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Home My WebLink About214-157CAUTION: 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:Ryan Thompson To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Keith Lopez Subject:SI26-NW2 (PTD# 2141570) 10-426 Date:Thursday, August 28, 2025 12:34:23 PM Attachments:SI26-NW2 CMIT-TxIA 08-22-2025.xlsx All – Please find attached 10-426 for non-witnessed passing CMIT-TxIA performed on SI26-NW2 (PTD 2141570) on 8/22/25. Thanks, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1LNDLWFKXT8QLW6,1: 37' OPERATOR:FIELD / UNIT / PAD:DATE: OPERATOR REP: AOGCC REP: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2141570 Type Inj W Tubing 1569 1676 1676 1676 Type Te 3605 BBL Pump 2.7 IA 1724 1818 1804 1794 Interva 1500 BBL Return 5.6 OA 260 260 260 260 Resul Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resul Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resul Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resul Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resul Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Te BBL Pump IA Interva BBL Return OA Resul TYPE TEST Codes INTERVAL Codes Result Codes P = Pressure Test I = Initial Test P = Pass O = Other (describe in Notes) 4 = Four Year Cycle F = Fail Non AOGCC witnessed CMIT-TxIA to confirm competent production casing for AA application. Chris Casey 08/22/25 SI26-NW2 9 9 9 9 999 9 9 9 9 9 9 -5HJJ CMIT-TxIA for AA application 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:Keith Lopez Cc:Sara Hannegan; Ryan Thompson; Brooks, Phoebe L (OGC) Subject:RE: AIO10D.001 SI26-NW2 Administrative Approval (PTD 2141570) Date:Monday, October 20, 2025 8:50:58 AM Attachments:FW Nikaitchuq well SI26-NW2 (PTD 2141570) Request for Administrative Approval .msg Keith, The AA application states that Hilcorp will have worked over the well and replaced tubing by July 2026. That workover will require a MIT in the July-Aug 2026 period – and so that was captured in the AA. If your plans change, we will review the AA. We have set our database to reflect next MIT due Aug 2026. 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: Keith Lopez <keith.lopez@hilcorp.com> Sent: Thursday, October 16, 2025 1:41 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: AIO10D.001 SI26-NW2 Administrative Approval Mr. Wallace, In reviewing upcoming MIT due dates, I noticed the AA for SI26 set the next MIT date for August 2026. The last MIT was conducted on 8/22/25 putting the next scheduled MIT only one year later. This date is inconsistent with condition #3 of the AIO which sets MIT frequency at every two years. Was wondering if this date was an error and if so, we can pursue an amended AA. Thanks for looking at this. Keith Lopez Operations Engineer – Western North Slope Office: 907-777-8438 Cell: 907-903-5432 keith.lopez@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are 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. 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: PWI SI26-NW2 (PTD: 2141570) to Operable per AIO-25-019 Date:Wednesday, September 3, 2025 4:59:06 PM From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Wednesday, September 3, 2025 4:47 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> Subject: PWI SI26-NW2 (PTD: 2141570) to Operable per AIO-25-019 Mr. Wallace. PWI SI26-NW2 (PTD: 2141570) has been made OPERABLE. Per AIO 10D.001, real-time SCADA monitoring for the IA and OA with low and high audible alarm points set on both annuli is in place. Please respond with any questions. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey 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:Rixse, Melvin G (OGC) To:Keith Lopez Cc:Darci Horner Subject:20250819 1053 APPROVAL SI26-NW2 (PTD #214-157) Tubing Cut Date:Tuesday, August 19, 2025 10:54:04 AM Keith, Good you updated AOGCC with the change. Thanks. Approved to utilize Eline tractor for the tubing cut. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Keith Lopez <keith.lopez@hilcorp.com> Sent: Tuesday, August 19, 2025 10:33 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Darci Horner <dhorner@hilcorp.com> Subject: SI26-NW2 (PTD #214-157) Tubing Cut Mr. Rixse, You approved the attached sundry for a contingency tubing cut on the injector SI26 using coil tubing. Logistically we are not able to mobilize coil to Spy Island. We have changed services lines to complete this program with Eline with a tractor. I don’t think it changes the sundry approval but wanted to pass it by you incase anything needed to change. Keith Lopez Operations Engineer – Western North Slope Office: 907-777-8438 Cell: 907-903-5432 keith.lopez@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing Cut 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 24,062 NA Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Production Liner NA Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Keith Lopez Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388572, ADL0388574, ADL0388575, ADL0388583, ADL0391283 214-157 NIKAITCHUQ SI26-NW2 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23531-00-00 NIKAITCHUQ Hilcorp Alaska, LLC Length Size Proposed Pools: 3,633 24,050 3,634 1,137 SCHRADER BLUFF OIL Same 160 160 L-80 TVD Burst 15,563 NA MD NA 15,740 5,020psi 5,750psi 2,446 3,628 2,834 15,740 15,740-24,062 3,6344-1/2" 160 20" 13-3/8" 9-5/8" 2,834 3,628'-3,633 907-777-8438 keith.lopez@hilcorp.com Operations Manager August 15, 2025 4-1/2" Perforation Depth MD (ft): NA HES PHL Packer, HS Packer, and NA 15,324' MD/3,602' TVD, 15,405' MD/3,605' TVD NA 24,0508,310 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:57 pm, Aug 01, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.08.01 15:11:26 - 08'00' Sara Hannegan (2519) 325-457 SFD 8/11/2025 CDW 08/11/2025 DSR-8/13/25MGR11AUG25 10-404 *&: 8/14/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.14 10:00:19 -08'00' RBDMS JSB 081825 CT Tubing Hole Diagnostics Well: SI26 Well Name:SI26 API Number:50-629-23510-00-00 Current Status:Offline water injector Permit to Drill Number:214-157 First Call Engineer:Keith Lopez (907) 903-5432 (c) Second Call Engineer:Ryan Rupert (907) 301-1736 (c) Maximum Expected BHP:1,500 psi @ 3,630’ TVD (8.0ppg) Max. Potential Surface Pressure: 1,137 psi Using 0.1 psi/ft Brief Well Summary Drilled in 2014 as a Schrader Bluff Oa injection well offset to SP21 and SP28. In March 2021, TxIA communication was developed and a tubing patch was installed. The patch failed to fix the communication and a RWO was conducted in July 2021 to replace the tubing with L80 and stacked a packer with an overshot. A 4-year MITIA failed on 06/21/25 when TxIA communication was established again. If the casing still has integrity, we apply for an AA and return the well to injection until we can replace the tubing string. If the combo MIT fails, we will cut the tubing in preparation for the RWO. Objectives in priority order: 1. Confirm 9-5/8” casing integrity Æ Plug set in 4-1/2” tubing at ~15,430’ MD + MIT 2. If combo MIT fails cut tubing Æ Cut tubing @ ~15,281’ Pertinent wellbore information: - Inclination o Goes > 70 degrees at 3,197’ MD o Sail angle of 89 degrees from 3,664 – 12,064’ MD - Critical depths: o Gauge Carrier: 15,251’ MD / 3,598’ TVD. o Injection packer stacked: 15,324’ MD / 3,602’ TVD (bottom of current monitorable annulus) o Initial injector packer: 15,405’ MD / 3,605’ TVD. o 9-5/8” Intermediate casing shoe: 15,740’ MD / 3,627’ TVD 50-629-23531-00-00 SFD CT Tubing Hole Diagnostics Well: SI26 CT Diagnostics Procedure 1. MIRU CT 2. PT lubricator to 250psi low / 2500psi high 3. RIH and drift to target depth = 15,550’ MD 4. MU test plug and RIH to 15,423’ MD (XN nipple) 5. Set plug in XN nipple @ 15,423’MD 6. Combo MIT tubing and production casing to 1,650 psi for 30 minutes. (Ending pressure needs to be above 1,500 psi. Work with ops to supply fluid for pressure test.) 7. IF MIT FAILS: Establish stable leak rate. 8. POOH with plug 9. IF MIT FAILS: Cut tubing @ 15,281’ (full jnt between the upper packer and gauge carrier.) 10. RDMO CT (no need to freeze protect well). Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 13-3/8" 68 ppf,Surf. Casing,2,834' MD,2,446' TVD58° Inc9-5/8" 40 ppf, H563,Intermediate Casing,15,740' MD, 3,627' TVD,86° Inc4-½”,12.6 ppf,H563, ProductionTubing4-½” 11.6 ppf,H521 Prod LinerZonal IsolationPackersInjection Control DevicesHS Packer15,405' MD, 3,605' TVD,87° IncConfidentialNikaitchuq Field – Spy IslandAs Completed July 22, 20212,162' MD, 2,006- 3.81" GX-nipple for possible injection valve15,440' MD, 3,609' TVD- HAL Mirage Plug with Auto-fill valveSI26-NW2 InjectorMonobore with Injection Control 15,546' MD, 3,615' TVD– Top of SLZXP Liner Hanger/Packer15,423' MD, 3,608' TVD -3.725" XN4-½” Ecc-Nose GuideShoe, 24,050' MD,3,633' TVD94° Inc15,563' MD, 3,616' TVD – Bottom of entry guide0TD 24,062' MD,3,632' TVD,94° IncItem Depth (ft) Item Depth (ft)ICD #1 23,561 ICD #9 19,995ICD #2 23,059 ICD #10 18,827ICD #3 22,559 ICD #11 18,251ICD #4 22,078 ICD #12 17,808ICD #5 21,538 ICD #13 17,362ICD #6 21,169 ICD #14 16,957ICD #7 20,799 ICD #15 16,453ICD #8 20,398 ICD #16 16,001Item Depth (ft)SP #1 23,469SP #2 22,813SP #3 21,636SP #4 19,904SP #5 18,922SP #6 18,385SP #7 16,747AV 06/29/202115,312' MD, 3,601' TVD 3.81" GX-nipple15,324' MD, 3,602' TVD 4-½” x 9-5/8" HESPHL Packer15,392' MD ,3,606' TVD 4-½” Overshot15,366' MD, 3,604' TVD3.81" GX-nipple 15,251' MD, 3,598' TVD 4-½”Gauge Carrier for P,T, tubing sensorDate Activity12/16/2014 Drill and Complete7/22/2021Due to leak in tubing, cuttubing above hanger and runnew tubing with overshot and2nd packer.Well History 13-3/8" 68 ppf,Surf. Casing,2,834' MD,2,446' TVD58° Inc9-5/8" 40 ppf, H563,Intermediate Casing,15,740' MD, 3,627' TVD,86° Inc4-½”,12.6 ppf,H563, ProductionTubing4-½” 11.6 ppf,H521 Prod LinerZonal IsolationPackersInjection Control DevicesHS Packer15,405' MD, 3,605' TVD,87° IncConfidentialNikaitchuq Field – Spy IslandProposed Schematic August 1, 20252,162' MD, 2,006- 3.81" GX-nipple for possible injection valve15,440' MD, 3,609' TVD- HAL Mirage Plug with Auto-fill valveSI26-NW2 InjectorMonobore with Injection Control 15,546' MD, 3,615' TVD– Top of SLZXP Liner Hanger/Packer15,423' MD, 3,608' TVD -3.725" XN4-½” Ecc-Nose GuideShoe, 24,050' MD,3,633' TVD94° Inc15,563' MD, 3,616' TVD – Bottom of entry guide0TD 24,062' MD,3,632' TVD,94° IncItem Depth (ft) Item Depth (ft)ICD #1 23,561 ICD #9 19,995ICD #2 23,059 ICD #10 18,827ICD #3 22,559 ICD #11 18,251ICD #4 22,078 ICD #12 17,808ICD #5 21,538 ICD #13 17,362ICD #6 21,169 ICD #14 16,957ICD #7 20,799 ICD #15 16,453ICD #8 20,398 ICD #16 16,001Item Depth (ft)SP #1 23,469SP #2 22,813SP #3 21,636SP #4 19,904SP #5 18,922SP #6 18,385SP #7 16,747Last updated by : DH 8-1-202515,312' MD, 3,601' TVD 3.81" GX-nipple15,324' MD, 3,602' TVD 4-½” x 9-5/8" HESPHL Packer15,392' MD ,3,606' TVD 4-½” Overshot15,366' MD, 3,604' TVD3.81" GX-nipple 15,251' MD, 3,598' TVD 4-½”Gauge Carrier for P,T, tubing sensorDate Activity12/16/2014 Drill and Complete7/22/2021Due to leak in tubing, cuttubing above hanger and runnew tubing with overshot and2nd packer.Well HistoryProposed Tubing cut at ~15,281' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from keith.lopez@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: SI26 AA Request (PTD 214-157) Date:Thursday, July 31, 2025 2:55:41 PM From: Wallace, Chris D (OGC) Sent: Thursday, July 31, 2025 2:52 PM To: Keith Lopez <keith.lopez@hilcorp.com> Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: SI26 AA Request (PTD 214-157) Keith, A quick look at our more recent waivered injection wells list shows me: 2150160 NIKAITCHUQ SI34-W6 IIR 1WINJ AIO 36.004 5/18/2023 TxIA 4/22/2023 CMIT 2 yr to greater of max inj. Press, 0.25xpacker TVD, 1500 psi; 2000psi max IA; 1000psi max IA and OA with alarms and SCADA; monthly rpt TIO pressures; MIT as soon as possible 2023; water only 2101060 NIKAITCHUQ OI11-01 IIR 1WINJ AIO 36.009 8/30/2023 TxIA 8/23/2023 CMITIA 2 yr to greater of max inj. Press, 0.25xpacker TVD, 1500 psi; 2000psi max IA; 1000psi max IA and OA with alarms and SCADA; monthly rpt TIO pressures; CMIT July 2025; water only 2191650 NIKAITCHUQ SI06-NE1 IIR 1WINJ AIO 36.010 12/14/2023 TxIA CMITIA 2 yr to greater of max inj. Press, 0.25xpacker TVD, 1500 psi; 2000psi max IA; 1000psi max IA and OA with alarms and SCADA; monthly rpt TIO pressures; CMIT May 2025; water only 2111300 NIKAITCHUQ OI24-08 IIR 1WINJ AIO 36.011 1/26/2024 TxIA CMITIA 2 yr to greater of max inj. Press, 0.25xpacker TVD, 1500 psi; 2000psi max IA; 1000psi max IA and OA with alarms and SCADA; monthly rpt TIO pressures; CMIT December 2025; water only So going by history, it would seem to be acceptable to AOGCC to have a CMIT, with alarms, pressure limits SCADA, etc. We would of course prefer you fix this well and all other TxIA wells… 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.govCONFIDENTIALITY 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 anunintended 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: Keith Lopez <keith.lopez@hilcorp.com> Sent: Thursday, July 31, 2025 2:13 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: SI26 AA Request (PTD 214-157) Mr. Wallace, SI26 (PTD 214-157) recently failed it’s 4-year MIT on 06/21/25 and was shut in. There was no indication of TxIA communication leading up to the pressure test. During the pressure test, the tubing and inner annulus began communicating. The injector was shut in and has remained so. Nikaitchuq has a history of microbial corrosion effecting our production and injection tubing. Injector tubing leak diagnostics typically find sections of corroded tubing and not a small, isolated area. Hilcorp would like to move toward a RWO to changeout the tubing once we have the materials and a working rig on the island. Hilcorp proposes conducting a combo MIT on SI26 to demonstrate casing integrity and with that information apply for the AA to continue injection until the RWO can be completed. The next window we will have to conduct the RWO on the island is ice road season. We plan to conduct the RWO by 06/01/26 or shut the well in pending further diagnostics or actions. As with most Nikaitchuq injectors this well is on a vacuum with a column of injection water. Would this approach be acceptable with the AOGCC? We need to barge a unit out to the island for the CMIT and don’t want to move it back if the AOGCC will not consider granting an AA without further diagnostics. Keith Lopez Operations Engineer – Western North Slope Office: 907-777-8438 Cell: 907-903-5432 keith.lopez@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from chris.casey@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: SI26-NW2 (PTD# 214157) - Shut in for Failed 4-year MIT-IA Date:Tuesday, June 24, 2025 2:05:26 PM Attachments:image001.png From: Chris Casey - (C) <Chris.Casey@hilcorp.com> Sent: Saturday, June 21, 2025 5:09 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: NOT OPERABLE: SI26-NW2 (PTD# 214157) - Shut in for Failed 4-year MIT-IA Mr. Wallace- PWI well SI26-NW2 (PTD # 214157) has been shut in and made NOT OPERABLE following a Failed 4-year MIT-IA and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Chris CaseyHilcorp Alaska LLCField Well Integrity chris.casey@hilcorp.com O: (907) 659-5738 P: (907)242-1021Alt: Steve Soroka Hilcorp North Slope, LLC 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. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 214157 Type Inj W Tubing -11 -11 -11 -11 Type Test P Packer TVD 3605 BBL Pump 2.8 IA 882 1652 1640 1639 Interval I Test psi 1500 BBL Return 2.8 OA 225 280 270 270 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: ENI US Operating Co Inc Nikaituq / SID-Offshore Lou Laubenstein Scott Hardy 08/14/21 Notes:Test post tubing repair/work over Notes: Notes: SI-26 Form 10-426 (Revised 01/2017)MIT NIK SI26 08-14-21 13-3/8" 68 ppf, Surf. Casing, 2,834' MD, 2,446' TVD 58° Inc 9-5/8" 40 ppf, H563, Intermediate Casing, 15,740' MD, 3,627' TVD, 86° Inc 4-½”,12.6 ppf, H563, Production Tubing 4-½” 11.6 ppf, H521 Prod Liner Zonal Isolation Packers Injection Control Devices HS Packer 15,405' MD, 3,605' TVD, 87° Inc Confidential Nikaitchuq Field – Spy Island As Completed July 22, 2021 2,162' MD, 2,006- 3.81" GX-nipple for possible injection valve 15,440' MD, 3,609' TVD- HAL Mirage Plug with Auto-fill valve SI26-NW2 Injector Monobore with Injection Control 15,546' MD, 3,615' TVD– Top of SLZXP Liner Hanger/Packer 15,423' MD, 3,608' TVD -3.725" XN 4-½” Ecc-Nose Guide Shoe, 24,050' MD, 3,633' TVD 94° Inc 15,563' MD, 3,616' TVD – Bottom of entry guide 0 TD 24,062' MD, 3,632' TVD, 94° Inc Item Depth (ft)Item Depth (ft) ICD #1 23,561 ICD #9 19,995 ICD #2 23,059 ICD #10 18,827 ICD #3 22,559 ICD #11 18,251 ICD #4 22,078 ICD #12 17,808 ICD #5 21,538 ICD #13 17,362 ICD #6 21,169 ICD #14 16,957 ICD #7 20,799 ICD #15 16,453 ICD #8 20,398 ICD #16 16,001 Item Depth (ft) SP #1 23,469 SP #2 22,813 SP #3 21,636 SP #4 19,904 SP #5 18,922 SP #6 18,385 SP #7 16,747 AV 06/29/2021 15,312' MD, 3,601' TVD 3.81" GX-nipple 15,324' MD, 3,602' TVD 4-½” x 9-5/8" HES PHL Packer 15,392' MD ,3,606' TVD 4-½” Overshot 15,366' MD, 3,604' TVD3.81" GX-nipple 15,251' MD, 3,598' TVD 4-½”Gauge Carrier for P,T, tubing sensor MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI26-NW2 NIKAITCHUQ SI26-NW2 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 SI26-NW2 50-629-23531-00-00 214-157-0 W SPT 3605 2141570 1500 663 667 290 320 4YRTST F Austin McLeod 6/21/2025 MITIA. Bump up from previous fail. @ 5 min T=664psi; I=1190psi; O=280psi. Well S/I. 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 SI26-NW2 Inspection Date: Tubing OA Packer Depth 1235 1667IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250621181204 BBL Pumped:4.2 BBL Returned:1.7 Thursday, July 24, 2025 Page 1 of 1          MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI26-NW2 NIKAITCHUQ SI26-NW2 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 SI26-NW2 50-629-23531-00-00 214-157-0 W SPT 3605 2141570 1500 661 667 260 360 4YRTST F Austin McLeod 6/21/2025 MITIA. @ two mins IA=1480 psi. @ five mins IA=1235psi. No bleed back. Bumped up. See separate report. 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 SI26-NW2 Inspection Date: Tubing OA Packer Depth 294 1683IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250621180818 BBL Pumped:6.3 BBL Returned: Thursday, July 24, 2025 Page 1 of 1         MEMORANDUM TO: Jim Regg ��( l P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 23, 2021 SUBJECT: Mechanical Integrity Tests Eni US Operating Company Inc. SI26-N W 2 NI"TCHUQ SI26-NW2 Src: Inspector Reviewed By: P.I. Supry Comm Well Name NIKAITCHUQ SI26-NW2 API Well Number 50-629-23531-00-00 Inspector Name: Lou Laubenstein Permit Number: 214-157-0 Inspection Date: 8/14/2021 Insp Num: mitLOL210815145149 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5126-NW2 Type Inj w TVD 3605 Tubing I 1 1 - 1 PTD 1 2141570 Type Test SPT Test psi 1500 IA 882 1652 1640 1639 - BBL Pumped: 2.8 BBL Returned: 2.8 OA 225 280- 270 270 ' - - IntervalINITAL PAF P Y - Notes: Initial test post Rig workover ZL11 l Monday, August 23, 2021 Page I of 1 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Pull/Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 24,062 feet N/A feet true vertical 3,632 feet N/A feet Effective Depth measured 24,050 feet 8,409' feet true vertical 3,633 feet 3,616 feet Perforation depth Measured depth 15,740-24,062 feet True Vertical depth 3627-3632 feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 15,312 3,601 Packers and SSSV (type, measured and true vertical depth)HES PHL Injection 15,324 3,602 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone:907-865-3379 Eni US Operating Co. Inc. N/A Stefano Pierfelici Well Operations Project Manager Amjad Chaudhry amjad.chaudhry@eni.com WINJ WAG N/A Water-Bbl MD 160 2834 964 425 879N/A TVD Oil-Bbl measured true vertical Packer 3700 Centerpoint Drive Suite 500, Anchorage 99503 SI26-NW2 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf 3. Address: 4. Well Class Before Work: N/A Representative Daily Average Production or Injection Data 1762323 Casing Pressure Tubing Pressure ADL 0391283, 0388583, 0388574, 0388575, 0388572 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-157 50-629-23531-00-00 N/A 5. Permit to Drill Number: Nikaitchuq Schrader Bluff Oil 2. Operator Name measuredPlugs Junk measured N/A Casing Structural 20 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-292 3 Size Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: Liner Length 160 2834 15740 0 8310 13.375 9.625 0 4.5 15740 0 24050 160 2446 3,627 0 3633 Burst 5,210 6,890 Senior Engineer:Senior Res. Engineer: ICDs Collapse 2,480 4,490 ICDs t Fra O 6. A G L PG , R g Form 10-404 Revised 3/2020 Submit Within 30 days of Operations 08/18/2021 By Samantha Carlisle at 10:36 am, Aug 19, 2021 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.08.18 16:26:40 -08'00' Stefano Pierfelic i RBDMS HEW 8/19/2021 VTL 9/9/21 DSR-8/19/21 SFD 8/19/2021 13-3/8" 68 ppf,Surf. Casing,2,834' MD,2,446' TVD58°Inc9-5/8" 40 ppf, H563,Intermediate Casing,15,740' MD, 3,627' TVD,86°Inc4-½”,12.6 ppf,H563, ProductionTubing4-½” 11.6 ppf,H521 Prod LinerZonal IsolationPackersInjection Control DevicesHS Packer15,405' MD, 3,605' TVD,87°IncConfidentialNikaitchuq Field–Spy IslandAs CompletedJuly 22, 20212,162' MD, 2,006- 3.81" GX-nipple for possible injection valve15,440' MD, 3,609' TVD- HAL Mirage Plug with Auto-fill valveSI26-NW2 InjectorMonobore with Injection Control15,546' MD, 3,615' TVD–Top of SLZXP Liner Hanger/Packer15,423' MD, 3,608' TVD -3.725" XN4-½” Ecc-Nose GuideShoe, 24,050' MD,3,633' TVD94°Inc15,563' MD, 3,616' TVD–Bottom of entry guide0TD 24,062' MD,3,632' TVD,94°IncItem Depth (ft) Item Depth (ft)ICD #1 23,561 ICD #9 19,995 ICD #2 23,059 ICD #10 18,827 ICD #3 22,559 ICD #11 18,251 ICD #4 22,078 ICD #12 17,808 ICD #5 21,538 ICD #13 17,362 ICD #6 21,169 ICD #14 16,957 ICD #7 20,799 ICD #15 16,453 ICD #8 20,398 ICD #16 16,001 Item Depth (ft)SP #1 23,469 SP #2 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Well Code: 28997 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 7/23/2021 Report #: 12 Page: 1 of 3 Well Header Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.71 Ground Level (ft) 13.09 First Flange (ft) 16.97 RKB - Base Flange (ft) 36.74 RKB - Tubing Spool (ft) 33.93 Rigs Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Rig Start Date 7/12/2021 Rig Release Date Daily Information Weather Overcast Temperature (°F) 37.5 Wind E @ 18 MPH Days LTI (days) Days RI (days) POB 99.0 Safety Incidents - Near Miss Date 7/23/2021 Category Type Subtype Severity Cause Lost time? No Comment No HSE incidents. Reviewed the 7C's with a focus on Communication. Reviewed Eni Golden Rules with a focus on Fire Safety. Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) BOP Test (pressure)1 7/13/2021 7/20/2021 -3 Fire Drill 4 7/22/2021 7/23/2021 0 Kick While Tripping Drill 8 7/20/2021 7/27/2021 4 Man Down Drill 1 7/18/2021 10/16/2021 85 Rig Evacuation Drill 2 7/19/2021 10/17/2021 86 Rig Inspection 12 7/23/2021 7/24/2021 1 Safety Meeting 12 7/23/2021 7/24/2021 1 Spill Drill 4 7/23/2021 7/24/2021 1 SWA Drill 1 7/17/2021 7/24/2021 1 TT Camp Evacuation Drill 1 7/13/2021 10/11/2021 80 Well Kill Drill 1 7/12/2021 10/10/2021 79 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date CASING 9 5/8 8.84 L-80 19.1 15,750.0 3,626.2 11/28/2014 LINER 4 1/2 3.96 L80 15,546.3 24,052.0 3,618.5 12/13/2014 CASING 13 3/8 12.42 L-80 0.0 2,833.7 2,446.0 12/20/2017 Last Cementing Cementing Start Date:11/29/2014 String:CASING, 15,750.0ftKB Comment:Shut down rig pumps and Schlumberger pumped 10 bbls. H2O to fill lines and tested lines to 1,308/ 3,775 psi.- good. Switched back rig pumping 100 bbls. of Mud Push II @ 10.5 ppg - rate of 5 bpm @ 397 psi. Shut-down and drop bottom plug. SLB mix & pump Lead slurry 222.85 bbls W/ 12.5 ppg Lite CRETE [1.56 ft3/sk Yield, mix water at 5.461 gal/sk.] - Pump rate of 4 bpm @ 400-600 psi. Shut down and drop top plug - SLB pump 10 bbls H20 and wash up. Displace with 1,176 bbls W/ 9.3 ppg mud with rig pump at 6 bpm w/ 550 psi, final pressure 550 psi. Plug bumped Press. up to 1,050 PSI and hold for 5 Min. Check floats, holding. Cement in place @ 13:00 hrs. Stg # Top (ftKB) Top Meas Meth Btm (ftKB) Com 1 11,430.0 13,188.0 Spacer Mud Push 2 10.5 ppg 2 13,188.0 15,750.0 12.5 ppg LiteCRETE Job Information Job Phase WORKOVER Planned Start Date 7/7/2021 00:00 Start Date 7/12/2021 00:00 End Date P50 Duration (days) 13.00 Daily Summary Operations 24h Forecast Run in hole with e-line to retrieve junk catcher. Pull out of hole and lay down junk catcher. Run in hole with equalizer tool and equilize pressure across plug. Pull out of hole. Pick up tools to pull nipple reducer. Work on Minor maintenance while e-line is timed out. 24h Summary Preform maintenance, clean pits, rig up and pull RHC plug from GX nipple at 15365’, Attempt to pull junk catcher from top of nipple reducer at 15423’. Pull out of hole no junk catcher. Redress tools and make up lubricator. While Halliburton is timed out and resting: Continue to wire wheel welds on base of derrick and bit breakers for inspection. Inventory pump spare parts and shaker screen inventory. Operation at 07.00 Running in hole with Junk catcher retieval tools. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. R 20 P While E-line crew timed out and resting. Continue working on Maintenance MP2’s. Finish clearing area in front of SP03. Change out leaky steam valve in pits. Inspect mud pump seats and valves. Check safety cables on shock hoses. Paint landing on bottom of doghouse stairs. 02:00 10:00 8.00 10.00 W.O. R 15 P Halliburton E-line run in hole with Welltec tractor and stroker with GS retrieving tool to 3300’ engage tractor and continue to tractor in hole to RHC plug in GX nipple at 15365. Engaged plug with GS tool and using stroker pulled RHC plug out of GX profile. Pulled out of hole with RHC plug to GX nipple at 15312, and had to engage stroker to get packing past nipple. Continue to pull out of hole with RHC plug. 10:00 11:00 1.00 11.00 W.O. R 15 P Remove and lay down RHC plug, Welltec service tractor, make up GR retrieval tool to pull junk catcher from top of nipple reducer. 11:00 20:30 9.50 20.50 W.O. R 15 P Halliburton E-line run in hole with Welltec tractor and stroker with GR retrieving tool to 3300’ engage tractor and continue to tractor in hole to Junk catcher in top of nipple reducer at 15423’. Make 2 strokes and pull, observe over pull. Pull out of hole. Break connection on lubricator and no Junk catcher. Inspect tools and all looked good. Re-dress and Make up GR tool, Purge tractor with oil and install lubricator. 20:30 00:00 3.50 24.00 W.O. R 20 P Halliburton time ou and resting. Continue with housekeeping, painting in pipe shed. Cut new pit suction rubbers. Continue to wire wheel welds on base of derrick, and bit breakers for inspection. Inventory pump spare parts and shaker screen inventory. Operation from 00:00 to 06:00 Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 29.00 W.O. K 20 P While E-line crew timed out and resting. Continue working on Maintenance MP2’s. Needle gun welds on tugger and EZ torque pedestals for upcoming inspection. Cut new pit suction rubbers. Inspect crown and grease crown sheaves. Inspect and service iron roughneck. Change out fuel filter and clean flow meter debris screen on 3.0 air heater. Perform weekly derrick inspection. 05:00 16:00 11.00 40.00 W.O. R 15 P Halliburton E-line run in hole with Welltec tractor and stroker with GR retrieving tool to 3,300’ engage tractor and continue to run in hole to nipple reducer at 15,423’, and tagged up on junk catcher. Engaged stroker and stroked a total of 5 times, 4 strokes appeared that we were pushing something last stroke we were able to see amperage spike prior to a full stroke. Released anchor on stroker and attempted to pick up with wire line winch, pulled 66% of weak point failure, and did not have any apparent movement of tools, Maintained 3500# of line pull for 30 minutes with brake locked to see if we had any tool movement without success. Released line tension and stroked down to see if the tools had moved up hole any, it did not appear that there was any tool movement. Engaged stroker and stroked up with tools monitoring amperage completed 1 stroke without seeing a sudden drop in amperage indicating that the pin had not sheared, made additional stroke with amperage slowly falling to free stroke rate. Released anchor on stroker and wireline was able to hoist tools out of hole. Continue to pull out of hole with Welltec tractor, stroker GR retrieving tool and junk catcher. Well Name: SI26-NW2 OR Wellbore Name: SI26-NW2 Well Code: 28997 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 7/23/2021 Report #: 12 Page: 2 of 3 Gas Readings Avg Background Gas (%) 0.00 Max Background Gas (%) 0.00 Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) 0.00 Max Trip Gas (%) 0.00 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Tank 57.0 Hole 1,126.0 Loss 0.0 Cumulative Mud Volumes Active Volume (bbl) 1,183.0 Hole Volume (bbl) 1,126.0 Additions (bbl) 0.0 Cum Additions (bbl) 0.0 Losses (bbl) 0.0 Cum Losses (bbl) 535.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Aivano ASRC Energy Services Drilling Supv.Micheal.Aivano@enternal.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Safety Representative Mark Hubler Beacon HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 907-685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Superior Thread Rep 12.00 0 GBR Pipe handling service 12.00 0 ASRC Energy Services SOA 12.00 1 ASRC Energy Services Lift Advisor 12.00 1 Beacon HSE 12.00 1 COMPETENTIA Fueler 12.00 1 HALLIBURTON Packer Tech 12.00 1 Vault Wellhead 12.00 1 ASRC Energy Services Rig clerk 12.00 2 HALLIBURTON Mud Loggers 12.00 2 Welltec Tractor 12.00 2 SCHLUMBERGER/Camco Completions service 12.00 2 Little Red Services Hot Oil 12.00 2 HALLIBURTON Eline 12.00 3 SCHLUMBERGER SLB - MI Swaco Mud Engineer 12.00 3 ASRC Energy Services Company man 12.00 4 SCHLUMBERGER SLB - MI-Swaco (Mud plant) 12.00 8 SCHLUMBERGER SLB - WIF 12.00 9 WORLEY Rig Support 12.00 17 DOYON Onshore Rig 12.00 39 BOP Stack & Components Description BOP Stack Start Date 7/12/2021 Last Certification Date 12/13/2019 Pressure Rating (psi) 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 4/6/2020 4 1/2" X 7" VBR Hydril MPL 5000 13 5/8 5,000.0 3/11/2021 Blind Shear Ram Hydril MPL 5000 13 5/8 5,000.0 12/13/2019 3 1/2" x 6" VBRs Hydril MPL 5000 13 5/8 5,000.0 12/13/2019 Slow Circulation Rates Pump Number:1 Make:White Star Model:Quatro 2450 Start Date 7/12/2021 End Date Liner Size (in) 6 Volume Per Stroke Override (bbl/stk) 0.110 Max Pressure (psi) 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Pump Number:2 Make:White Star Model:Quatro 2450 Start Date 7/12/2021 End Date Liner Size (in) 6 Volume Per Stroke Override (bbl/stk) 0.110 Max Pressure (psi) 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Pump Number:3 Make:National Supply Model:12-P-160 Start Date 7/12/2021 End Date Liner Size (in) 5 Volume Per Stroke Override (bbl/stk) 0.068 Max Pressure (psi) 6,720.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description:Equipment Fuel Unit Label:gal us Unit Size:1 Note: Date 7/23/2021 Consumed 747.0 Received 747.0 Returned Cum Consumed 5,232.0 Cum Received 5,232.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description:Mud Plant Boilers Unit Label:gal us Unit Size:1 Note: Date 7/23/2021 Consumed 198.0 Received 198.0 Returned Cum Consumed 2,376.0 Cum Received 2,376.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description:Rig Fuel Unit Label:gal us Unit Size:1 Note: Date 7/23/2021 Consumed 504.0 Received 0.0 Returned Cum Consumed 5,852.0 Cum Received 13,797.0 Cum Returned 0.0 Cum On Loc 7,945.0 Note Supply Item Description:Rig Water Unit Label:bbl Unit Size:1 Note: Date 7/23/2021 Consumed 23.0 Received 40.0 Returned Cum Consumed 506.0 Cum Received 580.0 Cum Returned 0.0 Cum On Loc 74.0 Note Supply Item Description:WIF Boilers Unit Label:gal us Unit Size:1 Note: Date 7/23/2021 Consumed 42.0 Received 42.0 Returned Cum Consumed 504.0 Cum Received 504.0 Cum Returned 0.0 Cum On Loc 0.0 Note Well Name: SI26-NW2 OR Wellbore Name: SI26-NW2 Well Code: 28997 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 7/23/2021 Report #: 12 Page: 3 of 3 Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Inc.2 LO/TO Of Equipment Doyon Drilling Inc.4 Housekeping Doyon Drilling Inc.12 Procedures MI Swaco 1 PPE MI Swaco 1Lifting MISWaco 2 Housekeeping MISWaco 1Lifting MISWaco 1 Walking Working Sufaces MISWaco 1 LO/TO Of Equipment Welltec 3 Procedure Worley 4 Procedure Worley 1 Tools/Equipmemt Worley 1 Enviroment Worley 1 Housekeeping Worley 1 Dropped objects General Notes Comment: 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 24,062 3,632 24,050 3,633 991 n/a Casing Collapse Structural Conductor Surface 2,480 Intermediate 4,790 Production Liner ICDs Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 COMMISSION USE ONLY Authorized Name: Authorized Title: 6/11/2021 ICDs Tubing Grade:Tubing MD (ft): 3627-3632 15,405' MD / 3,605' TVD Perforation Depth TVD (ft):Tubing Size: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391283, 0388583, 0388574, 0388575, 0388572 214-157 3700 Centerpoint Drive Suite 500, Anchorage 99503 50-629-23531-00-00 Eni US Operating Co. Inc. Length Size SI26-NW2 Nikaitchuq Schrader Bluff Oil n/a PRESENT WELL CONDITION SUMMARY L80 TVD Burst 15,400 MD 6,890 5,210 160 2,446 3,627 160 2,834 20 13.375 160 9.62515,740 2,834 Perforation Depth MD (ft): 15,740 15,740-24,062 4.5 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: June 25th, 2021 24,0508,310 4.5" 3,633 Halliburtons HS Packer Stefano Pierfelici Well Operations project Manager m n P s 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:44 pm, Jun 14, 2021 321-292 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.06.14 15:00:44 -08'00' Stefano Pierfelic i DLB 06/14/2021 X X X X BOP test 3500 psig Annular preventer test to 2500 psig DSR-6/14/21 10-404 pull/replace tubing X X VTL 6/15/21 dts 6/15/2021 JLC 6/15/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.15 12:00:16 -08'00' RBDMS HEW 6/16/2021 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com June 14, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SI26-NW2 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SI26-NW2 SI26-NW22 was completed on Spy Island on March 22, 2014, with an injection packer set at a depth of 15,405’ MD as a Schrader bluff water injector. The well was started up for injection march 2014, well failed a routine 4 years MIT in April 2021, a rig-less operation of ACX/Caliper logs confirmed that tubing has a leak. Well is down since April 2021 because of a tubing leak. The estimated date for beginning this work is June 25th, 2021. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.06.14 15:01:51 -08'00' Stefano Pierfelic i well failed a routine 4 years MIT in April 2021,pj ,y a rig-less operation of ACX/Caliper logs confirmed that tubing has a leak. SI26-NW2 Workover – Summary Page PTD#:214-157 Status Well SI26-NW2 is currently shut in. in April 2021 it failed required MIT, a rig less leak detection logs were performed and confirmed annulus to tubing communication, Owen tubing patch was installed but subsequent MIT failed again. Data acquisition for pressure-actuated sealant were also performed in order to allow an engineering solution, but due the severity of hydraulic communication, this possible solution has been aborted. Scope of Work Scope of this workover is pull out existing tubing and injection packer and run new tubing and new packer. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1354 psi (3,627’ TVD) during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/VBR/Shear rams/VBR TIFL/MIT-IA/MIT-OA: Attempted to perform state required MIT on May 16, 2021, failed due to suspected tubing leak. Well type: Injector Estimated start date: June 25, 2021 Drilling rig: Doyon Rig 15 Senior Drilling Engineer Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations project Manager Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 n April 2021 it failed required MIT, a rig less leak y pq,g detection logs were performed and confirmed annulus to tubing communication, Owengpg, tubing patch was installed but subsequent MIT failed again. Data acquisition for gp q g q pressure-actuated sealant were also performed in order to allow an engineering solution,ppgg , but due the severity of hydraulic communication, this possible solution has been aborted. Procedure: 1. Pump in bull heading 8.6-ppg 3%KCL/NaCl brine through tree. 2. Ensure well is killed. Set BPV. 3. MIRU Doyon Rig 15. 4. ND tree and NU BOP and test. 5. Set tubing plug in XN nipple below packer & perform casing pressure test to 2000 psi. 6. Punch tubing 7. Cut tubing above packer 8. Circ through tubing cut location displacing 4-1/2” x 9-5/8” annular fluids with 8.6-ppg 3%KCL/NaCl brine 9. POOH with 4-1/2” injection completion string x Note: 4-1/2” injection completion string below packer well remain in hole 10. Set packer above the original packer and test 9-5/8” casing to 2000 psi. 11. Contingent casing investigation may be performed based on the well condition. 12. MU new 4-1/2” injection completion sting and RIH to setting depth. x Note: New completion will include 4-1/2” x 9-5/8” packer with 4-1/2” tubing overshot below. Overshot will swallow 4-1/2” tubing stub from original completion. 13. Circ freeze protection and corrosion inhibited 8.6 ppg 3%KCL/NaCl brine completion fluid to 4-1/2” x 9-5/8” annulus 14. Land tubing hanger and overshot 15. Set 4-1/2” x 9-5/8” new packer 16. Pressure test 4-1/2” tubing to 3500 psi, charted 17. Pressure test 4-1/2” x 9-5/8” annulus to 2500 psi, charted 18. Pull tubing plug in XN nipple below lower packer 19. Install BPV and nipple down BOP. 20. NU tubing adapter and tree. 21. Pull BPV, install test plug and test tree. 22. RDMO. Below the current schematic of the well: VTL 6/15/21 State witnessed MIT-IA required after stabilized injection • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 28,2016 To: Jim Regg (-I-7Zt Zc� P P.I.Supervisor �� lc t SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC SI26-NW2 FROM: Jeff Jones NIKAITCHUQ SI26-NW2 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry e. NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI26-NW2 API Well Number 50-629-23531-00-00 Inspector Name: Jeff Jones Permit Number: 214-157-0 Inspection Date: 12/10/2016 Insp Num: mitJJ161213070137 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well SI26-NW2 ' Type Inj I W'TVD j 3605 ;Tubing 474 474 - ' 474 . 475 - r PTD 2141570 Type Test SPT Test psi 1500 - IA 1254 1660 - 1654 - 1652 Interval Li RTST P/F P '/ OA 250 1 260 - 250 -; 250 - Notes: 1.4 barrels diesel pumped. 1 well inspected,no exceptions noted. SCANNED APR 0 5 2.J 1?, Wednesday,December 28,2016 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ,(Q11.4. - 157 Well History ile Identifier Organizing(done) Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: mf BY: MD Date: gidgiir Isl Project Proofing Q� 'TIPBY: Maria Date: a V /S lsl Scanning Preparation ip x 30 = I Se + I d` = TOTAL PAGES / ?' - BY: g- rop (Count does not incude cover sheet) Date: �, //6— /s/ Production Scanning Stage 1 Page Count from Scanned File: I 1 3 (Count does include cover s eet) Page Count Matches Number in Scanning Preparation: YES NO 04 P BY: C Date: gJ , 'J/5 /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ 2DigiStage 2 Additional Well Reports: 41, NO TOTAL PAGES: (92.- Digital tal version appended by: Meredith Michal Date: 61/1(16. /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: a.,5-c5 Scanning is complete at this point unless rescanning is required. 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Zi c0 7 J o 0 a In USa 2o0 ON p ce, E 0 = U 03 o v -J a c Q R N 0. I— Z V O 5 C NI 6 N_ G co co,— m a pZ CO • N I— Z All 4o z E Q U E A Z d • N M UP CO r > CO 13 7t N N N N re 77- N • O V w N F U C., E E Guhl, Meredith D (DOA) From: Maugeri Giuseppe <Giuseppe.Maugeri@enipetroleum.com> Sent: Friday, August 21, 2015 12:50 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: SI26-NW2, PTD 214-157, Question Meredith, We didn't collect neutron and density log. The form is not correct. Sorry for that. Best regards, Giuseppe From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, August 14, 2015 9:12 AM To: Maugeri Giuseppe Cc: Bettis, Patricia K (DOA) Subject: SI26-NW2, PTD 214-157, Question Hello Giuseppe, In box 21 on the 10-407 form for SI26-NW2, PTD 214-157,the logs obtained list is "GR/RES/NEU/Den/Sonic". In my final compliance review of the data today, I did not find any neutron or density data. If the form is incorrect, meaning that neutron/density data was not collected, please advise and I will update it. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 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. 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 fif MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg D DATE: Wednesday,January 28,2015 P.I.Supervisor K`elt t13:41 SUBJECT: Mechanical Integrity Tests ll ENI US OPERATING CO INC SI26-NW2 FROM: Jeff Jones NIKAITCHUQ SI26-NW2 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv. NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI26-NW2 API Well Number 50-629-23531-00-00 Inspector Name: Jeff Jones Permit Number: 214-157-0Inspection Date: 1/16/2015 1 Insp Num: mitJJ150120220305 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill SI26-NW2 , Type Inj W 'TVD 3605 Tubing 468 468 468 468 _r PTD' 2141570 'Type Test SPT Test psi 1500 IA 712 1698 1685 1682 - Interval INITAL - P/F P ' OA 240 240 240 - 240 Notes: Wednesday,January 28,2015 Page 1 of I 41110 DATA LOGGED 2 1 4 1 5 7 t iq/2015 K BENDER � � � � O HAL.L_IBURTON Sperry E3rilling To: Alaska Oil and Gas Conversation Commission 333 W 7th Ave Suite 100 Anchorage, AK 99501 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 — SI26-NW2 AFE # 6927 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 Nar'ta Angela K. Singh Sign Name RECEIVED Date JAN 09 2015 AOGCC Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. RECEIVED STATE OF ALASKA ALASI SIL AND GAS CONSERVATION COMMI, )N IAN 0 A 9015 • o WELL COMPLETION ORen RECOMPLETION REPORT AND. LOG la. aStatus:WeIl . 20AAC 25.105 20AAc 25.110 Development ❑ Exploratory ❑ GINJ ❑ WNJ ❑� -WAG ❑ WDSPL ❑ No.of Completions: Service - Stratigraphic Test ❑ 2.Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: ENI US Operating Co. Inc. Aband.: 12/16/2014 214-157 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 11/9/2014 50-629-23531-00-00 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 4442.4 FSL 1412.5 FEL S19 T14N R9E UM 12/6/2014 Sl26-NW2 - Top of Productive Horizon: 8. KB(ft above MSL): 53.9 15. Field/Pool(s): 3726 FSL 4066 FEL 14 T14N R8EUM GL(ft above MSL): 13.1 • Total Depth: 9. Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 3711 FSL 5181 FEL 10 T14N R8EUM N/A 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 511497.34 y- 6053624.03 Zone- 4 24062'MD/3632'TVD ADL 0391283 0388583.0388574.0388575,0388572 TPI: x- 498478.41 y- 6058178.37 C t‘-- Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 492078.86 y- 6063447.12 Zone- 4 N/A ADL 417493 18. Directional Survey: Yes 2 , 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) 1858'MD/1758'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/ r/Sonic/U4t)w f.-"_e-i/ 3/a l/I,r 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 10.7 ppg Lead: 440 bbls 13.375 68 L-80 36.95 2834 36.95 2446 16 12.5 ppg Tail:63 bbls N/A 9.625 40 L-80 35.63 15740 35.63 3627 12.25 12.5 ppg LiteCRETE:223 bbls N/A 4.5 15.5 , L-80 4736 24050 3915 3632 8.75 Liner with ICD&Swelling Pac N/A 24.Open to production or injection? Yes E 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 15,653' 15,405'MD/3,605'TVD Liner with ICD ww.:=dw11:.0.1.�.1 COMPLETION 1 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. i 517i/Y - yob L i itip a. l�V� i Was hydraulic fracturing used during completion? Yes ❑ No ❑ 3cvd7 36 3�'j V) =I DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED +, 140‘ 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 .. . N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q . Sidewall Cores Acquired? Yes ❑ No ❑ 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 Revised 10/2012 ei- I CONTINUED ON REVERSE 4NIi� g��sSUb ldt_Of Lf}�❑ 7 i �l/yl�� Iill JHI� LUE ',..Yrf a 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ✓ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1858 1758 Top Ugnu 2470 2231 Top Lower Ugnu 13390 3210 Top Schrader Bluff 13980 3416 Top N Sand 14188 3477 Top OA Sand 15670 3622 Formation at total depth: OA sand 24062 13632 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 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: 1/6/2015 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 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. ED 6 CD C 0 o ❑ 2 0 — Z N V N H c O M C r O N o CV � N_ V O co M o o N CI t d -. F' Q �� 4 ..:, c .� a J 111 (W > . OL - ••••• L CL I o r> o N O = LaU > N `'r c I � _ .47. ❑ L �-. CO CO01 CO O N CO V O ,_ cK 'Ci 00 (.O CO O CO N 0 M N 6) co- co- CO Ja.' SUMMO0t N N (N ii O C m a. c t •Wm Q) ••••........... 0 Y CL N1 O - QJ a.1.t'W 4YY L wO X N 9- 0 0 t,Aimpea .' (n (n (n (n (n U) (n O Q NQ O 03 L a) X J H 1 N Y c ' pv c � \ -00 O N I C ti d CO LO . M NMH T5 p M Nr N- WK�N4.�, o .1:7� CI CD L ti i Nto CD � co CO „Q O O Q) L(7 co E O N CO- 0F- C ff. `r 0 _ N O .t- 2 C o0 O Q N N \ 4 Lai N u) o (T � LT o �"�, 0) CO N CO CO 0) C) C., • Q O CO CO r (D CO CO 73 ❑ lkc) N CO CO >. .— / O O O O O O 0 O a-- .,,c;A CL U i 4> CDY O V co o Lo o CO N rte) 1:3 • .., Co ,- ololoocomolco .......................A •• V = M CO' N N ,- ,- O O • N L Q - `� C M Q N N N N N N N N Q CD CS� � c --,.....= w, ,: Q = ❑ ❑ CI- N 0 • . CO to as 2 Y _ - V d' t0 0 Tt vkv a r, 4i ' OM 00 O E 0 0 0 0 0 0 0 0 Z M co Nt °:I o o o o U o U o I M C•I CV N M w r r Eni E&P Division Well Name:S. V2 ffit* EN!Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO • API/UWI:50-629-23531-00-00 2^ Date:11/5/2014 - Report tt: 1 i I� page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3,613.8 24,061.00 202.75 118.7 -3.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 112.0 14.0 Overcast WC-10` NE @ 50 MPH Daily summary operation 24h Summary Rig move operations,clean snow and ice F/mats.Prep ground for Herculite.Move and stage Rockwasher.Prep rig floor to skid.Blow down&R/D service lines in Pit Complex.Move and stage Pit Complex down the pad.Skid ng floor.Move Sub off SP21-NW1 and spot over 5126-NW2.Spot Pit Complex.Remove ice off Samson Beam for sub stompers and set stompers.Cont.W/Prep work for Herculite. Operation at 07.00 Cont.rig move. 24h Forecast Cont.to move ng. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(Er) Dur(Er) Phase Opr. Act. Plan Oper.Descr. 12.00 -18;00 6.00 6.00 MOB A 2 P PJSM Rig move operations,clean snow and ice F/mats.Prep ground for Herculite.Move and stage Rockwasher.Prep rig floor to skid.Blow down&R/D service lines in Pit Complex.Move and stage Pit Complex down the pad.Skid rig floor. 18:00 23.00 ' 5.00 11.00 MOB A 2 P ‘PJSA Move Sub off SP21-NW1 and spot over SI21-NW2.Spot Pit Complex. 23:00 00:00 1.00 12.00 MOB A 2 P 'PJSA Remove ice off Samson Beam for sub stompers and set stompers.Cont.W/Prep work for Herculite. 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 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 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(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Ott Pressure(psi) Eni E&P Division Well Name:S. 52 ri* ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUO • APIIUWI:50-629-23531-00-00 2 I' Date:11/6/2014 - Report#: 2 II page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33,94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3,613.8 24,061.00 202.75 118.7 -2.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.5 115.0 5.0 Partly Cloudy WC- E @ 18 MPH 14" Daily summary operation 24h Summary Skid rig floor back into drilling position.Place upper Beaver Slide into service position.Hook up steam&air to modules.Lay Herculite on ODS&begin welding seams.Work on inner connects&complete seam welding on Herculite.Lay rig mats for Pump#3 and Rockwasher.Work on berming operations.Spot#3 Pump.Work on DS suitcases.Begin spotting Rockwasher.Finish R/U DS suitcases.R/U power to rig shop.Finish R/U service lines to the rig floor.Load Vetco Grey Multi Bowl well head into cellar.Set mats and Rockwasher suitcases and connect.Load BHA#1 tools in Pipe Shed.Cont. berming around rig.Spot Mud Logger shack and MI Swaco shack and R/U.General housekeeping.Install Diverter line gag.R/U suitcase transfer hose. Operation at 07.00 Cont.rigging up. 24h Forecast Cont.rigging up.N/U Diverter Slack and line.P/U M/U 15,000'5"D.P. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 MOB A 2 P PJSM Skid ng floor back into drilling position.Place upper Beaver Slide into service position.Hook up steam&air to modules.Lay Herculite on ODS&begin welding seams. 03:00 06:00 3.00 6.00 MOB A 2 P PJSM Work on inner connects&complete seam welding on Herculite.Lay rig mats for Pump#3 and Rockwasher. 06:00 09:00 3.00 9.00 MOB A 2 P PJSM Cont.lay rig mats for Pump#3&Rockwasher.Cont,work on inner connects.Work on berming operations. 09:00 12:00 3.00 12.00 MOB A 2 P PJSM Cont.Berming operations and inner connects.Spot#3 Pump.Work on DS suitcases.Begin sporting Rockwasher. 12:00 18:00 6.00 18.00 MOB A 1 P PJSM Cont.welding Herculite for berming.Spot Rockwasher and rig up.Finish R/U DS suitcases.R/U power to rig shop. Finish R/U service lines to the rig floor.Load Vetco Grey Multi Bowl well head into cellar. 18.00 00.00 6.00 24.00 MOB A 1 P Set mats and Rockwasher suitcases and connect.Load BHA#1 tools in Pipe Shed.Cont.berming around rig.Spot Mud Logger shack and MI Swaco shack and R/U.General housekeeping.Install Diverter line pup.R/U suitcase transfer hose. 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 Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Em representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Em 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 rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test • Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) + 0,7* Eni E&P Division } Well Name::. .102 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUQ • API/UWI:50-629-23531-00-00 2�II II, Date:11/7/2014 - Report#: 3 page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5I26-NW2 DRILLING 11/9/2014 23,989.5 3,613.8 24,061.00 202.75 118.7 -1.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 116.0 5.0 Broken Clouds WC- E @ 9 MPH 10" Daily summary operation 24h Summary Cont.Berming and staging outside Equip.Cont.M/U suitcases on ODS.Install Starter Head.Surface Riser,Annular&Knife valve,Pitcher Nipple and two line sections of Diverter as per Vetco Rep onsite. Test Lower seals and riser seal to 500 PSI for 10 Min.Witnessed by CO Rep.Load and process 5"D.P.into Pipe Shed.SIMOPS Dress all egress areas W/proper grating and material.SIMOPS Test surface Annular Preventer,System Press.2,900 PSI,after 1,650 PSI.18 Sec for Knife valve to open,37 Sec for Annular to close.40 Sec for 200 PSI increase for full charge.5 bottle average Nitrogen 2,350 PSI.Test waived by AOGCC Bob Noble.Welder fabricate Diverter line spool.PJSM Finish N/U BOPE,Flow Line,drain hose,hole fill line and Diverter line spool.Install Mouse Hole and Equip.for picking up D.P.P/U M/U 5"D.P.and rack back in Derrick via Pipe Shed.(110 Jnts) Operation at 07.00 P/U M/U 5"D.P.and rack back in Derrick. 24h Forecast Cont.P/U M/U 5"D.P.from Pipe Shed and eack back in Derrick.Fluid and test Diverter Stack and lines.P/U M/U BHA#1. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 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 MOB A 1 P PJSA Cont.Berming and staging outside Equip.Cont.M/U suitcases on ODS. 02.00 08:00 6.00 8.00 MOB C 5 P PJSM Install Starter Head,Surface Riser,Annular&Knife valve,Pitcher Nipple and two line sections of Diverter as per Vetco Rep onsite.Test Lower seals and riser seal to 500 PSI for 10 Min.Witnessed by CO Rep. y; 08:00 12:00 4.00 12.00 MOB E 20 P PJSMLoad and process 5"D.P.into Pipe Shed.SIMOPS Dress all egress areas W/proper grating and material. 12:00 17:00 5.00 17.00 MOB C 5 P PJSM Cont.loading and prosessing 5"D.P.in Pipe Shed.SIMOPS Test surface Annular Preventer,System Press.2,900 I. , PSI,after 1,650 PSI.18 Sec for Knife valve to open,37 Sec for Annular to close.40 Sec for 200.PSI increase for full ` charge.5 bottle average Nitrogen 2,350 PSI.Test waived by AOGCC Bob Noble.Welder fabricate Diverter line spool. 17:00 20:00 3.00 20.00 MOB C 5 P PJSM Finish N/U BOPE,Flow Line,drain hose,hole fill line and Diverter line spool. 20:00 20:30 0.50 20.50 MOB E 20 P PJSA Install Mouse Hole and Equip.for picking up D.P. 20:30 00:00 3.50 24.00 MOB E 20 P PJSM P/U M/U 5"D.P.and rack back in Derrick via Pipe Shed.(110 Jnts) 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 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 Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling 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(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division Well Name: W2 EN!Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • Date:11/8/2014 - Report#: 4 API/UWI:50-629-23531-00-00 2" "o page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 0.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 116.0 7.0 Clear WC-10° NE @ 13 MPH Daily summary operation 24h Summary P/U M/U 5"D.P.and rack back in Derrick via Pipe Shed.(total 483 Jnts)Pull and L/D Mouse Hole.Clear ng floor of thread protectors.P/U BHA tools and Equip.to rig floor.Prep for Cut and slip.Dummy run 13 3/8"Hanger as per Vetco Grey Rep onsite.Cut and slip dulling line and inspect Brakes.SIMOPS Bring on 8.8 ppg Spud Mud to Pits.P/U rack back 4 stand 5"HWDP,1 stand JARS and 1 stand 8" Flex Collar.P/U M/U 16"Bit.Motor and 1 stand 5"HWDP as per Schlumberger DD Rep onsite.Pre Spud meeting W/all essential personnel.Flood all lines and Conductor,Press.test mud lines to 3,500 PSI,good.Clean out 20"Conductor 160'MD 40 RPM,450 GPM,350 PSI.TRO 1K,WOE 2-6K.Pump out of hole 450 GPM,350 PSI.P/U M/U BHA#2,GYRO,TeleScope,ARC 825,NM UBHO,NM STAB,8"NM FLEX DC as per Schlumberger DD and MWD Rep onsite.SIMOPS Load 56 Jnts 13 3/8"Csg into Pipe Shed. Operation at 07.00 Drill ahead 16"Surface hole to 275'MD. 24h Forecast Cont.P/U M/U BHA#2.Drill ahead to-260'MD.POOH and P/U M/U Jar stand.RIH and Cont.drilling 16"Surface hole. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 11:00 11.00 11.00 DRILL E 20 P PJSM P/U M/U 5"D.P.and rack back in Derrick via Pipe Shed.(Total 483 Jnts) 11:00 12:00 1.00 12.00 DRILL E 20 P PJSA Pull and L/D Mouse Hole.Clear rig floor of thread protectors.Prep for Cut and slip. 12:00 13:00 1.00 13.00 DRILL C 19 P PJSA Dummy run 13 3/8"Hanger as per Vetco Grey Rep onsite. 13:00 14:00 1.00 14.00 DRILL E 25 P PJSA P/U BHA tools and Equip.to ng floor. 14:00 16.00 2.00 16.00 DRILL E 25 P PJSA Cut and slip drilling line and inspect Brakes.SIMOPS Bring on 8.8 ppg Spud Mud to Pits. 16:00 17.30 1.50 17.50 DRILL E 20 P PJSM P/U rack back 4 stand 5"HWDP,1 stand JARS and 1 stand 8"Flex Collar. 17.30 19.00 1.50 19.00 DRILL E 20 P PJSA P/U M/U 16"Bit,Motor and 1 stand 5"HWDP as per Schlumberger DD Rep onsite. 19:00 19:30 0.50 19.50 DRILL E 20 P Pre Spud meeting W/all essential personnel. 19:30 20:00 0.50 20.00 DRILL E 12 P PJSA Flood all lines and Conductor,Press.test mud lines to 3,500 PSI.good. 20:00 21:30 1.50 21.50 DRILL E 3 P PJSA Clean out 20"Conductor 160'MD 40 RPM,450 GPM.350 PSI,TRO 1K,WOB 2-6K.Pump out of hole 450 GPM. 350 PSI. 21:30 00:00 2.50 24.00 DRILL E 20 P PJSA P/U M/U BHA#2,GYRO,TeleScope,ARC 825,NM UBHO,NM STAB,8"NM FLEX DC as per Schlumberger DD and MWD Rep onsite.SIMOPS Load 56 Jnts 13 3/8"Csg into Pipe Shed. 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 Dolling 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 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@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(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) a filit* Eni E&P DivisionWell Name:n. ✓02 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • API/U1NI:50-629-23531-00-00 2 i' Ih�, Date:11/9/2014 - Report#: 5 page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N` Operator EM Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(it) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5I26-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 1.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(`F) Weather Wind 1,373.0 1,334.1 1,373.00 9.60 143.0 112.0 18.0 Partly Cloudy WC 4" E @ 20 MPH Daily summary operation 24h Summary Drill 16"Surface F/160'to 397'MD(397'TVD)612 GPM,750 PSI,Stand back 3 stands 5"HWDP&M/U STAB,8"Collar,1 stand 5"HWDP and Jar stand to complete BHA#2. Drill 16"Surface FI 397' to 1.373'MD(1,337'TVD)643 GPM,1,220 PSI,40 RPM,WOB 16-20K,TON 5-7K,TQF 2-3K,HST 138K,SLK 128K,ROT 132K.ECD 9.68 ppg.Max Gas 29 units.ADT 9.6,ART 3.25,AST 6.35,Bit Hrs 9.6,Jar Hrs 9.6.Monitor well static. Operation at 07.00 Drill ahead 16"Surface hole to 1,720'MD. 24h Forecast Drill 16"Surface F/1,373'to-2,852'MD as per well plan.BROOH as per K&M BROOH schedule. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05.30 5.50 5.50 DRILL E 3 -P PJSM Drill 16"Surface F/160'to 397'MD(397'TVD)612 GPM,750 PSI,40 RPM.WOB 2-15K,TON 2K,TQF 1K,HST 101K,SLK 98K.ROT 100K.Max Gas 4 units.ADT 2.04,ART 1.63,AST.41,Bit Hrs 2.04,Jar Hrs 2.04.Monitor well,static. 05:30 07:30 2.00 7.50 DRILL E '4 P PJSA Stand back 3 stands 5"HWDP&M/U STAB,8"Collar.1 stand 5"HWDP and Jar stand to complete BHA#2. 07:30 12.00 4.50 12.00"DRILL E 3 P PJSM Drill 16"Surface Fl 397'to 624'MD(624'TVD)600 GPM,900 PSI,40 RPM.WOB 2-20K,TON 4K,TOF 2K,HST 130K,SLK 126K,ROT 125K.ECD 9.92 ppg.Max Gas 2 units.ADT 1.54,ART 0.55,AST 0.99,Bit Hrs 3.58,Jar Hrs 3.58. Monitor well,static. 12:00 18:00 6.00 18.00"DRILL E 3 P PJSM Doll 16"Surface F/624'to 968'MD(962'TVD)630 GPM,980 PSI,40 RPM,WOB 18-20K,TON 2-3K,TOF 2K,HST 130K,SLK 128K,ROT 128K.ECD 9.67 ppg.Max Gas 26 units.ADT 2.82,ART 0.28,AST 2.54,Bit Hrs 6.4,Jar Hrs 6.4. Monitor well,static. 18:00 00:00 6.00 24.00"DRILL E 3 P PJSM Drill 16"Surface F/968'to 1,373'MD(1,337'TVD)643 GPM,1,220 PSI,40 RPM,WOB 16-20K,TON 5-7K,TQF 2- 3K,HST 138K,SLK 128K,ROT 132K.ECD 9.68 ppg.Max Gas 29 units.ADT 3.2,ART 0.79,AST 2.41,Bit Hrs 9.6.Jar Hrs 9.6,Monitor well.static. 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 akrigclerksdoyonl5@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 Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division 1/1 Name:b.__.,i/V2EN/PetroleumCo.lnc: Daily Report Well Code:28997 Field Name: NIKAITCHUO 4 APIIUW1:50-629-23531-00-00 2^ Date:11/10/2014 - Report#: 6 II II page 1 of 1 Wellbore name. SI26-NW2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 2.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,846.0 2,452.6 1.473.00 10.37 142.0 113.0 23.0 Partly Cloudy WC 9° S @ 12 MPH Daily summary operation 24h Summary PJSA.Doll 1/1.373'MD to 1,902'MD.(1,796'TVD.)700 GPM,900 PSI,40 RPM,WOB 2-20K,TON 6-8K,TQF 3-5K,HST 150K,SLK 131K,Rot 142K,Max Gas 488 Units,ADT 4.26,ART 1.29,AST 2.97, Bit Hrs 13.86,Jar Hrs 13.86.Monitor well,static.PJSA.Drill(/1,902'MD to 2,309'MD.(TVD 2,120').700 GPM,900 PSI,40 RPM,WOB 2-20,TON 6-7K,TQF 4-6K,HST 155K.SLK 135K,Rot 145K,Max Gas 1,037 Units,ADT 2.35,ART 0.88 AST 1.47,Bit Hrs 16.21,Jar Hrs.16.21.Monitor Well.Static.PJSA.Drill(/2,309'MD to 2.732'MD.(TVD 2,389').810 GPM,1680 PSI,40 RPM,WOB 16-26,TON 5- 7K,TQF 6-8K,HST 160K,SLK 130K,Rot 145K,Max Gas 172 Units,ADT 2.89,TST 1.86 TRT 1.03,Bit Hrs 19.10,Jar Hrs.19.10.Monitor Well,Static.PJSA.Drill 1/2,732'MD to 2,846'MD.(TVD 2,452'). 820 GPM,1900 PSI,40 RPM,WOB 20-25,TON 7-9K,TOE 6-8K,HST 160K,SLK 130K,Rot 145K.Max Gas 75 Units,ADT 0.85,TST 0.26 TRT 0.59,Bit Hrs 19.95,Jar Hrs.19.95.Monitor Well, Static.CBU 2x while racking back 1 std for each F/2,846'MD T/2,651'MD,1,700 psi,6-8k TQ,60 RPM,HST 160K,SLK 130K,ROT 145K.PJSA,BROOH F/2,651'MD T/2,371 MD.850 GPM,1650 PSI,TQF 7-8K,HST 158K,SLK 132K,ROT 145K. Operation at 07.00 Continue to BROOH @ 1.265'MD. 24h Forecast Continue BROOH.L/D BHA#2.R/U GBR casing equipment.RIH 13 3/8"L-80 68#BTC Casing as per program. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib(gal) 9.15 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(/1,373'MD to 1,902'MD.(1,796'TVD.)700 GPM,900 PSI,40 RPM,WOB 2-20K,TON 6-8K,TOE 3-5K,HST 150K,SLK 131K Rot 142K,Max Gas 488 Units,ADT 4.26,ART 1.29.AST 2.97.Bit Hrs 13.86.Jar Hrs 13.86.Monitor well, static. 06.00 12:00 - 6.00- 12.00 DRILL -E 3 P PJSA.Drill f/1,902'MD to 2,309'MD.(TVD 2,120').700 GPM,900 PSI,40 RPM.WOB 2-20,TON 6-7K,TQF 4-6K,HST 155K,SLK 135K,Rot 145K,Max Gas 1,037 Units,ADT 2.35.ART 0.88 AST 1.47,Bit Hrs 16.21,Jar Hrs.16.21.Monitor Well,Static. 12.00 18.00 ' 6.00' 18.00 DRILL E 3 P •PJSA.Drill(/2,309'MD to 2,732'MD.(TVD 2,389').810 GPM,1680 PSI,40 RPM,WOB 16-26,TON 5-7K,TQF 6-8K.HST 160K,SLK 130K,Rot 145K,Max Gas 172 Units,ADT 2.89,TST 1.86 TRT 1.03,Bit Hrs 19.10,Jar Hrs.19.10.Monitor Well, Static. 18.00 20:00 ' 2.00 20.00 DRILL 'E 3 P PJSA.Drill(/2,732'MD to 2,846'MD.(TVD 2,452').820 GPM,1900 PSI,40 RPM,WOB 20-25,TON 7-9K.TOE 6-8K,HST 160K,SLK 130K,Rot 145K,Max Gas 75 Units.ADT 0.85,TST 0.26 TRT 0.59,Bit Hrs 19.95,Jar Hrs.19.95.Monitor Well, Static. 20:00 '20:30 0.50 20.50 DRILL E 11 P PJSM,Monitor well static.MWD survey @ 2,846'. 20:30 21:30 1.00 21.50 DRILL •E 7 P CBU 2x while racking back 1 std for each F/2,846'MD T/2,651'MD,1,700 psi.6-8k TO,60 RPM,HST 160K,SLK 130K, ROT 145K. 21:30 00:00 2.50 24.00 DRILL E 4 P PJSA,BROOH F/2,651'MD T/2,371'MD.850 GPM,1650 PSI,TQF 7-8K,HST 156K,SLK 132K,ROT 145K. 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 Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 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 HOE 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 ng15@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(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib(gal) Leak Off Pressure(psi) Ili* Eni E&P Division Well Name:a. N2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • Date:11/11/2014 - Report#: 7 API/UWI:50-629-23531-00-00 2" "o page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 3.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,846.0 2,452.6 0.00 117.0 24.0 Partly Cloudy WC NE @ 20 MPH 11° Daily summary operation 24h Summary PJSA.Clean and clear rig floor of all BHA tools and equipment.PJSA.Change out normal bails for long bails.Rig up Volant tool and all other equipment for running casing as per GBR casing.PJSM.Pick up 13 3/8"shoe track and float assy.Check floats(all good).RIH w/13 3/8"casing to 812'.PU=100K SO=.100K.Filling casing every 10 jts.(13 ffs).PJSA.Continue RIH w/13 3/8"casinjg as per detail 1/812'to 2,593'MD.HST=235K SLK=175K while RIH.Cal=57 bbls.Actual=53 bbls.Loss=4 bbls. Operation at 07.00 Circulating and preparing to cement 13 3/8"casing. 24h Forecast RIH 13 3/8"casing as per plan.Circulate hole.Cement 13 3/8"casing as per cementing plan.N/U BOPE and test same. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 DRILL E 4 P PJSM.Continue BROOH F/2,371'MD to 691'MD.TOF=2K,HST=122K,SLK=123K,ROT=125K. 06,30 08,00 1.50 8.00 DRILL E 4 P PJSA.POOH on elevators with HWDP Stds and rack back F/691'MD to 225'MD.HST=105K,SLK=109K. 08:00 08:30 0.50 8.50 DRILL E 20 P PJSA.Monitor well(Static)and service rig. 08:30 12:00 3.50 12.00 DRILL E 20 P PJSM.L/D BHA#2 as per SLB DD 8 MWD F/225'MD to o'MD. 12:00 13:00 1.00 13.00 DRILL E 20 P PJSA.Clean and Gear rig floor of all BHA tools and equipment. 13:00 15:30 2.50 15.50 DRILL E 20 P PJSA.Change out normal bails for long bails.Rig up Volant tool and all other equipment for running casing as per GBR casing. 1530 18.00 2.50 18.00 DRILL G 4 P PJSM.Pick-ug.13 3/81s)rgg_JraGk ang foat,assy..Chgokfloats.(all good).RIH 413 3/8"casing to 812'.PU=100K 50=.100K.Filling casing every 10 jts.(13 ffs).. 18:00 00.00 6.00 24.00 DRILL G 4 P PJSA.Continue RIH w/13 3/8"casinjg as per detail 1/812'to 2.593'MD.HST=235K SLK=175K while RIH.Cal=57 bbls. Actual=53 bbls.Loss=4 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Davide Simeone ENI Project Manager Eni representative Corrdado Leali ENI Dulling Eni representative Antonio Galletta ENI Drilling Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 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@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(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division Well Name: i12 1118* ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ •2Date:11/12/2014 - Report#: 8 APIIUWI:50-629-23531-00-00 m� �l II page 1 of 1 Wellbore name: S126-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5126-NW2 DRILLING 11/9!2014 23,989.5 3.613.8 24,061.00 202.75 118.7 4.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,846.0 2,452.6 0.00 111.0 21.0 Mostly Cloudy WC SW @ 9 MPH 11" Daily summary operation 24h Summary Cont.RIH 13 318"casing F/2,593'T/2,834'MD,Land casing.Cement 13 3/8"casing.R/D casing 8 cement equipment.flush stack,N/D surface stack,install multi bowl,test,N/LI BOPE,R/U to test BOPE. Operation at 07.00 Testing ROPE 24h Forecast Rig Maintenance,Test BOPE.Change shot Pin Assembly on Top Drive,P/U M/U BHA#3,RIH test 13 3/8 casing,drill out shoe track perform LOT/FIT,drill 12 1/4"hole section as per well plan Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 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 G 4 'P PJSM.Cont.RIH W/13 3/8"Casing F/2,593'T/2,792'MD,HST=260 K,SLK=180K.Displacement this tour 10 bbls W/no losses. 01:00 01:30 0.50 1.50 DRILL G 4 P PJSM,Land 13 3/8"Casing on hanger 8 - establish circulation y�i!IIll c 01:30 04:00 2.50 4.00 DRILL H 7 P PJSM.Circ 8 Condition Mud for cementing,W/ICP=60 psi @ 1.5 BPM.FCP=80 PSI @ 5 BPM G_41'4 0 04:00 04:30 0.50 4.50 DRILL H 1 P PJSM.R/U for cementing,blow do top drive&break circ.thru cement hose. 04:30 06:30 2.00 6.50 DRILL H 7 P PJSM.Cont to circ and condition mud,5 BPM @ 150 PSI (v 06:30 11:00 4.50 11.00 DRILL H 9 P PJSM,Blow air thru cement line 8 Fluid pack,Test lines 1,000/3,500 psi(good test),pump 100 bbls 10.1 spacer,drop C,N `.i bottom plug&cement W/440 bbls of 10.7 ppg lead slurry followed by 63 bbls of 12.5 ppg tail stony.Drop top plug 8 kick out W/10 bbls H2O 8 displace W/402 bbls with rig.Bump plug WI FCP=500 psi 8 pressure to 1,000 psi hold for 5 min. .. perform float check(successful).complete cement job,charted and witnessed by Company reps.CIP @ 11:00 total returns 'i 1 to surface 96 bbls. 11:00 1230 1.50 12.50 DRILL H 5 "P PJSM,R/D Cementing equipment,break out volant 8 prep for laying do landing int.drain stack and flush W/black water. L/D landing jnt 12:30 14:00 1.50 14.00 DRILL Change out bails,install bell guide,R/D Volant tool as per GBR 14:00 14:30 - 0.50 14.50 DRILL M 1 P PJSM,R/U Johnny Wacker surface riser and annular preventor 14:30 15:00 0.50 15.00 DRILL M 1 P Remove casing running equipment from rig floor. 15:00 16:30 1.50 16.50 DRILL C 5 P PJSM,N/D surface stack,riser,&pitcher nipple 16:30 18:30 2.00 18.50 DRILL C 5 P Remove staying head.dress 13 3/8"hanger,install multi bowl and test to 2,000 psi F/10 min.(good test).as per Vetco Rep. 18:30 23:00 4,50 23,00 DRILL C 5 P Nipple up BOPE and riser. 23:00 00.00 1.00 24.00 DRILL C 5 P R/U BOP test equipment 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 Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dolling 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(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division WelI Name: ✓42 fil* ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO • API/UWI:50-629-23531-00-00 2^" Date:11/13/2014 - Report#: 9 II page 1 of 1 Wellbore name: SI26-NW2 Well Header PermitConcession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72- 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 5.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,846.0 2,452.6 0.00 111.0 17.0 Partly Cloudy WC 4° WSW @ 13 MPH Daily summary operation 24h Summary C/O Saver sub,Perform BOPE Test,AOGCC Lou Grimaldi waiver witness to BOP Test, Change out shot pin ass.,P/U M/U BHA#3,RIH perform shallow hole test,RIH tag cement @ 2,744'MD,Circ& condition mud for csg test. Operation at 07.00 Drilling out shoe track 24h Forecast Perform csg test,drill out shoe track&20'new hole.Displace mud W/LSND,perform LOT/FIT,Drill 12 1/4"hole section as per plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 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 E 20 P PJSM.Change out saver sub due to normal wear and change pipe grabber dies. 02:00 0300 1.00 3.00 DRILL C 12 P Fill BOPE&Choke perform body test,unsuccessful, break out connection replace ring&reassemble,PT BOPE&Choike 250/2500,test successful. 03:00 10'00 7.00 10.00 DRILL C 12 P PJSM Ta�OPE.211 choke 981985 1-54 8 kill line demos to 250/3500 psi W/5"test jnt.test upper&lower pipe rams. 1✓ l blind rams 250/3500Test choke and kill HCR's&manuel valves manuel,Test all floor valves 250/300,Test upper and lower IBOP's 250/3500,test manual choke and super choke to 1500 psi,Perform koomey test.before,sys=2800,Man 1400,ann=800 after,sys 1500,man=1475,ann=800 200 psi increase=53 sec.W/full charge=204 sec.5 bottle avg=2400 psi BOPE TEST AOGCC Lou Grimaldi Waived Witness to Test. 1000 10.30 0.50 10.50 DRILL C 1 P PJSM.R/D&Blow Dn test equipment,lubricate top drive upper and lower(BOPS,Blow dn.choke&kill lines 10:30 11:00 0.50 11.00 DRILL C 5 P PJSM.Remove test plug&set wear ring W/Vetco on site,OD 13.438 ID 12.31.length 53.31 lock down screws run in. 11:00 12:00 1.00 12.00 DRILL E 25 P PJSM.Power wash Shot Pin&RLA area for shot pin replacement. 1200 15:30 3.50 15.50 DRILL E 25 P Change out shot pin assembly on top drive. 15:30 16:30 1.00 16.50 DRILL E 25 P Service drawworks.top drive,blocks,ST-80 16:30 1700 0.50 17.00 DRILL E 1 P P/U BHA#3 tools and equipment to dg floor. 17:00 18.00 100 18.00 DRILL E 1 P PJSM,Lay down 3 stands 5"HWDP&1 collar stand 18:00 2100 3.00 21.00 DRILL E 1 P P/U M/U BHA#3,as per SLB DD&MWD F/0;MD T/350'MD HST=100K,SLK=102K 21,00 22.00 1.00 22.00 DRILL E 4 P RIH F/350'MDT/1500'MD HST=I3SK SLK=110K 22:00 22:30 0.50 22.50 DRILL E 12 P Perform shallow hole test as per SLB DD&MWD,(Successful)800 psi 750 GPM 22:30 23:00 0.50 23.00 DRILL E 4 P PJSM.RIH F/1500'MD T/2591'MD.HST=155K,SLK=125K,fill pipe and wash do F/2591'MD T/2744'MD&tag cement. RPM 20 GPM=280 PSI=230 23:00 00:00 1.00 24.00 DRILL E 7 P PJSM,Circ&condition mud for csg test GPM=720 PSI=1000 TOF=4-6 K HST=155K SLK=125K Pumped 3500 stks. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnIIing@enipetroleum.com 907-685-0715 715-6434 Eni representative Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling 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 Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2.833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) • 119* Eni E&P Division Well Name: W2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • API/UWI:50-629-23531-00-00 2�, Date:11/14/2014 - Report#: 10 'I I) page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI26-NW2 DRILLING 11/9/2014 23.989.5 3.613.8 24,061.00 202.75 118.7 6.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,900.0 2,682.5 1,054.00 3,06 344.4 110.0 20.0 Partly Cloudy WC 7° E @ 13 MPH Daily summary operation 24h Summary Perform casing test to 2,500 psi for 1/2 hr.Trouble shoot upper IBOP cam rollers.Perform a stripping doll with dart and TIW valve.TIH and tag Float @2747'.drill out shoe track and 20'of new hole. Displace spud mud with LSND mud.Perform a LOT 12.4 EMW.Drill from 2,865'to 3,900'MD. Operation at 07.00 Drilling ahead @ 4,440'MD. 24h Forecast Drill ahead in 12 1/4"intermediate hole as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.25 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 1 P PJSM.Blow dn TD,R/U for casing test. 00:30 01:30 1.00 1.50 DRILL E 12 P PJSM,POOH F/2744'MD T/2680'MD,perform csg.test to 2,500 psi for 30 min.(successsful)Test charted 8 witness by company rep.37 strokes/3.8 bbls bleed back 01:30 02:00 0.50 2.00 DRILL E 20 P PJSM.Blow dn kill line 8 rig down test equipment. 02:00 02:30 0.50 2.50 DRILL E 25 P PJSM.Trouble shoot IBOP cam rollers 02:30 04:30 2,00 4.50 DRILL E 20 P PJSM.POOH F/2680'MD T/2398'MD,M/U TIW 8 Dart Valve,perform stripping drill W/all hands,Blow dn choke line topdrive,choke manifold,R/D TIW 8 dart Valves 04:30 05:00 0.50 5.00 DRILL E 4 P PJSM,TIH F/2398'T/2744'MD PU=155 K,S0=125 K. 05:00 06:00 3.00 8.00 DRILL E 3 P -PJSM,Tag float @ 2,747 MD Drill out float equipment and 20'new hole T/2,866'MD As per SLB DD,PU=156 K S0=130 K ROT=138 K.TQ=5-20 K.RPM=80,GPM=700,PSI=900. 08:00 09:30 1,50 9.50 DRILL E 7 P PJSM,Displace well F/Spud mud T/LSND,pumped 47 bbls viscosified water chased by new LSND mud.ICP=320 @ 9 bpm,FCP=500 @ 13 bpm 09:30 11:00 1.50 11.00 DRILL E 25 P PJSM Cut 8 Slip Drill Line,inspect brakes.(25') 11:00 12:00 1.00 12.00 DRILL E 12 P PJSM,CBU,Rig up perform LOT/FIT,R/D B/D all eg9ipsien/L12,4.AAD..1 Q.71_Charted.1.8 bbls pumped 1 bbl bleed back. SPR-MP#1)30-40 40-90,MP#2)30-40 40-90 MP#3 30-40 40-70 @ 2,762'MD,HRS=0530 W/9.2 PPG MW W/44 Vis 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA.Dig.1/2,866'to 3.148'MD(2,582'TVD)@700 gpm,780 psi,80 rpm,6-8k wob,6-7k tqn,4k tgf,142k puw.129k sow, 137 rotw,9.64 ECD,Max Gas 86,2.84 ADT,bit 2.84h,jar 2.84h.Monitor well,static. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSM,Dulling F/3,148'MD T/3,900'MD TVD=2,682,TON=7-9 K,TOF=5-6 K,HST=140 K,SLK=112 K,ROT=128 K, ECD's=9.8 PPG,MW=9.25 PPG,Max Gas=107 units„ADT 3.06,Bit Hours=5.9,Jars hrs=25.85,Monitor Well Static. SPR MP#1 30 SPM 110 PSI,40 SPM 140 PSI,MP#2 30 SPM 110 PSI,40 SPM 140 PSI,MP#3 30 SPM 100 PSI.40 SPM 130 PSI@ MD=3,802'TVD=2,683'Hrs=23:00 W/9.25 PPG Mud W/47 Viscosity.Tour loss=0 bbls 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 Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Em representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher sg15@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(ftKB) Bottom(ftKB) Run Date CASING 133/8 12,415 L-80 0.0 2,833,7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9,20 410,0 12.40 1,587.1 � Eni E&P Division Well Name:..__�aW2 ! ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • Date:11/15/2014 - Report#: 11 APIIUWI:50-629-23531-00-00 e i io page 1 of 1 Wellbore name: S126-NW2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI26-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 7.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6..009.0 2,706.8 2.109.00 9.35 225.6 111.0 14.0 Clear WC 2' W @ 9 MPH Daily summary operation 24h Summary Drill from 3.900'to 6,009'MD. Operation at 07.00 Drilling ahead @ 6,063'MD. 24h Forecast Drill ahead in 12 1/4"intermediate hole as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.25 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.Drilling.f/3,900'to 4.795'MD,2,694'TVD @900 gpm,1470 psi,160 rpm,4-10k wob,7-9k tqn,4k tgf,140k puw, 115k sow,128 rotw,9.94 ECD,9.25 MW,Max Gas 131,3.68 ADT,bit 9.58h,jar 29.53h.Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA.Drilling.f/4,795'to 5.109'MD,2,699'TVD @900 gpm,1490 psi,160/200 rpm,8-18k wob,8-13k tqn,4-6k tqf,145k puw,110k sow,128 rotw,9.73 ECD,9.2 MW,Max Gas 65,4.41 ADT,bit 13.99h,jar 33.94h.Monitor well,static. SPR MP#1 30 SPM 140 PSI,40 SPM 170 PSI,MP#2 30 SPM 140 PSI,40 SPM 170 PSI,MP#3 30 SPM 130 PSI,40 SPM 150 PSI@ MD=4,828'TVD=2,695'Hrs=06:00 W/9.2 PPG Mud W/47 Viscosity.Tour loss=0 bbls 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA.Drilling.f/5,109'to 5,855'MD,2,706'TVD @900 gpm,1680 psi,160 rpm,8-10k wob,9-10k tqn,5-6k tqf,150k puw, 108k sow,130 rotw,10.1 ECD,9.25 MW,Max Gas 58,4.19 ADT,bit 18.18h,jar 38.13h.Monitor well,static. 18.00 00.00 6.00 24.00 DRILL E 3 P PJSA.Drilling.f/5,855'to 6,009'MD,2,705'TVD @900 gpm,1700 psi,160/180 rpm,10-18k wob,10k tqn,4-5k tqf,150k puw,112k sow,130 rotw,9.87 ECD,9.25 MW,Max Gas 27,4.94 ADT,bit 23.12h.jar 43.07h.Monitor well,static. SPR MP#1 30 SPM 180 PSI,40 SPM 220 PSI,MP#2 30 SPM 180 PSI,40 SPM 220 PSI,MP#3 30 SPM 160 PSI,40 SPM 180 PSI@ MD=5.855'TVD=2.706'Hrs=18:00 W/9.25 PPG Mud W/51 Viscosity.Tour loss=0 bbls Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener EM Senior Drilling Supv SIDDrilling@enipetroleum.com '907-685-0715 .715-6434 Eni representative Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 Eni representative Vance Dale ENI Mats Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng15@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(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.866.0 2,463.05 LSND 9.20 410.0 12.40 1.587.1 Eni E&P Division .. Well Name: JJ2 fill* ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUQ • 2^,t Date:11/16/2014 - Report#: 12 ii APIIUWI 50-629-23531 -00 II II page 1 of 1 Wellbore name: SI26-NW2 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 8.00 Daily Information End Depth(ftKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,491.0 2,724.5 462.00 20.41 23.6 109.0 24.0 Overcast WC 12" NE @ 13 MPH Daily summary operation 24h Summary Drill from 6.009'to 6,491'MD. Operation at 07.00 Drilling ahead @ 6,497'MD. 24h Forecast Drill ahead in 12 1/4"intermediate hole as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 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.Drilling.1/6,009'to 6.215'MD,2,708'ND @900 gpm,1720 psi,80-200 rpm,8-28k wob,10k tqn,5-9k tgf,152k puw, 105k sow,128 rotw,9.93 ECD,9.25 MW,Max Gas 38,5.47 ADT,bit 28.59h,jar 48.54h.Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA.Drilling.(/6,215'to 6.264'MD,2,711'TVD @900 gpm,1760 psi,120/180 rpm,10-26k wob,10k tqn,5-6k tgf.152k puw,105k sow,128 rotw,9.89 ECD,9.25 MW,Max Gas 11,4.97 ADT,bit 33.56h,jar 53.51 h.Monitor well,static. SPR MP#1 30 SPM 140 PSI,40 SPM 180 PSI,MP#2 30 SPM 140 PSI,40 SPM 180 PSI,MP#3 30 SPM 120 PSI,40 SPM 160 PSI@ MD=6,263'TVD=2,711'Hrs=11:10 W/9.25 PPG Mud W/53 Viscosity.Tour loss=0 bbls 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA.Drilling.56,264'to 6,415'MD,2,717'ND @900 gpm,1770 psi,140-180 rpm,10-26k wob,8k tqn,5-7k tgf,165k puw,na sow,131 rotw,9.84 ECD,9.2 MW,Max Gas 10,5.25 ADT,bit 38.81h,jar 58.76h.Monitor well,static. 18:00 00:00 ' 6.00 24.00 DRILL E 3 P PJSA.Drilling.56,415'to 6,491'MD,2,72'ND @900 gpm,1830 psi,140/200 rpm,20-28k wob,9-11k tqn,5-6k tgf,156k puw,102k sow,102 rotw,9.79 ECD,9.2 MW,Max Gas 5,4.72 ADT,bit 43.53h,jar 63.48h.Monitor well,static. SPR MP#1 30 SPM 140 PSI,40 SPM 180 PSI,MP#2 30 SPM 140 PSI,40 SPM 180 PSI,MP#3 30 SPM 120 PSI,40 SPM 160 PSI@ MD=6,489'ND=2,722'Hrs=11:00 W/9.2 PPG Mud W/51 Viscosity.Tour loss=0 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 Giuseppe Maugeri ENI Engineer giuseppe.maugeri@enipetroleum.com 907-865-3328 907-947-9110 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HOE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 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(ftKB) Bottom(11KB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 Eni E&P Division Well Name: W2 IP* ENI Petroleum Co.Inc. Daily Repol l} Well Code:28997 Field Name:NIKAITCHUO • Date:1111712014 - Report#: 13 API/OWI:50-629-23531-00-00 2 rr rr ii page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 9.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,526.0 2,726.4 35.00 13.65 2.6 112.0 20.0 Scattered Clouds WC E @ 21 MPH 4" Daily summary operation 24h Summary Ng.f/6491'-6526'MD(2725'TVD).Pump out of hole to 6045'.Pump dry job and POOH to 5484'.Encounter over pull.CBU and BROOH to 5391'.BROOH to 3528'losing fluid.RIH to 3618'and circulating while adding Safe Carb 250. Operation at 07.00 Monitoring well,Static losses 56 bbl per hour 24h Forecast RIH to 4465'and circulating @ 150 gpm with SC 250.Establish well to no/low losses and pump out to 3528'.BROOH to casing shoe and perform cleanup cycle.POOH and C/O BHA, Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P PJSA DrIg.f/6491'-6502'MD(2724'TVD)@ 900 gpm,1770 psi,120-200 rpm,20-30k wob,10k tqn,5-7k tqf,152k puw, 102k sow,130k rotw,9,79k ECD,Max Gas 4,6.0 ADT,49.53 Bit,69.48 Jars, 06.00 12:00 6.00 12.00 DRILL E 3 P PJSA Ddg.f/6502'-6518'MD(2725'TVD)@ 900 gpm,1770 psi,40-200 rpm,5-40k wob.4-18k tqn,7k tqf,152k puw, 102k sow,130k rotw,9.77 ECD,Max Gas 3,3.81 ADT,53.34 Bit,73.29 Jars.73 bbls Touny fluid losses.SPR @ 6517'MD (2725'TVD)w/9.25 MW,#1/#2 @30-140.@40-180;#3@30-120,@40-160. 12.00 16:00 4.00 16.00 DRILL E 3 P PJSA Ddg.1/6516'-6526'MD(2725'TVD)@ 900 gpm,1830 psi,140-200 rpm,20-38k wob,9-10k tqn,5k tqf.162k pow. 105k sow,131k rotw,9.73 ECD,Max Gas 11,3.84 ADT.57.18 Bit,77.13 Jars.Do to low ROP.vibrations @ hi rpm and observing stick/slip tendancies,a decision was made to POOH and check our BHA. 16:00 17:00 1.00 17.00 DRILL E 4 U PJSA Monitor well.Pump out of hole f/6526'-6045'@ 400 gpm,500 psi,150k puw,115k sow. 17:00 18:30 1.50 18.50 DRILL E 4 U PJSA Pump Dry job and POOH on elevators f/6045'-5484',150k puw,115k sow.Encounter over pull. 18:30 23:30 - 5.00- 23.50 DRILL E 4 U PJSA CBU while BROOH 1 stand to 5391'.BROOH f/5391'-3528'@ 800 gpm,1420 psi,100 rpm,10k tq,145k puw,120k sow,130k rotw.Note;Started losing fluid 1/4200'-3700'with increasing losses. 23:30 00.00 0.50 24.00 DRILL E 4 U PJSA RIH to 3618'while circulating and adding Safe Carb 250.Still losing fluid,306 bbls Tourly fluid losses. Daily Contacts a 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 Vance Dale ENI Mails Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher i 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(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2.866.0 2,463.05 LSND 9.20 410.0 12.40 1,587,1 ° A. .a" Eni E&P Division Well Name: V2 ENI Petroleum Co.Inc. Daily Repo 1..t Well Code:28997 Field Name: NIKAITCHUO • Date:11/18/2014 - Report#: 14 APIIUWI:50-629-23531-00-00 2" " page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) 5126-NW2 DRILLING 11/9/2014 23,989.5 3,613.8 24,061.00 202.75 118.7 10.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,526.0 2,726.4 0.00 108.0 22.0 Overcast WC 6` ENE @ 22 MPH Daily summary operation 24h Summary RIH to 4549'circ.while adding Safe Carb 250.Mix and spot 50 BBLS of 30#/bbl LCM pill.Monitor well to 4.5 BPH losses.Pump 50 bbls down string and monitor well @ 1 bph losses.Circulate and stage pumps to 700 gpm.Minimal losses.BROOH w/900 gpm,120 rpm to 1750'.POOH to 1564'then LDDP with worn tool jts.LD BHA#3 and load off rig.Ready BHA#4 and strap and tally new BHA and DP. Operation at 07.00 P/U M/U 5"DP,RIH W/BHA#4 to 564'MD 24h Forecast M/U BHA#4 and RIH WI new DP to 2000'and perform shallow hole test.Cont.to RIH and set drilling parameters slowly to avoid loss circulation.Work to bottom and drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 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 4 U PJSA RIH f/3618'-4549',142k puw,110k sow. 00:30 02:30 2.00 2.50 DRILL E 7 U PJSA Circulate @ 160 gpm,140 psi 30 rpm 6k tq while adding Safe Carb 250.225 BPH losses. 02:30 03:00 0.50 3.00 DRILL E 7 U PJSA Mix and spot 50 bbl LCM pill(#10-mix med.108-mixt med,108-nut plug med/bbl). 03:00 04:30 1.50 4.50 DRILL E 7 U PJSA Blow down top-drive.Monitor well and fill hole @ 15 min-14 bbls,30 min-4.5 bbls.Pump 50 bbls down drill string @ 160 gpm,270 psi.Monitor well @ 1 BPH losses. 04:30 06:00 1.50 6.00 DRILL E 7 U PJSA Circulate and stage flow rate f/84 gym to 700 gpm,1180 psi.26 BPH losses. 06:00 09:00 3.00 9.00 DRILL E 4 U PJSA BROOH f/4549'-3431',700 gpm,1035 psi,40 rpm,5k tq,9.78 ECD. 09:00 09:30 0.50 9.50 DRILL E 7 U PJSA CBU @ 700 gpm,1010 psi,40 rpm,3.5k tq,9.68 ECD. 09:30 12:00 2.50 12.00 DRILL E 4 U PJSA BROOH f/3431'-3151'900 gpm.1530 psi,120 rpm,5k tq,9.87 ECD,152k puw,119k sow,139k rotw.3 bbls losses. 1083 bbls Tourly fluid losses. 12:00 15:00 3.00 15.00 DRILL E 4 U PJSA BROOH f/3151'-1750'@ 900 gpm,1340 psi,80-100 rpm,3k tq,130k puw,115k sow,125k rotw. 15:00 1530 0.50 15.50 DRILL E 4 U PJSA Blow down top-drive.POOH f/1750'-1564'128k puw,112k sow. 15:30 17.30 2.00 17.50 DRILL E 4 U PJSA POOH and L/D DP do to tool joint wear,5 1564'-350'. 17:30 20:00 2.50 20.00 DRILL E 4 U PJSA UD BHA#3 as per SLB. v 20:00 21:30 1.50 21.50 DRILL E 20 U PJSA Clear and clean rig floor from BHA#3.Load BHA#4 to rig floor. 2130 00:00 2.50 24.00 DRILL E 20 U PJSA Remove worn BHA and pipe from pipe shed.Load Drill pipe and BHA to shed,strap and tally.Service dg.10 bbls Tourly fluid losses. 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 Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 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(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth)ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,866.0 2463.05 LSND 9.20 410.0 12.40 1,587.1 Eni E&P Division } Well Name:. W2 EN!Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUO • Date:11/19/2014 - Report#: 15 APIIUWI:50 629-23531-00-00 2" "o page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3,613,8 24,061.00 202.75 118.7 11.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,042.0 2,746.6 515.00 3.47 148.4 102.0 19.0 Blowing Snow WC- E @ 40 MPH Gust 1° to 52 MPH Daily summary operation 24h Summary Process DP in pipe shed.M/U BHA#4 and pick up DP and RIH to 1560'.SHT @ 700 gpm.870 psi.RIH replacing washed DP to 2773'.Circ.and bring rate to 900 gym.1440 psi w/no losses.Wash thru casing shoe w/10k drag and RIH replacing DP as needed(79 jts total)to 5018'.No SOW,ream in hole f/5018'-6527'and clean bottom of hole.Dug.ahead f/6527'-7042'MD(2745'TVD). Operation at 07.00 Drilling ahead @ 7,700'and 24h Forecast Drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 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 20 U PJSA Load 80 jts 5"DP to shed and process. 01:00 03:30 2.50 3.50 DRILL E 4 U PJSA M/U BHA#4 as per SLB and RIH to 349'.100k puw/sow. 03:30 04:30 1.00 4.50 DRILL E 4 U PJSA P/U&M/U 5"DP singles(39 total)f/pipe shed and RIH f/349'-1560'.125k puw,120k sow. 04:30 05:00 0.50 5.00 DRILL E '12 U PJSA Perform shallow hole test @ 700 gpm.870 psi.Blow down top-drive. 05:00 08:00 3.00 8.00 DRILL E 4 U PJSA RIH t/1560'-2773'w/DP from derrick replacing washed out jts.as needed.140k puw,130k sow. 08:00 08:30 0.50 8.50 DRILL E 7 U PJSA Circulate @ casing shoe 700 qpm-960 psi,800 gpm,1190 psi,900 gpm-1440 psi.No Losses. 08:30 12:00 3.50 12.00 DRILL E 4 U PJSA RIH replacing washed DP(Grand total of 75 jts)f/2773'-3520'.Wash BHA through shoe @ 650 gpm,870 psi,lOk drag.SLB shoot surveys @ 3100'and 3500'.140k puw,120k sow.10 bbls Tourly fluid losses. 12:00 14.00 2.00 14.00 DRILL E 4 U PJSA RIH f/3520'-5018',140k puw,N/A sow.Replaced 4 jts.of 5"DP. -. 14:00 18.00 4.00 18.00 DRILL E 6 U PJSA Begin reaming,no slack off weight,f/5018'-6527'@ 900 gpm,1830 psi,80-150 rpm,2-6 wob,5-10k tq,160k puw, 128k rotw. 18.00 18.30 0.50 18.50 DRILL E 6 U PJSA Work BHA f/6527'-6515'to clean bottom of hole @ 900 gpm,1830 psi,150 rpm.8-10k tq. 18.30 00.00 5.50 24.00 DRILL E 3 P PJSA Ddg.f/6527'-7042'MD(2745'TVD)@ 900 gpm,1930 psi,160 rpm,2-10k wab,8k tqn,6k tqf,149k puw,100k sow,129k rotw,10.02 ECD,Max Gas 37,3.47 ADT/Bit/Jars.41 bbls Toury fluid losses.SPR @ 6695'MD(2740'TVD) W/9.25 MW;#1/#2 @ 30-190,@ 40-240,#3 @ 30-200,@ 40-240. 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 Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling I Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.866.0 2,463.05 LSND 9.20 410.0 12.40 1.587.1 liti* Eni E&P DivisionWell Name:. r V2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • Date:11/20/2014 - Report#: 16 APIIUWI:50-629-23531-00-00 ( l " page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(it) ,RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 12.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) FOB Temperature(°F) Weather Wind 9,252.0 2,792.5 2,210.00 12.76 172.9 102.0 19.0 Blowing Snow WC- ENE @ 45 MPH WI 3° Gust to 58 MPH Daily summary operation 24h Summary DrIg.f/7042'-8376'MD.Shut down operations because of winds and no emergency rescue(6 hrs.Total).Ddg f/8376'-9252'. Operation at 07.00 Drilling ahead @ 9,500'and 24h Forecast Drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 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 Ddg.f/7042'-8003'MD(2765'TVD)@ 900 gpm.2020 psi,160 rpm,3-10k wob,10k tqn.7k tqf,155k puw,98k sow, 129k rotw.10.08 ECD.Max Gas 32,3.92 ADT,7.39 Bit/Jars.SPR @ 7723'MD(2760'TVD)w/9.2 MW;#1/#2 @ 30- 200,@ 40-250.#3 @ 30-190.@ 40-230. 06:00 09:00 3.00 9.00 DRILL E 3 P PJSA Ddg.f/8003'-8376'MD(2774'TVD)@ 900 gpm,2060 psi,160-180 rpm,10k wob,10k tqn,6k tqf,152k puw,100k sow.130k rotw,10.06 ECD,Max Gas 29,2.49 ADT,9.88 Bit/Jars.Monitor well-static. 09:00 12:00 3.00 12.00 DRILL E 22 TWO1 PJSA Wait On Weather while circulating @ 900 gpm,2060 psi,160 rpm,6k lq.123 bbls Toady fluid losses. 12:00 15:00 3.00 15.00 DRILL E 22 TWO1 Cont.to WOW while circulating and reciprocating. 15:00 18:00 3.00 18.00 DRILL E 3 P PJSA DrIg.f/8376'-8743'MD(2782'TVD)@ 900 gpm,2120 psi,160 rpm,4-10k mob,10k tqn.7-8k tqf,153k puw,101k sow,129k rotw,10.19 ECD.Max Gas 26,2.18 ADT,12.06 Bit/Jars.SPR @ 8376'MD(2774'TVD)wl 9.25 MW;#1/#2 @ 30-200.@ 40-280,#3 @ 30-190,@ 40-220. 18.00 00:00 6.00 24.00 DRILL E 3 P PJSA Ddg.fl 8743'-9252'MD(2791'TVD)@ 900 gpm,2180 psi,160 rpm,4-10k wob.6-10k tqn.6-7k tqf,153k puw. 102k sow,130k rotw,10.18 ECD.Max Gas 24,4.19 ADT,16.25 Bit/Jars.Monitor well-static.59 bbls Tourly fluid losses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 ° Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-60 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 fff#1 Eni E&P Division Well Name:C. /2 j ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ � APIIUWI:50-629-23531-00-00 2^ Date:11/21/2014 - Report#: 17 II IIii page 1 of 1 Wellbore name: SI26-NW2 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(Mr) DFS(days) 5126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 13.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..1Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 11,529.0 2,849.5 2,277.00 19.13 119.0 102.0 18.0 Mostly Cear WC 1' E @ 33 MPH WI Gust to 50 MPH Daily summary operation 24h Summary Ddg.f/9252'-11,529'MD(2847'TVD). Operation at 07.00 Drilling ahead @ 12,016'MD 24h Forecast Drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 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 Ddg.f/9252'-9708'MD(2806'TVD)@ 900 gpm,2340 psi,160-180 rpm,10k web,10-13k tqn,9k tqf.158k puw, 98k sow.129k rotw,10.38 ECD,Max Gas 16,5.2 ADT,21.45 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Ddg.f/9708'-10.336'MD(2819'TVD)@ 900 qpm,2350 psi,160 rpm,6-10k wob,13-14k tqn,9k tqf,160k puw, 90k sow,130k rotw,10.39 ECD,Max Gas 21,4.6 ADT,26.05 Bit/Jars.45 bbls Toady fluid losses.SPR @ 10,336'MD (2819'TVD)w/9.25 MW,#1/#2 @ 30-280,@ 40-330,#3 @ 30-260,@ 40-300. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg.f/10,336'-10,906'MD(2830'TVD)@ 900 gpm,2420 psi,160-180 rpm,10-12 web,12-13k tqn,8k tqf,158k puw,95k sow,130k rotw,10.36 ECD,Max Gas 19,4.64 ADT,30.69 Bit/Jars. 18:00 00:00 - 6.00 24.00 DRILL E 3 P PJSA Ddg.f/10,906'-11,529'MD(2847'TVD)@ 900 gpm,2630 psi,160-180 rpm,10-12k wob,16k tqn,9k tqf,165k puw,N/A sow,130k rotw,10.46 ECD,Max Gas 9,4.69 ADT,35.38 Bit/Jars.74 bbls Tourly fluid losses.SPR @ 11,362' MD(2842'TVD)w/9.2 MW;#1/#2 @ 30-340,@ 40-400,#3 @ 30-320,@ 40-400. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dnlling Supv "SIDDnIling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 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 ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 318 12.415 L-80 0.0 2.833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 Eni E&P Division .} Well Name:S.. J2 EN/Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO • Date:11/22/2014 - Report 18 APIIUWI:50629-23531-00-00 c i 'r o page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24.061.00 202.75 118.7 14.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,770.0 3,349.6 2,241.00 16.67 134.4 104.0 7.0 Overcast WC-17° E @ 31 MPH Daily summary operation 24h Summary Drill 12.25"Intermediate hole F/11,529'to 13,770'MD(3.347'TVD)900 GPM,3,050 PSI,160-180 RPM.WOB 2-16K,TON 16K,TOF 10K,HST 185K.SLK 100K,ROT 147K,ECD 10.58 ppg,Max Gas 54 units.ADT 16.67,BIT HRS 52.05.JSR HRS 52.05.Total lost for today 160 bbl. Operation at 07.00 Drill 12.25"intermediate hole @ 14,140'MD. 24h Forecast Drill 12.25"intermediate hole F/13,770'to 15,415'MD as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P Drill 12.25"Intermediate hole F/11,529'to 12,164'MD(2,874'TVD)900 GPM,2,790 PSI,160-180 RPM,WOB 2-12K, TON 16K,TQF 10K,HST 170K,SLK 85K,ROT 132K,ECD 10.71 ppg,Max Gas 24 units.ADT 3.76,BIT HRS 39.14,JSR HRS 39.14. 06.00 12:00 6.00 12.00 DRILL E 3 P Drill 12.25"Intermediate hole F/12,164'to 12,733'MD(2,969'TVD)900 GPM,2,790 PSI,160-180 RPM,WOB 4-12K, TON 14K,TOF 10K,HST 175K,SLK 90K,ROT 136K,ECD 10.72 ppg,Max Gas 27 units.ADT 4.18,BIT HRS 43.32,JSR HRS 43.32.Lost 82 bbl for tour. SPR @ 12,296'MD(2,888'TVD)W/9.3 ppg MW MP#1 30-360,40-420 MP#2 30-360,40-420 MP#3 30-340,40-400 1200 18.00 6.00 18.00 DRILL E 3 P Drill 12.25"Intermediate hole F/12,733'to 13,349'MD(3,193'TVD)900 GPM.2.990 PSI,160-180 RPM,WOB 2-15K, TON 16K,TQF 10K,HST 185K,SLK 100K,ROT 147K,ECD 10.63 ppg,Max Gas 19 units.ADT 4.44,BIT HRS 47.76,JSR HRS 47.76. 18 00 0000 600 24.00 DRILL E 3 P Drill 12.25"Intermediate hole F/13,349'to 13,770'MD(3,347'TVD)900 GPM,3,050 PSI,160-180 RPM,WOB 2-16K, TON 16K,TOE 10K.HST 185K,SLK 100K,ROT 147K.ECD 10.58 ppg,Max Gas 54 units.ADT 4.29,BIT HRS 52.05.JSR HRS 52.05.Total lost for tour 78 bbl. SPR @ 13,416'MD(3,202'TVD)W/9.3 ppg MW MP#1 30-410,40-500 MP#2 30-410,40-500 MP#3 30-380,40-420 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 Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2.833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2.866.0 2,463.05,LSND 9.20 410.0 12.40 1.587.1 0ii,o Eni E&P Division Nme: .82 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • Date:11/23/2014 - Report#: 19 API/UWI:50-629-23531-00-00 2" " page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(11KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 15.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POE Temperature(°F) Weather Wind 15 417.0 3,606.6 1,647.00 18.45 89.3 105.0 2.0 Mostly Cloudy WC- WSW @ 9 MPH 17' Daily summary operation 24h Summary Drill 12.25"Intermediate hole F/13,770'to 15,417'MD(3,605'TVD)880 GPM.3,380 PSI.160-180 RPM.WOB 10-15K,TON 16K,TQF 10K,HST 195K,SLK 100K,ROT 148K.ECD 10.81 ppg.Max Gas 682 units.ADT 18.45,BIT HRS 70.50,JAR HRS 70.50.Lost 64 bbl today. Operation at 07.00 Drilling ahead as per geologist,at 15,645'MD 24h Forecast Drill 12.25"intermediate hole F/15,417'to 15.534'MD as per well plan.BROOH as per KW BROOH schedule. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.40 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 Drill 12.25"Intermediate hole F/13,770'to 14,307'MD(3,509'TVD)900 GPM,2,870 PSI,160-180 RPM,WOB 12-15K, TON 16-17K,TOF 12K,HST 192K,SLK 102K,ROT 149K,ECD 10.70 ppg,Max Gas 229 units.ADT 4.73,BIT HRS 56.78, JAR HRS 56.78. 06.00 1200 - 6.00- 12.00 DRILL -E 3 P Drill 12.25"Intermediate hole F/14,307'to 14,755'MD(3,574'TVD)900 GPM,3,310 PSI,160 RPM,WOB 15K,TON 16K, TOF 11.5K,HST 192K,SLK 100K,ROT 148K,ECD 10.78 ppg,Max Gas 682 units.ADT 4.09,BIT HRS 60.87,JAR HRS 60.87. SPR @ 14,349'MD(3,520'TVD)W/9.4 ppg MW MP#1 30-420,40-510 MP#2 30-420,40-510 MP#3 30-400,40-470 12.00 18:00 6.00 18.00 DRILL •E 3 'P Drill 12.25"Intermediate hole F/14,755'to 15,070'MD(3,585'TVD)888 GPM,3,380 PSI,160-180 RPM,WOB 10-15K, TON 19K,TOF 12K,HST 192K,SLK 100K,ROT 148K.ECD 10.78 ppg,Max Gas 470 units.ADT 5.53,BIT HRS 66.40, JAR HRS 66.40. 1800 00:00 6.00. 24.00 DRILL •E 3 P Drill 12.25"Intermediate hole F/15,070'to 15,417'MD(3,605'TVD)880 GPM,3,380 PSI,160-180 RPM,WOB 10-15K, TON 18K,TQF 10K,HST 195K,SLK 100K,ROT 148K,ECD 10.81 ppg,Max Gas 125 units.ADT 4.10,BIT HRS 70.50, JAR HRS 70.50. Lost for tour 64 bbl. , SPR @ 15,376'MD(3,602'TVD)W/9.4 ppg MW MP#1 30-440,40-480 MP#2 30-440,40-480 MP#3 30-400,40-460 Daily Contacts Position Contact Name Company Title E-mail Office Mobile En: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 Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 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(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2.833.7 11/12/2014 Last Leakoff Test Depth(f1KB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 Eni E&P Division Well Name: S.. .✓V2 II* EN/PetroleumCo.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUQ •2^n Date:11/24/2014 - Report#: 20 II APIIUWI:50-629-23531-00-00 II II page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10_ 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3,613.8 24,061.00 202.75 118.7 16.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15,750.0 3,626.2 333.00 4.33 76.9 111.0 Light Snow WC-13' W©9 MPH Daily summary operation 24h Summary Drill 12.25"Intermediate hole F/15,417'to 15,750'MD(3,627'TVD)880 GPM,3,440 PSI,180 RPM.WOB 8-15K,TQN 20K,TOF 13.5K,HST 198K,SLK 92K,ROT 147K,ECD 10.91 ppg,Max Gas 101 units.ADT 4.33,BIT HRS 74.83,JAR HRS 74.83.Circ.2X BU as per K&M schedule©800 GPM,3,440 PSI,140 RPM,TRQ 16K,ECD 10.76 ppg.Stand back 1 5"D.P.stand every EU to 15,566'MD. BROOH as per K&M BROOH schedule F/15,566'to 11,179'MD 880 GPM,2,950 PSI,140 RPM,TQ 15K,HST 190K,SLK 85K,ROT 134K.ECD 10.71 ppg.Calculated displacement 35 bbl,actual displacement 54 bbl,lost 19 bbl. Operation at 07.00 BROOH as per K&M schedule @ 9,683'MD. 24h Forecast BROOH as per K&M schedule F/11,179'MD at 7-8 Min.per stand. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E 3 P Drill 12.25"Intermediate hole F/15,417'to 15,750'MD(3,627'TVD)880 GPM,3,440 PSI,180 RPM,WOB 8-15K,TON 20K,TQF 13.5K,HST 198K,SLK 92K,ROT 147K,ECD 10.91 ppg,Max Gas 101 units.ADT 4.33,BIT HRS 74.83,JAR HRS 74.83. SPR @ 15,376'MD(3,627'TVD)W/9.45 ppg MW MP#1 30-380,40-450 MP#2 30-380,40-450 MP#3 30-360,40-420 05:00 08:30 3.50 8.50 DRILL E 7 P Circ.2X BU as per K&M schedule @ 800 GPM,3,440 PSI,140 RPM,TRQ 16K,ECD 10.76 ppg.Stand back 1 5"D.P. stand every BU to 15,566'MD. 08:30 12:00 3.50 12.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/15,566'to 14,913'MD 890 GPM,3,370 PSI,140 RPM,TO 13K,HST 200K,SLK 98K,ROT 152K.ECD 10.77 ppg.No losses for tour. 12:00 18:00 6.00 16.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule F/14,913'to 13,326'MD 880 GPM,3,250 PSI,140 RPM,TQ 10-11K,HST 205K,SLK 95K,ROT 142K.ECD 10.83 ppg. 18:00 00:00 6.00 24.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule Fl 13,326'to 11,179'MD 880 GPM,2,950 PSI,140 RPM.TQ 15K,HST 190K,SLK 85K,ROT 134K.ECD 10.71 ppg.Calculated displacement 35 bbl,actual displacement 54 bbl,lost 19 bbl. 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 Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 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(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 II* Eni E&P Division Well Name:b, vV2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO • Date:11/25/2014 - Report#: 21 API/UWI:50-629-23531-00-00 en page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N' Operator ENI Share CIA) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 17.00 Daily Information End Depth(11KB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15,750.0 3,626.2 0.00 108.0 -5.1 Overcast WC-22' ENE @ 9 MPH Daily summary operation 24h Summary BROOH as per K&M schedule F/11,179'to 5,000'MD 900 GPM,2,200 PSI,140 RPM.TOP 8-10K,HST 175K,SLK 95K.ROT 132K.ECD 9.97 ppg.At—5.120'MD encountered high torque and slight Press.spike.RIH W/stand and reduce RPM,Cont.BROOH at slower rate.At 5.060'MD increase RPM back to 140 RPM and Cont.BROOH @ 10 min per stand,no issue.Total lost today 70 bbl. Operation at 07.00 BROOH as per K&M schedule @ 4,091'MD. 24h Forecast BROOH as per K&M schedule F/5,000'MD at 7-8 Min.per stand. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.35 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 6 P PJSA BROOH as per K&M schedule F/11,179'to 6,978'MD 900 GPM,2,260 PSI,140 RPM,TQF 8K,HST 160K,SLK 95K,ROT 132K.ECD 10.15 ppg.Calculated displacement 35 bbl,actual displacement 99 bbl,lost 64 bbl for tour. 12:00 00:00 12.00 24.00 DRILL E 6 P PJSA BROOH as per K&M schedule F/6,978'to 5,000'MD 900 GPM,2.200 PSI,140 RPM,TQF 8-10K,HST 175K,SLK 95K,ROT 132K.ECD 9.97 ppg.At—5,120'MD encountered high torque and slight Press.spike.RIH W/stand and reduce RPM,Cont.BROOH at slower rate.At 5,060'MD increase RPM back to 140 RPM and Cont.BROOH @ 10 min per stand, no issue. Calculated displacement 16 bbl,actual displacement 22 bbl,lost 6 bbl for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross IENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 ' Tool Push Pete Martinusen Doyon Dnlling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 00 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9.20 410.0 1240 1.587.1 IP* Eni E&P Division .. wn N eame: Wz EN!Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUQ J • Date:11/26/2014 - Report#: 22 API/UWI:50 629-23531-00-00 2 r' "o page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 18.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) FOB Temperature(°F) Weather Wind 15,750.0 3.626.2 0.00 108.0 0.0 Partly Cloudy WC- E @ 17 MPH 19' Daily summary operation 24h Summary BROOH as per K&M schedule F/5,000'to 3,610'MD.Encountered pack off @ 3,610'MD.Lost 40 bbl,RIH to 3,985'MD.Stage pumps up to 900 GPM Circ.Safe Carb 250 down hole.BROOH as per K&M schedule F/2,770'to 1,470'MD 900 GPM,1,510 PSI.120 RPM,TQF 4K,HST 123K,SLK 118K,ROT 125K.ECD 9.89 ppg.Circ.hole clean F/1,470'to 1,400'MD @ 900 GPM,1.510 PSI,120 RPM,TRQ 4K.Total lost today 132 bbl. Operation at 07.00 C/O Upper Rams to 9 5/8"Csg.Rams.Test rams 24h Forecast Cont.Circ.hole clean.POOH F/1.400'to BHA#4. L/D BHA#4 as per Schlumberger DD and MWD.Pull Wear Bushing and set test plug.C/O Upper Rams to 9 5/8"Csg.Rams.Test rams.Pull test plug and install short body Wear Bushing.R/U Tesco CRT and Equip.P/U M/U 9 5/8"Shoe Track and test.Float in hole 9 5/8"Csg as per tally and K&M running schedule. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 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 6 P PJSA BROOH as per K&M schedule F/5,000'to 3.610'MD 900-950 GPM.1,930 PSI.140 RPM,TQF 10-20K.HST 150K. SLK 95K,ROT 132K.ECD 9.85 ppg. 07:00 08:00 1.00 8.00 DRILL E 3 P Encountered pack off @ 3,610'MD.Lost 40 bbl,RIH to 3,985'MD.Stage pumps up to 900 GPM Circ.Safe Curb 250 down hole. 08:00 12:00 4.00 12.00 DRILL E 6 P PJSA BROOH as per K&M schedule F/3,985'10 3,337 MD 900-950 GPM.1,880 PSI.140-180 RPM.TQF 4-5K,HST 149K,SLK 118K,ROT 138K.ECD 9.78 ppg.Calculated displacement 15 bbl,actual displacement 140 bbl,lost 125 bbl for tour. 12:00 19.00 7.00 19.00 DRILL E 6 P PJSA BROOH as per K&M schedule F/3,337'to 2.770'MD 900 GPM,1.670 PSI,120-140 RPM,TQF 2-8K,HST 140K. SLK 130K,ROT 135K.ECD 9.76 ppg.Monitor well for 10 Min,static. 19.00 23:30 4.50 23.50 DRILL E 6 P PJSA BROOH as per K&M schedule F/2,770'to 1,470'MD 900 GPM.1,510 PSI,120 RPM,TOE 4K,HST 123K,SLK 118K,ROT 125K.ECD 9.89 ppg.Calculated displacement 16 bbl.actual displacement 23 bbl,lost 7 bbl for tour. 23:30 00.00 0.50 24.00 DRILL E 7 P Circ.hole clean F/1,470'to 1,400'MD @ 900 GPM.1,510 PSI.120 RPM,TRO 4K. 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 Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.cow 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(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 liff* Eni E&P Division Well Name:: J2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ a Date:11/27/2014 - Report#: 23 API/UWI:50 29.23531-00-00 2 rr 'r II page 1 of 1 Wellbore name: S126-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA •ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI26-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 19.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15.750.0 3626.2 0.00 111.0 -5.0 Partly Cloudy WC- E @ 11 MPH 22' • Daily summary operation 24h Summary POOH on elevators F/1,400'to 350'MD.Monitor well,static.BHA#4 as per Schlumberger DD and MWD.HWDP had severe grooves right above wear bands on Pin-end.Grooving above hard banding on bottle-neck rig X10.Grooving into collar of ARC near wear bands.NM Flexes had grooving around hard band as well.NM stabilizer on the top had significant wear(down to 8 1/2"OD).Hi tool had significant damage and wear(down to 8 3/4"OD)-Also suspect movement of mechanism.ILS had significant wear(down to 8 3/4"OD)Xceed upper stabilizer wore down to collar(9 5/8"OD)Xceed lower stabilizer had wear down to 10 3/4"OD.12.25"Bit was graded 4-3-BT-A-X-IN-CT-TD.Clean and clear rig floor of BHA subs and stabs. M/U Stack Washer and X/O to Jnt D.P.,wash Stack W/336 GPM,80 RPM.UD Stack Washer. Pull Wear Bushing and set test plug as per Vetco Grey Rep onsite.C/O Upper Pipe Rams F/3.5"X 6"to 9 5/8"Cog Rams.Test 9 5/8"Csg.Rams to 250 PSI low and 3,500 PSI high,charted.R/D test Equip.Pull test plug and install Short Body Wear Bushing as per Vetco Grey Rep onsite.(ID 12.31")PJSM W/all essential personnel.R/U Tesco CRT and Equip.as per Tesco Reps onsite.P/U M/U 9 5/8"Csg.Shoe Track and test floats.(Good)RIH W/9 5/8"Csg.408,L-80,HYD-563 to 400'MD.SLK 87K.Float 9 5/8"Csg.as per tally and K&M running speed F/400'to 5,200'MD.Slack off fell to 60K,decision was made to rotate in hole @ 50 RPM,TRQ 8K,SLK 70-80K.Cont.float and rotate 9 5/8"Csg @ 50 RPM F/5,200'to 9,835'MD.TRO 10-11K,SLK 70-80K. Operation at 07.00 Float and rotate 9 5/8"Csg @ 50 RPM @ 11,165'Md. 24h Forecast Cont.to float and rotate @ 50 RPM 9 5/8"Csg.F/9,835'to 15,740'MD as per tally and K&M running speed.At TD fill 9 5/8"Csg as per MI Swaco Plan Forward. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deicer. 00:00 01:00 1.00 1.00 DRILL E 4 P PJSA POOH on elevators F/1,400'to 350'MD.Monitorwell,static. 01:00 03:00 2.00 3.00 DRILL E 4 P PJSA UD BHA#4 as per Schlumberger DD and MWD.HWDP had severe grooves right above wear bands on Pin-end. Grooving above hard banding on bottle-neck rig X/O.Grooving into collar of ARC near wear bands.NM Flexes had grooving around hard band as well.NM stabilizer on the top had significant wear(down to 8 1/2"OD).Hi tool had significant damage and wear(down to 8 3/4"OD)-Also suspect movement of mechanism.ILS had significant wear(down to 8 3/4"OD)Xceed upper stabilizer wore down to collar(9 5/8"OD)Xceed lower stabilizer had wear down to 10 3/4"OD. 12.25"Bit was graded 4-3-BT-A-X-IN-CT-TD 03:00 03:30 0.50 3.50 DRILL E 20 P PJSA Clean and clear rig floor of BHA subs and stabs. 03.30 04:00 0.50 4.00 DRILL C 20 P PJSA M/U Stack Washer and X/O to Jnt D.P.,wash Stack W/336 GPM,80 RPM.L/D Stack Washer. 04.00 05:00 1.00 5.00 DRILL C 20 P PJSA Pull Wear Bushing and set test plug as per Vetco Grey Rep onsite. 05:00 06:00 1.00 6.00 DRILL C 20 P PJSA CIO Upper Pipe Rams Fl 3.5"X 6"to 9 5/8"Csg Rams. F `' 06:00 06:30 0.50 6.50 DRILL C 12 P PJSA Test �/8"Csg.Rams to 250 PSI low and 3,500 PSI high,charted. G3 Q 06:30 07:00 0.50 7.00 DRILL C 20 P PJSA R/D test Equip.Pull test plug and install Short Body Wear Bushing as per Vetco Grey Rep onsite.(ID 12.31") _\ U 07:00 10:00 3.00 10.00 DRILL G 20 P PJSM W/all essential personnel.R/U Tesco CRT and Equip.as per Tesco Reps onsite. ,,,, 10:00 12:00 2.00 12.00 DRILL G 4 P PJSA P/U M/U 9 5/8"Csg.Shoe Track and test floats.(Good)RIH W/9 5/8"Csg.40#,L-80,HYD-563 to 400'MD.SLK t✓�y 87K. 12:00 18:00 6.00 18.00 DRILL G 4 P PJSM Float 9 5/8"Csg.as per tally and K&M running speed F/400'to 5,200'MD.Slack off fell to 60K,decision was made to rotate in hole @ 50 RPM,TRO 8K,SLK 70-80K. 18:00 00:00 6.00 24.00 DRILL G 4 P PJSA Float and rotate 9 5/8"Csg @ 50 RPM Fl 5,200'to 9,835'MD.TRO 10-11K,SLK 70-80K. 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 Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 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 Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,833.7 11/12/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2.866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 VI* Eni E&P Division Name:._ 41A/2ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • Date:11/28/2014 - Report#: 24 API/UWI:50-629-23531-00-00 2'r i El page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3,613.8 24,061.00 202.75 118.7 20.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15.750.0 3,626.2 0.00 111.0 1.0 Partly Cloudy WC- ENE @ 14 MPH 17" Daily summary operation 24h Summary Float and rotate 9 5/8"Csg @ 45 RPM about 2-3 min per stand F/9,835'10 15,710'MD.TRQ 15K,SLK 70K.M/U 9 5/8"landing joint and rotate 9 5/8"Csg down F/15.710'to 15,740'MD @ 45 RPM. TRQ 15K,SLK 70K.Shoe @ 15,740'MD.Calculated displacement observed for trip.PJSM R/D Tesco CRT and Equip.as per Tesco Rep onsite.Clear rig floor.PJSM R/U Bails,Cement Head and Circ. Equip.for filling 9 5/8"Csg.Fill 9 5/8"Csg.as per plan W/9.3 ppg LSND @ 4 bpm,450 PSI,450 bbl pumped.Cont.filling 9 5/8"Csg.@ 4 bpm,40 PSI stopping 1/2,3/4 and topping off to bleed air.Top off 3X with total of 1,300 bbl pumped. Operation at 07.00 Circ.and condition for cement job. 24h Forecast Break Circ,at 1 bpm staging up pump rate to 6-8 bpm and conditioning mud to<18 YP for cement job.Remove and load cement head W/plugs.Perform cement job.Perform 20 bbl injectivity test.N/D BOPE.Set emergency slips.Freeze protect 9 5/8"X 13 3/8"Annulus.N/U BOPE. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.40 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 G 4 P PJSA Float and rotate 9 5/8"Csg @ 50 RPM about 2-3 min per stand F/9,835'to 12,400'MD.TRO 14.5K,SLK 75K. 06:00 12:00 6.00 12.00 DRILL G 4 P PJSA Float and rotate 9 5/8"Csg @ 45 RPM about 2-3 min per stand F/12,400'to 15,585'MD.TRO 15K,SLK 70K. 12:00 12:30 0.50 12.50 DRILL G 4 P PJSA Float and rotate 9 5/8"Csg @ 45 RPM about 2-3 min per stand F/15,585'to 15,710'MD.TRQ 15K,SLK 70K. 12:30 13.00 0.50 13.00 DRILL G 4 P PJSA M/U 9 5/8"landing joint and rotate 9 5/8"Csg down F/15,710'to 15.740'MD @ 45 RPM,TRO 15K,SLK 70K.Shoe @ 15,740'MD.Calculated displacement observed for trip. 13:00 14:00 1.00 14.00 DRILL G 20 P PJSM R/D Tesco CRT and Equip.as per Tesco Rep onsite.Clear rig floor. 14:00 15:00 1.00 15.00 DRILL H 20 P PJSM R/U Bails,Cement Head and Circ.Equip.for filling 9 5/8"Csg. 15:00 18:00 3.00 18.00 DRILL G 9 P Fill 9 5/8"Csg,as per plan W/9.3 ppg LSND @ 4 bpm,450 PSI.450 bbl pumped. 18:00 00:00 6.00 24.00 DRILL G 9 P PJSM Cont.filling 9 5/B"Csg.@ 4 bpm.40 PSI stopping 1/2,3/4 and topping off to bleed air.Top off 3X with total of 1.300 bbl pumped. 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 Dolling Supv. 907-685-0715 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 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.com 907-685-0716 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(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(f1KB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2.866.0 2,463.05 LSND 9.20 410.0 12.40 1.587.1 cf Eni E&P DivisionWell Name: .(V1/2ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO eDate:11/29/2014 - Report#: 25 APIIUWI:50 629-23531-00-00 e r' rr ii 1 of 1 Wellbore name: SI26-NW2 Well Header Per nit/Concession N` Operator ENI Share(%) Well Configuration type /.L--SEe ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 3774 Rig Information Contractor Rig Name Rig Type D/Y06 RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/972014 23,989.5 3.613.8 24,061.00 202.75 118.7 21.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POE Temperature('F) Weather Wind 15,750.0 3,626.2 0.00 105.0 -4.0 Overcast WC-24° SW @ 15 MPH Daily summary operation 24h Summary Circ.and condition LSND to<18 YP as per MI Swaco plan.Start @ 2 bpm,420 PSI.Break over @ 400 PSI and stage up in.5 bpm to 8 bpm,350 PSI.Load wiper plugs W/Schlumberger cementer and CO Rep onsite.Resume Circ.PJSM WI all essential personnel.Schlumberger pump 10 bbl H2O and test 1,000 PSI low and 3,500 PSI high.Rig pumped 100 bbl 10.5 ppg Mud Push II,Drop bottom plug, Schlumberger pumped 223 bbl 12.5 ppg LiteCRETE slurry @ 4 bpm 400-600 PSI.Kick out top plug W/10 bbl H2O.Begin displacement W/rig pumps @ 6 bpm 450 PSI,slow rate to 3.5 bpm,430 PSI observe top plug bump @ 1,176 bbl.FCP 550 PSI increase Press.to 1,050 PSI and hold for 5 Min.Bleed off Press.and check floats.(Good)CIP @ 13:00.R/U perform injectivity test down 9 5/8"X 13 3/8"annulus W/9.3 ppg LSND @ 1.5 bpm.Observe injection @ 410 PSI,RCP 420 PSI.35 bbl pumped W/10 bbl returned during bleed down.R/D Cement Head,blow down and R/D cementing and testing Equip.N/D BOPE for setting Emergency Slips.Prep and set 9 5/8"slips W/100K set on slips as per Vetco Grey Rep onsite.Cut off 9 5/8"Csg and pull landing joint.Pull Csg.running Wear Bushing.Prep and set 9 5/8"Pack Off as per Vetco Grey Rep onsite.Lower and set BOPE.0/0 top rams to 3.5"X 6"variable rams.SIMOPS Test 9 5/8"Pack Off to 2,472 PSI for 10 Min.W/Vetco Grey and CO Rep onsite.Finish N/U BOPE.Pump Freeze Protect W/Little Red Services down 9 5/8"X 13 3/8"annulus 112 bbl away,1.75 bpm,525 PSI.SIMOPS clear rig floor,R/U to test BOPE.Set test plug as per Vetco Grey Rep onsite. Operation at 07.00 Test BOPE. 24h Forecast Finish Freeze Protect.Test BOPE,P/U Mill 4.5"D.P.and rack back in Derrick. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum _ `t Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL H 8 P PJSM Circ.and condition LSND to<18 YP as per MI Swaco plan.Start @ 2 bpm,420 PSI.Break over @ 400 PSI and Ci stage up in.5 bpm to 6 bpm,350 PSI.Load wiper plugs W/Schlumberger cementer and CO Rep onsite.Resume Circ. ` (� 07:00 13:00 6.00 13.00 DRILL H 9 P PJSM W/all essential personnel.Schlumberger pump 10 bbl H2O and test 1,000 PSI low and 3,500 PSI high.Rig pumped -Q r ` 100 bbl 10.5 ppg Mud Push II,Drop bottom plug,Schlumberger pumped 223 bbl 12.5 ppg LiteCRETE slurry @ 4 bpm 400- CAA 600 PSI.Kick out top plug W/10 bbl H2O.Begin displacement W/rig pumps @ 6 bpm 450 PSI,slow rate to 3.5 bpm,430 PSI observe top plug bump @ 1,176 bbl.FCP 550 PSI increase Press.to 1,050 PSI and hold for 5 Min.Bleed off Press. and check floats.(Good)CIP @ 13:00. 13:00 14:30 1.50 14.50 DRILL G 9 P PJSM R/U perform injectivity test down 9 5/8"X 13 3/8"annulus W/9.3 ppg LSND @ 1.5 bpm.Observe injection @ 0,10 PSI,RCP 420 PSI.35 bbl pumped W/10 bbl returned during bleed down. r,/ 14:30 15:30 1.00 15.50 DRILL H 20 P PJSM R/D Cement Head,Slowdown and R/D cementing and testing Equip. - - 15:30 17:00 1.50 17.00 DRILL C 5 P PJSM N/D BOPE for setting Emergency Slips. 17:00 18:00 1.00 18.00 DRILL C 20 P PJSA Prep and set 9 5/8"slips W/100K set on slips as per Vetco Grey Rep onsite. 18:00 19:30 1.50 19.50 DRILL C 20 P PJSA Cut off 9 5/8"Csg and pull landing joint.Pull Csg.running Wear Bushing.Cut length 39.37" 19:30 20:30 1.00 20.50 DRILL C 5 P Prep and set 9 5/8"Pack Off as per Vetco Grey Rep onsite. 20:30 21:00 0.50 21.00 DRILL C 5 P Lower and set BOPE. 21:00 22:00 1.00 22.00 DRILL C 20 P PJSA C/O top rams to 3.5"X 6"variable rams.SIMOPS Test 9 5/8"Pack Off to 2,472 PSI for 10 Min.WI Vetco Grey and CO Rep onsite. 22:00 22:30 0.50 22.50 DRILL 'C 5 P Finish N/U BOPE. 22:30 00:00 1.50 24.00 DRILL C -9 P PJSA Pump Freeze Protect W/Little Red Services down 9 5/8"X 13 3/8"annulus t 12 bbl away,1.75 bpm,525 PSI. SIMOPS clear rig floor,R/U to test BOPE.Set test plug as per Vetco Grey Rep onsite. 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 Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 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.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5:8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.866.0 2.463.05 LSND 9.20 410.0 12.40 1,587.1 IP* Eni E&P Division Well Name: W2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUO • Date:11/30/2014 - Report#: 26 APIIUWI:50 629-23531-00-00 2 r' i� page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23.989.5 3.613.8 24,061.00 202.75 118.7 22.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15,750.0 3,626.2 0.00 106.0 -11.0 Overcast WC-30" SW @ 13 MPH Daily summary operation 24h Summary Cont.to Freeze Protect W/Little Red Services.Total 160 bbl Diesel pumped,FCP 400 PSI.SIMOPS Cont.RIO test Equip.for BOPE test.Test BOPE.AOGCC witness waived by Bob Noble 11-29-14. Clean and clear rig floor of test Equip.and blow down lines.SIMOPS Pull test plug and install Wear Bushing as per Vetco Grey Rep onsite.C/O Saver Sub on TDS-8.Reinstall TDS-8 Bell Guide F/casing run.Bell Nipple Clamshell&inspect air boot.SIMOPS Take on Faze Pro F/Mud Plant to Pits.Service rig.Hang Blocks and slip and cut dolling line.R/U P/U M/U 4.5"D.P.F/Pipe Shed and rack back in Derrick,total 207 joints.Clear rig floor and load BHA#5 tools to rig floor.Test 9 5/8"Csg.to 3,000 PSI for 30 Min.charted.Witnessed by CO Rep onsite.Blow down and R/D test Equip.Service and inspect TDS-8 Block and Hook. Operation at 07.00 Single in hole BHA#5 W/4.5"D.P.F/Pipe Shed @ 455'MD. 24h Forecast P/U M/U BHA#5 as per Schlumberger DD and MWD.Single in hole W/4.5"D.P.F/Pipe Shed.Shallow hole test MWD tools @-1,500'MD.Cont.to single in hole W/4.5"D.P.RIH to TOC.Displace LSND to Faze Pro.Drill out Shoe Track. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 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 9 P PJSA Cont.to Freeze Protect W/Little Red Services.Total 160 bbl Diesel pumped,FCP 400 PSI.SIMOPS Cont.R/O test Equip.for BOPE test. r 01 00 06:00 5.00 6.00 DRILL C 12 P PJSA Test BOPE Test Annular Preventer W/4.5"and 5"test joint to 250 PSI low and 2.500 PSI high.Test 4.5"and 5"test •^ _n'� joint to Choke Valves 1-14,both HCR Kill&Choke,both Manual Kill and Choke,Kill Line Demco,Upper&Lower Rams, I]WL(Y�' Blind Rams,Upper and Lower IBOP,Dart and TIW valves to 250 PSI low and 3,500 PSI high for 5 Min.all charted.Perform Koomey Draw Down:Start Press.System 3,000 PSI,Manifold 1,500 PSI,Annular 800 PSI,after function System1,600, ,{/ Manifold 1,400,Annular 775.34 Sec 200 PSI increase.180 Sec full charge.AOGCC witness waived by Bob Noble 11-29- I,.5 14. {{{�� 06:00 07:00 1.00 7.00 DRILL C 20 P PJSA Clean and clear rig floor of test Equip.and blow down lines.SIMOPS Pull test plug and install Wear Bushing as per Vetco Grey Rep onsite. 07:00 09:30 2.50 9.50 DRILL E 25 P PJSM C/O Saver Sub on TDS-8. 09:30 10:30 1.00 10.50 DRILL E 25 P PJSA Reinstall TDS-8 Bell Guide F/casing run.Bell Nipple Clamshell&inspect air boot.SIMOPS Take on Faze Pro F/ Mud Plant to Pits. 10:30 11:00 0.50 11.00 DRILL E 25 P Service rig. 11:00 13:30 2.50 13.50 DRILL E 25 -P PJSM Hang Blocks and slip and cut drilling line. 13:30 20:30 7.00 20.50 DRILL E 20 P PJSM R/U P/U M/U 4.5"D.P.F/Pipe Shed and rack back in Derrick.total 207 joints. 20:30 21:30 1.00 21.50 DRILL E 20 P PJSM Clear ng floor and load BHA#5 tools to rig floor. 21:30 23:00 1.50 23.00 DRILL G 12 P PJSA Test 9 5/8"Csg.to 3,000 PSI for 30 Min.charted.Witnessed by CO Rep onsite.Blow down and R/D test Equip. 23:00 00.00 1.00 24.00 DRILL E 25 P PJSA Service and inspect TDS-8 Block and Hook. 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 Dolling Sups. 907-685-0715 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 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.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 19.1 15.7500 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,866.0 2,463.05 LSND 9.20 410.0 12.40 1,587.1 Eni E&P Division ..} Well Name:,_ �aW2 1 1191* EN/Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • APIIUW1:50-629-23531-00-00 2�fI^ Date:12/1/2014 - Report#: 27 iipage 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(it) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 23.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 15,750.0 3,626.2 0.00 105.0 -4.0 Overcast WC-22° W @ 7 MPH Daily summary operation 24h Summary P/U M/U 8.75"BHA#5 as per Schlumberger DD and MWD to 397'MD.P/U M/U 4.5"D.P.F/Pipe Shed and single in hole BHA#5 F/397'to 1,526'MD.Perform shallow hole test.460 GPM,900 PSI.RIH 8.75"BHA#5 W/4.5"D.P.F/Derrick F/1,526'to 6,000'MD.Lost down weight and the decision was made to rotate in hole F/6,000'to 6,660'MD.30 RPM,TRQ 7-8K,Rotate in hole 8.75"BHA#5 W/ 4.5"D.P.F/Derrick F/6,660'to 12,490'MD.30-40 RPM,TRQ 18K,Perform LWD MADD pass F/12.490'to 13,330'MD @ 100-900 FPH.40 RPM,TRO 22K,HST 235K,SLK 80K,ROT 145K. Operation at 07.00 MADD pass @ 14,633'MD. 24h Forecast Cont.LWD MADD pass F/13,330'to-15,651'MD. Displace LSND to Faze Pro,drill up plugs and F.0 while displacing.Drill out 9 5/8"Shoe Track and 20'of new hole to 15,770'MD.Perform LOT or FIT. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time _ Time Dur(hr( Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 - 3.50 3.50 DRILL E 20 P PJSA P/U M/U 8.75"BHA#5 as per Schlumberger DD and MWD to 397'MD.HST 98K,SLK 101K. 03:30 05:00 1.50 5.00 DRILL E 4 P PJSM P/U M/U 4.5"D.P.F/Pipe Shed and single in hole BHA#5 F/397'to 1,526'MD. 05:00 05.30 0.50 5.50 DRILL E 12 P PJSA Perform shallow hole test.460 GPM,900 PSI. 05:30 12.00 6.50 12.00 DRILL E 4 P PJSA RIH 8.75"BHA#5 W14.5"D.P.F/Derrick F/1,526'to 6,000'MD.Lost down weight and the decision was made to rotate in hole F/6,000'to 6.660'MD.30 RPM,TRQ 7-8K,HST 160K,ROT 120K. 12:00 21 00 9.00' 21.00 DRILL E 4 P PJSM Rotate in hole 8.75"BHA#5 W/4.5"D.P.F/Derrick F/6,660'to 12.490'MD.30-40 RPM.TRQ 18K.SLK 80-90K. 21:00 0000 3.00 24.00 DRILL -E 11 P PJSA Perform LWD MADD pass F/12,490'to 13,330'MD @ 100-900 FPH.40 RPM,TRO 22K,HST 235K,SLK 80K,ROT 145K. Daily Contacts Position Contact Name Company Title E-mail r Office Mobile Eni representative Mike Ross .ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 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 og15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 fic* Eni E&P DivisionWell Name: W2 ENI Petroleum Co.Inc. Daily ReportWell Code:28997 Field Name:NIKAITCHUO •2�, Date:12/2/2014 - Report#: 28 In! APIIUWI:50-629-23531-00-SO page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOVON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0126-NW2 DRILLING 11/9/2014 23.989.5 3613.8 24.061.00 202.75 118.7 24.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB 'Temperature(°F) Weather Wind 16,503.0 3,635.2 753.00 4.23 178.0 104.0 -2.0 Overcast WC-25° NNE @ 30 MPH Daily summary operation 24h Summary Perform LWD MADD pass F/13.330'to 15,384'MD @ 100-900 FPI-l.Wash down F/15,384'to 15,664'tag F.C.PJSM W/all essential personnel.Displace LSND to 9.3 ppg Faze Pro,pump 45 bbl Hi Vis Spacer,35 bbl LVT Spacer&1,130 bbl 9.3 ppg Faze Pro.While displacing,drill out Plugs,F.C.and cement F/15,664'to 15.692'MD.WOB 5-12K.POOH to 15,664'MD.Blow down RDS-8 and kill line. Clean all surface Equip.Clean out 9 5/8"Shoe Track F/15,664'to Shoe @ 15,750'MD.Drill out 20'of new hole to 15,770'MD.500 GPM,2,800 PSI,80 RPM,TRQ 6-12K,WOB 6-12K.POOH to 15,745' MD.Reciprocate F/15.745'to 15,664'MD 530 GPM,3.400 PSI.80 RPM,TRQ 14K.Circ.and condition mud till 9.25 ppg was observed in and out.R/U and perform FIT @ 15,753'MD to 720 PSI,EMW 13.0 ppg W/9.25 ppg MW.Pump 0.5 bpm,pumped 3.5 bbl to Pres.up.Bleed off 2.5 bbl retumed.Blow down R/D.Drill 8.75"Production hole F/15,750'to 16,503'MD(3,649'TVD)550 GPM,3,330 PSI, 140 RPM,WOB 2-12K,TON 19K,TQF 13K.HST 218K.SLK 80K,ROT 140K.ECD 11.58 ppg,ADT 4.23,Bit Hrs 4.23,Jar Hrs 4.23.Max Gas 804 units. Operation at 07.00 Drill 8.75"Production hole @ 16,770'MD. 24h Forecast Drill 8.75"Production hole F/16,503'to-20,046'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 4 P PJSA Perform LWD MADD pass F/13,330'to 15,384'MD @ 100-900 FPH.40 RPM,TRQ 28K,HST 260K,SLK 80K,ROT 145K. 06:00 07:30 1.50 7.50 DRILL E 6 P PJSA Wash down F/15.384'10 15,664'tag F.C.90 GPM.400 PSI,30 RPM,TRQ 28K,HST 265K,SLK 80K,ROT 145K. 07:30 11:00 3.50 11.00 DRILL E 9 P PJSM W/all essential personnel.Displace LSND to 9.3 ppg Faze Pro,pump 45 bbl Hi Vis Spacer,35 bbl LVT Spacer& 1,130 bbl 9.3 ppg Faze Pro.385 GPM,2,000 PSI,100 RPM,TRQ 20K.HST 210K,SLK 80K,ROT 140K.While displacing, drill out Plugs,F.C.and cement F/15,664'to 15,692'MD.WOB 5-12K.POOH to 15,664'MD. 11:00 12:30 1.50 12.50 DRILL E 20 P PJSA Blow down RDS-8 and kill line.Clean all surface Equip. 12:30 13.30 1.00 13.50 DRILL E 6 P PJSA Clean out 9 5/8"Shoe Track F/15.664'to Shoe @ 15,750'MD.Drill out 20'of new hole to 15,770'MD.500 GPM, 2.800 PSI,80 RPM,TRQ 6-12K,WOB 6-12K, 13:30 1800 1.50 15.00 DRILL 'E 4 P PJSA POOH to 15,745'MD.Reciprocate F/15,745'to 15,664'MD 530 GPM,3,400 PSI.80 RPM,TRQ 14K.Circ.and condition mud till 9.25 ppg was observed in and out. 15:00 16.30 1.50 16.50 DRILL E 11 P PJSA R/U and perform FIT @ 15,753'MD to 720 PSI,EMW 13.0 ppg W/9.25 ppg MW.Pump 0.5 bpm,pumped 3.5 bbl to Pres.up.Bleed off 2.5 bbl retumed.Blow down R/D. 16:30 18.00 1.50 18.00 DRILL E 3 P PJSM Drill 8.75"Production hole F/15,750'to 15,934'MD(3,633'TVD)550 GPM,3,470 PSI,80-100 RPM,WOB 2-10K, TON 17K,TQF 12K,HST 202K,SLK 80K,ROT 145K.ECD 11.3 ppg,ADT 1.10,Bit Hrs 1.10,Jar Hrs 1.10.Max Gas 347 units. SPR @ 15,770'MD(3,627'TVD)W/9.25 ppg MW MP#1 20-280,30-380 MP#2 20-280,30-380 MP#3 20-280,30-380 18:00 00:00 6.00 24.00 DRILL E 3 P PJSM Doll 8.75"Production hole F/15,934'to 16,503'MD(3,649'TVD)550 GPM,3,330 PSI,140 RPM,WOB 2-12K,TON 19K,TQF 13K,HST 218K,SLK 80K,ROT 140K.ECD 11.58 ppg,ADT 3.13,Bit Hrs 4.23,Jar Hrs 4.23.Max Gas 804 units. 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 Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyont5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Troy England ENI HOE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 cf* Eni E&P Division Well Name: . JV2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ •2�, Date:12/3/2014 - Report#: 29 I� " APIIUWI:50 629-23531-00-00 page 1 of 1 Wellbore name: S126-NW2 • Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.6 24,061.00 202.75 118.7 25.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 19,020.0 3.670.7 2.517.00 15.66 160.5 104.0 -8.0 Partly Cloudy WC-25 SSW@ 10 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/16,503'to 19,020'MD(3,685'TVD)Went out of 0A3 Sand zone @ 18,900 MD.Change tool face and direction down to find zone.530 GPM,3,400 PSI,140-160 RPM,WOB 2-12K,TON 20K,TQF 15K,HST 215K,SLK 80K,ROT 142K.ECD 11.74 ppg,ADT 3.66,Bit Hrs 19.91,Jar Hrs 19.91.Max Gas 1,260 units.Monitor well,static. Operation at 07.00 Drill 8.75"Production hole @ 19.250'MD. 24h Forecast Drill 8.75"Production hole F/19.020'to-24,046'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.20 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 1E 3 P 1 PJSA Drill 8.75"Production hole F/16,503'to 16,969'MD(3,640'TVD)530 GPM,3,300 PSI,140-160 RPM,WOB 6-10K, TON 19-21K,TQF 13-14K,HST 215K,SLK 80K,ROT 141K.ECD 11.56 ppg,ADT 5.31.Bit Hrs 9.54,Jar Hrs 9.54.Max Gas 841 units. 06:00 12.00 6.00 12.00 DRILL •E 3 'P -PJSA Drill 8.75"Production hole F/16,969'to 17,714'MD(3,657'TVD)530 GPM,3,430 PSI,140 RPM,WOB 4-8K,TON 20K,TOE 13-15K,HST 215K,SLK 60K,ROT 141K.ECD 11.79 ppg,ADT 2.48,Bit Hrs 12.02,Jar Hrs 12.02.Max Gas 1,151 units.Monitor well,static. SPR @ 17,714'MD(3,657'TVD)W/9.2 ppg MW MP#1 20-470,30-560 MP#2 20-470,30-560 MP#3 20-470,30-560 12.00 18:00 6.00 18.00 DRILL 1E 3 1P PJSA Drill 8.75"Production hole F/17,714'to 18,540'MD(3,681'TVD)530 GPM,3,430 PSI,140 RPM,WOB 2-10K,TON 21K,TOE 14K,HST 218K,SLK 60K,ROT 140K.ECD 11,66 ppg,ADT 4.23,Bit Hrs 16,25,Jar Hrs 16.25.Max Gas 1,287 units.Monitor well,static. 18:00 00:00 6.00 24.00 DRILL .15 3 •P PJSA Drill 8.75"Production hole F/18,540'to 19,020'MD(3,685'TVD)Went out of OA3 Sand zone @ 18,900 MD.Change tool face and direction down to find zone.530 GPM,3,400 PSI,140-160 RPM,WOB 2-12K,TON 20K,TOE 15K,HST 215K,SLK 80K,ROT 142K.ECD 11.74 ppg,ADT 3.66,Bit Hrs 19.91,Jar Hrs 19.91.Max Gas 1,260 units.Monitor well, static. SPR @ 18,714'MD(3,684'TVD)W/9.2 ppg MW MP#1 20-460,30-540 MP#2 20-460,30-540 MP#3 20-460,30-540 Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDnlling@enipetroleum.com 1907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 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@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(ftKB) Bottom(ftKB) Run Date CASING 9 5,18 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 15.770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2.461.9 r� Eni E&P Division Name:, W2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ e API/UWI:50-629-23531-00-00 2�, Date:12/4/2014 - Report#: 30 II II ii page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 10000 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SI26-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 26.00 Daily Information End Depth(fiKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(`F) Weather Wind 21,072.0 3,598.9 2,052.00 14.13 145.2 104.0 -2.0 Overcast WC-13` NNE @ 7 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/19.020'to 21,072'MD(3.613'TVD)Come back into OAl Sand @ 19,133'MD.Came out of top OAl and back into 0A3 F/19,22T to 19,994'MD.About 20,300'MD encountered losses and well bore breathing.530 GPM,3,550 P01,140-160 RPM,WOB 2-12K,TON 19K,TQF 13K.HST 220K.SLK 60K.ROT 138K.ECD 12.07 ppg,ADT 14.13,Bit Hrs 34.04.Jar Hrs 34.04.Max Gas 1,180 units.Monitor well,breathing.Lost about 45 bbl for the day. Operation at 07.00 Drill 8.75"Production hole @ 21,355'MD. _ 24h Forecast Drill 8.75"Production hole F/21.072'to-24,046'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 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 hole F/19,020'to 19,488'MD(3,688'TVD)Come back into OAl Sand @ 19,133'MD.530 GPM,3.500 PSI,140 RPM.WOO 8-12K,TQN 20-21K,TQF 14-15K,HST 245K,SLK 60K,ROT 143K.ECD 11.89 ppg. ADT 3.41,Bit Hrs 23.32.Jar Hrs 23.32.Max Gas 1,153 units.Monitor well,static. 06.00 1200 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/19,488'to 20,008'MD(3,611'TVD)Came out of top OAl and back into 0A3 F/19,227' to 19,994'MD.530 GPM,3,500 PSI,140 RPM,WOB 10-12K,TQN 20-21K,TQF 14K.HST 260K.SLK 80K,ROT 139K. ECD 12.21 ppg.ADT 2.92,Bit Hrs 26.24,Jar Hrs 26.24.Max Gas 135 units.Monitor well,static. SPR @ 19,955'MD(3,611'TVD)W/9.25 ppg MW MP#1 20-520,30-610 MP#2 20-520,30-610 MP#3 20-520,30-610 12.00 18.00 6.00' 18.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/20,008'10 20,514'MD(3,616'TVD)About 20,300'MD encountered losses and well bore breathing.530 GPM,3,540 PSI,140-160 RPM,WOB 2-14K,TON 20-22K,TOF 14K,HST 225K,SLK 80K,ROT 136K. ECD 12.07 ppg.ADT 4.36,Bit Hrs 30.60,Jar Hrs 30.60.Max Gas 697 units.Monitor well,breathing. 18:00 00:00 6.00 l 24.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/20,514'to 21,072'MD(3,613'TVD)530 GPM,3,550 PSI,140-160 RPM,WOB 2-12K, TON 19K,TQF 13K.HST 220K,SLK 80K,ROT 138K.ECD 12.07 ppg,ADT 3.44,Bit Hrs 34.04,Jar Hrs 34.04.Max Gas 1,180 units.Monitor well,breathing.Lost about 45 bbl for tour. SPR @ 20,795'MD(3,615'TVD)W/9.2 ppg MW MP#1 20-480,30-560 MP#2 20-480,30-560 MP#3 20-480,30-560 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 Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.cow 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ug15@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(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 15.770.0 3.625.08 FAZE PRO 9.25 720.0 13.07 2.461.9 Eni E&P Division Well Name:. W2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ eAPIIUWI:50-629-23531-00-00 2^ Date:12/5/2014 - Report#: 31 II II page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5I26-NW2 DRILLING 11/9/2014 23.989.5 3,613.8 24,061.00 202.75 116.7 27.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 23,195.0 3,634.3 2,123.00, 15.46 137.3 105.0 -5.0 Overcast WC-26° NNE @ 15 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/21,072'to 23,195'MD(3,649'ND)522 GPM,3,620 PSI,140-160 RPM,WOB 6-15K,TON 21K,TQF 13-15K,HST 225K,SLK 80K,ROT 138K.ECD 12.16 ppg,ADT 15.46, Bit Hrs 49.50,Jar Hrs 49.50.Max Gas 1,353 units.Monitor well,breathing.Lost about 92 bbl for the day. Operation at 07.00 Drill 8.75"Production hole @ 23,409'MD. 24h Forecast Drill 8.75"Production hole F/23,195'to^24,046'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblga I) 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 hole F/21,072'to 21,526'MD(3,623'TVD)530 GPM,3,590 PSI,140-160 RPM,WOB 8-15K, — TQN 19-20K,TQF 13-14K,HST 228K,SLK 80K,ROT 140K.ECD 12.16 ppg,ADT 4.96,Bit Hrs 39.00,Jar Hrs 39.00.Max Gas 1,238 units.Monitor well,breathing. 06.00 12.00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/21,526'to 22,102'MD(3,618'ND)530 GPM,3,600 PSI,140 RPM,WOB 8-12K,TQN 19K,TQF 13-14K,HST 220K,SLK 80K,ROT 139K.ECD 12.19 ppg,ADT 3.29,Bit Hrs 42.29,Jar Hrs 42.29.Max Gas 282 units.Monitor well,breathing.Lost about 24 bbl for tour. SPR @ 21,728'MD(3,618'ND)W/9.2 ppg MW MP#1 20-440,30-530 MP#2 20-440,30-530 MP#3 20440,30-530 12:00 18'00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/22,102'to 22,755'MD(3,636'ND)525 GPM,3,640 PSI,140-160 RPM,WOB 8-14K, TON 21-22K,TQF 13-15K,HST 225K,SLK 80K,ROT 139K.ECD 12.20 ppg,ADT 2.90,Bit Hrs 45.19,Jar Hrs 45.19.Max Gas 1,353 units. SPR @ 22,662'MD(3,634'TVD)W/9.2 ppg MW MP#1 20-490,30-580 MP#2 20-490,30-580 MP#3 20-490,30-580 18 00 00.00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/22,755'to 23,195'MD(3,649'ND)522 GPM,3,620 PSI,140-160 RPM,WOB 6-15K. TON 21K,TOP 13-15K,HST 225K,SLK 80K,ROT 138K.ECD 12.16 ppg,ADT 4.31.B0 Hrs 49.50,Jar Hrs 49.50.Max Gas 974 units.Monitor well,breathing.Lost about 68 bbl for tour. 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 Greg Parker ENI Marls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 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@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(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15.770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 f Eni E&P Division Well Name: v z EN!Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUO •2 in,II n Date:12/6/2014 - Report#: 32 API/uwl 50-629-23531-00-00 II page 1 of 1 Wellbore name. SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(05) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 28.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3.617.7 867.00 11.98 72.4 107.0 -9.0 Partly Cloudy-34' NNE @ 20 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/23,195'to 24,062'MD(3,632'ND)515 GPM,3,590 PSI,140 RPM,WOB 8-10K,TON 19-20K,TQF 15-16K,HST 235K,SLK 80K,ROT 140K ECD 12.23 ppg,ADT 11.98, Bit Hrs 61.52,Jar Hrs 61.52.Max Gas 754 units.Monitor well,breathing.Lost 49 bbl total while drilling.Perform final survey as per Schlumberger MWD.down link as per DD.Monitor breathing at TD. Start weighting up Faze Pro F/9.25 ppg to 9.4 ppg during CBU and back reaming.BROOH as per K&M schedule,CBU for one stand F/24,062'to 23,971'MD 535 GPM.BROOH as per K&M schedule F/ 23,940'to 22,571'MD.535 GPM,3,775 PSI,130-140 RPM,TQF 14-16K,HST 210K,SLK 80K,ROT 139K Monitor well for breathing after 5 stands.Lost 85 bbl to formation during BROOH. Operation at 07.00 BROOH at 20,750'MD. 24h Forecast BROOH as per KW BROOH schedule. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Dam. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/23,195'to 23,606'MD(3,655'TVD)530 GPM,3,690 PSI,140 RPM,WOB 8-10K,TON 19-20K,TQF 15-16K,HST 240K,SLK 80K,ROT 139K.ECD 12.26 ppg,ADT 4.63,Bit Hrs 54.13,Jar Hrs 54.13.Max Gas 753 units.Monitor well,breathing. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/23,606'to 23,800'MD(3,643'ND)525 GPM,3,670 PSI,140-175 RPM,WOB 8-17K, TON 19-27K,TQF 15-17K,HST 230K,SLK 80K,ROT 139K.ECD 12.18 ppg,ADT 4.61,Bit Hrs 58.74,Jar Hrs 58.74.Max Gas 435 units.Monitor well,breathing.Total tour loss 48 bbl. SPR(023,689'MD(3,653'ND)W/9.25 ppg MW MP#1 20-480,30-570 MP#2 20-480,30-570 MP#3 20-480,30-570 12:00 15:30 3.50 15.50 DRILL E 3 P PJSA Drill 8.75"Production hole F/23,800'to 24,062'MD(3,632'ND)515 GPM,3,590 PSI,140 RPM,WOB 8-10K,TON 19-20K,TQF 15-16K,HST 235K,SLK 80K,ROT 140K.ECD 12.23 ppg,ADT 2.74,Bit Hrs 61.52,Jar Hrs 61.52.Max Gas 754 units.Monitor well,breathing. SPR @ 24,062'MD(3,632'ND)W/9.4 ppg MW MP#1 20-480,30-580 MP#2 20-480,30-580 MP#3 20480,30-580 15:30 16:00 0.50 15.00 DRILL E 11 P PJSA Perform final survey as per Schlumberger MWD,down link as per DD.Monitor breathing at TD. 16:00 18:00 2.00 18.00 DRILL E 6 P PJSM Start weighting up Faze Pro F/9.25 ppg to 9.4 ppg during CBU and back reaming.BROOH as per K&M schedule, CBU for one stand F/24,062'to 23,971'MD 535 GPM,3,775 PSI,130-140 RPM,TQF 17-18K,HST 230K,SLK 80K,ROT 138K. 18:00 00:00 6.00 24.00 DRILL E 6 P PJSA BROOH as per K&M schedule F/23,940'to 22,571'MD.535 GPM,3,775 PSI,130-140 RPM,TQF 14-16K,HST 210K,SLK 80K,ROT 139K.Monitor well for breathing after 5 stands.Lost 85 bbl to formation during BROOH. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnllinggenipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 • Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative ,Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 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@doyondrilting.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(MIKE) Run Date CASING 9 5/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2.461.9 liffi* Eni E&P DivisionWell Name:, N2 EN!Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • APIIUWI:50-629-23531-00-00 2^ Date:12/7/2014 - Report#: 33 II II page 1 of 1 Wellbore name: SI26-NW2 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 5126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 29.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 102.0 -13.0 Partly Cloudy-42' NNE @ 21 MPH Daily summary operation 24h Summary BROOH as per K&M schedule F/22,571'to 19,800'MD.Encountered tight area,higher torque and slight packing off @ 19,800'to 19,771'MD.CBU 2X 510 GPM,3,300 PSI,140 RPM,TQF 18-20K,HST 257K,SLK 80K,ROT 139K.BROOH as per K&M schedule F/19,771'to 13,797'MD.No signs of over torque or packing off seen going through Shoe @ 15,750'MD.550 GPM,3,180 PSI,120-140 RPM, TQF 10-11K.HST 190K,SLK 100K,ROT 142K.Monitor well @ 15,745'MD,slight breathing is occurring.Lost 70 bbl to formation today. Operation at 07.00 BROOH at 12,020'MD. 24h Forecast BROOH as per K&M BROOH schedule. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9,40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05.00 5.00 5.00 DRILL E -6 P PJSA BROOH as per K&M schedule F/22,571'to 19,800'MD.530 GPM,3,600 PSI,140 RPM,TQF 18K,HST 258K,SLK 80K,ROT 139K.Monitor well,breathing is occurring. 05:00 10.00 5.00 '10.00 DRILL E 7 P -PJSA Encountered tight area,higher torque and slight packing off @ 19.800'to 19,771'MD.CBU 2X 510 GPM,3,300 PSI, 140 RPM,TOP 18-20K,HST 257K,SLK 80K,ROT 139K. 10:00 12:00 2.00 12,00 DRILL E 6 P PJSA BROOH as per K&M schedule F/19,771'to 18,900'MD.550 GPM,3,725 PSI,140 RPM,TQF 18K,HST 217K,SLK 80K,ROT 139K.Monitor well.breathing is occurring.Lost 56 bbl for tour. 12:00 18:00 6.00 18.00 DRILL E '6 P PJSA BROOH as per K&M schedule F/18.900'to 15,941'MD.550 GPM,3,260 PSI,140 RPM,TQF 12-13K.HST 200K, SLK 80K,ROT 140K. 18:00 00:00 6.00 24.00 DRILL E '6 P PJSA BROOH as per K&M schedule F/15,941'to 13,797 MD.No signs of over torque or packing off seen going through Shoe @ 15,750'MD.550 GPM,3,180 PSI,120-140 RPM,TQF 10-11K,HST 190K,SLK 100K,ROT 142K.Monitor well @ 15,745'MD,slight breathing is occurring.Lost 14 bbl for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com X907-685-0715 '715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 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(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2461.9 triff* Eni E&P Division Well Name: 042 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • APIIUW1:50-629-23531-00-00 2�" �', Date:12/8/2014 - Report#: 34 page 1 of 1 Wellbore name: S126-NW2 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI26-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 30.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3 617.7 0.00 104.0 -15.0 Clear WC-45° N @ 15 MPH Daily summary operation 24h Summary BROOH as per K&M schedule F/13,797'to 9,032'MD.550 GPM,2,650 PSI,120 RPM,TQF 10K,HST 150K,SLK 92K,ROT 128K.Reciprocate and rotate.CBU 5X and weight up F/9.4 ppg to 9.45 ppg. 550 GPM,2,650 PSI.Slip and cut drilling line(125'),Inspect Brakes,service and inspect TOS-8 and blocks.Pump 30 bbl Dry Job 11.1 ppg.Blow down TDS-8 and CIO handling Equip.over to 4.5". POOH 4.5"D.P.W/Elevators W/K&M schedule F/9,032'to 396'MD.PJSM W/all essential personnel.L/D BHA#5 as per Schlumberger DD and MWD.Slight wear to NM Stab,Sonic had stainless band cracked,TeleScope,ARC and Xceed showed slight wear.8.75"Bit grade 1,1,WT,A,X,IN.NO,TD. Clean and clear rig floor of all BHA#5 tools and Equip.Lost a total of 40 bbl to formation today. Operation at 07.00 RIH BHA#6 8.75"Hole Opener W/4.5"D.P.@ 2.097'MD. 24h Forecast P/U M/U BHA#6 8.75"Hole Opener BHA.RIH W/4.5"and 5"D.P. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 09:30 9.50 9.50 DRILL E 6 P PJSA BROOH as per K&M schedule F/13,797'to 9,032'MD.550 GPM,2,650 PSI,120 RPM,TQF 10K,HST 150K,SLK 92K,ROT 128K. 0930 13:30 4.00 13.50'DRILL E 7 P PJSM Reciprocate and rotate.CBU 5X and weight up F/9.4 ppg to 9.45 ppg.550 GPM,2,650 PSI,120 RPM,TQF 10K, HST 150K,SLK 92K, 13:30 15:00 1.50 15.00'DRILL E 25 P 'PJSM Slip and cut drilling line(125'),Inspect Brakes,service and inspect TDS-6 and blocks. 15:00 1530 0.50 15.50 DRILL E 7 P 'PJSA Pump 30 bbl Dry Job 11.1 ppg.Blow down TDS-8 and CIO handling Equip.over to 4.5". 15:30 21:00 5.50 21.00 DRILL E 4 P PJSA POOH 4.5"D.P.W/Elevators W/K&M schedule F/9,032'to 396'MD.HST 100K,SLK 100K. 21:00 23:30 2.50 23.50 DRILL E 4 P -PJSM W/all essential personnel.L/D BHA#5 as per Schlumberger DD and MWD.Slight wear to NM Stab,Sonic had stainless band cracked,TeleScope.ARC and Xceed showed slight wear.8.75"Bit grade 1,1.WT,A,X,IN,NO,TD. Monitor well for 20 Min.,static. 23.30 00.00 0.50 24.00 DRILL E 20 P 'PJSA Clean and clear ng floor of all BHA#5 tools and Equip. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnIling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 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 hg15@doyondrilfing.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 19.1 15.750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15..770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 01111 Eni E&P Division .} Well Name: W2 ENI Petroleum Co.Inc. Daily Report 0Well Code:28997 Field Name:NIKAITCHUO • APIIUWI:50-629-23531-00-00 2 II II, Date:12/9/2014 - Report#: 35 page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-N702 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 31.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 104.0 -14.0 Clear WC-42° N @ 18 MPH Daily summary operation 24h Summary M/U BHA#6 and RIH to 22,283'.Began reaming©19.011'@ 113 gpm,500 psi,70 rpm. Operation at 07.00 Reciprocate and circulate on bottom while mixing 9.5 ppg FazeAway Breaker fluid. 24h Forecast Ream to 24,062'and CBU while mixing Breaker fluid.PJSA with all personnel and pump Breaker @ 3 bpm as per MI.Drop rabbit and POOH as per K&M schedule to 15.500'. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dar(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00-00 00:30 - 0.50 0.50 DRILL E 20 P PJSA Continue to clear and clean rig floor.Mob BHA#6 to rig floor. 00:30 01:00 0.50 1.00 DRILL E 25 P PJSA Service rig. 01:00 02:30 1.50 2.50 DRILL E 4 P PJSA P/U&M/U BHA#6 and RIH to 203'.80k puw,86k sow.CIO handling equipment. 02:30 12:00 9.50 12.00 DRILL E 4 P PJSA RIH w/BHA#61011,548',165k puw,88k sow,fill pipe as required. 12:00 18:30 6.50 18.50 DRILL E 4 P PJSA RIH f/11,548'-10,011',215k puw,N/A sow. 18:30 00:00 5.50 24.00 DRILL E 4 P PJSA At 19,011'started reaming in hole,no slack off weight to 22,283',113 gpm,500 psi,70 rpm,220k puw,140k rotw,14 -15k tq. 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 Dolling Supv. SIDDrilling@enipetroleum.corn 907-685-0715 907-320-0058 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyon15@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 Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondnlling.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(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 Eni E&P Division Well Name: W2 Pi* ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUQ • Date:12/10/2014 - Report#: 36 API/UWI:50 629-23531-00-00 e i[I page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33,94 Rig Information Contractor Rig Name Rig Type DOYON _ _ _ RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(fiKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 32.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 104.0 0.0 Scattered Clouds WC W @ 5 MPH -47, Daily summary operation 24h Summary .. Ream to 24,062'and circulate and condition mud while budding Breaker.Pump 650 bbls of 9.5 ppg FazeAway Beaker,179 bbls of 9.4 ppg FazePro mud,35 bbls of 11.2 ppg dry job and clear lines w/10 bbls of FazePro mud.Drop 2.98 drift and POOH to 20,603'as per K&M Schedule. Operation at 07.00 POOH to 17,750'MD 24h Forecast Cont.to POOH to 15,500'and displace well to 9.1 ppg KCL brine.Clean surface equipment and Cut&slip drill line.POOH and UD BHA#6. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 P PJSA Reaming in the hole f/22.283'-24,062'@ 100 gpm,475 psi,70 rpm.16-17k tq,215k puw,145k rotw.Monitor well- static. 03:00 -07.30 4.50 7.50 DRILL E 7 P PJSA Circulate and condition mud while rotating and reciprocating @ 420 gpm,2500 psi,120 rpm,19k-20k tq,215k puw., 145k rotw.Sim Ops:Building FazeAway Breaker at Mud Plant 07:30 13.30 6.00 13.50 DRILL E 7 P PJSA held with all personnel on spotting Breaker while rotating and reciprocating.Pump 650 bbls of 9.5 ppg FazeAway Breaker,179 bbls 9.4 ppg FazePro mud,35 bbls 11.2 ppg dry job and chase w/10 bbls of 9.4 ppg FazePro to clear lines @ 3 bpm,420 psi,30 rpm,17k tq,140k rotw.Note.Clear lines from Mud Plant to rig w/35 bbls of 9.1 ppg brine.23 bbls burly fluid losses. 13:30 14:00 0.50- 14.00 DRILL ''E 4 P PJSA UD working single and blow down top-drive.Service rig and move mud for cleaning pits.Monitor well-static. 14:00 00:00 10.00 24.00 DRILL E 4 P PJSA Drop 2.98"drift and POOH on elevators f/24.060'-20,603',200k puw.78 bbls Tourly 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 Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Davide Simeone ENI Project Manager Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon 15@e nipetroleum.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 Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 19.1 15,750,0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 f� Eni E&P Division Name:ame: /W2 ENI Petroleum Co.Inc. Daily Repo).,}` Well Code:28997 Field Name:NIKAITCHUQ 2^ Date:12/11/2014 - Report#: 37 API/UWI:50-629-23531-00-00 II II ii page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5I26-NW2 DRILLING 11/9/2014 23.989.5 3.613.8 24,061.00 202.75 118.7 33.00 Daily Information End Depth(f1KB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 105.0 -9.0 Light Snow WC-32° ENE @ 9 MPH Daily summary operation 24h Summary POOH f/20,603'-15,500'.Circ.&condition mud while preping for KCL Brine displacement.Displace well to 9.1 ppg KCL Brine.Cleaning surface mud equip,while cut&slip drill line.Cont.to POOH f/ 15,500'-9961'. Operation at 07.00 POOH @ 6,482'MD 24h Forecast Cont.to POOH w/5"DP,CIO handling equip.and POOH w14.5"DP.L/D BHA#6.Prepare to P/U and run 4.5"injection liner. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 10.30 10.50 10.50 DRILL E 4 P PJSA POOH on elevators as per K&M schedule 1/20,603'-15,500',180k puw,95k sow. 10:30 12.30 2.00 12.50 DRILL E 7 P PJSA Circulate ansd condition mud @ 213 gpm,670 psi,30 rpm,9-10k to 180k puw,95k sow,143k rotw,Prep.for KCL Brine displacement.83 bbls Tourly fluid losses. 12:30 16.30 4.00 16.50 DRILL E 7 P PJSA with all personnel for brine displacement.Pump 40 bbls LVT,96 bbls citric interface pill @ 3 bpm,420 psi.Pump 1110 bbls of 9.1 ppg KCL Brine @ 6.5 bpm,900 psi ICP/540 psi FCP,30 rpm.142k rotw,10-14k tq while reciprocating. 16:30 18:30 2.00 18.50 DRILL E 25 P PJSA Cut and slip 72'of drill line,inspect and adjust brakes while cleaning surface mud equipment.Monitor well-static. 18:30 00:00 5.50 24.00 DRILL E 4 P PJSA POOH f/15,500'-9961',169k puw,89k sow.32 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 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Davide Simeone ENI Project Manager Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@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.cum 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Dnlling 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(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 19.1 15,750.0 11/28/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak OH Pressure(psi) 15,7700 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 • Eni E&P Division .. Well Name: W2 rill* ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUO • Date:12/12/2014 - Report#: 38 APIIUWI:50 629-23531-00-OS e i page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(it) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3.613.8 24,061.00 202.75 118.7 34.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 108.0 -11.0 Light Snow WC-26` SW @ 7 MPH Daily summary operation 24h Summary POOH and rack back 5"&4.5"DP.R/U GBR liner running equip.Hold Liner safety meeting and P/U&M/U 4.5"L80 11.6#H521 liner as per tally and RIH to 8472'(Total of 208 jts.).R/D CRT equip.& 0/0 handling equip.to 5". Operation at 07.00 RIH W/4.5"Liner @ 11.407'MD 24h Forecast M/U Baker Liner hanger assy,service and RIH w/liner on 5"DP to 24,062'.P/U to setting depth and set Liner hanger/packer as per Baker.Test packer and release from it.POOH. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 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 POOH f/9961'-8838',160k puw,95k sow. 01:30 07.00 0.50 2.00 DRILL E 20 P PJSA Change over handling equipment f/5"to 4.5".L/D Stand#191 w/rabbit. 02:00 0730 5.50 7.50 DRILL E 4 P PJSA POOH w/4.5"DP 1/8838'-203',90k puw/sow. 07:30 08:00 0.50 8.00 DRILL E 4 P PJSA C/O handling equipment to 5"and L/D HWDP and BHA#6. 08:00 09:30 1.50 9.50 DRILL G '20 P PJSA Bnng Liner running equipment to ng floor and R/U as per GBR. 09:30 12:00 2.50 12.00 DRILL G 4 P PJSA Hold Liner running safety meeting and P/U&M/U 4.5"L80 11.6#H521 Injection Liner as per tally and RIH f/0-569'. 85k puw/sow.26 bbls burly fluid losses. 1200 18.00 6.00 18.00 DRILL G 4 P PJSA M/U and RIH wl 4.5"Liner f/569'-4038',105k puw,102k sow. 18:00 23.30 5.50 23.50 DRILL G 4 P PJSA M/U and RIH w/4.5"Liner f/4038'-8472',112k puw,92k sow Total of 208 jts.52 bbls Toady fluid losses. 23.30 0000 ' 0.50 24.00 DRILL G 20 P PJSA R/D Volant tool and bail extensions.C/O handling equipment to 5". 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. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Ben Perry ENI Senior Dnlling 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 HOE 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 ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 j Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 15,546.3 24,052.0 12/13/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2.461.9 • fill* i* Eni E&P Division Well Name: .W2 ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO • Date:12/13/2014 - Report#: 39 API/UWI:50-629-23531-00-00 2" " page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) SI26-NW2 DRILLING 11/9/2014 23.989.5 3,613.8 24,061.00 202.75 118.7 35.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 110.0 -13.0 Clear WC-29` NE @ 7 MPH Daily summary operation 24h Summary M/U Baker liner hanger/packer and service.RIH w/liner on 5"DP to 19,629'.Rotate liner in hole f/19.629'-24.062'.Pull up to setting depth and Baker set hanger and packer w/4000 psi.Test packer to 1500 psi for 10 charted mins.POOH LDDP to 11,825'. Operation at 07.00 POOH LDDP @ 5,7.53'MD D 24h Forecast Cont to LDDP and Baker running tool.Clear and clean rig floor.R/U and test BOPE as per AOGCC regs. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(Br) Dur(Br) Phase Opr. Act. Plan Oper.Descr. 00.00 00:30 0.50 0.50 DRILL G 20 P PJSA Clear and clean rig floor. 00.30 01:30 1.00 1.50 DRILL G 20 P PJSA M/U Baker SLZXP LTP.Service and install pal mix and let set. 01'.30 02:00 0.50 2.00 DRILL G 7 P PJSA P/U 8 M/U 3-5"DP and circulate @ 212 gpm.330 psi.Blow down Top-drive. 02:00 06:00 4.00- 6.00 DRILL G 4 P PJSA RIH w/Liner on 5"DP f/8613'-15,700',172k puw,92k sow.140k rotw,@ 212 gpm,400 psi,30 rpm,10.5k tq. 06.00 09:00 3.00 9.00 DRILL G 4 P PJSA RIH w/Liner f/15,700'-19,629'.192k puw,78k sow. 09.00 12:00 3.00 12.00 DRILL G 4 P PJSA Rotate in hole w/Liner f/19,629'-21,589'@ 30 rpm,15k tq,206k puw.N/A sow,145k rotw.41 bbls.Tourly fluid losses. 12:00 16:00 4.00 16.00 DRILL G 4 P PJSA Continue to rotate in hole f/21,589'-24,062'@ 30 rpm,13-18k tq.240k puw,147k rotw. � 16:00 18:30 2.50 18.50 DRILL G 19 P PJSA Drop 1.625"Baker ball and pump @ 3 bpm,600 psi,slow to 2 bpm,390 psi,slow to 1.5 bpm,220 psi.Seat ball and E pressure to 2500 psi to set packer,increase to 3000 psi and hold for 5 min.Slack off to 90k and inc to 3500 psi to release 1 /� running tool.Increase to 4000 psi and bleed off pressure.Shut top rams and pressure up annulus to 1500 psi for 10 yr ( charted mins.Bleed off pressure.Liner shoe @ 25.052',Top of Liner @ 15,546'. u) 18.30 19:00 0.50 19.00 DRILL G 4 P PJSA Pull 1 stand and rack in derrick to pull running tool out of liner.Blow down Top-drive.kill line and mud pump. (4,� / 19:00 0000 5.00 24.00 DRILL G 4 P PJSA POOH LDDP tol1,825'.185k puw,90k sow.36 bbls.Tourly 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. SIDDnIling@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 Muffs 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 Dulling 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(RKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 15,546.3 24,052.0 12/13/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 f"I* Eni E&P DivisionWell Name:ENI ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUQ • API/UWI:50-629-23531-00-00 2^ Date:12/14/2014 - Report#: 40 In ') page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) S126-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7, 36.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 110.0 -12.0 Light Snow WC-32° WNW @ 12 MPH Daily summary operation 24h Summary POOH LDDP and Baker Liner running tool.Vetco pull wear bushing and install test plug.R/U to test BOPE.Test BOPE as per AOGCC specs.Tests witnessed by Matt Herrera.RIH WI DP and POOH LDDP. Operation at 07.00 LDDP 24h Forecast Cont.w/LDDP.Pull wear bushing and prep.to run 4.5"completion tubing.P/U and M/U 4.5"completion as per tally and RIH to locator.Space out and M/U pups and land tubing string. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08.00 8.00 8.00 DRILL G '4 P PJSA POOH LDDP f/11.825'.UD Baker Liner running tool.40 ffs.of 5"DP marked for inspection. 08:00 08.30 0.50 8.50 DRILL G 20 P PJSA Clear and clean ng floor. 08:30 09:30 1.00 9.50 DRILL C 20 P PJSA Pull wear bushing and install test plug as per Vetco. 09:30 12.00 2.50 12.00 DRILL C 20 P PJSA R/U for BOPE Testing.R/U line to IA to monitor losses during BOPE testing.27 bbls.Tourly fluid losses. 12:00 13.00 1.00' 13.00 DRILL C 20 P PJSA Cont.R/U for BOPE testing and perform shell test to 3500 psi. 13:00 17.00 4.00 17.00 DRILL C 12 P PJSA Test BOPE w/4.5"test ff.as per AOGCC specs.Tests witnessed by Matt Herrera. 17:00 1730 0.50 17.50 DRILL C 20 P PJSA RID and Blow down test equipment. 17:30 18:00 0.50 18.00 DRILL C 20 P PJSA Pull test plug and install wear bushing as per Vetco. 18:00 18:30 0.50 18.50 DRILL E 20 P PJSA RIH 1 stand of 5"and L/D same.C/O handling equipment to 4.5". '18:30 21:30 3.00 21.50 DRILL E 4 P PJSA M/U mule shoe and XO and RIH w/4.5"DP to 4744',130k puw,120k sow. 21:30 00:00 2.50 24.00 DRILL E 4 P PJSA Monitor well-falling slightly.POOH LDDP f/4744'-2853',125k puw,120k sow.29 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 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 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(ftKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 15.546.3 24,052.0 12/13/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07f 2,461.9 Eni E&P Division Name:, W2 � W ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name: NIKAITCHUO • �pfla* Date:12/15/2014 - Report#: 41 page 1 of 1 APIIUWI:50-629-23531-00-00 t i II IIWellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53,72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SI26-NW2 DRILLING 11/9/2014 23,989.5 3613.8 24,061.00 202.75 118.7 37.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 24,062.0 3,617.7 0.00 112.0 -10.0 Overcast WC-26° NNE @ 8 MPH Daily summary operation 24h Summary LDDP all drill pipe.Release rig from Drilling AFE#6927. Operation at 07.00 Last Drilling Report 24h Forecast Rig on Completion AFE#6928. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 4 P PJSA POOH LDDP 1/2853'. 02:30 03:30 1.00 3.50 DRILL E 4 P PJSA RIH w/4.5"DP to 3625',128k puw,120k sow. 03:30 05:00 1.50 5.00 DRILL E 25 P PJSA Cut and slip 102'drilling line and service rig. 05:00 08:00 3.00 8.00 DRILL E 4 P PJSA POOH LDDP,XO and mule shoe.30 bbls.Tourly 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 Ben Perry ENI Senior Dulling 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 Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 15,546.3 24,052.0 12/13/2014 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 ' i..- Eni E&P Division Well Name:. V2 EN/Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO • APIIUWI:50-629-23531-00-00 2 Date:12/15/2014 - Report#: 1 ii " page 1 of 1 Wellbore name: SI26-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(fl) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SI26-NW2 COMPLETION 37.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 112.0 -10.0 Overcast WC-26` NNE @ 8 MPH Daily summary operation 24h Summary R/U and RIH w/4.5"injection completion as per tally to 11,492'. Operation at 07.00 RIH WI Injection Completion @ 14,118'MD 24h Forecast Cont.to RIH w/4.5"tubing to TOL and work down to Fluted locator sub no-go.Space out and M/U pup jts.and Tubing hanger.Drain and clean stack and land tubing string as per Vetco.RILDS and test hanger seals to 5000 psi for 10 min.R/U and pump down string to close auto fill and check for leaks.Pressure up and set packer @ 2600 psi and chart for 30 min.Bleed pressure to 2000 psi and test IA to 2500 psi for 30 charted mins.Bleed IA to 0 and pressure tubing to 4400 psi to shear open the Mirage plug.Shear out GLM valve @ 2500 psi.Pull landing jt.and set BPV.N/D stack and install tree and test. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 08:00 08.30 0.50 0.50 COMP C 20 P PJSA Pull wear bushing as per Vetco. 08:30 09:00 0.50 1.00 COMP K 20 P PJSA R/U Volant CRT and associated equipment as per GBR. 09:00 12:00 3.00 4.00 COMP K 4 P PJSA with all personnel.P/U.M/U and RIH w/4.5"12.64 L80 H563 injection tubing as per tally to 1053',90k puw/sow. Note Bakerlok all assy.below HS Ret packer.7 bbls.fluid losses for RIH w/tubing. 12:00 18:00 6.00 10.00 COMP K 4 P PJSA RIH w/4.5"tubing f/1053'-6379',112k puw.100k sow. 18:00 00:00 6.00 16.00 COMP K 4 P PJSA RIH w/4.5"tubing 1/6392'-11,492',120k puw,93k sow.28 bbls Toury fluid losses. Daily Contacts Position Contact Name Company Title I E-mail Office Mobile Eni representative Jack Keener •ENI Senior Dulling 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 Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Em representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@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(RKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 15,546.3 24,052.0 12/13/2014 + Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 15,770.0 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 Eni E&P Division Wel Report Nm ae:, ,W2 /I "" ' ENI Petroleum Co.Inc. Daily Report Well Code:28997 Field Name:NIKAITCHUO • API/UWI:50-629-23531-00-00 2^ Date:12/16/2014 - Report#: 2 II II - page 1 of 1 Wellbore name: S126-NW2 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.72 13.10 36.75 33.94 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0126-N302 COMPLETION 38.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 111.0 -10.0 Overcast WC-39° NNE @ 29 MPH Daily summary operation 24h Summary Run 4.5"inj.liner into Baker liner sleeve and no-go out @ 15,565'.Space out tubing string and land Vetco hanger and RILDS.WIeg @ 15,563'.Test hanger seals to 5000 psi.R/U and pressure up to close Auto fill,set packer @ 3500 psi(tubing integrity test),Pressure IA to 2500 psi(IA integrity test),Pressure tubing to 4650 psi and shear Mirage plug,Pressure IA to 2650 psi and shear GLM valve. Set BPV and N/D BOPE.N/U tree and test void and tree to 5000 psi.Freeze protect IA w/120 bbls diesel.R/U Halliburton wire line equip,lest lubricator to 1000 psi and RIH set catcher and Run#2 to retrieve shear valve.Release rig from Well SI26-NW2 @ 2400 hrs. Operation at 07.00 RDMO Well SI26-NW2.(Final Completion Report) 24h Forecast Complete shear valve retrieval,install new valve and test to 500 psi.Retrieve catcher and secure well.RDMO.Accept Rig to SP05-FN7 RWO @ 0001 hrs. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) p 10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Diner. 00:00 05:00 5.00 5.00 COMP K 4 P PJSA M/U and RIH w/4.5"injection liner f/11,492'-15,565'as per tally,140k puw,88k sow.Set on no-go.Space out for landing hanger. 05:00 06:00 1.00 6.00 COMP K 4 P 'PJSA POOH L/D Jts.404,403 and 402.P/U 3-space out pups car total length of 17.51',jt#402 and XO pup. 06:00 06:30 0.50 6.50 COMP K 20 P PJSA UD GBR CRT and equipment.R/U 4.5"YC elevators. 06:30 08:30 2.00 8.50 COMP K 4 P PJSA M/U Vetco tubing hanger and landing jt.Install penetrator and inspect hanger.Land tubing w/140k puw,88k sow. Wleg @ 15,563'.RILDS and test upper and lower hanger seals to 5000 psi for 10 min. 08:30 11:00 2.50 11.00 COMP K 12 P PJSA R/U and pressure tubing to 1200 psi for 5 min to close Auto fill.Inc.pressure to 3500 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.Bleed IA pressure to 0 and C pressure tubing to 4650 psi to shear Mirage plug.Bleed tubing to 0.Pressure annulus to 2500 psi,2650 psi to shear GLM valve.All testing was charted. 11:00 12:00 1.00 12.00 COMP K 20 P PJSA Blow down all lines and R/D all testing equipment. 12:00 12:30 0.50 12.50 COMP C 20 P PJSA Pull landing jt.and set BPV as per Vetco. 12:30 14:00 1.50 14.00 COMP C 20 P PJSA N/D bell nipple,BOPE and high pressure riser. 14:00 15:30 1.50 15.50 COMP C 12 P PJSA Clean well head,N/U tree and test void to 5000 psi f/10 min. 15:30 16:30 1.00 16.50 COMP C 20 P PJSA Pull BPV.install TWC,bleeder and gauge on tree. 16:30 18:00 1.50 18.00 COMP C 12 P PJSA Fill tree w/diesel,R/U and test to 500 psi f/5 min.and 5000 psi f/15 min. 18:00 19:30 1.50 19.50 COMP K 9 P PJSA Freeze protect IA w/120 bbls of diesel @ 1.5 bpm,1400 IP/1120 FP. 19:30 22:30 3.00 22.50 COMP R 20 P PJSA w/Hallibuton Wire line.R/U equipment.Sim Ops;Move Pump#3,R/D for rig move. 22:30 00:00 1.50 24.00 COMP R 12 P PJSA Pressure test lubricator to 1000 psi.RIH and set catcher.POOH change tools and RIH to retrieve shear valve.Sim Ops;R/D and moving ng mans.Release rig from Well SI26-NW2 @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruno Ravagli 'ENI 'Dri Superintendent Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni 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 akrigclerksdoyon15@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(ftKB) Bottom(ftKB) Run Date LINER 41/2 3.960 L80 15,546.3 24,052.0 12/13/2014 Last Leakoff Test Depth(t1KB) TVD MKS) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 15 770.C 3,625.08 FAZE PRO 9.25 720.0 13.07 2,461.9 in q� 1p o� 0 `,,,,, --C.'72 ;tAoa NBFV^tRA YEg1gg.-1 von-aa to3Amriyb�10'�, §10vovff mcy'Q�N`'Q�� 9N't�"+i�°p'tte' otyp n ' NN1~VMM S.22lf 2 M.M2 YM 1ffRPS 122222 n1NONnN sn Nt(N iiE§F, Fa 2 n1.nnl0. nnnnn nnnnn nnnnn wnnnn n.nnn noolo10` On000 00 m LO L N m Mm ONN ONN NNOD O 0 D. 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NNa ANN '6 ❑ E t7 02 ; osoa B cQ ` 72 222.1'2 Af�NN 22222 002227 N20Ne 0p2220 0000QE ^pppC20 ONm 7p00200MMMMM MMMMM MMMMM MMMMM MMMMM MMMMM + t7p ♦00 O 2 . , ppf��177 {{77 �1pp 11p� �(Vy mm co •3 o � 22282 Ma�Om 2rm41A 42•112022r 222102 22m222 232A O q y 228,22 22282 222a2o22 222.2 220222 2220212 .'Arnm t a N ¢ C . 3 d y U gr 220002V1:0 Unman o`t♦pN2°2NVV 2222'ry a,(p$V c1`.�i2 1272222 2$712 i13- NNNNN NN0NC) 0NNNN NNNNN NNNN NNNNN NNNN N 0 M M M 2 8 2 2 O m cE g N 22 86 a y s . C C 3E 2 , V N 2 (] • r ENI US Operating Co.Inc. CASING&CEMENTING REPORT Lease&Well No. SI26-NW2 Date 12-Nov-14 County GPB State Alaska Supv. Simson CASING RECORD-Surface casing • TD 2846.00 Shoe Depth: 2834.00 PBTD: MD/ND Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 13-3/8 BTC WTF 2.45 2,834.00 2,831.55 2 13-3/8 68 L-80 BTC Tenaris 78.89 2,831.55 2,752.66 Float Collar 13-3/8 BTC WTF 1.48 2,752.66 2,751.18 69 13-3/8 68 L-80 BTC Tenaris 2,710.09 2,751.18 41.09 Pi&Hanger 13-3/8 68 L-80 BTC Tenaris 4.03 41.09 37.06 Totals 2,796.94 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 X No Liner hanger test pressure: Centralizer Placement: 1 centralizer 5'&8'above shoe,10'above FC,1 each joint up to 2368'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): 440/892 Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: 12.5 crete Yield(Ft3/sack): 1.56 Density(ppg) 12.5 Volume (BBLs/sacks): 63/228 Mixing/Pumping Rate(bpm): 3 a N Post Flush(Spacer) Type:H2O Density(ppg) 8.4 Rate(bpm): 5 Volume: 10 re LL Displacement: Type: Mud Density(ppg) 9.5 PPG Rate(bpm): 5 Volume(actual/calculated): 402/400 FCP(psi): 500 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 1000 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: 96 Cement In Place At: 11:00 Date: 11/12/2014 Estimated TOC: Surface Method Used To Determine TOC: Visual 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): a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 1— u) Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: yDisplacement: Type: \ _Density(ppg) . \ Rate(bpm): \ Volume(actual/calculated): \ FCP(psi): \ Pump used for disp: Rig pump#1 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: Visual Remarks: a EN!US Operating Co.Inc. CASING&CEMENTING REPORT Lease&Well No. 5126-NW2 Date 29-Nov-14 County GPB State Alaska Supv. Chant CASING RECORD-Intermediate casing TD 15750.00 Shoe Depth: 15740.25 PBTD: MD/ND Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 9-5/8 Hydril 563 Davis-Lynch 501 2.72 15,740.25 15,737.53 2 9-5/8 40 L-80 Hydril 563 Tenaris 80.97 15,737.53 15,656.56 Float Collar 9-5/8 Hydril 563 Davis-Lynch 700 3.02 15,656.56 15,653.54 388 9-5/8 40 L-80 Hydril 563Tenaris 15,623.54 15,653.54 30.00 Totals Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: Guide Casing Crew: Tesco Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 1 centralizer S'above shoe,10'above FC,1 each joint up to 13,5861,1D 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): 223/802 Mixing/Pumping Rate(bpm): 4 Tail Slurry Type: N/A Yield(Ft3/sack): N/A 0 Density(ppg) N/A Volume (BBLs/sacks): N/A Mixing/Pumping Rate(bpm): N/A vagi Post Flush(Spacer) ( Type:H2O Density(ppg) 8.4 Rate(bpm): 5 Volume: 10 rc LL Displacement: Type: Mud Density(ppg) 9.5 PPG Rate(bpm): 6 Volume(actual/calculated): 1176/1187 FCP(psi): 550 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 1050 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns during job 100 Cement returns to surface? Yes x No Spacer returns? Yes x No Vol to Surf: 0 Cement In Place At: 13:00 Date: 11/29/2014 Estimated TOC: 13,188 ft Method Used To Determine TOC: Calculated and volumes pumped 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 u, Type: Yield(Ft3/sack): a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 1- 0 Post Flush(Spacer) 0 0 Type: Density(ppg) Rate(bpm): Volume: w Displacement: ui 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: 2.\�-'57 2.5226 SchlumbergerTransmittal#: 06JAN15-SPO1 PetroTechnical Services PTS Answer Products DATA LOGGED :vi K.BENDER Customer: ENI Operating Co. Inc.Alaska Dispatched To: Makana Bender Well No: S126-NW2 Date Dispatched: 6-Jan-15 Job#: 13AKA0052 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product 4 Contents on CD N/A VISION*Resistivity 2"MD x x ---- ------ VISION*Resistivity 2"TVD x x RECEIVED VISION*Resistivity 5"MD x x VISION*Resistivity _5"TVDJAS 0 6 2015 x x AOGCC -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 Please sign and email a copy to: Please sign and email a copy to: andrew.buchanan(a�enipetroleum.com AlaskaPTSPrintCenter(cr�slb.com Attention:Andrew Buchanan Attention:Stephanie Pacillo Received By: - - ( Imo' QD .4... LA O W �� A ^R N m m m m R m r R bN M oo O mM r b r R R mMm, N m N R b b M N O-NNmNR ..,MN 1001MR NNRR 0o -M0 mO �NmYm OO bbmm ...MO 0o -NM M.....0bm, ObbmM ,o-mNR RmNm O.MNr M r mNRrm m. 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WMo \ ,_ N.-.- m r r.-MM tha 05.6 W 0)N 1-1- mmmm em 0000 E MMMMM MMMMM MMMMM MMMMM MMMMM MMMMM MMMM .0 C Woo) f � W N N W'00V di ° 0 0 ...m00, • • 07 > m J - N co CO m, - MvreO ANenW OrWm O00 44Oa r bC- 004W -a -W> am N NO a000m66 0000m 66666wmro 0004momri<: W mmmm mmmmo mWWWW WmWW WWm WWmmm mmm o n co h c U W N U p W MO mn :2224:12 O W m W m W o W W a W N N m M O n m 2248 OroO P r a n .:.,:r.-7,1,: me r 46.-Y6 <W�N 6.-6o.- ;;288O 0hro aM eOOWr 00W0) 4400)0) 40 0 N N N N N N NNN N N NNN( N N N N N N N N N N 2222 N N N N N N N. C .O e; O F 06 O E o N a U ul 0c. p c w2 O 0) 4 E EE c O . . 'c U .. p 4 2-52t�2 SchlumbergerTransmittal#: 19DEC14-SPO2 PetroTechnical Services DATA LOGGED PTS Answer Products /2-/2015 l.K.BENDER Customer: ENI Operating Co. Inc.Alaska Dispatched To: Makana Bender Well No: S126-NW2 Date Dispatched: 19-Dec-14 Job#: 13AKA0052 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product 1 Contents on CD N/A Answer Product: SonicVISION Best DT 15750' -24000' MD X x Digital Data N/A Contents on CD N/A ASCII/DLIS x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:PDF x —RECEIVED DEC 19 2014 AOGCC Please sign and email a copy to: Please sign and email a copy to: andrew.buchanan(d enipetroleum.com AlaskaPTSPrintCenter(i)slb.com Attention:Andrew Buchanan� Attention:Stephanie Pacillo Received By: 2a✓4K?.CLeJtov •- / ;," N d' x Y n a, U) W a al r O (9 ce ILI a W n r O Q. 0 a U I L Q LL } 0 w < < 0 LL •V ti.l W 0 U W 2 0 cn r-1 HN E Ei H a1 0- W ti Z alLT H W Q a1 �_ W > a ❑ Q Q Y W W V Z a Q J H to J W a • 0 Stn 2u1 < J a W H 2 W o Hm DM Q Z I— Z • •cn 0 N ^rr L0(N-I z0 < O w ^� H I l72 1 OF CO H a e V)a)Q I-a1 m . Tr ~ 0 W a a H W M 2W H M _I M 0 0 J < 0 m u3N. i -i i ' Da C❑ ❑❑ Q rn co c Q7ml-ucer. 2 a N o0 0 O _ mrn a)Qg5 E I _I H Q D a1 Q d oozw_Ozww LU to 0 < WC H O Lo-' I D I- > Y 7 N 0 o W^ am w 0 0 inN Z 0 m Y z Z E A cs 0 a1 Q U Ili 4 a �� H2 O O HHJH Y J k u t(�� re op D0 H Q W a 4 J Y 0 Q 0 o a W Q z Lo co 2 LLI a U m N.O0 :V) M V) _ co W D z0>-r•-I 0 V) I ❑ H 6C Q N J O Q Q lO Z J H m O 2 a m Oo Q a 3 _ a w tii > ai o H W I V) H __ o � V WQ aO� JN J a 0 r ro ' a3 U210U a m Z C a ? E _ HU QDn I- 0 Z °' I am Z WZd't-Ida1Q H = r LL n ro H ❑ r cth I.- wi_aawce QOM Y z QN. 5„ Z Z H H Ln O r 0 Cr) i Q V) d't0 z Z °- o N VI 0 0o g Imi . W 0 c W 3 E X 0 H o o ' O2Z HtO 0 Z 00 I... a Q Cf)O N V) I m Q Hi c) _ esx . 0 W < l0 I- J O z 03NIiU X CC ce 0) H Hi N ❑w 0 0 a1 I Cl) 2 HI >_ \k74%1Z N Z XN CO 2ScO Q H Y LU No 0 ao m � u N0 WFE ? w 0 2 w 0 J W M _ w W IY Z l7 M D! cc W W to I- W O<"' z -I w Q > U, S\% CC z W UO to Q J o_ (n O co 0 m Z 0 p U Q 0 2I I D 0 F HO W UN. N H W (n U Z o0 1- Z O (n w Q H W a W Wa w M V)Q a1 a C7 w X m__I_J_20 ¢ V) a a W /5/ U fi>� HALLIBURTON 21111 CMI PiiroIIuiririi Sperry Drilling PACKING LIST Spy Island Drillsite Nikaitchuq SI26-NW2 Shipping Date: 7-Dec-2014 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 S?2t,-NW2- #egievii m Descript10atr.zInterval Packaging Box Description SP22-NWr Washed and Dried Samples-50' 2,900'to 6,800' Paper envelopes 1 of 8 Washed and Dried Samples-50' 6,850'to 10400' Paper envelopes 2 of 8 Washed and Dried Samples-50' 10,450'to 14,000' Paper envelopes 3 of 8 Washed and Dried Samples-50' 14,050'to 15,750' Paper envelopes 4 of 8 Washed and Dried Samples-50' 15,800'to 18,000' Paper envelopes 5 of 8 Washed and Dried Samples-50' 18,050'to 20,000' Paper envelopes 6 of 8 Washed and Dried Samples-50' 20,050'to 22,350' Paper envelopes 7 of 8 Washed and Dried Samples-50' 22,400'to 24,062 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; Andrew Buchanan 907-865-3388 RECEIVED Received by Expediter. Date: 1 9 71114 AOGCC - Z��- V5'1 z5t3� SchlumbergerTransmittal#: 09DEC14-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery ,?,ticr�2ot-1 K BENDER Customer: ENI Petroleumeum Dispatched To: Makana Bender Well No: S126-NW2 Date Dispatched: 9-Dec-14 Job#: 50-629-23531-00-00 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicVISION Top of Cement x x EOW C_D 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/pds x RECEIVED DEC092014 AOGCC Please sign and email a copy to: Please sign and email/fax a copy to: Andrew.Buchanan@enipetroleum.com spacillo@slb.com Stephanie Pacillo Andrew Buchanan Fax:907-561-8317 907 865 3388 ✓�l.dtv `�``�� Received By: (-jr, OF ) I%%i THE STATE A_'.,C!' C : �` ri ,i, c A yLS :L 1 ,,i."---i47,=_'_::::- .2_-_._ ---- ,,,.i___/.;_, , _,- . .L-= .-_J_ ,_, :Cit --_-- ___—. – 333 West Seventh Avenue – I'r r ; SEAN Anchorage Alaska 99501-3572 .'s Main 907.2799 1433 O'-,Lik 1`' ir, ;0% 1,76 /`, Davide Simeone Well Ops Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SI26-NW2 ENI US Operating Co. Inc. Permit No: 214-157 Surface Location: 4443' FSL, 1413' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 3698' FSL, 5207' FEL, SEC. 10, T14N, R8E, UM Dear Mr. Simeone: 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ai/t47/3)1x7L__ Cathy P. Foerster Chair DATED this day of October, 2014. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ll Q `� PERMIT TO DRILL I, ., 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj 2' Single Zone 0• lc.Specify if well is proposed for: Drill EI- Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill El 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 • SI26-NW2 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 24046. TVD: 3614• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number. (f b Nikaitchuq/Schrader Bluff Surface: 4443 FSL,1413 FEL,S19 T14N R9E UM 1 ADL 0391283,0388583,0388574, 5'l1,0388572 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3459 FSL,3734 FEL,S14 T14N R8E UM ADL 417493 11/12/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3698 FSL,5207 FEL,S10 T14N R8E UM - 10842• 3336'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- 511497 y- 6053624 Zone- 4. GL Elevation above MSL: 13.1 fl , to Same Pool: 1194'to SP21-NW1 L1 16.Deviated wells: Kickoff depth- 250 feet • 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 93.09 degrees• Downhole: 1617 psig . Surface: 1222 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 Pre-Installed 16" 13-3/8" 68 L-80 BTC 2817 35 35 2852 2454 Surface Lead:441 bbls 12.5ppg DeepCrete 63 bbls 12.25" 9-5/8" 40 L-80 Hydril 563 15382 33 33 15415 3608 12.5 ppg DeepCRETE 201 bbls 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 8831 15215 3596 24046 3614 I 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 ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat ❑' BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis0 Diverter Sketch❑' Seabed Report ❑ Drilling Fluid Program 0 20 MC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 10/7/2014 22. I hereby certify that the foregoing is true and correct. Contact Andrea Lazzari 907-230 7511 Email andrea.lazzari@enipetroleum.com Printed Name ,/ Davide Simeone Title Well Ops Project Manager it Signature t7L Phone (907)865-3320 Date 10/7/2014 - Commission Use Only Permit to Drill a� /API N mber: Permit Approval 1 See cover letter for other Number: oZ 14I '- I. r 50-(029- ,23 53 1 -0o -00 Date: , requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:[l � e, Other: 3 5 0 e (,),.: / 1,r i 5 Samples req'd: Yes❑ No Mud log req'd:Yes❑ N r. H2S measures: Yes❑ No[✓> Directional svy req'd:YesEr No❑ z. iv fir- 1,4 ! eg`_ rfc,.x-•--,`r\Spacing exception req'd: Yes El No2 Inclination-only svy req'd:Yei Nod ( / ° '� "44 to 3(- APPROVED BY Approved by: Ai P-) kL_____ COMMISSIONER THE COMMISSION Date: i0_a /d . Zt / Flyby Submit Form and Form 10-401(nevi 1p/211t2) ( if r411 c rt�d�p124Aror�ths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate V VV �� II\\vv�� /H'\� LL G� /o/;�� Pi" En Petrolleurn em 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Davide Simeone Phone(907)865-3320 Email: Davide.Simeone@enipetroleum.com October 7,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector SI26-NW2 Dear Commissioners, Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the Offshore Injector well 5I26-NW2. 1 This well will be drilled and completed using Doyon 15.1 The planned spud date could be as early as 11/12/2014. 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, Davide Simeone W 11 Operti Nns Project Manager c..2 0,11.'69/ . .: /ice - //(0/42°14 ..„, en II *lot • Einiii Petirolleum Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 Application for Permit to Drill Document Injector Well SI26-NW2 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 P/ease see Attachment 7:Surface Platt 3 Requirements of 20 AAC 25.050(6) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC 25005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20AAC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 AAC 25,005(c)(7) 5 Requirements of 20AAC 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 Requirements of 20 AAC 25005(c)(9) 6 9. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 7 03 AOGCC PERMIT Document Page 1 of 10 Printed:7-Oct-14 117i* • Enii PetiroIIeim enn Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 10. Seabed Condition Analysis 7 Requirements of 20 AAC25.005(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:7-Oct-14 1"41 Eir 2n� ii PtiroIIuIIrrfl Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 1. Well Name Requirements of 20 AAC 25.005(0 Each we/i must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC25.040(6).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: SI26-NW2 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application fora 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 depot, referenced to governmental section lines. (B)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 4443 FSL, 1413 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1 ft'AMSL Northing: 6,053,624' Easting:511,497' Pad Elevation 13.1 ft'AMSL Location at Top of Productive Interval 3459 FSL, 3734 FEL, S14 T14N R8E UM _COA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 15,285' Northing: 6,057,910' Easting: 498,811' _ Total Vertical Depth, RKB: 3,600' Total Vertical Depth,SS: 3,546' Location at Total Depth 3698 FSL, 5207 FEL, S10 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 24,046' Northing: 6,063,433' Easting: 492,053' Total Vertical Depth, RKB: 3,614' Total Vertical Depth, 55: 3,560' 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 fora Permit to Ddll(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan 03AOGCC PERMIT Document Page 3 of 10 Printed:7-Oct-14 Enil P ran Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 (2)for all wells within 200 feet of the proposed wellbore (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 (8)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 an__ panied by each of the following 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 AAC 25.037,as applicable; Please see Attachment 4: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) 4n 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: (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 gradient; 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 vertical depth of the OA sand formation is: MPSP = (3,594'TVDss)(0.45 - 0.11 psi/ft) = 1222 psi (B)data on potential gas zones, The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormallygeopressured strata,last 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 MC 25.005(c)(5) 4n 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 formation integrity tests, as required under 20 AAC25.030(0 Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 03_AOGCC PERMIT Document Page 4 of 10 Printed:7-Oct-14 2no 1*. Eiriiii PtIroIkLuIIr1ni Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dnil 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 AAC 25.030,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 Bun Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (R) (R) (it) Cement Program 20 Driven 178.89 X-65 Welded 160 36/ 36 160'/ 160' Pre-Installed 13-3/8 16 68 L-80 BTC 2817' 35 / 35 2852'/ 2454' Surface Lead: 441 bbls 12.5ppg DeepCrete 63 bbls 9-5/8 12-1/4 40 L-80 Hydril 563 15382' 33 / 33 15415'/ 3608' 12.5 ppg DeepCRETE 201 bbls 4-1/2 8-3/4" 11.6 L-80 Hydril 521 8831' 15215'/ 3596' 24046'/ 3614' 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:7-Oct-14 ffi* • PtiroHuimlEnli 2n Application tor Permit to Drill SI26-NW2 Saved:7-Oct-14 Drilling Fluid Program Requirements of 20 AAC 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 AAC25.033; 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 9-5/8"Csg Point Value Value Density(ppg) 8.7 -9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity 45 60 (CP) (seconds) Yield Point 14 - 20 Plastic Viscostiy 12 - 18 (1b/100 sI) (CP) HTHP Fluid loss Yield Point 18-24 (ml/30 min <5.0 (lb/100 sJ) 200psi&100°F API Filtrate4 - 6 Oil/Water 60/ 40 (cc/30 min)) Ratio Chlorides(mg/1) <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 MC 25.005(c)(9) An application for a Permit to Drill must be acco,,,paned by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or strabgraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25 0?3(f1: Not applicable: Application is not for an exploratory or stratigraphic test well. 03_AOGCC PERMIT Document Page 6 of 10 Printed:7-Oct-14 EnliII* PtIr©IkLuIm 2no Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 9. Seismic Analysis Requirements of 20 AAC25.005(c)(10) 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: (10)for an exp/oratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(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 unii must be accompanied by each of the following items,except for an item already 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 by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file Willi 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) Ai;appiicato•on rot a Permit to unu must oe 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 1) Move in / rig up Doyon 15. 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 3500 PSI. 03 AOGCC PERMIT Document Page 7 of 10 Printed:7-Oct-14 C ■ • C�n�� Petirolleum 2nil Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 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. 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 4-1/2"tubing. Land tubing. 30) Test upper and lower seals to 5000 psi for 10 min. 31) RU to set PHL Injection Packer. Test surface lines to 5000 psi and bleed to zero. 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 (` 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 A4 ( T- Page 8 of 10 Printed:7-Oct-14 /"*. Einii PtIroIkLuIm eno Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 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). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the 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 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) At,application tot a H'ennit to Daft must be accompanied by each of the following items,except tot an item already on file with the commission and identified in the application: (14)a general descnption 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 (kr—) 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:7-Oct-14 IFIY*6 lEnli PtIroIIeLuIm en 11 Application for Permit to Drill SI26-NW2 Saved:7-Oct-14 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 CerCADE Summary Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 % Mile Scan Report Attachment 9 Casing Design Program 03_AOGCC PERMIT Document Page 10 of 10 Printed:7-Oct-14 voi,_ en o• FIs operrfi nng WELL SI26-NW2 Drilling Procedure SI26-NW2 Spy Island Conductor slot#26 Reservoir location #NW2 Injector (Schrader Bluff) Nikaitchuq Project SI26-NW2 Drilling Wellplan Page 1 of 40 10/06/14 ..„..w • en us operrafing WELL SI26-NW2 Spy Island Nikaitchuq Field reno peirollkum North Slope - Alaska S126-N W 2 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD TVD SIZE SPECS INFO Cement to Surface 20" 0 Hole Angle 'iii'-' X-65 0° 20"Conductor Shoe 160' 160' Driven Welded N/A - 0 GR/Res G Surface Csq Dr/PWD 0 0 13-3/8" to q 6 68# MW(ppg) Wellbore Stability Mud Motor B/Permafrost 1,849' 1,752' rr- L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning en Casing Sections KOP:250' Casing Wear DLS: Surface T/Tad Cerrent 2,347' 2,153' Ili 0-3.5 0/100' in o:. AD A el Hole Angle m m 62.09 Deg 13-3/8" 2,852' 2,454' 16" 50°F WBM GR/RES/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(ppg) Hole Cleaning L-80,Hydri 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 86.35 Deg _ BHA Expense ' Intermediate TOC 13,084' 3,087' i Pick-up Top of Sand la hi On • E in N Top 14,084' 3,453' 0 too m Ti; a Hole Angle TOL 15,215' 3,596' n. 86.35 Deg 9-5/8" 15,415' 3,608' 0.--i 12.25" 85°F WBM GR/RES ADN/ECOSCOPE IlEr, El Wellbore Stability K Lost Circulation a ICD Sintted Liner Hole Cleaning 4-1/2" Torque&Drag m ►" El 11.6# MW(ppg) Casing Sections Xceed 675 i L-80,Hydrd 521 8.7-9.4 Cashg Wear �p ICD p� BHA Expense CE EI ICD ISi�p � Hole Angle 89.66 Deg TD 24,046' 3,614' 8-3/9" 85°F MOBM SI26-NW2 Drilling Wellplan Page 2 of 40 10/06/14 2nD us operating WELL SI26-NW2 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 SI26-NW2 Drilling Wellplan Page 3 of 40 10/06/14 cf* 2n11 us operating WELL S126-NW2 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. SI26-NW2 Drilling Wellplan Page 4 of 40 10/06/14 2nn USS Ooper hnng WELL SI26-NW2 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. i 5. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD—Require GR/Res/Dir to achieve TD. SI26-NW2 Drilling Wellplan Page 5 of 40 10/06/14 2nd us operating WELL SI26-NW2 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (ppf) _ Type (psi) (psi) (kips) 20 178.89 X-65 Welded I8.25 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. D. Each conductor is to be marked with a common pad elevation survey mark by the surveyors D 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. D Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test D Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. D Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area D 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 D Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). SI26-NW2 Drilling Wellplan Page 6 of 40 10/06/14 o e l• us operraHng WELL SI26-NW2 SURFACE SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (4) True Formation Tops Measured Vertical Comments Depth,ft Depth,ft SV-4 767 765 SV-3 1127 1112 SV-2 1404 1365 B/Permafrost 1849 1752 SV-1 2054 1926 Ugnu Top(UG4) 2466 2235 13-3/8" Csg Shoe 2852 2454 SCP UG-2 Coal Bed Marker 5166 2685 Fault 5 12268 2877 Lower Ugnu 13556 3265 Schrader Bluff Top 13917 3400 N Sequence Top 14084 3453 N Top 14288 3504 ReCalc Intermediate Cement w/Actual N Bottom 14460 3536 N Sequence Base 14801 3569 9-5/8" Csg Shoe 15415 3608 ICP OA Top 15284 3600 OA-2 Top 15409 3608 TD 24046 3614 TD SI26-NW2 Drilling Wellplan Page 7 of 40 10/06/14 WELL SI26-NW2 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 (ppg) ReadingLoss ( � PH (ml/30min) 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 SI26-NW2 Drilling Wellplan Page 8 of 40 10/06/14 ff* 2rnno us op rraCDrnng WELL SI26-NW2 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: > 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. D 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: D Landed in good shale found in this area at 2454' TVD D 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. S126-NW2 Drilling Wellplan Page 9 of 40 10/06/14 $1* 2nll us operating WELL SI26-NW2 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (ppf) 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) Opt. OD Grade Conn.Type Make Up (in) (PPS Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running 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 SI26-NW2 Drilling Wellplan Page 11 of 40 10/06/14 2n us op rraV nng WELL SI26-NW2 Surface Centralizer Placement 10' oa 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 1st 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 between collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. SI26-NW2 Drilling Wellplan Page 13 of 40 10/06/14 2n� us operating WELL S126-NW2 > 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 S126-NW2 Drilling Wellplan Page 15 of 40 10/06/14 „ow • eno• us operating WELL SI26-NW2 INTERMEDIATE SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (4) True Formation Tops Measured Vertical Comments Depth,ft Depth,ft SV-4 767 765 SV-3 1127 1112 SV-2 1404 1365 B/Permafrost 1849 1752 SV-1 2054 1926 Ugnu Top(UG4) 2466 2235 13-3/8” Csg Shoe 2852 2454 SCP UG-2 Coal Bed Marker 5166 2685 Fault 5 12268 2877 Lower Ugnu 13556 3265 Schrader Bluff Top 13917 3400 N Sequence Top 14084 3453 N Top 14288 3504 ReCalc Intermediate Cement w/Actual N Bottom 14460 3536 N Sequence Base 14801 3569 9-5/8" Csg Shoe 15415 3608 ICP OA Top 15284 3600 OA-2 Top 15409 3608 TD 24046 3614 TD SI26-NW2 Drilling Wellplan Page 17 of 40 10/06/14 2no us operating FWELL SI26-NW2 Intermediate Drilling 1. Directionally Drill 12-1/4"hole • Use the following Parameters: • Flow rate of 900 GPM • 120-140 RPM 2. Casine Point:Land Intermediate casing at 15,415'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 Casine point: > 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-S 1: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. ➢ 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. SI26-NW2 Drilling Wellplan Page 19 of 40 10/06/14 1 2no us operating WELL SI26-NW2 • 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 I Float shoe—Davis-Lynch Model 501-DV-PVTS Baker Lock down jet float shoe(double valve)**** 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 +/-38 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. ➢ 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. SI26-NW2 Drilling Wellplan Page 21 of 40 10/06/14 2n� us operrafing WELL SI26-NW2 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Intermediate 9-5/8" Mudpush I1 100 bbls Density 10.5 ppg DeepCrete 201 bbls Density 12.5 ppg Top of Cement @ 13,084' MD Yield 1.50 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 1/2 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 tie pumps and LSND water-based drilline 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 SI26-NW2 Drilling Wellplan Page 23 of 40 10/06/14 .....w- FIs operating WELL SI26-NW2 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 Plugs 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 SI26-NW2 Drilling Wellplan Page 25 of 40 10/06/14 2no operaflng WELL SI26-NW2 Production Mud Program: FazePro Density HTHP FL Electrical Interval (ppg) YP (mV30min) 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/EcoSCOPE Production Drill Pipe Tool Joint Body DP Tool Make UPipe Tensile WT Grade Conn. Joint Joint Body rquep Torsion Torsional capacity ToCapacity (PPf) type OD ID(in) ID(in) (Albs) 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 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. Openhole 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. SI26-NW2 Drilling Wellplan Page 27 of 40 10/06/14 em us operating WELL SI26-NW2 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) dri 4-1/2 11.6 L-80 8211 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: SI26-NW2 Drilling Wellplan Page 29 of 40 10/06/14 co* 2Cn10 us operrah nng WELL SI26-NW2 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'/z 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. SI26-NW2 Drilling Wellplan Page 31 of 40 10/06/14 If* en us operrafi nng WELL SI26-NW2 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 SI26-NW2 Drilling Wellplan Page 33 of 40 10/06/14 2rnn� operaflng WELL SI26-NW2 Health, Safety & Environment I 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 H2S 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. H25 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. SI26-NW2 Drilling Wellplan Page 35 of 40 10/06/14 0'1 ( m us operrafi nng WELL SI26-NW2 D. 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. SI26-NW2 Drilling Wellplan Page 37 of 40 10/06/14 • If* 2no us operre ng WELL SI26-NW2 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 l 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. SI26-NW2 Drilling Wellplan Page 39 of 40 10/06/14 SI26-NW2(P4b)Proposal Geodetic Report Schlumberger ani (Del Plan) Report Date: October 02,2014-0454 PM Survey lDLS Computation: Minimum Curvature/Lubineki Client: En'Petroleum Vertical Section Azimuth: 298.858•(True North) Field: Nikalichuri ��Vertical ee �� E Wall: 5126NW2 � Structure Slot: Spy lair ��1[,�,v�/ Rolary Table 1100 IVO Refencelevabon: 54.100tlebove MSL Island 9.IG�W Borehole: SI26-NW2 Ground Elevation: 13.1008 above MSL APIS: 50829orm00 Magnetic Oecllvtion: 19.102• Survey Name: 5128-NW2(P40 Total Gravity FMB Strength: 1002.01581w(980865 Bred) Survey On: Ccbber 02,2014 Gravity Model: DOX Tort/AHD/DDI I ERD Ratb: 207.067°/22198.310 8 1 7.481/2088 Total Magnetic Field Strength: 57593 925 nT Coordinate Reference System: NAD27 Alaska Stele Plane,Zona 04,US Feel Magnetic Dip Angie: 81.059• Location Lat/Long: N70°33'27.78674•,W 149°54'20.51985 Declination Dela: November 15,2014 Location Grid N/E n/X: N8053824.030 BUS,E 511497.340 BUS Magnetic Declination Model: 0009 2014 CRS Grld Convergence Mille: 0.0889• North Reference: MA North Grid Scale Factor: 0.89990015 Grid Convergence Seed: 00000° Version/Patch: 2.7.1043.0 Total Corr Mag North-,True North: 191017° Local Coord Raterenced To: Weil Head Comments MO Incl /elm TrimTVDBB TVD VSEC 448 EW TF DLS Directional ExeluabExclusion 2°."n Zone tingle Walking Emoting RI) (l (9 (ft) (R) HO rn) PO (1 (71008) Difficulty Intl.= Alert M (1150)(NUS) rnU8) RTE 0.08 0.00 285.00 -54.10 0.00 0.00 0.00 0.00 2859 N/A 0.00 8.94 605362403 511497.34 100.00 0.00 285.00 45.90 100.00 0.00 0.00 0.00 2859 0.00 000 8.94 6053624.03 51149734 200.00 0.00 285.00 145.90 200.00 0.00 000 0.00 2859 0.00 0.00 894 6053824.03 51149734 KOP Cry 1/100 250.00 0.00 28500 19590 25000 000 0.00 0.00 2859 0.00 000 8.94 6053624 03 51149794 300.00 0.50 28500 245.90 30000 021 0.06 -0.21 28594 100 000 899 605362409 51149713 400.00 1.50 28500 345.88 39998 1.92 0.51 -1.90 2859 1.00 0.47 917 605362454 511495.44 Cry 2/100 45000 2.00 28500 39586 44996 3.42 0.90 3.37 285M 1.00 0.84 830 605362493 511493.97 500.00 300 285.00 445.81 499.91 5.55 147 -5.48 28504 2.00 1.23 963 605362549 511491.88 600.00 500 285.00 54556 599.88 12.38 327 12.22 285M 2.00 180 1054 605362728 511485.12 Crv3/100 850.00 6.00 285.00 595.33 649.43 17.07 4.51 -16.84 2658 2.00 202 11.11 6053628.52 511480.49 700.00 750 285.00 844.98 69908 22.82 8.03 -22.52 2656 3.00 2.24 1208 805363003 511474.81 SV.4 788.75 9.50 29500 711.00 765.10 32.48 859 -32.05 HS 3.00 2.50 13.48 8053832.57 51146526 800.00 10.50 285.00 743.74 79784 38.13 1008 -37.63 HS 300 2.61 1424 6053634.05 511459.70 900.00 1350 285.00 841.54 89564 5847 15.46 57.71 HS 3.00 291 1687 6053639.40 511469.81 1000.00 1850 285.00 938.13 99223 83.80 22.18 8271 HS 300 3.15 1926 605364606 511414.61 1100.00 19.50 28500 1033.22 1087.32 11404 30.18 -11255 05 3.00 3.38 2196 8053654.01 511384.75 SVS 1126.67 20.30 285.00 105830 1112.40 122.92 32.51 -121.32 843 300 3.41 22.69 6053656.35 511375.96 1200.00 22.50 285.00 1126.57 1180.67 14910 3943 14718 HS 3.00 3.54 24.71 605366323 511350.13 130000 25.50 285.00 1217.81 1272.01 18891 4998 .18645 05 000 3.70 27.52 605387369 511310.83 Cry0.5/100 139204 26.26 285.00 1300.00 1354.10 22963 60.73 -22664 95 3.00 383 3014 605388440 511270.63 140000 2830 285.00 1307.01 136111 233.32 8170 230.20 HS 0.50 3.84 3017 605368537 511268.99 SV-2 1404.06 2832 28500 1310.60 1364.70 235.21 62.20 -232.15 HS 0.50 3.85 3019 605368587 511285.12 150000 28.60 285.00 1394.85 1448.95 280.09 7407 -276.45 95 050 3.93 3085 8053697.67 511220.81 1800.00 29.30 285.00 1482.27 1536.37 327.81 8864 -323.35 HS 050 4.01 31.13 6053710.16 511173.89 1700.00 29.80 285.00 1569.28 1823.36 375.88 99.41 -37099 HS 0.50 4.00 3180 605372285 511126.23 190000 30.30 285.00 1655.82 1709.92 42489 112.37 -419.36 HS 050 414 32.08 6053735.74 511077.85 Base Perm 184880 30.55 28500 1697.90 1752.00 449.08 118.76 -44322 HS 0.50 417 32.32 603174209 511053.97 1900.00 30.80 265.00 1741.93 1796.03 47484 12552 -488.46 HS 0.50 4.20 32.58 60537411.81 511028.73 Cm 32/100 1987.72 31.14 285.00 1800.00 1854.10 50874 13454 302.12 HS 0.50 4.24 32.88 6053757.78 510995.06 2000.00 32.27 285.00 1827.46 1881.58 52534 138.93 31851 HS 3.50 4.27 3397 6053762.14 510978.67 SV-1 2053.59 34.15 28500 1872.30 1926.40 554.07 148.53 -546.86 HS 3.50 4.31 35.77 805376970 510950.31 2100.00 35.77 285.00 191033 1964.43 580.09 153.41 -57254 HS 3.50 4.36 3734 605377654 510924.62 • 220000 39.27 285.00 1989.64 2043.74 839.88 18917 331.36 HS 3.50 4.44 4073 605379220 51086576 ' 2300.00 42.77 285.00 2065.07 2119.17 70390 188.16 -094.74 HS 3.50 452 44.14 605380909 510802.38 2400.00 46.27 285.00 2136.36 2190.46 77251 20430 782.48 HS 3.50 480 47.58 6053827.13 510734.64 • Uplu Top(UG4) 2485.83 48.57 28500 2180.90 223500 819.95 21685 -80828 NS 350 4.65 49.81 606383960 51068781 2500.00 49.77 285.00 2203.24 2257.34 045.25 223.54 4334.25 HS 3.50 4.88 5098 605384625 510862.83 2800.00 53.27 285.00 2285.48 231956 921.85 24379 -909.85 HS 3.50 4.75 54.42 6053866.39 510587.20 2700.00 5677 28500 2322.78 2378.88 1002.02 26500 -988.99 HS 3.50 4.82 57.86 6053887.47 510508.05 2800.00 60.27 285.00 2374.99 2429.09 1085.47 287.07 .1071.35 HS 3.50 489 61.30 6053909.40 510425.86 133'8- 2851.88 62.09 28500 2400.00 2454.10 1129.95 298.83 -111525 HS 350 4.92 63.09 6053921.10 510381.74 2900.00 83.77 285.00 2421.90 2478.00 11]1.88 309.92 -1158.81 HS 3.50 4.95 64.74 605393212 510340.34 Cry 35/100 2867.]2 66.14 285.00 2450.57 250467 123192 325.80 -1215.90 5246 350 4.99 67.08 6053947.91 51028106 3000.00 67.28 285.11 2463.33 2517_43 1280.94 333.50 -1244.52 5.2R 350 5.01 88.17 605395556 510252.43 3100.00 70.75 28545 249915 2553.25 1352.39 358.10 -1334.57 5086 3.50 507 71 56 605398002 510162.35 320000 74.24 285.77 252923 2583.33 1445.91 38378 -1426.41 4.989 3.50 5.13 7495 805400554 51007048 3300.00 7772 28608 2553.45 2807.55 1541.16 410.38 .1519.89 4919 3.50 5.19 7834 605403201 509977.17 340000 8121 28838 2571.73 2825.83 163777 437.88 -1814.07 4.859 350 5.25 81 74 6054059.34 509882.75 350000 84.70 288.88 258399 2838.09 173540 486.09 -1709.20 481R 3.50 5.30 85.14 805408742 50978759 380000 86.19 28697 2590.19 2844.29 1833.66 494.98 -1804.72 4.86 3.50 5.35 8854 805411816 50969204 End Cry 360898 88.50 28700 2590.45 264455 1842.51 497.60 -1813.30 145 3.50 5.36 8884 605411077 509683.45 370000 88.50 287.00 2592.83 2646.93 1932.15 52421 -1900.32 HS 0.00 5.39 8884 605414523 509596.41 380000 88.50 287.00 259545 2649.55 2030.64 55343 .1915.91 HS 000 542 8884 6054174.31 509500.77 390000 88.50 287.00 2598.07 2652.17 2129.13 58288 -2091.51 HS 0.00 5.45 8884 6054203.39 509405.14 4000.00 88.50 287.00 2600.69 2654.79 2227.62 811.89 -2187.11 HS 0.00 5.48 8884 6054232.48 509309.51 410000 88.50 287.00 2603.30 2657.40 2328.11 641.12 9282.71 HS 000 5.51 8884 605426154 509213.87 4200.00 88.50 287.00 2605.92 286002 2424.80 87034 -2378.30 HS 0.00 5.54 8884 6054290.61 509118.24 4300.00 88.50 28700 2608.54 2662.84 2523.09 69957 -2473.90 HS 0.00 557 8684 605431969 50902261 440000 88.50 287.00 2611.16 266526 2621.58 72080 .2569.50 HS 0.00 559 8884 605434076 508926.97 450000 88.50 287.00 2613.78 288788 2720.07 75002 -2885.10 HS 0.00 562 8884 605437784 508831.34 460000 88.50 287.00 261839 2670.49 2818.58 787.25 -2700.70 HS 0.00 564 8884 8054406.92 50873571 470000 88.50 287.00 261901 2873.11 2917.05 816.48 -2858.29 HS 505 567 8884 605443599 508640.07 4800.00 88.50 28700 2621.63 2875.73 3015.54 645.71 -2951.89 HS 0.00 569 8884 6054465.07 508544.44 490000 88.50 28700 262425 2678.35 311403 87493 204749 HS 000 5.71 88.84 6054494.14 50844881 5000.00 88.50 28700 2626.86 2680.96 3212.52 904.18 -3143.09 HS 000 573 88.84 605452322 508353.17 5'00.00 88.50 287.00 262948 2683.58 331101 933.39 -3238.88 HS 0.00 5.75 8884 6054552.29 508257.54 5200.00 88.50 28700 2632.10 2686.20 3409.50 98281 -3334.28 HS 000 577 8884 605458137 50816191 5300.00 88.50 287.00 2634.72 2688.82 3507.99 99184 -3429.88 HS 000 579 8884 605461045 508086.27 5400.00 88.50 28700 2637.33 2691.43 3606.48 1021.07 -3525.48 HS 0.00 581 88.84 605463952 507970.84 550000 88.50 287.00 2639.95 2694.05 3704.97 105030 -3621.08 HS 0.00 583 8884 605466880 50787501 5600.00 88.50 287.00 264257 2696.67 3803.48 1079.52 -371667 HS 0.00 585 8884 605469767 50777938 570000 88.50 287.00 2645.19 2699.29 3901.95 1108.75 3812.27 HS 0.00 587 8884 605472075 507883.74 580000 88.50 28700 264781 2701.91 4000.44 1137.98 3907.87 HS 000 589 8884 805475583 507588.11 • 5900.00 88.50 28700 2650.42 2704.52 409093 116720 -400347 HS 000 591 88.84 605478480 507492.48 ' 800000 88.50 287.00 285304 270714 4197.41 1198.43 .4099.06 HS 000 592 8684 605481398 507398.84 610000 88.50 287.00 2655.66 2700.76 4295.90 122566 .4194.86 HS 000 594 8884 805484305 50730121 8200.00 88.50 28700 2658.28 2712.28 439439 1254.89 4290.26 HS 0.00 5.96 8884 6054872.13 507205.58 630000 88.50 28700 2660.89 2714.99 4492.88 1284.11 -4385.88 HS 0.00 5.97 88 84 6054901 20 507109.94 6400.00 88.50 287.00 2663.51 2717.61 4591.37 1313.34 .4481.45 HS 000 5.99 8884 605493028 50701431 8500.00 88.50 287,00 2666.13 2720.23 4889.86 134257 .4577.05 HS 0.00 8.00 8884 605495936 506918.68 6600.00 88.50 287.00 2868.75 272285 4788.35 1371.79 -467265 HS 0.00 6.02 8884 605498643 50882304 8700.00 88.50 287.00 267136 2725.46 488684 140102 .476825 HS 0.00 8.03 8884 605501751 50672741 8800.00 8850 287.00 2673.98 2728.08 4985.33 143025 -4863.85 HS 0.00 005 8884 6055048.58 50683178 8900.00 8850 287.00 267660 2730.70 5083.82 145948 -4959.44 HS 0.00 6.06 8884 605507566 508538.14 7000.00 88.50 28700 267922 2733.32 5182.31 1488.70 -505504 HS 0.00 8.08 8884 6055104.73 5064/051 7100.00 8850 287.00 268184 2735.94 5280.80 1517.93 -5150.64 HO 0.00 8.09 8884 6055133.81 5034488 7200.00 88.50 287.00 266445 2738.55 5379.29 1547.18 -524624 HS 0.00 6.11 8884 605518289 50624924 UG-2 Coal Bad 7227.77 8850 287.00 2685.18 2739.28 5406.84 1555.27 -5272.78 HS 0.00 611 86.64 6055170.96 508222.69 Marker 730000 88.50 287.00 288].0] 2741.17 547778 157838 5341.83 HS 0.00 8.12 8884 805519198 506153.61 7400.00 88.50 287.00 288989 2743.79 557827 160581 5437.43 HS 0.00 13 8884 805522104 508057.98 ]00.00 88.50 287.00 2692.31 2748.41 5874.76 163484 -55330 3 HS 0.00 014 88.84 605525011 505962.34 7800.00 88.50 287.00 2894.92 274902 577325 166407 .572883 HS 0.00 018 8884 605527919 5058667: 7700.00 88.50 287.00 2897.54 2751.64 5871.74 169329 -5724.22 HS 0.008.17 8884 805530827 505771.08 7800.00 88.50 28700 2700.18 2751.26 597023 172252 581982 HS 0.00 8.18 8884 6055337.34 50567544 7900.00 88.50 27.00 2702.78 2756.88 806872 1751.75 381542 HS 0.00 8.19 88.84 6055386.42 50557881 ' 8000.00 88.50 2867.00 2705.39 275949 816721 178097 4011.02 110 0.00 8.21 8884 605539549 505484.18 8100.00 88.50 287.00 2708.01 2782.11 8285.70 181020 410682 HS 0.00 8.22 8884 805542457 50538850 • 820000 88.50 287.00 2710.63 2764.73 6364.19 183943 420221 HS 0.00 8.23 8884 8055453.64 50529291 8300000 88.50 287.00 2713.25 2787.35 6462.88 186886 429781 HS 0.00 24 88.84 8055482.72 505197.28 800000 88.50 287.00 2715.87 278997 6561.17 189788 4393.41 05 0.50025 88.80 805551180 505101.65 8500.00 88.50 287.00 2718.48 2772.58 8659.86 192].11 4189.01 HS 0.00 826 8884 6055540.87 505006.01 8800.00 8850 287.00 2721.10 277520 8758.15 195834 458460 HS 0.00 8.28 8884 605556995 504910.38 870000 88.50 28700 2723.72 2777.82 6856.64 1985.56 4680.20 HS 0.00 8.29 8884 6055599.02 504814.75 8800.00 88.50 287.00 2726.34 2780.44 8955.13 2014.79 4775.80 HS 0.00 830 8884 6055828.10 50471911 Drilling Office 2.7.998.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P2) 10/7/2014 11:48 AM Page 1 of 3 MD Vol •71m True7VD88 TVD VSEL NS EW TF 018 Ox.edonN EtrcM144ZoneE1mlwbn Mn..16 Zr NorthingNorthing Footingm comm. . DO (1 (1 Pot Ml Ix) m) (x) (1 (moon) Dmlmex Index Mott 11 DOA) (BUS) 8900.00 88.50 287.00 2728.95 2783.05 705382 204402 687140 HS 000 631 8884 6055657.17 504623.48 900000 88.50 287.00 2731.57 2785.87 7152.11 2073.25 -8966.99 HS 0.00 632 8884 8055686.25 50452785 9100.00 88.50 287.00 2734.19 2788.29 7250.59 210247 7062.59 HS 0.00 833 8884 6055715.33 504432.21 9200.00 88.50 287.00 2736.81 2790.91 7349.08 2131.70 7156.19 HS 0.00 6.34 6884 605574440 504336.58 9300.00 88.50 287.00 273942 2793.52 7447.57 2180.93 7253.79 HS 000 13.35 6884 605577348 50424095 9400.00 8850 297.00 2742.04 279814 7546.06 2190.15 7349.39 HS 0.00 6.36 6884 605580255 504145.31 950000 88.50 28700 2744.86 2798.76 784455 221938 -744498 HS 0.00 637 88.84 605583163 50404908 960000 88.50 287.00 274729 2801.38 7743.04 224861 .754058 HS 0.00 838 88.84 6055860.71 50395405 970000 88.50 287.00 2749.90 2804.00 7841.53 227784 7838.18 HS 0.00 8.39 88.64 6055889.78 503858.41 980000 8050 28700 2752.51 2608.61 7940.02 2307.06 7731.78 HS 0.00 8.40 88.84 605591886 50376278 990000 8850 28700 275513 280923 8038.51 2336.29 .782737 HS 0.00 6.41 88.64 605594793 50366715 0000.00 8850 28700 275775 281185 8137.00 2365.52 -792297 HS 0.00 6.42 88.84 605597701 50357151 0100.80 8850 28700 2780.37 281447 823549 239474 -801657 HS 000 642 88.84 6056006.08 50347588 0200.00 8850 287.00 276298 281708 8333.98 2423.97 8114.17 NS 0.00 6.43 8884 605603518 50338025 0300.00 88.50 28700 2765.80 2819.70 843247 245320 6209.76 HS 0.00 644 8884 605 424 503284.61 0400.00 88.50 287.00 2768.22 2822.32 853096 2482.43 6305.36 HS 0.00 845 8884 805609331 50318898 0500.00 8050 287.00 2770.84 2824.94 862945 2511.65 -8400.96 HS 000 6.46 8884 605612239 503093.35 0800.00 86.50 287.00 2773.45 2827.55 8727.94 2540.88 -8498.58 HS 0.00 647 88.84 6056151.46 502997.71 0700.00 86.50 28700 2778.07 2830.17 8826.43 257011 8592.16 HS 0.00 6.48 88.84 6056180.54 502902.08 0800.00 88.50 287.00 277689 283279 892492 259933 8887.75 HS 000 849 88.84 605620961 502806.45 0900.00 88.50 287.00 2781.31 283541 902341 262856 8783.35 HS 000 649 8884 605623669 502710.81 1000.00 86.50 287.00 2783.93 2838.03 9121.90 2657.79 8878.95 HS 0.00 650 88.84 6056267.77 502815.18 1100.00 88.50 287.00 2786.54 2840.64 9220.39 288702 8974.55 HS 0.00 8.51 88.84 605629684 502519.55 120000 8850 287.00 2789.16 2843.26 931888 271624 -907014 HS 0.00 8.52 88.84 605632592 502423.92 1300.00 88.50 287.00 2791.78 2845.88 9417.37 2745.47 9113E74 HS 0.00 6.53 88.64 6056354.99 502328.28 1400.00 88.50 287.00 2794.40 284850 9515.86 2774.70 926134 HS 080 054 88.64 605638407 50223285 1500.00 88.50 28700 279701 2851.11 9614.35 2803.92 9358.94 HS 0.00 8.54 88.84 6056413.15 50213702 1600.00 8850 28700 2799.63 285373 9712.84 283315 -945254 HS 0.00 6.55 88.64 605644222 50204138 1700.00 88.50 28700 280225 2856.35 9811.33 286238 9548.13 HS 0.00 6.56 88.84 605647130 501945.75 1800.00 88.50 28700 2804.87 2858.97 9909.82 299161 -9643.73 HS 0.00 6.57 88.84 605850037 501850.12 1900.00 88.50 28700 280748 288158 10008.31 292063 -9739.33 HS 0.00 6.57 88.84 605852945 501751.48 2000.00 88.50 28700 2810.10 286420 10106.80 295006 9834.93 HS 0.00 6.58 88 84 605855852 50165885 2100.00 88.50 287.00 2812.72 2866.82 10205.29 297929 9930.52 HS 0.00 6.59 8884 6056587.60 501563.22 C7025700 2108.98 88.50 287.00 281296 2867.06 10214.13 2981.91 -9939.11 168376 0.00 6.50 8884 605659021 501554.63 2200.00 86.29 28754 281709 2871.19 10303.78 300890 -10025.93 166346 2.50 6.61 8657 6056617.06 501467.77 70u85 2288.30 84.63 287.94 2822.50 2876.80 10371.00 3029.65 .10090.76 186.316 250 6.62 8487 6056637.70 501402.80 2300.00 8386 288.13 282588 2879.78 10402.17 3039.41 .10120.77 186298 250 682 84.08 6056647.42 50137290 2400.00 81.43 288.73 2838.46 289258 1050027 307078 .10214.85 186226 250 864 8159 805867862 60127818 2500.00 79.00 289.34 2855.47 2909.57 1059789 3102.89 -10308.00 166.116 250 6.86 79.10 805671061 501185.59 2800.00 76.58 289.95 287862 2930.72 1069484 3135.75 -10400.04 165.986 250 8.67 713.61 605674332 501093.50 270000 74.15 290.58 290188 2955.98 10790.95 316926 -10490.80 165.826 2.50 6.89 74.12 6056776.68 501002.70 2800.00 71.73 291.23 2931.21 2985.31 10886.03 3203.36 -10580.10 165.636 2.50 8.70 7182 605891064 50091335 290000 89.31 291.89 2964.56 301886 10979.89 3238.00 -10867.78 165.41R 2.50 871 09.13 605884514 500825.84 End Cm 2959.62 67.86 29230 2988.40 3040.50 11035.39 3258.94 10719.38 HS 2.50 672 6784 6056866.00 500774.01 3000.00 87.86 292.30 3001.54 3055.64 1107249 327308 10753.81 HS 0.00 6.72 6784 605688007 500739.55 3100.00 87.88 29230 3039.22 3093.32 11184.82 330820 10839.52 HS 0.00 6.72 6764 6056915.07 500653.81 3200.00 67.86 292.30 3078.91 3131.01 11257.16 334335 10925.22 HS 0.00 8.72 6784 605695008 500588.06 3300.00 87.88 292.30 3114.59 31138.89 11349.49 337849 11010.02 HS 0.00 6.73 6784 6056985.08 500482.31 3400.00 87.86 292.30 3152.28 3206.38 1144163 3413133 11098.63 HS 0.00 8.73 6784 6057020.09 500396.56 3500.00 67.86 292.30 3189.96 3244.06 11534.16 3448.77 -11182.33 HS 000 6.73 8784 6057055.10 50031081 Lower UP.. 3555.84 6785 282.30 3211.06 3265.10 11585.72 3468.40 -11280.18 NS 0.00 6.72 67.64 805707464 500262.93 3800.00 87.86 29230 322784 3281.74 11628.50 3483.92 -11268.03 HO 0.00 6.73 6784 605709010 50022506 3700.00 67.86 29230 326533 3319.43 1171883 351906 -11353.73 HS 0.00 6.73 6784 605712511 500139.31 3800.00 67.88 292.30 3303.01 3357.11 1181117 3554.20 -11439.44 HS 0.00 6.73 87.64 805716011 500053.57 Cry 3.5/100 3821.80 67.86 29230 3311.22 3385.32 11831.29 3561.86 11458.12 35.486 0.00 6.73 6784 80571137.74 500034.88 390000 69.46 293.51 3339.68 3393.78 11903.96 359021 -11525.21 35.046 2.50 6.74 6903 805719599 499987.74 Sc8n4der Bluff 1391730 89.81 293.77 3345.70 3389.80 11920.15 359671 -11540.07 34.956 2.50 6.74 89.34 6057202.46 499952.88 Ta 14000.00 7151 295.02 337308 3427.18 11998.11 3628.95 -11811.13 34.53R 250 6.75 70.82 6057234.59 49988177 N Sequence 14083.61 73.24 290.26 3388.40 3452.50 12077.77 3663.43 -11882.96 34.168 2.50 6.76 72.33 8057186.95 499809.90 Top 14100.00 73.58 296.50 3403.08 3457.18 12093.48 387041 -11897.04 34096 2.50 6.77 7283 605727591 499795.81 14200.00 755 297.94 3429.61 3483.71 1218988 371451 11782.76 33.716 250 13.78 74.45 6057319.88 499710.03 N Top 14287.76 77.418 29819 3450.06 3504.10 1227557 3755.33 -11857.722 33.429 2.50 879 76.07 6057360.58 499632.01 14300.00 77.74 299.36 3452.83 3506.73 12287.14 3761.18 -11866.15 33.38R 2.50 6.79 78.29 6057366.40 499624.58 14400.00 79.83 300.76 3472.08 3528.18 1238507 3810.32 -11953.04 33.119 2.50 6.80 7614 605741540 499539.62 N Bottom 14460.45 81.08 301.80 3482.16 353820 12444.51 3841.18 -12004.04 32979 250 6.81 79.27 805744619 499488.58 14500.00 81.92 302.14 3487.94 3542.04 1248348 386183 -12037.26 32.896 2.50 682 8000 6057466.78 499455.33 14800.00 84.03 303.50 3500.17 3554.27 12582.18 3915.63 -12120.65 32.726 2.50 6.83 8187 805752044 499371.86 14700.00 88.13 304.86 350075 3562.85 12890.99 3971.80 -12203.07 32816 250 6.84 83.75 805757628 499289.37 End Gni 1471045 86.35 305.00 3509.44 3583.54 12891.32 3977.57 12211.82 HS 2.50 6.85 8395 805758224 49928081 14800.00 88.35 305.00 3515.14 356024 12779.78 4028.83 12284.82 HS 0.00 685 8395 805763338 49920753 N Sequence 14802.55 86.35 305.00 3515.30 3589.40 12782.31 4030.29 -12286.91 NS 0.00 6.85 83.95 6057634.84 499205.44 Bose 4900.90 86.35 30500 3521.50 3575.80 12878.58 4086.07 12388.57 HS 0.00 6.86 8395 605769049 49912570 5000.00 88.35 305.00 3527.87 3581.97 12977.37 4143.31 -12448.32 HS 0.00 6.86 8395 805774780 499043.87 510000 86.35 305.00 353424 3588.34 1307618 420055 -1253007 HS 0.00 6.87 8395 8057804.70 498962.04 5200.00 86.35 305.00 3540.50 3594.70 13174.95 4257.79 -12811.82 HS 0.00 687 8395 605786181 498880.21 GLI Top 5284.79 86.35 305.00 3546.06 3800.10 13258.72 4306.33 -12661.13 NB 000 688 83.94 605791024 498810.82 mow 86.35 30500 3546.97 3801.07 13273.74 4315.03 .12883.57 HS 0.00 6.88 83.94 605791892 498798.38 5400.00 8035 30500 3553.33 380743 1337253 437228 -1277E32 HS 0.00 6.88 83.94 805797803 498718.58 04-2 Top 54088 88..35 305.00 3553.98 3608.00 13387.31 437736 -12782.58 HS 00 6.88 83.94 6057981.10 498709.29 NW2 HW 541045 86.35 30500 3554.00 360810 13382.88 437828 12783.88 HS 0.00 688 83.94 6057982.00 498708.00 955- 5415.45 68.35 3015.00 3554.32 3601842 1338780 4381.12 -12787.95 NS 000 8.88 8324 605798.86 488703.91 Cm 3.75/100 543545 88.35 305.00 3555.59 3609.89 13407.56 439257 -12804.30 75.716 000 689 83.94 605799628 498687.54 5500.00 86.95 30735 3559.36 381346 13471.14 443060 -12858.31 75.57R 3.75 6.90 84.19 605803422 498635.48 5800.00 87.89 310.98 3563.87 3817.97 13568.72 4493.138 12933.75 75.410 3.75 891 84.59 6058097.18 498557.95 570000 88.84 314.61 3566.72 3620.82 1366482 456158 -13007.06 75.36 3.75 6.93 85.01 605816496 498484.52 5800.00 89.78 318.24 3567.92 362202 13759.02 4634.01 -13075.99 75.26R 3.75 6.95 8545 805823728 498415.50 End Cor 581923 89.98 318.94 3567.95 362205 13778.89 4848.44 1308871 HS 3.75 6.95 85.54 605825168 49840276 5900.00 89.98 318.94 3587.99 3822.09 13851.73 4709.34 -1314177 HS 000 6.96 8554 805831249 498349.62 CIV 3.75/100 5908.97 89.98 318.94 3567.99 3622.09 13860.05 4716.10 -13147.86 93351 0.00 6.96 8554 605831924 498343.71 SINW2 T511 5920.64 89.95 318.50 356800 362210 1387088 4724.87 -13155.36 119921 3.75 696 8557 6058328.00 498336.00 End Cry 5998.14 86.54 316.05 3569.00 3623.10 13941.62 478032 -13206.58 HS 3.75 697 8451 605838336 498284.71 8000.00 88.54 316.05 3589.09 3623.19 1394527 4783.10 13209.26 HS 0.00 697 84 51 6058386.14 498282 02 6100.00 88.54 31805 357165 362575 14039.86 485506 -13278.64 HS 000 698 84.51 605845799 49821253 Crv3.75/100 6111.04 88.54 318.05 3571.93 3626.03 14050.10 486301 13286.30 82.55L 0.00 6.98 84.51 605846592 498204.86 620000 88.94 312.96 3573.88 3627.98 14134.85 4925.34 13349 73 82491. 350 899 85 34 605852615 498141.34 8300.00 89.40 309.49 3575.33 3629.43 14231.70 499122 -13424.92 82441 350 701 8630 605859391 498066.05 6400.00 89.86 306.02 3575.97 3630.07 14329.88 505244 -13503.98 82.41L 3.50 702 8727 8058854 99 497986.92 SI NW 2 T912 642035 90.00 305.00 357600 3830.10 14358.89 5069.49 13527.87 80131 3.50 703 8755 6058872 00 497963.00 6500.00 90.42 30256 3575.74 3629.84 14429.02 510877 -13566.58 80.141 3.50 7.04 88.34 6058711.19 49790423 8800.00 9102 299.12 3574.48 3626.58 14528.76 516002 -13672.42 80.181 3.50 7.05 89.46 6058762.30 49781832 End Cm 66137/8 91.54 298.09 3572.51 3626.61 1461650 520087 -13750.18 HS 3.50 7.06 89.56 6058802 83 49774050 870000 91.54 29609 357218 382628 14828.71 520604 -13761.16 HS 0.00 7.08 8956 6058808.18 497729.52 0,52/100 8772.67 9154 296.09 357022 362432 14701.35 5237.99 -13826.40 117.916 0.00 7.07 8956 6058840.02 497664.24 6800.00 91.29 296.57 3569.55 3623.65 14728.67 5250.10 .13850.89 117.926 2.00 7.07 8989 6058852.10 497639.73 6800.00 90.35 29834 3568.12 3622.22 14828.85 529620 -13939.81 117.940 2.00 7.09 8891 605889805 497550.95 SI NW 2 T913 6937.52 9000 299.00 3588.00 3822.10 14888.15 531420 -1397253 119.986 2.00 709 88.46 6058916.00 49751800 End Cm 6961.58 89.76 29942 3568.05 3622.15 14890.19 532594 -1399354 HS 2.00 7.09 88.16 6058927.71 497498.98 7000.00 89.76 299.42 3568.21 3622.31 1492857 5344.81 14027.00 HS 0.00 7.09 88.16 6058946.52 497463.49 710000 89.76 299.42 3588.63 3622.73 15028.47 5393.93 -14114.11 HS 000 7.10 88.16 6058995.50 49737632 7200.00 89.76 299.42 3589.05 3823.15 15128.37 5443.04 -1420121 HS 000 7.10 88.16 605904447 49728915 730000 89.76 299.42 3569.47 3623.57 15228.27 5492.16 -14288.32 HS 0.00 7.11 88.16 605909345 497201.97 Cry 2/100 731584 89.76 299.42 3589.54 3623.64 15244.09 5499.94 -14302.11 86448 000 7.11 88.16 605910120 497188.17 7400.00 8981 301.10 3569.88 3623.98 15328.10 554234 -1437481 861413 200 7.12 87.95 605914350 497115.41 SI 9W27914 744504 8183 302.00 3570.00 3624.10 15372.99 556591 -14413.19 89080 2.00 7.12 87.84 605916700 497077.00 7500.00 8985 303.10 3570.15 362425 15427.88 5595.48 14459.51 89.060 2.00 7.13 87.89 6059196.49 49703063 End Cm 757384 89.87 30458 357033 362443 15500.97 563660 lamas HS 2.00 7.13 6749 605923751 49696924 780000 89.87 30458 3570.39 362449 15526.89 585144 -14542.39 HS 0.00 7.14 8749 605925232 498947.88 7700.00 89.87 30458 3570.62 3624.72 1582598 5708.19 -14824.72 HS 0.00 7.14 8749 6059308.94 498865.27 7800.00 89.87 304.58 3570.84 3624.94 1572508 5764.94 -14707.06 HS 0.00 7.15 8749 6059365.55 496782.85 082/100 7884.08 89.87 304.58 357103 3625.13 1580840 581266 14776.29 179.781 0.00 7.15 8749 605941316 496713.55 7900.00 8955 30457 3571.11 362521 15824.17 5821.69 -14789.40 179.781 2.00 7.15 87.18 6059422.17 49670043 SI NW2 7915 795270 88.50 304.57 3572.00 3626.10 1587639 585159 .14832.79 171.751 2.00 7.16 86.13 6059452.00 496657.00 8000.00 87.56 304.43 3573.82 3627.72 1592324 587837 -14871.74 171.75L 200 7.16 8523 6059478.71 496618.01 End Cm 8051.62 86.54 304.29 357628 3630.38 15974.35 590746 .14914.30 HS 200 7.17 8424 6059507.74 496575.41 8100.00 86.54 304.29 3579.20 3633.30 1802223 593486 .14954.20 HS 0.00 7.17 84.24 6059534.88 496535.47 Cm 2/100 8198.33 86.54 304.29 3585.13 363923 16119.56 5989.95 -15035.29 518913 000 7.17 84.24 605959003 49645430 8200.00 8856 30431 3565.23 363933 1812121 599019 -15036.67 518913 2.00 7.17 8426 6059590.97 496452.92 8300.00 8780 305.88 3590.14 364424 16220.06 6048.32 -1511839 51810 2.80 7.18 8525 6059648.26 498371.13 8400.00 B9.05 30745 359289 3846.99 1631655 8108.01 -15198.56 51.576 2.00 7.19 56.25 6059707 82 496290.86 • SINW2 T918 8460.82 8980 308.40 3593.50 3647.80 18378.04 614526 -15248.37 46.976 2.00 720 86.85 6059745.00 496243.00 End Cry 8474.33 89.99 308.60 3593.53 3847.63 18391.47 815380 .15257.11 HS 200 720 87.01 6059753.52 49823226 8500.00 89.99 30860 3593.53 3847.63 16416.60 616982 -15277.17 HS 0.00 7,20 87.01 6059769.50 49621217 Drilling Office 2.7.998.0 Nikaitchuq\Spy Island\S126-NW2\S126-NW2\S126-NW2(P2) 10/7/2014 11:48 AM Page 2 of 3 Comments Incl Axlm True NDSB ND D VSEC NS EW TF DLS oeelbroExclusion Zone l Exclusion Zone Northing EaMing Ang(X) (1 (1 (X) (0) (X) (X) (X) (1 (9„00X) DMIIcully Index Alenl9 (PUS) (XUS) 8600.00 8999 30860 3593.55 364765 8514.51 623220 -15355.32 HS 0.00 7.21 87.01 6059831.76 49613393 8700.00 89.99 308.60 3593.58 364768 881242 629459 .15433.47 HS 000 7.21 87.01 6059894.02 496055.69 8800.00 8999 308.60 3593.60 3647.70 6710.33 635698 -15511.62 HS 0.00 7.21 87.01 605995628 49597745 8900.00 89.99 308.60 3593.62 3647.72 8808.23 641937 15589.77 HS 0.00 7.22 87.01 6080018.55 495899.21 Cry 2/100 8937.60 89.99 308.60 3593.63 3847.73 884504 644283 -15619.18 32.729 0.00 7.22 87.01 808004195 495869.79 SI NW2 T017 8968.08 90.50 308.93 359350 3647.60 8874.87 646191 -1564292 40.66 2.00 7.22 87.47 606006100 495848.00 End Cry 898962 9083 309.21 3593.25 364735 6895.92 647519 15859.85 HS 2.00 7.23 87.75 606007455 49582926 9000.00 90.83 30921 3593.10 3647.20 6906.06 648205 15867.69 HS 0.00 7.23 8775 608008110 49582121 9100.00 90.83 30921 359166 3645.76 7003.73 654526 -15745.16 HS 0.00 7.23 87.75 6060144.18 49574364 9200.00 9083 30921 359021 3844.31 7101.41 8608.47 -15822.64 HS 0.00 7.24 87.75 608020726 49588808 9300.00 90.83 30921 3588.77 3642.87 7199.08 867168 15900.11 HS 0.00 7.24 87.75 6080270.35 495588.51 9400.00 90.83 30921 3587.33 3841.43 7296.76 673489 -15977 59 HS 0,00 7.25 87.75 608033343 49551095 Cr/2.5/100 9405.72 9083 309.21 3587.24 3841.34 7302.35 673651 -15982.02 33.939 0.00 7.25 87.75 606033704 495508.51 SI NW2 1988 947641 9200 310.00 3585.50 36339.60 7371.27 678358 -16036.47 46.089 2.00 7.25 88.79 608038200 49545200 9500.00 9233 310.34 3581.61 3838.71 7394.21 6798.76 -16054.48 46.099 2.00 7.28 89.07 6080397.18 495433.97 End Cry 9554.83 93.09 311.13 358202 3636.12 7447.38 683450 -16095.97 HS 2.00 7.26 89.71 6060432.85 495392.42 9600.00 93.09 311.13 3579.59 3633.89 7491.09 6864.17 .16129.95 HS 0.00 7.28 8971 608048248 495358.40 9700.00 9309 311.13 3571.20 3628.30 7587.86 6929.85 .16205.16 HS 0.00 7.27 89.71 606052802 49528309 9800.00 93.09 311.13 3588.81 3622.91 7684.64 6995.54 -16280.37 HS 0.00 7.27 89.71 608059358 495207.79 990000 9309 311.13 3563.43 3617.53 7781.41 706122 -1655.58 HS 0.00 7.28 89.71 6060659.14 495132.48 Cry 2.5/100 9918.10 93.09 311.13 356245 3616.55 7798.93 7073.11 -16369.20 144.759 0.00 7.28 89.71 6060671 01 49511885 SI NW2 T019 998466 9200 311.90 356950 3613.60 7863.28 7117.18 -16418.99 155.789 2.00 7.28 8852 608071500 49508900 2000000 00 91.72 312.03 3559.00 3613.10 787806 7127.43 16430.39 155.796 2.00 728 8822 606072523 495057.59 End Cry 2006107 90.81 312.53 3557.76 3611.86 7936.92 716821 .16475.56 HS 2.00 7.29 8705 808076623 495012.35 2010000 90.81 312.53 355735 3611.45 7974.40 719182 -1650425 HS 0.00 7.29 8705 806079250 494983.63 20200.00 90.61 312.53 355629 3610.39 8070.68 7262.41 -18577.99 HS 0.00 7.30 8705 808085996 494909.84 2030000 90.61 312.53 355523 3609.33 8166.95 7330.00 -16651.63 HS 0.00 7.30 8705 6060927/3 49483605 2040000 90.61 31253 3554.18 3608.28 8263.23 7397.59 -16725.33 HS 000 7.31 8705 608069490 49476226 Cm 2300 20438.34 90.81 312.53 3553.79 3607.89 8298.22 7422.15 -16752.10 123296 0.00 7.31 8705 6081019.42 494735.44 SI NW2 T0110 2049156 9000 313.45 355350 3607.60 8351.26 745980 .16792.49 906 2.00 7.31 88.32 608105700 49469500 2050000 90.00 313.82 355350 3607.60 835935 748561 .16798.62 9DR 2.00 7.31 8630 608106281 49488887 End Cry 20501.81 9000 313.68 355350 3607.60 8381.08 7466.86 -16799.92 HS 2.00 7.31 8629 6061064.05 494687.56 20000.00 9000 31566 355350 3607.60 8455.08 753465 -16870.97 HS 0.00 7.32 8629 6061131.72 49481842 20700.00 90.00 31566 35350 3807.60 855082 780388 -18943.32 HS 0.00 7.32 8629 6081200.63 49454397 20800.00 90.00 313.88 3553.50 3607.80 8646.5 7672.71 -17015.67 HS 0.00 7.33 8829 606126954 494471.52 20900.00 90.00 313.86 3553.90 3607.80 8742.28 7741.74 -17088.02 HS 0.00 733 8629 6061338.45 494399.07 Cm 2/100 20998.72 90.00 313.86 3553.50 3607.60 883487 780850 .17158.00 901 0.00 7.33 8629 608140510 49432900 SI NW2 Tg111 20999.47 9000 313.60 3553.50 3607.60 8837.51 7810.40 -17159.99 148.87L 2.00 733 8630 6061407.00 49432700 21000.00 89.99 313.59 3553.50 360760 8838.02 781077 -17180.37 148.87L 2.00 733 8829 6061407.37 494326.62 21100.00 88.28 312.56 3555.01 3609.11 8934.02 787906 -17233.40 148.51 2.00 7.34 84.74 608147553 49425349 End Cry 21151.79 87.39 312.02 355.96 3611.06 8983.88 791385 -17271.65 HS 2.00 7.35 8394 8061510.28 494215.19 21200.00 87.39 312.02 355916 3613.26 9030.39 794612 -17307.46 HS 0.00 7.35 8394 608154248 494179.33 21300.00 8739 31202 3583.71 3617.81 912681 801300 -17381.67 HS 0.00 7.35 8394 606180923 49410503 Cm 2/100 21369.27 8739 81202 3586.86 3620.96 9193.60 805932 -17433.07 19.541 0.00 7.38 8394 6061655.47 49405356 21400.00 87.97 311.82 3568.10 3622.20 9223.25 807984 -1745592 19.53L 2.00 7.36 84.55 6081675.95 49403068 21500.00 89.88 311.15 3589.99 3624.09 9319.98 8146.08 -17530.82 19.521 2.00 737 86.51 6061742.05 49395.69 SI NW2 13112 21507.54 90.00 311.10 3570.00 3624.10 9327.29 8151.02 17538.50 12.02L 2.00 737 8666 6081747.00 493950.00 End Cry 21510.19 9006 311.09 3570.00 3824.10 9330.15 8152.96 -17538.72 HS 2.00 7.37 88.71 8081748.93 49394778 21800.00 90.06 311.09 3589.91 3824.01 941691 8211.79 -17608.18 HS 0.00 7.37 88.71 8081807.65 493880.23 21700.00 90.06 311.09 3569.81 3623.91 9513.85 827751 -1788158 HS 0.00 7.38 86.71 6061873.25 493801.76 2180000 9008 311.09 3589.71 3623.81 9810.78 834323 -1775693 HS 0.00 7.38 86.71 6061938.85 493729.30 21900.00 90.06 311.09 3569.81 3623.71 9707.71 8408.95 -1783230 HS 0.00 7.39 88.71 608200444 193653.83 Cry 2/100 21996.77 9006 311.09 3589.51 3823.61 9801.51 8472.55 -1790523 99.049 000 7.39 86.71 6062087.92 493580.80 2200000 9005 311.15 3589.51 382361 980464 8474.68 .1790767 99 049 2.00 7.39 86.70 6062070.04 49357037 SI NW2 T9113 22015.11 9000 311.45 3569.50 362360 981928 848485 -17919.02 909 2.00 7.39 86.61 806208000 49356700 End Cry 2202941 9000 311.74 3589.50 382360 9833.10 8494.14 -17929.71 HS 2.00 7.39 86.56 6062089.47 493556.30 2210000 90.00 311.74 358950 382360 990133 8541.13 .1798239 HS 0.00 7.40 86.56 6062136.38 493503.55 22200.00 9000 311.74 359.50 3623.60 999797 8807.70 -18057.01 HS 0.00 7.40 8656 606220282 493428.83 22300.00 90.00 311.71 359.50 3623.80 20091.62 887427 -18131.63 HS 0.00 7.40 8656 606226927 493354.12 2240000 9000 311.74 358950 3623.60 2019127 8740.84 -1820625 HS 0.00 741 8606 8082335.72 49327940 22500.00 90.00 311.74 356950 3623.60 20287.92 880741 -18280.88 HS 0.00 741 8656 6062402.17 493204.68 Cry2/100 22521.82 9000 311.74 356950 3623.60 20308.81 8821.80 -1829701 909 0.00 7.41 86.56 606241653 493188.53 SI NW2 Tat 14 2252232 90.00 311.75 35950 3623.60 2030949 882227 -18297.53 7.439 2.00 741 8856 606241700 49318800 22600.00 91.54 311.95 3568.46 362256 20384.52 8874.09 -1835.39 7.439 2.00 742 8806 6062468.72 49313007 End Cry 22625.82 92.05 31202 35875 3621.75 2040943 889135 -18374.57 HS 2.00 742 8855 6082485.95 49311087 2270000 92.05 312.02 356499 3619.09 20480.98 894098 -18429.85 HS 0.00 7.42 8855 606253549 49305.72 2280000 92.05 312.02 351.41 3615.51 20577.44 900707 -18503.89 HS 0.00 7.43 8855 606260226 492981.38 22900.00 92.05 312.02 357.83 3611.93 20673.90 907476 18578.14 HS 0.00 743 8855 608266803 49290703 Cry 2J100 22927.47 92.05 312.02 3556.84 3610.94 20700.39 909314 -1859853 175.88L 0.00 7.43 8855 606268737 49288661 23000.00 90.61 311.91 355.16 3609.26 2077040 914182 -1865245 175.881 200 7.44 8714 6082735.77 492832.63 SINW2 Tp115 23030.38 90.00 311.87 355.00 360910 20799.72 916189 -186755 166.5L 2.00 7.44 86.54 606275600 49281000 End Cry 2304209 89.77 311.82 3555.02 3609.12 20811.04 916972 -18883.78 HS 2.00 744 86.33 6062763.81 49280125 23100.00 89.77 311.82 3555.25 3609.35 20867.00 920833 1872895 HS 0.00 7.44 8633 606280235 49275.03 23200.00 89.77 311.82 355.85 3609.75 20963.61 9275.00 1880148 HS 0.00 745 8633 608286890 492683.41 23300.00 89.77 311.82 355.05 361015 21060.22 934168 18876.00 HS 000 745 8633 8082935.45 492808.78 2340000 89.77 311.62 3558.45 3610.55 2115.83 940835 -18950.53 HS 0.00 7.46 86.33 6063002.00 49253416 23500.00 8977 311.82 355.85 3810.5 2125344 9475.02 -19025.06 HS 0.00 7.46 86.33 6083068.5 49245953 Cm 2/100 23534.09 89.77 311.82 3556.98 3611.08 21286.37 9497.75 -19050.47 128.758 0.00 7.46 8633 606309124 492434.10 SI NW2 59116 23538.24 89.72 311.88 355700 3611.10 21290.38 9500.52 -19053.56 121496 2.00 746 8827 6083094.00 492431.00 End Cm 23543.87 8966 311.98 3557.03 3611.13 2129582 95428 19057.75 HS 2.00 718 88.19 6063097.75 492426.81 2380000 8968 311.98 357.36 361146 21350.01 954182 -19099.48 HS 0.00 7.46 86.19 606313523 49238502 2370000 8968 311.98 3557.95 361205 2144855 9608.70 -19173.82 HS 0.00 7.17 86.19 6063201.99 49231059 23800.00 89.68 311.98 355855 36125 2154308 967558 -19248.18 HO 0.00 747 86.19 606326874 492238.15 2390000 89.5 311.98 355914 3613.24 2183962 974246 -19322.50 HS 0.00 7.48 86.19 6063335.50 492161.71 2400000 89.66 311.98 359.73 3613.83 21738.16 980934 -19396.84 HS 0.00 718 86.19 606340226 492067.27 TO 24048.04 89.86 311.98 358000 3814.10 21780.61 9840'4 -19431.07 0.00 748 88.19 606343300 492053.00 Surrey Error Model: ISCW SA Rev 0"'3-095 000%Co11k/once 2/955 MIMI Survey Program: MD From MD To ECU Frog Nolo 55e Casing Demeter Description Part X11 Poi (10 Bnl IM Survey Tool Type Borehole/Surrey 1 0.000 1175.000 1/100.000 18.000 13375 SL13_NSS.SSNOT 0126-NW2/51289W2(P4b) 1 1175.900 2851.879 1/100.000 10000 13375 SL13MWDr.SAG 0126-NW2/S1296W2(P4b) 2 1175000 2851.879 1/100.000 18.000 13375 SIB_MWD.GMAG S128-NW2/SI26-NW2(P4b) 2 2851879 4350000 1/100.000 12250 9.825 SLB_MWDaSAG S126-NW2/S128-NW2(P4b) 5 3 2851.879 154154 1700.000 12.250 9.825 SL6_MWD#OMAG 0126-NW2/5128-NW2(P413 3 1541515 18920.000 1/100.000 8150 5.500 SLB_MWD.SAG 0126-NW2/SI28-NW2(P4b) 4 15415.45 24048.044 1/100.000 8.750 5.500 SLBM_WD.GMAG S126-18W2/S126-NW2(P49) Leg.!2..crlp6on: Northing('7) (sating g() Surface:44424 FSL 14105 FEL S19 T143 R9E UM 6053824.030 511497340 rm2 heel:3530 FSL 3837 FEL 14 T14N R8EUM 8057982.000 498708.000 Id/BHL:3697 FSL 5207 FEL 10 1113 R8EUM 6063433.000 492053.000 Drilling Office 2.7.998.0 Nlkaltchuq\Spy Island\S126-NW2\S126-NW2\S126-NW2(P2) 10/7/2014 11:48 AM Page 3 of 3 N (/) To U_ C Q1 . ... ..........r.... ., ......i...........e.. .}. O 4"". . ._ M w •t, Q, N E$ l I 1 c c, Q O p e5'7,�i N e V O u Cr (.11)(..)A1 >e 88 Q _ _ W V! QQ 1 1I 1 I 1 8Q8Q8a8pt N N 07 (O M 0 Hl2JON 00 H1llOS O O N o 0 0 0 ev 2o zr m O o S N • f O A ckQZ/N, -v a:Zee\e.Z S.Z Ve• eet ° 0 14'dfe 414 0°(f f B a ie y C s o • p 0 o "Y • `� et "b e��d' , o cn co N 8 •�,, ° ¢� deo,� ¢� 4V(' ai d2 �Alk ° i q "t q� Zy trgi V m U_ I 4.4). �4j,�_ro!` ° -Y f / `6f flf o f -t(0 .... . `° , / a O 1 �' Y� r'ee - O et, %), Q1,,,,_ . (2,,gzet/ it,%ke z 4,, ,:' Qc4t • Z ° a � "t/a ° eZtt/� `C •per% ll Z I Q� r` O p.Yf O CV 0_ • I Q1.B <`�—o Cr i w f O p-�p �l M NKr 6' f p Y O. O �`�f-e ° Oaf,\/i -V ��('.a� Y ° 2�t f`fef ` ; / city .- Z LL Z ° ��f �t�°j<f° ch,6,,, 'Il a I ¢� �'if azu p ref ° /,� I ^; Nr !n h<f0l 00 N Bl. Lo II V c `�s�tff fPO NCI_ ii LL Tv a^ O O B 2cn ��R`� __�B O U w," co m Q.� A co yn t ti N ` ,—a4++maeliy, •V X f f., o y Qze N z ` ( Z �00% ask. IV Z 3 00 I.. a `41(4., - _ o v „: 7i0/ _.. Q co �D °° CV ,c' _ J ` m I 0-3 m a Qlza E O ry J pa SO '.- i' po d o O O N a 2o. U) a a01 1 °' o Z I Z Z N C •C C 6 N °' a C v N' C C7)r o l` . o u L'. NN oN CV Z C' 2I 1 (O 0 Uo o N f m II vCO .a I � , i I y o 0 0 0 0 0 0 Ao CO N co co N (4)09L:1,=aleoS(8)SN SI26-NW2(P4b)Anti-Collision Detailed Report Analysts Method: 3D Least Distance Distance Unit ft Depth Interval: Every 100.00(ft)Measured Depth Azimuth Unit deg Step-down Trajectory: Reference Trajectory IC Azimuth Reference: North Analysts Date-20hr Time: October 03 2014-17:30 North Reference: Ina Analysis Machine: AKA-DEC-9010 Client Eni Petroleum Database 1 Project: localhoribrillirg-Nikaltchuq 27 1043 Version/Patch: 27.10430 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 010300 m is always included for borehole diameters. All local minima Indicated. Results filtered:Depth 15400.00 ft<.MD<.24046.04 ft,Ct-Ct separation c=1500.00 ft Results highlighted:EOU-EOU separation<.1320.00 ft Anti-Collision Rules Used Rule Set Name DAM AntiCollision Standard S002 v5.1/52 Exemption Risk Level: Minor sole borne )tisk Level 8111.9 1.2121 Rale Label RoGo Rule SLB Alert Zone Threshold OSF=50 5002 05.1/5.2 Alert Ratio OSF=500 SLB Minor Risk Threshold OSF=1.5 5002 v5.1/5.2 Minor Ratio OSF=1.50 % SLB Major Risk Threshold OSF=1.0 5002 05.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule 000205.1/5.2 Major CT_CT MAS=32.81(ft) SLB Alert Zone Threshold CtC1<=15m 5002 v5.1/52 Alert CT_CT MAS=49.21(ft) Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 1 of 15 Reference Trajectory Summary Field: Nikedchuq Well: 5126-NW2 Structure: Spy island Borehole: 5126-NL12 Slot SP26 Trajectory: 5126-NW2(P46) Client En;Petroleum Type: Def Plan Coordinate System: 04027 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angie: 0.08892286. Grid Seale Factor: 099990015 Magnetic Declination: 19.102' Magnetic Declination Date: November 15.2014 Magneto Model: BGGM 2014 Reference Point lizthi0g Eating Elevation Structure Unc SlotQne. 6053624030(FUS) 511497.340(f1US) 54.100(11)MSL 0000(ft)(1 sigma) 0.000(11)(1 sigma) Tralectory Error Morel'ISCWSAO 3-0 95.000%Confidence 2.7955 sigma $urvevino Roy While Drilling Description Part MD From(R) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Size(In) Casing Diameter(in) Borehole/Survey 1 0.000 41.000 1/100.000 SLB_NSG+SSHOT-Depth Only-No Globe 16 000 13.375 5126-NN2/S126.NW2(P4b) 1 41.000 1175.000 1/100.000 SLB_NSG+SSHOT-No Globe 16000 13375 S126-NW2/3126NW2(P4b) 1 1175.000 2851879 1/100.000 SLB_MWD+SAG-No Globe 16000 13.375 0126-NW2/5126-NW2(P4b) 2 1175.000 2851.879 1/100.000 SLBMWD+GMAG-N0 Globe 16000 13375 S126-NW2/0126NW2(P4b) 2 2851.879 4350.000 1/103.000 SLB_ W MD+SAG-No Globe 12250 9625 S126-NW2/SI26-NW2(P4b) 3 2851.679 15415.455 1/100.000 SLB_MWD+GMAG-No Globe 12.250 9.625 5126-NW2/S126NW2(P4b) 3 15415.455 16920.000 1/100.000 SLB_MWD+SAG-No Globe 8.750 5.500 S126-NW2/SI26-NW2(P4b) 4 15415.455 24046.044 1/100.000 SLB MWD+GMAG-No Globe 8750 5.500 5126-NW2/0126NW2(P4b) Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 2 of 15 Offset Trajectory Summary Offset Selection Cdledy Offset Selection Criteria.Definitive Surveys-Definitive Plans-Definitive surveys exdude 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 Selection Summary Walls Selected:5 Boreholes Selected'.8 Definitive Surveys Selected:4 Non-Def Surveys Selected:i Definitive Plans Selected:4 Non-Def Plans Selected:0 Total Trejectories9 OSF filter in detailed report None •Excluded:The lrajedory was analyzed and fully passed all criteria so the detailed results have been excluded horn this report for clarity. Trajectory Borehole Well Type Passim Excluded' V/ SP28-NW3L1(P1) SP28-NII WLI SP28-NW3 Def Plan 51430-WI PB1 SP30-W1PB1 SP30-W1 Def Survey SP30-W1 SP30-W1 SP30-W1 Def Survey 51428-NW3(P2) SP28-NW3 SP28-NW3 Def Plan SP21-NW1 current SP21-NWI SP21-NW1 Non-Def Survey SI32-W2 SI32-W2 9132-W2 Det Survey SP21-NW1L1(P8) 51421-NWI L1 SP21-WW1 Def Plan SP21-NW1(P8) SP21-NWI SP21-NWI Def Plan SP22-FN1 S1422-FN1 51422-FN1 Def Survey • • • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 3 of 15 Field: MBeydwq Well: SP28-NN3 Structure: Spy/eland Borehole: SP28-NW3L1 Slot: SP28 Trajectory: SP28-IJW3L1(P1) Client: Eni Petroleum Type: Def Plan Coordinate System: 144027 Aleake Stele Plane,Zone 04.US Feel North Reference: True Grid Convergence Angle: 0 08880162' Grid Scale Factor: 0.99990015 Magnetic Declination: 19.483' Magnetic Declination Date: February 07,2014 Magnetic Model: BGGM 2013 Reference Point: Northing fasting Elevation Structure Unc. Slot Unc. 6053621 010(SUS) 511481 670(SUS) 54.100(ft)MSL 0000(ft)(1 sigma) 0000(k)(1 egma) Trajectory Error Model:ISCWSAO 3-D 95.000:Confidence 2.7965 slums Survevina Pros'While Drilling Description Part MD From(ft) MD To(S)EOU Freq(ft) Survey Tool Type Hole Size Din) Casing Diameter Din) Borehole/Survey I 0.000 41.000 1/100.000 SLB NSG+SSHOT-Depth Only-No Globe 16.000 13.375 SP28-NW3/SP28-N1AO(P1) 1 41.000 1000.000 1/100.000 SLB_NSG+SSHOT-No Globe 16.000 13.375 SP28-NW3/SP28-NW3(P1) 1 1000.000 2500.000 1/100.000 6LB_MII9D0SAG-No Globe 18000 13.375 SP28-511A0/0P28-NW3(P1) 2 1000000 2940.507 1/110.000 SLB_MWD+GMAG-No Globe 16.000 13.375 SP28-NW3/SP28.14003(P1) 2 2940.507 4405.000 1/100.000 SLB_MWD«SAG-No Globe 12.250 9.825 SP28-NAG/SP28-14003(P1) 3 2940507 15179.532 1/100.000 SLB_MWD+GMAG-No Globe 12.250 9625 SP28-NW3 l SP28-NW3(P1) 3 15179.532 15500.000 11100.000 SLB_MWD+SAG-No Globe 8.750 5500 SP28-NW3/SP28-NVG(P1) 4 15179.532 15500.000 1/100.000 SLB_MWD+GMAG-NO Globe 8.750 5.500 SP28-NW3/SP28-NW3(P1) 4 15500.000 23713.709 1/100.000 SLB_MWD+SAG-No Globe 30.100 30.000 SP28-NW3L1/SP28-NW3L1(P1) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Of/s.tEW North Asim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (T) (ft) (k) (k) (ft) (R) (') (5) (ft) (k) All local minima indicated. Results filtered:Depth 15400.0055=MD 44 24046.048 Results filtered:Ct-Ct aspiration<=1500.00 It Results highlighted:Ct-Ct aeperation a=132600g 15410.45 360810 4378.26 -12783.86 15684.69 3551.80 3504.23 -13403.39 2180 197(811 512.81 73,, 3.14 OSF 1.50 Waning 15500.00 3613.46 4430.60 -12856 31 15736 47 3555.03 353322 -13446.16 220.25 167$47 519.121 72:: al OSF 1.50 Warning 15600.00 3617.97 449368 -1293375 15793.67 355900 3563.45 -1349456 22377 1087.81 525.27 77- 31 OSF 150 Warning 16100.00 362575 485506 -1327864 1639338 357366 3899.12 -1398875 228.34 119197 51548 64 OSF 1.50 Warning 16300.00 3629.43 4991 22 -13424.92 16516.03 3573.26 3969.19 -1408939 222.08 122034 528 64 86 3 4 OSF 150 Warning 17315.84 3823.64 5499.94 -14302.11 17466.11 359111 4461.78 -14%111 210.9 ((tlMi1112(181] 582: 1. -- OSF 1.50 Warning 17445.04 3624.10 5565.91 -14413.19 17602.53 3593.88 4530.39 -1501898 213.44 -Prr• 585 f 80!:J OSF 150 Warning 17500.00 362425 5595.48 -14459.51 17657.44 3594.65 4558.10 -15066.39 214.50 1202.22 58'1 0 OSF 1.50 Warning 17700.00 3624.72 5708.19 -1462472 17856.94 359746 4658.78 -1523860 215.851 6.09 0'59-. I W OSF 1.50 Warning 18200.00 363933 599089 -1503667 18459.06 36.0923 4994.71 -15737.85 215.71 9 6 3 OSF 1.50 Warning 18300.00 3644.24 6048.32 -1511839 18543.61 3610.28 5043.03 -1580721 217.42 §1 611'Q 297 OSF 1.50 Warning 18400.00 3646.99 610801 -1519856 1862339 360882 5087.61 -15873.36 21918 122394 62' 296 OSF 150 Warning 18460.62 3647.60 6145.26 -15246.37 18680.53 3606.63 5119.05 -15921 02 220.30 1228.80 624: 1 OSF 1.50 Warning 20100.00 3611.45 7194.82 -16504.25 20519.88 3597 49 6343.30 -17288.85 22322 11 685 59 2.54 OSF 1.50 Warning 23200.00 360975 9275.00 -18801.48 23713.71 3600.86 8614.96 -19524.24 222.36 856.79 1.71 OSF 1.50 Warning 23300.00 3610.15 934168 -18876.00 23713.71 3600.86 8614.96 -19524.24 222. 881.88 - 1.66. OSF 1.50 Warning 23400.00 3610.55 9408.35 -18950.53 23713.71 3600 86 8614.96 -19524.24 222.36 / 8%.14- 3(696 .1.641 OSF 1.50 Warning 2350000 3610.95 9475.02 -19025.06 23713.71 360086 8614.% -19524.24 222.36 99448 905.26 39057 1.65 OSF 1.50 Warning 23534.09 3611.08 9497.75 -19050.47 23713.71 3600% 8614.96 -1952424 22236 100194 905.70 39773 1.66 OSF 1.50 Warning 23538.24 3611.10 9500.52 -19053.56 23713.71 3600 86 8614.% -19524.24 22241 1002.93 905.69 39873 1.% OSF 1.50 Warning 23543.87 3611.13 9504.28 -1905775 23713.71 360086 8614.96 -19524.24 22249 1004.30 905.63 40013 1.66 OSF 1.50 Warning 23600.00 3611.46 954182 -19099.48 23713.71 360086 8614.96 -19524.24 222.49 101961 903.82 41666 1.69 OSF 1.50 Warning 23700.00 3612.05 960870 -19173.82 23713.71 360086 861496 -19524.24 222.49 105378 89516 45660 1.77 OSF 1.50 Warning 23800.00 3612.65 %75.58 -19248.16 23713.71 3600.86 8614.% -19524.24 222.49 1096.03 880 75 508 46 1.87 OSF 1.50 Warning 23900.00 3613.24 974246 -19322.50 23713.71 360086 8614.% -1952424 22249 114548 86219 57027 199 OSF 1.50 Warning 24000.00 3613.83 9809.34 -1939684 23713.71 3600.86 8614.% -19524.24 222.49 1201.23 840.94 64020 2.14 OSF 1.50 Warning 24346.04 3614.10 9840.14 -1943107 23713.71 3600.86 8614.% -19524.24 222.49 122879 83059 67466 2.22 OSF 1.50 Warning End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 4 of 15 Field: Nikeilc/ruq Well: SP28-NW3 Structure: Spy Island Borehole: SP28-NW3 Slot: SP28 Trajectory: SP28-NW3(P2) Client: Eni Petroleum Type: De!Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.06880162" Grid Scale Factor 0.99980015 Magnetic Declination: 19.310° Magnetic Declination Date: May 30.2014 Magnetic Model: BOGM 2013 Reference Point oN rthina Eastlna Elevation Structure Unc. Slot Unc. 6053621 010(ft26) 511481 670 Mt%) 94.100 in)MSL 0000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-0 95.000:Confidence 2.7956 slgma Survey/no Pros:While Drilling Description Part MD From(ft) MO To(f8 EOU Freq(8) Survey Tool Type Hole else(b) Casing Diameter 9n) Borehole/Survey 1 0.000 41.000 1/100.000 SLB NSG+SSHOT-Depth Only-No Global 16.000 13.375 SP28-NNW/SP2S-NW3(P2) 1 41.000 1000.000 1/100.000 SLB_NSG+SSHOT-No Globe 16.000 13.375 SP28-NW3/SP28-NW3(P2) 1 1000,000 2500000 1/100.000 SLB_MWEHSAG-No Globa 16%0 13375 SP28-NW3/SP28-NW3(P2) 2 1000.000 2940.507 1/100.000 SLB_MWD+GMAG-No Globe 18.000 13.375 SP25-NMA/SP28-NEW(P2) 2 2940507 4405.000 1/100000 SLB MWD+SAG-No Globe 12.250 9.625 SP28-NW3 I SP28-105.0(P2) 3 2940.507 15179.532 1/100.000 SLB_MWD+GMAG-NO Globe 12.250 9.625 SP28-NW3/SP28-NW3(P2) 3 15179.532 16700.000 1/100.000 SLB_ W3 MWD+SAG-No Globe 8.750 5.500 SP28-N /SP28-NW3(P2) 4 15179.532 23679.837 1/100.000 SLB_MWD+GMAC-No Globs 8.750 5.500 SP28-NW3/SP28-NW!(P2) • Minimum Travehog Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct D'stanoe Separation Clearance OSF Controlirg RWM Status (h) (ft) (8) (ft) (ff) (ft) (ft) (ft) () (8) (ft) (ft) All local minima indicated. • Results filtered:Depth 15400 00 ft<=MD<=24046.04E Results filtered:Ct-Ct separation c 1500.00 ft Results highlighted:Ct-Ct separation<=1320.006 '.5600 3C 36::-1,... 4493.68 -12933 75 15962.58 3576.48 3710 79 -13618.15 223. 490.7 8L7!EI.3E; OSF 1.50 Warning15900 00 3622 09 4709.34 -13141.77 16248.69 3587.93 3902.20 -13830.44 230.60 1 1 il 49749 --'4 5tilltiltilllMOK.4.. OSF 1.50 Warning 16000.00 3623.19 4793.10 -13209.26 16321 94 3589.41 394902 -13886.76 227,65 503.91 738.7'�Y% OSF 1.50 Vyaming 17400.00 362396 5542.34 -14374.81 1755485 3578.54 4599.12 -14932.55 2134 800233.9 695700 .4 OSF 1.50 Warning 17445.04 3624 10 5565 91 -14413.19 17599.88 3579.18 4822.01 -14971.32 21434 602_ 895 78 2 73 OSF 1.50 blaming 17500.00 3624.25 5595.48 -14459.51 17654.80 3579.97 464994 -15018.81 21540 109936 694 76 2 73 OSF 1.50 Warning 17700.00 3624.72 5708.19 -14624.72 17854.36 3582.93 4751.40 -15190.42 216.73 111991. 61261 703.5 OSF 1.50 Warring 18200.00 3639.33 5990.89 -15036.67 18449.86 3594.67 508396 -15683.89 2t668p all. 620.29 7911 7 OSP 1.50 Waning 18300.00 364424 604832 -15118.39 1853237 3597.28 5131.36 -1575138 218.25 )15lll"'�� 62634 $01.211 267 OSF 1.50 Warning 18400.00 3646.99 610801 -15198.56 18609.27 360107 5174.21 -1581511 219.74 111992 632.95 5/199/.55 2.66 OSF 1.50 Warning 18480.82 3647.60 614526 -15246.37 18658.40 3604.15 5200.86 -1585627 22090 636.63 700.23' 2.611 OSF 1.50 Waning 20100.00 3611 45 7194.82 -16504.25 20489.33 3588 39 6420.43 -17216.29 223781opi 667.45 608.87 2 3 OSF 1.50 Wa ing 20491 56 3607 60 7459 80 -16792.49 20872.37 3581 57 6877.99 -17499.66 224.86 683.76' $$� 1 OSF 1.50 Wa ning 21600.00 362d.01 6211 79 -17808.18 21992.99 3593 W 7432.22 -18328.06 222.73 1062.90 722.41 $60. 1 OSF 1.50 Warn ng 22200.00 362360 860770 -18057.01 22659.50 3599.57 7906.10 -18796.55 223.09 1019.68 72826 533. j�191 OSF 1.50 Waning 23200.00 3609 75 9275 00 -18801.48 23679.84 3587 99 8689.89 -1944912 22328 7 757 46 367.71 / 3 OSF 1.50 Warning 23300.00 3610.15 934168 -18876.00 23679.84 358799 868989 -19449.12 223. 791.25945.$5 1.65 OSF 1.50 Warning 23400.00 361055 9408.35 -18950.53 2367984 358799 868989 -19449.12 22328 814.69 '57(810) 161 OSF 1.50 Weming 2350000 3610.95 947502 -19025.06 2367984 3587.99 868989 -19449.12 223.28 89263 82734 340 1.62 OSF 1.50 VVaming 23534.09 3611.08 9497.75 -1905047 2367994 358799 868989 -1944912 223.28 90116 829.28 34790 163 OSF1.50 Warning 23538 24 3611.10 950052 -1905358 2367984 3587.99 868989 -19449.12 223.33 902.29 829.44 348.92 1.63 OSF 150 Warning ' 23543 87 3611.13 950428 -19057.75 23679.84 3587.99 868989 -1944912 22341 90385 829.61 350.36 1.63 OSF 150 Warning 23800.00 3811.46 9541.82 -19099.48 23679.84 358799 868989 -19449.12 223.41 921.19 829.84 367.55 1.87 OSF 1.50 Warning 2370000 3612.05 9608.70 -19173.82 23679.84 3587 99 8689 89 -19449.12 223.41 859.47 823.89 409.74 1 75 OSF 1.50 Warning 23800.03 3612.65 9675.58 -19248.16 23679.84 3587.99 8689.89 -19449.12 223.41 1006.27 811.72 464.72 1.86 OSF 1.50 Warning 23900.00 3613.24 9742.46 -1932250 23679.84 358799 868989 -1944912 223.41 1060.46 795.01 530.05 2.00 OSF 1.50 Warning 24000.00 361383 9809.34 -19396.84 23679.84 3587 99 8689 89 -19449.12 223.41 112097 775.57 803.52 2.17 OSF 1.50 Warning 24048.04 3614.10 9840.14 -1943107 23679.84 358799 868989 -1944912 22341 1150.89 76809 639.56 2.25 OSF 1.50 Warning End of r sults • • • • • • • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 5 of 15 Field: Nikertchuq Well: SP30-W1 Structure: Spy Island Borehole: SP30-WI Slot SP30 Trajectory.. SP30-WI Client: Eni Petroleum Type: Def Survey Coordinate System: 54027 Alaska Stele Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08867938° Gnd Scale Factor: 0.998500149 Magnetic Declination: 20.271° Magnetic Declination Date: October 15,2012 Magnetic Model: BGGM 2012 Reference Point: Nortnlna Eastina Elevatlon Structure Unc. Slot Une. 6053617 960(ftUS) 511465.870(905) 53 920(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Traiectory Error Model:ISCWSAO S-0 95.000%Confidence 2.7955 slgeee 5urvevina Proa:As Drilled Description MD From(It) MD To(ft) EOU Fteq Survey Tool Type Hole She(In) Casing Meme a(In) Borehole I Survey 0.000 40.820 ActStrla SLB_GVRO-MWD-Oepth Only-No Global 18.000 13.375 SP3O-WIPB1/SP3O-WIPB1 40.820 956580 Act-Stns SLB_GVRO-MWD-No Globe 18.000 13375 SP30-W1PB1/SP3O-Wt PBI 956.580 2599700 Act-Stns SLB_MWO+GMAG-No Globe 16.000 13.375 SP30-W1PB1/SP30-W1 PB1 2599.700 9465.920 Act-S815 SLB_MWO+GMAG-No Globe 12250 9.625 SP304W1P61/SP30-Wt PBI 9485.920 12948.130 Act-Stns SLB MWD+GMAG-No Globe 8.750 8.750 SP3O-WIPB7 I SP3O-WIPBI 12948130 17879.520 ActStrs SLB_MWO+GMAG-No Globe 8.750 5.500 SP3O-Wl/SP3O-W1 17879520 17945.030 Act-Stns SLB BLIND+TREND-No Globe 8.750 5.500 SP30-WI/SP3O-W1 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Onset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (ft) (ft) (h) (ft) (ft) (8) (') (8) -91)_- - (8) All local minima indicated. Results filtered:Depth 15400.00 8<=MD<=24046 04 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted Ct-Ct separation<=1320.00 ft 540.00 360743 437228 -12775.32 794503 362558 413912 -1154823 45.03 1209.17 164.72 1139.03 1144 OSF 1.50 Peas 541045 3608.10 4378.26 -12783.86 7945.0 362588 4139.12 -11548.23 45.03 1258.68 18359 114929 11.80 OSF1.50 Pass • 5435.45 360969 439257 -1204.30 7945.0 362588 4139.12 -11548.23 45.03 128148 18102 117381 12.0 OSF 150 Pas- 5500.0 3613.48 4430.60 -12856.31 7945.0 3825.88 4139.12 -11548.23 45.15 1340.21 154.38 1238.96 13.10 OSF 1.50 Pass 5600.0 3617.97 4493.68 -12933.75 7945.0 3625.68 4139.12 -11548.23 45.87 1430.18 144.78 1333.35 14.91 OSF 1.50 Pass 570.0 3820.82 4561.58 -1307.08 7945.0 3625.68 413912 -1154823 47.14 151879 138.15 142770 16.84 OSF 150 Pass • 58000 3822.02 4834.01 -13075.99 7945.0 3625.68 413912 -11548.23 48.85 1605.92 128.82 1519.71 18.83 OSF1.50 Pass 5819.23 362205 4648.44 -13088.71 7945.0 3625.68 413912 -11548.23 49.23 1822.49 127.57 1537.12 19.21 OSF1.50 Pass • ' 590000 362209 4709.34 -1314177 7945.0 362568 4139.12 -11548.23 49.23 10249 123.20 1610.03 2078 OSF1.50 Pass 590897 3622.0 4716.10 -1314788 7945.0 3625.88 4139.12 -11548.23 49.23 1700.32 12279 1618.13 20.93 OSF 1.50 Pass 592064 362210 472487 -1315536 7945.0 3625.68 4139.12 -11548.23 48.84 1710.55 122.29 1828.89 21.14 OSF 1.50 Pess • 5996.14 3623.10 478532 -1320658 794500 362568 4139.12 -11548.23 49.39 1777.99 11974 107.83 22.44 OSF 1.50 Pass 800.0 3623.19 4783.10 -13209.26 7945.10 3625.68 4139.12 -11548.23 49.39 1781.49 119.65 1701.40 22.51 OSF 1.50 Pass 61000 362575 4855.0 -1327864 7945.0 3825.88 4139.12 -11548.23 49.39 187267 117.70 1793.87 24.05 OSF1.50 Pass 6111.04 3626.03 4863.01 -1328830 7945.0 3625.68 4139.12 -1154823 49.39 188279 117.56 1804.0 24.21 OSF1.50 Pass 6200.0 3627.88 492534 -1334973 7945.00 3625.68 4139.12 -11548.23 45.76 196559 118.88 1887,34 25.43 OSF1.50 Pess 830.0 3629.43 4991.22 -13424.92 7945.0 3625.68 4139.12 -11548.23 41.30 2061.08 118.79 198289 26.68 OSF 1.50 Pass 6400.0 363007 505244 -13503.98 7945.0 3625.66 4139.12 -11548.23 36.11 215849 117.05 2080.13 27.88 08F 1.50 Pass 8429.35 3830.10 5069.49 -13527.87 794500 3625.88 4139.12 -11548.23 34.32 218736 117.15 210.93 2823 OSF1.50 Pess 650.0 3629.84 5108.77 -13588.58 7945.0 3625.68 4139.12 -11548.23 28.33 2257.23 117.38 2178.65 29.08 OSF 1.50 Pass 660.0 3628.58 5160.02 -1367242 7945.0 3625.68 4139.12 -11548.23 11.54 2358.78 117.64 2278.03 30.29 OSF 1.50 Pass 6857.78 3626.61 520087 -13750.18 7945.0 3625.68 4139.12 -11548.23 308.62 2444.48 117.76 2365.64 31.39 OSF1.50 Pass 670.0 3626.28 5206.04 -13761.16 7945.0 3625.68 4138.12 -11548.23 308.62 2456.70 117.77 237785 31.54 OSF 1.50 Pass • 8772.67 3624.32 523799 -13826.40 794500 362588 4139.12 -11548.23 308.62 2529.34 117.83 245046 32.46 OSF1.50 Pass • 8800.0 3623.65 5250.10 -1385.89 7945.0 362568 4139.12 -11548.23 329.78 2558.86 117.85 247777 32.80 OSF 1.50 Pass • 6900.0 3622.22 5298.20 -13939.61 794500 3625.68 4139.12 -11548.23 22.06 2656.60 117.96 2577.63 34.05 OSF 150 Pass 693752 3622.10 531420 -1397253 794500 3625.68 4139.12 -11548.23 30.39 2894.08 112.33 281887 36.28 OSF 1.50 Pass 696158 3822.15 532594 -13993.54 794500 362588 4139.12 -11548.23 34.51 2718.10 112.34 284288 36.80 OSF1.50 Pass 700.0 3622.31 534491 -14027.0 794500 362568 4139.12 -11548.23 34.51 2756.44 112.35 288121 37.11 OSF1.50 Pass 710.0 3622.73 539393 -14114.11 794500 362568 4139.12 -11508.23 34.51 285826 112.40 278100 38.44 OSF 1.50 Pass • • 7200.0 3623.15 5443.04 -14201.21 7945.0 3625.68 4139.12 -11548.23 34.51 2956.10 112.46 2880.60 39.76 OSF 1.50 Pass • 730.0 3823.57 5492.18 -14288.32 790500 362568 4139.12 -11548.23 34.51 3055.94 112.52 2960.80 41.09 OSF1.50 Pass 7315.84 3623.64 549994 -14302.11 794500 362568 4139.12 -11548.23 34.51 3071.75 112.53 2986.41 41.29 OSF 1.50 Pass 740.0 3623.96 554234 -14374.81 794500 362568 4139.12 -11548.23 33.85 3155.72 112.59 3080.33 42.40 OSF 1.50 Pass 7445.04 3624.10 556591 -14413.19 79450 3625.68 4139.12 -11548.23 34.05 3200.58 112.84 3125,16 42.98 OSF 1.50 Pass 750.0 3624,25 5595.48 -14459.51 7945,00 362568 4139.12 -11548.23 34.85 3255.23 112.71 3179.77 43.69 OSF1.60 Pass 7573.84 3824.43 5636.60 -14520.85 7945.0 362568 4139.12 -11548.23 35.66 3328.50 112.82 3252.95 44.63 OSF 1.50 Pass • 760.0 3624.49 5651.44 -14542.39 7945.0 3625.68 4139.12 -11548.23 35.66 3354.41 112.87 3278.83 44.96 OSF 1.50 Pass 770.0 3624.72 570.19 -14824.72 7945.0 3625.68 4139.12 -11548.23 35.66 3453.52 113.07 3377.81 4620 OSF 1.50 Pass 780.0 3624.94 576494 -14707.0 7945.0 3625.68 4139.12 -11548.23 35.66 3552.87 113.29 3478.82 47.44 OSF 1.50 Pess • 7884.08 3625.13 5812.86 -14776.29 7945.0 3625.68 413912 -11548.23 3566 3836.08 113.48 3560.10 48.47 OSF 1.50 Pass 790.0 362521 5821.69 -1478940 7945.0 3625.68 4139.12 -11548.23 38.19 365187 11352 357587 48.66 OSF 1.50 Pass 7952.70 3626.10 5851.59 -1483279 7945.0 3625.68 4139.12 -11548.23 48.50 3704.17 113.64 3818.0 49.31 OSF1.50 Pass • 8000.0 3627.72 5876.37 -14871.74 7945.0 3625.68 4139.12 -11548.23 53.79 375109 113.75 367493 49.89 OSF 1.50 Pass 805182 3630.38 590746 -14914.30 7945.0 3625.68 4139.12 -11548.23 61.44 3802.29 113.85 3726.08 50.52 OSF 1.50 Pass 810.0 3633.30 5934.66 -14954.20 7945.0 3625.68 4139.12 -11548.23 81.44 385028 113.96 3773.98 51.11 OSF 1.50 Pass 8196.33 3639.23 5989.95 -1503529 7945.0 3625.68 4139.12 -1154823 6144 394783 114.15 3871.40 5232 OSF 1.50 Pass ' 620000 383833 590.89 -15038.87 7945.0 3625.68 4139.12 -11548.23 61.22 3949.49 114.15 387306 52.34 OSF1.50 Pass 830.0 364424 048.32 -15118.39 7945.0 3625.68 4139.12 -1154823 49.80 4048.63 114.40 3972.03 53.53 OSF1.50 Pass 8400.0 3646.99 610.01 -1519856 7945.0 3625.68 4139.12 -11548.23 41.53 4147.52 114.74 4070.0 54.68 OSF 150 Pess 846062 3647.0 6145.26 -1524637 7945.0 362568 4139.12 -11548.23 37.81 4207.30 114.98 413031 55.35 OSF1.50 Pess 8474.33 3647.63 6153.0 -15257.11 7945.0 3625.68 4139.12 -11548.23 36.97 4220.90 115.05 4143.77 55.49 OSF 1.50 Pass 8500.0 3647.13 6169.82 -1527717 7945.0 3625.66 4139.12 -11548.23 3697 4248.08 115.16 4168.97 5577 OSF 1.50 Pass 880.0 3647.65 623220 -1535532 7945.0 362568 4139.12 -11548.23 36.97 4344.58 115.61 4287.18 5634 OSF1.50 Pass 870.0 3847.68 629459 -15433.47 7545.0 3625.68 4139.12 -11548.23 38.97 4443.15 118.08 4365.45 5790 OSF 1.0 Pess 880.0 3647.70 6356.98 -15511.82 7945.0 3625.68 4139.12 -11548.23 36.97 4541.79 118.52 4483.78 58.95 OSF 1.0 Pass 890.0 3647.72 6419.37 -15589.77 79450 3625.68 4139.12 -11548.23 36.97 4640.48 118.99 4562.16 5999 OSF 1.0 Pass 8937.0 3647.73 644283 -15619.16 7945.0 362568 4139.12 -11548.23 36.97 4677.60 117.18 459917 0.38 OSF 1.0 Pass 8938.38 3647.73 644330 -15819.78 794500 362568 4139.12 -11548.23 36.90 4878.36 117.17 459992 0.39 OSF 1.50 Pass 8968.08 3647.60 6461.91 -15842.92 7945.0 362568 4139.12 -11548.23 34.27 4707.89 117.31 462915 60.69 OSF 1.50 Pass • • • • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 6 of 15 Trajectory:5128-NW2(P4b)Vs.SP3O-WI Minimum Trawling 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) (5) (ff) (ft) (5) (ft) (ft) (') (ft) (ft) (ft) 18989.62 3647.35 6475.49 -15659.65 1794500 3625.68 4139.12 -11548.23 32.78 4728.93 117.42 465033 60.91 OSF1.50 Pass 19000.09 364720 6482.05 -1566769 17945.00 3625.68 413912 -11548.23 32.78 4739.17 117.47 466052 61.01 OSF 150 Pass 19100.00 3645.76 654526 -15745.16 17945.00 3626.68 4139.12 -11548.23 32.78 4837.78 117.98 4758.80 62.01 OSF 1.50 Pass End of results • • • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\S126-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 7 of 15 Field: Nrkailchuq Well: SP3O-W1 Structure: Spy Island Borehole: SP3O-WlPB1 Slot SP30 Trajectory: SP3O-WIPB1 Client Em Petroleum Type: Del Survey Coordinate System: 04027 Alaska State Plane Zone 04.US Feet North Reference: True Grid Convergence Angle: 0 08867938' Grid Scale Factor: 0.999900149 Magnetic Declination: 20 271` Magnetic Declination Date: October 15.2012 Magnetic Model: BGGM 2012 Reference Point NDLMina Eastlna Elevatlon Structure Unc. Slo[ 6053617960(MOS) 511465870(ftUS) 53.920(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Survevino Prov As Drilled Description MD From(h) MD To(/l) EOU Freq Survey Tool Type Nota Size(ht) Ca**DWneeer(In) Borehole/Survey 0.000 40.820 Act-Stns SLB_GYRO-MND-Depth Only-No Globe 18.000 13.375 SP3O-W1PB1/SP30-WIPB1 40.820 958.580 Act-Sble SLB GYRO-MWD-No Globe 18.000 13.375 SP3O-WIPB1 I SP3O-W1 P81 958.580 2599.700 Act-Stile SLB MWO0GMAG-No Globe 18.000 13.375 SP30-W1PB1/SP3O-WIPB1 2599.700 9485.920 ActSMe SLBMWD+GMAG-No Globe 12.250 9.825 9P30-WIPBt/SP3OWIPBI 9465.920 13788.700 Act-Stns SLB_MW000MAG-No Globa 8.750 8.750 0P30-WIPB1/SP30-WIPBI 13788.700 13854.000 Act-Stns SLB BLIND+TREND-No Globe 8.750 8.750 SP3O-W1PB1/SP3O-WIPB1 • Minimum Trawling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Norti1 Palm Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (it) (h) (5) (ft) (0) (ft) (•) (ft) (ft) (ft) All local minima indicted. Results filtered:Depth 15400.00 ft<=MD<=24046.04 ft Results filtered:Ct-Ct separation<=1500.0011 Results highlighted Ct-Ct separation v=1320.008 End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\S126-NW2\SI26-NW2\S126-NW2(P4b) 10/2/2014 5:31 PM Page 8 of 15 Field: Nikeddruq WW1: SP22-Flet Structure: Spy Island Borehole: SP22-FNI Slot SP22 Trajectory: SP22-FNI Client: Eni Petroleum Typo: Del SuNey Coordinate System: NAD27 Alaska Slate Plans,Zons 04,US Feld North Reference: True Grid Convergence Anglo: 0.08928041 Grid Scale Factor. 0999900151 Magnetic Declination: 20.104° Magnetic Declination Date: January 31,2013 Magnetic Model: BGGM 2012 Reference Point Norminc Eastina Elevation Structure Une. Slot Ung 6053633 080(ftUS) 511543 560(NUS) 53.820(ft)MSL 0.000(It)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSA0 3-0 95.000%Congdenca 2.7990 slgrn9 Surveslnu Prov As Drilled Description MD From ate MD To(ft) EOU Fred Survey Tool Type Hole Sloe(In) Casing Diameter ten) Borehole I Survey 0000 40.720 Act-Stns SLB_NSG+MSHOT-Depth Only-No Global 18.000 13.375 SP22-FNIPB1/SP22-FNIPB1 40.720 865.420 Act-Stns SLB NSG+MSHOT-No Globe 16.000 13.375 SP22-FNIPBI(SP22-FNIPB1 865.420 3014.860 Act-Stns SLB MWD+GMAG-No Globe 18.000 13.375 SP22-FNIPBI/SP22-FNIP01 3014.860 12085.310 Act-Sins SLB_MWO+GMAG-No Globe 12.250 9.825 SP22-FNIPB1/SP22-FNIP61 12095.310 13272400 Act-Stns SLB MV4+GMAG-No Globe 8.750 5.500 SP22-FNIPB1/SP22-FNIPB7 " 13272.400 14859.310 Act-Stns SLB MWO+GMAG-No Globe 6.750 5.50D 0P22-FN1PB2/SP22-FNIPB2 14859.310 17940.580 Act-Stns SLB MWD+GMAG-No Globe 8.750 5.50D SP22-FNIP63/SP22-FNIPB3 17940.580 20181.550 Act-Stns SLB MWD+GMAC-No Globs 8.750 5.500 SP22-FNIPB4ISP22-FNIPB4 • 20181.550 22856.110 ActStne SLB MWD+GMAG-NB Globe 8.750 5.500 SP22-FN7/SP22-FN7 22856.110 22923.000 Act-Stria SLB BLIND+TREND-No Globe 8.750 5.500 SP22-FN7/SP22-FN7 Minimum Traveling Cyl,nder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset N5 Offset EW North Atrm Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (5) (0) (6) (0) (6) (ft) (ft) (ft) I') (ft) (0) (ft) All local minima indicated. Results filtered:Depth 15400.00 ft<=MD<=24046.04 ft Results filtered:Ct-Ct separation on 1500.00 ft Results highlighted Ct-Ct separation<=1320.00 ft 15410.45 3808.10 4378.28 -1278388 14521.71 3747.28 5585.38 -11068.75 40.34 2087.27 42205 1805 i=Mau OSF 1.50 Pass 18100.00 3625.75 4855.06 -13278.84 1517258 3752.19 6119.75 -11458.05 49.59 222036 43253 191.-1:® OSF1.50 Pass 16600.00 3828.58 5180.02 -13672.42 18139.47 3737.35 8875.37 -12054.00 31.58 2360.63 501.21Nr<. OSF 1.50 Pass 16700.00 3626.28 5206.04 -13781.18 16250.91 3737.09 6951.85 -12135.07 28.40 2388.36 50557 2050.':lllllllllllllllllllll• OSF 1.50 Pass 18937.52 3622.10 5314.20 -13972.53 16491.80 3735.46 7115.91 -12311.43 31.73 2453.21 530.•• 13n5 60 OSF 1.50 Pass 17300.00 3823.57 5492.18 -14288.32 1700.84 3732.23 7449.25 -12895.86 31.96 252548 558.88 2153.:: :17 OSF 1.50 Pass 17952.70 3826.10 5851.59 -14832.79 17578.20 3734.52 7825.65 -13133.56 37.13 20692 575.68 2222.81 'ItTr: OSF1.50 Pass 18600.00 3647.65 8232.20 -15355.32 18174.40 3730.56 8218.11 -1358213 40.39 2683.62 59614 2285.1., liJil OSF1.50 Pass 18900.00 3647.72 6419.37 -15589.77 18395.05 3730.80 8367.96 -13744.08 49.38 2685.24 600.62 2284 r mil OSF 1.50 Pass 19476.41 3839.80 6783.56 -18038.47 18789.85 3730.88 8648.80 -14021.69 41.67 274736 604.73 2343.1,MillM4T.V1 OSF 1.50 Pas 20800.00 3807.60 753465 -18870.97 21053.88 3748.59 9858.95 -15907.75 47.09 2519.93 706.98 2048.,!MINIM-1c5 OSF 1.50 Pass 21900.00 3623.71 640895 -17832.30 22923.00 3408.64 10111.27 -1786066 32.37 1724.42 728.45 1239.78 3.56 OSF1.50 Warning 21996.77 3823.61 847255 -17905.23 22923.00 3408.64 10111.27 -17860.66 32.37 1670.76 739.53 1177.41 3.39 OSF1.50 Warning 22000.00 3623.61 8474.88 -17907.67 22923.00 340884 10111.27 -17880.688 32.42 1889.03 739.95 1175.41 3.39 OSF 1.50 Warning 22015.11 3623.60 8484.65 -17919.02 22973.00 3408.64 10111.27 -1760.66 3266 1860.98 741.88 1188.06 3.36 OSF 1.50 blaming 22029.41 3623.60 8494.14 -17929.71 22923.00 3408.84 10111.27 -17860.86 32.92 1653.40 743.68 1157.28 3.34 OSF 1.50 Waming 22100.00 3823.60 8541.13 -17982.39 22923.00 3408.64 10111.27 -17680.88 32.92 1617.11 752.23 1115.30 3.23 OSF 1.50 Warning 22200.00 3623.0 8807.70 -18157.01 22923.00 3408.64 10111.27 -17660.66 32.92 1569.72 783.18 1060.61 3.09 OSF 1.50 blaming 22300.00 362360 8674.27 -18131.63 22923.00 3408.64 10111.27 -1760.66 32.92 1527.42 772.28 1012.25 2.97 OSF 1.50 Warning 2240.0 3623.0 8740.84 -18208.25 22923.00 3408.64 10111.27 -1760.66 3292 1490.63 779.00 970.98 2.87 OSF 1.50 Warning 22500.00 3623.60 8807.41 -1820.88 22923.0 3408.84 10111.27 -1760.0 32.92 1459.77 782.93 937.49 2.0 OSF 1.50 blaming 22521.62 3623.60 8821.80 -1829701 22923.0 3408.64 10111.27 -1780.0 32.92 1453.92 783.36 931.35 2.79 OSF 1.50 Naming 2252232 3623.0 882227 -1829753 229213.0 3408.64 10111.27 -1760.86 32.93 1453.73 78338 931.18 2.79 OSF 1.50 Naming 22600.00 3622.56 8874.09 -1835539 22823.00 3408.64 1011127 -1760.66 3351 1434.93 783.57 91222 2.75 OSF 1.50 Warning 22825.82 3621.75 8891.35 -1074.57 22923.0 3408.84 10111.27 -17860.66 33.69 1429.44 783.20 906.97 2.74 OSF 1.50 Warning 22700.00 3619.09 8940.98 -18429.85 22923.0 3408.64 10111.27 -17680.0 33.69 1416.06 70.78 89521 2.72 OSF 1.50 blaming 22800.0 3815.51 9007.87 -18503.89 22923.00 340864 10111.27 -1780.66 33.69 1404.05 774.16 887611 2.74 OSF 1.50 Warning 22900.0 3611.93 907476 -18578.14 22923.0 3408.84 10111.27 -17660.0 33.69 si 783.81 889.69 2.75 OSF 1.50 blaming 22927.47 3810.94 9093.14 -18598.53 22923.00 3408.64 10111.27 -17660.86 33.:,i500:T-'T: 760.03 891.98 2.76 OSF 1.50 VWming 23005.0 3809.26 914162 -18652.45 22923.0 3408.64 10111.27 -1760.66 33.63 1401.47 749.07 01.77 281 OSF 1.0 blaming 23030.36 3609.10 9181.89 -18675.05 22923.0 3408.64 10111.27 -1780.86 33.0 1403.74 743.84 07.52 2.83 OSF 1.0 Warning 23042.09 3809.12 9169.72 -18863.78 22923.00 3408.84 10111.27 -17680.68 33.59 1404.82 741.73 910.00 2.84 OSF 1.0 blaming 23100.00 3809.35 9208.33 -18726.95 22923.0 3408.64 1011127 -1780.66 33.59 1411.58 70.73 92410 2.0 OSF 1.0 Naming 23200.00 3809.75 9275.00 -18801.48 22923.00 3408.64 10111.27 -17680.66 33.59 1428.73 709.44 955.44 3.02 OSF 1.0 Naming 2330.0 3810.15 9341.68 -18876.00 22923.00 340864 10111.27 -1780.66 33.59 1452.57 685.55 995.21 3.18 OSF 1.50 Warning 2340.0 3810.55 9408.35 -1890.53 22923.0 3408.64 10111.27 -1760.66 33.59 1482.79 659.64 1042.70 3.37 OSF 1.0 Wanting 23500.0 3810.95 9475.02 -19025.06 22923.0 3408.64 10111.27 -1780.66 33.59 1519.00 632.32 1097.12 3.81 OSF 1.0 Warning 23534.09 3611.08 9497.75 -1905047 22923.00 3408.84 10111.27 -17130.68 33.59 1532.84 622.0 1117.11 3.69 OSF 1.0 Warning 23538.24 3811.10 9500.52 -19053.56 22923.0 3408.84 10111.27 -178086 33.69 1534.34 821.62 1119.59 3.71 OSF 1.0 Warning 23543.87 3811.13 950428 -19057.75 22923.0 3408.64 10111.27 -1760.66 33.81 1538.88 620.03 1122.98 3.72 OSF 1.50 Warning 23600.0 3611.46 9541.82 -19099.48 22923.00 3408.84 10111.27 -178600.0 33.81 1580.85 804.07 1157.61 3.88 OSF 1.0 Warning 2370.0 3812.05 908.70 -19173.82 22923.0 3408.64 10111.27 -1760.86 33.81 107.38 575.58 1223.33 4.19 OSF 1.50 Warning 2380.0 3812.69 9675.58 -19248.16 22923.0 3408.64 10111.27 -1760.86 33.81 1858.0 547.18 1293.69 4.55 OSF 1.0 blaming • 2300.0 3613.24 9742.46 -19322.0 22923.0 3408.64 10111.27 -1760.88 33.81 1714.53 519.25 1388.04 4.96 OSF 1.0 Warning 2400.0 3813.83 9809.34 -19398.84 22823.0 3408.64 10111.27 -1760.66 33.81 1774.15 492.07 1445.77 5.42 OSF 1.0 Pass 24046.04 3614.10 9840.14 -19431.07 22923.0 3408.84 10111.27 -1780.66 33.81 102.0 479.87 1482.58 5.64 OSF 1.50 Pass End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\S126-NW2\S126-NW2\S126-NW2(P4b) 10/2/2014 5:31 PM Page 9 of 15 Field: Nikeachoq Well: SP21-NIWI • Structure: Spy island Borehole: SP21-AWI • Slot SP21 Trajectory: SP21-NWS current Client Eni Petroleum Type: Non-Del Survey Coordinate System: 54027 Alaska Stale Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08934142° Grid Seale Factor- 0999900152 • Magnetic Declination: 19.192° Magnetic Declination Date: September 18,2014 Magnetic Model: BGGM 2014 Reference Point: N dieg Lyng Elevation Structure tiny Slot 1. 6053634 490(SUS) 511551.440(kUS) 53.870(ft)MOL 0.000(ft)(1 sigma) 0.000(k)(1 sigma) Traiectory Error Model:ISCWSAO 3-D 56.000%Confidence 2.7955 sigma Surveying Pr90 As Dr91ed Description MD From(II) MD To(1t) EOU Freq Survey Tool Type Hole Size(in) Casing Diameter 6n) Borehole/Survey Oho 2 gyro 0.000 40.770 Ant-Stets SLBNSG*SSHOT-Depth Only-No Global 16.000 13.375 SP21-NW1/SP21-NWI Current bha 2 gyro 40.770 1013.850 ActStlto SLB NSG.SSHOT-No Global 16.000 13.375 SP21-NWI 7SP21-NWI oonent bha 2 t surf 1013.850 2818.080 Act-Stns SLB M%O.GMAG-No Global 16000 13.375 SP21-NWI 15P21-NWI anent bha 3 2816.090 14812.000 ActSOn SLB MWD.GMAG-No Global 12.250 8.625 SP21-NWI/SP27-NWI current Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Norlh Azim Ct-Ct Distance Separation Clearance OSF Controlling Rug Statue (k) (ft) (ft) (ft) (ft) (ft) (k) (ft) 7) (ft) (ft) (k) 411 local minima indicated. • Results filtered:Depth 15400.00 ft<=MD<=24046.04 ft Results filtered:Ct-Ct separation<s 1500.00 ft • Results highlighted Ct-Ct separation<=1320.00 ft 5400.00 360743 4372.28 -12775.32 14812.00 3851.13 5261.33 -11706.93 37.85 1389.07 451.21 1087.91 4.63 OSF 1.50 Warning 5410.45 3808.10 437828 -12783.88 14812.00 3651.13 5261.33 .11708.93 37.85 1391.82 449.60 1091.72 465 OSF 1.50 Warning 5435.45 3609.69 439257 -12804.30 14812.00 3851.13 5281.33 -11708.83 37.85 1398.68 445.44 110137 4.72 OSF 1.50 Warning • 5500.00 3613.46 443060 -12858.31 1481200 3651.13 5261.33 -11706.93 39.85 1417.05 433.64 1127.60 491 OSF 1.50 W4ming 5800.00 3617.97 449368 -12933.75 1481200 3651.13 5261.33 -11706.93 43.00 1445.88 414.16 1169.42 5.25 OSF 1.50 Pass • 5700.00 3820.82 456158 -13007.08 1481200 3851.13 5261.33 •11708.93 46.20 1475.05 393.41 1212.42 5.64 OSF 1.50 Pass 5808.00 3622.02 4634.01 -13075.99 1481200 3651.13 5261.33 -11708.93 49.46 1504.41 371.58 1256.33 609 OSF 1.50 Pass ' 5819.23 3622.05 4648.44 -13088.71 14812.00 3651.13 5261.33 -11708.93 50.10 151000 387.28 1264.85 6.18 OSF 1.50 Pass 5900.00 3622.09 4709.34 -13141.77 1481200 3551.13 5281.33 -11708.93 50.10 1535.76 349.03 1302.72 6.62 OSF 1.50 Pass 5908.97 3622.09 4716.10 -13147.86 1481200 3651.13 5261.33 -11708.93 50.10 1538.86 347.00 1307.17 6.67 OSF 1.50 Pass 5920.64 3822.10 4724.87 -13155.36 1481200 3651.13 5261.33 •11708.93 49.68 154299 344.35 1313.06 6.74 OSF 1.50 Pass 5998.14 3623.10 4780.32 -13206.58 14812.00 3651.13 5261.33 -11708.93 47.90 1573.25 327.45 1354.59 7.23 OSF 1.50 Pass 8000.00 3623.19 4783.10 -13209.26 1481200 3651.13 5261.33 -11708.93 47.90 1574.95 326.80 1358.86 7.25 OSF 1.50 Pass 6100.00 3625.75 4855.06 -13278.64 1481200 365113 5261.33 -11708.93 47.90 1621.63 304.90 1418.01 800 OSF 1.50 Pass 6111.04 3626.03 4863.01 -13286.30 14812.00 3651.13 5281.33 -11708.93 47.90 1627.08 302.54 1425.03 8.09 OSF 1.50 Pass 6200.00 3627.98 4925.34 -13349.73 14812.00 3651.13 5261.33 -11708.93 44.68 1675.01 284.17 1485.21 8.87 OSF 1.50 Pass 6300.00 3629.43 4991.22 -13424.82 14812.00 3001.13 5261.33 -11708.93 40.97 1737.26 265.24 1560.08 9.86 OSF 1.50 Pass 6400.00 3630.07 505244 -13503.98 14812.00 3651.13 5281.33 •11708.93 37.15 1807.28 248.42 1641.32 10.95 OSF 1.50 Pass 6429.35 3630.10 5069.48 -13527.87 14812.00 3651.73 5261.33 •11708.83 36.00 1829.15 213.90 7888.79 11.29 OSF 1.50 Pass 8500.00 3629.84 5108.77 -13586.58 11812.00 3001.13 5281.33 -11708.83 33.08 1883.98 233.82 1727.73 12.13 OSF 1.50 Pass 6800.00 3628.58 5160.02 -13672.42 14812.00 3651.13 5281.33 -11708.93 28.72 1966.24 221.41 1818.27 13.38 OSF 1.50 Pass 6687.78 3826.61 5200.67 -13750.18 14812.00 3651.13 526133 -11708.93 24.63 2042.30 212.27 1900.44 14.50 OSF 1.50 Pass 6700.00 3626.28 5206.04 -13761.16 14812.00 3651.13 5281.33 -11706.93 24.63 2053.12 211.11 1912.03 14.65 OSF 1.50 Pass 6772.67 3624.32 5237.99 -13826.40 1481200 3851.13 5261.33 -11708.93 24.63 2117.77 204.48 1981.09 15.81 OSF 1.50 Pass 6800.00 3823.65 5250.10 -13850.89 14812.00 3651.13 5281.33 •11705.93 25.65 2142.18 202.08 2007.09 15.98 OSF 1.50 Pass 8900.00 3622.22 5296.20 -13939.61 14812.00 3651.13 5261.33 -11708.93 29.27 2231.14 193.43 2101.83 17.39 OSF 1.50 Pass 6937.52 3622.10 5314.20 -13972.53 14812.00 3651.13 5261.33 -11708.93 30.58 226441 194.83 213416 17.52 OSF 1.50 Pass 8961.58 362215 5325.94 -13993.54 14812.00 3651.13 5261.33 -11708.93 31.43 2285.70 192.80 2156.95 17.89 OSF 1.50 Pass 7008.00 362231 5344.81 -14027.00 14812.00 3851.13 5261.33 -11706.93 31.43 2319.75 189.11 2193.32 18.50 OSF 1.50 Pass 7100.00 362273 5393.93 -14114.11 1481200 3651.13 5281.33 -11708.93 31.43 2406.99 180.51 228830 20.13 OSF 1.50 Pass 7200.00 3623.15 5443.04 -14201.21 1481200 3651.13 5261.33 -11708.93 31.43 2499.05 172.49 2383.70 21.86 OSF 1.50 Pass 7300.00 3623.57 549216 -14288.32 1481200 3651.13 5261.33 -11706.93 31.43 2589.84 165.02 2479.48 23.89 OSF 1.50 Pass 7315.84 362364 5499.94 -14302.11 1481200 3851.13 5261.33 -11708.93 31.43 2604.28 163.88 2494.67 23.98 OSF 1.50 Pass 7400.00 3623.96 554234 -14374.81 1481200 3651.13 5261.33 -11708.93 32.88 2680.78 157.82 2575.22 25.64 OSF 1.50 Pass 7445.04 3624.10 5565.91 -14413.19 1481200 3851.13 5281.33 -11708.93 33.67 2721.49 154.54 2818.11 26.59 OSF 1.50 Pass 7500.00 3624.25 5595.48 -14459.51 14812.00 365113 5261.33 -11706.93 34.67 277094 150.52 2870.23 27.80 OSF 1.50 Pass • 7573.84 3624.43 563660 -14525.85 14812.00 3651.13 5261.33 -11708.93 36.01 2836.97 145.10 2739.88 29.53 OSF 1.50 Pass 7800.00 362449 5651.44 -14542.39 1481200 3651.13 5261.33 -11708.93 36.01 2860.31 143.20 2764.48 30.17 OSF 1.50 Pass 7700.00 3624.72 5708.19 -14824.72 14812.03 3651.13 5281.33 -11708.93 36.01 2949.95 138.28 2858.75 32.71 OSF 1.50 Pass 7800.00 3624.94 5764.94 -14707.06 1481200 3851.13 5261.33 -11708.93 38.01 3040.24 129.78 2953.37 35.42 OSF 1.50 Pass 7884.08 3625.13 5812.66 -14776.29 14812.00 3651.13 5261.33 .11708.93 36.01 3116.62 124.64 3033.18 37.82 OSF 1.50 Pass 7900.00 3625.21 5821.69 -14789.40 14812.00 3651.13 5281.33 -11708.93 36.72 3131.13 123.68 3048.31 38.29 OSF 1.50 Pass 7952.70 3826.10 5051.59 -14832.79 14812.00 3651.13 5261.33 -11708.93 39.06 3178.23 120.57 3098.49 3989 OSF 1.50 Pass 8000.00 3627.72 5878.37 -14871.74 14812.00 3651.13 5261.33 -11708.93 41.08 3222.52 117.87 3143.58 41.37 OSF 1.50 Pass 8051.62 3630.38 5907.46 -14914.30 14812.00 3651.13 5261.33 -11708.93 43.33 3269.91 115.03 319266 43.02 OSF 1.50 Pass 8100.00 363330 593466 -14954.20 1481200 3851.13 5281.33 -11708.93 43.33 3314.43 112.48 3239.09 44.61 OSF 1.50 Pass 8198.33 3639.23 5989.95 -15035.29 1481200 391.13 5261.33 -17708.93 43.33 340525 107.58 3333.17 47.94 OSF 1.50 Pass 8200.00 3639.33 5990.89 -15036.87 1481200 3651.13 5281.33 -11708.93 43.29 3406.80 107.49 3334.78 48.00 OSF 1.50 Pass 8300.00 3644.24 804832 -15118.39 14812.00 351.13 5261.33 -11708.93 4136 3499.11 102.60 3430.35 51.66 OSF 1.50 Pass • 8400.00 364699 6108.01 -15198.56 14812.00 3851.13 5261.33 -11708.93 39.77 3590.88 97.70 3525.39 55.72 OSF 1.50 Pass • 8480.62 3647.60 8145.28 -15246.37 1481200 3651_13 5261.33 -11708.93 38.98 364621 94.73 3582.70 58.38 OSF 1.50 Pass ' 6474.33 3647.63 6153.80 -15257.11 14812.00 3851.13 526133 -11708.93 38.76 3658.70 94.08 3595.63 59.00 OSF 1.50 Pass 8500.00 3647.63 6189.82 -15277.17 14812.00 3651.13 526133 -11708.93 38.76 3882.07 92.83 3819.83 80.17 OSF 1.50 Pass 8600.00 3647.65 6232.20 -15355.32 1481200 3651.13 5261.33 -11708.93 38.76 377343 88.23 3714.25 64.92 OSF 1.50 Pass 8700.00 3647.68 6294.59 -15433.47 14812.03 3651.13 5281.33 -11708.93 38.76 386521 8395 3808.89 69.94 OSF 1.50 Pass 8800.00 3647.70 6356.98 -15511.62 1481200 3651.13 5261.33 -11708.93 38.76 395739 79.95 3903.73 75.23 OSF1.50 Pass 8900.00 384772 6419.37 -15589.77 14812.00 3651.13 5261.33 -11708.93 38.76 404994 76.24 3998.76 80.79 OSF 1.50 Pass 8937.60 3647.73 6442.83 -15619.16 1481200 3051.13 5261.33 -11708.93 38.76 4084.83 7492 4034.53 82.95 OSF 1.50 Pass 8938.38 3647.73 6443.30 -15619.76 1481200 3651.13 5261.33 -11708.93 38.74 408554 74.89 4035.25 82.99 OSF 1.50 Pass 8868.08 364760 6461.91 -15642.92 14812.00 3851.13 5261.33 -11708.93 37.82 4113.11 73.86 4063.52 84.73 OSF 1.50 Pass 8989.62 3647.35 6475.49 -15659.65 '1481200 3651.13 5261.33 -11708.93 37.32 4133.08 73.12 4083.98 86.02 OSF 1.50 Pass 9000.00 3647.20 648205 -15687.69 1481200 3651.13 5261.33 -11708.93 37.32 4142.70 72.77 4093.83 88.64 OSF 1.50 Pass 9100.00 3645.76 6545.26 -15745.16 14812.00 3651.13 5261.33 -11708.93 37.32 4235.53 89.53 4188.82 92.77 OSF 1.50 Pass • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5.31 PM Page 10 of 15 Trajectory:5128-NW2(P4b)Vs.SP21-NW1 current 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 OSF Controlling Rule Status (ft) (ft) (ft) (ft) (ft) (9) (ft) (9) (°) (ft) (6) (ft) 9200.00 3644.31 8608.47 -15822.64 14812.00 3651.13 5281.33 -11708.93 37.32 4328.87 66.57 4283.94 99.11 OSF 1.50 Pass 9300.00 3642.87 6671.68 -15900.11 14812.00 3851.13 5281.33 -11708.93 37.32 4422.12 63.88 4379.19 105.80 OSF 1.50 Pass 9400.00 3641.43 6734.89 -15977.59 14812.00 3851.13 5281.33 -11708.93 37.32 4515.85 61.42 4474.55 112.21 OSF 1.50 Pass 9405.72 364134 6738.51 -15982.02 14812.00 3651.13 5261.33 -11708.93 37.32 4521.22 81.29 4480.01 11259 OSF 1.50 Pass 9476.41 3639.80 6783.56 -18038.47 14812.00 3851.13 5281.33 -11708.93 35.11 4587.47 59.70 4547.31 117.33 OSF 1.50 Pass 9500.00 3838.71 6798.76 -1805448 14812.00 3651.13 5261.33 -11708.93 34.69 4809.52 59.19 4569.70 118.94 OSF 1.50 Pass 9554.83 3636.12 6834.50 -18095.97 14812.00 3851.13 5261.33 -11708.93 33.80 4660.60 58.02 4821.57 122.71 OSF 1.50 Pass 9800.00 3633.69 6864.17 -18129.95 14812.00 3651.13 5261.33 -11708.93 33.80 470264 57.12 4864.20 125.81 OSF 1.50 Pass 9700.00 3828.30 892835 -1620516 14812.00 3851.13 5261.33 -11708.93 33.80 479589 55.35 4758.84 132.50 OSF 1.50 Pass 9800.00 3622.91 6995.54 -1828037 1481200 3651.13 5261.33 -11708.93 33.80 4889.41 53.85 4853.18 138.92 OSF 1.50 Pass End of result Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 11 of 15 Field: Nikartchuq Well: SP21-61W1 Structure: Spy Island Borehole: SP21-NW1L1 Slot SP21 Trajectory: SP21-NWILl(P8) Client: Ern Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane.Zone 04.US Feet North Reference: True Grid Convergence Angle: 0.08934142° Grid Scale Factor: 0999900152 Magnetic Declination: 19.218° Magnetic Declination Date: September 01,2014 Magnetic Model: BOOM 2014 Reference Point Northing Eastl00 Elevatlo Structure Unc Slot Unc. 6053634 490(SUS, 511551 440(IIUS) 54 100(ft)MSL 0000(ft)(1 sigma) 0.000(8)(1 sigma) Traiec tory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7965 Ng= Survevino Prov;Wille Drilling Description Part MD From NO MD To(ft)EOU Freq el) Survey Tool Type Hole Blas 9n) Casing Diameter(in) Boreholel Survey 1 0.000 0.230 ActSOs SLBNSG+SSMOT-Depth Only-No Global 18.000 13375 SP21NW11SP21-NW1(P8)(Projected-Up) 1 0230 41.000 1/100000 SLBNSG+SSMOT-Depth Only-No Globo 16.000 13.375 SP21-NWI/SP21-NWI(P8) 1 41.000 1200.230 1/100.000 SLB_NSG+SSHOT-No Globe 18.000 13.375 SP21-NWI I SP21NW1(P8) 1 1200.230 2700.230 11100000 SLB_MWD+SAG-No Globe 18.000 13.375 SP21-NWI I SP2INWI(PB) 2 1200.230 2907478 1/100.000 5L8_AMD+GMAG-No Glob. 18.000 13.375 SP21-NMA 15P21NWI(P8) 2 2907.478 4400.230 1/100.000 SLB_MWD+SAG-No Globe 12.250 9.625 SP21-NWI I SP2INWI(P8) 3 2907.478 14844.000 1/100.000 SLB_AMD+GMAG-No Globe 12.250 9.825 SP21-NWI I SP21-NWI(P8) 3 14844.000 14960.000 1/100.000 SLB MIND+GMAG-No Globe 8.750 5.500 SP21-NWIL1/SP21NWIL1(PB) 3 14%0.000 18480.000 1/100.000 SLB_MWD+SAG-No Globe 8.750 5.500 SP21-NWILI/SP2INWIL1(PB) 4 14644.000 23404.581 1/100.000 SLB_MISD+GMAG-No Globe 8750 5.500 SP21-NWILI ISP2INWIL1(P8) Minimum Traveling Cylinder Alowable EOO-EOU Reference MD Reference TVD Reference NO Reference EW Offset MD Offset TVD Offset NS Offset EW North 941m Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) C) (ft) (ft) (h) All local minima indicated. Results filtered:Depth 15400.00 ft<=MD<=24046.04 ft Results filtered-.Ct-Ct separation<=1500.00 ft Results highlighted.ClCt operation r_1320.006 3809.69 4392.57 -12804.30 1521347 3832.76 5459.69 -12078.98 3597 1290 514.63 947.tO ppppp[r110 OSF 1.50 Warning 15500 00 3629.84 5108.77 -13586.58 16305.53 3654.29 6117.13 -12947.62 33.74' 1193. 531.••ppppgj-E_fUl OSF 1.50 Warning 00 16700 3628.28 5206.04 -13781 16 18595.81 3666.39 6265.95 -13196.62 27 95 1201 5 561. 741961 3 21 OSF 1.50 Warning 17100.00 3822.73 5393.93 -14114.11 16968.82 3672.05 6440.24 -1352636 31.771 1201.1 589..t L50 306 OSF 1.50 Warning 17200.00 3623.15 5443.04 -14201.21 1703446 367300 6473.16 -13583.14 31801 59086 0,0.5'.11111K0 OSF 1.50 VJa ing 17800.00 3624.94 5764.94 -14707.06 17560.74 3679.64 6766.22 -14020.15 371606.11 t1 ss s1 OSF 1.50 Whming 18198.33 363923 5989.95 -15035.29 17935.41 366660 698226 -14325.91 35651 619. .:r sjjjjjjjjjjjjjjjj) OSF 1.50 Whining 19800.00 3633 69 6864.17 -16129.95 19265.09 3656 59 7806.81 -15367.01 42 33 121 •1 661.98 48110 MONIIMM OSF 1.50 Wamlrg 19700.00 3628 30 6929.85 -16205.16 19331 57 3657 99 7849.30 -15418.11 42 5 664(491 659.=t 1111111161/i*Z.' OSF 1.50 Warning 20501 81 3607 80 7486.88 -16799.92 20110.71 3673 67 837243 -15995.02 46 78 49.: 684.42 511 itlEii, OSF 1.50 Warrtlng 20600.00 3807.60 7534.65 -16870.97 20180.39 3673.89 8419.18 -16046.69 46 7•)430187 682 •1=M WADI 7. OSF 1.50 Warning 21100.00 3609.11 7879.06 -17233.40 20835.48 3677.08 8740.30 -16369.14 45.83 1 041 69187 ih 2.65 OSF 1.50 Wemirg 21500.00 3624.09 8146.06 -17530.82 21112.57 3688.22 9064.20 -16719.01 4321 IiikdAhlo 72363 74353 2.54 OSF 1.50 Warning 23300.00 3610.15 9341.68 -1887600 22905.39 3664.10 10236.81 -1807458 790.49 5575(31 OSF1.50 %%ming 23800.00 3612.65 9675.58 -19248.16 23404 58 367055 10569 55 -18446 66 44 7 61i5MYls 5 809 u8' b61 OSF 1.50 Warring 23900.00 3613.24 974246 -19322.50 23404 58 367055 10569.55 -18446 66 44 74 1206 01 792 05 677 57 229 OSF 1.50 Warning 24000 00 3613.83 9609.34 -19396.84 23404 58 3670.55 10569.55 -18446.66 44 74 1218 19 769.45 704 82 2.38 OSF 1.50 Warning 04046 04 3814.10 9840.14 -19431.07 23404 58 3670.55 10569.55 -18446.66 44 74 1226 50 757 54 721 07 2.43 OSF 1.50 %aming End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 12 of 15 Field: NikerIcnuq Well: SP21-NWI Structure: Spy Island Borehole: SP21-NW1 Slot: SP21 Trajectory: SP21-NWI(P8) Client: Ent Petroleum Type: Del Plan Coordinate System: NA027 Alaska Stele Plane,Zone 04.US Feet North Reference: True Grid Convergence Angle: 0 08934142° Grld Scale Factor: 0.999900152 Magnetic Declination: 19769° Magnetic Declination Date: September 01.2013 Magnetic Model: BGGM 2014 Reference Point NorthlnO Eastina LIME Structure Unc. Slot hoc 6053634 490(ftUSI 511551 440(flUS) 53.870(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-0 95.000%Cdnld'nee 2.7189 sigma Survevinc Pro%While Drilling Description Part MD From(I) MD To 66 EOU Frog fig Survey Tool Type Hole 6lze pn) Casing Olrl9Ov(In) Borehole l Survey 1 0.000 40770 1/100.000 SLBNSG+SSHOT-Depth Only-No Global 18.000 13.375 SP21-NW1/SP21-NWI(P8) 1 40.770 120.000 1/100 . 0 SLB_NSG+SSHOT-No Globs 18.000 13.375 0P21-NWI/SP21-NWI(PB) 1 1200.000 2700.000 1/100.000 SLBMWD0SAG-NO Globs 16.000 13.375 SP21-NWI/SP21-NWI(P8) 2 120.000 2807.248 1/100.000 SLB_MWD+GMAG-NO Globe 18000 13.375 SP21-NW1/SP21-NWI(P8) 0 00 2 2907.248 4400. 0 1/1 .0SLBMWD+SAG-No Globe 12.250 9625 SP21-NWI/5P21-NW1(P8) 3 2907.248 14925.084 1/10.000 SLBMWD+GMAG-No Globs 12.250 9.625 SP21-NW1/SP21-NWI(PB) 3 14925.084 15425.00 1/10.00 SIB MWD+SAG-No Globe 8.750 5.50 SP21-NWI/5P21-NWI(P8) 4 14925.064 23414.780 1/10.00 SLB_MWVD+GMAG-No Globe 8.750 5500 SP21-NWI/SP21-NWI(P8) 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 Separator Clearance ODE Controlling Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (•) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 15400.0 ft cc MD oc 24048.04 8 Results filtered:Ci-Ct separation 001500.0 ft Results highlighted:CtCt'operation so 1320.0ft 1660.0 3628 58 5160.02 -13872.42 18488.08 3849.85 6297.20 -1303450 3a w i 1ILL 556.62 932.58 3 52 OSF 1.50 blaming 16687.78 3626.61 520.67 -13750.18 16608.17 3850.77 6354.47 -13140.06 27.10 12.1.4 581 1x301I349 OSF 1.50 Warning 1710.0 3622.73 5393.93 -14114.11 18978.17 3657.22 6528.42 -13488.28 30.9 1.31) 589.51 J11. 3.33 OSF 1.50 Warning 0 17200. 3623.15 5443.04 -14201.21 17046.91 36.58.24 856499 -13527.63 30.96 _I.63) 59092 1 3,12 OSF 1.50 blaming 1800.0 3627 72 5878 37 -14871.74 17773.11 3873.01 6968.83 -1110.35 36.•ikS9AL' 614.0.a 809.45 '1 r1sJ, OSF 150 Warning 18051.62 3630.38 590746 -14914.30 1780.38 3674.47 6989.14 -1410.22 36.23 61430 80 3.0 OSF 1.50 VJamorg 1970.0 3628.30 8929.85 -18205.16 1933496 3669.58 7935.37 -15354.57 42.97 1 1 660 p021� 877. i. OSF 1.50 Warning 19800.0 3622.91 6995 54 -16280.37 19403.71 3887.77 780.42 -15406.47 430fi° 658 50 / OSF 1.50 Warning 20501.81 3607.60 7466.86 -18799.92 20106.72 3663.02 845224 -15927.38 46.07 3i �J 68417 595cr ini OSF 1.50 Warning 20800.0 3607.60 7534 65 -16870.97 20174.00 3663.41 8497.41 -1597723 46.0 1 14.:4 682.371 Uri OSF 1.50 Warning 2070.0 3607.0 760368 -16943.32 20242.55 3663.83 8544.63 -16028.92 4811 i81E1141 68020 86080 2.0 OSF 150 Naming 21000.0 3607.00 7810.77 -17160.37 20514.95 3685.63 8738.22 -18218.54 48.11 keblih 885.91 865.41 2.90 OSF 1.50 Warring 2140.0 3622.20 079.84 -17455.92 20998.15 3673.34 9070.59 -16588.92 44.rc.i6539h 718.46852,74 279 OSF 1.50 Wamng 23800.0 361265 9675.58 -19248.16 23401 86 3662.01 10650.02 -1838004 441-iuh. .0 809 251 1#.081 242 OSF 1.50 Warning 2390.0 3613.24 9742.46 -19322.50 23414 78 3662.30 10658.61 -18389.69 4.15 1'r 796 55 776.94 2 47 OSF 1.50 Warning 24000 361383 9809.34 -1939684 23414.78 366230 10658.61 -18389.69 415 131831 77728 79972 2.55 OSF 1.0 W4te4ng 24046.04 3814.10 9840.14 -19431.07 23414.78 3882.30 10868.61 -1830.69 44.15 1325.40 767.08 813.62 2.59 OSF 1.50 Warring End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 13 of 15 Field: 5:6. 45 Well: 5132-002 Structure: Spy Island Borehole: 5132-142 Slot SP32 Trajectory: 5/32-W2 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska Stale Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08849757` Gdd Scale Factor: 0 999900149 Magnetic Declination: 20.047° Magnetic Declination Date: March 08,2013 Magnetic Model: BGGM 2012 Reference Point: !191$09 lasnng JElevatlon Structure Unc. 105 t Unc. 6053613 370(SUS i 511442 370(ftUS) 53-820(ft)MSL 0.000(ft)(1 sigma) 0 000(t)(1 sigma) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Survedno Prow As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Size(In) Casing Dlarnehr(In) Borehole/Survey 0.000 40.520 Act-Stns SLB NSG+MSHOT-Depth Only-No Globe 16.000 13375 0132-952/0132-002 40.520 821.880 Act-Stns SLB6 NSG+MSHOT-No Globe 1000 13375 S132-W2/SI32-W2 821.880 2737.120 Act-Stns SLB_MND+GMAG-No Globe 16.000 13.375 5132-W2/5132-W2 2737.120 9259.750 ActSNs SLB MNA+GMAG-No Globe 12.250 9.625 0132-W21 S132-W2 9259.750 18282.740 Ae1Stls SLB MlnO+GMAG-No Globe 8750 5.500 S1324M/SI32-002 18282740 18350000 Act-Stns SLB BLIND+TREND-No Globe 8.750 5.500 5132-W2/SI32-012 Meimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Norm Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (N) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (8) All local ninlma indicated. Results ltered.Depth 15400 00 ft cc MD co 24346 04 ft Results hereof:Ct-Ct separa8on c-1500.00 ft Results highlighted:Ct-Ct eepara9on As 1320.00 ft 5400.00 3607.43 437228 -12775.32 835000 3808.36 3151 48 -1250591 21097 1250.17 42562 966.09 4.41 OSF 1.50 Warning 5410.45 3608.10 437826 -1278386 8350.00 360836 315148 -12505.91 210.97 1257.87 424.15 974.78 4.46 OSF 1.50 Warning 5435.45 3609.69 4392.57 -12804.30 835000 "'36 3151.48 -12505.91 210.97 1276.46 420.73 995.64 4.56 OSF 1.50 Warn.•.. 5500.00 3813.48 4430.60 -12858.31 8350.00 3608 36 3151.48 -12505.91 213.72 1326.28 411.25 1051.78 4.85 OSF 1.50 naming 5600.00 3617.97 4493.88 -17833.75 8350.00 3608 36 3151.48 -12505.91 21827 1406.78 398.32 114290 5.31 OSF 1.50 Pass 5700.00 3620.82 4581.58 -1300708 8350.00 3608 36 3151.48 -12505.91 223.31 1496.57 387.61 1237.83 5.80 OSF 1.50 Pass 5800.00 3622.02 463401 -13075.99 835000 3608.36 315148 -12505.91 229.08 158842 379.07 1335.38 630 OSF 150 Pass 5819.23 3622.05 4948.44 -1308871 8350.00 3608.36 3151.48 -12505.91 230.31 1806.48 377.67 1364.36 8.39 OSF 1.50 Pass 5900.00 3822.09 4709.34 -13141.77 8350.00 360836 3151.48 -12505.91 230.31 1882.88 372.13 1434.27 8.80 OSF 1.50 Pass 5908.97 362209 4718.10 -13147.66 835000 360836 3151.48 -12505.91 230.31 1001.18 371.54 1443.15 8.84 OSF1.50 Pass 5920.64 3622.10 4724.87 -1315536 8350.00 3608.36 3151.48 -12505.91 229.77 1702.22 370.78 1454.70 6.80 OSF 1.50 Pass 5996.14 3623.10 4780.32 -13208.58 835000 3608.36 3151.48 42506.91 223.52 177321 365.64 1529.12 7.29 OSF 1.50 Pass 6000.00 3823.19 478310 -13209.26 8350.00 3608.36 3151.48 -12505.91 223.52 1776.82 365.37 1532.91 7.31 OSF 1.50 Pass 8100.00 362575 4855.06 -13278.64 8350.00 3608 36 3151.48 -12505.91 223.52 1870.73 358.72 1631.25 7.84 OSF 1.50 Pass 6111.04 3626.03 4883.01 -13286.30 835000 360836 3151.48 -12505.91 223.52 1881.13 358.02 184212 790 OSF 1.50 Pass 6200.00 3627.98 4925.34 -1334973 8350.00 360836 3151.48 -12505.91 221.84 1984.43 35222 172930 8.39 OSF 1.50 Pass 6300.00 3829.43 499122 -13424.92 835000 3608.36 3151.48 -12505.91 219.59 2058.62 345.24 1826.13 8.96 OSF 1.50 Pass 8400.00 3630.07 5052.44 -1350398 8350.00 360836 3151.48 -12505.91 217.05 2147.15 337.85 1921.59 9.56 OSF 1.50 Pass 6429.35 3630.10 5069.49 -13527.87 835000 360836 3151.48 -12505.91 216.28 2173.39 335.61 1948.32 974 OSF 1.50 Pass 6500.00 3629.84 5108.77 -13586.58 8350.00 360836 3151.48 -12505.91 214.49 223591 330.08 2015.53 10.19 OSF1.50 Pass 8600.00 3628.58 5160.02 -1387242 835000 360836 3151.48 -12505.91 211.81 2322.80 321.98 2107.82 10.85 OSF1.50 Pass 6687.78 3826.61 5200.67 -13750.18 8350.00 3508.36 3151.48 -1250591 208.30 2397.45 314.62 2187.37 11.48 OSF 1.50 Pass 6700.00 3826.28 5206.04 -13761.16 8350.00 3608.36 3151.48 -12505.91 209.30 2407.74 313.58 2198.36 11.55 OSF 1.50 Pass 6772.67 382432 523799 -1382640 835000 3605.36 3151.48 -12505.91 209.30 2469.30 307.58 226393 12.08 OSF1.50 Peso 6800.00 3823.60 5250.10 -13850.89 8360.00 3608 36 3151.48 -12505.91 209.42 2492.68 305.40 2288.75 12.28 OSF 1.50 Pass 6900.00 362222 5296.20 -1383961 8350.00 3608.36 3151.48 -1250591 209.66 2579.83 297.98 2380.85 OSF 1.50 Pass 6937.52 362210 531420 -1397253 8350.00 3608.36 3151.48 -1250591 208.67 2613.15 302.71 2411.01 OSF1.50 Peas 6961.58 3622.15 5325.94 -13983.54 8350,00 3608.36 3151.48 -12505.91 209.61 2634.68 301.17 2433.57 1 1 OSF 1.50 Pass 7000.00 362231 5344.81 -1402700 8350.00 3608.36 3151.48 -12505.91 20861 2669.20 298.79 2489.67 1344 OSF 1.50 Pass 7100.00 3622.73 5393.93 -14114.11 8350.00 3608.36 3151.48 -12505.91 20981 275954 292.88 2563.96 1418 OSF 1.50 Pass 7200.00 362315 5443.04 -14201.21 8350.00 3608.36 3151.48 -1250591 209.61 2850.53 28730 2858.67 14.93 OSF 1.50 Pass 7300.00 3623.57 5492.16 -14288.32 8350.00 3608.36 3151.48 -12505.91 209.61 2942.11 282.04 2753.75 15.70 OSF 1.50 Pass 7315.84 3623.64 5499.94 -14302.11 8350.00 3608 36 3151.48 -12505.91 209.61 2956.66 281.23 2768.84 15.82 OSF 1.50 Pass 7400.00 3623.96 554234 -14374.81 6350.00 3608.36 3151.48 -1250591 21142 303468 277.20 284955 1047 OSF 1.50 Pass 7445.04 362410 5565.91 -14413.19 8350.00 3608.36 3151.48 -12505.91 212.39 3076.92 275.23 2883.11 16.82 OSF 1.50 Pass 7500.00 3624.25 5595.48 -14459.51 8350.00 3608.36 3151.48 -12505.91 213.57 3128.89 273.00 2946.56 17.25 OSF 1.50 Pass 7573.84 3624.43 5636.60 -14520.85 8350.00 360836 3151.48 -12505.91 215.16 3199.38 270.31 3018.85 17.81 OSF 1.50 Pass 7600.00 3624.49 5651.44 -14542.39 8350.00 360836 3151.48 -12505.91 21516 322449 26943 3044.54 18.01 OSF 1.50 Poen 7700.00 3624.72 5708.19 -14824.72 8360.00 3008 36 3151.48 -12505.91 215.18 3320.60 266.18 3142.82 18.78 OSF 1.50 Pass 71300.00 3624.94 576494 -1470706 8350.00 3608.36 3151.48 -12505.91 215.18 3416.95 283.11 324121 18.55 OSF 1.50 Pass 7884.08 3625.13 5812.66 -14778.29 8350.00 3608.36 3151.48 -12505.91 215.16 3498.11 260.68 332401 20.20 OSF 1.50 Pass 7900.00 3625.21 5821.69 -14789.40 8350.00 3608.36 3151.48 -1250591 213.97 3513.49 280.20 333970 20.33 OSF 1.50 Pass 7952.70 362610 5851.59 -14832.79 8350.00 360836 3151.48 -12505.91 209.98 356445 258.70 3391.65 20.74 OSF1.50 Pass 8000.00 362772 5878.37 -14871.74 8350.00 3608.36 3151.48 -12505.91 206.37 3610.19 257.38 3438.27 21.12 OSF 1.50 Pass 8051.82 3630.38 5907.46 -14914.30 8350.00 360836 3151.48 -12505.91 202.52 3660.09 255.95 3489.13 21.53 OSF 1.50 Pass 8100.00 3633.30 5934.66 -14954.20 835000 3608 36 3151.48 -12505.91 202.52 3706.87 254.65 3536.77 2191 OSF 1.50 Pass 8196.33 3639.23 5989.95 -15035.29 8350.00 360836 3151.48 -12505.91 202.52 380206 25214 3833.64 2270 OSF 1.50 Pass 8200.00 3639.33 5980.89 -15036.87 8350.00 3608.36 3151.48 -1250591 20261 3803.88 25210 3635.29 22.72 OSF 1.50 Pass 8300.00 364424 6048.32 -15118.39 8350.00 3608 36 3151.48 -12505.91 208.18 390103 249.78 3734.18 23.51 OSF 1.50 Pass 8400.00 3846.99 610801 -15198.56 8350.00 3608.36 3151.48 -1250591 215.28 399912 247.84 3833.56 24.29 OSF1.50 Pass 8480.82 3647.60 614526 -15246.37 835000 3608.36 3151.48 -12505.91 220.65 4058.87 246.85 3893.98 24.76 OSF 130 Pass 8474.33 3647.63 615380 -15257.11 8350.00 360836 3151.48 -12505.91 222.09 407241 246.84 3907.66 24.86 OSF 1.50 Pass 8500.00 3647.63 816982 -1527717 8350.00 3608.36 3151.48 -12505.91 222.09 4097.78 24827 393327 2505 OSF 1.50 Pass 8600.00 3647.65 623220 -15355.32 830000 360836 3151.48 -12505.91 222.09 419661 244.85 4033.05 25.81 OSF1.50 Pass 8700.00 3647.68 629459 -15433.47 8350.00 3608 36 3151.48 -12505.91 222.09 4295.50 243.50 4132.84 28.56 OSF 1.50 Pass 8800.00 3847.70 635698 -1551182 835000 3608.36 3151.48 -12505.91 222.09 439444 242.21 4232.64 2732 OSF 1.50 Pass 8900.00 3647.72 641937 -15589.77 8350.00 3608.36 3151.48 -12505.91 222.09 4493.43 240.96 4332.45 28.08 OSF 1.50 Pass 893760 3647.73 644283 -1561916 8350.00 3608.36 3151.48 -12505.91 22209 4530.66 240.53 4300.97 28.36 OSF 1.50 Poss 893836 3647.73 6443.30 -1561976 8350.00 3608.36 3151.48 -1250591 222.19 4531.41 24052 4370.74 2837 OSF1.50 Pass 8968.08 364760 646191 -1564292 8350.00 3608.36 3151.48 -1250591 228.35 4560.85 240.18 4400.40 2860 OSF1.50 Pass 896062 364735 6475.49 -1565965 8350.00 3608 36 3151.48 -1250561 22940 458221 239.94 4421.92 28.76 OSF 1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 14 of 15 Trajectory:5126-NW2(P4b)Vs.5132-W2 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 Defence Separation Clearance OSF Controlling Rule Status (ft) (5) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) 19000.00 3647.20 648205 -15667.69 18350.00 360836 3151.48 -12505.91 22940 4592.50 23983 4432.28 28.84 OSF 1.50 Pass 1910000 3645.76 654526 -15745.18 18350.00 360836 3151.48 -12505.91 229.40 4691.69 238.80 453216 29.59 OSF 1.50 Pass 19200.00 364431 660847 -1582264 18350.00 360836 315148 -12505.91 22940 4790.90 23781 4632.04 30.34 OSP 1.50 Pass 19300.00 364287 667168 -15950.11 18350.00 360836 3151.48 -12505.91 22940 489016 236.86 4731.92 31.09 OSF 1.50 Pass End of results • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI26-NW2\SI26-NW2\SI26-NW2(P4b) 10/2/2014 5:31 PM Page 15 of 15 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 / 5/u" 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 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 SPEO IDENTIFICATION CODE PAG 206 OF 338 r ENI S.p.A. Enti 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 = P x 10 + 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 CII E&P Division REVISION STAP-P-1-M-6140 0 1 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. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 Erd E&P Division REVISION STAP-P-1-M-6140 0 1 *It LEAK-OFF TEST REPORT Rep°11 1\1° Date: WELL NAME: WELL CO DE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rig type: J.UPs Hole Elameter(in): 121/4 Weight(KgA): 1.3 R.K.B.elexation(m): 26 Last Csg.Shoe(m): 797 Marsh Viscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter(in): 13"3/0 P.V.(cps): 19 Pumps: 12-P-160 Grade: 2-55 Y.P.(lb/100 f): 5 Liners(in): 6.5' Weight Ob/t): 61 Gels(lb/100 t): 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc/30 min): 10.5 Lithology. Shale Expected EMW 1.68 Kglcm2/10 m Time Vol Lrne Pressure Time Volume Pressure Time Vdume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 9b 2 480 3 0.75 200 10 2 470 4 100 300 10.5 2 463 5 125 400 11 2 455 6 150 500 11.5 2 450 7 1.75 570 12 2 446 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Note: Pumped with a constam low rate of(bbl): 'blume pumped(bbl): lblume returned(bbl). (pot) 1000 • 900 800 . stop pump rP zoo e 600 • f shut in curve 500 c vim. U 400 (- 8 minutes e 300 200 100 0 . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 Z 1 2 3 4 5 6 7 8 9 10 11 12 CurroulativeVolume(bbf) 4 I 10 Time mins RESULTS: (Press., +Press.Lo.)x1ODepth=[(1.3x797110)+(430x0.07)]x10J797=1.68(KgIcm°M0 m) Nate: I Company Representatite Figure 15-1 - Leak-Off Test Report •R v) iS 0 1 - ' . .. u' L.., gi 01 (.77 >O gggg z m , ga o p 12 Nv g Lu g mLu a w O.. ::; .O i .O - Z_, b� of J .n w o } j m Y O m m Q d Q .p • N M d tD I� O¢ <tl \ ma Nay 0 1 O GO w w w B w z w G O ¢ pp N w z �yI/^_�\\'` b J N Vv ¢aCC - z o — On¢ , ¢J a k Sl�a Yuz M-4 a J O N 'Li, O -I M' HI) a ` U M ❑. V j am aO ¢w L- m w O w o 0 a- l6 c�m Q aKQ -6—. -7 _"4.4- _ u_ _ z B ig m o m m ' m �rsS um 1 III ^$ - :•_10 ■ • . •11 n IIIII"j ■ v/ q ! 3=—=—=! il .9/. ill -Mr! 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Iu E 1 1 1 1 111! 11111011 1 IA GIN. ill IIII X11 g 2 111 31 ii1 II / i 2111 ss m -12t" Ny i$ i ill i 8 v "y i 1111141$ 91111$1 1!1__1 11111�ifl fl i a$$1111114404440m4, 44A4 4444,,41443 ,bc] D EEEEEEEEEEEEEEEEEEEEEEE 31li33i 14111aaaaaaaaaaaaaaaa49 lii44444ii4li; 4 .-. - ! !; lEEl11 b Z 133l3!l333333l3333333i31 � EEEEE111111�y"wE11411111111411111111 4taa4Eai444i4444' "'4444 444444 4444411 pili? REV DATE BY CK APP DEMPTION. REV DATE BY CK APP DESCRIPTION 0 10/01/ 0 DLS CC CC .ritic, Drowing VICINITY MAP SCALE: 1" .7.-. 2 Miles 14 '-* 16, 17 16 N f , . ......«.. re, .7 .042;or ... 2' .t A 19 X 2 i F I•1 THIS ,_ ----- 26 :25 30 29 :-.F SURVEY 25 30 29 26 2 i leg 6.1 lg , A.S.O. NAPE13, 24. 'n 3e. C4 3i 32 3.:3 :1.1 i5 '5F. 13' .- -1 cc ce - 3; .... T14N I T14N 113N 1 T13N 3 2 ' . Ktbk POINT PAoll,', 1-(,/2?</4 3 i 1 — -..- . . .. N 9 1G "3 1. \ 1? 7 e , ),k .\,..s-3R ijr+---""1 it) !S.,• 0 re' ) ,,.. , •• i I 1 If ../1_ . "-.. •_.__. . --- __,.._: AOC VKAA T AtAIPIA0 I ',At: , t e 1 6 15 r 14 t.. 13 ,,R DSTr..35Q - i \ ('''''''''Nmi'IL.,. iy i A-) \S I I \ D50_0 1 14 ___7;__ Q. ,. .12)... ,—\ ....-_1_..... '...... _ . 1 \.,, ,. ,.) 21 22 2,3 'e Cty-s c3,, Mine SI 10 '10 C ,., ire. ,,,,i is 2B 27 Os \IDS D S -3 M '' e" 11")..\16 \74'"4 i (9 e _,_ • Olak• , .._. VEST SAX 10 Al IF t... )...:,..:.1 . Q,"\ g.0 ect 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. ishimmatitut_ 4...'e. .,, OF ,614:1144. 46,4,„\b„.......................k....er4p ... # J SURVEYOR'S CERTIFICATE : ., .: 0 49th I\ ...".* $ 1 • • % 0 1 • - __. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 • ) .-,-; . 0 i - 1 LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 0 1 -4.4---- -- Ts • 7 a : • .0 v,• ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY 0 0 ••• FRANCIS J. CORNING ,.: DONE BY ME OR UNDER MY DIRECT SUPERVISION AND IA 6,,,,;,*. THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT v. w ''. L S-10695 S,Ar , --„„-, . II AS OF OCTOBER 01, 2010 va•-PAs''. 4)1 4-17.0teve el . v. •() .4..... ...0* .4 XIX?c) ....... Os" 417 44, reSSIONA-4.. `Iiikiws.s" IA 01&Asia SPY ISLAND DRILL SITE „ r )v. WELL CONDUCTORS • o v• -? AS-BUILT LOCATIONS WI 0 ' •• •o' CAD FILE:EN13543D9 us operating DATE: DRAWING NO: PART: REV; 10701/2010 Eni-3543-d9 1 OF 3 0 REV DATE BY CK APP DESCRIP1ON REV DATE BY CK APP DESCRIPTION 0 10/01/',0 3"S CC CC .1:C DrCW rg N , ,\S 49 �4 5,.c. 183 , Sec. i i Ci- ‘,Y Ser., -9 v Ser:. "P W j A.S.P. NAD83, 74. i0 J 0000°0 LP I N trJ W 000000 o) 4" N Ni j O' f to '.t 0 3> N O LA J (31 W - N N 0 CPN N 4 00 W N p rn v a) DETAIL A. SCALE: 1"=--80' SANDBAG TOE iiiiiiii GRAveL,$HGUIOE.R S tir nag n cc °" QSp= aac G n o n na" DETAIL A vP S t. SPY ISLAND DRILL SITE = ; (SID) GRAVEL SN°°"E '___ SANDBAG lot LEGEND SCALE 20 . 100 200 0 = WELL CONDUCTOR AS-BUILT THIS SURVEY ilEaliAll llilli 1" = 200' foil t4,0iAoc4� SPY ISLAND DRILL SITE v, WELL CONDUCTORS @n• AS-BUILT LOCATIONS n :"h CAD FILE:EN 3543D9 us Op( (r �Qng DATE: DRAWING DRAWING NO: Eni-3543—d9 PART: OF 3 REV: O REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 0 ";;/C'/ C "5 CC CC H1,c r)r(.Vj .,g, 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 EE.L Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70°33'27.209" 149°54'24.765" 797 1171 12.4 2 6053421.65 1651761.87 70°33'27.194" 149°54'25.000" 798 1179 12.4 3 6053420.07 1651754.10 70°33'27.179" 149°54'25.229" 800 1186 12.4 4 6053418.56 1651746.17 70°33'27.164" 149°54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70°33'27.149" 149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149°54'25.925" 804 1210 12.4 7 6053412.44 1651714.77 70°33'27.104" 149°54'26.391" 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 70°33'27.074" 149°54'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70°33'27.060" 149°54'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149°54'27.318" 813 1257 12.4 12 6053404.80 1651675.51 70°33'27.029" 149°54'27.551" 815 1265 12.4 13 6053400.38 1651652.80 70°33'26.986" 149°54'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70°33'26.971"' 149°54'28.453" 821 1296 12.4 15 6053397.31 1651637.12 70°33'26.956" 149°54'28.685" 822 1304 12.4 16 6053395.82 1651629.26 70°33'26.942" 149°54'28.917" 824 1311 12.4 17 6053394.32 1651621.47 70°33'26.927" 149°54'29.147" 825 1319 12.4 18 6053392.78 1651613.58 70°33'26.912" 149°54'29.380" 827 1327 12.4 19 6053389.63 1651597.90 70°33'26.881" 149°54'29.843" 830 1343 12.4 20 6053388.17 1651590.00 70°33'26.867" 149°54'30.076" 831 1351 12.4 21 6053386.60 1651582.24 7003326.852" 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70°33'26.838" 149°54'30.538" 834 1366 12.4 23 6053383.64 1651566.41 70°33'26.823" 149°54'30.773" 836 1374 12.4 24 6053382.12 1651558.61 70°33'26.808" 149°54'31.003" 837 1382 12.4 25 6053377.65 1651535.94 70°33'26.764" 149°54'31.673" 842 1405 12.4 26 6053376.14 1651528.13 70°33'26.750" 149°54'31.904" 843 1413 12.4 27 6053374.53 1651520.23 70°33'26.734" 149°54'32.137" 845 1421 12.4 1 28 6053373.11 1651512.46 70°33'26.720" 149°54'32.366" 846 1428 12.4 29 6053371.56 1651504.49 70°33'26.705" 149°54'32.602" 848 1436 12.4 30 6053370.06 1651496.66 70°33'26.690" 149°54'32.833" 849 1444 12.4 31 6053367.05 1651480.97 70°33'26.661" 149°54'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70°33'26.646" 149°54'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70°33'26.631" 149°54'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70°33'26.616" 149°54'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70°33'26.601" 149°54'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70°33'26.586" 149°54'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70°33'26.555" 149°54'34.941" 863 1516 12.4 38 6053354.74 1651417.32 70°33'26.541" 149°54'35.177" 864 1524 12.4 Oriobt O040 SPY ISLAND DRILL SITE --1WELL CONDUCTORS +6, AS-BUILT LOCATIONS @nil 'or.tk ,. 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J. z z N Z .8-.xc9 cl-6 i xvuu x,em,n m..ewa+�n.w-,w.u.co-vunsn xtewwwa�oesw�eo-aleannt..c au,a�eeh 5 were File: S126-NW2 (P4) Date: October 06, 2014 Page: 1 BURST LOADS DATA(13 3/8" Surface Casino) 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): 526.73 psi Shoe Depth, MD: 2851.9 usft Fracture Pressure at Shoe: 1598.42 psi Fracture Margin of Error: 0.00 ppg External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 12.4 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: No S126-NW2 StressCheck 5000.1.10.0 Build 1934 File:S126-NW2 (P4) Date: October 06, 2014 Page:2 BURST DESIGN (13 3/8"Surface Casino) 0 Design Load Line Pipe Rating 200 r 1 r r 1 400 600 800 1 J L 1 J O I i I I I i 1 I 1 1000 j L J J L 1 J i I + I I I 1200L a 1 4 I I I + I I I I I I 1400 + 4 + I I I I $ I I I I 2 1600 r r + L I 1 c I I I 0 1800 I I I I I I 2000— _+ r r T 7 C G I I 2200—__+- r 1 r T 1 2400---+- 2600---+- 1 I 2800 _+ 1 J L 1 J I + I I I I 1 I 1 I 30001 J J L L 1 J 1 I I I I 1 I I 1 3200— + I I I I I I I I I 3400 - + I 1 3600 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 Burst Rating (psi) SI26-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date: October 06, 2014 Page: 3 COLLAPSE LOADS DATA(13 3/8" Surface Casing) Drilling Load: Full/Partial Evacuation Mud Weight: 9.50 ppg Mud Level, MD: 2851.9 usft Assigned External Pressure: Fluid Gradients (w/ Pore Pressure) External Pressure: Fluid Gradients (w/ Pore Pressure) TOC, MD: 12.4 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 S126-NW2 StressCheck 5000.1.10.0 Build 1934 File: Sl26-NW2 (P4) Date:October 06, 2014 Page:4 COLLAPSE DESIGN (13 3/8"Surface Casing) 0 - - ---I- I Design Load Line Pipe Rating 200 T 1 r r T 1 r - 400 - I- - 600 - 8001 J L 1 J L - I I I I I I I I I I I 1000 1 J 1_ L 1 J L L - 1 J L 1 J ,_ 1200 , I I I I I I 1 I I 1400 I - I 1 I 1 1 1 I I X1600 + -i r t -I I- ,- _c- I I Q I I 0 1800 T 1 r T -1 r - -0 I 2>` I I ( N2000 1 r T -1 r - M I I I 2200 r 1 r T 1 r - 2400 2600 - 28001 J L 1 J L L _ I I + I I I I I I I I 3000 1 J L 1 J L L - I I I I I I I I 3200— L 1 -' - I I 3400— - I I I I I I I I I I 1 3600 T_ - I f I f I I 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Collapse Rating (psi) SI26-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date: October 06, 2014 Page: 5 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 S126-N W 2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date: October 06, 2014 Page: 6 AXIAL DESIGN(13 3/8"Surface Casino) 0 Design Load Line Pipe Rating 200— T T 1 --\ 400 600 800 1 _i J J I I + I I I I I I 1000 L 1 1 1 J J I I } I I I I I I 1200 hL4 4 t I I t I I 1 I I 1 I I 1400 4 -I i I I I I 21600 + , Y Y , a a) 0 1800 r r T l , , -a I I ill I I N a`) 2000 } T T l l , c I I G I I 2200 } T T , I 2400 +- 2600 +- -. 1 1 1 J J 2800 I + I I I I 1 I 3000 L 1 1 1 J J 3200L i i a .J _, I 1 I I I I I I I 3400 i -' I 3600 j j1 11 r _ ---T_ 0 400000 800000 1200000 1600000 2000000 2400000 2800000 3200000 3600000 Axial Force (lbf) SI26-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date:October 06, 2014 Page: 1 BURST LOADS DATA(9 5/8" Intermediate Casino) 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): 527.56 psi Shoe Depth, MD: 15415.5 usft Fracture Pressure at Shoe: 2351.58 psi ' Fracture Margin of Error: 0.00 ppg External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 13084.0 usft Prior Shoe, MD: 2851.9 usft Mud Weight Above TOC: 9.50 ppg Fluid Gradient Below TOC: 8.60 ppg Pore Pressure In Open Hole: Yes S126-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date:October 06, 2014 Page: 2 BURST DESIGN (9 5/8"Intermediate Casino) 0 Design Load Line Pipe Rating 1000---+ 2000 1 J J I I I I I I I I 3000— -+ 1 + J 4 I I I I I I I 4000 r r -r Y 7 I I I I 5000 6000 7000 I I I I I I I I I 8000 a � � � I I 9000 T -T z crit 10000 - 11000 I I I I I I I I I 12000— + + 4 I I I I I I I I 13000— + r r 1 Y Y I I I I 14000— + r T 4 -r 1 15000— t 16000 L 1 1 J J J I I I I I I I I I 17000— i I 18000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 Burst Rating (psi) S126-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date: October 06, 2014 Page: 3 COLLAPSE LOADS DATA(9 5/8" Intermediate Casino) Drilling Load: Full/Partial Evacuation Mud Weight: 9.50 ppg Mud Level, MD: 15415.5 usft Assigned External Pressure: Fluid Gradients (w/ Pore Pressure) External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 13084.0 usft Prior Shoe, MD: 2851.9 usft Fluid Gradient Above TOC: 9.50 ppg Fluid Gradient Below TOC: 9.50 ppg Pore Pressure In Open Hole Below TOC: No S126-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date: October 06, 2014 Page:4 COLLAPSE DESIGN(9 5/8" Intermediate Casino) 0 I Design Load Line Pipe Rating 1000—— L L 1 1 J 2000 1 I I I I I I I 3000 I I I I I I 4000 r r r y ti -1 I I I I I I I 5000— r r 7 - 1 6000 7000 L1 1 J J J I I I I I I 1 p = 800 4. + i -I -I I I i 0 9000 T r T , 1 -1 P2 L m N as 10000 M 11000 L 1 1 1 J J 1 I 1 I 1 I 12000 4 I I I I I I I 13000 1 r t T Y -1 -I 14000 r r T T 1 1 15000 -' + 16000 L L 1 1 J J I I I I I I I I I 17000 i i I I I I 18000 i i 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 Collapse Rating (psi) SI26-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date:October 06, 2014 Page: 5 AXIAL LOADS DATA(9 5/8" Intermediate Casing) Running in Hole-Avg. Speed: 0.0 ft/s Overpull Force: 0 lbf j Pre-Cement Static Load: Yes Pickup Force: 0 lbf Green Cement Pressure Test: 1000.00 psi L_Service Loads: Yes , S126-NW2 StressCheck 5000.1.10.0 Build 1934 File: S126-NW2 (P4) Date:October 06, 2014 Page:6 AXIAL DESIGN(9 5/8"Intermediate Casing) 0 i Design Load Line + Pipe Rating 1000 J 20001 1 J J + I I I 3000 +� _ I 4000 5000 r r 1 1 6000 7000 ` 1 I I 1 I I I I I I 8000 I 1 1 L I 1 1 a I 1 I 0 9000 CO CO 09 10000 11000 J -J I I I 1 I 1 I I I 1 12000 + i i 4 4 I I I I I I I 13000 -+ / I I I I 14000 + r T + I i 15000 t 1 16000 1 J J I I I 1 I I I I 17000 I I I I 18000 0 300000 600000 900000 1200000 1500000 1800000 2100000 2400000 Axial Force (lbf) S126-NW2 StressCheck 5000.1.10.0 Build 1934 CemCAD r_ well cementing recommendation for 13 3/8 Surface Casing Operator : Eni Petroleum Well : SI26-NW2 Country : USA State : Alaska Prepared for : Andrea Lazzari Location : Spy Island Proposal No. : Initial Draft2(P4) Service Point : Prudhoe Bay Date Prepared : 10/07/2014 Business Phone : +1 907 659 2434 Prepared by : Angele Diboue Phone : +1 907 306 8949 E-Mail Address : aedimo@slb.com d rb' C KUATE ,` 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 Mf stances that are not infallible. Calculations ere 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,DR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rgMs of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. *Mark of Schlumberger Page 1 SI26-NM2.cfw;10-07-2014; LoadCase Surface 13 3/6;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2852.0 ft BHST : 50 degF Bit Size : 16 in ft (); 1000)psi OD 2 18.:1 l) 1 2 – Frac _ ,-, I- i D I- - SV--1 D — t – 4 o_ OD 13.4 in c 6 28328 – SV-3 G 1:111L.---1 SV-2 � 5 o — 5 1 a.- �c2 �B/ Permafrost T N r" � � r, C4 1 SV-1 u l o !m TD y 0 0 VI— V/ell Lithology Formation Press. 1 Page 2 SI26-NM2.cfw;10-07-2014; LoadCaseSurface 133/8;Version wcscem472_05 Client : Eni Petroleum Well : Sl26-NW2 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 2772.0 ft Casing/liner Shoe MD : 2852.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2852.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 132.2 Mean OH Equivalent Diameter: 18.920 in Total OH Volume : 936.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1849.0 16.000 190.0 20.063 2852.0 16.000 35.0 16.822 Max. Deviation Angle : 62 deg Max. DLS : 3.508 deg/100ft Refer to appendix 1 for complete directional surveys Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1200.0 11.50 8.40 SV-4 Siltstone 1500.0 11.50 8.40 SV-3 Sandstone 1967.0 11.50 8.40 SV-2 Siltstone 2100.0 11.50 8.40 B/Permafrost Shale 2550.0 12.00 8.40 SV-1 Sandstone 2941.0 12.50 8.40 TD Sandstone Page 3 S126-NM2 cfw,10-07-2014, LoadCase Surface 13 3/8:Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 SchIbergcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1881.6 32 0.6 2852.0 2454.2 50 1.2 2941.0 2495.8 50 1.2 ft degF (x 1000)ft 0 2(1 40 60 n n 3 1.6 0.9 1.2 _—ceom.lPror —Hoe.Depart. I l IDn o - - O I0 4 un o r-. . '\0 o ��mem��m�m o r O O O O ir...; I:1 i o o csic!zir) _. -7 i---:o- N N ip I N 1 O O Cl— ea Temperature Hod. Departure Page 4 SI26-NM2.cfw;10-07-2014; LoadCaseSurface 133/8,Version wcs-cem472_05 Client : Eni Petroleum Well : Sl26-NW2 Schlumhcrger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 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 415.0 bbl Total Volume 1019.3 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 Ibf/100ft2 Surface Lead Slurry 441.2 2347.0 0.0 10.70 k:2.08E-1 Ibf.s"n/ft2 n:0.187 Ty:16.36 Ibf/100ft2 12.5ppg DeepCRETE 63.0 505.0 2347.0 12.50 k:1.68E-1 lbf.s"n/ft2 n:0.301 Ty:0.44 Ibf/100ft2 Surface Tail Mud 415.0 0.0 9.50 k:8.28E-2 lbf.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 2009 psi at 2772.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 59 ton Check Valve Diff Press 175 psi ft (x 1000) psi - ( > 0 2 J L ,-Hydrostat: -Frac -pore • G E \1 l G - ` Fluid Sequence Static Well Security Page 5 S126-NM2.ctw;10-07-2014; LoadCase Surface 13 3/8;Version wcscem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 13 3/8 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 5.0 441.2 88.2 441.2 80 Mix/Pump Lead SLurry(3-7 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 6.0 405.0 67.5 405.0 80 Displacement Mud 2.0 10.0 5.0 415.0 80 Slow rate to bump the plug Total 03:26 1019.3 bbl hr:mn Dynamic Security Checks: Frac 1 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2008 psi at 2772.0 ft Burst 4731 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 78 degF Simulated BHCT 78 degF Max HCT Depth 2852.0 ft CT at TOC 71 degF Max HCT Time 02:20:29 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 5126-NM2.cfw,10-07-2014, LoadCase Surface 13 3/8 Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlidergcr 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 2852 ft Depth= 2852 ft Frac Pore 0 Hydrostatic Dynamic LJ IJ I I 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 7 5126-NM2.cfw;10-07-2014, LoadCase Surface 13 3/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schl berger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Simulated Ecd at Previous shoe 160 ft __--_Depth= 160 ft co ---- L Froo — T —Pore N —Hydrostatic T-—Dynamic T co V 1/1( c //1 Tr 0 L -v - N- I co ol- ct od o ed O 20 40 60 80 100 120 140 160 180 200 220 Time (min) Simulated rate and pressure during placement Calc.CemHP ---- -Calc.F inp Press. I g P- O 20 40 60 80 100 120 140 160 180 200 220 Time (min) in —_ Fluids at 2852 ft 2, -Acquired O In i S O 1r — i -- O 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 8 SI26-NM2 cfw;10-07-2014: LoadCase Surface 13 3/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 ScIoberier String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Calc.CerrHP $ -Calc.Purrp Press. r 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) Fluids at 2852 ft tn ri O In Acquired O h C u1 zzN_ 6N O - 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) Simulated temperature during placement Last Sack Temp. 0 First Sack Temp. oo API BHCT -N I�- n g ru PB- co 83- •✓ T--T T--T- "- - 41 Q 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 9 SI26-NM2,cfw;10-07-2014; LoadCase Surface 13 3/8;Version wcs-cem472_05 Client : Eni Petroleum Well : Sl26-NW2 Schioberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Simulated temperature throuciht 24 hours after placement at Shoe 2852ft o Depth= 2852 ft co Rof ile .}Annul c(0_ Tubu- - ids N- Off_ N_ 2 E0 1— _ N oo 0 250 500 750 1000 1250 1500 1750 Time (min) Page 10 5126-NM2.cfw;10-07-2014; LoadCase Surface 13 3/6;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger 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 :2842.0 ft Casing Shoe :2852.0 ft NB of Cent. Used :15 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 92.0 0 0/0 100.0 56.0 172.0 2 1/1 NW-ST-13 3/8-8-ST A3B W131 0.0 171.7 2372.0 0 0/0 0.0 172.0 2812.0 11 1/1 NW-ST-13 3/8-8-ST A3B W131 0.0 2379.3 2852.0 2 2/1 NW-ST-13 3/8-8-ST A3B W131 88.7 2822.0 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-ST-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 °'o _ 0 20 0 60 80 100 ——Between cert. I1 --1. -1At Cent i .4.4 I i . + C i r i I I -,— 1 I — O O - N . ' + "Zi. ...._ O G C- _ KK Pipe S Page 11 SI26-NM2.cfw;10-07-2014, LoadCase Surface 13 3/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Section 5: WELLCLEAN II Simulator °/C °/O ft 0 25 50 75 100 0 25 50 75 100 o — Std Betw.Cent. Mud Contamination i — Cement Coverage — — Uncontaminated Slurry g i O_ T 1 I c 7\ Fluid Sequence Cement Coverage Uncontaminated Skrry ...z z w. 0 > > 0 0 0 I 500- I 500 500 500 1000- 1000 1000 1000 a 1500- E1500 a a 1500 1500 a a a, a, m D O D 0 2000 2000 2000 -2000 2500 2500 2500 2500 a ; a a ; a -O 0 : U o -a 0 3 3 0 0 0 z z ■2tpgNe,„.,1..e1M O ops ® ■; Page 12 SI26-NM2.cfw:10-07-2014, LoadCase Surface 13 3/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlimkrger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Section 6: operator summary 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 :441.2 bbl Density : 10.70 lb/gal Yield :2.40 ft3/sk Dry Phase Liquid Phase Blend: 1097.8 sk ✓ Design Mix Water 272.1 bbl 10.0 bbl LAS Design ASL(0.79) 103195.836 Fresh water 272.115 bbl 10.001 bbl lb 12.5ppg DeepCRETE Surface Tail Volume :63.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk L , Dry Phase Liquid Phase Blend: 242.6 sk✓ Design Mix Water 29.5 bbl 10.0 bbl LAS Design 12.5-0.82-53 22621.281 lb Fresh water 29.466 bbl 10.001 bbl D046 45.243 lb 0.200%BWOB D065 56.553 lb 0.250%BWOB D167 56.553 lb 0.250%BWOB D153 22.621 lb 0.100%BWOB Page 13 SI26-NM2.cfw;10-07-2014; LoadCase Surface 13 3/8;Version wcs-cem472_05 Client : Eni Petroleum Well : Sl26-NW2 S hi urger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : Surface 133/8 Appendix 1: Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 285.0 0.000 100.0 100.0 0.0 285.0 0.000 200.0 200.0 0.0 285.0 0.000 250.0 250.0 0.0 285.0 0.000 300.0 300.0 0.5 285.0 1.000 400.0 400.0 1.5 285.0 1.000 450.0 450.0 2.0 285.0 1.000 500.0 499.9 3.0 285.0 2.000 600.0 599.7 5.0 285.0 2.000 650.0 649.4 6.0 285.0 2.000 700.0 699.1 7.5 285.0 3.000 800.0 797.8 10.5 285.0 3.000 900.0 895.6 13.5 285.0 3.000 1000.0 992.2 16.5 285.0 3.000 1100.0 1087.3 19.5 285.0 3.000 1200.0 1180.7 22.5 285.0 3.000 1300.0 1272.0 25.5 285.0 3.000 1392.0 1354.1 28.3 285.0 2.999 1400.0 1361.1 28.3 285.0 0.503 1500.0 1449.0 28.8 285.0 0.500 1600.0 1536.4 29.3 285.0 0.500 1700.0 1623.4 29.8 285.0 0.500 1800.0 1709.9 30.3 285.0 0.500 1900.0 1796.0 30.8 285.0 0.500 1967.7 1854.1 31.1 285.0 0.502 2000.0 1881.6 32.3 285.0 3.501 2100.0 1964.4 35.8 285.0 3.500 2200.0 2043.7 39.3 285.0 3.500 2300.0 2119.2 42.8 285.0 3.500 2400.0 2190.5 46.3 285.0 3.500 2500.0 2257.3 49.8 285.0 3.500 2600.0 2319.6 53.3 285.0 3.500 2700.0 2376.9 56.8 285.0 3.500 2800.0 2429.1 60.3 285.0 3.500 2851.9 2454.1 62.1 285.0 3.508 2852.0 2454.2 62.1 285.0 0.000 I Page 14 5126-NM2.cfw;10-07-2014; LoadCase Surface 133/8;Version wcs-cem472_05 CemCAD E* well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : SI26-NW2 Country : USA State : Alaska Prepared for : Andrea Lazzari Location : Spy Island Proposal No. : Initial(P4) Service Point : Prudhoe Bay Date Prepared : 10/07/2014 Business Phone : +1 907 659 2434 Prepared by : Angele Diboue Phone : +1 907 306 8949 E-Mail Address : aedimo©slb.com S. L 14VATE � Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment.experience.and good oilfield practices. I, 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 WARRANtt 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 S126-NM2.cfw,10-07-2014; LoadCase Intermediate Casing 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 15415.0 ft BHST : 85 degF Bit Size : 12 1/4 in ft (x 1000)psi �t 2:: 0 2.5 -Siltstone— ti �L �y t ':::Sandstone'::: i i } r ti w E4•°'• Coal 1 ,! �til :: — ® t i _ Lithology Formation Press. Page2 S126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/B;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlimlirgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2852.0 13 3/8 68.0 12.415 Landing Collar MD : 15335.0 ft Casing/liner Shoe MD : 15415.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 15415.0 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 : 2181.8 bbl (including excess) Max. Deviation Angle : 89 deg Max. DLS : 3.508 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1200.0 11.50 8.40 SV-4 Siltstone 1500.0 11.50 8.40 SV-3 Sandstone 1967.0 11.50 8.40 SV-2 Siltstone 2100.0 11.50 8.40 B/Permafrost Shale 2550.0 12.00 8.40 SV-1 Sandstone 7200.0 12.50 8.40 Ugnu Top(UG4) Sandstone 14000.0 12.50 8.40 UG-2 Coal Bed Coal Marke 14600.0 12.50 8.40 Lower Ugnu Sandstone 14900.0 12.50 8.40 Schrader Bluff Top Sandstone 14950.0 12.50 8.40 N Sequence Top Sandstone 15415.0 12.50 8.40 TD Sandstone Page 3 8126-NM2.ciw;10-07-2014; LoadCase Intermediate Casing 9 5/6;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1881.6 32 0.6 3079.0 2546.2 50 1.2 15415.0 3608.4 85 1.8 ft degF (x 1000)ft 0 'Ifl 60 90 0 5 10 15 ,,__t- 1 H:,. Ce a.t I , Tr. 1 . O ty T o O O N _ i O O C'N'INN-\\I ‘– Tr. — ' 111111.1101111 RN (f) — NOM ' \ ' Ea r- ' UM c, cn NI• MOM mono t a ■ a Emu p _.-_ --}_..-_--_-_-..__-._. _._.__-._.- — .. vr N- Temperature Hori Departure Page 4 S126-NM2.cf w:10-07-2014: LoadCase Intermediate Casing 9 5/8,Version wcs-cem472_05 Client : Eni Petroleum Well : Sl26-NW2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 13084'(1,000'above the"N" Sand Top) Original fluid Mud 9.50 lb/gal k :5.97E-3 Ibf.sAn/ft2 n : 0.616 Ty :8.86 Ibf/100ft2 Displacement Volume 1162.8 bbl Total Volume 1463.9 bbl TOC 13084.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) MUDPUSH II 100.0 1195.1 11888.9 10.50 k:5.23E-2 Ibf.sAn/ft2 n:0.324 Ty:12.92 Ibf/100ft2 12.5ppg DeepCRETE 201.1 2331.0 13084.0 12.50 k:4.89E-3 Ibf.sAn/ft2 n:0.960 Ty:15.95 Ibf/100ft2 Mud 1162.8 0.0 9.50 k:5.97E-3lbf.s^n/ft2 n:0.616 Ty:8.86Ibf/100ft2 Static Security Checks Frac 345 psi at 2852.0 ft Pore 140 psi at 2852.0 ft Collapse 2542 psi at 15335.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 59 ton Check Valve Diff Press 92 psi ft (x 1000) psi 0 20 Hydrostatic -----Frac - Pore — G 1 G CJ— Fluid Sequence Static Well Security Page 5 SI26-t4M2.cfw;10-07-2014: LoadCaseIntermediate Casing 95/8,Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 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 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 Rate Volume Stage Time Cum.Vol lnj.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 6.0 201.1 33.5 201.1 80 Mix/Pump Cement Slurry(3-7 BPM) Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 6.0 40.0 6.7 40.0 80 Displacement Mud 5.0 1095.0 219.0 1135.0 80 Slow rate as soon WHP increases Mud 2.0 10.0 5.0 1145.0 80 Slow Rate to Bump Total 04:54 1446.1 bbl hr:mn Dynamic Security Checks: Frac 158 psi at 15415.0 ft Pore 140 psi at 2852.0 ft Collapse 2429 psi at 0.0 ft Burst 4440 psi at 0.0 ft Temperature Results BHCT 83 degF Simulated Max HCT 82 degF Simulated BHCT 81 degF Max HCT Depth 14250.6 ft CT at TOC 82 degF Max HCT Time 04:54:10 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 70 degF Bottom Hole (degF) (degF) 85 degF Page 6 S126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/8,Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlohergcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 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 15415 ft Depth= 15415 ft (`1 —Frac r Pore NHydrostatic Dynarric CIC!j � V t� OS T T T O 40 80 120 160 200 240 280 320 Time (min) Page 7 SI26-NM2.cfw V 10-07-2014, LoadCase Intermediate Casing 9 5/8 V Version wcs-cem472_05 Client : Eni Petroleum Well : Sl26-NW2 Sekbohrger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Simulated ECD at Previous shoe 2852 ft Depth= 2852 fttn N I-Frac L—Rue O Hydrostatic N —Dynamic to T 0 ^T Lr) s2c1 T Ln 05 i 11 gT T O 40 80 120 160 200 240 280 320 Time (min) Simulated rate and pressure during placement Calc.CerriiP Ca Pump Press. q ^ T- O \ T O 40 80 120 160 200 240 280 320 Time (min) Fluids at 15415 f[_ N Q h Acquired 0 In g _ 0 O 40 80 120 160 200 240 280 320 Time (min) Page 8 SI26-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 95/8 Version wco-cenat72OS Client : Eni Petroleum Well : S126-NW2 SchIoberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 _u) Cab.Ceni-IP T .Pump Press. X0 �1 T .1 I.L O 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 Pumped Volume (bbl) (x 1000) Fluids at 15415 ft in N: Qh -Acquired Q h C I E O V7 N ti cC N- I M I I O If T I f O 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 Pumped Volume (bbl) (x 1000) Simulated temperature during placement 0 Last Sack Terre. First Sack Temp. API BHCT ❑O N W I 0 O i K- Z. g. N E�0 co O te- 1 o 0 40 80 120 160 200 240 280 320 Time (min) Page 9 8126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/8,Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Simulated temperature throuqht 24 hours after placement at Shoe 15415ft Depth= 15415 ft co —API BHCT —Geoth.RofIle —+Annulus A_ Tubular Fluids co li 00 o)N' o Ts o to I ci N� I— a) (D CD CD CO 0 200 400 600 800 1000 1200 1400 1600 1800 2000 Time (min) Page 10 5126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/0;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Section 4: centralizer placement Top of centralization :9000.0 ft Bottom Cent. MD :15395.0 ft Casing Shoe :15415.0 ft NB of Cent. Used :38 NB of Floating Cent. :38 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 13895.0 0 0/0 0.0 13912.3 15415.0 38 1/1 HYDROFORM HFD 50.0 15415.0 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) (Ibf) (Ibf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford r" N.A. N.A. N.A. (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft oro t_______ e- 0 7t) 0 60 80 100 -—Oeel�een Cent. I --I I I + 4At Can. O O O ,_ _ _________ __, . ____, O :: Ii 'j r , Pipe Standoff Page 11 8126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/8.Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlmlbe String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Section 5: WELLCLEAN II Simulator ..,G 0/O ft 0 25 50 75 100 0 25 50 75 100 1 ' F i -Std Betw.Cent. Mud Contamination I —Cement Coverage — Uncontaminated Slurry f I I I j Z\ 1— < r 1J Fluid Sequence Cement Coverage Uncontaminated Slurry z z 9000 9000 9000 9000 10000 10000 10000 10000 11000 11000 11000 11000 " 12000 12000 " 12000 12000 "' r 1 r r r O• 13000 `r 13000 0 0 13000 13000 0 I i 14000— 14000 14000 14000 15000— 15000 15000 15000 m ; m 0 ; m -o o -‘3 o -o 3 3 3 0 0 0 z z C«:re A„E 11=11= Page 12 5126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 SchlumMer String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Section 6: operator summary 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 Ib/bbl of base fluid D031 11722.021 lb 117.22 lb/bbl of spacer 12.5ppg DeepCRETE Volume :201.1 bbl Density : 12.50 lb/gal r L 4 Yield : 1.56 ft3/sk " ..t.... 72 Dry Phase Liquid Phase Blend: (sk) Design Mix Water 94.0 bbl 10.0 bbl LAS Design 12.5-0.82-53 72158.258 lb Fresh water 93.991 bbl 10.001 bbl D046 144.317 lb 0.200%BWOB D065 180.396 lb 0.250%BWOB D167 180.396 lb 0.250%BWOB D153 72.158 lb 0.100%BWOB Page 13 SI2B-NM2.cfw,10-07-2014, LoadCase Intermediate Casing 9 5/B,Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Scbihrger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Appendix 1 Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 285.0 0.000 100.0 100.0 0.0 285.0 0.000 200.0 200.0 0.0 285.0 0.000 250.0 250.0 0.0 285.0 0.000 300.0 300.0 0.5 285.0 1.000 400.0 400.0 1.5 285.0 1.000 450.0 450.0 2.0 285.0 1.000 500.0 499.9 3.0 285.0 2.000 600.0 599.7 5.0 285.0 2.000 650.0 649.4 6.0 285.0 2.000 700.0 699.1 7.5 285.0 3.000 800.0 797.8 10.5 285.0 3.000 900.0 895.6 13.5 285.0 3.000 1000.0 992.2 16.5 285.0 3.000 1100.0 1087.3 19.5 285.0 3.000 1200.0 1180.7 22.5 285.0 3.000 1300.0 1272.0 25.5 285.0 3.000 1392.0 1354.1 28.3 285.0 2.999 1400.0 1361.1 28.3 285.0 0.503 1500.0 1449.0 28.8 285.0 0.500 1600.0 1536.4 29.3 285.0 0.500 1700.0 1623.4 29.8 285.0 0.500 1800.0 1709.9 30.3 285.0 0.500 1900.0 1796.0 30.8 285.0 0.500 1967.7 1854.1 31.1 285.0 0.502 2000.0 1881.6 32.3 285.0 3.501 2100.0 1964.4 35.8 285.0 3.500 2200.0 2043.7 39.3 285.0 3.500 2300.0 2119.2 42.8 285.0 3.500 2400.0 2190.5 46.3 285.0 3.500 2500.0 2257.3 49.8 285.0 3.500 2600.0 2319.6 53.3 285.0 3.500 2700.0 2376.9 56.8 285.0 3.500 2800.0 2429.1 60.3 285.0 3.500 2851.9 2454.1 62.1 285.0 3.508 2900.0 2476.0 63.8 285.0 3.491 2967.7 2504.7 66.1 285.0 3.500 3000.0 2517.4 67.3 285.1 3.484 3100.0 2553.3 70.8 285.5 3.504 3200.0 2583.3 74.2 285.8 3.503 3300.0 2607.5 77.7 286.1 3.493 j 3400.0 2625.8 81.2 286.4 3.502 3500.0 2638.1 84.7 286.7 3.503 3600.0 2644.3 88.2 287.0 3.502 3609.0 2644.6 88.5 287.0 3.468 3700.0 2646.9 88.5 287.0 0.000 3800.0 2649.6 88.5 287.0 0.000 3900.0 2652.2 88.5 287.0 0.000 4000.0 2654.8 88.5 287.0 0.000 4100.0 2657.4 88.5 287.0 0.000 4200.0 2660.0 88.5 287.0 0.000 4300.0 2662.6 88.5 287.0 0.000 4400.0 2665.3 88.5 287.0 0.000 4500.0 2667.9 88.5 287.0 0.000 4600.0 2670.5 88.5 287.0 0.000 4700.0 2673.1 88.5 287.0 0.000 4800.0 2675.7 88.5 287.0 0.000 Page 14 S126-NM2.cfw,10-07-2014; LoadCase Intermediate Casing 9 5/8;Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlemlinr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Appendix 1 Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4900.0 2678.3 88.5 287.0 0.000 5000.0 2681.0 88.5 287.0 0.000 5100.0 2683.6 88.5 287.0 0.000 5200.0 2686.2 88.5 287.0 0.000 5300.0 2688.8 88.5 287.0 0.000 5400.0 2691.4 88.5 287.0 0.000 5500.0 2694.1 88.5 287.0 0.000 5600.0 2696.7 88.5 287.0 0.000 5700.0 2699.3 88.5 287.0 0.000 5800.0 2701.9 88.5 287.0 0.000 5900.0 2704.5 88.5 287.0 0.000 6000.0 2707.1 88.5 287.0 0.000 6100.0 2709.8 88.5 287.0 0.000 6200.0 2712.4 88.5 287.0 0.000 6300.0 2715.0 88.5 287.0 0.000 6400.0 2717.6 88.5 287.0 0.000 6500.0 2720.2 88.5 287.0 0.000 6600.0 2722.8 88.5 287.0 0.000 6700.0 2725.5 88.5 287.0 0.000 6800.0 2728.1 88.5 287.0 0.000 6900.0 2730.7 88.5 287.0 0.000 7000.0 2733.3 88.5 287.0 0.000 7100.0 2735.9 88.5 287.0 0.000 7200.0 2738.6 88.5 287.0 0.000 7300.0 2741.2 88.5 287.0 0.000 7400.0 2743.8 88.5 287.0 0.000 7500.0 2746.4 88.5 287.0 0.000 7600.0 2749.0 88.5 287.0 0.000 7700.0 2751.6 88.5 287.0 0.000 7800.0 2754.3 88.5 287.0 0.000 7900.0 2756.9 88.5 287.0 0.000 8000.0 2759.5 88.5 287.0 0.000 8100.0 2762.1 88.5 287.0 0.000 8200.0 2764.7 88.5 287.0 0.000 8300.0 2767.3 88.5 287.0 0.000 8400.0 2770.0 88.5 287.0 0.000 8500.0 2772.6 88.5 287.0 0.000 8600.0 2775.2 88.5 287.0 0.000 8700.0 2777.8 88.5 287.0 0.000 8800.0 2780.4 88.5 287.0 0.000 8900.0 2783.1 88.5 287.0 0.000 9000.0 2785.7 88.5 287.0 0.000 9100.0 2788.3 88.5 287.0 0.000 9200.0 2790.9 88.5 287.0 0.000 9300.0 2793.5 88.5 287.0 0.000 9400.0 2796.1 88.5 287.0 0.000 9500.0 2798.8 88.5 287.0 0.000 9600.0 2801.4 88.5 287.0 0.000 9700.0 2804.0 88.5 287.0 0.000 9800.0 2806.6 88.5 287.0 0.000 9900.0 2809.2 88.5 287.0 0.000 10000.0 2811.8 88.5 287.0 0.000 10100.0 2814.5 88.5 287.0 0.000 10200.0 2817.1 88.5 287.0 0.000 10300.0 2819.7 88.5 287.0 0.000 10400.0 2822.3 88.5 287.0 0.000 10500.0 2824.9 88.5 287.0 0.000 Page 15 5126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/8:Version wcs-cem472_05 Client : Eni Petroleum Well : S126-NW2 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : Intermediate Casing 9 5/8 Appendix 1 Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 10600.0 2827.5 88.5 287.0 0.000 10700.0 2830.2 88.5 287.0 0.000 10800.0 2832.8 88.5 287.0 0.000 10900.0 2835.4 88.5 287.0 0.000 11000.0 2838.0 88.5 287.0 0.000 11100.0 2840.6 88.5 287.0 0.000 11200.0 2843.3 88.5 287.0 0.000 11300.0 2845.9 88.5 287.0 0.000 11400.0 2848.5 88.5 287.0 0.000 11500.0 2851.1 88.5 287.0 0.000 11600.0 2853.7 88.5 287.0 0.000 11700.0 2856.3 88.5 287.0 0.000 11800.0 2859.0 88.5 287.0 0.000 11900.0 2861.6 88.5 287.0 0.000 12000.0 2864.2 88.5 287.0 0.000 12100.0 2866.8 88.5 287.0 0.000 12109.0 2867.0 88.5 287.0 0.000 12200.0 2871.2 86.3 287.5 -2.499 12300.0 2879.8 83.9 288.1 -2.500 12400.0 2892.6 81.4 288.7 -2.502 12500.0 2909.6 79.0 289.3 -2.503 12600.0 2930.7 76.6 290.0 -2.492 12700.0 2956.0 74.2 290.6 -2.505 12800.0 2985.3 71.7 291.2 -2.498 12900.0 3018.7 69.3 291.9 -2.499 12959.8 3040.5 67.9 292.3 -2.506 13000.0 3055.6 67.9 292.3 0.000 13100.0 3093.3 67.9 292.3 0.000 13200.0 3131.0 67.9 292.3 0.000 13300.0 3168.7 67.9 292.3 0.000 13400.0 3206.4 67.9 292.3 0.000 13500.0 3244.1 67.9 292.3 0.000 13600.0 3281.8 67.9 292.3 0.000 13638.8 3296.4 67.9 292.3 0.000 13700.0 3319.4 67.9 292.3 0.000 13800.0 3357.1 67.9 292.3 0.000 13821.8 3365.4 67.9 292.3 0.000 13900.0 3393.8 69.5 293.5 2.503 14000.0 3427.2 71.5 295.0 2.496 14100.0 3457.2 73.6 296.5 2.506 14200.0 3483.7 75.7 297.9 2.492 14300.0 3506.7 77.7 299.4 2.505 14400.0 3526.2 79.8 300.8 2.501 14500.0 3542.1 81.9 302.1 2.495 14600.0 3554.3 84.0 303.5 2.505 14700.0 3562.9 86.1 304.9 2.499 14710.5 3563.5 86.3 305.0 2.494 14800.0 3569.2 86.3 305.0 0.000 14900.0 3575.6 86.3 305.0 0.000 15000.0 3582.0 86.3 305.0 0.000 15100.0 3588.3 86.3 305.0 0.000 15200.0 3594.7 86.3 305.0 0.000 15300.0 3601.1 86.3 305.0 0.000 15400.0 3607.4 86.3 305.0 0.000 15410.4 3608.1 86.3 305.0 0.000 15415.0 3608.4 86.3 305.0 0.000 Page 16 5126-NM2.cfw;10-07-2014; LoadCase Intermediate Casing 9 5/8;Version wcs-cem472_05 jv,, Bettis, Patricia K (DOA) From: Lazzari Andrea <Andrea.Lazzari@enipetroleum.com> Sent: Thursday, October 09, 2014 2:50 PM To: Bettis, Patricia K (DOA) Subject: RE: Nikaitchuq SI26-NW2: Permit to Drill Application Hello Patricia, No, we won't pre-produce SI26-NW2. Best regards, Andrea Lazzari Drilling Engineer Eni Petroleum Office: (907) 865-3323 Cell: (907) 230-7511 Email: andrea.Iazzarienipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, October 09, 2014 2:26 PM To: Lazzari Andrea Subject: Nikaitchuq SI26-NW2: Permit to Drill Application Good afternoon Andrea, Does ENI plan to pre-produce SI26-NW2 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 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, October 09, 2014 2:26 PM To: andrea.lazzari@enipetroleum.com Subject: Nikaitchuq SI26-NW2: Permit to Drill Application Good afternoon Andrea, Does ENI plan to pre-produce SI26-NW2 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. 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: / V i a Tc-t\ S' a(0 — /01/6r)-, PTD: 02 I /3-7- Development `Service Exploratory Stratigraphic Test Non-Conventional �I II / r FIELD: I 1/ ; �C POOL: / I/G �ch r 6s 34,34 6d 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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(0 O p, m 0 O qq 5. d Q Q d Lu Q O 0 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: December 22, 2014 Surface Data Logging End of Well Report SI26-NW2 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: SI26-NW2 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23531-00-00 Sperry Job Number: AK-AM-0901822325 Job Start Date: 06 November 2014 Spud Date: 08 November 2014 Total Depth: 24062’ MD, 3632’ TVD North Reference: True Declination: 19.102° Dip Angle: 81.059° Total Field Strength: 57593.928 nT Date Of Magnetic Data: 15 Nov 2014 Wellhead Coordinates N: North 70° 33' 27.78674" Wellhead Coordinates W: West 149° 54' 20.51965" Drill Floor Elevation 53.72’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Douglas Acker, Leigh Ann Rasher, Kori Jo Plowman, Rebecca Mulkey, Alexander Kalenuik SDL Sample Catchers: Lee Rice, Chris Silva, Lesley Hunter, Sonny Tiger Company Geologist: Andrew Buchanan Company Representatives: Jack Keener / Mike Ross SSDS Unit Number: 110 DAILY S UMMARY 11/06/2014 Skid rig floor into drilling position. Rig up operations in preparation for pre-spud acceptance. 11/07/2014 Continue rig up operations for pre-spud acceptance. Nipple up starter head, surface stack and install two diverter sections. Load and process 5" drill pipe in the pipe shed. Perform a diverter test. Finish nipple up of the surface BOP, flow line, hoses, trip tank & diverter line spool. Load 5" drill pipe in the pipe shed. Install mouse hole & equipment. Pick up 110 joints of 5" drill pipe via mouse hole and rack back in derrick 11/08/2014 Build total of 161 stands of 5" drill pipe via mouse hole and rack in derrick. Lay down mouse hole and run 13 3/8" hanger. Cut and slip drill line. Pick up heavy weight drill pipe, jars, 1 stand, flex collars and stand in derrick. Make up 16" bit, motor and heavy weight. Fill conductor and test surface equipment. Clean out conductor casing to 160’ MD 11/09/2014 Drill to 397' MD and pull out of hole 3 stands of heavy weight drill pipe. Make up stabilizers, drill collar and 1 stand of heavy weight with jars. Run in hole to 397' MD and drill to 1373' MD Gas: Max gas observed was 29 units at 1325' MD with an average gas of 12 units. Fluids: There were no losses. 11/10/2014 Drill from 1373' MD to TD of 2846' MD and circulated bottoms up. Backream out of hole from 2651' MD to 2371'MD Gas: Max gas observed was 1037 units at 2059' MD with an average gas of 34 units. Fluids: There were no losses. 11/11/2014 Backream out of hole from 2371' MD to 691' MD. Lay down BHA #2 and clean rig floor. Rig up 13 3/8" casing equipment and run 13 3/8" surface casing to 2593 MD' filling casing every 10 joints. Gas: Max gas observed was 803 units with an average gas of 25 units. Fluids: Total of 4 barrels lost down hole. 11/12/2014 Continue to run 13 3/8" casing from 2593' MD to 2834' MD. Make up landing joint and hanger. Circulate hole. Pump mud push and drop bottom plug. Pump cement and drop top plug. Rig down cement equipment. Flush and nipple down stack. Nipple up BOPE and rig up test equipment. Gas: No gas was observed. Fluids: There were no losses. 11/13/2014 Change out saver sub on top drive. Fill BOPE and choke. Replace ring on choke manifold. Test BOPE's and rig down test equipment. Replace Shot-pin on top drive and service rig. Make up BHA #3 and run in hole to 1500' MD. Shallow test MWD and run in hole to 2591’ MD Gas: No gas was observed. Fluids: There were no losses. 11/14/2014 Continue to run in hole to 2680” MD. Rig up and test 13 3/8" casing to 2500 psi for 30 min. Run in hole and tag the float at 2747' MD. Drill cement and new hole to 2866' MD. Displace from spud mud to 9.2 ppg LSND mud. Cut and slip drill line. Clean surface equipment. Preform FIT test to 12.4 ppg. Drill from 2866' MD to 3900' MD Gas: Max gas observed was 107 units at 3861' MD with an average gas of 27 units. Fluids: There were no losses. Geology: Sample consists of 80% well sorted sandstone with 20% soft to firm Siltstone. 11/15/2014 Drill ahead from 3935’ MD to 6020’ MD. Gas: Max gas observed was 131 units at 6015' MD with an average gas of 36 units. Fluids: There were no losses. Geology: Sample consists of mostly well sorted sandstone with intervals of soft to firm siltstone. 11/16/2014 Drill ahead from 6020’ MD to 6492’ MD. Gas: Max gas observed was 38 units at 6073' MD with an average gas of 13 units. Fluids: Total of 7 barrels lost down hole. Geology: Sample consists of mostly well sorted sandstone with abundant chert. 11/17/2014 Drill ahead from 6492’ MD to 6527’ MD. Decision made to pull out of hole due to low ROP. Gas: Max gas observed was 11 units at 6523' MD with an average gas of 4 units. Fluids: Total of 379 barrels lost down hole. Geology: Sample consists of mostly well sorted sandstone with abundant chert. 11/18/2014 Continue to pull out of hole and backream per K&M. Pull out of hole to 1564’ MD and lay down worn drill pipe to 350’ MD. Lay down BHA. Gas: Max trip gas was 4 units. Fluids: Total of 1093 barrels lost down hole. Geology: No samples collected. 11/19/2014 Load 5” drill pipe in shed. Make up BHA #4. Run in hole to 1560’ MD and shallow hole test MWD tools. Run in hole and lay down washed out drill pipe. Ream in hole from 5018’ MD to 6527’ MD. Drill ahead from 6527’ MD to 7063’ MD. Gas: Max gas observed was 37 units at 6684' MD with an average gas of 14 units. Fluids: Total of 51 barrels lost down hole. Geology: Sample consists of mostly well sorted sandstone. 11/20/2014 Drill ahead from 7063’ MD to 8376’ MD. Circulate and wait on weather (phase III). Drill ahead from 8376’ MD to 9278’ MD. Gas: Max gas observed was 32 units at 7534' MD with an average gas of 13 units. Fluids: Total of 182 barrels lost down hole. Geology: Sample consists of mostly sandstone with intervals of 10-50% siltstone. 11/21/2014 Drill ahead from 9278’ MD to 11520’ MD. Gas: Max gas observed was 21 units at 11418' MD with an average gas of 12 units. Fluids: Total of 119 barrels lost down hole. Geology: Sample consists of sandstone with intervals of 10%-70% siltstone and 10%-20% shale. 11/22/2014 Drill ahead from 11520’ MD to 13788’ MD. Gas: Max gas observed was 54 units at 13761' MD with an average gas of 16 units. Fluids: Total of 160 barrels lost down hole. Geology: Sample consists of mainly sandstone with intervals of up to 70% siltstone. 11/23/2014 Drill ahead from 13788’ MD to 15457’ MD. Gas: Max gas observed was 682 units at 14219' MD with an average gas of 129 units. Fluids: Total of 64 barrels lost down hole. Geology: Sample consists of mainly siltstone with around 30% sandstone. 11/24/2014 Drill ahead from 15457’ MD to intermediate TD of 15750’ MD. Circulate bottoms up twice and rack back one stand per bottoms up. Begin to back ream out of hole per K&M representative. Gas: Max gas observed was 1651 units at 15690' MD with an average gas of 237 units. Max gas while back reaming out of the hole was 219 units. Fluids: Total of 19 barrels lost down hole. Geology: Sample consists of mainly siltstone with 30%-50% sandstone from 15450’ MD to 15650’ MD. Samples consisted of clean sandstone from 15650’ MD to intermediate TD. 11/25/2014 Continue to back ream out of hole per K&M representative. Gas: Max gas observed was 21 units while back reaming out of the hole. Fluids: Total of 70 barrels lost down hole. 11/26/2014 Continue to back ream out of hole per K&M representative. Pack off at 3610’ MD and run in hole to 3985’ MD. Stage pumps at 900 gpm and circulate SafeCarb 250. Continue to back ream out of the hole per K&M representative from 3985’ MD to 1470’ MD. Gas: Max gas observed was 130 units while back reaming out of the hole. Fluids: Total of 133 barrels lost down hole. 11/27/2014 Pull out of the hole from 1400’ MD to 350’ MD and lay down BHA #4. Wash stack, pull wear ring and set test plug. Change out top rams to 9 5/8” and test. Rig down testing equipment. Pull test plug and casing wear ring. Rig up casing equipment and being to run in hole to 9835’ MD with 9 5/8” casing. Gas: Max trip gas was 8 units Fluids: There were no losses. 11/28/2014 Continue to run in the hole with 9 5/8” casing to 15710’ MD. Make up landing joint and rotate down to 15740’ MD. Rig down casing equipment and rig up bails, cement head and circulate equipment. Begin to fill 9 5/8” casing. Gas: No significant gas data. Fluids: There were no losses. 11/29/2014 Circulate and condition mud for cement job. Cement 9 5/8” casing and rig down cement head. Blow down and rig down cement equipment and nipple down BOP. Set 9 5/8” slips and cut off 9 5/8” casing. Pull 9 5/8” casing running wear bushings and set 9 5/8” pack off. Set BOP stack, change out top rams and test pack off. Nipple up BOP and freeze protect annulus. Gas: No significant gas data. Fluids: There were no losses. 11/30/2014 Rig up to test BOP and test BOP. Blow down choke, pull test plug and install wear ring. Change out saver subs and perform rig maintenance. Begin to pick up 4.5” drill pipe and rack back 69 stands. Load BHA tools to rig floor. Perform casing test for 30 minutes and rig down testing equipment. Gas: No significant gas data. Fluids: There were no losses. 12/01/2014 Make up BHA #5 and single in 4.5” drill pipe from shed to 1526’ MD. Shallow hole test MWD tools and continue to run in the hole to 6000’ MD. Begin to rotate in the hole to 12490’ MD. Begin LWD MAD pass from 12490’ MD to 13330’ MD. Gas: No significant gas data. Fluids: There were no losses. 12/02/2014 Continue LWD MAD pass from 13330’ MD to 15384’ MD. Wash down to 15664’ MD and displace well from LSND mud to 9.25 ppg FazePro. Drill out shoe track from 15664’ MD to 15750’ MD and 20 feet of new hole to 15770’ MD. Pull out of the hole to 15745’ MD and circulate. Perform FIT to 13.0 ppg EMW. Begin to drill 8.75” hole from 15770’ MD to 16530’ MD. Gas: Max gas observed was 804 units at 16453' MD with an average gas of 258 units. Fluids: There were no losses. Geology: Sample consists of mainly sandstone with trace siltstone. 12/03/2014 Drill ahead from 16530’ MD to 19069’ MD. Gas: Max gas observed was 1287 units at 17966' MD with an average gas of 508 units. Fluids: There were no losses. Geology: Sample consists of mainly sandstone with trace siltstone. 12/04/2014 Drill ahead from 19069’ MD to 19400’ MD. Notice slight breathing and monitor well. Continue to drill ahead from 19400’ MD to 21166’ MD. Gas: Max gas observed was 1185 units at 20862' MD with an average gas of 333 units. Fluids: Total of 45 barrels lost down hole. Geology: Sample consists of mainly clean sandstone with intervals of 10% to 30% siltstone. 12/05/2014 Drill ahead from 21166’ MD to 22102’ MD. Monitor well for breathing. Continue to drill ahead to 23216’ MD. Gas: Max gas observed was 1353 units at 22168' MD with an average gas of 551 units. Fluids: Total of 92 barrels lost down hole. Geology: Sample consists of mainly clean sandstone with intervals of 10% to 30% siltstone. 12/06/2014 Drill ahead from 23216" MD to production TD of 24062' MD. Circulate bottoms up. Begin to backream out of hole. Gas: Max gas observed was 754 units at 24047' MD with an average gas of 236 units. Fluids: Total of 134 barrels lost down hole. Geology: Sample consists of mainly clean sandstone. 12/07/2014 Continue to backream out of hole to 13797’ MD. Ream and circulate through tight spots. Gas: Max trip gas was 145 units. Fluids: Total of 70 barrels lost down hole. 12/08/2014 Continue to backream out of hole from 13797’ MD to 9032’ MD and then pull out of hole. Slip and cut drill line and service rig. Gas: Max trip gas was 5 units. Fluids: Total of 40 barrels lost down hole. 12/09/2014 Clean and clear rig floor. Make up and run in hole with clean-out BHA to 11548’ MD. Fill pipe every 2000’. Continue to run in hole to 19011’. Gas: Max trip gas was 3 units Fluids: There were no losses. 12/10/2014 Wash and ream hole, and tag bottom at 24062’ MD. Circulate and reciprocate to 23964’ MD. Mon itor well. Drop drift at 22771’ MD. Pull out of hole to 20603’ MD. Gas: No significant gas data. Fluids: Total of 101 barrels lost down hole 12/11/2014 Continue to pull out of hole to 15500’ MD. Displace hole from FazePro to Brine. Continue pulling out of hole to 9961’ MD Gas: No significant gas data. Fluids: Total of 115 barrels lost down hole 12/12/2014 Continue to pull out of hole and lay down BHA. Rig up GBR liner equipment. Run in hole with 4.5” liner to 8472’ MD Gas: No significant gas data. Fluids: Total of 78 barrels lost down hole 12/13/2014 Changeover handling equipment to 5” and clean rig floor. Rig up GBR tongs. Make up packer. Run in hole with 5” drill pipe to 15700’. Circulate at 9 5/8” casing shoe. Continue to run in hole to 19629’ MD. Run in and rotate in hole to 24062’ MD. Set packer and test. Blow down top drive. Lay down 5” drill pipe to 11825’ MD Gas: No significant gas data. Fluids: No trip losses 12/14/2014 Pull test plug and set wear ring. Lay down one stand of 5” drill pipe and changeover to 4.5” handling equipment. Lay down 4.5” drill pipe to 2853’ MD. Gas: No significant gas data. Fluids: Total of 56 barrels lost down hole 12/15/2014 Continue to lay down 4.5” drill pipe. Run in hole with 4.5” completion tubing Gas: No significant gas data. Fluids: There were no losses. 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 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: SI26-NW2 OPERATOR: Eni Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-XX-0901822325 Days vs. Depth 06 Nov 2014 Sperry SDL Continued on Location LOCATION: Nikaitchuq AREA: North Slope Borough STATE: Alaska SPUD: 8-Nov-2014 TD: 6-Dec-2014 Commenced 16" Surface Hole Section On Bot: 22:30 08 Nov 2014 TD Surface Hole Section 2846' MD, 2452' TVD Off Bot: 20:08 10 Nov 2014 Commenced 12.25" Intermediate Hole Section On Bot: 13:23 14 Nov 2014 Landed 13 3/8" Casing 2834' MD, 2445' TVD 12 Nov 2014 POOH to P/U Bit #3 Off Bot: 16:00 17 Nov 2014 On Bot: 18:30 19 Nov 2014 TD Intermediate Hole Section 15750' MD, 3628' TVD Off Bot: 05:10 24 Nov 2014 Commenced 8.75" Injection Hole Section On Bot: 13:30 02 Dec 2014 Landed 9 5/8" Casing 15740' MD, 3627' TVD 28 Nov 2014 TD ProductionHole Section 24062' MD, 3632' TVD Off Bot: 15:20 06 Dec 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 15 HOLE SECTION:Surface EMPLOYEE NAME:DATE: Recommendations: Be sure to check the time and depth calibrations in descriptors. The boxes have continued to stay checked so be sure there is no overlapping data. Innovations and/or cost savings: N/A Kori Jo Plowman 15-Nov-2014 What went as, or better than, planned: The gas equipment worked well with no major issues. There were no problems with the new gas traps. Difficulties experienced: The ADI computer shut down on its own just before drilling, no gaps in the log occurred from this. During surface casing the calibration boxes in the descriptors automaticaly checked themselves. A new run was created to see if this would fix the issue. It did not solve it, but no major problems have yet occured from this issue. SI26-NW2 Nikaitchuq Eni Petroleum North Slope Borough AK-XX-0901822325 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 15 HOLE SECTION:Intermediate EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Recommendations: SDL personnel should double check all computers before each job to make sure automatic updates are turned off. Innovations and/or cost savings: N/A Leigh Ann Rasher 27-Nov-2014 What went as, or better than, planned: No issues with Insite or gas equipment occurred. Difficulties experienced: All computers randomly had to restart for updates while drilling. No data was lost during this period due to low ROP. SI26-NW2 Nikaitchuq Eni Petroleum North Slope Borough AK-XX-0901822325 Alaska Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 15 HOLE SECTION:Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Recommendations: It would be good to try to maintain the dust that is collected on the filters of the computers. It is recommended the filters are cleaned at the beginning of each new well. Innovations and/or cost savings: N/A Alexander Kalenuik 11-Dec-2014 What went as, or better than, planned: No major issues were encountered during production section. Gas equipment and INSITE functioned properly. Difficulties experienced: The Aruba quit working and we lost connection for about 15 minutes. We were Tripping at the time. The Geo's and the Coman's computer have not had connection since December 8. GCI has been notified as it is an internet connection issue. SI26-NW2 Nikaitchuq Eni Petroleum North Slope Borough AK-XX-0901822325 Alaska Surface Data Logging After Action Review Surface Data Logging WELL NAME:SI26-NW2 LOCATION:Nikaitchuq OPERATOR:Eni Petroleum AREA:North Slope Borough MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:8-Nov-2014 SPERRY JOB:AK-XX-0901822325 TD:6-Dec-2014 Marker MD INC AZ TVD TVDSS Top Permafrost 100.0 100.0 100.0 100.0 -106.3 SV-4 766.0 8.6 286.0 765.0 -711.3 SV-3 1,131.0 22.8 290.6 1,114.5 -1060.8 SV-2 1,418.0 28.6 287.4 1,373.1 -1319.4 Permafrost Base 1,858.0 30.4 280.7 1,758.0 -1704.3 SV-1 2,056.0 36.4 281.1 1,921.8 -1867.4 UgnuTop (UG4)2,467.0 50.3 283.9 2,228.8 -2175.1 TD 16" Borehole 2,846.0 58.0 285.8 2,452.4 -2398.7 Fault 5,051.5 89.2 287.5 2,697.5 -2643.8 Lower Ugnu 13,388.0 67.1 292.7 3,209.0 -3155.3 Schrader Bluff 13,892.0 71.1 295.4 3,388.4 -3334.7 N Sequence Top 13,978.0 71.7 296.1 3,415.9 -3362.2 N Sand Top 14,172.0 74.1 297.1 3,472.0 -3418.8 N2 Top 14,283.0 75.4 298.5 3,502.0 -3448.3 N3 Top 14,303.0 75.8 298.7 3,507.2 -3453.5 N Sand Bottom 14,327.0 76.2 299.0 3,512.8 -3459.1 N Sequence Base 14,850.0 87.9 305.6 3,576.7 -3523 OA Top 15,682.0 85.6 312.1 3,622.4 -3568.7 TD 12 1/4" Borehole 15,750.0 86.5 312.3 3,627.6 -3573.9 OA -3 Top 15,775.0 87.1 312.4 3,628.5 -3574.8 OA-3 Top 16,732.0 92.3 304.2 3,645.8 -3592.1 OA-2 Top 16,817.0 92.2 301.5 3,642.5 -3588.8 OA-2 Top 18,251.0 87.5 308.0 3,681.0 -3527.3 OA Top 18,896.0 89.8 304.5 3,685.5 -3631.8 OA Top 19,137.0 85.6 305.6 3,686.8 -3633.1 Fault A 19,226.0 88.7 305.1 3,691.1 -3637.4 OA Bottom 19,944.0 97.7 312.1 3,618.6 -3564.9 OA-4 Top 19,944.0 97.6 312.1 3,612.1 -3558.4 OA-4 Top 19,981.0 97.8 312.4 3,614.4 -3560.7 OA-3 Top 20,122.0 90.9 310.9 3,603.4 -3549.7 OA-3 Top 20,294.0 87.1 310.3 3,608.2 -3554.5 OA-3 Top 21,486.0 90.4 312.0 3,620.3 -3566.6 OA-2 Top 21,764.0 90.4 314.3 3,618.0 -3564.3 OA-2 Top 22,690.0 87.9 313.3 3,634.3 -3580.5 OA-3 Top 22,861.0 86.5 313.2 3,643.1 -3589.4 OA-4 Top 23,365.0 87.7 314.2 3,653.4 -3599.6 OA-4 Top 23,592.0 92.2 312.1 3,654.5 -3600.8 Fault B 23,788.0 92.0 310.2 3,645.0 -3591.3 OA-2 Top 23,980.0 93.8 309.1 3,637.1 -3583.4 TD 8 3/4" Borehole 24,062.0 94.4 309.1 3,631.9 -3578.1 Formation Tops 12 1/4" Inermediate Borehole 8 3/4" Lateral Leg 16" Surface Borehole SI26-NW2 Eni Petroleum MI Swaco Doyon 15 AK-XX-0901822325 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++ 8-Nov 160 8.70 140 27 48 18/33/44 6.0 102/75/55/40/17/15 3/-2.0 0/98 0.00 0.10 9.6 25.0 .05/.20 1800 160 M/U BHA #2 9-Nov 1204 9.00 81 23 38 20/38/44 5.6 84/61/52/39/20/18 3/-2.8 0/97.25 0.15 0.20 9.5 23.0 .10/.45 2400 60 Drill 16" Surface Hole 10-Nov 2846 9.15 75 25 35 18/37/48 5.8 85/60/48/37/18/17 3/-3.0 0/97 0.10 0.20 9.8 23.0 .15/.55 2200 40 Drill 16" Surface Hole to TD 11-Nov 2846 9.30 66 26 31 13/31/46 5.8 83/57/45/33/14/13 3.0 0/97 0.10 0.15 9.0 23.0 .10/.38 2200 40 RIH w13 3/8" casing 12-Nov 2846 9.20 42 16 12 5/6/7 -44/28/24/17/6/5 -----8.5 ----Cement / R/U BOPs and test 13-Nov 2846 9.20 44 16 13 6/7/8 -45/29/24/18/7/6 -----9.2 ----M/U BHA #3 14-Nov 3522 9.25 49 10 28 11/13/17 5.4 48/38/33/26/12/10 1/-4.5 2.25/93.25 0.10 1.60 10.0 1.8 1.30/2.80 20500 120 Drill 12 1/4" Intermediate Hole 15-Nov 5987 9.25 50 12 29 10/14/17 5.8 53/41/34/28/12/10 1/-4.8 2.5/92.75 0.10 0.90 9.7 6.0 .45/1.80 19500 200 Drill 12 1/4" Intermediate Hole 16-Nov 6477 9.20 51 15 29 10/12/14 4.8 59/44/37/28/12/10 1/-5.0 3/92 0.10 1.00 9.7 9.0 .70/1.90 19000 120 Drill 12 1/4" Intermediate Hole 17-Nov 6526 9.20 51 15 25 10/11/12 4.6 55/40/33/26/12/9 1/-5.0 3/92 0.10 1.00 9.9 8.5 .75/2.25 17000 120 Circulate Hole 18-Nov 6526 9.30 48 12 27 9/11/13 5.0 51/39/34/26/12/10 -4.8 3/92 0.10 1.10 9.8 5.0 .80/2.20 19000 120 Remove DP from shed 19-Nov 6706 9.20 52 12 25 10/11/13 4.8 49/37/32/25/12/10 -5.0 3/92 0.10 1.00 9.8 5.0 .75/2.00 17500 160 Drill 12 1/4" Intermediate Hole 20-Nov 9103 9.30 52 12 28 10/12/15 4.9 52/40/34/28/12/10 1/-4.8 4/92 0.10 1.00 9.7 5.0 .75/2.00 18000 160 Drill 12 1/4" Intermediate Hole 21-Nov 11269 9.30 52 13 36 13/15/17 4.9 62/49/42/33/15/12 1/-5.0 3/92 0.10 1.00 9.6 8.0 .70/1.90 18000 160 Drill 12 1/4" Intermediate Hole 22-Nov 13600 9.40 52 17 36 14/16/17 5.1 70/53/45/35/15/13 1/-5.5 3/91 0.10 0.90 9.6 9.0 .60/1.90 17500 160 Drill 12 1/4" Intermediate Hole 23-Nov 15282 9.40 51 14 34 13/16/18 5.1 62/48/42/34/15/12 1/-5.5 4/91 0.10 0.70 9.5 11.0 .50/1.60 17000 160 Drill 12 1/4" Intermediate Hole 24-Nov 15750 9.50 50 14 29 12/15/17 5.9 57/43/37/29/13/11 1/-6.0 3/91 0.10 0.80 9.5 13.0 .60/2.00 15500 120 TD 12 1/4" Intermediate Hole 25-Nov 15750 9.40 46 13 21 11/12/15 6.0 47/34/29/24/12/10 1/-5.5 3/91 0.10 1.00 9.7 13.0 .70/2.10 16000 160 BROOH 26-Nov 15750 9.40 46 17 28 12/14/16 6.0 62/45/36/30/13/11 1/-6.0 3/91 0.10 0.80 9.6 14.0 .60/1.90 15000 160 BROOH 27-Nov 15750 9.40 47 16 28 12/15/17 6.0 60/44/35/29/14/10 1/-6.0 3/91 0.10 0.80 9.6 14.0 .60/1.90 15000 160 RIH w 9 5/8" casing 28-Nov 15750 9.4 46 14 17 7/10/2011 -45/31/26/19/8/6 ----------Fill 9 5/8" casing 29-Nov 15750 9.4 46 14 16 7/10/2011 -44/30/26/19/8/6 ----------R/U to test BOP 30-Nov 15750 9.4 46 14 16 7/10/2011 -44/30/26/19/8/6 ----------P/U BHA #5 1-Dec 15750 9.25 49 15 13 7/7/2008 4.4 43/28/23/17/7/6 -/2 10 66/34 2.7 3.51 540 6.59 -2.8/61.51 2.8 RIH w/ BHA #5 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 2-Dec 16222 9.25 50 14 20 8/8/8 4.4 8/9/8 -/2 10 65/35 2.8 3.64 620 29.94 -.2/61.62 2.8 Drilling 8 3/4" production 3-Dec 18833 9..2 47 15 17 8/8/9 4.5 20/9/8 -/2 9.85 67/33 2.8 3.64 630 29.25 -.5/60.3 2.8 Drilling 8 3/4" production 4-Dec 20713 9.25 45 13 18 7/7/8 4.6 19/8/7 -/1 7.47 68/32 2.4 3.12 800 26.98 -9.6/62.82 7.47 Drilling 8 3/4" production 5-Dec 23033 9.2 44 13 15 7/7/8 4.6 17/7/6 -/1 7.5 69/31 2.8 3.64 730 27.75 -12.6/59.9 7.5 Drilling 8 3/4" production 6-Dec 24062 9.4 44 13 16 7/7/8 4.6 23/42/29 -/1 8.32 69/31 2.5 3.25 670 25.59 -15.28/65.06 2.8 TD 8 3/4 Production 7-Dec 24062 9.4 44 12 17 7/7/7 -17/41/29 NA/-8.23 69/32 2.8 3.64 720 26.22 -14.81/64.65 2.8 BROOH 8-Dec 24062 9.45 45 13 15 7/7/7 -16/41/28 NA/-8.33 70/30 2.6 3.38 740 33.98 -14.59/65.84 2.8 BROOH 9-Dec 24062 9.45 47 13 17 6/7/7 -15/27/7 NA/-8.33 70/30 2.7 3.51 725 26.29 -14.59/65.84 2.8 RIH Hole Opener 10-Dec 24062 9.45 45 13 15 6/7/7 -15/41/6 NA/-8.33 70/31 2.6 3.38 720 26.29 -14.59/65.84 2.8 POH Hole Opener Casing Record WELL NAME:LOCATION:Nikaitchuq OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:8-Nov-2014 SPERRY JOB:TD:6-Dec-2014 Remarks 20" Conductor @ 160' MD, 160'TVD 13.375" Casing @ 2834' MD, 2445'TVD 9.625" Casing @ 15740' MD, 3627'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 2 100 1 Hughes MX-1 Mill Tooth 16.00 160 2846 2686 20.00 1.117 134.6 25 40 1850 800 1-1-WT-A-E-In-No-TD TD Surface Section 3 200 2 Hycalog SKHI716D-E10C PDC 12.25 2846 6527 3681 57.20 0.969 64.4 15 160 1800 900 8-2-RO-N-X-1-CT-PR POOH for ROP 4 300 3 HAL MM75D PDC 12.25 6527 15750 9223 74.80 0.969 123.3 15 160 3400 900 4-3-BT-A-X-IN-CT-TD TD Intermediate Section 5 400 4 Smith MDSi616 BPX PDC 8.75 15750 24062 8312 61.10 0.902 44.1 26 177 2040 761 1-1-WT-A-X-IN-NO-TD TD Production Section Alaska RIG:Doyon 15 SPUD:8-Nov-2014 WELL NAME:SI26-NW2 LOCATION:Nikaitchuq OPERATOR:Eni Petroleum AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901822325 TD:6-Dec-2014 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: (max) (current) 0 0 Cly 0 Set At Size Grade 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Rebecca Mulkey 0 0 Units* Casing Summary Lithology (%) 0 Oil/Water 0' Alkal 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth C-5n C-2 0 in 0Minimum Depth Time: 0 0' 0' 0' Max @ ft Current Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901671283 Skid Rig to SI26-NW2 PV 24 hr Max Weight 0 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 000 - Depth in / out Mud Type Lst Type Average 0Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air =10,000 Units Connection 0 Condition Bit # Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: SP21-NW1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 6-Nov-2014 12:00 AM Current Pump & Flow Data: Max 0 Lime (lb/bbl) Skid rig floor into drilling position. Rig up operations in preparation for pre-spud . No Gas was observed over the Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) 0 0 Cly 0 Set At Size Grade 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Rebecca Mulkey 0 0 Units* Casing Summary Lithology (%) 0 Oil/Water 0' Alkal 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth C-5n C-2 0 in 0Minimum Depth Time: 0 0' 0' 0' Max @ ft Current Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901671283 Picking up 5" DP PV 24 hr Max Weight 0 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 000 - Depth in / out Mud Type Lst Type Average 0Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air =10,000 Units Connection 0 derrick. No Gas was observed over the past 24hr. spool. Load 5" DP in pipe shed. Install mouse hole & equip. PJSM. Pick up 110 jts 5" DP via mouse hole from pipe shed & rack in Condition Bit # Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: SP21-NW1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 7-Nov-2014 12:00 AM Current Pump & Flow Data: Max 0 Lime (lb/bbl) Continued rig up operations for pre-spud acceptance. Nipple up starter head, surface stack & install two diverter Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) 0 0 Cly 0 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Kori Jo Plowman 0 0 551 130 Units* Casing Summary Lithology (%) 0 Oil/Water 167' Alkal 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 0/98 140 C-5n C-2 0 in 0Minimum Depth Time: 0 160' 167' 7' Max @ ft Current Date: Avg to 160' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 27 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901671283 $2,810.00 Drilling ahead PV 24 hr Max Weight 0 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 0.10 000 Spud Mud 6.0 160'48 Depth in / out Mud Type Lst Type Average 0Background (max) Trip 9.46 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) WOB Weld 100% Gas In Air =10,000 Units Connection 0 surface equip. Clean out conductor to 160' and M/U BHA #2. No Gas was observed over the past 24hr. 160' Condition Bit # 2.00 8.85 8.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 8-Nov-2014 12:00 AM Current Pump & Flow Data: 778 Max 0 Chlorides (lb/bbl) 1800.00 Build total of 161 stds 5" DP via mouse hole & rack in derrick. L/D mouse hole. Dummy run 13-3/8" hanger. Cut & Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Drill to 397'. POH 3 stds HWDP. M/U stb, DC & 1 std HW & jars. RIH to 397'. Drill from 624' MD to 1373' MD Density (ppg) out (sec/qt) Viscosity Solids % Chlorides (lb/bbl) 2400 0 9-Nov-2014 12:00 AM Current Pump & Flow Data: 143 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition Bit # 2.75 9.00 9.00 Size 160' 100% Gas In Air =10,000 Units Connection 0 Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) WOB Weld 9.86 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 12 Background (max) Trip Average Mud Type Lst Type Spud Mud 5.6 160'68 Depth in / out YP (lb/100ft 2) 5.60 000 00 Intermediate Cement Cht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901671283 Drilling ahead PV Footage J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 81 Gas Summary 0 0 0 (current) Avg to 167' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 167' 1440' 1273' Max @ ft Current Date: Time: 10 in 0 167'Minimum Depth C-5n 1325' C-2 29 SPP (psi) Gallons/stroke TFA Bit Type Depth 0/97.25 68 Oil/Water 1440' Alkal 0 0 0 Siltst 1146 653 Units* Casing Summary Lithology (%) 01035 0 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Kori Jo Plowman Set At Size 178.9 X-65 Grade 20.00'' (max) (current) 0 0 Cly 2987 . . * 24 hr Recap: (max) (current) 0 0 Cly 104185 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Kori Jo Plowman 14054 1098 849 185 Units* Casing Summary Lithology (%) 0 Oil/Water 2846' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 0/97 75 C-5n 2059' 0.0 C-2 1037 in 10 1506'Minimum Depth Time: 139 1440' 2846' 1406' Max @ ft Current 2135'214.0 Date: Avg to 1440' Yesterday's Depth: Current Depth: 24 Hour Progress: 325.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 25 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 BROOH PV 24 hr Max Weight 0 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.50 000 Spud Mud 5.8 160'35 Depth in / out Mud Type Lst Type Average 34 Background (max) Trip 9.52 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 160' WOB Weld 100% Gas In Air =10,000 Units Connection 0 bbls 160' Condition Bit # #1 3.00 16" 9.15 Hughes MX-1 9.15 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 10-Nov-2014 12:00 AM Current Pump & Flow Data: 1496 Max 0 Chlorides (lb/bbl) 2200 Drill f/1440' MD to TD at 2846' MD/ 2452' TVD. Max gas: 172 & 75 units. Shoot MWD surveys. Monitor well. CBU Density (ppg) out (sec/qt) Viscosity Solids % . . * 24 hr Recap: BROOH f/2371' to 691' L/D BHA #2. Clear rig floor. R/U Volant & 13-3/8" csg equip. Run 13-3/8" surface csg to 2593'. Density (ppg) out (sec/qt) Viscosity Solids % Chlorides (lb/bbl) 2200 0 11-Nov-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # #1 3.00 16" Hughes MX-1 9.30 Size 160' 100% Gas In Air =10,000 Units Connection 0 Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 25 160' 2846' WOB Weld 9.52 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 25 Background (max) Trip Average Mud Type Lst Type 40 Spud Mud 5.8 160'31 Depth in / out YP (lb/100ft 2) 9.00 000 00 Intermediate Cement Cht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 RIH w/ Casing PV 2686' Footage 20.00 J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 26 Gas Summary 0 0 0 (current) Avg to 2846' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2846' 2846' 0' Max @ ft Current Date: Time: 40 in 9Minimum Depth C-5n C-2 803 SPP (psi) Gallons/stroke TFA Bit Type Depth 0/97 66 Oil/Water 2846' Alkal 1.117 0 0 0 Siltst Units* Casing Summary Lithology (%) 04056 998 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Kori Jo Plowman Set At Size 178.9 X-65 Grade 20.00'' (max) (current) 0 0 Cly 80524 . . * 24 hr Recap: (max) (current) 0 0 Cly 0 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Kori Jo Plowman 0 0 Units* Casing Summary Lithology (%) 0 Oil/Water 2846' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 42 C-5n C-2 0 in 0Minimum Depth Time: 0 2846' 2846' 0' Max @ ft Current Date: Avg to 2846' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 16 2686' Footage 20.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Test BOPs PV 24 hr Max Weight 0 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 8.50 000 40 Spud Mud 160'12 Depth in / out Mud Type Lst Type Average 0Background (max) Trip 9.52 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 25 160' 2846' WOB Weld 100% Gas In Air =10,000 Units Connection 0 over the past 24 hrs. Total daily loss was 0 bbls. w/402 bbls mud. 96 bbls cmt at surface. R/D Volant equip. Flush stack. N/D stack. N/U BOPE's. R/U test equip. No gas observed 160' Condition 1-1-WT-A-E-In-No-TD Bit # #1 16" Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 12-Nov-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides (lb/bbl) Run 13-3/8" csg f/2593' to 2834'. M/U landing jt & hanger. cmt job. Circ hole. Lower pit vol. Pump 100 bbls 10.1 ppg Density (ppg) out (sec/qt) Viscosity Solids % . . * 24 hr Recap: C/O saver sub on top drive. Fill BOPE & choke. Replace ring on choke manifold. Test BOPE's. R/D test equip. Density (ppg) out (sec/qt) Viscosity Solids % Chlorides (lb/bbl) 0 13-Nov-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # #1 16" Hughes MX-1 9.20 Size #2 for casing test. No gas was observed over the past 24 hrs. Total daily loss was 0 bbls. Shallow test MWD. OK.RIH to 2591'. Wash down & tag cmt at 2744'. Circulate hole 3500 strokes at 720 gpm & 1000 psi & 20 rpm 160' 100% Gas In Air =10,000 Units Connection 0 Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 25 160' 2846' WOB Weld 9.52 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 0Background (max) Trip Average Mud Type Lst Type 40 Hycalog PDC Spud Mud 2846' 160'13 Depth in / out YP (lb/100ft 2) 9.20 000 00 Intermediate Cement Cht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Testing Casing Pressure PV 2686' 12.25" 0.969 Footage 20.00 J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 16 Gas Summary 0 0 0 (current) Avg to 2846' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2846' 2846' 0' Max @ ft Current Date: Time: 0 in 0Minimum Depth C-5n C-2 0 SPP (psi) Gallons/stroke TFA Bit Type Depth 44 Oil/Water 2846' Alkal 1.117 0 0 0 Siltst Units* Casing Summary Lithology (%) 00 0 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Kori Jo Plowman Set At Size 178.9 X-65 Grade 20.00'' (max) (current) 0 0 Cly 0 . . * 24 hr Recap: (max) (current) BTC 0 0 Cly 10845 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Douglas Acker Maximum Report By: Logging Engineers: Douglas Acker/Kori Jo Plowman 3389 402 13 3/8" 917 185 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 3935' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 2.25/92.25 49 C-5n 3861' 224.0 C-2 107 in 4 3039'Minimum Depth Time: 3390 2846' 3935' 1089' Max @ ft Current 3154'240.0 Date: Avg to 2846' Yesterday's Depth: Current Depth: 24 Hour Progress: 452.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 10 2686' 12.25" 0.969 Footage 20.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12 1/4" Intermediate PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 1.60 000 40 Hycalog PDC Spud Mud 5.4 2846' 160'28 Depth in / out Mud Type Lst Type Average 27 Background (max) Trip 9.81 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 25 160' 2846' WOB Weld 100% Gas In Air =10,000 Units Connection 0 #2 was 107 units @ 3861' with a back ground of 27 units. Total daily loss was 0 bbls. 2834' 160' Condition 1-1-WT-A-E-In-No-TD Bit # #1 4.50 16" 9.35 Hughes MX-1 9.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 14-Nov-2014 12:00 AM Current Pump & Flow Data: 1399 Max 0 Chlorides (lb/bbl) 20500 R/U & test 13-3/8" csg to 2500 psi 30 min at 2680'. R/D equip. RIH tag float at 2747'. Drill cmt & new hole to 2866' . Density (ppg) out (sec/qt) Viscosity Solids % . . * 24 hr Recap:Drill ahead f/ 3935' MD to 6020' MD. Max gas observed the past 24 hrs was 131u. Samples have consisted w/ sst w/ Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 19500 0 15-Nov-2014 12:00 AM Current Pump & Flow Data: 1463 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # #1 4.75 16" 9.25 Hughes MX-1 9.25 Size #2 2834' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 25160' 2846' WOB Weld 9.65 Avg Min Comments Surface RPM ECD (ppg) ml/30min 11Background (max)Trip Average Mud Type Lst 60 Type 40 Hycalog PDC LSND 5.8 2846' 5987'29 Depth in / out YP (lb/100ft2) 9.70 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12 1/4" Intermediate PV 2686' 12.25"0.969 Footage 20.00 J.Keener/G. Maugeri ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 0 (current) Avg to3935' Yesterday's Depth: Current Depth: 24 Hour Progress: 465.2 Flow In (gpm) Flow In (spm) 3935' 6020' 2085' Max @ ft Current 5037'233.9 Date: Time: intervals of sltst. No losses reported. 36 in 3 3935'Minimum Depth C-5n 6015' 20.2 C-2 131 SPP (psi) Gallons/stroke TFABit Type Depth 6.050 L-80 MBT 6020' pH 1.117 0 0 0 Siltst 13 3/8" 880 164 Units* Casing Summary Lithology (%) 0 40 4354 20 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 19588 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 5581 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman 819 8 13 3/8" 879 177 Units* Casing Summary Lithology (%) 0 L-80 MBT 6492' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 9.051 C-5n 6073' 0.0 C-2 38 in 3 6465'Minimum Depth Time: Daily losses reported was 7 bbls. 13 6020' 6492' 472' Max @ ft Current 6329'13.5 Date: Avg to6020' Yesterday's Depth: Current Depth: 24 Hour Progress: 610.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/G. Maugeri ShClyst TuffGvlCoal cP 15 2686' 12.25"0.969 Footage 20.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12 1/4" Intermediate PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 40 Hycalog PDC LSND 4.8 2846' 6477'29 Depth in / out Mud Type Lst 100 Type Average 3Background (max) Trip 9.49 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 25160' 2846' WOB Weld 100% Gas In Air=10,000 UnitsConnection 0 #2 2834' 160' Condition 1-1-WT-A-E-In-No-TD Bit # #1 5.00 16"Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 16-Nov-2014 12:00 AM Current Pump & Flow Data: 1772 Max 0 Chlorides (lb/bbl) 19000 Drill ahead f/ 6020' MD to 6492' MD. Max gas observed was 38u @ 6073' MD. Samples consisted mainly of sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill f/ 6492' MD to 6527' MD. Decision made to POOH due to low ROP. POOH to 6045' MD. Pump 25 bbl dry job. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 17000 0 17-Nov-2014 12:00 AM Current Pump & Flow Data: 151 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # #1 5.00 16"Hughes MX-1 9.20 Size #2 Max gas observed the past 24 hours was 11u @ 6523' MD & 15u while TOOH. Samples consisted of 100% sst w/ abd chert. 2834' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 25160' 2846' WOB Weld 9.75 Avg Min Comments Surface RPM ECD (ppg) ml/30min 3Background (max) Trip Average 15 Mud Type Lst 100 Type 40 Hycalog PDC LSND 4.6 2846' 6526'25 Depth in / out YP (lb/100ft2) 9.90 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 POOH PV 2686' 12.25"0.969 Footage 20.00 J.Keener/R. Wimmer ShClyst TuffGvlCoal cP 15 Gas Summary 0 0 0 (current) Avg to6492' Yesterday's Depth: Current Depth: 24 Hour Progress: 39.4 Flow In (gpm) Flow In (spm) 6492' 6527' 35' Max @ ft Current 6507'0.4 Date: Time: POOH to 5484' MD. BROOH to 3700' MD. RIH to 3618' MD & circ, 243 bbls lost in 1.5 hrs. Total daily losses was 379 bbls. 4 in 3 6492'Minimum Depth C-5n 6523' C-2 11 SPP (psi) Gallons/stroke TFABit Type Depth 8.551 L-80 MBT 6527' pH 1.117 0 0 0 Siltst 13 3/8" 31 154 Units* Casing Summary Lithology (%) 0241 9 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 586 . . * 24 hr Recap:RIH to 4549' MD & circ. Spot 50 bbl LCM pill. Monitor well, fill every 15 min. Circ B/U & BROOH per K&M rep. POOH Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 19000 0 18-Nov-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 8-2-RO-N-X-1-CT-PR Bit # #2 4.75 12.25"Hycalog PDC 9.30 Size #3 2834' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP Motor 1.83, GyroPulse, TeleScope, Arc API FL Chromatograph (ppm) 152846' 6527' WOB Weld Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average 4 Mud Type Lst Type 160 HAL PDC LSND 5.0 6527' 6526'27 Depth in / out YP (lb/100ft2) 9.80 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Remove DP from shed PV 3681' 12.25"0.969 Footage 57.20 M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 0 (current) Avg to6527' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 6527' 6527' 0' Max @ ft Current Date: Time: to 1564' MD. L/D worn DP to 350' & L/D BHA. Total daily loss was 1093 bbls. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 5.048 L-80 MBT 6527' pH 0.969 0 0 0 Siltst 13 3/8" Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap:Load 5" DP in shed. M/U BHA #4. RIH to 1560' MD & SHT MWD tools. RIH & L/D washed out DP. Ream in hole Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 17500 0 19-Nov-2014 12:00 AM Current Pump & Flow Data: 1927 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.02 DOYON15 Report For: Condition 8-2-RO-N-X-1-CT-PR Bit # #2 5.00 12.25"Hycalog PDC 9.20 Size #3 Little to no metal shavings seen in samples. Total of 51 bbls loss. the past 24 hrs was 37u @ 6684' MD & 25u while TIH. Samples have consisted of mainly sst w/ f-crs gr chrt & up to 10% slt. 2834' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 152846' 6527' WOB Weld 9.88 Avg Min Comments Surface RPM ECD (ppg) ml/30min 5Background (max) Trip Average 25 Mud Type Lst 100 Type 160 HAL PDC LSND 4.8 6527' 6706'25 Depth in / out YP (lb/100ft2) 9.80 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12.25" Section PV 3681' 12.25"0.969 Footage 57.20 M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 0 (current) Avg to6527' Yesterday's Depth: Current Depth: 24 Hour Progress: 460.1 Flow In (gpm) Flow In (spm) 6527' 7063' 536' Max @ ft Current 6607'84.2 Date: Time: f/ 5018' MD to 6527' MD. Recip f/ 6527' MD to 5018' MD x4 to clean hole. Drill ahead f/ 6527' MD to 7063' MD. Max gas observed 14 in 2 6527'Minimum Depth C-5n 6684' 176.1 C-2 37 SPP (psi) Gallons/stroke TFABit Type Depth 5.052 L-80 MBT 7063' pH 0.969 0 0 0 Siltst 13 3/8" 894 180 Units* Casing Summary Lithology (%) 01350 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 5390 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 4810 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman 50 1455 9 13 3/8" 894 180 Units* Casing Summary Lithology (%) 0 L-80 MBT 9278' pH 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.052 C-5n 7534' 50.9 C-2 32 in 5 7108'Minimum Depth Time: observed was 32u @ 7534' MD. Samples have consisted of mainly sst w/ intervals of 10-50% sltst. Total of 182 bbl loss. 13 7063' 9278' 2215' Max @ ft Current 7633'85.8 Date: Avg to7063' Yesterday's Depth: Current Depth: 24 Hour Progress: 679.5 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 12 3681' 12.25"0.969 Footage 57.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12.25" Section PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 160 HAL PDC LSND 4.9 6527' 9103'28 Depth in / out Mud Type Lst 50 Type Average 7Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 152846' 6527' WOB Weld 100% Gas In Air=10,000 UnitsConnection 0 #3 2834' 160' Condition 8-2-RO-N-X-1-CT-PR Bit # #2 4.75 12.25"Hycalog PDC 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 15 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Nov-2014 12:00 AM Current Pump & Flow Data: 2189 Max 0 Chlorides (lb/bbl) 18000 Drill ahead f/ 7063' MD to 8376' MD. Circ & wait on weather (phase III). Drill ahead f/ 8376' MD to 9278' MD. Max gas Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 2757 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman 30 1015 0 13 3/8" 899 181 Units* Casing Summary Lithology (%) 0 L-80 MBT 11520' pH 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 8.052 C-5n 11418' 111.5 C-2 21 in 3 9278'Minimum Depth Time: sst w/ intervals of 10%-70% sltst & 10%-20% sh. Total of 119 bbls loss. 12 9278' 11520' 2242' Max @ ft Current 10819'187.0 Date: Avg to9278' Yesterday's Depth: Current Depth: 24 Hour Progress: 392.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 13 3681' 12.25"0.969 Footage 57.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12.25" Section PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 000 160 HAL PDC LSND 4.9 6527' 11269'36 Depth in / out Mud Type Lst 70 Type Average 5Background (max) Trip 10.3610.39 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 152846' 6527' WOB Weld 100% Gas In Air=10,000 UnitsConnection 0 #3 2834' 160' Condition 8-2-RO-N-X-1-CT-PR Bit # #2 5.00 12.25"Hycalog PDC 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.46 DOYON15 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 21-Nov-2014 12:00 AM Current Pump & Flow Data: 2685 Max 0 Chlorides (lb/bbl) 18000 Drill ahead f/ 9278' MD to 11520' MD. Max gas observed was 21u @ 11418' MD. Samples have consisted of Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead f/ 11520' MD to 13788' MD. Max gas observed was 54u @ 13761' MD. Samples have consisted of Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 17500 0 22-Nov-2014 12:00 AM Current Pump & Flow Data: 2810 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.72 DOYON15 Report For: Condition 8-2-RO-N-X-1-CT-PR Bit # #2 5.50 12.25"Hycalog PDC 9.40 Size #3 2834' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 152846' 6527' WOB Weld 10.5810.65 Avg Min Comments Surface RPM ECD (ppg) ml/30min 13Background (max) Trip Average Mud Type Lst 70 Type 160 HAL PDC LSND 5.1 6527' 11269'36 Depth in / out YP (lb/100ft2) 9.60 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12.25" Section PV 3681' 12.25"0.969 Footage 57.20 M. Ross/O. Amend ShClyst TuffGvlCoal cP 17 Gas Summary 0 0 0 (current) Avg to11520' Yesterday's Depth: Current Depth: 24 Hour Progress: 390.0 Flow In (gpm) Flow In (spm) 11520' 13788' 2268' Max @ ft Current 11846'216.0 Date: Time: mainly sst with intervals of up to 70% sltst. Total of 160 bbls loss. 16 in 5 11520'Minimum Depth C-5n 13761' 35.8 C-2 54 SPP (psi) Gallons/stroke TFABit Type Depth 9.052 L-80 MBT 13788' pH 0.969 0 0 0 Siltst 13 3/8" 850 171 Units* Casing Summary Lithology (%) 0 30 1659 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Leigh Ann Rasher/Kori Jo Plowman Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 7880 . . * 24 hr Recap: (max) (current) BTC 1283 0 Cly 80152 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 22 Kori Jo Plowman Maximum Report By: Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman 70 12715 0 13 3/8" 874 176 Units* Casing Summary Lithology (%) 177 L-80 MBT 15457' pH 0.969 0 258 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 11.0 51 C-5n 14219' 57.5 C-2 682 in 5 13701'Minimum Depth Time: 129 13788' 15457' 1669' Max @ ft Current 14262'119.4 Date: Avg to 13788' Yesterday's Depth: Current Depth: 24 Hour Progress: 304.7 Flow In (gpm) Flow In (spm) Gas Summary 0 110 130 (current) M. Ross/O. Amend Sh Clyst Tuff Gvl Coal cP 14 3681' 12.25" 0.969 Footage 57.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Drilling 12.25" Section PV 24 hr Max 68.0 Weight 280 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.50 129 210 214 160 HAL PDC LSND 5.1 6527' 15282'34 Depth in / out Mud Type Lst 30 Type Average 37 Background (max) Trip 10.58 10.65 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 15 2846' 6527' WOB Weld 100% Gas In Air =10,000 Units Connection 289 #3 2834' 160' Condition 8-2-RO-N-X-1-CT-PR Bit # #2 5.50 12.25" Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.72 DOYON15 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Nov-2014 12:00 AM Current Pump & Flow Data: 3370 Max 208 Chlorides (lb/bbl) 17000 Drill ahead from 13788' MD to 15457' MD. The max gas observed was 682 units @ 14219' MD. Mud loss of 64bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) BTC 3040 0 Cly 107076 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 1168 Kori Jo Plowman Maximum Report By: Logging Engineers: Leigh Ann Rasher/Kori Jo Plowman 21954 27 13 3/8" 899 181 Units* Casing Summary Lithology (%) 277 L-80 MBT 15750' pH 0.969 0 2183 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 13.0 50 C-5n 15690' 0.0 C-2 1651 in 10 15618'Minimum Depth Time: 237 15457' 15750' 293' Max @ ft Current 15700'114.9 Date: Avg to 15457' Yesterday's Depth: Current Depth: 24 Hour Progress: 371.9 Flow In (gpm) Flow In (spm) Gas Summary 0 3054 1842 (current) M. Ross/O. Amend Sh Clyst Tuff Gvl Coal cP 14 3681' 12.25" 0.969 Footage 57.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 BROOH PV 24 hr Max 68.0 Weight 479 Hours C-3 00 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.50 229 330 374 160 HAL PDC LSND 5.9 6527' 15750'29 Depth in / out Mud Type Lst Type Average 13 Background (max) Trip 10.58 10.65 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 15 2846' 6527' WOB Weld 100% Gas In Air =10,000 Units Connection 3691 #3 2834' 160' Condition 8-2-RO-N-X-1-CT-PR Bit # #2 6.00 12.25" Hycalog PDC 9.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.72 DOYON15 Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 24-Nov-2014 12:00 AM Current Pump & Flow Data: 2919 Max 340 Chlorides (lb/bbl) 15500 Drilled ahead from 15457'MD to 15750'MD, TD for intermediate section. The max gas observed was 1651 units Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Continue BROOH per K&M to around 4900'MD as of midnight. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 16000 0 25-Nov-2014 12:00 AM Current Pump & Flow Data: 1923 Max Conductor ROP ROP (ft/hr) 4.61 @ Mud Data Depth Morning Report Report # 20 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 93% Rig Activity: 9.95 DOYON15 Report For: Condition 8-2-RO-N-X-1-CT-PR Bit # #2 5.50 12.25" Hycalog PDC 9.40 Size #3 2834' 160' 100% Gas In Air =10,000 Units Connection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 15 2846' 6527' WOB Weld 9.92 9.93 Avg Min Comments Surface RPM ECD (ppg) ml/30min 9Background (max) Trip Average Mud Type Lst Type 160 HAL PDC LSND 6.0 6527' 15750'21 Depth in / out YP (lb/100ft 2) 9.70 000 00 Intermediate Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 BROOH PV 3681' 12.25" 0.969 Footage 57.20 M. Ross/O. Amend Sh Clyst Tuff Gvl Coal cP 13 Gas Summary 0 0 0 (current) Avg to 15750' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15750' 15750' 0' Max @ ft Current Date: Time: 10 in 5 15750'Minimum Depth C-5n 15750' C-2 21 SPP (psi) Gallons/stroke TFA Bit Type Depth 13.0 46 L-80 MBT 15750' pH 0.969 0 0 0 Siltst 13 3/8" 894 180 Units* Casing Summary Lithology (%) 010 5 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Leigh Ann Rasher/Rebecca Mulkey Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 0 0 Cly 21 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 127 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey 16 5 13 3/8" 898 180 Units* Casing Summary Lithology (%) 0 L-80 MBT 15750' pH 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 14.046 C-5n 15750' C-2 130 in 5 15750'Minimum Depth Time: 16 15750' 15750' 0' Max @ ft Current Date: Avg to15750' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) M. Ross/O. Amend ShClyst TuffGvlCoal cP 17 3681' 12.25"0.969 Footage 57.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 BROOH PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 000 160 HAL PDC LSND 5.7 6527' 15750'28 Depth in / out Mud Type Lst Type Average 3Background (max)Trip 9.769.78 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 152846' 6527' WOB Weld 100% Gas In Air=10,000 UnitsConnection 0 #3 2834' 160' Condition 8-2-RO-N-X-1-CT-PR Bit # #2 6.00 12.25"Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 93% Rig Activity: 9.89 DOYON15 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.61 @ Mud Data Depth 26-Nov-2014 12:00 AM Current Pump & Flow Data: 1424 Max 0 Chlorides (lb/bbl) 15000 Continue BROOH per K&M to around 1400'MD as of midnight. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:finished BROOH and begain running in casing. About 250 joints in the hole as of midnight. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 15000 0 27-Nov-2014 12:00 AM Current Pump & Flow Data: 18 Max Conductor ROP ROP (ft/hr) 0.00 @ Mud Data Depth Morning Report Report # 22 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 93% Rig Activity: DOYON15 Report For: Condition 8-2-RO-N-X-1-CT-PR Bit # #2 6.00 12.25"Hycalog PDC 9.40 Size #3 2834' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 152846' 6527' WOB Weld Avg Min Comments Surface RPM ECD (ppg) ml/30min 3Background (max) Trip Average 1651 Mud Type Lst Type 160 HAL PDC LSND 5.7 6527' 15750'28 Depth in / out YP (lb/100ft2) 9.60 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 TIH Casing PV 3681' 12.25"0.969 Footage 57.20 M. Ross/O. Amend ShClyst TuffGvlCoal cP 16 Gas Summary 0 0 0 (current) Avg to15750' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15750' 15750' 0' Max @ ft Current Date: Time: 6 in 5 15750'Minimum Depth C-5n 15750' C-2 8 SPP (psi) Gallons/stroke TFABit Type Depth 14.047 L-80 MBT 15750' pH 0.969 0 0 0 Siltst 13 3/8" 0 0 Units* Casing Summary Lithology (%) 06 5 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 8 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 8 Set AtSize 178.9 X-65 Grade L-8015740' 20.00'' 9 5/8" 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey 6 1 13 3/8" 88 20 Units* Casing Summary Lithology (%) 0 L-80 MBT 15750' pH 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 46 C-5n 15750' C-2 8 in 1 15750'Minimum Depth Time: 6 15750' 15750' 0' Max @ ft Current Date: Avg to15750' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) M. Ross/O. Amend ShClyst TuffGvlCoal cP 14 3681' 12.25"0.969 Footage 57.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Filling pipe PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 000 160 HAL PDC LSND 6527' 15750'17 Depth in / out Mud Type Lst Hydrill 563 Type Average 3Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 152846' 6527' WOB Weld 100% Gas In Air=10,000 UnitsConnection 0 #3 2834' 160' Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 28-Nov-2014 12:00 AM Current Pump & Flow Data: 416 Max 0 Chlorides (lb/bbl) Landed 9 5/8" casing at 15740'MD. Filling pipe in preparation of cement job. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:pumped cement job. Curently nippling up and waiting on cement. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (lb/bbl) 0 29-Nov-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"Hycalog PDC 9.40 Size #3 2834' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 152846' 6527' WOB Weld Avg Min Comments Surface RPM ECD (ppg) ml/30min 3Background (max) Trip Average Mud Type Lst Hydrill 563 Type 160 HAL PDC LSND 6527' 15750'16 Depth in / out YP (lb/100ft2) 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 Waiting on cement PV 3681' 12.25"0.969 Footage 57.20 M. Ross/O. Amend ShClyst TuffGvlCoal cP 14 40.0 Gas Summary 0 0 0 (current) Avg to15750' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15750' 15750' 0' Max @ ft Current Date: Time: 5 in 1 15750'Minimum Depth C-5n 15750' C-2 11 SPP (psi) Gallons/stroke TFABit Type Depth 46 L-80 MBT 15750' pH 0.969 0 0 0 Siltst 13 3/8" Units* Casing Summary Lithology (%) 05 1 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey Set AtSize 178.9 X-65 Grade L-8015740' 20.00'' 9 5/8" (max)(current) BTC 0 0 Cly 11 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8015740' 20.00'' 9 5/8" 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey 0 0 13 3/8" Units* Casing Summary Lithology (%) 0 L-80 MBT 15750' pH 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 46 C-5n 15750' C-2 0 in 0 15750'Minimum Depth Time: 0 15750' 15750' 0' Max @ ft Current Date: Avg to15750' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) M. Ross/O. Amend ShClyst TuffGvlCoal cP 14 3681' 12.25"0.969 Footage 57.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901822325 picking up BHA PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 000 160 HAL PDC LSND 6527' 15750'16 Depth in / out Mud Type Lst Hydrill 563 Type Average 0Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 152846' 6527' WOB Weld 100% Gas In Air=10,000 UnitsConnection 0 #3 2834' 160' Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: SI26-NW2 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 30-Nov-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides (lb/bbl) Casing test and R/U for BOP test. Curently picking up BHA. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 15 160 #4 Smith PDC 8.75 0.902 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 160 15750' 9223' 907-685-0772Unit Phone: 0 Rebecca Mulkey Set AtSize 178.9 X-65 Grade 0 C-2 Gas Summary 0 0 0 0 0 0 0 0 0 15750'Minimum Depth 13 3/8" Maximum in 0 15750' 0 0 0 0 Alkal Coal Gallons/stroke L-80 0 15750 15750' 0' Lime TuffGvl C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Date: Time: API FL Depth Avg to15750' Current (current) Units* ClystSsChtSilt Casing Summary Lithology (%) 0.969 1549 3681' 12.25"0.969 Footage 40.0 TIH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Hours 0 Intermediate Cement C-1 C-5i ShSiltst Chromatograph (ppm) 0 0 00 C-4i C-4n 0 Lst Hydrill 563 (lb/100ft2) 9.25 Type 13 HAL PDC Mud (lb/bbl)ml/30min 3.512.70 15 C-3 Average Trip (max) 0 Comments Surface 0Background 2834' 100% Gas In Air=10,000 UnitsConnection Bit # #2 12.25"2846' #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR MWD Summary 96% %Mud Type LSND NA Ratio Mud Data Depth 1.9 4.23 @ Current Pump & Flow Data: DOYON15 Report For: 15750'6.6 Cor Solids Avg Min YP MaxECD (ppg) Tools Xceed675,TeleScope 675, ARC 6, ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 26 Customer: Well: Area: Location: Rig: SI26-NW2 1-Dec-2014 12:00 AM AK-AM-0901822325 18 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Picked up BHA. Tripping in the hole with BHA#5. Currently at 13515' in the hole. Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: 15 160 4-3-BT-A-X-IN-CT-TD #4 Smith PDC 8.75 0.902 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 160 15750' 9223' 907-685-0772Unit Phone: 0 Rebecca Mulkey Set AtSize 178.9 X-65 Grade tr 2 C-2 Gas Summary 804 0 0 0 0 744 0 0 236 15820'Minimum Depth 13 3/8" Maximum in 2 16453' 0 0 0 16,453' 258 616 Alkal Coal Gallons/stroke L-80 0 15750 16530' 780' Lime TuffGvl C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 124 SPP (psi) Max @ ft 16508' Date: Time: API FL Depth 16530' Avg to15750' Current 247.0341.0 (current) Units* ClystSsChtSilt Casing Summary Lithology (%) 0.969 1450 3681' 12.25"0.969 Footage 40.0 Drill 8 3/4" Production PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Hours 0 Intermediate Cement C-1 C-5i ShSiltst Chromatograph (ppm) 0 0 00 C-4i C-4n 0 Lst 100 Hydrill 563 (lb/100ft2) 9.25 Type 20 HAL PDC Mud (lb/bbl)ml/30min 3.642.80 15 C-3 Average Trip (max) 0 Comments Surface 406Background 2834' 100% Gas In Air=10,000 Units709Connection Bit # #2 12.25"2846' #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR MWD Summary 96% %Mud Type FazPro NA Ratio Mud Data Depth 1.9 4.23 @ Current Pump & Flow Data: DOYON15 Report For: 16222'6.5 11.13 11.13 Cor Solids 11.13 Avg Min YP MaxECD (ppg) Tools Xceed675,TeleScope 675, ARC 6, ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 436.0 Morning Report Report # 27 Customer: Well: Area: Location: Rig: SI26-NW2 2-Dec-2014 12:00 AM AK-AM-0901822325 3306 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Drill from 15,750' to 16,530', Sample Cuttings Consist of 100% sandstone with trace slitstone, Max Gas 804 units at Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap:Drill from 16,530' to 19,069', Sample Cuttings Consist of 100% sandstone with trace shale, Max Gas 1287 units at Density (ppg) out (sec/qt) Viscosity AK-AM-0901822325 3052 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Rig Activity: 489.4 Morning Report Report # 28 Customer: Well: Area: Location: Rig: SI26-NW2 ECD (ppg) Tools Xceed675,TeleScope 675, ARC 6, ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: DOYON15 Report For: 18833'6.6 11.13 11.13 Cor Solids 11.13 Mud Type FazPro N/A Ratio Mud Data Depth 2.0 YP 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"2846' #3 6527' 74.80 57.20 Size 2834' 100% Gas In Air=10,000 Units1197Connection Comments Surface 291Background Trip (max) 829Average Mud (lb/bbl)ml/30min 3.642.80 15 C-3 Lst 100 Hydrill 563 (lb/100ft2) 9.20 Type 17 HAL PDC 000 Chromatograph (ppm) 1560 936 C-4i C-4n Hours 4 Intermediate Cement C-1 C-5i ShSiltst Drill 8 3/4" Production PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Casing Summary Lithology (%) 0.969 1547 3681' 12.25"0.969 Footage 40.0 ClystSsChtSilt Avg to15750' Current 276.3147.0 MWD Summary Max @ ft 17345' Date: Time: API FL Current Pump & Flow Data: Avg Min Max C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 106 SPP (psi) 96% % 4.23 @ 16530 19069' 2539' Lime TuffGvl 3-Dec-2014 12:00 AM 5138 Alkal Coal Gallons/stroke L-80 17,966' 508 17966' 0 532 282 0Minimum Depth 13 3/8" Maximum in 3 (current) 0 72990 16859' Depth 16530' Units* 0 513 0 0 140823 03 C-2 Gas Summary 1287 907-685-0772Unit Phone: 146 Rebecca Mulkey Set AtSize 178.9 X-65 Grade Depth in / out L-8015740' Bit Type RPM 160 15750' 9223' Report By: 20.00'' 9 5/8" Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey (max)(current) BTC Cly 15 160 4-3-BT-A-X-IN-CT-TD #4 Smith PDC 8.75 0.902 15750' . . * 24 hr Recap: #4 Smith PDC 8.75 0.902 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 160 15750' 9223' 907-685-0772Unit Phone: 108 Leigh Ann Rasher Set AtSize 178.9 X-65 Grade 37 C-2 Gas Summary 1185 186 387 0 245 134476 0 0 40169 19220' Depth 21166' Units* Minimum Depth 13 3/8" Maximum in 6 (current) 20862' 3 394 226 0 Max gas observed the past 24 hours was 1185 units @ 20862' MD. Samples have consisted of mainly clean sst w/ intervals of 10% 333 525 Alkal Coal Gallons/stroke L-80 15 160 TuffGvl 4-Dec-2014 12:00 AM 4-3-BT-A-X-IN-CT-TD % 4.23 @ 19069 21166' 2097' Lime Yesterday's Depth: Current Depth: 24 Hour Progress: 124 SPP (psi) 96% 19677' Date: Time: API FL Current Pump & Flow Data: Avg Min Max Avg to19069 Current 224.9151.4 MWD Summary ClystSsChtSilt Casing Summary Lithology (%) 0.969 1345 3681' 12.25"0.969 Footage 40.0 Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Max @ ft Hours 4 Intermediate Cement C-1 C-5i ShSiltst Chromatograph (ppm) 1260 571 C-4i C-4n C-5n 61192124 Lst 100 Hydrill 563 (lb/100ft2) 9.25 Type 18 HAL PDC Mud (lb/bbl)ml/30min 3.122.40 15 C-3 Average Trip (max) 474 Comments Surface 83Background to 30% sltst. Total of 45 bbls lost downhole. 2834' 100% Gas In Air=10,000 UnitsConnection Bit # #2 12.25"2846' #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR N/A Ratio Mud Data Depth 68/32 YP 20713'7.5 Cor Solids Mud Type FazePro ECD (ppg) Tools Xceed675, TeleScope 675, ARC 675, Sonic ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Morning Report Report # 29 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 3547 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Rig Activity: 488.4 Drill ahead from 19069' MD 19400' MD. Notice slight breathing, monitor well. Cont to drill ahead to 21166' MD. Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap:Drill ahead from 21166" MD to 22102' MD. Monitor well for breathing. Cont to drill ahead to 23216' MD. Max gas Density (ppg) out (sec/qt) Viscosity 3622 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max 604.6 Morning Report Report # 30 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 Xceed675, TeleScope 675, ARC 675, Sonic ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 7.5 12.16 12.19 Cor Solids 12.17 Mud Type FazePro ECD (ppg) N/A Ratio Mud Data Depth 69/31 YP 23033' 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"2846' #3 6527' 74.80 57.20 Size downhole. 2834' 100% Gas In Air=10,000 UnitsConnection Comments Surface 40Background Trip (max) 719Average Mud (lb/bbl)ml/30min 3.642.80 15 C-3 Lst 80 Hydrill 563 (lb/100ft2) 9.20 Type 15 HAL PDC 61192124 Chromatograph (ppm) 1318 527 C-4i C-4n C-5n Hours 5 Intermediate Cement C-1 C-5i ShSiltst Drill 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Max @ ft Casing Summary Lithology (%) 0.969 1344 3681' 12.25"0.969 Footage 40.0 Ss Cht Silt 20 Avg to21166 Current 274.874.8 MWD Summary 22104' Date: Time: API FL Current Pump & Flow Data: Avg Min MaxTools 21166 23216' 2050' Lime Yesterday's Depth: Current Depth: 24 Hour Progress: 122 SPP (psi) 96% TuffGvl 5-Dec-2014 12:00 AM 4-3-BT-A-X-IN-CT-TD % 4.23 @ 516 Alkal Coal Gallons/stroke L-80 15 160 observed was 1353 units @ 22168' MD. Samples have consisted of mainly sst w/ 10%-30% intervals of sltst. Total of 92 bbls lost 551 22168' 5 357 204 0Minimum Depth 13 3/8" Maximum in 5 (current) 68948 22957' Depth 23216' Units* Clyst 186 354 3 245 153218 0126 C-2 Gas Summary 1353 0 907-685-0772Unit Phone: 96 Leigh Ann Rasher Set AtSize 178.9 X-65 Grade Depth in / out L-8015740' Bit Type RPM 160 15750' 9223' Report By: 20.00'' 9 5/8" Logging Engineers:Leigh Ann Rasher/Rebecca Mulkey (max)(current) BTC Cly #4 Smith PDC 8.75 0.902 15750' . . * 24 hr Recap:Drill ahead from 23216" MD to TD of 24062' MD a TVD of 3745'. Completed drill, TDed at 15:20. Max gas Density (ppg) out (sec/qt) Viscosity 3818 Xceed675, TeleScope 675, ARC 675, Sonic 8.3 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max 691.5 Current Morning Report Report # 31 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Mud Type 23216 API FL Min Max FazePro ECD (ppg) N/A Ratio Mud Data Depth 69/31 YP 24062' to 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"2846' #3 6527' 74.80 57.20 Size bbls lost downhole. Currently backreeming out of hole. 2834' 100% Gas In Air=10,000 UnitsConnection Comments Surface Background Trip (max) 217Average 35 Mud (lb/bbl)ml/30min 3.252.50 15 C-3 Lst 100 Hydrill 563 (lb/100ft2) 9.04 Type 16 HAL PDC 4610486 Siltst Chromatograph (ppm) 840 345 C-4i C-4n C-5n Oil / Water Max @ ft Hours 11 Intermediate Cement C-1 C-5i PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Casing Summary Lithology (%) 0.969 1344 3681' 12.25"0.969 Footage 40.0 Ss Cht Silt 0 Sh MWD Summary 23790' Date: Time: Current Pump & Flow Data: Avg BROOH 24 Hour Progress: 126 SPP (psi)38.40.0 6-Dec-2014 12:00 AM Tools 23216 24062' 846' Lime Yesterday's Depth: Current Depth: 4-3-BT-A-X-IN-CT-TD % 4.23 @ 96% TuffGvl Cor Solids 533 Alkal Coal Gallons/stroke L-80 15 160 observed was 754 units @ 24047' MD. Samples have consisted of predpminately of sst w/ 10%-30% intervals of sltst. Total of 85 236 24047' 12 313 209 5Minimum Depth 13 3/8" Maximum in 11 (current) 23561 23834' Depth 24062' Units* Clyst 90 291 7 93 90817 3256 C-2 Gas Summary 754 3 907-685-0772Unit Phone: 102 Paul Kalenuik Set AtSize 178.9 X-65 Grade Depth in / out L-8015740' Bit Type RPM 160 15750' 9223' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Rebecca Mulkey (max)(current) BTC Cly #4 Smith PDC 8.75 0.902 15750' . . * 24 hr Recap: #4 Smith PDC 8.75 0.902 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Rebecca Mulkey (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 160 15750' 9223' 907-685-0772Unit Phone: Paul Kalenuik Set AtSize 178.9 X-65 Grade C-2 Gas Summary Depth 24062' Units* Clyst Minimum Depth 13 3/8" Maximum in (current) Cont BROOH f/18,900' to 13,797' at 550 gpm, 3180 psi & 120 to 140 spm. Total FazePro loss: 341 bbls 552 Alkal Coal Gallons/stroke L-80 15 160 4.23 @ 96% TuffGvl Cor Solids 7-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) BROOH 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg Ss Cht Silt 0 Sh Casing Summary Lithology (%) 0.969 1244 3681' 12.25"0.969 Footage Hours Intermediate Cement C-1 C-5i C-4n C-5n 40.0 68.0 Weight Siltst Chromatograph (ppm) C-4i Lst 100 Hydrill 563 (lb/100ft2) 9.04 Type 17 HAL PDC Mud (lb/bbl)ml/30min 3.642.80 15 C-3 Average 145Trip (max) Comments Surface Background No issues to report. 2834' 100% Gas In Air=10,000 UnitsConnection Bit # #2 12.25"2846' #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR FazePro ECD (ppg) N/A Ratio Mud Data Depth 69/31 YP 24062' to Mud Type 24062 API FL Min Max Oil / Water PV cP Xceed675, TeleScope 675, ARC 675, Sonic ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Morning Report Report # 32 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM 3024 8.2 % Lime 4-3-BT-A-X-IN-CT-TD BROOH f/22,571' TO 19,800' at 530 gpm, 3600 psi & 140 spm. Ream & circ thru tight spots at 19,864' - 19,771'; Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: BROOH f/13,797 to 9,032. Con't to pull out of hole at 550 gpm, 2650 psi & 120 rpm. No loss while circ. Density (ppg) out (sec/qt) Viscosity 8.3 % Lime 4-3-BT-A-X-IN-CT-TD ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM Morning Report Report # 31 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Mud Type 24062 API FL Min Max Oil / Water PV cP Xceed675, TeleScope 675, ARC 675, Sonic FazePro ECD (ppg) N/A Ratio Mud Data Depth 70/30 YP 24062' to 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"2846' 1-1-WT-A-X-IN-NO-TD #3 6527' 74.80 57.20 Size 2834' 100% Gas In Air=10,000 UnitsConnection Comments Surface Background Trip (max) Average 5 Mud (lb/bbl)ml/30min 3.382.60 8312'17 15 C-3 Lst 100 Hydrill 563 (lb/100ft2) 9.45 Type 15 HAL PDC 68.0 Weight Siltst Chromatograph (ppm) C-4i Intermediate Cement C-1 C-5i C-4n C-5n 40.0 Casing Summary Lithology (%) 0.969 1345 3681' 12.25"0.969 Footage Hours Ss Cht Silt 0 Sh 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg 24 Hour Progress: SPP (psi) Clean Rig Floor 8-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 4.23 @ 96% TuffGvl Cor Solids Alkal Coal Gallons/stroke L-80 15 160 Slip & cut drill line. Service rig. Monitor well. Static. Daily FazePro loss: 40 bbls. Total FazePro loss: 381 bbls. Minimum Depth 13 3/8" Maximum in (current) Depth 24062' Units* Clyst C-2 Gas Summary 907-685-0772Unit Phone: Paul Kalenuik Set AtSize 178.9 X-65 Grade Depth in / out L-8015740' Bit Type RPM 24062' 177 160 15750' 9223' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Rebecca Mulkey (max)(current) BTC Cly #4 Smith PDC 8.75 0.902 61.50 15750' . . * 24 hr Recap: #4 Smith PDC 8.75 0.902 61.50 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Rebecca Mulkey (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 24062' 177 160 15750' 9223' 907-685-0772Unit Phone: Paul Kalenuik Set AtSize 178.9 X-65 Grade C-2 Gas Summary Depth Units* Clyst Minimum Depth 13 3/8" Maximum in (current) RIH f/11,548' to 19,011'. Start to ream at 2.7 bpm & 70 rpm to 22,283. No daily FazePro loss. Total FazePro loss: 381 bbls. 107 Alkal Coal Gallons/stroke L-80 15 160 4.23 @ 96% TuffGvl Cor Solids 9-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 24 SPP (psi) RIH Hole Opener 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg Ss Cht Silt 0 Sh Casing Summary Lithology (%) 0.969 1347 3681' 12.25"0.969 Footage Hours Intermediate Cement C-1 C-5i C-4n C-5n 40.0 68.0 Weight Siltst Chromatograph (ppm) C-4i Lst 100 Hydrill 563 (lb/100ft2) 9.45 Type 14 HAL PDC Mud (lb/bbl)ml/30min 3.512.70 8312'17 15 C-3 Average 3Trip (max) Comments Surface Background Continue to monitor flow, pit levels and gas. No issues to relate. 2834' 100% Gas In Air=10,000 UnitsConnection Bit # #2 12.25"2846' 1-1-WT-A-X-IN-NO-TD #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR FazePro ECD (ppg) N/A Ratio Mud Data Depth 70/30 YP 24062' to Mud Type API FL Min Max Oil / Water PV cP ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Morning Report Report # 34 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 ROP ROP (ft/hr) J. Keener/R.Wimmer 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM 275 8.3 % Lime 4-3-BT-A-X-IN-CT-TD Clean & clear rig floor. Service rig. M/U & RIH clean out BHA to 11,548'. Fill pipe every 2,000' Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: #4 Smith PDC 8.75 0.902 61.50 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Rebecca Mulkey (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 24062' 177 160 15750' 9223' 907-685-0772Unit Phone: Paul Kalenuik Set AtSize 178.9 X-65 Grade C-2 Gas Summary Depth Units* Clyst Minimum Depth 13 3/8" Maximum in (current) 420 gpm, 120 rpm & 2500 psi to 23,964'. Monitor well (Static) & service rig. Drop drift at 22,771'. POH per K&M to 20,603'. Alkal Coal Gallons/stroke L-80 15 160 4.23 @ 96% TuffGvl Cor Solids 10-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) POOH Hole Opener 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg Ss Cht Silt 0 Sh Casing Summary Lithology (%) 0.969 1345 3681' 12.25"0.969 Footage Hours Intermediate Cement C-1 C-5i C-4n C-5n 40.0 68.0 Weight Siltst Chromatograph (ppm) C-4i Lst 100 Hydrill 563 (lb/100ft2) 9.45 Type 15 HAL PDC Mud (lb/bbl)ml/30min 3.382.60 8312'17 15 C-3 Average 0Trip (max) Comments Surface Background 101 BBL loss. 2834' 100% Gas In Air=10,000 UnitsConnection Bit # #2 12.25"2846' 1-1-WT-A-X-IN-NO-TD #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR FazePro ECD (ppg) N/A Ratio Mud Data Depth 70/30 YP 24062' to Mud Type API FL Min Max Oil / Water PV cP ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Morning Report Report # 35 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 ROP ROP (ft/hr) J. Keener/R.Wimmer 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM 8.3 % Lime 4-3-BT-A-X-IN-CT-TD Wash & ream f/22,283' tag bottom at 24,062' at 100 gpm, 70 rpm & 475 psi. No loss while reaming. Circ & recip at Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Cont POH f/20,603' to 9,961'. Circ hole 3 to 5 bpm, 30 rpm. Circ loss: 10 bbls. PJSM. Displace f/FazePro to KCl/NaCl Density (ppg) out (sec/qt) Viscosity % Lime 4-3-BT-A-X-IN-CT-TD ROP ROP (ft/hr) J. Keener/R.Wimmer 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM Morning Report Report # 36 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Mud Type API FL Min Max Oil / Water PV cP FazePro ECD (ppg) N/A Ratio Mud Data Depth YP 24062' to 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Bit # #2 12.25"2846' 1-1-WT-A-X-IN-NO-TD #3 6527' 74.80 57.20 Size 2834' 100% Gas In Air=10,000 UnitsConnection Comments Surface Background Trip (max) Average 0 Mud (lb/bbl)ml/30min 8312'17 15 C-3 Lst 100 Hydrill 563 (lb/100ft2) 9.10 Type HAL PDC 68.0 Weight Siltst Chromatograph (ppm) C-4i Intermediate Cement C-1 C-5i C-4n C-5n 40.0 Casing Summary Lithology (%) 0.969 27 3681' 12.25"0.969 Footage Hours Ss Cht Silt 0 Sh 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg 24 Hour Progress: SPP (psi) POOH Hole Opener 11-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 4.23 @ 96% TuffGvl Cor Solids Alkal Coal Gallons/stroke L-80 15 160 Brine. No issues to report. Continue to monitor pits and flow in system. Minimum Depth 13 3/8" Maximum in (current) Depth Units* Clyst C-2 Gas Summary 907-685-0772Unit Phone: Paul Kalenuik Set AtSize 178.9 X-65 Grade Depth in / out L-8015740' Bit Type RPM 24062' 177 160 15750' 9223' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Rebecca Mulkey (max)(current) BTC Cly #4 Smith PDC 8.75 0.902 61.50 15750' . . * 24 hr Recap: #4 Smith PDC 8.75 0.902 61.50 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Rebecca Mulkey (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 24062' 177 160 15750' 9223' 907-685-0772Unit Phone:Paul Kalenuik Set AtSize 178.9 X-65 Grade C-2 Gas Summary Depth Units* Clyst Minimum Depth 13 3/8" Maximum in (current) R/U Volant tool & GBR liner equip. C/O equip. PJSM. RIH 4.5" liner to 8472'. Rig down Volant tool & bail extensions. C/O handling Alkal Coal Gallons/stroke L-80 15 160 4.23 @ 96% TuffGvl Cor Solids 12-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) C/O Handling Equip 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg Ss Cht Silt 0 Sh Casing Summary Lithology (%) 0.969 27 3681' 12.25"0.969 Footage Hours Intermediate Cement C-1 C-5iC-4n C-5n 40.0 68.0 Weight Siltst Chromatograph (ppm) C-4i Lst 100 Hydrill 563 (lb/100ft2) 9.10 Type HAL PDC Mud (lb/bbl)ml/30min 91000.00 8312'17 15 C-3 Average 0Trip (max) Comments Surface Background equip to 5". Daily Brine loss: 78 bbls. Total Brine loss: 90 bbls. 2834' 100% Gas In Air=10,000 UnitsConnection Bit # #2 12.25"2846' 1-1-WT-A-X-IN-NO-TD #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Brine ECD (ppg) N/A Ratio Mud Data Depth YP 24062' to Mud Type API FL Min Max Oil / Water PV cP ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Morning Report Report # 37 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 ROP ROP (ft/hr) J. Keener/R.Wimmer 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM % Lime 4-3-BT-A-X-IN-CT-TD Continue POH w/BHA #6. C/O f/5" to 4.5" handling equip. POH. L/D BHA #6. Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: #4 Smith PDC 8.75 0.902 61.50 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 24062' 177 160 15750' 9223' 907-685-0772Unit Phone: Paul Kalenuik Set AtSize 178.9 X-65 Grade C-2 Gas Summary Depth Units* Clyst Minimum Depth 13 3/8" Maximum in (current) 5 bpm & 330 psi. RIH w/5" DP f/8,613' to 15,700'. Circ at 9-5/8" shoe @ 5 bpm & 400 psi. RIH to 19,629' MD. Alkal Coal Gallons/stroke L-80 15 160 4.23 @ 96% TuffGvl Cor Solids 13-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) L/D 5" DP 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg Ss Cht Silt 0 Sh Casing Summary Lithology (%) 0.969 27 3681' 12.25"0.969 Footage Hours Intermediate Cement C-1 C-5i C-4n C-5n 40.0 68.0 Weight Siltst Chromatograph (ppm) C-4i Lst 100 Hydrill 563 (lb/100ft2) 9.10 Type HAL PDC Mud (lb/bbl)ml/30min 91000.00 8312'17 15 C-3 Average 0Trip (max) Comments Surface Background Rot. in hole to 24,062' 30 rpm. RIH loss: 16 bbls. P/U string 10'. Pump 1-5/8" ball. Set packer & test. OK 2834' 100% Gas In Air=10,000 UnitsConnection Blow down top drive. L/D 5" DP to 11,825'. No Trip loss. Bit # #2 12.25"2846' 1-1-WT-A-X-IN-NO-TD #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Brine ECD (ppg) N/A Ratio Mud Data Depth YP 24062' to Mud Type API FL Min Max Oil / Water PV cP ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Morning Report Report # 38 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 ROP ROP (ft/hr) J. Keener/R.Wimmer 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM % Lime 4-3-BT-A-X-IN-CT-TD C/O handling equip to 5" & clear floor. R/U GBR tongs. M/U packer. PalMix & let set 30 min. P/U 3 jts 5" DP. Circ Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: #4 Smith PDC 8.75 0.902 61.50 15750' Report By: 20.00'' 9 5/8" Logging Engineers:Paul Kalenuik/Kori Plowman (max)(current) BTC Cly Depth in / out L-8015740' Bit Type RPM 24062' 177 160 15750' 9223' 907-685-0772Unit Phone: Paul Kalenuik Set AtSize 178.9 X-65 Grade C-2 Gas Summary Depth Units* Clyst Minimum Depth 13 3/8" Maximum in (current) Monitor well. Fluid slightly falling. L/D 4.5" DP to 2,853'. Static loss rate 2 bph. PM tour loss: 29 bbls. Daily Brine loss: 56 bbls Alkal Coal Gallons/stroke L-80 15 160 4.23 @ 96% TuffGvl Cor Solids 14-Dec-2014 Tools 24062 24062' 0' Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) L/D 4.5" DP 0.0 Flow In (spm) MWD Summary Date: Time: Current Pump & Flow Data: Avg Ss Cht Silt 0 Sh Casing Summary Lithology (%) 0.969 27 3681' 12.25"0.969 Footage Hours Intermediate Cement C-1 C-5i C-4n C-5n 40.0 68.0 Weight Siltst Chromatograph (ppm) C-4i Lst 100 Hydrill 563 (lb/100ft2) 9.10 Type HAL PDC Mud (lb/bbl)ml/30min 91000.00 8312'17 15 C-3 Average 0Trip (max) Comments Surface Background 2834' 100% Gas In Air=10,000 UnitsConnection Bit # #2 12.25"2846' 1-1-WT-A-X-IN-NO-TD #3 6527' 74.80 57.20 Size 160'ConductorWeld 6527' WOB Hycalog PDC TFA Condition 8-2-RO-N-X-1-CT-PR Brine ECD (ppg) N/A Ratio Mud Data Depth YP 24062' to Mud Type API FL Min Max Oil / Water PV cP ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Avg Morning Report Report # 39 Customer: Well: Area: Location: Rig: SI26-NW2 DOYON15 Report For: AK-AM-0901822325 ROP ROP (ft/hr) J. Keener/R.Wimmer 24 hr Max Current Max @ ft Flow In (gpm) 12:00 AM % Lime 4-3-BT-A-X-IN-CT-TD Pull test plug & set wear ring.L/D 1 std 5" DP. C/O to 4.5" handling equip. RIH w/mule shoe, X/O & 4.5" DP to 4,744'. Density (ppg) out (sec/qt) Viscosity WELL INFORMATION Created On : Jan 06 2015 Customer :Eni Petroleum Well Name :SI26-NW2 Job Number :-XX-0901822325 Rig Name :Doyon 15 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') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 40.62 0.00 0.00 40.62 0.00 N 0.00 E 0.00 0.00 120.87 0.25 323.39 120.87 0.14 N 0.10 W 0.16 0.31 163.75 0.26 293.11 163.75 0.25 N 0.25 W 0.34 0.31 196.14 0.19 319.95 196.14 0.32 N 0.35 W 0.46 0.38 227.47 0.20 288.97 227.47 0.38 N 0.44 W 0.56 0.33 256.48 0.24 283.74 256.48 0.41 N 0.54 W 0.67 0.15 287.95 0.42 285.08 287.95 0.46 N 0.72 W 0.85 0.57 318.60 0.52 282.83 318.60 0.52 N 0.96 W 1.09 0.33 362.48 1.00 281.88 362.47 0.64 N 1.53 W 1.66 1.09 393.40 1.24 282.68 393.39 0.77 N 2.12 W 2.24 0.78 425.63 1.49 282.13 425.61 0.93 N 2.87 W 2.98 0.78 455.21 1.74 282.02 455.18 1.11 N 3.69 W 3.79 0.85 487.47 2.31 286.13 487.42 1.39 N 4.79 W 4.90 1.82 518.51 2.67 288.84 518.43 1.80 N 6.08 W 6.23 1.22 548.09 2.84 285.30 547.97 2.21 N 7.44 W 7.63 0.81 582.43 2.69 284.00 582.27 2.63 N 9.04 W 9.25 0.47 612.15 3.14 286.90 611.95 3.04 N 10.49 W 10.73 1.59 640.97 3.79 290.86 640.72 3.61 N 12.14 W 12.46 2.40 675.18 4.95 284.27 674.83 4.37 N 14.63 W 15.02 3.69 734.20 7.23 285.98 733.51 6.02 N 20.66 W 21.16 3.87 827.57 11.13 286.12 825.67 10.15 N 34.98 W 35.79 4.18 884.79 13.41 284.92 881.58 13.39 N 46.69 W 47.71 4.01 978.05 17.13 289.59 971.54 20.78 N 70.09 W 71.92 4.20 1071.36 20.96 290.15 1,059.72 31.14 N 98.72 W 102.14 4.11 1164.81 23.76 290.87 1,146.14 43.61 N 132.01 W 137.47 3.01 1258.28 24.02 287.88 1,231.60 56.16 N 167.71 W 174.99 1.32 1351.64 28.64 287.39 1,315.25 68.68 N 207.16 W 215.85 4.95 1444.90 28.53 287.33 1,397.15 82.00 N 249.75 W 259.86 0.12 1538.29 28.41 282.81 1,479.25 93.57 N 292.71 W 303.41 2.31 INSITE V8.1.10 Page 1Job No:-XX-0901822325 Well Name:SI26-NW2 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 1631.70 30.03 281.19 1,560.77 103.03 N 337.31 W 347.47 1.93 1725.06 29.34 281.30 1,641.88 112.05 N 382.66 W 392.00 0.74 1818.48 28.64 280.86 1,723.60 120.75 N 427.09 W 435.57 0.78 1911.75 32.89 280.58 1,803.72 129.62 N 473.96 W 481.39 4.56 2005.14 36.28 281.07 1,880.60 139.58 N 526.02 W 532.33 3.64 2098.56 36.51 281.19 1,955.79 150.28 N 580.40 W 585.68 0.26 2191.89 39.00 281.39 2,029.58 161.47 N 636.44 W 640.73 2.67 2285.19 40.22 282.58 2,101.46 173.83 N 694.62 W 698.22 1.54 2378.66 45.27 283.55 2,170.08 188.19 N 756.39 W 759.81 5.45 2472.01 50.63 283.24 2,232.58 204.23 N 823.80 W 827.20 5.75 2565.22 52.25 284.60 2,290.68 221.78 N 894.54 W 898.23 2.08 2658.58 54.05 285.55 2,346.67 241.21 N 966.67 W 971.36 2.09 2757.79 55.36 285.21 2,403.99 262.69 N 1,044.74 W 1050.71 1.35 2857.15 58.38 285.82 2,458.29 284.95 N 1,124.91 W 1132.29 3.08 2916.94 60.15 286.17 2,488.84 299.11 N 1,174.31 W 1182.76 3.00 3010.34 63.89 285.94 2,532.66 321.91 N 1,253.56 W 1263.76 4.01 3103.63 67.63 286.08 2,570.95 345.37 N 1,335.31 W 1347.29 4.01 3196.98 70.84 286.00 2,604.04 369.49 N 1,419.19 W 1433.01 3.44 3290.35 74.66 285.77 2,631.73 393.89 N 1,504.94 W 1520.54 4.10 3383.85 78.65 285.36 2,653.30 418.29 N 1,592.56 W 1609.73 4.29 3477.19 83.14 286.28 2,668.07 443.41 N 1,681.21 W 1700.17 4.91 3570.49 87.20 288.20 2,675.92 470.97 N 1,769.97 W 1791.80 4.81 3663.69 88.47 288.46 2,679.44 500.25 N 1,858.38 W 1883.91 1.39 3757.09 89.77 288.77 2,680.88 530.06 N 1,946.88 W 1976.33 1.43 3850.47 89.50 288.99 2,681.47 560.28 N 2,035.23 W 2068.80 0.37 3943.90 88.98 288.35 2,682.71 590.19 N 2,123.74 W 2161.27 0.88 4037.38 89.21 287.67 2,684.19 619.08 N 2,212.63 W 2253.62 0.77 4130.77 89.46 287.40 2,685.27 647.22 N 2,301.67 W 2345.77 0.39 4224.16 88.93 287.41 2,686.59 675.15 N 2,390.78 W 2437.89 0.57 4317.54 89.86 288.41 2,687.57 703.87 N 2,479.62 W 2530.12 1.46 4410.79 89.12 288.71 2,688.40 733.55 N 2,568.02 W 2622.39 0.86 4504.09 89.27 288.38 2,689.71 763.22 N 2,656.47 W 2714.70 0.39 4597.24 89.23 288.84 2,690.93 792.94 N 2,744.74 W 2806.88 0.50 4690.47 89.27 287.77 2,692.15 822.22 N 2,833.24 W 2899.06 1.15 4783.83 89.16 287.60 2,693.43 850.58 N 2,922.18 W 2991.22 0.22 4877.27 88.72 286.68 2,695.16 878.11 N 3,011.46 W 3083.30 1.09 4970.64 89.25 286.97 2,696.81 905.13 N 3,100.81 W 3175.23 0.65 5064.53 89.20 287.62 2,698.08 933.04 N 3,190.45 W 3267.80 0.69 5157.26 89.42 286.47 2,699.20 960.22 N 3,279.10 W 3359.17 1.26 5250.64 89.31 285.59 2,700.24 986.00 N 3,368.84 W 3450.88 0.95 5343.96 89.42 284.87 2,701.27 1,010.52 N 3,458.88 W 3542.27 0.78 5437.03 89.19 284.83 2,702.40 1,034.37 N 3,548.83 W 3633.30 0.25 5530.33 89.53 285.65 2,703.44 1,058.89 N 3,638.85 W 3724.68 0.95 5623.66 89.49 286.31 2,704.24 1,084.58 N 3,728.57 W 3816.33 0.71 5717.11 89.58 286.69 2,705.00 1,111.12 N 3,818.16 W 3908.25 0.42 INSITE V8.1.10 Page 2Job No:-XX-0901822325 Well Name:SI26-NW2 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 5810.53 90.39 287.73 2,705.02 1,138.76 N 3,907.40 W 4000.35 1.41 5903.95 90.06 288.02 2,704.66 1,167.44 N 3,996.31 W 4092.62 0.47 5997.33 88.98 288.80 2,705.44 1,196.93 N 4,084.90 W 4184.98 1.43 6090.71 89.49 289.72 2,706.68 1,227.73 N 4,173.05 W 4277.53 1.13 6184.04 88.17 288.68 2,708.59 1,258.41 N 4,261.17 W 4370.01 1.80 6277.34 87.82 289.39 2,711.85 1,288.82 N 4,349.31 W 4462.38 0.85 6370.67 86.84 289.03 2,716.20 1,319.50 N 4,437.35 W 4554.78 1.12 6464.58 86.50 289.41 2,721.66 1,350.36 N 4,525.87 W 4647.70 0.54 6557.43 85.53 287.97 2,728.11 1,380.04 N 4,613.61 W 4739.38 1.87 6650.78 86.44 285.73 2,734.65 1,407.03 N 4,702.73 W 4831.08 2.58 6744.99 87.92 284.57 2,739.28 1,431.62 N 4,793.55 W 4923.21 2.00 6837.78 88.66 285.19 2,742.05 1,455.44 N 4,883.18 W 5013.94 1.04 6930.86 88.77 285.27 2,744.14 1,479.88 N 4,972.97 W 5105.08 0.15 7024.62 89.00 285.55 2,745.96 1,504.79 N 5,063.35 W 5196.96 0.39 7117.75 89.41 285.57 2,747.26 1,529.77 N 5,153.05 W 5288.28 0.44 7211.16 88.79 285.60 2,748.72 1,554.86 N 5,243.02 W 5379.87 0.66 7304.52 88.64 286.31 2,750.82 1,580.52 N 5,332.76 W 5471.52 0.78 7397.92 88.33 285.84 2,753.29 1,606.37 N 5,422.47 W 5563.24 0.60 7491.35 88.50 286.25 2,755.87 1,632.19 N 5,512.23 W 5654.98 0.47 7584.71 89.22 286.09 2,757.73 1,658.18 N 5,601.88 W 5746.70 0.79 7678.13 88.77 286.48 2,759.37 1,684.37 N 5,691.54 W 5838.52 0.64 7771.55 88.62 286.09 2,761.49 1,710.56 N 5,781.18 W 5930.32 0.45 7864.81 89.02 286.24 2,763.41 1,736.52 N 5,870.74 W 6021.94 0.46 7958.23 88.21 286.79 2,765.67 1,763.07 N 5,960.28 W 6113.82 1.05 8051.56 89.10 286.96 2,767.86 1,790.15 N 6,049.56 W 6205.71 0.97 8144.90 88.86 286.73 2,769.52 1,817.20 N 6,138.88 W 6297.61 0.36 8238.22 88.79 286.88 2,771.44 1,844.17 N 6,228.20 W 6389.48 0.18 8331.61 88.39 286.30 2,773.74 1,870.83 N 6,317.67 W 6481.34 0.75 8425.47 88.40 286.29 2,776.36 1,897.15 N 6,407.73 W 6573.58 0.02 8517.84 89.32 286.34 2,778.20 1,923.10 N 6,496.36 W 6664.37 1.00 8611.17 88.64 285.31 2,779.86 1,948.54 N 6,586.14 W 6755.96 1.32 8705.17 88.66 284.83 2,782.08 1,972.98 N 6,676.88 W 6847.95 0.51 8798.04 88.61 285.37 2,784.29 1,997.16 N 6,766.52 W 6938.84 0.58 8891.39 89.36 284.39 2,785.94 2,021.13 N 6,856.72 W 7030.14 1.32 8984.48 89.77 285.91 2,786.65 2,045.46 N 6,946.57 W 7121.29 1.69 9077.75 88.77 286.73 2,787.84 2,071.66 N 7,036.07 W 7212.98 1.39 9171.40 88.76 287.89 2,789.86 2,099.52 N 7,125.46 W 7305.31 1.24 9265.41 88.45 286.72 2,792.15 2,127.48 N 7,215.18 W 7397.98 1.29 9357.78 88.40 286.40 2,794.69 2,153.79 N 7,303.69 W 7488.83 0.35 9451.18 88.48 286.33 2,797.23 2,180.10 N 7,393.27 W 7580.63 0.11 9544.63 88.18 285.48 2,799.95 2,205.70 N 7,483.11 W 7672.34 0.96 9637.05 87.84 286.54 2,803.16 2,231.17 N 7,571.89 W 7763.05 1.20 9731.49 88.24 286.12 2,806.39 2,257.71 N 7,662.46 W 7855.85 0.61 9824.89 88.45 285.78 2,809.09 2,283.36 N 7,752.23 W 7947.52 0.43 9918.36 89.00 285.69 2,811.17 2,308.71 N 7,842.17 W 8039.21 0.60 INSITE V8.1.10 Page 3Job No:-XX-0901822325 Well Name:SI26-NW2 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10011.63 88.80 285.77 2,812.96 2,333.99 N 7,931.93 W 8130.71 0.23 10104.84 88.80 286.56 2,814.91 2,359.93 N 8,021.44 W 8222.28 0.85 10198.12 88.99 286.73 2,816.71 2,386.65 N 8,110.79 W 8314.06 0.27 10291.48 88.88 286.60 2,818.45 2,413.41 N 8,200.22 W 8405.93 0.18 10384.72 89.12 287.07 2,820.07 2,440.41 N 8,289.45 W 8497.74 0.57 10478.18 88.53 287.16 2,821.99 2,467.91 N 8,378.75 W 8589.83 0.64 10571.59 89.51 287.52 2,823.59 2,495.75 N 8,467.90 W 8681.94 1.12 10664.95 89.12 289.31 2,824.70 2,525.24 N 8,556.47 W 8774.27 1.96 10758.17 88.72 288.98 2,826.46 2,555.80 N 8,644.52 W 8866.63 0.56 10851.67 88.12 288.27 2,829.04 2,585.65 N 8,733.09 W 8959.13 0.99 10944.95 88.36 287.33 2,831.90 2,614.15 N 8,821.86 W 9051.20 1.04 11037.79 88.13 286.27 2,834.75 2,640.97 N 8,910.69 W 9142.57 1.17 11131.55 87.63 285.26 2,838.22 2,666.43 N 9,000.86 W 9234.51 1.20 11224.79 88.85 284.91 2,841.08 2,690.68 N 9,090.85 W 9325.75 1.36 11318.11 88.82 284.76 2,842.98 2,714.57 N 9,181.04 W 9417.00 0.16 11411.46 88.54 284.66 2,845.13 2,738.27 N 9,271.30 W 9508.24 0.32 11504.74 88.46 284.94 2,847.57 2,762.09 N 9,361.46 W 9599.43 0.31 11598.12 88.54 285.91 2,850.01 2,786.92 N 9,451.44 W 9690.92 1.04 11691.48 88.12 285.82 2,852.73 2,812.43 N 9,541.21 W 9782.53 0.46 11784.80 88.46 286.09 2,855.52 2,838.07 N 9,630.89 W 9874.12 0.47 11878.16 87.99 288.44 2,858.41 2,865.76 N 9,720.00 W 9966.12 2.57 11971.45 88.20 289.05 2,861.51 2,895.73 N 9,808.29 W 10058.43 0.69 12064.81 85.97 289.15 2,866.26 2,926.23 N 9,896.39 W 10150.81 2.39 12158.23 83.67 289.18 2,874.69 2,956.77 N 9,984.26 W 10243.00 2.46 12251.65 83.03 288.88 2,885.51 2,987.03 N 10,071.98 W 10334.93 0.76 12344.88 81.93 288.74 2,897.71 3,016.83 N 10,159.47 W 10426.44 1.19 12438.23 80.42 289.13 2,912.03 3,046.76 N 10,246.73 W 10517.80 1.67 12531.44 77.60 288.80 2,929.80 3,076.50 N 10,333.25 W 10608.43 3.05 12624.79 75.97 288.52 2,951.14 3,105.57 N 10,419.35 W 10698.38 1.77 12718.12 74.40 287.77 2,975.01 3,133.67 N 10,505.08 W 10787.56 1.85 12811.55 72.92 287.88 3,001.29 3,161.12 N 10,590.43 W 10876.10 1.59 12904.95 72.24 288.27 3,029.25 3,188.77 N 10,675.15 W 10964.17 0.83 12998.39 69.35 289.27 3,059.99 3,217.15 N 10,758.69 W 11051.52 3.25 13091.80 67.01 290.53 3,094.70 3,246.66 N 10,840.23 W 11137.59 2.80 13186.01 67.22 291.09 3,131.34 3,277.49 N 10,921.36 W 11223.90 0.59 13278.46 67.43 291.96 3,166.98 3,308.79 N 11,000.71 W 11308.83 0.90 13371.56 67.08 292.67 3,202.98 3,341.39 N 11,080.14 W 11394.42 0.80 13464.85 67.00 292.82 3,239.37 3,374.60 N 11,159.36 W 11480.10 0.17 13559.03 68.09 292.93 3,275.34 3,408.43 N 11,239.55 W 11566.93 1.16 13651.65 70.09 293.70 3,308.40 3,442.68 N 11,319.00 W 11653.28 2.29 13745.47 70.02 294.42 3,340.40 3,478.63 N 11,399.53 W 11741.36 0.73 13838.42 70.92 295.21 3,371.47 3,515.40 N 11,479.04 W 11828.91 1.26 13932.27 71.28 295.49 3,401.87 3,553.42 N 11,559.28 W 11917.67 0.48 14025.28 72.07 296.64 3,431.12 3,592.21 N 11,638.59 W 12005.95 1.45 14118.64 74.09 296.49 3,458.29 3,632.15 N 11,718.48 W 12095.26 2.17 INSITE V8.1.10 Page 4Job No:-XX-0901822325 Well Name:SI26-NW2 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14211.87 74.05 297.57 3,483.88 3,672.90 N 11,798.34 W 12184.91 1.11 14305.28 75.79 298.74 3,508.18 3,715.45 N 11,877.85 W 12275.08 2.22 14398.62 77.64 299.74 3,529.63 3,759.83 N 11,957.11 W 12365.83 2.24 14491.96 79.86 301.68 3,547.84 3,806.58 N 12,035.81 W 12457.16 3.13 14585.39 83.14 303.70 3,561.65 3,856.48 N 12,113.56 W 12549.07 4.11 14678.76 86.34 304.91 3,570.21 3,908.88 N 12,190.35 W 12641.25 3.66 14772.82 88.39 305.54 3,574.53 3,963.07 N 12,267.10 W 12734.21 2.28 14865.47 87.79 305.59 3,577.62 4,016.93 N 12,342.42 W 12825.74 0.65 14958.79 87.59 306.28 3,581.38 4,071.65 N 12,417.92 W 12917.81 0.77 15051.96 86.89 308.07 3,585.87 4,127.88 N 12,492.07 W 13009.37 2.06 15145.29 86.95 308.80 3,590.88 4,185.81 N 12,565.07 W 13100.67 0.78 15238.40 86.83 310.17 3,595.93 4,244.93 N 12,636.82 W 13191.39 1.47 15331.81 86.77 310.58 3,601.15 4,305.34 N 12,707.87 W 13282.07 0.44 15425.11 86.81 310.76 3,606.37 4,366.05 N 12,778.53 W 13372.53 0.20 15518.47 86.81 311.38 3,611.57 4,427.29 N 12,848.80 W 13462.89 0.66 15611.62 85.89 312.09 3,617.50 4,489.17 N 12,918.17 W 13552.74 1.25 15706.40 85.52 312.07 3,624.59 4,552.51 N 12,988.32 W 13643.94 0.39 15787.35 87.36 312.40 3,629.62 4,606.82 N 13,048.14 W 13721.83 2.31 15880.76 89.28 313.83 3,632.36 4,670.63 N 13,116.29 W 13811.47 2.56 15974.12 89.73 313.23 3,633.17 4,734.93 N 13,183.98 W 13900.90 0.80 16067.52 87.83 312.83 3,635.15 4,798.65 N 13,252.23 W 13990.58 2.08 16160.97 88.17 309.80 3,638.42 4,860.30 N 13,322.37 W 14081.00 3.26 16254.30 88.15 309.46 3,641.41 4,919.79 N 13,394.21 W 14171.98 0.36 16347.73 87.25 308.22 3,645.16 4,978.34 N 13,466.93 W 14263.30 1.64 16441.15 88.91 307.70 3,648.29 5,035.77 N 13,540.54 W 14354.92 1.86 16534.42 88.66 304.99 3,650.27 5,091.03 N 13,615.64 W 14446.88 2.92 16627.83 91.73 304.75 3,649.95 5,144.42 N 13,692.27 W 14539.37 3.30 16721.59 92.32 304.55 3,646.64 5,197.70 N 13,769.35 W 14632.20 0.66 16814.50 92.25 301.45 3,642.93 5,248.25 N 13,847.20 W 14724.50 3.33 16907.82 90.60 301.57 3,640.61 5,297.01 N 13,926.73 W 14817.48 1.77 17001.21 88.21 299.35 3,641.58 5,344.34 N 14,007.22 W 14910.67 3.49 17094.53 88.86 299.68 3,643.97 5,390.30 N 14,088.40 W 15003.85 0.78 17187.44 88.67 300.08 3,645.97 5,436.58 N 14,168.94 W 15096.61 0.48 17280.77 88.73 300.01 3,648.09 5,483.30 N 14,249.71 W 15189.77 0.10 17374.22 88.72 300.53 3,650.17 5,530.39 N 14,330.40 W 15283.04 0.56 17467.64 89.06 301.63 3,651.98 5,578.61 N 14,410.39 W 15376.18 1.23 17560.99 88.90 302.86 3,653.64 5,628.40 N 14,489.33 W 15469.10 1.33 17654.08 88.99 304.41 3,655.35 5,679.96 N 14,566.82 W 15561.53 1.67 17747.35 88.93 305.04 3,657.05 5,733.08 N 14,643.47 W 15653.90 0.68 17840.72 88.86 306.21 3,658.85 5,787.45 N 14,719.35 W 15746.16 1.26 17934.05 89.45 306.70 3,660.22 5,842.90 N 14,794.40 W 15838.18 0.82 18027.38 88.36 307.41 3,662.01 5,899.13 N 14,868.87 W 15930.02 1.39 18120.78 87.22 307.44 3,665.61 5,955.85 N 14,942.99 W 16021.76 1.22 18214.23 87.26 307.38 3,670.11 6,012.55 N 15,017.13 W 16113.53 0.08 18307.68 87.88 308.13 3,674.07 6,069.72 N 15,090.95 W 16205.21 1.04 INSITE V8.1.10 Page 5Job No:-XX-0901822325 Well Name:SI26-NW2 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 18401.90 88.06 307.37 3,677.41 6,127.36 N 15,165.40 W 16297.67 0.83 18494.49 88.73 307.84 3,680.00 6,183.84 N 15,238.72 W 16388.60 0.88 18588.51 89.33 308.01 3,681.59 6,241.62 N 15,312.88 W 16480.86 0.66 18681.23 88.74 307.09 3,683.16 6,298.12 N 15,386.38 W 16571.96 1.18 18775.02 89.32 305.93 3,684.74 6,353.91 N 15,461.75 W 16664.40 1.38 18867.72 89.30 304.35 3,685.86 6,407.26 N 15,537.55 W 16756.13 1.70 18961.08 90.79 304.79 3,685.79 6,460.23 N 15,614.42 W 16848.64 1.66 19054.32 91.10 306.11 3,684.25 6,514.30 N 15,690.36 W 16940.82 1.45 19147.78 84.84 305.57 3,687.56 6,568.97 N 15,766.04 W 17033.03 6.72 19241.12 89.39 305.06 3,692.26 6,622.84 N 15,842.09 W 17125.22 4.91 19334.55 92.74 306.12 3,690.52 6,677.20 N 15,918.04 W 17217.53 3.76 19427.77 94.45 307.33 3,684.67 6,732.83 N 15,992.61 W 17309.19 2.25 19521.27 96.48 308.46 3,675.77 6,789.99 N 16,066.05 W 17400.54 2.48 19614.55 97.33 309.49 3,664.55 6,848.23 N 16,138.04 W 17491.08 1.43 19707.67 99.50 310.03 3,650.93 6,907.14 N 16,208.85 W 17580.86 2.40 19801.15 97.09 312.36 3,637.44 6,968.06 N 16,278.44 W 17670.47 3.57 19894.39 97.50 312.04 3,625.60 7,030.19 N 16,346.96 W 17759.66 0.56 19987.71 97.90 312.18 3,613.10 7,092.20 N 16,415.56 W 17848.88 0.45 20081.02 93.06 311.30 3,604.19 7,154.02 N 16,484.85 W 17938.63 5.27 20174.34 88.03 310.33 3,603.30 7,214.99 N 16,555.45 W 18029.16 5.49 20267.72 87.14 310.23 3,607.24 7,275.31 N 16,626.63 W 18119.90 0.96 20361.08 86.87 310.48 3,612.11 7,335.68 N 16,697.67 W 18210.56 0.39 20454.39 89.25 311.17 3,615.27 7,396.64 N 16,768.24 W 18301.06 2.66 20547.76 90.22 313.48 3,615.71 7,459.50 N 16,837.26 W 18391.04 2.68 20641.05 89.85 314.09 3,615.65 7,524.05 N 16,904.61 W 18480.29 0.76 20734.41 90.58 314.06 3,615.30 7,588.99 N 16,971.68 W 18569.46 0.78 20827.83 90.29 313.74 3,614.59 7,653.77 N 17,039.00 W 18658.78 0.46 20921.25 90.48 313.83 3,613.96 7,718.41 N 17,106.44 W 18748.15 0.23 21014.48 90.23 313.64 3,613.38 7,782.86 N 17,173.80 W 18837.36 0.34 21107.83 90.61 313.18 3,612.70 7,847.01 N 17,241.61 W 18926.84 0.64 21201.04 90.09 312.52 3,612.13 7,910.40 N 17,309.95 W 19016.45 0.90 21294.39 85.93 311.74 3,615.37 7,972.97 N 17,379.12 W 19106.42 4.53 21387.72 88.61 311.92 3,619.82 8,035.14 N 17,448.58 W 19196.48 2.88 21481.15 90.33 311.87 3,620.68 8,097.52 N 17,518.12 W 19286.70 1.84 21574.55 90.84 313.45 3,619.73 8,160.81 N 17,586.80 W 19376.56 1.78 21667.99 90.17 313.11 3,618.90 8,224.86 N 17,654.82 W 19466.19 0.80 21761.40 90.44 314.26 3,618.41 8,289.38 N 17,722.37 W 19555.60 1.26 21854.75 89.86 314.51 3,618.16 8,354.67 N 17,789.08 W 19644.61 0.68 21948.06 89.98 315.02 3,618.29 8,420.38 N 17,855.33 W 19733.40 0.56 22041.16 89.12 314.19 3,619.02 8,485.76 N 17,921.61 W 19822.07 1.28 22134.45 88.84 313.09 3,620.68 8,550.13 N 17,989.11 W 19911.37 1.22 22227.88 88.91 312.28 3,622.52 8,613.46 N 18,057.78 W 20001.24 0.87 22321.25 88.70 311.55 3,624.47 8,675.82 N 18,127.24 W 20091.39 0.81 22414.63 88.47 311.55 3,626.77 8,737.73 N 18,197.10 W 20181.69 0.25 22508.02 88.35 311.26 3,629.36 8,799.47 N 18,267.12 W 20272.05 0.34 INSITE V8.1.10 Page 6Job No:-XX-0901822325 Well Name:SI26-NW2 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 22601.48 88.58 313.19 3,631.87 8,862.26 N 18,336.30 W 20362.13 2.08 22694.88 87.86 313.32 3,634.77 8,926.23 N 18,404.29 W 20451.69 0.78 22788.24 86.71 313.34 3,639.19 8,990.22 N 18,472.13 W 20541.12 1.23 22881.47 86.45 313.21 3,644.75 9,054.01 N 18,539.89 W 20630.39 0.31 22974.88 89.80 314.89 3,647.81 9,118.92 N 18,606.97 W 20719.56 4.01 23068.22 89.91 315.48 3,648.04 9,185.13 N 18,672.76 W 20808.17 0.64 23161.56 89.88 315.20 3,648.21 9,251.52 N 18,738.37 W 20896.70 0.30 23254.99 88.19 316.64 3,649.79 9,318.62 N 18,803.35 W 20984.98 2.38 23348.36 87.56 314.56 3,653.25 9,385.29 N 18,868.63 W 21073.34 2.33 23441.70 88.10 312.67 3,656.79 9,449.62 N 18,936.16 W 21162.65 2.10 23535.07 91.62 313.02 3,657.01 9,513.11 N 19,004.60 W 21252.39 3.79 23628.39 92.53 311.50 3,653.63 9,575.82 N 19,073.62 W 21342.30 1.90 23721.56 93.88 311.42 3,648.43 9,637.41 N 19,143.33 W 21432.32 1.45 23814.89 91.20 309.69 3,644.29 9,698.02 N 19,214.17 W 21522.89 3.42 23908.00 92.04 309.31 3,641.66 9,757.22 N 19,285.98 W 21613.71 0.99 24002.84 94.35 309.05 3,636.37 9,817.04 N 19,359.38 W 21706.22 2.45 24062.00 94.35 309.05 3,631.88 9,854.20 N 19,405.19 W 21763.88 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 296.86 degrees (True) - A total correction of 19.10 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 24,062.00 feet is 21,763.89 feet along 296.92 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:-XX-0901822325 Well Name:SI26-NW2 Survey Report