3 "P PJSA Drill 12.25"Intermediate F/7,534'to 8,133'MD(2,819'ND)900 GPM,2,320 PSI,RPM 140-190,TON 10K.TOF 6K,WOB 8-10K,HST 158K,SLK 108K,ROT 131K.ADT 3.97,Bit Hrs 31.49,Jar Hrs 48.99.Max Gas 9 units.ECD 10.38 ppg W/9.25 ppg MW.Monitor well,static.No losses. SPR©7,720'MD(2,799'ND)W/9.3 ppg MW MP#1 30-260,40.300 MP#2 30-260,40-300 MP#3 30-260,40-300 18:00 00:00 6.00 24.00 DRILL t 3 P PJSA Drill 12.25"Intermediate F/8,133'to 8,683'MD(2,848'ND)900 GPM,2,320 PSI,RPM 140-190,TON 11-12K,TQF 7-8K,WOB 6-10K,HST 158K,SLK 106K,ROT 132K.ADT 3.8,Bit Hrs 35.29.Jar Hrs 52.79.Max Gas 8 units.ECD 10.25 ppg W/9.3 ppg MW.Monitor well,static.No losses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Cleric akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 864.41 741.64 LSND 1114.4 33.0 1559.9 115.7. fli* Eni E&P Division Well Name:Si. OR ENI Petroleum Co.Inc. Daily Report well Code:29543 Field Name:NIKAITCHUQ • API/U WI:50-629-23534-00-00 2^II n Date:212812015 - Report#: 11 '� I� page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 8.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,01386 087 04 367.28 13.70 26.8 118.0 -26.1 Blowing Snow WC- SW @ 32 MPH Gust 48° To 38 MPH Daily summary operation 24h Summary Doll 12.25"Intermediate F/9,587'to 9,888'MD(2,910'TVD)900 GPM,2,410 PSI,RPM 140-190,TQN 12-13K,TQF 7-8K,WOB 4-10K,HST 161K,SLK 105K,ROT 135K.ADT 13.7,Bit Hrs 48.99,Jar Hrs 66.49.Max Gas 9 units.ECO 10.18 ppg W/9.3 ppg MW.Monitor well,static.No losses.Due to Phase 3 weather condition,it was decided to Rack back two stands 5"D.P.F/9,888'to 9,776'MD. Circ.and reciprocate due to Phase 3 condition F/9,776'to 9,683'MD.400 GPM,700 PSI,60 RPM,TRQ 7K.Increase pump rate to 650 GPM to check shock and slick slip,none seen.Encountering 4-6 bph dynamic losses.Lost a total of 20 bbl. Operation at 07.00 Wait on Phase 3 weather condition. 24h Forecast Cont.to wait on Phase 3 weather condition.Cont.drilling 12.25"Intermediate. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11144 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/8,683'to 9,119'MD(2,872'TVD)900 GPM,2,360 PSI,RPM 140-190,TQN 11-12K,TQF 6-8K.WOB 4-12K,HST 158K,SLK 107K,ROT 136K.ADT 5.12,Bit Hrs 40.41,Jar His 57.91.Max Gas 8 units.ECD 10.24 ppg W/9.3 ppg MW.Monitor well,static.No losses. SPR @ 8,746'MD(2,851'ND)W/9.35 ppg MW MP#1 30-280,40-320 MP#2 30-280,40-320 MP#3 30-280,40-320 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/9,119'to 9,587'MD(2,897'ND)900 GPM,2,440 PSI,RPM 140-190,TON 12-13K.TOE 6-8K,WOB 8-12K,HST 159K,SLK 107K,ROT 138K.ADT 4.03,Bit Hrs 44.44,Jar His 61.94.Max Gas 9 units.ECD 10.34 ppg W/9.3 ppg MW.Monitor well,static.No losses. 12:00 17:30 5.50 17.50 DRILL E 3 P PJSA Drill 12.25"Intermediate F/9,587'to 9,888'MD(2,910'ND)900 GPM,2.410 PSI,RPM 140-190,TON 12-13K,TQF 7-8K,WOB 4-10K,HST 161K,SLK 105K,ROT 135K.ADT 4.55,Bit Hrs 48.99,Jar Hrs 66.49.Max Gas 9 units.ECD 10.18 ppg W/9.3 ppg MW.Monitor well,static.No losses. 17:30 18:30 1.00 18.50 DRILL E 4 XWO1 PJSA Due to Phase 3 weather condition,it was decided to Rack back two stands 5"D.P.F/9,888'to 9,776'MD.600 GPM, 1,300 PSI,80 RPM,TRQ 8-10K,ROT 131K. 18:30 00:00 5.50 24.00 DRILL E 22 XW01 PJSACirc.and reciprocate due to Phase 3 condition Fl 9,776'to 9,683'MD.400 GPM,700 PSI,60 RPM,TRQ 7K. Increase pump rate to 650 GPM to check shock and slick slip,none seen.Encountering 4-6 bph dynamic losses.Lost a total of 20 bbl. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gil) P LeakOff(kgf/cm') 864.41 741.64 LSND 1114.4 33.0 15599 115 7 ilios Eni E&P Division Well Name:SL OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ e n o•• Date:31112015 - Report#: 12 APIIUWI:50-629-23534-00-00 A page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 354 990 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 3,054.40 888.40 40.54 5.78 7.0 117.0 -26.7 Scattered Clouds WC SE @ 12 MPH -37° Daily summary operation 24h Summary Circ.and reciprocate due to Phase 3 condition F/9,776'to 9,683'MD.400 GPM,710 PSI,60 RPM,TRQ 9K.Increase pump rate to 650 GPM to check shock and slick slip,none seen.Encountering 4-5 bph dynamic losses.Lost a total of 45 bbl.Wash down F/9.683'to 9.888'MD 400 GPM,700 PSI,60 RPM,TRQ 9K.Drill 12.25"Intermediate F/9,888'to 10,021'MD(2.914'TVD)900 GPM,2,420 PSI, RPM 140-190,TON 12K,TOF 11-12K,WOB 4-12K,HST 161K,SLK 100K,ROT 135K.ADT 5.78,Bit Hrs 54.77,Jar Hrs 72.27.Max Gas 25 units.ECD 10.20 ppg W/9.3 ppg MW.Monitor well,static.No losses. Operation at 07.00 Drill 12.25"Intermediate @ 10,038'MD. 24h Forecast Drill 12.25"Intermediate F/10,021'to TD @-13,500'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 22 XWO1 PJSA Circ.and reciprocate due to Phase 3 condition F/9,776'to 9,683'MD.400 GPM,710 PSI,60 RPM,TRQ 9K. Increase pump rate to 650 GPM to check shock and slick sip,none seen.Encountering 4-5 bph dynamic losses.Lost a total of 45 bbl. SPR @ 9,776'MD(2,909 ND)W/9.3 ppg MW MP#1 30-300,40-340 MP#2 30-300.40-340 MP#3 30-300,40-340 12:00 14:30 2.50 14.50 DRILL E 22 XW01 PJSA Circ.and reciprocate due to Phase 3 condition F/9,776'to 9,683'MD.400 GPM,710 PSI,60 RPM,TRQ 9K.No losses to formation. 14:30 1500 0.50 15.00 DRILL E 6 P PJSA Wash down F/9.683'to 9,888'MD 400 GPM,700 PSI,60 RPM,TRO 9K. 15:00 18:00 3.00 18.00 DRILL E 3 P PJSA Drill 12.25"Intermediate Fl 9,888'to 9,895'MD(2,909'ND)900 GPM,2,460 PSI,RPM 140-190,TON 12K,TQF 7- 10K,WOB 4-12K,HST 162K,SLK 100K,ROT 135K.ADT 2.5,Bit Hrs 51.49.Jar Hrs 68.99.Max Gas 25 units.ECD 10.28 ppg W/9.3 ppg MW.Monitor well,static.No losses. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/9,895'to 10,021'MD(2,914'ND)900 GPM,2,420 PSI,RPM 140-190,TQN 12K,TQF 11-12K,WOB 4-12K,HST 161K,SLK 100K,ROT 135K.ADT 3.28,Bit Hrs 54.77,Jar Hrs 72.27.Max Gas 8 units.ECD 10.20 ppg WI 9.3 ppg MW.Monitor well,static.No losses. SPR @ 10,020'MD(2,914'ND)W/9.3 ppg MW MP#1 30-280,40-310 MP#2 30-280,40-310 MP#3 30-280,40-310 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bemie Leas ENI Rig Clerk akrigclerksdoyonl 5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13318 12.415 L-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 864.41 741.64 LSND 1114.4 33.0 1559.9 115.7 Eni E&P Division Well Name:S. JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • 2 II^rlfifi* Date:312/2015 - Report#: 13 API/UWI:50-629-23534-00-00 I� I� page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type D000N RIG 19 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 10.90 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 3,421.08 957.01 366.67 17.13 21A 108.0 -15.6 Overcast WC-20° E @ 32 MPH Daily summary operation 24h Summary Drill 12.25"Intermediate F/10,021'to 11,224'MD(3,139'TVD)900 GPM,2,600 PSI,RPM 140-190,TON 12-13K,TQF 8-9K,WOB 4-12K,HST 175K,SLK 100,ROT 141K.ADT 17.73,Bit Hrs 72.50,Jar Hrs 90.0.Max Gas 22 units.ECD 10.46 ppg W/9.4 ppg MW.Started weighting up to 9.4 ppg @ 10,550'MD due to NSand. Monitor well,slightly falling.Encountered about 9 bph dynamic losses around 10,980'MD.Total losses 31 bbl to formation. Operation at 07.00 Drill 12.25"Intermediate @ 11,453'MD. 24h Forecast Drill 12.25"Intermediate F/11,224'to TD @-13,500'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 11264 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 0600 6.00 6.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/10,021'to 10,053'MD(2,915'TVD)900 GPM,2,400 PSI,RPM 140-190,TON 12-14K, TQF 8-11K,WOB 8-12K,HST 167K,SLK 98K,ROT 138K.ADT 5.10,Bit Hrs 59.87,Jar Hrs 77.37.Max Gas 8 units.ECD 10.12 ppg W/9.25 ppg MW.Monitor well,static.No losses. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/10,053'to 10,427'MD(2,962'TVD)900 GPM,2,460 PSI,RPM 140-190,TON 11-13K, TQF 7-9K,WOB 2-11K,HST 170K,SLK N/A,ROT 139K.ADT 3.93,Bit Hrs 63.80,Jar Hrs 81.30.Max Gas 6 units.ECD 10.28 ppg W/9.3 ppg MW.Monitor well,static.No losses. SPR @ 10,331'MD(2,946'ND)WI 9.3 ppg MW MP#1 30-290,40-310 MP#2 30-290,40-310 MP#3 30-290,40-310 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/10,427'to 10,850'MD(3,042'ND)900 GPM,2,550 PSI,RPM 140-190,TON 11-13K, TQF 7-9K,WOB 4-12K,HST 173K,SLK 105,ROT 139K.ADT 4.36,Bit Hrs 68.16,Jar Hrs 85.66.Max Gas 9 units.ECD 10.33 ppg W/9.4 ppg MW.Monitor well,static.No losses.Started weighting up to 9.4 ppg @ 10,550'MD due to NSand. 18.00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 12.25"Intermediate F/10,850'to 11,224'MD(3,139'ND)900 GPM,2,600 PSI,RPM 140-190,TON 12-13K, , TQF 8-9K,WOB 4-12K,HST 175K,SLK 100,ROT 141K.ADT 4.34,Bit Hrs 72.50,Jar Hrs 90.0.Max Gas 22 units.ECD 10.46 ppg W/9.4 ppg MW.Monitor well,slightly falling.Encountered about 9 bph dynamic losses around 10,980'MD.Total losses 31 bbl to formation. SPR @ 11,171'MD(3,128'TVD)W/9.4 ppg MW MP#1 30-330,40.360 MP#2 30-330.40-360 MP#3 30-330,40-360 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.corn 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Mails Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 ' Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 - -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 864.41 741.64 LSND 1114.4 33.0 1559.9 115.7 Eni E&P DivisionWell Name:SI OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO fill* eAPIIUWI:50-629-23534-00-00 e^(I'I n Date:3/3/2015 - Report#: 14 IIpage 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100 00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-886 DRILLING 2/20/2015 7,331.05 ii 7271.92 205.69 35.4 11.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.877.67 1.049.75 456.59 1612 28.3 109.0 -17.2 Blowing Snow WC- SW @ 25 MPH 19° Gusts To 33 MPH Daily summary operation 24h Summary Drill 12.25"Intermediate hole f/11,224'to12,722'MD. Operation at 07.00 Drilling ahead 12.25"intermediate hole @ 12,877 MD 24h Forecast Doll 12.25"Intermediate f/12,722'-Est TD @ 13,500'.Perform cleanup cycle and BROOH. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11324 Time Log Start ' End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00:00 06:00 6.00 6.00 DRILL E 3 •P PJSA DIV.9 11,224'-11,640'MD(3246'Nd)(§)900 gpm,2610 psi,140-190 rpm,10-12k wob,12-13k tqn,7k tqf,178k puw,108k sow,146k rotw,10.46 ECD,Max Gas 33,4.13 ADT.76.63 Bit,94.13 Jars. 06:00 '12:00 6.00 12.00 DRILL E 3 .P PJSA Dr4g.f/11,640'-12,013'MD(3329'Nd)@ 900 gpm,2650 psi,140-190 rpm,8-10k Nob,12-13k tqn,8-10k tqf. 180k puw.110k sow.148k rotw.10.47 ECD,MAX GAS 53,3.85 ADT,80.48 Bit,97.98 Jars.49 bbls Touriy fluid losses. SPR @ 11,971'MD(3319'Nd)w/9.4 MW;#1/#2/#3 @ 30-350,@ 40-390. 12:00 .18:00 6.00 18.00 DRILL E 3 .P -PJSA Drig f/12,013'-12,472'MD(3415'tvd)@ 900 gpm,2730 psi,140-190 rpm,10k wob,13-14k tqn,8-9k tqf,183k puw,110k sow,148k rotw,10.56 ECD,MAX GAS 537,3.78 ADT,84.26 Bit,101.76 Jars. 18:00 00:00 6.00 •24.00 DRILL E 3 -P °PJSA Drig.f/12,472'-12,722'MD(3445'Nd)@ 900 gpm,2750 psi,140-190 rpm,10-11k wob,13-14k tqn,9k tqf,185k •puw,110k sow,148k rotw,10.64 ECD,MAX GAS 1004,4.36 ADT,88.62 Bit,106.12.SPR @ 12,666'MD(3441'Nd)w/ 9.45 MW;#1/#2/#3 @ 30-400,@ 40-460. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDnllirg@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.corn 907.685.0715 907-320-0058 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrgclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jack Kvasnikotf ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.corn 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907.685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 -012 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 864.41 741.64 LSND 11144 33.0 1559.8 115.7 Eni E&P Division . Well Name:Si, OR ENI Petroleum Inc. Daily Report` Well Code:29543 Field Name:NIKAITCHUO 2 II Co.^rif* Date:31412015 - Report#: 15 API/UWI:50-629-23534-00-00 I� �I Ipage 1 of 1 Wellbore name: SI34-W6 • Well Header PermitlConcession N' Operator ENI Share(%) Well Configuration type 215-016 EM PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16-39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information • Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI34-006 DRILLING 2!20!2015 7,331.05 7,271.92 205.69 35.4 12.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(`C) Weather Wind 4.058.72 1,055 90 181.05 14.18 12.8 108.0 -22.6 Overcast WC-26' N @ 10 MPH Daily summary operation 24h Summary Drill 12.25"Intermediate hole 6 12,722'-to TD @ 13,316'MD.Perform cleanup cycle and BROOH to 12,477' Operation at 07.00 BROOH @ 11,373'MD 24h Forecast BROOH f/12,477'as per K&M schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11264 Time Log Start ' End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 .06:00 6.00 6.00 DRILL E 3 P PJSA Dig.fl 12,722'-13,039'MD(3462'tvd)@ 900 gpm,2800 psi,140-190 rpm,8-12k wob,14-15k tqn,9-10k tqf. 185k puw,108k sow,146k rotw,10.74 ECD,Max Gas 55,5.16 ADT,93.78 Bit,111.28 Jars. 06:00 '12:00 6.00 12.00 1 DRILL E 3 P PJSA Ddg.f/13,039'-13,252'MD(3461'tvd)@ 900 gpm,2830 psi,140-190 rpm,8-12k wob,180k sow,143k rotw, 10.76 ECD,Max Gas 2056,3.93 ADT,97.71 Bit 115.21 Jars.SPR @ 13,252'MD(3461'tvd)w/9.5 MW:#1l#3 @ 30- 360,@ 40-400. 12:00 17:00 5.00 17.00'DRILL E 3 P PJSA Ong.f/13,252'- 13,316'MD(3462'tvd)@ 900 gpm,2660 psi,140-190 rpm,6-15k wob,15k tqn,10-11k tqf,185k puw,100k sow,142k rotw,10.45 ECD,Max Gas 2070,5.09 ADT,102.80 Bit,120.30 Jars. 17:00 17:30 0.50 17.50 DRILL E 7 P PJSA SLB down link and survey.Monitor well.SPR @ 13,316'MD(3462'tvd)wl 9.5 MW;#1/#2/#3 @ 30-300,@ 40- 340. 17:30 20:30 3.00 20.50 DRILL E 4 P PJSA CBU X 2 while BROOH @ 900 gpm,2580 psi,@ 120 rpm,185k puw,102k sow,149k rotw f/13,316'-13,135'. 20:30 00:00 3.50 24.00 DRILL E 4 P PJSA BROOH f/13,135'-12,477'@ 900 gpm,2580 psi,120 rpm,200k puw,102k sow,149k rotw,8k tq. Daily Contacts Position Contact Name Company Title E-mail I Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 5-907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 5-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/c m') 064 41 741.64 LSND 1114.4 33.0 1559.9 115.7 Eni E&P Division Well Name:SI JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO 2 nI^liff* Date:3/5/2015 - Report#: 16 API/UWI:50-629-23534-00-00 II II Ipage 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession W Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-7/6 DRILLING 2/20/2015 7.331 05 7,271 92 205.69 35.4 13.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,058.72 1,055.98 0.00 110.0 -19.6 Overcast WC-20' NNE @ 10 MPH Daily summary operation 24h Summary BROOH f/12,477'-5202'. Operation at 07.00 BROOH @ 4,363 24h Forecast Cont.BROOH to 1500'.Circ.until hole is clean.POOH LD BHA Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00- 6.00 DRILL E 4 P PJSA BROOH f/12,477'-10,427'@ 900 gpm,2450 psi,120 rpm,10-11k iq,170k puw,100k sow,140k rotw. 06.00 12:00 6.00 12.00 DRILL E 4 P PJSA BROOH f/10,427'-8656'@ 900 gpm,2200 psi,120 rpm,8-9619,160k puw,108k sow.136k rotw.46 bbls Tourly fluid losses. 12.00 18:00 ' 6.00 18.00 DRILL E 4 P PJSA BROOH 0 8656'-7041'@ 900 gpm,2040 psi,120 rpm,5-6k 19.170k puw,103k sow,139k rotw. -18.00 00:00 6.00 24.00 DRILL E 4 P PJSA BROOH f/7041'-5202'@ 900 gpm,1850 psi,120 rpm,8-10k tq,148k puw,110k sow,133k rotw.8 bbls Tourly fluid losses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 En,representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRgClerksDoyonl5@enipetmleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685.0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher dg15@doyondrilling.com 907-685-0716 Last Casing seat - Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 -0.12 854.35 2/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 864.41 741.64 LSND 1114.4 33.0 1559.9 115.7 Eni E&P DivisionWell Name:SL OR ENI Petroleum Co.Inc. Daily Report Well Code,29543 IP* Field Name:NIKAITCHUO 2 El^ Date:31612015 - Report#: 17 APIIUWI:50-629-23534-00-00 '� I'Ipage 1 of 1 Wellbore name: 5134-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331 05 7,271.92 205.69 35.4 14.90 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4.058.72 1.055.90 0.00 106.0 -17.8 Cloudy WC-22- NNE @ 22 MPH Daily summary operation 24h Summary BROOH f/5202'-1468'.POOH and L/D BHA#3.R/U to run 9 5/8"casing. Operation at 07.00 RIH w/9 5/8"casing @ 150' 24h Forecast Complete R/U to run casing.Hold Safety meeting and MN shoe track and test floats.P/U and RIH w/9 5/8"casing. Lithology Shows MAASP(kgticm") Mud Weight(gIL) 1126 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 4 P PJSA BROOH f/5202'-3504'@ 900 gpm,1620 psi.120 rpm,4-5k tq,165k puw,100k sow.129k rotw, work through tight area @ 3360'. 06:00 12:00 6.00 12.00 DRILL E 4 P PJSA BROOH f/3502'-2488'@ 900 gpm,1550 psi.80-120 rpm,3-4k tq,140k puw,138k sow.134k rotw.50 bbls Toudy fluid losses. 12:00 14:30 2.50 14.50 DRILL E 4 P PJSA BROOH f/2488'-1468'@ 900 gpm,1360 psi,120 rpm,2-3k tq,120k puw/sow,122k rolw. 14:30 15:00 0.50 15.00 DRILL E 20 P PJSA Blow down top-drive and mud lines.Monitor well. 15:00 16:00 1.00 16.00 DRILL E 4 P PJSA POOH f/1468'-348',100k puw/sow. 16:00 18:30 2.50 18.50 DRILL E 4 P PJSA LID BHA#3. 18:30 1900 0.50 19.00 DRILL A 20 P PJSA Clear and clean rig floor. 1900 21:00 2.00 21.00 DRILL C 20 P PJSA Change out upper rams to 9 5/8". 21:00 21:30 0.50 21.50 DRILL C 20 P PJSA Pull wear bushing and install test plug as per Vetco. 21:30 22:30 1.00 22.50 DRILL C 12 P PJSA R/U testing equip.and test 95/8"rams to 2501 3000 psi for 5 charted min.Pull test plug and install casing running wear bushing. 22:30 23:00 0.50 23.00 DRILL C 20 P PJSA Blow down from test and clear and clean rig floor. 23:00 00:00 1.00 24.00 DRILL G 20 P PJSA Load floor with casing running equipment and R/U Tesco,3 BBLS tour loss. Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI 'Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 '715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Em representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -1.22 4955.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Suri Applied(kgflcm") Eq.Mud Weight(gIL) P LeakOff(kgflcm") 864.41 741.64 LSND 11144 33.0 1559.9 115.7 Eni E&P Division (Well Name:SI CR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • em II II IIrif* Date:31712015 - Report#: 18 API/UW1:so-629-2353a-50-629-23534-00-00oo page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 15.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,058.72 1,055.98 0.00 105.0 -20.8 Light Snow WC-22° NNW @ 10 MPH Daily summary operation 24h Summary R/U to run casing.M/U&RIH V wI 9 5/8"408 L80 Hyd 563 casing 1012.747'.Begin rotating©3852'. Operation at 07.00 Filling 9 5/8"csg.w/LSND mud. 24h Forecast Complete running 9 5/8"csg to 13,304'.Fill casing as per MI schedule.Break circulation and bring up rate to 7 bpm.Hold PJSM for cementing and pump cement as per program. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 11384 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL G 20 P PJSA R/U Tesco CRT and associated equipment and function test.R/U emergency casing fill/bleed off lines.Hold PJSM for running casing. 02:00 06:00 4.00 6.00 DRILL G 4 P PJSA P/U&MN 95/8"shoe track,fill w/LSND mud and check floats. M/U and RIH to 2318'w/9 5/8"404f L80 Hyd 563 casing.82k sow. 06:00 07:30 1.50 7.50 DRILL G 4 P PJSA M/U casing f/2318'-3852',72k sow. 07:30 12:00 4.50 12.00 DRILL G 4 P PJSA Begin rotating 95/8"csg in hole f/3852'-6412',40 rpm,7-8k 1q,83k rotw.75k rotslk.11 bbls-lowly fluid losses. 12:00 18:00 6.00 18.00 DRILL G 4 P PJSA Running 9 5/8"csg f/6412'-9850',40 rpm,8-9k tq,82k rotw,70k rotslk. 18:00 00:00 6.00 24.00 DRILL G 4 P PJSA Running 9 5/8"csg f/9850'-12.747',40 rpm,1l k tq,83k rotw,70k rotslk. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv (SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetmleum.com 907-685-0722 Eni representative Vance Dale ENI Mats Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpedltor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 864.41 741.64 LSND 1114.4 33.0 1559.9 115.7 Eni E&P Division Name:SI JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • 2 n nffil* Date:3/8/2015 - Report#: 19 APIIUWI:50-629-23534-00-00 I� II II page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share CA) Well Configuration type 215-019 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m( Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 16.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(CC) Weather Wind 4,058.72 1,055.98 0.00 105.0 -8.7 Overcast WC-39° WSW @ 13 MPH Daily summary operation 24h Summary MN and RIH wl 9 5l8"408 L80 Hyd 563 casing to 13,304'.R/D Tesco and R/U bails,elevators and cmt head.Fill casing w/1009 bbls of LSND mud.Circulate and condition mud for cement job. Operation at 07.00 Displacing Cement 24h Forecast Cont.circulating until yield point reaches 20.Hold PJSM,pump 10 bbls of water and pressure test cmt.lines to 1000/3500 psi pump spacer,and perform cement job.Displace cmt,bump plug and check floats.Perform infectivity test.N/D well head,pick up and set emergency slips.Vetco cut casing. Lithology Shows MAASP(kgticm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00.30 (1.50 0.51) DRILL G 4 P PJSA RIH w/9 5/8"40#L80 Hyd 563 casing f/12,747'-13,304'TO @ 40 rpm,11-12k iq,83k rotw,68k rotslk. 00:30 01.30 1.00 1.50 DRILL G 20 P PJSA R/D Tesco CRT and associated equipment 01:30 03:00 1.50 3.00 DRILL G 20 P PJSA Install casing bails,and single jt.elevators.RN Cement head and all associated lines to fill and vent casing for Fluid filling. 0300 08:00 5.00 8.00 DRILL G 9 P PJSA Fill casing wl LSND mud as per schedule w/1009 bbls @ 4 bpm,letting mud/air swap f/10 min.between stages. 08:00 08:30 0.50 8.50 DRILL G 20 P PJSA Blow down choke and mud lines.R/D casing fill and vent line.R/U cement hose. 08:30 12:00 3.50 1200 DRILL H 7 P PJSA Circulate and condition mud w/ICP.5 bpm,260 psi,staging up to 2 bpm,350 psi. 12:00 18:00 6.00 18.00 DRILL H 7 P PJSA Circulate and condition mud,ICP 2 bpm,350 psi to 5 bpm,390 psi.Observed 6 bph losses @ 5 bpm.Circ @ 4.5 bpm,350 psi with minimal losses. 18:00 00:00 6.00 24.00 DRILL H 7 P PJSA Continue Circulating @ 4.5 bpm,350 psi.After 2 BU's raise rate to 5 bpm,360 psi with 8 bph losses.Slowed rate to 4.5 bpm,310 psi,24 yield.37 bbls Tourty fluid losses. Daily Contacts Position Contact Name Company Title ' E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig 15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5)8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 864.41 741.64 LSND 1114.4 33.0 1559 9 115 7 Eni E&P Division (well Name:SIJ OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO 2 II�I effiti* Date:31912015 - Report#: 20 APIIUWI:50-629-23534-00-00 I� n page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 215-010 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16-39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(in) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 17.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 4.058.72 1,055.98 0.00 101.0 -28.1 Mostly Cloudy WC- WSW @ 17 MPH 45" Daily summary operation 24h Summary Circ.to 20 yield point.Perform cmt job w/205.2 bbls of 12.5 ppg LiteCrete and displace w/996 bbls of LSND.Did not bump plug,floats held.CIP @ 0600 hrs.Perform 20 bbls injectivity test.N/D,raise stack and set emergency slips w/100k overpull.Cut 9 5/8"csg as per Vetco(5.82').Install packoff and N/U BOPE,test packoff and install wear bushing.Cut&slip drlg.line.RIH w/2300'5"DP and C/O bad its.POOH w/5". Operation at 07.00 MN 4.5"DP and rack in derrick. 24h Forecast P/U,M/U and rack back 50 stands of 4.5"DP. CIO upper rams and test BOPE.Perform csg test.P/U,MN BHA and single in hole and perform SHT.Cont.RIH. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1114 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL H 7 P PJSA Circulate and condition mud to 20 yield point @ 4.5 bpm.300 psi. Y 00:30 06:00 5.50 6.00 DRILL H "7 P PJSA Hold PJSM w/all personnel.Install cmt.plugs and K&M sensor.Test cement lines to 1000/3500 psi.Rig pump 100 _: bbls 10.5 ppg MudPush @ 4.5 bpm,ICP-300,FCP-210.Drop Btm plug and SLB pump 205.2 bbls,12,5 ppg,LiteCrete cmt @ 4.9 bpm,ICP-210,FCP-30.Drop Top plug and and kick out w/10 bbls of water.Displace w/996 bbls of 9.3 ppg LSND @ 4.5 bpm,ICP-80,FCP-490.Did not bump plug.Hold 300 psi f/5 min.CIP @ 0600 hrs.Floats held. ` 06:00 06:30 0.50 6.50 DRILL H .20 P PJSA B/D and RID f/cement job. 06:30 07:00 0.50 7.00 DRILL H 9 P PJSA Perform injectivity test w/20 bbls of LSND @ 1 bpm,400 psi. -07:00 09:00 2.00 9.00 DRILL H 20 P PJSA R/D Cement head and bails.R/U Ddg bails and 5"elevators.P/U 1 stand of DP and M/U FOSV.Run in casing purging fluid for casing cut.B/D Kill&Choke lines and drain stack. 09:00 10:30 1.50 10.50 DRILL C 20 P PJSA N/D kill,choke,flow,fillup lines.Seoarate Multibowl and raise stack and secure. 10:30 12:30 2.00 12.50 DRILL C 18 P PJSA Set Vetco emergency slips wl 100k overpull to 240k puw.Cut 95/8"csg.as per Vetco. 12:30 14:00 1.50 14.00 DRILL C 20 P PJSA Pull and L/D landing jt.w/5.82'cut piece.Pull wear bushing and install 9 5/8"packoff. 14:00 16:00 2.00 16.00 DRILL C 12 P PJSA N/U BOPE and test packoff to 2470 psi f/10 min. 16:00 16:30 0.50 16.50 DRILL C 20 P PJSA M/U and set 9"ID wear bushing. 16:30 19:00 2.50 19.00 DRILL E 25 P PJSA Cut and slip 133'of drilling line.Inspect and adjust brakes.Freeze protect OA w/120 bbls of diesel @ 1.7 bpm,2501 550 psi. 19:00 19:30 0.50 19.50 DRILL E 20 P PJSA Install bell guide on top-drive. 19:30 23:00 3.50 23.00 DRILL E 4 P PJSA RIH w/5"DP f/derrick changing out bad jts(20)to 2300',120k puw,115k sow. 23:00 00:00 1.00 24.00 DRILL E -4 P PJSA POOH w/5"DP racking in derrick. Daily Contacts Position Contact Name Company Title E-mall Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRIgClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator • Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -1.22 4.055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 804.41 741.64 LSND 1114.4 33.0 1559.9 115 7 Eni E&P Divisionwen Name:SC JR rill* ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • 2^II n Date:3/1012015 - Report#:, 21 API/UWI:50-629-23534-00-00 I' �I page 1 of 1 Wellbore name: SI34-W6 • Well Header PermitlConcession N° Operator ENI Share(q) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 18.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 4,058.72 1,055.98 0.00 95.0 -32.9 Clear WC-46° SW @ 6 MPH Daily summary operation 24h Summary L/D Mule Shoe and X/O.Install Mouse Hole and C/O Elevators to 4.5".P/U M/U 4.5"D.P.from Pipe Shed and rack back in Derrick.Total 136 stands.Clean and clear rig floor.L/D Mouse Hole.Thaw out ice build up on High Press.Riser.Pull Wear Bushing and set Test Plug.C/O Upper Rams F/9 5/8"Csg to 3.5"X 6"variable.SIMOPS MP2 IDS Brake.R/U to test BOPE.Flood BOPE stack and purge all lines and Equip.of air.Test BOPE W/4.5"and 5"test joints.Test waived by Matt Herrera.Pull test plug and install Wear Bushing 9"ID.R/D and blow down all testing lines and Equip.Bring BHA#4 tools and Equip.to rig floor.Purge air from Mud Pump#2 and lines.Test 9 5/8"Csg to 3,000 PSI for 30 Min.on chart.Witnessed by ENI Co Rep onsite.Pumped.5 bpm,8 bbl pumped and 8 bbl bled back.R/D and blow down all lines and test Equip. Service TDS-8,Blocks,Drawworks and ST-80. Operation at 07.00 RIH W/BHA#4 @ 600'MD. 24h Forecast P/U M/U BHA#4 as per Schlumberger DD and MWD.RIH single joints of 4.5"from Pipe Shed.Shallow hole test MWD.Cont.RIH and tag plug.Circ.and displace to Faze Pro.Drill Shoe Track and 20'of new hole.Perform FIT or LOT. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 ' 0.50 0.50 DRILL 'E 20 P PJSA UD Mule Shoe and X/O.Install Mouse Hole and CIO Elevators to 4.5". 00:30 09:00 8.50 9.00 DRILL E 20 P PJSA P/U M/U 4.5"D.P.from Pipe Shed and rack back in Derrick.Total 136 stands. 09:00 10:30 1.50 10.50 DRILL C 20 P PJSA Clean and clear ng floor.L/D Mouse Hole.Thaw out ice build up on High Press.Riser.Pull Wear Bushing and set Test Plug. 10:30 12:00 1.50 12.00 DRILL C 5 P PJSA C/O Upper Rams F/9 5/8"Csg to 3.5"X 6"variable.SIMOPS MP2 IDS Brake.R/U to test BOPE. 12:00 12:30 0.50 12.50 DRILL C 5 P PJSA Cont.to C/O Upper Ram. 12:30 13:30 1.00 13.50 DRILL C 1 P PJSM Flood BOPE stack and purge all lines and Equip.of air. 13:30 18:30 5.00 18.50 DRILL C 12 P PJSM Test BOPE:Test Annular W/4.5"and 5"test joint to 250 PSI low and 2,500 PSI high for 5 Min.Test Upper and Lower Rams,Choke Manifold valves 1-14,NC-46 and TT525 TIW and Dart Valve,Upper and Lower!BOP,Demco Kill, ,? Manual Kill and Choke,HCR Kill and Choke,Blind Rams with 4.5"and 5"test joint to 250 PSI low and 2,500 PSI high all 3 5 charted.Manual and Hydraulic Super Choke to 1,500 PSI.Perform draw down on Koomey,before Annular 750 PSI, 1 System Press.2,900 PSI,Manifold Press.2,900 PSI,after function Annular Press.750 PSI,System Press.1,600 PSI, Manifold Press 1,400 PSI.200 PSI increase in 57 Sec.Full charge in 204 Sec.Test waived by Malt Herrera. 18:30 19:00 0.50 19.00 DRILL C 5 P PJSA Pull test plug and install Wear Bushing 9"ID. 19:00 20:00 1.00 20.00'DRILL C 5 P PJSA R/D and blow down all testing lines and Equip. 20:00 21:00 1.00 21.00 DRILL E 20 P PJSA Bring BHA#4 tools and Equip.to rig floor. 21:00 23:00 2.00 23.00 DRILL G 12 P PJSA Purge air from Mud Pump#2 and lines.Test 9 5/8"Csg to 3,000 PSI for 30 Min.on chart.Witnessed by ENI Co Rep onsite.Pumped.5 bpm,8 bbl pumped and 8 bbl bled back. 23:00 23:30 0.50 23.50 DRILL G 20 P PJSA R/D and blow down all lines and test Equip. 23:30 00:00 0.50 24.00 DRILL E 25 P PJSA Service TDS-8,Blocks.Drawworks and ST-80. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Mats Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4.055.15 317/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOft(kgflcm') 864.41 741.64 LSND 1114.4 330 1559.9 115.7 VW* Eni E&P Division Well Name:Sia JR EN!Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ eo Date:3111/2015 - Report#: 22 APIIUWI:50-629-23534-00-00 2" " page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3 99 1122 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331 05 7271.92 205.69 354 19.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature("C) Weather Wind 4,058.72 1,055.98 0.00 99.0 -34.5 Clear WC-46° WSW @ 5 MPH Daily summary operation 24h Summary PJSM all essential personnel.P/U MN 8.75"BHA#4 as per Schlumberger DD and MWD.8.75"Hycalog,Xceed,PeroScope,TeleScope,ILS,SonicVision,ADNVision,NMFC,5"HWDP and Jar..PJSM with all essential personnel on loading Nuclear source.Install radioactive source as per Sclumberger MWD onsite.C/O handling Equip.to 4.5".RIH F/318'to 1,515'MD W/singles F/Pipe Shed.Shallow hole test MWD tools.400 GPM,600 PSI.Blow down TDS-8.Cont.RIH F/1,515'to 2,944'MD W/4.5"D.P.F/Pipe Shed.RIH 4.5"D.P.F/2,944'to 7,024'MD F/Derrick.Filling every 2000'MD.Ream in , hole W/4.5"D.P.F/7,024'to 10,533'MD.Filling every 2,000'.30 RPM,TRQ 13-14K,HST 190K,ROT 120K.Schlumberger MWD and DD send down link for logging mode,420 GPM,1,500 PSI.Start logging in hole @ 10,553'MD.Start CBL at 10 Min.per stand while reaming in hole W/4.5"D.P.F/10,533'to 10,915'MD.30 RPM,TRQ 15-16K,HST 199K,SLK NA,ROT 135K.C/O handling Equip to 5".Cont.to ream and CBL F/10,915'to 13,062'MD at 10 Min.per stand.30 RPM,TRQ 20K,HST 210K,SLK NA,ROT 145K. Operation at 07.00 Displacing well with Fazepro 24h Forecast Cont.to ream in hole and CBL.Displace to Faze Pro and drill out shoe track.Shut down and clean surface Equip.Cont.to drill out shoe track and 20'of new hole to 13,336'MD.POOH and perform LOT or FIT.Drill 8.75"production to 23,968'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P PJSM all essential personnel.P/U MN 8.75"BHA#4 as per Schlumberger DD and MWD.8.75"Hycalog,Xceed, PeroScope,TeleScope,ILS,SonicVision,ADNVision,NMFC,5"HWDP and Jar. 00:30 02:00 1.50 2.00 DRILL E 20 P PJSM with all essential personnel on loading Nuclear source,Install radioactive source as per Sclumberger MWD onsite. 02:00 03:00 1.00 3.00 DRILL E 4 P PJSA C/O handling Equip.to 4.5".RIH F/318'to 1,515'MD W/singles F/Pipe Shed. 03:00 03:30 0.50 3.50 DRILL E 12 P PJSA Shallow hole test MWD tools.400 GPM,600 PSI.Blow down TDS-8. 03:30 05:00 1.50 5.00 DRILL E 4 P PJSA Cont.RIH F/1,515'to 2,944'MD W/4.5"D.P.F/Pipe Shed. 05:00 08:00 - 3.00' 8.00 DRILL E 4 P PJSA RIH 4.5"D.P.F/2,944'to 7,024'MD F/Derick.Filling every 2000'MD.HST 160K,SLK 75K. 08:00 11:00 ' 3.00" 11.00 DRILL E 4 P PJSA Ream in hole W/4.5"D.P.F/7,024'to 8,352'MD.Filling every 2,000',30 RPM,TRO 9-12K,HST 180K,ROT 115K. 11:00 14:30 3.50" 14.50 DRILL E 4 P PJSA Ream in hole W/4.5"D.P.F/8,352'to 10,533'MD.Filling every 2,000'.30 RPM,TRQ 13-14K,HST 190K,ROT 120K. 14:30 15:00 0.50 15.00 DRILL E 11 P PJSA Schlumberger MWD and DD send down link for logging mode,420 GPM,1,500 PSI.Start logging in hole @ 10,533' MD. 15:00 16:30 1.50 16.50 DRILL E 4 P PJSA Start CBL at 10 Min.per stand while reaming in hole W/4.5"D.P.F/10,533'to 10,915'MD.30 RPM,TRQ 15-16K, HST 199K,SLK NA,ROT 135K.C/O handling Equip to 5". 16:30 23:00 " 6.50' 23.00 DRILL E 4 P PJSA CBL at 10 Min.per stand while reaming in hole W/5"D.P.F/10,915'to 13,062'MD.30 RPM.TRQ 20K.HST 210K, SLK NA,ROT 145K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Mats Coordinator Eni representative Jack Kvasniko# ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Grant Neuharth Doyon Drilling Tour Pusher • Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pm 1102.4 46.4 1541.8 162./1 Eni E&P DivisionWell Name:SI JR filifitil ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ • Date:3/12/2015 - Report#: 23 APIIUWI:50-629-23534-00-00 l�II �I II page 1 of 1 Wellbore name: S134-W6 Well Header PermitlConcession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-W6 DRILLING 2/20/2015 7.331.05 7,271.92 205.69 35.4 20.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) P06 Temperature(`C) Weather Wind 4.368 39 1.058.84 309.68 849 36.5 105.0 -34.7 Overcast WC-46° W @ 5 MPH Daily summary operation 24h Summary Tag Plug @ 13,061'MD W/10K,30 RPM,stall at 22K TRO.Stand back 1 stand 5"D.P.CBU @ 400 GPM,1,500 PSI,30 RPM,TRQ 20K.PJSM W/all essential personnel for displacement.Displace LSND to 9.25 ppg Faze Pro.Pump 50 bbl Hi Vis spacer,25 bbl LVT.912 bbl 925 ppg Faze Pro @ 250 GPM,ICP 1,870 PSI,FCP 2,300 PSI,80 RPM,TRQ 20-15K,SIMOPS Drill out top plug and cement F/13,061'to 13,153'MD.4-7K WOB,HST 190K,SLK NA,ROT 138K,TRQ 10K.Clean all surface Equip.of interface.Cont.to drill out shoe track,F.C.@ 13,226'MD.Drill Shoe and 20'of new hole to 13,336'MD 450 GPM,2,500 PSI,80 RPM,TRQ 14-16K,WOB 10K.Stand back 1 stand 5"D.P.to 13,246'MD.ADT 0.22,Bit Hrs 0.22,Jar Hrs 0.22.Circ.B/U @ 500 GPM,2,700 PSI,80 RPM, TRO 12K,Mud balanced @ 9.2 ppg in and out.R/U test Equip.,Perform FIT to 660 PSI 12.87 ppg EMW.2.8 bbl pumped and 2 bbl bled back.R/D test Equip.Blow down lines.Drill 8.75"Production F/ 13.336'to 14,332'MD(3,471'ND)500 GPM,2,840 PSI,140 RPM,TRN 16-17K,TOP 10K,WOB 4-8K,HST 205K,SLK NA,ROT 140K.ECD 11.03 ppg W/9.35 ppg MW.Max Gas 1.094 units.ADT 8.49,Bit Hrs 8.49,Jar Hrs 8.49.Monitor well @ 14,180'MD observed slight flow at connection.Decision was made to increase mud weight to 9.3 ppg while drilling ahead. Operation at 07.00 Drill 8.75"Production to 14,553'MD. 24h Forecast Drill 8.75"Production as per well plan to 23,968'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11084 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 4 P PJSA Tag Plug @ 13,061'MD W/10K,30 RPM,stall at 22K TRQ.Stand back 1 stand 5"D.P.CBU @ 400 GPM.1.500 PSI,30 RPM,TRQ 20K. 01:30 03:30 2.00 3.50 DRILL E 9 P PJSM W/all essential personnel for displacement Displace LSND to 9.25 ppg Faze Pro.Pump 50 bbl Hi Vis spacer,25 bbl LVT.912 bbl 9.25 ppg Faze Pm @ 250 GPM,ICP 1,870 PSI,FCP 2,300 PSI,80 RPM,TRQ 20-15K,SIMOPS Drill out top plug and cement F/13,061'to 13,153'MD.4-7K WOB,HST 190K,SLK NA,ROT 138K,TRO 10K. 03:30 04:00 0.50 4.00 DRILL E 20 P PJSA Clean all surface Equip.of interface. 04:00 07:00 3.00 7.00 DRILL E 3 P PJSA Cont.to drill out shoe track,F.C.@ 13,226'MD.Drill Shoe and 20'of new hole to 13,336'MD 450 GPM,2,500 PSI, 80 RPM,TRQ 14-16K,WOB 10K.Stand back 1 stand 5"D.P.to 13,246'MD.ADT 0.22,Bit Hrs 0.22,Jar Hrs 0.22. 07:00 08:00 1.00 8.00 DRILL E 8 P PJSA Circ.B/U @ 500 GPM,2,700 PSI,80 RPM,TRO 12K,Mud balanced @ 9.2 ppg in and out. 08:00 09:00 1.00 900 DRILL E 11 P PJSA R/U test Equip.,Perform FIT to 660 PSI 12.87 ppg EMW.2.8 bbl pumped and 2 bbl bled back.R/D test Equip.Blow down lines. 09:00 '12:00 3.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production F/13,336'to 13,420'MD(3,463'ND)500 GPM,2,780 PSI,120 RPM,TRN 13K,TQF 9K, WOB 4-10K,HST 192K,SLK 80K,ROT 140K.ECD 10.6 ppg W/9.2 ppg MW.Max Gas 509 units.ADT 1.73,Bit Hrs 1.95, Jar Hrs 1.95.Monitor well,static. SPR @ 13,247'MD(3,462'ND)W19.2 ppg MW MP#1 20-260,30-360 MP#2 20-260,30-360 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production F/13,420'to 13,969'MD(3,449'ND)500 GPM,2,820 PSI,140 RPM,TRN 14-15K,TQF 10K, WOB 8-10K,HST 190K,SLK NA,ROT 139K.ECD 10.72 ppg WI 9.2 ppg MW.Max Gas 1,094 units.ADT 3.94,Bit Hrs 5.89,Jar Hrs 5.89.Monitor well,static. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"Production F/13,969'to 14,332'MD(3.471'ND)500 GPM,2,840 PSI,140 RPM,TRN 16-17K,TQF 10K, WOB 4-8K,HST 205K,SLK NA,ROT 140K.ECD 11.03 ppg WI 9.35 ppg MW.Max Gas 933 units.ADT 2.6,Bit Hrs 8.49. Jar Hrs 8.49.Monitor well @ 14,180'MD observed slight flow at connection.Decision was made to increase mud weight to 9.3 ppg while drilling ahead. SPR @ 14,273'MD(3,450'ND)9.35 ppg MW MP#1 20-280,30-360 MP#2 20-280,30-360 MP#3 20-280,30-360 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruno Ravagli ENI Drill Superintendent Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksOoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Grant Neubarth Doyon Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1 22 4,055.15 317/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 liffiRel Eni E&P Division Well Name:SI )R ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ • Date:3/13/2015 - Report#: 24 APIIU WI:50-629-23534-00-00 e I) II'I page 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 21.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4.890 82 1,075.69 522.43 15.40 33.9 109.0 -35.8 Clear WC-53" SSW @ 10 MPH Daily summary operation 24h Summary Drill 8.75"Production FI 14,322'to 16,046'MD(3,528'ND)500 GPM,2,950 PSI,140-180 RPM,TRN 16-18K,TQF 12K,WOB 2-10K,HST 220K,SLK NA,ROT 140K.ECD 11.19 ppg WI 9.3 ppg MW. Max Gas 863 units.ADT 15.4,Bit Firs 23.89,Jar Hrs 23.89.Well had slight flow at connections and slowed to static.An increase of 39 bbl was seen due to thermal expansion of OBM.No losses to formation. Operation at 07.00 Drill 8.75"Production to 16,234'MD. 24h Forecast Drill 8.75"Production as per well plan to 23,968'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11204 Time Log Start 1 End Cum Time II Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 0 00 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/14,332'to 14,777'MD(3,488'TVD)500 GPM,2,830 PSI,140-180 RPM,TRN 16K,TQF 11K,WOB 5-10K,HST 220K,SLK NA,ROT 140K.ECD 11.13 ppg W/9.3 ppg MW.Max Gas 147 units.ADT 4.15,Bit Hrs 12.64,Jar Hrs 12.64.Monitor well,slight flow at connection. 06.00 "12.00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production F/14,777'to 15,182'MD(3,50T ND)500 GPM,2,980 PSI,140 RPM,TRN 15-17K,TOF 12K. WOB 5-10K,HST 220K,SLK NA,ROT 141K.ECD 11.27 ppg W/9.3 ppg MW.Max Gas 219 units.ADT 3.59,Bit Hrs 16.23,Jar Hrs 16.23.Monitor well,slight flow at connection.Increase of 39 bbl for tour due to thermal expansion of OBM. SPR @ 15,182'MD(3,507'ND)9.3 ppg MW MP#1 20-360,30-440 MP#2 20-360,30-440 MP#3 20-360,30-440 12.00 10 00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production F/15,182'to 15,400'MD(3,499'ND)500 GPM,2,870 PSI,140-180 RPM,TRN 16K,TQF 12K,WOB 2-12K,HST 202K,SLK NA,ROT 140K.ECD 11.10 ppg W/9.3 ppg MW.Max Gas 863 units.ADT 4.8,Bit Hrs 21.03,Jar Hrs 21.03.Monitor well,slight flow at connection. 18.00 '00:00 6.00 24.00 DRILL 6 3 P PJSA Drill 8.75"Production F/15,400'to 16,046'MD(3,528'ND)500 GPM,2,950 PSI,140-180 RPM,TRN 16-18K,TQF 12K,WOB 2-10K,HST 220K,SLK NA,ROT 140K.ECD 11.19 ppg W/9.3 ppg MW.Max Gas 834 units.ADT 2.86,Bit Hrs 23.89,Jar Hrs 23.89.Mondor well,static. SPR @ 15,860'MD(3,513'ND)9.3 ppg MW MP#1 20-360,30-460 MP#2 20-360,30-460 MP#3 20-360,30-460 Daily Contacts Position Contact Name Company Title LE-mail Office Mobile Eni representative Bruno Ravagli ENI Drill Superintendent Eni representative Mike Ross ENI Senior Drilling Supv SIDDrillirg@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRIgClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Marhnusen Doyon Drilling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4.055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) 'P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 15458 162 8 .� Eni E&P Division ,,y Well Name:Si. OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 777) Field Name:NIKAITCHUQ eii Date:3/14/2015 - Report#: 25 API/UWI:50-629-23534-00-00 2" " page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 EM PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3 99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331 05 7271.92 205.69 35.4 22.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) PO8 Temperature CC) Weather Wind 5,516 88 1,081.79 626.06 14.50 43.2 109.0 -33.0 Overcast WC-55° SSW @ 20 MPH Daily summary operation 24h Summary Doll 8.75"Production F/16,046'to 18.100'MD(3,545'TVD)500 GPM,3,130 PSI,140-180 RPM,TRN 18-24K,TOE 13K,WOB 2-16K,HST 220K,SLK NA,ROT 140K.ECD 11.36 ppg WI 9.3 ppg MW. Max Gas 1,000 units.ADT 14.3,Bit Hrs 38.19,Jar Hrs 38.19.Monitor well @ 17,726'MD and encountered slight flow and well bore breathing.Lost 26 bbl for tour. Operation at 07.00 Drill 8.75"Production hole to 18,660'MD. 24h Forecast Drill 8.75"Production as per well plan to 23,968'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 - 6.00' 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/16,046'10 16,513'MD(3,536'TVD)500 GPM,2,950 PSI,140 RPM,TRN 17-18K,TQF 14- 15K,WOB 6-8K,HST 215K,SLK NA,ROT 140K.ECD 11.38 ppg W/9.3 ppg MW.Max Gas 384 units.ADT 3.16,Bit He 27.05,Jar Hrs 27.05.Monitor well,static. 06.00 12:00 6.00- 12.00 DRILL E 3 P PJSA Drill 8.75"Production F/16,513'to 17,260'MD(3,544'TVD)500 GPM,3,100 PSI,140 RPM,TRN 18K,TQF 12K, WOB 4-10K,HST 220K,SLK NA,ROT 140K.ECD 11.59 ppg W/9.3 ppg MW.Max Gas 756 units.ADT 2.93,Bit Hrs 29.98,Jar Hrs 29.98.Monitor well,static. SPR @ 16,794'MD(3,533'TVD)9.3 ppg MW MP#1 20-380,30-480 MP#2 20-380,30-480 MP#3 20-380,30-480 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production F/17,260'to 17,726'MD(3,552'TVD)500 GPM,3,050 PSI,140-180 RPM,TRN 18-23K.TQF 13K,WOB 2-17K,HST 225K,SLK NA,ROT 140K.ECD 11.50 ppg WI 9.3 ppg MW.Max Gas 1,000 units.ADT 4.25,Bit Hrs 34.23.Jar Hrs 34.23.Monitor well @ 17,726'MD and encountered slight flow and well bore breathing.. SPR @ 17,726'MD(3,552'TVD)9.3 ppg MW MP#1 20-400,30-480 MP#2 20-400,30-480 MP#3 20-400,30-480 10 00 00:00 6.00 24.00 DRILL E '3 P PJSA Drill 8.75"Production F/17,726'to 18,100'MD(3,545'TVD)500 GPM,3,130 PSI,140-180 RPM,TRN 18-24K,TQF 13K,WOB 2-16K,HST 220K,SLK NA,ROT 140K.ECD 11.36 ppg W/9.3 ppg MW.Max Gas 949 units.ADT 3.96,Bit Hrs 38.19.Jar Hrs 38.19.Monitor well bore breathing.Lost 26 bbl for tour. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Bruno Ravagli ENI Drill Superintendent Eni representative Mike Ross ENI Senior Drilling Sup/ SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigCierksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 4.064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 Eni E&P Division Well Name:SI„ JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ enIf* APIIUWI:50-629-23534-00-00 2^ Date:3/15/2015 - Report#: 26 II II II page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 399 11.22 1 1.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours)hr) Avg ROP(mlhr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 2390 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 6.114 29 1,075.97 597.41 14.16 42.2 103.0 -29.7 Overcast WC-45" WSW @ 12 MPH Daily summary operation 24h Summary Drill 8.75"Production F/18,100'to 20,060'MD(3,529'TVD)500 GPM,3,280 PSI,140-180 RPM,TRN 18K,TQF 14K,WOB 2-16K,HST 225K.SLK NA,ROT 135K.ECD 11.71 ppg W/9.25 ppg MW. Max Gas 697 units.ADT 14.16,Bit Hrs 52.35,Jar Hrs 52.35.Monitor well @ 19.450'Monitor well until static for 25 min.14 BBL gain before going static.Mud loss for dap=38 BBLS Operation at 07.00 Drill 8.75"Production hole to 20,350'MD. 24h Forecast Drill 8.75"Production as per well plan to 23,968'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) • 11204 Time Log Start End Cum • Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06.00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/18,100'to 18,905'MD(3,543'TVD)500 GPM,3,170 PSI,140 RPM,TRN 19K,TQF 12K, WOB 4-10K,HST 230K,SLK NA,ROT 139K.ECD 11.60 ppg W/9.25 ppg MW.Max Gas 519 units.ADT 3.3,Bit Hrs 41.49,Jar He 41.49.Monitor well encountered slight flow and well bore breathing. SPR @ 18,752'MD(3,544'ND)9.25 ppg MW MP#1 20-440,30-540 MP#2 20-440,30-540 MP#3 20-440,30-540 06:00 12:00 6.00 12.00'DRILL E 3 P PJSA Drill 8.75"Production F/18,905'to 19,356'MD(3,535'ND)500 GPM,3,200 PSI,140-180 RPM,TRN 18K,TQF 13K,WOB 8-14K,HST 230K,SLK NA,ROT 140K.ECD 11.77 ppg W/9.3 ppg MW.Max Gas 593 units.ADT 3.69,Bit He 45.18,Jar His 45.18.Monitor well encountered slight flow and well bore breathing.Mud loss for tour 38 BBLS 12.00 18:00 ' 6.00 18.00 DRILL E 3 P PJSA Doll 8.75"Production FI 19,356 to 19,686'MD(3,530'ND)500 GPM,3,260 PSI,140-180 RPM,TRN 18-24K,TQF 14K,WOB 2-16K,HST 235K,SLK NA,ROT 135K.ECD 11.63 ppg W/9.3 ppg MW.Max Gas 697 units.ADT 3.78,Bit Hrs 45.18,Jar Hrs 45.18.Monitor well @ 19450'Monitor well unit)static for 25 min.14 BBL gain before going static 18.00 00:00 ' 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"Production F/19,686'to 20,060'MD(3,529'ND)500 GPM,3,280 PSI,140 RPM,TRN 18K,TQF 14K, WOB 2-16K,HST 225K,SLK NA,ROT 135K.ECD 11.71 ppg W/9.25 ppg MW.Max Gas 675 units.ADT 3.39,Bit Hrs 52.35,Jar Hrs 52.35.Mud gain/loss for lour-0 BBLS SPR @ 19,780'MD(3,529'ND)9.3 ppg MW I MP#1 20-500,30-580 MP#2 20-500,30-580 MP#3 20-500,30-580 Daily Contacts Position Contact Name Company Title 1 E-mail Office Mobile Eni representative Bruno Ravagli 'ENI Drill Superintendent Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satoh Bowe ENI Drilling Supv. Eni representative Mitch Billington ENI Rig Clerk AKRgClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Mats Coordinator Eni representative Jack Kvasniko0 ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rg15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Dulling Tour Pusher rg15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055 15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOft(kgf/cm') 4.064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 Eni E&P Division IWeIIName:Sr:. JR ENI Petroleum Co.Inc. Daily Report WellCode:29543 Field Name:NIKAITCHUQ eDate:3116/2015 - Report#: 27 APII:50-629-23534-00-00 2" " IUWpage 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7271.92 205.69 35.4 24.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 6,670.55 1,070.93 556.26 13.19 42.2 105.0 -22.7 Clear WC-35' ENE @ 20 MPH Daily summary operation 24h Summary Drill 8.75"Production Fl 20.060'10 21,885'MD(3,510'TVD)500 GPM,3,450 PSI,140-180 RPM,TRN 18-21K,TOF 14K,WOB 8-14K,HST 280K,SLK NA,ROT 135K.ECD 11.98 ppg W/9.35 ppg MW. Max Gas 549 units.ADT 13.19,Bit Hrs 65.58,Jar Hrs 65.58. Well bore still breathing.Mud loss for day=41 BBLS Operation at 07.00 Drill 8.75"Production hole to 22,276'MD. 24h Forecast Drill 8.75"Production as per well plan to 23,968'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11204 Time Log Start End Cum Time Time Dur(Or) Dur(Or) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/20,060'to 20,489'MD(3,488'TVD)500 GPM,3,280 PSI,140-180 RPM,TRN 18-22K,TQF 13K,WOB 6-18K,HST 235K,SLK NA,ROT 137K.ECD 11.83 ppg WI 9.3 ppg MW.Max Gas 470 units.ADT 3.64,Bit Hrs 55.99,Jar Hrs 55.99.Monitor well(Breathing) 06.00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production F/20,489'to 20,872'MD(3,510'TVD)500 GPM,3,380 PSI,140-180 RPM,TRN 19K,TQF 12K,WOB 6-12K,HST 275K,SLK NA,ROT 137K.ECD 11.96 ppg W/9.3 ppg MW.Max Gas 74 units.ADT 3.08,Bit Hrs 59.07,Jar Hrs 59.07.Monitor well(Breathing) Mud loss for tour=41 bbls SPRS @ 20,714'(3.499')MW-9.3 ppg MP#1 20-480,30-580 MP#2 20-480.30-580 MP#3 20-480.30-580 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production Fl 21,885'to 21,460'MD(3,5390'TVD)500 GPM,3,470 PSI,140-180 RPM,TRN 18-21K,TQF 16K,WOB 8-10K,HST 240K,SLK NA,ROT 140K.ECD 11.98 ppg WI 9.3 ppg MW.Max Gas 432 units.ADT 3.94,Bit Hrs 63.01,Jar Hrs 63.01.Monitor well(Breathing) 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"Production F/21,460'to 21,885'MD(3,510'TVD)500 GPM,3,450 PSI,140 RPM.TRN 19K,TOF 14K, WOB 8-14K,HST 280K,SLK NA,ROT 135K.ECD 11.98 ppg W/9.3 ppg MW.Max Gas 432 units.ADT 2.57,Bit Hrs 65.58,Jar Hrs 65.58.Monitor well(Breathing) Mud gain/loss for tour=0 bbls SPRS @ 21,647'(3,538')MW-9.35 ppg MP#2 20-500,30-580 MP#3 20-500,30-580 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Davide Simeone 'ENI Project Manager Eni representative Bruno Ravagli ENI Drill Superintendent Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Mitch Billington ENI Rig Clerk AKRgClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpedilor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinesen Doyon Drilling Tour Pusher rg15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4.064.81 1,056-05 Faze Pro 1102 4 46.4 1541.8 162 8 Eni E&P Division IWell Name:SL.. JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 • Field Name:NIKAITCHUQ • nIffj* Date:3/17/2015 - Report#: 28 APIIUW1:50-629-23534-00-00 e I) II IIpage 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..'Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7271.92 205.69 35.4 2590 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 7.081.72 1,045.60 411.18 15.83 26.0 105.0 -19.3 Overcast WC-14" W @ 6 MPH Daily summary operation 24h Summary Drill 8.75"Production Fl 21,885'to 23234'MD(3,429'TVD)500 GPM,3.510 PSI,140-180 RPM,TRN 14-19K,TQF 15K,WOB 8-23K,HST 250K,SLK NA.ROT 135K.ECD 11.88 ppg WI 9.35 ppg MW. Max Gas 318 units.ADT 15.83.Bit Hrs 81.41,Jar Hrs 81.41. Well bore still breathing.Mud loss for day=137 BBLS Operation at 07.00 Drill 8.75"Production hole to 23,604'MD. 24h Forecast Drill 8.75"Production as per well plan to 23,968'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/21.885'to 22,394'MD(3,447'TVD)500 GPM.3,530 PSI,140-180 RPM,TRN 18K,TQF 13K,WOB 8-14K,FIST 285K,SLK NA,ROT 135K.ECD 12.29 ppg W/9.3 ppg MW.Max Gas 41 units.ADT 3.84.Bit Hrs 69.42,Jar Hrs 69.42.Monitor well(Breathing) 06:00 12:00 6.00 i 12.00 DRILL E 3 P PJSA Drill 8.75"Production F/22,394'to 22,715 MD(3,398'TVD)500 GPM,3,470 PSI,140-180 RPM,TRN 18K.TQF 13K,WOB 10-16K,FIST 255K,SLK NA,ROT 133K.ECD 12.07 ppg W/9.35 ppg MW.Max Gas 183 units.ADT 3.01,Bit Hrs 72.43,Jar Hrs 72.43.Monitor well(Breathing)Mud loss for tour=48 bbls SPRS @ 22,580'(3,415 ND)MW 9.3 MP#1 20-500 30-600 MP#2 20-500,30-600 MP#3 20-500,30-600 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production F/22,715'to 22,995'MD(3,413'TVD)500 GPM,3,070 PSI,140-180 RPM.TRN 19K.TQF 15K,WOB 8-236K,FIST 255K.SLK NA,ROT 140K.ECD 11.8 ppg W/9.35 ppg MW.Max Gas 318 units.ADT 5.37,Bit Hrs • 77.80,Jar Hrs 77.80.Monitor well(Breathing)Mud loss for tour=48 bbls 18:00 00:00 6.00_ 24.00 DRILL E 3 P PJSA Drill 8.75"Production F/22,295'to 23,234'MD(3,425 ND)500 GPM,3,510 PSI,140-180 RPM,TRN 19K,TOP 15K,WOB 8-23K.FIST 250K,SLK NA,ROT 135K.ECD 11.88 ppg W/9.35 ppg MW.Max Gas 73 units.ADT 3.61,Bit Hrs 81.41.Jar Hrs 81.41.Monitor well(Breathing)Mud loss for tour=89 bbls SPRS @ 23,140'(3,422 ND)MW 935 MP#1 20-420 30-520 MP#2 20-420 30-520 MP#3 20-420 30-520 Daily Contacts , Position Contact Name Company Title • E-mail ! Office Mobile Eni representative 'Davide Simeone ENI Project Manager i Eni representative Bruno Ravagli ENI Drill Superintendent Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Mur0nusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 317/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 If* Eni E&P Division Well Name:SI., oR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ • n Date:3/18/2015 - Report#: 29 APIIUWI:50-629-23534-00-00 eII l IIpage 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 1122 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 2690 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 7.280.45 1,006.72 198.73 4.41 45.1 104.0 -16.1 Partly Cloudy WC- NNE @ 20 MPH 20° Daily summary operation 24h Summary Drill 8.75"Production F/23,234'to 23,886'MD(3,299'ND) ADT 4.41,Bit Hrs 85.86,Jar Hrs 85.86.Monitor well,static after 25 minutes.Circulate B/U strokes @ 500 GPM. BROOH per K&M schedule-F/23,886'T/22,124'500 GPM,140 RPM At 22,124'Reduced flow rate to 450 GPM 2,900 PSI'Due to excessive dynamic loss(40-50 bph)Cont'to BROOH T/21,834'loss rate @ 20 bph.HST=NA SLK=NA,ROT=140,TRQ=14-15 Mud loss for day 174 bbls Monitor well(breathing) Operation at 07.00 BROOH @ 21,637' 24h Forecast BROOH as per K&M schedule. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E 3 P • PJSA Drill 8.75"Production F/23,234'to 23,886'MD(3,299'ND)500 GPM,3,580 PSI,140 RPM,TRN 18K,TQF 14K, WOB 10-14K,HST 290K,SLK NA,ROT 128K.ECD 12.13 ppg W/9.3 ppg MW.Max Gas 76 units.ADT 4.41,Bit Hrs 85.86,Jar Hrs 85.86.Monitor well(Breathing)Mud loss=22 bbls SPRS @ 23,886'(3,299 TVD)MW 9.3 MP#1 20-420 30-530 MP#2 20-420 30-530 MP#3 20-420 30-530 07:00 07:30 0.50 7.50 DRILL E 21 P Monitor well,static after 25 minutes.(22 bbl return) 07:30 09:30 2.00 9.50 DRILL E 7 P Circulate B/U strokes @ 500 GPM,3,560 PSI,140 RPM,17K TRQ 09:30 12:00 2.50 12.00 DRILL E 6 P PJSA,BROOH per K&M schedule-F/23,886'T/23,330'@ 500 GPM,3,550 PSI,140 RPM,14 K TRQ,HST=250K, SLK=NA,ROT=140K,ECD=11.77 Mud loss for tour 29 bbls 12:00 18:00 6.00 18.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/23,330'T/22,308'@ 500 GPM,3,480 PSI,140 RPM,15 K TRQ,HST=NA SLK=NA,ROT=12K5,ECD=11.94 Monitor well(breathing) 18:00 00:00 6.00 24.00 DRILL E 6 P Cont' BROOH as hole allows-F/22,308'@ 500 GPM,3,440 PSI,140 RPM,15-17 K TRQ,At 22,124'Reduced flow rate to 450 GPM 2,900 PSI'Due to excessive dynamic loss(40-50 bph)Cont'to BROOH T/21,834'loss rate @ 20 bph. HST=NA SLK=NA,ROT=140K,TRQ=14-15 Mud loss for tour 145 bbls Monitor well(breathing) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(gIL) P LeakOff(kgflcm2) 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 Eni E&P Division Name:Sl OR ENI Petroleum nc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ II 2Co.^ Date:3119/2015 - Report#: 30 APIIUWI:50-629-23534-00-00 II �I n page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S134-W6 DRILLING 2/20/2015 7.331 05 7271.92 205.69 35.4 27.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 7280.45 1,006.72 0.00 101.0 -19.4 Partly Cloudy WC- NNE @ 20 MPH 29' Daily summary operation 24h Summary Cont' BROOH per K&M schedule-F/21,810'T/19,689'@ 450 GPM,2,720 PSI,140 RPM,15 K TRQ,HST=NA SLK=NA,ROT=128,ECD=11.16 Mud loss for day=298 bbls Monitor well(breathing) Operation at 07.00 BROOH @ 18,270' 24h Forecast BROOH as per K&M schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/21,810'T/21,472'@ 400 GPM,2,420 PSI,140 RPM,15 K TRQ,HST=NA SLK=NA,ROT=135K,ECD=11.37 06:00 12:00 6.00 12.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/21,472'T/20,530'@ 400 GPM,2,340 PSI,140 RPM,15 K TRQ,HST=NA SLK=NA,ROT=129K,ECD=11.55 Mud loss for tour 104 bbls 12:00 18:00 6.00' 18.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/20,530'T/20,107'@ 450 GPM,2,830 PSI,140 RPM,16 K TRQ,HST=NA SLK=NA,R0T=128K,ECD=11.83 18:00 00:00 6.00' 24.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/20,107'T/19,689'@ 450 GPM,2,720 PSI,140 RPM,15 K TRQ,HST=NA SLK=NA,ROT=128K,ECD=11.16 Mud loss for day=298 bbls Monitor well(breathing) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroieum.com -907-685-0715 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Jerad Vanderpool Doyon Drilling Tool Pusher Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.P fill* Eni E&P Division Well Name:5i_ JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ 2^ Date:3/20/2015 - Report#: 31 APIIUWI:50-629-23534-00-00 I) (I II page 1 of 1 Wellbore name: S)34-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331.05 7271.92 205.69 35.4 28.50 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 7280.45 1.006.72 0.00 107.0 -18.3 Overcast WC-14" NE @ 5 MPH Daily summary operation 24h Summary PJSA,Cony BROOH per K&M schedule-F/19,689'T/14,780'@ 500 GPM,2,980 PSI,140 RPM,15-17 K TRO,HST=NA SLK=NA,ROT=130,ECD=11.21 Monitor well(breathing)Mud loss for day=227 bbls Operation at 07.00 BROOH @ 14,643' 24h Forecast BROOH as per K&M schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114 4 Time Log • Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 600 DRILL E 6 P PJSA,Cony BROOH per K&M schedule-F/19,689'T/17,571'@ 450 GPM,2,500 PSI,140 RPM,15 K TRQ,HST=NA SLK=NA,ROT=13OK,ECD=10.85 Moonitor well(breathing) 06:00 12:00 6.00 12.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/17,571'T/15,673'@ 550 GPM,3,400 PSI,140 RPM,11 K TRQ,HST=NA SLK=NA,ROT=135K,ECD=10.98 Moonitor well(breathing)Mud loss for tour 125 bbls 12:00 18:00 6.00 18.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/15,673'T/14,962'@ 500 GPM,2,980 PSI,140 RPM,15 K TRQ,HST=NA SLK=NA,ROT=130K,ECD=11.75 Moonitor well(breathing) 18:00 00:00 6.00 24.00 DRILL E 6 P PJSA,ConY BROOH per K&M schedule-F/14,962'T/14.780'@ 500 GPM,2,980 PSI,140 RPM,15-17 K TRQ,HST=NA SLK=NA,ROT=130K.ECD=11.21 Monitor well(breathing)Mud loss for day=227 bbls Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akdgclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4.055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4.064.111 1,056.05 Faze Pro 1102.4 46.4 1541.8 162-8 Eni E&P Division Well Name:Si, OR ft* ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • Date:3/21/2015 - Report#: 32 APIIUWI:50-629-23534-00-00 2" " p page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11 22 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331 05 7,271.92 205.69 35.4 29.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 7,280.45 1,006.72 0.00 106.0 -19.4 Overcast WC-14' SSW @ 4 MPH Daily summary operation 24h Summary PJSA,Cont' BROOH per K&M schedule-F/14,780'T/13,526'@ 550 GPM,3,140 PSI,100 RPM,14 K TRO,HST=NA SLK=NA,ROT=135,ECD=11.41 Monitor well(breathing)Mud loss for day=47 Operation at 07.00 BROOH @ 12,792'MD 24h Forecast BROOH as per K&M schedule to-10,500'Reciprocate,rotate&perform K&M cleanup cycle.Slip and cut drilling line. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06-.00 6.00 6.00 DRILL E 6 P PJSA,Cont' BROOH per K&M schedule-F/14,780'T/14,620'@ 520 GPM,3,050 PSI,140 RPM,13-15 K TRO,HST=NA SLK=NA,ROT=130K,ECD=11.41 Monitor well(breathing) 06.00 12:00 6.00 12.00 DRILL E 6P PJSA,Cont' BROOH per K&M schedule-FI14,620'7/14,182'@ 530 GPM,3,200 PSI,140 RPM,13-15 K TRO,HST=NA SLK=NA,ROT=130K,ECD=11.08 Monitor well(breathing)Mud loss for tour=27 bbls 12.00 18:00 6.00 18.00 DRILL E 6 P PJSA,Con(' BROOH per K&M schedule-F/14.182'T/14,023'@ 550 GPM,3,250 PSI,140 RPM,15 K TRO,HST=NA SLK=NA,ROT=128K,ECD=11.44 Monitor well(breathing) 18.00 00:00 - 6.00 24.00 DRILL E 6P PJSA,Cont' BROOH per K&M schedule-F/14.023'TI13.526'@ 550 GPM,3,140 PSI,100 RPM,14 K TRO,HST=NA SLK=NA,ROT=135K.ECD=11.41 Monitor well(breathing)Mud loss for day=47 Daily Contacts Position i Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Satch Bowe ENI Dulling Supv. Eni representative Bernie Leas ENI Rig Clerk akrgclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jack Kvasnikop ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 11024 46.4 1541.8 162.8 * Eni E&P Division Well Name:SL JR ENI Petroleum Co.Inc. Daily Report wellcode:29543 Field Name:NIKAITCHUQ • e^n Date:3/2212015 - Report#: 33 APIIUWI:50-629-23534-00-00 II �I(I page 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N° Operator ENI Share(to) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 30.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 7.280.45 1.006.72 0.00 102.0 -16.1 Overcast WC-17° SW @ 18 MPH Daily summary operation 24h Summary PJSA,BROOH F/13,526'-T/10,915.CBU X5,weight up to 9.45ppg,rotate&reciprocate F/11,008'-T/10,915'@ 550 GPM,2,950 PSI,120 RPM,11-12 K TRQ,HST=165K SLK=102K,ROT=132K, ECD=10.59.Cut&slip drilling line,service rig.Monitor well during service(static).PJSA,POOH on elevators F/10,915'T/9,771'HST=160K,SLK=105K,Incorrect hole fill observed.Monitor well for 30 minutes(static).PJSA,Change out saver sub to 4.5"NC46.PJSA,Pump out of hole F/9,771'T/8,349'@ 4.5 BPM,410 PSI,HST=140K,SLK=100K, Operation at 07.00 POOH @ 6,084'MD 24h Forecast Cont'POOH,L/D BHA#4,test BOPE&P/U,M/U BHA#5 Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 11324 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08.30 8.50 8.50 DRILL E 6 P PJSA,Cant' BROOH per K&M schedule-F/13,526'T/10,915'@ 550 GPM,2,950 PSI,120 RPM,11-12 K TRQ,HST=165 SLK=102,ROT=132,ECD=10.54 Monitor well(static) 08:30 13:00 4.50 13.00 DRILL E 7 P PJSA,CBU X5,weight up to 9.45ppg,rotate&reciprocate f/11,008'to 10,915'@ 550 GPM,2,950 PSI,120 RPM,11-12 K TRQ.HST=165K SLK=102K,ROT=132K,ECD=10.59 Blowdown suface equipment&monitor well for 10 minutes with slight flow observed. 13:00 15:00 2.00 15.00-DRILL E 20 P PJSA,Cut&slip drilling line,adjust draw works brakes,service and inspect top drive,clean rig floor.Monitor well during service(static) 15:00 18:30 3.50 18.50 DRILL E 4 P PJSA,POOH on elevators F/10,915'T19,771'HST=160K,SLK=105K,Incorrect hole fill observed.Monitor well for 30 minutes(static) 18:30 21:00 2.50 21.00 DRILL E 20 P PJSA,Change out saver sub to 4.5"NC46 21:00 00:00 3.00 24.00 DRILL E 4 P PJSA,Pump out of hole F/9,771'T/8,349'@ 4.5 BPM,410 PSI,HST=140K,SLK=100K, , Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrillirg@enipetroleum.com 907-685-0715 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rg15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -1.22 4.055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4.064.81 1,056.05 Faze Pro 1102.4 464 1541.8 162.8 f illi* Eni E&P Division Well Name:SI, JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ • Date:3/23/2015 - Report#: 34 API/UWI:50-629-23534-00-00 e" o ii page 1 of 1 Wellbore name: SI34-W6 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM - 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331 05 7,271.92 205.69 35.4 3190 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 7,280.45 1,006.72 0.00 104.0 -28.3 Overcast WC-41° SW@ 10 MPH Daily summary operation 24h Summary Pump out of hole F/8,349'T/4,747'@ 4.5 BPM, POOH on elevators F/4,747'T/1,900'@ 4.5 BPM,320 PSI,HST=121K,SLK=120K,Monitor well(static) Pump trip pill&LD 4.5"DP F/1,900'1/380' L/D BHA#4 per Schlumberger DO and MWD.Stabilizer sleeve on the ILS came unscrewed&floated between shoulder on ILS&wear band.All tools in gauge.8.75"Bit grade 1,1,CT,A,X,IN,NO,TD. Monitor well for 20 Min.,static.R/U to test BOPE.Small flowback from the IA.Monitor gain during testing of BOPE.Test Annular with 5"test jl.To 250/2,500 psi.Upper rams 3.5"X 6"VBR failed high pressure test.Witness waived by AOGCC John Crisp on 3-21-15.R/D Testing equip,drain BOPE stack,re-dress upper ram blocks.2 bbl gain from IA flowback.R/U To complete BOPE test. Fluid loss for day=s bbls. Operation at 07.00 Cont To Test BOPE 24h Forecast Cont'Testing BOPE.P/U&M/U BHA#5 8.75"Hole Opener.RIH W14.5"and 5"D.P. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 11324 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 4 P PJSA,Pump out of hole F18,349'T/4,747'@ 4.5 BPM,320 PSI,HST=138K,SLK=111 K,Monitor well(static) 06:00 10:00 4.00 10.00 DRILL E 4 P PJSA,POOH on elevators F/4,747'T/1,900'@ 4.5 BPM,320 PSI,HST=121K,SLK=120K,Monitor well(static)Fluid loss=7 bbls 10:00 13:00 3.00 13.00 DRILL E 4 P PJSA,Pump trip pill&LD 4.5"DP F/1,900'T/380' HST=95K, Clear rig floor of SLB tools. 13:00 16:00 3.00 16.00 DRILL E 4 P PJSM W/all essential personnel.L/D BHA#4 as per Schlumberger DD and MWD.Stabilizer sleeve on the ILS came unscrewed&floated between shoulder on ILS&wear band.All tools in gauge.8.75"Bit grade 1.1,WT,A,X,IN,NO.TD. Monitor well for 20 Min.,static. 16:00 17:30 1.50 17.50 DRILL E 20 P PJSA Clean and clear rig floor of all BHA#5 tools and Equip.Pull wear bushing,set test plug 17:30 19:00 1.50 19.00 DRILL E1 P PJSM,R/U to test BOPE.Small flowback coming from the IA.Monitor gain during testing of BOPE. 19:00 20:00 1.00 20.00 DRILL E 12 P PJSA,Test Annular with 5"test jt.TO 250/2,500 psi.Upper rams 3.5"X 6"VBR failed high pressure test.Witness waived by AOGCC John Crisp on 3-21-15 20:00 23:30 3.50 23.50 DRILL E 5 P PJSA,R/D Testing equipment,drain BOP stack,re-dress upper ram blocks.2 bbl gain from IA flow back. 23:30 00:00 0.50 24.00 DRILL E 12 P RN To complete BOPE test.Fluid loss for day=5 bbls. Daily Contacts Position Contact Name CompanyTitle E-mail _ Office Mobile - Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrgderksdoyon15@enipetroieum.com 907.685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4.064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 Eni E&P Division !Well Name:SIS. OR ENI Petroleum Co.Inc. Daily Report well Code:29543 Field Name:NIKArTCHUO �Iff* Date:3/24/2015 - Report#: 35 APIIUWI:50-629-23534-00-00 211 IIWellbore name: SI34-W6 page 1 of 1 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(IVO...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331 05 7,271.92 205.69 35.4 32.90 Daily Information End Depth(mKB) End Depth(TVD)(...Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 7,280.45 1,006.72 0.00 107.0 -22.2 Partly Cloudy WC- NE @ 20 MPH 33- Daily summary operation 24h Summary PJSM,Test BOPE&all associated valves.Perform koomey test.Test upper and lower IBOP's lower test failed.PJSA,Replace lower IBOP&C/0 saver sub F/NC46 TO TT525.Retest lower IBOP/ good.test annular, upper&lower rams.All gas alarms tested.PJSA,R/D&Blow ON test equipment,lubricate TDS,upper and lower(BOPS,Blow DN.choke&kill lines. Remove test plug&set wear ring. MN BHA#5.RIH T/13,701' Fill pipe every 20 stands. Ream in hole F/13,701'T/14,445'@ 80 rpm,10-11k TO,ROT=140k, Operation at 07.00 Cont'reaming in hole to 16,405' 24h Forecast Ream to-21,600'.CBU while mixing Breaker fluid.PJSA with all personnel,pump Breaker @ 3 bpm per MI.Drop rabbit&POOH as per K&M schedule to 13,100'.Displace W/Brine per MI.POOH on elevators. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deaer. 00:00 04:00 4.00 4.00 DRILL E 12 P PJSM,Test BOPE,all choke valves 1-14&kill line demco to 250 13,500 psi W/5"test jnt.test upper&lower pipe rams, blind rams 250/3,500 Test choke and kill NCR's&manual valves,Test all floor valves 250/3,500.test manual choke and super choke to 1,500 psi,Perform koomey test.Test upper and lower IBOP's 250/3500,lower test tailed. 04:00 07:30 3.50 7.50 DRILL E 5 P PJSA,Replace lower IBOP&change out saver sub from NC46 TO TT525. 07:30 09:00 1.50 9.00 DRILL E 12 P PJSA,Test lower IBOP to 250/3,500 psi,anuular with 4.5 test jt.to 250/2,500 psi,upper&lower rams to 250/3,500 psi.All gas alarms tested. 09:00 11:30 2.50 11.50 DRILL E 20 P PJSA,R/D&Blow DN test equipment,lubricate top drive upper and lower(BOPS,Blow DN.choke&kill lines. Remove test plug&set wear ring W/Vetco on site,OD 13.438"ID 9",length 29.8" lock down screws run in. 11:30 12:00 0.50 12.00 DRILL E 1 P PJSA,Prep BHA#5 components for breaker run.No fluid loss for tour. 12:00 12:30 0.50 12.50 DRILL E 20 P PJSA,M/U BHA#5 T/204 12:30 18:00 5.50 18.00 DRILL E 4 P PJSA,RIH W/BHA#5 T/7,794'PN=145K,S/0=102k.Fill pipe every 20 stands. 18:00 22:30 4.50 22.50 DRILL E 4 P Cont'RIH F/7,794'T/13,701'S/O NA. 22:30 00:00 1.50 24.00 DRILL E 6 P PJSA,Ream in hole F/13,701'T/14.445'@ 80 rpm,10-11k TO,ROT=140k, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satoh Bowe ENI Drilling Supv. Eni representative Bemie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 c Eni E&P Divisionwen Name: si OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ 2 ii^ Date:3/25/2015 - Report#: 36 APIIUWI:50-629-23534-00-00 II II page 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession Ni Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331 05 7271.92 205.69 35.4 33.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 7,280.45 1.006 72 0.00 105.0 -23.3 Partly Cloudy WC- NE @ 15 MPH 32° Daily summary operation . 24h Summary PJSA,Cont' Ream in hole F/14,445'T/21,634'@ 80 rpm,P/U=205k,ROT=143,13k TO,Fill pipe every 20 stands.Fluid loss=13bbls for tour.Break circulation,stage up pump rates T/380 gpm,1,880 psi,ROT @120 rpm,TO 15k.Reciprocate F/21,634'T/21,544,conditioning mud to 9.5 ppg.in 8 out.SIM-OPS Build Fazeaway Breaker©Mud plant.Pill=220k,ROT=141,TQ=13.21 bbl loss during circulation.Monitor well for breathing 25 minutes.Slight flow observed.Pump 600 bbls of 9.5 ppg FazeAway Breaker,@ 2.5 bpm,ICP=400 psi,FCP=250, 40 rpm,13k tq,ROTW=141 k.Reciprocate F/21,634 T/21,544.600 bbls pumped,591 bbls returned=9 bbl loss.Fluid loss for day=43 bbls. Operation at 07.00 POOH @ 20,985' 24h Forecast POOH f/21,634'-13,100'per K8M trip schedule.Circ.8 condition mud while prepping for KCL Brine displacement.Displace well to 9.1 ppg KCL Brine.Cont.POOH T/BHA#5. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11324 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00.00 06:00 6.00 6.00 DRILL E 6 F' PJSA,Cont' Ream in hole F/14,445'T118,083'@ 80 rpm,P/U=195k,ROT=143,1l k TQ,Fill pipe every 20 stands. 06:00 12:00 6.00 12.00 DRILL E 6 P PJSA,Cont' Ream in hole F/18,083'T/21,634'@ 80 rpm,P/U=205k,ROT=143,13k TQ,Fill pipe every 20 stands.Fluid loss=13bbls for tour. 12:00 18:30 6.50 18.50 DRILL E 7 P PJSM.Break circulation,stage up pump rates T/380 gpm,1,880 psi,ROT @120 rpm,TQ 15k.Reciprocate F/21.634' T/21,544,conditioning mud to 9.5 ppg.in 8 out.SIM-OPS Build Fazeaway Breaker @ Mud plant.P/U=220k,ROT=141, TQ=13.21 bbl loss during circulation. 18.30 00:00 5.50 24.00 DRILL E 9 P PJSA,Monitor well for breathing 25 minutes.Slight flow observed.Pump 600 bbls of 9.5 ppg FazeAway Breaker,@ 2.5 bpm,ICP=400 psi,FCP=250, 40 rpm,13k tq,ROTW=141 k.Reciprocate F/21,634 T/21,544.600 bbls pumped.591 bbls returned=9 bbl loss.Fluid loss for day=43 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Jack Keener ENI Senior Dulling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rg15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -1.22 4,055.15 3/7/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm2) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 Eni E&P DivisionWell Name:SID OR IffilA ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ nDate:3/2612015 - Report#: 37 APIIUWI:50-629-23534-00-00 e I' �I II page 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 1122 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 34.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 7,280.45 1,006.72 0.00 107.0 -17.2 Overcast WC-16° NE©10 MPH Daily summary operation 24h Summary Cont'pumping 50 bbls of 9.5 ppg Faze Away Breaker for 650 total bbls.Chase with 134 bbls Faze Pro while reciprocating&rotating.RPM=140k,TQ=13-14k.Pump 35 bbls trip pill @ 11.5 ppg,chased with 10 bbls 9.5 ppg Faze Pro. Monitor well for flowback(static)/Sim-Ops BD surface equipment Service TDS&Travelling Equipment.POOH Per K&M Trip schedule-F/21,634'T/19,580'P/U=203k S/O=NA.Dropped 2.94"Rabbit with 140'tail on stand#226 @ 21,448'. POOH Per K&M Trip schedule-F/19,580'T/13,137'P/U=175k ROT=140,TQ=11k.Fluid loss=l5 bbls. Break circulation,stage pumps up T/260 GPM,800 psi,dynamic loss @18 BPH.ROT=80 rpm,TQ=10k.Reciprocate string F/13,137'T/13,044'.Sim-Ops PJSM for Brine displacement.Fluid loss of 36 bbls while circulating. Prep pits for displacement,Monitor well(static)Pump 40 bbls LVT @ 5.5 BPM,660 psi.77 bbls.Citric Acid high vis spacer @ 65 BPM,860 psi.Chase with 9.1 ppg KCL/NaCL Brine @ 6.7 BPM ICP=640 psi.ROT=80 rpm,TQ=15k Reciprocate F/13,137'T/13,044'. 938 bbls of Brine pumped,observed calculated returns.FCP=400 psi.PIU=190k,S/O=87k,ROT=145k.Fluid loss for day=51 bbls. Operation at 07.00 POOH laying down 4-1/2"DP @ 8,726'. 24h Forecast Clean surface equipment POOH standing back 5"DP.LD 4-1/2"DP&BHA.Prep for 4-1/2"Liner run. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '01:00 1.00 1.00 DRILL E 7 P PJSA,Cont.pumping 50 bbls of 9.5 ppg Faze Away Breaker for 650 total bbls.Chase with 134 bbls Faze Pro while reciprocating&rotating.RPM=140k,TQ=13-14k 01:00 01:30 0.50 1.50 DRILL E 7 P PJSA,Pump 35 bbls trip pill @ 11.5 ppg,chased with 10 bbls 9.5 ppg Faze Pro. 01:30 02:00 0.50 2.00 DRILL E '20 P PJSA,Monitor well for flowback(static)/Sim-Ops BD surface equipment.Service TDS&Travelling Equipment 02:00 06:00 4.00 6.00'DRILL -E -4 P PJSA,POOH Per K&M Trip schedule-F/21,634'T/19,580'P/U=203k S/O=NA.Dropped 2.94"Rabbit with 140'tail on stand #226 @ 21,448'. 06:00 '12:00 6.00 12.00 DRILL E 4 P PJSA,POOH Per K&M Trip schedule-F/19,580'T/16,874'P/U=190k S/O=NA.Fluid loss=6 bbls 12:00 18.00 6.00 18.00 DRILL E 4 P PJSA,POOH Per K&M Trip schedule-F/16,874'T/13,137' P/U=175k ROT=140 TQ=11 k.Fluid loss=9 bbls. 18:00 20:00 2.00 20.00 DRILL E 7 P PJSA,Break circulation,stage pumps up T/260 GPM,800 psi,dynamic loss @18 BPH.ROT=80 rpm,TQ=10k. Reciprocate string F/13,137'T/13,044'.Sim-Ops PJSM for Brine displacement.Fluid loss of 36 bbls while circulating. 20:00 00:00 4.00 24.00 DRILL E 7 P PJSA,Prep pits for displacement,Monitor well(static)Pump 40 bbls LVT @ 5.5 BPM,660 psi.77 bbls.Citric Acid high vis spacer @ 6.5 BPM,860 psi.Chase with 9.1 ppg KCL/NaCL Brine @ 6.7 BPM ICP=640 psi.ROT=80 rpm,TQ=15k Reciprocate F/13,137'T/13,044'. 938 bbls of Brine pumped,observed calculated returns.FCP=400 psi.P/U=190k, S/O=87k,ROT=145k.Fluid loss for day=51 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com '907-685-0715 715-6434 Eni representative Satoh Bowe ENI Drilling Supv. Eni representative Bemie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Marhnusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 5.52 6,562.95 3127/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 I ,C Eni E&P Division Weu Name:Si OR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO e^n ii Date:3/27/2015 - Report#: 38 APIIUWI:50-629-23534.00-00 l�II IIpage 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S134-W6 DRILLING 2/20/2015 7,331.05 7271.92 205.69 35.4 35.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 7,280.45 1,006.72 0.00 111.0 -15.6 Overcast WC-r W @ 2 MPH Daily summary operation 2411 Summary Clean surface equipment,Sim-Ops,Service Draw Works,TDS&Traveling equipment.Monitor well(static) POOH Per K&M Trip schedule-F/13,137'T/9,015'. Change over handling equipment f/5"to 4.5".Rabbit removed from the 4.5"DP.Cont'POOH laying down 4.5"DP F/9,015'T/205'.Total Jts.laid down=285.Total jts.culled for Hardbanding=59,L/D BHA#5 F/205'.Clear&clean rig floor of BHA #5,Handling equipment&components.R/U Volant tool&liner running equipment.Prep pipe shed for liner run.Hold Liner running safety meeting and P/U&M/U 4.5"L80 11.6#H521 Injection Liner as per tally and RIH f/0-5,730', GBR&Halliburton reps onsite. Fluid loss for day=48 bbls. Operation at 07.00 RIH W/4.5"Liner @ 8,216'MD 24h Forecast Cont'RIH w/liner on 5"DP to-21,538'.P/U to setting depth and set Liner hanger/packer as per Baker.Test packer and release from it.POOH. Lithoiogy Shows MAASP(kgflcm') Mud Weight(gIL) 10904 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P PJSA,Clean surface equipment,Sim-Ops,Service Draw Works.TDS&Traveling equipment.Monitor well(static) 00:30 02:30 2.00 2.50 DRILL E 4 P PJSA,POOH per K&M Trip schedule-F/13,137'T/9,015'P/U=157k, SIO=103k. 02:30 06:00 3.50 6.00 DRILL E 4 P PJSA.Change over handling equipment f/5"to 4.5".Rabbit removed from the 4.5"DP.Cont POOH laying down 4.5"DP F/9,015'TI5,645'.PA1=138k,SIO=110k. 06:00 10:30 4.50 10.50 DRILL E 4 P PJSA,Cont'POOH laying down 4.5"DP F/5,645'T/205'PN=83k SIO=84k.Total Jts.laid down=285.Total jts.culled for Hardbanding=59 10:30 11:00 0.50 11.00 DRILL E 20 P -PJSA,L/D BHA#5 F/205'SLB DD onsite. 11:00 12:00 1.00 12.00 DRILL E 20 P PJSM,Clear&clean rig floor of BHA#5,Handling equipment&components.Fluid loss for tote=25 bbls 12:00 13:30 1.50 13.50 DRILL E 20 P PJSA,R/U Volant tool&liner running equipment.Prep pipe shed for liner run. 13:30 18:00 4.50 18.00 DRILL G 4 P PJSA,Hold Liner running safety meeting and IOU&M/U 4.5"L80 11.64 H521 Injection Liner as per tally and RIH f/0- 2,291',P/U=98k,S/O=98k GBR&Halliburton reps onsite. 18:00 00:00 6.00 24.00 DRILL G 4 P PJSA,Cont'RIH with 4.5'Liner per tally,F/2,291,T/5,730'.P/U=110k,S/O=98k.Fluid loss for day=48 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satch Bowe ENI Drilling Supv. i Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyon15@enipetroteum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.corn 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 5.52 6,562.95 3/27/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4.064.81 1,056.05 Faze Pm 1102.4 46.4 1541.8 1628 Eni E&P Division IWell Name:SI. �R EN!Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUQ fill* eAPIIUWI:50.629-23534-00-00 2^n Date:3128/2015 - Report#: 39 'I II II page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 10000 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI34-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 36.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 7,280.45 1,006.72 0.00 111.0 -17.8 Light Snow WC-17° NE @ 11 MPH Daily summary operation 24h Summary Cony RIH with 4.5'Liner per tally,F/5,730',T/8,397'.R/D Volant&liner hanger handling tools.R/U GBR tongs to M/U Liner-Hanger Packer..P/U&M/U Liner-Hanger Packer with Baker Rep.&fill with Pal mix.RIH with 1 stand D/P F/8,397'T/8,563'.Fill pipe&verify circulation(successful).RIH with 5"D/P&Liner per tally F/8,563'T/14,971'.Fluid toss for tour-14 bbls.Cony RIH with 4.5"Liner on 5'D/P F/14,971'7/19,271 No Slack off weight available.Start rotating F/19,271'T/21,532'.P/U=220k,S/O=NA,RPM=30,TO=16.Drop 1.65"Baker ball& pump @ 4.5 bpm,740 psi,slow to 2 bpm.220 psi. Seat ball and pressure to 3,000 psi and hold for 5 min.Slack off to 80k and increase to 3,500 psi&hold for 5 min.Increase to 4000 psi and bleed off pressure.P/U string T/140k Close top rams and pressure up annulus to 1500 psi for 10 charted mins.Bleed off pressure.Liner shoe @ 21,532',Liner top @ 13,102'.Pull 16 stands and rack back to pull running tool out of liner&prep to Slip&cut drill line.Hang blocks,begin slip&cut drill line.Fluid loss for day=42 bbls. Operation at 07.00 POOH Laying Down 5-DP @ 9,978'.MD 24h Forecast Slip&cut drill line.POOH laying down 5"D/P.Prep rig door&pipe Shed for 4.5"Completion run.Run 4.5"Injector Completion. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. I Act. Plan Oper.Descr. 00:00 0400 4.00 4.00 DRILL G 4 P PJSM,Cony RIH with 4.5'Liner per tally,F/5,730',T/8,397'.P/U=118k,5/0=93k.Halliburton Rep onsite. 04:00 04:30 0.50 4.50 DRILL G 20 P PJSM,R/D Volant&liner hanger handling tools.R/U GBR tongs to M/U Liner-Hanger Packer.GBR Rep onsite. 04:30 05:30 1.00 5.50 DRILL G 20 P PJSM,P/U&M/U Liner--Hanger Packer with Baker Rep.&fill with Pal mix.RIH with 1 stand D/P F/8,397'T/8,563'.Fill pipe &verify circulation(successful).Company Rep.onsite. 05:30 12:00 6.50 12.00 DRILL G '4 P PJSA,RIH with 5"D/P&Liner per tally F/8,563'T/14,971'P/U=165k,S/O=100,ROT=141 k,TO=9-10k.Rotated through one tight spot per K&M Rep.F/13,731'7/13,947'Fill pipe every 20 stands.Fluid loss for tour-14 bbls. 12:00 16:00 4.00 16.00 DRILL G 4 P PJSM,Cont'RIH with 4.5"liner on D/P F/14,971'T/19,271' P/U=200k,S/O=NA. 16:00 20:00 4.00 20.00 DRILL G 4 P PJSA,No Slack off weight available.Start rotating F/19,271'T/21,532'.P/U=220k,S/O=NA,RPM=30,TQ=16.K&M Rep onsite. 20:00 22:30 2.50 22.50 DRILL G 19 P PJSA,Drop 1.65"Baker ball& pump @ 4.5 bpm,740 psi,stow to 2 bpm,220 psi.Seat ball and pressure to 3,000 psi and hold for 5 min.Slack off to 80k and increase to 3,500 psi&hold for 5 min..Increase to 4000 psi and bleed off pressure.P/U string 1/140k Close top rams and pressure up annulus to 1500 psi for 10 charted mins.Bleed off pressure.Liner shoe @ 21,532'.Liner top @ 13,102'. Company Rep onsite.Blow down surface equipment. 22:30 23:30 1.00 23.50 DRILL G '4 P PJSM,Pull 16 stand and rack in derrick to pull running tool out of liner&prep to Slip&cut drill line. 23:30 00:00 0.50 24.00 DRILL G 20 P PJSM,Hang blocks,begin slip&cut drill line.Fluid loss for day=42 bbls. 00:00 00:00 24.00 DRILL Daily Contacts Position Contact Name I Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig 15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 5.52 6,562.95 3/27/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 Eni E&P Division 'Well Name:SI; DR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • 2 I^nPi* Date:3129/2015 - Report#: 40 APIIUWI:50-629-23534-00-00 I I�II page 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 215-01G ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5134-W6 DRILLING 2/20/2015 7,331.05 7,271.92 205.69 35.4 37.40 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature('C) Weather Wind 7,280.45 1,006.72 0.00 103.0 -17.8 Partly Cloudy WC- ENE @ 20 MPH 21' Daily summary operation 24h Summary PJSM.POOH laying down 5"DP F/6,441'MD T/0'MD.PJSM.POOH laying down 5"DP F/11.575'MD T/6,441'MD.HST=150k SLK=120k.PJSM.POOH laying down 5"DP F/6,441'MD TIO'MD.PJSM. LID Liner I Packer running tool with Baker Hughes rep onsite.PJSA. Clear and clean rig floor and prep for tubing run. Operation at 07.00 Changed from S134-W6 Drilling to SI34-W6 Completion 24h Forecast Change from 5134-W6 Drilling to SI34-W6 Completion at 3-29-2015 at 1200 hours. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 02:00 2.00 2.00 DRILL G 20 P PJSM.Perform cut-n-slip drilling line ops.Service crown,draw works,top drive and travelling equipment.Inspect and adjust as required(12 wraps cut=102') 02:00 06:00 4.00 6.00'DRILL G 4 P PJSM.POOH laying down 5"DP F/11.575'MD T/6,441'MD.HST=150k SLK=120k. 06:00 10:30 4.50 10.50 DRILL G 4 P PJSM.POOH laying down 5"DP F/6,441'MD,T/0'MD. 10:30 11:00 0.50 11.00'DRILL G 4 P PJSM.LID Liner/Packer running tool with Baker Hughes rep onsite 11:00 12.00 1.00 12.00 DRILL G 20 P PJSA. Clear and clean rig floor and prep for tubing run. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satoh Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrgclerksdoyon15@enipetroleum.com 907-685-0722 907-26E-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 5.52 6.562.95 3/27/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162 8 fill* Eni E&P Division Well Name:SL OR l EN!Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO i II Date:312912015 - Report ii: 1 APIIUWI:50-629-23534-00-00 • �" page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5134-W6 COMPLETION 37.90 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 103.0 -20.0 Clear WC-34" NE @ 35 MPH Daily summary operation 24h Summary RU&Pull wear ring per Vetco Grey.RU GBR Volant tool&completion running equipment.Prep pipe shed.RIH with 4.5"Completion per tally.T12,537'P/U=105k,S/0=105k Cont'RIH with 4.5" Completion per tally F/2,537'T/8,126'P/U=138k SIO=92k.Total 201 joints.Fluid loss for tour-38 bbls. Operation at 07.00 Cont.RIH W/4.5"Tubing @ 10,469'MD 24h Forecast Cont' RIH w/4.5"tubing to TOL&work down to no-go sub.Space out, M/U pup jts.&Tubing hanger.Drain/clean stack&land tubing string per Vetco.RILDS& test hanger seals to 5000 psi for 10 min. R/U& pump down string to close auto fill&check for leaks.Pressure up,set packer @ 2600 psi&chart for 30 min.Bleed pressure to 2000 psi&test IA to 2500 psi for 30 charted mins.Bleed IA to 0& pressure tubing to 4400 psi to shear open the Mirage plug.Shear out GLM valve @ 2500 psi.Pull landing jt.&set BPV.N/D stack, install tree& test to 5000 psi. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 12:30 0.50 0.50 COMP K 20 P PJSA,RU&Pull wear ring per Vetco Grey. 12:30 14:00 1.50 2.00 COMP K 20 P PJSA,RU GBR Volant tool&completion running equipment.Prep pipe shed. 14:00 18:00 4.00 6.00 COMP K 4 P PJSM,RIH with 4.5"Completion per tally.T/2,537'P/U=105k,S/0=105k 18:00 00:00 6.00 12.00 COMP K 4 P Cont'RIH with 4.5"Completion per tally F/2,537'T/8,126'P/U=138k 5/0=92k.Total 201 joints.Fluid loss for tour-38 bbls Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI • Senior Dulling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Salch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnlling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 5.52 6.562.95 3/27/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4.064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 1.* Eni E&P Division Well Name:SI JR ENI Petroleum Co.Inc. Daily Report Wet Code:29543 Field Name:NIKAITCHUO e^n II Date:3/30/2015 - Report#: 2 APIIUWI:50-629-23534-00-00 II II page 1 of 1 Wellbore name: SI34-W6 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11 22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5134-W6 COMPLETION 38 90 Daily Information End Depth(mKB) End Depth(TVD)(...Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 97.0 -18.3 Blowing Snow WC- E @ 28 MPH 27° Daily summary operation 24h Summary RIH w/4.5"tubing F/8,126'T/13,102',Tag no go on liner top.Space out tubing,LID joint#326 and install 3 pup joints with total length of 19.33'.M/U Joint#326&land tubing hanger.WLEG @ 13,122'. R/D&L/D GBR tools&4.5"Sim-Ops with testing upper&lower seals on hanger T/5000 psi.for 10 minutes.R/U to set&test Packer.Test surface lines to 3500 psi.R/U&pressure tubing to 1200 psi for 5 min to close Auto fill.Inc.pressure to 3000 psi to set packer&hold for 30 min.Bleed tubing pressure to 2000 psi&pressure IA to 2500 psi&hold for 30 min.for Integrity test.Bleed IA pressure to 0& pressure tubing to 4800 psi to shear Mirage plug.Bleed tubing to 0.Pressure IA to 2200 psi,to shear GLM valve.All testing was charted.Blow down&R/Dtesting equipment.Pull landing jt.&set BPV per Vetco.N/D bell nipple,BOPE& high pressure riser.Clean well head,N/U tree&test void to 5000 psi f/10 min.PJSA Pull BPV,install TWC,bleeder&gauge on tree.Fill tree w/diesel,R/U&test to 500 psi f/5 min.&5000 psi f/15 min.Freeze protect IA w/150 bbls of diesel @ 1.5 bpm,700 IP/900 FP. Operation at 07.00 Prep To Move Rig To SP04-SE5 24h Forecast Complete shear valve retrieval,install new valve and test to 500 psi.Retrieve catcher and secure well.RDMO.Accept Rig to SP04-SE5 Rig released @ 00:00 hrs.3-30-15 Lithology Shows MAASP(kgflem") Mud Weight(g/L) 1090.4 Time Log Start End Cum Time Time Our(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 Zoo 7.00 COMP K 4P PJSA,RIH wl 4.5"tubing P18,126'T/13,102',P/U=148k,S/0=82k,Tag no go on liner top.Baker Rep onsite. 07:00 09:00 2.00 9.00 COMP K 4P PJSA,Space out tubing,L/D joint#326 and install 3 pup joints with total length of 19.33',M/U Joint#326&land tubing hanger.WLEG @ 13,122'.Vetco Gray Rep&Company Rep onsite. 09:00 09:30 0.50 9.50 COMP K 20 P PJSA,R/D&L/D GBR Volant tool&4.5"tubing handling tools.Sim-Ops RIDS& test upper&lower seals on hanger T/5000 psi.for 10 miutes. 09:30 11:30 2.00 11.50 COMP K 12 P PJSM,R/U to set&test Packer with Halliburton,Baker&Company Reps onsite. 11:30 12:00 0.50 12.00 COMP K 12 P PJSA,Pressure purge&pressure test surface lines t0 3500 psi.(successful) 12:00 14:00 2.00 14.00 COMP K 12 P PJSA,RN and pressure tubing to 1200 psi for 5 min to close Auto fill.Inc.pressure to 3000 psi to set packer and hold for 30 min.Bleed tubing pressure to 2000 psi and pressure IA to 2500 psi and hold for 30 min.for Integrity test.Bleed IA pressure to 0 and pressure tubing to 4800 psi to shear Mirage plug.Bleed tubing to 0.Pressure IA to 2200 psi,to shear GLM valve.All testing was charted. 14:00 14:30 0.50 14.50 COMP K 20 P PJSA Blow down all lines and R/D all testing equipment. 14:30 15:00 0.50 15.00 COMP C 20 'P PJSA Pull landing jt.and set BPV as per Vetco. 15:00 17:30 2.50 17.50 COMP C 20 P PJSA N/D bell nipple.BOPE and high pressure riser. 17:30 20:00 2.50 20.00 COMP C 12P PJSA Clean well head.NN tree and test void to 5000 psi f/10 min. 20:00 21:30 1.50 21.50 COMP C 12 P PJSA Pull BPV,install TWC,bleeder and gauge on tree.Fill tree w/diesel,RN and test to 500 psi f/5 min.and 5000 psi f/ 15 min. 21:30 00:00 2.50 24.00 COMP C 9 P PJSA Freeze protect IA w/150 bbls of diesel @ 1.5 bpm,700 IP/900 FP. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 5.52 6,562.95 3/27/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 4.064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 Iffi* Eni E&P DivisionWell Name:SI JR ENI Petroleum Co.Inc. Daily Report Well Code:29543 Field Name:NIKAITCHUO • Date:3/31/2015 - Report#: 3 APIIUWI:50-629-23534-00-00 e II �'IIpage 1 of 1 Wellbore name: S134-W6 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 215-016 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.39 3.99 11.22 11.22 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI34-W6 COMPLETION 39.40 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0.00 97.0 -20.0 Blowing Snow WC- NE @ 30 MPH 33" Daily summary operation 24h Summary PJSA and cont with freeze protect IA Ops with LRS.1,5 BPM @ 30 bbls pumped=1000 PSI.1.5 BPM@90 bbls pumped=900 PSI.Sim Ops with prep for move#3 pump.PJSM with all involved parties& RU HES to perform Slickline Ops SIM Ops with lay Herculite on SP04-SE5.PJSA&PIT lubricator with LRS 02000 psi(successful).1st run=RIH w/4.5 GL and set 4.5 slip stop catcher(successful).2nd run=PIT lubricator&TIH w/OK-6kick over tool.3rd run RIH w/OK-6 kick over tool with JK running tool&shear valve.Set and PIT 0800 psi.for 5 min'(successful).4th run=RIH w/4.5 GS and retrieve 4.5 slip stop catcher(successful) .SIM OPS with move rockwasher&lay mats on SP04-SES.Breakdown interconnects between modules&prep for rig move.PJSM&RID HES equipment.Secure well. IA=340 PSI,OAS=160 PSI,TBG=15 PSI.PJSA and prep rig floor for skid rig floor ops. Sim Ops with remove drilling valves from wellhead&install production caps.Clean wellhead area&transfer high pressure fittings from SI34-W6 well bay. Release rig from SI34-W6 @ 1200 hours. Operation at 07.00 Move rig to SP04-SE5 well. 24h Forecast Move rig to SP04-SE5 Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 - 0.50 0.50 COMP G 20 P PJSA and cont with freeze protect IA Ops with LRS.1,5 BPM @ 30 bbls pumped=1000 PSI.1.5 BPM@90 bbls pumped=900 PSI.Sim Ops with prep for move#3 pump. 00:30 03:00 2.50 3.00 COMP K 5 F' PJSM with all involved parties&RU HES to perform Slickline Ops SIM Ops with lay Herculite on SP04-SE5. • 03:00 08:00 5.00' 8.00 COMP K 20 P PJSA&PIT lubricator with LRS 02000 psi(successful).1st run=RIH w/4.5 GL and set 4.5 slip stop catcher(successful). 2nd run=P/T lubricator&TIH w/ok-6kick over tool.3rd run RIH w/OK-6 kick over tool with JK running tool&shear valve. Set and PIT 0800 psi.for 5 min-(successfuk).4th run=RIH w/4.5 GS and retrieve 4.5 slip stop catcher(successful) .SIM OPS with move rockwasher&lay mats on SP04-SE5.Breakdown interconnects between modules&prep for rig move. 08:00 09:00 1.00 9.00 COMP G 20 'P PJSM&R/D HES equipment.Secure well.IA=340 PSI,OAS=160 PSI,TBG=15 PSI. 09:00 12:00 3.00 12.00 COMP G 20 P PJSA and prep rig floor for skid rig floor ops. Sim Ops with remove drilling valves from wellhead&install production caps. Clean wellhead area&transfer high pressure fittings from SI34-W6 well bay. Release rig from SI34-W6 @ 1200 hours. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Satoh Bowe ENI Drilling Supv. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 5.52 6,562.95 3/27/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4,064.81 1,056.05 Faze Pro 1102.4 46.4 1541.8 162.8 U, . o m^V V m 4 m V.-010. W V.-O tm Nm O V m M m N a V a m..M a MNrem N 4 .-00,0N n m.-Mr^ CLN 9...VV... ONNN .MN, 0002 22804 8UNN NOa.-MN 2 0m m A 00000 mm2w, 2a0, 42m84 i2422 4002 82240 4NU)42 ° 4A. 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S N A m Ott-A812 N t^ N N0NQ <t0Nth01 t0Obt4(ON map b N O LL Cp h (y O a'Z Z pE MNNN NNNNN NNNNN NNNNN NNNN cV O 2 OlN7 tf m e g .F F W O LL N cNi 0 g, m A m e LL LL o m O 12. 2222 `8�ppim�pp000 SNep�� ry2ry?22S vg28A2 tnuI`g,e`S'i O w Tp m 2mONi2 O)Of 0f 0)O) G)C1SOf A m2GDODm abOm ONiT O 0000 a f"I b W y Q LL.N 2' b ..... E' c U f r2°?.82 22226- v26- AmgR ,oe 27 n^ 2S goo a 5i a mF2g 2 pE47 mG.1mmmVV § ,,,Vagmm Ot NNNNN I2 N ) 2b7W N NN NNNN NNNNN NNNNN NNNNN N O r- G e u, iOcci C J N 2ea g OI y O W a rm rn E 2 trE o 0 h 0 Eni Petroleum CASING&CEMENTING REPORT Lease&Well No. SI34-W6 Date 23-Feb-15 County GPB State Alaska Supv. John Chant CASING RECORD- 54.ci.F'4GC c.4 TD 2816.00 Shoe Depth: 2803.38 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 13-3/8 BTC WTF 1.90 2,803.38 2,801.48 2 13-3/8 68 L-80 BTC _ Tenaris 77.94 2,801.48 2,723.54 Float Collar 13-3/8 BTC WTF 1.48 2,723.54 2,722.06 68 13-3/8 68 L-80 BTC _ Tenaris 2,681.96 2,722.06 40.10 Pi&Hanger 13-3/8 68 L-80 BTC Tenaris 3.42 40.10 36.68 Totals 2,766.70 Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: Guide Casing Crew: GBR Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes _No Liner hanger test pressure: Centralizer Placement: 1 centralizer 5'&8'above shoe,10'above FC,1 each joint up to 2289'MD,2 centralizer inside CP. CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.1 Volume pumped(BBLs) 100 Lead Slurry Type: ASL Yield(Ft3/sack): 2.77 Density(ppg) 10.7 Volume (BBLs/sacks): 436/883 Mixing/Pumping Rate(bpm): 5.8 Tail Slurry Type: LiteCrete Yield(Ft3/sack): 1.56 0 Density(ppg) 12.5 Volume (BBLs/sacks): 64/230 Mixing/Pumping Rate(bpm): 4 H Post Flush(Spacer) 17, Type: H2O Density(ppg) 8.4 Rate(bpm): 5 Volume: 10 LL Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 5.5 Volume(actual/calculated): 408.5/408.8 FCP(psi): 370 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 850 Casing Rotated? Yes x No Reciprocated? _Yes x No %Returns during job 100 Cement returns to surface? x Yes No Spacer returns? x Yes No Vol to Surf: 174 bbls ASL Cement In Place At: 9:35 Date: 2/23/2015 Estimated TOC: Surface Method Used To Determine TOC: Visual cement at surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry w Type: Yield(Ft3/sack): F Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): (0 Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w Displacement: Type: Density(ppg) Rate(bpm): variable Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes _No %Returns during job Cement returns to surface? Yes _No Spacer returns?_Yes _No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: Eni Petroleum CASING&CEMENTING REPORT Lease&Well No SI34-W6 Date 9-Mar-15 County GPB State Alaska Supv. Chant / c. CASING RECORD-Intermediate casing 1 43 TD 13316 00 Shoe Depth 13304 31 PBTD MD/ ND Casing(Or Liner)Detail Setting Depths I No of Jts Size Wt. Grade THD Make Length Bottom Top Shoe 9-5/8 Hydril 563 Davis-Lynch 501 2.75 13,304.31 13,301.56 2 9-5/8 40 L-80 Hydril563 Tenaris 78.24 13,301.56 13,223.32 Float Collar 9-5/8 Hydril 563 Davis-Lynch 700 2.90 13,223.32 13,220.42 328 9-5/8 40 L-80 Hydri1563 Tenaris 13,190.42 13,220.42 30.00 Totals 1 13,274.31 Csg Wt On Hook Type Float Collar Float No Hrs to Run Csg Wt On Slips Type of Shoe Guide Casing Crew Fluid Description Liner hanger Info(Make/Model) Liner top Packer? _Yes X No Liner hanger test pressure Centralizer Placement. 1 centralizer 5'above shoe,10'above FC,1 each joint up to 11,263'MD CEMENTING REPORT Preflush(Spacer) Type Mud Push II Density(ppg) 10.5 Volume pumped(BBLs) 100 Lead Slurry Type DeepCrete Yield(Ft3/sack). 1 56 Density(ppg) 12 5 Volume (BBLs/sacks): 205/738 Mixing/Pumping Rate(bpm) 4 5 Tail Slurry Type N/A Yield(Ft3/sack) N/A aDensity(ppg) N/A Volume (BBLs/sacks) N/A Mixing/Pumping Rate(bpm) N/A I— Post Flush(Spacer) N Type H2O Density(ppg) 8 4 Rate(bpm) 5 Volume 10 LL Displacement: Type Mud Density(ppg) 9 3 PPG Rate(bpm) 4.5 Volume(actual/ccllculaled�y 1003/1006 FCP(psi) 490 Pump used for disp: Rig pumps Plug Bumped? _Yes No Bump press Casing Rotated? Yes X No Reciprocated' Yes x No %Returns during job Cement returns to surface? Yes x No Spacer returns'? Yes x No Vol to Surf0 Cement In Place At 6-00 Date 3/9/20.15 Estimated TOC. 10,950 Method Used To Determine TOC. Calculated Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type Yield(Ft3/sack) Density(ppg) Volume (BBLs/sacks) Mixing/Pumping Rate(bpm) Tail Slurry w Type Yield(Ft3/sack): F Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm). N Post Flush(Spacer) 0 o Type Density(ppg) Rate(bpm) Volume w Displacement: Type Density(ppg) Rate(bpm) Volume(actual/calculated) FCP(psi): Pump used for disp. Plug Bumped'? _Yes No Bump press Casing Rotated? Yes _No Reciprocated' Yes No %Returns during job Cement returns to surface? Yes _No Spacer returns'? Yes No Vol to Surf Cement In Place At Date Estimated TOC: Method Used To Determine TOC Remarks m 0Z-rr-W ITI m ? 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(7 ('j 70 arc 0 o .° •V PC ' -1 x a- N 01, S-01(o 1528 iffijot HALLIBURTON IC II III{ En PtiroIkiuiiriri 1 Sperry Drilling PACKING LIST Spy Island Drillsite Nikaitchuq 5134-W6 Shipping Date: 19-Mar-2015 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 6900 Arctic Blvd. Anchorage,AK 99501 Anchorage,AK 99515 Attn: Meridith Guhl 907-739-1235 Item Description IIMMI Interval Packaging Box Description SP21-NW1 Washed and Dried Samples-50' 2,900'to 5,000' Paper envelopes 1 of 8 Washed and Dried Samples-50' 5,050'to 7,550' Paper envelopes 2 of 8 Washed and Dried Samples-50' 7,600'to 10,100' Paper envelopes 3 of 8 Washed and Dried Samples-50' 10,150'to 12,650' Paper envelopes 4 of 8 Washed and Dried Samples-50' 12,700'to 15,400' Paper envelopes 5 of 8 Washed and Dried Samples-50' 15,450'to 18,350' Paper envelopes 6 of 8 Washed and Dried Samples-50' 18,400'to 21,200' Paper envelopes 7 of 8 Washed and Dried Samples-50' 21,250'to 23,900 Paper envelopes 8 of 8 Two(2)Bundles Contains Bundle 1-Four(4)Boxes Bundle 2-Four(4)Boxes Notes: Total Packages this Shipment: 2 Please notify sender upon receipt of delivery; Josh Zuber 907-865-3388 RECEIVE L Received by Expediter: Date: MAR 2 e 2015 AOGCC TA(c0F1 \�\\ y/�,,s� THE STATE Alaska Oil and Gas '71 ofALA J(j\ Conservation Commission - _:ate_ v 333 West Seventh Avenue ki x-_-_-=_ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 T4 Main: 907.279.1433 ALAS ' Fax: 907.276 7542 www.aogcc.alaska.gov Marc Kuck Drilling& Completion Engineering Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SI34-W6 ENI US Operating Co. Inc. Permit No: 215-016 Surface Location: 4430' FSL, 1484' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 4443' FSL, 3794' FEL, SEC. 22, T14N, R8E, UM Dear Mr. Kuck: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 1 P-7)2-e ("C----L. Cathy P. Foerster Chai DATED this3d yy of January, 2015. ham.: :tL- c'IVED STATE OF ALASKA JAN 1 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj 0+ Single Zone 0 • lc.Specify if well is proposed for: Drill 0 Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0. Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 . SI34-W6 - 3.Address: 6.Proposed Depth: '12 Field/Pool(s)• 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 23968. TVD: 3445• Nikaitchuq/Schrader Bluff • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 4430 FSL,1484 FEL,S19 T14N R9E UM - ADL 0391283,0388577,0388574,0388575 , Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4128 FSL,1425 FEL,S26 T14N R8E UM ADL 417493 3/7/2015 Total Depth: 9.Acres In Property: 14.Distance to Nearest Property: 4443 FSL,3794 FEL,S22 T14N R8E UM 8260 • 1815'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 54.1 ft 15.Distance to Nearest Well Open Surface:x- 511427 y- 6053610 Zone- 4 .. GL Elevation above MSL: " 13.1 ft to Same Pool: 1022'to SP31-W7 Ll 16.Deviated wells: Kickoff depth: 400 feet .. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 94.26 degrees . Downhole: 1573 psig Surface: 1188 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade • Coupling Length MD TVD MD ND (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 Pre-Installed 1130 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2866 35 35 2901 2454 LEAD:905 sx 10.7 ppg ASL TAIL:225 sx 12.5 ppg DeepCrete • 12.25" 9-5/8" 40 L-80 Hydril 563 13608 33 33 13641 3507 812 TOTAL sx 812 sx 12.5 ppg DeepCrete 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 10528 13441 3493 23968 3445 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program ❑' Time v.Depth Plot ❑ Shallow Hazard Analysis0 Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program 0 " 20 MC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 1/15/2015 22. I hereby certify that the foregoing is true and correct. Contact Andrea Lazzari 907-230 7511 Email andrea.lazzarK. enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager Signature � Phone (907)865-3322 Date 1/15/2015 Commission Use Only Permit to Drill / API Number: Permit Approvalkr6cA\(� See cover letter for other Number: ,.Q 15-0 1 10 50-6a4 -,23S 3y-00-010 Date: ✓ requirements. Conditions of approval: If box is checked,%yell may not be used to explore for,test,or produce coalbed methan ,gas hydrates,or gas contained in shales:[17f Other: S� .^A..' (2 Y(✓ �� /- Samples req'd: Yes[1 No[� Mud log req'd:YeC No[/ �[/ /Y kJ ` HZS measures: Yes[( No[/' Directional svy req'd:Yeo No❑ ) -c( o •J "kc7 3rd AA( ( -j (Iv'. Spacing exception req'd: Yes❑ NoQ' Inclination-only svy req'd:YeC No� u,(-f-,►�. D e"., ..9 w( A r-O 36 / APPROVED BY / Approved by 1 - COMMISSIONER THE COMMISSION Date: /- I S 2 / �'Kdl` ��� (Zp�3 Submit Form and Form 10-401(Revised 10/2012) 1114 ATILIs from the date of approval(20 AA .0050 Attachments in Duplicate L , /_- rn 1-alw2 !jEnii Pketrok loll111 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907)865-3322 Email: Marc.Kuck@enipetroleum.com January 16,2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector SI34-W6 Dear Commissioners, Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the Offshore Injector well SI34-W6. This well will be drilled and completed using Doyon 15. The planned spud date could be as early as 03/07/2015. Please find attached for the review of the Commission forms 10-401 as well as the information required by 20 ACC 25.005. If you have any questions or require further information,please contact Andrea Lazzari 907 230 7511 Sincerely, Marc Kuck, Drilling&Completion Engineering Manager wok • Enil Petirolleuim 2na • Application for Permit to Drill SI34-W6 Saved:15-Jan-15 Application for Permit to Drill Document Injector Well SI34-W6 Table of Contents 1. Well Name 3 Requirements of 20 AAC25.005(0 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20AAC25.005(c)(6) 5 7. Diverter System Information 5 Requirements of20AAC2S.005(c)(7) 5 Requirements of 20 AAC 25.005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program 6 (LSND) 6 Lateral Mud Program 6 (MI FazePro Mineral Oil Base) 6 8. Abnormally Pressured Formation Information 6 Requirement,of 20AAC25.005(c)(9) 6 9. Seismic Analysis 7 Requirements of 20 AAC25.005(c)(10) 7 03_AOGCC PERMIT Document Page 1 of 10 Printed:15-Jan-15 v.* e nn n • Enli P Application for Permit to Drill SI34-W6 Saved:15-Jan-15 10. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 11. Evidence of Bonding 7 Requirements of 20 MC 25.005(c)(12) 7 12. Proposed Drilling Program 7 Requirements of 20 AAC25.005(c)(13) 7 13. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 MC 25.005(c)(14) 9 14. Area of Review 9 15. Attachments 10 Attachment 1 Drilling Procedure 10 Attachment 2 Directional Plan 10 Attachment 3 Drilling Hazards Summary 10 Attachment 4 BOP and Diverter Configuration 10 Attachment 5 Cement Loads and CemCADE Summary 10 Attachment 6 Formation Integrity And Leak Off Test Procedure 10 Attachment 7 Surface Platt 10 Attachment 8 % Mile Scan Report 10 Attachment 9 Casing Design Program 10 03 AOGCC PERMIT Document Page 2 of 10 Printed:15-Jan-15 firA • Einiii PetroIkuim 2n Application for Permit to Drill SI34-W6 Saved: 15-Jan-15 1. Well Name Requirements of 20 AAC25.005(0 Each well in. be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SI34-W6 2. Location Summary Requirements of 20 AAC 25.005(c)(2) tin appncauo,tu;a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (5)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4430 FSL, 1484 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1 ft'AMSL Northing: 6,053,610' Easting:511,427' Pad Elevation 13.1 ft'AMSL Location at Top of Productive Interval 4128 FSL, 1425 FEL, S26 T14N R8E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13,609' Northing: 6,048,019' Easting: 501,130' Total Vertical Depth, RKB: 3,505' Total Vertical Depth, SS: 3,451' Location at Total Depth 4443 FSL, 3794 FEL, S22 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 23,968' Northing: 6,053,618' Easting: 493,476 Total Vertical Depth, RKB: 3,445' Total Vertical Depth, SS: 3,391' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Dali(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent we//bores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan 03 AOGCC PERMIT Document Page 3 of 10 Printed: 15-Jan-15 2no If* • Eli' PtiroIIeum Application for Permit to Drill SI34-Ws Saved: 15-Jan-15 (2)for all wells within 200 feet of the proposed wel/bore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC25.035,20 AAC25.036, or 20 MC 25.037,as applicab/e; • Please see Attachment 4: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the app/ication: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane oradient! The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11),_and_the planned_ -rtical depth of the OA sand formation is: MPSP = (3,494'TVDss)(0.45 - 0.11 psi/ft) = 1188 psi (B)data • •• • - • - The well bore is not expected to penetrate any gas zones. and (C)data concerning potentia/causes of hole problems such as abnormally geo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting fnnrmation integrity tests, as required under 20 AAC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 03AOGCC PERMIT Document Page 4 of 10 Printed:15-Jan-15 2n II TI"‘ Ein Petroleum Application for Permit to Drill SI34-W6 Saved: 15-Jan-15 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/It) Grade Connection (ft) (ft) (ft) Cement Program 20 Driven 178.89 X-65 Welded 160 36 / 36 160'/ 160' Pre-Installed 13-3/8 16 68 L-80 BTC 2866' 35/ 35 2901'/ 2454' Surface dead: 905 sx 12.5ppg DeepCrete 225 sx 9-5/8 12-1/4 40 L-80 Hydril 563 13608' 33 / 33 13641'/ 3507' 12.5 ppg DeepCRETE 812 sx 4-1/2 8-3/4" 11.6 L-80 Hydril 521 10528' 13441'/3493' 23968'/ 3445' Liner in Open Hole-no cement 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC25.035,unless this requirement is waived by the commission under 20 AAC25.035(h)(2); Please see Attachment 4: BOP Configuration. 03_AOGCC PERMIT Document Page 5 of 10 Printed: 15-Jan-15 lloott ■En!' PetirolleLuim 2no Application for Permit to Drill SI34-W6 Saved: 15-Jan-15 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 st) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/89 Csg Point 1ra/ae Value Density(ppg) 6.7_9 Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity 45 60 (CP) (seconds) Yield Point 14 - 20 Plastic Viscostiy 12 - 18 (lb/100 st) (CP) HTHP Fluid loss Yield Point 18-24 (ml/30 min ah <5.0 (lb/100 sf) 200psi&100°F API Filtrate4 - 6 Oil/Water 60/ 40 (cc/30 min)) Ratio Chlorides(mg/I) <500 Electrical >600 pH 9.0 - 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC25.005(c)(9) An app/icafion for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 70 MC 75033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 03AOGCC PERMIT Document Page 6 of 10 Printed:15-Jan-15 **• Petirolleuirn 2no Application for Permit to Drill SI34-W6 Saved:15-Jan-15 9. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An app/icalion for a Permit to Dail must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (10,)for an erpinratory or stratigraphic test well a seismic refraction or reh7ectfon analysis as required by 20 AAC25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Dri/l must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by20 AAC25.061(6); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC25.025(Bonding)have been met; Evidence of bonding for ENI is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: Please refer also to Attachment 1— Drilling Procedure pr %ur p,*r •t 1.,rs f 1) Move in / rig up Doyon 15. "T 2) RU Diverter and test as per AOGCC requirements 3) Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5) Install and test wellhead to 5000 PSI. 6) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 7) Pressure test casing to 2500 psi per AOGCC regulations. Record results. 8) PU 12-1/4"bit and directional drilling assembly with MWD, LWD and PWD. 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. • Min LOT: 11.00 ppg / 10) Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11) Install 9-5/8"casing rams in the BOP and test to 350 . 03_AOGCC PERMIT Document Page 7 of 10 Printed:15-Jan-15 tilos ■ • Eno Petirolleum ern Application for Permit to Drill SI34-W6 Saved:15-Jan-15 12) RU casing drive system. 13) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14) Install 9-5/8"Emergency Slips. 15) Install 9-5/8"packoff and test to 5000 psi. 16) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. v�' 17) Pressure test casing to 3000 psi per AOGCC regulations. Record results. 18) PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 19) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. • Min LOT: 12.00 ppg 20) Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 21) PU dumb iron assembly and TIH to TD 22) Displace well to 9.5 ppg FazeAway Delayed Breaker 23) POOH on elevators to intermediate casing shoe and displace to 9.0 ppg KCI brine. 24) POOH on elevators and LD BHA. RU to run 4-1/2"liner. 25) PU and run 4-1/2"liner to TD. Ensure cross over and FOSV is on the floor. 26) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8"intermediate casing. 27) Bleed DP pressure to zero, close annular and test annulus to 1500 psi for 10 min on chart. 28) POOH laying down DP as required. +--� 29) RU tubing running equipment and run 4:1i-2f-tubing. Land tubing. 30) Test upper and lower seals to 5000 psi for 10 min. iir ; 31) RU to set PHL Injection Packer. Test surface lines to 5000 psi and bleed to zero. ,I W 32) Pressure down tubing string to 1200 psi to close autofill valve and monitor for leaks. ✓33) Increase pressure down tubing to 3,500 psi to set packer and hold for 30 minutes. Record on chart as tubing integrity test. Ensure inner annulus is open and monitor for returns. ✓34) Reduce tubing pressure to 2,000 psi. Rig up and pressure inner annulus to 2,500 and hold for 30 IA UT j,4 minutes. Record annulus pressure on chart as inner annulus integrity test. Bleed annulus pressure to zero. 35) Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 36) Pressure inner annulus to 2,500 to shear valve in GLM. If valve does not open, cycle annular pressure from 0 to 2,500 psi several times while allowing tubing to bleed pressure. 37) Pull landing joint and set BPV. 03_AOGCC PERMIT Document Page 8of10 Printed:15-Jan-15 �� • Einiii P en Application for Permit to Drill SI34-W6 Saved: 15-Jan-15 38) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). 1// • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the D tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 39) Pull BPV and set TWCV. 40) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 41) Pull TWCV. 42) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 43) Set BPV and secure tree and wellhead. _ 44) RDMO /4)t 7'h.e_5 5 G.Q Mir— iA ."1. "- —t S 7-4-et - j#AT. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point or Spy Island Class I disposal well. Alternative disposal method will include hauling the fluids to the Prudhoe Bay Grind and Inject Facility. 14. Area of Review Requirements of 20 MC 25 To the knowledge of Eni US Operating Co. Inc. there are no other wells completed in the Schrader Bluff formation other then those stated in the attached 1/4 mile scan report. The Nikaitchuq Unit also includes the following wells drilled by Kerr McGee Oil &Gas Corporation: Nikaitchuq #1: Plugged and Abandoned 04/01/04 Nikaitchuq #2: Plugged and Abandoned 04/01/04 (East of Nikaitchuq Unit) Nikaitchuq #3: Plugged and Abandoned 04/26/05 Nikaitchuq #4: Plugged and Abandoned 04/21/05 Kigun #1: Plugged and Abandoned 03/30/05 Tuvaaq State #1: Plugged and Abandoned 03/09/05 To Eni US Operating Co. Inc.'s knowledge all wells have been cemented across the Schrader Bluff formation as per AOGCC regulations and plugged and abandoned. All wells that fall into the 1/4 mile radius said herein have been drilled and completed in the Schrader Bluff formation in accordance with 20 MC 25 AOGCC regulations. Please See attachment 8— 1/4 Mile Scan Report 03_AOGCC PERMIT Document Page 9 of 10 Printed:15-Jan-15 • Eirii PtiroIIeum eno Application for Permit to Drill SI34-W6 Saved: 15-Jan-15 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment 5 Cement Loads and CemCADE Summary Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 % Mile Scan Report Attachment 9 Casing Design Program 03AOGCC PERMIT Document Page 10 of 10 Printed:15-Jan-15 Attachment 1 Drilling Procedure viiiii en II ass operrang WELL SI34-W6 Drilling Procedure SI34-W6 Spy Island Conductor slot#34 Reservoir location #W6 Injector (Schrader Bluff) Nikaitchuq Project SI34-W6 Drilling Wellplan Page 1 of 40 01/15/15 VW* • 2n0 tsoperrahng WELL SI34-W6 Spy Island Nikaitchuq Field enn pefokkulmi North Slope - Alaska SI34-W6 ° DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD TVD SIZE SPECS INFO Cement to Surface 20" 0 Hole Angle ° X-65 00 20"Conductor Shoe 160' 160' Driven Welded N/A tl_Y GR/Res / Ni Surface Csg Dir/PWD -0 c 13-3/8" xo a 68# MW(ppg) Wellbore Stability Mud Motor B/Permafrost 1,850' 1,752' r- L-80,BTC 8.8-9.5 Lost Circulation w Hole Cleaning Al Casing Sections KOP:400' ° Casing Wear DIS: Surface T/Tat Cement 2,396' 2,181' 0-3.8°/100' Hole Angle III 66.40 Deg 133/8"Csg 2,901' 2,454' 16" 50°F WBM GR/Res ' Dir/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(ppg) Hole Cleaning L-80,Hydr1563 9.2-9.4 Torque&Drag Casing Sections Tangent Angle: Casing Wear 86.00 Deg BHA Expense Intermediate TOC 11,018' 3,085' Pick-up Top of Sand N M .0 a NTop 12,018' 3,318' 1Q ell m e Ili ls;c i o Hole Angle TOL 13,441' 3,493' MI 86.00 Deg 9 5/8"Csg 13,641' 3,507' 12.25" 85°F WBM GR/RES ' �p . Dir/Sonic ) ID Wellbore Stability N Lost Circulation ICD clotted liner Hole Cleaning m 4-1/2" Torque&Drag EEl 11.6# MW(ppg) Casing Sections Xceed 675 L-80,Hydrd 521 9.2-9.4 Casig Wear - ICD BHA Expense GE ICD SI Hole Angle 90.27 Deg TD 23,968' 3,445' 8-3/9" 85°F MOBM SI34-W6 Drilling Wellplan Page 2 of 40 01/15/15 / ....w enni FIs operating WELL SI34-W6 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 16 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 20 Intermediate Cementing 23 Pick Up Production Drilling Assembly 25 PRODUCTION SECTION 26 Production Drilling 28 Production Liner 29 ATTACHMENTS 33 Recommended Drilling Practices 34 Health, Safety & Environment 35 Safety Meeting Topics 36 Well Shut In Procedure While Running Production Tubing 38 Conductor Broach—Contingency Cementing Plan 39 TAM PORT COLLAR Utilization Decision Tree 40 SI34-W6 Drilling Wellplan Page 3 of 40 01/15/15 2no us operating WELL 5I34-W6 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Injector Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 4-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program & Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. 5I34-W6 Drilling Wellplan Page 4 of 40 01/15/15 us ®perahng WELL SI34-W6 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2. Land Intermediate casing point within 100' radius of the planned directional target. 3. Land the Intermediate hole section with the targeted inclination of 85°-87°above the OA sand. Maximum dogleg severity in the landing shall be no greater than 3.5°/100' DLS. 4. Target Greater than 90%within the OA sand Reservoir. 5. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD—Require GR/Res/Dir to achieve TD. S134-W6 Drilling Wellplan Page 5 of 40 01/15/15 191* 2no operrahng WELL SI34-W6 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (Pig) Type (Psi) (Psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. > Each conductor is to be marked with a common pad elevation survey mark by the surveyors > Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators,and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. > Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test > Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. > Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: D Assist in washing out surface casing hanger on cement jobs D Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). SI34-W6 Drilling Wellplan Page 6 of 40 01/15/15 • (en0 us operating WELL SI34-W6 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (6) Measured True Formation Tops Depth,ft Vertical Comments Depth,ft SV-4 760 760 SV-3 1133 1121 SV-2 1409 1372 B/Permafrost 1850 1752 SV-1 2048 1919 Ugnu Top(UG4) 2454 2219 13-3/8" Csg Shoe 2901 2454 SCP UG-2 Coal Bed Marker 5136 2669 Lower Ugnu 10853 3048 Schrader Bluff Top 11733 3252 N Sequence Top 11867 3283 N Top 12018 3318 N Bottom 12170 3351 Re Calc Intermediate Cement w/Actual N Sequence Base 12457 3404 OA Top 13609 3505 9-5/8" Csg Shoe 13641 3507 ICP OA-2 Top 15639 3519 OA-3 Top 15810 3521 Fault 14 19206 3549 Fault 3 21407 3461 TD 23968 3445 TD SI34-W6 Drilling Wellplan Page 7 of 40 01/15/15 en0 us opereing WELL SI34-W6 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point Density 6 RPM API Fluid Chlorides Interval Depth Loss PH (PPg) Reading (ml/30min) (mgA) 110'— 1800' 8.8-9.2 20—24 <8 <2000 9.0—9.5 Surface: 1800' —C.P. 9.2—9.5 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: Surface: MWD Directional LWD GR/Resistivity Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppf) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) . (ft.lbs) (gal/ft)_ 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 S-135 TT525 6.625 3.250 3.250 83,200 118,900 126,000 .43 990 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections 5I34-W6 Drilling Wellplan Page 8 of 40 01/15/15 en ussop rra1ing WELL SI34-W6 Surface Hole Procedure: 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: D. Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM ➢ Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. ➢ Consider adding 0.5%Drilzone for screen blinding in shallow intervals right below the conductor. 5. Surface casing point: ➢ Landed in good shale found in this area at 2454' TVD ➢ Below the sand at the base of the Sagavanirktok Formation(SV-1). ➢ Inside the upper Ugnu(UG-4). ➢ Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: ➢ Circulate until shakers are clean(+/-3 to 5 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 800 GPM or higher • 80 RPM or higher ➢ Backream to the HWDP • 800 GPM or higher • 80 RPM or higher • Pull 5-10 feet per minute • Decrease backreaming speed as torque and pump pressure dictate. SI34-W6 Drilling Wellplan Page 9 of 40 01/15/15 If* 2rnn° us operrafing WELL S134-W6 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from OP09-S1:While backreaming out of the hole in the transition from horizontal to vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate > Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casine. 5134-W6 Drilling Wellplan Page 10 of 40 01/15/15 us operreing WELL SI34-W6 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PPO Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque(ft.lbs) OD WT Opt' (in) (pp}) Grade Conn.Type Make Up Torque 13-3/8 68 I-80 BTC Triangle Surface Casing Casing Runnine Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: D. obtain SO Weights every 10 joints D obtain PU Weights every 10 joints 5I34-W6 Drilling Wellplan Page 11 of 40 01/15/15 ft* 2rnnn us operrafing WELL SI34-W6 4. Run the surface casing as follows: Surface Casing Running Order I Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing to hanger 7 Vetco Gray 13-3/8"mandrel hanger 13-3/8"landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +/- 16 13-3/8"Tandem Rise Weatherford SI34-W6 Drilling Wellplan Page 12 of 40 01/15/15 t 2rn10 us rperaLt n WELL SI34-W6 Surface Centralizer Placement IMC 10' 41111111 . 13-3/8"x 16"Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of 1°joint. • 1 at 10'above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry),1 centralizer per joint run on collars. Do not allow centralizer to float beMeen collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. SI34-W6 Drilling Wellplan Page 13 of 40 01/15/15 ritis en o us oper frog WELL SI34-W6 Surface Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry 146 bbl Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) Yield 2.77 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) 63 bbls 3 Top of Tail @ 2,395'MD field 1.57 ft/sk Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. ➢ To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. ➢ If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool ➢ If necessary,rack TAM running tool in derrick and ready to run D. Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. ➢ Run 4"lines x-over from 3"side outlets to a vacuum truck. ■ Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than 1/2 the shoe joint volume). SI34-W6 Drilling Wellplan Page 14 of 40 01/15/15 fff* 2rn0 us operrahng WELL SI34-W6 ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ■ The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. ■ PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC • SI34-W6 Drilling Wellplan Page 15 of 40 01/15/15 e n us operreing WELL SI34-W6 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: ➢ 12-1/4"bit • Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM ➢ 120-140 RPM ➢ See BHA attachment for running order and specifications 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. ➢ Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. ➢ Note:All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. ➢ See Float Equipment and Pities PDC Bit Drillout Recommendations Attachment 4. Drill 20'-50'of new hole using spud mud. 5. Displace hole to new LSND mud system. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. SI34-W6 Drilling Wellplan Page 16 of 40 01/15/15 • eno• us operating WELL SI34-W6 INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (6) True Formation Tops Measured Vertical Comments Depth,ft Depth,ft SV-4 760 760 SV-3 1133 1121 SV-2 1409 1372 B/Permafrost 1850 1752 SV-1 2048 1919 Ugnu Top(UG4) 2454 2219 13-3/8" Csg Shoe 2901 2454 SCP UG-2 Coal Bed Marker 5136 2669 Lower Ugnu 10853 3048 Schrader Bluff Top 11733 3252 N Sequence Top 11867 3283 N Top 12018 3318 N Bottom 12170 3351 ReCalc Intermediate Cement w/Actual N Sequence Base 12457 3404 OA Top 13609 3505 9-5/8" Csg Shoe 13641 3507 ICP OA-2 Top 15639 3519 OA-3 Top 15810 3521 Fault 14 19206 3549 Fault 3 21407 3461 TD 23968 3445 TD SI34-W6 Drilling Wellplan Page 17 of 40 01/15/15 ern° us operating WELL SI34-W6 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the "N" sand Interval Density PV 6 RPM API FL pH Drill Solids MBT (ppg) Reading (ml/30min) (%) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Tool Make Up Joint Body DP Tensile WT Conn. Joint Body Torsion Torsional capacity Pipe (Pp. Grade Type OD Joint ID(in) Torque al Yield Yield w/conn. Capacity (in) ID(in) (Albs) (ft lbs) (Albs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 S-135 TT525 6.625 3.250 3.250 83,200 118,900 126,000 .43 990 Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300'TVD from the top of the uppermost OA sand and at least 200'MD in length. b. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment will be damaged running through high dog legs(>6 degrees per hundred). c. Shallow test MWD tools. d. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. g. Swab/Surge: Make"easy on,easy off'slips a standard practice h. Control the ROP if necessary to maintain good hole cleaning i. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. S134-W6 Drilling Wellplan Page 18 of 40 01/15/15 6 � 2rno us operating WELL SI34-W6 Intermediate Drilling 1. Directionally Drill 12-1/4"hole ➢ Use the following Parameters: • Flow rate of 900 GPM • 120—140 RPM 2. Casing Point:Land Intermediate casing at 13,641'MD 3. LOW ROP:Consult with Town as ROP drops to< 1-2 ft/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: D. Circulate until shakers are clean(+/-5 to 7 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM ➢ Backream into the surface casing shoe. • 900 GPM • 120 RPM • Slow backreaming speed when pulling into the surface casing shoe/rathole. Hold parameters steady at 900 GPM and 120 RPM. Large chunks of coal can be deposited in the 16"rathole near the shoe. • Lesson Learned from OP09-S1:While backreaming out of the hole in the transition from horizontal to vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. Check drilling nipple for overflow at BOP's. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the surface casing shoe. Do not attempt to pull out on elevators once backreaming has started. D Circulate until shakers are clean(+/-3 to 7 bottoms up per K&M model)in the surface casing shoe • 900 GPM • 120 RPM 5. Pull and lay down BHA. SI34-W6 Drilling Wellplan Page 19 of 40 01/15/15 1 en� us operraCDrnns WELL SI34-W6 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppb) Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque(ft.lbs) Min. Target Max. (in) (ppf) Grade Conn.Type Tore,U - Make Up Make Up Yield Torque lbs Torque Torque 9-5/8 40 L-80 Hydril 10,800 13,000 N/A 75.000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go ➢ Shoe joint misalignment has caused cross threading with Hydril 563 connection and requires make up by hand for first 10-15 joints • Make-up Shoe track(and first 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cross threading • The shoe track joints should be Bakerlocked. • Inspect the float valves as the shoe track is picked up. • Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Connection Make Up: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. ➢ Draw a longitudinal line across the pin and box and reapply the published target torque. ➢ If the drawn line does not move more than 1/2"after the second torque application,continue running the rest of the string normally using the published target torque. ➢ If the drawn line moves more than'h"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than 1/2",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than 1/2",recheck the alignment,dope application and tong function, then continue to repeat this procedure from above until the drawn line does not move more than 1/2". SI34-W6 Drilling Wellplan Page 20 of 40 01/15/15 rnlo us operefing WELL S134-W6 ■ It is best practice to repeat this procedure in the event the tongs are changed out during the running of the pipe. 3. Ensure that the joint about to be made up is hanging along the same axis as the joint in the slips. Due to the fact that sometimes the rig is a few inches off center the slips and bell nipple may have to be adjusted. Casing Running Order Float shoe—Davis-Lynch Model 501-DV-PVTS 1 down jet float shoe(double valve)**** Baker Lock 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger 7 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-78 9-5/8"x 11-3/4"Rigid Hydroforms(Crimped) Volant 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ K&M Engineer will provide a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. ➢ Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000'MD and check flow through floats. Circulate bottoms up each time. D. Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights every 10 joints 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 8. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. • SI34-W6 Drilling Wellplan Page 21 of 40 01/15/15 It* . 2rnlo us operating WELL SI34-W6 Intermediate Centralizer Placement 1 1I T 10' Float 9-5/8" x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. • No centralizer on next joint • On Stop collar 10'above Float Collar. • From 4th joint to+/-1000'above the shoe- 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+/-500'above N sand oil bearing zone ) P CI r 5' SI34-W6 Drilling Wellplan Page 22 of 40 01/15/15 2rn1� us op rrahrnng WELL S134-W6 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Intermediate 9.5/8" Mudpush H 100 bbls Density 10.5 ppg DeepCretc 225 bbls Density 12.5 ppg Top of Cement @ 11,018'MD Yield 1.56 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than' the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! ➢ Cement volume is based on 50%excess and at least 1000'of annular fill above top of the N sand(highest known hydrocarbon bearing zone). Refer to attached cement detail sheet for volumes. 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps and LSND water-based drilling mud. > Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. ➢ Pump cement at 5 bpm and displace with 8.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger ➢ Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. ➢ Do not exceed 80%of intermediate casing collapse ➢ Record test on IADC report and in WellView SI34-W6 Drilling Wellplan Page 23 of 40 01/15/15 en o us operreo nng WELL SI34-W6 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. • Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM ▪ Pits must be clean and free of all Barite SI34-W6 Drilling Wellplan Page 24 of 40 01/15/15 cf* 'mil us operating WELL SI34-W6 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the attached BHA diagram. > 8-3/4"PDC > Rotary Steerable ➢ Flow rate: 550 GPM ➢ 120—140 RPM 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pressure Test on the Pressure LOT form in N drive Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits ➢ Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. ➢ See Float Equipment and Plu2s PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50'of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. > PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. > Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form in N drive SI34-W6 Drilling Wellplan Page 25 of 40 01/15/15 eno us operating WELL SI34-W6 PRODUCTION SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (6) True Formation Tops Measured Vertical Comments Depth,ft Depth,ft SV-4 760 760 SV-3 1133 1121 SV-2 1409 1372 B/Permafrost 1850 1752 SV-1 2048 1919 Ugnu Top(UG4) 2454 2219 13-3/8" Csg Shoe 2901 2454 SCP UG-2 Coal Bed Marker 5136 2669 Lower Ugnu 10853 3048 Schrader Bluff Top 11733 3252 N Sequence Top 11867 3283 N Top 12018 3318 N Bottom 12170 3351 ReCalc Intermediate Cement w/Actual N Sequence Base 12457 3404 OA Top 13609 3505 9-5/8" Csg Shoe 13641 3507 ICP OA-2 Top 15639 3519 OA-3 Top 15810 3521 Fault 14 19206 3549 Fault 3 21407 3461 TD 23968 3445 TD SI34-W6 Drilling Wellplan Page 26 of 40 01/15/15 ft* 2rnlo us operrafi nng WELL SI34-W6 Production Mud Program: FazePro Density HTHP FL Electrical Interval ,. . YP (mU30min) Oil:water Stability mlVolts Production 9.2 14-20 <5.0 60:40 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/SonicVision ✓ Production Drill Pipe Tool Joint Body DP WT Conn. Joint Tool Body Make Up Torsion Torsional capacity Tensile Pipe (PRI) Grade type OD Joint ID(in) Torque al Yield Yield w/conn. Capacity (in) ID(in) (Albs) (ft lbs) (Albs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Onenhole Sidetracking Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt.and consider tripping without circulating or without rotating past the sidetrack point. SI34-W6 Drilling Wellplan Page 27 of 40 01/15/15 e pis °Reveling WELL SI34-W6 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ Geosteering will be required to remain in the target boundary 100%of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. ➢ Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM ➢ Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE:2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreamine until depth at which it is possible to null out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. 5. Circulate until shakers are clean as per K&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. ➢ Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA ➢ When out of hole,down load the recorded tool data and send to the Geologist in town SI34-W6 Drilling Wellplan Page 28 of 40 01/15/15 WELL SI34-W6 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD Conn. Cplg OD Collapse Burst Tensile Yield (in) WT(ppf) Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 4-1/2 11.6 L-80 H5211 4.695 4.000 3.875 6360 7780 171 Production Liner Connection Make Up Torque (ft-lbs) Min. OD WT Make Up Target Max. Yield (in) (ppf) Grade Conn. Type Torque, ft- Make Up Make Up Torque lbs Torque' Torque 4-1/2 11.6 L-80 Hydril 521 3600 6300 N/A 16,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 4-1/2"x 7" top -Mid-joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover and FOSV is on the rig floor in case of a well control situation. • The liner will be run in FazeAway Delayed Breaker. Consult with completions engineer for liner detail. Liner string will be adjusted according to actual depths after drilling. Consult with completion engineer and ops geologist to determine exact placement and number of swell packers prior to installation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. • DO NOT run E-CD subs on drill pipe while running liner string. • Torque ratings for string components: SI34-W6 Drilling Wellplan Page 29 of 40 01/15/15 fiff* 2nus operating WELL SI34-W6 String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7"29#Hydril 563 39,000 4-1/2" 15.5#Hydril 521 16,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 4650 mch rel,3 pins 15%- 2713 psi Pusher Tool Activation Nominal - 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal - 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID *****Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with."pal mix"and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO,and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt.immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. SI34-W6 Drilling Wellplan Page 30 of 40 01/15/15 11041 2nd us operrahng WELL SI34-W6 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test,rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, 6,795 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0 ppg KC1 brine per MI recommended program. • 19. POOH and LD and inspect the liner running tools. Run 41/2 Injetor Completion String 1. Hold pre job safety meeting prior to start of any operations including review of applicable notes listed above. 2. Pick up seal-stem no-go entry guide assembly and two full joints. 3. RIH 4' Hydril 563 tubing joints until reaching Mirage Plug. 4. Make up Mirage Plug,Autofill valve,3.725 XN nipple,PHL Packer and 3.81 X nipple assemblies per HAL representative. 5. Continue RIH with 4-1/2"tubing. 6. Continue RIH until reaching GLM. Make up KBMG gas lift mandrel with DCK-2 annulus-to-tubing shear valve set for approximately 2,000 psi. 7. Continue RIH until the second 3.813"X nipple is reached.This second nipple should be placed at approximately 2200 feet MD. 8. Space out the landing of the seal stem entry guide and no-go sub in the liner tieback sleeve. Pick up additional joints of 4-1/2"tubing and land out no-go sub to obtain proper tubing hanger space out measurements. 9. Install correct pup joints to allow the tubing hanger to land properly while the seal stem is fully engaged in the liner tieback sleeve. Ensure entry guide will be engaged when tubing hanger is set. 10. Look at indicators to be sure the seal stem entry guide enters in the liner tieback sleeve. 11. Make up tubing hanger,pup joint and crossover. The upper most connection may be torque adjusted to allow for proper alignment of tubing hanger if necessary. 12. Drain and rinse BOP stack before landing tubing string and pick up landing joint. 13. Check hanger seal areas and grease hanger per Vetcogray recommendations. Ensure hanger is centered and land same. Run in Lock down screws. 14. Test upper and lower seals to 5,000 psi and hold for ten minutes. 15. Rig up pump to set packer. Test surface lines to 5,000 psi and then bleed pressure to zero. 16. Pressure down tubing string to 1200 psi to close Autofill Valve and monitor for leaks. SI34-W6 Drilling Wellplan Page 31 of 40 01/15/15 ff* 2rn1n us cooperrahns WELL SI34-W6 17. Increase pressure down tubing to 3,500 psi to set packer and hold for 30 minutes. Record on chart as tubing integrity test. Ensure inner annulus is open and monitor for returns. 18. Reduce tubing pressure to 2,000 psi. Rig up and pressure inner annulus to 2,500 and hold for 30 minutes. Record annulus pressure on chart as inner annulus integrity test. Bleed annulus pressure to zero. 19. Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 20. Pressure inner annulus to 2,500 to shear valve in GLM. If valve does not open,cycle annular pressure from 0 to 2,500 psi several times while allowing tubing to bleed pressure. 21. Pull landing joint and set BPV. 22. Nipple down stack and nipple up tree. Test void to 5,000 psi for ten minutes. 23. Pull BPV and set TWCV. 24. Fill tree with diesel and function valves. Test tree using rig test pump and chart to 500 psi for 5 minutes and then 5,000 psi for 15 minutes. 25. Pull TWCV. 26. Rig up flow manifold to tree. Circulate diesel through GLM to fill annulus and tubing volume from GLM depth to surface. Diesel volume should be approximately 160 bbls. Allow annulus and tubing pressures to equalize. 27. Set BPV and secure tree and wellhead. 28. RDMO. SI34-W6 Drilling Wellplan Page 32 of 40 01/15/15 1W* 2no us operratt ng WELL S134-W6 29. ATTACHMENTS 30. Recommended Drilling Practices 31. Health,Safety,and Environment 32. Safety Meeting Topics 33. Well Shut In Procedure While Running Tubing 34. Conductor Broaching Contingency Plan 35. Port Collar Decision Tree SI34-W6 Drilling Wellplan Page 33 of 40 01/15/15 2rn10 us operrenng WELL SI34-W6 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable RPM c) As the hole angle increases,hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip/ Connection Speeds High POOH and RIH speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. 5I34-W6 Drilling Wellplan Page 34 of 40 01/15/15 Pt* n 11 us operating WELL S134-W6 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H25 contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SI34-W6 Drilling Wellplan Page 35 of 40 01/15/15 2n o L operrafing WELL 5I34-W6 Safety Meeting Topics Move In, Rig Up ➢ Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. ➢ A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. • Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. D Perform and document all drills. D Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. D A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. D Potential formation pressures and mud weight,Well control procedures. D Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. D Stuck pipe,Lost circulation. SI34-W6 Drilling Wellplan Page 36 of 40 01/15/15 rn 11 us operahng WELL SI34-W6 • Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion ➢ Operation of the control line spooler. ➢ Pinch points associated with tongs and slips. ➢ Proper tripping practices and hole fill calculations with tubing and control line. ➢ Well control practices while running production tubing with control line. ➢ Pressure testing and minimizing personnel exposure to pressurized lines. • SI34-W6 Drilling Wellplan Page 37 of 40 01/15/15 vois en 0 operratong WELL SI34-W6 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install TIW and close annular around pipe and control line. 2. Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open 11W valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. SI34-W6 Drilling Wellplan Page 38 of 40 01/15/15 W 2no us operating, WELL SI34-W6 Conductor Broach - Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120'MD DP/Conductor Annular Volume 5"DP x 18.25"ID: (36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has occurred,POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20'below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. RIH to 200'below the base of the conductor. If mud viscosity is<300sec/qt.,spot a 150'pill of 150K cp polymer (Biozan)to 50'below the conductor. POOH to 20' inside the conductor. 6. Mix and displace+/-80 bbls of Artic Set 1 cement at 15.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace DP. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 16"bit and BHA and RIH to clean out cement to 40'below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. SI34-W6 Drilling Wellplan Page 39 of 40 01/15/15 • 2n0 us operating WELL SI34-W6 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job Nn rnmpnt Cement t Surface i i Drilling Foremen end fipple Up and Engineer determine the est BOP's Top of Cement 7 ♦ _ Top of Top of Cement Cement Continue with above Port / low Port Completion Collar / Collar / (1000'TVD) (1000'TVD) Indicators of Cement Top Perform Top Job as per 10. Open Port Collar 1. Observation of Tracers in Spacer ahead of lead cement requirements of If Top Job is ineffective or using drillpipe p AOGCC unacceptable to AOGCC 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface • 7 Nipple Up and Circulate Cement Test BOP's to Surface and close Port Collar Continue with Nipple Up and Completion Test GOP's Continue with j Completion SI34-W6 Drilling Wellplan Page 40 of 40 01/15/15 Attachment 2 Directional Plan 4#1941ki lthlumberger en SI34-W6(P6)Proposal Geodetic Report (Det Plan) Report Date: June 00,2014-1149 AM Survey/OLS Computation: Minimum Curvature/Lubinekl Client: En'Petroleum Vertical Section Azimuth: 300000•(True North) Field: Nikellchug �a`al{����.f�r177 Vertical Section Origin: 0.00011,000011 Well:Struc Spy Slat: S34-W6d/SP34 �� '/1��\•/�G.SLJ"W IVO Reference Elevetbn: 54.1008ePo.MSL Borehole: S134-W6 F®` ODUB�di G Ground Elevetlon: 13.1008 above MSL Apel: 506290w060 V^��� Magnetic DeclInetion: 18.977• Survey Name: S134-W6(P6) Total Gravity Field Strength: 10019929ngn(9.80665 BMW) Survey Date: June 052014 Greviy Model: GARM Tort/AHD/DDI/ERD Ratio: 302 749•122181.270 517.657/6 251 Total Magnetic Field Strength: 57815.916 nT Coordinate Reference System: NAD27 Alaska State Plane,Zone 04.US Feet Magnetic Dip Angle: 81.058° Location Let l Long: N 70.3 27.6530r,W 149.54'22.80959' Declination DM,: Deoenber31,2014 Location Grid WE SIX: N 8003610.3308US,E 511422.51308US Megretic Decllreton Model: BGOM 2013 CRS Grid Convergence Angie: 0.0884• North Reference: Tme North Grid Scale Factor: 0.99890015 Grid Convergence Used: 00000• Version I Patch: 2.7.1043.0 Total Corr Meg North-.True North: 169767• Local Coord Referenced To: Wel Head Exclusion tons Comments MD Incl 121m Trus NDSB NO VSEC NS EW TF OLS Directional Exclusion gene Anglo Seating(809) Northing (n) (') (1 P9 Of) (tU Pll (n) (1 ('/,eon) DHIIeuBy Intl.= Mstl 11 (BUS) (nus) RTE 0.00 0.00 170.00 54.10 000 000 0.00 0.00 170M N/A 000 894 511426.58 6053610.33 10000 000 170.00 4590 100.00 000 0.00 0.00 1709 0.00 000 894 511426.58 8053610.33 20000 000 170.00 14590 20000 0.00 0.00 000 1709 0.00 000 894 51142658 8053610.33 300.00 0.00 170.00 24590 300.00 000 0.00 000 1709 0.00 000 8.94 511426.58 605361033 KOP Cm 1.51'00 400.00 0.00 170.00 345.90 400.00 0.00 0.00 000 1709 0.00 0.00 8.94 51142658 605361033 500.00 1.50 170.00 44589 499.99 -0.81 -129 0.23 1709 1.50 029 10.28 51142681 6053609.04 Cry 3.5/100 60000 3.00 17000 54581 599.91 3.36 -5.18 0.91 205,449 1.50 120 11.66 511427.50 605380518 70000 5.48 205.44 64554 899.60 -543 -12.05 089 217,02M 3.50 1.91 14.40 51142591 605359828 600.00 8.70 217.02 74077 798.87 -4.88 -22.40 -7.29 18.91R 3.50 239 17.42 511419.32 605358792 90000 12.07 222.28 843.12 89722 -174 -36.18 18.88 13.13R 3.50 2.76 20.58 51140776 605357413 100000 1580 225.26 94023 994.33 4.00 -53.32 -3541 10248 3.50 3.06 23.84 511391.26 6053556.98 1100.00 1895 227.17 1035.73 1089.83 12.32 -73.77 -5881 9410 3.50 3.30 27.15 511369.89 605353648 120000 22.42 226.51 112927 118337 23.17 -97.45 -8301 7.158 3.50 3.51 30.50 511343.73 6053512 77 1300,00 2589 229.51 1220.50 127480 36.52 -124.28 -113.91 6,240 3.50 3.68 33.88 511312.87 605348590 Civ 3.5/100 1380,48 2800 230.00 127441 1328.51 45.79 -141.97 -134.83 HS 3.50 3.78 3593 511291.98 6053486.17 Crv0.5/100 1389.80 2902 230.00 130000 1354.10 5054 -150.90 -14548 HB 3.50 3.83 36.94 511281.35 6053459.22 1400.00 2907 23000 1309.09 1363.19 52.27 -15415 -14925 96 0.50 384 37.00 51127748 605345597 150000 2957 23000 139628 1050.38 6901 -185.62 188.86 96 0.50 394 37.49 511240.02 605342444 1800.00 3007 230.00 1483.04 1537.14 8602 -217.59 -22496 HS 0.50 4.02 37.99 511201.98 605339242 170000 3057 230.00 158936 182346 103.29 250.04 -283.63 HS 0.50 409 38.48 511103.30 6053358.91 • 1800.00 3107 23000 1655.23 170933 12081 282.97 302.88 H6 0.50 4.16 38.98 51112917 6053326.92 1900.00 3187 23000 174066 179476 13839 -316.39 34270 HS 0.50 422 39.48 51108440 6053293.44 Cm 3.75/100 1989.78 31.92 230.00 180000 1854.10 151.15 -33999 37083 12.13R 0.50 426 3982 511056.32 8053269.80 2000.00 3303 23044 182550 187880 156.76 -35037 363.30 11.768 3.75 4.29 4089 511043.86 605325940 2100.00 36.71 231.71 190753 1961.63 17734 386.26 -427.78 10.710 3.75 4.38 4445 510999.44 6053223.45 220000 40.40 232.79 1985.72 203982 200.96 -424.39 -477.06 9.870 3.75 447 4804 510950.22 6053185.25 2300.00 4410 233.71 205273 2113.83 22751 -464.59 -530.93 9.188 375 4.55 51.84 510898.42 6053144.97 2400.00 4780 234.52 212925 218335 256.08 -506.69 -589.16 8828 3.75 1.63 55.26 51083826 8053102.78 2500.00 5151 235-24 219398 2248.08 288.95 -550-52 -85150 8188 3.75 4.71 58.69 510776.00 605305886 2800.00 5522 23508 225364 230774 323.58 -595.69 717.7 7776 375 4.78 82.53 510709.90 805301340 2700.00 56.94 236.48 230797 236207 36062 84260 -78741 7458 3.75 4.85 86.17 510640.24 8052966.59 2800.00 6266 23702 235675 241085 39991 890.44 860.40 7.1861 3.75 492 6982 510567.33 6052918.63 2900.00 6638 237.53 2399.76 2453.86 44128 -739.23 -938.34 6986 375 4.99 7308 510491.48 6052869.73 13357Ce2 2900.60 06.40 237.54 2400.00 2454.10 441.53 -739.52 -838.80 8.960 3.75 4.99 73.50 510491.02 6052869.44 3000.00 70.11 23002 2436.82 2490.92 484.56 -768.74 -1014.90 6,788 3.75 5.05 77.14 510413.00 805282011 3100.00 73.83 238.48 2467.77 2521.87 529.56 -838.77 -1095.74 6648 375 511 8080 510332.24 8052769.96 3200.00 77.55 238.92 249248 254658 576.09 88909 1178.53 6530 3.75 5.17 84,16 510249.55 6052719.51 330000 81.28 239.35 2510.84 256494 62394 -93951 -126289 8.450 3.75 523 88.13 51018527 8052668.97 ' 345000 0501 239.78 252278 2576.88 67292 -989.79 1348.48 648 3.75 529 8821 510079.76 605261856 End CM 345347 87.00 24000 252650 258060 699.50 101655 139462 HS 3.75 532 8825 510033.87 8052591.73 • 3500.00 87.00 240.00 2528.94 2583.04 72273 1039.78 .143486 HS 0.00 533 8825 50099347 805256844 3600.00 87.00 240.00 2534.17 258827 772.67 1089.72 -1521.35 HS 0.00 5.37 86.25 509907.07 6052518.38 3700.00 87.00 240.00 253941 2593.51 822.80 1139.65 180703 HS 0.00 540 88.25 50982067 6052468.32 380000 67.00 24000 2544.84 2598.74 872.53 1189.58 -1694.31 HS 0.00 5.43 8625 50973428 605241826 390000 87.00 240.00 254987 2603.97 922.48 123951 178080 HS 0.00 5.48 8625 50964788 8052388.20 4000.00 87.00 240.00 2555.11 260921 972.39 128944 186728 HS 0.00 5.49 86.25 509561.48 805231814 4100.00 8700 240.00 256034 2614.44 102232 1339.37 1953.77 HS 000 5.52 8625 50947508 6052268.08 4200.00 87.00 2 000 258557 2619.67 107228 1389.30 -204025 NS 000 585 8625 50938868 605221802 4300.00 8700 24000 2570.81 2624.91 112219 1439.24 -2126.73 NS 000 558 8625 50930229 805216796 440000 8700 240.00 257604 2830.14 1172.12 1489.17 221322 HS 000 5.60 8825 509215.89 805211790 4500.00 8700 240.00 258127 263537 122205 1539.10 -2298.70 HS 0.00 5.83 8625 509129.49 605206784 4600.00 8700 240.00 258831 2840.61 1271.98 1589.03 2386.18 HS 0.00 5.65 8625 50904309 605201778 4700.00 8700 240.00 2591.74 284584 1321.91 1836.96 .247287 HS 0.00 587 8625 50895669 8051967.72 4800.00 87.00 24000 2596.97 2651.07 1371.84 1688.89 2559.15 HS 0.00 5.70 8625 50887030 6051917.66 4000.00 8700 240.00 280221 285831 1421.76 1738.82 -2845.64 HS 0.00 5.72 8625 50878390 805186760 5000.00 8700 240.00 280744 268154 1471.71 1788.76 -2732.12 HS 0.00 5.74 8625 50869750 805181754 5100.00 8700 240.00 2612.88 2666.78 1521.84 183069 .2818.60 HS 0.00 576 0625 508611 10 605177.48 11 520000 8700 240.00 261791 267201 1571.57 1880.62 -2005.08 HS 0.00 5.78 8625 508524.70 6051717.43 5300.00 8700 240.00 2623.14 287724 162150 1938.55 -209157 HS 0.00 5.80 8825 50843831 60516737 540000 8700 240.00 282038 2682.48 1671.43 1988.48 -307806 96 0.00 5.82 8625 508351.91 805161731 5500.00 8700 240.00 2833.81 2887.71 172136 2038.41 -316454 HS 0.00 5.84 80.25 508265.51 605156725 5800.00 87.00 240.00 2638.84 2892.94 1771.30 2088.35 3251.02 HS 0.00 506 8825 508179.11 6051517.18 5700.00 8700 240.00 2644.08 2898.18 182123 2136.28 333751 HS 0.00 5.87 8625 508092.71 605146713 5800.00 8700 240.00 264931 270341 1871.18 2186.21 3423.99 HS 0.00 539 8825 508006.32 6051417.07 5900.00 87.00 240.00 2654.54 2708.84 1921.09 2238.14 351047 HS 0.00 5.91 8625 50791992 605137.01 6000.00 87.00 24000 2659.78 271388 1971.02 228007 3596.96 HS 0.00 5.93 88.25 507833.52 8051316.95 010000 8700 240.00 266501 271911 202095 2336.00 -368344 HS 0.00 594 8825 50774712 805126689 620000 8700 240.00 2670.25 272435 2070.88 2387.93 376993 HS 000 5.98 8825 507660.73 605121683 6300.00 8700 240.00 2675.48 272958 2120.82 243707 -385641 HS 0.00 527 8625 507574.33 605116677 8400.00 87.00 240.00 2680.71 273401 217075 2487.80 394289 96 0.00 5.99 8825 507487.93 805111671 6500.00 87.00 240.00 2685.95 2740.05 222068 2537.73 4029.38 86 0.00 6.00 8625 507401.53 605106665 6800.00 87.00 240.00 2891.18 274528 2270.61 258766 .411586 66 0.00 602 8625 507315.13 605101859 700.00 8700 240.00 2898.41 2750.51 2320.54 2637.59 -4202.35 HS 0.00 603 8625 507228.74 6050966.53 6800.00 8700 240.00 2701.65 2755.75 237047 2687.52 -4288.83 HS 0.00 6.05 8825 507142.34 6050916.47 6900.00 87.00 241.00 2706.88 2760.98 242041 273745 .437531 HS 0.00 606 88.25 507055.94 605086641 7000.00 8700 24000 271211 2788.21 247034 2787.39 .446190 NS 0.00 608 86.25 50696954 605081625 7100.00 8700 240.00 271735 277145 2520.27 2837.32 454828 HS 0.00 6.09 8825 506883.14 805076629 7200.00 87.00 240.00 2722.58 2776.88 257020 2667.25 -463476 HS 0.00 610 8625 506796.75 805071623 7300.00 8700 240.00 2727.81 2781.91 2620.13 2937.18 -472125 HS 0.00 6.12 8825 50671035 6050666.17 7400.00 8700 240.00 273305 2787.15 2670.06 2987.11 -480773 HS 0.00 6.13 8625 506823.95 6050616.11 7500.00 87.00 240.00 2738.28 279238 271999 3037.04 489422 HS 0.00 614 8825 506537.55 805056605 7600.00 8700 240.00 2743.52 279782 2769.93 3086.97 -498070 HS 0.00 6.15 8625 506451.15 605051599 • 7700.00 87.00 240.00 2748.75 280285 281986 3136.91 -506718 HS 0.00 6.17 8821 506364.76 8050465.93 7800.00 87.00 240.00 2753.98 280808 286979 3186.84 515387 HS 0.00 6.18 88.24 506278.36 805041587 7900.00 8700 240.00 275922 281332 291972 3236.77 .5240.15 HS 0.00 6.19 88.24 506191.96 6050365.81 8000.00 87.00 240.00 278445 281955 296965 3286.70 .532664 HS 0.00 6.20 86.24 506105.56 6050315.75 8100.00 87.00 24000 278988 2823.78 301958 3336.63 -5413.12 H6 0.00 621 88.20 506019.16 605026569 0200.00 8700 240.00 277492 282902 306921 3386.58 -549980 HS 0.00 622 8624 505932.77 6050215 23 8300.00 8700 240.00 278015 283425 311945 3436.49 -5588.09 HS 0.00 623 8624 505848.37 605016557 8400.00 87.00 24000 278538 2839.48 316938 3486.43 567257 HS 0.00 625 8824 50575997 605011551 8500.00 87.00 24000 279082 2844.72 .3219.31 353838 -5759.05 HS 0.00 626 8824 505873.57 6050065.45 8600.00 8700 240.00 2795.85 284295 326924 358629 581554 HS 0.00 627 8624 505587.17 605001539 8700.00 87.00 24000 2801.08 2855.18 331917 363622 5932.02 HS 000 628 8824 505500.78 604996533 8800.00 87.00 20000 2808.32 286042 3369.10 3686.15 -6018.51 HS 0.00 629 8624 505414.38 804991528 8900.00 87.00 240.00 2811.55 288565 3419.03 3736.08 810499 HS 000 8.30 6624 50532798 604986522 9000.00 87.00 24000 2816.79 287089 3468.97 3786.02 819147 HS 0.00 631 8624 505241.58 6049815.16 9100.00 67.00 24000 2822.02 287612 3518.90 3835.95 827798 HS 0.00 632 8624 505155.19 6049785.10 8200.00 87.00 240.00 282725 288135 3588.83 388588 836444 HS 0.00 633 8624 505088.79 804971504 9300.00 6700 24000 283249 288859 361876 3935.81 8450.93 HS 0.00 6.34 8624 504982.39 604966498 9400.00 8700 240.00 283772 289132 3668.89 3985.74 253741 HS 0.00 6.35 8624 50489599 604981492 950000 87.00 240.00 2842.95 2897.05 371882 403587 4623.89 HS 0.00 636 8624 50480959 604956486 8800.00 87.00 240.00 2848.19 2902.28 376856 408560 4710.38 110 0.00 637 8624 50472320 604951480 9700.00 7.00 240.00 285342 2907.52 381849 4135.54 879886 HS 0.00 8.38 6624 504836.80 604546474 9800.00 87.00 240-00 2858.65 2912.75 386842 418547 -6883.34 HS 0.00 638 8824 504550.40 604941468 9900.00 87.00 240.00 286389 2917.99 3918.35 4235.40 896983 HS 0.00 639 8624 504464.00 604936462 1000000 87.00 240.00 2869.12 292322 3968.28 4285.33 705631 HS 0.00 6.40 8624 50437760 8049314.56 Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SP34-W7\SP34-W7\SP34-W7(P4) 1/15/20154:42 PM Page 1 of 3 MO Ind helm Trim T11058 TVD VSEC NS EW IF DLB Olr.Otloml Exclusion 7°n°.lon Zorn Emoting Northing Comm.m. (N) () (tel (9) (9) (N) (N) (N) (1 (710094) Om10Mty Index 4190 Angle (IN8) (US) 19 0100.00 87.00 240.00 2874.36 2928.46 4018.21 -433528 -7142.80 HS 0.00 641 86.24 504291.21 6019264.50 Gni 2/100 015347 87.00 240.00 2877.15 2931.25 4044.91 4381.96 -7189.04 178649 0.00 6.42 8624 504245.01 604923773 0200.00 8607 240.02 287997 2934.07 4068.14 4385.17 722927 178648 2.00 6.42 87.17 504204.82 6049214.46 0300.00 84.07 240.07 288856 2942.66 4118.02 443482 -7315.58 178646 2.00 8.44 89.16 50411859 604916459 0400.00 82.07 24012 2900.62 2950.72 4167.79 4484.41 7401.63 178.636 2.00 8.46 8884 50403283 604911497 0500.00 80.07 240.17 2916.14 297024 4217.40 4533.59 7487.30 178.639 2.00 647 8685 50394704 6049065.66 0800.00 78.07 24022 293510 298920 426677 -458240 7572.49 178629 2.00 6.49 84.85 503861.94 8049016.73 End Cry 0673.54 76.60 240.25 295122 300532 430290 -4618.02 7634.77 HS 2.00 650 83.39 50379972 8048981.01 070000 76.60 240.25 295735 301145 431587 4630.79 -7657.12 HS 0.00 6.50 8339 50377739 604896821 0800.00 76.80 240.25 298052 303482 436488 4679.08 -7741.58 HS 0.00 6.51 8339 50389301 604891981 090000 7660 240.25 300310 3057.80 441388 -4727.33 -7826.04 HS 0.00 6.51 8339 50360884 604887142 1000.00 7660 240.25 302687 3080.97 446389 4775.60 -7910.50 HS 0.00 052 83.39 503524.26 6048823.03 1100.00 7680 210.25 305004 3104.14 451190 -4823.88 -799495 HS 0.00 652 8339 503439.89 6048774.63 1200.00 7660 240.25 307321 312731 4560.91 -4872.13 -807941 HS 0.00 653 83.39 503355.51 6048726.24 1300.00 7660 240.25 3096.39 315049 460992 -492040 -816387 110 0.0D 6.53 8339 50327114 6048677.84 1400.00 7660 240.25 3119.56 317386 465893 -4968.67 8248.33 HS 0.00 6.54 8039 503186.76 604862945 1500.00 7680 240.25 314273 319683 470794 -5016.94 833379 HS 0.00 654 83.39 503102.39 604858106 1600.00 7680 240.25 3165.90 322000 475694 -5065.21 841725 HS 0.00 655 83.39 50301801 604853266 1700.00 7660 24025 3189.07 324317 480595 -5113.48 8501.70 HS 0.00 655 8339 502933.84 604848427 1800.00 7660 24025 321225 326635 485498 -5161.75 8586.16 HS 000 6.56 8339 502849.26 604843587 1900.00 76.60 24025 323542 3289.52 490397 -521001 667082 HS 0.00 656 8339 502764.89 604838748 2000.00 7660 240.25 325859 3312.69 495298 5258.28 8755.08 HS 000 627 8339 502680.51 604833909 Cry 3/100 2039.87 76.60 24025 326783 3321.93 497252 -527753 -878875 71219 0.00 657 83.39 502646.87 6048319.79 2100.00 77.19 24200 328146 333558 5002.79 -530580 884003 70.829 3.00 658 83.79 502595.64 604829144 2200.00 78.19 244.90 3302.79 3356.69 5058.64 -534946 -892742 7029 3.00 660 6448 502508.33 604824785 2300.00 79.22 24777 332238 3376.48 5114.74 -5388.82 -901723 69.839 3.00 661 85.18 502418.59 6048208.16 2400.00 80.28 250.82 3340.18 339428 5176.93 -5423.76 910921 69.139 3.00 683 85.89 502326.88 604817308 2500.00 81.36 25346 3356.14 3410.24 5243.03 5454.19 9203.11 68.679 300 685 8661 502232.83 604814251 2800.00 82.46 25628 3370.22 3424.32 5312.87 -548002 9296.67 68.289 3.00 667 8734 502137.32 604811653 2700.00 8358 25908 338238 343648 5386.28 -550120 9395.63 67949 3.00 6.613 8808 50204040 604809521 2800.00 8471 261.87 339258 344668 5462.98 -551765 -9493.73 67.659 3.00 6.70 88.83 501942.34 6048078 61 2900.00 85.86 26486 3400.81 3454.91 5542.85 -552933 9592.69 674213 3.00 672 8957 50164341 6048066.777 End Cry 2912.38 86.00 265.00 340168 3455.78 555294 553045 .960499 HS 3.00 672 8966 501831.11 604806564 3000.00 86.00 265.00 340780 3461.90 582454 553808 989208 HS 0.00 6.72 89.86 501744.06 604805789 3100.00 86.00 265.00 341477 346887 5706.25 554676 979144 45 0.00 673 89.66 501644.71 604804904 3200.00 8600 285.00 3421.75 347585 578797 5555.45 -9890.81 HS 0.00 674 89.66 501545.35 604804020 3300.00 86.00 26500 3422872 348282 586969 -5564.15 9990.19 HS 000 674 8966 501446.00 6048031.35 340000 8600 265.00 343570 348980 595140 557284 -10089.57 HS 000 675 89.86 50134665 604802250 3500.00 86.00 26500 3442.68 349678 6033.12 558154 -1018694 HS 000 676 89.66 50124729 604801366 3600.00 86.00 265.00 3449.65 3503.75 611483 -5590.23 -10288.32 HS 0.00 676 8986 501147.94 604800481 8&reed 3840.70 86.00 285.00 345249 3508.59 644509 5593.77 -10328.77 NS 000 679 8966 501107.50 6048001.21 370000 88.00 285.00 345663 351073 6196.55 559892 1038770 HS 0.00 677 8966 501048.59 604799596 TM Heel 3712.38 86.0D 265.00 3457.49 3511.59 6206.86 -5600.00 .10400.00 84.4613 0.00 877 8986 501036.29 604799487 380000 86.35 268.50 3463.34 3517.44 6279.76 .5804.98 19487.27 84.2213 4.00 678 8950 500949.03 604798977 3900.00 86.76 272.48 346936 352346 636661 560411 -10587.07 83.989 4.00 6.80 8832 500849.25 604799047 4009.00 87.18 27648 347465 3528.75 6456.71 5596.32 1068680 83.779 4.00 682 8914 50074971 6047998.11 4100.00 87.82 280.44 347918 353328 654961 5581.64 -1078539 83.599 4.00 884 8887 500650.91 604801264 4200.00 88.06 28442 3482.93 3537.03 6644.86 5560.12 -1088296 83449 4.00 6.86 88.80 500553.32 6048033.99 430000 88.54 288.40 3485.89 353999 8741.99 -5531.89 -1097882 83339 4.00 688 88.64 500457.42 6048062.07 4400.00 89.00 292.37 348804 354214 664055 -549708 1107252 83.249 4.00 690 8848 500083.88 604809614 4500.00 89.48 296.34 348936 354346 6940.03 -545585 -1116380 83.199 4.00 691 88.33 500272.55 6048137.83 4600.00 6995 300.31 3489.86 354398 703997 -5408.41 -11251.60 83.179 4.00 693 88.19 50018448 604818513 End Cm 4694.80 90.40 30408 348957 354367 7134.68 5357.91 11331.81 HS 4.00 695 88.07 500104.20 604823550 4700.00 90.00 304.08 3489.53 354363 7139.87 535499 11336.12 HS 0.00 6.95 88.07 500099.89 604823841 4800.00 90.40 304.08 348883 3542.93 7239.61 -5298.96 11418.94 HS 0.00 685 88.07 500016.99 604829431 Cm4/100 4819.65 9040 304.08 348889 3542.79 725921 .5287.95 .11435.22 80.779 0.00 695 88.07 500000.70 604830529 4900.00 9092 30725 348776 3541.88 7339.15 .5241.11 .11500.48 80.839 4.00 697 88.10 499935.37 604835202 5000.00 9155 311.20 348581 3539.71 7437.82 -5177.90 11577.91 80.899 4.00 698 88.15 499857.85 6048415.11 T011 5070.80 9200 314.00 348341 353751 7506.88 -513000 .11630.00 85.559 4.00 7.00 8820 499805.69 6048462.92 5100.00 92.09 315.17 348237 3538.47 7535.11 -510952 11650.78 85.59R 400 7.00 8812 49978488 604848337 5200.00 9239 319.16 3478.46 3532.56 7630.57 -5036.28 .11718.74 85.749 4.00 702 8787 499718.85 6048556.51 5300.00 9268 323.15 3474.03 3528.13 772372 -4958.47 1178138 85.929 4.00 7.03 8764 49965408 604863420 End Cm 530428 92.70 32332 3473.82 352792 7727.65 4955.05 -11783.92 HS 400 7.03 87.63 49965152 604863762 CM 325/100 536893 92.70 32332 347088 352498 7785.12 4904.86 -11821.30 107.139 0.00 7.04 87.63 49961406 604868774 5400.00 9238 324.35 346941 352351 7815.33 487819 -11840.79 107.179 325 7.04 87.18 499594.53 604871438 550000 9142 32746 3466.10 3520.20 790523 4795.44 1189282 107.279 3.25 7.05 85.84 499538.38 604879704 5600.00 9045 330.56 346447 351857 799266 4709.74 1194830 107.329 325 707 84.51 49948678 604888265 TM 5846.47 90.00 33000 3464.29 3518.39 803237 4668.99 11970.62 105.189 3.25 707 83.90 499464.39 8048923.36 5700.00 8954 33388 346450 3518.80 8077.35 4821.36 11995.06 105.179 3.25 7.08 8325 499439.88 604897095 5800.00 88.70 33882 346604 352014 8158.99 4530.57 -1203692 105.129 3.25 7.09 82.07 49939789 604906166 End Cry 5835.48 8839 337.93 346694 3521.04 8187.18 4497.83 1205057 HS 3.25 7.10 8165 499384.19 604909438 5900.00 8839 337.93 346875 3522.85 8238.05 443606 -12074.80 HS 0.00 7.10 8165 49935987 6049154.10 Crv2.5/100 5985.87 8839 337.93 3471.15 352525 8305.75 4358.52 1210705 8.569 0.00 7.11 81.65 499327.50 6049233.59 8000.00 8874 33798 3471.51 3525.61 831889 4345.42 1211235 8.568 2.50 7.11 82.00 49932218 8049248.67 T03 8046.76 8990 338.18 3472.06 352816 835370 4302.05 -1212981 8.479 2.50 7.11 83.13 49930485 604929002 End Cm 6047.63 8992 338.16 3472.06 3528.16 835439 4301.24 -12130.14 HS 2.50 7.11 83.15 49930433 604929082 6100.00 8992 338.18 3472.13 352823 839556 4252.63 .12149.82 HS 0.00 7.12 8315 499284.77 604933940 6200.00 8992 338.16 347227 352637 8474.19 4159.81 .1218882 HS 0.00 7.12 83.15 49924743 604943215 Crv25/100 6228.42 8992 338.16 347231 352641 849654 4133.43 -1219739 91.571 0.00 712 8315 499236.82 604945851 6300.00 8987 33637 3472.44 352654 8553.50 4067.45 12225.05 91.584, 2.50 713 8329 499209.06 604952448 8400.00 8980 333.87 3472.72 3528.82 863529 3978.70 -1226712 91.551 2.50 7.14 8349 49918686 604961512 6500.00 8974 33137 3473.12 352722 871950 3887.91 -12313.10 91.541 2.50 7.15 8171 499120.74 604970383 TM 4 6554.94 89 70 330.00 347339 352749 8766.75 384000 -12340.00 500341 2.50 7.16 8323 49909377 6049751 69 17600.00 8950 328.89 347371 352791 880599 380120 12362.90 100.33L 2.50 7.16 83.76 499070 81 6049790 45 8700.00 8905 328.43 3474.97 3529.07 889454 3718.73 -12416.39 10001. 250 7.18 83.62 499017 21 604987484 8800.00 8860 323.97 3477.02 3531.12 898500 3834.63 .12473.44 100251 2.50 7.19 83.49 49896003 8049956.83 690000 88.16 321.51 347980 353394 9077.18 3555.08 -12533.95 100.18L 2.50 7.20 8337 49889940 6050036.29 End Gni 6959.08 8790 320.08 3481.87 353597 913239 3509.33 -1257128 HS 2.50 720 8330 49886200 6050081.97 Cry 2.5/100 6990.12 87.90 320.06 340301 3537.11 9161.52 3485.55 12591.20 1.511 0.00 7.20 8330 498842.09 8050105.72 7000.00 88.15 320.05 3483.35 353745 917080 3477.98 -12597.54 1.511 2.50 721 83.55 498835.71 605011328 7045 707414 9000 320.00 3484.55 353865 924044 3421.18 12645.16 051 2.50 721 8539 498788.00 605017000 710000 9065 319.99 3484.40 3538.50 928474 3401.37 -12661.78 051 2.50 722 8603 498771.35 6050189.78 End Cm 7117.66 91.09 319.99 3484.14 353824 928134 3387.84 -1287314 HS 2.50 722 8647 498759.97 604020329 7200.00 9109 319.99 3482.57 353667 935870 3324.79 -12726.06 HS 0.00 722 8647 498708.96 6050266.28 7300.00 9109 319.99 3480.67 353477 945286 3248.21 -1279034 HS 000 723 8047 498642.58 605034273 7400.00 91.09 319.99 347078 353288 9546.82 317183 -1285482 HS 000 723 8647 498578.17 605041920 7500.00 91.09 31999 3478.88 353098 9640.57 -3095.05 -1291890 HS 000 724 8647 49851378 605049568 Cry 2/100 7529.38 9109 319.99 347632 353042 9668.18 -3072.55 -1293779 137881 000 724 86.47 49849488 6050518.15 760000 90.04 319.04 3475.62 3529.72 9734.74 3018.84 -1298364 137.691 2.00 725 8556 498448.94 805057178 70113 7602.95 90.00 319.00 3475.62 3529.72 9737.53 3016.61 -12985.57 131.871 2.00 725 8553 498447.00 605057400 End Cry 7857.46 8927 318.18 347597 3530.07 9789.19 -2975.73 13021.62 HS 2.00 725 8492 496410.89 6050614.82 7700.00 8927 318.19 347651 353061 982960 2944.03 -1304998 HS 0.00 725 8492 499382.49 605064648 7800.00 8927 318.19 3477.78 3531.88 992460 -2889.50 13116.64 HS 0.00 726 84.92 498315.71 6050720.90 7900.00 8927 318.19 347905 353315 0019.59 -279497 1318331 HS 0.00 726 8492 494248.94 605079531 8000.00 8927 31019 348032 353442 011459 -272044 -1324997 HS 0.00 727 84.92 498182.17 605080973 8100.00 8927 31019 3181.59 3535.69 0209.58 -2645.92 1331683 HS 0.00 727 8492 498115.40 6050944.15 C5v2/100 8120.67 8927 318.19 3481.85 3535.95 0229.22 -2630.51 -1333041 1311 0.00 727 8492 498101.60 805095953 1917 8132.05 8950 318.18 3481.97 3538.07 0240.03 -262203 -1333800 0.62L 2.00 728 85.14 498094.00 805096800 End Cis 8154.55 8995 318.18 348208 353618 026140 -260527 13353.00 HS 2.00 728 8559 498078.98 6050984.74 8200.00 8995 318.18 3482.12 353822 030459 -257139 1338331 HS 0.00 728 8559 49804882 605101856 8300.00 8985 318.18 348221 353001 0399.80 -2498.87 -1344999 HS 0.04 728 8559 49798183 605109297 8400.00 8995 319.18 348229 353639 0494.61 -242235 1351667 HS 000 729 85.59 497915.04 6051167.39 850000 8995 318.18 348238 353648 0589.82 -234782 1358335 HS 000 729 8559 497848.25 6051241.80 8600.00 8995 318.18 3482.47 3538.57 088463 -2273.30 -1385003 HS 000 730 8559 49778148 805131621 Cm 2/100 8601.70 8995 318.18 348247 353857 088624 -2272.04 13651.17 129.139 000 730 8559 497780.33 605131747 To8 8861.11 8920 319.10 348291 3537.01 0742.53 -222744 1369043 120.179 2.00 730 84.72 497741.00 6051362.00 870000 88.81 319.77 348359 3537.69 077920 -2197.91 -1371511 120.186 2.00 731 8424 497715.67 605139150 End Cry 8722.79 88.58 320.17 348410 353820 080081 218048 -1373037 119 2.00 731 8396 497700.99 605140892 8800.00 8858 320.17 3486.02 354012 087307 -2121.19 13779.81 HS 0.00 7.31 83.96 49785146 6051488.11 8800.00 8858 320.17 348850 354260 096691 -204042 -13843.84 HS 0.00 7.32 8306 49758732 605154477 9000.00 86.58 320.17 349097 3545.07 1060.75 1967.85 13907.88 HS 0.00 7.32 8396 497523.17 605162143 Crv2/100 9092.86 8858 320.17 349127 3547.37 1147.89 -1896.37 -13967.34 43219 000 733 8396 497483.60 8061692.62 9100.00 8868 320.28 349044 3547.54 115459 -1890.88 -1397191 40219 2.00 733 8405 49745903 605169809 1219 9190.23 9000 321.50 3494.48 354858 123889 1820.88 -1402883 44.279 2.00 734 8518 49740200 605176800 9200.00 90.14 32184 349447 354857 124797 1813.23 -1403490 44.279 200 734 8531 49739592 805177564 930000 9157 323.03 3492.97 354707 134045 1734.09 1409600 44299 2.00 735 8655 497334.71 605185468 End Cry 9380.23 92.72 324.15 348997 354407 141092 1669.57 14143.58 HS 2.00 725 87.55 49728703 6051919.12 9400.00 92.72 324.15 348903 354313 1431.94 1653.55 -1415515 HS 0.00 735 8755 497275.44 6051935.12 9500.00 9272 324.15 348429 353639 1523.06 -1572.59 -14213.64 65 000 7.36 8755 497218.83 805201599 9600.00 9272 324.15 347954 353364 161422 1491.82 -14272.13 HS 0.00 736 87.55 497158.22 8052096.86 Cm2/100 9684.11 9272 324.18 3475.55 3529.85 1890.89 1423.51 1432134 136.399 0.00 737 8755 497108.92 6052164.88 9700.00 9249 324.37 347483 3528.93 1705.35 -1410.63 14330.80 138.48 2.00 737 8729 497099.63 805217774 TM 10 9720.01 9220 324.85 3474.01 3528.11 172324 -1394.35 -1434221 139.39 2.00 737 88.97 497088.00 8052194.00 End Cm 9754.20 9188 325.10 347285 3528.95 1754.54 -1366.40 14381.87 HS 2.00 737 8640 49706030 605222192 9800.00 9168 325.10 347151 352581 1798.00 -132888 14366.07 HS 0.00 7.37 88.40 49704204 605225942 Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SP34-W7\SP34-W7\SP34-W7(P4) 1/15/2015 4:42 PM Page 2 of 3 Exdwlon Zoos NO Incl .xlm Two 7VD66 TVD VSEC NS EW TF OLS Olredbr 8 Exclusion ions EseBnp Northing Comments 00 ('1 (1 00 00 00 00 00 l9 moon) DHIleu87 In0s9 AWN Angle 11 (MUS) MSS) 1990000 91.68 325.10 3468.57 3522.67 188652 -1246.88 -1444526 HS 000 738 8640 496984.73 605234130 Dv 2/100 19979.02 9188 325.10 3486.28 352038 195805 -118211 -14490.46 7024L 0.00 7.38 8640 '498939.44 6052406.00 20000.00 91.82 324.70 346561 351971 197707 -1164.95 -14502.52 70251. 200 7.38 86.59 496927.35 6052423.14 20100.00 9250 32282 346184 351594 206853 1084.36 -14561.59 70.32L 2.00 7.39 8750 496868.16 6052503.63 20200.00 93.17 32093 3456.90 351100 216121 1005.79 -1462325 70.42L 2.00 740 88.41 496806.39 605258209 T0111 20249.31 9350 320.00 3454.03 3508.13 220733 967.83 -1465458 74.881 2.00 710 88.86 498775.00 605262000 9537C90 20274.06 93.63 319.52 345249 3506.59 1230.59 -948.96 -14670.55 74.911_ 2.00 7.41 89.05 496759.00 6052838.84 20300.00 93.76 319.02 345082 3504.92 225501 .92935 -14887.43 7494L 2.00 741 89.25 490742.09 8052658.42 End Cry 2039523 9426 817.17 3444.16 349826 234531 -858.85 -14750.88 HS 2.00 742 89.99 498678.55 005272902 2040000 91.26 917.17 3443.80 349790 234985 655.16 14754.11 HS 0.00 742 89.99 496875.31 605273250 20500.00 94.26 317.17 3431438 3490.48 2445.13 -782.02 14821.90 HS 0.00 7.12 89.99 498807.42 6052805.53 2060000 94.26 317.17 342896 3483.08 254041 .70888 1488969 HS 000 743 89.99 496539.52 605287856 Cry 2/100 20678.04 94.26 317.17 342317 3477.27 2614.76 65180 1494259 139.68 0.00 7.43 89.99 496486.54 805293555 2070000 9392 317.46 342160 3475.70 263567 -635.70 -14957.44 139.626 2.00 7.43 89.62 496471.66 6052951.63 T9112 20780.18 92.70 318.50 3418.97 347107 271180 57624 15011.02 132.118 2.00 7.44 88.27 496418.00 6053011.00 2080000 92.13 31879 3416.08 3470.18 273057 561.37 -15024.10 132.13R 2.00 7.44 87.97 496404.89 605302584 2090000 91.09 32028 341301 3467.11 282476 48533 -15088.96 132178 200 7.45 8644 496339.92 6053101.78 End Cry 2092621 90.74 32067 341259 3466.69 284931 46512 -1510584 HS 200 7.45 86.04 49632321 805312197 21000.00 9074 32067 341163 3465.73 2918.35 408.05 -15152.41 HS 0.00 7.45 86.04 496276.36 6053178.96 Cry2/100 21018.30 90.74 320.67 341140 3465.50 293517 393.89 15164.01 90.121 0.00 7.45 86.04 496264.74 605319309 21100.00 90.73 31740 341035 346445 3012.89 332.22 -1521756 90.161 4.00 746 88.47 496211.10 8053251.68 21200.00 9072 31340 340908 346318 3109.07 -26104 .1528776 90211 4.00 7.47 87.01 496140.80 6053325.74 21300.00 90.70 309.40 340784 346194 3207.07 194.93 15362.75 90261 4.00 748 87.57 496065.71 6053391.73 15113 21309.94 9070 309.00 340772 346182 3216.88 -188.64 -1537045 90371 4.00 7.48 8763 496058.00 6053398.00 21400.00 90.88 30540 340684 3460.74 330821 -13421 -15112.17 90.411 4.00 7.49 88.14 495988.21 6053452.32 21500.00 90.84 301.40 340549 3459.59 340601 -79.18 -15525.64 90.461 400 751 8871 495902.66 605350721 21600.00 90.81 297.40 340439 3458.49 3505.97 30.11 15612.74 90.51 4.00 702 8929 495815.50 6053556.15 21700.00 90.57 293.40 340335 345745 3605.63 12.77 -1570305 90.541 4.00 753 8987 49572513 605359888 21800.00 90.51 289.40 340238 345648 3704.48 49.25 15796.14 90581 4.00 754 8954 495632.00 605363521 21900.00 9049 28540 3401.49 3455.59 • 3802.04 79.14 -15891.54 90621 4.00 7.55 88.96 495538.56 6053664.95 22000.00 90.45 28140 3400.66 3454/6 3897.85 102.30 -15988.79 90 651 4.00 7.58 88.39 495439.28 605388796 22100.00 9040 277.40 3399.92 3454.02 3991.43 118.63 1608743 90681 4.00 757 8782 495340.63 6053704.13 2220000 90.35 273.40 3399.26 345326 4082.34 128.03 -1618606 90.711 400 7.58 8726 49524109 6053713.38 22300.00 90.30 28940 3398.69 3452.79 4170.11 13047 1628691 90731 4.00 7.59 86.72 495141.15 6053715.87 End Cry 22368.05 9027 268.88 339834 3452.44 4227.84 128.14 -16354.92 HS 4.00 7.59 8636 495073.15 6053713.23 22400.00 9027 286.68 339820 345230 1254.54 126.29 -16386.81 115 0.00 7.60 8638 49504126 6053711.33 22500.00 90.27 28668 339773 345183 4338.09 12049 1648664 HS 0.00 7.80 8836 494941.45 6053705.38 22800.00 9027 268.68 3397.28 3451.36 4121.85 114.69 -16586.47 HS 0.00 7.60 86.36 494841.64 605389943 22700.00 90.27 266.68 3396.79 3450.89 450521 108.89 -16686.30 HS 0.00 7.81 8636 49474183 605369348 22800.00 9027 26668 339632 3450.42 4588.76 10310 16786.13 HS 0.00 7.61 8836 494642.02 605368753 22900.00 9027 288.68 339585 344995 467232 97.30 1688596 HS 0.00 782 8836 494542.21 605388157 23000.00 90.27 286.88 339528 344948 4755.88 91.50 -16985.79 HS 0.00 7.82 8636 494442.40 6053675.62 23100.00 8027 288.68 339491 344801 483044 85.70 -17085.62 HS 0.00 7.62 8836 494342.59 8053669.67 23200.00 9027 286.68 339444 344854 4922.99 79.90 -1718545 HS 0.00 783 8836 494242.77 6053683.72 23300.00 9027 266.68 339397 3448.07 5006.55 74.11 -17285.29 HS 0.00 7.83 8636 49414296 6053657.77 23400.00 9027 266.68 339351 3447.61 5090.11 6031 -17385.12 HS 0.00 7.83 8636 494043.15 6053651.82 23500.00 9027 286.68 339304 3447.14 5173.66 62.51 17484.95 HS 0.00 784 8836 49394334 6053845.87 23600.00 9027 268.88 339257 3446.67 5257.22 56.71 17584.78 116 0.00 7.84 8636 493843.53 6053639.91 23700.00 90.27 268.68 339210 344620 5340.78 50.91 17684.61 HS 0.00 7.85 8638 49374372 6053633.96 23800.00 9027 266.68 3391.63 344573 542433 4511 -1778444 HS 0.00 7.85 8828 493643,90 605362801 23900.00 9027 286.68 3391.16 344526 5507.89 39.32 -1788427 HS 0.00 765 8638 493544,09 605382206 TO 23968.22 9027 268.68 3390.84 3444.94 558469 35.36 17952.38 0.00 7.66 8836 493476,00 8053618.00 8urv.5 Type: Del Nen • • • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SP34-W7\SP34-W7\SP34-W7(P4) 1/15/2015 4:42 PM Page 3 of 3 .L`(.1 PRil 11274s m 2 ill (A7*.:' 1:' , t.0 --- I I 1, Ct. WO I M 1 N % u 2 $$ QQ V e e 0 n Q it 1,' 1 1 I I 1 I S,T 1 I tie I I I ja I I 1z i $o UDant ev 04ant Attachment 3 Drilling Hazards Summary Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill,Reduced pump rates,Reduced drilling fluid temperatures,Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates,mud rheology,LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy gY Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning,PWD tools,hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates,mud rheology,LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out,backreaming Attachment 4 BOP & Diverter Configuration 01 ... 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JZI]4— / } Q 4 104ei r $s1 i1 It loo = W I - /..JP .. `Ili 0a.°i / Al t!A> ®! N Fgi ;^ !`I his F `'�• $ b' -, .o-me----r -I-j -- .< -ow - • - -- ---- t r 4-.008/ I R g /) / /1. )/ /1 C c „ \\\ HI fr*tfN:# = 1 io j\\IJIi1 !V3 i 8HEE000 a x N4 4q4DAtItA 1 � 3 1 ;i1:1111r-- 4 g 1 / / 0 J1/1° .. I §,1 b b �f5Hff.Ee ' 2 a 11 -! 1 , .'.:.) r i R R ffo II / a . i 11 . •__ I a1 - ` I � 11;; eg O 0aIN • b 8� N f1 _ z< _ : Attachment 5 Cement Loads & CemCADE Summary Schlumberger Cem CAD E*well cementing recommendation for 13 3/8 Surface Casing Operator : Eni Petroleum Well : S134-W6 Country : USA State : Alaska Prepared for : Andrea Lazzari Location : Spy Island Proposal No. : Initial Service Point : Prudhoe Bay Date Prepared : 01/14/2015 Business Phone : +1 907 659 2434 Prepared by : Angele Diboue Phone : +1 907 306 8949 E-Mail Address : aedimo©slb.com $1, C L gluATE Disclaimer Notice' Schlumberger submits this document with the benefit of its Judgment,experience.and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals.recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. .Mark of Schlumberger Page 1 SI34-W6 cfw;01-14-2015, LoadCase Surface 13 3/8;Version wcs-cem472 05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Load case : Surface 133/8 Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2900.0 ft BHST : 50 degF Bit Size : 16 in ft _ (x 1000)ft OD 20.in 0 0.25 0.50 0.75 1.00 1.25 - @ 160ft Fbri.Depart. U, O N — _ O O O _ U, OD 13.4 in @ 2900ft11 LO \0 0_ I- L ) O N _ � O X In O_ U N - LC @2820 ft LO •- - - 0 Ce O — N u7 M• - N N O p U, N Well Hori. Departure Page 2 SI34-W6.cfw.01-14-2015; LoadCase Surface 133/8;Version wcs-cem472 05 Client : Eni Petroleum Well : S134-W6 Stiloberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 2820.0 ft Casing/liner Shoe MD : 2900.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2900.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 130.6 % Mean OH Equivalent Diameter: 18.887 in Total OH Volume : 949.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1850.0 16.000 190.0 20.063 2900.0 16.000 35.0 16.822 Max. Deviation Angle :66 deg Max. DLS : 3.750 deg/100ft Refer to appendix 1 for complete directional surveys Formation Data MD Frac. Pore Name Llthology (ft) (lb/gal) (lb/gal) 1850.0 11.50 8.40 B/Permafrost Shale 2900.0 12.50 8.40 TD Sandstone Page 3 SI34-W6ciw,01-14-2015, LoadCaseSurface 133/8,Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 13 3/8 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1850.0 1752.1 32 0.7 2900.0 2453.8 50 1.2 ft degF (x 1000)ft 0 I 40 60 n n 75 n F0 0 75 1 00 1-25 - Geoth.Profile Hy- Ceoart I l I •J Lc) c,- 11.11111.1111111 ■M �■ o -0ezi _ - r = O o - _ �� r`rrlrr rrRrrrrr -aill . t CJ - r - ••••'' .1 x 6 C, - 4^� _ O - ...__I. 1..._. u r _ IIIIIIIIIIIIIII (--) - a. o MOM o - _._..__.._ c-, . anniniiiiiiiiiiiiiiii cNi G __ Mii�ni�.iiii O : 0 v- cv Temperature Hori Departure Page 4 SI34-W6.cfw.01-14-2015; LoadCase Surface 133/8;Version wcs-cem472_05 Client : Eni Petroleum Well : Sl34-W6 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 13 3/8 Section 2: fluid sequence Job Objectives: Bring cement to surface. Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n :0.262 Ty :0.48 lbf/100ft2 Displacement Volume 422.2 bbl Total Volume 1031.5 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 lbf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 Surface Lead Slurry 446.2 2395.0 0.0 10.70 k:1.52E-1 Ibf.s^n/ft2 n:0.315 Ty:1.35 lbf/100ft2 12.5ppg DeepCRETE 63.0 505.0 2395.0 12.50 k:1.56E-2 lbf.s^n/ft2 n:0.811 Ty:3.01 lbf/100ft2 Surface Tail Mud 422.2 0.0 9.50 k:8.28E-2lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 7 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2011 psi at 2820.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 59 ton Check Valve Diff Press 173 psi ft (x 10O0) psi G_ < , 0 2 - —Hydrostatic o - —Fracy o- —Pare 1 o _ --j 0 G- _ o _ O G 0 0 o - __. Fluid Sequence Static Well Security Page 5 SI34-W6 cfw;01-14-2015; LaadCase Surface 13 3/8,Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Section 3: pumping schedule - Spacer/Cement Max Rate is 7-BPM - (No significant amount of time to be spent outside of+/-0.2ppg Density Range) - Maintain returns during cement job if possible(note returns,losses in Job report). - Max displacement Rate is 6-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Do not overdisplace more than 1/2 shoe track volume if plug bump not observed. - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from noted Rates in Job Report Pumping Schedule Name Flow Volume Stage Cum.Vol Inj. Comments Rate (bbl) Time (bbl). Temp. (bbl/min) (min) (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead with Rig Pumps Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug Surface Lead Slurry 5.0 446.2 89.2 446.2 80 Mix/Pump Lead SLurry(3-6 BPM) 12.5ppg DeepCRETE Surface 4.0 63.0 15.8 63.0 80 Mix/Pump Tail Slurry(3-5 BPM) Tail Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 6.0 412.0 68.7 412.0 80 Displacement Mud 2.0 10.2 5.1 422.2 80 low rate to bump the plug Total 03:28 1031.5 bbl hr:mn Dynamic Security Checks : Frac 3 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2011 psi at 2820.0 ft Burst 4759 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 68 degF Simulated BHCT 68 degF Max HCT Depth 2900.0 ft CT at TOC 59 degF Max HCT Time 03:28:46 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 50 degF Page 6 5134-W6.cfw;01-14-2015, LoadCase Surface 133/8;Version wcs-cem472 05 Client : Eni Petroleum Well : SI34-W6 Schimberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue: time<20 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue: time<10 min c) Note displacement volume pumped by mud pumps: verify with Co. Rep/WSL d) Subtract pumped volume from total volume=volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit: volume verified by Co. Rep/WSL Simulated ECD at shoe 2900 ft o - Depth 2900 ft a7T Pbre Frac Hydrostatic �Q Oynanic - O 0 MO 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 7 SI34-W6.cfw.01-14-2015, LoadCase Surface 133/6:Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Simulated ECD at Previous shoe 160 ft Depth= 160 ft Frac Pore N Hydrostatic Dynamic CO r I g O gess o co co 2 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Simulated temperature during placement Last Sack Temp. Fret Sack Temp. API BHC r le bid O 8- � 0- 9 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 8 S134-W6.cfw;01-14-2015; LoadCase Surface 13 3/6;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 13 3/8 Simulated rate and pressure during placement --- Calc.Cent IP Calc.Amp Ress. Acquired Pressure o I O 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 Pumped Volume (bbl) (x 1000) Fluids at 2900 ft Qh :e. Acquired Q In Q Out 1 IS i ,--- g 7 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 Pumped Volume (bbl) (x 1000) Cab.CemHP I Calc.Rinp Press. Acquired Pressure O - O 20 40 60 80 100 120 140 160 180 200 220 Time (min) Fluids at 2900 ft ▪ N- 0 Acquired Q In C 0 Q out 1 ---- -V.- . a) g Ln N •0 O 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 9 s134-We.clw;el-14-2015; LoadCase Surface 13 3/8;Version wcs-cem412_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Simulated temperature throught 24 hours after placement at Shoe 2900ft Depth= 2900 ft API BHCT Geoth.Profile p —{Annulus N- ---Tubular Fluids rVi co co i O LL CY)LL) N In o c LO 2 Qin it E - 0) I— O C'9 c) 0 250 500 750 1000 1250 1500 1750 Time (min) Page 10 5134-W6.clw;01-14-2015; LoadCase Surface 133/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumbergcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2890.0 ft Casing Shoe :2900.0 ft NB of Cent. Used :16 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 100.0 0 0/0 100.0 60.0 180.0 2 1/1 NW-ST-13 3/8-8-ST A3B W131 78.8 160.0 2420.0 0 0/0 0.0 182.7 2820.0 10 1/1 NW-ST-13 3/8-8-ST A3B W131 0.0 2425.3 2900.0 4 2/1 NW-ST-13 3/8-8-ST A3B W131 88.6 2830.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-5T-13 3/8-8-ST W131 13 3/8 18.386 14.685 No Hannover 16.000 1225.21 2996.70 A3B (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft 0 10 20 30 40 50 60 70 80 90 100 0 Between Cent. + +At Cent. C_ . oT • YJ Pipe Standoff Page 11 S134-WGcfw;01-14-2015; LoadCase Surface 133/8,Version wcs-cem472 05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Section 5: WELLCLEAN II Simulator ft % % 0 25 50 75 100 0 25 50 75 100 0 —Std Betw.cent. —Cement coverage 11111t. O . SIP 1 1 - Mud Contamination - Uncontaminated Slurry 1 Fluid Sequence Cement Coverage Uncontaminated Skrry em..w 10*ye 2031.2031 CON.'", .»urarcfr .0{...W v Rai NWPu.val 3 z z 0 1 ------- 0 0 0 590 500 500 500 1000 1000 1000 1000 w a 1500- 1500 a a 1500 1500 a a, m a) m 0 0 0 0 2000 2000 2000 2000 2500 2500 2500 2500 as 3 a a3 a -o o -o -o o i 3 3 t 0 0 z z ®'Z'',cog DaoCRE,rSows. G= s'',Y ®t., ■ Page 12 S134-W6.ciw,01-14-2015; LoadCase Surface 133/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Section 2: operator summary TOTAL MATERIAL REQUIREMENTS Dead Volumes Operator Volumes Name Pumped Volume Dead Vol. Applies to Blend Dead Mass (bbl) (bbl) (Ib) Mud 422.2 0.0 Total Fluid 0 MUDPUSH II 100.0 0.0 Total Fluid 0 Surface Lead 446.2 40.0 Total Fluid 0 Slurry Mix Water Requirements : Fresh water 18236 gal MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density : 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 lb/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 lb/bbl of spacer Surface Lead Slurry Volume :486.2 bbl Density : 10.70 lb/gal Yield :2.77 ft3/sk &/ Dry Phase Liquid Phase Blend : 100885.7 lbs Design Mix Water 317.1 bbl 10.0 bbl LAS Design BLD ASL 98617.461 lb Fresh water 308.407 bbl 9.726 bbl B439 D046 394.470 lb 0.400%BWOB D044 9710.924 lb 9.000%BWOW D065 493.087 lb 0.500%BWOB D079 493.087 lb 0.500%BWOB S002 887.557 lb 0.900%BW OB 12.5ppg DeepCRETE Surface Tail Volume :73.0 bbl Density : 12.50 lb/gal / Yield : 1.57 ft3/sk Dry Phase Liquid Phase Blend: 26266.8 lbs Design Mix Water 34.4 bbl 10.0 bbl LAS Design 12.5-0.82-53 26084.256 lb Fresh water 33.734 bbl 9.820 bbl D046 52.169 lb 0.200%BWOB D186 26.084 gal 7.593 gal 0.100 gal/sk blend D065 65.211 lb 0.250%BWOB D167 65.211 lb 0.250%BWOB Note: Dead volume including: 10 bbls for tail and 40 bbls for lead Page 13 5134-W6.cfw,01-14-2015, LoadCase Surface 13 3/8,Version wcs-cem472_05 Client : Eni Petroleum Well : SI34-W6 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Appendixl: Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 170.0 0.000 100.0 100.0 0.0 170.0 0.000 200.0 200.0 0.0 170.0 0.000 300.0 300.0 0.0 170.0 0.000 400.0 400.0 0.0 170.0 0.000 500.0 500.0 1.5 170.0 1.500 600.0 599.9 3.0 170.0 1.500 700.0 699.6 5.5 205.4 3.500 800.0 798.8 8.7 217.0 3.500 900.0 897.2 12.1 222.3 3.500 1000.0 994.3 15.5 225.3 3.500 1100.0 1089.8 19.0 227.2 3.500 1200.0 1183.3 22.4 228.5 3.500 1300.0 1274.6 25.9 229.5 3.500 1360.5 1328.5 28.0 230.0 3.500 1389.6 1354.1 29.0 230.0 3.500 1400.0 1363.2 29.1 230.0 0.500 1500.0 1450.4 29.6 230.0 0.500 1600.0 1537.1 30.1 230.0 0.500 1700.0 1623.4 30.6 230.0 0.500 1800.0 1709.3 31.1 230.0 0.500 1900.0 1794.7 31.6 230.0 0.500 1969.8 1854.1 31.9 230.0 0.500 2000.0 1879.6 33.0 230.4 3.750 2100.0 1961.6 36.7 231.7 3.750 2200.0 2039.8 40.4 232.8 3.750 2300.0 2113.8 44.1 233.7 3.750 2400.0 2183.3 47.8 234.5 3.750 2500.0 2248.1 51.5 235.2 3.750 2600.0 2307.7 55.2 235.9 3.750 2700.0 2362.0 58.9 236.5 3.750 2800.0 2410.8 62.7 237.0 3.750 2900.0 2453.8 66.4 237.5 3.750 Page 14 S134-W6 cfw;01-14-2015; LoadCase Surface 13 3/8;Version wcs-cem472_05 Schlumberger CemCAD E*well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : S134-W6 Country : USA State : Alaska Prepared for : Andrea Lazzari Location : Spy Island Proposal No. : Initial Service Point : Prudhoe Bay Date Prepared : 01/14/2015 Business Phone : +1 907 659 2434 Prepared by : Angele Diboue Phone : +1 907 306 8949 E-Mail Address : aedimo©slb.com \GN n • 40ATE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying an facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. Mark of Schlumberger Page 1 SI34-W6.cfw;01-14-2015; LoadCase Intermediate 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schiumbergcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 13641.0 ft BHST : 85degF Bit Size : 12 1/4 in ft (x 1000)ft joD2o.in 0 2 4 6 8 10 12 I@ 160ft w Hod.Depart. CO O co• O OD 13.4 in p� @ 2900ft O O — o T a OD 9.62 in @ 13641ft O O O T •� x N� O N LC@13561ft . N— M O O � O r � Well Hori. Departure Page 2 5134-W6 cfw:01-14-2015; LoadCase Intermediate 9 5/S.Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlohrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2900.0 13 3/8 68.0 12.415 Landing Collar MD : 13561.0 ft Casing/liner Shoe MD : 13641.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 13641.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 IFJ Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1865.3 bbl (including excess) Max. Deviation Angle :87 deg Max. DLS : 3.750 deg/100ft Refer to appendix 1 for complete directional surveys Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (Ib/gal) 7200.0 12.50 8.40 Ugnu Top(UG4) Sandstone 12018.0 12.50 8.40 N Sequence Top Sandstone 13641.0 12.50 8.40 TD Sandstone Page 3 5134-W6.cfw,01-14-2015; LoadCase Intermediate 95/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Scrlinkrger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Geothermal Temperature Profile MD TVD Temperature Gradient • (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1879.6 32 0.6 2900.0 2453.8 50 1.2 13641.0 3506.6 85 1.9 ft degF (x 1000)ft 0 lf1 60 90 S 6 9 12 —Geoth.Pro Ie I —Hori.Depart. + i♦ � V 0 .... ��• ' O _ 1111111,11111111111111111111111111,11111111111111111111,1111111111111111111111..� 11111111111111111111111o 1111111111111 ...... NI 11111111111111111111111111111111111111111 onommomm 0mmummoommommammm ■.�....... _ _ — _ .... ..... - IMMINo .. _....� . . ......... 1 0o ci I . ...... ._, ......... o 'cr. 111111111111111111111111111111111M1111��o— N 1.. 1. . ..... .co ..... n Ihir...... - .x..1. 1.. I 1111111111111111111 ... .. n 11111111111111111 .a11.. m 1 .. ....Ia.. • ..�.....r7. o- C 1 .1......��� to ---- 07 - - Temperature Hon. Departure Page 4 0134-W6.ciw;01-14-2015; LaadCase Intermediate 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 11018' MD(1,000'above the"N" Sand Top). Original fluid Mud 9.50 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n :0.616 Tv :8.86 Ibf/100ft2 Displacement Volume 1028.3 bbl Total Volume 1353.8 bbl TOC 11018.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1195.1 9822.9 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 12.5ppg DeepCRETE 225.5 2623.0 11018.0 12.50 k:4.44E-3 Ibf.s^n/ft2 n:1.002 Ty:19.29 Ibf/100ft2 Mud 1028.3 0.0 9.50 k:5.97E-31bf.s^n/ft2 n:0.616 Ty:8.86lbf/100ft2 Static Security Checks: Frac 382 psi at 2900.0 ft Pore 140 psi at 2900.0 ft Collapse 2564 psi at 13561.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 74 psi ft (x 1O001 psi - 0 2 I- Hyv.,.ct_t —Frac Po-f. - i�. r. E. G C• C• Fluid Sequence Static Well Security Page 5 SI34-W6.cfw,01-14-2015, LoadCase Intermediate 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Load case : Intermediate 9 5/8 Section 3: pumping schedule - Spacer/Cement Max Rate is 7-BPM - (No significant amount of time to be spent outside of+/-0.2ppg Density Rangel - Maintain returns during cement job if possible(note returns,losses in Job report(. - Max displacement Rate is 6-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Do not overdisplace more than 1/2 shoe track volume if plug bump not observed. - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from noted Rates in Job Report Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj.Temp. Comments (bbl/min) (bbl) (min) (bbl). (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead w/Rig Pumps Pause 0.0 . 0.0 5.0 0.0 80 Drop Bottom Plug 12.5ppg DeepCRETE _ 5.0 _ 225.5 45.1 225.5 80 Mix/Pump Cement Slurry(3-5 BPM) Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 6.0 1018.0 169.7 1018.0 80 Displacement Mud 2.0 10.3 5.1 1028.3 80 Slow rate to bump the plug Total 04:09 1353.8 bbl hr:mn Dynamic Security Checks : Frac 138 psi at 13641.0 ft Pore 140 psi at 2900.0 ft Collapse 2424 psi at 88.5 ft Burst 4441 psi at 0.0 ft Temperature Results BHCT 83 degF Simulated Max HCT 70 degF Simulated BHCT 64 degF Max HCT Depth 0.0 ft CT at TOC 64 degF Max HCT Time 04:04:46 hr:mn:sc Static temperatures : At Time 1 (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 71 degF Bottom Hole (degF) (degF) 85 degF Page 6 SI34-W6.cfw:01-14-2015. LoadCase Intermediate 95/8;Version wcs-cem472_05 Client : Eni Petroleum Well : SI34-W6 Schlmbergcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 95/8 Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue: time<20 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue: time<10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume=volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Simulated ECD at shoe 13641ft o Depth=13641 ft M Frac Pore Hydrostatic Dynamic O O Of • 0 30 60 90 120 150 180 210 240 270 Time(min) Page 7 5134-W6.cfw,01-14-2015, LoadCase Intermediate 9 5/8:Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Simulated ECD at Previous shoe 2900 ft o Depth= 2900 ft Cd ' Frac rPore N_„- r Dynamic 0 , N- _I r 4o1' r d gd J Z 0 crS2- o cd I 0 30 60 90 120 150 180 210 240 270 Time (min) Simulated temperature during placement 0 Last Sack Term. r API BHCT I 1 t N P- 1 d i t t i xt a t t t ! N 69 t t -c4 t 8` ! !. 8 e 03 4 g, r O 0 30 60 90 120 150 180 210 240 270 Time (min) Page 8 S134-Wt cfw;01-14-2015; LoadCase Intermediate 9 5/0,Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Simulated rate and pressure during placement bS — — mHP Cab. Press- Acc Liked Lire § I g O O 30 60 90 120 150 180 210 240 270 Time (min) Fluids at 13641 ft n 0 2 Acquired Q h E o Q out 1 lc/ g /-----1V __N EE 0 O 30 60 90 120 150 180 210 240 270 Time (min) ,Ic.CemHP r. rrp Press. - cquk essure A 0 O 0.25 0.50 0.75 1.00 1.25 1.50 Pumped Volume (bbl) (x 1000) Fluids at 13641 ft Ln r; Q h --Acquired Q h P 0 Q Out r` -- 1 16 2• Lo zN 17 _ Q o �. O 0.25 0.50 0.75 1.00 1.25 1.50 Pumped Volume (bbl) (x 1000) Page 9 5134-W6.ctw;01-14-2015; LoadCase Intermediate 9 5/8,Version was-rem4/2 05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Simulated temperature throuaht 24 hours after placement at Shoe 15725ft Depth= 13641 ft co API BHCT Geoth.Prof ile .r.,4 Annulus co Tubular Fluids 3 co N- ri 0) 0 LO 0 2 N . r 0_ E 0 rn co co co / �,.k...r.�.. 0 0 200 400 600 800 1000 1200 1400 1600 1800 Time (min) Page 10 8134-We.cfw;01-14-2015; LoadCase Intermediate 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Section 4: centralizer placement Top of centralization :9000.0 ft Bottom Cent. MD :13621.0 ft Casing Shoe :13641.0 ft NB of Cent. Used :78 NB of Floating Cent. :78 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 10521.0 0 0/0 0.0 10538.9 13641.0 78 1/1 HYDROFORM HFD 50.0 13641.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (Ibf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford I'I N.A. N.A. N.A. (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 0D specifications ft 0 10 20 30 40 50 60 70 80 90 100 - Between Cent. + +At Cent. O O_ O U) O O O- O O - O O LI) Pipe Standoff Page 11 SI34-W8.ctw;01-142015; LoadCase Intermediate 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 95/8 Section 5: WELLCLEAN II Simulator ft 0 25 50 75 100 0 25 50 75 100 — Std Betw.Cent. Mid Contarrination Cement Coverage — Uncontaminated Slurry 14 i i 111111111111 I F r I Fluid Sequence Cement Coverage Uncontaminated Slu'ry I,mu.. w wima,.r,awi.moa COMMIRPL - - z 3 3 z 9000 MIIIIIIIIIIMININI 9000 9000 9000 9500 9500 9500 9500 t 10000 i 10000 10000 10000 _ 10500 f 10500 _ 10500 10500 j 11000— 11000 11000 11000 t t s s 11500— 11500 11500 11500 m o - o 0 cn 12000— 12000 12000 12000 12500— 12500 12500 12500 13000— 13000 13000 13000 13500— 13500 13500 13500 m 3 m a, ; m 13 O U -0 ° O 0 3 3 0 z z G::rgrr„ ■ ■t. Page 12 SI34-W6.ciw;01-14-2015; LoadCase Intermediate 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Section 2: operator summary TOTAL MATERIAL REQUIREMENTS Dead Volumes Operator Volumes Name Pumped Volume Dead Vol. Applies to Blend Dead Mass (bbl) (bbl) (Ib) Mud 1028.3 0.0 Total Fluid 0 MUDPUSH II 100.0 0.0 Total Fluid 0 12.5ppg 225.5 10.0 Total Fluid 0 DeepCRETE Mix Water Requirements : Fresh water 8427 gal MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density : 10.50 lb/gal Code Quantity Design Fresh water 90.625 bbl D047 20.000 gal 0.200 gal/bbl of spacer D182 543.750 lb 6.000 lb/bbl of base fluid D031 11722.021 lb 117.22 lb/bbl of spacer 12.5ppg DeepCRETE Volume :235.5 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk 3 Dry Phase Liquid Phase Blend : 85211.3 lbs Design Mix Water 110.0 bbl 10.0 bbl LAS Design 12.5-0.82-53 84618.977 lb Fresh water 110.022 bbl 10.001 bbl D046 169.238 lb 0.200%BWOB D065 211.547 lb 0.250%BWOB D167 211.547 lb 0.250%BWOB Note: Including Dead volume of 10 bbls for slurry Page 13 SI34-W6 cfw:01-14-2015: LoadCase Intermediate 9 5/8,Version wcs-cem472 05 Client : Eni Petroleum Well : SI34-W6 Schlumacrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 170.0 0.000 100.0 100.0 0.0 170.0 0.000 200.0 200.0 0.0 170.0 0.000 300.0 300.0 0.0 170.0 0.000 400.0 400.0 0.0 170.0 0.000 500.0 500.0 1.5 170.0 1.500 600.0 599.9 3.0 170.0 1.500 700.0 699.6 5.5 205.4 3.500 800.0 798.8 8.7 217.0 3.500 900.0 897.2 12.1 222.3 3.500 1000.0 994.3 15.5 225.3 3.500 1100.0 1089.8 19.0 227.2 3.500 1200.0 1183.3 22.4 228.5 3.500 1300.0 1274.6 25.9 229.5 3.500 1360.5 1328.5 28.0 230.0 3.500 1389.6 1354.1 29.0 230.0 3.500 1400.0 1363.2 29.1 230.0 0.500 1500.0 1450.4 29.6 230.0 0.500 1600.0 1537.1 30.1 230.0 0.500 1700.0 1623.4 30.6 230.0 0.500 1800.0 1709.3 31.1 230.0 0.500 1900.0 1794.7 31.6 230.0 0.500 1969.8 1854.1 31.9 230.0 0.500 2000.0 1879.6 33.0 230.4 3.750 2100.0 1961.6 36.7 231.7 3.750 2200.0 2039.8 40.4 232.8 3.750 2300.0 2113.8 44.1 233.7 3.750 2400.0 2183.3 47.8 234.5 3.750 2500.0 2248.1 51.5 235.2 3.750 2600.0 2307.7 55.2 235.9 3.750 2700.0 2362.0 58.9 236.5 3.750 2800.0 2410.8 62.7 237.0 3.750 2900.0 2453.8 66.4 237.5 3.750 2900.6 2454.1 66.4 237.5 3.721 3000.0 2490.9 70.1 238.0 3.750 3100.0 2521.8 73.8 238.5 3.750 3200.0 2546.5 77.6 238.9 3.750 3300.0 2564.9 81.3 239.4 3.750 3400.0 2576.8 85.0 239.8 3.750 3453.5 2580.6 87.0 240.0 3.750 3500.0 2583.0 87.0 240.0 0.000 3600.0 2588.2 87.0 240.0 0.000 3700.0 2593.5 87.0 240.0 0.000 3800.0 2598.7 87.0 240.0 0.000 3900.0 2603.9 87.0 240.0 0.000 4000.0 2609.2 87.0 240.0 0.000 4100.0 2614.4 87.0 240.0 0.000 4200.0 2619.6 87.0 240.0 0.000 4300.0 2624.9 87.0 240.0 0.000 4400.0 2630.1 87.0 240.0 0.000 4500.0 2635.3 87.0 240.0 0.000 4600.0 2640.6 87.0 240.0 0.000 4700.0 2645.8 87.0 240.0 0.000 4800.0 2651.0 87.0 240.0 0.000 4900.0 2656.3 87.0 240.0 0.000 5000.0 2661.5 87.0 240.0 0.000 5100.0 2666.7 87.0 240.0 0.000 Page 14 5134-W6.ctw;01-14-2015; LoadCase Intermediate 95/8,Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 9 5/8 Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 5200.0 2672.0 87.0 240.0 0.000 5300.0 2677.2 87.0 240.0 0.000 5400.0 2682.4 87.0 240.0 0.000 5500.0 2687.7 87.0 240.0 0.000 5600.0 2692.9 87.0 240.0 0.000 5700.0 2698.1 87.0 240.0 0.000 5800.0 2703.4 87.0 240.0 0.000 5900.0 2708.6 87.0 240.0 0.000 6000.0 2713.8 87.0 240.0 0.000 6100.0 2719.1 87.0 240.0 0.000 6200.0 2724.3 87.0 240.0 0.000 6300.0 2729.5 87.0 240.0 0.000 6400.0 2734.8 87.0 240.0 0.000 6500.0 2740.0 87.0 240.0 0.000 6600.0 2745.2 87.0 240.0 0.000 6700.0 2750.5 87.0 240.0 0.000 6800.0 2755.7 87.0 240.0 0.000 6900.0 2761.0 87.0 240.0 0.000 7000.0 2766.2 87.0 240.0 0.000 7100.0 2771.4 87.0 240.0 0.000 7200.0 2776.7 87.0 240.0 0.000 7300.0 2781.9 87.0 240.0 0.000 7400.0 2787.1 87.0 240.0 0.000 7500.0 2792.4 87.0 240.0 0.000 7600.0 2797.6 87.0 240.0 0.000 7700.0 2802.8 87.0 240.0 0.000 7800.0 2808.1 87.0 240.0 0.000 7900.0 2813.3 87.0 240.0 0.000 8000.0 2818.5 87.0 240.0 0.000 8100.0 2823.8 87.0 240.0 0.000 8200.0 2829.0 87.0 240.0 0.000 8300.0 2834.2 87.0 240.0 0.000 8400.0 2839.5 87.0 240.0 0.000 8500.0 2844.7 87.0 240.0 0.000 8600.0 2849.9 87.0 240.0 0.000 8700.0 2855.2 87.0 240.0 0.000 8800.0 2860.4 87.0 240.0 0.000 8900.0 2865.6 87.0 240.0 0.000 9000.0 2870.9 87.0 240.0 0.000 9100.0 2876.1 87.0 240.0 0.000 9200.0 2881.3 87.0 240.0 0.000 9300.0 2886.6 87.0 240.0 0.000 9400.0 2891.8 87.0 240.0 0.000 9500.0 2897.0 87.0 240.0 0.000 9600.0 2902.3 87.0 240.0 0.000 9700.0 2907.5 87.0 240.0 0.000 9800.0 2912.7 87.0 240.0 0.000 9900.0 2918.0 87.0 240.0 0.000 10000.0 2923.2 87.0 240.0 0.000 10100.0 2928.4 87.0 240.0 0.000 10153.5 2931.2 87.0 240.0 0.000 10200.0 2934.0 86.1 240.0 -2.000 10300.0 2942.6 84.1 240.1 -2.000 10400.0 2954.7 82.1 240.1 -2.000 10500.0 2970.2 80.1 240.2 -2.000 10600.0 2989.2 78.1 240.2 -2.000 10673.5 3005.3 76.6 240.3 -2.000 Page 15 5134.W6.ciw;01-14-2015; LoadCaseIntermediate 95/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S134-W6 Schlumkrger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate 95/8 Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 10700.0 3011.4 76.6 240.3 0.000 10800.0 3034.6 76.6 240.3 0.000 10900.0 3057.8 76.6 240.3 0.000 11000.0 3080.9 76.6 240.3 0.000 11100.0 3104.1 76.6 240.3 0.000 11200.0 3127.3 76.6 240.3 0.000 11300.0 3150.5 76.6 240.3 0.000 11400.0 3173.6 76.6 240.3 0.000 11500.0 3196.8 76.6 240.3 0.000 11600.0 3220.0 76.6 240.3 0.000 11700.0 3243.1 76.6 240.3 0.000 11800.0 3266.3 76.6 240.3 0.000 11900.0 3289.5 76.6 240.3 0.000 12000.0 3312.7 76.6 240.3 0.000 12039.9 3321.9 76.6 240.3 0.000 12100.0 3335.5 77.2 242.0 3.000 12200.0 3356.9 78.2 244.9 3.000 12300.0 3376.4 79.2 247.8 3.000 12400.0 3394.2 80.3 250.6 3.000 12500.0 3410.2 81.4 253.5 3.000 12600.0 3424.3 82.5 256.3 3.000 12700.0 3436.4 83.6 259.1 3.000 12800.0 3446.6 84.7 261.9 3.000 12900.0 3454.9 85.9 264.7 3.000 12912.4 3455.7 86.0 265.0 3.000 13000.0 3461.8 86.0 265.0 0.000 13100.0 3468.8 86.0 265.0 0.000 13200.0 3475.8 86.0 265.0 0.000 13300.0 3482.8 86.0 265.0 0.000 13400.0 3489.7 86.0 265.0 0.000 13500.0 3496.7 86.0 265.0 0.000 13600.0 3503.7 86.0 265.0 0.000 13640.7 3506.5 86.0 265.0 0.000 13641.0 3506.6 86.0 265.0 0.000 Page 16 SI34-W6.cfw.01-14-2015; LoadCase Intermediate 95/8;Version wcs-cem472_05 Attachment 6 FIT & LOT Procedure SPEO IDENTIFICATION CODE PAG 206 OF 338 - - ENI S.p.A. Erg E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW = +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 I LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 Enii E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. it SPEO IDENTIFICATION CODE PAG 209 OF 338 �n ENI S.p.A. EInlll E&P Division REVISION STAP-P-1-M-6140 0 1 *041 LEAK-OFF TEST REPORT Rept"N' Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NPM1AE: RIG CODE: Open hole depth(m): 825 _MudT}pe: FWGELS Rig type: J.UPs Hole Ofameter(in): 12 1/4 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh vAscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter On): 13"3/8 P.V.(cps): 19 Pumps: 12•P.160 Grade: .155 Y.P.Ob/1001): 5 Liners(in): 6.5" Weight 0b/t): 61 •Gels(1b/100 e): 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc130 min): 10.5 LOholog y Shale Expected EMW 1.68 Kg/cm2/1 0 m Time Volare Pressure Time Volume Pressure Time Volume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 075 200 10 2 470 4 1 00 300 10.5 2 483 5 125 400 11 2 465 6 150 500 11.5 2 450 7 1.75 570 12 2 446 8 2D0 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Ncte: Pumped with a constant tow rate of(661): \tdume pumped(bbl): \blume returned(bbl): (pa) 1000 900 • 800 stop pump 700 r ` e 600 S 500 .� shut in curve S • —•—•—•—•—• • ► U 400 r - 8 minutes e 300 200 100 0 r . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbf) 4 Time mins RESULTS: (P rens.mw+Press.Lo.)x101D epth=[(1.3 x 797/10)+(430 x 0.07)]x10 1797=1.68(Kg/cm2/10 m) Note: I Company Re presentative Figure 15-1 - Leak-Off Test Report Attachment 7 Surface Platt REV DATE BY CK APP DESCRIPTION REV DATE . BY CK APP DESCRIPTION 0 10/01/:0 DHS CC CC ,r-, c: ircw•-c VICINITY MAP SCALE: 1" vv. 2 Miles • Ila i 13 I ',.''' I 17 16 . .. . 1 i 1 t. 1 7 t , !41 1 . i N 1 __ . ,_ ._. _ Ib 21"., 21 23 !41 ;* Nraiii;;0 •-•'''N . 1 "4 18 THIS • - -- - 411..... 30 29 ...,Ei SURVEY 25 30 29 28, 1 26 25 iii"6 CO 0) la tt ix 33 44 -15 3qi &Ei 31 A.S.P. NAP83, Z4. 3* 36 31 37 T14N T14N T13N T13N 3 2 1 :OCT&PONT PAD °Lttigl2K '5 3.4 1 :t: 4 10 S \1, ,s-3R \`', i * - , ••\ io .1 41‘. c) . , Izrei'....,.tiz _rnt ,)____ciLt_.0 —'_1_,..j.. r '4 rploiwO ---) i• ' ; 16 i!-, y\ 14 & J3 !a Ds'TtQl.,-iii„.('-',,li , q , r-, ., ' r A / `M, ' ' , DS 30 , \ _LI _ _ 'I(-- , ';','' 5, Mi e Si it, to irrt c 4 ' 21 22 '41 \z) I, ., ____ k/11 ' 1 • 1 i,_., ] °EQUIP PAO IQ 4 MRU.. 75-31.4 Oa . DS 04 . 0 • J(.1,;;Ap ,"" '18 27 A ' I . •MP, ,Lsj __\ . , ---.---* *- ...TUT SAX le .C. - C('' lire 33 Iii.., „ Alk - -' .' , , ;1. -:D MD m '' , (ai--‘ ,—• '' _I"_. At .--- DRAWING NOTES: 1. GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE. HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM GPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 FOR COORDINATE VALUES IN NAD27. 00010111111wmi. 4,4•!;t::\.................... `414, ir ..',. .... v a, . ••J \ • SURVEYOR'S CERTIFICATE : 4/ 49th I\ • • 1 0 • t_ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 ,r-- --), , LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OFL:..(14,-4,1%- -.?....% t T. , ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY r c" - FRANCISJ. CORNING DONE BY ME OR UNDER MY DIRECT SUPERVISION AND OA 6-2 .• h" ....; LS-10685 ::si Ar THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT r. 4.1A:: . II AS OF OCTOBER 01, 2010 0 (" ...• to/1,-/ 9ir 1 •............... '4iik.ik'ressiorstg-;;..•` -111‘vratmgwill'` 01&Ai, .1b ,00 SPY ISLAND DRILL SITE IA if WELL CONDUCTORS f k. AS—BUILT LOCATIONS @r111 %ASV -44,. . CAD FILE:ENI3543D9 us operating DATE1:0/01/2010 ' DRAWING NO: PART: REV: Eni-3543—d9 1 OF 3 0 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 0 'C/C'/'.D DHS CC CC • c 0'cwH g -N i o�S Qs _ _ • r��Y1 �1 1�c. 1N `� Ser-. 17., Al�l W A.S.P. NADB3, 74. 1 f, LC) J 000 ,�l,�(� J W W� 6) N N 4 t1 .� CP 3 W W l tJ++"- 1 0� Na ut N NA N 00 W WO CA O" W W0 Wy, N o3 DETAIL A, SCALE: 1"�--80' SANDBAG TOE GRAvEE SHDUIR DEI ' cooY r Y a "Y DETAIL A \''t. S SPY ISLAND DRILL SITE == I (SID) CAE cs{OUIOE' - SANDBAG SCALE LEGEND 200 0 100 200 0 = WELL CONDUCTOR AS-BUILT THIS SURVEY t -- , 1'• - 200' Iiiiiiil �.e.,&agre SPY ISLAND DRILL SITE s� � WELL CONDUCTORS • AS-BUILT LOCATIONS 211(1 ,, ,. CAD FILE:EN 3543D9 US operating DA7ti0/01/2010 DRAWING NO: Eni-3543—d9 PART: 3 REO r REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 0 /•n :).,S CC CC Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane, NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. 'Y' 'X' Latitude (N) Longitude (W) F.N.L F.E.L Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70033127.209" 149°54'24.765" 797 1171 12.4 2 6053421.65 1651761.87 70033127.194" 149°54'25.000" 798 1179 12.4 3 6053420.07 1651754.10 70033127.179" 149°54'25.229" 800 1186 12.4 4 6053418.56 1651746.17 70033'27.164" 149054125.463" 801 1194 12.4 5 6053417.03 1651738.44 70033'27.149" 149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149054'25.925" 804 1210 12.4 7 6053412.44 1651714.77 70033127.104" 149054'26.391" 807 1226 12.4 8 6053410.91 1651706.96 70°33'27.089" 149°54'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70033'27.074" 149°54'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70033127.060" 149054127.084" 812 1249 12.4 11 6053406.32 1651683.39 70033'27.044" 149054127.318" 813 1257 12.4 12 6053404.80 1651675.51 70033127.029" 149054127.551" 815 1265 12.4 13 6053400.38 1651652.80 70033126.986" 149054'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70033126.971" 149054128.453" 821 1296 12.4 15 6053397.31 1651637.12 70033126.956" 149054'28.685" 822 1304 12.4 16 6053395.82 1651629.26 70033126.942" 149054'28.917" 824 1311 12.4 17 6053394.32 1651621.47 70°33'26.927" 149054129.147" 825 1319 12.4 18 6053392.78 1651613.58 70033126.912" 149°54'29.380" 827 1327 12.4 19 6053389.63 1651597.90 70°33'26.881" 149054129.843" 830 1343 12.4 20 6053388.17 1651590.00 70033126.867" 149054'30.076" 831 1351 12.4 21 6053386.60 1651582.24 70°33'26.852" 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70033'26.838" 149054130.538" 834 1366 12.4 23 6053383.64 1651566.41 70033126.823" 149054130.773" 836 1374 12.4 24 6053382.12 1651558.61 70033126.808" 149054131.003" 837 1382 12.4 25 6053377.65 1651535.94 70033126.764" 149°54'31.673" 842 1405 12.4 26 6053376.14 1651528.13 70°3326.750" 149054131.904" 843 1413 12.4 27 6053374.53 1651520.23 70°33'26.734" 149054132.137" 845 1421 12.4 28 6053373.11 1651512.46 70033'26.720" 149054132.366" 846 1428 12.4 29 6053371.56 1651504.49 70033126.705" 149054132.602" 848 1436 12.4 30 6053370.06 1651496.66 70033126.690" 149054'32.833" 849 1444 12.4 31 6053367.05 1651480.97 70033126.661" 149054'33.296" 852 1460 12.4 32 6053365.47 165147.3.16 70°33'26.646" 149054'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70033'26.631" 149054133.762" 855 1476 12.4 34 6053362.44 1651457.37 70033126.616" 149054'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70033'26.601" 149054134.225" 858 1491 12.4 36 6053359.33 1651441.62 70°33'26.586" 149054134.459" 860 1499 12.4 37 6053356.19 1651425.30 70033'26.555" 149054134.941" 863 1576 12.4 38 6053354.74 1651417.32 70033126.541" 149°54'35.177" 864 1524 12.4 if~ S •? otl4440 SPY ISLAND DRILL SITE �� iiiiiiwo ' WELL CONDUCTORS AS-BUILT LOCATIONS O CAD FILL. 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N m m en m en m in mm O B. -v ci u ui U • 0 0 0 0 _ 0 Attachment 8 1/4 Mile Scan Report J 0) 0) ,-- 0 O O OOOd o _ _ O0. d O J N OO w o ¢Y�°rae cOv O O c0 N ,L mco •P7if. o 04, .o . l • g`vo 0L y • I�eO ° . � '1 • p� fieo ¢ti e ¢4 dii8 �0aa 3�too ¢t yp .4sse ° a .t gf .,cz4t � , 0 CU o CL, ° 4 re t40 �1q� m64E'a °/.4! `e•Poie� �L m �l 863,_ `ecr ,f ,.. ° � 0c¢ � ° P , ° ani eereC I N p9 r O ` Q�` �t ergZ o l/ o z - 0a'Q = o • . Qls Y . ° 3503 ND f ,_11, e`er yJFB °I/ aCa N F CO, A ` e m p ° ' t`b �e % 0 0a l '( 6j { 3i i aly ° Q , r� *Co - O 2 rc l ° f Y VrE, 6° j O :,% M _dY 11 E. ( 4 I oi„ {I 1°, e O ,s` 1fip ¢,�A .7 06 8`09 /1 tr gleI cr o3rNf H a CO 4 I edQr: o ° ° N 1 oie 44 et, � � Oloy I oW 4 ° • CM �Y o o � OZ N p ^ nM 6 ° �Plrf I N f ° 1 0IIe`o� � ° s 0 (r r o l Ti, ° ° r I I c I "F-��� ° ei °\ W� 1,40,,!'• „n O ° JF { 101.3 f I I I I I ” o i I II I I 1 0 ca gl ry x 71 8 2 { I 1 I { I te = 3 , A°- Ek I I I I i LI N s o a I I 1 I 1 0 o o 4--- a 1 1 0 I ! � I I I I o 1 /*3445 1 ► I I 1 - no s E I 1 I I m s o i a I I I I O 12 m -� __ M I 1 m .n o 0 I I r I I i I I I II I II I OI 1 1 I I 1 I'� ao I I I I I I I I a qN m LL II I II II II I 1 ! 1I I i oo Vik /1 Mavo 0 ,^ p U q Z f m m O O O O Oo O 0 O O o Oo Oo Oo ° N g O O O O O O O O O N N M V O m m F l8)000Z L=aleoS IS)SN V1 .( SI34-W6(P6b)Anti-Collision Detailed Report Analysis Method: Normal Plane Distance Unit ft Depth Interval: Every 100.00(ft)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-24hr Time: January 15,2015-08:57 North Reference: True Analysis Machine: AKA-DEC-9010 Client Eni Petroleum Database I Project: localhost)drilling-Nikaitchuq 2.8 572 Version/Patch: 2.8.572.0 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters. All local minima indicated. Results filtered:Depth 13600.00 ft ce MD<=23866.22 ft,Ct-Ct separation se 1500.00 ft Results highlighted:EOU-EOU separadon o 1320.00 ft Anti-Collision Rules Used Rule Set Name DSM AntCollision Standard 500205.1/5.2 Exemption Risk Level: Minor 81112161/01 RISK Level Rule Type Rule Label Roto Rule SLB Alert Zone Threshold OSF=505002 v5.15.2 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.55002 v5.1/5.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold 05F=1.05002 v5.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule 5002 v5.1/5.2 Major CT_CT MAD=3281(ft) SLB Alert Zone Threshold CtCt<=15m 5002 v5.15.2 Alert CT_CT MAS=49.21(ft) • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-W6\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 1 of 13 Reference Trajectory Summary Field: Nikeitchuq Well: 5134-6 • Structure: Spy Island Borehole: 5134-456 Slot SP34 Trajectory: SI34-W6(P66) Client: Eni Petroleum Type: Del Plan • Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grld Convergence Angle: 0.08837540° Grid Scale Factor: 0.999900148 Magnetic Declination: 18940° Magnetic Declination Date: February 28,2015 MagneBc Model: BGGM 2014 Reference Point j{gablpB En= Era=ado" Structure Unc slot Una 6053610.330(BUS) 511426.580(PUS) 54.100(ft)MSL 0.000(5)(1 sigma) 0.000(ft)(1 sigma) • • Tralectory Error Model:ISCWSAO 3-0 98.000%Confidence 2.7956 sigma • Survevinc Pro%While Drilling Description Part MD Front(ft) MD To(11) EOU Freq(ft) Survey Tool Type Hole Sloe(In) Casing Diameter(In) Borehole I Survey 1 0.000 41.000 7/100.000 SLB NSG+SSHOT-DepsrOrly-No Globs 16.000 13.375 SDI-W6/51344b(P60) 1 41.000 1050.000 1/100.000 SLB NSG*SSHOT-NOGluba 16.000 13.375 SI34-W6/513445b(P6b) 1 1050.000 2550.000 1/100.000 SLB MWD+SAG-No Globe 16.000 13.375 0134-Vs8/S134-N.8(P6b) 2 1050.000 2903.598 1/100.000 SLB MWD+GMAG-No Globa 18.000 13.375 SI34-Vs6/SI34-VW(P6b) 2 2900.508 4400.000 1/100.000 SLB MWDa0AG-No Globe 12.250 9.625 SI34-1115/6134W6(P6b) 3 2900.598 13640.701 1/100.000 SLB MWD+GMAG-No Global 12.250 9.625 ' 0134-W6/S13416(Kb) 3 13640.701 15140.000 1/100.000 SLB MWD+SAG-No Globa 8.750 5.500 S134-W6/5134446(P6b) 4 13640.701 23988.221 1/100.000 SLB MWD+GMAC-No Globs 8.750 5.500 SI34-W6/0134-N6(P6b) • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-W6\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 2 of 13 Offset Trajectory Summary Offset Selection Criteria: Offset Selection Citrons:Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set In a borehole-All Non-Def Plans when no Def-Plan Is set in a borehole Offset Seketlon Summary Wells Selected 3 Boreholes Selected:5 Definitive Surveys Selected:3 Non-Det Surveys Selected:1 Definitive Plans Selected:2 Non-Det Plans Selected:0 Total Trajectores:6 OSF filter in detailed report Notre •Excluded:The trajectory was analyzed and fully passed all criteria so the detailed results have been excluded from this report for clarity. Trajectory Borehole WNI TYPO Passing Excluded• 0113-03 0113-03 0113-03 Def Survey SP36-W5L1 SP36-WeL1 5P36-N5 Def Survey SP36-N5 SP36-WS SP36-1h6 Dot Survey SP31-W7(PSb) SP31-W7 SP31-W7 Def Plan SP31-W7 current SP31-W7 SP31-W7 Non-Def Survey SP31-W7L1(P3b) 5P31-W7L1 SP31-W7 Del Plan • Drilling Office 2.8:572.0 Nikaitchuq\Spy Island\SI34-VV6\SI34-VV6\SI34-VV6(P6b) 1/15/2015 9:07 AM Page 3 of 13 Field: N/keitchuq Well: 0113-03 Structure: 001008 Point Borehole: 0113-03 Slot OP/3 Trajectory: 0113-03 Client: ENI Type: De/Survey Coordinate System: 1,44027 Alaska Stele Wane,Lorre 04,US Feet North Reference: True Grid Convergence Angle: 0.12847606' Grid Scale Factor: 0.999900315 Magnet*Declination: 20.662° Magnetic Declination Date: October 25,2011 Magnetic Model: BGGM 2011 Reference Point /RUMOR Eastln* E maton Structure Ulu. Slot Une. 6036524,380(ftUS) 516654.550(ftUS) 53.200(ft)MOL 0.000(0)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Survevlte Progj As Drilled Description MD From(ft) MDT*(ft) BOO Freq Survey Tool Type Hole Sloe(In) Casing Diameter(In) Borehole/Survey 0.000 41.000 1/98.425 SLB GYRO-MWD-Depth Only-No Globe 16.000 13375 0113-0310113-03 41.000 41.000 ActShs SLB GYRO-MWD-Depth Only-No Globe 16.000 13375 0113-03/0113-03 41.000 1013.510 AclStrs SLB_GVRO-MWD-No Gioba 16.000 13.375 0113-03/0113-03 1013.510 2577.280 Act-Stns SLB_MWD0GMAG-No Globe 16.000 13.375 0113-03/0113-03 2577280 2659.280 ActShs SLB_MNA-INC ONLVNO-No Globe 12.250 9.625 0113-03/0113-03 • 2659.260 21262.440 Act$hs SLB_MWD*GMAG-No Globe 12.250 9.625 0113-03/011303 21262440 21327.000 Act-Stns SLB BLIND+TREND-No Globe 12.250 9.625 0113-03/0113-03 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSE Controlling Rule Status (0) (tt) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (8) All local minima indicated. Results filtered:Depth 13600.00 ft<=MD<=23968.22 ft Results Mitred:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation c 132000 ft Trace 1 Trace 2 Trace 3 End of results • • • • • • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\S134-W6\S134-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 4 of 13 Field: Nikeitcnuq Well: SP36-W5 Structure: Spy Island Borehole: SP36-W5L1 Slot SP36 Trajectory: SP36-WSL1 Client: En/Petroleum Type: Del Survey Coordinate System: NAD27 Aleske Stele Plane.Zone 04.US Feel North Reference: True Grid Convergence Angle: 008As5655° Grid Scale Factor: 0.999900148 Magnetic Declination: 19.778° Magnetic Declination Date: July 31.2013 Magnetic Model: BGGM 2013 Reference Point Nor ;9111 liana J=lewabon Shucture Unc. Slot Unc. 6053607.230(BUS) 511410.830(ftUS) 53670(tri MSL 0.000(8)(1 sigma) 0000(to(1 sigma) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 signs Surveying Prop;As Drilled Description MD From(R) MD To(ft) EOU Freq Survey Tool Type Hole Size(In) Casing Diameter(in) Borehole/Survey 0.000 40.570 1/98.425 SLB_NSG+SSHOT-Depth Only-No Global 16.000 13.375 SP36-N5/SP36-Nb 40.570 40.570 Act-Sins SLB_NSG+SSHOT-Depth Only-No Global 18.000 13.375 SP364A5/SP36-N5 40.570 914.910 ActSfis SLB NSG+SSHOT-No Globe 18.000 13.375 SP36-N5/SP36-05 914.910 3400.090 Act-Stns SLB MWD+GMAG-No Globe 16.000 13375 SP36-W5/SP36-N5 3400.090 11409.980 Act-Sins SLB_MWD+GMAG-No Globe 12.250 9.625 SP36-MD/SP36-N5 11409.960 11437.000 Act-Stns SLB MWD+GMAG-No Globe 12.250 9.825 SP36-W5L1/5P36-N6L1 11437.000 11852.980 ActSfis SLB MWD-INC ONLY FILLER-No Globe 8.500 5.500 SP36-W5L7/SP36-N5L1 11652.980 20804.170 Act-Stns SLB_MWD+GMAG-No Globe 8.500 5.500 SP36-NNL1/SP36N5L7 20804.170 20870000 ActSOs SLB BLIND+TREND-No Globe 8500 5500 SP36-N5L1/SP364A6L1 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (ft) (ft) (6) (ft) (ft) (1t) (°) (ft) (ft) (0) All local minima indicated. Results filtered:Depth 13600.0011 no MD co 23968,22 ft Results filtered:Ct-Ct separation ss 1500.00 ft Results highlighted:Ct-Ct separation co 1320.00 ft Trace 1 Trace 2 15781.27 3519.74 -4547,75 -12029.46 14900.00 352565 -3679.62 -10058.18 66.39 2153.98 10321 2084.85 31.59 OSF1.50 Pass Trace 3 15845.26 3521.31 -4488.77 -12054.24 14900.00 3525.65 -367982 -10058.18 68.05 2153.83 103,37 208459 31.54 OSF1.50 Pam Trace 4 14906.51 3541.78 5237.18 -11505.85 15100.00 352602 -3548.08 -10203.83 37.09 2129.55 195.40 1998.96 16.42 OSF1.50 Pam 14988.42 3540.01 5185.49 -11569.17 15081.57 3526.10 -3573.38 -10179.89 40.31 2128.191 184.31 200489 17.41 01F1.50 Pam 15118.06 3535.80 -5096.84 -11663.42 15000.00 3525.92 -3613.67 -10133.35 45.62 213083 168.21 2018.36 19.10 OSF1.50 Pam Trace 5 15934.59 3523.82 -4406.02 -1208779 1.95.00 3525.92 -361367 -10133.35 67.99 2108.95 105.82 2038.07 30.16 OSF1.50 Pam Trace 6 1375249 3514.33 -5802.93 -10439.91 15600.00 3516.91 -3215.06 -10581.58 356.66 239207 327.11 2173.67 11.00 OSF1.50 Pass ' 13866.56 3521.53 5605.16 -10553.70 15500.00 3521.41 -3281.64 -10507.10 1.15 2324.00 318.11 2112.92 11.06 OSF1.50 Pam 13999.09 3528.70 5598.42 -10685.5 15400.00 3523.97 -3348.35 -10432.66 6.31 2282.27 301.45 2080.97 11.29 OSF1.50 Pam 14151.43 3535.31 5571.42 -1083575 15300.00 3525.07 -3415.54 -10358.60 12.22 2208.08 28245 201945 1176 OSF1.50 Pam 14325.51 3540.62 -5523.83 -1100285 15200.00 3525.55 -3482.12 -10283.99 19.01 2184.47 258.38 199190 12.61 OSF1.50 Pero 14502.62 3543.49 -5454.68 -11185.94 1510826 3525.99 -3542.63 -10215.03 25.W 2135.53 23205 1980.50 13.86 OSF1.50 Pam 14519.24 3513.62 -544720 -11180.78 15100.00 3526.02 -3548.08 -10208.83 28.63 213346 229.54 1980.10 14.00 OSF1.50 Pam Trace 7 18029.56 3526.07 -4318.01 -12123.41 15100.00 3526.02 -3548.08 -10208/3 6809 2063.59 108.51 1990.92 28.77 OSF1.50 Pam Trace 9 14778.91 3543.08 -5310.78 -11401.47 15100.00 352602 -3548.08 -1020883 33.62 2128.33 206.09 1990.61 15.56 OSF1.50 Pam Trace 10 Trace 11 16121.17 3526.28 -4232.98 -12157.50 15200.00 352555 -3482.12 -1028389 58.14 2018.37 11125 194388 27.44 OSF1.50 Pam Trace 16 . Trace 17 • 16210.73 3526.39 -4149.85 -12190.81 15300.00 3525.07 -3415.54 -10358.60 68.12 1973.88 113.93 157.60 26.20 OSF1.50, Pam Trace 20 Trace 21 16267.63 3526.47 -4097.18 -12212.29 1540000 3523.97 -3348.35 -10432.66 67,11 1930.75 116.31 1852.88 25.10 OSF1.50 Pam Tram 24 13617.93 3505.00 -5591.79 -1030614 15500.00 3521.41 -3281.64 -1050710 355.41 2318.93 328.83 2099,52 10.61 OSF1.50 Pass Trace 25 1631717 3526.58 -4051.71 -12232.00 15500.00 3521.41 -3281.64 -10507.10 65.79 1888.99 119.13 1809.24 23.97 OSF1.50 Pam Trace 28 13685.84 3508.74 -5597.69 -10373.63 1560000 3516.91 -3215.06 -1058158 35517 2391.70 33021 2171.24 10.89 OSF1.50 Pam Trace 29 1636782 3528.72 -4005.87 -12253.07 15600.00 3516.91 -321506 -10581.58 64.38 1849.15 122.48 1787.17 2282 OSF1.50 Pam 1641924 3526.89 -3959.46 -12275.66 15700.00 3513.37 -314777 -10655.46 6296 1812.21 126.47 1727.57 21.65 OSF1.50 Pass 16471.87 3527.10 -3912.88 -12299.78 15800.00 3510.10 -3080.08 -10729.00 61.53 1777.88 131.14 1890.13 20.48 OSF1.50 Pam 16525.61 3527.34 -3885.50 -12325.50 15900.00 3507.17 -301137 -10801.60 60.07 1747.06 136.45 1655.76 19.33 OSF1.50 Pam 16580.41 3527.65 -3818.01 -12352.85 18000.00 3504.00 -294209 -10873.64 58.59 1719.26 142.33 1624.05 1824 OSF1.50 Pam 16636.26 3528.17 -3770.31 -12381.88 18100.00 3501.84 -2872.11 -10945.03 57.11 1894.89 14887 1595.25 17.20 OSF1.50 Pam 16692.76 3528.95 -3722.77 -12412.39 16200.00 3502.45 -280226 -11016.59 55.70 1672.22 155.45 156925 18.23 OSF1.50 Pam 16749.74 3529.99 -3675.58 -12444.32 16300.00 3502.16 -2733.05 -11088.77 54.24 1651.26 162.68 154248 15.31 OSF1.50 Pam 16807.04 3531.29 -362894 -12477.59 16400.00 3501.43 -2665.40 -11162.41 52.75 1630.65 170.20 1516.85 14.45 OSF1.50 Pam 16864.81 3532.86 -3582.78 -12512.27 16500.00 3500.40 -2598.31 -11236.55 51.22 1611.73 178.02 1492.73 13.65 OSF1.50 Pam 16923.12 353471 -3537.07 -12548.42 16600.00 3501.45 -2531.21 -11310.68 49.75 159526 185.99 1470.94 12.93 OSF1.50 Pam 16997.10 3537.36 -3480.20 -12595.68 16700.00 3505.49 -2465.70 -11386.12 48.89 1579.01 192.30 1450.48 12.37 OSF1.50 Pam 17095.24 3538.55 -3405.01 -12658.73 16800.00 3511.27 -240146 -1146254 4899 1561.64 195.46 1431.01 1204 OSF1.50 Pam 17193.42 3536.80 -3329.83 -12721.83 16900.00 3515.55 -2338.30 -11539.95 49.20 154287 198.63 1410.12 11.70 OSF1.50 Pam 17291.42 3534.94 -3254.78 -12784.83 17000.00 3516.67 -2275.84 -11618.02 49.30 1523.19 201.85 1388.29 11.37 OSF1.50 Pam 1738971 3533.07 5179.51 -1284801 17100.00 3515.70 -221239 -11&95.31 49.33 1504.77 205.09 1367.71 11.05 OSF1.50 Pam 17487.98 3531.20 3104.25 -12911.18 17200.00 3516.47 -2148.85 -11772.52 49.42 1486.48 208.32 1347.25 10.75 OSF1.50 Pam 17571.66 3529.85 -3040.30 -12985.13 17300.00 3519.20 -2084.52 -11849.03 49.01 1469.45 21349 1328.80 1037 OSF1.50 Pam 17643.93 3528.92 -2985.83 -13012.62 17400.00 3523.50 -2020.19 -1192547 48.14 1454.10 220.32 1306.89 9.94 05F1.50 Pam Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-W6\SI34-006\SI34-W6(P6b) 1/15/2015 9:07 AM Page 5 of 13 Trajectory:5134-666(P6b)Vs.SP36-W5L1 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset NO Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (6) (ft) (1t) (ft) 5) (ft) (ft) (ft) (') (0) (ft) (ft) 17737.90 3531.09 -2915.78 -13075.24 7500.00 3528.26 -1954.94 -12001.10 48.08 1441.19 224.33 1291.30 9.67 OSF1.50 aSS 1783704 3532.35 -284190 -13141.33 760000 3533.15 -188949 -12076.54 4822 1428.59 227.62 127651 945 08F1.50 ass 17936.13 3533.60 -2768.05 -13207.39 7700.00 3538.04 -1824.30 -12152.22 48.37 1415.65 230.94 1261.37 9.23 OSF1.50 aSS 18035.34 353486 -2894.10 -13273.53 7800.00 3541.80 -1758.56 -12227.48 48.47 1403.40 234.29 1246.88 9.02 OSF1.50 aSS 18134.41 353609 -2820.27 -13339.57 7900.00 3543.57 -1692.72 -12302.71 48.49 1391.22 237.67 1232.44 8.81 OSF1.50 ass 18233.63 3536.25 -2546.33 -13405.73 800000 3541.35 -1625.87 -12377.04 48.39 1360.39 241.11 1219.32 8.62 OSF1.50 aSS 1833321 3536.33 -2472.12 -1347214 8100.00 3538.88 -1557.45 -12449.91 48.28 1371.70 244.48 1208.39 8.44 OSF1.50 aSS 18432.90 3536.42 -2397.83 -13538.61 8200.00 3538.06 -1488.44 -12522.28 48.25 1363.79 247.80 1198.28 8.28 OSF1.50 aSS 18532.63 3536.51 -2323.51 -13605.11 8300.00 3538.06 -1418.93 -1259417 48.24 1356.56 251.18 1188.78 OSF1.50 ass 18614.06 3536.60 -2262.81 -13659.39 8377.04 3537.38 -1364.69 -12648.88 48.40 1351.94 253.22 1162.80 0 OSF1.50 aSS 18850.20 353687 -2235.68 -13683.27 840000 3536.93 -1348.38 -12665.03 48.93 1350.60 252.24 1182.12 8.06 OSF1.50 18778.89 3539.59 -2137.39 -13766.29 8500.00 3532.86 -1276.11 -12734.02 49.68 1344.41 251.82 117620 8.03 OSF1.50 ass 18878.43 354206 -2060.98 -13830.03 8600.00 3529.44 -1204.42 -12803.65 49.63 1338.90 255.27 11136.39 7.88 OSF1.50 956 18978.04 3544.53 -1984.52 -13893.81 8700.00 3528.82 -1133.17 -12873.81 49.49 1328.70 258.68 1155.92 7,73 OSF1.50 ase 19077.28 3546.99 -1908.33 -13957.37 880000 3530.36 .-1064.73 -12946.69 49.44 1316.59 26212 1141.52 756 OSF1.50 ass 1921436 3548.51 -180195 -14043.80 890000 3531.06 -999.35 -13022.35 5107 1299.17 28028 1125.32 7.51 OSF1.50 ass 19357.59 3545.08 -1687.86 -1413028 900000 3531.41 -934.34 -13098.33 53.22 1277.85 25752 1105.84 7.47 OSF1.50 956 1948172 3540.20 -1603.58 -14191.25 910000 3531.17 889.64 -1317458 53.74 1253.94 260.00 1080.28 7.26 OSF1.50 ass 1955905 353559 -1524.77 -14248.18 9200.00 3532.57 -803.54 -13249.59 54.01 1231.82 26345 105586 703 OSF1.50 ass 19656.41 3530.97 -1445.94 -1430513 930000 3537.33 -736.51 -13323.64 54.46 1211.06 26691 103279 6.83 OSF1.50 965 19772.91 352640 -1351.07 -14372.57 940000 354462 871.07 -1339890 55.98 1187.76 267.35 1009.20 668 OSF1.50 a. 1986940 3523.57 -127197 -14427.76 950000 3552.01 -605.54 -13474.06 5650 1163.82 270.75 982.99 6.47 OSF1.50 ass 19965.78 3520.74 -1192.96 -1448289 960000 3557.76 540.76 -13550.02 56.96 1138.85 27419 955.73 625 OSF1.50 ass 20039.37 3518.37 -1132.98 -14525.46 9700.00 356106 -477.71 -13627.55 56.16 1112.41 28097 92477 595 OSF1.50 965 2011045 3515.48 -1076.05 -1456792 9800.00 3561.96 -413.61 -13704.30 5507 1089.41 28842 896.80 5.68 OSF1.50 ass 2018217 3511.97 -1019.65 -1461207 9900.00 3565.73 -349.00 -13780.52 54.15 1069.64 29596 87201 543 OSF1.50 055 2025426 3507.83 -964.04 -14657.77 2000000 3570.40 -284.91 -13857.14 53.32 1051.73 303.53 849.04 521 OSF1.50 855 2032660 350214 509.40 -14704.93 20100.00 357342 -221.10 -13934.07 52.40 1035.82 31124 82800 500 OSF1.50 9613 2040145 3497.80 -85410 -14755.09 20200.00 3570.84 -15620 -1401009 51.28 1023.44 318.78 810.59 4.83 OSF1.50 Warning 2050088 3490.43 -78152 -14822.36 20300.00 3568.05 -91.17 -14086.01 51.58 101233 322.22 79719 4.72 OSF1.50 Warning 2059985 3483.07 -708.99 -14889.58 20400.00 3567.42 -25.72 -14161.80 5202 1001.97 32562 784.57 4.63 OSF1.50 Naming 20705.56 3475.32 83181 -14961.18 20500.00 3569.61 39.33 -14237.52 5300 991.33 327.78 772.49 455 OSF1.50 Warning 20839.37 3468.69 -531.64 -15049.86 2060000 3568.51 104.46 -14313.37 55.24 978.27 32497 78130 4.52 OSF1.50 Warning 20962.23 3486.22 -43726 -1512847 20700.00 3563.70 172.06 -14388.90 5647 96473 324.12 748.33 4.47 OSF1.50 Warning 21044.14 346516 -374.06 -15180.56 2080000 3555.44 241.04 -1445879 5507 33086 7170 4.33 OSF1.50 Naming 21085.88 3464.63 -34265 -15208.06 20870.00 354543 289.25 -14508.73 52370.91 . 1 OSF1.50 Naming End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-666\SI34-666\SI34-W6(P6b) 1/15/2015 9:07 AM Page 6 of 13 Field: Nikeitchcg Well: SP36-W5 Structure: Spy Island Borehole: SP36-W5 Slot SP36 Trajectory. SP36-W5 Client: Eni Petroleum Type: Del Survey Coordinate System: NA027 Alaska State Plane,Zone 04,US Fee! North Reference: True did Convergence Angle: 0.08825355° Grid Scale Factor: 0.999900148 Magnetic Declination: 19.811° Magnetic Declination Date: July 10 2013 Magnetic Model: BGGM 2013 Reference Point 009 6!0S Wang Elevation Structure Unc. Slaune. 6053607.230(ftUS) 511410.830(800) 53.670(ft)MSL 0.000(ft)(1 sigma) 0.000(5)(1 sigma) Tralectory Error Model:ISCWSAO 3-0 95.000%Cadldenee 2.7956 sigma Survevin9 Proq;As Drilled Description MD From(It) MD Ta(It) EOU Freq Survey Tod Type Hole Site(In) Casing Diameter On) Borehole I Sway 0.000 40.570 1198.425 SLB NSG+SSHOT-Depsl Only-No Glebe 16.000 13.375 SP36-W5 I SP36-0.5 40.570 40.570 Act-Stns SLB NSG+SSHOT-Depth Only-No Gleba 16.000 13.375 SP36-W5 I SP36-05 40.570 914.910 Act-Stns SLB NSG+SSHOT-No Gleba 16.000 13.375 SP38-W5 I SP36-1/5 914.910 3400.090 Act-Stns SLB MVot+GMAG-No Globo 16.000 13.375 SP36-W5 I SP36-15u5 3400.090 12360.330 ActSbrs SLB MWD+GMAG-No Gleba 12.250 9.625 SP38-5551 SP38-1/95 12360.330 21749.750 ActSOs SLB_MWD+GMAG-No Gleba 8.750 5.500 SP38-1A5/SP38-1A5 21749.750 21813.000 Act-Stns SLB BLIND+TREND-No Gleba 8.750 5.500 SP361A5 I SP36-005 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aram Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (0) (ft) (9) (0) (8) (ft) (M) C) (ft) (ft) (0) All local minima indicated. Results filtered'.Depth 13600.00 ft.=MD r-23969.22 ft Results filtered:Ct-Ct separation is 1500.00 ft Results highlighted:Ct-Ct separation on 1320.00 ft Trace 1 1533771 3526.35 -4928.27 -11803.87 14900.00 3518.50 -3583.94 -999815 5307 2251.21 137.46 2159.24 24.73 OSF1.50 Pass 15911.09 3523.16 -4427.79 -12078.96 14900.00 3516.50 -3583.94 -999815 67.76 2245.42 88.41 2186.15 38.51 OSFI.50 Pass Trace 4 15069.58 353755 -5130.85 -11629.12 15000.00 3518.31 -3517.99 -1007330 43.46 224104 19094 2113.42 17.69 OSFI.50 Pass 15245.48 353060 5001.43 -11747.87 14900.00 3516.50 -3583.94 -999815 50.61 2251.89 148.11 2152.82 22.95 OSFI.50 Pass Trace 5 14887.05 354206 -5248.90 -11490.14 15100.00 3519.39 -3451.73 -1014619 36.18 2243.03 220.35 2095.80 15.33 OSF1.50 Pass 15040.92 3538.50 -5150.53 -11608.30 15015.71 3518.62 -3507.60 -10085.08 42.311 2240.491 195.44 2109.87 17.27 OSF1.50 Pass 15500.29 3520.19 -4795.19 -11896.97 14900.00 3516.50 -3583.94 -999815 57.37 2252.26 119.79 2172.07 28.42 OSF1.50 Pass Trace 6 374380 3513.75 -5602.39 -10431.26 5700.00 3531.30 3053.88 -10596.93 35665 2553.95 35417 2317.51 10.84 OSF1.50 Pass 3839.48 3519.80 -5605.45 -10526.67 5600.00 3532.02 -3121.11 -10522.91 0.35 2484.37 345.94 2253.42108 OSF1.50 Pass 3948.67 3526.12 -5601.18 -10635.57 5500.00 3531.18 -3188.21 -10448.77 4.54 2420.20 33501 2196.54, 1 OSF1.50 Pass 4073.85 3532.17 -5586.14 -10759.66 5400.00 3527.58 -3254.09 -10373.63 9.29 2363.79 320.52 2149.78 11.09 OSF1.50 Pass 4214.93 3537.52 -5556.33 -10897.39 5300.00 3522.62 -3319.08 -10297.79 14.65 2316.26 301.96 211483 11.54 OSF1.50 Paso 4369.68 3541.57 -5508.32 -11044.37 5200.00 3519.71 -3385.14 -10222.79 2062 2278.70 27929 2090.18 12.27 OSF1.50 Pass 4480.27 3543.27 -5464.48 -11145.86 5133.23 3519.31 -3429.64 -10173.01 24.95 2255.57 261.87 2080.66 12.96 OSF1.50 Pass 4537.35 3543.75 -5438.85 -11196.85 5100.00 3519.39 -3451.73 -10148.19 27.20 2246.97 252.57 13.39 OSF1.50 Pont 4550.24 3543.82 -5432.78 -11208.22 5092.59 3519.40 -345665 -10142.65 27.71 2245.24 250.41 207791 13.49 OSF1.50 Pass • Trace 7 16098.85 352623 4253.70 -12149.19 15100.00 3519.39 -3451.73 -10148.19 67.98 2155.74 93.58 209303 34.91 OSF1.50 Pass 16188.41 352635 .4170.56 -12182.51 15200.00 3519.71 -3385.14 -10222.79 67.98 2111.27 96.44 2046.64 33.16 05F1.50 Pont 16254.31 3526.45 4109.45 -12207.16 15300.00 3522.82 -3319.08 -10297.79 67.41 2066.49 100.03 1999.48 31.28 OSF1.50 Pat 1630183 3526.54 -4065.92 -12225.71 15400.00 3527.58 3254.09 -1037363 66.36 2022.19 104.96 195189 29.16 OSF1.50 Paw 16350.20 3526.68 -4021.65 -12245.68 15500.00 3531.18 3188.21 -10448.77 65.25 1980.79 110.81 1908.59 27.04 OSF1.50 Paw 16400.04 3526.82 -3976.66 -12267.14 1560.00 3532.02 -3121.11 -10522.91 64.02 1942.76 116.95 1864.47 25.12 OSF1.50 Paw 16450.79 3527.01 -3931.35 -12289.98 15700.00 3531.30 -3053.88 -10596.93 62.73 1906.94 124.03 1823.93 23.23 OSF1.50 Paw 16502.38 352723 3885.83 -12314.23 15800.00 3530.46 -2988.77 -10671.06 61.41 1873.06 131.54 1785.04 21.51 OSF1.50 Paw 16554.80 3527.49 -3840.12 -12339.93 15900.00 3529.06 -2919.41 -1074496 60.05 1841.64 139.61 174824 19.92 OSF1.50 Paw 1660844 3527.88 3793.99 -12367.28 16000.00 3527.57 -2851.82 -1081864 58.67 1812.72 148.02 1713.71 18.48 00F1.50 Paw 1666272 3528.51 -3747.95 -12396.02 16100.00 3526.29 -2784.59 -10892.66 57.28 1785.54 156.72 1680.74 17.19 OSF1.50 Paw 1671789 3529.38 3702.02 -12426.22 16200.00 3525.71 -2717.35 -10986.68 55.88 1760.64 165.72 1649.83 16.02 OSF1.50 Paw 18773.05 3530.49 -3656.51 -12457.72 10300.00 3525.84 -2651.59 -11042.01 54.48 1736.12 175.01 1619.11 14.96 OSF1.50 Paw 1682895 3531.86 -3611.33 -12490.61 16400.00 3526.19 -2586.37 -11117.82 53.07 1713.22 184.58 1589.84 13.99 OSF1.50 Pont 1668556 3533.49 -3586.41 -12525.00 1650.00 3528.17 -2520.38 -11192.93 51.62 1693.72 194.42 156378 13.13 OSF1.50 Paw 18942.70 3535.38 -3521.92 -12560.82 18600.00 3525.76 -2453.94 -11267.69 50.13 1677.16 204.43 1540.54 12.38 OSF1.50 Paw 17029.24 3538.21 -3455.58 -12616.31 16700.00 3524.30 -2387.17 -11342.12 49.55 1662.91 209.85 1522.88 11.94 OSF1.50 Paw 17127.68 3538.05 -3380.17 -12879.58 16800.00 352150 -232031 -11416.42 49.42 1648.98 213.31 1506.45 11.64 OSF1.50 Paw 17226.71 3536.17 -3304.33 -12743.24 10000.00 3517.61 -2253.33. -11490.58 49.34 1635.27 216.69 1490.48 11.36 OSF1.50 Pass 17325.70 353429 3228.53 -12806.86 17000.00 3513.53 -2186.58 -11564.92 4926 1621.26 220.01 1474.26 11.10 OSF1.50 Pont 17424.66 3532.41 -3152.74 -12870.48 17100.00 3511.27 -212001 -11639.51 49.24 1606.94 223.29 145776 10.84 OSF1.50 Pont 17523.47 3530.53 -3077.08 -12933.99 17200.00 3512.63 -2053.98 -11714.58 49.35 1591.85 226.59 1440.46 10.58 OSF1.50 Pass 17596.92 3529.72 -3021.17 -12981.62 1730000 3513.25 -198827 -11789.96 48.48 1577.08 234.22 1420.61 10.14 OSF1.50 Pass 17671.33 3530.24 -2965.39 -13030.87 17400.00 3512.67 -1922.57 -11865.35 47.54 1564.05 241.85 1402.48 9.73 OSF1.50 Paw 17770.49 353150 -2891.50 -13096.97 17500.00 351272 -1857.25 -11941.06 47.49 1551.18 245.27 1387.34 9.52 OSF1.50 Pont 17869.55 353276 -2817.66 -13163.01 17600.00 3517.54 -179218 -1201683 47.62 1538.04 248.61 1371.97 9.31 OSF1.50 Paw 17968.34 3534.01 -2744.04 -13228.86 17700.00 3524.88 -1728.12 -121193.26 47.84 1523.73 251.99 1355.41 9.10 OSF1.50 Paw 18067.35 3535.27 -2670.25 -13294.87 17800.00 3528.80 -1663.49 -12169.46 47.94 1510.02 255.48 1339.37 8.89 OSF1.50 Paw 18166.38 3536.19 -2596.45 -13360.89 17900.00 3528.86 -1597.90 -12244.93 47.90 1497.50 259.04 1324.48 8.70 OSF1.50 Paw 18265.69 3538.28 -2522.44 -13427.11 18000.00 3527.94 -1531.63 -12319.82 47.86 1485.89 262.60 1310.50 8.51 OSF1.50 Paw 1836482 3536.36 -2448.49 -1349328 18100.00 3527.60 -1465.93 -12395.20 47.84 1473.52 266.12 129578 8.33 OSF1.50 Paw 18463.91 3536.45 -2374.72 -1355929 18200.00 3530.35 -1401.41 -12471.54 47.94 1459.64 269.57 1279.81 8.15 OSFI.50 Paw 1856280 3536.54 -2301.03 -1362523 18300.00 3534.10 -1337.34 -12548.24 48.08 1445.20 273.02 1262.86 7.96 OSF1.50 Paw 18664.86 3537.06 -2224.61 -1369288 18378.20 3538.75 -1287.06 -12608.07 49.15 1433.81 271.39 1252585 OSF1.50 Pass 18702.75 3537.74 -2195.80 -1371749 184 000 3537.48 -1272.97 -12624.68 49.81 1430.33 26923 1250.51,, . OSF1.50 Pass 18810.01 354037 -2113.50 -1378622 18500.00 354132 -1207.89 -12700.52 50.21 1413.82 271.16 1232.72 7.84 OSF1.50 Pass 18908.69 3542.81 -2037.75 -13849.41 18600.00 3545.02 -1142.53 -12776.10 50.26 1397.65 274.67 1214.20 7.65 OSF1.50 Pass 19007.29 3545.25 -1962.06 -1391255 18700.00 354916 -1077.48 -12851.94 50.33 1381.08 278.18 1195.29�f OSF1.50 Paw 1911203 3547.80 -1881.63 -1397958 1880000 355423 -1012.76 -1292800 50.70 1364.11 280.47 1176. 7 OSF1.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-W6\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 7 of 13 Trajectory.5134-446(P6b)Vs.SP36-V5 Mini Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Sopa ration Clearance OSF Controlling Rule Status ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) {0) 9257.10 3548.02 -1768.22 -14070.03 890000 3560.62 -947.84 -1300350 5297 1345.38 274.88 1181.80 7.38 05F1.50 Par 9393.48 3543.44 -1658.84 -14151.33 900000 356753 -883.48 -13080.02 5520 1322.67 27064 114192 735 00F1.50 Paw • 9490 26 3538 85 -1580 47 -14207 94 9100 00 3571 48 -818 61 -13156 01 55 60 1299 26 274 19 1116,�14 7 137 8133 OSF1 50 Pass 9587.34 3534.24 -150187 -14264.73 920000 357168 -753.58 -1323198 5584 1275.89 277 � 72 1090. f OSF1.50 Pass 968430 3529.64 -1423.36 -14321.44 930000 3571.97 689.11 -13308.42 56.10 1251.85 281.19 1064 OSF1.50 Pass 980263 3525.53 -1326.70 -14389.57 9400.00 3571.81 623.16 -1338358 5726 1228.47 280.06 104143 OSF1.50 Pass 9900.22 3522.67 -1246.70 -14445.39 9500.00 356992 -555.59 -13457.27 57.34 1206.75 263.64 101733 6.40 OSF1.50 Pass 999237 3519.95 -1171.18 -14498.12 960000 357070 -488.34 -1353125 57.30 1184.77 28828 99225 6.18 OSF1.50 Pass 20062.02 3517.51 -1114.73 -14538.84 970300 3578.66 -422.10 -13605.71 56.55 1163.71 297.60 964.98 588 OSF150 Pass 20132.30 351447 -1058.75 -14581.23 9800.00 358511 -356.01 -13690.46 55.75 1144.65 307.04 93963 5.81 OSF1.50 Pass 20203.42 3510.81 -1003.14 -14825.41 9900.00 3586.84 -289.67 -13755.25 54.74 1127.83 316.63 916.41 535 OSF1.50 Pass 2027506 3506.53 -948.21 -14671.19 20000.00 3584.51 -223.36 -13830.06 53.53 1113.10 326.33 895.22 513 OSF150 Pass 20347.07 350173 -894.15 -14718.51 20100.00 358006 -15607 -13903.90 52.19 1102.04 336.08 877.66 4.83 OSF1.50 Naming 20428.35 3495.80 -834.43 -14773.32 0Ee200 3578.86 -88.57 -13977.65 51.53 1093.74 343.64 86432 4.78 OSF1.50 Warning 20527.12 3486.47 -762.19 -14840.28 20300.00 3584.04 -21.87 -1405177 52.24 1085.93 347.00 85427 4.70 OSF1.50 Naming 2062553 3481.16 690.21 -14906.99 20400.00 3591.55 4451 -14126.35 53.07 1077.68 350.30 843 OSF1.50 Naming 20741.38 3473.10 605.14 -14985.22 2050.00 3598.06 110.88 -14201.06 54.72 1089.06 349.59 835. OSF1.50 Naming 20881.89 3467.49 -499.23 -15077.36 2060000 301.38 177.62 -1427508 5728 1058.29 342.98 82931 4 OSF150 Naming 20994.09 3465.81 -41262 -15148.68 2070.0 3604.77 244.76 -1434929 58.31 104425 342.87 815.34 4.58 OSF1.50 Naming 2106180 348494 -36067 -15192.09 20800.0 3607.21 311.18 -14424.02 56.86 1030.30 35379 794.11 4.38 OSF1.50 Warning 2112002 3484.19 -31758 -1523121 2090000 360703 377.83 -14498.55 54.65 1020.19 36720 775.06 4.17 OSF150 Warning 21178.62 3483.45 -275.84 -15272.34 21000.0 360393 444.49 -14573.02 5222 101373 380.48 759.75 40 OSF150 Warning 21237.39 348271 -235.70 -15315.26 2110.0 359874 510.43 -14848.02 49.64 393.47 74752 3.86 OSF1.50 Waning 2128376 348214 -20530 -15350.26 2117905 3591.07 56209 -1470735 47. 403.63 739.97 3.76 OSF1.50 %%ming 21296.0 348199 -197.47 -15359.67 2120000 3588.25 575.71 -1472301 4674 i 406.30 738.30 3.73 OSF150 Naming 21353.91 3461.29 -161.50 -1540504 2130.0 357026 64024 -1479722 43.42 1011.99 418.9 383 OSF1.50 We ming 00 2141056 3460.61 -128.12 -15450.80 214 . 3544.49 703.43 -14870.28 39.70 1017.61 431 3.55 OSF1.50Wlming 2146572 3459.98 -9739 -1549660 2150.0 351273 765.75 -1494174 35.71 1027.45 44255 7 3.49 OSF1.50 %%ming 2151965 3459.37 6906 -1554248 2180.0 347777 82724 -1012.42 31.62 1041.47 453.10 739.08 Warning ning 2157243 3458.79 -43.03 -15588.39 21700.00 3440.65 887.91 -15082.71 2752 1059.57 462.62 750. OSF1.50 Naming 21823.72 3458.24 -19.37 -15633.89 2180000 3401.20 948.0 -15151.70 23.43 1082.92 485.18 759.13 OSF150 Warring 21630.31 3458.17 -1844 -15639.80 21813.0 3398.03 956.48 -15160.66 22.91 1088.29 489.89 759.37 3.33 05F150 Warring Trace 10 - Trace 11 160296 3525.67 -4342.68 -12113.46 15000.0 3518.31 -351799 -1073.30 67.80 220.55 90.92 2139.61 3669 00F1.50 Paw Trace 16 Trace 17 14782.72 3543.05 -5308.64 -11404.63 1510.00 3519.39 -3451.73 -10148.19 33.47 2242.17 22982 2088.63 14.69 OSF1.50 Paw Trace 22 Trace 23 , 13620.42 3505.18 -559201 -1037.62 1560000 353202 -3121.11 -10522.91 35562 2480.32 354.02 224397 10.53 OSF1.50 Paw 13688.7 3509.0 -5597.89 -1037586 1570.00 3531.30 -3053.88 -10596.93 355.48 2553.69 35606 2315.99 1078 OSF1.50 Paw End of results • • • • • • • • • • • • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-015\SI34-606\SI34-W6(P6b) 1/15/2015 9:07 AM Page 8 of 13 Field: Nikeifchug Welk SP31-W7 Structure: Spy island Borehole: SP31-W7 Slot SP31 Trajectory. SP31-W7 current Client: Eni Petroleum Type: Non-Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feel North Reference: True Grid Convergence Angle: 0.08855791° Grid Scale Factor: 0.999900149 Magnetic Declination: 19.029' Magnetic Declination Date: January 01.2015 Magnetic Model: BGGM 2014 Reference Point Northing Easgna Elevation Structure Unc. Slott 6053614 950(ftlJS) 511450.170(ftUS) 53.770(ft)MSL 0.000(ft)(1 sigma) 0.000(6)(1 sigma) Traleetory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7855 sigma Survevino Pro%As Drilled Description MD From(tt) MD To(tt) EOU Free Survey Tool Type Hole SW(In) Casing Diameter(in) Borehole/Survey 0.000 40670 1/98.425 SLB NSG+SSHOT-Depth Only-No Global 15000 13.375 SP31-W7/SP31-007 current 40.670 40.670 Act-Stns SLB NSG+SSHOT-Depth Only-No Global 16.000 13.375 SP31-007/SP31-007 current 40.870 1012.580 Act-Sins SLB_NSG+SSHOT-NoGbbal 18.000 13.375 SP31-W7/SP31-007 current 1012.560 2597.520 Act-Stns SLB MWD+GMAC-No Global 16.000 13.375 SP31-007/SP31-007 current bhe 3 2597.520 12905.140 Act-Slots SLB MWD+GMAG-No Global 12.250 9.625 SP31-007/SP31-007 current Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset IVO Offset NS Offset EW North Arm Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (9) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (6) All local minima indicated. Results filtered:Depth 13600.009<e MD<_23968.22 ft Results filtered:Ct-Ct separation ca 1500.00 ft Results highlighted Ct-Ct separation c 1320.009 Trace 1 End of results • • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-006\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 9 of 13 Field: Nikeitchuq Well: SP31-W7 Structure: Spy Island Borehole( SP31-W7 Slot: SP31 Treleetory: SP31-W7(P8b) Client: Eni Petroleum Type: Del Flan Coordinate System: NAD27 Alaska Stale Plane,Zone 04.US Feet North Reference: True Grid Convergence Angle: 008855791° Grid Seek Factor: 0.999900149 Magnetic Declination: 19.029° Magnetic Declination Date: January 01,2015 Magne80 Model: BOOM 2014 Reference Point Northing Dojo Eievadon Stuctu.Une. Slot Unc. 6053614.950 IftUSj 511450.170(RUS) 53.770(ft)MSL 0.000(6)(1 sigma) 0.000(5)(1 sigma) Trajectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Survevina Prod Mlle Drilling Description Part MD Front(R) MD To(It) EOU Freq(R) Survey Tool Type Hole SI»(In) Cuing Monet.(in) Borehole I Survey 1 0.000 40.670 1/100.000 SLB NSG+SSHOT-Depth Only-No Globe 16.000 13.375 SP31-007/SP31-007(P8b) 1 40.670 1100.000 1/100.000 SLB 666.3/SHOT-No Globe 16.000 13.375 SP31-W7/SP31-W7(P8b) 1 1100.000 2850.132 1/100.000 SLB MWD+SAG-No Globe 18.000 13.375 SP31-W7/SP31-W7(P8b) 2 1100.000 2850.132 1/100.000 SLB_MW9+GMAG-No Globe 18.000 13.375 SP31-W7/SP31-007(P8b) 2 2850.132 4350.000 1/100.000 SLB MWD+SAG-No Globe 12.250 9.825 5P31-W7/SP31-007(P8b) 3 2850.132 13207.309 1/100.000 SLB MWD+GMAG-No Globe 12.250 9.825 SP31-W7ISP31-W7(P8b) 3 13207.309 14700.000 1/100.000 SLB_MWD+SAG-No Globe 8.750 5.500 SP31-W71 SP31-W7(P8b) 4 13207.309 22950.592 1/100.000 SLB MWD+GMAG-No Globe 8.750 5500 SP31-W7/5P31-W7(P8b) Minima Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aom Et-Et Distance Separation Clearenca OSF Controlling RUM Status (5) (ft) (ft) (II) (5) (5) (5) (R) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 13600.00 ft r_MD<-23968.22 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted.CtCt separation r_1320.006 Trace 1 3639.09 3506.48 -5593.63 -10327.17 4900.00 3532.17 -7171.57 -10187.31 174.07 1584.33 397.98 1318.61 599 OSF1.50 Peas 372269 3512.31 -560088 -1041025 5000.00 3531.17 -7148.91 -1028471 174.71 1553.25 398.47 1287.19 5.86 OSF1.50 Pass 376881 3515.42 -560380 -1045617 5100.00 3530.17 -7126.28 -10382.10 176.70 1524.33 393.05 126189 OSF1.50 Pass 3815.80 3518.44 -5805.29 -10503.04 5200.00 3529.17 -710360 -10479.50 178.71 1498.54 387.15 12400 BlEB. OSF1.50 Pass 3863.59 3521.35 -5605.22 -1055074 5300.00 3528.17 -7080.95 -10576.89 180.77 1475.97 380.81 122169 5.83 OSF1.50 Pass 3912.06 352414 -5603.53 -10599.09 5400.00 3527.83 -7057.62 -1067413 182.82 1456.02 373.84 1206.39 586 OSF1.50 Pass 398102 3526.77 5800.18 -10847.86 5500.00 3529.89 -7031.99 -10770.76 184.79 1437.08 366.33 1192.45 5.90 OSF1.50 Pass 4010.42 3529.25 5595.11 -10696.94 5800.00 353443 -7004.05 -10866.86 186.67 1419.13 358.45 1179.78 5.85 OSF1.50 Pass 4080.32 3531.57 -5588.28 -10746.31 5700.00 3539.95 6975.20 -10962.25 188.52 1403.85 350.49 1189.58 6.02 OSF1.50 Pass 4110.68 353372 5579.68 -10795.88 5800.00 3545.39 6946.14 -11057.78 190.39 1391.40 342.08 1162.94 8.12 OSF1.50 Pass 4161.28 353567 -5569.26 -10845.36 5900.00 3549.82 6914.01 -11152.37 192.29 137942 333.18 1156.89 8.23 OSF1.50 Pass 4212.06 3537.43 5557.07 -10894.62 8000.00 355307 6877.91 -11245.58 194.24 1368.75 323.91 1150.40 6.35 OSF1.50 Pass 4263.12 3538.99 -554308 -10843.70 6100.00 3555.66 6839.43 -11337.82 196.23 1355.04 314.37 114505 6.48 OSF1.50 Pass 4314.55 354035 -5527.23 -10992.60 6200.00 3558.25 6800.92 -11430.08 198.21 1348.84 304.54 11434)/ 6.85 OSF1.50 Pass 4366.19 354150 -509.58 -11041.11 6300.00 3560.98 6761.43 -11521.80 . 270.19 1341.14 294.42 114446 6.86 OSF1.50 Pass 441791 354244 5490.18 -11089.04 8400.00 3564.27 -6718.17 -11611.99 202.14 1334.91 284.02 1145.15 707 OSF1.50 Pass 4489.72 3543.15 -5489.00 -11136.33 650.00 3568.01 6871.08 -11700.11 20407 1327.94 273.44 1145.24 7.31 OSF1.50 Pas 4521.83 3543.64 -5448.11 -1118290 6800.00 3672.15 6820.17 -11796.08 25.96 1320.25 282.89 1144 71.. 757 OSF1.50 Pees 4573.64 354391 -5421.50 -11228.73 670000 3576.63 6565.97 -11870.00 277.84 1312.29 251814 1144Q1 7.85 OSF7.50 Pass 482516 3543.96 5395.15 -11273.81 880000 3580.32 43510.35 -1195301 219.75 1306.25 24076 1145X11 8.17 05F150 Pas 467823 3543.77 -5367.11 -1131903 6900.00 358131 6451.99 -1203420 21177 1��2y(3�gggy000.49 229.66 114697 8.53 OSF7.50 Pass 763.15 3543 19 -531961 -11388 42 7000.00 3580 -6392.30 -1211443 21141 129584 22812 .9e, 153 OSF150 Pass 4842. 3542 60 -5274 96 -11454 09 10000 -6332.81 OSF150 Pass 44918.14 3540.96 -52134 3.35 -115391 658.30 7 00 379 720000 35078.89 22-6272.91 12355.1652 217 227419 215.34 (293.f4 20572215 a1155 69 llf 9.01 OSF1.50 Pas 5000.73 358.69 -5177.42 -11578.46 740000 3579.54 6153.53 -12435.35 219.47 129948 19588 116848 10.00 00F1.50 Pas 5053.07 3538.11 -5142.23 -11617.18 750000 3578.60 6083.00 -1251494 22152 1308.27 186.60 1183.46 10.58 OSF1 50 Pas 5104.93 3536.29 -5106.02 -11654.25 7800.00 3577.41 4032.11 -12594.25 223.58 1321.21 177.96 1211.16 11.19 OSF1.50 Pees 5156.21 3534.33 -5088.92 -11889.59 7700.00 357623 -5971.22 -12873.57 225.81 1335.70 158.26 1229.79 12.75 06F1.50 Pas 5206.85 2532.27 5031.07 -11723.17 7800.00 3575.04 -5910.33 -12752.89 227.62 1354.70 148.30 1255.43 13.80 06F1.50 Pas 525675 3530.10 -499265 -11754.93 7900.00 357385 -5849.44 -12832.20 229.60 1377.14 13923 128391 14.95 OSF1.50 Pas 530741 3527.78 -4952.54 -11785.79 8000.00 3571.84 5786.17 -12911.21 231.52 1402.42 13169 1314.29 18.12 06F1.50 Pas 5387.68 3524.03 -488801 -11833.70 810000 3568.74 -5726.40 -12889.78 232.18 1428.78 131.39 1340.78 18.45 OSF1.50 Pas 544188 3521.92 -4843.91 -11884.80 85.00 356564 -5864.62 -13088.36 233.93 1457.41 126.37 137275 17.45 OSF1.50 Pas 549530 3527.32 -4799.39 -11894.29 830000 3562.17 5801.10 -13145.50 235.70 1486.61 122.22 1404.73 18.41 OSP1.50 Pas 5548.73 3519.20 -475403 -11922.48 840000 3557.70 -5533.12 -13218.67 237.51 1512.81 118.87 1433.15 19.27 OSF1.50 Pas 5602.15 3518.56 -470788 -11949.35 850000 3552.45 -5460.85 -13287.57 239.38 1535.89 118.56 1457.78 19.58 OSF1.50 Pas 5855.50 3518.40 -4661.00 -1197484 8600.00 3548.72 -5384.54 -13351.92 241.24 1555.84 115.37 1478.52 20.43 OSF1.50 Pas 570857 3518.68 -4613.67 -1199884 8700.00 3540.51 5304.48 -13411.49 243.15 1572.66 115.42 1495.30 21.84 OSF1.50 Pas 5761.30 3519.37 -4565.97 -1202131 8800.00 3534.11 -5222.79 -13488.82 245.07 1589.83 117.68 1510.78 21.46 05F1.50 Pas 581353 3521.46 -4518.12 -12142.21 83300.00 3528.31 -5140.54 -1352538 . 246.96 1608.51 120.63 1527.68 OSF1.50 Pas 5892.61 3522.64 -4444.90 -12072.02 9000.00 6525.61 5055.60 -13578.06 247.83 1825.15 12228 1543 OSF1.50 Pas 5990.99 352539 -4353.77 -12108.97 9100.00 3524.78 -4965.22 -1362843 247.97 1639.37 124.44 1550.00 OSF1.50 Pas 6083.90 3526.21 -4287.57 -1214363 9210.00 3523.96 -4882.83 -13678.80 248.24 1853.87 127.83 1568.24 19.58 OSF1.50 Pas 6182.87 3526.35 -4175.71 -12180.45 9300.00 3523.14 -4798.27 -13728.85 248.27 1688.13 130.85 1580.49 19.29 OSF1.50 Pas 6429.08 3528.92 -3950.87 -12280.09 8400.00 3522.39 -4707.65 -13775.24 243.30 1675.87 135.54 158511 1870 OSF1.50 Pas 678490 3530.76 3646.88 -12464.60 98500.00 321.83 -4818.81 -13816.92 234.65 1664.22 171.68 1549.36 14.83 OSF1.50 Pas 700493 353761 -3474.21 -12800.70 9600.00 3521.51 -4524.33 -13854.98 230.61 168.92 199.03 1502.82 1240 OSF1.50 Pas 710234 358.48 -3399.58 -12663.29 9700.00 3521.20 -443177 -13892.80 330.81 1605.43 212.8 1470.12 11.96 05F1.50 Pas 7197.76 358.72 -3326.50 -1272462 9600.00 352089 -4339.20 -1393063 230.57 1574.88 20530 1437.61 11.57 OSF1.50 Pas 7292.97 3534.91 -3253.59 -1278583 9800.00 3520.58 -4246.63 -13968.48 230.52 154433 25.23 1405.10 11.18 OSF1.50 Pas 7388.44 358.09 -3180.48 -12847.19 21000.00 3521.94 -415447 -14007.22 230.41 1514.74 21067 1373.88 1084 OSF1.50 Pas 7484.41 3531.27 -3106.99 -12908.88 21100.00 352765 -4063.48 -14048.8 230.13 1487.67 213.17 1345.15 10.52 OSF1.50 Pas 760803 3529.72 -301278 -12888.91 20200.00 3534.39 -3973.24 -14090.83 228.74 1461.76 222.44 1313.06 9.90 OSF1.50 Pas 772375 358.91 -2926.32 -13085.81 20300.00 353878 -388472 -14137.12 227.88 1437.46 229.87 1283.80 9.12 OSF1.50 Pas 7821.70 3532.15 -2853.33 -13131.11 21400.00 3540.51 -3798.32 -14187.43 227.85 1417.35 232.94 128116 9.17 06F1.50 Pas 792024 3533.40 -2779.8 -13196.80 21500.00 3540.42 -3713.56 -14240.49 227.90 1400.39 28.14 124256 8.93 OSF1.50 Pas 801880 3534.65 -2706.43 -13282.50 2800.00 3540.26 -3626.87 -14293.66 227.98 1383.55 239.43 1223.52 8.70 06F1.50 Pas • ii • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-006\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 10 of 13 Trajectory.5134-V (P6b)Vs.SP31-W7(PBb) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset WD Offset NS Offset EW North Azim Ct-Ct Dianne Separation Clearance OSF Controlling Rule Status (ft) (ft) (ft) (ft) (ff) (ff) (6) (1t) (") (6) (ft) (6) 18117.37 3535.91 -2632.97 -13328.21 20700.00 3540.11 -3544.18 -14346.84 228.01 1388.72 242.75 1204.48 8.48 OSF1.50 Par 18218.27 353623 -255927 -13394.15 2080000 3539.93 -3459.95 -14400.74 228.02 1350.72 246.08 1186.27 8.27 OSF1.50 Par 18315.45 3536.32 -2485.35 -13460.29 20900.00 3539.67 -3377.57 -14457.41 228.03 1338.02 249.23 1171.46 8.09 OSF1.50 Par 18415.02 3536.41 -2411.15 -13526.69 21000.00 3539.33 -3297.21 -14518.92 228.05 1328.79 252.49 1160.05 7.93 OSF1.50 Par 18514.72 3538.49 -2336.86 -13593.17 21100.00 3538.95 -3217.75 -14577.63 228.07 1321.04 258.00 1149.96 OSF1.50 Par 18611.08 3536.59 -2265.04 -1365741 21200.00 3538.56 -3136.28 -14638.33 228.24 1313.30 25871 11404 OSF1.50 Par 18684.06 353738 -2210.05 -13705.39 21300.00 3538.18 -3058.82 -14899.04 229.46 1306.81 255.79 113588 7.69 OSF1.50 Par 18768.65 3539.34 -2145.26 -13759.73 21400.00 3537.05 -2979.58 -14760.03 230.27 1302.58 25569 1131.71 7.67 OSF1.50 Par 18868.40 3541.81 -2068.68 -13823.61 21500.00 3532.96 -2901.33 -14822.15 230.56 1300.18 25920 1128.98 7.55 OSF1.50 Par 18968.05 354428 -1992.18 -13887.42 21600.00 352720 -2823.70 -14884.92 230.92 1298.74 26271 1123.19 7.44 OSF1.50 Par 1906770 3546.75 -1915.68 -13951.23 21700.00 352145 -2746.07 -14947.69 231.28 1297.35 26623 1119.46 OSF1.50 Par 19095.92 354745 -1894.02 -13968.30 21729.25 3519.76 -2723.36 -1496606 231.43 1296.96 26704 1118. OSF1.50 Par 19150.11 3548.38 -1852.16 -14003.71 2180000 3515.96 -2667.91 -15009.83 232.38 1295.67 265.58 111821 OSF1.50 Par 19226.72 354841 -1792.23 -14051.42 21900.110 3511.52 -258777 -15068.47 233.65 1292.55 263.35 1116.58 7.39 00F1.50 Par 19303.26 3546.98 -1731.48 -14097.86 22000.00 350809 -2505.66 -15126.43 23481 1287.88 261.19 1113.34 7.42 OSF1.50 Par 19379.83 3544.09 -1669.89 -14143.35 22100.00 3505.35 -242187 -15180.63 235.88 1281.65 259.21 110844 744 OSF1 50 Par 1947948 3539.36 -158920 -14201.64 22200.00 3502.82 -2337.10 -1523393 235.80 1275.27 26281 1089.68 7.31 OSF1.50 Par 1957926 3534.63 -1508.41 -14268.00 22300.00 350029 -2252.52 -1528723 235.71 1268.89 286.46 1090.841090.842,1.7_ OSF150 Par 1967904 3529.89 -1427.62 -14318.37 22400.00 349776 -216796 -15340.54 235.61 1262.53 270.11 108205) 7011 05F1.50 Par 1975768 3526.85 -1363.55 -14363.87 22500.00 349449 -2084.44 -15395.44 236.57 1258.92 268.70 1079.38 7.05 OSF1.50 Par 19857.68 3523.92 -1281.58 -14421.06 22600.00 349044 -2002.27 -15452.28 236.62 1258.55 272.15 1076.70 8.96 00F1.50 Par 1995767 3520.98 -1199.61 -14478.25 22700.00 3486.35 -1920.15 -15509.20 238.67 1258.27 27588 1073.94 687 OSF1.50 Par 2011389 3515.33 -1073.32 -14570.00 22800.00 3482.27 -1838.03 -15566.12 234.06 1258.23 29174 1061.33 648 00F1.50 Per 2028502 3505.89 -94066 -14677.66 22900.00 3478.19 -1755.91 -15623.04 23058 311.63 OSF1.50 0 Pa 2037194 3499.96 -87575 -1473515 22950.59 3476.12 -1714.37 -15851.84 228.7 12 322 00F1.50 Par End of maul% • • • • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-686\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 11 of 13 Field: Nikeitchuq Nhll: • SP31-W7 Structure: Spy Island Borehole: SP31-W7L7 Slot: SP31 Tralectoeyi SP31-W7L1(P35) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska Stale Plane,Zone 04,US Feat North Reference: True Grid Convergence Angle: 0 08855791" Grid Scale Factor: 0.999900145 Magnetic Declination: 19007° Magnetic Declination Date: January 15,2015 Magnetic Model: BGGM 2014 Reference Point akg Iglu Elevatlon Structure Unc. Slot Unc 5053614.950(ttUS) 511450.170(8US) - 54.100(ft)MSL 0.0001910 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSAO 3-31 95.000%Confidence 2.7965 sign Survevina Prog:While Drilling Description Part MD From(ft) MD To(ft) EOU Frog(B) Survey Tool Type Hole SW(In) Casing Diameter(In) Borehole/Survey 1 0.000 0.330 Act-Scta SLB NSG+SSHOT-0eplh Only-No Global 16.000 13.375 SP31-W7/SP31-W7(P8b)(Pmjected4lp) 1 0.330 0.330 1/100.000 SLB NSG+SSHOT-0epth Only-No Global 18.000 13.375 SP31-007/SP31-007(PBb) 1 0330 41.000 Act-Slot. SLB NSG+SSHOT-0spth Only-No Global 18.000 13.375 5P31-W71 SP31-W7(P8b) 1 41.000 1100.330 1/100.000 SLB NSG*SSHOT-No Global 18.000 13.375 SP31-W7/SP31-W7(P8b) 1 1100.330 2850.462 1/100.000 SLB MWD+SAG-No Global 18.000 13.375 SP31-W7/SP31-W7(P8b) 2 1100.330 2850.462 1/100.000 SLB MWO*GMAG-No Global 18.000 13375 SP31-W7/SP31-W7(P8b) 2 2850.482 4350330 1/100.000 SLB_MWD+SAG-No Global 12.250 9.825 SP31-W7I SP31-W7(P8b) 3 2850.482 13100.000 1/100.000 SLB MWO+GMAG-Na Global 12.250 9.525 SP31-W7/SP31-W7(P8b) 3 13100.000 13500.000 1/100.000 SLB_MWO-INC ONLY FILLER-No Global 5.750 5.500 SP31-W7L1/SP3I-W7L1(P3b) 3 13500.000 15000.000 1/100.000 SLB MWD+SAG-No Global 8.750 5.500 SP31-W7L1/SP31-W7L7(P30) 4 13500.000 22821.271 1/100.000 SLB_MWO*GMAG-No Global 6.750 5.500 SP31-W7L1/SP31-WILT(P3b) Minmum Traveling Cylinder Allowable EOU-EOU Reference MD Reference NO Reference N5 Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (0) (ft) (ft) (ft) (ft) (ft) (It) (ft) I`) (5) (ft) (ft) All local minima indicated. Results filtered:Depth 13600.00 ft<=MD<=23968.22 ft Results filtered:Ct-Ct separation en 1500.00 ft Results highlighted Ct-Ct separation c 1320005 Trace 1 3626.96 3505.63 -5582.57 -10315.11 4900.00 3521.10 -702175 -10188.99 174.38 1434.81 415.06 1157.70 5.20 OSF1.50 Paw 371626 3511.86 -5600.33 -10403.86 5000.00 3527.57 X93.43 -10284.66 174.51 1396.27 41714 1119.771 5.041 OSFI 50 Pas 376409 3515.11 -5603.57 -1045147 5100.00 3534.04 6965.11 -10380.36 176.27 138352 399.82 1096.70 5.13 OSF1.50 Pas 3813.10 3518.27 -5805.24 -10500.34 5200.00 3540.44 -6987.02 -10478.12 17806 1332.18 393.02 1098.78 OSF1.50 Paw 3858.98 3521.08 -5605.30 -10546.13 529109 354561 -691367 -1056401 179.77 1308.73 386.53 1050 OSF1 50 Pass 386353 3521.35 -5605.22 -10550.67 5300.00 3546.07 6911.53 -107265 179.94 1306.73 385.88 1049.08 OSF1.50 Pass 3915.15 3524.31 -5603.37 -10602.17 5400.00 3550.59 6889.20 -1067002 181.91 1287.69 376.15 103538 5.12 OSF1.50 Pass 396751 3527.11 -5599.61 -10654.32 5500.00 355466 6868.04 -1076767 183.93 1273.78 369.99 1026.71 5.18 OSF1.50 Pass 4020.34 3529.73 -5593.89 -1070.77 560000 3558.73 6848.87 -10865.32 185.96 1263.31 38141 102196 526 OSF1.50 Pass 407343 3532.15 -5586.21 -10759.25 570500 356252 6823.38 -1096242 187.98 1254.12 352.46 101573 5.35 OSF1.50 Pass 412664 3534.36 -5576.57 -1011.52 58000 3566.93 -6794.83 -11058.16 19000 124341 343.20 1014.20 5.45 OSF1.50 Pass 4179.98 3536.34 -5564.97 -10863.55 590000 357107 -6761.31 -1115227 192.01 1231.18 333.64 103834 555 OSF1.50 Pass 4233.51 3538.11 -5551.41 -10915.30 6000.00 357523 -6723.54 -11244.77 19401 1218.12 323.80 1001.85 566 OSF1.50 Pass 428747 3539.66 -5535.79 -10966.92 61000 3579.39 -6685.20 -1133703 198.01 1208.17 31366 998.85 579 OSF1.50 Pass 434169 3540.98 -5518.17 -11018.18 6200.00 358259 -664482 -11428.45 19607 1188.75 303.31 997.13 5.95 OSF1.50 Pass 439604 3542.07 -5498.58 -1108.86 630.00 3583.69 -6600.10 -1151787 200.21 1190.24 292.77 994.66 8.12 OSF1.50 Pass 445053 354291 -547704 -11118.90 6400.00 3582.87 6551.07 -11605.01 202.44 117980 282.15 991.09 629 0SF7.50 Pass 450519 3543.51 -545354 -11168.24 650.00 3580.47 -6498.06 -11689.76 204.73 1188.07 27142 7 6.48 OSF1.50 Pass 456022 3543.66 -5428.01 -11216.99 6600.00 357772 6444.18 -11773.96 207.06 1159.30 260. 6.89 OSF1.50 Pass 4615.56 3543.96 -5400.48 -11264.99 670.00 357496 -8390.30 -11858.16 209.39 115436 24998Q007725 0666.96 OSF1.50 Pass 4671 04 3543.81 -537195 -1131202 6800.00 3572.43 -6335.96 -1194206 - 211.71 52 74 23243 992 72 05E1.50 Pam 5199 354327 -532586 -11379.18 6900.00 3571.510 627.8 060 -12023.96 212.67 11236.85900944O5F1.50 Peen 4837.66 3542.64 -5277.77 -11450.07 70 .00 357091 -6220.65 -121 .46 213.34 ((`2570 23594 g�_2S ii OSF1.50 Pan 489338 3541.97 -5245.11 -11495.20 7100.00 3570.32 6182.70 -12186.95 215.58 11 22623 7, OSF1.50 Pew 494097 3540.95 -5210.82 -11538.95 7203.00 356972 -6104.75 -12268.45 217.76 1154.17 217.02 1009.08 6.01 OSF1.50 Pas 5004 28 3539.59 -5175.0 -11581.12 73000 3569.12 {A46.80 -1234995 219.91 116269 208.38 1023.37 8.41 OSF1.50 Paw 5059.0 3537.91 -5138.11 -11621.54 74000 356773 -5989.50 -12431.89 222.08 1175.76 200.51 104168 8.84 OSF1.50 Pas 511309 3535.99 -510.20 -11659.96 75000 3566.14 -5832.36 -1251394 224.24 119276 19349 1083.36 9.30 OSF1.50 Pas 5166.29 3533.93 -501.48 -1160.39 760.00 3564.54 -5875.23 -1259600 226.36 1213.43 176.29 1095.49 1039 09F7.50 Pas 521860 3531.77 -502213 -11730.77 77000 3562.94 -581809 -1267805 228.45 1237.69 188.68 112483 1108 OSF1.50 Paw 5269.89 3529.51 -4982.35 -11763.07 78000 356134 -5760.96 -12760.11 230.50 1285.43 162.17 1156.91 11.78 OSF1.50 Pas 5334 50 3526.50 -4930.84 -11801 95 790.00 3558.05 -5703 55 -12841 91 231 92 1296 00 159.28 1189.40 1229 00F1.50 Pas 540.58 3523.37 -4875.28 -11842.88 8000.00 3551.99 -5545.48 -12923.0 233.22 1326.0 157.79 1221.36 12.70 OSF1.50 Paw 545901 352136 -4829.72 -1187440 8100.00 3547.53 -5583.94 -13001.77 235.08 1356.0 154.78 1253.0 13.24 05F1.50 Pas 5514.39 3519.86 -4783.28 -1190451 8200.00 3545.25 -5517.98 -13076.87 236.85 1383.79 152.64 1281.62 13.70 OSF1.50 Pass 5569.73 3515.99 -4735.97 -11933.20 8300.00 364499 -5447.80 -13148.09 238.56 1406.30 15142 13095 14.05 OSF1.50 Pass 5625.0 3518.43 -4887.81 -1100.48 8400.00 3545.58 -5373.48 -13214.0 240.25 1429.98 151.18 1328.68 14.29 00F1.50 Pass 5880.28 3518.47 -4838.99 -1198622 8500.00 3546.79 -5295.20 -1327717 241.94 144843 151.89 1348.76 1441 OSF1.50 Pas 5735.13 3518.97 -458972 -12010.33 00.00 3548.36 3214.74 -1333853 243.63 1488.39 15360 1363.58 14.42 OSF1.50 Pass 5789.35 3519.91 -4540.35 -12032.70 8700.00 354993 6134.26 -13395.87 245.33 148723 158.26 1382.98 14.38 OSF1.50 Pass 5849.33 352143 -4485.00 -12055.77 8800.00 3550.28 -502.59 -13453.56 246.83 1506.91 159.55 140213 14.28 OSF1.50 Pass 5947.56 3524.18 -4394.0 -1209266 8900.00 3548.54 -4988.28 -1350727 247.02 1526.92 161.75 1418.88 14.28 OSF1.50 Pass 6040.29 352614 -4308.0 -12127.40 9000.00 3545.77 -4882.80 -13558.77 247.40 154249 184.28 1432.58 14.18 OSF1.50 Pass 613842 352629 -4216.0 -12163.91 9100.00 3543.32 -479E07 -1380.81 247.53 1558.72 168.56 1445.27 14.11 OSF1.50 Pas 6258.74 352646 -410536 -1220.86 9200.00 3541.94 470.76 -1365374 246.84 156612 188.11 1452.64 14.06 OSF1.50 Pas 3571.94 3527.59 -382532 -12348.55 9300.00 3541.66 -4814.91 -1369323 239.07 1559.43 176.20 1441.55 13.36 OSF1.50 Pass 6861.82 3532.77 3585.15 -12510.44 940.00 3541.81 4520.82 -1372734 232.11 153512 202.32 1399.83 11.44 OSF1.50 Pass 7019.98 353801 3482.75 -12610.30 9500.00 354203 -4426.43 -13760.09 229.88 1500.23 215.52 1356.15 10.49 OSF1.50 Pass 711432 3538.30 -3390.40 -12670.99 980.0 354224 -4331.94 -13792.83 228.84 1464.60 21812 1318.78 10.12 OSF1.50 Pass 720.00 3536.52 -3318.66 -1273121 970.0 3542.23 4237.71 -13826.28 22976 1429.64 22049 1282.24 977 OSF1.50 Pas 7303.18 3534.71 -3245.79 -1279237 9800.00 354092 -4145.09 -13883.95 229.74 1398.0 222.77 1250.03 9.48 OSF1.50 Pass 7389.74 353288 3171.82 -12854.46 9900.00 3538.20 -405452 -1390.22 229.77 1373.09 225.21 1222.54 9.19 OSF1.50 Pass 7497.49 3531.02 -3096.97 -12917.29 2000.00 3534.07 3986.24 -1302.98 229.86 1352.15 227.80 1199.87 8.94 OSF1.50 Pas 7627.68 352979 -280.00 -13001.55 20100.00 3528.72 3880.16 -14003.59 228.68 1334.79 23683 1176.50 8.49 OSF1.50 Pass 773615 353107 -2917.0 -1307408 20200.00 3524.49 -379473 -1405539 228.47 1316.55 24171 1155.00 8.20 OSF1 50 69s= Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-006\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 12 of 13 Trajectory:$134-145(P6b)Vs.SP31-W7L1(P3b) Minimum Trawling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Rsfenxws EW Offset MO Offset TVD Offset NS Offset EW North Aom Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (6) (6) (6) (ft) (6) (6) (6) (6) (') (6) (ft) (6) 783471 3532.32 -2843.63 -1313978 2030000 352327 -371013 -14108.69 228.59 1289.88 24431 1136.80 801 OSF1.50 Pass 793341 353357 -2770.07 -13205.58 2040000 352325 -3625.89 -1416256 228.65 1283.88 24733 111858 7.82 OSF1.50 Paw 8032.12 3534 82 -2696.51 -1327138 20500 00 3523.24 -3541.64 -14218.44 228.71 1267.88 25037 1100.56 7.63 OSF1.50 Pass 8130.97 3536.06 -262284 -1333728 20600 00 3523.23 3457.39 -1427031 226.77 1251.88 253.47 1062.49 744 0571.50 Pass 8229.90 3536.24 -2549.11 -13403.25 20700.00 352322 -3373.16 -14324.20 228.78 1235.88 256.61 1064.40 725 OSF1.50 Pas 8328.92 3536.33 -2475.32 -13469.27 2080700 3523.21 -3290.07 -14379.84 226.79 1221.93 25947 1048.54 709 OSF1.50 Pas 842836 3538.42 -2401.21 -13535.58 2090000 3522.99 -32178.97 -14438.33 228.81 121145 26244 1036.08 6.95 057150 Pas 8528.09 3536.50 -2328.89 -13602.08 21000.00 3522.44 -312976 -14499.37 228.85 1204.13 285.53 1028.7 s OSF1.50 Pas 862141 3536.63 -2257.32 -13664.27 21100.00 3521.82 -30550.93 -14560.89 229.19 1197.49 26745 10187 OSF1.50 Pa 869571 3537.60 -2201.18 -1371294 21200.00 3521.21 -2972.09 -1482241 230.49 1192.36 28545 1014.98 6.6 OSF1.50 Paw 878578 353977 -213210 -1377070 2130000 352085 -289327 -14883.95 23109 1189.01 268.71 1010.80 8.71 097150 Pas 888575 354224 -205536 -1383472 21400.00 352221 -2815.04 -1474821 231.13 1186.73 289.82 1008.57 6.63 OSF1.50 Pass 898573 354.72 -1978.61 -13898.74 21500.00 3525.23 -2737.24 -14808.97 231.11 1185.06 273.00 1002.67 6.53 OSF1.50 Paw 9085 72 3547.20 -1901 85 -13962.77 2180000 3528.25 -2659.45 -1487173 231.08 118344 276.40 998.76 644 0071.50 Pass 9100 72 3547.56 -189033 -13972.37 21617.18 352877 -2648.08 -14882.51 231.18 1183.16 276.54 998.40114 0571.50 Pass 9165.51 3548.50 -1840.19 -14013.39 2170000 353073 -2580.98 -14933.88 232.02 1181.53 275.71 99731 6.45 OSF1.50 Pass 924350 354823 -1778.98 -14061.72 2180000 3531.64 -2500.63 -14993.18 23305 117642 274.72 99486 646 OSF1.50 Pass 932138 3548.43 -1716.98 -14108.81 2190000 3530.96 -241847 -1505018 234.09 1174.10 273.83 991.14 6.45 0571.50 Pas 940461 3542.91 -1649.82 -14157.84 2200000 3528.65 -233461 -1510459 234.85 1166.54 27403 98544 6.42 OSF1.50 Pass 9504.34 3538.18 -1589.07 -14218.18 2210000 3525.12 -2249.53 -15157.01 23480 1161.19 277.31 975.91 6.30 OSF1.50 Pass 9604.05 3533.45 -1488.34 -14274.50 2220000 3521.51 -2164.37 -15209.32 234.75 1153.71 280.67 96619 0871.50 Pas 9699.56 3528.95 -1410.99 -1433035 22300.00 3517.81 -2080.06 -15262.95 23492 1147.84 283.10 9587 OSF1.50 Pas 9784.80 3526.05 -1341.32 -14379.37 22400.00 3513.87 -1997.43 -15319.14 23571 1148.21 28348 95683 OSF1.50 Pass 9884.79 3523.12 -1259.35 -1436.57 22500.00 3509.89 -1915.06 -1537570 23576 1145.47 288.89 953.81 6.01 OSF1.50 Pass 9988.29 3520.08 -117452 -1495.77 22600,00 3505.91 -1832.69 -1543226 23563 114473 290.96 950.34 5.92 OSF1.50 Pas 20148.74 3513.68 -1045.80 -1459132 22700.00 3501.93 -175032 -15488.82 23249 1141.04 305.49 936.97 582 OSF1.50 Pas 20308.91 3504.33 -922.65 -14693.28 22800.00 3497.95 -1887.95 -1554538 22917 1 320.89 91774 5.31 OSF1.50 Pass 2034305 350201 497.13 -14715.83 22821.27 3497.11 -1650.43 -15557.41 228.4 1 324.24 912671 5241 OSF1.50 Pass End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SI34-076\SI34-W6\SI34-W6(P6b) 1/15/2015 9:07 AM Page 13 of 13 Attachment 9 Casing Design Program File: S134-W6 (P6) * Date:January 16, 2015 Page: 1 MINIMUM SAFETY FACTORS(13 3/8" Surface Casino) Depth(MD) Minimum Safety Factor(Abs) (usft) OD/Weight/Grade Connection Burst Collapse Axial Triaxial 1 0 13 3/8",68.000 ppf,L-80 N/A 2.50 B5 +100.00 Cl 8.08 B5 3.15135 2 10 2.51 B5 +100.00 C1 8.13 B5 3.16 B5 3 101 9.83 B11 +100.00 Cl 10.22 A5 6.34 A5 4 12 9.83 811 +100.00 Cl 10.23 A5 6.34 A5 5 __ 31 9.85 B11 +100.00 Cl 10.31 A5 6.34 A5 6 31 9.81 B11 +100.00 Cl 10.31 A5 6.34 A5 7 1601 9.80811 28.70C1 10.95 A5 6.62 A5 8 400 9.78 B11 11.48 Cl 11.85 Al 7.22 A5 9 400 9.78 811 11.48 Cl 7.38 A5 6.53 A5 10 800' 9.74 B11 5.75 Cl 5.23 A5 526 Al 11 800 9.74 B11 5.75 C1 5.24 A5 5.26 Al 12 1000' 9.72 B11 4.62 Cl 5.48 A5 5.33 Al 13 1000, 9.72 B11 4.62 Cl 5.49 A5 5.33 Al 14 1036' 9.72 B11 4.46 Cl 5.53 Al 5.34 Al 15 1200 9.71 B11 3.88 Cl 5.64 Al 5.42 Al 16 1360 9.69 B11 3.46 Cl 5.77 Al 5.51 Al 17 1650 9.67 B11 2.91 Cl 6.06 Al 5.72 Al 18 1650' 13 3/8",68.000 ppf,L-80 N/A 9.67 B11 2.91 Cl 6.06 Al 5.72 Al 19 1700 9.67 B11 2.83 Cl 6.12 Al 5.76 Al 20 19111 ' 9.65 B11 2.55 Cl 6.38 Al 5.15 Cl 21 2000 9.65 B11 , 2.44 Cl 5.23 Cl 4.93 Cl 22 _ 2000 9.65 B11 12.44 Cl 5.24 Cl 4.93 Cl 23 21001 9.64B11 2.34 C1 5.19 C1 4.80Cl 24 2115 9.64B11 2.33Cl 5.18C1 4.78 C1 25 2200 9.63 B11 2.25 Cl (4.77)Cl 4.67 Cl 26 23001 9.62 B11 1 2.17 Cl (4.73)Cl 4.56 Cl 27 2300 9.62 B11 2.17 Cl (4.74)Cl 4.57 Cl 28 2400 9.62 B11 2.10 Cl (4.70)Cl 4.46 Cl 29 2500 9.61 B11 � 2.04 Cl (4.66)Cl 4.37 Cl 30 25001 9.61 B11 ' 2.04 Cl (4.67)Cl 4.37 Cl 31 2586 9.61 B11 2.00 Cl (4.64)Cl 4.30 Cl 32 26001 9.60 B11 1.99 Cl (4.64)Cl 4.29 Cl 33 2600 9.60 B11 1.99 Cl _ (4.63)Cl 429 Cl 34 2700' 9.60 B11 I 1.94 Cl (4.60)Cl 4.22 Cl 35 2800 9.59 B11 1.90 Cl (4.58)Cl 4.16 Cl 36 2899' 9.59 B11 1.87 Cl (4.56)Cl 4.10 Cl 37 29001 9.59 1311 1.87 Cl (4.56)Cl 4.10 Cl 38 39 B5 Pressure Test 40 B111 Fracture @ Shoe w/1/3 BHP at Surface 41 C11 Full/Partial Evacuation 42 All Running in Hole-Avg.Speed 43 A5 Green Cement Pressure Test(Axial) X44 0, Compression S134-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) " Date:January 16, 2015 Page: 2 BURST LOADS DATA(13 3/8" Surface Casing) Drilling Load: Pressure Test Test Pressure: 2000.00 psi Mud Weight: 9.50 ppg Plug Depth, MD: 10.0 usft Assigned External Pressure: Fluid Gradients (w/ Pore Pressure) Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface Surface Pressure (1/3* BHP): 511.86 psi Shoe Depth, MD: 2900.0 usft Fracture Pressure at Shoe: 1598.26 psi Fracture Margin of Error: 0.00 ppg External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 31.0 usft Prior Shoe, MD: 0.0 usft Mud Weight Above TOC: 9.50 ppg Fluid Gradient Below TOC: 8.60 ppg Pore Pressure In Open Hole: Yes 5134-W6 StressCheck 5000.1.10.0 Build 1934 File: Sl34-W6 (P6) * Date:January 16, 2015 Page: 3 BURST DESIGN(13 3/8" Surface Casino) 0 Design Load Line Pipe Rating 200- r 1 . r T 1 400 +- 600 800--_+- 1 J L 1 J I 1 I 1 I I I I ' I I 1000 _+- 1 J J L 1 J I I I 1 I I I I I 1 1200 + _, J L 1 J I 1 I � I 1 i I 1 I I 1400 I — a f I I I I I C I I 1600 + -, -1 r t -1 + I -CD I I I I 0 1800 r -, -1 r r 1 -a I I Q) I I i I I NI ca) 2000---+- i 1 -1 r 1 1 L 2200--- +- r 1 r r 1 2400—--+- 2600---+- 2800 i- 1 J L 1 I I + I 1 I 1 30001 J J L L 1 J I I 1 I 1 1 3200 14 L 1 4 I I I I I I I I 3400— . + -, - r + -I I � 3600 I I I I 7 1 f 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 Burst Rating (psi) SI34-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) * Date:January 16, 2015 Page: 4 COLLAPSE LOADS DATA(13 3/8" Surface Casing) Drilling Load: Full/Partial Evacuation Mud Weight: 9.50 ppg Mud Level, MD: 2900.0 usft Assigned External Pressure: Fluid Gradients (w/Pore Pressure) External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 31.0 usft Prior Shoe, MD: 0.0 usft Fluid Gradient Above TOC: 9.50 ppg Fluid Gradient Below TOC: 9.50 ppg Pore Pressure In Open Hole Below TOC: No S134-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) ` Date:January 16, 2015 Page: 5 COLLAPSE DESIGN (13 3/8"Surface Casing) 0 r + Design Load Line Pipe Rating 200— 7 1 r T 1 r - 400—- • - 600— - 800 1 J L 1 J L - I I I I I I I 10001 J F L 1 J L - I I I I I 1 I I 1200 J r 1- 1 J L - I I I I I I I I I I 1400 1- - I I I I I U I 1600 + -1 r t -1 r r - I I I I Q a) I I 0 1800 Y 1 r Y -1 r - -0 I I I eI I >` I I I UI I co2000 I 1 7 r T 1 r 2 I I I I I I I I I I 2200 T 1 r T 1 r - 2400 - 2600 - 28001 J L 1 J L L - I I I I I I I 3000 1 J L 1 J L L - I I I I I I I I I I I I I I I 3200 J a J I_ - - I 1 I 1 I I 3400 + + -, - I 3600 j I I I f I I 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Collapse Rating (psi) SI34-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) * Date:January 16, 2015 Page: 6 AXIAL LOADS DATA(13 3/8" Surface Casing) Running in Hole -Avg. Speed: 0.0 ft/s Overpull Force: 0 lbf Pre-Cement Static Load: Yes Pickup Force: 0 lbf Green Cement Pressure Test: 1000.00 psi Service Loads: Yes it S134-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) * Date:January 16, 2015 Page: 7 AXIAL DESIGN (13 3/8"Surface Casino) 0 r ' Design Load Line Pipe Rating 200 -r 1 1 400— + • 600 800 +_ 1 1 J J J 1 I 1 I 111 1 I I I I I 1000 J J J I I I I I I I I I 1200 + 1 1 4 4 J I I 1 I 1 I 1 I 1400 i -' -a I I I I I I I I I v 1600 ,- , -, , +I I I y L Q. I 1 0 1800 r r Y 7 1 -I I I I 2 I I I I + 1 I NI I aCD 2000 T T "7 C 1 I I L '+ I 1 I I I I I 2200 i1 r T , 2400 2600 p + 2800 L 1 1 J J J I I I I j + , I 1 3000L 1 1 J J J I I I I I I I I 3200 '- t J J I 1 I I I I I I I 3400 i I I I I I I I 1 I I I 3600 r 1 0 400000 800000 1200000 1600000 2000000 2400000 2800000 3200000 3600000 V Axial Force (lbf) SI34-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) * Date:January 16, 2015 Page: 1 MINIMUM SAFETY FACTORS(9 5/8" Intermediate Casing) Depth(MD) Minimum Safety Factor(Abs) (usft) OD/Weight/Grade Connection Burst Collapse Axial Triaxial 1 01 9 5/8",40.000 ppf,L-80 N/A 2.86 B5 +100.00 Cl 4.97 B5 3.52 B5 2 12 2.87 B5 +100.00 Cl 5.0085 3.53 65 3 20 2.87 B5 +100.00 Cl 5.01 B5 3.53 B5 4 20 11.42 B11 +100.00 Cl 5.36 A5 5.49 A5 5 400 11.29 611 15.36 Cl 5.89 A5 5.77 A5 6 400 11.29 Bi 1 15.35 Cl 4.78 A5 5.07 A5 7 800 11.16 611 7.73 C1 4.09 A5 4.49 A5 8 800 11.16611 7.73 C1 4.10 A5 4.50 A5 9 1000 11.10611 6.22 C1 4.24 A5 4.62 A5 10 1000 11.10 811 6.22 C1 4.25 A5 4.62 A5 11 1200 11.04 611 5.24 C1 4.40 A5 4.73 A5 12 1200 11.041311 5.24 C1 4.40 A5 4.74 A5 13 1360 11.00 611 4.68 Cl 4.52 A5 4.83 A5 14 1488 10.96 B11 4.32 C1 5.36 Al 4.93 A5 15 1700 10.91 B11 3.84 Cl 5.37 Al 5.10 Al 16 192 10.85 B11 3.44 Cl 5.41 Al 4.78 Cl 17 2000 10.83 611 3.33 C1 4.91 A5 4.68 Cl 18 2100 10.80611 3.19 C1 5.00 A5 4.61 Cl 19 2200 10.78 611 3.07 Cl 5.09 A5 4.55 Cl 20 2300 10.76 B1 l 2.96 C1 5.17 A5 4.49 Cl 21 2400 10.74 611 2.87 C1 5.26 A5 4.43 C1 22 2400 10.74 611 2.87 Cl 5.25 A5 4.43 C1 23 2500 10.72 B11 2.79 Cl 5.33 A5 4.38 Cl 24 2500 10.72 611 2.79 C1 5.34 A5 4.38 C1 25 2601 10.70 811 2.71 C1 5.41 A5 4.33 Cl 26 260# 10.70 611 2.71 Cl 5.40 A5 4.33 Cl 27 • 2700 10.68 611 2.65 Ci 5.47 A5 4.29 Cl 28 2700 10.68 B11 2.65 Cl 5.48 A5 4.29 Cl 29 2800 10.67 611 2.60 Cl 5.54 A5 4.25 C1 30 2900 10.65 611 2.55 C1 5.60 A5 4.22 C1 31 2900 10.65811 2.55 C1 5.60 A5 4.24 C1 32 2901 10.65811 2.55C1 5.64 A5 4.24 C1 33 2901 10.65 Bit 2.55 Cl 5.59 A5 4.21 Cl 34 3000 10.64 611 2.51 Cl 5.64 A5 4.18 C1 35 3000 10.64 611 2.51 Ci 5.65 A5 4.19 Ci 36 __ 3003 10.64 611 2.51 Cl 5.65 A5 4.19 Cl 37 3100 10.63611 2.48C1 5.69 Al 4.16 C1 38 3200 10.62 B11 2.46 Cl 5.72 Ai 4.14 C1 39 3300 10.62811 2.44 C1 5.75 Al 4.13 C1 40 3309 10.62 611 2.44 C1 5.75 Al 4.13 C1 41 3400 10.61 1311 2.43 Cl 5.77 A5 4.12 Ci 42 3400 10.61 1311 2.43 Ci 5.78 A5 4.12 Cl 43 340: 10.61 B11 2.43 Ci 5.78 Al 4.12 Cl 44 10200 10.51 1311 2.13 Cl 6.43 Al 4.25 Cl 45 10300 10.50 611 2.13 Cl 6.44 Al 4.25 Cl 46 10400 • 10.50 Bt i 2.12 Ci 6.44 Al 4.23 Cl 47 10500 10.49 611 2.11 Cl 6.45 Al 4.22 Cl 48 10600 10.49 811 2.09 Cl 6.46 Al 4.20 Cl 49 11000 10.46 611 2.03 C1 6.49 Al 4.49 Cl 50 11000 7.97 611 2.03 Cl 6.49 Al 4.47 Cl 51 12100 7.77B11 1.88 C1 7.26 Al 3.64C1 52 12100 7.77 611 1.88 C1 7.26 Al 3.63 Cl 53 12300 7.74 611 1.85 Ci 7.57 Al 3.60 Cl 54 12407 7.73 611 1.84 Cl 7.76 Al 3.59 Cl 55 12500 7.72B11 1.83Cl 7.76811 3.57Cl 56 12700 7.70 B11 1.82 Cl 7.77 811 3.55 Cl 57 12813 7.69 611 1.81 Ci 7.76 611 3.54 Cl 58 12900 7.69 611 1.81 Cl 7.75 611 3.53 Cl 59 12900 7.69 811 1.81 Ci 7.82 611 3.54 Cl 60 13000 7.68 811 1.81 Cl 9.11 Al 4.00 Cl 61 13639 7.65 611 1.78 Ci 11.46 Al 3.95 Ci 62 13640 7.65 611 1.78 Cl 11.46 Al 3.95 Cl 63 64 B5 Pressure Test 65 B11 Fracture @ Shoe w/1/3 BHP at Surface 66 Cl Full/Partial Evacuation ! 67 Ai Runnin.in Hole-AVS.S. S134-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) * Date:January 16, 2015 Page: 2 MINIMUM SAFETY FACTORS(9 5/8" Intermediate Casing) Depth(MD) Minimum Safety Factor(Abs) OD/Weight/Grade Connection (ustt) Burst Collapse Axial Triaxial 68 A5 Green Cement Pressure Test(Axial) 4i 69 j • S134-W6 StressCheck 5000.1.10.0 Build 1934 File: Sl34-W6 (P6) * Date:January 16, 2015 Page: 3 BURST LOADS DATA(9 5/8" Intermediate Casing) Drilling Load: Pressure Test Test Pressure: 2000.00 psi Mud Weight: 9.50 ppg Plug Depth, MD: 20.0 usft Assigned External Pressure: Fluid Gradients (w/ Pore Pressure) Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface Surface Pressure (1/3 * BHP): 502.88 psi Shoe Depth, MD: 13640.0 usft Fracture Pressure at Shoe: 2285.19 psi Fracture Margin of Error: 0.00 ppg External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 11000.0 usft Prior Shoe, MD: 2900.0 usft Mud Weight Above TOC: 9.50 ppg Fluid Gradient Below TOC: 8.60 ppg Pore Pressure In Open Hole: Yes Sl34-W6 StressCheck 5000.1.10.0 Build 1934 File: SI34-W6 (P6) * Date:January 16, 2015 Page:4 BURST DESIGN(9 5/8"Intermediate Casing) 0 - — f Design Load Line Pipe Rating 1000—-+- r r r 1 7 2000-- + 3000 4000 L L � 1 J 1 � I I � I I I I I 5000 L 1 _1 1 J I I I 1 1 1 I 1 6000 L 1 1 1 J _, I 7000 1- - I I 80001- Y t H , -I ti 4) I I 0 9000 r r 7 1 -I -1 " I I d) I >` I I U) N 10000 + r r 1 1 11000--- +• r r T 1 1 12000--- + 13000 - I + X 14000 L L 1 J J I I I I I I I I 15000 L 1 1 1 J J I I I I I 1 16000— '- -' 4 I I I I I I I 1 17000— -a I 18000 --r rt---- --- 1 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 Burst Rating (psi) SI34-W6 StressCheck 5000.1.10.0 Build 1934 J File: S134-W6 (P6) * Date:January 16, 2015 Page: 5 COLLAPSE LOADS DATA(9 5/8" Intermediate Casino) Drilling Load: Full/Partial Evacuation Mud Weight: 9.50 ppg Mud Level, MD: 13640.0 usft Assigned External Pressure: Fluid Gradients (w/ Pore Pressure) External Pressure: Fluid Gradients(w/Pore Pressure) TOO, MD: 11000.0 usft Prior Shoe, MD: 2900.0 usft Fluid Gradient Above TOC: 9.50 ppg Fluid Gradient Below TOC: 9.50 ppg Pore Pressure In Open Hole Below TOC: No S134-W6 StressCheck 5000.1.10.0 Build 1934 File: SI34-W6 (P6) * Date:January 16, 2015 Page:6 COLLAPSE DESIGN (9 5/8" Intermediate Casing) 01 T - Design Load Line Pipe Rating 1000-- r r 1 1 2000 3000 4000 L 1 J J I I I I I I I I 5000 L L 1 1 J J I I I I I 6000 L 1 1 J J J I I I I I I I I 1 7000 F i I I I I _ I I co 1 8000 t t - I a) I I 0 9000 r r Y 1 -I -I I 1 P2 I I HI co 10000 r - r T 1 1 - C I L I 1 I I I 11000 r r T 1 1 12000 13000 + 14000 L L 1 1 J J I I I I I I I I I I 15000 L L 1 A J J I I I t I I I I 16000— 1 1 1 J I I I I I I I I I 17000 4 4 -I I I I I I I I I I I 1 18000 I I I I r I I i 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 Collapse Rating (psi) ] / SI34-W6 StressCheck 5000.1.10.0 Build 1934 File: S134-W6 (P6) * Date:January 16, 2015 Page: 7 AXIAL LOADS DATA(9 5/8" Intermediate Casing) Running in Hole -Avg. Speed: 0.0 ft/s Overpull Force: 0 lbf Pre-Cement Static Load: Yes Pickup Force: 0 lbf Green Cement Pressure Test: 1000.00 psi Service Loads: Yes S134-W6 StressCheck 5000.1.10.0 Build 1934 File: SI34-W6 (P6) * Date:January 16, 2015 Page: 8 AXIAL DESIGN(9 5/8" Intermediate Casino) 0 + Design Load Line Pipe Rating 1000 fi T1 2000 3000-- I 4000 I I 5000 L 1 1 J J 6000 J 7000 -- i I a I I I I I I 8000 Q 1 9000 r r I � I N 0 10000 C t I G I 11000 r Ir -r 1 12000 + 13000 14000 15000 L 1 1 J J L 16000— 1 17000 I 18000 r i 0 300000 600000 900000 1200000 1500000 1800000 2100000 2400000 Axial Force (lbf) SI34-W6 StressCheck 5000.1.10.0 Budd 1934 J 4 Bettis, Patricia K (DOA) From: Lazzari Andrea <Andrea.Lazzari@enipetroleum.com> Sent: Friday,January 23, 2015 2:30 PM To: Bettis, Patricia K (DOA) Subject: RE: Nikaitchuq SI34-W6: Permit to Drill Application Good afternoon Patricia, No, we are not planning to pre-produce the well. Have a good weekend, Andrea Lazzari Drilling Engineer Eni Petroleum Office: (907) 865-3323 Cell: (907) 230-7511 Email: andrea.lazzariCaenipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, January 23, 2015 2:00 PM To: Lazzari Andrea Subject: Nikaitchuq SI34-W6: Permit to Drill Application Good afternoon Andrea, Does ENI plan to pre-produce SI34-W6 and if so, for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. 1 If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 4. Bettis, Patricia K (DOA) From: Lazzari Andrea <Andrea.Lazzari@enipetroleum.com> Sent: Thursday,January 22, 2015 4:51 PM To: Bettis, Patricia K (DOA) Subject: RE: Nikaitchuq SI34-W6: Permit to Drill Application Attachments: SI34-W6 (P6) plot.pdf Good afternoon Patricia, Please find attached the required plot. Let me know if it meets your needs. Thanks, Andrea Lazzari Drilling Engineer Eni Petroleum Office: (907) 865-3323 Cell: (907) 230-7511 Email: andrea.lazzari@ienipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, January 22, 2015 4:39 PM To: Lazzari Andrea Subject: Nikaitchuq SI34-W6: Permit to Drill Application Good afternoon Andrea, Please submit a wellbore plat, both planar and cross-sectional views, for SI34-W6. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in 1 t. this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 P C In 1 I CI Lo IIcn IN ,l0 1III0 s e M_ 'In - - /� ( f I I i-11 Yy s E1 1 i ) 1 . 6 / RQ 1f,, O I I 1 I 1 Sr j vo § § P§ 1 ie 1 it xi �r zz Want es UUani Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, January 22, 2015 4:39 PM To: andrea.lazzari@enipetroleum.com Subject: Nikaitchuq SI34-W6: Permit to Drill Application Good afternoon Andrea, Please submit a wellbore plat, both planar and cross-sectional views, for SI34-W6. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 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: 'I4044Sl 3k1' W PTD: 2)s' OI So Development /Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: POOL: IV 1 2 AdFi 0,-/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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J N• • d i a) c o , ° Lu d r- c cocL a 0 I LU 0 Q 0_ U �r Q Q Q a 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. Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: April 7, 2015 Surface Data Logging End of Well Report SI34-W6 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ENI Petroleum Rig: Doyon 15 Well: SI34-W6 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23534-00-00 Sperry Job Number: AK-XX-0902143510 Job Start Date: 18 February 2015 Spud Date: 20 February 2015 Total Depth: 23886’ MD, 3299’ TVD North Reference: True Declination: 18.940° Dip Angle: 81.060° Total Field Strength: 57584.994 nT Date Of Magnetic Data: 28 Feb 2015 Wellhead Coordinates N: North 70° 33' 27.65307" Wellhead Coordinates W: West 149° 54' 22.60959" Drill Floor Elevation 53.64’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Alexander Kalenuik, Kori Jo Plowman, Gregory Dellner, Christopher Silva SDL Sample Catchers: Michael Frazier, Javier Valdovinoc-Sierra Company Geologist: Josh Zuber Company Representatives: Jack Keener / Mike Ross SSDS Unit Number: 110 DAILY SUMMARY 02/18/2015 SDL continues on location from previous well. Skid rig floor into drilling position. Rig up operation in preparation for pre-spud acceptance. Set SDL mud logging unit and rig up 02/19/2014 Complete rig up operations. Calibrate gas equipment. Nipple up wellhead. Cut and slip drill line. Begin to pick up tools and bring BHA #1 to rig floor. 02/20/2014 Make up BHA #1. Test mud line and flood conductor. Drill out Conductor to 165’ MD and clean out. Make up BHA #2 and drill from 165’ MD to 392’ MD. Backream out of hole to make up remaining BHA. Drill ahead from 392’ MD to 1053’ MD. Gas: Max gas observed was 49 units at 1035' MD with an average gas of 10 units. Fluids: No fluid losses 02/21/2014 Continue to drill from 1053’ MD to TD of 2816’ MD. Begin to backream out of hole Gas: Max gas observed was 1005 units at 2031' MD with an average gas of 143 units. Fluids: Total of 4 barrels lost to formation 02/22/2014 Continue to backream out of hole. Rack back heavy weight drill pipe, jars, and collars. Clean rig floor. Make up casing equipment and begin to run 13 3/8” casing Gas: Max gas observed while backreaming was 713 units. Fluids: No fluid losses 02/23/2014 Continue to run 13 3/8” casing. Land on hanger at 2803’ MD. Rig up and perform cement job. Clean rig floor and rig up for BOP body test. Gas: N/A Fluids: No fluid losses 02/24/2014 Perform body test on BOP and choke. Load 5” drill pipe into pipe shed. Build 122 stands of 5” drill pipe. Rig up test equipment and begin full BOP test. Gas: N/A Fluids: No fluid losses 02/25/2014 Continue testing BOP. Make up BHA #3. Run in the hole to 1750’ MD and shallow hole test. Drill out float, shoe track, and cement. Drill 20’ of new hole to 2836’ MD. Displace from Spud mud to LSND mud. Perform formation integrity test to 13 ppg. Drill ahead from 2836’ MD to 3572’ MD. Gas: Max gas observed was 113 units at 3050' MD with an average gas of 14 units. Fluids: No fluid losses Geology: Samples consist of mainly clean sandstone with some areas of siltstone and shale 02/26/2015 Drill ahead from 3,572’ MD to 6,194’ MD. Gas: Max gas observed was 151 units at 4044' MD with an average gas of 34 units. Fluids: No fluid losses Geology: Samples consist of mainly clean sandstone with some areas of siltstone 02/27/2015 Drill ahead from 6,194’ MD to 8,746’ MD. Gas: Max gas observed was 50 units at 6342' MD with an average gas of 9 units. Fluids: Total of 35 barrels lost to formation Geology: Samples consist of mainly clean sandstone with some areas of siltstone 02/28/2015 Drill ahead from 8,746’ MD to 9,892’ MD. Rack back two stands to 9,776’ MD due to Phase 3 weather conditions. Circulate. Gas: Max gas observed was 11 units at 9,726' MD with an average gas of 7 units. Fluids: Total of 20 barrels lost to formation Geology: Samples consist of mainly clean sandstone with some areas of siltstone 03/01/2015 Circulate while waiting on Phase 3 conditions. Wash down from 9,863’ MD to 9,892’ MD. Drill ahead from 9,892’ MD to 10,022’ MD. Gas: Max gas observed was 25 units at 9,899' MD with an average gas of 6 units. Fluids: Total of 45 barrels lost to formation. Geology: Samples consist of mainly clean sandstone with some areas of siltstone 03/02/2015 Drill ahead from 10,022’ MD to 11,224’ MD. Gas: Max gas observed was 33 units at 11,157' MD with an average gas of 7 units. Fluids: Total of 31 barrels lost to formation. Geology: Samples consist of mainly clean sandstone with some areas of siltstone 03/03/2015 Drill ahead from 11,224’ MD to 12,736’ MD. Gas: Max gas observed was 1005 units at 12,403' MD with an average gas of 94 units. Fluids: Total of 49 barrels lost to formation. Geology: Samples consist of mainly clean sandstone with some areas of siltstone 03/04/2015 Drill ahead from 12,736’ MD to 13,316’ MD. Circulate two bottoms-up and rack back to stands to 13,135’. Backream out of hole to 12,477’ Gas: Max gas observed was 2070 units at 13,079' MD with an average gas of 385 units. Fluids: No fluid losses. Geology: Samples consist of mainly clean sandstone with some areas of siltstone 03/05/2015 Continue to backream out of hole to 5,202’. Gas: Max gas observed while backreaming was 118 units. Fluids: Total of 54 barrels lost to formation. 03/06/2015 Continue to backream out of hole to 1,468’. Lay down BHA. Test rams. Move casing equipment to rig floor. Gas: Max gas observed while backreaming was 62 units. Fluids: Total of 53 barrels lost to formation. 03/07/2015 Rig up Tesco and 9 5/8” casing equipment. Make up shoe track and test floats. OK. Run in hole with casing to 3,852’. Start to rotate at 40 rpm from 3,852’ to 12,747’ MD. Gas: N/A. Fluids: Total of 11 barrels lost to formation. 03/08/2015 Run in hole with 9 5/8” casing, rotating from 12,474’ MD to 13,304’ MD. Rig down Tesco equipment. Rig up long bails and cement head. Fill casing. Blow down choke and rig down fill line and cement hose. Condition hole. Gas: Max gas observed while circulating was 250 units. Fluids: Total of 37 barrels lost to formation. 03/09/2015 Circulate and condition hole. Test cement lines and cement casing. Check floats and drain stack. Rig down BOP. Set emergency slips. Cut 9.625” casing. Install packoff and test. Nipple up BOP. Cut and slip drill line. Run in the hole with 5” drill pipe. Lay down 20 bad joints and pull out of the hole with 5” drill pipe. Gas: N/A Fluids: No fluid losses. 03/10/2015 Lay down shoe and install mouse hole. Pick up 84 stands of 4.5" drill pipe and rack back. Clean and clear rig floor, pull wear ring, install test plug. Rig up and test BOPE. Pull test plug, install wear ring. Rig down and break down all lines, tools, and equipment. Bring BHA #4 tools and equipment to floor. Purge mud pump lines, test 9-5/8" casing to 3000 psi. Load 730 barrels of oil-based mud to pits. Service top drive Gas: N/A Fluids: No fluid losses. 03/11/2015 Pick up BHA #4. Run in hole to 1515’ MD and shallow hole test MWD tools. Ream in hole and start cement bond log while reaming from 10533’ MD to 12987’ MD. Gas: N/A Fluids: No fluid losses. 03/12/2015 Continue to run in hole and displace well from water based mud to oil based mud. Drill out plug and clean service equipment. Drill out 20’ of new hole to 13336’ MD. Rig up and perform formation integrity test to 13.0 ppg. Drill from 13336’ MD to 14347’ MD Gas: Max gas observed was 1094 units at 13845' MD with an average gas of 350 units. Fluids: No fluid losses. Geology: Samples consist of mainly clean sandstone with local siltstone 03/13/2015 Continue to drill ahead from 14347’ MD to 16040’ MD Gas: Max gas observed was 863 units at 15358' MD with an average gas of 147 units. Fluids: No fluid losses. Geology: Samples consist of mainly clean sandstone with local siltstone 03/14/2015 Continue to drill ahead from 16040’ MD to 18147’ MD Gas: Max gas observed was 1000 units at 17426' MD with an average gas of 370 units. Fluids: Total of 26 barrels lost to formation Geology: Samples consist of mainly clean sandstone 03/15/2015 Continue to drill ahead from 18147’ MD to 20108’ MD Gas: Max gas observed was 697 units at 19499' MD with an average gas of 292 units. Fluids: Total of 38 barrels lost to formation Geology: Samples consist of mainly clean sandstone with local siltstone 03/16/2015 Continue to drill ahead from 20108’ MD to 21928’ MD Gas: Max gas observed was 549 units at 21259' MD with an average gas of 128 units. Fluids: Total of 41 barrels lost to formation Geology: Samples consist of mainly clean sandstone with local siltstone 03/17/2015 Continue to drill ahead from 21928’ MD to 23295’ MD Gas: Max gas observed was 318 units at 22675' MD with an average gas of 57 units. Fluids: Total of 137 barrels lost to formation Geology: Samples consist of mainly clean sandstone with local siltstone 03/18/2015 Continue to drill ahead from 23295’ MD to 23866’ MD Gas: Max gas observed was 371 units at 23327' MD with an average gas of 72 units. Fluids: Total of 174 barrels lost to formation Geology: Samples consist of mainly clean sandstone with local siltstone 03/19/2015 Begin to back ream out of hole from TD of 23886’ MD Gas: Max trip gas observed was 31 units. Fluids: Total of 402 barrels lost to formation. 03/20/2015 Continue to back ream out of hole from TD of 23886’ MD Gas: Max trip gas observed was 31 units. Fluids: Total of 227 barrels lost to formation. 03/21/2015 Continue to back ream out of hole from TD of 23886’ MD Gas: Max trip gas observed was 19 units. Fluids: Total of 47 barrels lost to formation. 03/22/2015 Continue to back ream out of hole. Pull out of hole from 10915’ MD to 9771’ MD then pump out of hole Gas: Max trip gas observed was 12 units. Fluids: Total of 12 barrels lost to formation. 03/23/2015 Continue to pump out of hole to 4747’ MD. Pull out of hole and lay down BHA #4. Clean rig floor and rig up to test BOP Gas: Max trip gas observed was 8 units. Fluids: Total of 7 barrels lost to formation. 03/24/2015 Test BOPE. Replace and test IBOP. Test annular, upper and lower rams. Clean rig floor. Make up cleanout BHA #5. Run in hole to 14445’ MD, filling pipe every 20 stands Gas: Max trip gas observed was 72 units. Fluids: No fluid losses. 03/25/2015 Ream in hole from 14445’ MD to 21634’ MD Gas: Max trip gas observed was 868 units. Fluids: Total of 43 barrels lost to formation. 03/26/2015 Begin to pull out of hole Gas: Max trip gas observed was 745 units. Fluids: Total of 51 barrels lost to formation. 03/27/2015 Continue to pull out of hole. Lay down cleanout BHA. Run in hole with 4.5” liner Gas: Max trip gas observed was 8 units. Fluids: Total of 48 barrels lost to formation. 03/28/2015 Continue to run in hole with 4.5” liner then 5” drill pipe. Set packer and test. Pull out of hole 5” drill pipe Gas: Max trip gas observed was 61 units. Fluids: Total of 42 barrels lost to formation. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 22000 23000 24000 25000 0 5 10 15 20 25 30 35 40 45 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: SI34-W6 OPERATOR: ENI Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-XX-0902143510 Days vs. Depth 18 February 2015 Sperry SDL Continued on Location LOCATION: Nikaitchuq AREA: North Slope Borough STATE: Alaska SPUD: 20-Feb-2015 TD: 18-Mar-2015 Commenced 16" Surface Hole Section On Bot: 08:00 20 Feb 2015 Landed 13.375" Casing 2803' MD, 2416' TVD 22 Feb 2015 TD Surface Hole Section 2816' MD, 2423' TVD Off Bot: 19:47 21 Feb 2015 Commenced 12.25" Intermediate Hole Section On Bot: 17:10 25 Feb 2015 TD Surface Hole Section 13316' MD, 3462' TVD Off Bot: 16:59 04 Mar 2015 Commenced 8.75" Injection Hole Section On Bot: 09:50 12 Mar 2015 Landed 9.625" Casing 13304' MD, 3462' TVD 08 Mar 2015 TD Injection Hole Section 23886' MD, 3299' TVD Off Bot: 06:55 18 Mar 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Difficulties experienced: No major difficulties were experienced. As usual, depths did not track perfectly during the first part of the surface section, so it was necessary to check and edit the bit depth frequently. Recommendations: Check bit depth at each connection and edit if necessary. Innovations and/or cost savings: N/A Doyon 15 Surface Gregory Dellner 21-Feb-2015 What went as, or better than, planned: Surface section was completed with no major problems. All equipment functioned as it should. SI34-W6 Nikaitchuq ENI Petroleum North Slope Borough AK-XX-0902143510 Alaska Surface Data Logging After Action Review WELL NAME: LOCATION: OPERATOR: AREA: SPERRY JOB: STATE: RIG: HOLE SECTION: EMPLOYEE NAME: DATE: Difficulties experienced: No major difficulties were experienced. The canrig computer did freeze towards the beginning of the section and was fixed by closing out the RigWatch program and restarting it. The bit depth got thrown off a few times during connections. Recommendations: Check your bit depth during each connection to make sure it stays on track. Innovations and/or cost savings: Ran backup sample line from gas trap to air supply line. Doyon 15 Intermediate Alexander Kalenuik 17-Mar-2015 What went as, or better than, planned: Intermediate section was completed with no major problems. All equipment functioned as it should. SI34-W6 Nikaitchuq ENI Petroleum North Slope Borough AK-XX-0902143510 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Difficulties experienced: The only incident or anomaly we encountered was on our time log the data would spike to zero and our lag depth would be incorrectly adjusted but then would reset itself to it's proper depth. Recommendations: It would be wise to reinstall the Insite software on the 4th computer to see if this corrects the issue. Innovations and/or cost savings: A second (backup) sample line was installed from the shaker room trap all the way to the umbilical line that is fed to monitoring Unit. This will ensure an uninterrupted ability to monitor gas readings. Doyon 15 Production Paul Kalenuik 19-Mar-2015 What went as, or better than, planned: Operations ran smoothly. Samples were caught and interpeted in a timely and accurate manner. Measuring of surface parameters went as planned and all equipment functioned properly. Personnel on site worked as a team toward the efficient logging of well. SI34-W6 Nikaitchuq ENI Petroleum North Slope Borough AK-XX-0902143510 Alaska Surface Data Logging After Action Review WELL NAME:SI34-W6 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:20-Feb-2015 SPERRY JOB:AK-XX-0902143510 TD:18-Mar-2015 Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.0 0.1 327.8 160.0 -106.4 SV-4 758.0 8.7 199.9 756.6 -703.0 SV-3 1,136.0 20.8 235.6 1,122.7 -1,069.1 SV-2 1,409.0 28.0 234.6 1,370.3 -1,316.6 Permafrost Base 1,859.0 31.7 231.2 1,759.0 -1,705.5 SV-1 2,048.0 37.3 230.0 1,914.5 -1,860.8 Ugnu Top (UG4)2,465.0 49.3 232.7 2,217.5 -2,163.8 13 3/8" Casing Shoe 2,803.0 59.8 239.0 2,416.9 -2,363.3 TD 16" Borehole 2,816.0 60.2 238.9 2,423.4 -2,369.8 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 4,904.0 87.1 239.5 2,654.7 -2,601.0 Lower Ugnu 10,847.0 76.2 238.0 3,041.9 -2,988.3 Schrader Buff 11,778.5 77.0 245.5 3,274.2 -3,220.6 N Sequence Top 11,940.0 76.3 246.7 3,312.1 -3,258.4 N Sand Top 12,085.0 77.5 249.4 3,344.9 -3,291.3 N Sand Bottom 12,231.5 78.6 252.5 3,376.0 -3,322.4 N Sequence Base 12,516.0 82.1 255.4 3,420.6 -3,367.0 OA Sand Top 13,011.5 88.2 259.7 3,460.1 -3,406.4 OA-2 13,125.0 89.7 261.1 3,462.0 -3,408.3 9 5/8" Intermediate Csg. Shoe 13,304.0 89.7 264.2 3,462.2 -3,408.5 TD 12 1/4" Borehole 13,316.0 89.7 264.2 3,462.2 -3,408.6 8 3/4" Lateral Leg OA-3 13,340.5 89.2 265.6 3,462.7 -3,409.0 Fault A 13,980.0 92.2 273.0 3,450.7 -3,397.1 OA Sand Top 14,323.0 83.4 288.3 3,470.7 -3,417.1 OA-2 14,374.0 84.5 290.5 3,476.1 -3,422.5 OA-3 14,420.0 85.6 291.8 3,480.2 -3,426.5 Fault B 14,590.0 90.0 295.8 3,486.4 -3,432.7 OA Sand Top 14,864.0 82.5 305.6 3,500.5 -3,446.8 Fault C 14,940.0 85.2 306.2 3,508.7 -3,455.0 OA-Sand Base 15,109.0 93.5 311.7 3,511.5 -3,457.8 OA-4 15,163.0 95.1 314.1 3,507.0 -3,453.4 Fault D 15,620.0 87.9 323.3 3,508.4 -3,454.8 OA-Sand Top 15,705.0 89.1 326.4 3,510.6 -3,457.0 OA-Sand Top 15,895.0 85.1 337.2 3,519.3 -3,465.7 OA-2 17,463.0 88.4 320.9 3,544.3 -3,490.6 OA-3 17,570.0 86.7 320.6 3,548.9 -3,495.3 OA-3 19,295.0 93.0 324.9 3,538.9 -3,485.2 OA-2 19,400.0 93.0 325.3 3,533.4 -3,479.8 Fault E 19,923.0 89.5 323.8 3,530.7 -3,477.1 OA-Sand Base 20,195.0 97.3 323.5 3,513.4 -3,459.8 OA-4 20,213.0 97.1 323.4 3,511.1 -3,457.5 OA-3 20,360.0 93.8 322.2 3,496.2 -3,442.6 OA-2 20,400.0 92.7 322.2 3,493.8 -3,440.1 OA Sand Top 20,450.0 91.3 322.5 3,492.1 -3,438.4 OA Sand Top 20,752.0 87.0 318.2 3,504.4 -3,450.7 Fault F 21,455.0 86.8 298.7 3,537.8 -3,484.2 OA-Sand Base 22,452.0 99.9 273.1 3,435.2 -3,381.6 OA-4 22,470.0 99.8 273.3 3,432.2 -3,378.5 OA-3 22,637.0 94.8 274.1 3,409.5 -3,355.8 OA-2 22,660.0 94.0 274.1 3,407.7 -3,354.1 OA Sand Top 22,690.0 92.8 274.1 3,405.9 -3,352.3 Formation Tops WELL NAME:SI34-W6 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:20-Feb-2015 SPERRY JOB:AK-XX-0902143510 TD:18-Mar-2015 Marker MD INC AZ TVD TVDSS 8 3/4" Lateral Leg OA Sand Top 22,797.0 85.7 272.1 3,406.9 -3,353.3 OA-2 22,905.0 88.4 272.1 3,410.4 -3,356.8 OA-3 22,980.0 87.9 273.1 3,413.0 -3,359.4 Fault G 23,380.0 93.4 268.6 3,424.7 -3,371.1 OA-Sand Base 23,664.0 107.4 264.2 3,372.0 -3,318.3 OA-4 23,670.0 107.5 264.2 3,370.2 -3,316.5 OA-3 23,707.0 108.7 264.3 3,358.7 -3,305.0 OA-2 23,716.0 109.0 264.3 3,355.8 -3,302.1 OA Sand Top 23,731.0 109.5 264.3 3,350.9 -3,297.3 TD 8 3/4" lateral 23,886.0 109.4 264.5 3,298.7 -3,155.3 Formation Tops SI34-W6 ENI Petroleum MI Swaco Doyon 15 AK-XX-0902143510 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 20-Feb 867 9.10 106 30 34 18/43/61 5.3 94/64/52/37/16/14 3/-3.5 1/96 0.15 0.20 9.6 25.0 0.10/0.40 2000 120 Drilling 16" Surface Hole 21-Feb 2816 9.50 86 25 37 16/40/58 5.4 87/62/51/35/15/13 3/-4.5 1/95 0.15 0.25 9.4 22.0 0.10/0.30 2100 120 BROOH 22-Feb 2816 9.40 81 23 27 18/46/63 5.5 73/50/42/29/14/11 3/-4.5 1/95 0.15 0.20 9.5 21.0 0.10/0.35 2000 120 Run 13 3/8" Casing 23-Feb 2816 9.30 46 13 13 --42/29/22/15/7/6 ----------R/U for BOP test 24-Feb 2816 9.30 46 13 16 --42/29/22/15/7/6 ----------BOP Testing 25-Feb 3278 9.30 46 9 25 10/12/14 6.0 43/34/28/23/12/10 1/-4.5 3/93 1.20 9.8 3.0 0.80/2.20 16000 140 Drilling 12.25" Hole 26-Feb 5758 9.30 50 13 27 10/14/16 6.0 53/40/34/27/12/9 1/-4.8 3/92.2 0.10 0.80 9.5 8.5 0.50/2.00 15500 Drilling 12.25" Hole 27-Feb 8451 9.40 54 13 29 10/14/16 5.8 55/42/34/28/13/10 1/-6.0 3/91 0.10 0.70 9.5 13.0 0.35/1.60 15000 160 Drilling 12.25" Hole 28-Feb 9888 9.30 50 13 22 10/12/16 5.6 48/35/28/22/11/9 1/-6.0 3/91 0.10 0.70 9.7 12.5 0.35/1.70 17000 140 Circulate. Wait on Weather 1-Mar 9989 9.30 56 12 26 10/12/15 5.0 50/38/32/24/12/9 1/-6.0 3/91 0.10 0.70 9.8 11.5 0.40/1.70 16500 140 Drilling 12.25" Hole 2-Mar 11080 9.40 53 14 26 9/12/15 4.6 54/40/33/27/12/9 1/-6.0 3/91 0.10 0.65 9.6 10.0 0.35/2.30 18000 160 Drilling 12.25" Hole 3-Mar 12640 9.45 58 14 30 10/13/16 4.8 58/44/38/29/12/10 1/-6.5 3.5/90 0.10 0.80 9.8 11.0 0.45/2.00 15500 120 Drilling 12.25" Hole 4-Mar 13316 9.40 54 13 24 10/12/15 4.6 50/37/32/24/11/9 1/-8.0 3.5/88.5 0.10 0.60 9.8 12.0 0.40/2.40 16000 120 BROOH 5-Mar 13316 9.50 57 12 31 12/15/17 4.6 55/43/38/30/13/11 1/-8.0 3/89 0.10 0.65 9.8 12.5 0.30/2.20 15000 120 BROOH 6-Mar 13316 9.40 50 11 26 11/13/16 4.6 48/37/31/25/12/10 1/-8.0 3/89 0.10 0.70 9.7 12.5 0.35/2.20 15000 120 Mobilize Casing Equip 7-Mar 13316 9.50 63 12 32 12/15/17 4.8 56/44/38/30/13/12 1/-8.0 3/89 0.10 0.60 9.7 12.5 0.30/2.20 15000 120 RIH 9.625" Casing 8-Mar 13316 9.30 49 9 17 5/7/9 4.8 35/26/21/16/6/5 1/-7.5 3/89.5 0.10 0.50 9.6 10.0 0.25/2.00 14000 120 Circulate Hole 9-Mar 13316 9.30 50 10 16 6/7/9 4.8 36/26/21/16/6/5 1/-7.5 3/89.5 0.10 0.50 9.7 10.0 0.25/2.00 14000 120 Rack Back DP Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 10-Mar 13316 9.2 47 14 14 7/7/8 4.6 42/28/23/17/7/6 -/2 6.78 66/34 2.7 3.51 573 28.51 -0.4/6.4 2.7 Service Top Drive 11-Mar 13316 9.25 46 14 14 7/7/8 -42/28/22/17/7/6 -/-6.73 66/34 2.6 3.38 563 28.64 -0.4/6.4 2.7 Ream in hole 12-Mar 14180 9.25 48 14 13 7/7/8 4.8 41/27/21/16/7/6 -/2 3.07 60/40 2.7 3.51 631 29.53 -0.1/7.1 2.6 Drilling 8.75" Hole 13-Mar 15744 9.3 48 13 19 7/8/8 4.8 45/32/26/19/7/6 -/2 7.89 67/33 2.5 3.25 660 28.73 -0.9/6.4 2.8 Drilling 8.75" Hole 14-Mar 17978 9.35 48 14 17 7/8/8 4.8 45/31/26/19/7/6 -/2 8.01 69/31 2.3 2.99 722 28.98 -1.0/7.0 2.8 Drilling 8.75" Hole 15-Mar 19901 9.35 48 13 18 7/8/8 4.2 44/31/26/18/7/7 -/2 8.48 70/30 2.6 3.38 727 30.12 -0.8/7.6 2.8 Drilling 8.75" Hole 16-Mar 21650 9.35 47 13 18 7/7/8 4.2 44/31/25/17/7/6 -/2 8.53 70/30 2.6 3.38 746 29.17 -0.9/7.7 2.8 Drilling 8.75" Hole 17-Mar 23234 9.35 44 13 15 6/6/7 4.2 41/28/22/15/6/5 -/-11.5 71/29 2.2 2.86 685 29.44 -1.1/7.6 2.8 Drilling 8.75" Hole 18-Mar 23886 9.35 45 15 15 6/7/7 NA/-45/30/23/16/6/5 -/-8.75 71/30 2.2 2.86 663 29.14 -1.1/7.7 2.8 BROOH 19-Mar 23886 9.3 45 13 15 6/7/8 4.4 41/28/23/16/6/3 -/2 7.52 69/31 2 2.6 635 27.69 -1.2/6.0 2.9 BROOH 20-Mar 23886 9.3 47 14 15 7/7/7 4.4 43/29/23/17/7/6 -/2 7.5 69/31 1.9 2.47 633 27.39 -1.5/5.8 2.9 BROOH 21-Mar 23886 9.3 43 14 13 6/7/7 -41/27/22/15/6/5 -/-7.46 69/31 2.40 3.12 686 27.76 -1.8/5.4 3 BROOH 22-Mar 23886 9.45 45 15 13 7/7/7 -43/28/24/16/7/6 NA/-7.72 69/31 2.30 2.99 639 28.42 -1.6/6.6 2.9 BROOH 23-Mar 23886 9.45 49 15 14 7/7/8 -44/29/24/16/7/6 NA/-7.7 2.2 2.30 2.99 633.0 28.3 -1.6/6.7 2.9 POOH 24-Mar 23886 9.45 51 15 14 7/7/8 -44/29/25/16/7/6 NA/-8.5 2.3 2.20 2.86 625.0 28.2 -1.6/6.9 2.9 BOP test 25-Mar 23886 9.45 51 15 14 7/7/8 -44/29/25/16/7/6 NA/-8.5 2.3 2.20 2.86 620.0 28.2 -1.6/6.9 2.9 Ream in hole 26-Jan 23886 9.45 51 15 14 7/7/8 -44/29/25/16/7/6 NA/-8.5 2.3 2.20 2.86 62.0 28.2 ---Run 4.5" Casing Casing Record WELL NAME:LOCATION:Nikaitchuq OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:20-Feb-2015 SPERRY JOB:TD:18-Mar-2015 Remarks 20" Conductor @ 160' MD, 160' TVD 9.625" Intermediate Casing @ 13304' MD, 3462' TVD 13.375" Surface Casing @ 2803' MD, 2417' TVD W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 200 1 Hughes MX-1 Mill Tooth 16.00 160 2816 2656 17.50 1.117 151.7 20 40 1700 800 1-1-WT-A-E-NO-TD Surface Section 3 300 2 Hughes T507X PDC 12.25 2816 13316 10500 102.80 0.969 102.1 18 193 3236 2520 1-5-BT-S-X-2-ER-TD Intermediate Section 4 400 3 Hycalog SKH616M 8.75 13316 23886 10570 85.90 0.902 123.1 12 140 3600 500 1-1-CT-A-X-I-NO-TD Injection Section WELL NAME:SI34-W6 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902143510 TD:18-Mar-2015 MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:20-Feb-2015 B i t R e c o r d . . * 24 hr Recap: out (sec/qt) Viscosity Cor Solids % Rig up 0 Chlorides mg/l 18-Feb-2015 12:00 AM Current Pump & Flow Data: Max Depth ROP ROP (ft/hr) 4.23 @ Mud Data Density (ppg) Morning Report Report # 1 Customer: Well: Area: Location: Rig: Job No.: Daily Charges: Total Charges: B.Simonson/O. Amend MWD Summary 96% Rig Activity: Report For: Tools Size Condition Bit # 0 WOB Cement 100% Gas In Air =10,000 Units Connection Min Comments RPM ECD (ppg) ml/30min API FL Background (max) Trip Average Mud Type Lst Type Depth in / out 000 0 C-4i C-4n Sh Clyst Chromatograph (ppm) 24 hr Max Weight 0 Hours C-3 0 (ppb Eq) C-1 C-5i PV YP (lb/100ft 2)cP Silt Footage Ss Cht Tuff Gvl Coal Gas Summary 0 0 0 (current) to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Avg Date: ENI PETROLEUM SI34-W6 SPY ISLAND NORTH SLOPE AK-AM-0901938178 DOYON 15 0' 0' 0' Max @ ft Current RIG UP Time: Avg in Minimum Depth C-5n C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth MBT 0' pH 0 0 0 Siltst Units* Casing Summary Lithology (%) 00 0 (907) 685-0772 Unit Phone: 0 Paul Kalenuik Maximum Report By: Logging Engineers: Paul Kalenuik/Kori Jo Plowman Set At Size Grade (max) (current) 0 0 Cly 0 . . * 24 hr Recap: (current) 0 0 Cly 0 Set At Size Grade (907)685-0772 Unit Phone: 0 Paul Kalenuik Maximum Report By: Logging Engineers: Paul Kalenuik/Kori Jo Plowman Complete rig up. N/U flow riser, N/U Diverter. Dummy run 13-3/8" hanger. Service/inspect top drive. Cut/slip 105' drill line. Bring BHA to floor, install short/long mouse hole. M/U 5 std HWDP w/jars & saver sub, 1 std 8" NMFC. 0 0 Units* Casing Summary Lithology (%) Siltst 0 MBT 0' pH 0 0 0 Gallons/stroke TFA Bit Type Depth 24.0 172 C-2 SPP (psi) DOYON 15 in Minimum Depth C-5n 0' 0' 0' Max @ ft Current Date: ENI PETROLEUM SI34-W6 Time: MU HWDP Job No.: Daily Charges: Total Charges: B.Simonson/O. Amend Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Sh Clyst Tuff Gvl Coal Footage Size Ss (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.80 24 hr Max Weight 0 Hours C-3 0 000 0 Cement C-4i 0'48 Depth in / out Cht Silt C-4n Mud Type Lst Type Average Background (max) Trip (max) RPM ECD (ppg) ml/30min Spud 5.9 Avg Min Comments cP 32 Tools API FL Chromatograph (ppm) WOB 100% Gas In Air =10,000 Units Connection 0 3.0 8.80 96% Rig Activity: Report For: Condition Bit # Morning Report Report # 2 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE AK-AM-0901938178 ROP ROP (ft/hr) 4.23 @ Mud Data Depth MWD Summary 19-Feb-2015 12:00 AM Current Pump & Flow Data: Max 0 mg/l 1600.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 L/D mouse hole, clean/clear rig floor. M/U BHA #1 as per SLB. Test mud line, flood conductor. Drill out conductor 100% Gas In Air =10,000 Units BROOH f/392' t/ 117'. M/U remaining BHA t/341', wash down t/392'. Drill f/392' t/1053'MD, 1044'TVD. Max gas=46units. Chlorides mg/l 2000.00 0 20-Feb-2015 12:00 AM Current Pump & Flow Data: 1000 Max SP Motor, Telescope 825, ARC 825 ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: MWD Summary 96% Rig Activity: 13.34 Report For: 160' Condition Bit # 1 3.5 16 9.10 Connection 0 0 Tools API FL Chromatograph (ppm) 160' WOB 9.42 10.29 Avg Min Comments RPM ECD (ppg) ml/30min 3Background (max) Trip Average Mud Type Lst Type Spud 5.3 867'34 Depth in / out 000 0 0 Cement Cht Silt C-4i C-4n Sh 24 hr Max Weight 0 Hours C-3 cP 30 Ss (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.60 Footage Size Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to 160' Yesterday's Depth: Current Depth: 24 Hour Progress: 504.0 Flow In (gpm) Flow In (spm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Job No.: Daily Charges: Total Charges: Drilling 16" hole B.Simonson/O. Amend 160' 1053' 893' Max @ ft Current Date: ENI PETROLEUM SI34-W6 Time: 10 DOYON 15 in 3 543'Minimum Depth C-5n 1035' 136.0 C-2 49 SPP (psi) Gallons/stroke TFA Bit Type Depth 25.0 106 MBT Present pH 1.117 0 0 0 640 153 Units* Casing Summary Lithology (%) Siltst 480'188.0 (current) 1652 44 0 0 (max) (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 7265 Set At Size Grade 20.00'' . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Drill f/1053' t/2816'MD, 2422'TVD. BROOH f/2816' t/2268' @850gpm. mg/l 2100.00 Evermar 21-Feb-2015 12:00 AM Current Pump & Flow Data: 1600 Max Depth 0 ROP ROP (ft/hr) 4.23 @ Mud Data Chlorides Morning Report Report # 4 Customer: Well: Area: Location: Rig: MWD Summary 96% Rig Activity: 10.69 Report For: 160' Condition Bit # 1 16 9.50 Connection 0 9.52 10.16 100% Gas In Air =10,000 Units 4.5 SP Motor, Telescope 825, ARC 825 0 Conductor API FL Chromatograph (ppm) 160' WOB 178.9 X-65 Avg Min Comments RPM ECD (ppg) ml/30min Tools 3Background (max) Trip Average Mud Type Lst Type Spud 5.4 2816'37 Depth in / out 0 0 0 Cement 0 Tuff Gvl 25 Cht Silt C-4i C-4n Sh Clyst 24 hr Max Weight 0 Hours C-3 cP Size Ss (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.40 Gas Summary 0 0 0 (current) Yesterday's Depth: Current Depth: 24 Hour Progress: 407.0 Flow In (gpm) Coal Footage B.Simonson/O. Amend DOYON 15 Avg to 160' SPY ISLAND NORTH SLOPE AK-AM-0901938178 Job No.: Daily Charges: Total Charges: BROOH 1053' 2816' 1763' Max @ ft Current Date: ENI PETROLEUM SI34-W6 Time: 143 5 1998'Minimum 2031' N/A C-2 1005 in Bit Type Depth 22.0 86 C-5n Depth Set At Flow In (spm) 1.117 0 0 0 SPP (psi) Gallons/stroke TFA Units* Casing Summary Lithology (%) Siltst 2545'188.0 MBT Present 116 850 201 0 pH (max) 21198 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Size Grade 20.00'' (current) 0 0 Cly 128002 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD BROOH f/2268' t/400'. L/D BHA as per SLB f/400 t/0', rack back HWDP, jars & collars. Clean/clear rig floor. MOB & 0 16 10,000 Units float equip. Run 13-3/8" casing f/120' t/2763', break circ. every 10jts. Chlorides mg/l 2000.00 22-Feb-2015 12:00 AM Current Pump & Flow Data: 100 Max Run 13 3/8" Casing ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: MWD Summary 96% Rig Activity: Report For: 160' Condition Bit # 1 4.5 9.40 100% Gas In Air =Connection 0 0 Tools API FL Chromatograph (ppm) 20.0 160' 2816' WOB Avg Min Comments RPM ECD (ppg) ml/30min 40.0 3Background (max) Trip Average Mud Type Lst Type Spud 5.5 2816'27 Depth in / out 2656' 000 0 0 Cement Cht Silt C-4i C-4n Sh 24 hr Max Weight 0 Hours C-3 cP 23 Ss (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.50 Footage 17.50 Size Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Job No.: Daily Charges: Total Charges: B.Simonson/O. Amend 2816' 2816' 0' Max @ ft Current Date: ENI PETROLEUM SI34-W6 Time: 29 DOYON 15 in 3Minimum Depth C-5n C-2 713 SPP (psi) Gallons/stroke TFA Bit Type Depth 21.0 81 MBT pH 1.117 0 0 0 110 25 Units* Casing Summary Lithology (%) Siltst (current) 4109 0 0 0 (max) (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 94045 Set At Size Grade 20.00'' . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth 1-1-WT-A-E-IN-NO-TD Land 13-3/8" casing on hanger @2803'. B/D top drive, R/U circ. & condition for cement job, stage up t/5bpm. Test 0Average 174bbls of cmt returns. Drain stack, fill w/contam pill, rinse, R/D Volant, L/D landing jt. Install bails, 5" elevators, M/U stack wash Chlorides mg/l 23-Feb-2015 12:00 AM Current Pump & Flow Data: Max Evermar Conductor R/U for BOP test ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: MWD Summary 96% Rig Activity: Report For: equip. Flush BOP stack, L/D casing equip. N/D diverter. Set multi-bowl, test hanger seals. N/U BOP. Level rig floor. R/U for BOP 0 Connection body test. 160' Condition Bit # 1 16 100% Gas In Air =10,000 Units API FL Chromatograph (ppm) 20.0 160' 2816' WOB 178.9 X-65 Avg Min Comments RPM ECD (ppg) ml/30min Tools Background (max) Trip Mud Type Spud 2816' (ppb Eq) C-1 9.30 40.0 Ss 00 Lst 0 0 Cement Cht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 0 PV YP (lb/100ft 2)cP 13 2656' 16 Footage 17.50 Size Depth in / out Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) C-5i Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Job No.: Daily Charges: Total Charges: B.Simonson/O. Amend 2816' 2816' 0' Max @ ft Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 in Minimum Depth C-5n C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth 46 0 MBT pH 1.117 0 0 0 Units* Casing Summary Lithology (%) Siltst 0 0 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Set At Size Grade 20.00'' Type (max) (current) 0 0 Cly 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD Con't N/U BOPE's. Perform body test on BOPE & Choke. OK. SIMOPS: process 5" DP in pipe shed. B/D Choke 0 0 5" DP. R/U test equip. Test BOPE's per regulations. Chlorides mg/l 24-Feb-2015 12:00 AM Current Pump & Flow Data: Max J. Keener/O. Amend ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: MWD Summary 96% Rig Activity: Report For: Avg Min Bit # 1 =10,000 Units Connection 9.30 100% Gas In Air 160' Tools API FL Chromatograph (ppm) 20.0 160' 2816' WOB Comments RPM ECD (ppg) ml/30min 40.0 Condition Background (max) Trip Average Mud Type Lst Type Spud 2816'16 Depth in / out 2656' 000 0 0 Cement Cht Silt C-4i C-4n Sh 24 hr Max Weight 0 Hours C-3 cP 13 Ss (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) Footage 17.50 Size 16 Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Job No.: Daily Charges: Total Charges: BOP Testing 2816' 2816' 0' Max @ ft Current Date: ENI PETROLEUM SI34-W6 Time: Depth C-5n DOYON 15 in Minimum C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth 46 0 MBT pH 1.117 0 0 0 Units* Casing Summary Lithology (%) Siltst 0 0 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Set At Size Grade 20.00'' Evermar (max) (current) 0 0 Cly 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Test BOPE's. 30 min csg test to 2500 psi. M/U 12-1/4" bit & BHA. RIH to 1,749'. Shallow test MWD. OK. RIH to 2,682' Chlorides mg/l 16000.00 0 8Background 25-Feb-2015 12:00 AM Current Pump & Flow Data: 1500 Max J. Keener/O. Amend Drill 12.25" Hole Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE Displace to 9.3 ppg LSND. Clean surface equip. FIT test: 13.0 ppg. Service rig. Drill f/2,836' to 3,518' MD/2,598' TVD. Monitor well. MWD Summary 96% Rig Activity: 9.87 Report For: 4.5 9.30 Static. 160' Condition Bit # 1 16 0 9.52 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst Type PDC LSND 6.0 2816' 3278'25 Depth in / out 2 2656' 000 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 9 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.80 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: 400.0 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 9.73 Avg Total Charges: 2816' 3572' 756' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 14 0 0 Depth 16.00'' Set At Gas Summary 0 0 0 3174'Minimum C-5n 3050' 117.0 C-2 113 TFA Bit Type Depth 3.0 46 in Xceed 900, Telescope 825, ARC 825 0 MBT Present pH 1.117 0 0 0 0 901 213 Units* Casing Summary Lithology (%) Siltst 3177'218.6 0 0354 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 16204 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Drill f/3,518' to 6,136' MD/2,721' TVD. Monitor well. Static. Chlorides mg/l 15500.00 0 6Background 26-Feb-2015 12:00 AM Current Pump & Flow Data: 2000 Max J. Keener/O. Amend Drill 12.25" Hole Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: 10.36 Report For: 4.8 9.30 160' Condition Bit # 1 16 0 9.58 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst 100 Type PDC LSND 6.0 2816' 5758'27 Depth in / out 2 2656' 000 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 13 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.50 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: 487.0 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 9.99 Avg Total Charges: 3572' 6194' 2622' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 34 0 0 Depth 16.00'' Set At Gas Summary 0 0 3 4554'Minimum C-5n 4044' 170.0 C-2 151 TFA Bit Type Depth 8.5 50 in Xceed 900, Telescope 825, ARC 825 0 MBT Present pH 1.117 0 0 0 5439 901 213 Units* Casing Summary Lithology (%) Siltst 6136'246.3 0 013 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 21800 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Drill f/6,194' to 8,746' MD/2,848' TVD. Chlorides mg/l 15000.00 0 6Background 27-Feb-2015 12:00 AM Current Pump & Flow Data: 2400 Max J. Keener/O. Amend Drill 12.25" Hole Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: 10.55 Report For: 6.0 9.40 160' Condition Bit # 1 16 0 10.04 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst 90 Type PDC LSND 5.8 2816' 8451'29 Depth in / out 2 2656' 000 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 13 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.50 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: 470.9 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 10.32 Avg Total Charges: 6194' 8746' 2552' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 9 0 0 Depth 16.00'' Set At Gas Summary 0 0 2 8279'Minimum C-5n 6342' 160.0 C-2 50 TFA Bit Type Depth 13.0 54 in Xceed 900, Telescope 825, ARC 825 0 MBT Present pH 1.117 0 0 0 882 892 212 Units* Casing Summary Lithology (%) Siltst 7640'221.0 0 083 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 7682 10 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Drill f/8,746' to 9,892' MD. Monitor well. Static. Rack back 2 stds to 9,776' due to Phase 3 weather conditions. Chlorides mg/l 17000.00 0 2Background 28-Feb-2015 12:00 AM Current Pump & Flow Data: 700 Max J. Keener/O. Amend Wait on Weather Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: 10.53 Report For: 6.0 9.30 160' Condition Bit # 1 16 0 7.00 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst 90 Type PDC LSND 5.6 2816' 9888'22 Depth in / out 2 2656' 000 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 13 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.70 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: 446.5 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 10.31 Avg Total Charges: 8746' 9892' 1146' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 7 0 0 Depth 16.00'' Set At Gas Summary 0 0 2 8875'Minimum C-5n 9726' - C-2 11 TFA Bit Type Depth 12.5 50 in Xceed 900, Telescope 825, ARC 825 0 MBT Present pH 1.117 0 0 0 243 404 96 Units* Casing Summary Lithology (%) Siltst 8871'223.4 6 0141 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 1113 10 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Circulate hole while waiting on Phase 3 conditions. Wash down f/9,863' to 9,892'. Drill f/9,892' to 10,022' MD. Monitor Chlorides mg/l 16500.00 0 1Background 1-Mar-2015 12:00 AM Current Pump & Flow Data: 2400 Max J. Keener/O. Amend Drill 12.25" Hole Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: 10.53 Report For: 6.0 9.30 160' Condition Bit # 1 16 0 7.00 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst 90 Type PDC LSND 5.0 2816' 9989'26 Depth in / out 2 2656' 000 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 12 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.80 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst 10 Tuff Gvl Coal Ss 24 Hour Progress: 254.4 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 10.31 Avg Total Charges: 9892' 10022' 130' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 6 0 6 Depth 16.00'' Set At Gas Summary 0 0 2 10018'Minimum C-5n 9899' 5.1 C-2 25 TFA Bit Type Depth 11.5 56 in Xceed 900, Telescope 825, ARC 825 0 MBT Present pH 1.117 0 0 0 253 903 214 Units* Casing Summary Lithology (%) Siltst 9973'91.5 13 00 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 465 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Drill f/10,021' to 11,224' MD. Daily LSND loss: 31 bbls. Chlorides mg/l 18000.00 0 3Background 2-Mar-2015 12:00 AM Current Pump & Flow Data: 2600 Max J. Keener/O. Amend Drill 12.25" Hole Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: 10.53 Report For: 6.0 9.40 160' Condition Bit # 1 16 0 7.00 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst 80 Type PDC LSND 4.6 2816' 11080'26 Depth in / out 2 2656' 000 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 14 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.60 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: 411.9 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 10.31 Avg Total Charges: 10022' 11281' 1259' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 7 0 5 Depth 16.00'' Set At Gas Summary 0 0 2 10317'Minimum C-5n 11157' 165.0 C-2 33 TFA Bit Type Depth 10.0 53 in Xceed 900, Telescope 825, ARC 825 0 MBT Present pH 1.117 0 0 0 938 904 214 Units* Casing Summary Lithology (%) Siltst 10429'194.1 20 7 0172 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 4941 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Drill f/11,281' to 12,736' MD. Daily LSND loss: 49 bbls. Chlorides mg/l 15500.00 150 29 Background 3-Mar-2015 12:00 AM Current Pump & Flow Data: 2700 Max J. Keener/O. Amend Drill 12.25" Hole Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: 10.69 Report For: 6.5 9.45 160' Condition Bit # 1 16 902 10.26 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst 60 Type PDC LSND 4.8 2816' 12640'30 Depth in / out 2 2656' 5104 183 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 14 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.80 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: 405.5 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 10.50 Avg Total Charges: 11281' 12736' 1455' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 94 0 192 Depth 16.00'' Set At Gas Summary 440 726 2 12097'Minimum C-5n 12403' 49.5 C-2 1005 TFA Bit Type Depth 11.0 58 in Xceed 900, Telescope 825, ARC 825 183 MBT Present pH 1.117 0 895 0 9452 898 212 Units* Casing Summary Lithology (%) Siltst 11774'141.2 40 1674 033 (907)685-0772 Unit Phone: 15 Greg Dellner Maximum Report By: Logging Engineers: Kori Jo Plowman/Greg Dellner Cly 96735 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Drill f/12,722' to TD at 13,316' MD. Circ x 2 & rack back 2 stds to 13,135'. BROOH to 12,477'. Chlorides mg/l 16000.00 1012 11 Background 4-Mar-2015 12:00 AM Current Pump & Flow Data: 2500 Max J. Keener/R. Wimmer BROOH Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: 10.84 Report For: 8.0 9.40 160' Condition Bit # 1 16 4385 10.40 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst 30 Type PDC LSND 4.6 2816' 13316'24 Depth in / out 2 2656' 262 745 428 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 13 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.80 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: 335.6 Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max 10.63 Avg Total Charges: 12736' 13316' 580' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 385 0 675 Depth 16.00'' Set At Gas Summary 2771 1317 5 13314'Minimum C-5n 13079' - C-2 2070 TFA Bit Type Depth 12.0 54 in Xceed 900, Telescope 825, ARC 825 522 MBT Present pH 1.117 20 2068 22 9452 898 212 Units* Casing Summary Lithology (%) Siltst 13052'138.0 70 3327 8308 (907)685-0772 Unit Phone: 792 Greg Dellner Maximum Report By: Logging Engineers: Paul Kalenuik/Greg Dellner Cly 150928 Size Grade 20.00'' BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Evermar Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface BROOH f/12,477' to 5,202'. Daily LSND loss: 54 bbls. Chlorides mg/l 15000.00 0 3Background 5-Mar-2015 12:00 AM Current Pump & Flow Data: 1700 Max J. Keener/R. Wimmer BROOH Max @ ft SPP (psi) Gallons/stroke ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: SPY ISLAND NORTH SLOPE MWD Summary 96% Rig Activity: Report For: 8.0 9.50 160' Condition Bit # 1 16 0 2803' 100% Gas In Air =10,000 Units Min Comments RPM ECD (ppg) ml/30min 40.0 Tools API FL (max) Trip (max) (current) Connection Average Mud Type Lst Type PDC LSND 4.6 2816' 13316'31 Depth in / out 2 2656' 000 0 0 Cht Silt C-4i C-4n Sh Chromatograph (ppm) C-3 cP 12 Cement 20.0 2816' WOB C-1 C-5i PV YP (lb/100ft 2) 9.80 68.0 Weight 12.25 0.969 Footage 17.50 Size Hours 160' (current) Clyst Tuff Gvl Coal Ss 24 Hour Progress: Flow In (gpm) Flow In (spm) (ppb Eq) 24 hr Max Avg Total Charges: 13316' 13316' 0' Avg to 2816' Yesterday's Depth: Current Depth: Current Date: ENI PETROLEUM SI34-W6 Time: DOYON 15 AK-AM-0901938178 Job No.: Daily Charges: 19 0 0 Depth 16.00'' Set At Gas Summary 0 0 3 13314'Minimum C-5n 13079' C-2 118 TFA Bit Type Depth 12.5 57 in Xceed 900, Telescope 825, ARC 825 0 MBT Present pH 1.117 0 0 0 0 903 213 Units* Casing Summary Lithology (%) Siltst 0 00 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Paul Kalenuik/Greg Dellner Cly 0 Size Grade 20.00'' BTC . . * 24 hr Recap: Mill Tooth 2816' Density (ppg) out (sec/qt) Viscosity Cor Solids % Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface Comments 40.0 BROOH f/5,202' to 1,468'. POH. L/D BHA #3. Clean rig floor. Pull wear ring & set test plug. Test rams. OK. Clean rig 1-5-BT-S-X-2-ER-TD Chlorides mg/l 15000.00 0 00 6-Mar-2015 12:00 AM Current Pump & Flow Data: Max J. Keener/R. Wimmer Mobilize Csg Equip ROP ROP (ft/hr) 4.23 @ Mud Data Avg Min pH 9.40 Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: 0 MWD Summary 96% Rig Activity: Report For: 8.0 Connection 160' Condition Bit # 1 16 WOB 2803' 100% Gas In Air =10,000 Units Tools API FL Chromatograph (ppm) 10 20.0 160' 2816' (max) (current) RPM ECD (ppg) ml/30min Background (max) Trip PDC LSND 4.6 Average 0 C-4n Ss Mud Type Lst Cht Silt C-4i 13316'26 13316' Depth in / out 2 0 0 0 Cement 24 hr Max 68.0 Weight 0 Hours C-3 Type (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.70 190 cP 11 2656' 12.25 0.969 Footage 102.80 10500' 17.50 Size 1.117 Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Job No.: Daily Charges: Total Charges: 13316' 13316' 0' Max @ ft Current Date: ENI PETROLEUM SI34-W6 Time: 9 Depth C-5n DOYON 15 in 2Minimum C-2 50 MBT 62 SPP (psi) Gallons/stroke TFA Bit Type Depth 12.5 0 0 0 16.00'' Units* Casing Summary Lithology (%) 0 0 0 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Paul Kalenuik/Greg Dellner Set At Size Grade 20.00'' BTC Evermar 0 Cly 0 Siltst . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface 1-5-BT-S-X-2-ER-TD 40.0 68.0 R/U Tesco & 9-5/8" csg equip. M/U shoe track & test floats. OK. RIH csg to 3,852'. Start rotate at 40 rpm f/3,852' Chlorides mg/l 15000.00 0 Background to 7-Mar-2015 12:00 AM Current Pump & Flow Data: Max J. Keener/R. Wimmer RIH 9 5/8" Csg Gallons/stroke ROP ROP (ft/hr) 4.23 @ 24 hr Max Avg Mud Data Depth Morning Report Report # 18 Customer: Well: Area: Location: Rig: MWD Summary 96% Rig Activity: Report For: 8.0 160' Condition Bit # 1 16 Connection 0 9.50 2803' 100% Gas In Air =10,000 Units Tools API FL Chromatograph (ppm) 10 20.0 160' 2816' Avg Min Comments RPM ECD (ppg) ml/30min (max) Trip (max) (current) Average Mud Type Lst Type PDC LSND 4.8 2816' 13316'32 13316' Depth in / out 2 WOB 000 0 00 Silt C-4i C-4n 0 Hours C-3 Sh Clyst Gas Summary Cement Ss (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.70 190 2656' 12.25 0.969 Footage 102.80 10500' 17.50 Size C-5n Tuff Gvl Coal Job No.: 0 0 (current) 0' Max @ ft Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Current Date: ENI PETROLEUM SI34-W6 Time: Daily Charges: Total Charges: 13316' 13316' DOYON 15 in SPP (psi) Minimum Depth Flow In (spm) cP 12 C-2 pH 1.117 0 0 0 TFA 12.5 63 0 MBT Bit Type Depth 0 16.00'' Units* Casing Summary Lithology (%) 0 0 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Paul Kalenuik/Greg Dellner Size Grade 20.00'' BTC Weight Evermar Cly 0 Set At 0 Siltst Cht . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface 1-5-BT-S-X-2-ER-TD 40.0 68.0 RIH 9-5/8" csg rot at 40 rpm f/12,747' to 13,304'. R/D Tesco equip. R/U long bails & cmt head. Fill csg. Blow down Chlorides mg/l 14000.00 0 Background to 8-Mar-2015 12:00 AM Current Pump & Flow Data: Max J. Keener/R. Wimmer Circ Hole Gallons/stroke ROP ROP (ft/hr) 4.23 @ 24 hr Max Avg Mud Data Depth Morning Report Report # 19 Customer: Well: Area: Location: Rig: MWD Summary 96% Rig Activity: Report For: 7.5 160' Condition Bit # 1 16 Connection 0 9.30 2803' 100% Gas In Air =10,000 Units Tools API FL Chromatograph (ppm) 10 20.0 160' 2816' Avg Min Comments RPM ECD (ppg) ml/30min (max) Trip (max) (current) Average Mud Type Lst Type PDC LSND 4.8 2816' 13316'17 13316' Depth in / out 2 WOB 000 0 00 Silt C-4i C-4n 0 Hours C-3 Sh Clyst Gas Summary Cement Ss (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.60 190 2656' 12.25 0.969 Footage 102.80 10500' 17.50 Size C-5n Tuff Gvl Coal Job No.: 0 0 (current) 0' Max @ ft Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Current Date: ENI PETROLEUM SI34-W6 Time: Daily Charges: Total Charges: 13316' 13316' DOYON 15 in SPP (psi) Minimum Depth Flow In (spm) cP 9 C-2 pH 1.117 0 0 0 TFA 10.0 49 0 MBT Bit Type Depth 0 16.00'' Units* Casing Summary Lithology (%) 0 0 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Paul Kalenuik/Greg Dellner Size Grade 20.00'' BTC Weight Evermar Cly 0 Set At 0 Siltst Cht . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Mill Tooth Conductor 178.9 X-65 1-1-WT-A-E-IN-NO-TD L-80 Surface 1-5-BT-S-X-2-ER-TD 40.0 68.0 L-80 Intermediate Chlorides Evermar mg/l 14000.00 0 Background 9-Mar-2015 12:00 AM Current Pump & Flow Data: Max J. Keener/R. Wimmer Rack Back DP ROP ROP (ft/hr) 4.23 @ Mud Data 24 hr Max Avg to Depth Circ & cond hole. Test cmt lines. OK. Cmt casing. Did not bump plug. Check floats. OK. Drain stack. R/D BOP. Set Morning Report Report # 20 Customer: Well: Area: Location: Rig: bad jts. POH 5" DP. MWD Summary 96% Rig Activity: Report For: 7.5 160' Condition Bit # 1 16 Connection 9.30 2803' 100% Gas In Air =10,000 Units Tools API FL Chromatograph (ppm) 10 20.0 160' 2816' Avg Min Comments RPM ECD (ppg) ml/30min (max) Trip (current) Average Mud Type Lst Type PDC LSND 4.8 2816' 13316'16 13316' Depth in / out 2 WOB 000 0 00 Cement Cht Silt C-4i C-4n Tuff Hours C-3 Sh Clyst 0 Hydril 563 (ppb Eq) C-1 C-5i PV YP (lb/100ft 2) 9.70 190 Weight cP 10 2656' 12.25 0.969 Footage 102.80 10500' 17.50 Size Gvl Coal 40.0 Gas Summary Cly Ss C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) SPY ISLAND NORTH SLOPE AK-AM-0901938178 Job No.: Date: ENI PETROLEUM SI34-W6 Time: Daily Charges: Total Charges: 13316' 13316' 0' DOYON 15 in Current Max @ ft 0 0 (current) Minimum Depth 0 0 C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 50 MBT pH 1.117 0 0 0 Set At Units* Casing Summary Lithology (%) Siltst 0 16.00'' 0 0 (907)685-0772 Unit Phone: 0 Greg Dellner Maximum Report By: Logging Engineers: Paul Kalenuik/Greg Dellner Size Grade 13304' 20.00'' 9.63'' (max) BTC 0 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0902143510 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft Customer: Well: Area: Location: Rig: SI34-W6 Avg 10-Mar-2015 Morning Report Report # 21 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg) Tools None 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 13316'7 Mud Type FazePro N/A Ratio Mud Data Depth 66/349.20 Oil / Water (lb/100ft2) 2816' WOB Mill Tooth TFA Condition 1-1-WT-A-E-IN-NO-TD 14 RPM 47 20.0 Size 160'ConductorEvermar PDC Casing Summary L-80 Bit Type L/D shoe, install mouse hole, C/O elevators t/4.5". P/U 84stds 4.5" DP & rack back. Clean/clear rig floor, pull wear Trip equip. Bring BHA #4 tools/equip to floor. Purge mud pump lines, test 9-5/8" casing t/3000psi. Load 730bbls of OBM to pits. R/D 2 2816' 102.80 & B/D all lines/equip. Service top drive, inspect dies. 100% Gas In Air=10,000 UnitsConnection Average Background Mud (lb/bbl)ml/30min 3.512.70 (max) 0 C-3 10500' Chromatograph (ppm) 0 0 0 0 0 0 Cement C-1 C-5i ShSiltst LstClyst C-4i Service Top Drive PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 1012.25 0.969 Footage 40.0 Depth in / out 13304' 16 160' 13316' 2803' Ss Cht Silt to13316' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 13316' 13316' 0' Lime TuffGvl Surface 1-5-BT-S-X-2-ER-TD 96% Date: % Alkal Coal Gallons/stroke ring, install test plug. R/U to test BOPE. Test BOPE w/4.5" & 5" test jt. Pull test plug, install wear ring. R/D & B/D all lines, tools & 0 0 0 Minimum Depth 16.00'' Maximum in Lithology (%) 1 Bit # 0 0 Depth Present 1.117 14 0 C-2 0 C-4n 0 Gas Summary (lb/100ft2)(current) Units* 907-685-0772Unit Phone: 0 Greg Dellner Set AtSize 178.9 X-65 Grade 190 40.0 Hours 17.50 Cly Hydril 563 L-80 Comments Intermediate 2656' Report By: 20.00" 9.63'' Logging Engineers:Alexander Kalenuik/Greg Dellner (max)(current) BTC 0 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers: Alexander Kalenuik/Greg Dellner (max) (current) BTC 0 0 190 40.0 Hours 17.50 Cly Hydril 563 L-80 Comments Intermediate 2656' 907-685-0772 Unit Phone: 0 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary 70 (current) Units* C-2 0 C-4n 0 0 0 Depth Present 1.117 14 0Minimum Depth 16.00'' Maximum in Lithology (%) 1 Bit # 0 0 0 % Alkal Coal Gallons/stroke 13316' 13316' 0' Lime Tuff Gvl Surface 1-5-BT-S-X-2-ER-TD 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to 13316' Current MWD Summary Ss Cht Silt 30 12.25 0.969 Footage 40.0 Depth in / out 13304' 16 160' 13316' 2803' Ream in hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 0 0 0 0 Morning Report Report # 22 10500' Chromatograph (ppm) 0 0 Mud (lb/bbl) ml/30min 3.38 2.60 (max) 0 C-3 Average Background 100% Gas In Air =10,000 Units Connection CBL f/10915' t/12987'. P/U BHA #4 as per SLB. Install radioactive source as per SLB. P/U BHA #4 as per SLB. C/O handling equip t/4.5", Trip downlink for logging mode. Start CBL while reaming in hole f/10533' t/10915', C/O handling equip f/4.5" t/5". Ream in hole and 2 2816' 102.80 10 20.0 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 2816' WOB Mill Tooth TFA Condition 1-1-WT-A-E-IN-NO-TD RPM Mud Data Depth 66/34 9.25 Oil / Water (lb/100ft 2) 14 46 Report For: 13316'7 Mud Type FazePro N/A Ratio Cor Solids Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ Current Pump & Flow Data: DOYON 15 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 11-Mar-2015 12:00 AM AK-AM-0902143510 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 0 00 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 103 57 241 12:00 AM AK-AM-0902143510 2785 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 13916'391.0 Customer: Well: Area: Location: Rig: SI34-W6 Avg 12-Mar-2015 Morning Report Report # 23 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.20 Cor Solids 10.98 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 14180'3 10.78 Mud Type FazePro N/A Ratio Mud Data Depth 60/40 9.25 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 13 RPM 48 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type RIH, displace well to OBM. Drill out plug and clean surface equipment. Drill out 20' of new hole to 13336' MD. Trip 3 13316' tr pyr. Samples up to around 14000' MD consisted of mainly clean Sst. Sample: The last sample collected was @ 14250' MD with around 80% Sst and 20% Siltst: m-v f gr, sb ang-sb rnd, mod srt, r mic, 100% Gas In Air =10,000 Units Connection Average 6Background Mud (lb/bbl) ml/30min 3.51 2.70 (max) 589 C-3 Chromatograph (ppm) 1094 763 216 298 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt 80 to 13316' Current 252.0 9.2 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 116 SPP (psi) 13316' 14347' 1031' Lime Tuff Gvl Surface 96% Date: % 491 Alkal Coal Gallons/stroke 350 13845' 0 322 135 Minimum Depth 16.00'' Maximum in 3 Lithology (%) 2 Bit # 36291 519 13339' Depth Present 0.969 14 66 C-2 0 C-4n 0 Gas Summary 1094 20 (current) Units* 907-685-0772 Unit Phone: 72 Kori Jo Plowman Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 122513 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 96136 0 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772 Unit Phone: 76 Kori Jo Plowman Set At Size 178.9 X-65 Grade Gas Summary 863 20 (current) Units* C-2 0 C-4n 0 16359 205 15452' Depth Present 0.969 13 53 Minimum Depth 16.00'' Maximum in 5 Lithology (%) 2 Bit # 15358' 0 280 164 147 % 495 Alkal Coal Gallons/stroke 14347' 16040' 1693' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 117 SPP (psi) Avg to 13316' Current 219.0 239.0 MWD Summary Ss Cht Silt 80 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 124 283 0 0 Morning Report Report # 24 Chromatograph (ppm) 963 547 Mud (lb/bbl) ml/30min 3.25 2.50 (max) 273 C-3 Average 32 Background 100% Gas In Air =10,000 Units Connection med-v f gr, sb ang-sb rnd, mod srt, uncons, r shl, r glauc, r pyr Sample : The last sample collected was from 15850' MD-15900' MD with around 80% Sst and 20% Siltst Continue to drill ahead from 14347' MD to 16040' MD. The max gas was 863u at 15358' MD, no fluid losses to Trip 3 13316' 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 67/33 9.30 Oil / Water (lb/100ft 2) 19 48 Report For: 15744'8 10.88 Mud Type FazePro N/A Ratio Cor Solids 11.15 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.33 4.23 @ Current Pump & Flow Data: DOYON 15 375.0 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 13-Mar-2015 12:00 AM AK-AM-0902143510 2939 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 15434' 89 45 134 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 163 77 217 12:00 AM AK-AM-0902143510 3109 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 17764'382.0 Customer: Well: Area: Location: Rig: SI34-W6 Avg 14-Mar-2015 Morning Report Report # 25 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.68 Cor Solids 11.38 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 17978'8 11.01 Mud Type FazePro N/A Ratio Mud Data Depth 69/31 9.35 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 17 RPM 48 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type Continue to drill ahead from 16040' MD to 18147' MD. The max gas was 1000u at 17426' MD, 26 bbl loss to Trip 3 13316' f-v f gr, sb ang-sb rnd, v w srt, uncons, r pyr, tr glauc Sample : The last sample collected was from 18050' MD-18100' MD with mainly Sst 100% Gas In Air =10,000 Units Connection Average 38 Background Mud (lb/bbl) ml/30min 2.99 2.30 (max) 458 C-3 Chromatograph (ppm) 1067 569 205 374 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt 100 to 13316' Current 263.0 125.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 118 SPP (psi) 16040' 18147' 2107' Lime Tuff Gvl Surface 96% Date: % 499 Alkal Coal Gallons/stroke 370 17426' 0 379 225 Minimum Depth 16.00'' Maximum in 5 Lithology (%) 2 Bit # 43067 262 16862' Depth Present 0.969 14 90 C-2 0 C-4n 0 Gas Summary 1000 (current) Units* 907-685-0772 Unit Phone: 99 Kori Jo Plowman Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 110416 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 77318 0 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772 Unit Phone: 96 Kori Jo Plowman Set At Size 178.9 X-65 Grade Gas Summary 697 10 (current) Units* C-2 2 C-4n 3 25583 198 19021' Depth Present 0.969 13 132 Minimum Depth 16.00'' Maximum in 5 Lithology (%) 2 Bit # 19499' 6 297 210 292 % 491 Alkal Coal Gallons/stroke 18147' 20108' 1961' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 116 SPP (psi) Avg to 13316' Current 246.0 188.0 MWD Summary Ss Cht Silt 90 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 163 288 5 8 Morning Report Report # 26 Chromatograph (ppm) 779 401 Mud (lb/bbl) ml/30min 3.38 2.60 (max) 319 C-3 Average 40 Background 100% Gas In Air =10,000 Units Connection f-v f gr, sb ang-sb rnd, v w srt, uncons, r glauc Sample : The last sample collected was from 19900' MD-19950' MD consisting mainly of Sst with occasional Siltst Continue to drill from 18147' MD to 20108' MD. Max gas was 697 units at 19499' MD. 38 bbl loss to formation Trip 3 13316' 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 70/30 9.35 Oil / Water (lb/100ft 2) 18 48 Report For: 19901'8.48 11.13 Mud Type FazePro N/A Ratio Cor Solids 11.61 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.81 4.23 @ Current Pump & Flow Data: DOYON 15 441.0 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 15-Mar-2015 12:00 AM AK-AM-0902143510 3228 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 19600' 138 66 173 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 80 26 67 12:00 AM AK-AM-0902143510 3473 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 20996'421.0 Customer: Well: Area: Location: Rig: SI34-W6 Avg 16-Mar-2015 Morning Report Report # 27 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 12.12 Cor Solids 11.85 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 21650'8.53 11.25 Mud Type FazePro N/A Ratio Mud Data Depth 70/30 9.35 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 18 RPM 47 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type Continue to drill from 20108' MD to 21928' MD. Max gas was 549 units at 21259' MD. 41 bbl loss to formation Trip 3 13316' 70% Sst, 30% Siltst: med-v f gr, sb ang-sb rnd, mod srt, uncons, r shl, tr glauc, abd pyr Sample : The last sample collected was from 21750' MD-21800' MD: 100% Gas In Air =10,000 Units Connection Average 20 Background Mud (lb/bbl) ml/30min 3.38 2.60 (max) 166 C-3 Chromatograph (ppm) 590 115 65 166 4 7 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt 70 to 13316' Current 207.0 176.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 117 SPP (psi) 20108' 21928' 1820' Lime Tuff Gvl Surface 96% Date: % 495 Alkal Coal Gallons/stroke 128 21259' 12 137 147 Minimum Depth 16.00'' Maximum in 5 Lithology (%) 2 Bit # 14679 38 20598' Depth Present 0.969 13 187 C-2 0 C-4n 0 Gas Summary 549 30 (current) Units* 907-685-0772 Unit Phone: 39 Kori Jo Plowman Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 61737 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 30703 9 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772 Unit Phone: 8 Kori Jo Plowman Set At Size 178.9 X-65 Grade Gas Summary 318 20 (current) Units* C-2 0 C-4n 0 5253 6 22563' Depth Present 0.969 13 928 Minimum Depth 16.00'' Maximum in 6 Lithology (%) 2 Bit # 22675' 8 8 17 57 % 495 Alkal Coal Gallons/stroke 21928' 23295' 1367' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 117 SPP (psi) Avg to 13316' Current 180.0 116.0 MWD Summary Ss Cht Silt 80 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 5 8 2 3 Morning Report Report # 28 Chromatograph (ppm) 169 8 Mud (lb/bbl) ml/30min 2.86 2.20 (max) 43 C-3 Average 21 Background 100% Gas In Air =10,000 Units Connection 80% Sst, 20% Siltst: med-v f gr, sb ang-sb rnd, mod srt, uncons, tr shl, tr glauc, abd pyr Sample : The last sample collected was from 23050' MD-23100' MD: Continue to drill from 21928' MD to 23295' MD. Max gas was 318 units at 22675' MD. 137 bbl loss to formation Trip 3 13316' 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 71/29 9.35 Oil / Water (lb/100ft 2) 15 44 Report For: 23009'8.56 11.39 Mud Type FazePro N/A Ratio Cor Solids 12.00 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 12.40 4.23 @ Current Pump & Flow Data: DOYON 15 372.0 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 17-Mar-2015 12:00 AM AK-AM-0902143510 3515 ROP ROP (ft/hr) M. Ross/S. Bowe 24 hr Max Max @ ft 22116' 12 56 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 8 34 12:00 AM AK-AM-0902143510 2911 ROP ROP (ft/hr) M. Ross/S. Bowe 24 hr Max Max @ ft 23444'375.0 Customer: Well: Area: Location: Rig: SI34-W6 Avg 18-Mar-2015 Morning Report Report # 29 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 12.40 Cor Solids 12.00 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 23886'8.75 11.39 Mud Type FazePro N/A Ratio Mud Data Depth 71/29 9.35 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 15 RPM 45 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type Continue to drill from 23295' MD to 23886' FTD. Max gas was 371 units at 23327' MD. Begin to backream out of Trip 3 13316' 100% Gas In Air =10,000 Units Connection Average 7Background Mud (lb/bbl) ml/30min 2.86 2.20 (max) 44 C-3 Chromatograph (ppm) 242 15 4 5 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt 80 to 13316' Current 165.0 0.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 105 SPP (psi) 23295' 23886' 591' Lime Tuff Gvl Surface 96% Date: % 444 Alkal Coal Gallons/stroke 72 23327' 0 3 10 Minimum Depth 16.00'' Maximum in 8 Lithology (%) 2 Bit # 7994 4 23744' Depth Present 0.969 15 73 C-2 0 C-4n 0 Gas Summary 371 20 (current) Units* 907-685-0772 Unit Phone: 4 Kori Jo Plowman Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 45735 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0902143510 2874 ROP ROP (ft/hr) M. Ross/S. Bowe 24 hr Max Max @ ft Customer: Well: Area: Location: Rig: SI34-W6 Avg 19-Mar-2015 Morning Report Report # 30 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.86 Cor Solids 11.18 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 23886'7.50 10.22 Mud Type FazePro N/A Ratio Mud Data Depth 69/31 9.30 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 15 RPM 47 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type Continue to BROOH, 402 bbls lost to formation, max 31 units gas while BROOH Trip 3 13316' 100% Gas In Air =10,000 Units Connection Average Background Mud (lb/bbl) ml/30min 2.47 1.90 (max) 0 C-3 31 Chromatograph (ppm) 0 0 0 0 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i BROOH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt to 13316' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 115 SPP (psi) 23886' 23886' 0' Lime Tuff Gvl Surface 96% Date: % 495 Alkal Coal Gallons/stroke 0 0 0 Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 Depth 23886' 0.969 14 0 C-2 0 C-4n 0 Gas Summary (current) Units* 907-685-0772 Unit Phone: 0 Kori Jo Plowman Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 0 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0902143510 2874 ROP ROP (ft/hr) M. Ross/S. Bowe 24 hr Max Max @ ft Customer: Well: Area: Location: Rig: SI34-W6 Avg 20-Mar-2015 Morning Report Report # 31 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.86 Cor Solids 11.18 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 23886'7.50 10.22 Mud Type FazePro N/A Ratio Mud Data Depth 69/31 9.30 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 15 RPM 47 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type Continue to BROOH, 227 bbls lost to formation, max 31 units gas while BROOH Trip 3 13316' 100% Gas In Air =10,000 Units Connection Average Background Mud (lb/bbl) ml/30min 2.47 1.90 (max) 0 C-3 31 Chromatograph (ppm) 0 0 0 0 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i BROOH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt to 13316' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 115 SPP (psi) 23886' 23886' 0' Lime Tuff Gvl Surface 96% Date: % 495 Alkal Coal Gallons/stroke 0 0 0 Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 Depth 23886' 0.969 14 0 C-2 0 C-4n 0 Gas Summary (current) Units* 907-685-0772 Unit Phone: 0 Kori Jo Plowman Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 0 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 0 0 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772 Unit Phone: 0 Kori Jo Plowman Set At Size 178.9 X-65 Grade Gas Summary (current) Units* C-2 0 C-4n 0 0 0 Depth 23886' 0.969 14 0Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 0 % 546 Alkal Coal Gallons/stroke 23886' 23886' 0' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 129 SPP (psi) Avg to 13316' Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' BROOH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 0 0 0 0 Morning Report Report # 32 Chromatograph (ppm) 0 0 19 Mud (lb/bbl) ml/30min 3.12 2.40 (max) 0 C-3 Average Background 100% Gas In Air =10,000 Units Connection Continue to BROOH, 47 bbls lost to formation, max 19 units gas while BROOH Trip 3 13316' 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 69/31 9.30 Oil / Water (lb/100ft 2) 13 43 Report For: 23886'7.46 10.19 Mud Type FazePro N/A Ratio Cor Solids 11.13 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 12.23 4.23 @ Current Pump & Flow Data: DOYON 15 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 21-Mar-2015 12:00 AM AK-AM-0902143510 3089 ROP ROP (ft/hr) M. Ross/S. Bowe 24 hr Max Max @ ft 0 00 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0902143510 3089 ROP ROP (ft/hr) M. Ross/S. Bowe 24 hr Max Max @ ft Customer: Well: Area: Location: Rig: SI34-W6 Avg 22-Mar-2015 Morning Report Report # 33 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 12.23 Cor Solids 11.13 Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 23886'7.72 10.19 Mud Type FazePro N/A Ratio Mud Data Depth 69/31 9.45 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 13 RPM 45 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type Pump out of hole, 12 bbls lost to formation, max 12 units gas while BROOH Trip 3 13316' 100% Gas In Air =10,000 Units Connection Average Background Mud (lb/bbl) ml/30min 2.99 2.30 (max) 0 C-3 12 Chromatograph (ppm) 0 0 0 0 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i Pump out of hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt to 13316' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 129 SPP (psi) 23886' 23886' 0' Lime Tuff Gvl Surface 96% Date: % 546 Alkal Coal Gallons/stroke 0 0 0 Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 Depth 23886' 0.969 15 0 C-2 0 C-4n 0 Gas Summary (current) Units* 907-685-0772 Unit Phone: 0 Kori Jo Plowman Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: A. Paul Kalenuik/Kori Jo Plowman (max) (current) BTC 0 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers: Kori Jo Plowman/Chris Silva (max) (current) BTC 0 0 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772 Unit Phone: 0 Chris Silva Set At Size 178.9 X-65 Grade Gas Summary (current) Units* C-2 0 C-4n 0 0 0 Depth 23886' 0.969 15 0Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 0 % 0 Alkal Coal Gallons/stroke 23886' 23886' 0' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Avg to 13316' Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Pump out of hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 0 0 0 0 Morning Report Report # 34 Chromatograph (ppm) 0 0 8 Mud (lb/bbl) ml/30min 2.99 2.30 (max) 0 C-3 Average Background 100% Gas In Air =10,000 Units Connection Pump out of hole, 7 bbls lost to formation, max 8 units gas while pumping out of hole Trip 3 13316' 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 69/31 9.45 Oil / Water (lb/100ft 2) 14 49 Report For: 23886'7.72 Mud Type FazePro N/A Ratio Cor Solids Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ Current Pump & Flow Data: DOYON 15 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 23-Mar-2015 12:00 AM AK-AM-0902143510 16 ROP ROP (ft/hr) M. Ross/S. Bowe 24 hr Max Max @ ft 0 00 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 12:00 AM AK-AM-0902143510 597 ROP ROP (ft/hr) J. Keener/S. Bowe 24 hr Max Max @ ft Customer: Well: Area: Location: Rig: SI34-W6 Avg 24-Mar-2015 Morning Report Report # 35 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 23886'8.53 Mud Type FazePro N/A Ratio Mud Data Depth 70/30 9.45 Oil / Water (lb/100ft 2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 14 RPM 51 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type Test BOPE's. Mobilize cleanout BHA #5. Make up BHA #5 and run in hole to 13,701' MD. No mud losses, Trip 3 13316' 100% Gas In Air =10,000 Units Connection Average Background Mud (lb/bbl) ml/30min 2.86 2.20 (max) 0 C-3 72 Chromatograph (ppm) 0 0 0 0 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i Ream in hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt to 13316' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) 23886' 23886' 0' Lime Tuff Gvl Surface 96% Date: % 0 Alkal Coal Gallons/stroke 0 0 0 Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 Depth 23886' 0.969 15 0 C-2 0 C-4n 0 Gas Summary (current) Units* 907-685-0772 Unit Phone: 0 Chris Silva Set At Size 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers: Kori Jo Plowman/Chris Silva (max) (current) BTC 0 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers: Kori Jo Plowman/Chris Silva (max) (current) BTC 0 0 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772 Unit Phone: 0 Chris Silva Set At Size 178.9 X-65 Grade Gas Summary (current) Units* C-2 0 C-4n 0 0 0 Depth 23886' 0.969 15 0Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 0 % 0 Alkal Coal Gallons/stroke 23886' 23886' 0' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Avg to 13316' Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ream in hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 0 0 0 0 Morning Report Report # 36 Chromatograph (ppm) 0 0 868 Mud (lb/bbl) ml/30min 2.86 2.20 (max) 0 C-3 Average Background 100% Gas In Air =10,000 Units Connection Ream in hole from 14,445' MD to 21,634' MD. 43 bbls lost to formation, max 868 units gas while reaming in hole. Trip 3 13316' 10 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 70/30 9.45 Oil / Water (lb/100ft 2) 14 51 Report For: 23886'8.53 Mud Type FazePro N/A Ratio Cor Solids Avg Min YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ Current Pump & Flow Data: DOYON 15 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 25-Mar-2015 12:00 AM AK-AM-0902143510 59 ROP ROP (ft/hr) J. Keener/S. Bowe 24 hr Max Max @ ft 0 00 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 0 00 26-Mar-2015 12:00 AM AK-AM-0902143510 60 ROP ROP (ft/hr) J. Keener/S. Bowe 24 hr Max Max @ ft Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 23886'8.53 Mud Type FazePro N/A Ratio Mud Data Depth 70/309.45 Oil / Water (lb/100ft2) 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD 14 RPM 51 10 Size 160'ConductorEvermar PDC Casing Summary L-80 Bit Type Pull out of hole from 21,634' MD to 16,874' MD, max 745 units gas while circulating. 51 bbls lost to formation. Trip 3 13316' 100% Gas In Air=10,000 UnitsConnection C-3 Average Background Mud (lb/bbl)ml/30min 2.862.20 (max) 0 0 745 Morning Report Report # 37 Chromatograph (ppm) 0 0 0 0 0 Cement C-1 C-5i ShSiltst LstClyst C-4i Pull out of hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Ss Cht Silt Avg to13316' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) 23886' 23886' 0' Lime TuffGvl Surface 96% Date: % 0 Alkal Coal Gallons/stroke 0 0 0 Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 Depth 23886' 0.969 15 0 C-2 0 C-4n 0 Gas Summary (current) Units* 907-685-0772Unit Phone: 0 Chris Silva Set AtSize 178.9 X-65 Grade 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' Report By: 20.00" 9.63'' Logging Engineers:Kori Jo Plowman/Chris Silva (max)(current) BTC 0 0 . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers:Kori Jo Plowman/Chris Silva (max)(current) BTC 0 0 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772Unit Phone: 0 Chris Silva Set AtSize 178.9 X-65 Grade Gas Summary (current) Units*C-2 0 C-4n 0 0 0 Depth 23886' 0.969 0Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 0 % 0 Alkal Coal Gallons/stroke 23886' 23886' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Avg to13316' Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Run 4.5" liner PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 0 0 0 0 Morning Report Report # 38 Chromatograph (ppm) 0 0 8 Mud (lb/bbl)ml/30min (max) 0 C-3 Average Background 100% Gas In Air=10,000 UnitsConnection Run in hole with 4.5" casing to 5,730' MD. Max 8 units gas while circulating, 48 bbls lost to formation. Trip 3 13316' 10 Size 160'ConductorEvermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 9.10 Oil / Water (lb/100ft2) 27 Report For: 23886' Mud Type 3% KCL.NACL Ratio Cor Solids Avg Min YP MaxECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ Current Pump & Flow Data: DOYON 15 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 27-Mar-2015 12:00 AM AK-AM-0902143510 17 ROP ROP (ft/hr) J. Keener/S. Bowe 24 hr Max Max @ ft 0 00 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00" 9.63'' Logging Engineers:Kori Jo Plowman/Chris Silva (max)(current) BTC 0 0 190 Hours 102.80 Cly Hydril 563 L-80 Comments Intermediate 10500' 907-685-0772Unit Phone: 0 Chris Silva Set AtSize 178.9 X-65 Grade Gas Summary (current) Units*C-2 0 C-4n 0 0 0 Depth 23886' 0.969 0Minimum Depth 16.00'' Maximum in Lithology (%) 2 Bit # 0 0 0 Max 61 units gas while circulating, 42 bbls lost to formation. % 0 Alkal Coal Gallons/stroke 23886' 23886' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Avg to13316' Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13304' 12.25 2816' 2803' Cut & slip drill line PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 0 0 0 0 Morning Report Report # 39 Chromatograph (ppm) 0 0 61 Mud (lb/bbl)ml/30min (max) 0 C-3 Average Background 100% Gas In Air=10,000 UnitsConnection Run in hole with 4.5" casing from 5,730' MD to 8,397' MD. Run in hole with 5" drill pipe from 8,397' MD to 13,731' MD. Trip 3 13316' 10 Size 160'ConductorEvermar PDC Casing Summary L-80 Bit Type 13316' WOB PDC TFA Condition 1-5-BT-S-X-2-ER-TD RPM Mud Data Depth 9.10 Oil / Water (lb/100ft2) 27 Report For: 23886' Mud Type 3% KCL/NaCL Ratio Cor Solids Avg Min YP MaxECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675 NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ Current Pump & Flow Data: DOYON 15 Customer: Well: Area: Location: Rig: SI34-W6 ENI PETROLEUM SPY ISLAND 28-Mar-2015 12:00 AM AK-AM-0902143510 17 ROP ROP (ft/hr) J. Keener/S. Bowe 24 hr Max Max @ ft 0 00 Density (ppg) out (sec/qt) Viscosity WELL INFORMATION Created On : Apr 17 2015 Customer :ENI Petroleum Well Name :SI34-W6 Job Number :AK-XX-0902143510 Platform :Spy Island Field Name :Nikaitchuq Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 253.79 0.03 154.41 253.79 0.06 S 0.03 E 0.01 0.01 346.64 0.23 242.86 346.64 0.17 S 0.13 W 0.20 0.25 402.03 1.19 176.02 402.03 0.79 S 0.19 W 0.61 2.02 447.98 3.04 177.31 447.94 2.48 S 0.10 W 1.50 4.03 540.85 3.28 173.10 540.67 7.58 S 0.34 E 4.07 0.36 571.23 3.79 172.23 570.99 9.44 S 0.58 E 4.94 1.69 633.81 5.31 181.61 633.37 14.38 S 0.78 E 7.61 2.70 727.13 7.89 196.94 726.08 24.83 S 1.21 W 15.23 3.32 820.47 10.53 204.52 818.21 38.72 S 6.62 W 27.63 3.11 913.72 12.39 218.01 909.61 54.36 S 16.32 W 44.55 3.49 1007.14 15.35 228.66 1,000.31 70.43 S 31.78 W 66.43 4.17 1064.98 17.85 233.21 1,055.74 80.80 S 44.63 W 82.90 4.87 1158.20 21.76 236.19 1,143.43 98.98 S 70.44 W 114.47 4.33 1251.60 23.72 235.08 1,229.57 119.37 S 100.23 W 150.57 2.15 1344.94 27.75 235.21 1,313.63 142.52 S 133.48 W 191.09 4.32 1438.28 28.14 234.33 1,396.09 167.75 S 169.21 W 234.83 0.61 1531.49 29.00 234.32 1,477.95 193.75 S 205.42 W 279.40 0.92 1624.71 31.77 232.44 1,558.36 221.90 S 243.24 W 326.52 3.14 1717.67 30.89 232.01 1,637.76 251.50 S 281.44 W 374.80 0.98 1810.99 30.50 231.79 1,718.01 280.90 S 318.93 W 422.37 0.43 1904.18 32.88 230.76 1,797.30 311.53 S 357.11 W 471.21 2.62 1997.51 36.42 230.47 1,874.06 345.20 S 398.11 W 524.11 3.80 2090.82 37.99 229.59 1,948.38 381.45 S 441.35 W 580.32 1.78 2184.23 42.14 230.60 2,019.85 419.99 S 487.47 W 640.21 4.50 2277.52 44.48 231.38 2,087.73 460.26 S 537.20 W 704.04 2.57 2370.50 45.49 232.00 2,153.49 501.00 S 588.77 W 769.66 1.18 2463.87 49.23 232.69 2,216.73 542.95 S 643.15 W 838.26 4.04 2557.18 51.93 236.03 2,275.99 584.90 S 701.73 W 910.31 4.00 2650.57 52.64 238.21 2,333.12 625.00 S 763.77 W 984.13 2.00 2735.17 57.46 239.33 2,381.57 660.92 S 823.06 W 1053.30 5.80 INSITE V8.1.10 Page 1Job No:AK-XX-0902143510 Well Name:SI34-W6 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2816.00 61.50 240.00 2,422.61 696.07 S 883.15 W 1122.68 5.05 2821.76 60.38 239.11 2,425.41 698.63 S 887.49 W 1127.70 23.67 2915.13 65.13 238.75 2,468.14 741.46 S 958.57 W 1210.50 5.10 3008.55 68.16 239.18 2,505.17 785.67 S 1,032.05 W 1296.05 3.27 3101.84 73.23 238.88 2,536.00 830.96 S 1,107.51 W 1383.84 5.44 3195.20 78.06 239.40 2,559.14 877.34 S 1,185.13 W 1474.03 5.20 3288.38 81.44 240.10 2,575.72 923.52 S 1,264.33 W 1565.39 3.70 3381.74 85.52 241.21 2,586.32 968.96 S 1,345.17 W 1657.67 4.53 3475.09 87.81 241.20 2,591.75 1,013.85 S 1,426.83 W 1750.31 2.45 3568.45 91.08 241.47 2,592.66 1,058.63 S 1,508.73 W 1843.09 3.51 3661.81 88.15 241.84 2,593.28 1,102.94 S 1,590.89 W 1935.80 3.16 3755.17 87.88 239.67 2,596.52 1,148.53 S 1,672.30 W 2028.63 2.34 3848.44 87.41 239.83 2,600.35 1,195.47 S 1,752.80 W 2121.50 0.53 3941.82 87.12 238.53 2,604.81 1,243.26 S 1,832.90 W 2214.53 1.42 4035.11 87.16 238.02 2,609.46 1,292.25 S 1,912.15 W 2307.55 0.55 4128.52 87.25 238.97 2,614.02 1,341.01 S 1,991.69 W 2400.67 1.02 4221.89 87.35 238.33 2,618.42 1,389.53 S 2,071.34 W 2493.75 0.69 4315.21 85.92 238.00 2,623.89 1,438.67 S 2,150.49 W 2586.76 1.57 4408.54 86.81 237.58 2,629.81 1,488.32 S 2,229.29 W 2679.79 1.05 4501.96 86.31 238.24 2,635.42 1,537.86 S 2,308.30 W 2772.92 0.89 4595.44 87.54 238.30 2,640.43 1,586.95 S 2,387.69 W 2866.12 1.32 4688.81 87.84 239.13 2,644.19 1,635.39 S 2,467.42 W 2959.21 0.94 4782.25 87.63 239.44 2,647.89 1,683.08 S 2,547.69 W 3052.32 0.40 4875.73 87.13 239.75 2,652.16 1,730.34 S 2,628.23 W 3145.40 0.63 4968.96 86.88 239.46 2,657.03 1,777.45 S 2,708.53 W 3238.20 0.41 5062.38 86.61 239.95 2,662.33 1,824.50 S 2,789.06 W 3331.16 0.60 5156.16 86.65 239.33 2,667.85 1,871.82 S 2,869.84 W 3424.47 0.66 5248.81 86.64 240.48 2,673.27 1,918.19 S 2,949.86 W 3516.62 1.24 5342.12 86.06 240.94 2,679.21 1,963.75 S 3,031.08 W 3609.28 0.79 5435.47 87.11 241.35 2,684.77 2,008.72 S 3,112.69 W 3701.92 1.21 5528.82 87.22 241.41 2,689.39 2,053.38 S 3,194.54 W 3794.58 0.13 5622.26 87.38 241.69 2,693.79 2,097.85 S 3,276.60 W 3887.31 0.34 5715.62 87.19 241.66 2,698.21 2,142.09 S 3,358.69 W 3979.93 0.21 5809.04 87.04 242.41 2,702.91 2,185.84 S 3,441.10 W 4072.53 0.82 5902.36 87.05 241.03 2,707.73 2,230.00 S 3,523.17 W 4165.08 1.48 5995.74 87.14 240.76 2,712.46 2,275.36 S 3,604.65 W 4257.85 0.30 6089.13 86.97 240.43 2,717.26 2,321.15 S 3,685.90 W 4350.67 0.40 6182.51 87.39 241.16 2,721.85 2,366.66 S 3,767.31 W 4443.46 0.90 6275.83 87.09 240.02 2,726.34 2,412.43 S 3,848.51 W 4536.23 1.26 6369.25 87.30 239.68 2,730.92 2,459.30 S 3,929.20 W 4629.20 0.43 6462.55 87.65 240.33 2,735.03 2,505.89 S 4,009.92 W 4722.06 0.79 6555.88 87.16 240.05 2,739.25 2,552.24 S 4,090.82 W 4814.91 0.60 6649.19 86.83 239.63 2,744.14 2,599.06 S 4,171.38 W 4907.76 0.57 6742.62 87.18 240.41 2,749.02 2,645.68 S 4,252.20 W 5000.70 0.91 6835.95 87.12 239.85 2,753.67 2,692.11 S 4,333.03 W 5093.54 0.60 INSITE V8.1.10 Page 2Job No:AK-XX-0902143510 Well Name:SI34-W6 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6929.13 87.65 239.53 2,757.92 2,739.08 S 4,413.39 W 5186.31 0.66 7022.46 87.30 239.38 2,762.03 2,786.47 S 4,493.69 W 5279.27 0.41 7115.84 87.18 240.63 2,766.53 2,833.10 S 4,574.47 W 5372.18 1.34 7209.17 86.53 239.78 2,771.65 2,879.40 S 4,655.34 W 5464.99 1.15 7302.46 86.88 239.71 2,777.01 2,926.33 S 4,735.79 W 5557.80 0.38 7395.81 87.21 240.23 2,781.82 2,972.98 S 4,816.50 W 5650.68 0.66 7489.14 86.95 239.37 2,786.57 3,019.87 S 4,897.06 W 5743.56 0.96 7582.44 87.30 239.45 2,791.25 3,067.29 S 4,977.27 W 5836.47 0.38 7675.72 86.86 239.20 2,796.01 3,114.81 S 5,057.40 W 5929.36 0.54 7769.07 87.08 239.80 2,800.94 3,162.13 S 5,137.72 W 6022.29 0.68 7862.33 87.16 239.10 2,805.63 3,209.47 S 5,217.93 W 6115.15 0.75 7955.57 87.25 239.27 2,810.17 3,257.18 S 5,297.91 W 6208.03 0.21 8048.83 87.20 239.07 2,814.69 3,304.92 S 5,377.90 W 6300.94 0.22 8142.23 87.02 239.18 2,819.40 3,352.78 S 5,457.96 W 6393.98 0.23 8235.34 86.96 239.87 2,824.29 3,399.94 S 5,538.10 W 6486.67 0.74 8328.56 86.86 238.55 2,829.31 3,447.59 S 5,618.06 W 6579.50 1.42 8421.94 87.20 238.71 2,834.15 3,496.13 S 5,697.68 W 6672.57 0.40 8515.35 87.26 240.00 2,838.66 3,543.69 S 5,777.95 W 6765.60 1.38 8608.71 87.08 239.47 2,843.27 3,590.69 S 5,858.49 W 6858.52 0.60 8702.00 86.81 239.17 2,848.25 3,638.22 S 5,938.60 W 6951.42 0.43 8795.35 86.82 239.93 2,853.43 3,685.45 S 6,018.95 W 7044.33 0.81 8888.82 86.84 239.81 2,858.60 3,732.30 S 6,099.67 W 7137.32 0.13 8982.22 87.16 240.35 2,863.49 3,778.82 S 6,180.51 W 7230.22 0.67 9075.46 86.74 240.75 2,868.45 3,824.60 S 6,261.59 W 7322.89 0.62 9168.99 87.03 239.94 2,873.53 3,870.81 S 6,342.75 W 7415.88 0.92 9262.33 87.13 240.83 2,878.29 3,916.87 S 6,423.79 W 7508.69 0.96 9355.77 86.51 241.05 2,883.47 3,962.19 S 6,505.34 W 7601.48 0.70 9449.12 86.55 240.88 2,889.12 4,007.41 S 6,586.81 W 7694.15 0.19 9542.54 86.94 241.63 2,894.43 4,052.27 S 6,668.58 W 7786.87 0.90 9635.93 87.15 241.94 2,899.24 4,096.36 S 6,750.77 W 7879.48 0.40 9729.28 86.76 242.35 2,904.20 4,139.92 S 6,833.18 W 7971.97 0.61 9822.64 89.23 243.65 2,907.47 4,182.27 S 6,916.31 W 8064.36 2.99 9916.00 87.98 243.91 2,909.74 4,223.51 S 7,000.03 W 8156.60 1.37 10009.33 88.22 245.28 2,912.83 4,263.52 S 7,084.29 W 8248.57 1.49 10102.78 85.63 242.41 2,917.85 4,304.65 S 7,168.04 W 8340.75 4.13 10196.15 82.40 240.50 2,927.58 4,349.01 S 7,249.60 W 8433.01 4.01 10289.55 81.52 239.16 2,940.65 4,395.48 S 7,329.55 W 8525.16 1.70 10382.94 80.89 240.55 2,954.93 4,441.83 S 7,409.36 W 8617.12 1.62 10476.14 81.45 240.11 2,969.23 4,487.42 S 7,489.38 W 8708.82 0.76 10569.42 80.30 239.75 2,984.02 4,533.56 S 7,569.08 W 8800.57 1.29 10662.70 78.86 238.81 3,000.90 4,580.43 S 7,647.95 W 8892.05 1.83 10756.07 77.27 237.50 3,020.21 4,628.62 S 7,725.54 W 8983.26 2.19 10849.63 76.19 238.03 3,041.68 4,677.19 S 7,802.57 W 9074.22 1.28 10942.68 74.34 236.17 3,065.35 4,726.06 S 7,878.12 W 9164.14 2.77 11036.10 74.23 235.53 3,090.65 4,776.54 S 7,952.54 W 9254.05 0.67 INSITE V8.1.10 Page 3Job No:AK-XX-0902143510 Well Name:SI34-W6 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 11129.56 75.75 235.46 3,114.86 4,827.68 S 8,026.93 W 9344.32 1.63 11222.49 75.64 236.58 3,137.82 4,878.01 S 8,101.60 W 9434.35 1.17 11316.17 75.78 234.96 3,160.94 4,929.07 S 8,176.65 W 9525.12 1.68 11409.50 75.46 235.07 3,184.12 4,980.91 S 8,250.72 W 9615.53 0.36 11502.76 74.20 237.17 3,208.53 5,031.08 S 8,325.44 W 9705.51 2.56 11596.17 76.17 239.62 3,232.42 5,078.40 S 8,402.35 W 9795.65 3.30 11689.54 77.47 243.89 3,253.71 5,121.40 S 8,482.42 W 9885.90 4.67 11782.86 76.97 245.57 3,274.36 5,160.25 S 8,564.71 W 9975.60 1.84 11876.20 76.17 245.92 3,296.04 5,197.54 S 8,647.48 W 10064.79 0.93 11969.45 76.32 247.13 3,318.21 5,233.62 S 8,730.56 W 10153.54 1.27 12062.87 77.57 248.76 3,339.31 5,267.79 S 8,814.90 W 10242.23 2.16 12156.04 77.42 251.44 3,359.49 5,298.75 S 8,900.42 W 10330.04 2.81 12249.26 78.91 252.78 3,378.61 5,326.77 S 8,987.25 W 10417.23 2.13 12342.66 81.22 254.28 3,394.72 5,352.85 S 9,075.46 W 10504.45 2.94 12436.00 81.77 255.48 3,408.53 5,376.93 S 9,164.58 W 10591.26 1.40 12529.34 82.14 255.40 3,421.59 5,400.16 S 9,254.03 W 10677.86 0.41 12622.55 83.67 256.07 3,433.10 5,422.95 S 9,343.67 W 10764.37 1.79 12715.77 85.42 256.82 3,441.97 5,444.70 S 9,433.88 W 10850.73 2.04 12808.73 86.33 257.43 3,448.65 5,465.36 S 9,524.27 W 10936.62 1.18 12902.05 86.74 258.39 3,454.29 5,484.87 S 9,615.35 W 11022.42 1.12 12995.24 87.90 259.51 3,458.65 5,502.71 S 9,706.71 W 11107.50 1.73 13088.57 89.39 260.32 3,460.86 5,519.05 S 9,798.57 W 11192.11 1.82 13181.88 90.30 262.27 3,461.11 5,533.17 S 9,890.80 W 11275.76 2.31 13271.46 89.68 264.16 3,461.13 5,543.75 S 9,979.75 W 11354.69 2.22 13316.00 89.68 264.16 3,461.37 5,548.28 S 10,024.05 W 11393.59 0.00 13370.56 88.98 265.71 3,462.01 5,553.10 S 10,078.40 W 11440.86 3.12 13463.93 87.71 266.15 3,464.71 5,559.72 S 10,171.49 W 11520.92 1.44 13557.35 89.20 269.10 3,467.23 5,563.59 S 10,264.78 W 11599.56 3.54 13650.64 91.99 270.16 3,466.26 5,564.19 S 10,358.05 W 11676.31 3.20 13744.00 92.37 271.80 3,462.71 5,562.60 S 10,451.33 W 11751.80 1.80 13837.18 94.24 272.03 3,457.34 5,559.49 S 10,544.30 W 11826.18 2.02 13930.54 92.92 272.04 3,451.51 5,556.18 S 10,637.42 W 11900.56 1.41 14024.28 91.64 273.25 3,447.78 5,551.86 S 10,730.98 W 11974.72 1.88 14117.25 86.96 275.60 3,448.91 5,544.69 S 10,823.63 W 12046.50 5.63 14210.61 83.88 280.18 3,456.37 5,531.93 S 10,915.78 W 12114.67 5.90 14303.97 82.98 287.04 3,467.07 5,510.12 S 11,005.87 W 12175.95 7.36 14397.24 84.95 291.00 3,476.88 5,479.90 S 11,093.53 W 12230.43 4.72 14490.62 87.54 292.13 3,482.99 5,445.65 S 11,180.18 W 12281.76 3.03 14583.91 90.19 294.93 3,484.84 5,408.42 S 11,265.68 W 12330.44 4.13 14677.32 89.19 298.57 3,485.34 5,366.39 S 11,349.08 W 12374.65 4.04 14770.59 85.94 300.93 3,489.31 5,320.16 S 11,429.96 W 12414.39 4.30 14864.01 82.34 305.01 3,498.85 5,269.61 S 11,507.91 W 12449.25 5.81 14957.34 85.80 305.71 3,508.49 5,215.90 S 11,583.60 W 12480.44 3.78 15050.76 90.15 308.02 3,511.79 5,159.90 S 11,658.27 W 12509.49 5.27 15144.24 95.65 313.25 3,507.06 5,099.15 S 11,729.07 W 12532.65 8.11 INSITE V8.1.10 Page 4Job No:AK-XX-0902143510 Well Name:SI34-W6 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 15237.61 93.76 315.67 3,499.40 5,033.98 S 11,795.48 W 12549.66 3.28 15331.05 90.10 316.85 3,496.25 4,966.52 S 11,860.03 W 12563.85 4.12 15424.53 87.21 317.20 3,498.45 4,898.16 S 11,923.73 W 12576.81 3.11 15517.76 87.60 320.33 3,502.67 4,828.13 S 11,985.11 W 12586.93 3.38 15611.18 87.74 322.77 3,506.47 4,755.03 S 12,043.15 W 12592.54 2.61 15704.28 89.20 326.00 3,508.95 4,679.38 S 12,097.34 W 12593.54 3.81 15798.19 87.92 332.36 3,511.32 4,598.80 S 12,145.41 W 12586.71 6.91 15890.92 84.84 336.60 3,517.17 4,515.32 S 12,185.28 W 12571.47 5.64 15984.27 87.48 336.99 3,523.42 4,429.72 S 12,221.97 W 12552.44 2.86 16077.62 90.07 339.54 3,525.42 4,343.04 S 12,256.53 W 12531.02 3.89 16171.06 89.38 340.42 3,525.87 4,255.25 S 12,288.51 W 12506.87 1.20 16264.65 88.28 339.55 3,527.78 4,167.33 S 12,320.54 W 12482.68 1.50 16357.84 88.52 337.06 3,530.38 4,080.79 S 12,354.97 W 12461.24 2.68 16451.16 89.70 334.87 3,531.83 3,995.57 S 12,392.97 W 12443.50 2.67 16544.54 89.94 332.68 3,532.12 3,911.81 S 12,434.24 W 12429.25 2.36 16637.93 90.17 330.33 3,532.04 3,829.74 S 12,478.79 W 12418.67 2.53 16731.31 88.92 327.03 3,532.78 3,749.98 S 12,527.32 W 12412.68 3.78 16824.63 88.42 326.97 3,534.94 3,671.74 S 12,578.13 W 12409.42 0.54 16918.05 88.38 325.41 3,537.55 3,594.15 S 12,630.09 W 12407.48 1.67 17011.35 89.33 324.11 3,539.42 3,517.97 S 12,683.91 W 12407.88 1.73 17104.68 89.27 322.31 3,540.56 3,443.23 S 12,739.80 W 12410.79 1.93 17197.99 89.95 321.89 3,541.19 3,369.61 S 12,797.12 W 12415.51 0.86 17291.42 90.09 321.74 3,541.16 3,296.17 S 12,854.88 W 12420.70 0.22 17384.75 90.07 321.02 3,541.03 3,223.25 S 12,913.13 W 12426.59 0.77 17477.93 88.13 320.55 3,542.49 3,151.07 S 12,972.03 W 12433.44 2.14 17571.26 86.59 319.82 3,546.79 3,079.46 S 13,031.72 W 12441.27 1.83 17664.64 89.47 319.26 3,550.00 3,008.46 S 13,092.28 W 12450.15 3.14 17757.97 90.14 316.55 3,550.32 2,939.21 S 13,154.84 W 12461.67 2.99 17851.26 90.97 317.81 3,549.41 2,870.79 S 13,218.24 W 12474.37 1.62 17944.61 91.72 317.09 3,547.22 2,802.04 S 13,281.35 W 12486.63 1.11 18037.94 90.57 318.60 3,545.36 2,732.87 S 13,343.97 W 12498.25 2.03 18131.88 90.57 319.23 3,544.42 2,662.07 S 13,405.70 W 12508.21 0.67 18224.52 90.55 318.86 3,543.52 2,592.11 S 13,466.42 W 12517.82 0.40 18317.87 90.25 318.98 3,542.87 2,521.74 S 13,527.76 W 12527.70 0.35 18411.66 90.11 318.96 3,542.57 2,450.99 S 13,589.33 W 12537.56 0.15 18504.37 89.96 318.54 3,542.52 2,381.29 S 13,650.46 W 12547.65 0.48 18597.63 90.17 319.03 3,542.41 2,311.14 S 13,711.91 W 12557.75 0.57 18691.03 90.23 319.67 3,542.08 2,240.27 S 13,772.75 W 12566.94 0.69 18784.14 90.14 320.33 3,541.78 2,168.95 S 13,832.60 W 12575.06 0.72 18877.36 90.11 321.98 3,541.58 2,096.35 S 13,891.07 W 12581.31 1.77 18970.74 89.93 321.84 3,541.55 2,022.85 S 13,948.67 W 12586.34 0.24 19064.15 88.69 322.34 3,542.67 1,949.16 S 14,006.06 W 12591.08 1.43 19157.51 91.30 324.12 3,542.68 1,874.39 S 14,061.94 W 12593.96 3.38 19250.80 93.04 323.85 3,539.15 1,798.98 S 14,116.75 W 12595.62 1.89 19344.15 92.97 325.74 3,534.25 1,722.82 S 14,170.49 W 12595.95 2.02 INSITE V8.1.10 Page 5Job No:AK-XX-0902143510 Well Name:SI34-W6 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 19437.62 93.06 324.71 3,529.34 1,646.15 S 14,223.73 W 12595.58 1.10 19531.02 90.43 324.08 3,526.49 1,570.25 S 14,278.07 W 12596.57 2.90 19624.26 89.22 323.49 3,526.78 1,495.03 S 14,333.16 W 12598.55 1.44 19717.79 89.86 323.11 3,527.53 1,420.04 S 14,389.06 W 12601.32 0.80 19811.13 90.11 323.75 3,527.55 1,345.08 S 14,444.67 W 12603.88 0.74 19904.57 89.07 323.61 3,528.22 1,269.79 S 14,500.01 W 12606.03 1.12 19997.92 91.15 323.06 3,528.04 1,194.92 S 14,555.75 W 12608.74 2.30 20091.34 95.33 322.67 3,522.76 1,120.58 S 14,612.04 W 12612.22 4.49 20184.73 97.49 322.71 3,512.34 1,046.77 S 14,668.29 W 12615.96 2.31 20278.08 96.45 322.58 3,501.01 973.11 S 14,724.51 W 12619.76 1.12 20371.44 93.48 321.33 3,492.93 899.88 S 14,781.83 W 12624.71 3.45 20464.80 90.90 321.89 3,489.36 826.76 S 14,839.76 W 12630.22 2.83 20558.13 87.62 321.75 3,490.57 753.41 S 14,897.43 W 12635.40 3.52 20651.58 85.84 322.20 3,495.90 679.92 S 14,954.90 W 12640.32 1.96 20744.95 87.16 318.32 3,501.60 608.27 S 15,014.47 W 12648.02 4.38 20838.35 86.06 315.05 3,507.13 540.45 S 15,078.42 W 12661.50 3.69 20931.74 87.38 313.24 3,512.47 475.51 S 15,145.33 W 12679.06 2.40 21024.94 88.10 311.69 3,516.15 412.64 S 15,214.02 W 12699.27 1.83 21118.22 88.08 309.96 3,519.25 351.70 S 15,284.57 W 12722.10 1.85 21211.50 88.14 306.82 3,522.33 293.81 S 15,357.63 W 12748.75 3.36 21304.87 86.55 303.27 3,526.66 240.26 S 15,433.98 W 12780.57 4.16 21398.09 85.83 300.14 3,532.85 191.38 S 15,513.10 W 12817.35 3.44 21491.48 87.35 297.57 3,538.41 146.40 S 15,594.74 W 12858.43 3.19 21584.90 92.38 295.82 3,538.63 104.45 S 15,678.17 W 12902.71 5.70 21678.36 95.59 294.00 3,532.14 65.18 S 15,762.72 W 12949.44 3.95 21771.66 96.96 291.32 3,521.94 29.45 S 15,848.29 W 12999.04 3.21 21865.58 96.96 287.51 3,510.55 1.53 N 15,936.20 W 13053.28 4.03 21958.30 97.01 283.69 3,499.27 26.28 N 16,024.82 W 13111.69 4.09 22051.56 97.08 280.67 3,487.83 45.80 N 16,115.28 W 13174.59 3.21 22144.97 97.02 276.99 3,476.36 60.03 N 16,206.87 W 13241.46 3.91 22238.34 97.00 275.15 3,464.97 69.83 N 16,299.02 W 13311.32 1.96 22331.66 97.58 275.75 3,453.12 78.62 N 16,391.17 W 13381.76 0.89 22425.00 100.24 274.63 3,438.67 86.96 N 16,482.99 W 13452.19 3.09 22518.25 99.41 275.51 3,422.76 95.08 N 16,574.51 W 13522.50 1.29 22611.67 97.13 274.41 3,409.32 103.07 N 16,666.61 W 13593.36 2.70 22704.84 92.33 274.22 3,401.64 110.06 N 16,759.17 W 13665.18 5.16 22798.06 85.40 272.94 3,403.48 115.87 N 16,852.13 W 13737.99 7.56 22891.46 88.56 272.34 3,408.40 120.17 N 16,945.29 W 13811.84 3.44 22984.80 87.85 273.47 3,411.33 124.90 N 17,038.46 W 13885.45 1.43 23078.14 86.00 271.52 3,416.34 128.96 N 17,131.57 W 13959.39 2.88 23171.35 86.51 269.72 3,422.42 129.96 N 17,224.57 W 14035.00 2.00 23264.57 89.55 268.99 3,425.63 128.91 N 17,317.72 W 14111.90 3.35 23357.53 92.30 268.92 3,424.13 127.22 N 17,410.64 W 14188.99 2.96 23450.85 96.94 267.01 3,416.61 123.92 N 17,503.57 W 14267.00 5.37 23544.04 102.10 266.09 3,401.20 118.40 N 17,595.28 W 14345.29 5.62 INSITE V8.1.10 Page 6Job No:AK-XX-0902143510 Well Name:SI34-W6 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 23637.37 106.57 264.68 3,378.10 111.13 N 17,685.39 W 14423.27 5.01 23730.68 109.54 264.70 3,349.19 102.93 N 17,773.71 W 14500.33 3.18 23824.09 109.36 264.50 3,318.08 94.64 N 17,861.40 W 14576.92 0.28 23886.00 109.36 264.50 3,297.56 89.04 N 17,919.54 W 14627.75 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 235.00 degrees (True) - A total correction of 18.94 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 23,886.00 feet is 17,919.76 feet along 270.28 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 7Job No:AK-XX-0902143510 Well Name:SI34-W6 Survey Report
